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"#$$%&!' ((!)"!)*+),$)' .)" /011/ " )"' ()234&(5/61!$$'//$'7 ! "82 9 )" (6 0)"///: 2 /1* ! "3$%&(5/,!)")";( 1(".2) 2 .2) 1!)")5) 6.)/ ( 0( ")"<721(6=/! ' ()234" ((!)"= ):)0 6.2)%)'$/!1!( 6*)12)2 .2.)2.",6)(1 2 . : ()5) "( < ((!)"= ):)0 6 .2)4)'$/!6)1)".)2.""!5 "(.(/0 2 !)(!)""1!$%//(2 (2"4%//6=/)"(( ()."1.6(: 2<"()11")/26=/)"(( ' (((! )"= ):)0 "/.)2) '( 1.;'$/!#$)6 /!#4$)6'$/!#7)6/!#%$)6'$/!#)6/!#)' ./>21!:.:>21 6:)> "*=/! ,' 2</ ? Sundry #321-490 applies to laterals KRU 3H-14BL2/PTD 205-205, KRU 3H-14BL3/PTD 205-206, and KRU 3H-14BL4/PTD 206-008 as well as motherbore: KRU 3H-14B/PTD 205-012. Suspension date of 1/31/2022 applies to all 4 wells.“ • ~< ~*" ~: ,, -; - h -,~~. ;e. `R^~, ~- r MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ,~ r~.. DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2060080 Well Name/No. KUPARUK RIV UNIT 3H-14BL4 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20092-63-00 MD 10070 TVD 6192 Completion Date 1/22/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD GR Well Log Information: Log/ Electr Data Digital Dataset Type ed/Frmt Number Name (data taken from Logs Portion of Master We11 Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ~~ D Asc Directional Survey 9158 10070 Open 3/28/2006 ~ I ~C Directional Survey 9158 10070 Open 3/28/2006 QED C Lis 15093 Gamma Ray 8025 10070 Open 5/4/2007 LIS Veri GR, ROP w.Graphics TXT, TIF and ~ META ~Lq~ 15093 Gamma Ray 25 Blu 8025 10070 Open 5/4/2007 MD GR 18-Jan-2006 l/ w/Graphics (,~og 15093 Gamma Ray 25 Biu 8025 10070 Open 5/4/2007 TVD GR 18-Jan-2006 ~ w/Graphics gRpt 15093 LIS Verification 8025 10070 Open 5/4/2007 LIS Veri GR, ROP w.Graphics TXT, TIF and META Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y"~ Daily History Received? ~N Chips Received? Y TN`- Formation Tops ~ N Analysis ~`7'iC-'"" Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT Zi2si2oos Permit to Drill 2060080 Well Name/No. KUPARUK RIV UNIT 3H-14BL4 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20092-63-00 MD 10070 TVD 6192 Completion Date 1/22/2006 Completion Status 1-OIL Current Status 1-OIL UIC N A Compliance Reviewed By: Date: ~ ~ V Transmittal Form , ~ ~~ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7`h Ave, Suite 100 Anchorage, Alaska _:.~ { ~ ~ ~-< ~-~ ~~, 99501 `~ _ - Attention: Helen Warman ~~~ '','~' ~~ ~~ ~~d, Reference: 3H-14BL4 ~ ~ ~`~ ~~~~ Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 1047250 Sent By: Deepa Joglekar Date: May 02, 2007 Received By: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: ~9i~7) 26?-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 p7 ~~ ~~ ~ Direct: (907) 267-6612 FAX: (907) 267-6623 ~ tSC~-a3 !Duna ~. ~~ =-- ~..,~.. ~:_.~ ~i 1'~ _ !' ',' j'7. ' _. - j _ .-_ ,, '~_--~ ..,.. i STATE OF ALASKA ~~~~~ ALAS~IL AND GAS CONSERVATION COMSION ~fi~,~ 0 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ ~ Z 06 ~lask~ Iii I~~s Cons. Commission ~~~~rflr~ran-a 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 1/22/2006 12. Permit to Drill Number 206-008 3. Address: c/ o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1 /16/2006 ~ 13. API Number 50-103-20092-63-00 4a. Location of Well (Governmental Section): Surtace: ' ' 7. Date T.D. Reached 1/18/2006 ' 14. Well Name and Number: Kuparuk 3H-14BL4 1157 FNL, 281 FWL, SEC. 12, T12N, ROSE, UM Top of Productive Horizon: 1429' FSL, 1232' FEL, SEC 01, T12N, R08E, UM (From B) g. KB Elevation (ft): 79.60 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool ° Total Depth: 3120' FSL, 283' FEL, SEC. 01, T12N, R08E, UM 9. Plug Back Depth (MD+TVD) 10070 + 6192 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498655 " y- 6000500' Zone- ASP4 10. Total Depth (MD+TVD) ~ 10070 + 6192 Ft 16. Property Designation: ADL 025531 ~ TPI: x- 502420 y- 6003086 Zone- ASP4 Total Depth: x- 503369 Y- 6004778 Zone- ASP4 11. Depth where SSSV set 2329' MD 17. Land Use Permit: ---------~--- ----------"----------- -------------------- i f P f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ckness o erma rost 20. Th 2451' (Approx.) 21. Logs Run: /iCoP 9'! 7S ~~~ MWD GR ~~ ~• G•G~6 2. CASING, LINER AND EMENTING RECORD CASING IN(3 EPTH MD ETTINp EPTH TYD ~O~ MOUNT SIZE WT. PER FT. GRADE OP TTOM OP' TTOM ti1ZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 115' Surtace 115' 24" 00 sx Arcticset I 9-5/8" 36# J-55 Surface 3455' Surface 3002' 12-1/4" 1350 sx AS III, 400 sx Class 'G' 7" 26# J-55 Surface 6039' Surtace 4848' 8-1/2" 00 sx Class'G', 175 sx AS I 5-1/2" 15.5# L-80 6039' 7925' 4848' 6007' 6-3/4" 01 sx Class 'G' 3-1 /2" 9.3#' L-80 7780' 8025' 5916' 6075' 4-3/4" 2 sx Class 'G' 2-3/8" 4.4# L-80 8040' 9532' 6085' 6093' 3" Uncemented Slotted Liner 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) 2-3/8" Slotted Section Note: 3-112", 9.3#, L-80 7780' 7780' MD TVD MD TVD 8243' - 9499' 6109' - 6094' Only Well Branch 3H-14B & 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3H-148L4 Are Di l DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED rect y Accessible ~ 2000' Freeze Protect w/ 18 Bbls of McOH 26• PRODUCTION TEST Date First Production: February 8, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 2/28/2006 Hours Tested 27 PRODUCTION FOR TEST PERIOD OIL-BBL 882 GAS-MCF 792 WATER-BBL 839 CHOKE SIZE 176 Bean GAS-OIL RATIO 1,013 Flow Tubing Press. 11 Casing Pressure 1259 CALCULATED 24-HOUR RATE OIL-BBL 721 ' GAS-MCF 730 WATER-BBL 733 OIL GRAVITY-API (CORK) 21.6 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~:a, None ~ ~~ I~~ !~ YI~I~.°`u ~~~ Form 10-407 Revised 12/2003 l ~~ ~ ~~ 1\~~ ~UED ON REVERSE SIDE ~~~p~ tl~ ~ n~ ~j " ~u~V - ~~~~ d ! ~` y 4 6 i 28. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. Llst intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". From 3H-14B None .- Kuparuk C4 8018' 6069' Kuparuk A3 9179' 6088' Kuparuk A4 9220' 6086' Kuparuk A3 9290' 6088' Kuparuk A4 9540' 6093' Unit B 9580' 6090' Kuparuk A4 9870' 6104' Kuparuk A3 9905' 6113' Kuparuk A2 9955' 6130' Kuparuk Al 10020' 6161' 30. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~~ Signed Terris Hubble Title Technical Assistant Date Kuparuk 3H-146L4 206-008 Prepared By NameAVumber.• Terris Hubble, 564-4628 Well Number Permit No. / A rOVal No. Drilling Engineer: ftras Worthington, 564-4102 INSTRUCTIONS GENEaA~: 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 Welis: 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 B: 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. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, 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-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 Ria: Nordic #2 PRE-RIG WORK 12/08/05 PRE-CTD PRESSURE TEST AND DRAWDOWNTEST 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. EQ DHSIT AND ATTEMPT TO PULL. 12/19/05 ATTEMPT TO PULL DHSIT. 12/20/05 CIRC OUT W ELL 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. i 2/22/05 ATTEMPTED TO MILL RETAINER AT 8223'. MADE APPROX. 1.2' AND COULD NOT GO FURTHER. MULTIPLE STALLS W ITH 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~3 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. • I BP EXPLORATION Page 1 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date 'From - To ' Hours ' Task '~ Code --J-- 12/28/2005 ~ 11:00 - 13:30 2.50 ~ MOB ~ P 13:30 - 15:30 ~ 2.00 MOB P 15:30 - 17:30 2.00 MOB P 17:30 - 18:45 1.25 MOB P 18:45 - 00:00 ~ 5.25 ~ MOB ~ P 12/29/2005 00:00 - 03:00 3.00 MOB P 03:00 - 03:45 0.75 MOB P 03:45 - 06:00 2.25 MOB P 06:00 - 06:15 0.25 MOB P 08:00 - 00:45 2.75 OPSUR P 10:45 - 16:00 f 5.251 BOPSUR P 16:00 - 16:30 I 0.501 CLEAN I P 16:30 - 17:30 I 1.001 CLEAN I P 17:30 - 18:00 I 0.50 I CLEAN ( P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:00 0.50 CLEAN P 19:00 - 20:00 I 1.001 CLEAN I P 20:00 - 21:30 1.50 CLEAN P 21:30 - 23:30 2.00 CLEAN P 23:30 - 00:00 I 0.501 CLEAN I P 12/30/2005 100:00 - 01:00 I 1.001 CLEAN Spud Date: 12/30/2005 Start: 12/28/2005 End: 1 /22/2006 Rig Release: 1/22/2006 Rig Number: NPT ' Phase Description of Operations 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. PRE Wait for aircraft traffic. PRE Move to intersection of spine road and 1 F pad access road. PRE Wait for CPF2 and CPF3 crew changes. Hold PJSM with night tour crew coming on rig. Discuss move and hazards. Review SOP. PRE Move down spine road toward 3H pad. Rig is just past CPF3 at midnight PRE Continue move from CPF3 to 3H pad. PRE PJSM prior to moving rig in over well. PRE MIRU. Rig accepted at 0500hrs PRE PJSM with crew change.. need to level rig, hook-up comms (not good) start NU BOP's PRE Level rig. PRE NU BOP's Take on used 8.5ppg Flo-Pro form previous well. Hook up comms ant wire coming from rig. PRE Test BOPS 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. WEXIT Gather all hands and hold Pre-Spud meeting. Discuss anticipated high pressure problems. SSSV operations. Possible pressure deployment problems. review next 48hr operations. WEXIT Check WHP 927 psi. Close SSSV and bleed down to cuttings tank. All fluid retums. Montior well to see if SSSV is holding. As off 1730hrs it still Opsi. Waiting for Well Support to install hardline for Tiger Tank. WEXIT Wait until hardline to Tiger Tank is install and continue monitoring SSSV performance. WEXIT Crew change. WEXIT Pre spud meeting with night crew. Discuss unusual aspects of this well. Discuss hazards, and mitigations to hazards. 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. WEXIT Shut SSSV, bleed off WHP. Check for flow. No flow observed. Make up BHA #1:2.74" D331, WF PDM, BHI MWD BHA. 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 truck that brought us the mud. Continue in hole pumping at full rate. Clean down to 8100` CTM. WEXIT Log down accross GR charecter from 7950'-8050'. Make -14' correction. WEXIT Log CCL pass down. Confirm that collars are on depth to tie in Printed: 1/23/2006 1:0636 PM BP EXPLORATION Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Start: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date 12/30/2005 From - To Hours ! Task !Code ' NPT ' Phase 00:00 - 01:00 1.00 CLEAN 01:00 - 02:20 1.33 CLEAN 02:20 - 02:30 0.17 CLEAN 02:30 - 03:45 1.25 WHIP 03:45 - 06:35 2.83 WHIP 06:35 - 07:25 0.83 WHIP 07:25 - 09:30 2:08 W H I P 09:30 - 10:40 1:17 WHIP 10:40 - 12:45 2.08 WHIP 12:45 - 12:55 I 0.171 WHIP 12:55 - 14:10 1.25 WHIP 14:10 - 15:00 0.83 WHIP 15:00 - 16:25 1.42 BOPSUF 16:25 - 17:00 0.58 WHIP 17:00 - 18:25 1.42 W H I P 18:25 - 19:00 0.58 WHIP 19:00 - 20:00 1.00 STWHIP 20:00 - 21:00 1.00 STWHIP 21:00 - 21:50 0.83 STWHIP 21:50 - 23:00 1.17 STWHIP 23:00 - 23:15 0.25 STWHIP 23:15 - 0.00 STWHIP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Page 2 of 23 Spud Date: 12/30/2005 End: 1 /22/2006 Description of Operations log. POOH, pumping at full rate. Flow check well, and hold PJSM re: BHA swap. Lay down BHA #1, cleanout BHA. Reconfigure BHI MWD tool and test. Pick up BHA #2, WF anchor assembly, BHI MWD tool including HOT. RIH with BHA #2, whipstock anchor. EDC is open, pumping at minimum rate. Seeing some BU gas and oil. 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. TOH following pressure schedule to maintain 3800psi BHP. Trap 1100psi on well and shut-in SSSV. LD packer setting BHA and PU whipstock assembly. 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. 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 TOH following pressure schedule LD BHA #3. 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 2-3/8" combi's close. Above and below area 2.380" In the zone 2.370" PU BHA #4 RIH open SSSV Log tie in pass down from 7900'. Make a -14' correction. 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. 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. 8026.0'. Milling ahead. Motor work is 170 psi. DHWOB = 3300 lbs. String wt = 2000 lbs. Getting more metal hair on the magnets. 8026.8'. Motor work dropped off and WOB dropped off. Possibly exited window. Continue at the 0.1'/6 minute pace to allow string reamer to clean off the lip. 8028.0'. Stall. Pickup. Possibly string reamer at lip. Continue milling at 0.1'/6 minutes. 8028.2'. W e are out the window. Push on it to see if 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: 1/23/2006 1:06:36 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 I From - To L Hours I Task ', Code NPT Phase ~~I 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 #4) 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/HSTF ann= 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 W HP ann= 3845 ecd= 12.38 @ 1.56bpm/3600 1-2k wob 20-30'/hr 10:45 - 12:35 1.83 DRILL P PROD1 12:35 - 14:15 1.67 DRILL P PROD1 14:15 - 18:00 3.75 DRILL P PRODi 18:00 - 19:00 1.00 DRILL P PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 21:00 1.50 DRILL P PROD1 21:00 - 22:00 1.00 DRILL N DFAL PROD1 22:00 - 22:10 0.17 DRILL N DFAL PROD1 22:10 - 22:45 0.58 DRILL N DFAL PROD1 TOH following revised 9.9ppg pressure schedule. Close SSSV w/ 650psi. Pull to 200" bleed down well and monitor for flow. 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. Circulate and warm coil. Unstab injector. Cut-off Kendal CTC. Dress end of a-fine. Stab on well and reverse circ for Slack Mgmt. Cut-off 50' coil. Install Kendal CTC pull test to 40k. Circulate to warm coil. Build BHI UOC. Meg line. Checks ok. Attach pressure test plate. PT to 4500 psi ok. Pump slack forward to complete slack management. Pick up BHA #6 to drill lateral section. 1 deg motor. Same hycalog bicenter bit as previous run. Full MW D BHA. 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. 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 clean coming up, no overpull or problems. PJSM while flowchecking well. Discuss plan forward. Need to diagnose problem and correct. 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 1:06:36 PM BP EXPLORATION Page 4 of 23 Operations Summary Report Legal Well Name: 3 H-14B Common W ell Name: 3H-146 Event Nam e: DRILL+C OMPLE TE Contractor Name: NORDIC CALIST A Rig Name: NORDIC 2 Date From - To ' Hours Task~ Code ~ NPT 12/31(2005 22:10 - 22:45 0.58 DRILL N DFAL 22:45 - 23:05 0.33 DRILL N DFAL 23:05 - 00:00 0.92 DRILL N DFAL 1/1/2006 00:00 - 01:15 1.25 DRILL N DFAL 01:15 - 01:45 0.50 DRILL P 01:45 - 03:10 1.42 DRILL P 03:10 - 05:00 1.83 DRILL P 05:00 - 05:30 0.50 DRILL P 05:30 - 07:00 1.50 DRILL P 07:00 - 10:00 3.00 DRILL P 10:00 - 10:30 0.50 DRILL P 10:30 - 14:15 3.75 DRILL P 14:15 - 16:45 2.50 DRILL P 16:45 - 18:20 1.58 DRILL P 18:20 - 19:00 0.67 DRILL P 19:00 - 19:10 0.17 DRILL P 19:10 - 00:00 4.83 DRILL P Spud Date: 12/30/2005 Start: 12/28/2005 End: 1/22/2006 Rig Release: 1/22/2006 Rig Number: Phase Description of Operations PROD1 on the Vast well 1 L-25. This is the first trip in the hole with a motor with a wearpad on this well. 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. PROD1 Pickup new motor with the champhered wear pad. BHA #7. PROD1 RIH with BHA #7 to begin drilling the Li lateral section. No problems running in the hole. The new motor solved the problem. PROD1 Continue RIH. PROD1 Log tie in pass down from 7850' down past RA tag. Make -12' correction. 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. PROD1 Geo needs to see a sample of the sand we are now drilling. Make a slow wiper trip while circulating bottoms up to get a sample for the Geo. PRODi Resume drilling. Hit hard streak at 8262 drilled slow to 8266 then back to 50'/hr. At 8278' lost partial returns 1.56/1.21 pit vol 380bb1s PROD1 PU to 8250' gaining returns 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'/hr 1.62/1.62/ PROD1 Wiper trip back to window. Last 60' of hole ratty both up and back. 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. PROD1 Drill ahead f/ 8447' 1.57/1.53/3600fs pit vol 357bb1s ann=3900 ecd 12.55ppg 1-2k wob 20-30'/hr PROD1 Drill ahead ff 8495' 1.58/1.56/3600fs pit vol 350 bbls slow drilling on siderite. PROD1 Wiper trip to window. Clean PU off bottom. Ratty up to 8300', clean to the window. Ratty running back in the hole. PROD1 Resume drilling. Free spin 3350 psi at 1.46 bpm. Drilling at 1.46/1.47/3420 psi. ROP=50 fph. PVT=344 bbls. BHP=3912 psi. ECD=12.51 ppg. IAP=750 psi. OAP=188 psi. String wt = 5001bs. DHW06=26601bs. 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 PRODi Wiper trip to window. Clean PU off bottom. A few minor Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 5 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 I, Hours Task ~ Code' NPT ~ Phase Description of Operations _. _ _ - 1/2/2006 101:45 - 02:30 0.75 DRILL P PROD1overpulls, but nothing bad on the way to the window. Clean 02:30 - 06:00 3.50 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:30 1.00 DRILL P PRODi 07:30 - 10:40 3.17 DRILL P PROD1 10:40 - 12:05 1.42 DRILL P PROD1 12:05 - 14:50 2.75 DRILL P PROD1 14:50 - 17:00 2.17 DRILL P PROD1 17:00 - 18:00 1.00 DRILL P PRODi 18:00 - 18:50 0.83 DRILL P PROD1 18:50 - 19:50 1.00 DRILL P PROD1 back in the hole. 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. Drilling ahead f/ 8780' 1.54/1.52/3600fs 200-300mw ann=3980 ecd= 12.74 1-2k wob 20-30'/hr 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. Wiper trip to window 30'/hr 1.64 5-10k overpulls first 100'. Minor overpulls at 8500-8495, clean going in. 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 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. 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 Wiper trip to window. Pull tight at 9050' Hole in great shape but lost 16 bbls mud during wiper trip Drill ahead f/ 9120' 1.53/1.15/3650fs 120-150TF 75deg inc 2k wob 60-70'/hr in Al sand Alerted SLB cementers of possible job. Could be ready to pump +/- 8hrs 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. Geo called this TD. Call Baker TT to get crossovers needed to Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Operations Summary Report Page 6 of 23 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: ~~~ Hours Task Code NPT Phase Description of Operations Date From - To _ ~ ~ -_ 1 -- -- 1/2l2006 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 I 0.251 DRILL I P I I PROD1 20:05 - 20:30 0.42 DRILL P PROD1 20:30 - 20:55 0.42 DRILL P PROD1 20:55 - 21:35 I 0.671 DRILL I P I I PROD1 21:35 - 23:15 I 1.671 DRILL I P I I PROD1 23:15 - 23:35 ~ 0.33 ~ DRILL ~ P ~ ~ PROD1 23:35 - 00:00 0.42 DRILL P PROD1 1/3/2006 00:00 - 04:00 4.00 DRILL C PROD1 04:00 - 04:15 0.25 DRILL C PROD1 04:15 -04:50 0.58 LCR C PROD1 04:50 - 05:15 I 0.421 LCR I C I I PROD1 05:15 - 06:40 1.424 LCR C PRODi 06:40 - 07:20 0.671 LCR C PROD1 07:20 - 09:00 1.67 LCR C PROD1 09:00 - 09:15 0.25 LCR C PROD1 09:15 - 10:45 ~ 1.50 ~ LCR ~ C ~ ~ PROD1 10:45 - 11:00 ~ 0.25 ~ LCR ~ C ~ ~ PROD1 11:00 - 11:45 0.75 LCR C PROD1 11:45 - 14:00 2.25 DRILL C PROD1 Log tie in pass down over RA tag in whipstock. Make +0.5' correction. RIH, smooth. Back on bottom. Tag depth is 9200.2'. Circulate LCM pill to bottom to slow losses 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 bbl/hr. 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 while pulling up hole. Bullheaded 5 more bbls away from 8300 psi. Only had a 200 psi pressure bump during squeeze. 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. Tag up at surface. Shut EDC. Perform no flow test prior to unstabbing injector: Hold PJSM while checking well for flow. Discuss plan forward for laying down BHA. Lay down BHA #7. Wait on 1-1/4" CSH from Nordic 1. PJSM Re: running CSH. Make up BHA #8, Cement nozzle, R-1 checks, 15 jts of 1-1/4" CSH, X/O. Disconnect UOC> make end of eline water tight. Make up CTC and stab injector. RIH with BHA #8 to P&A L1 lateral. PJSM with all hands. Review cementing procedures, WHP management etc. Same time shut-in choke and bullheaded 16bbls to clear openhole of any gas. RIH to 9200' without problems. Circulate at min rate. Wait on a load of mud that will 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. TOH following pressure schedule. Close SSSV trapping 1000psi. Park at 500' bleed off well and monitor for flow PJSM: review plan forward for I/d of 1-1/4" CSH. Monitor well same time. LD BHA. Found 400" in CSH Waterproof end of a-line. Do Slack management 14:00 - 15:00 1.00 DRILL C PROD1 Attach CTC and 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: 1/23/2006 1:06:36 PM BP EXPLORATION Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To .Hours Task ~ Code - - - _~_ 1 /3/2006 ~ 17:00 - 17:15 0.25 ~ LCR I C 17: i 5 - 17:45 0.50 LCR C 17:45 - 20:15 2.50 LCR C 20:15 - 20:45 0.50 LCR C 20:45 - 21:45 1.00 LCR C 21:45 - 22:30 I 0.75 I LCR I C 22:30 - 00:00 1.50 LCR C 1/4/2006 00:00 - 00:30 0.50 LCR C 00:30 - 01:00 0.50 LCR C 01:00 - 02:00 1.00 STKOH P 02:00 - 03:20 1.331 STKOH ~ P 03:20 - 03:45 0.42 STKOH P 03:45 - 04:45 1.00 STKOH P 04:45 - 06:00 I 1.25 i STKOH I P 06:00 - 07:40 1.67 STKOH { P 07:40 - 08:40 1.00 STKOH P 08:40 - 09:55 i 1.25 STKOH ~ P 09:55 - 10:15 I 0.331 STKOH I P 10:15 - 10:30 I 0.251 STKOH I P 10:30 - 10:40 I 0.171 STKOH I P 10:40 - 11:15 i 0.58 ~ STKOH ~ P 11:15 - 12:45 1.50 STKOH P 12:45 - 13:00 ` 0.25 STKOH P Page 7 of 23 Spud Date: 12/30/2005 Start: 12/28/2005 End: 1/22/2006 Rig Release: 1/22/2006 Rig Number: NPT ~ Phase Description of Operations PROD1 PJSM with rig hands and Baker TT hand to discuss job, and plan forward for setting IBP. PRODi Pick up BHA #9, IBP setting BHA. PROD1 RIH with BHA #9 to set IBP. PROD1 Log gr tie in from 8030'. Subtract 11' correction. 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. 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'. PROD1 Pull out of hole. Displace well to new mud for sidetrack. PROD1 Continue to pull out of hole. PJSM in ops cab to discuss undeploying BHA. PROD1 Get off well. Unstab coil. LD Baker IBP running tools. PROD1 Mu BHA #10 (OH sidetrack with 1.8 AKO & R60ST bit). Stab coil. Get on well. PROD1 Run in hole. Open SSSV. Continue in hole maintaining BHP as per schedule. PROD1 Log gr tie in from from 8040'. Subtract 7' correction. 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. PRODi Begin troughing down at 160R TF, 20 fph. 3050 psi fs at 1.47 in/out. PROD1 Continue troughing. PROD1 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. PROD1 Time milling at 2 fph. DHWOB= 200 lbs. String wt=7230 lbs. 3164 psi at 1.48 bpm. WHP=O, BHP=3829 psi. ECD=12.26 ppg. PVT=310 bbls. PRODi 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. PROD1 Start drilling at 10 fph. Taking wt and getting motor work. Life is good. DHWOB=300 lbs. 1.48/1.46/3300 psi. String wt = 6200 lbs. Near bit INC is changing from original wellbore. PROD1 Start drilling at 30 fph. Good wt on bit andmotor work. DHWOB=1500 lbs. 1.48/1.45/3350 psi. PVT=318 bbls. INC confirms that we have a sidetrack. PROD1 Back ream at high side and 45 LOHS and 45 ROHS to knock off the lip. Now have some slight losses. 1.48/1.38/3479 psi. PVT=318 bbls. PROD1 POH to pick up lateral section BHA. 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 7:06:36 PM BP EXPLORATION Page 8 of 23 Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To !Hours Task ~ Code 1/4/2006 13:00 - 13:30 0.50~STKOH P 13:30 - 13:45 0.25 I BOPSUR P Start: 12/28/2005 Rig Release: 1/22/2006 Rig Number: Spud Date: 12/30/2005 End: 1/22/2006 13:45 - 14:30 I 0.751 DRILL I P I I PROD2 14:30 - 15:40 1.17 DRILL P PROD2 15:40 - 16:25 0.75 DRILL N SFAL PROD2 16:25 - 16:35 0.17 DRILL N SFAL PROD2 16:35 - 17:10 0.58 DR1LL N SFAL PROD2 17:10 - 18:00 0.83 DRILL N SFAL PROD2 18:00 - 18:45 0.75 DRILL P PROD2 18:45 - 19:00 0.25 DRILL P PROD2 19:00 - 22:00 3.00 DRILL P PROD2 22:00 - 23:00 1.00 DRILL P PROD2 23:00 - 00:00 1.00 DRILL P PROD2 1/5/2006 00:00 - 02:15 2.25 DRILL P PROD2 02:15 - 03:15 1.00 DRILL P PROD2 03:15 - 06:00 2.75 DRILL P PROD2 06:00 - 09:00 3.00 DRILL P PROD2 09:00 - 09:40 I 0.671 DRILL I P I I PROD2 09:40 - 10:10 I 0.501 DRILL I P I I PROD2 10:10 - 10:20 0.17 DRILL P PROD2 10:20 - 10:40 0.33 DRILL P PROD2 10:40 - 13:40 3.00 DRILL P PROD2 13:40 - 14:40 I 1.001 DRILL I P I I PROD2 14:40 - 15:30 I 0.831 DRILL I P I I PROD2 15:30 - 17:45 I 2.251 DRILL I P I 1 PROD2 Description of Operations Lay down BHA #10, L1 lateral OH sidetracking BHA. Function test BOP stack as per 7 day AOGCC test requirement. All functioned properly. Make up BHA #11, first L2 lateral section BHA. BHA consists of hycalog 2.70" x 3.0" bicenter bit with Full Round TREX cutters, a 0.9 deg AKO motor, and bull BHI MWD BHA. RIH with BHA #11, to begin drilling the L2 {ateral section. 4800'. Found leaking O-Ring on lubricator connection below packoff. Need to change out. POOH for repair to lubricator O-Ring. Tag back up at surface. Flow check well. Discuss plan forward for chaning out O-Ring. Check well again. No flow observed. Unstab lubricator, break OC. Break out upper lubricator. Replaced damaged O-Ring on lubricator. Stab lubricator again. Make up OC. Stab injector. Run back in hole with BHA #11 from 4800'. Continue RIH. Log gr tie in from 8040'. Subtract 9' correction. Drill ahead from 8305'. 3550 psi fs at 1.46 in/1.4 out. DPSI: 150-200. DHWOB: 1.0-2.0 k#. WHPIBHP/ECD: 15/3911/12.53 ppg. IA/OA/PVT: 70/74/267. Losing about 5 bpm mud. ROP: 40-60 fph. Wiper trip to window. Ho{e smooth. Drill ahead from 8450'. Drill ahead to 8600'. Wiper trip to window. Hole smooth. Drill ahead to 8690'. 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=O psi. BHP=3928 psi. ECD=12.56 ppg. String wt = 3900 lbs. DHWOB=1200 lbs. Out rates went from 1.42/1.39 to 1.42/1.49. 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. 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. Log tie in pass down. Make +2.5' correction. Run back to bottom on wiper trip. Drill ahead. Free spin 3700 psi at 1.4 bpm. WHP=150 psi. Lost 8 bbls in last hour. Wiper trip to window. Clean PU off bottom. Clean up to window and back down. Better than last wiper trip. Resume drilling. PVT=312 bbls. WHP=250 psi. BHP=4125 psi. ECD=13.19 ppg. 1.39/1.14/3948. Free spin 3800 psi at 1.4 bpm. 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 NPT I Phase PROD1 PROD2 Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 9 of 23 Operations Summary Report Legal Wel! Common W Event Nam Contractor Rig Name: Date -_ Name: 3 ell Name: 3 e: Name: From - To ~ H-14B H-14B DRILL+C NORDIC NORDIC Hours OMPLETE CALISTA 2 Task ~ Code NPT - Spud Date: 12!30/2005 Start: 12/28/2005 End: 1/22/2006 Rig Release: 1/22/2006 Rig Number: Description of Operations , ' Phase ~ 1/5/2006 15:30 - 17:45 2.25 DRILL P PROD2 medium (250 micron) size LCM to see if we can slow down fosses 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. Hofe 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#. WHP/BHP/ECD: 249/4203/13.44 ppg. IA/OA/PVT: 43/42/395 bbls. Continue to lose 15 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 in/1.30 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 in/1.45 out. 06:00 - 07:10 1.17 DRILL P PROD2 Resume drilling. 1.55/?/4220 psi. WHP=322 psi. BHP=4236 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=5001bs, 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 I 1.001 DRILL I P I I PROD2 11:15 - 15:15 4.00 DRILL P PROD2 15:15 - 16:15 i.00 DRILL P PROD2 16:15 - 16:20 0.08 DRILL P PROD2 16:20 - 17:15 0.92 DRILL P PROD2 17:15 - 18:00 0.75 DRILL P PROD2 18:00 - 20:00 I 2.001 DRILL I P 20:00 - 22:30 2.50 DRILL P 22:30 - 00:00 1.50 DRILL P 1/7/2006 ~ 00:00 - 03:00 ~ 3.00 ~ DRI LL ~ P PROD2 Free spin 4190 psi at 1.53 bpm. Tag bottom, resume drilling 1.54/1.36/4300 psi. PVT=357 bbls. Lost 57 bbls in 2:45 hours. Average of 21 bbls/hr. PVT=336 bbls. Lost 21 bbls in last hour. Wiper trip to window. Clean PU off bottom. Clean in OH. Log tie in pass. Make +2' correction. Run back in hole. Clean to bottom. 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 lbs. DHWOB=800 lbs. IAP=80 psi, OAP=95 psi. Drill ahead from 9750'. PVT: 405 bbls. Continue climb at 91.7 deg, looking for A sand. WHP/BHP/ECD: 375-400/4246/13.6 ppg. Some crude in mud, occasional gas alarms at shaker. Attempt to adjust WHP/BHP to minimize crude influx. PROD2 Wiper trip to window. 16.5k# up wt off btm. Hole smooth in both directions. 3955 psi fs at 1.46 in/1.31 out. PROD2 Drill ahead from 9850'. PVT: 344 bbls. Have lost 13.5 BPH since 1800 hrs. PROD2 Drill ahead from 9910. 4025 psi fs at 1.54 in/1.32 out. DPSI: 200-300. DHWOB: 1.43 k#. WHP/BHP/ECD: 420/4356/13.94 Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 10 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 i Hours ~ Task ~ Code ~ NPT Phase ~'~ Description of Operations 1!7/2006 ~ 00:00 - 03:00 I 3.00:.. ~ _ _ -- __ DRILL ~ P ~ PROD2 ppg. IA/OA/PVT: 115/107/294 bbls. INC/AZM/TF: 03:00 - 04:30 1.50 DRILL P PROD2 04:30 - 06:00 1.50 DRILL P PROD2 06:00 - 07:00 1.00 DRILL P PROD2 07:00 - 07:55 0.92 DRILL P PROD2 07:55 - 08:00 ~ 0.08 ~ DRILL ~ P ~ ~ PROD2 08:00 - 08:45 0.75; DRILL P PROD2 08:45 - 09:55 1.17 DRILL P PROD2 09:55 - 10:10 0.25 DRILL P PROD2 10:10 - 11:15 1.08 DRILL P PROD2 11:15 - 13:00 1.75 DRILL P PROD2 13:00 - 14:00 I 1.001 DRILL I P I I PROD2 14:00 - 15:30 1.50 DRILL P PROD2 15:30 - 17:00 1.50 DRILL P PROD2 17:00 - 18:00 I 1.00 (DRILL I P I I PROD2 18:00 - 20:00 I 2.001 DRILL I P I I PROD2 20:00 - 22:00 I 2.001 DRILL I P I I PROD2 22:00 - 00:00 I 2.001 DRILL I P I I PROD2 1/8/2006 100:00 - 03:00 I 3.001 DRILL I P I I PROD2 03:00 - 04:30 ~ 1.50 ~ DRILL ~ P ~ ~ PROD2 91-92/19-35/90R-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. Wiper trip to window. 4153 psi fs at 1.53 in. Hole smooth. Drill ahead from 10,000'. Continue drilling ahead, In shale trying to drill down and find 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. Continue drilling ahead. Lost 14 bbls in last hour. String wt = -15001bs. DHW06=16001bs. Had hard spot in drilling at 10127'. Broke thru something and 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. PVT=219 bbls. Lost 23 bbls in last hour. Wiper trip to window. Clean PU off bottom at 16 klbs. Log tie in pass over RA tag. Make +2' correction. RBIH on wiper trip. Taking on new mud. 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. 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. 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. PVT 355 bbls. Lost 31 bbls in last 1-1/2 hours. Top off pits with new mud. Broke thru the A6, back into good sand. ROP up to 50 fph. PVT=433 bbls. Drill ahead from 10275'. 4020 psi fs at 1.45 in/1.26 out. 408 bbls at i 830 hrs. 12 BPH loss rate. Having weight transfer problems. Decide to wiper trip early. Wiper trip to window. 16.3k# up wt off btm. PVT: 385 at start of trip. 355 bbls at end of trip. Hole smooth. 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. Drill ahead f/ 10,295'. 4100 psi fs at 1.53 in/out 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: 85-83/25-55/ 180-230 deg. Continued hard slow drilling. Losses variable from zero to 18 BHP. Wt transfer still looks adequate. Able to stall mtr too. Drill ahead from 10320'. PVT: 312 bbls. INC: 82-83 deg. Plan Printed: 7/23/2006 7:06:36 PM BP EXPLORATION Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Start: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date 1 /8/2006 1 /9/2006 From - To Hours Task Code NPT ~ Phase _~ 103:00 - 04:30 1.50 ~ DRILL I P ~ ~ PROD2 04:30 - 05:15 0.75 DRILL P 05:15 - 06:00 0.75 DRILL P 06:00 - 07:05 1.08 DRILL P 07:05 - 07:20 I 0.251 DRILL I P 07:20 - 09:20 I 2.001 DRILL I P 09:20 - 11:15 I 1.921 DRILL I P 11:15 - 11:30 0.25 DRILL P 11:30 - 12:50 1.33 DRILL P 12:50 - 13:30 I 0.671 DRILL I P 13:30 - 14:45 I 1.25 ~ DRI LL P 14:45 - 16:30 I 1.751 DRILL I P 16:30 - 18:00 I 1.501 DRILL ( P 18:00 - 19:00 1.00 DRILL P 19:00 - 22:00 3.00 DRILL P 22:00 - 00:00 2.00 DRILL P 00:00 - 03:45 f 3.75 DRILL P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Page 11 of 23 Spud Date: 12/30/2005 End: 1 /22/2006 Description of Operations to hold this angle until finding the A3/A2. See a few drill breaks, but then ROP became even slower. Wiper trip back to window. Pull out of hole to check BHA. 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. 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. 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. 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. Log tie in pass over RA tag. Make -10.5' correction. Run to bottom. No problems in open hole down to 10130', then had to work it to bottom. 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. Free spin at reduced pump rate is 4140 psi at 1.37 bpm. Free spin 4000 psi at 1.3 bpm. Tag bottom, resume drilling. 1.3/?/4400 psi. Swapping to new mud to try to reduce pump pressures. ROP=iS fph. DHWOB=2800 lbs. String wt = 1080 lbs. WHP=500 psi. ECD=14.06 ppg. BHP=4407 psi. 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. Broke back into good sand. Continue drilling down to find the A2. Drill ahead from 10430'. PVT: 436 + 105 bbls. 4100 psi fs at 1.31 in. 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 trom 10175' to 10280'. Drill ahead from 10,450'. Plan is to continue to hold 83-84 deg incl to stay in A3/A2 zones. Drill ahead from 10533'. 4100 psi fs at 1.35 in/1.30 out. DPSI: Printed: 7/23/2006 7:06:36 PM BP EXPLORATION Page 12 of 23 Operations Summary Report Legal Well Name: 3 H-146 Common W ell Name: 3 H-14B Spud Date: 12/30/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALIS TA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours ~ Task Code ~ NPT Phase Description of Operations E 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/AZMlTF: 82-83/12-54/185-285 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. BHP=4420 psi. ECD=14.05 ppg. DHWOB=1200 lbs. String wt = 700 lbs. 10:00 - 11:30 1.50 DRILL P 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 will 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 Pull 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 PROD2 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. 19:30 - 22:15 2.75 CASE P RUNPRD MU 59 jts of 2-3/8" slotted & solid, 4.4#, L80, STL liner. Indexing guide shoe on btm. Weatherford 2.5" od aluminum billet on top. OAL: 1916'. 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. Found 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 7:06:36 PM BP EXPLORATION Operations Summary Report Legal Well Name: 3H-146 Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Start: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date ;From - To j Hours Task - -~ -- I _- 1/10/2006 x00:30 - 02:15 ~ 1.75 ~ CASE Code I; NPT II Phase P 02:15 - 03:00 ! 0.75 I CASE I P 03:00 - 05:30 2.50 CASE N 05:30 - 06:00 0.50 CASE N 06:00 - 06:10 0.17 CASE N 06:10 - 06:30 0.33 CASE N 06:30 - 08:00 1.50 CASE N 08:00 - 12:00 4.00 CASE N 12:00 - 12:15 0.25 CASE P 12:15 - 12:25 0.17 CASE P 12:25 - 13:00 0.58 CASE P 13:00 - 14:25 1.42 CASE P 14:25 - 14:45 I 0.331 CASE I P 14:45 - 15:05 ~ 0.33 ~ CASE ~ P 15:05 - 16:30 I 1.421 CASE I P Page 13 of 23 Spud Date: 12/30/2005 End: 1/22/2006 Description of Operations 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 1100 psi. Work down to 9831'. Stack max wt several times. 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. DPRB RUNPRD Close EDC. Circulate down coil at min rate. Pull out of hole. Close SSSV. Continue to POH to surface. DPRB RUNPRD Flow check. Get off well. Unstab coil. LD BHA tools. 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. DPRB RUNPRD PJSM to discuss plan forward with rig crew. Discuss hazards of tripping pipe. Assign jobs, and review mitigations to hazards. DPRB RUNPRD Stand back 14 stand of 2-3/8" liner. DPRB RUNPRD Discuss plan with town again. Confirmed we will run liner in 2 sections. Contact Baker TT. They have about 1-1l2 hrs in equipment preparation yet. Wait on Baker. RUNPRD Baker hand on location. PU deployment sleeve and bottom nose. RUNPRD PJSM prior to making up Baker eq. RUNPRD Make up deployment sleeve, BOT GS, BHI MWD tool. Stab injector. Surface check MWD tools. All passed ok. 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 2-3/8" Solid tubing 14 jts of 2-3/8" Slotted tubing Unique indexing guide shoe. Total liner run in hole this run is 1009.8'. RUNPRD Weight check at window up wt = 16500 lbs. RIH wt at the window=7000 lbs. DHWOB at window = -2300 lbs. Pumps down. Wt bobble at sidetrack 8273'. Depth String Wt. DHWOB. 8400' 7000 -12001bs. 8700' 6500 501bs. 9000' 5000 18601bs. 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. RUNPRD Continue RIH with liner. Depth String Wt. DHWOB 9200 3800 22801bs 9400 2500 17001bs Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 14 of 23 Operations Summary Report Legal Well Name: 3H-146 Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date i From - To Hours I! Task ;Code ~I NPT - -- - 1/10/2006 15:05 - 16:30 ~ 1.421 CASE I P 16:30 - 18:20 ~ 1.83 ~ CASE ~ N 18:20 - 19:30 I 1.171 CASE I N 19:30 - 21:30 I 2.001 CASE I P 21:30 - 22:00 ~ 0.50 ~ CASE ~ P 22:00 - 23:00 I 1.001 CASE I N 23:00 - 00:00 I 1.001 CASE I N 1/11/2006 100:00 - 00:30 I 0.501 CASE I N 00:30 - 00:40 ~ 0.17 ~ CAS E ~ N 00:40 - 02:15 1.58 CASE I N 02:15 - 02:20 0.08 CASE N 02:20 - 04:30 2.17 CASE N 04:30 -04:40 0.17 CASE N 04:40 - 05:15 0.58 CASE N Spud Date: 12/30/2005 Start: 12/28/2005 End: 1/22/2006 Rig Release: 1/22/2006 Rig Number: Phase ' Description of Operations RUNPRD 9600 3000 24401bs 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 Ibs 1.47 bom 4725 psi PU 50K Attepmt to RIH Lock up at 10132. CirculaTE A7 1.4 BPM 10133 -7200 6120 Holding 300 PSI 1.47 bpm No Go 10133 -4400 6700 Holding 0 PSI 1.47 bpm No Go Decided to release liner. notify anchorage of liner release. 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. 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. 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 w1 1000 psi 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 RUNPRD MU BBT GS w/jars, wt bars and accelerators. Add MWD assy w/o DPS and DGS since BHI have only one functional DPS and will be jarring RUNPRD RIH w/ BHA #15 circ thru GS 0.26/1950 following pressure schedule. Open TRSSSV w/ 1000 psi 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'lmin continue to circ 0.2/1800 holding 600 psi whp 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 RUNPRD PUH to 45k and were latched on first try. Hold 45k at 9124.7' and jars tired 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 RUNPRD Release GS from liner 1.25/4000 RUNPRD POOH thru open hole, clean. POOH following pressure schedule. Divert returns to tlowback tank when they were quite crude. Swap back to gas buster for remainder of trip OOH. Close TRSSSV w1 1050 psi. Tag up, chk for flow RUNPRD Safety mtg: LD BHAlcleanout choke RUNPRD LD fishing assy Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 15 of 23 Operations Summary Report Legal Well Name: 3 H-14B Common W ell Name: 3H-146 Spud Date: 12/30/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALIS TA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date From - To Hours i Task Code ~ NPT i Phase I' Description of Operations - - - ~ __- _. _ - _ - l _ - _ _ _ - _ -- 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 asst' w! BHA 20:15 - 22:30 2.25 CASE P RUNPRD MU WFT GS Anti-turn Spear onto 4 ea slotted 2-318" 4.43# L-80 STL liner doubles from derrick. Add remainder of stood back doubles. POOH LD 18 singles. Add WFT aluminum WS asst' and MWD asst' 22:30 - 00:00 1.50 CASE P RUNPRD RIH w/ section 2 of L2 liner asst'. Circ thru open EDC 0:2611700 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 wt, 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 returns, 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 PROD3 MU sidetrack asst' 03:50 - 05:20 1.50 STKOH P PROD3 RIH w/ BHA #17 (1.5 deg motor, new STR324 bit) circ thru EDC 0.2/1600 and following pressure schedule. Open TRSSSV w/ 1100 psi 05:20 - 05:35 0.25 STKOH P PROD3 Log tie-in down from 8050', corr -15.5'. 05:35 - 06:20 0.75 STKOH P PROD3 Wiper to top of billet. Tag top of billet at 8859.3. 06:20 - 09:00 2.67 STKOH P PROD3 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 C~ 3800 psi , ROP 30. Dress window TF 458, 908 & 1508 09:00 - 11:00 2.00 STKOH P PROD3 POH following pressure schedule. 11:00 - 11:15 0.25 STKOH P PROD3 Flow Check to confirm SSSV integrity. OK. 11:15 - 12:15 1.00 STKOH P PROD3 Swap bit and dial down motor bend. 12:15 - 13:55 1.67 STKOH P PROD3 RIH following pressure schedule. 13:55 - 14:10 0.25 STKOH P PROD3 Log tie-in. Correction -13.5'. 14:10 - 17:10 3.00 STKOH P PROD3 Directionally 1.57 / 1.56 bpm C~3 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 PROD3 Wiper to window PVT 404 18:10 - 19:40 1.50 DRILL P PROD3 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/ returns cut to 9.25 ppg. Swap to left at 9100' 19:40 - 20:10 0.50 DRILL N SFAL PROD3 Wiper while WO BHI to reconcile surveys-a software thing 20:10 - 21:10 1.00 DRILL P PROD3 Dril{ from 9106' 1.5511.10!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 1:06:36 PM BP EXPLORATION Operations Summary Report Legal Well Name: 3H-14B Common Well Name: 3H-146 Event Name: DRILL+COMPLETE Start: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date ~ From - To it Hours I~ Task Code NPT II Phase - -_ - ~ - - 1/12/2006 20:10 - 21:10 ~ 1.00 ~ DRILL P ~ I PROD3 21:10 - 21:55 0.75 DRILL P PROD3 21:55 - 22:10 0.25 DRILL P PROD3 22:10 - 22:55 0.75 DRILL P PROD3 22:55 - 00:00 1.08 DRILL P PROD3 1/i3/2006 ~02:~5-04:35 2.33 DRILL P PROD3 04:35 - 05:30 0.92 DRILL P PROD3 05:30 - 05:45 0.25 DRILL P PROD3 05:45 - 06:00 0.25 DRILL P PROD3 06:00 - 08:30 2.50 DRILL N RREP PROD3 08:30 - 09:05 I 0.58 DRILL P PROD3 09:05 - 12:17 ` 3.20 DRILL P PROD3 12:17 - 13:55 1.63 DRILL P PROD3 13:55 - 17:30 3.58 DRILL P PROD3 17:30 - 19:10 i.67 DRILL P PROD3 19:10 - 21:00 1.83 DRILL P PROD3 21:00 - 21:30 0.50 DRILL P PROD3 21:30 - 21:40 0.17 DRILL P PROD3 21:40 - 22:50 ~ 1.17 ~ DRILL ~ N ~ ~ PROD3 22:50 - 23:10 0.33 DRILL N PROD3 23:10 - 00:00 0.83 DRILL N PROD3 1/14/2006 00:00 - 00:15 0.25 DRILL P PROD3 00:15 - 00:35 0.33 DRILL P PROD3 00:35 - 01:25 ~ 0.83 ~ DRILL ~ P ~ ~ PROD3 01:25 - 02:00 I 0.58 !DRILL I P I I PROD3 Page 16 of 23 Spud Date: 12/30/2005 End: 1 /22/2006 Description of Operations 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' Slow wiper to window while geo's determine where we are Log tie-in down from 8040', Corr +3.5' Slow wiper to TD tagged at 9162' was clean PVT 335 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' TVD and in assumed A3 that has high GR Drill from 9230-9275' at 93 deg Wiper to window was clean both directions 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 Wiper to window was clean Log tie-in down from 8040', corr +2.5' Wiper thru window. While repairing pump#2. Noticed Pump #1 leaking from liner. PU into pipe while comppetion repairs on pump #2. upon completion#1 leaking from liner repair same. RIH Directionally drilling 1.56 @ 4200 psi.3900 psi =FS, WOB 2.OK, EDC 14.0, Annular pressure 4390, Drill to 9575'. Wiper to window. Clean trip. 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. Wiper to window was clean both directions PVT 253 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 Wipers to remove DLS from TF change Break out into faster drilling at 9835' and drill to 9837' and geo not sure where we are PVT 240 Wiper up the hole at 10'lmin 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 Log tie-in down from 8040', add 6.0' Wiper back to TD Finish wiper to TD tagged at 9840' PVT 218 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 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 Drill from 9870' 1.52/1.52l4030/700l105L 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: 3 H-14B Common W ell Name: 3H-14B Spud Date: 12/30/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALIS TA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date i From - To ~ Hours ' Task ~ Code ~; NPT Phase Description of Operations 1 _ _ ~ - ~ _ _ - __ _ _ __ 1/14/2006 02:00 - 03:15 I 1.25 DRILL P PROD3 Wlper toward window while geodecide where to head next 03:15 - 03:30 0.25 DRILL P PROD3 Log tie-in down from 8040', add 2.0' 03:30 - 04:40 1.17 DRILL P PROD3 Wiper back to TD was clean 04:40 - 06:50 2.17 DRILL P PROD3 Drill from 9920' 1.50/1.50/4030/650/45L 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 PROD3 Wiper to window. 09:20 - 12:15 2.92 DRILL P PROD3 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 PROD3 Wiper to window. 13:30 - 13:45 0.25 DRILL P PROD3 Log tie-in correction +4.5'. 13:45 - 15:00 1.25 DRILL P PROD3 Wiper to TD. Tag TD at 10106' while spotting 50 bbp pill with 3#/bbl beads. 15:00 - 17:30 2.50 DRILL P PROD3 POH following pressure schedule. 17:30 - 18:15 0.75 DRILL P PROD3 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 W FT 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 RIH 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 1:25 CASE P RUNPRD POOH circ thru EDC 1.35/3400 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 C~3 1.35 bpm. Pu11 thru TRSSSV wl5k 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 i .7314200 and spend 30 minutes this time. No success at getting valve to close-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 warm Safety mtg re: pressure undeploy Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Operations Summary .Report Legal Well Name: 3H-14B Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date 1115!2006 From - To Hours Task 'Code NPT 02:35 - 04:30 I 1.92 (CASE f N 04:30 - 04:45 04:45 - 06:30 0.25 WHSUR P 1.75 WHSUR P 06:30 - 07:20 07:20 - 09:15 09:15 - 11:00 11:00 - 13:00 13:00 - 13:15 13:15 - 14:15 14:15 - 15:00 15:00 - 15:15 15:15 - 15:35 15:35 - 16:00 16:00 - 16:15 16:15 - 16:25 16:25 - 18:00 18:00 - 18:15 18:15 - 22:30 22:45 - 23:30 23:30 - 23:45 23:45 - 00:00 1/16/2006 00:00 - 02:00 02:00 - 03:40 03:40 - 04:05 04:05 - 05:00 05:00 - 08:30 08:30 - 11:00 0.83 WHSUR P 1.92 WHSUR P 1.75 WHSUR N 2.00 WHSUR N 0.25 WHSUR N 1.00 WHSUR 0.751 WHSUR I N 0.25 WHSUR N 0.33 WHSUR N 0.42 WHSUR N 0.25 WHSUR N 0.17 WHSUR N 1.58 WHSUR N 0.25 WHSUR N 4.25 WHSUR N 0.751 WHSURIN 0.25 DRILL P 0.25 DRILL P 2.00 STKOH P 1.671 STKOH I P 0.42 STKOH P 0.92 STKOH P 3.50 I STKOH I P 2.501 STKOH I P Page 18 of 23 Spud Date: 12/30/2005 Start: 12/28/2005 End: 1/22/2006 Rig Release: 1/22/2006 Rig Number: Phase Description of Operations 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 WHDTRE Safety mtg re: slack management WHDTRE Cut off CTC (no obvious scars). Reverse slack back. Wire hung up at free end. No wire movement.Reverse circulate second attempt. WHDTRE PJSM. RU cutter and cut off 200' WHDTRE Behead coil. Pull and Pressure test. WHDTRE Wait on wireline.Continue with pod replacement in #1 pump. WHDTRE RU Wireline WHDTRE PJSM with wireliners. WHDTRE PT lubricator to 2000psi..Bleed to 1175. Open up to well bore. RIH to SSSV. WHDTRE Run brush numerous passes thru SSSV/ Pressure cycle valve periodically. Run thru SSSV to see if flapper grabs brush. No Go. Valve still wide open. WHDTRE POH. Close master. Bleed off 1250 psi. WHDTRE LD brush. PU friction tool. Pressure test to 2000 psi. Bleed to 1175 psi. WHDTRE RIH with friction tool. WHDTRE Work and jar on SSSV sleeve. Sheared off WHDTRE POH. Blead off well head pressiure to 750 psi. Came right back to 1117. WHDTRE Close master. Bleed off pressure. LD and repin friction tool w/ 4 brass and sheared off WHDTRE Safety mtg re: Fresh Nordic crew, crew change/SL ops 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 318" brass shear stock in hole WHDTRE RDMO WL unit. Men are limited out on daily hours, unit has scheduled maint tomorrow, KRU has no 'Hite' shift slickliners W il! 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 PROD4 Safety mtg re: pressure deployment of BHA PROD4 MU drilling BHA PROD4 Continue pressure deployment of BHA #20 w/ 1120 psi final whp 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) PROD4 Close EDC. Log tie-in down from 8040', corr -20' 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 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'. PROD4 POH. Following the pumping schedule. to SSSV. Open EDC L'J Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Operations Summary Report Legal Well Name: 3H-14B Page 19 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 ' Phase Description of Operations __ ~ _ __ ~ _ _ ~_ i _ l _- 1/16/2006 ~ 08:30 - 11:00 ~ 2.50 ~ STKOH P ~ ~PROD4 (and wash across SSSV 1.7 BPM. Continue to POH to surface. 11:00 - 12:00 1.00 STKOH P PROD4 12:00 - 12:45 0.75 STKOH P PROD4 12:45 - 15:15 2.50 STKOH P PROD4 15:15 - 16:00 0.75 STKOH P PROD4 16:00 - 17:30 1.50 STKOH P PROD4 17:30 - 18:50 1.33 DRILL P PROD4 18:50 - 19:10 0.33 DRILL P PROD4 19:10 - 19:50 0.67 DRILL P PROD4 19:50 - 20:05 0.25 DRILL P PROD4 20:05 - 20:35 0.50 DRILL N PROD4 20:35 - 21:05 0.50 DRILL N PROD4 21:05 - 21:25 0.33 DRILL N PROD4 21:25 - 23:10 1.75 DRILL P PROD4 23:10 - 00:00 0.83 DRILL P PROD4 1/17/2006 00:00 - 00:50 0.83 DRILL P PROD4 00:50 - 02:40 1.83 DRILL P PROD4 02:40 - 03:50 1.17 DRILL P PROD4 03:50 - 04:55 1.08 DRILL P PROD4 04:55 - 05:40 0.75 DRILL P PROD4 05:40 - 05:55 0.25 DRILL P PROD4 05:55 - 06:45 0.83 DRILL P PROD4 06:45 - 12:00 5.25 DRILL P PROD4 12:00 - 13:50 1.83 DRILL P PROD4 13:50 - 13:55 0.08 DRILL P PROD4 13:55 - 16:35 I 2.671 DRILL I P I I PROD4 Attempt to bleed off. Well pressured back up/ No Luck with the wash job. PJSM for pressure undeploy. LD milling BHA and PU Nozzel. Stab onto well. PT lubricator. Open to well. RIH to 2279 to 2360. Circulate 2.0 bpm @4300 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. POH per pumping schedule. LD nozzel. PU Pressure deploy BHA. RIH w! BHA #21 circ thru bit following pressure schedule Log tie-in down from 8040', Corr -18' Wiper to TD was clean. Tag at 9201' PVT 165 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 Wiper to tie-in again. Found a spot in OH that will work at 8700' Log tie-in down from 8650', corr -2' Wiper back to TD and tagged at 9208' 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 Wiper to window while geodecide where to go next was clean. Finish mud swap Wiper back to TD while checking out pump #1 and waiting for guidance from geo's was clean Drill from 9328' 1.42/1.32/4180/550/85L w/ 50-150 psi diff, 2k wob w/ 14.27 ECD at 88 deg. Come to a halt at 9425' PVT 270 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! Break out of hard stuff at 9431' and drilling firm stuff at 30'/hr Wiper to window was clean Tie-in log correction +4'/ Wiper back to TD Directionally drill 1.49 bpm X3900 psi FS = 3800psi.407 psi differentail, WOB iK, ECD 14.1, TF 310. Wiper to window was clean both directions Drill from 9625' 1.51/1.45/4000/600/1008 w/ 100-200 psi diff, 1-2k wob w/ 14.20 ECD at 96 deg to 9626' (6008' 7VD) and need to geodecide again 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-146 Event Name: DRILL+COMPL ETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ' Hours i Task Code NPT 1/17/2006 16:35 - 16:55 0.33 DRILL P 16:55 - 17:15 0.33 DRILL P 17:15 - 20:35 3.33 DRILL P 20:35 - 21:35 1.00 DRILL P 21:35 - 21:45 0.17 DRILL P 21:45 - 22:45 1.00 DRILL P 22:45 - 00:00 1.25 DRILL P 1/18/2006 00:00 - 00:30 0.50 DRILL P 00:30 - 04:45 4.25 DRILL P 04:45 - 05:45 1.00 DRILL P 05:45 - 06:00 0.25 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 09:30 2.50 DRILL P 09:30 - 10:40 1.17 DRILL P 10:40 - 10:50 0.17 DRILL P 10:50 - 12:00 1.17 DRILL P 12:00 - 13:00 1.00 DRILL P 13:00 - 15:00 V 2.001 DRILL I P 15:00 - 16:00 1.00 DRILL N 16:00 - 16:15 0.25 WHSUR N 16:15 - 20:20 4.08 DHEQP N 20:20 - 21:50 I 1.501 DHEQP { N 21:50 - 00:00 2.171 DHEQP N Spud Date: 12!30!2005 Start: 12/28/2005 End: 1 /22/2006 Rig Release: 1/22/2006 Rig Number: Phase ' Description of Operations PROD4 Wiper back to TD PROD4 Received new targets from town. Circ while plan how to get there PROD4 Drill from 9626' 1.5/1.42/4030/650/1508 PROD4 Wiper back to window. No problem areas. PROD4 Log tie-in to RA tag. +2.5' PROD4 Wiper trip to bottom. Clean to bottom. PROD4 WOO from town geos. Plan forward is to drop 75' tvd thru all of A sands. No liner planned for this lateral. PROD4 RIH to bottom. 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 PROD4 Wiper to window. No problems PROD4 Tie-into RA tag. +1' correction PROD4 Wiper back to bottom, clean 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 PROD4 Wiper to window, clean PROD4 Log tie-in down from 8040', Corr +1.5' PROD4 Wiper back to TD tagged at 10070' (official TD of L4) was clean PROD4 Wiper back to window leaving fresh 9.9# mud w/ max tubs in the open hole 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 PROD4 Pressure undeploy w/ final 1240 psi. LD drilling BHA. MI HES WHDTRE Safety mtg re: WL ops WHDTRE RU HES WL tools 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. WHDTRE Add 5' section of lubricator. PU tools. PT lubricator to 2k. RIH and set slip-stop catcher 1st full jt below SSSV. WHDTRE PU Z5 tool. RIH. Engage SSSV sleeve. Spang up several times. Pull to 1400#. Apply hyd pressure to SSSV. Nowt 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: 1/23/2006 1:06:36 PM BP EXPLORATION Page 21 of 23 Operations Summary Report Legal Well Name: 3 H-14B Common W ell Name: 3 H-14B Spud Date: 12/30/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/28/2005 End: 1/22/2006 Contractor Name: NORDIC CALIST A Rig Release: 1/22!2006 Rig Name: NORDIC 2 Rig Number: Date From - To II Hours Task Code I NPT Phase i Description of Operations 1/18/2006 21:50 - 00:00 2.17 DHEOP 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 DHEOP 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 MV/SV 1200psi on well. RIH 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 1.54/32340 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. Held 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 BTT deployment sleeve w/ GS. Install BHI MWD. Fill hole and has taken progressively less each fill 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 returns 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 returns initially, then full returns 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 5276' and CBU to 1/1 returns. Swap to pumping mixed fluids at avg 11.4 ppg since have 100 bbls of mixed returns and getting avg 10.5 ppg back at 0.6/2000 at 90'/min. Continue RIH 10:55 - 11:20 0.42 CASE P RUNPRD 8000' 19.Ok, 6.5k 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 Common Well Name: 3H-14B Event Name: DRILL+COMPLETE Start: 12/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/22/2006 Rig Name: NORDIC 2 Rig Number: Date 1 /20/2006 From - To Hours ' Task Code ~ NPT 'I Phase 11:20 - 11:45 ~ 0.42 ~ CASE ~ P ~ ~ RUNPRD 11:45 - 12:20 ~ 0.58 ~ CASE ~ P ~ ~ RUNPRD 12:20 - 13:15 I 0.921 CASE I P I I RUNPRD 13:15 - 14:45 I 1.501 CASE I N I I RUNPRD 14:45 - 17:05 I 2.331 CASE I N I I RUNPRD 17:05 - 18:30 1.42 CASE N RUNPRD 18:30 - 19:00 0.50 CASE N .RUNPRD 19:00 - 20:00 1.00 CASE N RUNPRD 20:00 - 20:30 I 0.501 CASE I N I I RUNPRD 20:30 - 20:50 I 0.33 CASE N RUNPRD 20:50 - 21:00 0.17 CASE N RUNPRD 21:00 - 23:45 2.75 CASE N RUNPRD 23:45 - 00:00 0.25 CASE N RUNPRD 1/21/2006 00:00 - 01:30 1.50 CASE N RUNPRD 01:30 - 01:45 0.25 CASE N RUNPRD 01:45 - 03:00 1.25 CASE N RUNPRD 03:00 - 06:00 I 3.001 CASE I N I I RUNPRD Page 22 of 23 Spud Date: 12/30/2005 End: 1/22/2006 Description of Operations downs and was solid (acts like GS hanging up on bottom of window). PUH slow to 9450' and circ to warm up CT at 0.25 bpm 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 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' 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 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 RIH w/ BHA #25 (GS and agitator) following pressure schedule Log tie-in -20' correction. tag TOL at 8028'. Attempting to work liner down with Agitator. 1.1 bpm/.87/3800J250whp latched into liner pp= 4160psi stack out CT wt +/- 9k. PU off liner check wt 18k No visable 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. 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. Log tie-in. +4' RIH tagged TOL same place 8028' 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 TOH Finish TOH. PJSM review Pressure Undeployment procedures. Close 2-3/8" combi's. Push/Pull test. Bleed down lubricator. Unstab setback injector and circulate. Pressure undeploy BHA. WO SWS. Grease injector. Check R1 check valves -good. Printed: 1/23/2006 1:06:36 PM BP EXPLORATION Page 23 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 I! From - To ~~ Hours Task Code ~! NPT II Phase i Description of Operations ~ - - --- - - -- i - ~ - - -_ _ _ - 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 THA 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 asst'. 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 asst' 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 asst' 16:35 - 18:10 1.58 WHSUR P POST RIH w/ nozzle asst' 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 UOC. 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 lower 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 C~ 0600 hrs Further entries for day will be found under 1 Q-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 Riq: Nordic #2 POST RIG WORK 01 /26/06 TAGGED TOP OF LINER W/ 20' OF 1 3/4 O.D. DRIFT C~ 8026' RKB. WORKED 700LS TO HOP INTO LINER AND DRIFTED DOWN TO 8063' RKB. PERFORMED SBHPS W/ DUEL PANEX GAUGES @ 8026' RKB (4183 PSI @ 143 DEG} AND 7926' RKB (4171 PS{ 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 C~ 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 Cam? 7748' 01/30/06 CHEMICAL CUT 2 3/8" LINER AT 8040' 02/03/06 RECOVERED i 4' X 2-318" LINER TOP FROM 8026' RKB. 02/24/06 TIFL PASSED (POST RIG SIDETRACK) V KRU 3H-14BL1/L2/L3/L4 A-sand Producer Proposed Completion ~.r1C~C#P~'11~1~-~- Alaska, fnc. 9-5/8" 40#~ L-80 @ 3455' 7" 26# L-80 Widow @ 6227' MD 3-1/2" Camco TRMA-10E SSSV at 2329' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 3-'/" Camco KBUG-M GLM's @ 2967', 4824, 6022' MD ~~ Top of 5'/z" liner @ 6039' M D 3-'/z" Camco KBG-2-9 GLM's @ 7114', 7706' MD 3-''/2" Camco DS nipple, 2.75" min ID @ 7748' MD Baker HR Packer w/SBE @ 7780' MD 5 '/s" 15.5# L80 @ 7925' and L1 KOP 8025' MD, in C-sand A sand perfs 8172' - 8187' OH KOP @ 8285' and IBP @ 8718' and 2-3/8" liner top ~ 8025' and 2-3/8" slotted liner ------ ---- -~---- 3-%2" WS-R-BB packer/ whipstock (retrievable tray with _ _ integral standing valve) - - - 3" openhole (all) 3-112" 9.3# L-80 3H-146L1 (pilot hole P/N 206-008 @ 8a5o' MD TD @ 9200' and P/N 205-204 s 3H-14BL3 TD @ 10,106' and P/N 205-206 KOP @ 8857' and / 3H-146L2 TD @ 10,774' and P/N 205-205 ~ ------- ------ -- - - - - -- KOP @ 9175' and 3H-14BL4 TD @ 10,070' and . ' Conoc Phillips ~ Baker Hughes INTEQ Baker Hughes INTEQ Survey Report _ ~~5 tNTE(~ Company: ConocoPhillips Alaska, Inc. Date: 2/18/2006 Time: 16:23:17 Page: i 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 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Wellpath: 3H-146L4 Survey Calculation 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-14BL4 Drilled From: 3H-146L3 Tie-on Depth: 9158.41 ft Current Datum: 3H-14B Height 79.60 ft Above System Datum: Mean Sea Level Magnetic Data: 1/17/2006 Declination: 0.00 deg Field Strength: 0 nT Mag Dip Angle: 0.00 deg Vertical Section: Depth From (TVD) +N/-S +E/-W DireMion ft ft ft deg 79.60 0.00 0.00 45.00 Survey Program for Definitive Wellpath Date: 1/17/2006 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 8240.73 MWD (8000.00-9200.00) (4) MWD MWD -Standard 8274.00 8853.55 MWD (8274.00-10774.00) (5) MWD MWD -Standard 8859.00 9158.41 MWD (8859.00-10106.00) (6) MWD MWD -Standard 9174.00 10070.00 MWD (9174.00-10070.00) MWD MWD -Standard Annotation MD TVD ft ft 9158.41 6089.14 TIP 9174.00 6088.18 KOP 10070.00 6191.57 TD Survey: MWD Start Date: 1/17/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~ ~ Cor~t~hillips Baker Hughes INTEQ ~ ~ Baker Hughes INTEQ Survey Report EyriEt~ -- Company: ConocoPhillips Alaska, Inc. Date: 2/18/2006 Time: 16:23:17 Page: 2 1';eld: 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-14BL4 Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD ft Incl deg Azim deg TVD ft SSTVD ft N/S ft E/W ft 9158.41 93.67 46.57 6089.14 6009.54 3535. 99 4290.22 9174.00 93.36 44.78 6088.18 6008.58 3546. 87 4301.35 9205.33 92.13 52.53 6086.68 6007.08 3567. 52 4324.83 9235.38 90.11 59.96 6086.09 6006.49 3584. 20 4349.79 9265.87 88.27 60.96 6086.52 6006.92 3599. 23 4376.31 9296.25 85.72 57.03 6088.11 6008.51 3614. 85 4402.31 9324.81 85.90 51.07 6090.20 6010.60 3631. 57 4425.36 9349.96 86.70 47.81 6091.83 6012.23 3647. 89 4444.42 9380.41 89.34 45.76 6092.88 6013.28 3668. 72 4466.60 9410.32 88.24 39.87 6093.51 6013.91 3690. 65 4486.91 9443.01 90.11 34.56 6093.98 6014.38 3716. 67 4506.67 9473.05 89.62 30.40 6094.05 6014.45 3742. 00 4522.80 9502.50 90.17 24.94 6094.11 6014.51 3768. 07 4536.47 9534.04 92.38 20.84 6093.40 6013.80 3797. 12 4548.73 9563.53 94.57 18.61 6091.62 6012.02 3824. 82 4558.67 9592.54 95.03 14.85 6089.19 6009.59 3852. 50 4566.99 9621.95 96.94 13.74 6086.12 6006.52 3880. 84 4574.21 9655.63 93.03 12.11 6083.19 6003.59 3913. 54 4581.71 9685.52 86.51 11.04 6083.31 6003.71 3942. 80 4587.71 9716.25 88.20 15.89 6084.73 6005.13 3972. 65 4594.85 9745.23 87.68 21.34 6085.78 6006.18 4000. 08 4604.09 9774.96 86.73 26.18 6087.23 6007.63 4027. 25 4616.05 9805.36 80.74 28.62 6090.54 6010.94 4054. 07 4629.95 9837.05 78.45 30.72 6096.27 6016.67 4081. 15 4645.37 9866.38 76.13 26.02 6102.72 6023.12 4106. 31 4658.97 9895.73 74.98 23.60 6110.04 6030.44 4132. 11 4670.89 9926.97 70.78 18.70 6119.24 6039.64 4159. 93 4681.67 9961.30 64.83 18.85 6132.21 6052.61 4190. 01 4691.90 9990.64 60.41 16.43 6145.70 6066.10 4214. 83 4699.80 10020.15 55.39 14.62 6161.38 6081.78 4238. 90 4706.50 10042.55 51.94 13.52 6174.65 6095.05 4256. 40 4710.89 10070.00 51.94 13.52 6191.57 6111.97 4277. 42 4715.94 MapN MapE ft ft 6004035.27 502945.83 6004046.14 502956.96 6004066.79 502980.44 6004083.46 503005.40 6004098.48 503031.92 6004114.10 503057.92 6004130.81 503080.97 6004147.12 503100.03 6004167.95 503122.21 6004189.87 503142.53 6004215.88 503162.29 6004241.21 503178.42 6004267.28 503192.10 6004296.32 503204.36 6004324.02 503214.30 6004351.69 503222.62 6004380.03 503229.85 6004412.72 503237.36 6004441.98 503243.36 6004471.82 503250.51 6004499.25 503259.75 6004526.42 503271.72 6004553.23 503285.62 6004580.30 503301.04 6004605.46 503314.64 6004631.25 503326.57 6004659.07 503337.35 6004689.15 503347.58 6004713.96 503355.49 6004738.03 503362.19 6004755.53 503366.59 6004776.54 503371.64 VS DLS Tool ft deg/100ft 5533.97 0.00 M W D 5549.53 11.63 MWD 5580.73 25.02 MWD 5610.18 25.62 MWD 5639.56 6.87 MWD 5668.99 15.40 MWD 5697.11 20.82 MWD 5722.13 13.32 MWD 5752.54 10.97 MWD 5782.41 20.03 MWD 5814.78 17.22 MWD 5844.10 13.94 MWD 5872.20 18.63 MWD 5901.41 14.76 MWD 5928.02 10.59 M W D 5953.48 13.01 M W D 5978.62 7.50 MWD 6007.05 12.57 M W D 6031.98 22.10 MWD 6058.14 16.70 M W D 6084.07 18.88 MWD 6111.74 16.57 MWD 6140.53 21.26 MWD 6170.58 9.73 MWD 6197.99 17.52 MWD 6224.66 8.89 M W D 6251.96 20.13 MWD 6280.46 17.34 M W D 6303.59 16.75 MWD 6325.35 17.79 MWD 6340.83 15.90 MWD 6359.26 0.00 MWD • ~, ~ y J '~ ,~, a ,"°ei 1"1 7 ~°, ~~ ~ ~ 1 ~ ~'~+ + " ~~ :~ ~, ~ ~ FRANK H. MURKOW l ~, ~ , _, , ~ °~ ~ ~.~ ~ ":,~1 SK, GOVERNOR ~T t~l °~-~~1aT ~~ ~ lTl~ ~ 333 W. T" AVENUE, SUITE 100 CO"SrjRQ~~~1` C~~IIssi~~ I~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907} 279-1433 FAX (907) 276-7542 Aras Worthington CT Drilling Engineer Conoco Phillips Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River, 3H-14BL4 Conoco Phillips Alaska Inc. Permit No: 206-008 Surface Location: 1157' FNL, 281' FWL, SEC. 12, T12N, R08E, UM Bottomhole Location: 3044' FSL, 212' FEL, SEC. O1, T12N, R08E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 3H-14B, Permit No. 205-021, API 50-103-20092-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). 206-008 Sincerely, ~,.%" • Daniel T. Seamount Jr. Commissioner rd DATED thi~ day of January, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ALASKA AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 AAC 25.005 _ RECEIVED ,~C~~'JAN 1 8 2006 A{aska Oil & Cas Cans, Commission enn~fn.w..~ 1 a. Type Of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil ^ Multipl one ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: Kuparuk 3H-14BL4 ' 3. Address: c/ o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10000 ' TVD 6020ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. location of Well (Governmental Section): Surface: 1157 FNL 281' FWL SEC T12N 12 R08E UM ~ 7. Property Designation: ADL 025531 s River Pool , , . , , , Top of Productive Horizon: 1428' FSL, 1232' FEL, SEC 01, T12N, R08E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 15, 2006 ^ Total Depth: 3044' FSL, 212' FEL, SEC. 01, T12N, R08E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 27300'. 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 498655 ' - 6000500 ' Zone- ASP4 10. KB Elevation (Height above GL): 79.60 feet 15. Distance to Nearest Well Within Pool 31-16 is offset by 1800' ' 16. Deviated Wells: Kickoff Depth: 8860 feet ~ Maximum Hole Angle: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 5000 ' Surface: 4400 ' 18. asing rogram: Size Specffications Setting Depth To Bottom uantlty o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD ND MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 1980' 8020' • 5993' 10000'• 6020' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed #or Redrill AND Re-e ntry Operations) Total Depth MD (ft): 10106 Total Depth TVD (ft): 6033 Plugs (measured): None Effective Depth MD (ft): 10106 Effective Depth TVD (ft): 6033 Junk (measured): None Casin Len th Size Cement Volume MD TVD n r 115' 16" 00 sx AS I 115' 115' 3455' 9-5/8" 1350 sx AS I I1, 400 sx Class 'G' 3455' 3001' 6039' 7" 800 sx Class 'G', 175 sx AS I 6039' 4847' Pr i n 1886' S-1/2" 01 sx Class 'G' 6039' - 7925' 4847' - 6007' r 660' 3-1/2" 82 sx Class 'G' 7780' - 8440' 5916' -6400' Liner 3H-14BL1 710' 2-3/8" Uncemented Slotted Liner 8350' - 9060' 6025' - 6088' Liner 3H-14BL2 2450' 2-318" Uncemented Slotted Liner 8700' - 11150' 6034' - 6154' Liner 3H-14BL3 2-3/8" Uncemented Slotted Liner Perforation Depth MD (ft): 7884' - 8254' (3H-146) Perforation Depth TVD (ft): 5981' - 6248' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ 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 a d correct to the best of my knowledge. Contact Aras Worthington, 56a-4102 Printed Name Ara Worthi gt n Title CT Drilling Engineer Prepared By Name/Number. Si nature Phone 564-4387 Date ! ! ,6 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill ` ,,~{~ Number: ~C]rv •._~'~'U API Number: 50- 103-20092-63-00 Permit Approval Date: ~ • (~Q See cover letter for other requirements Conditions of Approval: Samples Required ;'-j Yes ~'No Mud Log Required ^ Yes ~No Hydrogen Sulfide Measures L Yes ^ No Directional Survey Required "'Yes L No Other: ~~~d1~5`t ~~n~c~.v~-1~j0~ ~S'~" n APPROVED BY ~Q~ A roved B THE COMMISSION Date ~ D~rrr~ ~„J Form 10-401 Revised 06/2004 ~~ ~ Submit In Duplicate KRU 3H-14BL1, 3A=146L2, 3H-14BL3, &3H-14BL4 Sidetracks -Coiled Tubing Drilling 5ummary of Operations: Coiled tubing plans to drill 3 laterals 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 we113H-14B will be left open production. The third lateral (L3) that was drilled yielded little pay. It has been deemed advisable to re-drill the L3 lateral targeting A3 sands. This lateral will be called L4 ' CTD Drill and Complete 3H-14BL1.3H-14BL2, 3H14BL3, & 3H-14BL4 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 5. Set 31/z" whipstock at 8020' and 6. Mi112.74" window at 8020' and and 10' of openhole 7. Dril13" 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 drill 3" 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 SSSV as a barrier. 11. Kick-off of Aluminum billet top and dri113" hole horizontal lateral in A sands to TD @ ~ 11,150' md. 12. Complete with 2 3/8" slotted liner from TD to 8860' with an Aluminum kick-off billet; deploy liner using SSSV as a barrier. ~ 13. Kick-off of Aluminum billet top and drill 3" hole horizonta atera m sap s to ~ m . l4. Complete with 2 3/8" slotted liner from TD to the window @ 8020'; deploy liner using SSSV as a barrier. 15. ND BOPE. RDMO Nordic 2. -~-~; ~ ~r 16. Post CTD rig. BOL. '~ _, Mud Program: • Step 6-14: 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 a~k~' and to 11,150' md. t,`:\l~~ C £s$~~ ~~ ~L Y-----~ • 3H-14BL4: 2 3/8", 4.6#, L-80, STL slotted liner from 8020' and to 10,000' md. ~-- ~'~`i 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 2500 psi. KRU 3H-14BL1, 3R=14BL2, 3H-14BL3, &3H-146L4 Sidet~ks -Coiled Tubing Drilling Directional • See attached directional plans for 3H-14BL1, 3H-14BL2, & 3H-14BL3. • Magnetic and inclination surveys 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. ~-~- • The nearest well to 3H-14BL4 is 3I-16, which is offset by 1.800'. KRU boundary is 27,300' away. - ,~-- 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, & L4) is 5000 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. 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. Operator: Conoco Phillips Alaska, Inc. Grid Correction: -0.01 Job No: 1047250 Field: Kuparuk Magnetic Declination: 23.88 AFE No: KRD231426 Well: 3H-14BL4 Dip: 80.78 API No: 50-103-20092-62-00 Rig: Nordic 2 Dogleg per: 100 ft MWD Company: Baker Hughes INTEQ Surface Location Original VS Plane: 45.00 Parent Well: 3H-14BL3PB1 X: 498655.40 ft View VS Plane: 45.00 RKB Height: 79.60 ft Y: 6000500.40 ft Start Date: 01/15/06 TD Date: #N/A Meas. Incl. TRUE Subsea Coords. -True North Coords. -ASP or Grid Dogleg Original View Tool Build Turn Course Drilled Depth (ft) Angle (deg) Azi. (deg) TVD (ft) N(+)/S(-) (ft) E(+)/R'(-) (ft) N(+)/S(-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°1100 ft) VS (45°) (ft) VS (45°) (ft) Face (deg) (°1100 ft) (°1100 ft) Length (ft) Distance (ft) Comments 8000.00 45.85 69.72 5977.07 2582.86 3754.10 6003082.60 502409.95 11.34 4480.91 4480.91 8025.00 43.04 69.48 5494.92 2588.96 3770.51 6003088.70 502426.36 11.26 4496.82 4496.82 -177 -11.24 -0.96 25.00 25.00 8052.71 54.38 63.50 6013.18 2597.33 3789.51 6003097.07 502445.37 43.99 4516.18 4516.18 -24 40.92 -21.58 27.71 52.71 8083.11 70.28 57.18 b02226 26]0.70 3812.76 6003110.43 502468.62 55.41 4542.08 4542.08 -21 52.30 -20.79 30.40 83.11 8113.69 85.41 50.37 6033.69 2628.34 3836.76 6003128.07 502492.62 54.03 4571.52 4571.52 -25 49.48 -22.27 30.58 113.64 8143.35 90.60 37.40 6034.73 2649.66 38-57.26 6003149.38 .502513.12 47.06 460].09 4601.09 -68 17.50 -43.73 29.66 143.35 8180.98 92.7.5 30.27 6033.63 2680.88 3878.19 6003180.60 502534.06 19.78 4637.96 4637.96 -73 5.71 -18.95 37.63 180.98 8210.65 94.60 26.05 6031.72 2706.97 3892.16 6003206.69 502548.03 15.50 4666.29 4666.29 -66 6.24 -14.22 29.67 210.65 8240.73 94.66 22.56 6029.30 2734:29 3904.50 b003234.01 502560.37 11.57 4694.34 4694.34 -89 0.20 -11.60 30.08 240.73 8274.00 93.51 1.5.15 6026.92 2765.68 3915.21 600326.5.39 502571.10 22.48 4724.10 4724.10 -99 -3.46 -22.27 33.27 274.00 8303.89 88.76 22.00 6026.33 2793.98 3924.72 6003293.69 502580.61 27.88 4750.84 4750.84 125 -15.89 22.92 29.89 303.89 8333.41 9038 25.68 6026..55 2820.97 3936.65 6003320.69 502592.55 13.62 4778.37 4778.37 66 5.49 12.47 29.52 333.41 8366.26 92.4] 29.97 6025.75 2850.01 3951.98 6003349.72 502607.88 14.44 4809.73 4809.73 65 6.18 ]3.06 32.85 366.26 8393.50 91.61 33.70 6024.80 2873.13 3966.33 6003372.84 502622.24 14.00 4836.24 4$36.24 ]02 -2.94 13.69 27.24 393.50 8426.81 90.97 30.02 6024.04 2901.41 3983.91 6003401.12 502639.82 11.21 4868.66 4868.66 -100 -1.92 -11.05 33.31 426.81 8454.03 88.51 26.41 6024.17 2925.39 3996.78 6003425.09 502652.69 16.05 4894.71 4894.71 -124 -9.04 -13.26 27.22 454.03 8483.34 84.79 20.03 6025.88 2952.26 4008.31 6003451.96 502664.22 25.16 4921.87 4921.87 -120 -12.69 -21.77 29.31 483.34 8513.24 84.30 15.39 6028.73 2980.61 4017.36 6003480.31 502673.28 1.5.53 4948.31 4948.31 -96 -1:64 -15.52 29.90 513.24 8544.b0 85.96 12.40 6031.39 3010.94 4024.86 6003510.63 502680.79 10.87 497596 4975.06 -6] 5.29 -9.53 31.36 544.60 8573.69 88.79 10.33 6032.72 3039.42 4030.59 6003539.12 502686.52 12.05 4999.25 4999.25 -36 9.73 -7.12 29.09 573.69 860498 40.91 7.67 6032.$0 3069.43 4035.34 6003569.13 502691.27 11.19 5023.83 5023.83 -51 6.98 -8.75 30.39 604.08 8633.27 88.51 5.05 6032.95 3098.44 4038.57 6003598.13 502694.51 12.17 5046.63 5046.63 -132 -8.22 -8.98 29.19 633.27 8663.60 88.73 7.6] 6033.68 3128.57 4041.91 6003628.27 502697.86 8.47 5070.30 5070.30 85 0.73 8.44 30.33 663.60 8694.26 86.49 9.94 6034.96 3158.84 4046..59 6003658.54 502702.54 10.54 5095.01 5095.01 134 -7.31 7.60 30.66 694.26 8725.96 89.22 10.98 6036.14 3189.99 4052.34 6003689.68 502708.29 9.21 5121.10 5121.10 21 8.61 3.28 31.70 725.96 8757.12 90.29 14.46 6036.28 3220.38 4054.20 6003720.07 502715.16 11.68 5147.44 S1A244 73 3.43 11,17 31.16 757.12 8785.81 91.73 17.26 6035.77 3247.97 4067.04 6003747.66 .502723.00 10.97 5172.49 5172.49 63 5.02 9.76 28.69 785.81 8816.83 91.89 19.78 6034.79 3277.37 407b.88 6003777.06 502732.85 8.14 5200.24 5200.24 86 0.52 8.12 31.02 816.83 8353.55 92.14 23.29 6033.50 3311, 50 4090.35 60038] 1.18 502746.33 9.58 5233.90 5233.90 86 0.68 9.56 36.72 853.55 Tie-in Point from 3H-14BL2PB1 8859.00 92.05 23.89 6033.30 3316.49 4092.53 6003816.17 502748.51 11.13 5238.97 5238.97 99 -1.65 1].01 5.45 859.00 KOP .~ 8890.53 94.31 30.00 6031.55 3344.54 4106.79 6003844.22 502762.77 20.63 5268.88 ' 5268.88 70 7.17 19.37 31.53 890.53 8932.08 94.96 35.68 6028.19 3379.32 4129.23 6003879.00 502785.22 13.72 5309.35 5309.35 83 1.56 13.67 41.55 932.08 8966.79 94.56 37.87 6025.31 3407.02 4149.94 6003906.70 502805.94 6.39 5343.58 5343.58 100 -1.15 6.31 34.71 966.79 9000. I $ 94.90 44.3 ] 6022.55 3432.09 4171.80 6003931.76 502827.80 19.25 5376.77 5376.77 87 1.02 19.29 33.39 IOOO.l8 9031.04 94.Sb 46.27 6020.01 3453.73 4193.66 6003953.39 502849.66 6.42 5407.52 5407.52 ]00 -1.10 6.35 30.86 1031.04 9066.49 94.47 49.60 6017.22 3477.40 4219.89 6003977.06 502875.89 9.37 5442.81 5442.81 9l -0.25 9.39 38.45 1066.49 9094.61 94.81 52.75 601.4.94 3494.97 4241.72 6003994.63 502897.73 11.23 5470.67 5470.67 84 1.21 11.20 28.12 1094.61 9122.80 95.55 50.28 60L2.40 3512.44 4263.64 6004012.09 502919.71 9.11 5498.56 5498.56 -73 2.63 -8.7b 28.19 1122.80 9158.41 93.67 46.57 6009.53 3535.99 4290.24 6004035.64 502946.26 11.65 5533.98 5533.98 -117 -5.28 -10.42 35.61 1158.41 Tie-in Point from 3H-14BL3 9179.00 93.26 44.21 6008.29 3550.42 4304.87 6004050.07 502960.89 11.61 5554.53 5554.53 -100 -1.99 -11.46 20.59 1179.00 KOP 9200.00 90.00 47.00 6007.69 3565.10 4319.87 6004064.75 502975.89 20.43 5575.52 5575.52 139 -15.52 13.29 2L00 1200.00 9250.00 87.00 5]..61 6009.00 3597.68 4357.75 6004097.32 5030]3.78 11.00 5625.34 5625.34 123 -6.00 9.22 50.00 1250.00 9275.00 88.00 53.50 6010.09 3612.87 4377.58 6004112.50 503033.61 8.54 5650.10 5650.10 62 4.00 7.55 25.00 1275.00 9300.00 88.00 51.61 6010.96 3628.06 4397.41 6004127.69 503053.45 7.55 5674.87 5674.87 -90 0.00 -7.55 25.00 1300.00 9350.00 88.50 40.65 6012.50 3662.64 4433.39 6004162.26 503089.43 21.93 5724.7b 5724.76 -88 1.00 -2]..92 50.00 1350.00 9400.00 88.00 40.65 6014.02 3700.55 4465.95 6004200.17 503121.99 1.00 5774.59 5774.59 179 -1.00 0.00 50.00 1400.00 9450.00 88.00 35.15 6015.77 3739.96 4496.63 6004239.58 503152.69 11.00 5824.16 5824.16 -90 0.00 -11.01 50.00 1450.00 9500.00 90.00 29.65 6016.64 3782.16 4523.41 6004281.77 503179.47 11.71 5872.92 5872.92 -70 4.00 -11.01 50.00 1500.00 9550.00 94.00 24.14 6014.90 3826.69 4546.00 6004326.30 503202.07 13.60 5920.39 5920.39 -54 8.00 -11.01 50.00 1550.00 9600.00 96.00 18.64 6010.54 3873.05 4564.17 6004372.65 503220.24 11.67 5966.02 5966.02 -70 4.00 -11.00 50.00 1600.00 Current Survey Page 1 of 2 (3H-14BL4 Plan#8 Geotrak.xls) 1118/2006 7:31 AM Meas. Incl. TRUE Subsea Coords. -True North Coords. -ASP or Grid Dogleg Original .View Tool Build Turn Course Drilled Depth (ft) Angle (deg) Azi. TVD (deg) (ft) N(+)/S(-) (ft) E(+)/W(-) (Ct) N(+)/S(-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (45°) (ft) VS (45°) (ft) Face (deg) (°/100 ft) (°/100 ft) Length (ft) Distance (ft) Comments 9650.Q0 96.00 24.14 6005.30 3919.33 4582.30 6004418.93 503238.38 10.94 6011.56 6011.56 90 0.00 1.1.00 50.00 1650.00 9700.00 93.00 29.44 6001.38 3963.80 4604.76 6004463.40 503260.85 12.14 6058.89 6058.89 119 -6.00 10.58 50.00 ]700.00 9750.00 90.00 34.05 6000.07 4006.29 4631.05 6004505.88 503287.15 11.00 6107.52 6107.52 123 -6.00 9.22 50.00 1750.00 9800.00 56.00 39.47 6001.82 4046.30 4660.93 6004545.89 50331204 13.46 6156.95 6156.95 127 -8.00 10.84 50.00 1800.00 9850.00 85.00 44.98 6005.74 4083.20 4694.41 6004582.78 503350.53 11.17 6206.72 6206.72 101 -2.00 11.03 50.00 1850.00 9900.00 85.00 39.47 6010.10 4120.07 4727.88 6004619.65 503383.99 10.98 6256.45 6256.45 -90 0.00 -LL03 50.00 1900.00 9950.00 84.00 34.04 6014.90 4159.93 4757.65 6004659.50 503413.77 10.98 6305.68 6305.68 -101 -2.00 -10.85 50.00 1950.00 10000.00 84.00 28.52 6020.13 4202.41 4783.46 6004701.98 503439.54 10.98 6353.97 6353.97 -90 0.00 -] 1.04 50.00 2000.00 • • Current Survey Page 2 of 2 (3H-146L4 Plan#8 Geotrak.xls) 1!18!2006 7:31 AM KRU 3H-14BL1/L2/L3/L4 A-sand Producer Proposed Completion 9-5/8" 40#~ L-80 3455' ~a r' 2s# L-so /b~090..~(ID (~ ~~'~-~ ~~,`-~,,(( `i~ 5-'/2" 15.5# L80 @ 7925' and L1 KOP 8020' MD, in C-sand A sand peMs 8172' - 8187' 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 ~~~~i ~~ ~ ~ ~~ 3-'h" Camco KBG-2-9 GLM's @ 7114', 7706' MD 3-%" Camco DS nipple, 2.75" min ID @ 7748' MD Baker HR Packer w/SBE @ 7780' MD ~~~(~~ KOP @ 8350' and 2;3/8" liner top ~ 8025' and 3 '/Z' WS-R-BB packer/ whipstock (retrievable tray with integral standing valve) 3-112" 9.3# L-80 CcD 8450' MD Aluminum billets 3" openhole R i ~onc~~oPh~Is Alaska, Inc. 3H-14BL3 TD @ 10,106' and /~ ~ / ~ ~ 3H-14BL2 ~ TD @ 10,774' and -~ ~ \' - - ~- ~ - KOP @ 8700' and 3H-14BL4 `~ TD @ 10,070' m - 3H-14BL1 (pilot hole) TD @ 9200' and Kuparuk DOBCTD BOP configur~n 2" CT Well 3H-146L1,L2,L3 Rig Floor .- ~:' ~. ~S +li;~i~+i ~_ C ~" 5000 psi (~~~ HCR Choke Line C C Tree Size ~- I Lutxicator ID = 6.375' with 6" Otis -~~.~ 71/16' 5000 psi BOP's. ID = 7.06" .' 3 y ?: 71/16' 5000 psi, RX-46 1/4 Tum LT Valve 7 1/16" 5000 si RX-46 -k CR ~'~' ~ Kill Line - 2 1/16' 5000 psi , RX-24 ~~ 7 uis• 500o psi (wc-4sj or ~- 4 1/16" 5000 psi (RX-39j Swab Valve SSV Master Valve Base Flan e Page 1 C] Pf=RMIT 70 DRILL 20 AAC 25.005 • (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shat! designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • TRANSMITTAL LETTER CHECKLIST WELL NAME .`~~C~C ~T7 -- f~f..~ ~ Development Service Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES i MULTI LATERAL The permit is for anew wellbor segment of existing ,,: / well ~/~L~(,. ~ lT ' ~y ~ , (If last two digits in permit No. ~ .`~ 'C~Z %, API No. 50- /D~- ~~~Z- -~7 . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool _ Well Name: KUPARUK RIV UNIT 3H-146L4 Program DEV Well bore seg ~ PTD#:2060080 Company CONOCOPHILLIPS ALASKA INC Initial Classffype DEV 1 PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mit_feeatlached_ _ _ _ - _ NA_ - _ _ Multilateral_wellbore,feewaived_per20AAC25.005(e) , - - - - _ - - - - - - - - - - - - - - - - - 2 Lease number appropriat_e______________________ _________________ Yes_ __-_____-.-_ ___--__ 3 Uniquewell_n_ameandnumber_,___________________________________ Yes_ __-__-,__-_--,__-__--__-__-_- 4 Well located in a_defnedpool_ _ _ - _ - Yes - _ _ - KUPARUK RIVER,-KUPARUK RVOIL -490.100, governed by Conservation Order No. 4320.- _ 1 5 Well located proper distance from drilling gnit_boundary- Yes - - _ Conservation Order No. 4320 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 in_tenyell-spacing-restrictions: _ _ 7 Sufficient acreage ayaif_able in_d_rilling unit_ Yes - _ Conservation Order No. 4320 has no in_terwell_spacing_restrictions, Wellbore will be_more than 500' from 8 If_tleviated, is_wellbore plat_included - - _ - Yes - - an external property line_where_ownership or_landownershipchonges. _ - 9 Operator only affected party- - - - - - Yes 10 Operalorhas_appropriate-bond inforce_________________________________ Yes_ -________-__-_______--_--__--_, 11 Permit can be issued without conservation order Yes Appr Date 12 Permitcanbeissuedwithoutadministrative_approval____ _____ ___________ __ Yes_ ---_____-_____--__---.--__-.-__------__--___-___ SFD 1/1912006 i 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by_Injection Order # (put 10# in_comments)_ (For- NA_ . _ _ - 15 All wells-within 1/4_mile area_of review identified (For service well only) _ _ _ _ _ _ - - _ _ _ - _ NA_ _ - _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 16 Pre-produced injector; duration-of pre Production Less than 3 months. (For_servfce well only) , - NA_ _ . _ _ _ - ACMP_Finding of Consistency_has been issued-fgr_this project_ NA_ - - - . _ - - _ - - Engineering 18 Conductor string_provided NA- - Conductor set_in original_well, 3H-14 (187.123). , 19 Surface casing_protgctsoll known- U$DWs - - - - - NA- _ - -All anuifarc exemptatl, 40 CFR-147.102_ (b)(3)__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 CMT.vol adeguate.to circulate-on conductor & surf_csg NA_ _ - - - _ _ _ Surface casing set in_original wel_I,_3H-14_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _C_MT-vol_ adequate-to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ NA_ _ - - _ _ _ _ Production_casing set in_original well, 3H-14._ Top_ of 7"window-at 622T_md_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ 22 CMT_will coverall known-productive horizon_s_ No .Slotted liner completion planned, - - - _ - - - 23 Casing designs adequate f_or C, T ~ &_permafrost_ NA_ O[iginal well_met design specifications. NA for slotted liner._ . - - 24 Adequate tankage_o_r reserve pit _ - Yes Rig ise_quipped with steel_pits. No rese_rve_pitplanned. All waste to approved disposalwells. 25 Ifare-drill, has_a-10-403 for abandonment been approved - - NA_ - _ - - Existing perf_oration_s will_be retained. - - 26 Adequate wellbore separation_proposed _ _ - _ _ _ - - _ _ _ . - - _ _ _ _ _ _ _ _ _ - Yes _ _ _ , _ _ Proximity analysis performed, Nearest branch_ is 3H-14BL3 and trajectories diverge_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 If diverterlequired,doesitmeetregulations_______ ___ ______ _________-_ _N_A__ --___BOPStack_willalready_bein place,__._____.-______--_____--__.---__--____-- Appr Date 28 Drilling fluid_ program schematic_& equip list adequate- Yes _ _ - - Maximum expected formation pressure 15.9 EMW.-Plan is to employ dynamic oveCballance with 9.9 ppg fluid and TEM 1!1912006 2g _B_OPEs,-do they meet regu_la_tion - _ - Yes either_applied or frictional pressure. 2_wellbo_re volumes of kill weight fluid available for contingency . - - - - . ~(~ 30 BO_PE_press rating appropriate; test to_(put psig in comments).. - - _ Yes - _ - _ - Calculated_MASP 4400 psi._ Planned BOP test 4500 psi, - - _ - 31 Choke-manifold complieswiAPI-RP-53 [May84)___________ ________________ Yes_ __-_-____--.______-____- 32 Work will occur witheut operation shratdown_ _ - _ _ _ _ , _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Is presence_of H2S gas_ probable - _ - - Yes DS #H is-an H2S-pad. _Mud-should preclude_H2S on rig._ Rig has sensors and_alarms•- - 34 Mechanical condition of wellsvaithinAORyerified(For_servicewellgnly)______________ NA-_ _ ._--___----_____--____---_____--____-- _________ Geology 35 Permit can be issued w!o hydrogen sulfide measures No_ 3H-Pad- is a designated H2S pad, with measurements to 450 ppm.- H2S measures required. - , _ _ _ _ - _ _ _ , . 36 Data-presented on potential oye_rpressure zones- - Yes _ _ - - Estimated reservoir pressure is 15.9 ppg EMW._ Will be drilled with 9.9 ppg mud using coiled tubing _ _ Appr Date 37 Seismic analysis of shallow gas zones_ NA_ and oyerbalan_ced drilling techniques. . - . - - - ---------------------------- SFD 111912006. 38 Seabed contljtion survey_(if off-shore) _ . _ - NA - - 39 Contact name/pho_ne for weekly_p_rogress reports-[exploratory only] - - - - - - - - - - - - - - - - NA_ _ _ - Geologic Date: Engineering Date Public Date The preceeding lateral, KRU 3H-14BL3 had little pay. This spoke was verbally approved on Jan. 15, 2006 by Tom Maunder. Commissioner: Commissioner: Commissioner • • Well History File APPENDIX C~ Information of detailed nature that is not particularly germane to the Weli 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 06/01/18 1047250 O1 2.375 CTK *** LIS COMMENT RECORD *** Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8027.8000: Starting Depth STOP.FT 10070.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska Inc. WELL. WELL: 3H-14BL4 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 24' 45.364"N 150 deg 00' 39.419"W CNTY. COUNTY: North Slope Borough STAY. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375 CTK DATE. LOG DATE: 18-Jan-06 API API NUMBER: 50103200926300 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 !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las ab~ oaf ~ ~So93 ~ i (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths 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 10046 ft.MD to 10070 ft.MD (6097.2 ft.SSTVD to 6112.0 ft.SSTVD) was not logged due to bit to sensor offset at TD. (9) The wellbore 3H-14BL2 was sidetracked off the wellbore 3H- 14BL1PB1 at 8274.0 ft.MD (6026.93 ft.SSTVD) (10) The wellbore 3H-14BL3 was sidetracked off the wellbore 3H-14BL2 at 8859 ft. MD (6033.3 ft.SSTVD) (11) This wellbore 3H-14BL4 was sidetracked off the wellbore 3H-14BL3 at 9174 ft.MD (6008.6 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 68 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 3H-14BL4 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 3H-14BL4, FN Kuparuk River Unit COUN North Slope Borough i • STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final has not been depth shifted *** 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: 0.500000 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: 49 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 58 Minimum record length: 54 Maximum record length: 4124 8025.000000 10070.000000 0.500000 feet records... bytes bytes **** FILE HEADER **** MWD .002 1024 • • *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 3H-14BL4.xtf LCC 150 CN ConocoPhillips Alaska In WN 3H-14BL4, 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 MGTD 6 8 1 AAP I 4 4 2 ROP MWD 68 1 FjHR 4 4 8 Total Data Records: 107 Tape File Start Depth = 7840.000000 Tape File End Depth = 10068.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 116 records... Minimum record length: 54 bytes ~ i Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 06/01/18 1047250 01 **** REEL TRAILER **** MWD 07/05/01 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • u Tape Subfile 1 is type: LIS C~ 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 148.7700 -999.2500 8400.0000 89.7400 58.0400 8500.0000 127.8600 66.3800 8600.0000 151.4100 59.4900 8700.0000 78.6300 62.9200 8800.0000 74.3900 53.7000 8900.0000 74.1300 63.4100 9000.0000 96.1000 61.6200 9100.0000 133.1500 42.6700 9200.0000 102.1800 46.6800 9300.0000 50.5700 132.7600 9400.0000 69.3600 65.6300 9500.0000 75.9800 42.8400 9600.0000 159.3600 39.7500 9700.0000 156.4400 49.5400 9800.0000 114.3600 27.5200 9900.0000 123.6200 56.2900 10000.0000 129.9800 56.8000 10070.0000 -999.2500 -999.2500 • Tape File Start Depth = 8025.000000 Tape File End Depth = 10070.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape 5ubfile 3 is type: LIS DEPTH GR ROP 7840.0000 84.4500 -999.2500 7840.2500 85.1775 -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 148.7700 -999.2500 8400.0000 89.7400 58.0400 8500.0000 127.8600 66.3800 8600.0000 151.4100 59.4900 8700.0000 78.6300 62.9200 8800.0000 74.3900 53.7000 8900.0000 74.1300 63.4100 9000.0000 96.1000 61.6200 9100.0000 133.1500 42.6700 9200.0000 102.1800 46.6800 9300.0000 50.5700 132.7600 9400.0000 69.3600 65.6300 9500.0000 75.9800 42.8400 9600.0000 159.3600 39.7500 9700.0000 156.4400 49.5400 9800.0000 114.3600 27.5200 9900.0000 123.6200 56.2900 10000.0000 129.9800 56.8000 10068.0000 -999.2500 16.6100 Tape File Start Depth = 7840.000000 Tape File End Depth = 10068.000000 Tape File Level Sparing = 0.250000 Tape File Depth Units = feet ~~ ~~ Tape Subfile 4 is type: LIS