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Home My WebLink About205-204• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. O~ Q ,~ - ~ ~ ~- Well History File Identifier 9,~., ,,~,a~ iuimnniiiuiu ., Re,~a~~reaealuuiiuiiuuiu RESCAN DIGITAL DATA Q Color Items: ^ Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~j O $ /s/ Project Proofing ' / II I II II II V III I I III BY: ~ Maria Date: ~ ~1~ g /s/ ~. ,_ ,_ Scanning Preparation ~ x 30 = ~_ + ~ =TOTAL PAGES~~ (Count does not include cover sheet) BY: Maria Date: ~ I ~ ~ /s/ Production Scanning III II'III VIII II III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ' / Q ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II ~I II I (III (I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I (I P P 10/6/2005 Well History File Cover Page.doc ~~-'~/J DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2052040 Well Name/No. KUPARUK RIV UNIT 3H-146L1 Operator CONOCOPHILLIPS ALASKA INC MD 9200 TVD 6170 Completion Date 1/3/2006 Completion Status P&A Current Status P&A REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD GR Well Log Information: Log/ Electr Data Digital Dataset T~ Med/Frmt Number Name API No. 50-103-20092-60-00 UIC N Sampies No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ~ED D Asc Directional Survey // Directional Survey Rpt J 15090 LIS Verification Lo ! 15090 G R g amma ay Log ~ 15090 Gamma Ray 7962 9200 Open 3/28/2006 PB 1 7962 9200 Open 3/28/2006 PB 1 8025 9199 Open 5/4/2007 P61 LIS Veri, GR, ROP w/Graphics LIS, & PDF 5 Blu 1 8025 9200 Open 5/4/2007 MD PB1 GR 2-Jan-2006 w/Graphics 5 Blu 1 8025 9200 Open 5/4/2007 TVD PB1 GR 2-Jan-2006 w/Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y '~J Daily History Received? ~ N Chips Received? ~ftid- Formation Tops ~ N Analysis aG~hiQ~ Received? Comments: Compliance Reviewed By: Date: Transmittal Form ~" `. ~~ _~,tt~ BAKER HUGHES .. ~. ,~ v .. ,.. , INTEQ Anchorage GEOScience Center - To: AOGCC 333 West 7`h Ave, Suite 100 Anchorage, Alaska r~-~. i 99501 Attention: Helen Warman _v--.. Reference: 3H-14BL1PB1 µ~~~~t «~~~- '~ -`3 W-~~ ~ i ~' Contains the following: _ ~ , -~- ._~ ____ __ __ _.__ _._ _ _ - i °- 1 LDWG Compact Disc - ni (Includes Graphic Image files) •~~°° ~= "-~ "-::i ~ I 1 LDWG lister summary ~! i -~ ~~ t; 1 bLieline - GR Measured Depth Log ~~ 1 blueline - GR TVD Log i z~ ~~ - - it C - - -- - ! E ; -. L> ' - ~~~ LAC Job#: 1047250 ~! . Sent By: Deepa Joglekar Date: Nlay 02, 2007 ;~ - y- Received By: Date: ~ ~ ~ ~~ ~~ - = J __ PLEASE ACKNOWLEDGE RECEIPT BY SIGN ING & RETURNING OR FAXING YOUR COPY - -- - ~nn ~ L 2 F AX: 7V~ 2S'-552~ ,.. ~ a~~_ ~ dl.~ Baker Hughes INTEQ ~ ! .- 7260 Homer Drive -- --- ~ is-~~ ~ Anchorage, Alaska ~ 99518 ! Direct: (907) 267-6612 I FAX: (907) 267-6623 ~` STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COM ~ ~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~'~~'~aIED ' ej q ~~0~ r~, .-. n ;. x. ~;~nmission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned zoAACZS.,os ^ GINJ ^ WINJ ^ WDSPL No. of Completions ^ Suspended ^ WAG zoAACZS.»o Zero Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 1/3/2006 ~ 12. Permit to Drill Number 205-204 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/31/2005 13. API Number 50-103-20092-60-00 4a. Location of Well (Governmental Section): Surtace: ' ~ 7. Date T.D. Reached 1/2/2006 ' 14. Well Name and Number: Kuparuk 3H-14BL1 ' 1157 FNL, 281 FWL, SEC. 12, T12N, R08E, UM Top of Productive Horizon: 1429' FSL, 1232' FEL, SEC 01, T12N, R08E, UM (From B) 8. KB Elevation (ft): 79.60 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 2460' FSL, 779' FEL, SEC. 01, T12N, R08E, UM 9. Plug Back Depth (MD+TVD) 8717 + 6110 Ft 4b. Location of W@II (State Base Plane Coordinates): Surtace: x- 49865 6000500 " 5' y- Zone- ASP4 10. Total Depth (MD+TVD) 9200 + 6170 Ft f6. Property Designation: ADL 025531 _ _ _ __ _ TPI: x- 502420_ y- 6003086 Zone- ASP4 Total Depth: x-~ 502 7 Zone- 873 Y- 600411 ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: _ _ _ _ f P f 18. Directional Surve y ®Yes ^ No 19. Water depth, if offshore WA MSL 20. Thickness o erma rost 2451 (Approx.) 21. logs Run: MWD GR r/~J W ~ a,~'r~7p ~ ~G•v (o 2. ASING, LINER AND EMENTING RECORD CASING ETfINO EPTH MD ETrINQ EPTH TVD I..1O~ atOUNT SIZE WT. PER FT. GRADE Op TTOM OP TTOM SIZE CEMENTING RECORD PULLED Did not run liner, As Planned Isolated O en Hole w/ IBP 23. Perforations open to Produc tion (MD + TV D of Top and " " 24, ` TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) None N/A MD TVD MD TVD 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 8024' et W hipstock 8717' et Inflatable Bridge Plug to Isolate BL1 Leg 26• PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Pr@SS. Casing Pressure CALCULATED Z4-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ._. ___ ~. _.i~iv None '~ ~ ~ t i a:'~ 9 _---_ r Form 10-407 Revised 12/2003< ' ~ ~o~vrINUED ON REVERSE SIDE ~~t~ ~ l~! ~ ~' ~.. a e I~ ~P~~/~/ l ~ l7 i 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state °None°. From 3H-146 None Kuparuk C4 8018' 6069' Kuparuk C4 8028' 6077' Kuparuk B3 8050' 6093' Kuparuk 62 8065' 6104' Kuparuk B3 8185' 6194' Kuparuk C4 8250' 6245' Kuparuk 63 8545' 6487' Kuparuk C4 8580' 6516' Kuparuk A6 8770' 6674' Kuparuk A3 8810' 6707 Kuparuk A2 8875' 6761' Kuparuk Ai 9063' 6917' 30. List of Attachments: Summary of Pre-Rig Work and-Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / ~ / Signed TeMe Hubble ~ Title Technical Assistant Date ~ l ~l ~~p Kuparuk 3H-146L1 205-204 Prepared ey Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. OriUing Engineer: Aras Worih/ngton, 564-4102 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029.20123-00-00). ITEM 20: True vertical thickness. fTEM 22: Attached supplemental records for this welt 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 ~- s Well: 3H-146 Multilaterals Accept: 12/29/05 Field: Kuparuk River Unit Spud: 12/31/05 API: 50-029-20092 Release: 01 /22/06 Permit: 205-205 / 205-206 / 206-008 Rig: Nordic #2 PRE-RIG W®RK 12/08/05 PRE-CTD PRESSURE TEST AND DRAWDOWN TEST OF MASTER VALVE, SWAB VALVE AND SSSV -ALL PASSED, BLEED DOWN OA 12/13/05 TAG FILL AT 8225' RKB. SET DHSIT AND GAUGES FOR PBU AT 7748' RKB. 12/18/05 DRIFT TUBING DOWN TO D NIPPLE AT 7748' RKB. EO DHSIT AND ATTEMPT TO PULL. 12/19/05 ATTEMPT TO PULL DHSIT. 12/20/05 CIRC OUT WELL W/SEA WATER AND DIESEL. MITIA TO 2500#; GOOD TEST. SET DGLV AT 6022' RKB. DRIFT W/ 10' X 2.74" AS FAR AS "D" NIPPLE AT 7748' RKB. 12/22/05 ATTEMPTED TO MILL RETAINER AT 8223'. MADE APPROX. 1.2' AND COULD NOT GO FURTHER. MULTIPLE STALLS WITH 3000-4000 # OVERPULLS. 12/23/05 DRIFTED DOWN TO THROUGH THE 2.75" "D" NIPPLE AT 7748' RKB W/ 47" X 2.74" DRIFT. HAD TO WORK IT SLIGHTLY TO GET IT THROUGH THE NIPPLE. SET DOWN C~ 8188' RKB, UNABLE TO ANY DEEPER. 12/26/05 INSTALLED BPV AND TORQUED WELLHEAD FLANGES TO MANUFACTURERS SPECIFICATIONS. DRILLED MOUSEHOLE IN FRONT OF WELLHEAD PER TOOLPUSHER DIRECTION. REMOVED BPV. READY FOR CTD. BP'EXPLORATION Page.«1 of 23 Operations Summary Report Legal Well Name: 3H-146 Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/28/2005 11:00 - 13:30 2.50 MOB P PRE Start rig move to 3H-14. Pull onto 1 F pad and wait for flight #351 to arrive at 1330hrs and scheduled departure at 1530hrs. 13:30 - 15:30 2.00 MOB P PRE Wait for aircraft traffic. 15:30 - 17:30 2.00 MOB P PRE Move to intersection of spine road and 1 F pad access road. 17:30 - 18:45 1.25 MOB P PRE Wait for CPF2 and CPF3 crew changes. Hold PJSM with night tour crew coming on rig. Discuss move and hazards. Review SOP. 18:45 -00:00 5.25 MOB P PRE Move down spine road toward 3H pad. Rig is just past CPF3 at midnight. 12/29/2005 00:00 - 03:00 3.00 MOB P PRE Continue move from CPF3 to 3H pad. 03:00 - 03:45 0.75 MOB P PRE PJSM prior to moving rig in over well. 03:45 - 06:00 2.25 MOB P PRE MIRU. Rig accepted at 0500hrs 06:00 -06:15 0.25 MOB P PRE PJSM with crew change.. need to level rig, hook-up comms (not good) start NU BOP's 06:15 - 08:00 1.75 MOB P PRE Level rig. 08:00 - 10:45 2.75 BOPSU P PRE NU BOP's Take on used 8.5ppg Flo-Pro form previous well. Hook up comms ant wire coming from rig. 10:45 - 16:00 5.25 BOPSU P PRE Test BOPE 250psi/low 4500psi/high. Problem with annular holding on 2-3/8" test jt. LD and inspect. Roughed up on closing area. PU 2" test jt and tested good. RU Tiger Tank. 16:00 - 16:30 0.50 CLEAN P WEXIT Gather all hands and hold Pre-Spud meeting. Discuss anticipated high pressure problems. SSSV operations. Possible pressure deployment problems. review next 48hr operations. 16:30 - 17:30 1.00 CLEAN P WEXIT Check WHP 927 psi. Close SSSV and bleed down to cuttings tank. All fluid returns. Montior well to see if SSSV is holding. As off 1730hrs it still Opsi. Waiting for Well Support to install hardline for Tiger Tank. 17:30 - 18:00 0.50 CLEAN P WEXIT Wait until hardline to Tiger Tank is install and continue monitoring SSSV performance. 18:00 - 18:30 0.50 CLEAN P WEXIT Crew change. 18:30 - 19:00 0.50 CLEAN P WEXIT Pre spud meeting with night crew. Discuss unusual aspects of this well. Discuss hazards, and mitigations to hazards. 19:00 - 20:00 1.00 CLEAN P WEXIT 900 psi on WHP. It is fluid and not gas. No hardline to tiger tank yet. Call AES to get ASAP. Bullhead well dead. Pumping 3.5 bpm, 2200 psi, IAP=35 psi, OAP=O psi. Pumped a total of 75 bbls. 20:00 - 21:30 1.50 CLEAN P WEXIT Shut SSSV, bleed off WHP. Check for flow. No flow observed. Make up BHA #1:2.74° D331, WF PDM, BHI MWD BHA. 21:30 - 23:30 2.00 CLEAN P WEXIT RIH pumping 1.37 bpm, 2700 psi thru WF motor. At 545', something plugged off. No flow at 4000 psi. Open EDC. Able to pump at 1.4 bpm, 2300 psi. Shut EDC. Attempt to pump, and able to pump at 1.5 bpm, 3400 psi. Possibly had the motor shuck a chunk of rubber which caught in the nozzle. Continue RIH pumping at full rate. Catch sample from returns. It was not rubber, but a slug of cuttings, paint chips, metal flakes and other debris. Possibly junk from AES vac tnrck that brought us the mud. Continue in hole pumping at full rate. Clean down to 8100' CTM. 23:30 -00:00 0.50 CLEAN P WEXIT Log down accross GR character from 7950'-8050'. Make -14' correction. 12/30/2005 00:00 - 01:00 1.00 CLEAN WEXIT Log CCL pass down. Confirm. that collars are on depth to tie in Printed: 1/23/2008 1:08:36 PM - BP EXPLORATION - Page 2 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From-To Hours Task Code NPT Phase DescriptionofiOperations 12/30/2005 00:00 - 01:00 1.00 CLEAN WEXIT log. 01:00 - 02:20 1.33 CLEAN WEXIT POOH, pumping at full rate. 02:20 - 02:30 0.17 CLEAN WEXIT Flow check well, and hold PJSM re: BHA swap. 02:30 - 03:45 1.25 WHIP WEXIT Lay down BHA #1, cleanout BHA. Reconfigure BHI MWD tool and test. Pick up BHA #2, WF anchor assembly, BHI MWD tool including HOT. 03:45 - 06:35 2.83 WHIP WEXIT RIH with BHA #2, whipstock anchor. EDC is open, pumping at minimum rate. Seeing some BU gas and oil. 06:35 - 07:25 0.83 WHIP WEXIT Log tie-in to GR. -14' correction. Log CCL f/ 7980 to 8090'. On depth to collars. Close EDC preessure up and set bottom of packer at 8045' top at 8042'. PU to 8035" RIH tag packer at 8843' set down 4k, looks good. 07:25 - 09:30 2.08 WHIP WEXIT TOH following pressure schedule to maintain 3800psi BHP. Trap 1100psi on well and shut-in SSSV. 09:30 - 10:40 1.17 WHIP WEXIT LD packer setting BHA and. PU whipstock assembly. 10:40 - 12:45 2.08 WHIP - WEXIT RIH open SSSV note breakover at 1100psi, exactly what we left on it. Continue RIH following pressure schedule. No BU gas to surface seen as in prior TIH. 12:45 - 12:55 0.17 WHIP WEXIT Check up st at 8000' 16K RIH tag anchor at 8043'. Latch into same. Pull to 22k. Good indication of set. Tray face oriented to 10L. Top of whipstock 8028' bottom 8032.7 (not confirmed by tie-in) Three pip tags were install 4.70' below TOW 12:55 - 14:10 1.25 WHIP WEXIT TOH following pressure schedule 14:10 - 15:00 0.83 WHIP WEXIT LD BHA #3. 15:00 - 16:25 1.42 BOPSU WEXIT Setback injector. PU Pressure Deployment lubricator. Strip 60' and rehead wireline. MU and pressure test to 2500psi. Setback lubricator. PU injector Also mic BHI tools where 2-318" combi's close. Above and below area 2.380' In the zone 2.370' 16:25 - 17:00 0.58 WHIP WEXIT PU BHA #4 17:00 - 18:25 1.42 WHIP WEXIT R1H open SSSV 18:25 - 19:00 0.58 WHIP WEXIT Log tie in pass down from 7900'. Make a -14' correction. 19:00 - 20:00 1.00 STWHIP WEXIT Dry tag top of whipstock. PU, kick on pumps. Free spin 1.56 bpm at 3750 psi. Tag top of whipstock at 8024'. Begin time milling window at 0.1'!6 minutes. 20:00 - 21:00 1.00 STWHIP WEXIT 8025.0'. Milling ahead. Motor work is 150 psi. DHWOB=980 lbs. String wt = 5800 lbs. Starting to get metal hair on the ditch magnets. 21:00 - 21:50 0.83 STWHIP WEXIT 8026.0'. Milling ahead. Motor work is 170 psi. DHWOB = 3300 lbs. String wt = 2000 lbs. Getting more metal hair on the magnets. 21:50 - 23:00 1.17 STWHIP WEXIT 8026.8'. Motor work dropped off and WOB dropped off. Possibly exited window. Continue at the 0.1'16 minute pace to allow string reamer to clean off the lip. 23:00 - 23:15 0.25 STWHIP WEXIT 8028.0'. Stall. Pickup. Possibly string reamer at lip. Continue milling at 0.1'/6 minutes. 23:15 - 0.00 STWHIP WEXIT 8028.2'. We are out the window. Push on it to see ff it will drill. Drilling at 20 fph, 1.56/1.49/3850 psi. PVT=297 bbls. Preliminary window depths; Window Top = 8024.0' Window Bot = 8026.8' RA Tag = 8028.5'. Printed: 1123/2006 1:06:38 PM BP EXPLORATION Page'3 of 23 Operations Summary Report Legal Well Name: 3H-146 Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date Frorn - To Hours Task Code NPT Phase Description of Operations 12/31/2005 00:00 - 00:40 0.67 STWHIP P WEXIT Make 2 reaming passes thru window. Dry drift up and down with no problems. 00:40 - 01:50 1.17 STWHIP P WEXIT POOH to pick up build section BHA. 01:50 - 02:10 0.33 STWHIP P WEXIT Tag up, shut SSSV. Flow check well while holding PJSM. No flow observed. 02:10 - 02:45 0.58 STWHIP P WEXIT Lay down window milling BHA. (BHA ff4) Lay down MWD tools. 02:45 -04:20 1.58 DRILL P PROD1 Reconfigure BHI MWD BHA to include HOT. Test on catwalk. Pick up 2.8 deg motor, Hycalog bicenter bit, and full MWD BHA. Stab on injector. 04:20 - 05:45 1.42 DRILL P PROD1 RIH with BHA #5 to drill build section. 05:45 - 06:15 0.50 DRILL P PROD1 Log tie in pass down from 7900'. -13.5' correction 06:15 - 10:45 4.50 DRILL P PROD1 Drilling ahead with build section f/ 8037' (1.63/3600/HSTFavn= 3850 ecd= 12.4this values are while holding 350psi whp) wob= 1-2k 100-200psi mw CTW=+6k Will soon be entering the B shale. IA 880/OA 68 Starting mud swap to 9.9ppg formate mud system. 9.9ppg around. Drop all WHP ann= 3845 ecd= 12.38 C~3 1.56bpm/3600 1-2k wob 20-30'/hr 10:45 - 12:35 1.83 DRILL P PROD1 TOH following revised 9.9ppg pressure schedule. Close SSSV w/ 650psi. Pull to 200" bleed down well and monitor for flow. 12:35 - 14:15 1.67 DRILL P PROD1 LD BHA #5. PU lateral BHA. Surface test tools. Short..most likely in UOC. We're been having trouble unstabing/stabbing injector because of the present bend in coil. This will be a good excuse to cut coil and rehead before getting into the lateral section. There's 8 runs on this head already. Normal rehead is at 10. 14:15 - 18:00 3.75 DRILL P PROD1 Circulate and warm coil. Unstab injector. Cut-off Kendal CTC. Dress end of a-line. Stab on well and reverse circ for Slack Mgmt. Cut-off 50' coil. Install Kendal CTC pull test to 40k. Circulate to warm coil. 18:00 - 19:00 1.00 DRILL P PROD1 Build BHI UQC. Meg line. Checks ok. Attach pressure test plate. PT to 4500 psi ok. Pump slack forward to complete slack management. 19:00 - 19:30 0.50 DRILL P PROD1 Pick up BHA #6 to drill lateral section. 1 deg motor. Same hycalog bicenter bit as previous run. Full MW D BHA. 19:30 - 21:00 1.50 DRILL P PROD1 Shallow hole test BHA. Passed ok. Open EDC, RIH. Set down at 850', fell thru. Straight hole, and no jewalry at this depth. Continue in hole. Set down at 3328', then fell thru. No jewalry, nothing on DHWOB sensor. PU and examine 200' of coil. Nothing observed on coil. RBIH. 4500', started seeing set downs every 30'. Somthing isn't right on the BHA. 21:00 -22:00 1.00 DRILL N DFAL PR001 It appears as if there is a sharp shoulder or upset we are hanging up on on the tubing collars. POH to examine BHA. Pulled dean coming up, no overpull or problems. 22:00 -22:10 0.17 DRILL N DFAL PROD1 PJSM while flowchecking well. Discuss plan forward. Need to diagnose problem and correct. 22:10 - 22:45 0.58 DRILL N DFAL PRODi Examine BHA. No problems or upsets found on CTC, or body of BHA. BHI motor has a wear pad on the heel that is probably causing the problem. The wear pad is carbide, about 1/2' thick, with a champher On the top side, no champher on the bottom side. This is a new wear pad design that was first run Printed: 1/23/2006 1:08:36 PM BP EXPLORATION Page 4 of 23 Operations Slummalry Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From `- To Hours Task Code NPT Phase- Description of Opera#ions 12/31/2005 22:10 - 22:45 0.58 DRILL N DFAL PROD1 on the last well 1 L-25. This is the first trip in the hole with a motor with a wearpad on this well. 22:45 - 23:05 0.33 DRILL N DFAL PROD1 The backup motor on location also has the wear pad on the heel. The motor from the build section is a high time motor, but does not have the wear pad. Comparison of the motors on location shows that the design of the wear pad is different. The new backup motor has a wear pad with a champher on both top and bottom. The motor that was in the hole only has a champher on top. It has an abrupt square edge on the bottom. It looks like a prototype design, and needs to have a champher added before we can run it in the hole. 23:05 - 00:00 0.92 DRILL N DFAL PROD1 Pickup new motor with the champhered wear pad. BHA #7. 1/1/2006 00:00 - 01:15 1.25 DRILL N DFAL PROD1 RIH with BHA #7 to begin drilling the L1 lateral section. No problems running in the hole. The new motor solved the problem. 01:15 - 01:45 0.50 DRILL P t PROD1 Continue RIH. 01:45 - 03:10 1.42 DRILL P PROD1 Log tie in pass down from 7850' down past RA tag. Make -12' correction. 03:10 - 05:00 1.83 DRILL P PROD1 Run to bottom. Free spin 3770 psi at 1.56 bpm. PVT=380 bbls. IAP=590 psi, OAP=42 psi. ECD=12.54 ppg. WHP = 0 psi. BHP = 3920 psi. Drilling ahead at 1.56/1.59/3850 psi. 50 fph. String wt = 4600 lbs. DHWOB=2000 lbs. 05:00 - 05:30 0.50 DRILL P PROD1 Geo needs to see a sample of the sand we are now drilling. Make a stow wiper trip while circulating bottoms up to get a sample for the Geo. 05:30 - 07:00 1.50 DRILL P PROD1 Resume drilling. Hit hard streak at 8262 drilled slow to 8266 then back to 50'fir. At 8278' lost partial returns 1.5611.21 pit vol 380bb1s 07:00 - 10:00 3.00 DRILL P PROD1 PU to 8250' gaining retums quickly 1.5611.46 RIH back on bottom continue drilling 1.56/1.48/3545fs ann=3880 ecd= 12.49 lost 2 bbls Drilling ahead f/ 8278' 30-50'fir 1.62/1.62/ 10:00 - 10:30 0.50 DRILL P PROD1 Wiper trip back to window. Last 60' of hole ratty both up and back. 10:30 - 14:15 3.75 DRILL P PROD1 Drill ahead f/ 8362' 1.61/1.61/3650fs 200-300mw 1-3k wob. Ratty drilling rop's all over the place. Drilling in the C4 which has siderite. Pit vol at 8400' 365bb1s. 14:15 - 16:45 2.50 DRILL P PROD1 Drill ahead f/ 8447' 1.57/1.53/3600fs pit vol 357bb1s ann=3900 ecd 12.55ppg 1-2k wob 20-30'fir 16:45 - t8:20 1.58 DRILL P PROD1 Drill ahead f/ 8495' 1.58/1.56/3600fs pit vol 350 bbls slow drilling on siderite. - 18:20 - 19:00 0.67 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. Ratty up to 8300', clean to the window. Ratty running back in the hole. 19:00 - 19:10 0.17 DRILL P PROD1 Resume drilling. Free spin 3350 psi at 1.46 bpm. Drilling at 1.46/1.4713420 psi. ROP=50 fph. PVT~44 bbls. BHP=3912 psi. ECD=12.51 ppg. IAP=750 psi. OAP=188 psi. String wt = 5001bs. DHWOB=26601bs. 19:10 -00:00 4.83 DRILL P PROD1 PVT =343 bbls. Taking on new mud to top of pits prior to crossing the fault. PVT after taking on new mud was 464 bbls. 1/2/2006 00:00 - 01:45 1.75 DRILL P PROD1 Continue drilling ahead in the C sand with moderate siderite cementation. ROP fluctuates from 0 to 65 fph. PVT=459 bbls. 01:45 - 02:30 0.75 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. A few minor Printed: 1/2312006 1:08:38 PM BP EXPLORATION Page 5 of 23 Operatiolns Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12!28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To .Hours Task Code NPT Phase. Description of Operations 1/2/2006 01:45 - 02:30 0.75 DRILL P PROD1 overpulls, but nothing bad on the way to the window. Clean .back in the hole. 02:30 - 06:00 3.50 DRILL P PROD1 Resume drilling. 1.52/1.47/3604 psi. BHP=3940 psi. ECD=12.61 ppg. ROP=40 fph. WOB=3200 lbs. CT string wt _-4300 lbs. 06:00 - 06:30 0.50 DRILL P PROD1 Drilling ahead f/ 8780' 1.54/1.52/3600fs 200-300mw ann=3980 ecd= 12.74 1-2k wob 20-30'1hr pit vol= 445bb1s May have crossed fault at -8770'. No pressure increases seen. in/out rates same. ROP> 70-80'/hr PU at 8820 for scheduled wiper trip. Stuck at 8760' roll orienter around 180 deg unstuck. Continue wiper. 06:30 - 07:30 1.00 DRILL P PROD1 Wiper trip to window 30'/hr 1.64 5-10k overpulls first 100'. Minor overpulls at 8500-8495, clean going in. 07:30 - 10:40 3.17 DRILL P PRODi Drill ahead f/ 8820' 1.60/1.56/3650fs. Drilled to 8945 seen 200psi increase in ann pressure lost 25% returns. Some gas to surface correlating to -8932'. Pinch choke to hold 300psi PU to 8900' slowly RIH and resume drilling to 8970'. Confirmed this is the major fault. Smaller one -8720'-70 10:40 - 12:05 1.42 DRILL P PROD1 Wiper trip to window. pits 394 to start Tie-in at pip tag +5' correction. RIH gs diminishing reducing whp 100psi increments returns 90% with 100psi WHP. Setdown at 8770' (sh section) pu MW thru RIH minor setdown at 8935' ok to bottom. 12:05 - 14:50 2.75 DRILL P PROD1 Drill ahead fr/ 8870' 1.55/1.41/3650fs 9.89/9.84 370bb1s in pits. whp=100psi ann=4027 ecd=12.88 1-2k wob 20-30'/hr > 50-60'/hr Start seeing increase in BU gas as a result of lowering whp. go back to 300psi.(pit vol 364 at 12:30 12bb1/hr loss rate) Start dropping angle at 8977' 150TF Time Depth WHP Pit Vol in/out gas nb inc 1230 8990 100 364 1.56 40u 86.94 1245 9010 300 355 1.56 25u 81.73 1300 9027 300 342 1.56 20u 80.45 1315 9036 300>250 331 1.56 30u 1330 9039 250 325 1.56 10u 78.37 1405 9059 250>200 305 1.56 10u 1415 9060 200 304 1.53 10 1430 9063 200 295 1.53 10 76.77 1445 9066 200 289 1.53 10 1500 9069 180 283 1.53 10 Drilling break at 9070 70-80'/hr w/ 2k wob 1515 9084 180 279 1.53 10 1530 9100 180>150 273 1.53 1550 9120 150 264 1.53 14:50 -17:00 2.17 DRILL P PROD1 Wiper trip to window. Pull tight at 9050' Hole in great shape but lost 16 bbls mud during wiper trip 17:00 - 18:00 1.00 DRILL P PROD1 Drill ahead f/ 9120' 1.53/1.15/3650fs 120-150TF 75deg inc 2k wob 60-70'/hr in Ai sand Alerted SLB cementers of possible job. Could be ready to pump +/- 8hrs 18:00 - 18:50 0.83 DRILL P PROD1 Drilling ahead. ROP 20-60 fph. 1.53/1.35/3990 psi. WHP=190 psi. BHP=4075 psi. ECD=12.93 ppg. IAP=220 psi. OAP=210 psi. Losing about 20 bbls of mud per hour. 18:50 - 19:50 1.00 DRILL P PROD1 Geo called this TD. Call Baker TT to get crossovers needed to Printed: 1!23/2006 1:06:36 PM BP EXPLORATION Page 6 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+GOMPLETE Start: 12/28/2005 End: 1/22!2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: -Date From - To Hours Task Code NPT Phase Description of Operations 1/2/2006 18:50 - 19:50 1.00 DRILL P PROD1 pump cement. Call town to discuss cement job. Call Schlumberger to get cementers headed this way. Make wiper trip to window. Clean up to window. No problems on wiper trip. 19:50 - 20:05 0.25 DRILL P PR001 Log tie in pass down over RA tag in whipstock. Make +0.5' correction. 20:05 - 20:30 0.42 DRILL P PROD1 RIH, smooth. 20:30 - 20:55 0.42 DRILL P PRODi Back on bottom. Tag depth is 9200.2'. Circulate LCM pill to bottom to slow tosses prior to cementing. Pumping 20 bbls of new mud with 3 #/bbl of 250 mesh (Fine) CaC03. Loss prior to LCM pill reaching bit are 18 bbifir. 20:55 - 21:35 0.67 DRILL P PROD1 Pull up hole laying in LCM pill 1 for 1 as we pull. No problems pumping LCM thru motor. Stop at 8300'. SI choke, squeeze LCM into loss zone. Lost 13 bbls to loss zone white pulling up hole. Bullheaded 5 more bbls away from 8300 psi. Only had a t 200 psi pressure bump during squeeze. 21:35 - 23:15 1.67 DRILL P PROD1 Continue POH, pumping at full rate and holding 200 psi on WHP. Losing fluid still. LCM didn't seem to help much. Clean in OH to the window. Continue OOH pumping full rate thru an open EDC in casing. 23:15 - 23:35 0.33 DRILL P PROD1 Tag up at surface. Shut EDC. Perform no flow test prior to unstabbing injector. Hold PJSM while checking well #or flow. Discuss plan forward-for laying down BHA. 23:35 - 00:00 0.42 DRILL P PROD1 Lay down BHA #7. 1/3/2006 00:00 -04:00 4.00 DRILL C PRODi Wait on 1-1/4" CSH from Nordic 1. 04:00 -04:15 0.25 DRILL C PROD1 PJSM Re: running CSH. 04:15 -04:50 0.58 LCR C PROD1 Make up BHA #8, Cement nozzle, R-1 checks, 15 jts of 1-1/4" CSH, X/O. 04:50 - 05:15 0.42 LCR C PROD1 Disconnect UQC, make end of etine water tight. Make up CTC and stab injector. 05:15 -06:40 1.42 LCR C PROD1 RIH with BHA #8 to P&A L1 lateral. 06:40 - 07:20 0.67 LCR C PROD1 PJSM with alt hands. Review cementing procedures, WHP . management etc. Same time shut-in choke and bullheaded 16bbls to clear openhole of any gas. 07:20 -09:00 1.67 LCR C PROD1 RIH to 9200' without problems. 09:00 -09:15 0.25 LCR C PROD1 Circulate at min rate. Wait on a toad of mud that wilt be needed for cleanup. review job again go over calcullations etc. Call from town and discuss cmt job. Came to light that if we proceed with cement job there's a very good chance we would cement the perfs below the whipstock/packer assembly. A frac job was just completed on those perfs prior to rigging up. So cancelled cement job. Will run an IBP or something similar. 09:15 - 10:45 1.50 LCR C PROD1 TOH following pressure schedule. Close SSSV trapping 1000psi. Park at 500' bleed off weU and monitor for flow 10:45 - 11:00 0.25 LCR C PROD1 PJSM: review plan forward for Ud of 1-1/4" CSH. Monitor well same time. 11:00 -11:45 0.75 LCR C PROD1 LD BHA. Found 400" in CSH 11:45 - 14:00 2.25 DRILL C PROD1 Waterproof end of a-line. Do Slack management 14:00 - 15:00 1.00 DRILL C PROD1 Attach CTC oral UOC to coil. Discuss options with town. Current plan forward is to set an IBP at 8700'-8725'. Notify Baker TT to prepare equipment and bring to rig. 15:00 - 17:00 2.00 DRILL C PROD1 Wait for BOT to bring out IBP and setting tools. Printed: 1/23/2008 1:06:36 PM `$P EXPLORATION Page 7 of 23 Operations Summary Report Legal Well Name: 3H-146 Common We11 Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From'- To Hours Task 'Code NPT Phase Description of Operations. 1/3/2006 17:00 - 17:15 0.25 LCR C PROD1 PJSM with rig hands and Baker TT hand to discuss job, and plan forward for setting IBP. 17:15 - 17:45 0.50 LCR C PROD1 Pick up BHA #9, IBP setting BHA. 17:45 - 20:15 2.50 LCR C PROD1 RIH with BHA #9 to set IBP. 20:15 - 20:45 0.50 LCR C PROD1 Log gr tie in from 8030'. Subtract 11' correction. 20:45 - 21:45 1.00 LCR C PROD1 Run in hole to setting depth at 20 fpm. 8.4 k# do wt. Slow to 10 fpm to allow temperature to stabilize. BHT: 151 deg F. 21:45 - 22:30 0.75 LCR C PROD1 Pressure coil to set IBP at 8718'. Pressure coil to 750 psi for 5 min. WHP: 550 psi. Increase to 1100 psi for 5 min. Increase pressure to 1300 psi. See pressure drop. Set down wt. Not taking wt. Increase coil pressure to 1370 psi. Increase coil pressure by 250 psi increments. Pressure to 2300 psi. Bled back to 1000. Something happened. Pull up hole slowly to allow IBP to fully set. Run in hole. Set down 2k# . IBP appears to be set. Btm at 8720'. Top of IBP at 8709'. 22:30 - 00:00 1.50 LCR C PROD1 Pull out of hole. Displace well to new mud for sidetrack. 1/4/2006 00:00 - 00:30 0.50 LCR C PROD1 Continue to pull out of hole. PJSM in ops cab to discuss undeploying BHA. 00 30 00 01 0 50 LCR C P B IBP i G ff U b i k l : - : . ROD1 well. nsta l. LD a er runn ng too s. et o co 01:00 - 02:00 1.00 STKOH P PROD1 Mu BHA #10 (OH sidetrack with 1.8 AKO & R60ST bit). Stab ,(,Z. coil. Get on well. 02:00 - 03:20 1.33 STKOH P PROD1 Run in hole. Open SSSV. Continue in hole maintaining BHP as per schedule. 03:20 - 03:45 0.42 STKOH P PROD1 Log gr tie in from from 8040'. Subtract 7' correction. 03:45 -04:45 1.00 STKOH P PROD1 Run in hole. Circulate at 1.52/3250 psi bpm to try and knock off brass cap. Run through hard spots and higher dog leg areas at 180 degress opposite the original tool face. 04:45 - 06:00 i.25 STKOH P PROD1 Begin troughing down at 160R TF, 20 fph. 3050 psi fs at 1.47 iNout. 06:00 - 07:40 1.67 STKOH P PROD1 Continue troughing. 07:40 - 08:40 1.00 STKOH P PRODi Begin time drilling at 1 Ft/hr. DHWOB=O lbs. String wt=6645 lbs. Free spin = 3180 psi. WHP=O psi. BHP=3826 psi. ECD=12.25 ppg. Taking on new mud. 08:40 - 09:55 1.25 STKOH P PROD1 Time milling at 2 fph. DHW08- 200 lbs. String wt=7230 lbs. 3164 psi at 1.48 bpm. WHP=O, BHP=3829 psi. ECD=12.26 ppg. PVT=310 bbls. 09:55 - 10:15 0.33 STKOH P PROD1 Time drilling at 3 fph. DHWOB=80 lbs. String wt = 7876 lbs. 3208 psi at 1.47 bpm. WHP=O psi, BHP=3830 psi. ECD=12.26 ppg. PVT=320 bbls. Finished taking on mud. 10:15 - 10:30 0.25 STKOH P PROD1 Start drilling at 10 fph. Taking wt and getting motor work. Life is good. OHW06=3001bs. 1.48/1.46/3300 psi. String wt = 6200 lbs. Near bit INC is changing from original wellbore. 10:30 - 10:40 0.17 STKOH P PROD1 Start drilling at 30 fph. Good wt on bit and motor work. DHWOB=1500 lbs. 1.4811.45/3350 psi. PVT=318 bbls. INC confirms that we have a sidetrack. 10:40 - 11:15 0.58 STKOH P PRODi Back ream at high side and 45 LOHS and 45 ROHS to knock off the lip. Now have some slight losses. 1.4811.38/3479 psi. PVT=318 t~ls. 11:15 - 12:45 1.50 STKOH P PROD1 POH to pick up lateral section BHA. 12:45 - 13:00 0.25 STKOH P PROD1 Tag up at surface. FlowcheCk well to ensure that SSSV is holding. Hold PJSM while flow checking well. Discuss BHA swap and function test of BOP's. Check well for flow. No flow observed. Printed: 1/23!2006 1:06:36 PM BP EXPLORATION ' Page 8 of 23' Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date- From - To Hours Task Code NPT Phase Description of Operations 1/4/2006 13:00 - 13:30 0.50 STKOH P PRODi lay down BHA #10, L1 lateral OH sidetracking BHA. 13:30 - 13:45 0.25 BOPSU P PROD2 Function test BOP stack as per 7 day AOGCC test requirement. All functioned properly. 13:45 - 14:30 0.75 DRILL P PROD2 Make up BHA #11, first L2 lateral section BHA. BHA consists of hycalog 2.70" x 3.0' bicenter bit with Fuli Round TREX cutters, a 0.9 deg AKO motor, and bull BHI MWD BHA. 14:30 - 15:40 1.17 DRILL P PROD2 RIH with BHA #11, to begin drilling the L2 lateral section. 15:40 - 16:25 0.75 DRILL N SFAL PROD2 4800'. Found leaking O-Ring on lubricator connection below packoff. Need to change out. POOH for repair to lubricator O-Ring. 16:25 - 16:35 0.17 DRILL N SFAL PROD2 Tag back up at surface. Flow check well. Discuss plan forward for chaning out O-Ring. Check well again. No flow observed. 16:35 - 17:10 0.58 DRILL N SFAL PROD2 Unstab lubricator, break OC. Break out upper lubricator. Replaced damaged O-Ring on lubricator. Stab lubricator t again. Make up OC. Stab injector. 17:10 - 18:00 0.83 DRILL N SFAL PROD2 Run back in hole with BHA #11 from 4800'. 18:00 - 18:45 0.75 DRILL P PROD2 Continue RIH. 18:45 - 19:00 0.25 DRILL P PROD2 Log gr tie in from 8040'. Subtract 9' correction. 19:00 - 22:00 3.00 DRILL P PROD2 Drill ahead from 8305'. 3550 psi fs at 1.46 iN1.4 out. DPSI: 150-200. DHWOB: 1.0-2.0 k#. WHP/BHP/ECD: 15/3911/12.53 ppg. IA/OA/PVT: 70/74/267. Losing about 5 bpm mud. ROP: 40-60 fph. 22:00 - 23:00 1.00 DRILL P PROD2 Wiper trip to window. Hole smooth. 23:00 -00:00 1.00 DRILL P PROD2 Drill ahead from 8450'. 1/5/2006 00:00 - 02:15 2.25 DRILL P PROD2 Drill ahead to 8600'. 02:15 - 03:15 1.00 DRILL P PROD2 Wiper trip to window. Hole smooth. 03:15 -06:00 2.75 DRILL P PROD2 Drill ahead to 8690'. 06:00 - 09:00 3.00 DRILL P PROD2 Drilling ahead. Free spin 3150 psi at 1.4 bpm. Drilling at 1.41/1.39/3550 psi. ROP is variable from 0-60 fph. IAP=130 psi, OAP=120 psi. WHP=0 psi. BHP=3928 psi. ECD=12.56 ppg. String wt = 39001bs. DHWOB=1200 lbs. 09:00 - 09:40 0.67 DRILL P PROD2 Out rates went from 1.42/1.39 to 1.4211.49. Took a 2 bbl pit ' gain. Looks like we crossed the fault we were expecting. Increase WHP to 250 psi, and now have BHP of 4041 psi. Losses now 1.41/1.19. Calculated losses are 13 bph. Begin swap to conventional Flopro mud to minimize losses of Formate mud. Saving Formate for return to MI. 09:40 - 10:10 0.50 DRILL P PROD2 Make wiper trip to window. Clean PU off bottom. Clean in OH up to 8530. Ratty 8530'-8420', then clean to the window.. Still swapping to new mud. 10:10 - 10:20 0.17 DRILL P PROD2 Log tie in pass down. Make +2.5' correction. 10:20 - 10:40 0.33 DRILL P PROD2 Run back to bottom on wiper trip. 10:40 - 13:40 3.00 DRILL P PROD2 Drill ahead. Free spin 3700 psi at 1.4 bpm. WHP=150 psi. Lost 8 bbls in last hour. 13:40 - 14:40 1.00 DRILL P PROD2 Wiper trip to window. Clean PU off bottom. Clean up to window and back down. Better than last wiper trip. 14:40 - 15:30 0.83 DRILL P PROD2 Resume drilling. PVT=312 bbls. WHP=250 psi. BHP~125 psi. ECD=13.19 ppg. 1.39/1.14/3948. Free spin 3800 psi at 1.4 bpm. 15:30 - 17:45 2.25 DRILL P PROD2 Lost 12 bbls in last 45 minutes, and have been getting crude and gas back in returns. Increasing choke any more increases our losses to 50%. Call mud man to mix 40 bbls of CaCo3 Printed: 1/23/2006 1:06:36 PM `$P EXPLORATION Page 9 of 23 Operations Summary Report Legal Well Name: 3H-146 Common WeII Name: 3H-14B Spud Date: 12/30!2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: -Date From -'To Hours Task Code NPT Phase Description of Operations. 1/5/2006 15:30 - 17:45 2.25 DRILL P PROD2 medium (250 micron) size LCM to see if we can slow down losses so that we can increase choke pressure. 17:45 - 18:50 1.08 DRILL P PROD2 Pump 40 bbls of mud with LCM. Drill ahead until pill exits bit. Increase WHP to 300 to 500 psi to force pill into formation. Returns were reduced, no apparent effect on out rate once WHP reduced back to 250 psi. 18:50 - 20:00 1.17 DRILL P PROD2 Wiper trip to window. Hole smooth. 20:00 - 23:00 3.00 DRILL P PROD2 Drill ahead from 9099'. 4100 psi fs at 1.54 in/1.25 out. DPSI: 100-200. DHWOB: 0.5 - 1.5 k#. WHPBHP/ECD: 249/4203/13.44 ppg. tA/OA/PVT: 43/42/395 bbls. Continue to lose f 5 to 20 bph. ROP 30-50 fph. INC/AZM/TF: 88-89/15-35/ 90R-120L 23:00 - 00:00 1.00 DRILL P PROD2 Wiper trip to window. 16k# up wt off btm. Hole clean. 1/6/2006 00:00 -00:30 0.50 DRILL P PROD2 Log gr tie in from 8040'. Add 1.5' correction. 00:30 - 01:00 0.50 DRILL P PROD2 Continue to run in hole. Smooth to btm. 3950 psi fs at 1.48 iN1.30 out. 01:00 -04:00 3.00 DRILL P PROD2 Drill ahead from 9250'. Losses seem to healing slowly. 1.57 in/1.41 out. 4100 psi fs. DHWOB: 1.2-1.5 k#. ROP: 30-40 fph. PVT: 290 bbls. INC/AZM/TF: 86-89/15-32/30R-45L. Some faster drilling through cleaner zones. 04:00 - 06:00 2.00 DRILL P PROD2 Wiper trip to window. Losses continue to heal. 4200 psi fs at 1.52 iNi .45 out. 06:00 - 07:10 1.17 DRILL P PROD2 Resume drilling. 1.55/?/4220 psi. WHP=322 psi. BHP~t236 psi, ECD=13.55 ppg. IAP=63 psi, OAP=57 psi. ROP=60 fph. INC=94 deg. Losses last half hour were 3 bbls. PVT=333. String wt=500 Ibs, DHWOB=1100 lbs. 07:10 - 07:30 0.33 DRILL P PROD2 PVT=315 bbls. Lost 18 bbls in last 70 minutes. About 15 bbls/hr. Bring an additional 100 bbls of new mud into pits. 07:30 - 08:40 1.17 DRILL P PROD2 New mud on board. PVT=414 bbls. 08:40 - 10:15 1.58 DRILL P PROD2 Wiper trip to window. Clan PU off bottom. Clean in open hole. 10:15 - 11:15 1.00 DRILL P PROD2 Free spin 4190 psi at 1.53 bpm. Tag bottom, resume driAing 1.54/1.3614300 psi. PVT=357 bbls. Lost 57 bbts in 2:45 hours. Average of 21 bbls/hr. 11:15 - 15:15 4.00 DRILL P PROD2 PVT=336 bbls. Lost 21 bbls in last hour. 15:15 - 16:15 1.00 DRILL P PROD2 Wiper trip to window. Clean PU off bottom. Clean in OH. 16:15 - 16:20 0.08 DRILL P PROD2 Log tie in pass. Make +2' correction. 16:20 - 17:15 0.92 DRILL P PROD2 Run back in hole. Clean to bottom. 17:15 - 18:00 0.75 DRILL P PROD2 Resume drilling. Free spin 3913 psi at 1.44 bpm. Drilling at 1.44/1.44/4025 psi. Momentarily no losses. Yipee! It probably won't last long though. Taking on mud to top off pits. String wt _ +3500 Ibs. DHWOB=800 Ibs. IAP=80 psi, OAP=95 psi. 18:00 - 20:00 2.00 DRILL P PROD2 Drill ahead from 9750'. PVT: 405 bbls. Continue climb at 91.7 deg, looking for A sand. WHPBHP/ECD: 375-400/4246/13.6 ppg. Some crude in mud, occasional gas alarms at shaker. Attempt to adjust WHPBHP to minimize crude influx. 20:00 -22:30 2.50 DRILL P PROD2 Wiper trip to window. 16.5k# up wt off btm. Hole smooth in both directions. 3955 psi fs at 1.46 iN1.31 out. 22:30 -00:00 1.50 DRILL P PROD2 Drilt ahead from 9850'. PVT: 344 bbls. Have lost 13.5 BPH since 1800 hrs. 1/7/2006 00:00 - 03:00 3.00 DRILL P PROD2 Drill ahead from 9910. 4025 psi fs at 1.54 iN1.32 out. DPSI: 200-300. DHWOB: 1.43 k#. WHPBHP/ECD: 420/4356113.94 Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 10 of 23 Operations Summary Report Legal Wel{ Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: 'Date From - To Hours Task Code NPT Phase Description of Operations 1!7/2006 00:00 - 03:00 3.00 DRILL P PROD2 ppg. IA/OA/PVT: 115/107/294 bbls. INC/AZMITF: 91-92119-35/90R-90L. ROP: 30-55 fph. Continue to lose 12-18 bph. Gas alarms every so often. Send mud to cuttings box if cut with too much crude. Take on additional 100 bbls flo pro into pits. 03:00 -04:30 1.50 DRILL P PROD2 Wiper trip to window. 4153 psi fs at 1.53 in. Hole smooth. 04:30 -06:00 1.50 DRILL P PROD2 Drill ahead from 10,000'. 06:00 - 07:00 1.00 DRILL P PROD2 Continue drilling ahead. In shale trying to drill down and fired the sand. Drilling at 1.47/1.26/4340 psi. PVT=255 bbls. Call for truck to top off pits. IAP=126 psi, OAP=115 psi. BHP=4376 psi. WHP=425 psi. 07:00 - 07:55 0.92 DRILL P PROD2 Continue drilling ahead. Lost 14 bbls in last hour. String wt = -15001bs. DHW08=16001bs. 07:55 - 08:00 0.08 DRILL P PROD2 Had hard spot in drilling at 10127'. Broke thru something and 1 return rate jumped up. Possibly took another kick. Increased ~ WHP to keep returns about the same as the start of tour. Drilling with 475 psi on WHP. Rate 1.52!1.28/4150 psi. 08:00 - 08:45 0.75 i DRILL P PROD2 PVT=219 bbls. Lost 23 bbls in last hour. 08:45 - 09:55 1.17 DRILL P PROD2 Wiper trip to window. Clean PU off bottom at 16 klbs. 09:55 - 10:10 0.25 DRILL P PROD2 Log tie in pass over RA tag. Make +2' correction. 10:10 - 11:15 1.08 DRILL P PROD2 RBIH on wiper trip. Taking on new mud. 11:15 - 13:00 1.75 DRILL P PROD2 Resume drilling. Free spin is 4200 psi at 1.43 bpm. Drilling at 1.44/1.05/4300 psi. ROP=71 fph. PVT = 435 bbls. 13:00 - 14:00 1.00 DRILL P PROD2 Geo confirms that we crossed a fault at 10127'.. We are now in the A6 shale. Discuss with town. We need to get down out of this ASAP. The A6 has proved to be a problem on previous wells when a considerable distance drilled horizontally. Drill down at 83-85 degrees INC. 14:00 -15:30 1.50 DRiLt P PROD2 PVT=386 bbls. Lost 18 bbls of mud in last hour. BHP=4390 psi. WHP=440 psi. 1.51/1.24/4300 psi. ROP errattic. It is varying from 0-30 fph, with ocassional hard spots. 15:30 - 17:00 1.50 DRILL P PROD2 PVT 355 bbls. Lost 31 bbls in last 1-1/2 hours. Top off pits " with new mud. 17:00 - 18:00 1.00 DRILL P PROD2 Broke thru the A6, back into good sand. ROP up to 50 fph. PVT=433 bbls. 18:00 - 20:00 2.00 DRILL P PROD2 Drill ahead from 10275'. 4020 psi fs at 1.45 iN1.26 out. 408 bbls at 1830 hrs. 12 BPH loss rate. Having weight transfer problems. Decide to wiper trip early. 20:00 - 22:00 2.00 DRILL P PROD2 Wiper trip to window. 16.3k# up wt off btm. PVT: 385 at start of trip. 355 bbls at end of trip. Hole smooth. 22:00 -00:00 2.00 DRILL P PROD2 Drill ahead from 10287'. Good differential and DHWOB, just hard drilling. Plan is to drop to 82-83 degrees inclination, drill through the A3, and level off in the A2. 1/8!2006 00:00 -03:00 3.00 DRILL P PROD2 Drill ahead f/ 10,295'. 4100 psi fs at 1.53 iNout DPSI: 150-200. DHWOB: 2.52k#. Coil Wt: -6500#. WHP/BHP/ECD: 403/4363/13.93 ppg. IA/OA/PVT: 122/94/341 bbls. INC/AZM/TF: 85-83/25-551 180-230 deg. Continued hard slow drilling. Losses variable from zero to 18 BHP. Wt transfer still looks adequate. Able to stall mtr too. 03:00 -04:30 1.50 DRILL P PROD2 Drill ahead from 10320'. PVT: 312 bbls. INC: 82-83 deg. Plan Printed: 1/23/2006 1:06:36 PM BP EXPLORATION. Page 11 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From -'To -Hours Task Code NPT Phase Description of Operations. 1/8/2006 03:00 -04:30 1.50 DRILL P PROD2 to hold this angle until finding the A3/A2. See a few drill breaks, but then ROP became even slower. 04:30 - 05:15 0.75 DRILL P PROD2 Wiper trip back to window. 05:15 -06:00 0.75 DRILL P PROD2 Pull out of hole to check BHA. 06:00 - 07:05 1.08 DRILL P PROD2 POOH from window. Following a revised pressure schedule to maintain constant bottom hole pressure. Pull thru the SSSV, and trap 1200 psi. Shut SSSV, pull to surface. 07:05 - 07:20 0.25 DRILL P PROD2 Tag up at surface. Open choke and check for flow at possum belly. Hold PJSM to discuss plan forward. No flow observed at possum belly after PJSM. 07:20 - 09:20 2.00 DRILL P PROD2 Lay down BHA #11. Bit graded 2,2 with 2 chipped cutters. Bit was found with 1 nozzle plugged with rubber. The motor seemed tight when checked with pipe wrenches, but the presence of rubber in the nozzle suggests that the motor stator was starting to come apart. Pick up a new motor, new hycalog DS100 bit. Pick up the Agitator, and remove the flapper checks from the UOC. Check the 1 R dart style checks in the DFS. PT the CTC. 09:20 - 11:15 1.92 DRILL P PROD2 RIH with BHA #12. Using Hycalog DS100 bit with Tuff Edge, full round cutters. Motor AKO 0.9 deg. Agitator in BHA, checks in UOC out. Shallow hole test MWD tools passed. OK. RIH to 500', kick on pumps Agitator functions ok. RIH. Open SSSV. Found 1030 psi under the SSSV. RIH bring pumps on, bring WHP up to 1200 psi, follow the latest pressure schedule while RIH. 11:15 - 11:30 0.25 DRILL P PROD2 Log tie in pass over RA tag. Make -10.5' correction. 11:30 - 12:50 1.33 DRILL P PROD2 Run to bottom. No problems in open hole down to 10130', then had to work it to bottom. 12:50 - 13:30 0.67 DRILL P PROD2 Backream A6 shale interval prior to begining to drill. Still have origional mud in the hole. Free spin with Agitator in BHA is 4500 psi at 1.48 bpm. 13:30 - 14:45 1.25 DRILL P PROD2 Free spin at reduced pump rate is 4140 psi at 1.37 bpm. Free spin 4000 psi at 1.3 bpm. Tag bottom, resume drii{ing. 1.31?/4400 psi. Swapping to new mud to try to reduce pump pressures. ROP=15 fph. DHWOB=2800 lbs. String wt = 1080 lbs. WHP=500 psi. ECD=14.06 ppg. BHP=4407 psi. 14:45 - 16:30 1.75 DRILL P PROD2 Geo examined sample from interval we reamed earlier. Sample is consisted with A5-A6 interval. Drilling ROP is very slow and GR is high. Possibly crossed another fault. Point tool face down and intend to drop angle to 83 deg to attempt to drill down out of possible A5-A6 interval again. 16:30 - 18:00 1.50 DRILL P PROD2 Broke back into good sand. Continue drilling down to find the A2. 18:00 - 19:00 1.00 DRILL P PROD2 Drill ahead from 10430'. PVT: 436 + 105 bbls. 4100 psi fs at 1.31 in. 19:00 -22:00 3.00 DRILL P PROD2 Wiper trip to window while deciding on directional plan forward with town team.. 17.5k# up wt off btm. Got a lot of crude and some gas back in btms up part way through trip. Ran returns through gas buster and sent 33 bbls mud to cuttings box. Hole smooth except for a few bobbles from 10175' to 10280'. 22:00 -00:00 2.00 DRILL P PROD2 Drill ahead from 10,450'. Plan is to continue to hold 83-84 deg incl to stay in A3/A2 zones. 1/9/2006 00:00 -03:45 3.75 DRILL P PROD2 Drill ahead from 10533'. 4100 psi fs at 1.35 iN1.30 out. DPSI: Prated: 1/23/2008 1:06:36 PM BP EXPLORATION Page 12 of 23 Operations'Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12!30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22!2006 Contractor Name: NORDIC CALISTA Rig Release: i/22/2006 Rig Name: NORDIC 2 Rig Number: Date. From -To Hours Task Code- NPT Phase Description of Operations 1/9/2006 00:00 - 03:45 3.75 DRILL P PROD2 100-150. DHWOB: 2.65 k#. Coil Wt: -1350#. WHP/BHP/ECD: 600/4386/13.95 ppg. IA/OA/PVT: 83/59/373 bbls. INC/AZMlfF: 82-83/12-541185-285 deg. ROP variable: 12 - 55 fph. Getting gas and crude in returns when ECD drops below 14.0 ppg. WHP of 550 to 600 psi required to maintain "balance". 03:45 -06:00 2.25 DRILL P PROD2 Wiper trip to window. 19.4k# up wt. PVT: 352 bbls. 4050 psi fs at 1.39 bpm. 06:00 - 07:00 1.00 DRILL P PROD2 Continue RIH on wiper. Hole relatively clean down to 10200'. Had one set down, then fell thru it. Run the rest of the way to bottom kind of ratty. 07:00 - 10:00 3.00 DRILL P PROD2 Tag bottom, resume drilling. Free spin was 4330 psi at 1.5 bpm. Drilling ahead at 1.5/?/4800 psi. PVT=384 bbls. IAP=110 psi, OAP=75 psi. 8HP=4420 psi. ECD=14.05 ppg. DHWOB=1200 lbs. String wt = 700 lbs. 10:00 - 11:30 1.50 DRILL P I PROD2 Wiper trip to window. Sticky pickup off bottom. Sticky for 150', then smoothed out. No problems in A6 sand 10200'-10127'. 11:30 - 11:45 0.25 DRILL P PROD2 Log tie in pass, make +8.5' correction.. 11:45 - 13:20 1.58 DRILL P PROD2 Run back in hole. Geo reports that latest cuttings indicate we are in the C sand, and not the target A sand. Discuss with town. Drilling further trying to get back into the A wilt require significant amount of footage, and we will be risking the wellbore as we approach the injector. Plan is to call this TD. Continue trip in the hole for final tag, and to lay in glass beads. Thru the 10130'-10200' interval with no problems. Rough/ratty hole from 10541' to TD. Tag TD at 10774'. This is tied in TD depth. 13:20 - 15:00 1.67 DRILL P PROD2 Pu11 back up hole. to 10100'. Hole is in much better shape this time. One overpull at 10400'. Work bottom section of hole until clean. Swap to 20 bbl pill of new mud with 3#/bbl of MI Alpine Glass beads. 15:00 -16:20 1.33 DRILL P PROD2 POOH laying in glass bead pill. Bottom of hole in good shape. No problems on trip up hole in open hole. 16:20 - 18:00. 1.67 DRILL P PROD'2 SD pumps, pull thru the window. Open EDC. Pump at full rate while POH. Close SSSV. POH to surface. Flow check well. Stable. Hold PJSM to discuss BHA handling. 18:00 - 18:45 0.75 DRILL P PROD2 Get off well. Unstab coil. LD drilling BHA. 18:45 - 19:15 0.50 CASE P RUNPRD RU floor to run liner. 19:15 - 19:30 0.25 CASE P RUNPRD Hold PJSM with crew to discuss running liner. Discuss assignments, procedures, well control, hazards, and how to minimze hazards. i 9:30 -22:15 2.75 CASE P RUNPRD MU 59 jts of 2-3/8' slotted & solid, 4.4#, 180, STL liner. indexing guide shoe on btm. Weatherford 2.5" od aluminum billet on top. OAL: 191 fi. 22:15 - 23:15 1.00 CASE P RUNPRD MU MWD tools (DGS, DPS, ECD& comms}. Stab coil. Get on well. 23:15 -00:00 0.75 CASE P RUNPRD Circ coil. Pressure well to 1200 psi. Open SSSV. Fourxf 1099 psi on well. Run in hole. 1/10/2006 00:00 -00:30 0.50 CASE P RUNPRD Run in hole to 8000'. Up wt: 18k#. Close EDC. Maintain WHP at 1100 psi. Continue to run in hole. 7.7k# do wt just below window. Slight bobble at OH sidetrack depth of 8285'. 00:30 - 02:15 1.75 CASE P RUNPRD Set down at 9190'. PU and run through ok. RIH to 9698'. Set Printed: 1/23/2006 1:06:36 PM $P EXPLORATION Page 13 of 23 Operations Summary Report Legal Wetl Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT 'Phase Description of Operations. 1/10/2006 00:30 - 02:15 1.75 CASE P RUNPRD down. PU and work pipe. Able to push ahead to 9768'. Unable to get any deeper. Pull up hole to to get another run at it. Bleed WHP to 600 psi. Try to run in hole. No improvement. Work pipe with 600 psi WHP. No go. Bring WHP back up to ! 100 psi. Work down to 9831'. Stack max wt several times. 02:15 - 03:00 0.75 CASE P RUNPRD Open EDC. Break circulation at 1.6 bpm /3450 psi. Reduce WHP to 600 psi. Attempt to RIH. No go. Limited to -10k# pull on EDC when open. Unable to move pipe up hole under these conditions while circulating. Step WHP down in increments to 650 psi while circulating. Continue to work pipe slowly down hole. Eventually not able to make any more footage Acts like we are in lock up. 03:00 - 05:30 2.50 CASE N DPRB RUNPRD Close EDC. Circulate down coil at min rate. Pull out of hole. Close SSSV. Continue to POH to surface. 05:30 -06:00 0.50 CASE N DPRB RUNPRD Flow check. Get off well. Unstab coil. LD BHA tools. 06:00 - 06:10 0.17 CASE N DPRB RUNPRD Call town to discuss situation, and plan forward. Plan to run liner in 2 pieces. Call Baker TT to order out 2nd deployment sleeve and round nose guide shoe for bottom of upper liner. 06:10 - 06:30 0.33 CASE N DPRB RUNPRD PJSM to discuss plan forward with rig crew. Discuss hazards of tripping pipe. Assign jobs, and review mitigations to hazards. 06:30 - 08:00 1.50 CASE N DPRB RUNPRD Stand back 14 stand of 2-3/8" liner. 08:00 - 12:00 4.00 CASE N DPRB RUNPRD Discuss plan with town again. Confirmed we will run liner in 2 sections. Contact Baker TT. They have about 1-1/2 hrs in equipment preparation yet. Wait on Baker. 12:00 - 12:15 0.25 CASE P RUNPRD Baker hand on location. PU deployment sleeve and bottom nose. 12:15 - 12:25 0.17 CASE P RUNPRD PJSM prior to making up Baker eq. 12:25 - 13:00 0.58 CASE P RUNPRD Make up deployment sleeve, BOT GS, BHI MWD tool. Stab injector. Surface check MWD tools. All passed ok. 13:00 - 14:25 1.42 CASE P RUNPRD RIH with BHA #14, shorty liner on coil for first section of 2 needed on L2 lateral. Currently running liner as follows; BOT Deployment SLV 4 jts of 2-3/8" Slotted tubing 13 jts of 2-3/$" Solid tubing 14 jts of 2-3/8' Slotted tubing Unique Indexing guide shoe. Total liner run in hole this run is 1009.8'. 14:25 - 14:45 0.33 CASE P RUNPRD Weight check at window up wt = 165001bs. RIH wt at the window=7000 lbs. OHWOB at window = -2300 lbs. Pumps down. Wt bobble at sidetrack 8273'. Depth String Wt. DHWOB. 8400' 7000 -12001bs. 8700' 6500 501bs. 9000' 5000 18601bs. 14:45 - 15:05 0.33 CASE P RUNPRD Log tie in pass down as MWD GR tool passes RA tag in whipstock. String wt during logging pass =4500 lbs. DHWOB=2120 lbs. Depth =9032'. Make -13' correction. 15:05 -16:30 1.42 CASE P RUNPRD Continue RIH with liner. Depth String Wt. DHWOB 9200 3800 22801bs 9400 2500 17001bs Printed: 1/23J2006 1:06:36 PM ''$P EXPLORATION Page 14 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12!30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/10/2006 15:05 - 16:30 1.42 CASE P RUNPRD 9600 3000 2440 Ibs 9800 -600 24001bs 9900 -3000 24401bs 10000 -6000 24001bs Set down at 10033'. Looked like we hit lockup. Pick up 30'. Kick on pumps to 1.35 bpm. 4220 psi. RIH. 10030 -5600 25001bs 10100 -1000 2490 Ibs Over the hump, going down hill. 10150 -5500-8800 6600 tbs 1.47 bom 4725 psi PU 50K Attepmt to RIH Lock up at 10132. CirculaTE AT 1.4 BPM 10133 -7200 6120 Holding 300 PSI 1.47 bpm No Go 10133 -4400 670.0 Holding 0 PSI 1.47 bpm ~ No Go Decided to release liner. notify anchorage of liner release. 16:30 - 18:20 1.83 CASE N RUNPRD Circulate well to new mud .Flowing well while attempting to work liner to bottom caused light spot inreturns. Anch advise liner need to be reconfigured blanks in sweet spot. 18:20 - 19:30 1.17 CASE N RUNPRD Latch into GS and attempt to pull liner. Pull max No Go. Circulate and adgitate Latched good action indicated in surface coil and on wt indicator. Continuing mud swap. 19:30 - 21:30 2.00 CASE P RUNPRD release from liner. Left TOL at 9123', BOL at 10133' w/ solid pipe 9257-9667'. POOH while finish mud swap following pressure schedule. Close TRSSSV w/ 1000 psi 21:30 - 22:00 0.50 CASE P RUNPRD LD liner running tools and inspect. GS dogs are okay, but sleeve appears sandblasted (not shiny steel as it went in the hole-sandpaper rough). LD BHI MWD assy and reconfigure 22:00 - 23:00 1.00 CASE N RUNPRD MU BBT GS w/ jars, wt bars and accelerators. Add MW D assy w/o DPS and DGS since BHI have only one functional DPS and will be jarring 23:00 -00:00 1.00 CASE N RUNPfiD RIH w/ BHA #15 circ thru GS 0.26/1950 following pressure schedule. Open TRSSSV w/ 1000 psi 1/11/2006 00:00 -00:30 0.50 CASE N RUNPRD Continue RIH w/fishing assy. Wt chk at 8000' 18.3k, did not correct to normal correction of minus 10-14'. RIH thru open hole at 60'/min continue to circ 0.2/1800 holding 600 psi whp 00:30 -00:40 0.17 CASE N RUNPRD 19.5k ®9100' w/ 5k down. Circ 1.1/3600 to clean off GS. RIH to wt loss at 9138' CTD which is a -14' corr. SD pump while stack wt and hold 1100 psi whp. Swap to manual choke since Swaco would not completly shut 00:40 - 02:15 i.58 CASE N RUNPRD PUH to 45k and were latched on first try. Hold 45k at 9124.7' and jars fired after 1:38. Work 30 cycles at 60k. Up jars fired 19 times, down jars 7 times. No movement either direction. Pump down CT occasionally to warm up 02:15 -02:20 0.08 CASE N RUNPRD Release GS from liner 1.25/4000 02:20 -04:30 2.17 CASE N RUNPRD POOH thru open hole, clean. POOH following pressure schedule. Divert returns to flowback tank when they were quite crude. Swap back to gas buster for remainder of trip OOH. Gose TRSSSV w/ 1050 psi. Tag up, chk for flow 04:30 -04:40 0.17 CASE N RUNPRD Safety mtg: LD BHA/cleanout choke 04:40 - 05:15 0.58 CASE N RUNPRD ~D fshing assy Printed: 1/23/2008 1:06:36 PM BP EXPLORATION Page 1'S of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2006 05:15 - 05:45 0.50 CASE N RUNPRD SI swab and master. Circ thru Swaco choke and blow out debris 05:45 - 09:00 3.25 CASE P RUNPRD Clear floor, RU test joint, Load Pipe shed with 1" CSH for possible cleanout run. Work in plan forward options. 09:00 - 16:00 7.00 CASE P RUNPRD Test BOP Test witnessing waived by Lou Grimaldi AOGCC. Test witnessed by Well site supervisor Bob Laule. 16:00 - 20:00 4.00 CASE N DPRB RUNPRD Wait on fabrication of deployment sleeve spear. Remove 1"CSH from pipeshed 20:00 - 20:15 0.25 CASE P RUNPRD Safety mtg re: PU/LD liner assy w/ BHA 20:15 - 22:30 2.25 CASE P RUNPRD MU WFT GS Anti-tum Spear onto 4 ea slotted 2-3/8" 4.43# L-80 STL liner doubles from derrick. Add remainder of stood back doubles. POOH LD 18 singles. Add WFT aluminum WS assy and MWD assy 22:30 - 00:00 1.50 CASE P RUNPRD RIH w/ section 2 of L2 liner assy. Circ thru open EDC 0.26/1700 following pressure schedule. Open TRSSSV w/ 1100 psi 1/12/2006 00:00 - 00:30 0.50 CASE P RUNPRD Park at 8000', close EDC. Did not correct or tie-in. 19.2k, 6.Ok. RIH thru open hole clean to 9100', 22.2k, 6.Ok. RIH and tag TOL at 9136' CTD. PUH w/ 2k overpull. Plant spear in GS at 70'/min. Stack wl, start pump. Release from liner w/ GS 1.25/4000 20.Ok Left section 2 of L2 liner 8857-9123'. Spear has a 0.75" hole for production to flow thru 00:30 - 02:20 1.83 CASE P RUNPRD POOH following pressure schedule. Had crude and gas in retums, but less than prior trips. Close TRSSSV w/ 1050 psi 02:20 - 02:50 0.50 CASE P RUNPRD LD liner running tools 02:50 - 03:50 1.00 STKOH P PRODS MU sidetrack assy L3 03:50 - 05:20 1.50 STKOH P PRODS RIH w/ BHA #17 (1.5 deg motor, new STR324 bit) circ thru r EDC 0.2/1600 and following pressure schedule. Open 11Y_ TRSSSV w/ 1100 psi 0520 - 05:35 0.25 STKOH P PRODS Log tie-in down from 8050', Corr -15.5'. 05:35 -06:20 0.75 STKOH P PRODS Wiper to top of billet. Tag top of billet at 8859.3. 06:20 -09:00 2.67 STKOH P PRODS PU and started milling procedure at 8859'. Mill off billet with 1.4 bpm ~ 3845 psi,900 psi well head. EDC 14.1 annular pressure 4420 psi. TF 708 .6K WOB. Drill rathole to 8880'. 1.45/1.42 bpm ~ 3800 psi , ROP 30. Dress window TF 458, 908 & 1508 09:00 - 11:00 2.00 STKOH P PRODS POH following pressure schedule. 11:00 - 11:15 0.25 STKOH P PRODS Flow Check to confirm SSSV integrity. OK. 11:15 - 12:15 1.00 STKOH P PRODS Swap bit and dial down motor bend. 12:15 - 13:55 1.67 STKOH P PRODS RIH following pressure schedule. 13:55 - 14:10 0.25 STKOH P PRODS Log tie-in. Correction -13.5'. 14:10 - 17:10 3.00 STKOH P PRODS Directionally 1.57 / 1.56 bpm ~ 4200 psi.FS = 3900 psi. holding 560 psi well head. ECD13.8 ppg, DH annular pressure 4320psi. 17:10 - 18:10 1.00 DRILL P PRODS Wiper to window PVT 404 18:10 - 19:40 1.50 DRILL P PRODS Drill from 9040' 1.54/1.6/4050/600/908 w/ 100-300 psi dill, 1-2k wob w! 13.92 ECD (4342 psi DHP) at 94 deg. Drill to 9106' while gaining 2 bbls w/ retums cut to 9.25 ppg. Swap to left at 9100' 19:40 - 20:10 0.50 DRILL N SFAL PRODS Wiper while WO BHI to reconcile surveys-a software thing 20:10 - 21:10 1.00 DRILL P PRODS Drill from 9106' 1.55/1.10/4220/620/5-90L w/ 100-250 psi dill, 1-2k wob w/ 14.3 ECD and losing 0.5 bpm w/ higher ECD due Printed: 1/23/2006 1:08:36 PM BP EXPLORATION' Page 16 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-146 Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CAL{STA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date 'From - To 'Hours 'Task Code NPT Phase Description ofiOperations 1/12/2006 20:10 - 21:10 1.00 DRILL P PRODS to return density increasing to 9.5 ppg. Lower whp to 575 psi. Continue the balancing act of drilling w/ crude cut returns and minimizing loss rate. Drill to 9160' 21:10 - 21:55 0.75 DRILL P PRODS Slow wiper to window while geo's determine where we are 21:55 - 22:10 0.25 DRILL P PRODS Log tie-in down from 8040', corr +3.5' 22:10 - 22:55 0.75 DRILL P PRODS Slow wiper to TD tagged at 9162' was clean PVT 335 22:55 -00:00 1.08 DRILL P PRODS Drill from 9162' 1.55/1.6/4030/575/90L w/ 50-200 psi dill, 0.75-1.5k wob w/ 14.10 ECD holding 93 deg at 6012' ND and in assumed A3 that has high GR 1/13/2006 00:00 - 00:45 0.75 GRILL P PRODS Drill from 9230-9275' at 93 deg 00:45 - 02:15 1.50 DRILL P PRODS Wiper to window was clean both directions 02:15 -04:35 2.33 DRILL P PRODS Drill from 9275' 1.56/1.56/4050/600/90L w/ 100-200 psi dill, 1-2k wob w/ 14.10 ECD (4379 psi DHP) at 93 deg. Point TF down at 9300' to begin 87 deg drop at 6006' TVD. Drill to 9423' and swab on pump #2 washed out PVT 295 04:35 - 05:30 0.92 DRILL P I PRODS Wiper to window was clean 05:30 - 05:45 0.25 DRILL P PRODS Log tie-in down from 8040', corr +2.5' 05:45 -06:00 0.25 DRILL P PRODS Wiper thru window. 06:00 - 08:30 2.50 DRILL N RREP PRODS While repairing pump#2. Noticed Pump #1 leaking from liner. PU into pipe while comlpetion repairs on pump #2. upon completion#1 leaking from liner repair same. 08:30 - 09:05 0.58 DRILL P PRODS RIH 09:05 - 12:17 3.20 DRILL P PRODS Directionally drilling 1.56 ~ 4200 psi.3900 psi =FS, WOB 2.OK, EDC 14.0, Annular pressure 4390, Drill to 9575'. 12:17 - 13:55 1.63 DRILL P PRODS Wiper to window. Clean trip. 13:55 - 17:30 3.58 DRILL P PRODS Directionally drilling 1.56/1.45 bpm ~ 4000 psi., WOB 1.7K, . EDC 14.10, Annular pressure 4390, TF 90R,ROP 45, Annular pressure 4400 psi. 17:30 - 19:10 1.67 DRILL P PRODS Wiper to window was clean both directions PVT 253 19:10 - 21:00 1.83 DRILL P PRODS Drill from 9725' 1.52/1.5/4120/620/908 w/ 100-200 psi dill, 1-2k wob w/ 14.05 ECD (4376 psi) at 87 deg from 6023' TVD. Swap to left at 9780' and bring TF up to hold 90 deg. Drill to 9835' and stacking and can't make hole 21:00 - 21:30 0.50 DRILL P PRODS Wipers to remove DLS from TF change 21:30 - 21:40 0.17 DRILL P PRODS Break out into faster drilling at 9835' and drill to 9837' and geo not sure where we are PVT 240 21:40 - 22:50 1.17 DRILL N PRODS Wiper up the hole at 10'/min while WOO. Pulled tite at 9765' w/ no MW. Attempt to go down and not. Work up and down for 5 min w/ no movement. Incr WHP to 900 psi and red rate. Pull free w/ Sk over. Continue wiper at 30'/min while geo's come up with a plan to drill footage in small increments and then reevaluate. Finish wiper to window 22:50 - 23:10 0.33 DRILL N PRODS Log tie-in down from 8040', add 6.0' 23:10 -00:00 0.83 DRILL N PRODS Wiper back to TD 1/14/2006 00:00 -00:15 0.25 DRILL P PRODS Finish wiper to TD tagged at 9840' PVT 218 00:15 -00:35 0.33 DRILL P PR003 Drill from 9840' 1.5/1.5/4000/650/90L w/ 100 psi dill, 1 k wob at 14.05 ECD. Took off drilling at 120'/hr. Drilled to 9870' while penetration rate slowed. Need to geodecide 00:35 - 01:25 0.83 DRILL P PRODS 200' wipers while woo from geos on TF setting to find 1' TVD sand. Set down on first wiper at 9770', had sli wt loss on 4th down pass 01:25 - 02:00 0.58 DRILL P PRODS Drill from 9870' 1.52/1.52/4030/700/105L at 89 deg to try and follow dip. Drill to 9920' Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 17 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task.. Code NPT phase Description of Operations 1/14/2006 02:00 - 03:15 1.25 DRILL P PRODS Wlper toward window while geodecide where to head next 03:15 - 03:30 0.25 DRILL P PRODS Log tie-in down from 8040', add 2.0' 03:30 -04:40 1.17 DRILL P PRODS Wiper back to TD was clean 04:40 - 06:50 2.17 DRILL P PRODS Drill from 9920' 1.50/1.50/4030/650l45L w/ 100-200 psi dill, 1.5-2.Ok wob w/ 14.11 ECD at 6033' TVD. Will build angle from 88 to 91 deg until intersecting the good sand, then follow it using known dip 06:50 - 09:20 2.50 DRILL P PRODS Wiper to window. 09:20 - 12:15 2.92 DRILL P PRODS Drill from 10060' 1.39/1.23/4127/610/60L w/ 100-200 psi dill, 2.0-2.5k wob w/ 14.25 ECD, Drilled to 10103. Geo called TD. 12:15 - 13:30 1.25 DRILL P PRODS Wiper to window. 13:30 - 13:45 0.25 DRILL P PRODS Log tie-in correction +4.5'. 13:45 - 15:00 1.25 DRILL P PRODS Wiper to TD. Tag TD at 10106' while spotting 50 bbp pill with 3#/bbl beads. 15:00 - 17:30 2.50 DRILL P PRODS POH following pressure schedule. 17:30 - 18:15 0.75 DRILL P PRODS Chk for flow. LD drilling BHA 18:15 - 19:00 0.75 CASE P RUNPRD Crew change. RU to run liner 19:00 - 19:15 0.25 CASE P RUNPRD Safety mtg re: MU liner 19:15 - 20:30 1.25 CASE P RUNPRD MU BTT tapered shoe w/ 28 jts 2-3/8" 4.43# L-80 STL liner. Install WFT liner top aluminum deployment sub w/ GS. MU BHI MWD 20:30 - 21:40 1.17 CASE P RUNPRD RIH w/ liner assy on CT circ thru EDC at 0.5/2250 following pressure schedule. Open TRSSSV w/ 1200 psi 21:40 - 22:20 0.67 CASE P RUNPRD 8000' 16.4k, 7.4k R1H thru window, clean. RIH thru open hole at 70'/min to 8800'. Close EDC. Did not tie-in or correct. RIH w/ liner 70'/min w/o circ and choke SI w/ 1025 psi w/ 4390 psi dhp. RIH w/ 5.6k to wt loss at 10122' CTD. PUH 2O.7k, clean for 30'. Set liner back at TD and stack 4k 22:20 - 22:25 0.08 CASE P RUNPRD Start pump 1.05/4300 w/ 650 psi whp and release from liner at 16.7k Left L3 liner w/ top of billet at 9179', BOL at 10106' 22:25 - 22:45 0.33 CASE P RUNPRD POOH thru open hole at 0.6/3000 circ thru WFT GS holding 900 psi whp=14.0 ECD 22:45 -00:00 i.25 CASE P RUNPRD POOH circ thru EDC 1.3513400 following pressure schedule. Got 50 bbls crude cut returns w/ gas. Dump 20 bbls to cuttings box while routing returns thru gas buster. Returns cleaned up by 3000' 1/15/2006 00:00 - 00:15 0.25 CASE P RUNPRD Continue POOH w/liner setting tool while circ thru EDC ~ 1.35 bpm. Pull thru TRSSSV w/5k overpull at 2362' which would be at the top of the BHA. Close TRSSSV while fin POOH. Check for flow and SV was not shut (and is probably full open since we're getting 5+ bpm back w/choke open). Cycle twice w/o success 00:15 - 01:50 1.58 CASE N RUNPRD RBIH and circ 1.6/4000 thru EDC over TRSSSV area and attempt to wash clean. No success in getting valve to close. Repeat washing operation at slower speed 1.73J4200 and spend 30 minutes this time. No success at getting valve to dose-flows 6.2 bpm w/ choke open. Noted some beads in returns 01:50 - 02:25 0.58 CASE N RUNPRD Finish POOH 02:25 - 02:35 0.17 CASE N RUNPRD Tag up w/ 1240 psi whp. PVT 215 Bullhead 0.25/2300/1410 to keep CT wamt Safety mtg re: pressure undeploy Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 18 of 23 Operations. Summary Report Legal Well Name: 3H-146 Common Wefl Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28!2005 End: 1/22!2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ;Task Code NPT Phase. Description of Operations 1/15/2006 02:35 -04:30 1.92 CASE N RUNPRD Remove SSSV pressure sensor and connect to back of BOP's. SIP is 1265 psi. Undeploy BHA. SI master and swab w/ 1210 psi whp. LD liner running tool and MWD assy 04:30 -04:45 0.25 WHSUR P WHDTRE Safety mtg re: slack management 04:45 -06:30 1.75 WHSUR P WHDTRE Cut off CTC (no obvious scars). Reverse slack back. Wire hung up at free end. No wire movement.Reverse circulate second attempt. 06:30 - 07:20 0.83 WHSUR P WHDTRE PJSM. RU cutter and cut off 200' 07:20 - 09:15 1.92 WHSUR P WHDTRE Rehead coil. Pull and Pressure test. 09:15 - 11:00 1.75 WHSUR N WHDTRE Wait on wireline.Continue with pod replacement in #1 pump. 11:00 - 13:00 2.00 WHSUR N WHDTRE RU Wireline 13:00 - 13:15 0.25 WHSUR N WHDTRE PJSM with wireliners. 13:15 - 14:15 1.00 WHSUR WHDTRE PT lubricator to 2000psi..Bleed to 1 i75. Open up to well bore. RIH to SSSV. 14:15 - 15:00 0.75 WHSUR N WHDTRE Run brush numerous passes thru SSSV/ Pressure cycle valve t periodically. Run thru SSSV to see if flapper grabs brush. No Go. Valve stilt wide open. 15:00 - 15:15 0.25 WHSUR N WHDTRE POH. Close master. Bleed off 1250 psi. 15:15 - 15:35 0.33 WHSUR N WHDTRE LD brush. PU friction tool. Pressure test to 2000 psi. Bleed to 1175 psi. 15:35 - 16:00 0.42 WHSUR N WHDTRE RIH with friction tool. 16:00 - 16:15 0.25 WHSUR N WHDTRE Work and jar on SSSV sleeve. Sheared off 16:15 - 16:25 0.17 WHSUR N WHDTRE POH. Blead off well head pressiure to 750 psi. Came right back to 1117. 16:25 - 18:00 1.58 WHSUR N WHDTRE Close master. Bleed off pressure. LD and repin friction tool w/ 4 brass and sheared off 18:()0 - 18:15 0.25 WHSUR N WHDTRE Safety mtg re: Fresh Nordic crew, crew change/SL ops 18:15 -22:30 4.25 WHSUR N WHDTRE RIH w/friction tool pinned w/ steel and work to shift sleeve until shearing tool. Bleed off well pressure of 1180 psi to see if SV will close. Repin tools and rerun. Repeat 2 more times w/o success. Left one 114" OD x 3/8° brass shear stock in hole 22:45 -23:30 0.75 WHSUR N WHDTRE RDMO WL unit. Men are limited out on daily hours, unit has scheduled maint tomorrow, KRU has no 'Hite' shift slickliners ' Will sidetrack off the billet while town decides the future plan for the well and while slickline gathers more information on the TRSSSV (the spring in particular). Will be forced to use KW mud to run future liner(s) if the SV remains inoperable 23:30 - 23:45 0.25 DRILL P PROD4 Safety mtg re: pressure deployment of BHA 23:45 -00:00 0.25 DRILL P PROD4 MU drilling BHA L~ 1/16/2006 00:00 - 02:00 2.00 STKOH P PROD4 Continue pressure deployment of BHA #20 w/ 1120 psi final whp 02:00 -03:40 1.67 STKOH P PROD4 RIH w/ BHA #20 (1.5 deg motor, used 2.73' STR324 bit) while circ thru EDC 1.78/4200 pumping slack forward and following pressure schedule. Swap TRSSSV pressure sensor back to panel and pressure up TRSSSV (to open, just in case) 03:40 -04:05 0.42 STKOH P PROD4 Close EDC. Log tie-in down from 8040', Corr -20' 04:05 - 05:00 0.92 STKOH P PROD4 Finish repairs to pump #1. Fill w/fluid and PT to 4500 psi. Wiper to billet and lost wt at 8860' (billet#1 sdtrk depth). Orient around to get stops closer to drilled TF and RIH, clean to tag at 9175' at min rate PVT 140 05:00 - 08:30 3.50 STKOH P PROD4 Begin sidetrack ops of L4 from L3 billet top at 9175' at 908 w/ 1.5/1.45/4170/560/908 KO billet and drill to 9200'. 08:30 - 11:00 2.50 STKOH P PROD4 POH. Following the pumping schedule. to SSSV. Open EDC Printed: 1/23/2006 1:0636 PM BP EXPLORATION Operations Summary Reporf Page 19 of 23 Legal Well Name: 3H-146 Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/16/2006 08:30 - 11:00 2.50 STKOH P PROD4 and wash across SSSV 1.7 BPM. Continue to POH to surface. Attempt to bleed off. Weil pressured back up/ No Luck with the wash job. 11:00 - 12:00 1.00 STKOH P PROD4 PJSM for pressure undeploy. 12:00 - 12:45 0.75 STKOH P PROD4 LD milling BHA and PU Nozzel. Stab onto well. PT lubricator. Open to well. 12:45 - 15:15 2.50 STKOH P PROD4 RIH to 2279 to 2360. Circulate 2.0 bpm X4300 psi wash at 4 fpm. Bauble at 2331. Wash from 2360 to 2300. Made second trip across valve and back to 2300'.Nothing at 2331'. Pressure cycle SSSV control line to 4500 psi 6 cycles. Bleed off wellhead to 300 psi. Immediatele built back to 1100psi. Wash past SSSV one additional cycle. Cycle SSSV line pressure 4 additional time NO Luck. Bleed off well head .Pressure builds up immediately SSSV not functioning. POH. 15:15 - 16:00 0.75 STKOH P PROD4 POH per pumping schedule. 16:00 - 17:30 1.50 STKOH P PROD4 LD nozzel. PU Pressure deploy BHA. 17:30 - 18:50 1.33 DRILL P PROD4 RIH w/ BHA #21 circ thru bit following pressure schedule 18:50 - 19:10 0.33 DRILL P PROD4 Log tie-in down from 8040', corr -18' ' 19:10 - 19:50 0.67 DRILL P PROD4 PVT 165 Wiper to TD was clean. Tag at 9201 19:50 - 20:05 0.25 DRILL P PROD4 Drill from 9201' 1.45/1.4/4230/650/1208 w/ 100-150 psi dill, 1-2k wob w/ 14.25 ECD at 93 deg. Drill to 9210' (or is it 9205'). BHI and SWS depths are different and can't figure out whose is in error 20:05 - 20:35 0.50 DRILL N PROD4 Wiper to tie-in again. Found a spot in OH that will work at 8700' 20:35 - 21:05 0.50 DRILL N PROD4 Log tie-in down from 8650', corr -2' 21:05 - 21:25 0.33 DRILL N PROD4 Wiper back to TD and tagged at 9208' 21:25 - 23:10 1.75 DRILL P PROD4 Resume drilling from 9208'1.45/1.35/4230/600/1208 w/ 100-200 psi dill, 2k wob w/ 14.4 ECD at 92 deg. Got fair crude and gas back from bottoms up. Swap to left side at 9265'. Drill to 9328' while swap to fresh mud 23:10 - 00:00 0.83 DRILL P PROD4 Wiper to window while geodecide where to go next was clean. Finish mud swap 1/17/2006 00:00 - 00:50 0.83 DRILL P PROD4 Wiper back to TD while checking out pump #1 and waiting for guidance from geo's was clean 00:50 - 02:40 1.83 DRILL P PROD4 Drill from 9328' 1.42/1.32/4180/550/85L w/ 50-150 psi dill, 2k wob w/ 14.27 ECD at 88 deg. Come to a haft at 9425' PVT 270 02:40 - 03:50 1.17 DRILL P PROD4 Drill ahead slowly on what acts like ankerite. A few mini wipers 1.46/1.40/4200/600/85L w/ 14.19 ECD is balance point for full returns w/ no crude or gas in returns-still looks like new mud! 03:50 -04:55 1.08 DRILL P PROD4 Break out of hard stuff at 9431' and drilling firm stuff at 30'/hr 04;55 - 05:40 0.75 DRILL P PROD4 Wiper to window was clean 05:40 - 05:55 0.25 DRILL P PROD4 Tie-in log correction +4'/ 05:55 -06:45 0.83 DRILL P PROD4 Wiper back to TD 06:45 - 12:00 5.25 DRILL P PROD4 Directionally drill 1.49 bpm X3900 psi FS = 3800psi.407 psi differentail, WOB 1K, ECD 14.1, TF 310. 12:00 - 13:50 1.83 DRILL P PROD4 Wiper to window was clean both directions 13:50 - 13:55 0.08 DRILL P PROD4 Drill from 9625' 1.51/1.45/4000/600/1008 w/ 100-200 psi dill, 1-2k wob w/ 14.20 ECD at 96 deg to 9626' (6008' TVD) and need to geodecide again 13:55 - 16:35 2.67 DRILL P PROD4 Slow wiper at reduced rate while WO geo instructions 1.1/3180 2'/min to 9300' Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 20 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Spud Date: 12!30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date ` .From - To Hours Task Code NPT Phase Description of Operations 1/17/2006 16:35 - 16:55 0.33 DRILL P PROD4 Wiper back to TD 16:55 - 17:15 0.33 DRILL P PROD4 Received new targets from town. Circ while plan how to get there 17:15 - 20:35 3.33 DRILL P PROD4 Drill from 9626' 1.5/1.42/4030/650/1508 20:35 - 21:35 1.00 DRILL P PROD4 Wiper back to window. No problem areas. 21:35 - 21:45 0.17 DRILL P PROD4 Log tie-in to RA tag. +2.5' 21:45 - 22:45 1.00 DRILL P PROD4 Wiper trip to bottom. Clean to bottom. 22:45 - 00:00 1.25 DRILL P PROD4 WOO from town geos. Plan forward is to drop 75' tvd thru all of A sands. No liner planned for this lateral. 1/1812006 00:00 - 00:30 0.50 DRILL P PROD4 RIH to bottom. 00:30 -04:45 4.25 DRILL P PROD4 Directional! drill ahead f/ 9775' turn left to avoid interference with L3 lateral and then diving down +/- 75' tvd. 1.45/3800 250MW 14.17ECD w/ 570WHP 1-2k wob 40'/hr Losses 6-8bbls/hr 04:45 - 05:45 1.00 DRILL P F PROD4 Wiper to window. No problems 05:45 - 06:00 0.25 DRILL P PROD4 Tie-in to RA tag. +1' correction 06:00 - 07:00 1.00 DRILL P PROD4 Wiper back to bottom, clean 07:00 - 09:30 2.50 DRILL P PROD4 Drill from 9929' 1.5/1.43/3980/600/175L w/ 200 psi dill, 2k wob w/ 14.18 ECD at 6040' TVD at 70 deg and continuing the dive. Drill to 10070' (6110' TVD) at 50 deg 09:30 - 10:40 1.17 DRILL P PROD4 Wiper to window, clean 10:40 - 10:50 0.17 DRILL P PROD4 Log tie-in down from 8040', corr +1.5' 10:50 - 12:00 1.17 DRILL P PROD4 Wiper back to TD tagged at 10070' (official TD of L4) was clean 12:00 - 13:00 1.00 DRILL P PROD4 Wiper back to window leaving fresh 9.9# mud w/ max lubs in the open hole 13:00 - 15:00 2.00 DRILL P PROD4 Open EDC at 7950'. POOH 1.75/3900 following pressure schedule. Wash TRSSSV for 15 min. Fin POOH. At 200', bleed off whp while dump SSSV press and no closure of valve. Well pressured back up to 1220 psi. Close EDC. Fin POOH. PJSM re: pressure undeploy 15:00 - 16:00 1.00 DRILL N PROD4 Pressure undeploy w/ final 1240 psi. LD drilling BHA. MI HES 16:00 - 16:15 0.25 WHSUR N WHDTRE Safety mtg re: WL ops 16:15 - 20:20 4.08 DHEQP N WHDTRE RU HES WL toots w/ 0.108 wire. PT lubricator to 2000 psi. RIH and set slip-stop catcher below TRSSSV. Unable to shear off the catcher which shears in the down travel. Heavy mud and pressures adding to the problem. No Howoc lubricator was set-up hence no wt bars added to assist in shearing off. Advised Howco that more rig lubricator could be added if needed for wt bar additon. Adding another 5' of our lubricator. Howco setting up shear off tool pinned lighter. 20:20 - 21:50 1.50 DHEQP N WHDTRE Add 5' section of lubricator. PU tools. PT lubricator to 2k. RIH and set slip-stop catcher 1st full jt below SSSV. 21:50 -00:00 2.17 DHEQP N WHDTRE PU Z5 tool. RIH. Engage SSSV sleeve. Spang up several times. Pull to 1400#. Apply hyd pressure to SSSV. No wt Inc seen. Release wireline pull wt. No pressure decrease seen. Not good signs. Spang several times again and sheared pins. POH redress tool with heavier pins. Repeat as before with pull/pressure sequences until sheared pins again. No movement seen. Could continue with this but: if we do succeed in moving the flowtube in order for the flapper to close there's a good chance we'll do enough damage that opening the valve again and keeping it open will be minimal. This would prevent Printed: 1/23/2008 1:06:36 PM BP EXPLORATION Page 21 of 23' Operations Summary Report Legal Well Name: 3H-146 Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28!2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Mours' Task Code NPT Phase Description of Operations. 1/18!2006 21:50 - 00:00 2.17 DHEQP N WHDTRE safe passage beyond the valve with tools with the anticipation of getting the tools back out without hanging up on the flapper.(ordered first load of 14.6ppg KWM) Confirmed with town that next liner will be all slotted. 1/19/2006 00:00 - 01:30 1.50 DHEQP N WHDTRE RIH retrieve slip-stop catcher. RD Howco wireline. Try 1 time to shut SSSV using rig controls without luck. 01:30 - 02:00 0.50 BOPSU P PROD4 Perform weekly BOP function test. All good. 02:00 - 16:00 14.00 CASE N RUNPRD WO KWM. Prep liner. 16:00 - 16:30 0.50 CASE N RUNPRD RU nozzle assy. Stab injector onto lub 16:30 - 22:00 5.50 CASE N RUNPRD Circ over closed swab while wo KW mud. Just recieved word that MI inadventently added 50 bbls of water to almost completed 190 bbls of 14.6ppg KWM. Delay of another 4hrs. 22:00 - 22:15 0.25 CASE N RUNPRD PJSM. Discuss plans to RIH to 8300' and kill well with the 210bb1s of 14.6ppg mud on location. 22:15 - 00:00 1.75 CASE P RUNPRD Open MVlSV i200psi on well. R1H following pressure schedule. Up wt at window 15.6k dw wt 6.2k RIH to 8300'. 1/20/2006 00:00 - 00:25 0.42 CASE P RUNPRD CBU 1.54132340 holding 560psi on wellhead pit vol 224 to start 00:25 - 03:00 2.58 CASE P RUNPRD Start pumping 14.6ppg KWM. Pumped 2 bbls out EOP then TOH laying in KWM. Lost approximately 50 bbls KWM to formation at tag-up. Shutdown pump. 03:00 -04:00 1.00 CASE P RUNPRD Monitor well. Filled hole after 20min took 2.7bbls Wait another 20min took 2.9bbls to fill. No gas. Hefd PJSM for running liner. 04:00 - 07:00 3.00 CASE P RUNPRD Setback injector and pump remaining 50bbls of KWM onto rig. Circ injector. RU to run liner. Start PU 2-3/8" liner. Fin run 40 jts slotted and 8 jts solid 2-3/8" 4.43# L-80 STL R2 liner w/ tapered guide shoe. Install 8TT deployment sleeve w/ GS. Install BHI MWD. Fill hole and has taken progressively less each fiN and now losing +/-2 bph 07:00 - 08:00 1.00 CASE P RUNPRD Displace 14.6# mud in CT w/ 9.9# mud 08:00 - 08:25 0.42 CASE P RUNPRD Stab on w/injector PVT 349 08:25 - 10:00 1.58 CASE P RUNPRD Open EDC. RIH w/ BHA #24 (liner L4) w/o pump and had no retums by 1000'. Begin Circ w/ 9.9# mud thru EDC 0.5/1250 while RIH slow. Incr rate to 1.0 bpm and start getting 1/2 retums initially, then full retums after 5 bbls pumped. Continue RIH at normal running speed circ thru EDC at 0.5/1270 losing avg 0.1-0.2 bpm over normal returns, and slowing running speed at times to minimize loss rate. Take mixed fluids to pit #1 10:00 - 10:55 0.92 CASE P RUNPRD Park at 5278' and CBU to 1/1 retums. Swap to pumping mixed fluids at avg 11.4 ppg since have 100 bbls of mixed retums and getting avg 10.5 ppg back at 0.6/2000 at 90'lmin. Continue RIH 10:55 - 11:20 0.42 CASE P RUNPRD 8000' 19.Ok, 6.Sk RIH thru window, clean while circ thru EDC 0.6/2200. RIH thru open hole 65'/min, w/o a bobble to 9450' CTD. PVT 349 Lost 30 bbls while RIH .. . 11:20 - 11:45 0.42 CASE P RUNPRD Log tie-in down 0.57/0.8/2300 at 13.97 ECD (w/ P sub at 7900' MD) and well was starting to flow (gained 2 bbls). Started stacking wt so abort log. Stop pump while close EDC and SI at choke w/ 250 psi. PUH 24k for 30' and get a run and get to 9546' and stack max wt. Need to get to 9560' w/ normal correction. Get to 9555', then lost ground to 9547' w! two set Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Operations Summary Report Legal Well Name: 3H-146 Page 22 of 23 Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Start: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours ~ Task ~ Code ~ NPT I Phase I Description of Operations 1/20/2006 11:20 - 11:45 0.42 CASE P RUNPRD downs and was solid (acts Tike GS hanging up on bottom of window). PUH slow to 9450' and Circ to warm up CT at 0.25 bpm 11:45 - 12:20 0.58 CASE P RUNPRD Circ thru GS 0.25 bpm maintaining 500 psi WHP. RIH to 9530' and set down, then get to 9520-9525' on several tries, then start losing ground back to 9510'. Tried using max WHP of 1200 psi and also with choke wide open and well flowing. Now PU's are also starting to get sticky. Keep after it and once more get to 9553' w/ max stacked wt and call it good-TOL est to be at 8029', but will log to be sure. Incr pump to 1.25/4200 and release from liner at 18k 12:20 - 13:15 0.92 CASE P RUNPRD PUH to 7900' and log tie-in down, Corr -19'. This would put TOL at 8025.8'. Circ at 1.0 bpm w/ 300 psi whp. RIH and had wt loss at 8023.1'. Stack max wt and appeared to move a few feet. RBIH and first wt loss at 8025.1' and stacked max to + 8029.9'. RBIH faster and first wt loss at 8026'. Beat on it w/ several tries and check and find that 8026' is as far as it will go. This puts the TOL in the middle of the window (8025.0'-8027.8') and makes the WS not recoverable. Discuss and will try moving the liner downhole w/ the agitator Left TOL at 8025.8', BOL at 9532' 13:15 - 14:45 1.50 CASE N RUNPRD Open EDC and POOH at 1.1 bpm w/mixed fluids of 11.0 ppg avg density following pressure schedule. Tag up w/ 1000 psi Safety mtg re: pressure undeploy 14:45 - 17:05 2.33 CASE N RUNPRD Pressure undeploy w/ 970 psi final whp. LD liner running tools. Check GS and had no marks. MU GS on agitator and MWD assy. Pressure deploy w/ 920 psi 17:05 - 18:30 1.42 CASE N RUNPRD RIH w/ BHA #25 (GS and agitator) following pressure schedule 18:30 - 19:00 0.50 CASE N RUNPRD Log tie-in -20' correction. 19:00 - 20:00 1.00 CASE N RUNPRD tag TOL at 8028'. Attempting to work liner down with Agitator. 1.1 bpm/.87/3800/250whp latched into liner pp= 4160psi stack out CT wt +/- 9k. PU off liner check wt 18k No visabte movement after 20 min increase whp to 500psi. SD pump ' pick-up to stretch liner, bring on pump and RIH to max stackout. Try this 3 times no movement. 20:00 - 20:30 0.50 CASE N RUNPRD SD pump PU on liner 45k. Doesn't want to move. But work Agitator with this added stretch several times. Not seeing any movement. Setdown and push for another 15min. Unlatch from liner. Coil life is 30% at these depths. Further working pipe with these pressures and wts are taking a fast toll on coil life. 20:30 - 20:50 0.33 CASE N RUNPRD Log tie-in. +4' 20:50 - 21:00 0.17 CASE N RUNPRD RIH tagged TOL same place 8028' 21:00 - 23:45 2.75 CASE N RUNPRD Discuss options with town. SWS crews not available until 0600hrs. Open EDC and swap back to 9.8ppg mud. 1.55!1.56 Close EDC. Go down and tag TOL try 1 last time with Agitator to move liner. No go 23:45 -00:00 0.25 CASE N RUNPRD TOH 1/21/2006 00:00 - 01:30 1.50 CASE N RUNPRD Finish TOH. 01:30 - 01:45 0.25 CASE N RUNPRD PJSM review Pressure Undeployment procedures. 01:45 - 03:00 1.25 CASE N RUNPRD Close 2-3/8" combi's. Push/Pull test. Bleed down lubricator. Unstab setback injector and circulate. Pressure undeploy BHA. 03:00 - 06:00 3.00 CASE N RUNPRD WO SWS. Grease injector. Check R1 check valves -good. Printed: 1/23/2006 1:06:38 PM BP EXPLORATION Page 23 of 23 Operations' Summary Report. Legal Well Name: 3H-14B Common Well Name: 3H-14B Spud Date: 12/30/2005 Event Name: DRILL+COMPLETE Stark: 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task. Code NPT Phase Description of Operations 1/21/2006 03:00 - 06:00 3.00 CASE N RUNPRD Surface test BHI tools. 06:00 - 07:30 1.50 CASE N RUNPRD SWS a-line unit arrive on location. Ambient is -42F w/ 10-16 mph wind, WC -70F Inclement Weather Operating Procedures in effect for both Kuparuk and GPB operating areas. Initial 7HA yielded excessive outside work in getting BOP's to floor (have to tear down in pieces since can't use boom truck to lift). Will swap out units for one that has a bigger inside workspace and bring out BOP's from shop already broke down). SWS head back to KIC 07:30 - 11:15 3.75 CASE N RUNPRD WO SWS 11:15 - 11:45 0.50 CASE N RUNPRD SWS arrive back on location w/ one unit and two crews. Ambient -43F w/ 10-16 mph wind. Safety mtg and THA 11:45 - 12:15 0.50 CASE N RUNPRD Use loader to unload basket w/ BOP assy. Piecemeal BOP's to floor using loader and tugger up beaver slide. Start on second piece and receive word to suspend operations on well. Wells Group will be more efficient to finish remaining operations of chemical cut, fish GS, and fish WS assy when weather improves 12:15 - 13:00 0.75 CASE N RUNPRD Safety mtg. Remove BOP's off rig and put BOP's back on stand and load onto picker. MO SWS 13:00 - 16:00 3.00 WHSUR N POST WO vac trucks to displ and FP well. Start cleaning pits 16:00 - 16:35 0.58 WHSUR P POST MU nozzle assy 16:35 - 18:10 1.58 WHSUR P POST RIH w/ nozzle assy circ SW 0.5/2000 following pressure schedule and displacing 9.8# mud 18:10 - 19:50 1.67 WHSUR P POST Housing on coil reel's drillers side drive motor cracked. Still able to move coil. Resume TIH to 8000' displacing 9.8ppg flopro with seawater. 19:50 - 22:00 2.17 WHSUR P POST TOH to 2000'. Pump remaining SW from truck. Switch to meth 22:00 - 22:30 0.50 WHSUR P POST Freeze protect well with 18 bbl of methanol from 2000' to surface. SIP 1650 22:30 -00:00 1.50 RIGD P POST Slowdown reel with N2 to Tiger Tank. 1/22/2006 00:00 - 00:30 0.50 RIGD P POST Close MV/SV. Unstab injector. Cut-off BHi's UDC. Prep end of coil for pull back to reel. 00:30 - 01:00 0.50 RIGD P POST PJSM: review plan forward for securing coil to reel and removing reel from rig. SIMOPS changing out ram bodies for next well. Vac trucks removing final fluids from rig and TT. 01:00 -04:00 3.00 RIGD P POST Pull back coil and secure to reel. Remove inner reel hardlines. Drop reel. Change out rams in tower 3 TOT cavities for next well. Clean pits. 04:00 -06:00 2.00 RIGD P POST Continue changing TOT rams. ND BOPE, NU tree cap and PT to 4000 psi Phz 1 Kuparuk, MPU, GPB RREL ~ 0600 hrs Further entries for day will be found under 1Q-04 RWO Printed: 1/23/2006 1:06:36 PM • Well: 3H-14B Multilaterals Accept:. 12/29/05 Field: Kuparuk River Unit Spud: 12/31/05 API: 50-029-20092 ~ Release: 01 /22/06 Permit: 205-205 / 205-206 / 206-008 Rig: Nordic #2 POST RIG WORK 01/26/06 TAGGED TOP OF LINER W/ 20' OF 1 3/4 O.D. DRIFT Cam? 8026' RKB. WORKED TOOLS TO HOP INTO LINER AND DRIFTED DOWN TO 8063' RKB. PERFORMED SBHPS W/DUEL PANEX GAUGES @ 8026' RKB (4183 PSI C~ 143 DEG) AND 7926' RKB (4171 PSI C~ 149 DEG). 01/27/06 DISPLACED TBG. W/ 95 BBLS OF DIESEL. SET 3 1/2 CATCHER SUB (36 1/2" OAL) IN D-NIPPLE ~ 7748' RKB. PULLED DGLV'S FROM STA # 5 (7706' RKB ), # 4 (7004' RKB ), AND # 3 (6022' RKB ). (LEFT POCKETS OPEN ). GLW IN PROGRESS. 01/28/06 PULLED DGLV'S FROM STA # 1 (2967' RKB) AND # 2 (4824' RKB ). SET GLV DESIGN W/ LGLV'S IN STA # 1 (2967' RKB ), 2 (4824' RKB ), 3 (6022' RKB ), AND 4 (7004' RKB ). SET OGLV IN STA # 5 (7706' RKB ). PULLED EMPTY CATCHER SUB FROM D-NIPPLE C~1 7748' 01/30/06 ! CHEMICAL CUT 2 3/8" LINER AT 8040' 02/03/06 RECOVERED 14' X 2-3/8" LINER TOP FROM 8026' RKB. 02/24/06 TIFL PASSED (POST RIG SIDETRACK) KRU 3H-14BL1/L2/L3/L4 A-sand Producer Proposed Completion s-5~s" ao# L-80 3455' 7" 26# L-80 Widow (416227' MD 3-1/2" Camco TRMA-10E SSSV at 2329' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 3-'/2" Camco KBUG-M GLM's @ 2967', 4824, 6022' MD ~/~ Top of 5'/:" Ilner ~ 6039' MD 3 '/z" Camco KBG-2-9 GLM's @ 7114', 7706' MD 3-'/z" Camco DS nipple, 2.75" min ID @ 7748' MD Baker HR Packer w/SBE @ 7780' MD 5=/:" 15.5# L80 @ 7925' and L1 KOP 8025' MD, in C-sand OH KOP @ 8285' and \ ~ IBP @ 8718' and ;3/8" liner top ~ 8025' and ~ 3-'/2" WS-R-BB packer/ whipstock (retrievable tray with integral standing valve) 3" openhole (all) A sand perfs 8172' - 8187' 3-112" 9.3# L-80 8450' MD 87~ -tea y ~'' . ConocoPhi I ~ i ps Alaska, Inc. • 3H-146L3 TD @ 10,106' and P/N 205-206 KOP @ 8857' and / 3H-14BL2 TD @ 10,774' and P/N 205-205 ~ ------- - - -- - KOP @ 9175' and 3H-146L4 TD @ 10,070' and ~3H-146L1 (pilot hole P/N 206-008 ` TD @ 9200' and PIN 205-204 .,. Conoc Phillips Baker Hughes INTEQ Baker Hughes INTEQ Survey Report L i~v~~c:~ Company: ConocoPhillips Alaska, Inc. Date: 2/18/2006 Time: 16:19:27 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3H-14, True North Site: KRU 3H Pad Vertical (TVD) Reference: 3H-146 79.6 Well: 3H-14 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Wellpath: 3H-146L19B'I {f ~ `o~ }~ p~t Survey Calculatioe Method: Minimum Curvature Db: Sybase Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 3H Pad UNITED STATES :North Slope Site Position: Northing: 6001657.06 ft Latitude: 70 24 56.740 N From: Map Easting: 498373.50 ft Longitude: 150 0 47.691 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.01 deg Well: 3H-14 Slot Name: Well Position: +N/-S -1156.72 ft Northing: 6000500.40 ft Latitude: 70 24 45.364 N +E/-W 282.18 ft Easting : 498655:40 ft Longitude: 150 0 39.419 W Position Uncertainty: 0.00 ft Wellpath: 3H-146L1 PB1 Drilled From: 3H-148 Tie-on Depth: 7962.79 ft Current Datum: 3H-146 Height 79.60 ft Above System Datum: Mean Sea Level Magnetic Data: 12/14!2005 Declination: 23.88 deg Field Strength: 57608 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 79.60 0.00 0.00 45.00 Survey Program for Definitive Wellpath Date: 1/4/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 103.60 6227.00 GYRO (103.60-8253.60) (0) GCT-MS Schlumberger GCT multishot 6299.36 7962.79 MWD (6299.36-8450.00) (3) MWD MWD -Standard 8000.00 9200.00 MWD (8000.00-9200.00) MWD MWD -Standard Annotation MD TVD ft ft 7962.79 6031.75 TIP 8025.00 6074.51 KOP 9200.00 6169.69 TD Survey: MWD Start Date: 1/4/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path f1~ }~~ i n. ~ ~~,~ `~ V~ Baker Hu Conoc~hillips ghes INTEQ Baker Hughes INTEQ Survey Report ~~ iNTEtl Company: ConocoPhillips Alaska, Inc. Date: 2/18!2006 Time: 16:19:27 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3H-14, True North Site: KRU 3H Pad Vertical (TVD) Reference: 3H-14B 79.6 Well: 3H-14 Wellpath: 3H-146L1~6'I ~~ ~~~ ~~~ ~ Section (VS) Reference: Survey Calculation Method: Well (O.OON,O.OOE,45.OOAzi) Minimum Curvature Db: Sybase Survey MD Inc! Azim TVD SS TVD N/S E/W MapN MapE VS DLS Tooi ft deg deg ft ft ft ft ft ft ft deg/100ft 7962.79 50.06 70.03 6031 .75 5952.15 2573.35 3728.16 6003072.83 502383.65 4455. 84 0 .00 MWD 8000.00 45.85 69.72 6056 .67 5977.07 2582.86 3754.10 6003082.32 502409.59 4480. 91 11 .33 MWD 8025.00 43.04 69.48 6074 .51 5994.91 2588.96 3770.51 6003088.42 502426.00 4496. 82 11 .26 MWD 8052.71 54.38 63.50 6092 .78 6013.18 2597.33 3789.52 6003096.79 502445.00 4516. 18 43 .99 MWD 8083.11 70.28 57.18 6106 .86 6027.26 2610.69 3812.77 6003110.15 502468.25 4542. 07 55 .41 MWD 8113.69 85.41 50.37 6113 .29 6033.69 2628.34 3836.77 6003127.79 502492.26 4571. 52 54 .03 MWD 8143.35 90.60 37.40 6114 .33 6034.73 2649.65 3857.26 6003149.09 502512.75 4601. 08 47 .06 MWD 8180.98 92.75 30.27 6113 .23 6033.63 2680.87 3878.19 6003180.31 502533.68 4637. 96 19 .78 MWD 8210.65 94.60 26.05 6111 .32 6031.72 2706.97 3892.16 6003206.40 502547.66 4666. 29 15 .50 MWD 8240.73 94.66 22.56 6108 .89 6029.29 2734.29 3904.50 6003233.72 502560.00 4694. 33 11 .57 MWD 8273.64 93.51 15.15 6106 .55 6026.95 2765.33 3915.10 6003264.75 502570.60 4723. 78 22 .73 MWD 8303.61 92.90 11.04 6104 .87 6025.27 2794.47 3921.88 6003293.89 502577.39 4749. 18 13 .84 MWD 8334.26 87.50 6.81 6104 .76 6025.16 2824.73 3926.63 6003324.14 502582.14 4773. 93 22 .38 MWD 8367.01 86.64 359.99 6106 .44 6026.84 2857.36 3928.57 6003356.77 502584.09 4798. 38 20 .96 MWD 8398.03 89.65 357.19 6107 .44 6027.84 2888.35 3927.80 6003387.76 502583.33 4819. 75 13 .25 MWD 8428.36 88.60 1.55 6107 .91 6028.31 2918.67 3927.47 6003418.07 502583.00 4840. 95 14 .78 MWD 8458.54 86.86 5.63 6109 .10 6029.50 2948.76 3929.36 6003448.16 502584.90 4863. 56 14 .69 MWD 8488.56 86.67 9.79 6110 .80 6031.20 2978.45 3933.38 6003477.85 502588.92 4887. 40 13 .85 MWD 8518.07 88.20 12.50 6112. 12 6032.52 3007.37 3939.08 6003506.76 502594.62 4911. 88 10 .54 MWD 8548.33 88.57 16.56 6112 .97 6033.37 3036.65 3946.66 6003536.03 502602.21 4937. 95 13 .47 MWD 8578.61 89.92 19.50 6113. 37 6033.77 3065.43 3956.03 6003564.82 502611.59 4964. 93 10 .68 MWD 8608.52 92.66 22.23 6112 .70 6033.10 3093.37 3966.68 6003592.75 502622.24 4992. 21 12 .93 MWD 8638.91 92.38 26.16 6111 .36 6031.76 3121.06 3979.12 6003620.43 502634.69 5020. 59 12 .95 MWD 8668.24 91.83 31.15 6110. 28 6030.68 3146.77 3993.17 6003646.14 502648.74 5048. 70 17 .10 MWD 8698.37 88.91 25.66 6110 .09 6030.49 3173.26 4007.50 6003672.62 502663.07 5077. 56 20 .64 MWD 8728.38 89.83 21.55 6110. 42 6030.82 3200.75 4019.51 6003700.11 502675.09 5105. 50 14 .03 MWD 8761.05 91.34 18.22 6110 .08 6030.48 3231.47 4030.62 6003730.82 502686.20 5135. 07 11 .19 MWD 8789.39 91.12 22.56 6109. 48 6029.88 3258.02 4040.49 6003757.37 502696.07 5160. 83 15 .33 MWD 8820.60 89.19 25.65 6109. 39 6029.79 3286.50 4053.23 6003785.84 502708.82 5189. 98 11 .67 MWD 8851.83 89.59 29.37 6109 .72 6030.12 3314.19 4067.66 6003813.53 502723.25 5219. 76 11 .98 MWD 8883.00 90.02 32.41 6109. 83 6030.23 3340.94 4083.66 6003840.27 502739.25 5249. 98 9 .85 MWD 8910.16 87,86 27.69 6110 .33 6030.73 3364.44 4097.25 6003863.76 502752.85 5276. 21 19 .11 MWD 8940.40 86.76 23.13 6111. 75 6032.15 3391.71 4110.21 6003891.03 502765.81 5304. 66 15 .50 MWD 8970.25 86.94 20.06 6113. 39 6033.79 3419.42 4121.18 6003918.74 502776.78 5332. 01 10. 29 MWD 9000.16 83.49 21.01 6115 .89 6036.29 3447.33 4131.63 6003946.64 502787.24 5359. 13 11 .96 MWD 9030.06 79.52 21.38 6120. 30 6040.70 3474.90 4142.32 6003974.20 502797.93 5386. 18 13. 33 MWD 9060.22 77.36 24.66 6126 .35 6046.75 3502.09 4153.87 6004001.39 502809.48 5413. 58 12 .84 MWD 9090.29 75.35 27.66 6133. 44 6053.84 3528.31 4166.75 6004027.61 502822.37 5441. 23 11 .78 MWD 9120.86 72.67 30.13 6141. 87 6062.27 3554.04 4180.94 6004053.33 502836.56 5469. 46 11 .71 MWD 9150.21 68.67 31.71 6151 .58 6071.98 3577.79 4195.16 6004077.08 502850.79 5496. 31 14 .54 MWD 9200.00 68.67 31.71 6169. 69 6090.09 3617.25 4219.54 6004116.53 502875.17 5541. 45 0. 00 MWD n l 11/09/04 STATE OF ALASKA O IL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: ,tiE'3..rE`r~~,;<u~~f~i~3_s~~tf_~~c_ F3~b~~ E;~::I{E`f1S~£'iflk,'~,J„J~ ~~f~":1~3_S~~:tf. ~?t_f~ Contractor: Nordic Rig No.: 2 DATE: 1/11/06 Rig Rep.: Mckeirnan / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Laule / Sevcik E-Mail ~i~~c~~~lc~rl~rE_~_~ic ry~c?z~~~gs~E~E_ ~~~~:~_t±l Well Name: 3H-14BL1 PTD # 205-204 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-4500 Annular: 250-2500 Valves: 250-4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3050 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity Test Result 200 psi Attained 0:12 P No. Valves 14 P Full Pressure Attained 1:27 P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4@ 2100 Test Results Number of Failures: 0 Test Time: 6 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with written confirmation to Superviser at: ~~E~3_.-rE~g~~z±tc~rril3,st~tf~ ~X_ Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES NO X c - Oper./Rig Waived By Lou Grimaldi c -Database Date 1/11/06 Time 0600 c -Trip Rpt Five Witness Bob Laule c -Inspector Test start 0930 Finish 1530 Coil Tubing BFL 11/09/04 Nordic 2 BOP 1-11-06.x1s r~ 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submitto: .€ir~3...rf'ct~~a~rfi~3:sf~_tf_~x_us a S~ cc~'rC.~l.~:~ ~'+i [E~~`i'~(~£? i3ci''d ~'cE~~B'~16~~.:~f,r~3:w~.c~h.E.eS Contractor: Nordic Rig No.: 2 DATE: 12/29/05 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Feketi-Sarber E-Mail ~t~~c~~~rc~~i~r~~~~ic~tc?~~~?~S~E~E_~7~?:~_~:3 Well Name: 3H-146L1 PTD # 205-204 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-4500 Annular: 250-2500 Valves: 250-4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1!8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity Test Result 200 psi Attained 20 sec P No. Valves 14 P Full Pressure Attained 80 secs P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 5.5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with written confirmation to Superviser at:.E~E"3..~E'4~ ~~~rfit3._~~~t f_~K.q Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES ??? NO c - Oper./Rig Waived By ???? c -Database Date 12/28/05 Time ???? c -Trip Rpt File Witness Daniell /Feketi c -Inspector Test start 10:30 Finish 16:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 12-29-05p.xls Re: [Fwd: 3H-14B laterals] r Subject: Re: [Fwd: 3H-14B.laterals] From: Thomas Maunder <tom_inaunder~i?adlnin.state.ak.us> Date: Tue, 20 Dec ?005 14:05:04 -0900 ~©_~ -~~ To: "~Vot-thin~ion, bras .I" ~~:.Aras.~1'orthin~lol~rubp.ri~m=~~ This is a good example of how confusing it can get when there are a whole lot of "close" numbers and tubular sizes and multiple changes through the years. Thanks for looking into this matter. Tom Worthington, Aras J wrote, On 12/20/2005 1:50 PM: Roger that Tom; I confused rnyself on the 5 112" vs. 3 1/2" shoe yet again...thanks for clarifying {2nd time)! Cheers, Arcs From: Thomas Maunder [mailto:tor_maunder@admin.state.ak.us] Sent: Tuesday, December 20, 2005 11:22 AM To: Worthington, Aras J Subject: Re: [Fwd: 3H-14B laterals] Aras, Thanks for the reply. On item 3, the 5-1/2" shoe is at 7925 which is what your drawing and text '; shows. The 10' difference is for the 3-1/2", but you are not going that deep. '', Thanks for looking in to these points. Most are not critical, but as this shows it is possible to "pass on" errors. I had a workover I was doing on M pad and the drawing indicated there was 9-5/8" in the well, but whenever I circulated it always took longer to "get bottoms up". I went to where BP kept their records and got the original file and found out that this was a well with "thermocase" in it. Essentially I should. have been using 10-3/4" for my calculations. Volumes were close, but short. There often is worth going back to square 1 when there have been a lot of changes in a well. Tom Worthington, Aras J wrote, On 12/20/2005 11:06 AM: Tom, You are correct on the discrepancies here; here is what I found: Item #2: I don't have the tallies for reference here; I can get them from Conoco but you are correct ', that there is a discrepancy: the completion report shows 6039' but the drilling report text says TC?L 6010' - I°m not }ust sure at this point, Item 3: The 3 112" shoe is indeed 7926'; not 8450' as in rx~y drawing; i got that from the schematic ', which is incorrect in this case. - I will correct my drawing, Item #4: My drawing is not descriptive of the 3 1I2" liner tap details, it is just to give an idea of what the completion looks like s it pertains to the CTD operation {in this case -not critioal for our 1 of 2 1/19!2006 3:14 PM Re: [Fwd: 3H-14B laterals] operation}, Item You are correct that the 7°' window is @ 6227'; the compietian report for 3H-14B is apparently wrong in stating 6039', The drilling text clearly reads 6227' as T®1111. - I will correct this on my drawing. Arcs From: Thomas Maunder [maiito:tom__maunder@admin,state.ak.us] Sent: Tuesday, December 20, 2005 10:32 AM To: Worthington, Aras J Subject: [Fwd: 3H-14B laterals] -------- Original Message -------- Subject:3H-14B laterals Date:Tue, 20 Dec 2005 10:27:56 -0900 From:Thomas Maunder <tort~ ma~~det-(rzadn~in.state.ak.us=~ Organization:State of Alaska To:Aras Worthington ~~ar•as.j.~~~orthin~;ton~~%cornocohillips.com=> Aras, I have gone back to look at the files to understand the history of 3H-14B, et al. Just a couple of "points" after looking at the files. 1. I was able to confirm the shoe depth for the 5-1/2" liner. 2. There seems to be a discrepancy about the top of the 5-1J2" liner. 6039 and 6010 appear in the narrative report provided with the 3H-14B 407. 6039 is what you show on the 401 and I agree that is probably correct. I don't have any tallies to reference. 3. There maybe a 10' discrepancy on the shoe depth of the 3-1/2" liner. Your drawing shows 8450' and that is the TD tagged when the liner was run. The shoe could have been set 10' off bottom and that may be reflected in the liner tallies that are not in the file I have. 4. Your drawing doesn't show the 3-1/2" as a liner with the top at 7780 (according to the 401 for 3H-14BL1). 5. Your drawing shows a 7" shoe to be at 6039'. This is one of the possible liner top depths, but the 7" actually extends deeper. The top of the window according the the completion report is 6227'. Please give me a call if you'd like to discuss. I don't think these issues are critical here since all your coil work will be conducted inside the 3-1/2" liner well away from any other tubulars. But, as I point out, there appear to be some differences with the "text numbers" on the 401 and the drawing. Thanks, Tom Maunder, PE AOGCC 2 oft 1/19/2006 3:14 PM RE: [Fwd: 3H-14B laterals] Subject: RE: [Fwd: 3H-I4B laterals] From: "Worthington, Aral J" <Aras.Worthington~bp.com> Date: Tue, 20 Dec 2005 13:50:46 -0900 To: Thi~nu~s ~~laundel- =tom maunder!~i'admin.state.ak.us> Roger that Tom; l confused myself on the 5 1!2" vs. 3 1I2" shoe yet again...thanks for clarifying {2nd time}! Cheers, Aral From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, December 20, 2005 11:22 AM To: Worthington, Aras J Subject: Re: [Fwd: 3H-14B laterals] Aras, Thanks for the reply. On item 3, the 5-1/2" shoe is at 7925 which is what your drawing and text shows. The 10' difference is for the 3-1/2", but you are not going that deep. Thanks for looking in to these points. Most are not critical, but as this shows it is possible to "pass on" errors. I had a workover I was doing on M pad and the drawing indicated there was 9-5/8" in the well, but whenever I circulated it always took longer to "get bottoms up". I went to where BP kept their records and got the original file and found out that this was a well with "thermocase" in it. Essentially I should have been using 10-3/4" for my calculations. Volumes were close, but short. There often is worth going back to square 1 when there have been a lot of changes in a well. Tom Worthington, Aras J wrote, On 12/20/2005 11:06 AM: Tom, You are correct on the discrepancies here; here is what 1 found: Item 2: 1 don't have the tallies for reference here; l can get them from Conoco but you are correct that there is a discrepancy: the completion report shows 6039' bu# the drilling report text says TOtr. @ 6010' - t'm not just sure at this point, Item #3: The 3 112" shoe is indeed 7925'; not 8450' as in my drawing; I got that from the schematic which is incorrect in this case. - I will correct my drawing. Item #4: Nly drawing is not descriptive of the 3 1/2" finer top details; it is just to give n idea of what the completion looks like as it pertains to the CTD operation {in this case -not critical for our operation). Item 5: You are correct that the 7" window is ~a 6227'; the completion report for 3H-14 is apparently wrong in stating 6039`. The drifting text clearly reads 6227' as TOW. -twill correct this on my drawing. Aras 1 of 2 12/20/2005 3:18 PM RE: [Fwd: 3H-14B laterals] From: Thomas Maunder [mailto:tam _maunder@admin.state.ak.us] Sent: Tuesday, December 20, 2005 10:32 AM To: Worthington, Aras J Subject: [Fwd: 3H-14B laterals] - Original Message -------- Subject:3H-14B laterals Date:Tue, 20 Dec 2005 10:27:56 -0900 From:Thomas Maunder <totn rnaunder(u admin.state.ak.us> Organization:State of Alaska To:Aras Worthington <arcs.j.worthin~;ton(ci%conocophillips.coin~ Aras, I have gone back to look at the files to understand the history of 3H-14B, et al. Just a couple of "points" after looking at the files. 1. I was able to confirm the shoe depth for the 5-1/2" liner. 2. There seems to be a discrepancy about the top of the 5-1/2" liner. 6039 and 6010 appear in the narrative report provided with the 3H-14B 407. 6039 is what you show on the 401 and I agree that is probably correct. I don't have any tallies to reference. 3. There maybe a 10' discrepancy on the shoe depth of the 3-1/2" liner. Your drawing shows 8450' and that is the TD tagged when the liner was run. The shoe could have been set 10' off bottom and that may be reflected in the liner tallies that are not in the file I have. 4. Your drawing doesn't show the 3-1/2" as a liner with the top at 7780 (according to the 401 for 3H-14BL1). 5. Your drawing shows a 7" shoe to be at 6039'. This is one of the possible liner top depths, but the 7" actually extends deeper. The top of the window according the the completion report is 6227'. Please give me a call if you'd like to discuss. I don't think these issues are critical here since all your coil work will be conducted inside the 3-1/2" liner well away from any other tubulars. But, as I point out, there appear to be some differences with the "text numbers" on the 401 and the drawing. Thanks, Tom Maunder, PE AOGCC 2 of 2 12/20/2005 3:18 PM _- O~cc~~,o ~ ~ ~ ~ P~~ ~c~c~. c~ k~r~~'1 ~~ i ~--o~.- ,~ ~~ z5 3.5" x 7" Cement Squeeze Perfs 7725' - 7729' Collapsed Tubing 7752" ~~~~ P ~ Camco'MMG-2' Mandrel Punch Location 2 " FHL packer Tubing to fish loaded with 12.2 ppg Naar brine 7685' - 7690' MD 3'/i' x 7" two-string window 7697' MD PBTD -Fish consisting of pressure sub, motor, and bit 7709' TD of redrilied hole ~ra~~ 1~,~~,~ - w~ ~~ ^~ E ~.: '\ i 3 la ~ \ ~~e~ ~.. ~S L~_~°~' 7710' Bottom of Cement Plug (Placed after hole collapse) Collapsed openhole, partially plugged with 15.8 ppg Class'G' ,~'`~~ ~~-~y 8702' MD TD of collapsed 3" openhole ff''y~ PJR 1/17/05 ~~®~ V~~ • `~ A ~ :7 ~ ~, a ~ s ~ ~ .~w~ ~, ALAS-IfA OIL ~1QD VcA.S COI~TSLRQATIOI~T COMI-IISSIOI~T Aras Worthington CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 .~ FRANK H. MURKOWSKl, GOVERNOR 1 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 f' PHONE (907) 279-1433 FAx (so7) 27sasa2 Re: Kuparuk 3H-14BL 1 ConocoPhillips Alaska Inc. Permit No: 205-204 Surface Location: 1157' FNL, 281' FWL, SEC. 12, T12N, R08E, UM Bottomhole Location: 2309' FSL, 858' FEL, SEC. O1, T12N, R08E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to redrill 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. 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this'L~ day of December, 2005 cc: Department of Fish & Game. Habitat Section w/o encl. STATE OF ALASKA L~[ l~F~'~IVEF~ ALASK~IL AND GAS CONSERVATION C MI SIDN ~` PERMIT TO DRILL 20 AAC 25.005 DES 1 ~ 2005 Alaska Uri ~ Gas COfiS. ColnmisSioll 1a. Type of work ~ Drill ®Redrill ~ ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil (a~one ^ Stratigraphic Test ^ Service ^Development Gas 'Q one 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ^ Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: Kuparuk 3H-14BL1 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9061' ' TVD 6088' ' 12. Field /Pool(s): Kuparuk River Unit /Kuparuk . 4a. Location of Well (Governmental Section): Surtace: 1157' FNL 281' FWL 12 SEC T12N R08E UM' 7. Property Designation: ADL 025531 " River Pool , , . , , , Top of Productive Horizon: 1428' FSL, 1232' FEL, SEC 01, T12N, ROSE, UM 8. Land Use Permit: 13. Approximate Spud Date: December 24, 2005 Total Depth: 2309' FSL, 858' FEL, SEC. 01, T12N, R08E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 27300' ' 4b. Location of We11 (State Base Plane Coordinates): Surtace: x-498655 ' y-6000500 ' Zone-ASP4 10. KB Elevation (Height above GL): 79.60 ' feet 15. Distance to Nearest Well Within Pool 3H-14 is offset by 700' ~ 16. Deviated Wells: Kickoff Depth: 8020' feet Maximum Hole Angle: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ,,xx Downhole: 5000 Surface: ~25U iryG1~ ~~9 18. Casing rogram: Size Specifications Setting pepth To Bottom uantrty o ement 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 710' 8350 6025 9060 6088 Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMM ARY (To'be completed focRedrill AND. Re-entry Operations) Total Depth MD (ft): 8450 Total Depth TVD (ft): 6409 Plugs (measured): None Effective Depth MD (ft): 8223 Effective Depth TVD (ft): 6224 Junk (measured): None Casin Len th Size Cement Volume MD TVD r rl n u r 115' 16" 00 sx AS I 115' 115' 3455' 9-5/8" 1350 sx AS II1, 400 sx Class 'G' 3455' 3001' 6039' 7" 00 sx Class 'G', 175 sx AS I 6039' 4847' Pro i n 1886' 5-1/2" 01 sx Class 'G' 6039' - 7925' 4847' - 6007' 660' 3-1 /2" 17 bbls i 5.8 Class 'G' 7780' - 8440' 5916' -6400' Perforation Depth MD (ft): 7884' - (8254 ('~ l~ Perforation Depth TVD (ft): 5981' - 6248' 20. Attachments 'fling Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis [] Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Name Aras Worthington Title CT Drilling Engineer Prepared By Name/Number: Si nature ~ j ',~ ~~ Phone 564-4102 Date 6~OS Sondra Stewman, 564-4750 Commission Use Only Permit To Drill ` / Number: ~~OJ`-- 71jjY API Number: . 50-103-20092-60-00 Permit Approval Date: ~ 'Q~ See cover letter for other requirements Conditions of Approval: Samples Required ~_ Yes No Mud Log Required ^ Yes ~'No Hydro Sulfide Measures 'Yes ^ No Directional Survey Required Yes ^ No Other: ~~O ~~~~~Q~ ~~` __ `~ T APPROVED BY /~j ~1 n D~ A roved B THE COMMISSION Date f ~' Lam' Form 10-401 Re ive sed 06/2 ~ ~ ~~~ ~ ~ (, L Stfbmit I~ Duplicate f KRU 3H-14BL1, 3H-146L2, & 3H-146L3 Sidetracks -Coiled Tubing Drilling Summary of Operations: Coiled tubing plans to dri1131aterals in producer KRU 3H-14B using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). The horizontal laterals will target Kuparuk A & (possibly) .. C-sands for production. The existing frac'ed Kuparuk A-Sand perforations in the existing well 3H-14B will be left open production. CTD Drill and Complete 3H-14BL1.'3H-14BL2, & 3H14BL3 program: Planned for Dec. 24, 2005 1. Pre CTD MIT-IA, MITT 2. Pre CTD test MV & SV 3. Pre CTD drift tubing/liner with dummy whipstock ~~~~ ~~~`~~ 4. MIRU Nordic 2. NU 7-1/16" BOPE, test ~ QS - c7 5. Set 3'/z" whipstock at 8020' and `' 6. Mi112.74" window at 8020' and and 10' of openhole 7. Drill 3" bicenter hole pilot lateral from window to 9060' and going through the C4 sand and drill through Kuparuk A sands across a mapped fault to delineate the A-sands across the fault (3H-14BL1) 8. Complete with 2 3/8" slotted liner from TD to 8350' with an Aluminum kick-off billet; deploy liner using SSSV as a barrier. 9. Kick-off of Aluminum billet top and dri113" hole horizontal lateral in A sands to TD @ 11,150' md. 10. Complete with 2 3/8" slotted liner from TD to 8700' with an Aluminum kick-off billet; deploy liner using SC~V ac a harrier ~®S - a ®~7 11. Kick-off of Aluminum billet top and drill 3" hole horizontal lateral in A sands to TD @ ~ 11,150' md. - 12. Complete with 2 318" slotted liner from TD, up into the 3 1/2" liner to 8010'; deploy liner using SSSV as a barrier. 13. ND BOPE. RDMO Nordic 2. ~o ~ _ ~~~" 14. Post CTD rig. BOL. Mud Program: • Step 6-12: 9.9 ppg Chloride based Flo-Pro mud ' 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 Drillsite 4 • Class I wastes will go to Pad 3 for disposal Casing Program: • 3H-14BL1: 2 3/8", 4.6#, L-80, STL slotted liner from --8350' and to 9060' md. • 3H-14BL2: 2 3/8", 4.6#, L-80, STL slotted liner from 8700' and to 11,150' md. • 3H-14BL3: 2 3/8", 4.6#, L-80, STL slotted liner from 8010' and to 11,150' md. Well Control: • Two wellbore volumes (250 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. • The annular preventer will be tested to 400 psi and 25j~0~0 psi. Directional -~~ _ ~~' ~ ~" v~-~~ ~ • See attached directional plans for H-14BL1, 3H-14BL2, & 3H-14BL3. • Magnetic and inclination survey will be taken every 30 ft. No gyro will be run. • The nearest well to 3H-14BL1 is 3H-14, which is offset by 700'. KRU boundary is 27,300' away. • The nearest well to 3H-14BL2 is 3I-16, which is offset by 1800'. KRU boundary is 27,300' away. • The nearest well to 3H-14BL3 is 3I-16, which is offset by 1800'. KRU boundary is 27,300' away. KRU 3H-1~L1, 3H-146L2, & 3H-14BL3 Sidetrac~- Coiled Tubing Drilling Logging • MWD Gamma Ray will be run. Hazards • 3H is an H2S pad, the highest H2S measurement on the pad is 450 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure • The expected reservoir pressure of 3H-14B (L1, L2, & L3) is5000 psi at 6071' TVD, 15.9 ppg EMW. ~--- Max. surface pressure with gas (0.1 psi/ft) to surface is 4400 psi. '' DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant ' bottom hole pressure by using 9.9 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long wellbores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding 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. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2 3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. J Estimated max reservoir pressure: 5000 psi at 6071' TVD, 15.9 ppg EMW. Expected annular friction losses while circulating: 720 psi. Planned mud density: 9.9 ppg equates to 3125 psi hydrostatic bottom hole pressure. While circulating 9.9 ppg fluid, bottom hole circulating pressure will be kept at an estimated 5100 psi or 16.lppg ECD. ,/ When circulation is stopped, a minimum of 1250 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements and shale behavior while drilling. ConocoPhillips Alaska, Inc. KRU 3H-146 ~~ 3H-146 API: 501032009202 Well T : PROD An le TS: 44 d 8018 ruelNC (0-7780, OD:3.500 SSSV Type: TRDP Ong COm IetlOn: 4/19/2005 Angle @ TD: 34 deg @8450 , ID:2.ssz) Annular Fluid: Last W/O: 6/16/2005 Rev Reason: PERF, FRAC, FCO TAG Reference L : 37.5' RKB Ref L Date: Last U ate: 8/29/2005 Last Tag: 8223 CTMD retainer TD: 8450 ftK6 Last Ta Date: 8/29/2005 Max Hole An le: 56 d 7048 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 WELD SURFACE 9.625 0 3455 3002 36.00 J-55 BTC PRODUCTION 7.000 0 6039 4848 26.00 J-55 BTC LINER 5.500 6039 7925 6007 15.50 L-80 HYDRIL511 LINER 3.500 7780 8450 8450 9.30 L-80 HYDRIL511 _ _ Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7780 5916 9.30 L-80 ModEUE8rd Perforations Summa ~ROOUCnoN 0 6039 Interval TVD Zone Status Ft SPF Date T e Comment ( - , oD:7.oo0, 7884 - 7886 5981 - 5982 2 4 5/18/2005 (PERF Shot TBG unch holes 9 wt:2s.oo) 7886 - 7888 5982 - 5984 2 4 5/13/2005 IPERF Shot TBG unch holes 9 8172 - 8187 6184 - 6196 A-2 15 6 8/9/2005 APERF 2.5" HSD 60 de hase 8250 - 8254 6245 - 6248 A-1 4 6 5/13/2005 SOZ 2506 PF chgs, 60 deg hase Stimulations & Treatments Interval Date T e Comment 8172 - 8187 8/28/2005 A-SAND FRAC 132 000# 16/20 CARBOLITE Gas Lift Mandrels/Valves - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2967 2661 CAMCO KBUG-M DMY 1.0 BK-5 0.000 0 6/15/2005 2 4824 3977 CAMCO KBUG-M DMY 1.0 BK-5 0.000 0 6/15/2005 3 6022 4836 CAMCO KBUG-M DMY 1.0 BK-5 0.000 0 6/15/2005 4 7004 5460 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 6/15/2005 5 7706 5872 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 6/20/2005 Other lu s e ui .etc. -JEWELRY De th TVD T e Descri lion ID 2329 2208 SLEEVE FRAC SLEEVE 80" OAL 2.857" NO GO - set 8/14/2005 2.300 2329 2208 SSSV CAMCO TRMA-10E SSSV set 6/16/2005 2.810 7748 5897 NIP CAMCO 'D' NIPPLE w/NO GO PROFILE set 6/16/2005 2.750 7789 5922 SEAL BAKER SEAL ASSEMBLY 3 SETS set 6/16/2005 2.990 Other lu s e ui .etc. -LINER JEWELRY De th TVD T e Descri lion ID 6039 4848 PACKER BAKER CPH LINER TOP PACKER FOR 5.5" LINER 4.500 6050 4856 HANGER BAKER HMC LINER HANGER FOR 5" LINER 4.000 7780 5916 PACKER BAKER'HR' SZP LINER FOR 3.5" LINER 3.500 7807 5933 HANGER BAKER HMC LINER HANGER FOR 3.5" LINER 3.500 8223 6224 RETAINER HES EZ-DRILL SVB RETAINER set 5/13/2005 2.690 General Notes Date Note 9/16/1999 WAIVERED WELL: IA x OA COMMUNICATION Perf 4/21/2005 WELL SIDETRACKED FOR SECOND TIME (7asa-78as> Perf (7886-7888) 4/29/2005 TREE: 3-1/8" CIW GEN 3 5K TREE CAP CONNECTION: 5" OTIS Perf (8172-8182) A-SAND FRAC (8172-8187) ~~ RETAINER (8223-8224, OD:3.500) Perf (8250-8254) LINER (7780-8450, OD:3.500, W t:9.30) KRU 3H-14BL1/L2/L3 A-sand Producer Proposed Completion 9-5/8" 40# L-80 3455' 26# L-80 039' MD 3-1/2" Camco TRMA-10E SSSV at 2329' MD 3-1 /2" 9.3# L-80 EUE 8rd Mod Tubing 3-'/2" Camco KBUG-M GLM's @ 2967', 4824, 6022' MD 3-'h" Camco KBG-2-9 GLM's @ 7114', 7706' MD 3-'h" Camco DS nipple, 2.75" min ID @ 7748' MD Baker HR Packer w/SBE @ 7780' MD 5 '/2" 15.5# L80 @ 7925' and KOP @ 8350' and L1 KOP 8020' MD, in C-sand Aluminum billets ConocoPhilli s p Alaska, Inc. 3H-14BL2 TD @ 11,150' and 3-'h" WS-R-BB packer/ whipstock (retrievable tray with integral standing valve) A sand perfs 8172' - 8187' ^-,-,-,-,--•{ CcD 8450' MD 3" openhole ~_- -_- KOP @ 8700' and 3H-14BL3 `~ TD@11,150'm 3H-14BL1 (pilot hole)~"~ TD @ 9"40' and • Kuparuk DOBCTD BOP configuratio • 2" CT Well 3H-146L1,L2,L3 Rig Floor Swab Valve Tree Size Flow Tee Flow Line SSV Master Valve Base Flan e Page 1 Cannco~hillps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~I~~ ~:-~ ~~~ Companc: ConocoPhillips Alaska, Inc. Date: 12/14/2005 Time: 17.17:05 Page 1 Feld: Kuparuk River Unit Co-ordinate(NE) Reference ~{Vell: 3H-14, True North - Site: KRU 3H Pad Vertical (I'Vll) Reference 3H-14B 79.6 Well: 3H-14 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) 1Vcllpath: Plan 4, 3H-14BL1 Survey Calculation Method: Minimum Curvature ~ Db: Oracle Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 3H Pad UNITED STATES :North Slope Site Position: Northing: 60016 57.06 ft Latitude: 70 24 56.740 N From: Map Eastiug: 4983 73.50 ft Longitude: 150 0 47.691 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.01 deg Well: 3H-14 Slot Name: Well Position: +N!-S -1156.72 ft Northing: 60005 00.40 ft ' Latitude: 70 24 45.364 N +E/-W 282.1$ ft Eastiug : 4986 55.40 ft ' Longitude: 150 0 39.419 W Position Uncertainty: 0.00 ft Wellpath: Plan 4, 3H-146L1 Drilled From: 3H-146 Tie-on Depth: 7962.79 ft Current Datum: 3H-14B Height 79.60 ft 'Above System Datum: Mean Sea Level Magnetic Data: 12!14/2005 Declination: 23.88 deg Field Strength: 57608 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 79.60 0.00 0.00 45.00 Plan: Plan #4 Date Composed: 12/14!2005 Copy Lamar's PIan4 Version: 1 Principal: Yes Tied-to: From: Definitive Path Tazgets Map Map <--- Latitude --> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Uip. Uir. Annotafion ~ MD 'CND - - - _ __ ft ft 7962.79 6031.75 TIP 8020.00 6070.88 KOP 8040.00 6085.15 End of 9°/100' DLS 8151.39 6121.81 4 8201.39 6117.39 End of 45°/100' DLS 8301.39 6108.55 6 8366.39 6103.18 7 8586.39 6098.15 8 8661.39 6100.50 9 8851.39 6109.49 10 8911.39 6116.98 11 9061.39 0.00 TD Plan Section Information MD Intl lzim TVD +N/-S +E/ W DLS Build Tm'n TFO Target ft deg deg ft ft ft degl100ft deg/100ft d eg/100ft deg 7962.79 50.06 70.03 6031.75 2573.35 3728.16 0.00 0.00 0.00 0.00 8020.00 43.58 69.53 6070.88 2587.76 376729 11.34 -11.33 -0.87 183.05 8040.00 45.35 69.09 6085.15 2592.71 3780.40 9.00 8.87 -2.20 350.00 8151.39 95.00 61.40 6121.81 2636.21 3872.04 45.00 44.57 -6.90 350.00 8201.39 95.00 38.82 6117.39 2667.95 3910.01 45.00 0.00 - 45.17 271.00 .~.. ~ Ct~nb~at~;l~ips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report 1~r~ ~~~~ ~~~;r~_- ~C'ompany: ConocoPhillips Alaska, Inc. Date 12114!2005 'l'ime: 17:17.05 Page 2 Field: K uparuk Rive r Unit Co-o rdinatef~~=) keferencc: Well: 3H-14 , True North Site: K RU 3H Pad Verti cal (T~'D) keferencc: 3 H-14B 79.6 VGell: 3 H-14 Secti on (4 S) Re1'cren cc: Well (O.OON, O.OOE,45.OO Azi) I Wcllpath: Pl an 4, 3H-14 BL1 Surve~~ Calculation Method: Minimum Cu rvature Db: Oracle Plan Section Cnt'ormatiou MD Inc! Azim CVD +~/-S +E/-«' llLS Kui ld Turn TFO PargcC ft deg deg ft ft ft deg/100ft deg/100ft deg/10 0ft deg 8301.39 95.10 26.77 6108.55 2751.53 3963.86 12.00 0. 10 -12.05 271,00 8366.39 94.37 18.98 6103.18 2811.17 3989.02 12.00 -1. 11 -11.99 265.00 8586.39 88.20 353.29 6098.15 3027.93 4012.25 12.00 -2. 81 -11.68 257.00 8661.39 88.22 2.29 6100.50 3102.76 4009.36 12.00 0. 03 12.01 90.00 8851.39 86.43 25.05 6109.49 3285.96 4053.90 12.00 -0. 95 11.98 95.00 8911.39 79.23 25.05 6116.98 3339.85 4079.08 12.00 -12. 00 0.00 180.00 9061.39 61.23 25.05 6167.52 3467.21 4138.60 12.00 -12. 00 0.00 180.00 Survey ---- MD Inc! 9zim SS TAU ~/S F/~'1' Map!ti ~1apE UC,S VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 7962.79 50.06 70.03 5952.15 2573.35 3728.16 6003072.83 502383.65 0.00 4455.84 0.00 MWD 8000.00 45.85 69.72 5977.07 2582.86 3754.10 6003082.32 502409.59 11.34 4480.91 183.05 MWD 8020.00 43.58 69.53 5991.28 2587.76 3767.29 6003087.22 502422.78 11.34 4493.70 183.26 MWD 8040.00 45.35 69.09 6005.55 2592.71 3780.40 6003092.17 502435.88 9.00 4506.46 350.00 MWD 8050.00 49.79 68.07 6012.30 2595.40 3787.26 6003094.86 502442.75 45.00 4513.23 350.00 MWD 8060.00 54.23 67.17 6018.45 2598.41 3794.55 6003097.86 502450.04 45.00 4520.50 350.69 MWD 8070.00 58.68 66.37 6023.98 2601.69 3802.21 6003101.15 502457.69 45.00 4528.24 351.24 MWD 8080.00 63.14 65.64 6028.84 2605.25 3810.19 6003104.70 502465.68 45.00 4536.40 351.69 MWD 8090.00 67.60 64.97 6033.00 2609.04 3818.44 6003108.50 502473.93 45.00 4544.92 352.04 MWD 8100.00 72.06 64.34 6036.45 2613.06 3826.92 6003112.51 502482.41 45.00 4553.76 352.32 MWD 8110.00 76.52 63.74 6039.16 2617.28 3835.58 6003116.72 502491.06 45.00 4562.86 352.54 MWD 8120.00 80.99 63.16 6041.11 2621.66 3844.35 6003121.11 502499.83 45.00 4572.16 352.70 MWD 8130.00 85.45 62.59 6042.29 2626.19 3853.18 6003125.63 502508.67 45.00 4581.61 352.81 MWD 8140.00 89.92 62.04 6042.69 2630.83 3862.03 6003130.27 502517.52 45.00 4591.14 352.88 MWD 8150.00 94.38 61.48 6042.32 2635.55 3870.83 6003134.99 502526.32 45.00 4600.71 352.90 MWD 8151.39 95.00 61.40 6042.21 2636.21 3872.04 6003135.65 502527.53 45.00 4602.03 352.88 MWD 8160.00 95.06 57.51 6041.45 2640.57 3879.43 6003140.01 502534.92 45.00 4610.34 271.00 MWD 8170.00 95.09 52.99 6040.57 2646.25 3887.61 6003145.68 502543.10 45.00 4620.14 270.66 MWD 8180.00 95.10 48.48 6039.68 2652.55 3895.32 6003151.99 502550.81 45.00 4630.05 270.26 MWD 8190.00 95.07 43.96 6038.79 2659.44 3902.51 6003158.87 502558.00 45.00 4640.00 269.86 MWD 8200.00 95.01 39.44 6037.91 2666.88 3909.14 6003166.31 502564.63 45.00 4649.95 269.46 MWD 8201.39 95.00 38.82 6037.79 2667.95 3910.01 6003167.38 502565.50 45.00 4651.32 269.06 MWD 8225.00 95.04 35.97 6035.72 2686.64 3924.29 6003186.06 502579.79 12.00 4674.63 271.00 MWD 8250.00 95.08 32.96 6033.52 2707.16 3938.39 6003206.58 502593.88 12.00 4699.11 270.75 MWD 8275.00 95.10 29.95 6031.30 2728.40 3951.38 6003227.82 502606.87 12.00 4723.32 270.49 MWD 8301.39 95.10 26.77 6028.95 2751.53 3963.86 6003250.94 502619.36 12.00 4748.50 270.22 MWD 8325.00 94.85 23.94 6026.91 2772.79 3973.93 6003272.19 502629.43 12.00 4770.65 265.00 MWD 8350.00 94.57 20.94 6024.86 2795.81 3983.44 6003295.22 502638.95 12.00 4793.66 264.75 MWD 8366.39 94.37 18.98 6023.58 2811.17 3989.02 6003310.57 502644.52 12.00 4808.46 264.51 MWD 8375.00 94.14 17.97 6022.94 2819.31 3991.74 6003318.71 502647.25 12.00 4816.14 257.00 MWD 8400.00 93.46 15.04 6021.28 2843.23 3998.82 6003342.62 502654.33 12.00 4838.06 256.93 MWD 8425.00 92.77 12.12 6019.92 2867.49 4004.68 6003366.88 502660.20 12.00 4859.36 256.73 MWD 8450.00 92.07 9.20 6018.87 2892.04 4009.30 6003391.43 502664.82 12.00 4879.98 256.57 MWD 8475.00 91.36 6.28 6018.12 2916.79 4012.66 6003416.18 502668.19 12.00 4899.87 256.45 MWD 8500.00 90.65 3.36 6017.69 2941.70 4014.76 6003441.08 502670.29 12.00 4918.96 256.36 MWD 8525.00 89.94 0.45 6017.56 2966.68 4015.60 6003466.06 502671.13 12.00 493722 256.31 MWD 8550.00 8923 357.53 6017.74 2991.68 4015.1fi 6003491.05 502670.69 12.00 4954.58 256.30 MWD 8575.00 88.52 354.62 6018.23 3016.61 4013.45 6003515.98 502668.99 12.00 4971.00 256.32 MWD 8586.39 88.20 353.29 6018.55 3027.93 4012.25 6003527.30 502667.79 12.00 4978.15 256.37 MWD 8600.00 88.20 354.92 6018.98 3041.46 4010.85 6003540.84 502666.40 12.00 4986.74 90.00 MWD 8625.00 88.21 357.93 6019.76 3066.40 4009.29 6003565.77 502664.84 12.00 5003.27 89.95 MWD 8650.00 88.22 0.93 6020.55 3091.38 4009.04 6003590.75 502664.60 12.00 5020.76 89.85 MWD 8661.39 88.22 2.29 6020.90 3102.76 4009.36 6003602.13 502664.92 12.00 5029.03 89.76 MWD • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~r~ M_ _ --_ _ a ~ rte c~ Compan~~: ConocoPhillips Alaska, Inc. Date: 12/14/2005 'l'ime 17:17:05 Page: 3 I Field: Ku paruk River Unit Cu-or dinate(VE) Reference: Well: 3H-14, True North / Site: KRU 3H Pad l'crtical (TVll) Referee}ce: 3H-14B 79.6 Well: 3H -14 Sectio n (VS) Referen ce: Well (O.OON, O.OOE,45.DOAzi) Wcllpath: Plan 4, 3H-14BL1 Survey Calculation liethod: Minimum Cu rvature ~ Db: Oracle Sw'vcv MD incl Azim SSTb'll Y/S L/~V MapV A1apE llLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 8675.00 88.08 3.92 6021.34 3116.34 4010.10 6003615.71 502665.66 12.00 5039.16 95.00 MWD 8700.00 87.82 6.91 6022.23 3141.21 4012.46 6003640.58 502668.02 12.00 5058.41 94.95 MWD 8725.00 87.57 9.91 6023.23 3165.92 4016.11 6003665.28 502671.68 12.00 5078.46 94.84 MWD $750.00 87.33 12.90 6024.35 3190.40 4021.05 6003689.76 502676.62 12.00 5099.26 94.72 MWD 8775.00 87.10 15.89 6025.56 3214.58 4027.25 6003713.94 502682.83 12.00 5120.75 94.59 MWD 8800.00 86.87 18.89 6026.88 3238.41 4034.72 6003737.76 502690.29 12.00 5142.87 94.44 MWD 8825.00 86.65 21.88 6028.29 3261.80 4043.41 6003761.15 502698.99 12.00 5165.56 94.28 MWD 8851.39 86.43 25.05 6029.89 3285.96 4053.90 6003785.30 502709.48 12.00 5190.06 94.11 MWD 8875.00 83.59 25.05 6031.94 3307.27 4063.86 6003806.60 502719.44 12.00 5212.17 180.00 MWD 8900.00 80.59 25.05 6035.38 3329.70 4074.34 6003829.03 502729.93 12.00 5235.44 180.00 MWD 8911.39 79.23 25.05 6037.38 3339.85 4079.08 6003839.18 502734.68 12.00 5245.98 180.00 MWD $925.00 77.59 25.05 6040.11 3351.93 4084.73 6003851.26 502740.33 12.00 5258.52 180.00 MWD 8950.00 74.59 25.05 6046.12 3373.92 4095.00 6003873.24 502750.60 12.00 5281.32 180.00 MWD 8975.00 71.59 25.05 6053.39 3395.58 4105.13 6003894.90 502760.73 12.00 5303.81 180.00 MWD 9000.00 68.59 25.05 6061.90 3416.88 4115.08 6003916.19 502770.68 12.00 5325.90 180.00 MWD 9025.00 65.59 25.05 6071.63 3437.74 4124.83 6003937.05 502780.44 12.00 5347.54 180.00 MWD 9050.00 62.59 25.05 6082.56 3458.11 4134.35 6003957.42 502789.96 12.00 5368.68 1$0.00 MWD 9061.39 • 61.23 25.05 6087.92 ' 3467.21 4138.60 6003966.51 502794.21 12.00 5378.12 180.00 MWD Ctmocvi~hillps I 3H 3 3H 3H-3~ 3H-2 8 3H~_~_ ~ ~_}.-... T~ 3H-1 ~~ 3H-i!ca. 3H-1~6 1 I1 3H~22 ~ ` -~_ __._. 3~ ~ , KRU 3H-14BL1 ~~ ~ ~ Proposed 1-Oil .~' 2052040 ~ T1 N, 8E~ UM ~ ,~3 - 9 3 17 ~ -. ~.GflildE'f ElE3~ lh`E'`14,> ;'R 1"'E? ~`?.' SFD 12N9/2005 Kuparuk ' Pe rfs ~i }I1 V~ 31-1 7 1 3 13a ~. i 3 -- }bi'.ii' 3H- 2 ^,i~,; 1 ,a r~ p ~, 0 -~-~..- ~ - ,v ~ ~ o --~ = ; ` .psi=, -,.._~_ - --__ - - _.. ~, -- • _ . 3H-~~ ._. _. _ .. - _ . - • - } ~ ` `~ H-26I { f - ~.- 1 ~ ~ -~ , .. ~ _ t~ _, 3H-U5 • ___ -- -' ~s /?i~_ _-_ ,. 7. .~~ _ 3H -01 4~ 34-17 SC~4 3H-02 • 3 . 07 ,..{_ _ Feet • 0 1,004 2,444 3,000 4,040 t: sc ~~,, 3f~- I 0 / ir.~~ ~~ J • • SONDRA D STEWMAN- as-sii2sz 138 BP EXPLORATION AK 1NG "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 oarE ~ ~.~ ~~ PAY TO THE -~~~...~ ( )~~~ ~ ~`~ ORDER OF ~Ld ,,..//1 ~ ~~~~ 9 v~.Y.c~~ ~~vlo~.. ~1~5 DOLLARS First National Bank Alaska Anchorage,. AK 99501 , MEMd~~ y IL~~~I ~~ ~ ~~ ~: i 25200060:99 i4~~+6 2 27~~+ i 56411' O L38 a • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK WHAT APPLIES WELL NAME ~~ ~~ ~~~~ / PTD# Z~S- 20 `~ ADD-ONS (OPTIONS MULTI LATERAL (If API number last two (Z) digits are between 60-69) "CLUE" The permit is for a new,w/etlb''or//e segment of existing well ~~ •~~+' ~ ~`7g Permit No,~'~~ API No. sa-~3~v~Z^ Production should continue to be reported as a function of the original API number stated above. PILOT HOLE ~ In accordance with ZO AAC 2~.005(f), all (per ~ records, data and logs acquired for the pilot '~ hole must be clearly differentiated in both name (name on permit plus PH) and API number (~0 - 70/80) from records, data and togs acquired for well (name on permit). SPACING ,The permit is approved subject to full EXCEPTION 'compliance with ZO AAC Z5.05~. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing j exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE ~ Commission must be in no greater than 30' sample intervals from below the permafrost j or from where samples are first caught and 10' sample intervals through target zones. ~L Rev: 04/01/05 C\jody\transm ittat_checklist WELL PERMIT CHECKLIST Field & Pool_KUPARUK RIVER, KUPARUK RVOIL-490100 Well Name: KUPARUK RIV UNIT 3H-14BL1 Program DEV Well bare seg ~ PTD#:2052040 Company CONOCOPHILLIPS ALASKA INC Initial Ciasslfype DEV 1 PEND GeoArea 890 Unit 11160 On/Off Shore Qn Annular Disposal ^ Administration 1 Permit_feeattached___ ___ __________ - Yes _--__-___,_--__,-__ - - - 2 Lease numberappropriate___ __________________ _________ ______-Yes _____.,_--.__ - - 3 Unique well-name andnumbe[ --- -- - --- -------- - ~ Yes -- ----- -- ------ - -- ------------ -- ------ -- - -- - - - 4 Well located in_a-defnedpool_ _ _ _ _ . - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Kupar-uk River OiI Pool, governed by Conservation Order No. 4320 _ _ _ _ _ _ _ - - - - _ _ _ _ - - _ _ _ _ _ - _ _ - - 5 Well located proper distance from drilling unit_boundary_ - - _ - _ Yes Conservation Order No. 432G contains no spacing restrictions with respect to drilling unit boundaries.... . 6 Well located proper distance from other wells_ _ - - Yes - _ - - - Conservation Order No. 4320 has no intenyell_spacing-restrictions, _ . - , 7 Sufficient acreage available in_drilling unjt_ _ - - Yes Conservation Order No. 4320 has no interwell_spacing_restriclions, Wellbore will be_more than 500' from _ 8 If deviated, is wellbore plat_inclu_ded .... - - - - . - - No_ - an external property line_where_ownership or_landownershipchonges. Directional data forproposed borehole _ - 9 Oper_atoronlyaffectedparty_____________________________ ____---.Yes_ __-__trajecto_ry_included.-Plotted well trajectory on base map._SFD-_______--_-___.-__-________- 10 Ope[atorhas-appropriate_bondinforce-_________--__________ _________Yes .._----.._ 11 Permit can be issued without conservation order ------------------------------------------------ Yes ------------- -------------------------------------------------------------------------- Appr Date 12 Permitcanbeissuedwithoutadministraiiv_e_approval________________ ___„____Yes- -______ __--_____.__-________________-__ SFD 12!19!2005 13 Can permit be approved before 15-day wait Yes 14 Well locatedwithipareaandstrataauthprizedby_InjectionOrder#(put1O#incomments).(FQr NA_ -.-.----_-_------------- -_--..__-__--...-_-__..-_-__-.-.--_-.-.--_.-_ 15 AIIwellswithinll4_mileareaofreyiewidentified(Forservicewellgnly)______ _________NA._ ___--__-_--..-_._--_...--.-_-...__----...---_---__.-_. 16 Pre-produced injector; duration of pre production lessihan_3months_(For_servi_cewellonly)-_NA- ____________________---_,________________-______-______-_____-______. ACMP,FindingofConsistency_hasbeenissued_fo[thisproject„--------- --------- NA,_ ____,_----_____-__-______-.__-_____--._-___._--______-_______-____--____ Engineering 18 Conductor string_provided _ . - - . _ - - _ _ _ - NA. _ Conductor set_in original welh 3H-14 (187-12.3). . _ - , ------------------------------- 19 Surface casing_protectsall_knownUSDWS___...___-.--.- __-.-NA_ _____Allaquifersexempked,40CFR,i47,102(b)~3)_______ ______________ ____-______-_,__-_ 20 CMT_voladequate_tocircul_ate_onconductor&surf_csg-_____._______ ________NA_ _.__.-Surface casing satin_orginalwell,3H-14.__-__,_-__- _ _______--____-_-_-____-___-_ 21 CMT_voI_ adequate_to tie-in long string to surf csg_ _ _ - No_ Production_casing set in_original well, 3H-14 _Top of 7" window at622T md, - _ - - _ _ - 22 CMT_willcoyerallknown_productiyehorizon_s______________ - No,- - --____Slottedlinercompletion planned._._-----___..__-_-___..-_--_.-..__..--.-__.__. 23 Casing desgns adequate for C,_T, B &_ permafrost_ - - - , .. _ _ - - _ _ _ - - NA- _ Original well met design specifications. -NA for slotted liner._ _ _ 24 Adequate tankage_o_r reserve pit - - , - - - - - - .. - - .. -Yes . ... - Rig is_equipped with steel_pits. No reserve_pitplanned, All waste to approved disposalwells._ - . - - 25 Ifa_re-drill,has.a10-403forabandonmentbeenapproved_____ _______ _________NA__ ___--Existingperf_orationswill_beretained,_____-_____----______,-____--_____--_-_ 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ ... _ - .Proximity analysis performed: Nearest branch_ is 3H-14B and trajectories diverge._ .. _ - _ _ _ _ . _ _ _ _ _ - . _ _ - 27 Ifdiverterrequiretl,doesjtmeetregulations______._-- _-_____- ______ --NA-_ ____--BOPstack_willal[eady_beinplace,________--____.--,____-._ -------------------- Appr Date 28 Drilling fluid_ program schematic & equip list adequate _ _ _ - _ _ - - _ Yes Maximum expected formation pressure 15.9 EMW._ Plan is to employ dynamic gve[balance with 9.9_ppg fluid and_ TEM 1212012005 29 BOPEs,.do they meet regulation _ . - _ _ _ Yes - . - either.applied or frictional pressure. 2 wellbore volumes of kill weight fluid available for contingency p~ ~!-~J,/~ '" 30 BOPE press rating appropriate; test to-(put psig in comments}_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ - - Calculated_MA$P 4400 psi._ Planned BOP test 4500psi, , _ - - - _ _ . _ _ _ , _ ~ j~~,'K 31 Choke_manifoldcomp_IieswIAPIRP-53 (May84)______________ Yes- ----.-__.__.----__-....----__..--__-___.... 32 Work will occur. without operation shutdown_ _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . - - _ - --------------------------------------------------------------------- 33 Is presence-of H2$ gas_probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - - _ _ _ _ DS 3H is.an H2Spad..Mud-should preclude_H2S onlig.- Rig has sensors and_alarms._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mechanical_conditionofwellswithinAORyerified(Forservicewellonly)_____ _________NA__ _,_--,__-_____--_______.-_--_____-______.-_--__-___--__ ------------------- Geology 35 Permitcan be issued w/o hydrogen_sulfide measu[es - - - - - - - - - - - _ _ .. No_ 3H-Pad wells measured between 60_ & 450_ppm_H2S_during2004. Monitoring equipment-will be_ used.- - - . - - 36 Dala.presented on potential overpressure zones- - - - - - ---- - - - Yes _ - Expected pressure is 15,9.ppg EMW; wiltbe drilled with 9,9_ppg mud and_overbalanced pressure-using _ , Appr Date 37 Seismic analysis of shallow gas_zones- - - - - NA_ _ - ,coiled tubing (equiv_alent circulating density will be 16:1_ ppg). - - - SFD 12J1912005 38 Seabed condition survey-(if off_-shore) . - _ _ - _ _ _ NA_ - - - ~i 39 Contact namelphone for weekly-progress reports [exploratory only] - - tJA_ _ . , - - Geologic Engineering Pub c Date: Date ' Date Expected reservoir pressure is 5000 psi at 6071 feet ND, or 15.9 ppg EMW. Will be drilled using coiled tubing and Commissioner: Commissioner: C s ner ~~ ~ dynamically overbalanced pressure drilling techniques. SFD T r /1 \n O 1 J J~ ~~~V 111 ~ a wO~ • • Wel I H isiory File APPENDIX Information of detailed nature that is not U particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 07/05/01 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MwD 06/01/02 1047250 01 2.375 CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8027.8000: Starting Depth STOP.FT 9200.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska Inc. WELL. WELL: 3H-14BL1P~'1 N;!st «~~~- FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 24' 45.364"N 150 deg 00' 39.419"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375 CTK DATE. LOG DATE: 02-Jan-06 API API NUMBER: 50103200927000 Parameter Information Block #MNEM.UNIT Value Description - - -- - ----------- -- --- ------ -- - SECT. - 12 Section TOWN.N 12N Township RANG. 08E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 79.6 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 79.6 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~bs aoy ~ ~5o9a (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Aepths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, and Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Directional, Outer Downhole Pressure, and Downhole Weight on Bit), a and Gamma Sub, and a Hydraulic Orienting Sub with a near Bit Inclination Sensor. (6} Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) This well was drilled from 3H-14B through a milled window in 7" liner: Top of Window 8025.0 ft.MD (5994.9 ft.SSTVD) Bottom of Window 8027.8 ft.MD (5996.9 ft.SSTVD) (8) The interval from 9176 ft.MD to 9200 ft.MD (6081.4 ft.SSTVD to 6090.1 ft.SSTVD) was not logged due to bit to sensor offset at TD. (9) Tied into 3H-14B at 8000.00 ft.MD (5977.07 ft.SSTVD) (10) The wellbore 3H-14BL2 was sidetracked off this wellbore 3H- 14BL1PB1 at 8274.0 ft.MD 6026.93 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MG7D-AAPI [MG~7D] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 3H-14BL1PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 3H-14BL1PB1, FN Kuparuk River Unit COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 • • The data presented here is final and has not been depth shifted *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 28 Tape File Start Depth = 8025.000000 Tape File End Depth = 9199.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 37 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ~ i ----------------------- WDFN 3H-14BL1PB1.xtf LCC 150 CN ConocoPhillips Alaska In WN 3H-14BL1PB1, FN Kuparuk River Unit COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 65 Tape File Start Depth = 7839.000000 Tape File End Depth = 9199.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 74 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD • • 06/01/02 1047250 O1 **** REEL TRAILER **** MGTD 07/05/01 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS i Tape Subfile 2 is type: LIS DEPTH GR ROP 8025.0000 75.7200 -999.2500 8025.5000 81.6750 -999.2500 8100.0000 143.4700 24.5100 8200.0000 116.2100 64.5100 8300.0000 103.5100 63.1700 8400.0000 111.1800 45.3700 8500.0000 98.4800 7.2300 8600.0000 102.4500 37.4000 8700.0000 98.4800 50.7800 8800.0000 146.1200 31.3100 8900.0000 120.1800 52.8700 9000.0000 113.8300 62.4300 9100.0000 123.0900 61.7500 9199.0000 -999.2500 -999.2500 Tape File Start Depth = 8025.000000 Tape File End Depth = 9199.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GR ROP 7839.0000 -999.2500 -999.2500 7839.2500 -999.2500 -999.2500 7900.0000 113.0400 -999.2500 8000.0000 158.5600 -999.2500 8100.0000 143.4700 24.5100 8200.0000 116.2100 64.5100 8300.0000 103.5100 63.1700 8400.0000 111.1800 45.3700 8500.0000 98.4800 7.2300 8600.0000 102.4500 37.4000 8700.0000 98.4800 50.7800 8800.0000 146.1200 31.3100 8900.0000 120.1800 52.8700 9000.0000 113.8300 62.4300 9100.0000 123.0900 61.7500 9199.0000 -999.2500 -999.2500 • Tape File Start Depth = 7839.000000 Tape File End Depth = 9199.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS