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Home My WebLink About207-003• • Image Project Well NiStary File Cover Page XNVZE 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 ~rganR-ng (done) RES N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o.,aea iuumiuuiiuu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ~~ Re,~a~Nee~ea Illllllll~lillllll OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOT!_:S: ^ Other.: BY: Maria Date: ~ ~.~ /s/ Project Proofing II I II II II () III I I III BY: aria Date: ~. ~ ~ ~ /s/ Scanning Preparation ~ x 30 = ~ + ~~~ =TOTAL PAGES__~~ f (Count does not include cover sheet) , n /) BY: Maria Date: J ~ ~ n 1 / ufi !sl ~ Y' Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ltJ ~7 /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I II ReScanned BY: Maria Date: /s/ Comments about this file: o~,~„~~«ea iuimiuuimiu 10!6/2005 Well History File Cover Page.doc i . ~ ~ ~s ~~~ ., 4 ~~ ~ t ,,, j ' ~ ^~ x MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2070030 Well Name/No. KUPARUK RIV UNIT 1C-01 L1-03 Operator CONOCOPHILLIPS ALASKA INC MD 10000 TVD 6515 Completion Date 1/9/2007 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No API No. 50-029-20526-63-00 UIC N Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, RES, GR Well Log Information: Log/ Electr Data Digital Dataset T~e Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ~'ED D Asc Directional Survey t Directional Survey D C Lis 14567 Gamma Ray ~'~~ ` 14567 LIS Verification +~Log 15467 Induction/Resistivity slog 15467 Induction/Resistivity 8325 10000 Open 1/24/2007 Disk in 1C-01 L1 (206-148) History 8325 10000 Open 1/24/2007 7190 10000 Open 10/2/2007 LIS Veri, GR, ROP w/TIF and Meta graphics 7190 10000 Open 10/2/2007 GR, ROP 25 Blu 7250 10000 Open 10/2/2007 MD Multi Prop Resisitivity, GR 7-Jan-2007 25 Blu 7250 10000 Open 10/2/2007 TVD Multi Prop Resisitivity, GR 7-Jan-2007 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /® Chips Received? '~/T~~ Analysis `~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2070030 Well Name/No. KUPARUK RIV UNIT 1C-01 L1-03 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20526-63-00 MD 10000 TVD Compliance Reviewed By: 6515 ompletion Date 1/9/2007 ___ _ _ _ ___ _______ __ Completion Status 1-OIL Current Status 1-OIL ~) Date: ~'~ ! Va~/ UIC N ~~ Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1 C-01L 1-03 • r~tr BAKER HUGHES Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 bluelines - MPR-DIR_md Log 1 bluelines - MPR-DIR tvd Log av°~-~~ ~1~~~~ LAC Job#: 1303032 Sent By: De ~ ~-~ ~.„ Date: Sept.28, 2007 Received By: ~''~ ~; ~ J, Date: _ ~.., PLEASE ACKNOWLEDGE~RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~surrw a,romnrrut ..., ....__. ~t i ~ i ..>, .: _- ~l _ _._. =- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED FEB ,0 8 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LO~aska Oi! & Gas Cons. Corrrmission Anchorage 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 1/9/2007 12. Permit to Drill Number 207-003 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/1/2007 13. API Number S0-029-20526-63-00 4a. Location of Well (Governmental Section): Surface: ' ' ' 7. Date T.D. Reached 1/7/2007 • 14. Well Name and Number: Ku aruk 1C-01L1-03 1718 FNL, 1364 FWL, SEC. 12, T11 N, R10E, UM Top of Productive Horizon: 1965' FNL, 1305' FEL, SEC. 12, T11 N, R10E, UM 8. KB Elevation (ft): 94 ' 15. Field /Pool(s): Kuparuk River Unit I Kuparuk Total Depth: 3551' FNL, 372' FEL, SEC. 12, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 10000 + 6515 Ft River Pool . 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562372 - y- 5968523 ~ Zone- ASP4 10. Total Depth (MD+TVD) ~ 10000 + 6515 Ft 16. Property Designation: ADL 025649 • TPI: x- 564985 y- 5968297 Zone- ASP4 Total Depth: x- 565932 y- 5966719 Zone- ASP4 11. Depth where SSSV set 2041' MD 17. Land Use Permit; 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1650' (Approx.) 21. Logs Run: MWD DIR, RES, GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD' SETTING D EPTH ND HOLE AMOUNT SIZE WT. PER: FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2-3/8" 4.4# L-80 7763' 6565' 9933' 6515' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and `24: TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section See 1 C-01 L1-02 MD TVD MD TVD 7932' - 8594' 6552' - 6522' Well Branch Well Branch 8634' - 9899' 6520' - 6513' 1 C-01 L1-03 1 C-01 L1-03 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From Is not Directly DEPTH INTERVAL MD AMOUNT Sc KIND OF MATERIAL USED Well Branch Accessible 1 C 01 L1 02 - - , PTD #207-002, at 7751' MD 6 ' T D ( V ) 566 26. PRODUCTION TEST Date First Production: Reported on 1 C-01 L1-02 Method of Operation (Flowing, Gas Lift, etc.): See 1 C-01 L1-02 10-407 (Dated 02-08-07, PTD 207-002) for Production & Test Data Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HDUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or watBl~~ Sg}parate sheet, if necessary). Submit core chips; if none, state "none". ) ;'~I~i_~i108 ~.,' 1~~~ ~~ rt~. None ^ r ~s :1 ~ ti~tl,~ /•• 07 11:;~1r-'I0 ' Form 10-407 Revised 12/2003 CRIC-INAL CONTINUED ON REVERSE SIDE .,e~ a i • r2 • ~ ~-ia~~ -~~iy~J 28. GEOLOGIC MARKE 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". (From 1 C01 L1-01) None ~, Top C2 /Base C3 (Inverted) 8060' 6546' (From 1C-01 L1-03) .. Top C3 /Base C4 (Inverted) 8664' 6519' Base C4 /Top C3 9320' 6505' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~ d vV Signed Terrie Hubble Title Technical Assistant Date ~ Kuparuk 1C-01L1-03 207-003 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Aras Worthington, 564-4102 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 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. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ ~ i_ I', BP AMERICA Page 1 of 30 ' Operations Summary Report Legal Well Name: 1 C-01 .Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 'Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations - - - - ~~ 12/5/2006 00:00 - 03:00 3.00 MOB P PRE RD off of 1 C-25. SLB changing blocks to 2-3/8" 03:00 - 03:30 0.50 MOB P PRE Held PJSM on moving off of well. identified the hazards and determined personels work place II 03:30 - 05:00 1.50 MOB P PRE Move off well and position to conduct pad prep wit Drilling Tool House 05:00 - 18:00 13.00 RIGU P PRE Change out BOP's rams, swapped out annular and prep pad i for rig Insatlled hericulit in cellar area. Held PJSM on back t over well. CPAI Drilling Safety HSE Rep attended. Moved rig over well and set down, NU BOP's RIG ACCEPTED 11:00 hrs 12/6/2006 18:00 - 00:00 6.00 BOPSU P PRE BOP test witness waived by AOGCC's Jeff Jones. Pressure test BOP equipment. SIMOPS: Remove 2" reel. Move rig camp a few feet down pad to allow reel track access. Lift 2-3/8" reel into position. Install reel hardline. Continue with BOP test. Get good body test. Choke valve leaking. Grease same. Door seal leaking. Replace same. Lower 2-3/8" combis leaking. Open rams and replace same. Still leaking. 12/6/2006 00:00 - 05:00 5.00 BOPSU P PRE Continue with BOP equipment test. Lower 2-3/8" rams still leaking. Try a different test joint. Continue with remainding tests. 05:00 - 11:00 6.00 BOPSU N RREP PRE Held Weekly Safety Meeting with Nigt crew. Covered Stop Cards HSE alerts and watch the Hand Safety video. Testing choke HCR, changing 3" pipe slips to 2" pipe slip to test the variables. Pulled bottom door and remove loer 2-3/8" combi's for visual inspection. Changed out the lower 2-3/8" combi's and PT as per AOGCC Some problem with the guide on the 2-3/8" ram blocks. 11:00 - 13:00 2.00 BOPSU P PRE Held Pre Spud Meeting with Day crew on 1 C-01 CTD and PJSM on pulling the CT across the pipe shed and heading up. Pad Operator with assistance from us installed the ESD for well 1 C-27 (Driller side flowing well) The ESD will be controlled from the Nordic's Driller platform. 13:00 - 15:15 225 RIGU P PRE RU and pull 2-3/8" CT across the pipe shed roof and into the injector head. 15:15 - 16:30 1.25 RIGU P PRE Load CT with 2ppb Biozan. Having trouble with Nordic's in micro motion, trobleshoot same . Loaded CT with 60 bbl of 2ppb biozan 16:30 - 18:15 1.75 RIGU P PRE RU to reverse cir CT for slack management 18:15 - 20:00 1.75 BOPSU P PRE Hold PJSM. PU lubricator. Remove BPV from well. RD and LD lubricator. 20:00 - 20:30 0.50 KILL P WEXIT Hold PJSM with night crew in Ops cab. j 20:30 - 21:30 1.00 KILL P WEXIT MU a-coil head. Test same. 21:30 - 22:45 1.25 KILL P WEXIT MU nozzle BHA assembly. Stab coil. Get on well Close choke and open master & swab valves to test SSSV. No WHP. 22:45 - 23:15 0.50 KILL P WEXIT Run in hole to 1950'. 23:15 - 00:00 0.75 KILL P WEXIT Circulate out diesel to tiger tank. Repair leaking hardline in reel. Continue to circulate. .12/7/2006 00:00 - 02:00 2.00 KILL P WEXIT Circulate bio at 950 psi 2.0 in/1.54 out with 475 psi WHP. Get gas and crude back. Circulate 1.5 annular volume. Still getting gas back with some crude.l Printed: 1/16/2007 70:32:30 AM ~ ~ BP AMERICA Page 2 of 30 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date a Name: 1 ell Name: 1 e: R Name: N From - To C-01 C-01 EENTE ORDIC NORDIC Hours R+COM CALIST 2 ...:Task PLET A Code E NPT 12/7/2006 02:00 - 03:00 1.00 KILL P 03:00 - 04:00 1.00 KILL P 04:00 - 05:00 1.00 KILL P 05:00 - 09:50 4.83 WHIP P 09:50 - 10:00 0.17 WHIP P 10:00 - 10:50 0.83 WHIP P 10:50 - 13:00 2.17 WHIP P 13:00 - 13:45 0.75 WHIP P 13:45 - 15:35 1.83 WHIP P 15:35-17:15 1.67 STWHIP P 17:15-19:00 1.75 STWHIP P 19:00 - 19:45 0.75 STWHIP P 19:45 - 20:15 0.50 KILL P 20:15 - 00:00 3.75 STWHIP P 12/8/2006 00:00 - 04:30 4.50 STW H I P P 04:30 - 07:00 2.50 STWHIP P 07:00 - 08:35 1.58 STWHIP P 08:35 - 10:45 2.17 STWHIP P 10:45 - 12:20 1.58 DRILL P 12:20 - 13:00 0.67 DRILL P Spud Date: 12/5/2006 Start: ~ 12/5/2006 End: 1/9/2007 Rig Release: 1/9/2007 Rig Number: Phase Description of Operations WEXIT Line up and bullhead down coil annulus. 880 psi whp at 2.53 bpm. Pump 125 bbls. WEXIT Pull out of hole filling 1:1 down coil annulus. 0.9 bpm at 520 whp. Close sssv with 550 psi below. Flow check. Get a little gas. CBU. Flow check. Well stable. Continue to surface replacing voidage. Hold PJSM to discuss handling the BHA. WEXIT At surface. Flow check. Get off well. LD BHA. WEXIT RU BHI's BHA Ordered and wait on 3-Pip Tags. SLB during Safety Shut Down in Deadhorse WEXIT PJSM on handling WS, BHI's MWD and BOT setting tool WEXIT PU BOT WS, 80T setting tool and aligned as to HS TF. WEXIT RIH with EDC open to 1980 ft. Increased WHP to 350 psi and open SSSV. Increased Op to equal the out rate. RIH at 100 fpm at 1.00/1.31 bpm keeping WHP at 250 ps EDC. Diverted 20 bbl of oil to TT with bottoms up WEXIT Set BOT Gen II Whipstock at 7192.5 ft and the TOWS at 7175ft at 30degRHS at 3850 psi . Slacked off and POOH WEXIT SWI and open EDC. POOH maintaining flow at 1:1 holding 300 psi WHP. Getting some gas and oil to surface. Diverted 30 bbl's to tiger tank. Trapped 340 psi below SSSV. Checked flow. POOH cir at 1:1 WEXIT OOH, check flow, held PJSM. LD Whipstock setting BHA and PU window exit BHA with 3.74 / 3.72 mills. WEXIT RIH circulating at min rate. Open sssv. Continue in hole. 0.36 in/0.35 out. WEXIT Log gr tie in from 7080'. Subtract 11' correction. Circulate at 2.55 in. Getting 3.55 out. WEXIT Shut in well. Monitor WHP and BHP. Static WHP: 282 psi. BHP: 3087 psi/9.47 ECD. Come on line with pump. WHP: 70 psi. 2.55 in/3.45 out. ECD: 9.32 ppg. Well is obviously giving back fluid. Increase WHP to get 1:1 rtns. 170-180 psi w/ 9.50 ECD seems to work well. WEXIT Zero DHWOB. Tag whipstock pinch point at 7181'. Begin milling window. 2050 psi fs at 2.46 in/2.25 out. Run light to establish a mill patern. WHP: 185 psi. ECD: 9.53 ppg. PVT: 323 bbls. IA/OA:320/0. DHW06:2-3k#. WEXIT Continue milling window from 7185'. 2050 psi fs at 2.50 in/2.40 out. 100-200 dpsi. DHWOB: 2-3k#. WHP/BHP/ECD: 172/3155/9.56 ppg. IA/OA/PVT: 15/0/284 bbls. Continue to mill ahead smoothly. Lots of metal on magnets. Continue to lose about 0.2-0.3 bpm to formation. WEXIT Drill formation rathole. Reamed 3 times, clean dry tagged at 7200 ft WEXIT POOH with control BHP and closed SSSV and trapped 350 psi, Stopped at 200 ft, held PJSM and SD tool. PUH inspecting CT WEXIT LD Milling BHA and gauged Window mill at 3.72" no/go from 3.74" no/go. MU build section BHA with 3 deg bend motor and 3.72" Undergauage RWD 2ST324 BC Bit PROD1 RIH holding 200 to 250 psi WHP.Started mud swap at 5000 ft PROD1 Logged down tieing in. Subtracted 15 ft. SD pump and trapped 300 psi WHP and closed EDC. RIH and make ready Printed: 7/16/2007 70:32:30 AM L~ BP AMERICA Page 3 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 12/5/2006 Start: ~ 12/5/2006 End: 1 /9/2007 Rig Release: 1 /9/2007 Rig Number: Date -From - To 'Hours Task Code NPT ( Phase' Description of Operations 12/8/2006 12:20 - 13:00 0.67 DRILL P 13:00 - 15:15 2.25 DRILL P 15:15 - 16:30 I 1.251 DRILL I P 16:30 - 16:40 0.17 DRILL P 16:40 - 20:00 3.33 DRILL P 20:00 - 21:45 I 1.751 DRILL I P 21:45 - 22:45 1.00 DRILL P 12/9/2006 00:00 - 01:00 1.00 DRILL P 01:00 - 02:30 I 1.501 DRILL I P 02:30 - 03:00 0.50 DRILL P 03:00 - 07:00 4.00 DRILL P 07:00 - 09:00 2.00 DRILL P 09:00 - 10:00 1.00 DRILL P 10:00 - 11:45 1.75 DRILL P 11:45 - 12:10 0.42 DRILL P 12:10 - 12:25 0.25 DRILL 12:25 - 16:45 4.33 DRILL P PROD1 to drill build section PROD1 Drilling Build Section starting in C4 TF at 30R HS Using Prressure Management while drilling technique Op = 2.58 / 2.45 bpm CTP = 2400 PSI; WOB 1-2k ROP, 45-60 fph BHP = 3174psi ECD = 9.55 ppg WHP = 50 psi Vp= 260 bbl TOWS @ 7177 ft TOW @ 7181 Ft BOW @ 7190 ft RA Marker @ 7187 ft PROD1 Drilling Build Section starting in C4 TF at HS Op = 2.58 / 2.33 bpm CTP = 2400 PSI; WOB 1-3k ROP, 45-100 fph BHP = 3213psi ECD = 9.61 ppg WHP = 50 psi Vp= 255 bbl 1st good survey at 7,249 ft. ave DLS = 33 deg /100 ft. Presently need +43 deg BR's to land at 6,495 ft At 7336 ft DLS required will be +50 dge PROD1 Wiper trip at 7337 ft MD PROD1 Drilling Build Section starting in C4 TF at HS Op = 2.52 / 2.33 bpm CTP = 2465/2675 psi; WOB 1-3k ROP, 45-100 fph BHP = 3227psi ECD = 9.63 ppg WHP = 40 psi Vp= 415 bbl Added new flo-pro to system. Finish build then most of turn at 7455'. Est 96 deg inc and 155 deg azm at bit. Deepest TVD: 6507'. PROD1 W Iper trip back to window. Shut do pump to go through window. Open EDC. Circulate out of hole. Maintain 100 psi overbalance above 9.45 ppg BHP. 2.48 in/1.93 out at 100 fpm coil speed. Close SSSV. Continue to surface. PROD1 At surface. Get off well. PUII and LD BHA assembly. Bit 1-1. PROD1 Hold PJSM with crew in Ops Cab. MU lateral BHA assembly with USMPR resistivity tool. PROD1 Get on well. Run in hole. Open sssv. Continue in hole. Hold 170-180 psi WHP to allow 1:1 rtns. PROD1 Log gr tie in from 7080'. Subtract 14' correction. PROD1 Drill ahead from 7455'. 2200 psi fs at 2.46 in/2.37 out. 200-250 dpsi on mtr. Ct Wt: 13k#. DHWOB:1.5-2.5k#. WHP/BHP/ECD: 48/3257/9.63 ppg. IA/OA/PVT: 66/0/323 bbls. ROP: 40-60 fph. Unable to get turn rate with 1 deg AKO setting on motor PROD1 POOHTrapped 350 psi below SSSV at 2040 ft. Held PJSM on handling BHA. Meeting conducted by BHI DD trainee. PROD1 LD BHA and change AKO setting on motor to 1.5 deg, checked bit, cleaned out jets, changed out LOC. PU and RIH PROD1 RIH circulating at 1:1. PROD1 Tie-in at 7100 ft MD (RA Marker at 7186.8 ft) Substracted 15 ft PROD1 RIH PROD1 Drilling Trunk Lateral Section at 80-100R TF Printed: 7/162007 10:32:30 AM '~ BP AMERICA Page 4 of`30 Operations Summary Report Legal Well Name: 1C-01 'I Common Well Name: 1C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 ', Rig Name: NORDIC 2 Rig Number: ', Date ~i From - Ta Hours Task `Code NPT Phase I 12/9/2006 ~ 12:25 - 16:45 ~ 4.33 DRILL P PRODi 16:45 - 17:25 I 0.671 DRILL I P I I PROD1 17:25 - 19:30 I 2.081 DRILL I P I I PROD1 19:30 - 20:15 0.75 DRILL P PROD1 20:15 - 22:30 2.25 DRILL P PROD1 22:30 - 23:30 1.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 12/10/2006 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 03:15 0.75 DRILL P PROD1 03:15 - 03:45 0.50 DRILL P PROD1 03:45 - 04:30 0.75 DRILL P I PROD1 04:30 - 07:00 2.50 DRILL P PROD1 07:00 - 08:30 1.50 DRILL P PROD1 08:30 - 11:30 3.00 DRILL N WAIT PROD1 11:30 - 11:35 I 0.081 DRILL I P I I PROD1 11:35 - 12:15 0.67 DRILL P PROD1 12:15 - 12:40 0.42 DRILL P PROD1 Description of ..Operations Op = 2.50 / 2.28 bpm CTP = 2350 psi WOB 1-3k ROP, 25 60 fph BHP = 3260psi ECD = 9.67 ppg WHP=51psi Vp= 381 bbl Wiper trip. Talked to Schlumberger about using their Farr tongs setup for running 3-3116" tubing on this liner job. Drilling Trunk Lateral Section at 80-100R TF Op = 2.50 / 2.28 bpm CTP = 2350-2650 psi WOB 1-3k ROP, 25 45 fph BHP = 3260psi ECD = 9.67 ppg WHP = 51psi Vp= 409 bbl Wiper trip to window. Hole smooth. Drill ahead from 7850'. 2480 psi fs at 2.53 in/2.30 out. 200 dpsi. 30k# up wt. DHWOB: 3-4.5k#. WHP/BHP/ECD: 51/3292/9.8 ppg. IA/OA/PVT: 395/0/353 bbls. ROP: variabbe. 15 to 100 fph. Appear to drilling through formation changes. Wiper trip to tbg tail. Hole smooth. Log gr tie in from 7,080'. Add 4' correction. Drill ahead from 8,000'. 2250 psi fs at 2.45 in/2.35 out. 200-300 dpsi. DHWOB: 1-4k#. WHP/BHP/ECD: 48/3326/9.92 ppg. IA/OA/PVT: 117/21/276 bbls. Continue to build angle, to 94-95 deg inc. ROP variable, but mostly over 60 fph. Continue to look for the C3 sand and found It I Wiper trip to window. Hole smooth. log gr tie from 7080'. Add 2' correction. Wiper trip to TD. Start new flo pro down coil. Confirm td is 8160'. POOH laying in new flopro. Held PJSM and LLD BHA. RU to run liner Called CPAI for a crane to load Farr tongs in the pipe shed at 06:15 hrs. Was informed by Equipment Service Supervisor at 09:30 hrs that the crane will be here when it gets here and no sooner. Was told by the CPAI Wells Coordinator stand in that the Equipment supervisor didn't like all of the phone messages left on his machine and there was nothing he could do about it. Presently have waited 4 hrs at 4800 /hr. Called Veco Dispatch for a crane. Kupuark's crane showed up at 10:00 hrs and I was informed that they will install 1C-25 wellhouse before making any pick for me. Veco dispatch in Deadhorse is trucking Endicott's Crane from MPI to Kupuark. The reason a crane was needed is that Nordic does not have the correct slips to dress their tongs for running 3-3/16" liner. Nordic 2 had to get tongs from SLB and load them on to the rig. Spotted crane open cattle chute, loaded Farr tongs in pipe shed and close cattle shoot Prep tongs for 3-3/16' tubing Held PJSM and review the Liner running Procedure developed for CTD. Found faults and noted. Determined hazards and mitigated same. Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 5 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 12/10/2006 12:40 - 16:00 3.33 CASE P PROD1 Running 3-3/16" liner Filled 1/2 way in with liner. Lost rig power, restart 16:00 - 17:00 1.00 CASE P PROD1 PU jewerly at the top of the liner and the BHI MWD. Set counter to 1040.8 ft 17:00 - 19:15 2.25 CASE P PROD1 RIH slowly due to the seal in the top of the liner. Stop and subtract 15' correction before passing through window. Continue to run in hole. Perform weight check at 7900'. 36.5k# up, 14k# do wt. Land solid at 8047'. Bring on pumps to 1.5 bpm at 1765 psi. POH. CT up weight is now 28k#. 19:15 - 22:00 2.75 EVAL P PROD1 Pull up hole. Log gr down from 6,920'. -2' correction for a total correction of -17'. Tied in with OH gr log, liner top is 15' shallow. Inteq CCL not working. Cannot tie in to tbg jewelry. Discuss plan forward with town. Decide to rig up slickline. POOH with coil. 22:00 - 22:45 0.75 EVAL P PROD1 Hold PJSM with Hallib. and Nordic. Spot slickline unit. Bring lubricator in through pipe shed. Continue to POH with GS BHA. 22:45 - 23:30 0.75 EVAL P PROD1 Flow check. Get off well. LD GS BHA assembly. 23:30 - 00:00 0.50 EVAL P PROD1 Finish rigging up Halliburton. 12/11/2006 00:00 - 07:00 7.00 EVAL P PROD1 Complete rig up of slickline unit. MU and test lubricator to 3500 psi. Pressure well to 350 psi to open and hold sssv. RIH with sliding sleeve tool. Tag liner at 7,049' SLM. PU and locate sliding sleeve at 7011' SLM. Correction so sleeve is +11'. This puts corrected liner top at 7060'. Liner is engaged in tbg seal assembly. POOH. Re-pin tool to shift sleeve back open. Run in hole. Shift sleeve open. Tag TOL again. POOH. RD slickline unit. 07:00 - 07:30 0.50 CASE P PROD1 PJSM on pickling the 2-3/8" CT for storage and transportation to Nordic 1 07:30 - 09:00 1.50 CASE N WAIT PROD1 Cir and wait on N2 pumper. Doyon 16 rig move to MPU. N2 pumper is behind rig 09:00 - 13:15 4.25 CASE P PROD1 Pumping CT pickle fluid cocktail Blow down with Nitrogen Bleed down to tiger tank 13:15 - 16:00 2.75 CASE P PROD1 Remove TCT and stab wire inside. RU to pull CT across pipe shed. Unstab CT from injector and pulled across. Open Bombay doror in reel house and swap out reel. Crew change out TOT ram to 2" 16:00 - 19:00 3.00 BOPSU P PROD1 BOP Test. Chuck Sieve waived witnessing the BOP test. Installing 2" CT into reel house. MU hard line inside reel. 19:00 - 00:00 5.00 BOPSU P PROD1 Continue BOP test. Choke manifold. Rebuild two valves. SLB converting injector from 2-3/8" to 2". Also converting packoff assembly. 12/12/2006 00:00 - 03:00 3.00 CASE P PROD1 Complete BOP test and injector conversion from 2-3/8" to 2". 03:00 - 05:00 2.00 CASE P PROD1 MU packoff assembly to injector. Stab coil in injector. 05:00 - 06:45 1.75 CASE P PROD1 MU external coil connector and Baker dart catcher. Fill coil with kcl water and circulate 06:45 - 10:00 3.25 CASE P PROD1 Lanched new 2" dart and displaced at 1.5 bpm to to dart catcher. Vp = 40 .6 bbl Pumped it again and lost of black trash came out of CT and the volume was 4 bbl greater. Pumped 10 min and loaded # 3 dart. V= 40.6 bbls. PU BOT's CTLRT. Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 6 of 30 Operations Summary. Report Legal Well Name: 1 C-01 Common Well Name: 1C-01 Event Name: REENTER+COMPLETE Contractor Name: .NORDIC CALISTA Rig Name: NORDIC 2 Date From.-To`(Hours Task Code NPT 12/12/2006 10:00 - 13:00 3.00 CEMT P 13:00 - 14:00 1.00 CEMT P 14:00 - 16:00 2.00 CEMT P 16:00 - 17:00 1.00 CEMT P 17:00 - 18:00 1.00 CEMT P 18:00 - 20:00 2.00 CEMT P 20:00 - 20:30 0.50 CEMT P 20:30 - 21:00 0.50 CASE P 21:00 - 22:00 1.00 CASE P 22:00 - 22:55 0.92 CASE P 22:55 - 00:00 1.08 CASE P 12/13/2006 00:00 - 01:15 1.25 CASE P 01:15 - 01:40 0.42 CASE P 01:40 - 05:50 4.17 CASE P 05:50 - 07:00 1.17 CASE P 07:00 - 09:00 2.00 DRILL P 09:00 - 11:30 2.50 DRILL P 11:30 - 13:30 2.00 DRILL N WAIT 13:30 - 14:30 1.00 DRILL P Spud Date: 12/5/2006 Start: ~ 12/5/2006 End: 1 /9/2007 Rig Release: 1/9/2007 Rig Number: Phase Description of Operations PROD1 Set counters and RIH with CTLRT BHA Change fluids in CT to flo-pro instead of KCL. Pumped a total of 70 bbl (5120 ft) before catching fluid. Close choke and pressure up to 300 psi Open SSSV and RIH circulating at 1:1. Wt Check at 7000 ft = 23.4k wo/ pumps = 23.9k. Tagged at 7,063 ft and worked seals down into deployment sleeve to 7,066 ft CTP increase 50 psi. Pumped 10 bbl to confime stung in RIH, set down and latch 4" GS. PU to confirm latched PROD1 Dropped 5/8" ball and released from liner V= 32.1 bbl pressured up to 4200 psi and sheared. Still shutting well in with 300 psi when shutting down pumps PROD1 Displacing wellbore to 2% KCL DS. Spot and RU SLB cementers. PROD1 Hold PJSM with Nordic & SLSB crews. Batch mix cement. Pressure test lines to 4000 psi. PROD1 Pump 5.5 bbls 15.8 ppg Class G into reel. Hold 300 psi WHP. 1:1 rtns. Shut in. Clean out hard line back to cementers. Load dart. Pressure to 380 psi. Pump 0.2 bbls. Open reel cap to verify dart launch. Displace cement with biozan using rig pumps. 2450 psi at 1.96 in/1.91 out. Pressure dropping as cement passes goose neck. WHP: 286 psi. Land and shear dart at 41.6 bbls / 3700 psi. Displace wiper plug to landing collar. Land at 49.0 bbls. Bleed coil pressure. Floats holding. ~~ Pressure coil to 400 psi. Unsting. Circulate out of hole keeping 1:1 rtns. PROD1 Circulate out of hole replacing voidage, overall 1:1. Adjust WHP to maintain correct returns. Close TRSSSV PROD1 LD CTLRT tools and load out PROD1 RU DS N2 pumper. Spot HES WL unit PROD1 Stab back on and WO rig water and McOH PROD1 Displace KCI in CT w/ rig water followed by 24 bbls rig water w/ A266 corrosion inhibitor, followed by 15 bbls McOH to tiger tank. DS cool down N2. VECO load trailer w/ E-CT reel PROD1 DS blow down reel w/ N2 and bleed off to tiger tank PROD1 Cut off BTT CTC. Install internal grapple and pull CT back to reel and secure i PROD1 Set injector on legs. Safety mtg re: SIMOPS RU HES slickline tools. SWS RD hardline in reel house and load out a-free 2" I reel PROD1 Bring HES WL tools to floor. RU BOP's and lub. PT 900 psi. RIH w/ D084 shifting tool. Close sliding sleeve. PT wellbore w/ 8.7# mud at 550 psi to verify closed. POOH SWS load in 2" E-CT and RU hardline PROD1 At surface with slickline BHA. Get off well. Tool indicates sleeve has shifted. Rig down Halliburton slickline. PROD1 Hold PJSM to review stabbing a-coil. Good discussion. Move injector over well. Release coil from reel. Pull coil through injector. PROD1 MU kendal connector. Circulate two coil volumes with flopro mud. MU Baker connector. Test a-line. PROD1 Baker held up by 4ES rig move from M Pad to DS 1. PROD1 MU milling/clean out BHA. 2.74 " HTC mill (D331GE6) had fine cutright added to top of three of six "blades" to provide Printed: 1/16/2007 70:32:30 AM ~~ BP AMERICA Page 7 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 .Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 ',Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 IRig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ` NPT Phase 12/13/2006 13:30 - 14:30 1.00 DRILL P PROD1 14:30 - 14:45 0.25 DRILL P PROD1 14:45 - 16:00 1.25 .DRILL P PROD1 16:00 - 16:15 0.25 DRILL P PROD1 16:15 - 17:00 0.75 DRILL P PROD1 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 18:20 0.33 DRILL P PROD1 18:20 - 18:40 I 0.331 DRILL I P I I PROD1 18:40 - 20:40 I 2.001 DRILL 1 P I I PROD1 20:40 - 00:00 I 3.331 DRILL I P I I PROD1 112/14/2006 100:00 - 01:30 I 1.501 DRILL I P I I PROD1 01:30 - 02:00 I 0.501 DRILL I P I I PROD1 02:00 - 04:00 2.00 DRILL P PROD1 04:00 - 04:40 0.67 DRILL P PROD1 04:40 - 06:15 1.58 DRILL P PROD1 06:15 - 07:30 1.25 DRILL P PROD1 07:30 - 07:45 0.25 DRILL P PROD1 07:45 - 08:00 0.25 DRILL P PROD1 08:00 - 11:15 3.25 DRILL P PROD1 11:15 - 12:30 1.25 DRILL P PROD1 12:30 - 15:00 2.50 DRILL P PROD1 15:00 - 18:00 3.00 DRILL N DPRB PROD1 Description of Operations backreaming capability. Stab coil. Get on well. Open SSSV. Bleed off WHP. Monitor well for flow to verify sliding sleeve and floats etc are holding. Well stable. Run in hole. Log GR tie in from 7,170'. Subtract 15' correction. RIH. Tag btm at 8038'. PU and bring pumps uo to 1.5 bpm at 2175 psi fs. Mill out cement and float equipment. Drill to 8040.6' where motor stalled. PUH w/ initial sli overpull due to being packed off aUabove mill. Could circ 0.8/3600 and were pulling w/ 5k less than normal string wt at 19k. PUH slow to 7950' while cycle pump to max press. Shucked impediment after 10 min and were back to normal 1.47/2240 w/ 24.2k Ream back to 8040.0' and got increase in dill Resume milling from 8040.0' 1.55/2300 and get to 8040.15' and had a repeat of the above. Get back to first MW at 8039.3' Resume milling from 8039.3' 1.52/2300 at a slower rate. Get back to 8040.6' after 1.5 hrs w/o stalls. Continue at an intentionally slow pace to 8041.0' 50' wiper was clean. Resume milling from 8040.8' 1.51/2300 w/ 200-400 psi dill, 2-3k wob at 9.15 ECD. Sit on a hard spot at 8042.5' for 1.5 hrs. Mill to 8043.3' Continue drilling float equipment from 8043.3' w/ max wt of 3k and 200 psi dill. Recip several times and started getting steady, albiet slow progress. Drill to 8045.8' and had loss of diff and wt which was the calculated bottom of the shoe. Found a cement stringer at 8048', then hole was clean to 8065'. MW D GR quit during this time Ream thru shoe track 3 times until clean. Dry drift twice w/ well SI to check BHP. Had no increase in WHP in 10 min. BHI BHP/ECD = 8.6# POOH from 8065' circ thru mill 1.6/2300. Close TRSSSV. LD and load out milling assy MU drilling assy. Stab coil. Test tools. Get on well. Run in hole to 2100'. Stop to check out a thumping noise in reel. PJSM. Adjust a reel motor mounting plate. Continue to run in hole. Log gr tie in from 7186'. Subtract 16' correction. Run in hole to TD. Tag btm at 8160'. Drill ahead from 8160'. 2800 psi fs at 1.48 in/1.49 out. 150-250 dpsi. DHWOB: 1-2k#. WHP/BHP/ECD: 110/3170/9.5 ppg. IA/OA/PVT: 0/0/267 bbls. INC/AZM: 95.2/220 deg. Begin displacement to new flopro light once on bottom. ROP: 70-100 fph. W Iper trip to RA tag at 7187'. (exit angle is 14 deg at "window"). Hole smooth. Drill ahead from 8300'. ECD has slowly climbed. Open choke. WHP/BHP/ECD: 35/3212/9.61 ppg. Hit a hard spot. Lost 4-5 deg inclination. Having trouble building back up to 94-96 deg needed to achieve target. Discuss with rig team. Need a different motor. Wiper trip to window. Circulate out of hole to 6500'. RIH to 7000'. Take static pressure survey with DPS. 2875 psi at Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 8 of 30 Operations Summary Report- Legal Well Name: 1 C-01 'Common Well Name: 1C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: 12/5/2006 End: 1/9/2007 Contractor Name: ..NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 12/14/2006 15:00 - 18:00 3.00 DRILL N DPRB PROD1 7000' md/ 6198' TVD. Wellhead slowly climbing. 8.92 ppg. 18:00 - 18:15 I 0.251 DRILL I N I DPRB I PROD1 18:15 - 19:00 ~ 0.751 DRILL N I PROD1 19:00 - 21:00 I 2.001 DRILL I N I SFAL I PROD1 21:00 - 00:00 I 3.001 DRILL I N I SFAL I PROD1 112/15/2006 100:00 - 02:30 I 2.501 DRILL I N I SFAL I PROD1 02:30 - 04:00 I 1.501 DRILL I N I SFAL I PROD1 04:00 - 05:00 I 1.001 DRILL I N I SFAL I PROD1 05:00 - 06:00 1.00 DRILL N SFAL PROD1 06:00 - 09:30 3.50 DRILL N SFAL PROD1 09:30 - 10:30 1.00 DRILL N 10:30 - 11:45 1.25 DRILL N 11:45 - 13:30 1.75 DRILL N 13:30 - 15:30 2.00 DRILL N 15:30 - 18:15 18:15 - 20:15 20:15 - 22:15 SFAL PROD1 SFAL PROD1 SFAL PROD1 SFAL IPRODI 2.75 DRILL N SFAL PROD1 2.00 DRILL N SFAL PROD1 2.001 DRILL I N I SFAL I PROD1 This seems low. Decide to POH with 3100 psi at 6198'. Adjust schedule. Open EDC and MWD tool shorted out. POH. Perform kick while tripping drill. Close sssv. Continue to POH. Crew change/safety mtg. Also discuss the 'thump'. This usually means that the reel bushings wi11 need replacement within a few more runs. Elect to do it now LD drilling BHA. SI swab. Bit had no wear. Motor was loose and was the reason that no more hole could be made-not a hard spot. Check MWD BHA assy and tested fine. Meg eline and no test Safety mtg re: Change bushing on ODS of reel Open swab, RIH 30' w/ CT to TDS spot to pick reel w/ slings. Circ at min rate 0.2/480. Slide out and inspect reel bushing and drive pins. No abnormal wear on either. Found that the reel bushing keeper bolt had backed out about 2" which could allow the bushing to wobble. Tighten up the bolt and put humpty back together again. POOH w/ CT Safety mtg re: Determine continuity break in eline starting in reelhouse Find short at junction box in reelhouse (loose wire). Retest line and still have open circuit Continue to try to find open circuit in eline. Cut off CTC and still have short. RU and cut off 50' of eline and still have short WO SWS eline techs 1 hr. After arrival, techs perform continuity checks and determine that line is bad about 1/3 of the way from the downhole end. This would put usable CT at about 10850'. The second lateral on this well is the deepest at 10100' WOO. Discuss w/SWS management. This reel has 455k RF and has 14811' left. There is not a backup 2" E-CT reel loaded on a lowboy and cranes are hard to come by. SWS decide to cut CT in 1000' increments then retest to pinpoint bad spot Safety mtg re: Cut off CT Cut off 1000 ' CT. Line test not showing we are getting any closer to line fault. Crew change. Hold PJSM with day crew. Dlscuss job scope and hazards. Continue to cut coil. SLB decides to stop cutting and use a new a-coil reel. Rig up nitrogen pumper. Displace reel to rig water. Hold PJSM. Blow down reel with N2. Bleed off to tiger tank. PJSM. RU grapple and tugger line. Unstab coil and secure on reel. Remove inner reel hard line. Lower reel on to lowboy for transport. PJSM. Spot new reel on lowboy under reel house. Lift into reel house. Install bulk head connection and hardline inside reel. Install internal grapple into new 2" HS90 E-CT and PT. Pull CT to injector and stab. Install new packoff. Set injector over bunghole Fill CT w/ 5 bbls McOH followed by 40 bbls FW at 1.0 bpm. Found some leaks in hardline in reel house Printed: 1/16/2007 10:32:30 AM BP AMERICA Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1C-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 12/15/2006 22:15 - 00:00 1.75 DRILL N SFAL 12/16/2006 00:00 - 02:30 2.50 DRILL N SFAL 02:30 - 03:15 0.75 DRILL N SFAL 03:15 - 04:00 0.75 DRILL N DPRB 04:00 - 04:45 0.75 DRILL N SFAL 04:45 - 05:20 0.58 DRILL N SFAL 05:20 - 06:15 0.92 DRILL N DPRB 06:15 - 06:45 0.50 DRILL N DPRB 06:45 - 08:45 2.00 DRILL N DPRB 08:45 - 10:30 1.75 DRILL P 10:30 - 13:00 2.50 DRILL C 13:00 - 15:30 2.50 DRILL C 15:30 - 16:30 1.00 DRILL C 16:30 - 17:45 1.25 DRILL C 17:45 - 19:00 1.25 DRILL C 19:00 - 19:30 0.50 DRILL C 19:30 - 20:00 0.50 DRILL C 20:00 - 20:45 0.75 DRILL C 20:45 - 22:00 1.25 DRILL C 22:00 - 23:50 1.83 DRILL C Page 9 of 30 Spud Date: 12/5/2006 Start: ~ 12/5/2006 End: 1 /9/2007 Rig Release: 1/9/2007 Rig Number: Phase ~ Description of Operations PROD1 Stab onto well. Reverse slack into reel. Cut off 29' CT PROD1 Install Kendall CTC. Blow CT back w/ air. Head up BHI. Attempt to circ after 1 hr and were froze. Install nozzle. RIH to thaw CT, then circ to warm up. PT CTC at 4000 psi and BHI XO below CTC leaked End SWS NPT PROD1 Breakoff XO, inspect, tighten and re-PT at 4050 psi PROD1 Set injector over bung hole and displace FW w/ mud while MU BHA PROD1 SWS regrease pressure bulkhead packing after it had a slow leak. Re-PT at 4000 psi PROD1 BHI remeg line and had bad test. Find short at UOC and fix. Stab on w/ inj PROD1 RIH w/ BHA #11 to 200'. Open EDC. Pump slack forward 2.4/3280 while RIH. Park coil and open sssv with no WHP. Try again to open sssv with 300 psi WHP. SSSV open. WHP remaining at 295-300 psi. Formation appears to be very tight. PROD1 Log gr tie in from 7200'. Subtract 15' correction. PROD1 Wiper trip through open hole. Several set downs. Maintain as drilled TF. Tag btm at 8440'. PU and ream btm 50'. PROD1 Drill ahead from 8,440'. 2510 psi fs at 1.55 in/1.57 out. Coil do wt: 15k# at btm. WHP/BHP/ECD: 26/3130/9.27 ppg. IA/OA/PVT: 0/0/326 bbls. Get some gas back with btms up. Increase whp to 100 psi using tri-flo choke. Oil in rtns. Divert to gas buster. Increase whp to 200 psi. Divert to tiger tank. Circulate 30 bbls. Still getting gas back. Increase circ rate to 1.5 bpm. 9.85 ppg ECD. Returns cleaned up..Bring mud back inside to pits. PROD1 Drill ahead from 8,467' to 8,500'. Build angle to 90 deg, then get knocked back down to 88 deg. This is not working. Discuss with rig and town team. PROD1 W iper trip to window. Circulate out of hole holding 3200 psi equivalent BHP. Close sssv. Flow check. Circulate OOH to surface. PROD1 Get off well. Change angle motor to 2.1 deg. MU Smith M-09 2.73" bit. Disassemble Swaco choke to inspect for debris. None found. PROD1 MU BHA. Stab coil. Test tools. Get on well. PRODi RIH circ thru EDC following pressure schedule. Open TRSSSV w/ 300 psi assist PROD1 Log tie-in down, corr -15' PROD1 RIH thru liner circ thru EDC 1.65/2300 to 8064' PROD1 Close EDC, RIH at 15'/min while precautionary ream 1/53/2470 at DTF to TD tagged at 8498'. PU 25.2k Perform several 50' backreams to allow BHA to slide better PROD1 Drill from 8498' 1.53/2500/10L w/ 0.2-1.Ok wob, <100 psi dill initially to get bit started. Gradually work up WOB to 4k and drill to 8516' PROD1 Drill on a hard spot from 8516.0' w/ 1.52/2450/5L w/ 4.3k max wob, no dill, 9.36 ECD. Acts like glass (Lisburne type drilling). Pickup every 30 min, can't get drill off. Make 0.2' in 1:50. Assume bit cutters are micro dulled. NB incl at 8502' is 89.3 deg-no change last 18' drilled Printed: 1/76/2007 10:32:30 AM • • BP AMERICA Page 10 of 30 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To C-01 C-01 REENTE NORDIC NORDIC Hours ~ R+COM CALIST 2 Task PLET A Code E NPT 12/16/2006 22:00 - 23:50 1.83 DRILL C 23:50 - 00:00 0.17 DRILL C 12/17/2006 00:00 - 00:15 0.25 DRILL C 00:15 - 02:00 1.75 DRILL C 02:00 - 03:15 1.25 DRILL C 03:15 - 04:45 1.50 DRILL C 04:45 - 05:10 0.42 DRILL C 05:10 - 05:30 0.33 DRILL C 05:30 - 05:50 0.33 DRILL C 05:50 - 06:00 0.17 DRILL C 06:00 - 09:00 3.00 DRILL C 09:00 - 11:15 2.25 DRILL C 11:15 - 13:45 2.50 DRILL C 13:45 - 16:15 2.50 DRILL C 16:15 - 17:45 1.50 DRILL C 17:45 - 18:10 0.42 DRILL C 18:10 - 18:25 0.25 DRILL C 18:25 - 18:40 0.25 DRILL C 18:40 - 00:00 5.33 DRILL C 12/18/2006 00:00 - 00:40 0.67 DRILL C 00:40 - 01:40 1.00 DRILL C 01:40 - 07:30 5.83 DRILL C Spud Date: 12/5/2006 Start: 12/5/2006 End: 1 /9/2007 Rig Release: 1 /9/2007 Rig Number: Phase Description of Operations PROD1 Returns have become crude cut and 'out' density has dropped to 8.5 ppg PROD1 Wiper to shoe prior to POOH for bit PROD1 Wiper to shoe was clean PROD1 Open EDC at 8050'. Circ thru EDC at 1.85/2400. Returns becoming lighter in in density so start following pressure schedule. At 7000', out density was 7.6 ppg. Incr whp to 400 psi while Circ thru EDC. POOH and adjust WHP based on return rate. Close TRSSSV w/ 500 psi whp. Close EDC. Bleed off 600 psi whp and check for flow PROD1 Check motor, okay. M09X bit was 1-1-1 (had no chips, only micro dulled) PROD1 RIH w/ BHA #12 (same 2.1 deg motor, new HCC bi bit). Open EDC at 200'. RIH circ thru EDC 0.4/700 SWS tighten reel drive plate. Open TRSSSV w/ 500 psi assist. RIH following pressure schedule for 3300 psi at 6400' TVD PROD1 Log tie-in down from 7190', Corr -16' PROD1 RIH thru liner circ thru EDC 0.4/1130 following pressure schedule PROD1 Close EDC at 8050'. Wiper to TD PROD1 Ream last 18' to TD tagged at 8516.2' while break in bit PROD1 Bit took off immediately after tagging TD so drill from 8516' 1.6/2600/10L w/ 100-300 psi dill, 1.5-2.5k wob holding 100 psi whp at 60'/hr! NB incl at 8506' showing 92.4 deg. Build angle quickly to 94-95 NB inc. Measuring 30-37 deg doglegs. Drill on hard spot at 8610'. finally break through. PROD1 Drill ahead from 8610'. 2600 psi fs at 1.63 in/1.62 ouit. 200-300 dpsi. CT do wt: 12k#. DHWOB: 1.5 - 3.Ok#. WHP/6HP/ECD: 103/3241/9.72 ppg. IA/OA/PVT: 137/0/362 bbls. Holding 93-94 deg inc. ROP varying between zero and 75 fpm. Suspect high angle motor is hanging up BHA, or bit has dulled. Decide to trip for BHA and bit. PROD1 Wiper trip to liner shoe. Open EDC. Circulate out of hole. Maintain BHP as per pressure schedule. Close sssv with 400 psi underneath. POH to surface. Get off well. Unstab coil. PROD1 LD BHA. Bit 1-1. LD motor. Motor feels tight, has +/- 30 hrs. Service CT injector. MU lateral BHA. Adjust motor to 1.2 deg. PU a new HTC bicenter bit. Stab coil. Test tools. Get on well. PROD1 Run in hole. Pressure well to 400 psi. Open sssv. Continue to RIH. Follow pressure schedule PROD1 Log tie-in down from 7190', corr -17' PROD1 RIH thru liner to 8050'. Close EDC PROD1 Wiper to TD tagged at 8634' was clean PROD1 Resume drilling pilot hole (to find fault #3 and D shale) from 8634' (6424' TVD) 1.6/2650/908 w/ 100-300 psi dill, 1.5-2.5k wob holding 100 psi whp for 9.75 ECD. Continue invert at 94.5 deg and are parallel to original plan and 12' TVD deep. Drilling iri and out of assumed minor siderite streaks to 8765' PROD1 Drill from 8765-8790' at 94 deg. Lost 5 deg at 8755' PROD1 Wiper to shoe was clean PROD1 Continue drilling pilot invert from 8790' 1.6/2700/208 w/ 100 psi Punted: 1/16/2007 10:32:30 AM BP AMERICA Page 11 Of 30 Operations Summary Report .Legal Well Name: 1C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 iContractor Name: NORDIC CALISTA Rig Release: 1/9/2007 ',Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task ` Code') NPT Phase - r = ~ -_ _---- 12/18/2006 01 ~40 - 07:30 I 5.83 DRILL ~C ~ PROD1 07:30 - 08:30 1.00 DRILL C PROD1 08:30 - 12:00 3.50 DRILL C PROD1 12:00 - 14:45 I 2.751 DRILL I C I I PROD1 14:45 - 15:30 0.75 DRILL C PROD1 15:30 - 22:00 6.501 DRILL P PROD1 22:00 - 00:00 2.00 CASE C PROD1 12/19/2006 00:00 - 02:00 2.00 CASE C PROD1 02:00 - 03:00 1.00 CASE C PROD1 03:00 - 04:30 1.50 CASE C PROD1 04:30 - 04:50 I 0.331 CASE I C I I PROD1 04:50 - 06:00 1.17 CASE C PROD1 06:00 - 08:30 2.50 CASE X DFAL PROD1 08:30 - 09:00 I 0.501 CASE I X I DFAL I PROD1 09:00 - 11:00 I 2.001 CASE I X I DFAL I PROD1 11:00 - 12:00 1.00 CASE X DFAL PROD1 12:00 - 15:00 3.00 FISH X DFAL PROD1 15:00 - 17:00 2.00 BOPSU X SFAL PROD1 17:00 - 17:45 0.75 FISH X DFAL PROD1 17:45 - 19:30 1.75 FISH X DFAL PROD1 19:30 - 20:20 I 0.831 FISH I X I DFAL I PROD1 Description of Operations dill, 1-2k wob w/ 100 psi whp for 9.80 ECD at 92 deg in and out of thin siderite beds Wiper trip to liner shoe. Hole smooth. Drill ahead from 8950'. 2900 psi fs at 1.59 in/1.62 out. 150-250 dpsi. DHWOB: 1.45-2.3k#. WHP/BHP/ECD: 95/3292/9.86 ppg. IA/OA/PVT: 144/20/343 bbls. PU every 5' to check for sticky formation. W iper trip at 25 fpm/1.5 bpm to 8,000' laying in beads. POOH above liner top to 7000'. Open EDC. Circulate out of hole at 80%. Close TRSSSV LD drilling BHA. Secure tree. Circ mud thru CT at min rate to bung hole Safety Standdown w/ day, then Hite crews (31 total personnel) RU pipeshed and floor to run liner MU Unique Indexing guide shoe followed by 18 jts 2-3/8" 4.41 # L-80 STL liner. MU BTT steel WS tray w/ open hole anchor and running tool (600.64' OA) MU BHI MWD assy RIH w/ liner assy on CT w/ EDC open Circ 0.3/1100 psi. Pressure wellbore to 400 psi to open TRSSSV. RIH w/o pump following pressure schedule. Wt chk at 7000' 21.5k Close EDC. Log tie-in down from 7770', corr -17'. Wt chk 25.4k RIH w/ liner w/o pump thru 3-3/16" shoe, clean. RIH thru open hole, clean. PU at 8960' was 27.5k. RIH and set liner at TD tagged at 9011'. Top of WS will be at 8417'. Pressure up to 4400 psi before shear pins sheared. Wait for tool to stroke. Have trouble releasing Pull coil maximum of 60k# up wt. Able to get 20k# down wt at BHA. Set to neutral wt. Activate orienter max left. Cycle pipe to 60k# several times. Orient max right in neutral. Cycle pipe to max pull several times. No movement. Orienter function ok, but no positive effect. Concerned about working pipe too much and losing ability to disconnect.. Relax pipe to neutral weight and continue to circulate at 1.5 bpm at 2650 psi. WHP/BHP/ECD: 99/3308/9.95 ppg. Discuss options with slope and town team. Trap 300 psi WHP. Shut in pump. Activate EDC. Released from lower BHA at 30k# up wt. POOH circulating at min rate. Maintain 350 psi WHP. Order fishing tools from Deadhorse. At surface. Get off well. Unstab coil. LD recovered BHA. Re-head coil with Kendal and Inteq flow sub. PT 35k, 4000 psi Nordic repair hyd leak on actuator on TOT BOP's and PT Fishing tools arrive. Bring tools to floor MU fishing BHA RIH circ thru GS following pressure schedule. Open TRSSSV. Corr -17' at 7217'. Wt chk @ 8300' 22.6k at 20'/min TIH dwn wt 2k tagged at 8366'. failed to latch 1st try. Latch in GS overpull 4k - good latch. Stack 5k. No luck. Pull up and recock jars. Pull up to 10k over. Stack back down. Jar down - p/u and pull 8k over. Stack dwn with 5k - pu check f/free. Pull up to 10K over and jar up. Jar Printed: 1/16/2007 10:32:30 AM ~ ~ BP AMERICA ` Page 12 of 30 Operations` Summary Report Legal Well Name: 1 C-01 'Common Well Name: 1C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 ',Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 IRig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Ph ~ Descri tion of O erations ase 12/19/2006 19:30 - 20:20 0.83 FISH X DFAL PROD1 20:20 - 22:15 I 1.921 FISH I X I DFAL I PROD1 22:15 - 22:45 I 0.501 FISH I X {DFAL I PROD1 22:45 - 00:00 I 1.251 FISH I X I DFAL I PROD1 12/20/2006 00:00 - 00:30 0.50 FISH X DFAL PROD1 00:30 - 04:10 3.67 CASE X DFAL PROD1 04:10 - 04:45 0.58 CASE X DFAL PROD1 04:45 - 05:05 0.33 CASE X SFAL PROD1 05:05 - 05:45 0.67 CASE X SFAL PROD1 05:45 - 07:00 1.25 CASE X SFAL PROD1 07:00 - 09:00 I 2.001 CASE 1 X I SFAL I PROD1 09:00 - 12:30 I 3.501 CASE I X I SFAL I PROD1 12:30 - 14:30 2.00 CASE X SFAL PROD1 14:30 - 14:45 0.25 CASE X SFAL PROD1 14:45 - 15:25 0.67 CASE X SFAL PROD1 15:25 - 15:55 0.50 CASE X PROD1 15:55 - 17:45 1.83 CASE X PROD1 17:45 - i 8:00 I 0.251 STKOH I X I I PROD1 18:00 - 19:00 I 1.001 STKOH I X I I PROD1 p. p hit run back in and try down lick again. Same time move some fluids in coil to prevent freeze up. Off line with pump. PU and check for free. PU 10K over and jar up. Stack 10k and jar dwn. PU 12k over jar up again. Stack 11 k jar down. PU 15K over jar up twice something gave on last jar lick. Pulling 300-4001bs heavy. TOH (PJSM: Review plan forward to handle fishing tools and BHI tools) Setback injector and circ. PU fishing tools to GS spear and Ld. LD recovered EDC, Gamma, Orientor, and DPS. Also recoverd Bakers setting rod. Still in the hole is the Cross Link Sleeve (.60 length) and WS setting sleeve (1.40" length) all of which is attached to the WS. Sleeves are 2.65" OD and 2.25" ID. Discuss options with town. Openhole sidetrack at +/- 8300' or attempt to run a small section of liner with aluminum sidetrack billet on top. Wait for decision. Decided to run short liner with alum billet. Loadout fishing tools. Prep end of a-line for slack management. Cut-off 10' coil. Install dipple CTC pull test to 40K. Install BHi's upper quick connect. Meg tested good. Pressure test to 4K PU cleanout BHA RIH .Lost comms with downhole tools. TOH Setback inj. LD BHA. Found a-line pulled from UOC. Cut-off CTC. Will need to redo slack mngmt and rehead. Reverse slack back 3.0/3500 w/mud. Heard slack move a bunch, but found that wire at end of CT had not moved. Reverse slack again, no movement, minor wire movement. Meg line and no test Reverse in 10 bbls FW to CT in case cutting a tot of CT is necessary. Cut off 100' and found a birds nest. Cut additional 100'. Test line and tested good. Pump FW out of CT. Reverse slack back w/mud. Cut off another 50'. Meg test good Head up BHI connections. Found a short at the flow sub. Change it out Safety mtg re: MU liner x WS assy MU BOT fluted guide shoe/spear on 6 jts 2-3/8" 4.4# L-80 STL slotted tubing. Add WFT 2.5" aluminum OH WS assy w/ two solid 2-3/8" STL pups + down jars MU BHI Power Comms w/ EDC assy RIH w/ BHA #18 at 80'/min circ thru EDC and pumping slack forward 1.6/2300 for CT volume. Open TRSSSV w/ 400 psi assist. Continue RIH circ thru EDC 0.4/1600 following pressure schedule. Corr -17' at 7217' Close EDC at 8000'. RIH w/ liner/WS assy into open hole to 8380' 25.Ok, 13.8k wo/pump RIH to tag at 8412' CTD With fluted spear setting on top of previously set Baker WS jar down 6 times in the attempt to drive spear into the portion of the setting sleeve left in hole yesterday. PU each time was purposely less than the 25k PU wt indicated earlier. Bring on pump to 1 bpm and release GS from WTF aluminum Punted: 1 /16/2007 10:32:30 AM BP AMERICA Page 13 of 30 Operations Summary Report Legal Well Name: 1C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To 12/20/2006 118:00 -19:00 19:00 - 20:45 20:45 - 22:10 22:10 - 23:45 23:45 - 00:00 12/21 /2006 00:00 - 00:40 00:40 - 06:00 06:00 - 06:45 06:45 - 08:00 08:00 - 08:45 08:45 - 09:50 09:50 - 10:25 10:25 - 12:00 12:00 - 12:30 12:30 - 14:10 14:10 - 15:45 15:45 - 16:10 16:10 - 16:30 16:30 - 16:45 16:45 - 17:10 17:10 - 21:30 Hours Task Code NPT Phase- Description of Operations 1.00 STKOH X PROD1 billet OHWS. PU wt 23.5 w/pump. Stilt some doubt if fluted spear has engage setting sleeve. So RIH and jar once wo/pump. PU wo/pump but wt is the same at 23.5k RIH w/pump 2550psi and engage top GS on WS. No pump pressure increase. Little expected. Jar once PU wt 23.5K. Weight indications are +/- 1k less which is about the wt of liner. Nothing else to indicate weather liner is in place. No indication that tapered fluted spear in wedged into the setting sleeve either. Was hopeing to see an increase in PU wt. 1.75 STKOH C PROD1 TOH hold PJSM review plan forward to LD WTF tools. Also discuss what-if plans should the liner be still attached. 1.42 STKOH C PROD1 Setback injector and circ. Remove BHA from well. liner did release. LD tools. Prep next BHI tools and test. PU 1.5 deg motor and used 2.74" no-go ST324 bit. MU BHA and test. -good. 1.58 STKOH C PROD1 TIH following pressure schedule. tagged top of 3-3/16" liner at 7064' with 180 TF rotate to HS went through good. 0.25 STKOH C PROD1 Log tie in. Subtract 16' 0.67 STKOH C PROD1 Continue TIH. Tagged top of alum billet at 8202'. 5.33 STKOH C PROD1 Confirm tag depth. PU bring on pump to 1.60/2900 RIH to 8200'. Set toolface to 60L Time drill: 0.1'/4min for 1' to 8200.7' and tagged billet. PU and start over again at 8199'. Increase speed 0.1'/2min f/ 8200' to 8200.7' Continual stalls at 8200.7' Increase pump to 1.83/3300 stalled at 8200.7' PU to 8190' and trough 20'/hr back to 8200.7' 3 times 0500hr Time milling 8200.7' at .05'/5min seeing motor work without stalls. Will continue at this pace then inc to .1'/5min 0.75 STKOH C PROD1 Drill to 8203', reduce whp from 350 psi to 100 psi (10.6 ECD to 9.5 ECD) 1.25 STKOH C PROD1 Start adding up to 1 k wt and drill from 8203-8220' 1.81/3200/70L w/ 9.6 0.75 STKOH C PROD1 Backream/ream by billet at DTF twice until clean 1.08 STKOH C PROD1 Resume drilling from 8220' 1.6/2700/100L w/ 50-200 psi whp, 1.5-2.5k wob w/ 100 psi whp to give 3271 psi dhp (9.7 ECD). Drill to 8247' while level out for lateral assy 0.58 STKOH C PROD1 Wiper to 3-3/16" shoe was clean. Wiper thru 3-3/16" was clean 1.58 STKOH C PROD1 Open EDC at 7000'. POOH circ 2.0/3250 following pressure schedule. Wash TRSSSV before closing w/ 380 psi 0.50 STKOH C PROD1 LD sidetrack assy. Bit was the same as before RIH 1.67 DRILL C PROD1 MU drilling assy w/ resistivity 1.58 DRILL C PROD1 RIH w/ BHA #20 (1.1 deg motor, bi bit) circ thru bit 0.25/1100 following pressure schedule. Open TRSSSV w/ 400 psi assist 0.42 DRILL C PROD1 Log tie-in down from 7180', Corr -15' 0.33 DRILL C PROD1 RIH thru 3-3/16" liner. Start pump and precautionary ream to 8220' 0.25 DRILL C PROD1 Log MAD pass down from 8220' 1.66/3030/60L w/ 100 psi whp to TD 0.42 DRILL C PROD1 Backream and ream at full rate thru sidetrack area and was clean 4.33 DRILL X PROD1 Drill from 8247' 1.65/2950/90L w/ 100-200 psi dill, 0.6-2.Ok wob w/ 100 psi whp Printed: 1/16/2007 10:32:30 AM I i BP AMERICA Page 14 of 30 Operations Summary Report` Legal Well Name: 1 C-01 Common W ell Name: 1 C-01 Spud Date: 12/5/2006 Event Nam e: REENTE R+COM PLET E Start : 12/5/2006 End: 1 /9/2007 Contractor Name: N ORDIC CALIST A Rig Release: 1/9/2007 ~, ~ Rig Name: N ORDIC 2 Rig N umber: ~ Date From - To ~ Hours Task Code NPT Phase Description of Operations i 12/21/2006 21:30 - 22:15 0.75 DRILL X PROD1 Wiper trip back to 3-3/16" shoe. No problems. Went past alum billet fine. 25k off bottom 22:15 - 00:00 1.75 DRILL X PROD1 Continue drilling ahead f/ 8400' to 8457 1.60/1.60 3000psi FS 2-300psi MW .5-2k WOB 12/22/2006 00:00 - 03:45 3.75 DRILL P PROD1 Continue drilling ahead f/ 8457' 1.60 / 1.60 3000psi w/ 200psi motor work. Maintaining 200psi on wellhead with Swaco choke. .5-2k wob ROP = 10-20'/hr Ann= 3855psi ECD= 11..52ppg 03:45 - 04:45 1.00 DRILL P PROD1 Wiper trip to 8000'. No problems 04:45 - 06:00 1.25 DRILL P PROD1 Continue drilling f/ 8443' 1.60 / 1.60 3010psi 100-200psi mw Ann= 3877 ECD= 11.82 WHP= 210 WOB= 1k 15-20'/hr 06:00 - 09:10 3.17 DRILL P PROD1 Drill from 8560' 1.61/2900/1108 w/ 100-200 psi diff, 0.5-2.5k wob w/ 100 psi whp or 10.54 ECD 40-60'/hr at avg 91 deg 09:10 - 09:55 0.75 DRILL P PROD1 W iper to shoe was clean except for overpull at 8550'. Continue wiper to 7080' while circ thru bit. Open EDC 09:55 - 10:10 0.25 DRILL P PROD1 Log tie-in down from 7190' circ thru EDC 2.1/3240 w/ 100 psi whp. Add 6.0' 10:10 - 10:35 0.42 DRILL P PROD1 RIH circ thru EDC 2.15/3250 to 8000' 10:35 - 11:00 0.42 DRILL P PROD1 Wiper to TD was clean except for one setdown at 8550' (had drilled thru hard spot here) 11:00 - 13:30 2.50 DRILL P PROD1 Drill from 8700' 1.58/2960/908 w/ 100-200 psi diff, 0.5-2.Ok wob, w/ 100 psi whp giving 3466 dhp or 10.36 ECD. Swap to left at 8730'. Drill to 8850' 13:30 - 14:25 0.92 DRILL P PROD1 Wiper to shoe was clean both directions 14:25 - 17:30 3.08 DRILL P PROD1 Drill from 8850' 1.58/3010/90L w/ 50-250 psi diff, 0.5-2.Ok wob j w/ 100 psi whp giving 3521 psi dhp or 10.50 ECD. Drill to 9000' 17:30 - 18:30 1.00 DRILL P PROD1 Wiper to shoe. Slight bobble at 8552' going back in. i 18:30 - 21:20 2.83 DRILL P PROD1 Directionally drill ahead f/ 9000'. 1.60 / 1.60 8.7/8.65 3050psi free-spin 150-200psi MW ann= 3526psi holding 150psi whp. ~ 1 k wob 40-50'/hr 21:20 - 23:25 2.08 DRILL P PROD1 Wiper trip. At 8050' trap 450 on well and open EDC. PUmp 1.9bpm up to 7050'. 23:25 - 23:35 0.17 DRILL P PROD1 Log tie-in to RA marker at 7187' plus 8' correction 23:35 - 00:00 0.42 DRILL P PROD1 Wiper trip in hole. No problems at 8550'. 12/23/2006 00:00 - 00:30 0.50 DRILL P PROD1 Wiper trip back to bottom. No hole problems 00:30 - 03:55 3.42 DRILL P PROD1 Continue directionally drilling ahead f/ 9147' 1.60 / 1.60 3100psi freespin 100-200psi MW ann= 3500psi w/ 100psi held at surface. Drill rate stopped at 9152'..fault? Ratty drilling 10-20'/hr to 9170' then 70-80'/hr to 9276'. 03:55 - 05:30 1.58 DRILL P PROD1 Wiper trip to 8200'. No problems. 05:30 - 07:50 2.33 DRILL P PROD1 Directionally drill ahead f/ 9276'. 1.60 / 1.60 3120psi. Have trouble making steady hole. Drills like atransition/caprock area. Sticky pickups from 9285' and samples show higher than normal clay and pyrite. Grill to 9292' with 1.5k wob and going nowhere fast 07:50 - 09:05 1.25 DRILL P PROD1 Wiper to window was clean. Wiper to 7000' was clean 09:05 - 10:20 1.25 DRILL P PROD1 Open EDC at 7000'. POOH circ 2.0/3000 following pressure schedule. Close TRSSSV w/ 400 psi ', 10:20 - 11:50 1.50 DRILL P PROD1 LD drilling BHA. Bit was microdulled, motor okay. Change bit, add agitator 11:50 - 13:15 1.42 DRILL P PROD1 RIH w/ BHA #21. Check agitator at 300', open EDC. RIH circ 0.3/1100 following pressure schedule. Open TRSSSV w/ 400 Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 15 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 12/23/2006 11:50 - 13:15 1.42 DRILL P 13:15 - 13:35 0.33 DRILL P 13:35 - 14:05 0.50 DRILL P 14:05 - 14:50 0.75 DRILL P 14:50 - 17:00 2.17 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 19:50 1.83 DRILL P 19:50 - 22:15 I 2.421 DRILL I P 22:15 - 23:30 I 1.251 DRILL I P 23:30 - 00:00 0.50 DRILL P 12/24/2006 00:00 - 01:30 1.50 DRILL P 01:30 - 03:10 I 1.671 DRILL I P 03:10 - 05:10 I 2.001 DRILL I P 05:10 - 07:10 ~ 2.00 ~ DRILL ~ P 07:10 - 07:25 I 0.251 DRILL I P 07:25 - 07:45 0.33 DRILL P 07:45 - 08:55 1.17 DRILL P 08:55 - 10:00 ~ 1.08 ~ DRILL ~ P Spud Date: 12/5/2006 Start: 12/5/2006 End: 1 /9/2007 Rig Release: 1/9/2007 Rig Number: Phase Description of Operations PROD1 psi assist PROD1 Log tie-in down from 7190', Corr -15' PROD1 RIH to 8040', close EDC PROD1 Wiper to TD tagged at was clean 9294' PVT 3i4 PROD1 Drill from 9294' 1.58/3580/30L w/ 50-150 psi dill, 0.3-1.8k wob at 94 deg w/ 100 psi whp giving 3451 psi dhp or 10.32 ECD. Had 16' of hard drilling, then took off at 45-60'/hr. Begin planned climb from 92 to 100 deg PROD1 Drill a hard spot at 9390' then take off at 70'/hr. Drill to 9445' PROD1 Wiper trip back to 8200'. First 135' had ocasssional 5-10k overpulls. RIH setdown at 9280' PU went thru other setdowns at 9300, 9391' no problem getting thru. PROD1 Continue drilling f/ 9445' 1.60 3600psi 2-300psi MW maintaining 100psi whp. Ann= 3450psi ECD= 10.34ppg 1-2k wob 40-50'/hr Swapping out to new 8.6ppg Flo-Pro mud PROD1 Wiper trip to 8050'. Ratty hole 9300' - 9325' setdowns at 9492', 9533' PU once and run to bottom. PROD1 Drill ahead f/ 9542 to 9554'. PROD1 Continue drilling ahead f/ 9555' 1.60 / 1.58 3050psi freespin 1-200psi MW maintaining 100psi WHP 1-2K wob 40-60'/hr Ann= 3420psi ECD= 10.30ppg. Stacking out PROD1 Wiper trip back to 9000' w/ 5-10k overpulls off bottom. Working back to bottom problems starting at 9550' all the way to bottom. Pull back up through slowly with 1807E to 9200'. RIH with 'as drilled' TF's 25'/min 8k CTW 3550psi FS Hole condition better. PROD1 Continue drilling f/ 9625' on a hard spot 2-300psi motorwork. Took off drilling good to 9654' then hit hard streak, then another at 9669'. Drills good after hard sections. Currently at 9690' rop= 70-80'/hr w/ 1 k wob and 2k ctw PROD1 Wiper trip. Tight f/ 9670' to 9600' pulling 10k over then trouble going back down. Continuing wiper above 9600' was clean to the shoe. Continue wiper ihru 3-3/16" 1.6/3600 to 7080' PROD1 Open EDC and circ 1.94/2940 while log down from 7190'. Corr +14' PROD1 RIH thru liner circ 1.95/2940 PROD1 Close EDC at 8040'. Wiper back to TD was clean. Struggle past 9600' due to classic lock-up. Had to pick up 3 times, but make it back to TD tagged at 9714' (6381' TVD) PRODi Resume drilling from 9714' 1.5/330060L w/ 200 psi dill, 0.5-2.5k wob w/ Ok surface wt holding 100 psi whp giving 3384 psi dhp or 10.21 ECD. Drill to 9730.0' 10:00 - 10:25 0.42 DRILL N SEAL PROD1 SWS traction motor for power pack shut down . Wait on electrician (from Nordic 3) to arrive to troubleshoot Continue to circ thru bit at drilling rate 1.59/3700/45L until 9725' sample caught holding 100 psi whp to give 3400 psi dhp or 10.25 ECD 10:25 - 12:30 2.08 DRILL N SEAL PROD1 Red rate to 0.75/1800 and incr whp to 300 psi to hold 3500 psi dhp or 10.55 ECD 12:30 - 14:30 2.00 DRILL N SEAL PROD1 Electrician arrives and initial observation is that brushes may be able to be rebuilt so that we could get out of the hole. Printed: 1/76/2007 10:32:30 AM BP AMERICA Page 16 of 30 ~ Operations.. Summary Report Legal Well Name: 1C-01 Common Well Name: 1C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006. End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From --To ~ Hours Task Code I NPT Phase I Description of Operations 12/24/2006 12:30 - 14:30 2.00 DRILL N SFAL PROD1 Further investigation showed that the motor needs to be replaced 14:30 - 18:00 3.50 DRILL N SFAL PROD1 Safety mtg. Begin dismantling hoses, bolts, etc to remove power pack assy which includes traction motor. Replacement motor arrives from SWS Deadhorse. Grane arrives. Arrange for tractor/trailer to move power pack assy to SWS KIC shop area to finish removal of motor from pump and necessary parts from the dead one and install on the new one 18:00 - 18:20 0.33 DRILL N PROD1 Review plan forward to remove power unit package with crane ', operator. Insure all personnel or out of the TechLimit office during the lifting operations. 18:20 - 19:30 1.17 DRILL N PROD1 Remove power pack and loadout on truck. Take to KIC for traction motor swap. 19:30 - 00:00 4.50 DRILL N PROD1 Circulate hole at 1.3bpm and wait. Maintaining 100psi WHP. ~ 12/25/2006 - 0.00 Merry Christmas 00:00 - 06:00 6.00 DRILL N SFAL PROD1 Continue making repairs to SLB's Hyd. Power Pack unit. Traction motor burned out. Swapping out traction motors. Mounting holes not exactly the same which is adding to the time required to make the swap. Once unit is back together installation and testing could take at least 6-8hrs. Circulating the well between 1.2 - 1.6 bpm. Well is taking fluid at the rate of 3 bbls/hr 06:00 - 10:00 4.00 DRILL N PROD1 Continue to circ 0.75/1900 holding 300 psi whp for 3530 psi dhp or 10.67 ECD. Cut new mounting holes on frame and shim motor so coupling to pump will match. This motor is different in a lot of respects size-wise to the one that was removed. 10:00 - 16:30 6.50 DRILL N PROD1 Power pack skid w/ new traction motor arrive on location. Crane too. Safety mtg. Lift power pack skid w/ 90T crane and set back in room on 3rd level. Install roof. Release crane DS mechanics start reinstallation of hydraulic hoses followed by electrical. Lost about 1/2 of digital gauges output on SWS screen after rewiring started. SWS techs arrive and trouble shoot. Will need to SD SWS PC's (drilling screen/data, etc) while motor is wired 16:30 - 18:00 1.50 DRILL N PROD1 SD SWS PC after ensuring all mechanical gauges are reading correctly and all hands know where to find info (doing it the old fashioned way-using mechanical gauges!) Continue to circ 0.75/2100 w/ 300 psi whp w/ 3600 psi dhp or 10.8 ECD 18:00 - 18:20 0.33 DRILL N PROD1 Review start-up procedures for the Power Pack with oncoming crews. 18:20 - 21:40 3.33 DRILL P PROD1 Start-up PP look for any problems. Working good. (good team effort by everyone swapping out traction motors) Pull to 45k wo movement. Relax pipe. Increase pump rate to 1.6bpm intial high PP 4100psi. Dump WHP same time PU and came free. TOH following pressure schedule. Hole seems good which it should after circulating for the last 32 hrs. Keeping close watch on PP. Pull above SSSV and close trapping 450spi on well. Tag up bleed off whp and osbserve for flow. None. 21:40 - 22:15 0.58 DRILL P PROD1 Setback injector. LD BHA. Isolate res tool and test calibration. 22:15 - 23:30 1.25 DRILL P PROD1 Need to work on SCR. When the power pack went out it also Printed: 1/16/2007 10:32:30 AM BP AMERICA Operations Summary Report Page 17 of 30 Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 12/25/2006 22:15 - 23:30 1.25 DRILL P PROD1 blew a fuse in the SCR. Power to rig pumps will be shutdown. PU injector and blow back fluids to prevent freezing while working on SCR. Remove upper check from BHi UOC. Blow back coil with rig air. Res tool calibrated the same as before going in the hole. So no MAD pass logging needed. 23:30 - 00:00 0.50 BOPSU P PROD1 Test BOPE. AOGCC notified of test. 12/26/2006 00:00 - 04:45 4.75 BOPSU P PROD1 Pressure test BOPE 3500psi high / 250 low 5min/ea Test inner reel valve to 3500psi. Draw down test accumulator. 04:45 - 04:55 0.17 BOPSU P PROD1 PJSM: review plan forward and picking up BHA. 04:55 - 06:00 1.08 BOPSU P PROD1 PU BHA #22 Surface tested good. 06:00 - 07:25 1.42 DRILL P PROD1 RIH w/ BHA #22 (new HYC bi bit, fresh 1.1 deg motor and agitator w/ same res tool) circ thru EDC 0.3/1200 following pressure schedule. Open TRSSSV w/ 400 psi assist 07:25 - 07:40 0.25 DRILL P PROD1 Log tie-in down from 7190', Corr -17' 07:40 - 08:00 0.33 DRILL P PROD1 RIH thru 3-3/16" liner circ thru EDC 08:00 - 09:10 1.17 DRILL P PROD1 Close EDC at 8020'. Wiper to TD 1.45/3190 was clean to 9635' where wt was lost w/o MW. Did not PU, but just let agitator vibrate BHA 'up' to TD. Get to 9724'. Wiper back to 9600', then wiper back to TD tagged at 9727' 09:10 - 13:50 4.67 DRILL P PROD1 Drill from 9727' 1.6/3300/70L w/ 100-250 psi dill, 0-1.5k wob w/ 100 psi whp, 10.6 ECD at 102 deg while looking for siderite streak, then D shale in order to call TD. Drills like siderite or shale, 13' in two hours, 25' in four hours, etc. Drill to 9760' and see GR shift 13:50 - 14:20 0.50 DRILL P PROD1 150' wiper 24.3k, w/ 5k overpull at 9720'. TD is called at 9760'-geo can see D shale on log at 9720' (means the motor and bit were in the D Shale for 32 hrs during repairs) Wiper back to TD just to be sure we can get there, but can't. Stacked out and had 10k overpull at 9724'. Also had high MW. Elect not to tear up the D shale. PUH then wiper back to 9715' was clean both ways. Will plan to set liner shoe here at a minimum 14:20 - 16:00 1:67 DRILL P PROD1 Wiper to shoe while mix beads in pits 4 and 5 16:00 - 16:15 0.25 DRILL P PROD1 Log tie in +9' correction 16:15 - 17:05 0.83 DRILL P PROD1 Continue wiper to bottom. Clean to 9717' (everyone's decided this is far enough). 17:05 - 21:00 3.92 DRILL P PR001 TOH laying new Flo-Pro w/ 2#/bbls beads. Stopped at 1,300 ft and trappped 400 psi below SSSV. Bleed presssure down, monitored well, some flow. Cycled SSSV and bleed pressure down and moniotored well. Well dead. POOH, filling hole. Held THA on handling BHA 21:00 - 22:45 1.75 DRILL P PROD1 LD BHA and PJSM on PU & Running 2-3/8" liner 22:45 - 00:00 1.25 CASE P PROD1 RU to run 2-3/8" liner 12/27/2006 00:00 - 03:00 3.00 CASE P PROD1 Running 2-3/8" slotted liner. PU BHI MWD BHA Open SSSV 03:00 - 05:00 2.00 CASE P PROD1 RIH with 2-3/8" slotted liner. Wt check at 7030 ft = 26k; RIH = 14.5k 05:00 - 05:30 0.50 CASE P PROD1 Tie-in to RA Marker at 8,030 ft Corrected -17 ft 05:30 - 06:25 0.92 CASE P PROD1 RIH at 9700' CTW 12k wt up 27.2k RIH to 9724' (see a slight tag) line up to pump down coil. Pump 1.55 bpm PU lost 4k everything looks like liner is dropped. 06:25 - 08:10 1.75 CASE P PROD1 TOH following pressure schedule. Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 18 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task `Code NPT Phase Description of Operations 12/27/2006 08:10 - 09:10 1.00 CASE P PROD1 LD BHi tools. Unable to circ coil. Trace down to beads in the 09:10 - 09:20 I 0.171 CASE I P 09:20 - 10:45 I 1.421 CASE I P 10:45 - 11:30 0.751 CASE P 11:30 - 13:50 2.331 CASE P 13:50 - 15:50 I 2.001 CASE I P 15:50 - 16:00 0.17 CASE P 16:00 - 17:20 1.33 STWHIP P 17:20 - 19:05 1.75 STWHIP P 19:05 - 19:15 0.17 STWHIP P 19:15 - 19:45 I 0.501 STWHIP P 19:45 - 19:50 0.08 STWHIP P 19:50 - 21:35 1.75 STWHIP P 21:35 - 21:55 0.33 STWHIP P 21:55 - 23:30 1.58 STWHIP P 23:30 - 00:00 0.50 STWHIP P 12/28/2006 00:00 - 01:00 1.00 ST W H I P P 01:00 - 01:30 0.50 STWHIP P 01:30 - 01:45 0.25 STWHIP P 01:45 - 07:15 5.50 STWHIP P 07:15 - 09:00 1.75 STWHIP P 09:00 - 10:45 1.75 STWHIP P 10:45-10:55 ~ 0.17~STWHIP~P PROD1 PROD1 PRO01 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 10:55 - 11:35 0.67 STWHIP P PROD1 11:35 - 16:40 5.08 STWHIP N SFAL PROD1 charge pump. Coil almost frozen. PJSM: discuss hazards with picking up liner. Review potential pinch points on the rig floor with the hands. PU top section of liner. Baker Lock all jewelry connections. Guide shoe and o-ring sub's inner portion are drillable. PU BHi tools. Stab on injector. RIH wt ck at 7000' was 25.4k tie-in to RA -15' RIH wt chk at 8800' 27k RIH pumping 1.4bpm 3475psi tagged top of bottom liner segment at 8847' PU 22.6k liner in place. Liner top 8808'md TOH following pressure schedule 1.4gpm taking returns over shaker stripping out beads. PJSM review LD BHA and PU Baker Whipstock and BHi tools. PU Baker Mono Bore TT Whipstock setting tool and BHi orienter and GR tools. RIH with BOT TTWS Stopped at 7230 ft and PUH to 7225 ft. Logged tie-in from 7225ft to 7200 ft Corrected (-15 ft) RIH and set TOWS at 7750 ft and bottom at 7758 ft Confirmed depth with 3-3/16" pipe tally in relationship to no/go on 4-1/2" TT. SD pump and closed EDC Set TF at 90L of HS Set WS using 4,400 psi Whipstock from 7,750 ft and 7,758 ft POOH, trapped 400 psi below SSSV OOH, held PJSM and identified the hazards associated with handling the WS setting BHA and injector head LD WS setting BHA. MU BHI's BHA. PU 2.74" DSM BHA RIH to mill window RIH to mill window Logged tie-in from 7170 ft to 7189 ft and corrected -15 ft RIH and dry tagged TOWS at 7750 ft Tagged at 7751 ft Mill window as per BOT SOP's Started time milling at 7,750.9 ft Op = 1.54 / 1.54 bpm CTP = 3200 psi Vp = 345 bbls Drill rathole f/ 7756' to 7766'. Back ream clean-up window area twice. Dry run / wo pump thru window looks good. Open EDC and POH follow pressure schedule. At 1500' close SSSV. PJSM review plan forward. LD BHI / BTT tools. Review plans for doing 'slack management' on coil. Observe well for flow. Unstab injector. LD BHA. Cut-off CTC. Dress end on a-line couldn't 'stuff' end on a-ilne up into coil so MU weld-on CTC. By that time coil was frozen. RIH to 280' unthaw coil. At surface. Check end of coil..no a-line sticking out...good. Stab on injector and reverse at 2bpm for 5 min. Clould hear slack moveing back in the reel house. Cut off CTC but found wire 1' up. Redress wire and try again. (may have a birds nest again) Not moving. Somethings not right. Rig and cut coil. Found several kinked areas between 20-40'. Cut 100' then meg line...good. RU and reverse again at 2bpm. Cut Printed: 1/16/2007 10:32:30 AM BP AMERICA Operations. Summary Report Page 19 of 30 ~ Legal Well Name: 1 C-01 Common Well Name: 1C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1 /9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours.. Task Code `NPT Phase` Description of Operations 12/28/2006 11:35 - 16:40 5.08 STWHIP N SFAL PROD1 35' and found a-line. Circ and warm coil. Behead w/ SLB Kendal CTC. Warmed coil again. 16:40 - 21:00 4.33 DRILL N SFAL PROD1 Behead BHi UOC Had to RIH to 200 ft to be able to circulate. POOH and PT CTC to 3500 psi, (OK), Set Injector backi and circulate while PU BHI's BHA Megged line and its shorted. Changed flow sub. Re-megged. Failed. Circulated CT ordered MEOH and loaded pit 4 with fresh water. Need to change flow sub. Line up to reverse pump water and MEOH up the CT. Reversed in 5 bbl water, 10 bbl of MEOH SD and blow surface lines down Ambient temperature at -40 ft Changed flow sub and megged line (ok). PU motor (set at 1.1 deg) and BHI's Coiltrac, scribed offset. 21:00 - 21:25 0.42 DRILL N RREP PROD1 Found red winch hydraulic line leaking. Repair same 21:25 - 21:45 0.33 DRILL P PROD1 Run BHA in the hole. Stab injector head, test tool (no upper check in BHA) 21:45 - 23:20 1.58 DRILL P PROD1 Set counters and RIH, (EDC closed) 23:20 - 23:30 0.17 DRILL P PROD1 Log tie-in at 7188 ft (corrected -17 ft) 23:30 - 23:50 0.33 DRILL P PROD1 RIH TOWS =TOW = 7750.9 ft 23:50 - 00:00 0.17 DRILL P PROD1 Tagged bottom at 7766 ft MD set TF at 90 LHS Op = 1.60 / 1.61 bpm CTP 3226 / 3450 psi Vp = 318 bbl BHP 3460 psi at 10.15 ppg ECD; WHP =200 psi ROP 60 to 70 fph with 2.Ok WOB 12/29/2006 00:00 - 01:30 1.50 DRILL P PROD1 Drilling Zone C2 at TF at 90 LHS Op = 1.60 / 1.61 bpm CTP 3226 / 3450 psi Vp = 318 bbl BHP 3486 psi at 10.38 ppg ECD; WHP =205 psi ROP 60 to 100 fph with 1.5-2.Ok WOB 01:30 - 01:40 0.17 DRILL P PRODi Wiper trip after drilling 150 ft 01:40 - 03:47 2.12 DRILL P PROD1 Drilling Zone C2 and headed up to C3 at TF at 80 - 110 LHS Op = 1.60 / 1.61 bpm CTP 3226 / 3505 psi Vp=317bb1 BHP 3504 psi at 10.46 ppg ECD; WHP =205 psi ROP 80 to 100 fph with 1.5-2.Ok WOB 03:47 - 04:00 0.22 DRILL P PROD1 W iper trip to 7760 ft 04:00 - 07:10 3.17 DRILL P PROD1 Drilling Zone C2 and headed up to C3 at TTumed TF from 80Lto90RTFat8100ft Op = 1.58 / 1.58 bpm CTP 3300 / 3505 psi Vp = 317 bbl BHP 3504 psi at 10.46 ppg ECD; WHP =205 psi ROP 40 to 100 fph with 1.5-2.Ok WOB 07:10 - 07:25 0.25 DRILL P PROD1 Wiper trip to window ...good. 07:25 - 09:25 2.00 DRILL P PROD1 Continue drilling ahead f/ 8200' Op=1.56/1.57 CTP = 3250 / 3330 Vp = 318 BHP = 3514psi EDC = 10.50ppg WHP = 200psi ROP 50-70'/hr wob 1-2k May have a cederite stringer. Pulled 5k over off bottom. Close Printed: 1/162007 70:32:30 AM BP AMERICA Page 20 of 30 Qperations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: R Name: From - To C-01 C-01 EENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code ~ E NPT' Start Rig Rig Phase Spud Date: 12/5/2006 : 12/5/2006 End: 1/9/2007 Release: 1/9/2007 Number: Description of Operations ,12/29/2006 07:25 - 09:25 2.00 DRILL P PROD1 to wiper time.... ' 09:25 - 10:30 1.08 DRILL P PROD1 Wiper trip to above 3-3/16" liner top Q 7060' i 10:30 - 10:40 0.17 DRILL P PROD1 Log tie in bit ~ 7190' +T 10:40 - 11:20 0.67 DRILL P PROD1 Wiper back to bottom. Clean ', 11:20 - 13:30 2.17 DRILL P PROD1 Continue drilling ahead f/ 8333' I ~ Op = 1.57 / 1.62 Vp=316 CTP = 3220 / 3500 BHP = 3493 EDC = 10.44ppg WHP 140psi ROP = 50-70'/hr WOB = 1k CTW 8100 Stacking wt ROP < 20'/hr 32k off btm 13:30 - 14:40 1.171 DRILL P PROD1 Wiper trip to window. 14:40 - 16:45 2.08 DRILL P PROD1 Continue drilling ahead f/ 8444' i Op=1.50/1.50 Vp = 330 turned on centrifuge CTP 3100 / 3300 BHP = 3450 EDC 10.3ppg WHP 100 1 ROP = 50-80'/hr 1-2k WOB 16:45 - 17:50 1.08 DRILL P PROD1 Wiper trip to window. 27k off bottom 17:50 - 18:10 0.33 DRILL P PROD1 Continue drilling forvvard f/ 8600' Op=1.52/1.50 CTP 3020 / 3350 Vp = 323 BHP 3412 EDC 10.2 ROP = 40-60'/hr 18:10 - 18:30 0.33 DRILL N SFAL PROD1 Lost all electrical on rig, Generators shut down because of underfrequence 18:40 - 19:00 0.33 DRILL N RREP PROD1 Wiper trip to restart the res tool after the power electrical shut down on the rig Lost restisitivy tool and the NBI is acting strange Res tool started up again. RIH 19:00 - 21:00 2.00 DRILL P PROD1 Continue drilling from f/ 8623' Op = 1.52 / 1.50 bpm CTP = 3040 / 3350 psi Vp = 319 bbl BHP = 3367 psi EDC 10.12 ppg WHP = 105 psi ROP = 40-60 fVhr Started mud swap at 20:00 hrs at 8675 ft 21:00 - 22:25 1.42 DRILL P PROD1 Wiper trip to 7760 ft 22:25 - 00:00 1.58 DRILL P PROD1 Continue drilling in C4 from f/ 8750' 120 R TF Op=1.62/1.63 bpm CTP = 2950 / 3250 psi Vp = 319 bbl BHP = 3367 psi EDC 10.12 ppg WHP = 105 psi ROP = 40-60 ft/hr 12/30/2006 00:00 - 00:15 0.25 DRILL P PROD1 Drilled to 8873 ft and stacking increasing. 00:15 - 02:45 2.50 DRILL P PROD1 Wiper trip to tie in and clean out 3-3/16" liner. SD pump and PUH above WS Open EDC and Cir at 1.8 bpm while PUH to 7180 ft. Log tie-in from7180 ft to 7200 ft (+ 12 ft) Surged liner at 7067 ft (TOL). RIH and closed ECD at 7700 ft. RIH 02:45 - 06:00 3.25 DRILL P PROD1 Continue drilling in C4 from f/ 8881' 100-120 R TF Op = 1.64 / 1.64 bpm CTP = 2950 / 3250 psi Printed: 1/16/2007 10:32:30 AM i w BP AMERICA Page 21 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1 /9/2007 Rig Name: NORDIC 2 Rig Number: -Date ~ From - To Hours j Task Code NPT ~ Phase Description of Operations 12/30/2006 102:45 - 06:00 3.251 DRILL P PROD1 Vp = 318 bbl 06:00 - 07:30 1.50 DRILL P PROD1 07:30 - 09:40 2.17 DRILL P PROD1 09:40 - 12:40 I 3.001 DRILL I P I I PROD1 12:40 - 13:15 0.58 DRILL P PROD1 13:15 - 13:25 0.17 DRILL P PROD1 13:25 - 14:30 1.08 DRILL P PROD1 14:30 - 15:45 1.25 DRILL P PROD1 15:45 - 16:05 0.33 DRILL P PRODi 16:05 - 17:30 1.42 DRILL P PROD1 17:30 - 17:40 ( 0.171 DRILL I P I I PROD1 17:40 - 18:45 1.08 DRILL P PROD1 18:45 - 19:10 0.42 DRILL P PROD1 19:10 - 19:30 ~ 0.331 DRILL I N I DPRB (PROD1 19:30 - 21:53 I 2.381 DRILL I P I I PROD1 BHP = 3441 psi EDC 10.36 ppg. WHP = 198 psi ROP = 40-60 fUhr Wiper trip to window. Continue drilling ahead f/ 9020' Op = 1.65 / 1.69 bpm CTP = 3000 / 3250psi Vp = 305 BHP = 3410 /EDC 10.26ppg WHP = 150psi ROP = 80-100'/hr w/ 1 k wob CTW = 5k TOH. (unable to obtain high enough LH doglegs. Need at least 20's to stay within the polygon) Few small overpulls 9150-8900'. Pull to 7030' then open EDC. Op = 1.95 / 1.62 following pressure schedule out. Close SSSV. Tag-up bleed off WHP observe for flow. Unstab inj. LD BHA Shut off electrical power to pumps, drwworks, power pack and replace 600v buss for gen #2 in SCR room PU BHA w/ 1.7 deg motor and agitator RIH pumping min rate holding 400psi WHP Log tie-in minus 16' correction RIH slowly taking care to adjust TF's as drilled. Several setdowns..PU and went through easily down to 8970'. Last 100' had to work it. Continue drill ahead in the C4 f/ 9170' Op = 1.53 / 1.54 bpm CTP = 3200 / 3450psi Vp = 295bb1s BHP = 3430 /ECD = 10/33 WHP = 150 ROP = 70-80'/hr 1-2k wob CTW = -1k Stacking wt. Make a short wiper back to Wiper slowly back to 8950' in attempt to clean this section up. Continue drill ahead with agitator in the C4 f/ 9184' Op = 1.53 / 1.54 bpm CTP = 3200 / 3550psi Vp = 294bb1s BHP=3426/ECD=10.3 WHP=150 ROP = 70-80'/hr 1-2k wob CTW = -1k Hole is getting sticky and stacki for not being in a shale or sederite Wiper trip to try and clean up wellbore. Sticky hole conditions after drill 1445 ft of open hole. PU is 26.7k up at 26 fpm 30k at 9,130 ft RIH. tagged twice at 9,138 ft had to PU twice and pull tight Talked to town on hole condition and Continue drill ahead with agitator in the C4 f/ 9197' TF at 120 L HS Op = 1.53 / 1.54 bpm; CTP = 3200 / 3550psi Vp = 294bb1s; BHP = 3426 /ECD = 10.3 WHP = 150 ROP = 10-55'lhr ratty ROP WOB 0.5 to 1.5 k CTW = 5k to -3k Bit stacking PU is 10k over before pulling free. Wellbore breach the pologan as per design Printed: 1/16/2007 10:32:30 AM • BP AMERICA Page 22 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of-Operations 12/30/2006 21:53- 00:00 2.12 DRILL P PROD1 Wiper trip to check hole conditions. PU at 15k over. Ratty PUH from 9,273 ft to 9,070 ft. Pulled smooth after that. RIH from 7,765 ft. Set down at 9,020 ft fell through. Set down at 9,080 ft with motor work. Tagged at 9,115 ft, PU, lowered Op, RIH, set down at 9,181ft and 9,203 ft, fell through. Increased WHP to 200 psi 12/31/2006 00:00 - 00:15 0.25 DRILL P PROD1 Tag bottom after wiper trip at 9273 ~~ 00:15 - 02:15 2.00 DRILL P PROD1 Drilled f/ 9273' to 9316' PU at 9270 tough getting back on ~ (turned TF to 180 deg at 9273') Unable to get below 9280' ~ Stopped at 9289' ~~ 02:15 - 02:50 0.58 ~ DRILL P PROD1 Finally back on bottom at 9317 Drilled to 9325' w/ CTW at 4500#. PU 30k. 02:50 - 03:20 0.50 DRILL P PROD1 Drill ahead 40'/hr. TD well at 9345'. PU to tie-in 43K 03:20 - 05:00 1.671 DRILL P PROD1 Wiper back to 7190'. 05:00 - 05:30 0.50 i DRILL P PROD1 log tie-in plus 14'. 05:30 - 07:20 1.83 i DRILL P PROD1 Wiper trip to bottom. Setdowns at 8838, 8853, 8907, 9024' (pu 33k), 9029, 9065, 9167' then rough going to bottom. Tagged bottom at 9354' 07:20 - 09:45 2.42 DRILL P PROD1 TOH laying in 25 bbls flo-pro w/ 2#/bbl Alpine beads. 35k about 20' off bottom. Close SSSV trapping 400psi on well. At surace bleed down and observe for flow. Dead.... PJSM while close to surface for LD BHA and RU tools to run liner 09:45 - 10:30 0.75 DRILL P PROD1 Set back injector on legs. LD BHi tools. 10:30 - 11:00 0.50 CASE P PROD1 RU to run liner. 11:00 - 11:10 0.17 CASE P PROD1 PJSM on rig floor. Point out and review hazards for PU liner. 11:10 - 12:00 0.83 CASE P PROD1 MU 1jt solid and 14 jts slotted 2-3/8" 4.4# L80 STL liner. 12:00 - 12:30 0.50 CASE P PROD1 Crew changeout and PJSM with new crew members again on the irg floor reviewing plan forward and hazards for PU 1"CSH. 12:30 - 13:15 0.75 CASE P PROD1 RU 1" YT elevators, false RT, changeout dies in Little Jerks to 1 ". 13:15 - 15:10 1.92 CASE P PROD1 MU 14jts 1"CSH and spaceout. MU BHi tools MU injector 15:10 - 16:40 1.50 CASE P PROD1 RIH to 7650'. 16:40 - 16:50 0.17 CASE P PROD1 Log tie-in -18'. Make wtcheck 24.5K 16:50 - 17:45 0.92 CASE P PROD1 RIH smooth no pump maintaining 400psi. Wt ck at 9333' 28k RIH to bottom at 9354'. Bring on pump lbpm 2500psi. PU appears to have lost liner 26.5k 17:45 - 19:45 2.00 CASE P PROD1 TOH.. wt ck again at 7650' pulling same speed 19:45 - 22:00 2.25 CASE P PROD1 OOH, Pressured wellbore up to 400 psi and close SSSV. Released pressure and SSSV holding LD MWD and discovered that the liner was still attached. RU and LD 1"CSH. 22:00 - 22:15 0.25 CASE P PROD1 Held PJSM on PU 2-3/8" liner. Determined hazards and mitigated same. 22:15 - 00:00 1.75 CASE P PROD1 PU 2-3/8" STL Liner, Installed WFT's AI billet with hydraulic GS Spear. PU BHI's MWD and RIH. Stab injector head. Damaged wet connect on LOC. Set injector back and change out LOC 1/1/2007 00:00 - 02:00 2.00 CASE P PROD1 Test tool, set counters and RIH with billet liner Wt Check at 7,050 ft = 22.8k @ 23 fpm Wt Check @7,750 ft = 23.2k at 23 fpm 02:00 - 02:25 0.42 CASE P PROD1 Log tie-in at 8,150 ftCorrected - 18 ft to 8180.3 ft 02:25 - 03:00 0.58 CASE P PROD1 RIH at 11.4k down at 24 fpm Wt check at 9150 ft, Printed: 1/16/2007 10:32:30 AM BP AMERICA Operations Summary Report Page 23 of 30 ~ Legal Well Name: 1 C-01 Common Well Name: 1C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: l Date From - To Hours Task " Code NPT Phase Description of Operations 1/1/2007 02:25 - 03:00 0.58 CASE P PROD1 Down = 8.7k down / 28k at 17 fpm 03:00 - 05:30 2.50 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 06:15 0.25 STKOH P 06:15 - 07:00 0.75 STKOH P 07:00 - 07:10 0.17 STKOH P 07:10 - 08:15 1.08 STKOH P 08:15 - 08:30 0.25 BOPSU P 08:30 - 09:15 0.75 STKOH P 09:15 - 10:45 1.50 STKOH P 10:45 - 10:55 0.17 STKOH P 10:55 - 11:30 0.58 STKOH P 11:30 - 14:30 I 3.00 I STKOH I P 15:00 - 16:00 0.00! STKOH P 16:00 - 18:00 I 2.00 I STKOH I P 18:00 - 20:00 I 2.00 I STKOH I P 20:00 - 21:30 1.50 DRILL P 21:30 - 21:50 0.33 DRILL P 21:50 - 22:40 0.83 DRILL P 22:40 - 00:00 1.33 DRILL P 11/2/2007 100:00 - 01:35 I 1.581 DRILL I P Tagged at 9,353 ft. Set 2k down Smooth trip in the hole. Lined up pump down CT and inc Op to 1.5 bpm. PUH and lost 5,500 Ib PROD1 POOH fill down annulus. Close SSSV. PROD1 LD BHI CoilTrac MWD and WFT liner running tool PROD1 Crew change. PSJM between driller and floorhand to prep for CDL. PROD1 Close swab valve. Hang blocks and remove front guard from drawworks. PROD1 PSJM with all crew members for CDL, confined space entry. Took into consideration the cold temps which are currently -37 with a WC of -80. PROD1 CuVslip 60' drlg line. Service injector. PROD1 Perform weekly BOP fuction test. All's good. PROD1 PU sidetrack BHA. Stab on injector. PROD1 RIH to 7190' PROD1 Log tie in -17' correction PROD1 RIH back to min rate on pump and tag aluminum billet at 8353.8' 8353.1' with pump. PROD1 Starting from 8352.6' time drill 0.1'/5min intervals holding 90L TF Op = 1.55 / 1.54 CTP = 3050 / 3350 Vp = 254 bbls BHP = 3495 ECD = 10.30ppg WHP = 150 PROD1 Drill ahead f/ 8360' to 8375'. PROD1 Backream sidetrack 60 deg high/low from 90L back to 8340' several times. PROD1 TOH. Seeing alot of AI coming across shakers. Tag up then RIH 500' to clear cuttings. PROD1 LD ST BHA and checked out tool, install res tool and rebuild FVS and double ball valve. PU BHA PROD1 RIH PROD1 Logging tie down starting at 7185 ft Corrected (-17 ft) PROD1 RIH PROD1 Drilling build and turn section C3 from 8,375 ft 90L TF Op = 1.55 / 1.51 bpm; CTP = 3054 / 3350 psi Vp = 257 bbls BHP =3470 ECD = 10.40ppg; WHP =205 bbl WOB = Ito 2k ROP 50 fph 1st few drill good and then slowed down. Working to get bit to drill. PROD1 Drilling build and turn section C3 from 8,406 ft to 8408 ft 90L TF Op = 1.55 / 1.51 bpm; CTP = 3054 13350 psi Vp = 257 bbls BHP = 3470 ECD = 10.40ppg; WHP =205 bbl WOB = Ito 2k ROP slow. Working to get bit and motor. Get sand and al shaving over the shaker. Tried several thing but Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 24 of 30 Operations Summary Report Legal Well Name: 1C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To _ Hours ~ Task Code NPT Phase Description of Operations 1/2/2007 00:00 - 01:35 1.58 DRILL P PROD1 unable to get it to drill 01:35 - 03:50 2.25 DRILL P PROD1 POOH 03:50 - 05:30 1.67 DRILL P PROD1 Change out motor, picked up agitator and RR BC bit. Agitator Number AGS218-59-114 05:30 - 06:45 1.25 DRILL P PROD1 RIH 06:45 - 07:00 0.25 DRILL P PROD1 Log tie-in minus 7' 07:00 - 08:00 1.00 DRILL P PROD1 RIH adjust TF to 90L for WS and AI billet. At 8300' MM plugged off switch to manual choke. Clear MM back on Swaco choke. Tagged bottom at 8413'. 08:00 - 10:20 2.33 DRILL P PROD1 Directionally drill ahead f/ 8413' Op = 1.54 / 1.52 CTP = 3724 / 3900 Vp = 247 bbls Ann = 34501 ECD = 10.33ppg WOB = 3k ROP = 60-90'/hr 10:20 - 11:20 1.00 DRILL P PROD1 Wiper trip to whipstock at 7751'. No problems. 11:20 - 13:30 2.17 DRILL P PROD1 Continue drilling ahead f/ 8554' Op=1.51/1.52 CTP = 3600 / 3750 Vp = 258 bbls increase due to centrifuge being turned on Ann = 3460psi ECD = 10.32ppg WOB = 2-3k ROP = 50-60'/hr 13:30 - 14:45 1.25 DRILL P PROD1 Wiper trip to window. 14:45 - 17:15 2.50 DRILL P PROD1 Continue drilling ahead f/ 8700 ft Op = 1.51 / 1.52 bpm CTP = 3,600 / 3,750 psi Vp = 245 bbls Ann = 3500 psi ECD = 10.52ppg WOB = 1-2 k ROP = 50-80'/hr 17:15 - 19:00 1.75 DRILL P PROD1 Wiper trip 1st 150 ft is ratty. 5 to 10 k over pulls. Hole smooth on trip in. 19:00 - 23:15 4.25 DRILL P PROD1 Drill ahead from 8850'. 3300 psi fs at 1.58 in/1.57 out. 150-250 dpsi. DHWOB: 2.5 - 3.5k#. WHP/BHP/ECD: 150/3353/10.08 ppg. IA/OA/PVT: 0/0/68. ROP: erratic and mostly slow. Begin mud swap. Take on new flo pro from tank farm. Haul off old fluid for injection. ROP improved with new mud around. Cannot tell if this is due to mud or formation or both. 23:15 - 00:00 0.75 DRILL P PROD1 Wiper trip to window. Clean trip out. 1/3/2007 00:00 - 01:00 1.00 DRILL P PROD1 Continue wiper trip to tie in point. Hole mostly smooth. A little ratty from 8,759' to 8,850'. 01:00 - 01:30 0.50 DRILL P PROD1 Log gr tie in from 7180'. Add 2' correction. 01:30 - 02:45 1.25 DRILL P PROD1 Continue wiper trip back into hole. 02:45 - 05:00 2.25 DRILL P PROD1 Drill ahead to 9,150 05:00 - 07:45 2.75 DRILL P PROD1 Wiper trip at 9150 ft Clean trip out 0745 07:45 - 10:45 3.00 DRILL P PROD1 Continue drilling ahead f/ 9,150 ft Turned TF to 180 deg to get the drop required Op = 1.51 / 1.52 bpm CTP = 3,000 / 3,170 psi Vp = 419 bbls Ann = 3,345 psi ECD = 10.03 ppg WOB = 1 k ROP = 50-100'/hr Unable to drop hole angle with TF at 180 deg Printed: 1/16/2007 70:3230 AM i • BP AMERICA Operations Summary Report Page 25 of 30 Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT + Phase Description of Operations 1/3/2007 10:45 - 13:35 2.83 DRILL P 13:35 - 15:00 I 1.421 DRILL I P 15:00 - 16:25 1.42 DRILL P 16:25 - 16:50 0.42 DRILL P 16:50 - 18:00 I 1.171 DRILL ~ P 18:00 - 00:00 I 6.001 DRILL I P ~ 1/4/2007 ~ 00:00 - 03:00 ~ 3.00 ~ DRILL ~ P 03:00 - 04:00 1.00 DRILL P 04:00 - 06:00 2.00 DRILL P 06:00 - 07:30 1.50 DRILL P 07:30 - 10:45 3.25 DRILL P 10:45 - 12:35 I 1.831 DRILL I P 12:35 - 13:45 I 1.171 DRILL I P PROD1 POOH to change bit and motor bend. Need to drop some hole angle / TVD Closed SSSV with 400 psi trapped below PROD1 Stood back injector, and coiltrac BHA. Set motor to 1.5 deg and picked up 2.73" M-09 bit. Re ran agitator # AGS218-59-114 PROD1 RIH with dropping BHA PROD1 Tie-in from 7,170 ft down. (corrected -16 ft) RIH to 7,738 ft and closed EDC. PROD1 RIH with corrected drilled TF. Having some problems getting the M-09 in the hole. Taking time to ensure the TF is in the correst azimuth. Having some trouble at 9157 ft PROD1 Drilling ahead f/ 9,292 ft w/ TF at 170LHS Op=1.61/1.60 bpm CTP = 3,000 / 3,170 psi Vp = 403 bbls Ann = 3,382 psi ECD = 10.16 ppg W OB = 2 k ROP = 70-80' /hr Hit a hard spot at 9309'. Broke through. Drill ahead with NB incl at 84-85 deg. ROP 15 to 30 fph. PROD1 Drill ahead from 9368'. 3500 psi fs at 1.66 in/1.66 out. 200 dpsi. DHWOB: 1.5 to 2.5k#. WHP/BHP/ECD: 155/3388/10.18 ppg. IA/OA/PVT: 35/10/396 bbls. Continue to drill ahead decreasing inclination. Drill tangent at 84 deg inc, then increase angle to 89-90 est at bit. PROD1 W iper trip to window. Log gr tie in. PROD1 Open EDC. Circulate out of hole. Close SSSV with 300 psi on well. PROD1 OOH, change motor bend to 1.1 deg and PU HTC BC bit PROD1 RIH Tied-in at 7199 ft (corrected -16 ft), RIH Closed EDC and ran in the open hole Having some trouble getting in the hole past 9,074 ft. TF turned 90L to 90R at 9,125 ft. Hole is ratty from 9,074 ft (C4) to 9320 ft This is the resistivity sepration area between 9,130 ft to 9,300 ft. Hole below 9,300 ft not bad PROD1 Tagged bottom at 9396 ft, orient TF to 120E deg. hole angle builds, dropped TF to 180 Drilling lateral in C3 Op = 1.61 / 1.60 bpm CTP = 3,370 / 3,650 psi WOB / ROP = 1.8k at 34 to 50 fph Vp 371 bbl's BHP 3436 psi at 10.32 ppg ECD A 12:109 hrs PU 60 ft at 9,466 ft. Took some work hard to get back to 9,466 ft This is the same vertical section only deeper that gave us trouble in the last lateral. (Siderite) Pulling 10 to 12k over and unsanle to get back to bottom. Took 30 minutes to get back to bottom at 9465 ft. PROD1 TF to 180E deg. Drilling lateral in C3 Op = 1.61 / 1.60 bpm CTP = 3,370 / 3,550 psi W OB / ROP = 1.8k at 34 to 50 fph.. CT wt at -5700 to - 6000 k Vp 368 bbl's BHP 3436 psi at 10.32 ppg ECD WHP = 200 to 150 psi Printed: 1/16/2007 70:32:30 AM BP AMERICA" Page 26 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 '.Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 IRig Name: NORDIC 2 Rig Number: Date From.- To Hours Task Code NPT Phase 1/4/2007 12:35 - 13:45 1.17 DRILL P PROD1 13:45 - 14:25 0.67 DRILL P PROD1 14:25 - 17:30 I 3.081 DRILL I P I I PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 19:30 1.00 DRILL P PROD1 19:30 - 22:30 I 3.001 DRILL I P I I PROD1 22:30 - 23:15 I 0.751 DRILL I P I I PROD1 23:15 - 00:00 0.75 DRILL P PROD1 1/5/2007 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01:00 0.25 DRILL P PROD1 01:00 - 03:15 2.25 DRILL P PROD1 03:15 - 05:00 I 1.751 DRILL I P I I PROD1 05:00 - 09:10 ~ 4.17 ~ DRILL ~ P ~ ~ PROD1 09:10 - 12:45 ~ 3.58 ~ DRILL ~ P ~ ~ PROD1 Description of Operations ROP 1 to 30 fph PU to 35k and restarted TF to 180E deg. Drilling lateral in C3 Unable to drop out of this with 180 deg TF. Op=1.61/1.60 bpm CTP = 3,370 / 3,550 psi WOB / ROP = 1.8k at 34 to 50 fph. CT wt at -5700 to - 6000 k Vp 365 bbl's BHP 3436 psi at 10.32 ppg ECD WHP = 150 psi ROP 1 to 50 fph POOH to change bit to a 2.73" M-09 and and a 1.3 deg AKO setting. Pulled tight at 9,308 ft. This hole is TF sensitivity Pulled clean above 9,400 ft. Close sssv with 300 psi on well. Flow check. Pull to surface. At surface. Flow check. Get off well. Unstab coil. LD BHA. Reverse circulate through coil. 1850 psi at 1.81 bpm. Reverse 10 bbls water followed by 15 bbls meoh. Cut 60' coil and 65' a-line. MU and test a-coil head. Displace water &meoh. Flow check well. MU lateral BHA with 1.3 motor angle M-09 bit. Stab coil. Test tools. Get on well. Agitator s/n: AGS218-59-114 Run in hole. Pressure well to 400 psi. Open sssv. Continue to RIH. Continue to run in hole. Log gr tie in from 7180'. Subtract 16' correction. Continue to run in hole. Maintain as drilled tool face. A few bobbles from 8700' to 8800'. Set down hard at 9380'. PU. Vary pump and TF. Got past 9380' at 90L and 1.0 bpm pump rate. Set down hard again at 9399'. PU and back ream to 9350'. RIH. Bounce past 9380', eventually get past 9399'. Set down again at 9477'. Might be bottom. Work past by varying pump rate, TF, and running speed. Tag bottom at 9,494'. (DHWOB and mtr work) Drill ahead. 3200 psi fs at 1.6 in! 1.65 out. 150-200 dpsi. DHWOB: 1.5-2.5k#. WHP/BHP/ECD: 99/3364/10.10 ppg. IA/OA/PVT: 0/5/333 bbls. TF: 185. NB Inc: 90.7. Drilling Lateral TF set at 165 to 180 deg Op =1.61 / 1.58 bpm CTP = 3350 / 3625 psi Vp = 332 bbl's ROP = 1-5 fph CTW = -7500 to -9000 k; DHWOB = 2-3k At 9,542 ft turned TF up to 60L to level out 6,418 ft w/ a 84 deg hole angle. Lowest angle = 83 deg ROP increased to 80 fph once leveled out. CTW = -3k Drilling Lateral TF set at 65L-90L-100E-HS - 45R TF Op =1.61 / 1.55 bpm CTP = 3350 / 3800 psi PVT = 320 bbl's ROP = 10-50 fph CTW = -300 to -5000 k; DHWOB = 1-2k Turned TF to HS to Printed: 1 /16/2007 10:32:30 AM • BP AMERICA Page 27 of 30 Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ___ _ I- __ ;-_ - --_ _ -- 1/5/2007 09:10 - 12:45 3.58 DRILL P PROD1 build up to 93 deg to level out at 6,418 ft TVD. Then carry this to 6,425 ft to TD 12:45 - 14:15 1.50 DRILL P PROD1 Wiper / backream open hole section from 9,650 ft to 9,000 ft Pulled tight 9600 ft, 9535 ft, 9425 ft, 9300 ft, 14:15 - 14:30 0.25 DRILL P PROD1 Pulled above WS ar 7751 ft. Isolated Swaco choke for 14:30 - 16:30 2.00 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 20:00 2.50 DRILL P PROD1 20:00 - 21:15 .1.25 DRILL P PROD1 21:15 - 23:15 2.00 DRILL P PROD1 23:15 - 00:00 0.75 DRILL P PROD1 1/6/2007 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 04:30 2.50 DRILL P PROD1 04:30 - 05:30 1.00 DRILL P PROD1 05:30 - 07:00 1.50 DRILL P PROD1 07:00 - 09:05 2.08 DRILL P PROD1 09:05 - 10:45 1.67 DRILL P PROD1 10:45 - 11:10 0.42 DRILL P PROD1 11:10 - 11:20 0.17 DRILL P PROD1 11:20 - 12:50 1.50 DRILL P PROD1 repairs. Nordic Electrician checking SCR 2 voltage as for AC leakage. SCR #2 is the cleanest SCR. RIH with correct drilled toolface. Took wt at 8,895 ft, 9,063 ft, 9,250 ft, 9,334 ft, 9,385 ft, 9,418 ft, 9,442 ft, 9500 ft (had to turn TF around, at stops) 9,600 ft Most of the tight spots seem to be TF changes. Drilling Lateral from 9650 ft Op =1.61 / 1.55 bpm CTP = 3350 / 3800 psi PVT = 291 bbl's ROP = fph CTW = -300 to -7 k; DHWOB = 1-2k Drill ahead from 9700'. 3500 psi fs at 1.59.in/1.54 out. 200 dpsi. DHWOB: 1-2k#. WHP/BHP/ECD: 100/3499/10.5 ppg. IA/OA/PVT: 73/13/281 bbls. ROP: 10-50 fph, depending on lithology. Unable to get WOB. Make several short wiper trips. Unable to get back to bottom. Back ream at 20 fph to window. Several overpulls from 9490 to 9350'. Run back in hole. Set down at 9290', 9400', 9533', 9590', 9640' to 9670', 9720'. Drill ahead f/ 9740'. 3600 psi fs at 1.58.in/1.52 out. 200 dpsi. DHWOB: 2-3k#. TF: 150R. NB Inc: 93 deg. Start 2 ppb alpine beads down hole. Continue to drill ahead from 9740'. Continue to trickle in beads. 8 - 9k CT down weight with beads around. Smooth CT pick ups. (26k#) Able to get 1- 1.5k# DHWOB. ROP is zero. Able to tag btm, but no progress or motor work. Wiper trip back to window. Continue to circulate 1-1.5 ppb beads (in case we run liner right here, as is). Log gr tie in from 7140'. Repeat tie in to verify. Add 27' correction. Current TD is 9791'. Circulate out of hole. Leave EDC closed due to beads. Checked agitator at surface, the agitator is working well while pumping through it at surface. Held PJSM conducted by SLB trainee (good job) Identified hazards and mitagated same. Checked flow, set back injector Changed out bit orienter and motor. Re run agitator #AGS218-59-114 RIH, replaced reel pin which broke while RIH. Open EDC at 800 ft. Lose 100 amp breaker which controls the lighting on the rig floor. Fixed every thing. Tagged the top of the Seal bore at 7,067 ft 1st time Tie-in at 7181 ft logging down RIH to 7700 ft and trap 400 psi on wellhead. Close EDC Set TF at 90L RIH with drilled TF orientation Tagged at 9,280 ft, 9,385 ft, 9,479 ft 9,513 ft; 9,548 ft, 9,580 ft, 9,607 ft, 9,624 ft, 9,716 ft Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 28 of 30 Operations Summary Report Legal Well Name: 1C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task. Code -NPT Phase Description of Operations 1/6/2007 11:20 - 12:50 1.50 DRILL P PROD1 Looking for bottom after CT correction after drilling to 9,763 ft. 12:50 - 14:30 ~ 1.67 ~ DRILL ~ P ~ ~ PROD1 14:30 - 14:45 ~ 0.25 ~ DRILL ~ P ~ (PROD1 14:45 - 16:25 1.67 DRILL N DFAL PROD1 16:25 - 16:45 0.33 DRILL N DFAL PROD1 16:45 - 18:30 I 1.751 DRILL I N I DFAL I PROD1 18:30 - 21:00 ~ 2.50 ~ DRILL ~ N ~ DFAL ~ PROD1 21:00 - 23:00 I 2.001 DRILL I N I DFAL I PROD1 23:00 - 00:00 1.00 DRILL N DFAL PROD1 1/7/2007 00:00 - 00:30 0.50 DRILL N DFAL PROD1 00:30 - 01:00 0.50 DRILL N DFAL PROD1 01:00 - 02:15 1.25 DRILL N DFAL PROD1 02:15 - 05:40 ~ 3.42 ~ DRILL ~ P ~ ~ PROD1 05:40 - 07:30 1.83 DRILL P PROD1 07:30 - 09:00 1.50 DRILL N DFAL PROD1 09:00 - 11:00 2.00 DRILL N DFAL PROD1 Tagged bottom at 9,782 ft Drilling Lateral from 9,782 ft at 90R TF. Mud swap once TD was reached. At 9,872 ft, turned TF to 135E TF Op =1.50 / 1.50 bpm CTP = 3,800 / 4,000 psi PVT = 320 bbl's (Mud Swap) ROP = 50 fph We are in the sweet spot in C3 Consistant drilling at 50 fph New mud help out WOB and slide CTW = 4-5 k; DHWOB = 1k Mini Wiper after turning the TF from 90R to 135E PUW = 25.4k Lost communication with Coiltrac. Trouble shoot and looks like its downhole POOH due to lack of tool comms. PUH to 7000 ft Trouble shoot Coiltrac electrical. Found parted wire injunction box, fixed and still have the short. POOH, testing SCR 2 under load on assigment 4 on driller's SCR pan. SCR tested good. At surface. Get off well. LD BHA tools. Test e-coil. Good test. Trouble shoot MWD. Found EDC was drawing a very high current load. Will need to be evaluated in Anchorage. Rest of tools ok. Replace resistivity tool due to hours. Test e-line again before stabbing coil. MU BHA assembly w/ same motor and HYC bi-cent bit. Stab coil. Test MW D tools. Get on well. Circ test agitator (# AGS218-59-114). Run in hole. Circ at min rate. Pressure well to 350 psi. Open sssv. Continue to RIH following WHP schedule. Continue to run in hole. Maintain WHP as per schedule. Log gr tie in from 7180'. Subtract 16' correction. Continue to RIH. Maintain as drilled TF. Tag at 9150', 9240', 9387'. Several tight spots from 9410' to 9600'. Pushing negative CT weight the whole way. Reduce pump rate from 1.60 in to 0.96 in. CT wt improved alot. (3-5K# positive) Negative CTW f/ 9730' to 9760'. Drill ahead. 3450 psi fs at 1.61 in/1.56 out. 200 dpsi. DHWOB: 2-3k#. WHP/BHP/ECD: 150/3470/10.11 ppg. IA/OA/PVT: 0/0/400 bbls. Incl/Azm/TF: 90.8/146/110L. ROP: 35 to 50 fph. Steady drilling in sand. Wiper trip before reaching TD. Lost communication with tool down hole. at 7,870 ft POOH to change out MWD components PJSM after tagging up. PJSM conducted with SLB trainee. Tested cable in reel and same results as yesterday 4 m ohms slowly falling down to 0.3 m ohms. LD Coiltrac MWO and check same. Trouble shoot Tool and found the EDC has shorted as before. Do not have a replacement at this time. 2-2-3/8" EDC are presently in Anchorge ready to ship. Looking for a charter plane to bring them up. Found Security Aviation Anchorage to fly BHI tools to Slope Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 29 of 30 Operations Summary Report ;Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Spud Date: 12/5/2006 Event Name: REENTER+COMPLETE Start: ~ 12/5/2006 End: 1/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date !From - To Hours I Task Code ~ NPT Phase, . Description of Operations 1/7/2007 11:00 - 15:10 4.17 DRILL N DFAL PROD1 Waiting on charter with tools from BHI Anchorage Megged cable and trouble shoot tools. Plane left at 13:00 hrs today and should arrive 15:00 hrs SLB checked chains. Plane landed at 15:00 hrs, BHI at airport unloading plane 15:10 - 16:30 1.33 DRILL N DFAL PROD1 PU tool to pipe shed. and MU tools on catwalk PU BHA and stab on the well 16:30 - 18:15 1.75 DRILL N DFAL PROD1 RIH to cleanout for liner 18:15 - 18:30 0.25 DRILL N DFAL PROD1 Log gr tie in f/ 7,180'. Subtract 16' correction. 18:30 - 20:00 1.50 DRILL N DFAL PROD1 Run in hole. Maintain as drilled TF. Hole in good condition to TD. A few tight spots. Tag TD at 10,000'. 20:00 - 20:45 0.75 DRILL P PROD1 Back ream out of hole at 1.61 bpm / 20 fpm to 9100'. Some tight spots, but mostly smooth. 20:45 - 21:15 0.50 DRILL P PROD1 RIH to 10,000'. POOH laying beads 1:1 21:15 - 00:00 2.75 DRILL P PROD1 POOH laying 2 ppb beads in new flopro at 1:1 displacement. 28k# up, 7k# do CT weight at 9900'. 1/8/2007 00:00 - 00:45 0.75 CASE P PROD1 Hold PJSM. At surface. Flow check. Get off well. LD drilling BHA assembly. 00:45 - 02:00 1.25 CASE P PROD1 Rig up floor to run liner. Bring Baker tools to pipe shed and rig floor. Hold detailed PJSM with all crews. Discuss well control & dropping pipe procedure. Job steps. Roles. And hazards of running & handling pipe. Discuss training of new hands, how and who will supervise and perform which tasks. 02:00 - 04:15 2.25 CASE P PROD1 MU 1 jt 2-3/8" solid and 40 2-3/8" slotted STL liner w/ indexing shoe & o-ring sub. 04:15 - 04:30 0.25 CASE P PROD1 Hold PJSM to discuss picking up the 1"CSH inner string. 04:30 - 07:45 3.25 CASE P PROD1 PU stinger. MU on 1"CSH work string. MU GS running tool, stab injector 07:45 - 09:55 2.17 CASE P PROD1 RIH with liner and 1"CSH inner string Wt check at 7730 ft = 28.4k hydraulic, 28 k electrical Tie-in at 8740 ft, corrected -18 ft Wt Check at 8740 ft (7169 ft) = 27.5 k 09:55 - 12:50 2.92 CASE P PROD1 Tagged up at 9,100 ft and worked down to 9,220 ft. Its hard. Tried several running speeds up to 150 fpm and its hard at 9,219 ft. Mixed up 40 bbl 2ppb bead pill and pumped down at 1.5 bpm Setting wt down on shoe while pumping beads at 1.40 bpm at 3,300 psi CTP. Worked down to 9,987 ft using various running speeds up to 160 fpm and -9k down weight PU to 99927 ft to try and get the 13 ft and it didn't move past 9927 ft MD 12:50 - 13:55 1.08 CASE P PROD1 Released from liner. POOH to tie-in 13:55 - 14:10 0.25 CASE P PROD1 PUH logging tie-in at 8480 ft Correction at +17 ft + 3 ft 14:10 - 15:40 1.50 CASE P PROD1 POOH. 15:40 - 18:00 2.33 CASE P PROD1 At surface. Get off well. LD BHA. Stand back CSH in derrick. 18:00 - 18:30 0.50 CASE P PROD1 Hold PJSM after crew change. Review running liner procedure & THA for same. 18:30 - 20:30 2.00 CASE P PROD1 MU 26 jts 2-3/8" 4.6# STL liner (21 sltd, 5 solid) with drillable guide shoe and o-ring sub. 20:30 - 21:00 0.50 CASE P PROD1 MU Inteq MWD BHA with GS spear assembly. Stab coil. Get on well. 21:00 - 22:30 1.50 CASE P PROD1 Run in hole. Maintain WHP as per schedule. 22:30 - 23:00 0.50 CASE P PROD1 Log gr tie in from 7180'. Subtract 17' correction. 23:00 - 23:45 0.75 CASE P PROD1 Run in hole. 9k# dn, 28.5k# up wt at 8600'. Tag top of liner Printed: 1/16/2007 10:32:30 AM • BP AMERICA Page 30 of 30 .Operations Summary Report i, Legal Well Name: 1 C-01 Common W Event Name Contractor Rig Name: Date ell Name: 1 : R Name: N N From - To C-01 EENTE ORDIC ORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig N Phase Spud Date: 12/5/2006 : ~ 12!5/2006 End: 1/9/2007 Release: 1/9/2007 umber: Description of Operations 1/8/2007 23:00 - 23:45 0.75 CASE P PROD1 section #1 (lower) at 8632'. PU to 8590'. RIH to 8605', This puts TOL section #2 at 7763'. Circulate at 1.55 bpm at 3650 psi. PU. CT up wt: 24.5k#. Lost 3k#. Appear to have released. Pull up hole. 23:45 - 00:00 0.25 CASE P PROD1 Log gr tie again from 7180' to verify liner top setting depth. Add 2' correction. 1/9/2007 00:00 - 01:45 1.75 CASE P PROD1 Pull out of hole. Maintain WHP as per schedule. Close sssv with 400 psi on well. POH to surface. 01:45 - 02:30 0.75 CASE P PROD1 Get off well. LD liner running BHA. 02:30 - 03:00 0.50 FISH P PROD1 MU whipstock retrieval BHA. MU orienter on MWD tools. Scribe Baker whipstock hook to BHA. Hook latch is oriented 90L with 90R TF. 03:00 - 04:30 1.50 FISH P PROD1 Stab coil. Test tools. Get on well. RIH. Open SSSV. Continue to run in hole. 04:30 - 05:00 0.50 FISH P PROD1 Log gr tie in. Subtract 16' correction. 05:00 - 05:45 0.75 FISH P PROD1 Run in hole. 11 k# dn, 23k# up wt. RIH to 7,760. No tag. Try again. No tag to 7,762'. Orient hook to 135R. RIH. Tag at 7758'. PU and had 12k# overpull to 36k#. Appear to have WS. Open EDC. 05:45 - 07:30 1.75 FISH P PROD1 Pull out of hole. Maintain WHP as per schedule. 07:30 - 07:45 0.25 FISH P PROD1 OOH, PJSM and monitor well with closed SSSV (400 psi trapped) 07:45 - 09:00 1.25 FISH P PROD1 Recovered WS, LD same Change out BHA to 2.5" nozzle BHA with CV and EDC 09:00 - 13:40 4.67 FISH P PROD1 RIH with 2.5" nozzle to 7000 tt T= -38 deg F PUH laying in SW to 2200 ft. RU LRS and pumped 40 bbl diesel and FP the 4-1/2" from 2200 ft to surface. PUH laying in diesel to surface. Reverse circulated 15 bbl MEOH back through CT 13:40 - 19:00 5.33 WHSUR P POST Circulate diesel to tiger tank. Reverse circulated 15 bbl MEOH back through CT. RU to blow down CT to TT. Pumped 15 bbl MEOH down CT Set BPV Clean and vac pits, cuttings box and tiger tank 19:00 - 21:00 2.00 W HSUR P POST Blow down N2 and 15 bbl of MEOH to tiger tank 21:00 - 00:00 3.00 WHSUR P POST ND 7-1/16" ROPE. NU tree cap and PT @ 4000 Rig release at 2400 hrs 1/9/07 Further entries on 2Z-13 Printed: 1/16/2007 10:32:30 AM by ~ BP Alaska Baker Hu hes INTE a Re g Q Surv y port ~ii~~ iNTEQ Company: BP Amoco Date: 1/10/2007 Time: 16:12:25 Page: 1 Field: Kuparuk Co-ordinate(NE) Reference: Well: 01, True North Site: KRU 1 C Pad Vertical (TVD) Reference: 1 C-01 94.0 Well: 01 Section (VS) Reference: Well (O.OON,O.OOE,117.37Azi) Wellpath: 1 C-01 Li -03 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk 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 Site: KRU iC Pad UNITED STATES :North Slope Site Position: Northing: 5968605.00 ft Latitude: 70 19 29.107 N From: Map Fasting: 562247.20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 01 Slot Name: Well Position: +N/-S -83.48 ft Northing: 5968522.56 ft Latitude: 70 19 28.286 N +E/-W 124.19 ft Fasting : 562372.07 ft Longitude: 149 29 39293 W Position Uncertainty: 0.00 ft Wellpath: 1 C-01 Li -03 Drilled From: 1 C-01 L1-01 50-029-20526-63 Tie-on Depth: 8325.08 ft Current Datum: 1 C-01 Height 94.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/2/2007 Declination: 23.71 deg Field Strength: 57622 nT Mag Dip Angle: 80.86 deg Vertical Section: Depth From (TVD) +N/-S +FJ-W Direction ft ft ft deg 94.00 0.00 0.00 117.37 Survey Program for DeSnitive Weltpath Date: 1/2/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 500.00 7100.00 Gyro (500.00-7780.00) (0) CB-GYRO-MS Camera based gyro multishot 7175.00 7734.58 MW D (7175.00-9010.00) (1) MW D MW D -Standard 7750.90 8325.08 MW D (7750.90-9345.00) (2) MW D MW D -Standard 8353.00 10000.00 MW D (8353.00-10000.00) MW D MW D -Standard Annotation b1D TVD ft ft 8325.08 6531.69 TIP 8353.00 6529.25 KOP 10000.00 6514.77 TD Survey: MW D Start Date: 1 /8/2007 Company: Baker Hughes INTEO Engineer. Tool: MW D;MW D -Standard Tied-to: From: Definitive Path ,Z©~- ~~3 by # BP Alaska. ~ s Baker Hu hes INTE Surve Re ort g Q 3' p iNTEQ ~- Company: BP Amoco Date: i/f0/2007 Tim e: 16:12:25 Page: 2 Fyeld: Kuparuk Co-ordinate(NE) R eference: Well: 01, True North Site: KR U 1 C Pad Vertical (TVD) Reference: 1 C-01 94.0 Well: 01 Sectio n (VS) Reference: Well (O.OON,O.OOE,117.37Azi) Wellpath: 1 C-01 Li -03 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Atim TVD Sys TVD N/S EJW MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100 ft 8325.08 94.32 185.31 6531.69 6437.69 -501.23 2671.70 5968043.60 565047.59 2603.03 0.00 MW D 8353.00 95.72 189.01 6529.25 6435.25 -528.82 2668.23 5968015.99 565044.35 2612.64 14.12 MW D 8388.01 95.98 180.00 6525.68 6431.68 -563.50 2665.50 5967981.28 565041.91 2626.16 25.61 MW D 8418.18 93.11 173.52 6523.28 6429.28 -593.51 2667.20 5967951.29 565043.86 2641.46 23.43 MW D 8448.38 91.70 170.76 6522.01 6428.01 -623.40 2671.33 5967921.45 565048.23 2658.87 10.26 MWD 8479.27 89.62 166.25 6521.66 6427.66 -653.66 2677.48 5967891.24 565054.64 2678.24 16.08 MW D 8508.98 89.46 162.02 6521.90 6427.90 -682.23 2685.60 5967862.74 565062.99 2698.59 14.25 MW D 8542.29 90.91 157.58 6521.79 6427.79 -713.48 2697.10 5967831.59 565074.75 2723.17 14.02 MW D 8574.19 89.22 152.01 6521.75 6427.75 -742.33 2710.68 5967802.86 565088.57 2748.49 18.25 MW D 8605.43 91.46 151.12 6521.57 6427.57 -769.80 2725.55 5967775.51 565103.67 2774.33 7.72 MW D 8634.92 93.21 155.90 6520.37 6426.37 -796.16 2738.69 5967749.26 565117.02 2798.12 17.25 MW D 8663.58 93.49 160.15 6518.69 6424.69 -822.69 2749.40 5967722.83 565127.95 2819.82 14.84 MW D 8693.48 94.32 164.55 6516.65 6422.65 -851.11 2758.44 5967694.49 565137.22 2840.92 14.94 MW D 8725.72 91.12 169.59 6515.12 6421.12 -882.48 2765.64 5967663.18 565144.68 2861.74 18.50 MW D 8763.48 89.31 175.78 6514.98 6420.98 -919.91 2770.45 5967625.79 565149.80 2883.21 17.08 MW D 8793.48 89.59 172.03 6515.27 6421.27 -949.74 2773.63 5967596.00 565153.23 2899.75 12.53 MWD 8826.36 90.60 166.13 6515.21 6421.21 -982.00 2779.86 5967563.79 565159.73 2920.12 18.20 MW D 8855.10 93.98 162.40 6514.07 6420.07 -1009.64 2787.64 5967536.22 565167.74 2939.74 17.51 MW D 8886.89 96.69 158.39 6511.11 6417,11 -1039.45 2798.25 5967506.50 565178.60 2962.87 15.18 MWD 8916.79 93.76 150.96 6508.38 6414.38 -1066.34 2810.98 5967479.72 565191.55 2986.54 26.61 MWD 8945.98 89.16 144.05 6507.64 6413.64 -1090.93 2826.65 5967455.27 565207.42 3011.75 28.43 MW D 8972.96 92.81 141.12 6507.17 6413.17 -1112.35 2843.03 5967433.99 565223.98 3036.15 17.35 MWD 9004.06 93.09 136.90 6505.57 6411.57 -1135.78 2863.40 5967410.72 565244.54 3065.01 13.58 MW.D 9033.25 91.80 132.78 6504.33 6410.33 -1156.34 2884.08 5967390.34 565265.38 3092.83 14.78 MWD 9062.21 89.74 126.01 6503.94 6409.94 -1174.71 2906.44 5967372.16 565287.90 3121.13 24.43 MW D 9107.92 87.74 128.84 6504.94 6410.94 -1202.48 2942.73 5967344.70 565324.41 3166.12 7.58 MW D 9137.27 88.17 133.14 6505.99 6411.99 -1221.71 2964.86 5967325.65 565346.70 3194.62 14.71 MWD 9167.09 91.92 140.96 6505.97 6411.97 -1243.52 2985.16 5967304.01 565367.18 3222.67 29.08 MW D 9196.90 91.40 145.69 6505.10 6411.10 -1267.41 3002.95 5967280.27 565385.17 3249.46 15.96 MW D 9226.53 90.91 149.78 6504.51 6410.51 -1292.45 3018.76 5967255.36 565401.18 3275.01 13.90 MW D 9257.23 91.00 152.17 6503.99 6409.99 -1319.29 3033.66 5967228.65 565416.30 3300.58 7.79 MW D 9289.30 90.44 154.37 6503.59 6409.59 -1347.93 3048.08 5967200.14 565430.95 3326.55 7.08 MW D 9318.99 83.87 149.01 6505.06 6411.06 -1374.02 3062.12 5967174.17 565445.22 3351.02 28.54 MW D 9348.84 85.75 141.82 6507.77 6413.77 -1398.47 3078.99 5967149.86 565462.28 3377.24 24.80 MW D 9378.15 89.77 135.18 6508.91 6414.91 -1420.39 3098.38 5967128.11 565481.85 3404.54 26.46 MWD 9408.50 91.61 129.84 6508.55 6414.55 -1440.89 3120.74 5967107.80 565504.38 3433.82 18.61 MWD 9438.20 90.72 131.20 6507.95 6413.95 -1460.18 3143.32 5967088.70 565527.11 3462.73 5.47 MWD 9467.40 90.38 131.13 6507.67 6413.67 -1479.40 3165.30 5967069.66 565549.25 3491.09 1.19 MWD 9497.57 89.77 132.40 6507.63 6413.63 -1499.49 3187.80 5967049.76 565571.92 3520.31 4.67 MW D 9526.93 83.13 131.76 6509.44 6415.44 -1519.12 3209.54 5967030.31 565593.82 3548.64 22.72 MW D 9556.75 84.49 126.00 6512.66 6418.66 -1537.72 3232.61 5967011.91 565617.04 3577.68 19.74 MW D 9592.80 86.02 119.80 6515.65 6421.65 -1557.22 3262.76 5966992.66 565647.34 3613.42 17.66 MW D 9626.61 87.71 109.49 6517.50 6423.50 -1571.28 3293.40 5966978.86 565678.10 3647.09 30.85 MW D 9655.35 93.52 112.54 6517.19 6423.19 -1581.58 3320.21 5966968.78 565704.99 3675.64 22.83 MW D 9688.31 93.98 120.66 6515.03 6421.03 -1596.29 3349.59 5966954.31 565734.50 3708.50 24.62 MW D 9718.49 94.16 129.09 6512.89 6418.89 -1613.49 3374.27 5966937.33 565759.31 3738.31 27.87 MW D 9753.57 91.58 131.04 6511.13 6417.13 -1636.04 3401.08 5966915.00 565786.30 3772.49 9.21 MW D 9783.66 90.69 139.46 6510.53 6416.53 -1657.38 3422.24 5966893.83 565807.64 3801.10 28.13 MW D 9818.45 89.28 145.49 6510.54 6416.54 -1684.96 3443.42 5966866.44 565829.05 3832.58 17.80 MW D 9847.86 88.91 151.00 6511.01 6417.01 -1709.96 3458.89 5966841.57 565844.72 3857.81 18.77 MWD 9877.75 87.01 153.22 6512.07 6418.07 -1736.35 3472.86 5966815.29 565858.91 3882.36 9.77 MW D 9907.47 87.16 148.22 6513.58 6419.58 -1762.24 3487.37 5966789.54 565873.64 3907.14 16.81 MW D 9938.03 88.85 144.15 6514.65 6420.65 -1787.60 3504.37 5966764.31 565890.84 3933.90 14.41 MW D . by BP Alaska ~ s ~k r H a e ughes INTEQ Survey Report uvTEQ Company: BP Amoco Date: 1/10/2007 'Lym e: 16:12:25 Page: 3 Feld: Kuparuk Site: KRU 1C Pad Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 01, True North iC-01 94.0 Well: 01 Section(VS)Reference: Well (O.OON,O.OOE,117.37Azi) Wellpath: 1 C-01 Li-03 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 9966.79 90.20 138.57 6514.89 6420.89 -1810.06 3522.32 5966742.01 565908.97 3960.16 19.96 MWD 10000.00 90.20 138.57 6514.77 6420.77 -1834.96 3544.29 5966717.30 565931.15 3991.12 0.00 MW D i .' KRU 1C-01 L1, L1-01, L1-02, L1-03 Producer C-sand CTD Completion Updated 1/11/2007 10-3/4" shoe 3-3/16" liner top @ 7060', stu into 3.75" sealbore X-profile at 7082' I D = 2.813" 4-'/2 x T Baker Thru-tubing i -~. L1-01 southeast lateral flow-by whipstock at7175' ' ~~ TD @ 9355' ~ ~~;~-'' (50-029-20526-61) ' -' " ~' 2-3/8" slotted liner ~ L1-03 southeast lateral TD @ 10,000' C sand (50-029-20526-63) perforations Aluminum billet @ 8355' and 7" shoe • 4-'/2' SSSV set at 2040' • 4-1/2" 12.6# L-80 IBT Mod tubing w/ 4-1/2" x 1"gas lift mandrels (five) • 4 '/~" x 7" packer at 6965' • Baker CMU sliding sleeve @ 7020' (closed) • 6' sealbore with 3.75" ID at 7068' • 4-1/2" tubing tail at 7078' • Windauv in T' 26# J55 casing @ 717T and 2-3/8" liner top @ 8008' 3-3/16 shoe @ 8054' I (cemented) Aluminum Jaillet @ 8202' L1 southwest C4 later TD @ 9010' --~ ~-- 2-3/8" liner top @ 7763' Drillable aluminum insert @ 8846' 2-3/8" slotted liner ~~~1=====__-=_-_ L1-02 southwest C3/C4 lateral TD @ 9760' (50-029-20526-62) KRU 1 C-O1 System of Lateral Wellbores Current Wellbore Names NOTE: Final wellbore names selected by the operator and shown herein do not match the actual order of drilling and casing operations for the 1C-O1 system of laterals (see attached slide)! 1C-O1L1-O1: Not directly accessible from surface TD of 9355' MD (6498' TVD) reached on 12-31-2006 2-3/8" liner run to 9353' MD (6497' TVD) on 1-1-2007 Top of 2-3/8" liner at 8355' MD (629' TVD) 1C-O1L1-02: Accessible from surface Top Window at 7181' MD (6468' TVD) • 1C-O1L1-02: Accessible from surface TD of 9760' MD (6460' TVD) reached on 12-26-2006 2-3/8" liner run to 9724' MD (6468' TVD) on 12-27-2006 Top of 2-3/8"liner at 8202' MD (6541' TVD) 1C-O1L1-03: Not accessible from surface TD of 10000' MD (6515' TVD) reached on 1-7-2007 1C-O1L1: Not directly accessible from surface 2-3/8" liner run to 9933' MD (6515' TVD) on 1-8-2007; no TD of 9010' MD (6491' TVD) reached on 12-18-2006 junction, liner dropped off at 7763' MD (665' TVD) 2-3/8" liner rim to 9010' MD (6491' TVD) on 12-19-2006 outside of window at 7751' MD (6566' TVD). Top Window at 7751' MD (666' TVD) Kuu lc-ol • 070212_KRU_ 1 C-0l _Lateral_System.ppt SFD 2-12-2007 KRU 1C-O1 System of Lateral Wellbores Order of Operations KRU 1C-Ol 6. I C-0 I L l -O l :Top Window at 775 I' M D (6566' TVD) , milled on 12-28-06; new formation drilled on 12-28-06 7. l C-0l L 1-01: Not directly accessible from surface TD of 9355' MD (6498' TVD) reached on 12-31-2006 2-3/8" liner run to 9353' MD (6497' TVD) on 1-1-2007, top of 2-3/8" liner at 8355' MD (6529' TVD) 8. 1C-O1 L1-03: OH sidetrack began drilling at 8353' MD (6529' TVD) on 1-1-2007 . / 9. 1C-O1L1-03: Not directly accessible from surface VVV TD of 10000' MD (6515' TVD) reached on 1-7-2007 2-3/8" liner run to 9933' MD (6515' TVD) on 1-8-2007; no junction, liner dropped off at 7763' MD (6565' TVD) outside of window at 7751' MD (6566' TVD). 1. Beginning of System of Laterals: Top Window at 7181' MD (6468' TVD), milled on 12-7-06; New formation drilled on 12-8-06 2. Liner point: Liner point of 8160' MD (6544' TVD) reached on 12-10-2006; 3-3/16" liner run on 12-10-2006, with shoe at 8054' MD (6551' TVD) 3. 1 C-01 L 1: Not directly accessible from surface TD of 9010' MD (6491' TVD) reached on 12-t 8-2006 2-3/8" liner run to 9010' MD (6491' TVD) on 12-19-2006 4. 1C-O1L1-02: OH sidetrack began drilling at 8200' MD (6541' TVD) on 12-21-2006 5. 1 C-01 L 1-02: Accessible from surface TD of 9760' MD (6460' TVD) reached on 12-26-2006 2-3/8" liner run to 9724' MD (6468' TVD) on 12-27-2006 • 070212_KRU_ I C-01 _Lateral_Systemppt SFD 2-12-2007 a ~s®.i-7~l~i~li®id ii®S~I®1` Aras Worthington Ct Drilling Engineer ConocoPhillips (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Pool, 1 C-01 L 1-03 ConocoPhillips (Alaska), Inc. Permit No: 207-003 Surface Location: 1718' FNL, 1364' FWL, Sec. 12, T 11 N, R 10E, UM Bottomhole Location: 3630' FNL, 283' FEL, Sec. 12, T 11 N, R 10E, UM Dear Mr. Worthington: 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 1C-01, Permit No 180- 128, API 50-029-20526-00. 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, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). incer , Daniel T. Seamount, Jr. _`l~ ' Commissioner DATED this ~ day of January, 2007 SARAH PALIN, GOVERNOR cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI~ PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ~ ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil • ^ Single Zone 1 c. Specify if well is prop ^ Coalbed Methane IJ Gasytfrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ` 11. Well Name and Number: Kuparuk 1C-01L1-03 ' 3. Address: do P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10100 • TVD 6425ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section}: Surface: 1718' FNL 1364' FWL SEC 12 T11N R10E UM' 7. Property Designation: ADL 025649 River Pool , , . , , , Top of Productive Horizon: 1202' FNL, 1458' FEL, SEC. 12, T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: In Progress • Total Depth: 3630' FNL, 283' FEL, SEC. 12, T11N, R10E, UM 9. Acres in Property: 2560 ~ 14. Distance to Nearest Property: 9700' 4b. Location of Well (State Base Plane Coordinates): Surface: x-562372 ~ y-5968523 Zone-ASP4 10. KB Elevation (Height above GL}: 94 feet 15. Distance to Nearest well Within Pool: 1450' 16. Deviated Wells: Kickoff Depth: 8355 ' feet Maximum Hole An le: 97 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3252 ' Surface: 2606 ' 18. asin Pr ram: S cifiCations To - S ttin D th -Bo ttom uan it of Cement c.f. or saGcs Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2349' 7751' ~ 6472' 10100'• 6425' Uncement d Slo ed Liner 19. PRESE NT WELL CONDITION SUMMARY (To tae completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9355 Total Depth TVD (ft): Plugs (measured): 6410 None Effective Depth MD (ft): 9355 Effective Depth TVD (ft): 6410 Junk (measured): None asing Lengttr ize Cement Volume MD Conductor /Structural Surface 80' 16" 200 sx Permafrost 80' 80' Intermediate 2704' 10-3/4" 1350 sx Fondu 250 sx AS II 2798' 2683' Pr i n 7664' 7" 4 sx Cl ss ' 7758' 7 2 ' Liner 1036' 3-3116" 15 sx Class 'G' 7064' - 8100' 6260' -6449' Liner L1 810' 2-3/8" Uncemented Slotted Liner 8200' - 9010' 6443' -6428' Lin r L1- 2 1747' 2-3/8" Uncemented Slotted Liner 8 1 ' - 97 645 ' - 66' Liner L1-01 1000' 2-3/8" Uncemented Slotted Liner 8355' - 9355' 6436' -6410' Perforation Depth MD (ft): Slotted Liner Perforation Depth TVD (ft): Slotted Liner 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Aras Worthington, 564-4102 Printed Name Aras rthington Title CT Drilling Engineer Prepared ey Name/Number: Si nature ~ y~n0~ Phone 564-4102 Date / ~,~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~~"~3 API Number: 50-029-20526-63-00 Permit Approval Da e: ~ b~ See cover letter for oth rre it m nts Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed met.,h/ane, gas hydrates, or gas contained shales: ~,/ Samples Req'd: ^ es LrJ No Mud Log Req'd: ^ Yes Lid No i ~~- ~~PC ~p 3~ ~ t.~, y~.~,~, y~,j,w~.tgy„t HZS Measures: ~es ^ No Directional Survey Req'd: Yes ^ No Other: ~WY S u ~ t ~v ZO I`~f~`L c,S • d 3 ~ C i' ~ +~fcit.~ ~ ~~~A 4M f!~ r~ (~C,/k~o ~•,1 S C~:I1,Q I. / h~ tl~ ~ . Date ~ ~ APPROVED BY THE COMMISSION COMMISSIONER Form 1-401 Revised 12/20t15 Submi In Duplicate ~~'/.r.p .SAN ~ 4 2007 'on 1 C-01 L1-02 & 1 C-01 L1-03 Sidetrack Laterals Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling unit will drill two laterals from producer KRU 1 C-01 using the managed pressure drilling technique. These horizontal laterals will target Kuparuk C4 and C3 sand reserves for increased pattern throughput. The 1C-01L1 will be a 2525' lateral drilled to the southwest, and the 1C-O1L101 will be a 2350' lateral kicked off from the 1 C-O1 L1 and drilled to the southeast. A pre-CTD workover has been performed to equip the well with 4%2" tubing and a SCSSV which will serve as a deployment valve during CTD operations. Update: An additional lateral, 1 C-01 L 1-02 was added to the 1 C-0l L1 southwest lateral and completed with slotted liner. Lateral 1C-O1L1 has been also been drilled and completed. During the drilling of 1C-O1L1-01 southeast lateral, hole conditions prompted sidetracking the wellbore, requiring another yet-to-be permitted lateral named 1 C-01 L 1-03. 1C-Ol CTD Drill and Complete Program: Planned for 9ctehe~December, 2006: Pre-CTD Prep Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs - T & IC. 3. Slickline dummy GLV's and pull plug in tailpipe of packer. 4. MIT-IA, MIT-OA. 5. Caliper 7" casing using PDS' 40-arm memory caliper. 6. Drift tubing/liner with dummy whipstock. 7. Set 4%" flow-through whipstock on a-line at 7175' MD at an orientation of 30° right of highside. CTD Rig Work (Completed as of 1/05/06) 1. MIRU Nordic Rig #2 using 23/8" coil tubing. NU 7-1/16" BOPE, test. Z. Mi113.74" window and 10' of open hole at 7175' MD. 3. Drill the 1 C-01 L 1 trunk lateral to the southwest with a 3.70" x 4'/8" bi-center bit from the window to X8100' TD up to the base of the Kuparuk C3 sand. 4. Run a 3-3/16" solid liner from TD up into the 4%z" tubing tail at 7064' MD. The top of the liner will be suspended from a 3.75" sealbore in the 4%z" tubing tail in order to provide isolation from the open perfs in the original 1 C-01 wellbore. 5. Pump a 3 to 4 bbl "puddle" cement job around the 3-3/16" liner. 6. Close the 4%2" sliding sleeve above the 3.75" sealbore to finish isolating the 1C-O1 perfs. 7. Swap reel to 2" coil tubing and 23/8" BHA. Change pipe rams, retest BOPE. 8. Drill out the 3-3/16" float and shoe and 20' of new formation. 9. Drill the remaining portion of the L1 lateral with a 2.70" x 3" bi-center bit to 9010' MD targeting C3 and C4 sands. Hole problems were encountered and the D-shale was intercepted. Decided to TD the lateral @ 9010' MD, run liner and an aluminum billet top, and sidetrack to drill L 1-021ateral. ,~ ,~ ~;~:,..,r* i„~~o~ , o o „+o..oa ;,, a..:~i;..,. +~o r , i.,+o,..,i. Was not required. 11. Drill L1-021ateral to 9760' md. Ran 2 3/8" liner to TD with liner top @ 8013'. 12. Set whipstock in 3 3/16" liner @ 7750' md. 13. Mill a 2.74" window in the 3-3/16" liner plus 10' of open hole to 7760' MD. 14. Drill L1-O1 lateral to 9355' md. Terminate drilling due to deteriorating hole conditions from 8800' and to 9355. Run 2-3/8" slotted liner with aluminum billet top @ 8355' md. Kick off billet. Page 1 of 5 October 2, 2006, FINAL • 1 C-01 L1-02 & 1 C-01 L1-03 Sidetrack Laterals Coiled Tubing Drilling 15. Sidetracked off of aluminum billet in L1-O1 to drill L1-03. Currently drilling ahead @ 9400' md, planned to 10,100' md. Page 2 of 5 October 2, 2006, FINAL C 1 C-01 L1-02 & 1 C-01 L1-03 Sidetrack Laterals Coiled Tubing Drilling CTD Rig Work (Remaining) 16. Dri11 the L1-03 lateral to the southeast with a 2.70" x 3" bi-center bit to 10,100' MD targeting C3 and C4 sands. 17. Complete L1-03 lateral with 2 3/8" slotted liner to TD and with the top of the liner spotted 5'- 10' outside the window to allow retrieval of the thru-tubing whipstock. 18. Pull the whipstock in the 3-3/16" liner at 7750' MD. 19. ND BOPE. RDMO Nordic 2. Post-CTD Rig Work 1. Pull the inflatable bridge plug in the 3-3/16" liner (if one was run). 2. Run GLVs, obtain static BHP. Leave the sliding sleeve above the 3-3/16" liner top closed for the time being to monitor production exclusively from the new laterals. Mud Program• • Steps 2, 8, & 12 (CTD): chloride-based Biozan brine (8.6 ppg) ~ • Steps 3, & 9-18 (CTD): chloride-based Flo-Pro mud (8.6 ppg) Disposal• • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well ' • Class II drill solids to Grind & Inject at PBU Drill site 4 Class I wastes will go to Pad 3 for disposal. Casing Program• • 1C-OILI trunk: 3-3/16", 6.2#, L-80, TC-II solid liner from 7064' MD to 8100' MD • 1C-O1L1: 23/8", 4.6#, L-80, STL slotted liner from 8200' MD to 9010' MD w/ Al billet top • 1C-O1L1-02: 23/8", 4.6#, L-80, STL slotted liner from 8013' MD to 9760' MD • 1C-O1L101: 23/8", 4.6#, L-80, STL slotted liner from 8355' MD to 9355' MD w/ Al billet top • 1 C-0l L103: 23/8", 4.6#, L-80, STL slotted liner from 7751' MD to 10,100' MD ' Existing Casing/Liner Information Surface: 103/", K-55, 45.5# Burst 3580 psi; Collapse 2090 psi. Production: 7", K-55, 26# Burst 4980 psi; Collapse 4320 psi Well Control• • Two well bore volumes 0320 bbl) of KWF will be location during drilling operations. • BOP diagrams are attached for operations with 2" and 23/a" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure is 2606 psi assuming a gas gradient to surface and original formation pressure. • The annular preventer will be tested to 400 psi and 2500 psi. Directional• • See attached directional plans for 1C-O1L1 and 1C-O1L101. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. The nearest well to the proposed 1C-O1L101 lateral is 1C-21L1 which is offset by approximately 1450'. The nearest well to the 1C-O1L1 lateral is 1C-02 at 1930' away. The KRU boundary is 9700' away. Logging• Page 3 of 5 October 2, 2006, FINAL • 1 C-01 L1-02 & 1 C-01 L1-03 Sidetrack Laterals Coiled Tubing Drilling • MWD directional, resistivity, and gamma ray will be run over the entire open hole section in both laterals. Drilling Hazards: • Lost circulation is a risk due to fault crossings and potential thief zones in the basal C4 sand. The completion is configured so that the existing perfs in the mother bore will be isolated when the 3-3/16" liner is set in the trunk lateral prior to drilling the productive portion of L1. Furthermore, if losses are encountered while drilling the L1 lateral, that particular hole section can be isolated during drilling of the L101 lateral. • The risk of encountering excess pressure while drilling a fault crossing is considered low. The pressure differential between the 1C-O1 laterals and offset injection wells is expected to be less than 500 psi. • Well 1C-O1 has a HZS reading of 120 ppm as measured on 6/18/06. Well 1C-27 is the nearest wellhead to 1C-O1, and it has 80 ppm HZS as measured on 07/23/05. All HZS monitoring equipment will be operational. Reservoir Pressure: • The most recent static BHP survey in well 1 C-O1 was taken in September 2006 after the well had been shut-in for 5 days. The measured reservoir pressure was 3085 psi at 6456' TVD which corresponds to 9.2 ppg EMW. Expect to encounter similar or increasing formation pressure as the laterals are drilled away from the mother well. Maximum expected pressure is 32_52 psi (original reservoir pressure) which corresponds to an EMW of 9.7 ppg at 6456' TVD (top of C4 perfs). Maximum potential surface pressure with gas (assume 0.1 psi/ft gradient) to surface is 2606 psi. Variance request: • ConocoPhillips requests a variance to 20 AAC 25.036(d)(4) regarding the requirement to function pressure test ram-type BOP equipment after using such for purposes other than well control. The variance will not apply when the use of ram-type BOP equipment may have compromised their effectiveness, such as if the pipe rams are inadvertently closed on a tool joint during routine operations. While drilling the 1 C-01 laterals it will be routine to close the 23/8" or variable combi-rams (i.e. pipe/slip rams. Specific size dependent upon the size of coil tubing being used) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling: Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. However, actual well conditions (ex: drilling mud adequately overbalances formation pressure and the hole is stable) may not necessarily require pressure deployment. This well will be equipped with a tubing retrievable subsurface safety valve following the pre-CTD workover. As a contingency, pressure deployment of the BHA may be accomplished utilizing the BOP pipe/slips (i.e. 23/8" or variable rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Page 4 of 5 October 2, 2006, FINAL • C 1 C-01 L1-02 & 1 C-01 L1-03 Sidetrack Laterals Coiled Tubing Drilling Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3127 psi at 6537' TVD, or 9.2 ppg EMW. - • Expected annular friction losses while circulating: 606 psi (assuming friction of 60 psi/1000 ft). • Planned mud density: 8 6 ppg equates to 2923 psi hydrostatic bottom hole pressure at 6537' TVD • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3529 psi or 10.4 ppg ECD. - • When circulation is stopped, it is anticipated that an additional 204 psi of surface pressure shall have to be applied to balance reservoir pressure. Page 5 of 5 October 2, 2006, FINAL KRU 1C-01 L1, L1-01, L1-02, L1-03 Producer C-sand CTD Completion 10-3/4" J shoe 3-3/16" liner top @ 7060', stabbed into sealbore L1-01 north lateral TD @ 9355' (50-029-20526-61) 2-3/8" slotted liner L1-03 North lateral ro osed TD @ 10 100' and -- 4-''/z x 7' Baker Thru-tu flow-by whipstock P P / C sand (50-029-20526-63) Aluminum billet Perforations @ 8355' and I i `. `. ~~_~__ i ,, ~, • 4-'/z' SSSV set at 2040' • 4-1/2" 12.6# L-80 IBT Mod tubing w/ 4-1 /2" x 1-1/2" gas lift mandrels • 4-''/2' x 7" packer at 6967' • Baker CMU sliding sleeve @ 7021' • 6' sealbore with 3.75" ID at 7064' • 4-1/2" tubing tail at 7070' Winda/v in 7' 26# J55 casaig ~ @ 717T and Baker retrievable flow-by monobore whipstock @ 7750' Aluminum billet @ 8200' and • 2-3/8" liner top @ 8013' L1 southwest C4 lateral TD @ 9010' ~';'~ 50-029-20526-60 ---- _~~ •a -- -------- ~; 2-3/8" slotted liner 2-3/8" liner i top@7751'- ~~ ____ ____ ___ 3-3/16 shoe @ 8046' L1-02 southwest C3/C4 lateral TD @ 9760' (50-029-20526-62) 7" shoe Operator: Conoco Phillips Alaska, Inc. (:rid Correction: UAS Job Nu: 1303032 Field: Kuparuk Magnetic Declina[iou: 23.75 AFE No: KRD 231734 Well: 1C-0ILI-03 Plau k9 Uip: 80.84 API No: 50-029-22941-xx Rig: Nordic 2 Uogleg per: FOU ft Coordinate ticstcm: ,~ iii Surface Location Original VS Plane: 150.00 Parent \\'cll: 1C-O1L1-Ol X: 562372.07 ft View VS Plaoe: 150.00 RKR Deighc 94.00 ft 1': 5968522.56 ft Meas. Incl. -IRCF: tiuL~•.-.~ ('curds. -'1'ruc Nurth (~oord,. - \tiP ~n~ Crid UuglcM1 Original \'iee Ilml Build turn Course Drilled Depth (fl) Angle ldeg) .\~i. IJ~ \I ~ ):'til-I Itu 1!1 ~ I'\\ I-I iii ` tic~rril~ I~ u~ \ 8I Igo I \ ti I ISU°I ~ft~ t ,., I~ tli I~ ~ iu Lcugth Ifi) Distance lft) Comments 7734.58 94.78 19h.r~ 68.52 2607 I`_es C:1 I~: 1214.1~~ Tie-inPoim fromlC-OILI-01 725090 94.'8 I~iS.~~.~ - 53.86 _6!'38 I8.'_' C~-3.21 I?5454 0.00 18?9 15.42 15.1'_ 7770.00 94.78 l9-~"~ :5,.-1 ,~. 34.91 '596_°; 9.02 ~_~.-.~~~~~ 1'_6;.88 0.00 -9.05 '_0.00 35.42 '775.00 94.77 14~~J~ - 30.14 _'594."'v 11.96 L'~1.3(~ 1271.30 -0?0 -1'_.00 5.90 40.42 7800.00 94.71 I93.a- 6J,' ]588.3i~ 12.(10 I]RS.o, I_BS.v' -0?4 -1'_.04 '_5.00 65.43 7810.00 94.68 19'._- _ -3.64 _i8p.l~i 11.16 1'_'16." I'9(i.~'_ -0.30 -I?.UO 111.00 ?5.3? '78_'5.90 9453 19u.1- ~ I.~ -18.30 _'583.19 13.00 1307.44 1307.44 ~ -1.09 -12.00 15.00 99.42 7850.00 94_'8 18-.1 •>>3?._~~ -d' 9' 'ST150 13.01 1326.8' 132~i.8' -1.00 -I?-OU 25.00 115.4' 78'5.00 94.01 1811 :,55o.-i~ -t 7.72 25;6.;1 12.02 1347.00 1345~~~~ -I.OS -1'.00 25.00 140.12 7900.90 93.73 181.1~~ ?~-i.:~- `x"'62 25~5.a_' 11.99 136 ~.9'_ 136?,v_ -I.I'3 -11.96 '5.00 165.-1'_ 7925.00 93.45 I"8-1~, - -t17.5; _'575.4' 11.99 138953 138253 -1.13 -11.96 '_5.00 190.42 7950.00 93.15 1 75.Su _ 531- o -14'_.49 2576.-~ 13.00 141 E%' 141 E` -1?0 -11.96 '_5.00 '_15.42 7975.00 9'_.85 17'_.51 0551~.1~ -167.3' 2579.3a 1390 14345' 143457 a• -1?0 -1196 '_5.09 2-10.3° 8900.00 92.53 109.5' r,=,w._:; -191.95 '_533.'_, 13.02 1357.88 1457.88 -~!::, -I.IR -11.96 '5.00 265.43 8025.00 92'1 166.51 :>-1_i> ~,51K, -?16.41 '588.1' 11.98 14SL61 148L63 -1.28 -11.92 2590 290.42 8050.00 91.89 I(, ;.ti ~ ',5 -21055 2594.8-:~ 12.02 1505."5 1505,'5 -I_'8 -I 1176 '_5.00 315.42 8060.00 91.76 102.31, a-iS ~~~ - -.~!, -ISO.IU 259.-,~- 1197 1515.49 1515.49 -1.30 -1190 10.00 325.42 8075.00 9_'.04 161.11 = ~1~~_51 -264.x( ?60'_.11 13.01 030.09 1530.0`7 1.87 IL87 15.00 340.32 8100.00 9250 I G-. l u ~ ~ ~ ~ ? - ~~~_, -388.65 '_608.3.' 1 197 155111 i 551J 4 ~8 ~ 1.84 1 1.84 35.00 365.42 8125.00 9'.96 I'O.Ir •~1~q„ ~-!as°, -;13.13 '1,1~'~~ 12.01 L,".sl x__'.81 1.84 11.88 '_5.00 390.4? 8150.00 93.41 I"3321 ~11~.",. - ;'.8. 'blo.•~J 12.00 Io1,L~;_ Iot~L~.Q 1.80 11.88 '_5.00 415.42 8175.00 93.85 I'6.IC (:1-- ~"~ ~1! _~,~ -;6'.65 -%:I`L+~~ 1'_.03 16_3.x' 16'.'>.72 1.76 11.9? 25.00 449.43 8200.00 94?7 1"%8.44 _. -~,'. ,,. -38~Sb _i~'U.+'~ 11.97 1~~15.83 1645.83 , 1.68 11.88 25.00 465.12 8'10.00 94.E ISU,Iv ~.~> :' -;9753 'o2U.1;: 12.09 In51.v~ 165450 1.70 12.1X1 10.00 175.42 8225.00 94.38 L'S_:x .".3-_ -111.11 '6_l1„~. 12.04 I~,~•-5~ lbc,'.55 -0.40 -12.07 15.09 190.32 8250.00 94.36 1,5.3X -~i -43].3" 262?01- 11.98 1634--b 1689.-5 -0.48 -12.00 '_5.00 515.4_ 8275.00 94.13 I-~ ,- -46'.16 '_6'_4.6~~ 12.02 1-1'_58 ISLSN -053 -1'_.04 25.00 510.42 8300.90 9399 16`>,.;- -486.78 u_S.i.:: 1198 I-32.8- 1735.8" -9.56 -1_'.00 '_5.00 565.4'_ 8.3'_5.00 93.84 166.3a - ~ -SILI6 _633.x• 12.03 I-51.61 1-59(,1 -0.60 -12.04 ?2.00 ;90.42 R359.00 93.68 16:?a - '~~; s -5;5.34 '_h10.3a IL94 I~: ~,;.-' 183.x' -0.64 -1'_.00 '_5.00 615.42 837590 9350 lou.30 _ ~~~ -558.95 ~G18.I~J I?UU I1~8.Ii 1808.14 -0.7? -1290 ?5.00 640.43 8400.00 93.32 157?6 3:~ ~. r:5'~.~al -58~ ~' '65°.I~1 1'_00 Is;'_.?`~ 18.3."9 -0.72 -1?99 25.00 665.42 8410.00 93.25 156.1[ .S'S.'1 -591.3`1 _bbLi~B 12.99 181_'.~(~ 184_.;0 -0.70 -12.00 1000 675.43 8325.90 93.66 157 91 = +- -- ~5.~_5-t -605.18 2660.1' 11.96 18S7.5o 185756 2.73 11.67 15.09 69Q42 8450.00 9435 160.31 - -628.52 :'075.1 12.01 Ixs2.17 188_'.17 '_.76 11.7? '5.00 715.42 8475.00 95.03 163._-- -~»"5 '_683.=:~ IL99 I `~1.r.. ; l 190651 2.73 11.72 '_5.00 740.4'_ 8500.00 95.70 160.-I ,SI~C'I -070.33 Ii,89.0' ILUI 19;,,_';_ 11;.03= 2,68 11.76 25.00 765.12 8525.00 96.35 169.24, - - -70(:.65 '694, ~ I 1_'.02 I v51.11 1'13». I i 2.60 11.80 '_5.00 790.3_' 8550.00 96.98 I "' i~ l - 7'_5.18 2698.53 IL99 14-" ~ I~~-' 2.>? I L80 '_5.00 815.42 8560.00 97.23 173.-`~ - -735.121 .644.-; I L97 I'18GA~ I~ixo.4'' '.50 I L80 19.00 825.42 8575.00 96.87 I"_!~I - -"49.81 '_'%ULSi R.U_' '~,inr.15 _00(2.13 -2.40 -11.87 15.00 840.4°_ 8600.00 96_'6 169r~„ _ ?74,30 3-053,4 11.97 _n?3.1x ;.;8 ~ -3.44 -11.80 '_5.90 865.3'_ 86_'5.00 95.63 166.11 ~ -798.58 2710.48 12.0(1 '_1~1i.09 =i ~4~.U9 -252 -11.80 '_5.90 890.42 8650.00 94.99 163.1- -822.58 2717.5 `~ 11.99 2~~-1.17 _'0'1.17 I'.!? -256 -11.76 '_5.00 915.42 8675.00 94.33 Ibo.'? -84624 27_5.1!, 1'.01 '_09556 _`65.56 -2 b4 -11.76 '_5.00 940.42 8700.00 93.66 I>~.' -869 -38 1731.4> 1199 ' 120 ' I i 'n ~ I -1.68 -I 1.72 '_5.00 965.1_' 87205.00 92.98 151.;- -893.25 '744.62 12.01 '14>.U4 '_115.04 -1.72 -11.72 '_5.09 990.1? 8750.00 93.30 151--I~ - -914A8 2756.1' IL98 ~169.`~- X169.97 ...r_ -11.68 '_5.00 1015.4_' 8775.00 91.60 118.15 -936.11 2768.5_ 12.00 _191.9i~ ^194.96 -2.80 -11.68 25.00 1040.12 8800.00 9091 145.0 I ,:3~~1.i~ `>57.09 _'78'_.10 12.00 '~ 19 9' "19.9? -IJ6 -11.68 25.00 1065.43 8825.00 90_'1 1130`1 ~>7~.35 '796.1 13.01 Z'11.-s 2244.78 -2.80 -IL6R '_5.(10 1090.43 885Q00 89.51 139.7' ~~-l•~3~8~~ -996.84 ?812_~`i 13.01 I:i,~~.19 2269.49 -3.80 -11.68 '_5.00 1115.42 8875.00 88.81 136.8; -1015.51 2829.0` 12.01 ^-''93.96 2293.96 -iu1 -2.89 -11.68 '_5.00 1140.42 8885.09 88.53 135.04 <e$ -102?. i.3 '_8i5.`+s 1193 '_363,6- ?303.67 -I~i1 -2.80 -11.60 10.00 1150.42 8900.00 88.6? 13-.18 ~4n3.S-~ -103359 2810.'6 9.95 2318.25 '_318.25 0.69 9.93 15.00 1165.42 8950.09 88.93 11'_.18 -1071.117 '88.60 10.0? 232•-.11 _'367.41 O.G2 10.00 50.00 1'_15.42 Original Plan Page 1 of 2 (1C-01L1-03 PIan10 Geotrak.xls) 1/4/2007 9:01 AM Meas. lucl. TKUE tiuhua HKIS Coords.-Tnu~\unh (lnn~d~.- UI'~~, ~,ud Uuglrg Uri„iual \'ie~r I~~ul Build Iuru Course Drilled Depth (fll Angle (deg) :A~i. IJcgi I ~ U IIU itu N(+l/SI-1 Ilu Fa-IIN I-I uu ~~ ~ ~i. i ~ ~ ~ ~~ ~ i 1c.crit) I IOn In ~,ti 115U`) ~fti ~'ti 1110°1 (ft) I~,n~~~ (deq) i lun tU I Ihu iii Length (fl) DisUUCe (fl) Comments - 9000.00 89_'3 13"'J, -,-i~~~~.-~ -III'.4% wp^.4v 10.00 _1-.18 ?417JR 0.63 9.98 X0.00 I'_b~.-1? 9050.00 8956 15_.I~, ~ -1155.61 2932,74 10.00 ?16.16 '_467J6 U.64 9.98 10.00 1315.3'_ 9100.00 89.88 Ii-.1 ~ i-; ~~~ ~.i -I'UU.-B - '954J i 10.00 2516.48 ~5161~8 _ ~~~ O.b4 998 50.00 1365.32 9105.00 89,91 i5-,., ,.~, -"~ -r_i,5.1o ,v>r,.o~, 10.02 52.93 253i~~~ ~~~ 0.60 n,.uo 5.00 1370.12 9150.00 89.60 i;; i„ -~- ~, -i21r~.17 ;;1.;a io.ou _51,6.-2 2566.;2 a -u.69 -998 15.00 1115.32 9200.00 89.26 138.1- - I ?89 88 ;999? . 10.00 ]a l q.?0 2616.70 ~7a -0.68 -998 50.00 1165A2 92 A).00 88.92 111.1~~ -:,~~ ~,•. -1;31.15 302iR5 10.00 V~(~~~_54 266654 -v1 -0.68 -9.98 50.00 1515.3'_ 9300.00 88.58 138J~! ~-~'a -1369.81 3059,11 10.00 _'ISRS 2715.85 '11 -U.68 -998 50.00 1565.4' 9350.00 88.26 133'.~~ -~~~~. ~;il.-lq -14f55; 1ii`i4.~~1 IU.00 '~r,.i'~, 2764?6 .•N -0.44 -9.98 50.00 1615.3'_ 9400.00 8296 128. 'i~ r•4~i`%.I'~ oiU ±_I I -14i8.U 1131.k8 IILUI 'NI1.41 2811.41 -`~-I -U.6U -I~LOD 50.00 1665.4? 9450.00 8266 I?3.]I h-111-~~_ ~~5p%.0_ -1467.1~~ 1172.=1-? 9.99 2~4it,.'74 _'856.94 ail -0.60 -998 50.00 1715.9? 9500.00 8239 II8_'I 6113.11 osn-.IS -I4v'.SU 3?IS.i:w IU.UI _iuoA4 2900.1v -al -0.54 -Ib,DU 50.00 1765.13 9A15.u0 87.36 II"'._..i na13-11 ~,S~c.~l -1195.11 r~i,~,;v 10.01 2901J.4 ?704.73 -93 0.60 -IRUO 5.00 1770.12 95>0.00 87.71 C2_l~~ 46 ; ~i~ri? ~1 -1517.59 S: i8, 111.00 :IV-!l of ?443.63 y~ 0.83 '/.98 45.00 1815.12 9600.00 88.17 I'~' Ix -I >46.0'' '~`~.n~i 999 %vHfi ".9~~18,79 x1 11.86 9.96 50.00 1865.12 9610.00 88.6'_ 131; ^1..5' -1574,93 1;8.'4 IIr.U3 3ii~S.r,3 ti~15.61 x; 1190 998 50.00 1915.32 9700.00 89.08 13~.i~ - -- -1613.01 174,81 IO.UO 1n83.81 3083.84 8S 0JJ3 99L 50.00 1965.32 9750.00 8955 11'.C •~~-1.!- -Ibil.l'_ 3196.15 9.98 111 i.uu 11,43.00 x, 094 9.94 50.00 '_015.42 9800.00 90.02 11~Ju ~,iia_?.~. -1641.87 i415J- IU.OU +I~'~ 318'_.77 0.94 4.96 50.00 '_065.12 9830.00 90.30 6i~tr~ -111;.1- 335ri_".~ IO.uI t:l~-:~• 122.^; 0.91 9.97 30A0 '_09.1.3' 9850.00 90.10 118 ;~ ~'-LI~r -IT1t~1 ld;,l.~ii Iu.00 .1'1_.',1 1'12."~'• -L~Ni -7.91 '_0.00 '115.4_ 9900A0 89.61 111.1' <,:7'S -1-`,5.88 318`1?b - 10.01 1]8'.59 ~2R2.5'i -0.98 -9.96 50.00 '_Ib5.13 99>0.00 89.1; 13x.1 i ~l ~. _ -18115] 152u,v~~ 9.99 333 L90 >331 ~~0 ~. -11.96 -9.94 50.00 '_'_15.12 10000.00 88.65 133.1- _ _ ~ ~ -Ixi~ lv1x~~ IU.OU 338Ci.32 ;181.32 -0.96 -996 50.00 '_'_65.3'' 10050.00 88.18 Lx,ly ,11 . I~~~,.~ lu.u0 312;.1? ~ -n.93 -9.76 50.00 '_;15.12 10100.00 87.7; I_1.`I 9.9y 11;w~ -u.9u -9.96 50.00 2365.12 • Original Plan Page 2 of 2 (1C-O1L1-03 PIan10 Geotrak.xls) 1/4/2007 9:01 AM • • Z,o 7 - c~o3 Subject: Re: 1C-011,1-d1 added lateral From: Thomas Maunder <tom maunder~.adnlin.state.ak.us> Dater Tuc. m ran 2007 09:55:36 -0900 7~0: "Venltau~~. Dan E" <DanE.Venhau~nc~n~cn}~hillilis:c<~tit'~ CC: "[;ller,.l (nary"<J.Gary.Lll~~r~c~i;cnnoc~~phillip~~.coni-~~. Stc~c [)a~ics<steve_daviescr~.a~lmin.~(at~.ak.us=-~ Dan, Thanks for the information. With regard to the name, 1C-O1L1-03 is acceptable. A reply to Gary's email regarding naming is being prepared. It is agreed that suffixes beyond L1-XX are unwieldy. I look forward to the receiving the new paperwork. Call or message with any questions. Tom Maunder, PE AOGCC Venhaus, Dan E wrote, On 1/2/2007 9:48 AM: Tom, Due to deteriorating hole conditions this weekend, we had to perform an unplanned openhole sidetrack on 1 C-01 L1-01. The unplanned lateral was completed with a slotted liner and therefore will need to be permitted. I asked the company man on Nordic 2 to contact the state inspector on the slope this weekend so maybe you have already received notification. I have not submitted this paperwork in the past but after talking with others I will forward you the following information: • Anew 1C-01 L1-01 planned survey (operations are continuing forward) • Actual 1C-01 L1-01-01 survey • 401 for 1C-01 L1-01-01 Note the naming convention is rather unwieldy and based on previous e-mails, ConocoPhillips would prefer to permit this added lateral as 1C-01 L1-03. I have enclosed a geological profile with new lateral. Please let me know if you need anything else. «1C-01 L1-01 xsection.xls» Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907-263-4372 office 907-230-0188 cell • ~~El~f~tf~ ~a ol~lf_t_ ~o ~~c z~.ao~ (e~ Each uretl branch requires a separate Permit to Driii, if a previously cir~fled weft is proposed to be redrifl~f below the structural or conductor casing to a new bottom-hole locations the application far a Perrr~it to l]~ritl must be accompanied by all items regsairecl under (c) of this section. if concurrent multiple well branches are proposed from a single conductor, surface,. or production casing... ~~~ for each other weft branch, the applic;atirsn for a Perrr~it to Drilf neec9 only irgclude information under (c} of ttais section that is unique tea that Jeff branch and need sn®~ be acccart~~aa~u~dl ~~ too ~~flt6 $~. i • • TRANSMITTAL LETTER CI~ECKLIST WELL NAIVtE PTU# ZC~ ~ -a~~ ®evelopment Service Exploratory Stratigraphic Test Yon-Conventional Wett Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter ' CHECK I ADD-ONS TEXT FOR APPROVAL LETTER WHAT ~ (OPTIONS) APPLIES ~ I MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ we[ l /C2~ ~C "' ~ i (If fast two digits I in t _~__~~~~a-"-~ ~~~~~, AP[ No. s0-OZ Permit No./ i API number ;between 60-69) ~ are ; ~ !Production should continue to be reported as a function of the original API number stated above. PILOT HOLE [n accordance with 20 AAC 2~.005(f), all records, data and logs i ~ ~ acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number ~ ~ ~ (~0_ _ -_~ from records, data and logs ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC 'EXCEPTION ~ 2~.0». Approval to perforate and produce /inject is contingent ', (upon issuance of a conservation order approving a spacing I .exception. assumes the ~ liability of any protest to the spacing exception that may occur. ;DRY D[TCH ;All dry ditch sample sets submitted to the Commission must be in i SA!~IPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ' Please note the following special condition of this permit: Non-Conventional ~ production or production testing of coal bed methane is not allowed ~'"ell ;for (name of well) until after (Companv 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 I ;program. Rev: l '2~i06 C ^ jody~transmittal_checklist • • ~: fp : ~ , ~ ° ~, Q N I a~ o o' : o ~ Q ~ m I c ~ Q ui ~ w o ~ it ~ v' ° ~ II I !i c. c. ~ ~. i ~ p, N ~ OI ~ Z ~ o N ~ ' I ~ ~ ~ m I I ° o ~ = Q ~ 'g. ~ rn c v~ i j~', O ~ o _ 3 m~ '! i ~ ' ~ DI C ~, C• Y: i I ~ O ~~ ~~ U. a O. ~: y. 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O a , N a U ~ Q , , a z , . . , ~ ~ tn U U U U U , ¢ = ~ Q = o ~ . . m m U, ~ N, - ~, a , , o cn, .. . ~, U, m , , , , , , , . , , , , , , . , , W °- O ~ N M V~ CO I~ ~ W O O ~ N M ~~ Co N OO O O ~ N M~~ LO CO 1~ W O i ~ r- N M V ~ CO h 00 O ~ ~ .- ~ ~ ~ ~ ~ ~ N N_ N N _-___ _. _ _ N N --_._ N N N _ N M M M ~ M M ~.M - M M M M I v __. _ _ __ __. __ -..__ i C y ~ O ~ N I N y O ~~ ~ I ~ ~ r O ~ J y Gf ~ ~ C ~ L ~ ~ L Q ~ ~ L ~ ~ ° v a n i ~ a~ ° ' C9 a a Q w a~ ~, a a~ -~ m c .~ m M 0 J O U c a~ E o~ a~ N N 0 3 m n O O N v ro c (6 C O c O ' .N E~ U~ N N s o~ Q a ~ w rn m E m n Q O Y y H O 3 ~ rn o~ '~ U Q ~ N M N t f6 f'- Q f0 N C O ,U 'y ~ .N a'~ 0 U °? D '1 V rn °~ I c c o I .~ y ° y I ~~ ~ m c W U~ N f6 N U p _o o `~ y o '~ ~ O U Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 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. **** REEL HEADER **** LDWG 07/09/27 AWS 01 **** TAPE HEADER **** LDWG 20/09/07 01 *** LIS COMMENT RECORD *** TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: LDWG File Version 1.000 Extract File: LISTAPE.HED MWD RUN 3 3 T. MACISAAC G. GOODRICH MWD RUN 8 8 N. FAULKNER C. SEVCIK MWD RUN 21 21 S. TOMLIN M. FEKETI MWD RUN 24 24 S. GANDRA G. GOODRICH SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 1C-01L1-03 50029205266300 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 20-SEP-07 MWD RUN 4 MWD RUN 5 4 5 T. STURDIVANT W. PUTNAM D. HILDRETH G. GOODRICH MWD RUN 19 MWD RUN 20 19 20 C. EKE D. YOUNG M. FEKETI D. HILDRETH MWD RUN 22 MWD RUN 23 22 23 D. YOUNG A. BENNETT D. HILDRETH M. FEKETI 12 11N 10E 94.00 a~~ _~3 ~- ~ sal ~~ 1 DERRICK FLOOR: 00.00 GROUND LEVEL: 00.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 10.750 2798.0 2ND STRING 7.000 7758.0 3RD STRING 3.875 7750.0 PRODUCTION STRING 3.00 10000.0 REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG I5 THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 28.286" LONG: W149 DEG 29' 39.293" LOG MEASURED FROM K.B. AT 94.0 FT. ABOVE PERM. DATUM (M.S.L.). COMMENTS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (SSTVD) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (6) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole downhole pressure, Vibration and Downhole Weight on Bit), a Directional Sub, and Hydraulic Orienting Sub with a near bit inclination sensor and Ultra Slim Resistivity Sub. (7) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log. The INTEQ Gamma Ray is the PDC for this wellbore. (8) The sidetrack was drilled from 1C-01L1-01 through a milled window in 3 3/16" liner. Top of window 7181.4 ft. MD (6373.9 ft. SSTVD) Bottom of window 7190.0 ft. MD (6382.2 ft. SSTVD) (9) The interval from 9960 ft. to 10000 ft. MD (6420.90 ft. to 6420.78 ft. SSTVD) was not logged due to bit to sensor offset. (10) This wellbore 1C-01L1-03 was kicked off the wellbore 1C-01L1-01 at 8355 ft. MD (6435.05 ft. SSTVD). Tape Subfile: 1 92 records... Minimum record length: 8 bytes Maximum record length: 132 bytes 4 **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED 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 MWD 7190.0 10000.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 7190.0 7425.0 MWD 4 7425.0 7533.0 MWD 5 7533.0 8128.0 MWD 8 8128.0 8341.0 MWD 19 8341.0 9256.0 MWD 20 9256.0 9355.0 MWD 21 9355.0 9457.0 MWD 22 9457.0 9724.0 MWD 23 9724.0 9834.0 MWD 24 9834.0 10000.0 REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 1C-01L1-03 5.xtf LCC 150 CN ConocoPhillips Alaska, Inc. WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Borough STAY Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 20 Total Data Records: 134 Tape File Start Depth = 7190.000000 Tape File End Depth = 10000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 182 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** i ` LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 7190.0 7425.0 LOG HEADER DATA DATE LOGGED: 08-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 7455.0 TOP LOG INTERVAL (FT): 7190.0 BOTTOM LOG INTERVAL (FT): 7425.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 25.3 MAXIMUM ANGLE: 88.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NTJMBER MPR MULT. PROP. RESIST. 10000103 GRAM GAMMA RAY 1079131 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT) 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 110.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ) 0 REMARKS: BIT RUN 3 (MWD Run 3). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-AP I) RPCL - DEEP PHASE RESISTIVITY (O HMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) ! • RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 20 Total Data Records: 23 Tape File Start Depth = 7190.000000 Tape File End Depth = 7425.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 104 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT; .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 7425.0 7533.0 LOG HEADER DATA DATE LOGGED: 09-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 7575.0 TOP LOG INTERVAL (FT): 7425.0 BOTTOM LOG INTERVAL (FT) 7533.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 97.8 MAXIMUM ANGLE: 98.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RES IST. 10000103 GRAM GAMMA RAY 1079131 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ~ ~ MUD AT MEASURED TEMPERATURE (MT): .000 115.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN); .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 4 (MWD Run 4). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F ~ ~ 5 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 20 Total Data Records: 11 Tape File Start Depth = 7425.000000 Tape File End Depth = 7533.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 92 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!~~~~!!!!~~~ Extract File: FILE013.HED FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N0: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 7533.0 8128.0 LOG HEADER DATA DATE LOGGED: 09-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8160.0 TOP LOG INTERVAL (FT): 7533.0 BOTTOM LOG INTERVAL (FT) 8128.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 91.5 MAXIMUM ANGLE: 96.2 a ~ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10000103 GRAM GAMMA RAY 1079131 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 121.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN) .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 5 (MWD Run 5). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 • RACH RACH RACHX * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM Total Data Records: 57 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 20 Tape File Start Depth = 7533.000000 Tape File End Depth = 8128.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 138 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .005 1024 • *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N0: 8 • r DEPTH INCREMENT: .2500 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEP TH MWD 8128.0 8341.0 LOG HEADER DATA DATE LOGGED: 14-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8437.0 TOP LOG INTERVAL (FT): 8128.0 BOTTOM LOG INTERVAL (FT): 8341.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 96.4 TOOL STRING (TOP TO BOTTOM} VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY ZDGS002 DIR DIRECTIONAL ZPC003 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 35500 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 147.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 8 (MWD Run 8). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAY Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHl~II~I 4 4 20 Total Data Records: 21 Tape File Start Depth = 8128.000000 Tape File End Depth = 8341.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 6 102 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .006 1024 *** LIS COMMENT RECORD *** LDWG File Version 1.000 Extract File: FILE015.HED FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 19 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8341.0 9256.0 LOG HEADER DATA DATE LOGGED: 03-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9290.0 TOP LOG INTERVAL (FT): 8341.0 BOTTOM LOG INTERVAL (FT): 9256.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 87.5 MAXIMUM ANGLE: 96.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL 10241335 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 149.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ) 0 REMARKS: BIT RUN 19 (MWD Run 19). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 • 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 20 Total Data Records: 88 Tape File Start Depth = 8341.000000 Tape File End Depth = 9256.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 7 169 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .007 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!~ Extract File: FILE016.HED FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N0: 20 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9256.0 9355.0 LOG HEADER DATA DATE LOGGED: 03-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9395.0 TOP LOG INTERVAL (FT): 9256.0 BOTTOM LOG INTERVAL (FT): 9355.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 85.8 MAXIMUM ANGLE: 89.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL 10241335 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 149.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 20 (MWD Run 20). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 20 Total Data Records: 10 Tape File Start Depth = 9256.000000 Tape File End Depth = 9355.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 8 91 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .008 1024 *** LIS COMMENT RECORD *** !!!!~!!!!!!!!!!!!!~ LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE017.HED FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 21 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9355.0 9457.0 • LOG HEADER DATA DATE LOGGED: 04-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9497.0 TOP LOG INTERVAL (FT): 9355.0 BOTTOM LOG INTERVAL (FT): 9457.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 90.7 MAXIMUM ANGLE: 91.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL 10241335 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 151.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 21 (MWD Run 21). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (O HMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 • FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 20 Total Data Records: 10 Tape File Start Depth = 9355.000000 Tape File End Depth = 9457.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 9 91 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .009 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE018.HED FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 22 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9457.0 9724.0 LOG HEADER DATA DATE LOGGED: 06-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9764.0 TOP LOG INTERVAL (FT): 9457.0 BOTTOM LOG INTERVAL (FT): 9724.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 83.1 MAXIMUM ANGLE: 94.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL 10241335 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 23500 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 151.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 22 (MWD Run 22). • GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT --------- CNAM ODEP GRAX --------- GRAX ------------ GRAX ----------------- 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 20 Total Data Records: 26 Tape File Start Depth = 9457.000000 Tape File End Depth = 9724.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 10 107 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .010 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE019.HED FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N0: 23 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9724.0 9834.0 LOG HEADER DATA DATE LOGGED: 06-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9874.0 TOP LOG INTERVAL (FT): 9724.0 BOTTOM LOG INTERVAL (FT): 9834.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 89.3 MAXIMUM ANGLE: 90.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL 10241335 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro ' • MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 151.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 23 (MWD Run 23). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY ( OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIV ITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM Total Data Records: 11 Size Length 4 4 4 4 4 4 4 4 4 4 20 Tape File Start Depth = 9724.000000 Tape File End Depth = 9834.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 11 92 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .011 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!~~~~ Extract File: FILE020.HED FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N0: 24 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9834.0 10000.0 LOG HEADER DATA DATE LOGGED: 07-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 10000.0 } ` • ~ • TOP LOG INTERVAL (FT): 9834.0 BOTTOM LOG INTERVAL (FT): 10000.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 87.0 MAXIMUM ANGLE: 88.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL 10241335 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 10000.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 151.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN) .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 24 (MWD Run 24). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-03.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-03 FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO • MNEM ------ CHAN DIMT -------------- CNAM ODEP GRAX -- GRAX ------------ GRAX ------------------ 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 20 Total Data Records: 16 Tape File Start Depth = 9834.000000 Tape File End Depth = 10000.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 12 97 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes