Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
207-002
Irraege Projecfi Well Misfior~- File Cover F'~ge XI-IVZE This pr~cte identifies those items that were not scanned during the initial production scanning phase. They ar.~ available in the original file, may be scanned dtaring a special rescan activity or are viewable by direct inspection of the file. - !~ ~ ~ Well History File Identifier C?rganizing (done) ^ Two-sided III 11111111 III II III ^ Rescan Needed RE AN DIGITAL DATA QVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Pro "ect Proofin _ J 9 III II'III I I III (I III BY: Maria Date: ~ /s/ Scanning Preparation x 30 = + _~ =TOTAL PAGES BY M i D (Count does not include cover sheet) : ar a ate: ~ Q /s/ Production Scanning II I II ~I I I I ~ III ~ I III Stage 1 Page Count from Scanned File: _ ~~~ (Count does include cov r sheet) ~ Page Count Ma tches Number in Scanning Preparation : _~ YES NO BY: Maria Date: ~..,/ ~~ ~ /s/ ~~,~ Stage 1 If NO in stage 1 , page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I (I'lll I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III 11'111111 II'I III 10/6/2005 Well History File Cover Page.doc ~~.' y ~~ ~ ~ . ,~ ~~ :~ :« ~ ~ b.~~;. ~ ~~ ~' T~~ `~~ ~ ~ ,x ~. E MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ F~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2070020 Well Name/No. KUPARUK RIV UNIT 1C-01 L1-02 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20526-62-00 MD 9760 TVD 6460 Completion Date 1/9/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION . Types Electric or Other Log s Run: MWD DIR, RES, GR (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number - -- Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 8177 9760 Open 1/24/2007 Disk in 1C-01 L1 (206-148) I History ~ pt Directional Survey 8177 9760 Open 1/24/2007 I '~ C Lis 15466 Gamma Ray 7190 9760 Open 10/2/2007 LIS Veri, GR, ROP w/TIF and Meta Graphics I ~pt 15466 LIS Verification 7190 9760 Open 10/2/2007 GR, ROP ',~feog 15466 Induction/Resistivity 25 Blu 7175 9760 Open 10/2/2007 MD Mutli Prop Resisitivity, ~~ GR 27-Dec-2006 I ~ ';'Log 15466 Induction/Resistivity 25 Blu 7175 9760 Open 10/2/2007 TVD Mutli Prop Resisitivity, II GR 27-Dec-2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORM~N ~/ N Well Cored? Y / Daily History Receive d? Chips Received? ~~ ~ "' Formation Tops ~/ N Analysis W pL.__ Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2070020 Well Name/No. KUPARUK RIV UNIT 1C-01 L1-02 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20526-62-00 MD 9760 TVD 6460 mpletion Date 1/9/2007 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: _ _ _ _ Date: ~ ~ f ~ ~1~ ~ _ ___ _ - _ ._ _ _ - _ J Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1 C-O1L1-02 ~~~~ mtrw rc»z r~: BAKER ~~^~! NUGHES -=- Anchorage GEOScience Center ~~~- --~ °........,__. I 1 ~I Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary I bluelines - MPR-DIR_md Log 1 bluelines - MPR-DIR tvd Log ao~ -~~ ~ ~ s~~~ LAC Job#: 1303032 Sent By: Deepa Jo ekar Date, ; S~p~~~a~ Received By: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RE'F{RNING 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 g . ;: r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~v~® ~- ~B 0 8 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' ~lasfia Oil & Gas Cons. Commission w .-,.Mw-~nn 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,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 207-002 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/21/2006 • 13. API Number 50-029-20526-62-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/26/2006 14. Well Name and Number: Kuparuk 1C-01 L1-02 ' 1718 FNL, 1364 FWL, SEC. 12, T11 N, R10E, UM Top of Productive Horizon: 1456' FNL, 1310' FEL, SEC. 12, T11 N, R10E, UM 8. KB Elevation (ft): 94 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 3117' FNL, 2444' FEL, SEC. 12, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 9760 + 6460 Ft River Pool . 4b. Location of Well (State Base Plane Coordinates): Surface: x- 562372 ` y- 5968523 ' Zone- ASP4 10. Total Depth (MD+TVD) • 9760 + 6460 , Ft 16. Property Designation: ADL 025649 TPI: x- 564976 y- 5968806 Zone- ASP4 Total Depth: x- 563857 y- 5967135 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 DEPTH TVD ' HOLE AMOUNT SIZE WT. PER FT. GRADE TOP '' BOTTOM TOP BOTTOM. SIZE CEMENTING RECORD PULLED 16" 65# H-40 Surface 80' Surface 80' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surface 2798' Surface 2683' 13-3/4" 1350 sx Fondu 250 sx AS II 7" 26# K-55 Surface Surface 6464' -3/4" 460 sx Class 'G' 3-3/16" 6.2# L-80 7060' 6350' 8054' - 6551' ~ 4-1/8" 27 sx Class'G' Puddle Cement Job 2-3/8" 4.4# L-80 8008' 6554' 9724' 6468' ~ 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBtNG RECGRD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-318" Slotted Section - 4-1/2", 12.6#, L-80 7079' 6965' MD TVD MD TVD 8010' - 8836' 6553' - 6536' 8848' - 9203' 6536' - 6536' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9298' - 9712' 6529' - 6470' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 2200' Freeze Protect w/ 40 Bbls Diesel 26. PRODUCTION TEST Date First Production: January 20, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 1/30/2007 Hours Tested 12 PRODUCTION FOR TEST PERIOD OIL-BBL 2,833 GAS-MCF 3,007 WATER-BBL 1,661 CHOKE SIZE 32 Bean GAS-OIL RATIO 1,283 FIOW TUbing Press. 544 CaSing PreSSUre 1,263 CALCULATED 24-HOUR RATE• OIL-BBL 5,134 GAS-MCF 6,587 WATER-BBL 3,267 OIL GRAVITY-API (CORK) 23.5 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wat attach separate sheet, if necessary). Submit core chips; if none, state "none". ~"'~~?r:i t ~v~ ~~~~°~ ~~ Dr.:~: None '? .,lr,%`~._~s w~'_. Form 10-407 Revised 12/2003 ` TINUED ON REVERSE .SIDE .~~ ~ * ~_' ~~' ,t~~ ~~~ry ~fy~~ 28 GEOLOGIC MARKERS 29. RMATION 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 C-01 L1) None ` Top C1 /Base C2 (Inverted) 7539' 6587' Top C2 /Base C3 (Inverted) 8078' 6550' (From 1 C-01 L1-02) Top C2 /Base C3 (Inverted) 9380' 6519' Top C3 /Base C4 (Inverted) 9513' 6494' Top C4 / Base D Shale (Inverted) 9721' 6469' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. D Signed Terrie Hubble Title Technical Assistant Date ~/Q Kuparuk 1 C-01 L1-02 207-002 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Aras WoRhington, 564-4102 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). ITEniI 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. ITenn 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITenn 20: True vertical thickness. ITenn 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP AMERICA Operations Summary Report Page 1 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 i Task :'~ Code NPT ~ Phase Description of Operations 12/5/2006 00:00 - 03:00 3.00 MOB P PRE 03:00 - 03:30 0.50 MOB P PRE 03:30 - 05:00 1.50 MOB P PRE 05:00 - 18:00 13.00 RIGU P PRE 18:00 - 00:00 6.00 I BOPSUp P PRE 12/6/2006 100:00 - 05:00 I 5.001 BOPSUR P I I PRE 05:00 - 11:00 6.00 BOPSU N RREP PRE 11:00 - 13:00 2.00 BOPSU P PRE 13:00 - 15:15 2.25 RIGU P PRE 15:15 - 16:30 1.25 RIGU P PRE 16:30 - 18:15 1.75 RIGU P PRE 18:15 - 20:00 1.75 BOPSU P PRE 20:00 - 20:30 0.50 KILL P WEXIT 20:30 - 21:30 1.00 KILL P WEXIT 21:30 - 22:45 1.25 KILL P WEXIT 22:45 - 23:15 0.50 KILL P WEXIT 23:15 - 00:00 0.75 KILL P WEXIT 12/7/2006 00:00 - 02:00 2.00 KILL P WEXIT RD off of 1C-25. SLB changing blocks to 2-3/8" Held PJSM on moving off of well. identified the hazards and determined personels work place Move off well and position to conduct pad prep wit Drilling Tool House Change out BOP's rams, swapped out annular and prep pad for rig Insatlled hericulit in cellar area. Held PJSM on back 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 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. Continue with BOP equipment test: Lower 2-3/8" rams still leaking. Try a different test joint. Continue with remainding tests. 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. 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. RU and pull 2-3/8" CT across the pipe shed roof and into the injector head. Load CT with 2ppb Biozan. Having trouble with Nordic's in micro motion, trobleshoot same . Loaded CT with 60 bbl of 2ppb biozan RU to reverse cir CT for slack management Hold PJSM. PU lubricator. Remove BPV from well. RD and LD lubricator. Hold PJSM with night crew in Ops cab. MU a-coil head. Test same. MU nozzle BHA assembly. Stab coil. Get on well. Close choke and open master & swab valves to test SSSV. No WHP. Run in hole to 1950'. Circulate out diesel to tiger tank. Repair leaking hardline in reel. Continue to circulate. 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.i 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 12/7/2006 ~ 02:00 - 03:00 ~ 1.00 ~ KILL ~ P 03:00 - 04:00 I 1.001 KILL I 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 I 0.501 KILL I P 20:15 - 00:00 I 3.751 STWHIPI P 12/8/2006 100:00 - 04:30 I 4.50 I ST W H I P I P 04:30 - 07:00 I 2.501 STWHIPI P 07:00 - 08:35 I 1.581 STWHIPI P 08:35 - 10:45 I 2.171 STWHIPI P 10:45 - 12:20 1.58 DRILL P 12:20 - 13:00 0.67 DRILL P Page 2 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 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, BOT 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. DHW0B: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: 1/16/2007 10:32:30 AM BP AMERICA 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 ~I From - To ;Hours Task Code ~ NPT 12/8/2006 12:20 - 13:00 .0.67 DRILL P 13:00 - 15:15 2.25 DRILL P 15:15 - 16:30 ~ 1.25 (DRILL ~ 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 Start: 12/5/2006 Rig Release: 1/9/2007 Rig Number: Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 07:00 - 09:00 2.00 DRILL P PROD1 09:00 - 10:00 1.00 DRILL P PROD1 10:00 - 11:45 1.75 DRILL P PROD1 11:45 - 12:10 0.42 DRILL P PROD1 12:10 - 12:25 0.25 DRILL PROD1 12:25 - 16:45 4.33 DRILL P PROD1 Page 3 of 30 ~ Spud Date: 12/5/2006 End: 1 /9/2007 Description of Operations to drill build section 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 C~ 7177 ft TOW Q 7181 Ft BOW @ 7190 ft RA Marker @ 7187 ft 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 Wiper trip at 7337 ft MD 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'. Wlper 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. At surface. Get off well. PUII and LD BHA assembly. Bit 1-1. Hold PJSM with crew in Ops Cab. MU lateral BHA assembly with USMPR resistivity tool. Get on well. Run in hole. Open sssv. Continue in hole. Hold 170-180 psi WHP to allow 1:1 rtns. Log gr tie in from 7080'. Subtract 14' correction. 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 POOHTrapped 350 psi below SSSV at 2040 ft. Held PJSM on handling BHA. Meeting conducted by BHI DD trainee. LD BHA and change AKO setting on motor to 1.5 deg, checked bit, cleaned out jets, changed out LOC. PU and RIH RIH circulating at 1:1. Tie-in at 7100 ft MD (RA Marker at 7186.8 ft) Substracted 15 ft RIH Drilling Trunk Lateral Section at 80-100R TF Printed: 1/16/2007 10:32:30 AM BP AMERICA Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 C-01 1 C-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date I From - To I Hours I Task I Code I NPT - -- _ --- 12/9/2006 ~ 12:25 - 16:45 4.33 ~ DRILL P 16:45 - 17:25 ~ 0.67 ~ DRILL ~ P 17;25 - 19:30 I 2.081 DRILL I P 19:30 - 20:15 0.75 DRILL P 20:15 - 22:30 225 DRILL P 22:30 - 23:30 1.00 DRILL P 23:30 - 00:00 0.50 DRILL P 12/10/2006 00:00 - 02:30 2.50 DRILL P 02:30 - 03:15 0.75 DRILL P 03:15 - 03:45 0.50 DRILL P 03:45 - 04:30 0.75 DRILL P 04:30 - 07:00 2.50 DRILL P 07:00 - 08:30 1.50 DRILL P 08:30 - 11:30 3.00 DRILL N 11:30 - 11:35 I -0.081 DRILL I P 11:35 - 12:15 0.67 DRILL P 12:15 - 12:40 0.42 DRILL P WAIT Page 4 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 PRODi Op = 2.50 / 2.28 bpm CTP = 2350 psi WOB 1-3k ROP, 25 60 fph BHP = 3260psi ECD = 9.67 ppg WHP = 51 psi Vp= 381 bbl PROD1 Wiper trip. Talked to Schlumberger about using their Farr tongs setup for running 3-3/16" tubing on this liner job. PROD1 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=51 psi Vp= 409 bbl PROD1 Wiper trip to window. Hole smooth. PROD1 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: varialbe. 15 to 100 fph. Appear to drilling through formation changes. PROD1 Wiper trip to tbg tail. Hole smooth. PROD1 Log gr tie in from 7,080'. Add 4' correction. PROD1 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 ! PROD1 Wiper trip to window. Hole smooth. PROD1 Log gr tie from 7080'. Add 2' correction. PROD1 Wiper trip to TD. Start new flo pro down coil. Confirm td is 8160'. PROD1 POOH laying in new flopro. PROD1 Held PJSM and LLD BHA. RU to run liner PROD1 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 lhr. Called Veco Dispatch for a crane. Kupuark's crane showed up at 10:00 hrs and I was informed that they will install 1 C-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. PROD1 Spotted crane open cattle chute, loaded Farr tongs in pipe shed and close cattle shoot PROD1 Prep tongs for 3-3/16' tubing PROD1 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 Operations Summary Report Page 5 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: i Date From - To ' Hours ; Task Code ~! NPT Phase I Description of Operations 12/10/2006 12:40 - 16:00 3.331 CASE P PROD1 Running 3-3/16" liner Filled 1/2 way in with liner. Lost rig 16:00 - 17:00 1.001 CASE P PROD1 17:00 - 19:15 I 2.251 CASE I P I I PROD1 19:15 - 22:00 I 2.751 EVAL I P I I PROD1 22:00 - 22:45 0.75 EVAL P PROD1 22:45 - 23:30 0.75 EVAL P PROD1 23:30 - 00:00 0.50 EVAL P PROD1 12/11/2006 00:00 - 07:00 7.00 EVAL P PROD1 07:00 - 07:30 I 0.501 CASE I P I I PROD1 07:30 - 09:00 1.50 CASE N WAIT PROD1 09:00 - 13:15 4.25 CASE P PROD1 13:15 - 16:00 I 2.751 CASE I P I I PROD1 16:00 - 19:00 I 3.001 BOPSUFI P I I PROD1 19:00 - 00:00 I 5.001 BOPSUFI P I I PROD1 12/12/2006 00:00 - 03:00 3.00 CASE P PROD1 03:00 - 05:00 2.00 CASE P PROD1 05:00 - 06:45 1.75 CASE P PROD1 06:45 - 10:00 I 3.251 CASE I P I I PROD1 power, restart PU jewerly at the top of the liner and the BHI MWD. Set counter to 1040.8 ft 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#. 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. Hold PJSM with Hallib. and Nordic. Spot slickline unit. Bring lubricator in through pipe shed. Continue to POH with GS BHA. Flow check. Get off well. LD GS BHA assembly. Finish rigging up Halliburton. 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. PJSM on pickling the 2-3/8" CT for storage and transportation to Nordic 1 Cir and wait on N2 pumper. Doyon 16 rig move to MPU. N2 pumper is behind rig Pumping CT pickle fluid cocktail Blow down with Nitrogen Bleed down to tiger tank 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" BOP Test. Chuck Sieve waived witnessing the BOP test. Installing 2" CT into reel house. MU hard line inside reel. Continue BOP test. Choke manifold. Rebuild two valves. SLB converting injector from 2-3/8" to 2". Also converting packoff assembly. Complete BOP test and injector conversion from 2-3/8" to 2". MU packoff assembly to injector. Stab coil in injector. MU external coil connector and Baker dart catcher. Fill coil with kcl water and circulate 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: 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 NPT Phase ~ Description of Operations -_,_ 12/12/2006 10:00 - 13:00 3.00 CEMT P 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 13:00 - 14:00 1.00 CEMT P 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 14:00 - 16:00 2.00 CEMT P PROD1 Displacing wellbore to 2% KCL DS. Spot and RU SLB cementers. 16:00 - 17:00 1.00 CEMT P PROD1 Hold PJSM with Nordic & SLSB crews. Batch mix cement. Pressure test lines to 4000 psi. 17:00 - 18:00 1.00 CEMT P 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. Dlsplace 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. Unsling. Circulate out of hole keeping 1:1 rtns. 18:00 - 20:00 2.00 CEMT P PROD1 Circulate out of hole replacing voidage, overall 1:1. Adjust WHP to maintain correct returns. Close TRSSSV 20:00 - 20:30 0.50 CEMT P PROD1 LD CTLRT tools and load out 20:30 - 21:00 0.50 CASE P PROD1 RU DS N2 pumper. Spot HES WL unit 21:00 - 22:00 1.00 CASE P PROD1 Stab back on and WO rig water and McOH 22:00 - 22:55 0.92 CASE P 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 22:55 - 00:00 1.08 CASE P PROD1 DS blow down reel w/ N2 and bleed off to tiger tank 12/13/2006 00:00 - 01:15 1.25 CASE P PROD1 Cut off BTT CTC. Install internal grapple and pull CT back to reel and secure 01:15 - 01:40 0.42 CASE P 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" reel 01:40 - 05:50 4.17 CASE P PROD1 Bring HES WL tools to floor. RU BOP's and lub. PT 900 psi. R1H w/ DOB4 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 05:50 - 07:00 1.17 CASE P PROD1 At surface with slickline BHA. Get off well. Tool indicates sleeve has shifted. Rig down Halliburton slickline. 07:00 - 09:00 2.00 DRILL P PROD1 Hold PJSM to review stabbing e-coil.. Good discussion. Move injector over well. Release coil from reel. Pull coil through injector. 09:00 - 11:30 2.50 DRILL P PROD1 MU kendal connector. Circulate two coil volumes with flopro mud. MU Baker connector. Test a-line. 11:30 - 13:30 2.00 DRILL N WAIT PROD1 Baker held up by 4ES rig move from M Pad to DS 1. 13:30 - 14:30 1.00 DRILL P PROD1 MU milling/clean out BHA. 2.74 " HTC mill (D331GEB) had fine cutright added to top of three of six "blades" to provide Printed: 1/76/2007 10:32:30 AM i BP AMERICA 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 1 NPT 12/13/2006 13:30 - 14:30 1.00 DRILL P 14:30 - 14:45 0.25 DRILL P 14:45 - 16:00 1.25 DRILL P 16:00 - 16:15 0.25 DRILL P 16:15 - 17:00 0.75 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 18:20 0.33 DRILL P 18:20 - 18:40 I 0.331 DRILL ~ P 18:40 - 20:40 I 2.001 DRILL I P 20:40 - 00:00 I 3.331 DRILL I P 12/14/2006 ~ 00:00 - 01:30 i 1.50 ~ DRILL ~ P 01:30 - 02:00 I 0.501 DRILL I P 02:00 - 04:00 2.00 DRILL P 04:00 - 04:40 0.67 DRILL P 04:40 - 06:15 1.58 DRILL P 06:15 - 07:30 1.25 DRILL P 07:30 - 07:45 0.25 DRILL P 07:45 - 08:00 0.25 DRILL P 08:00 - 11:15 3.25 DRILL P 11:15 - 12:30 1.25 DRILL P 12:30 - 15:00 2.50 DRILL P Page 7 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 backreaming capability. Stab coil. Get on well. PROD1 Open SSSV. Bleed off WHP. Monitor well for flow to verify sliding sleeve and floats etc are holding. Well stable. PROD1 Run in hole. PROD1 Log GR tie in from 7,170'. Subtract 15' correction. PROD1 RIH. Tag btm at 8038'. PU and bring pumps uo to 1.5 bpm at 2175 psi fs. PROD1 Mill out cement and float equipment. PROD1 Drill to 8040.6' where motor stalled. PUH w/ initial sli overpull due to being packed off aVabove 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 PROD1 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' PROD1 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' PROD1 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' PROD1 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 dill and wt which was the calculated bottom of the shoe. Found a cement stringer at 8048', then hole was clean to 8065'. MWD GR quit during this time PROD1 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# PROD1 POOH from 8065' circ thru mill 1.6/2300. Close TRSSSV. PROD1 LD and load out milling assy PROD1 MU drilling assy. Stab coil. Test tools. Get on well. PROD1 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. PROD1 Log gr tie in from 7186'. Subtract 16' correction. PROD1 Run in hole to TD. Tag btm at 8160'. PROD1 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. PROD1 W Iper trip to RA tag at 7187'. (exit angle is 14 deg at "window"). Hole smooth. PROD1 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. 15:00 - 18:00 3.00 DRILL N DPRB PROD1 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 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: ... NORDIC CALIST A Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours , Task - Code ~ NPT Phase i 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. 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. 18:00 - 18:15 0.25 DRILL N DPRB PROD1 Crew change/safety mtg. Also discuss the 'thump'. This usually means that the reel bushings will need replacement within a few more runs. Elect to do it now 18:15 - 19:00 0.75 DRILL N PROD1 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 19:00 - 21:00 2.00 DRILL N SFAL PROD1 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 21:00 - 00:00 3.00 DRILL N SFAL PROD1 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 12/15/2006 00:00 - 02:30 2.50 DRILL N SFAL PROD1 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 02:30 - 04:00 1.50 DRILL N SFAL PROD1 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' 04:00 - 05:00 1.00 DRILL N SFAL PROD1 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 05:00 - 06:00 1.00 DRILL N SFAL PRODi Safety mtg re: Cut off CT Cut off 1000 ' CT. Line test not showing we are getting any '~, closer to line fault. 06:00 - 09:30 3.50 DRILL N SFAL PROD1 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. ', 09:30 - 10:30 1.00 DRILL N SFAL PROD1 Rig up nitrogen pumper. Displace reel to rig water. 10:30 - 11:45 1.25 DRILL N SFAL PROD1 Hold PJSM. Blow down reel with N2. Bleed off to tiger tank. 11:45 - 13:30 1.75 DRILL N SFAL PROD1 PJSM. RU grapple and tugger line. Unstab coil and secure on reel. Remove inner reel hard line. Lower reel on to lowboy for transport. 13:30 - 15:30 2.00 DRILL N SFAL PROD1 PJSM. Spot new reel on lowboy under reel house. Lift into reel house. 15:30 - 18:15 2.75 DRILL N SFAL PROD1 Install bulk head connection and hardline inside reel. 18:15 - 20:15 2.00 DRILL N SFAL PROD1 Install internal grapple into new 2" HS90 E-CT and PT. Pull CT to injector and stab. Install new packoff. Set injector over bunghole i 20:15 - 22:15 2.00 DRILL N SFAL PROD1 Fill CT w/ 5 bbls McOH followed by 40 bbls FW at 1.0 bpm. t 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: 1 C-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 Start: 12/5/2006 Rig Release: 1/9/2007 Rig Number: Phase PROD1 PROD1 02:30 - 03:15 0.75 DRILL N SFAL PROD1 03:15 - 04:00 0.75 DRILL N DPRB PROD1 04:00 - 04:45 0.75 DRILL N SFAL PROD1 04:45 - 05:20 0.58 DRILL N SFAL PROD1 05:20 - 06:15 0.92 DRILL N DPRB PROD1 06:15 - 06:45 0.50 DRILL N DPRB PROD1 06:45 - 08:45 2.00 DRILL N DPRB PROD1 108:45 - 10:30 I 1.751 DRILL I P ( I PROD1 10:30 - 13:00 I 2.501 DRILL I C I I PROD1 13:00 - 15:30 I 2.501 DRILL I C I I PROD1 15:30 - 16:30 I 1.001 DRILL I C I I PROD1 16:30 - 17:45 1.25 DRILL C PROD1 17:45 - 19:00 1.25 DRILL C PROD1 19:00 - 19:30 0.50 DRILL C PROD1 19:30 - 20:00 0.50 DRILL C PROD1 20:00 - 20:45 0.75 DRILL C PROD1 20:45 - 22:00 1.25 DRILL C PROD1 22:00 - 23:50 1.83 DRILL C PROD1 Page 9 of 30 ~ Spud Date: 12/5/2006 End: 1 /9/2007 Description of Operations Stab onto well. Reverse slack into reel. Cut off 29' CT 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 Breakoff XO, inspect, tighten and re-PT at 4050 psi Set injector over bung hole and displace FW w/ mud while MU BHA SWS regrease pressure bulkhead packing after it had a slow leak. Re-PT at 4000 psi BHI remeg line and had bad test. Flnd short at UOC and fix. Stab on w/ inj RIH w/ BHA #11 to 200'. Open EDC. Pump slack forward 2.4/3280 while RIH. Park coif 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. Log gr tie in from 7200'. Subtract 15' correction. Wiper trip through open hole. Several set downs. Maintain as drilled TF. Tag btm at 8440'. PU and ream btm 50'. 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. Dlvert 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. 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. Wiper trip to window. Circulate out of hole holding 3200 psi equivalent BHP. Close sssv. Flow check. Circulate OOH to surface. 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. MU BHA. Stab coil. Test tools. Get on well. RIH circ thru EDC following pressure schedule. Open TRSSSV w/ 300 psi assist Log tie-in down, corr -15' RIH thru liner circ thru EDC 1.65/2300 to 8064' 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 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' 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: 1/16/2007 10:32:30 AM • BP AMERICA Operations Summary Report Legal Well Name: 1 C-01 Common Well Name: 1 C-01 Event Name: REENTER+COMPLETE Start: 12/5/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date i From - To I Hours Task Code NPT Phase 12/16/2006 22:00 - 23:50 1.83 DRILL C PROD1 23:50 - 00:00 0.17 DRILL C PROD1 12/17/2006 00:00 - 00:15 0.25 DRILL C PROD1 00:15 - 02:00 1.75 DRILL C PROD1 02:00 - 03:15 ~ 1.25 ~ DRILL ~ C ~ ~ PROD1 03:15 - 04:45 I 1.501 DRILL I C I I PRODi 04:45 - 05:10 0.42 DRILL C PROD1 05:10 - 05:30 0.33 DRILL C PROD1 05:30 - 05:50 0.33 DRILL C PRODi 05:50 - 06:00 0.17 DRILL C PROD1 06:00 - 09:00 3.00 DRILL C PROD1 09:00 - 11:15 I 2.251 DRILL I C I I PROD1 11:15 - 13:45 ~ 2.50 ~ DRILL ~ C ~ ~ PROD1 13:45 - 16:15 I 2.501 DRILL IC I IPRODI 16:15 - 17:45 I 1.501 DRILL I C I I PROD1 17:45 - 18:10 0.42 DRILL C PROD1 18:10 - 18:25 0.25 DRILL C PROD1 18:25 - 18:40 0.25 DRILL C PROD1 18:40 - 00:00 5.33 DRILL C PROD1 12/18/2006 00:00 - 00:40 0.67 DRILL C PROD1 00:40 - 01:40 1.00 DRILL C PROD1 01:40 - 07:30 5.83 DRILL C PROD1 Page 10 of 30 ~ Spud Date: 12/5/2006 End: 1 /9/2007 Description of Operations Returns have become crude cut and 'out' density has dropped to 8.5 ppg Wiper to shoe prior to POOH for bit Wiper to shoe was clean 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 Check motor, okay. M09X bit was 1-1-I (had no chips, only micro dulled) 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 Log tie-in down from 7190', Corr -16' RIH thru liner Circ thru EDC 0.4/1130 following pressure schedule Close EDC at 8050'. Wiper to TD Ream last 18' to TD tagged at 8516.2' while break in bit 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. 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/BHP/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. 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. 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. Run in hole. Pressure well to 400 psi. Open sssv. Continue to RIH. Follow pressure schedule Log tie-in down from 7190', corr -17' RIH thru liner to 8050'. Close EDC W iper to TD tagged at 8634' was clean 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 in and out of assumed minor siderite streaks to 8765' Drill from 8765-8790' at 94 deg. Lost 5 deg at 8755' Wiper to shoe was clean Continue drilling pilot invert from 8790' 1.6/2700/208 w/ 100 psi Printed: 1/16/2007 10:32:30 AM BP AMERICA Operations Summary Report Legal Well Name: 1C-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 12/18/2006 ~ 01:40 - 07:30 ~ 5.83 ~ DRILL ~ C 07:30 - 08:30 1.00 DRILL C 08:30 - 12:00 3.50 DRILL C 12:00 - 14:45 I 2.751 DRILL I C 14:45 - 15:30 0.75 DRILL C 15:30 - 22:00 6.50 DRILL P 22:00 - 00:00 2.00 CASE C 12/19/2006 00:00 - 02:00 2.00 CASE C 02:00 - 03:00 1.00 CASE C 03:00 - 04:30 1.50 CASE C 04:30 - 04:50 0.33 CASE C 04:50 - 06:00 1.17 CASE C 06:00 - 08:30 2.50 CASE X 08:30 - 09:00 0.50 CASE X 09:00 - 11:00 2.00 CASE X 11:00 - 12:00 1.00 CASE X 12:00 - 15:00 3.00 FISH X 15:00 - 17:00 2.00 BOPSU X 17:00 - 17:45 0.75 FISH X 17:45 - 19:30 1.75 FISH X 19:30 - 20:20 I 0.831 FISH I X Page 11 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 dill, 1-2k wob w/ 100 psi whp for 9.80 ECD at 92 deg in and out of thin siderite beds PROD1 Wiper trip to liner shoe. Hole smooth. PROD1 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. PROD1 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 PROD1 LD drilling BHA. Secure tree. Circ mud thru CT at min rate to bung hole PROD1 Safety Standdown w/ day, then Hite crews (31 total personnel) PROD1 RU pipeshed and floor to run liner PROD1 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) PROD1 MU BHI MWD assy PROD1 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 PROD1 Close EDC. Log tie-in down from 7770', Corr -17'. Wt chk 25.4k PROD1 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 DFAL ~ PROD1 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. DFAL PROD1 Trap 300 psi WHP. Shut in pump. Activate EDC. Released from lower BHA at 30k# up wt. DFAL PROD1 POOH circulating at min rate. Maintain 350 psi WHP. Order fishing tools from Deadhorse. DFAL PROD1 At surface. Get off well. Unstab coil. LD recovered BHA. DFAL PROD1 Re-head coil with Kendal and Inteq flow sub. PT 35k, 4000 psi SFAL PROD1 Nordic repair hyd leak on actuator on TOT BOP's and PT Fishing tools arrive. Bring tools to floor DFAL PROD1 MU fishing BHA DFAL PROD1 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. DFAL PROD1 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 Operations Summary Report Legal Well Name: 1C-01 Common Well Name: 1C-01 Event Name: REENTER+COMPLETE Start: 12/5/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours I, Task Code NPT ~ Phase _ -- -L 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 I 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 I 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 - 18:00 0.25 STKOH X PROD1 18:00 - 19:00 1.00 STKOH X PROD1 Page 12 of 30 ~ Spud Date: 12/5/2006 End: 1 /9/2007 Description of Operations 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 lot 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 mfg 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 W FT 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 lbpm and release GS from WTF aluminum Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 13 of 30 ~ Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 C-01 1 C-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 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 billet OHWS. PU wt 23.5 w/pump. Still 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 +/- 1 k 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. PROD1 TOH hold PJSM review plan forward to LD WTF tools. Also discuss what-if plans should the liner be still attached. 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. PROD1 TIH following pressure schedule. tagged top of 3-3/16" liner at 7064' with 180 TF rotate to HS went through good. PROD1 Log tie in. Subtract 16' PROD1 Continue TIH. Tagged top of alum billet at 8202'. 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 PROD1 Drill to 8203', reduce whp from 350 psi to 100 psi (10.6 ECD to 9.5 ECD) PROD1 Start adding up to 1 k wt and drill from 8203-8220' 1.81/3200/70L w/ 9.6 PROD1 Backream/ream by billet at DTF twice until clean 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 PROD1 W iper to 3-3/16" shoe was clean. Wiper thru 3-3/16" was clean PROD1 Open EDC at 7000'. POOH circ 2.0/3250 following pressure schedule. Wash TRSSSV before closing w/ 380 psi PROD1 LD sidetrack assy. Bit was the same as before RIH PROD1 MU drilling assy w/ resistivity 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 PROD1 Log tie-in down from 7180', corr -15' PROD1 RIH thru 3-3/16" liner. Start pump and precautionary ream to 8220' PROD1 Log MAD pass down from 8220' 1.66/3030/60L w/ 100 psi whp to TD PROD1 Backream and ream at full rate thru sidetrack area and was clean PROD1 Drill from 8247' 1.65/2950/90L w/ 100-200 psi diff, 0.6-2.Ok wob w/ 100 psi whp Date ;From - To !Hours ; Task I Code ! NPT 12/20/2006 18:00 - 19:00 ~ 1.00 ~ STKOH X 19:00 - 20:45 I 1.75 I STKOH I C 20:45 - 22:10 I 1.42 I STKOH I C 22:10 - 23:45 1.581 STKOH C 23:45 - 00:00 0.25 STKOH C 12/21/2006 00:00 - 00:40 0.67 STKOH C 00:40 - 06:00 5.33 STKOH C 06:00 - 06:45 I 0.75 I STKOH I C 06:45 - 08:00 I 1.25 I STKOH I C 08:00 - 08:45 0.75 STKOH C 08:45 - 09:50 1.08 STKOH C 09:50 - 10:25 0.58 STKOH C 10:25 - 12:00 1.58 STKOH C 12:00 - 12:30 0.50 STKOH C 12:30 - 14:10 1.67 DRILL C 14:10 - 15:45 1.58 DRILL C 15:45 - 16:10 0.42 DRILL C 16:10 - 16:30 0.33 DRILL C 16:30 - 16:45 I 0.251 DRILL I C 16:45 - 17:10 I 0.421 DRILL I C 17:10 - 21:30 I 4.331 DRILL I X Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 14 of 30 ~ Operations Summary Report Legal Well Name: 1C-01 Common Well Name: 1 C-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 12/5/2006 Rig Release: 1/9/2007 Rig Number: Spud Date: 12/5/2006 End: 1 /9/2007 Date :From - To ~ Hours ~ Task ~I Code'~~i NPT 12/21/2006 ~ 21:30 - 22:15 0.751 DRILL ~ X 22:15 - 00:00 I 1.751 DRILL I X 12/22/2006 100:00 - 03:45 I 3.751 DRILL I P 03:45 - 04:45 1.00 DRILL P 04:45 - 06:00 1.25 DRILL P 06:00 - 09:10 3.17 DRILL P 09:10 - 09:55 0.75 DRILL P 09:55 - 10:10 0.25 DRILL P 10:10 - 10:35 0.42 DRILL P 10:35 - 11:00 0.42 DRILL P 11:00 -13:30 2.50 DRILL P 13:30 - 14:25 0.92 DRILL P 14:25 - 17:30 3.08 DRILL P 17:30 - 18:30 1.00 DRILL P 18:30 - 21:20 2.83 DRILL P 21:20 - 23:25 I 2.081 DRILL I P 23:25 - 23:35 0.17 DRILL P 23:35 - 00:00 0.42 DRILL P 12/23/2006 00:00 - 00:30 0.50 DRILL P 00:30 - 03:55 3.42 DRILL P 03:55 - 05:30 1.58 DRILL P 05:30 - 07:50 2.33 DRILL P 07:50 - 09:05 1.25 DRILL P 09:05 - 10:20 1.25 DRILL P 10:20 - 11:50 I 1.501 DRILL I P 11:50 - 13:15 ~ 1.42 ~ DRILL ~ P Description of Operations I Phase I; - --- - - PROD1 Wiper trip back to 3-3/16" shoe. No problems. Went past alum billet fine. 25k off bottom PROD1 Continue drilling ahead f/ 8400' to 8457' 1.60/1.60 3000psi FS 2-300psi MW .5-2k WOB 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 PROD1 Wiper trip to 8000'. No problems PROD1 Continue drilling f/ 8443' 1.60 / 1.60 3010psi 100-200psi mw Ann= 3877 ECD= 11.82 WHP= 210 WOB= 1 k 15-20'/hr 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 PROD1 W iper to shoe was clean except for overpull at 8550'. Continue wiper to 7080' while circ thru bit. Open EDC PROD1 Log tie-in down from 7190' circ thru EDC 2.1/3240 w/ 100 psi whp. Add 6.0' PROD1 RIH circ thru EDC 2.15/3250 to 8000' PROD1 Wiper to TD was clean except for one setdown at 8550' (had drilled thru hard spot here) 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' PROD1 Wiper to shoe was clean both directions PROD1 Drill from 8850' 1.58/3010/90L w/ 50-250 psi diff, 0.5-2.Ok wob w/ 100 psi whp giving 3521 psi dhp or 10.50 ECD. Drill to 9000' PROD1 Wiper to shoe. Slight bobble at 8552' going back in. 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. 1k wob 40-50'/hr PROD1 Wiper trip. At 8050' trap 450 on well and open EDC. PUmp 1.9bpm up to 7050'. PROD1 Log tie-in to RA marker at 7187' plus 8' correction PROD1 Wiper trip in hole. No problems at 8550'. PROD1 Wiper trip back to bottom. No hole problems 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'. PROD1 Wiper trip to 8200'. No problems. 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. Drill to 9292' with 1.5k wob and going nowhere fast PROD1 Wiper to window was clean. Wiper to 7000' was clean PROD1 Open EDC at 7000'. POOH circ 2.0/3000 following pressure schedule. Close TRSSSV w/ 400 psi PROD1 LD drilling BHA. Bit was microdulled, motor okay. Change bit, add agitator 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: 1C-01 Common Well Name: 1 C-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALIS TA 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 Start: 12/5/2006 Rig Release: 1/9/2007 Rig Number: Spud Date: 12/5/2006 End: 1 /9/2007 17:00 - 18:00 1.00 DRILL P 18:00 - 19:50 1.83 DRILL P 19:50 - 22:15 ~ 2.42 ~ DRILL ~ 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 ~ 1.67 ~ DRILL i P 03:10 - 05:10 I 2.001 DRILL I P 05:10 - 07:10 I 2.001 DRILL I 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 I 1.081 DRILL I P 10:00 - 10:25 0.421 DRILL N I SFAL 10:25 - 12:30 I 2.081 DRILL i N I SFAL 12:30 - 14:30 I 2.001 DRILL I N 1 SFAL 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 314 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 180TF 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 W iper 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 thru 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) PROD1 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' 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 PROD1 Red rate to 0.75/1800 and incr whp to 300 psi to hold 3500 psi dhp or 10.55 ECD 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: 1/16/2007 10:32:30 AM • BP AMERICA Page 16 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 I, From -To ~ Hours ~ Task Code NPT Phase _ 12/24/2006 ~ ~ 12:30 - 14:30 ~ ___ _ I 2.00 ~ _ DRILL _ __ ~ N SFAL PROD1 14:30 - 18:00 I 3.501 DRILL I N 18:00 - 18:20 i 0.331 DRILL I N 18:20 - 19:30 I 1.171 DRILL I N 19:30 - 00:00 4.50 DRILL N 12/25/2006 - 0.00 00:00 - 06:00 6.00 DRILL N 06:00 - 10:00 10:00 - 16:30 4.001 DRILL I N 6.50 i DRILL ~ N 16:30 - 18:00 1.50 DRILL N 18:00 - 18:20 0.33 DRILL N 18:20 - 21:40 3.33 DRILL P 21:40 - 22:15 0.58 DRILL P 22:15 - 23:30 1.25 DRILL P SFAL IPRODI PROD1 PROD1 PROD1 SFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Description of Operations Further investigation showed that the motor needs to be replaced Safety mtg. Begin dismantling hoses, bolts, etc to remove power pack assy which includes traction motor. Replacement motor arrives from SWS Deadhorse. Crane 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 Review plan forward to remove power unit package with crane operator. Insure all personnel or out of the TechLimit office during the lifting operations. Remove power pack and loadout on truck. Take to KIC for traction motor swap. Circulate hole at 1.3bpm and wait. Maintaining 100psi WHP. Merry Christmas 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 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. 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 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 Review start-up procedures for the Power Pack with oncoming crews. 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. Setback injector. LD BHA. Isolate res tool and test calibration. Need to work on SCR. When the power pack went out it also Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 17 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: NORDIC CALIST A Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date '~ From - To ~~ Hours Task i 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', tort -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 dirt, 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'. Aiso 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 PROD1 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 ftCorrected -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: 1C-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours ~ Task ; Code ~ NPT 12/27/2006 ~ 08:10 - 09:10 ~ 1.00 ~ CASE ~ P 09:10 - 09:20 I 0.171 CASE I P 09:20 - 10:45 I 1.421 CASE I P 10:45 - 11:30 0.75 CASE P 11:30 - 13:50 2.33 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 STWHIPI 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 STWHIP 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 ~ 1.751 STWHIP P 09:00 - 10:45 1.751 STWHIP P Spud Date: 12/5/2006 Start: 12/5/2006 End: 1 /9/2007 Rig Release: 1/9/2007 Rig Number: Phase I Description of Operations i PROD1 LD BHi tools. Unable to circ coil. Trace down to beads in the charge pump. Coil almost frozen. PROD1 PJSM: discuss hazards with picking up liner. Review potential pinch points on the rig floor with the hands. PROD1 PU top section of liner. Baker Lock all jewelry connections. Guide shoe and o-ring sub's inner portion are drillable. PROD1 PU BHi tools. Stab on injector. PROD1 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 PROD1 TOH following pressure schedule 1.4gpm taking returns over shaker stripping out beads. PROD1 PJSM review LD BHA and PU Baker Whipstock and BHi tools. PROD1 PU Baker Mono Bore TT Whipstock setting tool and BHi orienter and GR tools. PROD1 RIH with BOT TTWS PROD1 Stopped at 7230 ft and PUH to 7225 ft. Logged tie-in from 7225ft to 7200 ft Corrected (-15 ft) PROD1 RIH and set TOWS at 7750 ft and bottom at 7758 ft Confirmed depth with 33/16" pipe tally in relationship to no/go on 4-1/2" TT. SD pump and closed EDC Set TF at 90L of HS PROD1 Set WS using 4,400 psi Whipstock from 7,750 ft and 7,758 ft PROD1 POOH, trapped 400 psi below SSSV PROD1 OOH, held PJSM and identified the hazards associated with handling the WS setting BHA and injector head PROD1 LD WS setting BHA. MU BHI's BHA. PU 2.74" DSM BHA PROD1 RIH to mill window PROD1 RIH to mill window PROD1 Logged tie-in from 7170 ft to 7189 ft and corrected -15 ft PROD1 RIH and dry tagged TOWS at 7750 ft Tagged at 7751 ft PROD1 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 PROD1 Drill rathole f/ 7756' to 7766'. Back ream clean-up window area twice. Dry run / wo pump thru window looks good. PROD1 Open EDC and POH follow pressure schedule. At 1500' close SSSV. 10:45 - 10:55 0.17 STWHIP P PROD1 PJSM review plan forvvard. LD BHI / BTT tools. Review plans for doing 'slack management' on coil. 10:55 - 11:35 0.67 STWHIP P PROD1 Observe well for flow. Unstab injector. LD BHA. 11:35 - 16:40 5.08 STWHIP N SFAL PROD1 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 Page 19 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 i Start Rig Rig Phase ~~ Spud Date: 12/5/2006 : 12/5/2006 End: 1 /9/2007 Release: 1/9/2007 Number: i 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. Rehead w/ SLB Kendal CTC. Warmed coil again. 16:40 - 21:00 4.33 DRILL N SFAL PROD1 Rehead 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 PROD1 W iper 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 Wiper trip to 7760 ft 04:00 - 07:10 3.17 DRILL P PROD1 Drilling Zone C2 and headed up to C3 at TTurned 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'/hrwob 1-2k May have a cederite stringer. Pulled 5k over off bottom. Close Printed: 1/16/2007 10:32:30 AM ! ~ BP AMERICA Operations Summary Report Legal Well Name: 1C-01 Common Well Name: 1C-01 Event Name: REENTER+COMPLETE Start: 12/5/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours '. Task Code NPT Phase ~ 12/29/2006 07:25 - 09:25 2.00 DRILL P PROD1 09:25 - 10:30 1.08 DRILL P PROD1 10:30 - 10:40 0.17 DRILL P PROD1 10:40 - 11:20 0.67 DRILL P PROD1 11:20 - 13:30 2.17 DRILL P PROD1 13:30 - 14:40 1.17 DRILL P PROD1 14:40 - 16:45 2.08 DRILL P PROD1 16:45 - 17:50 1.08 DRILL P PROD1 17:50 - 18:10 0.33 DRILL P PROD1 18:10 - 18:30 0.33 DRILL N SFAL PROD1 18:40 - 19:00 0.33 DRILL N RREP PROD1 19:00 - 21:00 I 2.001 DRILL I P I I PROD1 21:00 - 22:25 1.42 DRILL P PROD1 22:25 - 00:00 1.58 DRILL P PROD1 12/30/2006 00:00 - 00:15 0.25 DRILL P PROD1 00:15 - 02:45 2.50 DRILL P PROD1 02:45 - 06:00 I 3.251 DRILL I P I I PROD1 Page 20 of 30 ~ Spud Date: 12/5/2006 End: 1 /9/2007 Description of Operations to wiper time.... Wiper trip to above 3-3/16" liner top @ 7060' Log tie in bit @ 7190' +7' Wiper back to bottom. Clean Continue drilling ahead f/ 8333' 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 Wiper trip to window. Continue drilling ahead f/ 8444' Op = 1.50 / 1.50 Vp = 330 turned on centrifuge CTP 3100 / 3300 BHP = 3450 EDC 10.3ppg WHP 100 ROP = 50-80'/hr 1-2k WOB Wiper trip to window. 27k off bottom Continue drilling forward f/ 8600' Op=1.52/1.50 CTP 3020 / 3350 V p = 323 BHP 3412 EDC 10.2 ROP = 40-60'/hr Lost all electrical on rig, Generators shut down because of underfrequence 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 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 ft/hr Started mud swap at 20:00 hrs at 8675 ft Wiper trip to 7760 ft 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 Drilled to 8873 ft and stacking increasing. 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 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 BP AMERICA Page 21 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 ~ i PLET A Code E NPT Start Rig Rig Phase _ Spud Date: 12/5/2006 : 12/5/2006 End: 1/9/2007 Releaser 1/9/2007 Number: Description of Operations __- --- - -- 12/30/2006 02:45 - 06:00 3.25 DRILL P - _ - PROD1 _ Vp = 318 bbl BHP = 3441 psi EDC 10.36 ppg. WHP = 198 psi ROP = 40-60 ft/hr 06:00 - 07:30 1.50 DRILL P PROD1 W iper trip to window. 07:30 - 09:40 2.17 DRILL P PROD1 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 09:40 - 12:40 3.00 DRILL P PROD1 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 W HP observe for flow. 12:40 - 13:15 0.58 DRILL P PROD1 Unstab inj. LD BHA 13:15 - 13:25 0.17 DRILL P PROD1 Shut off electrical power to pumps, drwworks, power pack and replace 600v buss for gen #2 in SCR room 13:25 - 14:30 1.08 DRILL P PROD1 PU BHA w/ 1.7 deg motor and agitator 14:30 - 15:45 1.25 DRILL P PROD1 RIH pumping min rate holding 400psi WHP 15:45 - 16:05 0.33 DRILL P PROD1 Log tie-in minus 16' correction 16:05 - 17:30 1.42 DRILL P PROD1 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. 17:30 - 17:40 0.17 DRILL P PROD1 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 = -1 k Stacking wt. Make a short wiper back to 17:40 - 18:45 1.08 DRILL P PROD1 Wiper slowly back to 8950' in attempt to clean this section up. 1.8:45 - 19:10 0.42 DRILL P PROD1 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 19:10 - 19:30 0.33 DRILL N DPRB PROD1 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 19:30 - 21:53 2.38 DRILL P PROD1 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'/hr 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 Operations Summary Report ,Legal Well Name: 1 C-01 'Common Well Name: 1 C-01 Event Name: REENTER+COMPLETE Start: 12/5/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2007 Rig Name: NORDIC 2 Rig Number: Date ~ From - Too ours ~ Task Code ! NPT Phase 12/30/2006 121:53 - 00:00 2.121 DRILL P PROD1 12/31/2006 00:00 - 00:15 0.25 DRILL P PROD1 00:15 - 02:15 2.00 DRILL P PROD1 02:15 - 02:50 I 0.581 DRILL I P I I PROD1 02:50 - 03:20 0.50 DRILL P PROD1 03:20 - 05:00 1.67 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 05:30 - 07:20 1.83 DRILL P PROD1 07:20 - 09:45 I 2.421 DRILL I P I I PROD1 09:45 - 10:30 0.75 DRILL P PROD1 10:30 - 11:00 0.50 CASE P PROD1 11:00 - 11:10 0.17 CASE P PROD1 11:10 - 12:00 0.83 CASE P PROD1 12:00 - 12:30 0.50 CASE P PROD1 12:30 - 13:15 I 0.751 CASE I P I I PROD1 13:15 - 15:10 1.92 CASE P PROD1 15:10 - 16:40 1.50 CASE P PROD1 16:40 - 16:50 0.17 CASE P PROD1 16:50 - 17:45 0.92 CASE P PROD1 17:45 - 19:45 2.00 CASE P 19:45 - 22:00 2.25 CASE P 22:00 - 22:15 0.25 CASE P 22:15 - 00:00 1.75 CASE P 11/1/2007 100:00 - 02:00 I 2.001 CASE I P 02:00 - 02:25 0.42 CASE P 02:25 - 03:00 0.58 CASE P Page 22 of 30 ~ Spud Date: 12/5/2006 End: 1 /9/2007 Description of Operations 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 Tag bottom after wiper trip at 9273 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' Finally back on bottom at 9317' Drilled to 9325' w/ CTW at 4500#. PU 30k. Drill ahead 40'/hr. TD well at 9345'. PU to tie-in 43K Wiper back to 7190'. Log tie-in plus 14'. W iper trip to bottom. Setdowns at 8838, 8853, 8907, 9024' (pu 33k), 9029, 9065, 9167' then rough going to bottom. Tagged bottom at 9354' 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 Set back injector on legs. LD BHi tools. RU to run liner. PJSM on rig floor. Point out and review hazards for PU liner. MU 1jt solid and 14 jts slotted 2-3/8" 4.4# L80 STL liner. Crew changeout and PJSM with new crew members again on the irg floor reviewing plan forward and hazards for PU 1" CSH. RU 1 " YT elevators, false RT, changeout dies in Little Jerks to 1 ". MU 14jts 1"CSH and spaceout. MU BHi tools MU injector RIH to 7650'. Log tie-in -18'. Make wt check 24.5K RIH smooth no pump maintaining 400psi. Wt ck at 9333' 28k RIH to bottom at 9354'. Bring on pump 1 bpm 2500psi. PU appears to have lost liner 26.5k TOH.. wt ck again at 7650' pulling same speed OOH, Pressured wellbore up to 400 psi and close SSSV, Released pressure and SSSV holding LD MW D and discovered that the liner was still attached. RU and LD 1"CSH. Held PJSM on PU 2-3/8" liner. Determined hazards and mitigated same. PU 2-3/8" STL Liner, Installed W FT'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 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 Log tie-in at 8,150 ftCorrected - 18 ft to 8180.3 ft RIH at 11.4k down at 24 fpm Wt check at 9150 ft, PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 23 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 II From - To Hours Task Code NPT ! Phase I Description of Operations ___, --- _ -- 1/1/2007 102:25 - 03:00 0.58 CASE P PROD1 Down = 8.7k down / 28k at 17 fpm 03:00 - 05:30 2.50 CASE P PROD1 05:30 - 06:00 0.50 CASE P PROD1 06:00 - 06:15 I 0.251 STKOH I P I I PROD1 06:15 - 07:00 ~ 0.75 ~ STKOH P ~ ~ PROD1 07:00 - 07:10 I 0.171 STKOH I P I I PROD1 07:10 - 08:15 1.08 STKOH P PROD1 08:15 - 08:30 0.25 BOPSU P PROD1 08:30 - 09:15 0.75 STKOH P PROD1 09:15 - 10:45 1.50 STKOH P PROD1 10:45 - 10:55 0.17 STKOH P PROD1 10:55 - 11:30 0.58 STKOH P PROD1 11:30 - 14:30 I 3.001 STKOH I P I I PROD1 14:30 - 15:00 0.50 STKOH P PROD1 15:00 - 16:00 1.00 STKOH P PROD1 16:00 - 18:00 I 2.001 STKOH I P I I PROD1 18:00 - 20:00 I 2.001 STKOH I P I I PROD1 20:00 - 21:30 1.50 DRILL P PROD1 21:30 - 21:50 0.33 DRILL P PROD1 21:50 - 22:40 0.83 DRILL P PROD1 22:40 - 00:00 1.33 DRILL P PROD1 1/2/2007 100:00 - 01:35 I 1.581 DRILL I P l I PROD1 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 POOH fill down annulus. Close SSSV. LD BHI CoilTrac MWD and WFT liner running tool Crew change. PSJM between driller and floorhand to prep for CDL. Close swab valve. Hang blocks and remove front guard from drawworks. PSJM with all crew members for CDL, confined space entry. Took into consideration the cold temps which are currently -37 with a W C of -80. CuUslip 60' drlg line. Service injector. Perform weekly BOP fuction test. All's good. PU sidetrack BHA. Stab on injector. RIH to 7190' Log tie in -17' correction RIH back to min rate on pump and tag aluminum billet at 8353.8' 8353.1' with pump. 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 Drill ahead f/ 8360' to 8375'. Backream sidetrack 60 deg high/low from 90L back to 8340' several times. TOH. Seeing alot of AI coming across shakers. Tag up then RIH 500' to clear cuttings. LD ST BHA and checked out tool, install res tool and rebuild FVS and double ball valve. PU BHA RIH Logging tie down starting at 7185 ft Corrected (-17 ft) RIH 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. Drilling build and turn section C3 from 8,406 ft to 8408 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 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 Operations Summary Report Legal Well Name: 1C-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 1/2/2007 00:00 - 01;35 1.58 DRILL P 01:35 - 03:50 2.25 DRILL P 03:50 - 05;30 1.67 DRILL P Start: 12/5/2006 Rig Release: 1/9/2007 Rig Number: Page 24 of 30 Spud Date: 12/5/2006 End: 1 /9/2007 Phase Description of Operations PROD1 PROD1 PROD1 05:30 - 06:45 1.25 DRILL P PROD1 06:45 - 07:00 0.25 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 10:20 I 2.331 DRILL I P I I PROD1 10:20 - 11:20 1.00 DRILL P PROD1 11:20 - 13:30 2.17 DRILL P PROD1 13:30 - 14:45 1.25 DRILL P PROD1 14:45 - 17:15 2.50 DRILL P PROD1 17:15 - 19:00 I 1.751 DRILL I P I I PROD1 19:00 - 23:15 I 4.251 DRILL I P I I PROD1 23:15 - 00:00 0.75 DRILL P PROD1 1/3/2007 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 01:30 0.50 DRILL P PROD1 01:30 - 02:45 1.25 DRILL P PROD1 02:45 - 05:00 2.25 DRILL P PROD1 05:00 - 07:45 2.75 DRILL P PROD1 07:45 - 10:45 3.00 DRILL P PROD1 unable to get it to drill POOH Change out motor, picked up agitator and RR BC bit. Agitator Number AGS218-59-114 RIH Log tie-in minus 7' 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'. Directionally drill ahead f/ 8413' Op = 1.54 / 1.52 CTP = 3724 / 3900 Vp = 247 bbls Ann = 3450 /ECD = 10.33ppg WOB = 3k ROP = 60-90'/hr Wiper trip to whipstock at 7751'. No problems. 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 W iper trip to window. 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 Wiper trip 1st 150 ft is ratty. 5 to 10 k over pulls. Hole smooth on trip in. Drill ahead from 8850'. 3300 psi fs at 1.58 inl1.57 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 scow. 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. Wiper trip to window. Clean trip out. Continue wiper trip to tie in point. Hole mostly smooth. A little ratty from 8,759' to 8,850'. Log gr tie in from 7180'. Add 2' correction. Continue wiper trip back into hole. Drill ahead to 9,150 Wiper trip at 9150 ft Clean trip out 0745 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 10:32:30 AM BP AMERICA 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 I Code ~NPT 1/3/2007 ~ 10:45 - 13:35 ~ 2.83 DRILL P 13:35 - 15:00 1 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 I 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 Page 25 of 30 ~ Spud Date: 12/5/2006 Start: 12/5/2006 End: 1/9/2007 Rig Release: 1/9/2007 Rig Number: Phase j Description of Operations 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 WOB = 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=1.8kat34to50fph 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 WOB / 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 W HP = 200 to 150 psi Printed: 1/16/2007 10:32:30 AM BP AMERICA Page 26 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 - 1 1 /4/2007 12:35 - 13:45 1.17 ` DRILL P 13:45 - 14:25 0.67 DRILL P 14:25 - 17:30 I 3.081 DRILL I P 17:30 - 18:30 1.00 DRILL P 18:30 - 19:30 1.00 DRILL P 19:30 - 22:30 I 3.001 DRILL I P 22:30 - 23:15 I 0.751 DRILL I P 23:15 - 00:00 0.75 DRILL P 1/5/2007 00:00 - 00:45 0.75 DRILL P 00:45 - 01:00 0.25 DRILL P 01:00 - 03:15 2.25 DRILL P 03:15 - 05:00 I 1.751 DRILL I P 05:00 - 09:10 I 4.171 DRILL I P 09:10 - 12:45 I 3.581 DRILL I P Spud Date: 12/5/2006 Start: 12/5/2006 End: 1 /9/2007 Rig Release: 1/9/2007 Rig Number: Phase j Description of Operations PROD1 ROP 1 to 30 fph PROD1 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 PROD1 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. PROD1 At surface. Flow check. Get off well. Unstab coil. LD BHA. PROD1 Reverse circulate through coil. 1850 psi at 1.81 bpm. Reverse 10 bbls water followed by 15 bbls meoh. PROD1 Cut 60' coil and 65' a-line. MU and test a-coil head. Displace water &meoh. PROD1 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 PROD1 Run in hole. Pressure well to 400 psi. Open sssv. Continue to RIH. PROD1 Continue to run in hole. PROD1 Log gr tie in from 7180'. Subtract 16' correction. PROD1 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) PROD1 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. PROD1 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 PROD1 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 N ame: 1 C-01 Common W ell Name: 1 C-01 Event Name : R EENTE R+COM PLETE Contractor N ame: N ORDIC CALIST A Rig Name: N ORDIC 2 Date From - To ~ Hours Task Code NPT 1/5/2007 09:10 - 12:45 3.58 DRILL P 12:45 - 14:15 1.50 DRILL P 14:15 - 14:30 0.25 DRILL P 14:30 - 16:30 2.00 DRILL P 16:30 - 17:30 1.00 DRILL P 17:30 - 20:00 2.50 DRILL P 20:00 -21:15 .1.25 DRILL P 21:15 - 23:15 2.00 DRILL P 23:15 - 00:00 0.75 DRILL P 1/6/2007 00:00 - 02:00 2.00 DRILL P 02:00 - 04:30 2.50 DRILL P 04:30 - 05:30 1.0 0 DRILL P 05:30 - 07:00 1.5 0 DRILL P 07:00 - 09:05 2.0 8 DRILL P 09:05 - 10:45 1.6 7 DRILL P 10:45 - 11:10 0.4 2 DRILL P 11:10 - 11:20 0.1 7 DRILL P 11:20 - 12:50 1.5 0 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 build up to 93 deg to level out at 6,418 ft TVD. Then carry this to 6,425 ft to TD PROD1 Wiper / backream open hole section from 9,650 ft to 9,000 ft Pulled tight 9600 ft, 9535 ft, 9425 ft, 9300 ft, PROD1 Pulled above WS ar 7751 ft. Isolated Swaco choke for repairs. Nordic Electrician checking SCR 2 voltage as for AC leakage. SCR #2 is the cleanest SCR. PROD1 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. PROD1 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 PROD1 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. PROD1 Back ream at 20 fph to window. Several overpulls from 9490 to 9350'. PROD1 Run back in hole. Set down at 9290', 9400', 9533', 9590', 9640' to 9670', 9720'. PROD1 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. PROD1 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. PROD1 Wiper trip back to window. Continue to circulate 1-1.5 ppb beads (in case we run liner right here, as is). PROD1 Log gr tie in from 7140'. Repeat tie in to verify. Add 27' correction. Current TD is 9791'. PROD1 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. PROD1 Checked flow, set back injector Changed out bit orienter and motor. Re run agitator #AGS218-59-114 PROD1 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 PROD1 Tie-in at 7181 ft logging down PROD1 RIH to 7700 ft and trap 400 psi on wellhead. Close EDC Set TF at 90L PROD1 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 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 'I From - To ;Hours Task 'Code NPT Phase Description of Operations - _ -~ ---- - - - - _ I __ ' _ 1 /7/2007 11:00 - 15:10 4.17 ~ DRILL ~ N ~ DFAL ~ PROD1 Waiting on charter with tools from BHI Anchorage 15:10 - 16:30 I 1.331 DRILL I N I DFAL I PROD1 16:30 - 18:15 1.75 DRILL N DFAL PROD1 18:15 - 18:30 0.25 DRILL N DFAL PROD1 18:30 - 20:00 1.50 DRILL N DFAL PROD1 20:00 - 20:45 I 0.751 DRILL I P I I PROD1 20:45 - 21:15 0.50 DRILL P PROD1 21:15 - 00:00 2.75 DRILL P PROD1 1/8/2007 100:00 - 00:45 1 0.751 CASE I P I I PROD1 00:45 - 02:00 I 1.251 CASE I P I I PROD1 02:00 - 04:15 2.25 CASE P PROD1 04:15 - 04:30 0.25 CASE P PROD1 04:30 - 07:45 3.25 CASE P PROD1 07:45 - 09:55 2.17 CASE P PROD1 09:55 - 12:50 2.92 CASE P PROD1 12:50 - 13:55 1.08 CASE P PROD1 13:55 - 14:10 0.25 CASE P PROD1 14:10 - 15:40 1.50 CASE P PROD1 15:40 - 18:00 2.33 CASE P PROD1 18:00 - 18:30 0.50 CASE P PROD1 18:30 - 20:30 2.00 ~ CASE P ~ PROD1 20:30 - 21:00 0.50 CASE P PROD1 21:00 - 22:30 1.50 CASE P PROD1 22:30 - 23:00 0.50 CASE P PROD1 23:00 - 23:45 0.75 CASE P PROD1 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 PU tool to pipe shed. and MU tools on catwalk PU BHA and stab on the well. RIH to cleanout for liner Log gr tie in f/ 7,180'. Subtract 16' correction, Run in hole. Maintain as drilled TF. Hole in good condition to TD. A few tight spots. Tag TD at 10,000'. Back ream out of hole at 1.61 bpm / 20 fpm to 9100'. Some tight spots, but mostly smooth. RIH to 10,000'. POOH laying beads 1:1 POOH laying 2 ppb beads in new flopro at 1:1 displacement. 28k# up, 7k# do CT weight at 9900'. Hold PJSM. At surface. Flow check. Get off well. LD drilling BHA assembly. 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. MU 1 jt 2-3/8" solid and 40 2-3/8" slotted STL liner w/ indexing shoe & o-ring sub. Hold PJSM to discuss picking up the 1"CSH inner string. PU stinger. MU on 1"CSH work string. MU GS running tool, stab injector 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 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 Released from liner. POOH to tie-in PUH logging tie-in at 8480 ft Correction at +17 ft + 3 ft POOH. At surface. Get off well. LD BHA. Stand back CSH in derrick. Hold PJSM after crew change. Review running liner procedure & THA for same. MU 26 jts 2-3/8" 4.6# STL liner (21 sltd, 5 solid) with drillable guide shoe and o-ring sub. MU Inteq MW D BHA with GS spear assembly. Stab coil. Get on well. Run in hole. Maintain WHP as per schedule. Log gr tie in from 7180'. Subtract 17' correction. Run in hole. 9k# dn, 28.5k# up wt at 8600'. Tag top of liner Printed: 1/t 6/2007 10:32:30 AM • • R t BP AMERICA Page 30 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 1/8/2007 23:00 - 23:45 0.75 ~ CASE ~ P ~ PROD1 section #1 (lower) at 8632'. PU to 8590'. RIH to 8605', This 23:45 - 00:00 0.25 CASE P PROD1 1/9/2007 00:00 - 01:45 1.75 CASE P PROD1 01:45 - 02:30 0.75 CASE P PROD1 02:30 - 03:00 0.50 FISH P PROD1 03:00 - 04:30 1.50 FISH P PROD1 04:30 - 05:00 0.50 FISH P PROD1 05:00 - 05:45 0.75 FISH P PROD1 05:45 - 07:30 1.75 FISH P PROD1 07:30 - 07:45 0.25 FISH P PROD1 07:45 - 09:00 1.25 FISH P PROD1 09:00 - 13:40 4.67 FISH P PROD1 13:40 - 19:00 I 5.331 WHSUR I P I I POST 19:00 - 21:00 2.00 W HSUR P POST 21:00 - 00:00 3.00 W HSUR P POST 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. Log gr tie again from 7180' to verify liner top setting depth. Add 2' correction. Pull out of hole. Maintain WHP as per schedule. Close sssv with 400 psi on well. POH to surface. Get off well. LD liner running BHA. MU whipstock retrieval BHA. MU orienter on MWD tools. Scribe Baker whipstock hook to BHA. Hook latch is oriented 90L with 90R TF. Stab coil. Test tools. Get on well. RIH. Open SSSV. Continue to run in hole. Log gr tie in. Subtract 16' correction. 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 W S. Open EDC. Pull out of hole. Maintain WHP as per schedule. OOH, PJSM and monitor well with closed SSSV (400 psi trapped) Recovered WS, LD same Change out BHA to 2.5" nozzle BHA with CV and EDC RIH with 2.5" nozzle to 7000 ff T= -38 deg F PUH laying in SW to 2200 ff. 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 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 Blow down N2 and 15 bbl of MEOH to tiger tank ND 7-1/16" BOPE. 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 BP Alaska ~- {~, by Baker Hughes INTEQ Survey Report uvTEQ Company: BP Amoco Uate: 1/10/2007 Time: 16:41:44 Page: 1 Field: Kuparuk Co-ordinate(NE) Reference: Well: 01, True North Site: KRU 1C Pad Vertical (TVD) Reference: 1C-01 94.0 Well: 01 Section (VS) Reference: Well (O.OON,O.OOE,133.55Azi) Wellpath: 1 C-01 L1-02 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 1 C Pad UNITED STATES :North Slope Site Position: Northing: 5968605.00 ft Latitude: 70 19 29.107 N From: Map Easting: 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 Easting : 562372.07 ft Longitude: 149 29 39.293 W Position Uncertainty: 0.00 ft Wellpath: 1 C-01 L1-02 Drilled From: 1 C-01 L1 50-029-20526-62 Tie-on Depth: 8200.00 ft Current Datum: 1 C-01 Height 94.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/22/2006 Declination: 23.72 deg Field Strength: 57621 nT Mag Dip Angle: 80.86 deg Vertical Section: Depth From (1'VD) +N/-S +E/-W Direction ft ft ft deg 94.00 0.00 0.00 133.55 Survey Program for Definitive Wellpath Date: 12/22/2006 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 8177.13 MWD (7175.00-9010.00) (1) MWD MWD -Standard 8200.00 9760.00 MWD (8200.00-9760.00) MWD MWD -Standard Annotation MD T<~ ft ft 8177.13 6542.94 TIP 8200.00 6540.72 KOP 9760.00 6460.23 TD Survey: MWD Start Date: 12/22/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ,~ ~ b p BP Alaska Baker Hughes INTEQ Survey Report ~a~ B~ 1NTEQ Company: BP Amoco Date: 1/10/2007 Time: 16:41:44 Page: Z Field: Kuparuk Co-ordinate(NE) Reference: Well: 01, True North Site: KR U 1 C Pad Vertical (TVD) Reference: 1 C-01 94.0 Well: 01 Section (VS) Reference: Well (O.OON,O. OOE,133.55Azi) Wellpath: 1C-01 L1-02 Surve y Calculation Method: Minimum Curvature Db: Oracle SUrve_V r MD Incl Azim TVU Sys TvD N/S E/W htapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 8177.13 95.09 220.41 6542.94 6448.94 -287.62 2352.90 5968254.54 564727.06 1903.49 0.00 MINA 8200.00 96.04 222.59 6540.72 6446.72 -304.66 2337.82 5968237.37 564712.12 1904.31 10.36 MWD 8230.14 98.93 214.30 6536.79 6442.79 -328.04 2319.26 5968213.84 564693.75 1906.96 28.90 MWD 8261.23 89.95 206.02 6534.38 6440.38 -354.80 2303.72 5968186.96 564678.44 1914.14 39.22 MWD 8290.60 87.96 202.09 6534.91 6440.91 -381.60 2291.76 5968160.05 564666.70 1923.93 15.00 MWD 8320.90 90.35 206.95 6535.36 6441.36 -409.16 2279.19 5968132.40 564654.36 1933.81 17.87 MWD 8350.83 90.20 213.06 6535.22 6441.22 -435.06 2264.23 5968106.37 564639.62 1940.81 20.42 MWD 8379.45 89.37 218.42 6535.32 6441.32 -458.29 2247.52 5968083.01 .564623.10 1944.70 18.95 MWD 8407.27 90.17 223.41 6535.44 6441.44 -479.30 2229.30 5968061.85 564605.07 1945.98 18.17 MWD 8438.44 89.65 229.01 6535.49 6441.49 -500.86 2206.81 5968040.10 564582.76 1944.53 18.04 MWD 8486.44 89.74 231.96 6535.74 6441.74 -531.40 2169.79 5968009.26 564545.99 1938.74 6.15 MWD 8519.96 88.88 233.24 6536.14 6442.14 -551.76 2143.16 5967988.68 564519.54 1933.47 4.60 MWD 8550.60 90.60 235.60 6536.28 6442.28 -569.58 2118.24 5967970.65 564494.77 1927.69 9.53 MWD 8580.11 94.78 239.80 6534.90 6440.90 -585.33 2093.34 5967954.70 564470.00 1920.49 20.07 MWD 8611.46 92.69 244.57 6532.86 6438.86 -599.92 2065.68 5967939.89 564442.47 1910.49 16.58 MWD 8641.37 89.71 250.20 6532.23 6438.23 -611.41 2038.09 5967928.16 564414.97 1898.41 21.29 MWD 8672.67 88.05 254.98 6532.84 6438.84 -620.77 2008.24 5967918.56 564385.21 9883.23 16.16 MWD 8702.47 88.63 260.16 6533.70 6439.70 -627.18 1979.16 5967911.91 564356.18 1866.57 17.48 MWD 8732.09 88.48 264.86 6534.45 6440.45 -631.04 1949.81 5967907.81 564326.87 1847.95 15.87 MWD 8762.27 88.36 260.36 6535.28 6441.28 -634.92 1919.90 5967903.68 564297.00. . 1828.95 14.91 MWD 8792.16 89.34 256.27 6535.88 6441.88 -640.97 1890.64 5967897.38 564267.79 1811.91 14.07 MWD 8822.42 90.29 251.80 6535.98 6441.98 -649.29 1861.56 5967888.82 564238.78 1796.57 15.10 MWD 8854.04 90.81 247.52 6535.68 6441.68 -660.28 1831.92 5967877.59 564209.23 1782.65 13.63 MWD 8885.36 90.32 243.12 6535.37 6441.37 -673.35 1803.46 5967864.28 564180.90 1771.04 14.13 MWD 8916.70 89.19 238.10 6535.50 6441.50 -688.73 1776.17 5967848.68 564153.73 1761.85 16.42 MWD 8946.77 88.88 233.52 6536.01 6442.01 -705.62 1751.30 5967831.59 564129.01 1755.47 15.26 MWD 8992.74 89.55 226.80 6536.64 6442.64 -735.05 1716.03 5967801.87 564093.99 1750.18 14.69 MWD 9027.50 89.28 221.81 6537.00 6443.00 -759.92 1691.76 5967776.80 564069.93 1749.72 14.38 MWD 9058.53 88.70 217.37 6537.54 6443.54 -783.82 1671.99 5967752.74 564050.36 1751.86 14.43. MWD 9091.52 88.66 213.18 6538.30 6444.30 -810.74 1652.95 5967725.66 564031.54 1756.61 12.70 MWD 9121.87 88.60 209.22. 6539.03 6445.03 -836.69 163724 5967699.59 564016.05 1763.10 13.05 MWD 9157.23 92.32 205.28 6538.75 6444.75 -868.11 1621.05 5967668.04 564000.13 1773.02 15.32 MWD 9192.34 94.69 207.79 6536.60 6442.60 -899.46 1605.40 5967636.56 563984.74 1783.27 9.82 MWD 9226.62 95.27 212.22 6533.62 6439.62 -929.02 1588.33 5967606.86 563967.91 1791.27 12.98 MWD 9256.36 94.64 217.43 6531.05 6437.05 -953.34 1571.41 5967582.41 563951.20 1795.76 17.58 MWD 9286.76 92.14 223.08 6529.25 6435.25 -976.49 1551.81 5967559.10 563931.79 1797.50 2029 MWD 9316.19 94.53 221.98 6527.54 6433.54 -998.13 1531.95 5967537.29 563912.12 1798.02 8.94 MWD 9345.81 96.57 218.19 6524.67 6430.67 -1020.68 1512.97 5967514.58 563893.33 1799.80 14.48 MWD 9376.43 100.92 217.17 6520.02 6426.02 -1044.63 1494.48 5967490.49 563875.03 1802.89 14.58 MWD 9409.47 103.52 211.89 6513.02 6419.02 -1071.21 1476.17 5967463.75 563856.96 1807.95 17.49 MWD 9447.26 101.76 206.08 6504.75 6410.75 -1103.46 1458.32 5967431.37 563839.37 1817.22 15.71 MWD 9477.57 99.21 202.10 6499.23 6405.23 -1130.66 1446.16 5967404.07 563827.44 1827.15 15.41 MIND 9508.72 97.60 195.59 6494.67 6400.67 -1159.81 1436.22 5967374.84 563817.74 1840.03 21.31 MWD 9538.34 96.02 189.42 6491.16 6397.16 -1188.50 1429.86 5967346.09 563891.62 1855.19 21.36 MWD 9570.00 94.76 181.69 6488.18 6394.18 -1219.85 1426.81 5967314.72 563808.83 1874.58 .24.63 MWD 9600.67 93.95 174.79 6485.85 6391.85 -1250.40 1427.75 5967284.19 563810.03 1896.31 22.59 MWD 9642.83 96.61 165.74 6481.96 6387.96 -1291.73 1434.83 5967242.92 563817.45 1929.92 22.28 MWD 9671.90 98.71 162.75 6478.08 6384.08 -1319.45 1442.65 5967215.27 563825.50 1954.68 .12.49 MWD 9701.17 102.29 158.77 6472.75 6378.75 -1346.62 1452.13 5967188.19 563835.20 1980.27 18.12 MWD 9760.00 102.29 158.77 6460.23 6366.23 -1400.20 1472.94 5967134.78 563856.46 2032.27 0.00 MWD i h 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" L1-01 southeast lateral TD @ 9355' (50-029-20526-61) 2-3/8" slotted liner L1-03 southeast lateral TD 10 000' ~\ i ~ `. 4-'h x 7' Baker Thru-tubing , `~~. flow-by whipstock at7175' ~ ~ ----~~ i ~;<~'~ i - '~ (50-029-20526-63) ~ C sand Aluminum billet Perforations @ 8355' and 7" shoe • 4-'/z' 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-'/z" 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' '' Window in T' 261# J55 casing @ 7177' and Aluminum 2-3/8" liner fillet @ 8202' top @ 8008' 3-3/16 shoe @ 8054' (cemented) L1 southwest C4 later TD @ 9010' 50-029-20526-60 ~~ 2-3/8" slotted liner 2-3/8" liner ~ top @ 7763' ~~ °° -~--------- °_ Drillable L1-02 southwest C3/C4 lateral aluminum insert TD @ 9760' @ 8846' (50-029-20526-62) KRU 1C-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 (6529' TVD) 1C-O1L1-02: Accessible from surface Top Window at 7181' MD (6468' TVDj • 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 (6565' TVD) 2-3/8" liner run to 9010' MD (6491' TVD) on 12-19-2006 outside of window at 7751' MD (6566' TVD). Top Window at 7751' MD (6566' TVD) KRU 1 C-O1 • 0702 12_KRU_ 1 G01 _Lateral_System.ppt SFD 2-I2-2007 KRU 1 C-O1 System of Lateral Wellbores Order of Operations KRU 1 C-Ol 6. I C-01 L 1-01: Top Window at 7751' MD (6566' TVD) , milled. on 12-28-(?6; new formation drilled on 12-28-06 7. 1 C-01 L 1-01: Not directly accessible from surface TD of93~5' 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. 1 C-01 L 1-03: OH sidetrack began drilling at 8353' MD (629' TVD) on 1-1-2007 9. 1 C-O1 L 1-03: Not directly accessible from surface 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 directlyaccessible from surface TD of 9010' MD (6491' TVD) reached on 12-18-2006 2-3/8" liner run to 9010' MD (6491' TVD) on 12-19-2006 • 4. 1C-O1 L1-02: OH sidetrack began drilling at 8200' MD (6541' TVD) on 12-21-2006 5. 1 C-O1 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 0702 12_KRU_ 1 C-0l _Laterdl_System.ppt SFD 2-12-2007 SARAH PALIN, GOVERNOR ~s~-7~ ®ia/ oi~I~~+~~ 333 W. 7th AVENUE, SUITE 100 ®~S~i~Q~ilO~` ~O~IIS-7IO~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Aras Worthington Ct Drilling Engineer ConocoPhillips (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Kuparuk River Field, Kuparuk River Pool, 1 C-O l L 1-02 ConocoPhillips (Alaska), Inc. Permit No: 207-002 Surface Location: 1718' FNL, 1364' FWL, Sec. 12, T11N, RlOE, UM Bottomhole Location: 3118' FNL, 2444' FEL, Sec. 12, T11N, R10E, 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 1 C-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). incerel Daniel T. Seamount, Jr. Commissioner S f~ DATED this- day of January, 2007 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 ~~~ JAN 0 4 2007 ~iasica Oie & Gas Cans. Commission 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 proposraga ^Coalbed Methane ^ Gas Hydrates ^ 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 1 C-01 L1-02 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9760 ~ TVD 6366ss 12. Field /Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: 12 1718' FNL 1364' FWL SEC 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 Sp e: In ogre Total Depth: 3118' FNL, 2444' FEL, SEC. 12, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance t est 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: 8200 ~ feet Maximum Hole An le: 104 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3252 Surface: 2606 , 18. Casin Pro ram: S cificatio ns T ttin D th - Bott m uanti of Cement c.f. or sacks 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 1747' 8013' • 6455' 9760' ~ 6366' Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9760 Total Depth TVD (ft): 6366 Plugs (measured): None Effective Depth MD (ft): 9760 Effective Depth TVD (ft): 6366 Junk (measured): None -asing Length: ze ement Volume MD Conductor /Structural Surface 80' 16" 200 sx Permafrost 80' 80' Intermediate 2704' 10-3/4" 1350 sx Fondu 25 sx A II 2798' 2683' Pr ducti n 7664' 7" 460 sx Cla 77 7023' Liner 1036' 3-3/16" 15 sx Class 'G' 7064' - 8100' 6260' -6449' Liner L1 810' 2-3/8" Unc ment d Slotted Liner 8200' - 9010' 6443' - 6428' 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 ^ Diverte 'vetch ^ 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 co ct. Contact Aras Worthington, 564-4102 Printed Name Aras rthington Title CT Drilling Engineer ,,)l Prepared By Name/Number. Si nature 9~~d~ Phone 564-4102 Date / ~ Terrie Hubble, 564-4628 ` Commission Use Onl Permit To Drill Number: ZD?"~Z API Number: 50-029-20526-62-00 Permit Approval ii See cover letter for Date: l ~ ~ her re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me~tha/ne, gas hydrates, or gas contained shales: ,_,/ Samples Req'd: ^ Yes L~INo Mud Log Req'd: ,^,/Yes LJ No ~ t S'~ $t~ ~~ '~'0 3 s~ ~ ~ ~ Yu~ ttiCyKu ~-~. • HZS Measures: Q~Yes ^ No Directional Survey Req'd: L~J Yes ^ No O er: C Z-5.o33(i ~ a ~i,v 5~~--~ ~ ~ , u,u.(~ r ~ atc>.~t.E.e ~ ~ ll ~ °-f~'- ~~ ~t,Lvt.-~ ct'1°P W U e d . / S APPROVED BY THE COMMISSION Date ,COMMISSIONER For~r'r0-401 Revised~2/2005 Submit In Duplicate ~ je~~o J~ • r~ 1 C-01 L1-02 & 1 C-01 L1-03 Sidetrack Laterals Coiled Tubing Drilling Summary of Ouerations: A coiled tubing drilling unit will drill two laterals from producer KRU 1C-O1 using the managed pressure - drilling technique. These horizontal laterals will target Kuparuk C4 and C3 sand reserves for increased pattern throughput. The 1 C-O1 L 1 will be a 2525' lateral drilled to the southwest, and the 1 C-O1 L101 will be a 2350' lateral kicked off from the 1C-O1L1 and drilled to the southeast. A pre-CTD workover has been performed to equip the well with 4'/z" 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-01 L1 southwest lateral and completed with slotted liner. Lateral 1 C-01 L 1 has been also been drilled and completed. During the drilling of 1 C-O1 L1-01 southeast lateral, hole conditions prompted sidetracking the wellbore, requiring another yet-to-be permitted lateral named 1 C-01 L 1-03. 1C-O1 CTD Drill and Complete Program: Planned for 9Ftelie~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'/Z" 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. 2. Mi113.74" window and 10' of open hole at 7175' MD. 3. Drill the 1 C-O1 L1 trunk lateral to the southwest with a 3.70" x 4'/8" bi-center bit from the window to (8100' 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'/z" 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 L1-021ateral. ,> » ,,;r;,.,,r+ i,.~.,o~ . o 0 0 .,+o..oa ;~ a,aii;.,,..i,o r ~ i„+o..,,i Was not required. 11. Dri11 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 2-3l8" slotted liner with aluminum billet top @ 8355' md. Kick off billet. Page 1 of 5 October 2, 2006, FINAL c: ,] 1 C-01 L1-02 & 1 C-01 L1-03 Sidetrack Laterals Coiled Tubing Drilling 15. Sidetracked off of aluminum billet in L1-01 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. Drill 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 ppg) • Steps 3, & 9-18 (CTD): chloride-based Flo-Pro mud (8. 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-O1L1 trunk: 3-3/16", 6.2#, L-80, TC-II solid liner from 7064' MD to 8100' MD • 1C-O1L1: 23/s", 4.6#, L-80, STL slotted liner from 8200' MD to 9010' MD w/ Al billet top • 1C-01L1-02: 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 w1 Al billet top / • 1 C-01 L 103: 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 23/8" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to .500:-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 1 C-01 L 1 and 1 C-01 L 101. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to the proposed 1C-OIL101 lateral is 1C-21L1 which is offset by approximately 1450'. The nearest well to the 1 C-O1 L1 lateral is 1 C-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 IC-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-Ol was taken in September 2006 after the well had been sh for 5 days. The measured reservoir pressure was 3085 psi at 6456' TVD which corresponds to 2 g EMW. Expect to encounter similar or increasing formation pressure as the laterals are drilled a~aypfrom the mother well. Maximum expected pressure is 3252 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 1C-O1 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 • • 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. r • When circulation is stopped, it is anticipated that an additiona1204 psi of surface pressure shall have to be applied to balance reservoir pressure. Page 5 of 5 October 2, 2006, FINAL KRU 1 C-01 L1, L1-01, L1-02, L1-03 Producer C-sand CTD Completion 10-3/4" shoe • 4-''/2' 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 • 3-3/16" liner top @ 7060', stabbed into sealbore L1-01 north lateral j 4-''/z x 7' Baker Thru-tu TD @ 9355' flow-by whipstock (50-029-20526-61) ~~ 2-3/8" slotted liner ~ L1-03 North lateral proposed TD @ 10,100' and C sand (50-029-20526-63) Aluminum billet Perforations @ 8355' and ~. '~~~/ • 4-'/z" 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' '' Windauv in 7'26# J55 casing @717T and Baker retrievable flow-by monobore whipstock @ 7750' / Aluminum billet @ 8200' and ~ 2-3/8" liner top @ 8013' 2-3/8" liner \ top @ 7751' 3-3/16 shoe @ 8046' L1 southwest C4 lateral TD @ 9010' -----------1 2-3/8" slotted liner L1-02 southwest C3/C4 lateral TD @ 9760' (50-029-20526-62) 7" shoe Operator: Conoco Phillips Alaska, Inc. (:rid Correction: Job No: 1303032 Field: Kuparuk Magnetic lleclination: AF'E No: K12U 231734 - Wcll: IC-OlLl-02 Uip: AYI No: 50-029-22941-xx Rig: Nordic2 Dogleg per. ft DIWD Gnnpanp: Is.u.c ~ Ilu~~u~. i'~ ; i e) Surface 1,ocalion Original VS I'lanc: ° Parent \\cll: 1C-Ol X: 562372.07 ft view VS Plane: RIC1311eight: 94.00 ft ]": 5968522.56 ft Start Date: 1'D Uate: #N/A Meas. Incl. 7RUE tiubsca Gourds.-I7ue•\orth Goordti ~~I'nr~:rid Do;;le~ View I~~~~1 build Turn Course Drilled Depth (ft) Angle (deg) Azi. (deg) I A I) fttl \(+I~S(-) Iltl 1:(~)/A\Y-I Ilil ~~ ~ ` ~ F i ~ 1 ~~ i-t ~ ~ ~ ~ 1e~crit~ I lien Itl A'S 131111°1 (fti I :~ . I I~ni lu I` lien tU Length (ft) Distance Ift) Comments 8200.00 96.04 222.59 ~~-4-10 -' -30467 2337.x~ - I ' ,~ ~ ~ 10.36 -513.2 ~ 4.15 9.53 22.87 1100.00 Into laced KOP tYom IC-01L1-02 ~ 8230.14 98.93 214.311 :~~4"~~ -325.04 2319?h ~ ~ ?x.vU -117.~~ % ~ e.SU -?780 30.14 1130.14 lnte olated AZ 8'_61.'_3 89.9; 2116.03 ~~74n ;~. _354.50 23113.7' ~ ~ 3~1" -45452 -'_8.55 -26.63 31.09 1161.23 5290.60 87.96 202.119 n3ar_~~~1 -381.61 '391 J6 ~ 1560 -42133 I!, -6.78 -13.3?; 29.37 1190.60 8320.90 90.35 2Ur,,.95 ~~-171 ?~ -409J6 2279.19 ~~! 17.87 -395.04 ~~~ 7.89 16.04 30.30 1220.90 8350.53 90.20 213.116 -435.07 _'26-1.23 20.42 -365.15 ~~ I -0.50 20.41 29.93 1210.$3 8379.45 89.37 318.42 ~ -45529 2347 52 15.95 -338.0-{ -2.90 15.73 28.62 IZ79.45 840727 90.17 23.41 -479.31 2229.3n nu>.?I 15.17 -312.07 I 2.58 1794 27.52 1307?7 8435.44 89.65 229.n1 -5011.57 '206.81 ~~~~~~ 18.04 -2a4.1I '~~ -1.67 17.97 31.17 1338.44 8486.44 89.74 23L~~~~ ~ -531.41 216'179 ~ ~-~ 6.15 -343.75 ~~~~ OJ9 6.15 45.00 1386.44 8519.96 88.85 233.'3 -551.76 ?143.16 4.60 -?14.52 I'! -2.57 3.52 33.52 1419.96 8550.60 90.60 235.0~~ -X69.59 341S24 9.53 -189.24 ~~7 5.61 7.70 311.64 1450.60 8580.11 94.78 239.eu ~ ~ -585.33 2093.34 ~ _! 20.07 -165.9; 14.16 1323 29.51 1450.11 8611.46 92.69 244.>- -59992 211(15.65 „~. -~~ 1655 -142.i1~ ~ ~~ -6.67 15.22 31.35 1;11.46 364L37 89.71 250'i~ -611.42 2038.09 it~~_'I X129 -122.5' -9.96 18.82 29.91 1;.}1.37 8672.67 38.05 ~5-l.rr~~ -620.78 'UU?i24 16.16 -1(13.53 -530 IS?7 31.30 157267 8702.47 83.63 360Ji~ -627.19 1979.16 ~ 17.-18 87.15 L95 17.35 29.80 1602.47 8732.09 83.48 26-{.~~~ -631.05 1~1 i~>.81 15.87 -' ~.z8 -0.51 15.87 29.62 1632.09 8762.27 38.36 260?, ~ ~ -63493 I~+1990 14.91 nu.ul -OAO -14.91 30.15 166227 8792.16 59.34 256_', !~-14; - -640.98 1890.(14 14.07 -13.3'_ 3.28 -13.68 29.59 1692.16 8323.42 9029 3iL5u ~ -6-3930 1361.511 IS.IU -'6.55 3.14 -14.77 30?6 1722.42 8854.04 90.31 247.5' -66025 1831.92 ~~ 13.63 -b.09 L64 -L3.54 31.62 1714.04 3385.36 90.32 243.12 ~~-+-I '. -67336 1503.47 14.13 15.93 ~~ -1.56 -14.05 31.32 1785.36 8916.70 89.19 235. I u ~-i-t : _~ -655.73 177b.17 - ~ 16.42 39.71 ~ -3.61 - I b.U2 3134 1 S 16.70 8946.77 38.88 233.>' -705.6' I7513u ~ 152h b4.119 ~ -1.03 -15.23 30.117 1846.77 8992.74 89.55 226.~i~ ~-l~_' ~.,; -73>.(~~ I":16.(13 14.69 IU3.51 1.4(1 -14.62 41.97 1392.74 902750 8928 221.61 ~~'~-t;~~~ -759.92 i691.r 14.35 135.48 -u.73 -14.36 34.76 1927.50 90;8.53 88.70 217.3` ~ -753.52 16?L'~" 14.43 Ib470 -1.57 -14.31 31.03 1958.53 9091.52 88.66 313. I ~ ~ -'~~ 10.74 I b5- '~- ~ 12.70 196.51 ~ -0.12 -12.70 32.99 1991.53 9121.37 38.60 209" -536.69 Ib37?4 -i~~ ~ 13.115 22b?6 ~ -020 -13.05 30.35 2021.87 9157.23 92.32 2(15 'y ~ ~ - -868.11 162L05 ~ ~,inL~ 4 15.33 261.33 -4 , 10.52 -11.14 35.36 2057.23 9192.34 94.69 ~0',_7~~ ~ -899.46 1605.4(1 ~~ 9.52 '96.14 1- 6.75 7.15 35.11 21192.34 9226.62 9527 ? I ~ " -929.03 1555. ~ ; ~ ~ 13.95 329. ; i, y. ' 1.69 12.92 3425 2126.62 9256.36 94.64 217.-}3 ~~ -953.3-0 l 171.41 : i 17.58 358.3` - -2.12 17.52 29.74 2156.36 9236.76 92.14 233.us 076.49 155 Ls l 3029 35h.A3 I I 1 -522 18.59 30.-10 3156.76 9316.19 9453 221.9 098.14 I>3L~>~ 894 413.99 3.12 -3.74 29.43 3216.19 9345.81 96.57 213.1~~ i~4i~~~.4- -1020.69 151'_9, 14.48 -141.67 i~l 6.89 -12.30 29.62 2241.81 9376.43 100.92 217. I ~ 1> 1'0_~ ~ ' -1044.b3 1494"78 ~ 14.55 470.49 ~ I ~ 14.21 -3.33 30.62 ?276.43 9409.47 103.52 21L89 _ 6-}1~--'~ -107122 147h.1- 17.-49 ~ii1.74 bt 7.87 -15.93 33.04 2309.47 944726 IOL76 206.08 1103.46 1455..'.' 15.71 X35.14 li)' -4.6b -15.37 37.79 234726 9477.57 9921 202.10 -I 130.66 1446.11, ~ 15.41 567.J6 I_'~ -8.41 -13.13 30.31 237757 9508.72 97.60 1955' -1159.51 1x36." 21.31 595.65 In~1 -5.17 -20.90 31.15 2305.72 9538.34 96.02 189.4 -1 15551 1429 a'~~ 21.36 627.79 111-1 -5.33 -20.33 29.62 2433.34 9570.00 94.76 181.1,9 -1219.86 1426.81 24.63 115829 ~„~ -3.98 -24.42 31.66 2470.00 9600.67 93.95 174.-" -1250.40 142'.-`~ 32.>9 u8b.63 -2.64 -22.50 30.67 25UQ67 9642.83 96.61 165._4 -1291.73 1434.8. 22.28 723.09 6.31 -21.47 42.16 2542.33 9671.90 98.71 163.,E -1310.46 1442.1:> ~ 12.49 7]6.47 ~~>4 7.22 -10.29 29.07 3571.90 9701.17 102.29 155.'' ~ ~ -13-16.62 1452.13 18.12 768.7> !' 12.23 -13.60 2927 2601.17 Current Survey Page 1 of 2 (1C-01 L1-02 Geotrak.xls) 1/4/2007 9:01 AM Meas. Incl. I'RL'E Sub,ca Cuords. - "true \orth ('ourd,. - .151' or Grid Uo;;lc~ \'icw I'uul Build Turn Course llrilled Depth (fl) Angle Azi. (deb) (dcel I A I) \(+)/5(-) ~ lu EI+)/~~'(-I Uil A(~ i ~i-1 Fi ~ r~~ i-1 tic,~critc i lun u~ ~~5 131111°) itt~ 1'ncc ~,dcc; r lnu lil I"~ Inn lid Length (ft) Distance (tip Comments 9760.00 102.29 ISR.77 Iluu~n I~7'.~~~ 0.01 till9'~ ~ uUO U.UU 58.83 2660.00 Pro'ectiontol'D. • Current Survey Page 2 of 2 (1C-01L1-02 Geotrak.xls) 1/4/2007 9:01 AM • Subject: Re: 1C-O1Ll-Ol added lateral From: Thomas Maunder <tom_maunder@admin.state.ak.us> 1)atc: Tuc_ 0^ T~~n ?00 % 09:~~: ;(-0900 "t~o: "V~nh3us_ Da» E" ~=Dan.F..~`cnhalls%~conoc~iphillrps.c~ni= 20'7 - OD Z ('(': "1 lcr,.l (_i;v;'" ~J ~~ar}.l~ll~~i"ucoiioeophilli}~.~.coui=. Steve Ua~~~~ ~~tc~e__d~n'ic,u-a~lmin.~t,~te.ak iii.-~ 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, i~-oic~-o2., 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. 1 have not submitted this paperwork in the past but after talking with others I will forward you the following information: A new 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-01L1-03. 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 ~ ~ 84A1 G`2 8460 ddDO Measured Depth -----Original Message----- From: Thomas Maunder [mailto:tom maunders admin,state.ak.us] Sent: Monday, December 18, 2006 10:46 AM To: Eller, J Gary Subject: Re: Additional Sidetrack Off of 1C-O1L1 Lateral Gary, Do you have a drawing of what occurred? Thanks, Tom Subject: Re Additional Sldctrack i>ffof iC`-O1Ll Lateral From: Thomas 2tilaLmdcl ~-tom rraunderrw'adminstatc.ak.u~= Date: Mon, 13 Uec ?GO6 I t 2-t 30 -0900 To: °Eller, J Crary" ~t.Garv.Etlercueonocophillips.com> CC: SCece Davie; ~steve daviesia~adminstate_ak.us> Gary, Steve Davies and I have reviewed the drawing. It is our opinion that the segment you would call L2 should more properly be called L1-02. The reasoning here is that this segment will originate from a lateral not from a parent wellbore. What you refer to as the modified L1 would still be properly called L1 since the intended BHL has not changed. You will need to send in a 401 for LI-02. In the interim, continuing operations is acceptable. Call or message with any questions. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 12/18/2006 11:08 AM: Tom - As you can see, we got knocked off course at 18400' MD in the L1 lateral. We spent the next 100' or so trying to cut up through a hard siderite stringer. By the time that we punched up through the siderite, we were unable to crest in the top of the C4 and then drop down prior to crossing Fault #3. So we opted to incline across the entire C4 sand (L2, shown below). We'll run liner across the L2 lateral, then sidetrack at 8410' MD. We'll drill the modified L1 laterally from 8410' until we cross Fault #3, at which time we'll resume the original directional plan to finish the L1 lateral. -Gary KRU ZG-0117 Measured Depff~ Profile WaY -a-Surrey Lt -Plan L1 gym! fh4~ ra,.>3~3 `} , . r ~ ~suu rrt IPlaou #r ~! 2fM h~ 272 ~ r ~Y~3pfldletd _ % -r . _ .-._.~~.-,-•-, .r ~ ~ ~ '- - ~~..--.~ _ _ - - 8360 _ .~ .. . Merry Christmas to you as well!! ~~ ~~ P~" c~,ca 1 of 2 2/22/2007 2:51 PM 8~0 tmm ~ ~ mm ~ ~ vao s~ 2m s+oa s® ® ®o arm ® ®o em ® ® e+m mm r~ rem nm 2sm ism rim r~ lam r+m rmo • t~EFtlVl°f° T© C}RILI. 20 AAC 25.005 • (e~ Each we!! branch requires a separate Perrrtit to Drill. if a previously drilled well is proposed to be redriBled belaw the structure! or conductor casting to a new bottom-hole location, the application for a Perrrait to Drill must be accompanied by all items required under (c} of this section. if concurrent multiple ~oe9l branches are proposed from a single conductor, surface, or production casting, (2~ for each other well branch, the application for a Permit to Dri11 need only include inforn-sation under (c) of this section that is unique to that weld branch and need not ~e accom~anii~ ~y she $9flfl fee. J • • 'I'RANSIVIITI'AL LE"T'I'ER CFIIECKLIST' WELL idAlvlE /C~2GC /G -D l L. !-- o Z PTD# ?~ ~- oo~--~ Development Service Exploratory Stratigraphic "Test Yon-Conventional Wel! Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CI{ECK ~ ADD-ONS V4'HAT ~ (OPTIONS) i APPLIES TEXT FOR APPROVAL LETTER MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ j ~ wel l~ /2~ ~~ " ~ V ~ (If last two digits in permit No. API No. 50-OZq - ZOSZ(~ - did. i API number are I ;between 60-69) ;Production should continue to be reported as a function of the original API number stated above. j PLOT HOLE . In accordance with 20 A.4C 25.00~(f), all records, data and logs j acquired for the pilot hole must be clearly differentiated in both ~ I i ~ well name ( PH) and API number j i ; (50- - -_~ from records, data and logs I ~ ~ acquired for well j SPACING 'EXCEPTION i i' ~ ~ I The permit is approved subject to full compliance with 20 AAC ~ 25.0». Approval to perforate and produce /inject is contingent i upon issuance of a conservation order approving a spacing j ~ exception. assumes the liability of any protest to the spacing exception that may occur. i DRY DITCH j All dry ditch sample sets submitted to the Commission must be in ,' SAMPLE I no greater than 30' sample intervals from below the permafrost or I I from where samples are first caught and !0' sample intervals ', I through target zones. ~' ~ ~ Please note the following special condition of this permit: ~ Non-Conventional i production or production testing of coal bed methane is not allowed I Fell ~ for (name of well) until after jCompany Name) has designed and I j implemented a water well testing program to provide baseline data ~ j on water quality and quantity. (Company Name) must contact the !Commission to obtain advance approval of such water well testing Rev: 1'2~i06 C:`.j ody~transmittal_checkl ist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 _ - _ - - - - - -- - _ - PTD#:207002D Company CONOCOPHILLI_PSRLASKA INC -__ __ _ -Initial Class/Type - __.__Well Name: KUPARUK RIV UNIT 1G-01L1-02 _ __ _ _ __ Program DEV _ Well bore seg ~'/I DEV I PEND____GeoArea 890 _ Unit 11-160 _ ___ OnlOff Shore On Annular Disposal [' Administration 1 Permit_fee attached NA Multilateral wellbore segment; fee waived per 20 AAC 25.005(e)._ j 2 Leasenumber appropriate_ Yes Entire well in ADL 025649. X1 3 Unique well name and numb_e[ Yes 4 Well located in a definedpool Yes _ KUPARUK RIVER, KUPARUK RVOIL - 490100, governed by Conservation Order No. 432C. - ' 5 Well located proper distance from drilling unit_boundary_ Yes ConseNation Order No. 432C contains no spacing restrictions with. respect to drilling unit boundaries. 6 Well ocated proper distance from_ other wells Yes ConseNation Order No. 4320 has no interwell spacing. restrictions.- 7 Sufficient acreage available in-drilling unit Yes Conservation Order No. 432C has no nferwell_spacing_restrictions. Wellbore will be more than 5Q0' from 8 If deviated, is_wellbore plat_included No_ an external property line_where ownership or landownership changes.. Using directional survey information 1 9 Operator only affected party_ Yes provided,_plotted on AOGCC base map. Conforms to spacing and-set-back requirements. 1 10 _Operator has_appropriate_bond in force No_ 11 Pe[mit_can be issued without conservation order . _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ 12 Permit_can be issued without administrative_approyal _ _ _ _ _ Yes _ _ _ _ Appr Date 13 Can permit be approved before 15-daywait _ Yes _ SFD 11512007 14 Well located within area and strata authorized by_ Injection Order # (put_1O# in comments)_(For NA X 15 All wells-within 114-mile area of review identified (For service well only) - NA_ 16 Pre-produced injector: duration of pre Production I_ess_ than_ 3 months-(For service well_ only) NA 17 Nonconuen, gas conforms to AS31 04,030(~.1.A),(j.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ 18 Conductor stung provided - _ _ _ _ - - - - - NA - -- --- - _- ' Engineering 19 Surface casing_protectsall known_ U$DWs _ NA 1 20 CMT vol adeguate_to circulate on conductor_& surf_csg NA- - 1 21 CMT vol adequateto tie-in long string to surf csg_ _ _ _ . _ _ _ - NA I~ 22 CMT will coverall known productive horizons No Slotted 1: 23 Casing designs adequate f_or C, T, B &_ permafrost_ Yes 24 Adequate tan_kage_or reserve pit. Yes - CTQt). 25 If a re-drill, has_a_ 10-4.03 for abandonment been approved NA_ Lateral, 26 Adequate wellbore separation proposed Yes 127 If diverter required, does it meet regu_lations_ NA_ Sidetrack. 28 Drilling. fluid_program schematic & equip list adequate- Yes - Max. MW 8.6_ ppg, UBD ops approved. -------- Appr Date 29 BOPEs, do they meet regulation Yes WGA 12/5/2006 !30 BOPE press rating appropriate; test to_(put psig m comments)_ Yes Test to 3500_psi. _MSP 2606 psi.- - - 31 Choke_manifgld complies_wIAPI-RP-53 (May 84)_ Yes - - - - 32 Work will occur without operation shutdown_ Yes '33 Is presenee_ of H2S gas probable - - .. - - - - . Yes H2S on pad.- ~34 Mechanical condition of wells within AOR Verified (Forservice well only) _ _ _ _ _ _ - _ _ _ NA_ _ _ 35 Permit_can be issued wlo_ hydrogen sulfide measures _ _ No_ _ _ Well 1C-01_ measured 100 ppm H2S on 611.8/2006 _ Geology x '36 Data-presented on_ potential overpressure zones Yes - Expected reservoir pressure is 9.2_ppg EMW; drilled with 8.6 ppg. mud_ and managed pressure drilling techniques 37 Seismic analysis_ of shallow gas zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ - - - _ _ NA_ to achieve an ECD of 10,4 ppg, _ _ _ _ _ _ _ _ _ Appr Date 38 Seabed condition surue _(if off-shore _ y ) NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ SFD 11512007 39 Contact name/phone for weekly_progress reports [exploratory only] NA Geologic Daie: Engineering Date public Date This application was submitted to the Commission on January 4, 2007, after wellbore segment 1 C-OtL1-02 had been drilled to Commissioner: C~ne : Commissioner 9760' MD and liner set (see page 1, Update" and CTD Rig Work paragraph, items 9-15). _--DTI-- ~ ~~ /f • • • Well I-iisiory File APPENDIX Inforrnation of detailed nature that is not particularly gem~rane io 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 io chronologically . organize this category of information. **** REEL HEADER **** LDWG 07/09/26 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: 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 18 18 S. DRAKE C. SEVCIK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL; WELL CASING RECORD 1C-01L1-02 50029205266200 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 16 MWD RUN 17 16 17 W. PUTNAM D. YOUNG C. SEVCIK M. FEKETI MWD RUN 19 19 W. PUTNAM M. FEKETI 12 11N 10E 94.00 00.00 00.00 ab~-~ ~ r~Y~~ 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 8054.0 PRODUCTION STRING 3.00 9760.0 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 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 9730 ft. to 9366 ft. MD (6372.0 ft. to 6366.00 ft. SSTVD) was not logged due to bit to sensor offset. (10) This wellbore 1C-01L1-02 was kicked off the wellbore 1C-01L1 at 8200 ft. MD (6446.73 ft. SSTVD). Tape Subfile: 1 88 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** 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; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH MWD 7190.0 all bit runs merged. STOP DEPTH 9760.0 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 8176.0 MWD 16 8176.0 8223.0 MWD 17 8223.0 9258.0 MWD 18 9258.0 9698.0 MWD 19 9698.0 9760.0 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-01L1-02 5.xtf LCC 150 CN ConocoPhillips Alaska, Inc. WN 1C-01L1-02 FN Kuparuk River Unit COUN North Slope Borough STAT Alaska *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 RAD RAD RACLX RAS RAS RACHX ROP ROP ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 GAPI 2 RPD MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RAD MWD 68 1 OHMM 5 RAS MWD 68 1 OHMM 6 ROP MWD 68 1 FPHR Total Data Records; 143 0.0 0.0 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 7190.000000 Tape File End Depth = 9760.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 190 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! 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 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) 9760.0 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 (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVI TY (OHMM) RACH - SHALLOW ATTENUATION RESIST IVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1C-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 ROPA ROPA ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 6 ROPA MWD 68 1 FPHR 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 27 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 Minimum record length Maximum record length **** FILE HEADER **** LDWG .003 1024 109 records... 8 bytes 4124 bytes *** 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: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MPR MULT. PROP. RESIST. GRAM GAMMA RAY DIR DIRECTIONAL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: 09-DEC-06 ADVANTAGE 3 CTK MEMORY 7575.0 7425.0 7533.0 0 97.8 98.2 TOOL NUMBER 10000103 1079131 10079128 3.00 9760.0 Flo-Pro 8.60 .0 .0 35000 .0 .000 .000 115.0 .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-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 ROPA ROPA ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 6 ROPA MWD 68 1 FPHR Total Data Records: 13 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 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 95 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: 10-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 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): 9760.0 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 (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-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 ROPA ROPA ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 6 ROPA MWD 68 1 FPHR Total Data Records: 67 0.0 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 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: 5 149 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 U Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DE PTH INCREMENT: .2500 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8128.0 8176.0 LO G 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): 8176.0 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): 9760.0 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-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 ROPA ROPA ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 6 ROPA MWD 68 1 FPHR 4 4 24 Total Data Records: 6 Tape File Start Depth = 8128.000000 Tape File End Depth = 8176.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 6 88 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: 16 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8176.0 8223.0 LOG HEADER DATA DATE LOGGED: 22-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8247.0 TOP LOG INTERVAL (FT): 8176.0 BOTTOM LOG INTERVAL (FT) 8223.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 96.0 MAXIMUM ANGLE: 98.9 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): 9760.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 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): .000 153.0 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 16 (MWD Run 16). 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-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 ROPA ROPA ROPS 0.0 * FORMAT RECORD (TYP E# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Sc ale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 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 6 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 6 ROPA MWD 68 1 FPHR Total Data Records: 6 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 8176.000000 Tape File End Depth = 8223.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 7 88 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 NO: 17 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8223.0 9258.0 LOG HEADER DATA DATE LOGGED: 23-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9292.0 TOP LOG INTERVAL (FT): 8223.0 BOTTOM LOG INTERVAL (FT): 9258.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 88.0 MAXIMUM ANGLE: 95.3 • • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL ZPC003 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 9760.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 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): .000 145.0 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 17 (MWD Run 17). 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-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 • ROPA ROPA ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 6 ROPA MWD 68 1 FPHR Total Data Records: 116 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 8223.000000 Tape File End Depth = 9258.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 8 198 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: 18 DE PTH INCREMENT: .2500 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9258.0 9698.0 LO G HEADER DATA DATE LOGGED: 25-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9730.0 TOP LOG INTERVAL (FT): 9258.0 BOTTOM LOG INTERVAL (FT): 9698.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 92.0 MAXIMUM ANGLE: 103.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL ZPC003 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT): 9760.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 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): .000 153.0 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 18 (MWD Run 18). 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-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 ROPA ROPA ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 6 ROPA MWD 68 1 FPHR 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 49 Tape File Start Depth = 9258.000000 Tape File End Depth = 9698.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 9 131 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: 19 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9698.0 9760.0 LOG HEADER DATA DATE LOGGED: 26-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 2.375 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9760.0 TOP LOG INTERVAL (FT): 9698.0 BOTTOM LOG INTERVAL (FT): 9760.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 102.0 MAXIMUM ANGLE: 102.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10188653 GRAM GAMMA RAY 10218973 DIR DIRECTIONAL ZPC003 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.00 DRILLER'S CASING DEPTH (FT) 9760.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (5): .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-01L1-02.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1C-01L1-02 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 ROPA ROPA ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 Curves: Name Tool Code Samples Units Size Length r 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 6 ROPA MWD 68 1 FPHR Total Data Records: 7 Tape File Start Depth = 9698.000000 Tape File End Depth = 9760.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 10 89 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes 4 4 4 4 4 4 4 4 4 4 4 4 24 •
