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Home My WebLink About205-084• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o~©~ - ~~ ~-~-~- Well History Fife Identifier Organizing (done) ^ Two-sided III II~IIIII III IIIII ^ Rescan Needed III IIlIIIIIII III III SCAN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. M ^ Maps: ^ Greyscale Items: ^ Other, No(Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES; ^ Other:: BY: Maria Date: ~ ~.. ~ /s/ Project Proofing II I II II II I ~ III I I III SY: ~ Maria Date: ~ ~ ~ `~, ~L ~ ~_ _ _ _ _ _ Isl p i ~ Scanning Preparation _~ x 30 = _!~~ + =TOTAL PAGES___ S~%L (Count does not include cover sheet) BY: Maria Date: ' r f ~C~' % D ~ ls! Production Scanning Stage 1 Page Count from Scanned File: (count does include c/over sneer) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ' ~' ~ ! ~ ~ /s/ Stage 1 if NO in stage 1, pages} discrepancies were/found: YES NO BY: Maria Date: /s! Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III II ~I II I I III I I III BY: Maria Date: /s/ Comments about this fife: Quality Checked III (I'III III (I'I III 10/6/2005 Well History File Cover Page.doc • Transmittal Form INTEQ To: AOGCC 333 West 7~` Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1D-36L1 & 1D-36L2 r.~ BAKER HUGHES Anchorage GEOScience Center Contains the following: 2 LDWG Compact Disc (Includes Graphic Image files} 2 LDWG lister summary ! 2 blueline - GR Measured Depth Log 2 blueline - GR TVD Log ~- I aas -o~sN ~ ~ 5-69 ~ L.2 ~iS-o~S `~ ~S ~9~ II LAC Job#: 941648 Sent By: Cosett~ a Todirica Date: Nov. 13, 2007 Received By: (a 1/ k,~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN~-& RETURNhN OR FAXING YOUR COPY FAX: (907) 267-6b23 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 .,.,.. ,,. , :~: .. ^~ ~_ ,t_ i. _ - F_~_ ,I' ~.. t ~' DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050840 Well Name/No. KUPARUK RIV UNIT 1D-36L1 Operator CONOCOPHILLIPS ALASKA INC MD 13548 TVD 6588 Completion Date 811/2005 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD GR Well Log Information: Log/ Electr Data Digital Dataset T ire Med/Frmt Number Name API No. 50-029-22973-60-00 UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH i Scale Media No Start Stop CH Received Comments ~ ED D Asc Directional Survey j,',Ptpt ~ Directional Survey ~'Cog 14314 Gamma Ray I i~ILog 14314 Gamma R ay tc ~l:v':S: c~.-.~ j,~Rpt 14314 ~ ~ y ire S °~og C ryas 14314 -'Induction/Resistivity Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y / N Analysis ~LN Received? Comments: 11275 13548 8/9/2005 11275 13548 8/9/2005 25 Blu 11416 13548 Open 1/10/2007 TVD GR 24-Jul-2005 wlGraphics 25 Blu 11416 13548 Open 1/10/2007 MD GR 24-Jul-2005 wlGraphics 11401 13548 Open 1/10/2007 LIS Veri in LAS Format w/Graphics 22-Dec-2006 11401 13548 Open 1/10/2007 LIS Veri in LAS Format wlGraphics 22-Dec-2006 S ample Set Sent Received N umber Comme nts Daily History Received? ~`'N Formation Tops ~N DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050840 Well Name/No. KUPARUK RIV UNIT 1D-36L1 MD 13548 TVD 6588 Ijj~~ ompletion Date 8!1!2005 Compliance Reviewed By: ____ _~F~~~~_--___._- Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22973-60-00 Completion Status 1-OIL Current Status 1-}OILIl~ ~... UIC N Date: r~ J ~ t.ti a-~~~ Transmittal Form • INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1D-36L1 & 1D-3bL2 Contains the following: 1_LDWG Compact Disc (Includes Graphic Image files} LDWG lister~summary ~L.bluelines GR Measured Depth Log ~ ~„blueline~ GR TVD Log 'I LAC Sob#: 941648 Sent By: Cosette Todirica Date: Die. 22; X006' 3 ~? ., ~ Received By: ~ '~ Date: PLEASE ACI{N®WLEDGE RECEIPT BY SIGNING & RETURNING ®R FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ a OS _ d~ <~ ~) '=! 3/ ~~ 7260 Homer Drive Anchorage, Alaska 99518 ~~,-_d~rJ- ~ r'GI3/~~ Direct: (907) 267-6612 FAX 907 267 662"' i i ;:~;-: i _ - -- -A _. ~.~ ,. t . i I __ __ _' :. .( ) - ~ STATE OF ALASKA ALAS LAND GAS CONSERVATION COM ~ °SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 8/1/2005 ~ 12. Permit to Drill Number 205-084 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/19/2005 13. API Number 50-029-22973-60-00 4a. Location of Well (Governmental Section): Surface: 4 7' F ' 7. Date T.D. Reached 7/23/2005 14. Well Name and Number: Kuparuk 1D-36L1 7 NL, 420 FEL, SEC. 23, T11N, R10E, UM Top of Productive Horizon: 2553' FNL, 2363' FWL, SEC. 25, T11N, R10E, UM g. KB Elevation (ft): 105.3 15. Field /Pool{s}: Kuparuk River Unit /Kuparuk River Pool Total Depth: 1497' FNL, 3697' FWL, SEC. 25, T11N, R10E, UM 9. Plug Back Depth (MD+TVD) 13548 + 6588 Ft 4b. Location of Well {State Base Plane Coordinates): Surtace: x- 560671 y- 5959189 "Zone- ASP4 10. Total Depth (MD+ND) ` 13548 + 6588 `~ Ft 16. Property Designation: ADL 025661 TPI: x- 563519 y- 5951857 Zone- ASP4 Total Depth: x- 564844 - Y- 5952924 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1870' 21. Logs Run: MWD GR '7-'~ l.~"~~,1~~~: ; /~y ~~~~' f~'l~~ fc5/~~' ~'b 2 CASING, LINER AND EMENTING RECORD CASING ETTING DEPTH MD ETTING PTH TW HOLE MOUNT SIZE WT. PER FT. GRADE OP OTTOM OP' OTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surtace 121' Surtace 121' 30" 14 cu ds ABI T e III 9-5/8" 40# L-80 Surface 7047' Surface 4297' 12-1/4" 850 sx AS III Lite, 415 sx LiteCrete 7" 26# L-80 Surface 11038' Surface 6245' 8-1/2" 170 sx Class 'G' 3-112" 9.3# L-80 10885' 11410' 6170' 6426' 6-1/8" 174 sx Class 'G' 2-3/8" 4.6# L-80 11394' 13310' 6418' 6524' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. Tu$ING RECORD Bottom Interval, Size and Number; if none, state none }: SIZE DEPTH SET {MD) PACKER SET {MD) 2-3/8" Slotted Section 3-112", 9.3#, L-80 10918' NIA MD TVD MD TVD 11406' - 12262' 6424' - 6440' 12356' - 12$33' 6442' - 6479' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12927' - 13276' 6487' - 6520' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11410' Set Retrieveable Whipstock (For L1} 26. PRODUCTION TEST Date First Production: August 6, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 8/16/2005 Hours Tested 17 PRODUCTION FOR TEST PERIOD ~ OIL-BBL 2,243 GAS-MCF 3,154 WATER-BBL 427 CHOKE SIZE 176 GAS-OIL RATIO 1,406 Flow Tubing Press. 2p CeSing PreSSUre 780 CALCULATED 24-HOUR RATE OIL-BBL 3,167 GAS-MCF 4,453 WATER-BBL 603 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ,.,...-~ , ; ~, Sip ~ 6 2045 & cti ~ _ ~ , None $ "~'~" IED K `RRRa Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE (~ ~ ~~~~ ~ '~ ~~ !.~! t ~ ~~.% s g ~~ ~ v ~ If .. ~1 2~. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk C (From 1 D-36) 11358' 6400' Nane Kuparuk B 13476' 6561' 30. List of Attachments: Summary of Pre-Rig work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date ~-` '~~'~ Kuparuk 1 D-36L1 205-084 Prepared By Name/Plumber: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Scott Kolstad, 564-5347 Permit No. / A royal No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas lnjection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing lnterval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 1212003 Submit Original Only ~` . Cca'npcoPhillips Alma, ne. ~ ~ 1 D-36 L 1 apl• i TUBING (0-10885, OD:3.500, ID:2.992) LINER ;1 0885-1 1 41 1, OD:3.500) ! Reference Lo :29.22' RKB Last Ta ' ~,~ , Last Tag Date: ~Casing_Strin~_ COMMO_N_S_T_RI ~i Descri tion Siz 1 1 KRU 'D-36L1 PRODUCTION 7.000 0 11038 11038 26.00 L-80 CONDUCTOR 20.000 0 121 121 72.00 H-40 SURFACE 9.625 0 7047 7047 40.00 L-80 WINDOW to L2 3.500 11360 11364 11364 9.30 L-80 WINDOW to L1 _ ~Casin~c StrincZ- Ci/C2-SA _ 3.500 NDS LINE 11410 R~Slotted l _ 11411 iner of alte 11411 rnatingsol 9_.30_ L-80 _ id/slotted tubin ___ _ Description ~ Size 1 Top ~ Bottom J TVD ~ Wt ~ Grade Thread _ SLOTTED LINER 2.375 11394_ . 13310 13310_y _ 4.60 _ L-80_ ___STL,__ Gas Lift_Mandrels/V_afves _ St ~ MD TVD r Man TMan Type V Mfr Mfr __ T V Typ ______ e V OD Latch Port TRO _ Date Run ____ Vlv Cmnt 1 3655 3655 CAMCO MMG OV 1.5 RK 0.250 0 8!3/2005 2 6481 6481 CAMCO MMG DMY 1.5 RK 0.000 0 9/16/2000 3 8237 8237 CAMCO MMG DMY 1.5 RK 0.000 0 9!1612000 4 9706 9706 CAMCO MMG DMY 1.5 RK 0.000 0 9/16/2000 _5_ 108_1.9_ 10819 CAMCO Other lugs, egu~„etc Depth TVD Type ~ _MMG _ DMY_ . =COMMON JEWELRY ~ __i._5____ R_K__ __ Description _0_.000 _ _0_ __ 9_/16/2000 _ ___ ~ ID 545 545 NIP CAMCO 'DS' NIPPLE w/NO G O PROFILE 2.875 e Blank Pipe ,11396-11406, OD:2.375) Perf 11406-12261) Blank Pipe 12202-12356, OD:2.375) Perf 12356-12832) Blank Pipe 12833-12927, OD:2.375) Pert 12927-13276) Blank Pipe ;13276-13308, OD:2.375) ~I 11370 11370 PACKER WEATHERFORE WS-R-BB PACKER set 7/22/2005 1.250 11394 11394 Deploy BTT SEAL BORE DEPLOYMENT SUB TO LATERAL LEG L1 set 2.250 Sub L1 7/22/2005 11410 11410 Whipstock WHIPSTOCK TO L1, set 7/22/2005 1.250 to L1 Other ( plugs, _equ~., etc .1_C1/C2 SAND LINER L1 I - - `General Notes Date Note _ 8/1/2005 MULTI i, F _ ~_ _ -.I I.= - ~ ') De th TVD 11394 11394 11396 11396 E 12202 12202 E 12833 12833 E 13276 13276 E • • Well: 1 D-36L1 / L2 Accept: 07/16/05 Field: Kuparuk River Unit Spud: 07!19!05 API: 50-029-22973-60-00 / -61-00 Release: 08/01/05 Permit: 205-084 & 205-085 Rig: Nordic #2 PRE-RIG WORK 02112/05 PPPOT-T AND IC PASSED, FUNCTION TESTED LDS'S (ALL MOVED FREELY). MIT-OA FAILED WITH A LLR OF 9 GPM AT 1500 PSI. PT MASTER AND SWAB VALVES, PASSED. 02/23/05 TIFL -PASSED. 03/06/05 DRAW DOWN TEST MASTER AND SWAB VALVES. PASSED. 04/30/05 GAUGED TBG TO 2.70" TO 11455' WL, NO SPANGS. LOGGED PDS CALIPER FROM 11454' MD TO 10060' MD; GOOD DATA. DRIFTED TBG WITH 2.74" X 10' DUMMY TO 11450' WLM, TIGHT SPOT AT 7033' WLM. 07110!05 SET 2.81" XN PLUG AT 10971' RKB. REPLACED OV W/ DV AT 10819' RKB. 07/11/05 PULLED GLV'S, RAN DV'S AT 9706' AND 8237' RKB. OPEN POCKETS AT 3655' AND 6481' RKB. 07/12/05 RAN DV'S AT 3655' AND 6481' RKB. PT TBG TO 2500#, HELD. PULLED 1.5" DV AT 10819' RKB. (OPEN POCKET) LOAD I/A W/ SEAWATER. 07/13/05 SET 1 1/2" DUMMY VALVE AT STA #5. MITIA-PASSED, PULLED 2.81" XN LOCK. JOB COMPLETE. BP Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1D-36 Event Name: REENTER+COMPLETE Start: 7/21/2005 Contractor Name: NORDIC CALISTA Rig Release: 81112005 Rig Name: NORDIC 2 Rig Number: ~ Date f ~ From - To i Hours Task i Code NPT ~'i Phase 7/16/2005 05:00 - 06:00 1.00 MOB P PRE 06:00 - 06:30 0.50 MOB P PRE 06:30 - 07:00 0.50 MOB P PRE 07:00 - 07:30 0.50 MOB P PRE 07:30 - 08:30 1.00 MOB P PRE 08:30 - 09:00 0.50 MOB P PRE 09:00 - 09:15 0.25 MOB P PRE 09:15 - 10:00 0.75 MOB P PRE 10:00 - 13:00 3.00 BOPSU P PRE 13:00 - 14:40 1.67 BOPSU P PRE 14:40 - 18:00 3.33 BOPSU P PRE 18:00 - 19:00 1.00 BOPSU N WAIT PRE 19:00 - 22:30 I 3.501 BOPSUF{ P I PRE 22:30 - I 0.001 RIGU I P I l PRE 7/17/2005 00:00 - 01:00 1.00 RIGU P PRE 01:00 - 03:30 2.50 RIGU N HMAN PRE 03:30 - 07:00 3.50 RIGU P PRE 07:00 - 08:30 1.50 CLEAN P WEXIT 08:30 - 10:50 2.33 CLEAN P WEXIT 10:50 - 11:05 I 0.251 CLEAN I P I I W EXIT 11:05 - 13:30 I 2.42 I CLEAN I P I I W EXIT 13:30 - 15:30 ! 2.001 CLEAN ! P I I W EXIT 15:30-16:00 0.50{STWHIPP I (WEXIT 16:00 - 17:25 I 1.421 STWHIP( P I I WEXIT 17:25 - 20:20 2.92 STWHIP P WEXIT 20:20 - 20:35 0.25 STWHIP P WEXIT Page 1 of 13 Spud Date: 911/2000 End: 8!1 /2005 Description of Operations Prepare to move rig off of well 1 D-42. Crew change and PJSM to move off well Pull off 1 D-42 Lay out 30'x30' herculite Wait while Weil Support removes hump in fron of 1 D-36 Remove tree cap. Install BOP equipment. Notify AOGCC of pending BOP test.Layout i00'xi00' herculite. Position rig mats. PJSM review procedures for pulling over well. Call for rig water. Move onto 1 D-36 and level. Rig accepted at 0900hrs due to waiting on dirt work. NU BOPE Wait on water truck. Test BOPE 250psi low and 3500psi high. AOGCC rep Jeff Jones witnessing test. On initial body test found leaks on newly installed kill line. Replaced Greyioc ring. Proceed with testing okay. Shut down BOP test so that Well Site Leader can address some issues with respect to SIMOP's occuring on the pad. CPA( crew is excavating dirt around well 1 D-32 which is directly behind the rig. They are troubleshooting areported casing leak to atmosphere. Finish SOP testing. 4 valves leaked. All were greased and held fine after greasing. Stab injector. Pressure test inner reel valve. Pump slack management. Pump slack management. Repair damage to spoke on Schlumberger coil reel. Damage to spoke repaired. Cut coil to find end of eline. Cut 30' of coil to find eline. Dress end of coil tubing. Build coil aline head. Pull test to 35k PT connector to 3500psi. Circulate over bung hole 1 circulation while holding PJSM for pressure deployment of cleanout BHA. Checked WHP 675psi. Pressure deploy 2.74" mill and motor BHA. Pressure stack to RIH maintaining 700psi on well. Wt check at 10500' 32k RIH tagged at 11427' no pump seeing 3300psi annular pressure. Bring on pump 0=1.67 / 1.40 holding 400psi whp cleanout to 11502', taking returns to Tiger Tank. Displace wellbore fluids with 8.7ppg Flo-Pro while TOH following pressure schedule. Good mud to surface after displacing 102 bbls to TT. Take returns inside. Trapped 600 psi on well. Bleed down to 370psi prior to shutting in. Coil wt indicator showing 10k and should be zero or slightly negitive. Coil may be bent. Bleed down residual coil pressure through bleed port. {new mud) Coil is bent 3' above CTC. Undeploy SHA #1. Straighten coil. Install 3 RA tags in WE LSX whipstock 5.68' below TOW PU Weatherford LSX whipstock. MU to BHI tools and note tray face alignments. Pressure deploy. Stab injector. Surface test tools. PT lubricator to 500psi. Open we11370psi. Open EDC. RIH following pressure schedule. Log tie in pass over GR charecter at 11197'. Using Sperry Printed: 8(8!2005 7:43:10 AM gp Page 2 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common W ell Name: 1 D-36 Spud Date: 9/1/2000 Event Nam e: REENTE R+COM PLET E Start: 7!21/2005 End: 8/1/2005 Contractor Name: NORDIC CALIST A Rig Release: 8/1/2005 Rig Name: NORDIC 2 Rig Number: Date ~ From - To i Hours Task j Code 1 NPT ! Phase i Description of Operations --------I ------ L L--- !----~ --~ I 7117/2005 20:20 - 20:35 0.25 STWHIP P WEXIT MWD log as tie in log as per geologist. Make up logging pass as per W F hand. Make -9' correction. 20:35 - 20:50 0.25 STWHIP P WEXIT RIH to 11440', pull up hole to 11419'. PU wt = 27 klbs. WS setting depth is 11419', WS is 9' long, top of WS will be at 11410'. Pressure up on coil to 3400 psi. Good indication of shear. Lost weight and pressure. Set down to confirm it is set. Good indication of weight loss on string wt and downhole WOB sensor. Open EDC. Pickup at 27 klbs. 20:50 - 22:15 1.42 STWHIP P WEXIT POH to pick up window milling BHA. 22:15 - 22:30 0.25 STWHIP P WEXIT PJSM Re: undeployment and redeployment. Held meeting off of the critical path while POH with the whipstock setting BHA. 22:30 - 00:00 1.50 STWHIP P WEXIT Tag up at surface. Undeploy BHA following SOP. 7/18/2005 00:00 - 00:20 0.33 STWHIP P WEXIT Continue undeployment of WF setting tool BHA. All recovered ok, whipstock left in the hole as planned. 00:20 - 01:30 1.17 STWHIP P WEXIT Reconfigure BHI BHA for milling window. Check out on catwalk electrically. Replace packoffs in coil injector. Behead SLB slickline head. Slickline damaged during rig down. 01:30 - 01:50 0.33 STWHIP P WEXIT PJSM for deploying window milling BHA. 01:50 - 03:00 1.17 STWHIP P WEXIT Deploy window milling BHA. (BHA #3). 03:00 - 05:00 2.00 STWHIP P WEXIT RIH with BHA #3. Pumping at minimum rate thru an open EDC and following the pressure schedule. 05:00 - 05:15 0.25 STWHIP P WEXIT Log tie in pass down over GR marker. Make -13' correction. 05:15 - 06:00 0.75 STWHIP P WEXIT Tag top of WS at 11409.5'. Begin milling window. 1.63!1.2913700 psi. IAP=550 psi, OAP=O psi. Pit vol = 331 bbis. 06:00 - 12:00 6.00 STWHIP P WEXIT Time milling window Q= 1.63! 1.38 83% returns fs= 3650 200psi mw full open choke ECD= 11.65ppg slow pump to 1.5 fs= 3550 (new mud also contributing to high ECD's) ECD= 11.59 Q= 1.5 11.32 88% returns 1100 hrs 11414.7' Q= 1.51 / 1.44 seeing sand in samples Milled to 11415.8' (exit 14415.2') 12:00 - 12:30 0.50 STWHIP P WEXIT Drill fromation to 11423' 0= i.5 / 1.47 12:30 - 14:15 1.75 STWHIP P WEXIT Ream window area. Run through wo motor. Clean 14:15 - 16:30 2.25 STWHIP P WEXIT TOH following pressure schedule. 16:30 - 17:20 0.83 STWHIP P WEXIT Pressure undeploy BHA. 370psi on well. 17:20 - 20:40 3.33 DRILL P PROD1 Coil appears to be bent just above coil conector. Cut 20' of coil and rehead. PT new CTC to 3500 psi. Pull test to 35 klbs. CTC weeped on first PT. Tighted connections and repeat. Tested at 3500, 1000, 5000, 200, 0, 200, 500, 3500 psi. Passed ok on a{I tests.. 20:40 - 21:00 0.33 DRILL P PROD1 PJSM Re: deployment of build section BHA. Emphasis placed on good coordination between SLB SL unit operator and Nordic DD. Discussed not getting in a hurry, but doing the job following the proceedure and working at a safe and efficient pace. 21:00 - 22:10 1.17 DRILL P PRODi Deploy L1 lateral build section BHA. Can't get motor thru tubing hanger. PU, slack off numerous times. Try everything we can think of. Rock the lubricator. pump into the well, etc. Hard tag up right at the tubing hanger every time. Not going to be able to lubricate this BHA in the hole. Either need to drop motor bend and lubricate, or kill well and use the pipe wrench technique with this 2.8 degree motor. 22:10 - 23:20 1.17 DRILL N WAIT PROD1 Discuss with DD and Geo reducing motor bend. Examine the Printed: 8/8/2005 7:43:10 AM BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 7/18/2005 ~ 22:10 - 23:20 1 D-36 1 D-36 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 3 of 13 Spud Date: 911/2000 Start: 7/21/2005 End: 8!112005 Rig Release: 8/i/2005 Rig Number: Hours I Task ~ Code ~ NPT !i Phase j Description of Operations r ~____~----'----_----------------- 1.17I~DRILL N ~ WAIT ~ PROD1 possibilty of going wide on the polygon while staying above the 23:20 - 00:00 0.67 DRILL P 7/19/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 02:30 2.00 DRILL P 02:30 - 02:45 0.25 DRILL P 02:45 - 06:00 I 3.251 DRILL l P 06:00 - 09:30 I 3.501 DRILL I P 09:30 - 09:45 0.25 DRILL P 09:45 - 14:00 4.25 DRILL P 14:00 - 15:00 1.00 DRILL P 15:00 - 16:45 I 1.751 DRILL I P 16:45 - 17:05 I 0.331 DRILL ~ P 17:05 - 18:30 1.42 DRILL P 18:30 - 20:15 1.75 DRILL P 20:15 - 22:00 1.75 DRILL P 22:00 - 22:30 0.50 DRILL P 22:30 - 00:00 /20/2005 ~ 00:00 - 06:00 06:00 - 07:40 07:40 - 08:15 1.501 DRILL I P 6.001 DRILL I P B shale. Discuss options with town engineer and Geo. Town geo confirms plan forward is ok. PROD1 Adjust motor shims to 2.2 deg. Redeploy Build section BHA. PROD1 Continue deploying BHA #4, Build section BHA for the L1 lateral. Made it past tubing hanger with this BHA with no trouble. PROD1 RIH with build section BHA. PROD1 Log tie in pass down over GR marker at 11197'. Make -14' correction. PROD1 RIH thru window. Free spin 3520 psi at i.6 bpm. Tag up at 11425'. Begin drilling. 1.6!1.45/3700 psi. Losing about 20 ~- bbls/hr. Pit volume = 450 bbls. IAP=600 psi. OAP=O psi. ECD=11.76 ppg, BHP=3844 psi. PROD1 Continue drilling build section f/ 11470` 0= 1.54 / 1.44 ECD= 11.64 1-2k wob 20-30'/hr PROD1 Wiper trip to the shoe. PROD1 Resume drilling. PROD1 Drilling ahead. Build and turn coming ih as plan. Getting better dog legs than expected with a 2.2 degree motor. ROP=15-40 fph and ratty. Drilling at 1.59!1.5113700 psi. Free spin = 3480 psi at 1.58 bpm. Pit Volume = 351 bbls. IAP=386 psi, OAP=O psi. PROD1 Build and turn section completed. POOH to pick up lateral section BHA. Ratty pickup, possibly due from siderite stringers in hole. ROP thru this section was ratty and slow, and we are seeing pulls at the same depths. PROD1 Hold PJSM Re: Undeployment. Discuss good communications between SLB SL operator and Nordic driller. Focus attention on moving the blocks and SL unit in unison, and staying off the radio when stripping the injector up. We reviewed the step by step proceedure in detail, and made job assignments. PROD1 Undeploy Li build section BHA. (BHA #4). PROD1 Deploy L1 lateral BHA (#5) PROD1 Run in hole. Maintain BHP following WHP schedule.. PROD1 Log GR pass to tie in RA tag to main well bore. Subtract 15' correction. Log RA tag at 11,415.7. TOW: 11,410'. BOW: 11,415.4' , RIH to btm. Hole smooth. PROD1 Drill ahead from 11,700'. 3550 psi fs @ 1.56 in.1.38 out. 100-300dpsi. DHWOB: ik-2k#. WHP/BHP/ECD: 33/3940(11.98 ppg. INC(AZMfTF: 92.1/75.8/90L. IA/OAlPVT: 292/0!332 bbls. PRODi Drill ahead from 11,757'. 3490 psi fs @ 1.61/1.41. 100-3200 dpsi. DHWOB: 1.5-2.5k#. WHP/BHP/ECD:33l3940111.98 ppg. ING/AZMlTF: 92.1/75.8190L. IAlOA1PVT: 464!01277 bbls. ROP varying from 40 to 70 fph with numerous stalls. 1.67 DRILL P PRODi 11926'. Continue drilliing ahead. Fast ROP intervals with an occasional hard streak. Drilling at x.56/1.46/3880 psi. Pit volume =270 bbls. IAP=480 psi, OAP=O psi. ECD=12.43 ppg, BHP=4083 psi. 0.58 DRILL P PROD1 Wiper trip to window. Clean pickup off bottom. Slight amount Printed: 8/8/2005 7:43:10 AM BP Operations Summary Report Page 4 of 13 Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9/1/2000 Event Name: REENTE R+COM PLET E Start : 7/21/2005 End: 8!1/2005 Contractor Name: NORDIC CALIST A Rig Release: 8/1/2005 Rig Name: NORDIC 2 Rig Number: Date ~ From - To !~ ~~ Hours 1 i Task ~ Code i NPT i Phase ~ Description of Operations 7/20/2005 07:40 - 08:15 0.58 DRILL P ~ PROD1 of motor work from 11780'-11700'. Much less than we observed yesterday during the wiper trips after drilling the build section. 08:15 - 09:20 1.0$ DRILL P PRODi Resume drilling. Free spin 3850 psi at 1.55 bpm. Drilling at 1.56/1.51/3950 psi. Pit volume 245 bbls. Vac truck coming to shuttle fluid. 09:20 - 10:15 0.92 DRILL P PROD1 357 bbls in pits after vac truck delivery. Drilling ahead. 10:15 - 10:45 0.50 DRILL P PROD1 Wiper trip to window. Clean PU off bottom at 26 klbs. Slight bobble of motor work at 11782'. Possibly cuttings beds at the start of the build section. No real problem. 10:45 - 10:50 0.08 DRILL P PRODi Log tie in pass over RA tag. Make +3' correction. 10:50 - 1 i:20 0.50 DRILL P PROD1 Continue back in hole on wiper. 11:20 - 14:00 2.67 DRILL P PROD1 Resume drilling. 14:00 - 15:00 1.00 DRILL P PROD1 Wipertrip to the window. Clean PU off bottom at 25 klbs. Clean to window except for 1 little blip of motor work at 11790'. 15:00 - 18:00 3.00 DRILL P PROD1 Drill. ahead from 12325'. 18:00 - 18:45 0.75 DRILL P PROD1 Drill ahead from 12,466'. 3950 psi fs C~3 1.54/1.48 bpm. 100-300 dpsi. DHWOB: 0.5- 1.5k#. WHP/BHPlEGD: 33/4210/12.84 ppg. INC/AZM/TF: 87/23/1508. IA/OA/PVT: 154/327/206 bbls. ROP 30-70 fpm. 18:45 - 20:00 1.25 DRILL P PRODi Wiper trip to i 1,000'. Hole very smooth. 20:00 - 23:30 3.50 DRILL P PROD1 Drill ahead from 12,475'. Call for trucks to swap mud. Complete mud swap. Old mud: 4000 psi fs at 1.51/i.41 bpm. BHP: 4210 psi /ECD: 12.8 PPg• New mud: 3500 psi fs at 1.56/1.56 bpm. BHP: 3890 psi ECD: 11.8 ppg. Big improvement. 23:30 - 00:00 0.50 DRILL P PROD1 Drill ahead from 12600'. ROP varying from 10 to 155 fph. 7/21/2005 00:00 - 00:15 0.25 DRILL P PROD1 Drlf ahead to 12650'. 00:15 -00:45 0.50 DRILL P PROD1 Wiper trip to 11300'. Weld repair reel spoke. 00:45 - 01:00 0.25 DRILL P PROD1 Log gr tie in to RA tag. Add 4' correction. 01:00 - 01:45 0.75 DRILL P PROD1 Wiper trip in hole. Hole very smooth in and out. 01:45 - 05:45 4.00 DRILL P PROD1 Drill ahead from 12,650'. 3800 psi fs ~ 1.61/1.61. 100-200 dpsi. DHWOB: 0.75 - 1.95k#. WHP/BHP/ECD: 33/3850/11.8 ppg. INC/AZM/TF: 92.2/39.4/908. IA/OA/PVT: 95/316!324 bbls. Very erratic ROP. Able to get good DHWOB 1k-2k# 05:45 - 07:00 1.25 DRILL P PROD1 Wiper trip to window. Clean pickup. Clean to window and back down. No problems. 07:00 - 11:30 4.50 DRILL P PROD1 Free spin 3700 psi at 1.55 bpm, Drilling at 1.55!1.54/3750 psi. String wt = -500 lbs. WOB=1500 lbs. ECD=21.2 ppg, BHP=4024 psi. Pit Vol=322 bbls. IAP=171 psi. OAP=340 psi. 11:30 - 13:05 1.58 DRILL P PRODi Wiper trip to the window. Clean PU off bottom at 27 klbs. 13:05 - 18:00 4.92 DRILL P PROD1 Resume drilling from 12950. 272 bbls in pits. Call for Vac truck to add new mud. 18:00 - 21:00 3.00 DRILL P PROD1 Drill ahead from 13005'. 4000 psi fs C~1 1.61/1.57. 100-200 dpsi. DHWOB: 0.50 - 1.35k#. WHP/BHP(ECD: 33(4200!12.7 Printed: 8/8/2005 7:43:10 AM BP Page 5 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To I Hours ii Task i Code j NPT 7/21/2005 18:00 - 21:00 ~ 3.00 ~ DRILL P 21:00 - 22:00 1.00) DRILL I P 22:00 - 23:45 ~ 1.75 DRILL I P 23:45 - 00:00 0.25 DRILL P 7/22/2005 00:00 - 02:00 2.00 DRILL P 02:00 - 06:00 4.00 DRILL P 06:00 - 07:20 1.33 DRILL P 07:20 - 09:15 I 1.921 DRILL I P 09:15 - 13:00 I 3.751 DRILL I P 13:00 - 14:00 I 1,001 DRILL I P 14:00 - 15:00 I 1.001 DRILL I P 15:00 - 16:45 I 1.751 DRILL I P 16:45 - 17:00 0.25 DRILL I P 17:00 - 18:15 1 1.25 I DRILL I P Spud Date: 9/1/2000 Start: 7/2112005 End: 811/2005 Rig Release: 8/1/2005 Rig Number: Phase Description of Operations PROD1 ppg. INC/AZMlTF:87.3/87.5/45L. IA/OA/PVT:249/336/357 bbls. PRODi Drill ahead from 13075'. DHWOB is 0.5k to 1.3k#, but very hard to keep pipe moving and get differential on motor. Decide to try Alpine glass beads. Mix 125 bbls of 12 ppb inn flo pro mud. PROD1 Wiper trip to window. Log gr tie in across RA tag. Add 6.5' correction. Hole very smooth. PROD1 Drill ahead from 13,110'. PROD1 Drill ahead from 13,110'. 3900 psi fs ~ 1.52/1,42. 0-100 dpsi. DHWOB: 0.5 - 1.3k#. WHP/6HP/ECD: 33/4180112.6 ppg. INClAZMtrF: 86.5/75.9/105L. IA/OA/PVT: 270/334/307 bbls. Start 120 bbl glass bead pill. Mud density in: 8.7 ppg. DHWOB increased slowly as beads came up backside. Up wt 23k# with beads vs 26k# without at 13157' at 1.51 bpm Dn wt 3.9k# with beads vs 2.3 k# without while RIH at 30 fpm C«? 1.51 bpm Max DHWOB increased from 1.2# to 1.5k#. Able to maintain a steady 20 fpm ROP for a while. No significant change in motor work. Shakers partially blinded off ,losing 0.1 bpm mud. PRODi Drill ahead to 13215'. Stacking max weight. 1.25k# DHWOB. ROP: 15-20 fph. Slow going. PROD1 Continue drilling ahead with very slow ROP. 1.56/1.52/4020 psi. Pit volume = 255 bbls. IAP=310 psi, OAP=334 psi. ECD=12.7 ppg, BHP=4220 psi. WOB=1000 lbs. PROD1 Wiper trip to window. Clean PU off bottom at 25 klbs, Clean up to window. Clean back in hole. Pump 30 bbl pill of mud with 10#/bbl of Alpine Glass beads to observe if there is any improvement in ROP. PROD1 Tag bottom at 13249'. Free spin 1.5711.56/4000 psi. Drilling at 1.58!1.5414100 psi. Glass beads just coming out. WOB=1260 Ibs prior to beads hittiing formation. WOB= 1300 after hitting formation. No significant change in WOB or ROB with a 30 bbl sweep. ROP still 20-30 fph. PROD1 ROP continues to trend down. Not making much hole, and having difficulty getting weight to bit. PRODi Have only made 2' in last hour. ROP now unacceptable. Possibly a combination of siderite, worn bit, and low WOB. Need to either POH and pick up Agitator, or calf this TD. Begin wiper trip. Call town and ask for orders. Clean PU off bottom. Clean in OH to window. PROD1 Town confirms plan forward is to drill additional footage. Continue trip OOH to pick up Agitator tool and Baker TT checks. PRODi PJSM prior to undeploying BHA. Review proceedure. Focus on good coordination between driller and SLB slickline operator. PROD1 Undeploy BHA #5. LD motor and bit (HCC STR RWD bi-cent 1-1-I, in overall good shape with no broken nose cutters. Bit recovered balled up with clay. Motor checked out ok). SIWHP; 435 psi. Printed: 8/8/2005 7:43:10 AM BP Operations Summary Report Page 6 of 13 Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8!1/2005 Rig Name: NORDIC 2 Rig Number: Date j From - To ; Hours i Task i Code i NPT ~~~ Phase ~ Description of Operations --_-' ------ L-- ~_--- ~ ----` ----~- ----L------__-------__---------------- 7/22/2005 18:15 - 19:30 1.25 DRILL P PRODi Hold PJSM with night crew to review deploy procedure. Also discuss re-configured BHA with agitator & dart check valve. MU BHA #6 (1.0 deg mtr w/ HYC DS 100 bicent bit). Stab coil. Test MWD. Get on well. 19:30 - 22:15 2.75 DRILL P PROD1 Run in hole. Shallow test agitator. Coil vibration indicates tool is working. Continue in hole. Circ at min rate with EDC open. 22:15 - 22:30 0.25 DRILL P PROD1 Log gr tie in from 11430'. Subtract 10' correction. 22:30 - 23:30 1.00 DRILL P PROD1 Gontinue to run in hole. Down wt near btm: 4500#. Noted 2500# without agitator yesterday. Tag TD at 13298'. 23:30 - 00:00 0.50 DRILL P PROD1 Drill ahead from 13398'. 3900 psi fs @ 1.44 in/1.42 out. 100-200 dpsi. DHWOB: 1.95k#. Initial ROP: i0-20 fph. WHP/BHPlECD: 11/4148/12.48 ppg. IA/OA/PVT: 154/358(371 bbls. 7!2312005 00:00 - 03:00 3.00 DRILL C PROD1 Drill ahead from 13310'. 4000 psi fs ~ 1.52 in/1.52 out. 100-200 dpsi. DHWOB: 1.5k - 2.Ok#. INC/AZMIfF: 84.6/63.7/120L. IA/OA/PVT: 245/358/251 bbls i ~ ROP: 10-50 fph 03:00 - 03:45 0.75 DRILL C 03:45 - 05:00 1.25 DRILL C 05:00 - 06:00 1.00 DRILL C 06:00 - 06:45 0.75 DRILL C 06:45 - 07:15 0.50 DRILL C 07:15 - 07:25 0.17 DRILL X 07:25 - 08:10 0.75 DRILL C 08:10 - 08:15 0.08 DRILL X 08:15 - 10:55 2.67 DR1LL C 10:55 - 11:05 0.17 DRILL X 11:05 - 11:20 0.25 DRILL C 11:20 - 14:00 2.67 DRILL P 14:00 - 14:40 0.67 DRILL N PROD1 Drill ahead from 13380'. Alternating hard spots with fast drilling intervals. Appear to be in a lithology change. PROD1 Ciculate bottoms up to get sample. Wiper trip to clean hole. Wait on town to evaluate logs. PROD1 Town decision is to drill up to 50 additional feet. We are close to, but not in B shale yet. PROD1 Resume drilling. Drilling at 1.49!1.45!4170 psi. ROP=70 fph. String wt =-500 lbs. WOB =1000 lbs. IAP=260 psi, OAP=350 psi. ECD=12.68 ppg, BHP=4220 psi. Agitator made a huge difference from yesterday. PROD1 BHI tool may be near falure. It keeps switching on and off. Possibly due to vibration from the Agitator? DFAL PROD1 BHI equipment not working. Could be uphole or downhole. MW D engineer needs some time to sort it out. Make mini wiper trip to give him some time. Clean PU off bottom. Problem is downhole. BHA keeps shutting off. It is working intermittanly. Resume drilling and drill until it fails. PROD1 Free spin 4076 psi at 1.49 bpm. Drilling at 1.49!1.4614200 psi. WOB=1500 lbs. String wt = -7000 lbs. ROP=26 fph. Possibly coming into the B shale that we are looking for. DFAL PROD1 BHI tool shut down. Need to make wiper trip to give MWD engineer time to sort out situation. MWD tool working again. PROD1 Resume drilling. ROP has slowed down, but we are able to get 2500 Ibs WOB with -7600 Ibs string weight. This is significantly better than we were able to achieve yesterday when we were at lockup. DFAL PRODi BHI MW D lost power again. Wiper to see if they can sort it out. PROD1 Power back on. Not sure what the problem it, but it appears to be downhole. Resume drilling. PROD1 Geo has seen the B shale on the GR log. Make wiper to window for final Tie in. Clean PU off bottom. Clean in open hole. Open EDC, pull thru the window. Pump at max rate, 1.92 bpm, 4240 psi. DFAL PROD1 Attempt to log tie in pass at RA tag. BH{ having downhole Printed: 8!8/2005 7:43:10 AM BP Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To ~ Hours ~i Task i Code 7/23/2005 ~ 14:00 - 14:40 ~ 0.67 f DRILL ~ N ~ DFAL ~ PROD1 14:40 - 15:50 1.17 DRILL P PROD1 15:50 - 17:00 1.17 DRILL P PROD1 17:00 - 19:30 I 2.501 DRILL I P I PROD1 19:30 - 21:00 I 1.501 DRILL I P I I PROD1 21:00 - 22:00 I 1.001 CASE I P I I RUNPRD 22:00 - 22:15 I 0.251 CASE I P I I RUNPRD 22:15 - 00:00 I 1.751 CASE I P I I RUNPRD 7/24/2005 00:00 - 01:00 1.00 CASE P RUNPRD 01:00 - 01:45 0.75 CASE P RUNPRD 01:45 - 03:15 1.50 CASE P RUNPRD 03:15 -04:15 1.00 CASE P RUNPRD 04:15 - 04:45 I 0.501 CASE I P I (RUNPRD 04:45 - 06:50 2.08 CASE P RUNPRD 06:50 - 07:30 0.67 CASE P RUNPRD 07;30-08:151 0.751STWHIPIP I IWEXIT 08:15-11:101 2.921STWHIPIP I IWEXIT 11:10-11:451 0.58ISTWHIPP I IWEXIT 11:45 - 13:30 I 1.751 STWHIPI P I IWEXIT Start: 7121 /2005 Rig Release: 8/112005 Rig Number: problems. Can't get GR log. MWD engineer can't get downhole BHA working again. Probably damaged by vibration from Agitator tool. It has been intermitant several times today, and finally gave up the ghost. RIH blind to lay in KW F. Clean all the way to TD. POOH, laying in 10.2# KWF. The first 30 bbls contained 6#Jbbl of the large sized Alpine beads. They were pumped thru the BHI motor with no problems observed. Pulled up smooth in open hole. No problems. Pull thru window, circulate bottoms up. Pull out of hole circulating at 1.4 bpm. At surface. Flow check for 15 minutes. Well stable. Get off well. Unstab coil. LD Inteq tools. RU floor to run liner. Trouble shoot mwd failure from previous run. Tool surface check ok. Coil a-line cable check good. 'Fault found in cable from TL camp {mwd office) to rig. Weekly function test BOPs. Hold PJSM with crew to discuss running liner. Review hazards, job assignments, running order and more. MU 60 jts 2-3/8" 4.6# L-80 R2 STL slotted and solid liner w! indexing guide shoe. Continue to MU 2-3/8" liner assembly. MU mwd tools and GS spear. Stab coil. Run in hole with liner. At window. 7.3k# do wt, 29.7k# up wt. Subtract 12' correction. Continue in hole. Log gr tie in from 13105' at 2.5 fpm. 5k# do wt at 2.5 fpm. Subtract 2.5' correction. Continue in hole. Liner btm at 13,310'. Liner top at 11,394'. Final do wt: 5k# at 30 fpm. Bring on pumps at 1.47 bpm at 4150 psi. Coil up wt 24.5k#. Released from liner. Pull up hole to 13,1 i0'. Tie in to PDC log. Log GR and CCL down to 5' above TOL. Pull out of hole. Tag up at surface. Flow check. No flow observed. Rig down liner running BHA. Make up BHI MWD tool, Weatherford Alpha Fury setting tool and W S-R-BB packer anchor. Scribe orienting slot on anchor to MWD tool. RIH with BHA #8 to set whipstock anchor for L2 lateral window. RIH at 70 fph, pumping at 0.5 bpm thru an open EDC. Log tie in pass up with BHI MWD tools, accross GR marker around 11200'. Make -11.5' correction. Position WS anchor with top at 11370'. Shut EDC. Orient slot to low side. Bring on pumps, pressure tup to 4600 psi. Hold pressure for 2 minutes. PU, got good indication of shear. Set back down, tagged up on top of anchor at 11370.9'. Good indication of set. POOH to pick up WS tray. Note -Orienting slot is oriented straight down. Will need to make sure that WS tray orienting lug is 180 degrees out to WS tray face when we pick up WS Page 7 of 13 Spud Date: 911!2000 End: 8/112005 Description of Operations NPT ! Phase Printed: 8/8/2005 7:43:10 AM BP Page 8 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1/2005 Rig Name: NORDIC 2 Rig Number: Date (From - To ~ Hours ~ Task I Code j NPT ! Phase Description of Operations ------L-----' -------- 1__-- ---- ---_-_--__ -------------- 7/24/2005 11:45 - 13:30 1.75 STW HI P P WEXIT tray. 13:30 - 13:45 0.25 STWHIP P WEXIT Hold PJSM while POOH to discuss BHA swap out. 13:45 - 14:15 0.50 STWHIP P WEXIT Flow check well. Break off injector. Lay down WF Alpha Fury Settling tool. (BHA #8) 14:15 - 14:50 0.58 STWHIP P WEXIT Make up BHA #9, WF whipstock tray with RA tag. Distance from top of WS to RA tag is 2.04'. Orienter scribed to the orienting lug. Tray face 180 degrees out to the orienting fug. Need low side tool face when latching W S tray. 14:50 - 17:30 2.67 STWHIP P WEXIT RIH with BHA #9 to set whipstock tray. Pumping minimum rate, RIH at 70 fpm. 17:30 - 18:00 0.50 STWHIP P WEXIT Log GR tie in from 11200'. Subtract 15' correction. 18:00 - 18:30 0.50 STWHIP P WEXIT Orient to 180 deg. Up wt: 25.4k#. Dn wt: 7.3k#. RIH at 5 fpm. Circ at min rate: 1750 psi @ .59 bpm. EDC open. Tag packer at 11371'. Set do 3k#. PU to 26k#. Set do again with 3k# dn. PU to 30K and jar off. Pressure well to 500 psi. Held ok. Pressure up to 970 psi. Held ok. Bleed off. WS appears to be set. 18:30 - 20:30 2.00 STWHIP P WEXIT Pull out of hole. 20:30 - 21:45 1.25 STWHIP P WEXIT At surface. Flow check. Get off well. Uhstab coil LD WS running tools. (WS in hole). MU window milling assembly (#10). Stab coil. Test mwd. Get on well. 21:45 - 00:00 2.25 STWHIP P WEXIT Run in hole. Prep to swap out 10.4 # mud for 8.6# flo-pro. 7/25/2005 00:00 - 00:15 0.25 STWHIP P WEXIT Tag WS at 1Log gr tie in from 11,210'. Subtract 15' correction. RIH. 00:15 - 06:00 5.75 STWHIP P WEXIT Tag whipstock at 11359'. Flag pipe. Continue to displace well from 10.4 to 8.6 ppg mud. Pump pressure & free spin varying as a result. 8.6# mud to surface. 3650 pis fs at 1.55 in/1.59 out. Several stalls getting started. DHWOB slowly increasing from 0.25k# up to 2.5k# Begin time milling at 1' per hr. WHP/BHP/ECD: 15/3908/12.0 PP9• Observe metal on magnets. 06:00 - 07:25 1.42 STWHIP P WEXIT Milling rathole at 10'/hr. 1 for 1 returns. Window depths (Prior to final tie in on build section run) Window Top = 11359' RA Tag = 11361' Window Bot = 11363.4' 07:25 - 09:25 2.00 STWHIP P WEXIT TD 10' of rathole at 11373'. Ream/Backream window. Make 3 passes. Had a slight over pull with dry drifting. Make an additional 2 passes. Dry drift window again. Smooth down but a slight bump on weight at top of window. Ream just the top 2' of window. Not getting any motor work. Ream for 30 minutes. Dry drift again. Again a slight bump on tension as we pull up thru it. Nothing additional we can do, if we don't get any motor work. 09:25 - 11:15 1.83 STWHIP P WEXIT POOH following back pressure schedule, and pumping thru an open EDC. 11:15 - 11:30 0.25 STWHIP P WEXIT Safety meeting prior to undeploying BHA. Reviewed proceedure, and job assignments. Discuss hazards. Assign the driller to read the checklist as he undeploy's the BHA. 11:30 - 12:45 1.25 STWHIP P WEXIT Undeploy BHA #10, L2 window milling BHA. Both mills Printed: 8/8/2005 7:43:10 AM BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date j From - To 7/25/2005 1 i :30 - i 2:45 12:45 - 15:50 1 D-36 1 D-36 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours i Task ;Code i 1 ~- --- -~___- ~_ -- -l 3.08 DRILLIP P I 15:50 - 16:40 0.83 DRILL N 16:40 - 17:45 1.08 DRILL P 17:45 - 18:15 0.50 DRILL P 18:15 - 19:30 1.25 DRILL P 19:30 - 21:00 21:00 - 21:30 21:30 - 00:00 7!26!2005 00:00 -00:30 00:30 - 01:00 1.50 DRILL P 0.50 DRILL P 2.50 DRILL P 0.50 DRILL- P 0.50 DRILL P 01:00 - 06:00 06:00 - 07:15 07:15 - 09:15 09:15 - 09:30 09:30 - 11:45 11:45 - 13:50 13:50 - 14:05 14:05 - 17:15 17:15 - 18:15 18:15 - 00:00 5.001 DRILL I P 1.25 DRILL P 2.00 DRILL P 0.25 DRILL P 2.25 DRILL P 2.08 DRILL P 0.25 DRILL P 3.17 DRILL P 1.00 DRILL P 5.75 DRILL P Start: 7121 /2005 Rig Release: 8/1/2005 Rig Number: NPT Phase WEXIT~ PROD2 RREP PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Page 9 of 13 Spud Date: 9/1/2000 End: 8/1 /2005 Description of Operations recovered at 2.73" go, 2.72" no go. Cut off CTC. Dress end of eline. Pump slack management. Cut off excess coil. Found eline 120' up inside coil. Build new eline head/CTC. Pull test to 35 klbs. Can't pressure test. Rig mud manifold torn apart. Rig crew replacing a valve on rig floor manifold. Started job during slack management, and not finished yet. Pressure test CTC to 4000 psi. Stab back on well. Pump 1 CT volume forward to complete slack management process. PJSM prior to deploying Build section BHA. BHA #11. Deploy BHA #11 (2.2 deg mtr w/ bi-cent). Stab coil. Test mwd tools. Get on well 390 psi SIWHP after opening swab & master. Run in hole. Maintain 420 psi WHP while circ at min rate. Log gr tie in from 11210`. Subtract 15' correction. RIH through window with HS TF. Drill ahead from 11376'. 3700 psi fs C~ 1.6 in/1.6 out. 100-200 dpsi. DHW06:1k#-2.5k#. WHPIBHP.ECD:1513950/12.2 ppg. IAJOA/PVT: 0/332/381 bbls.TF: 30L Drill ahead from 11,400'. Pull into cased hole and re-log main well bore from 11,210'. Add 1' correction to tie into PDC Iog.RIH to 11,380. Log RA tag. Found it at 11,362'. Final top of window: 11,360' Final RA tag: 11,362' Final bottom of window: 11,364.4'. Drill ahead from 11420'. 3700 psi fs ~ 1.6 in/1.6 out. 100-200 dpsi. DHWOB: 1k# -3.5k#. WHPIBHP.ECD: 15/3950/12.1 ppg. IA/OA/PVT: 77/375/376 bbls. Getting 35-40 deg dog leg in build. Landing shallower than needed. Roll TF to 285-310 to increase turn with build under control. Begin hitting hard streaks at 11,480'. ROP varying from 10 to 50 fph. Continue drilling ahead, 1.6511.68/4150 psi. WOB=3200 Ibs, String wt=600 Ibs. BHP=4050 psi. ECD=12.48 ppg. {AP=115 psi, OAP=370 psi. Pit volume = 371 bbls. Window landed at 11600'. POH to pick up lateral section BHA. PU weight was 25 klbs. A little ratty on pickup. Clean the rest of the way in OH. Got a slug of cuttings just as we tagged up. Did a job with coil to clean it up. Stop at 500'. Hold PJWM with Nordic and SWS crews prior to undeploying BHA. Trap 450 psi on well. Undeploy BHA #11. Bit recovered 1,2, balled up. Adjust motor bend to 1.1 deg. Pick up rebuilt Hughes bi center bit, 2.7" x 3.0". Pressure deploy BHA #12. RIH with BHA #12 to begin drilling lateral section of L2 lateral. Log tie in pass over RA tag in whipstock. Make -16' correction. RIH. Free spin 3830 psi at 1.6 bpm. Tag up at 11597'. Begin drilling lateral section. 1.61/1.6313950 psi. Drilling at 100 fph. Pit volume = 378 bbls. IAP=O> OAP=330 psi. BHP=3998 psi, ECD=12.18 pP9• Wiper trip to window. PVT 384 Drill from 11750' 1.56l4000185L w/ full returns w/ 100-300 psi Printed: 8/8/2005 7:43:10 AM gp Page 10 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common W ell Name: 1 D-36 Spud Date: 911!2000 Event Nam e: REENTE R+COMPLET E Start : 7/21!2005 End: 8/1!2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1/2005 Rig Name: NORDIC 2 Rig Number: Date i From - To i~ Hours ~~ Task '~~ Code NPT i Phase j Description of Operations -~ --------i---1 _--1- _ - ~---- ~ -----1 - - ------ ------__-------_____ 7/26/2005 18:15 - 00:00 5.75 DRILL P PROD2 diff w/ 2-3k wob w/ 4000 psi DHP/12.25 ECD at 91 deg and continue turn in mostly hard (slow) streaks PVT 372 7/27/2005 00:00 - 01:00 1.00 DRILL P PROD2 Continue drilling from 11877' w/ slow ROP in siderite 01:00 - 01;50 0.83 DRILL P PROD2 Wiper to window, clean both ways 01:50 - 07:00 5.17 DRILL P PROD2 Drill from 11900' 1.56/3930175L w1 100-300 psi dill, 2-3k wob w14040 psi DHP/12.37 ECD at 91 deg w/ slow penetration in siderite 07:00 - 10:00 3.00 DRILL P PROD2 Drill ahead from 11988'. 4000 psi fs ~ 1.6 inl1.6 out. 100-200 dpsi. DHWOB: 2k# -3.5k#. WHP/BHP.ECD: 1514060112.4 ppg. IA/OA/PVT: 220/325/356 bbls. Continued slow drilling in C4 interval. Noting a lot of siderite in samples. Begin mud swap at 0845. ECD with old mud: 12.4, BHP 4060 psi, circ press fs: 4000 psi. ECD with new mud: 11.8, BHP 3870 psi, circ press fs: 3750 psi 10:00 - 15:00 5.00 DRILL P PROD2 Drill ahead from 12,035'. ROP avg about 10 fph. 15:00 - 18:00 3.00 DRILL P PR002 Drill ahead from 12,086'. PVT 403 18:00 - 21:40 3.67 DRILL P PROD2 Drill from 12125' 1.77139001110E wl 500-250psi dill, 2-2.5k ' wob wf 12.05 ECD at 90 deg at 6307 TVD. Swap TF to right at 12140'. Penetration rate incr at 12175' PVT 399 21:40 - 22:45 1.08 DRILL P PROD2 Wiper to window, clean both ways 22:45 - 00:00 1.25 DRILL P PROD2 Drill from 12200' 1.6/3600/1108 w/ 200-400 psi diff, 0.5-2.Ok wob w/ 12.0 ECD at 88 deg at 6309' TVD at 60'fhr to 12220' and then back into siderite Gen 1 shut down. Change SCR assignment to use #2 & #3 7!28!2005 00:00 -06:00 6.00 DRILL P PROD2 Continue drilling in siderite from 12221' 1.6/3600/1208 w! 100-300 psi diff, 1.5-2.5k wob at 3890 psi DHP/11.9 ECD at 88 deg at 6310' TVD 06:00 - 10:30 4.50 DRILL P PROD2 Drill ahead from 12,295'. 3600 psi fs C 1.6 in/1.6 out. 100-200 dpsi. DHWOB: 1.5k# -3.Ok#. WHPIBHP.ECD: 1513940!12.0 ppg. IA/OA/PVT: 250!3331382 bbls. I N C/AZM/TF: 88.1 /14.7/65 R. Continued very slow drilling, attributed to siderite in C4 interval. 10:30 - 11:30 1.00 DRILL P PROD2 Wiper trip to 10,700'. Open EDC up inside casing. RIH to 11,286'. Hold 200 psi Whp at 0.53 bpm. 11:30 - 12:15 0.75 DRILL P PROD2 Trouble shoot Genset #1 problem while inside casing. 12:15 - 12:45 0.50 DRILL P PROD2 Log gr tie in from 11270'. Add 4' correction. 12:45 - 13:15 0.50 DRILL P PROD2 Continue wiper trip back to bottom. 13:15 - 18:30 5.25 DRILL P PROD2 Drill ahead from 12,350'. PVT: 372 18:30 - 23:00 4.50 DRILL P PROD2 Drill from 12440' 1.53/3450/758 w/ 100-300 psi diff, 1-3k wob at 12.1 ECD at 87 deg at 6320' TVD. Drill to 12500' (6324' TVD) PVT 379 23:00 - 00:00 1.00 DRILL P PROD2 Wiper to window 712912005 00:00 - 00:15 0.25 DRILL P PROD2 Finish wiper from window, clean both ways 00:15 - 05:15 5.00 DRILL P PROD2 Drill from 12500' 1.52/3600/808 w/ 100-250 psi diff, 1-2k wob w/ 4000 psi DHP/12.2 ECD at 84 deg (6330' TVD) and miserably slow and still in siderite. Start losing 2 bph at 12520' PVT 349 05:15 - 06:00 0.75 DRILL P PROD2 Wiper to window, clean 06:00 - 08:00 2.00 DRILL P PROD2 POOH for bit following pressure schedule 08:00 - 09:30 1.50 DRILL P PROD2 PJSM. Undeploy BHA. Blow down BHA on catwalk with new plumbing hook up to pits. Worked well. Bit pilot cutters not Printed: 8/8!2005 7:A3:10 AM BF Page 11 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common W ell Name: 1 D-36 Spud Date: 9/112000 Event Nam e: REENTE R+COM PLET E Start : 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALIST A Rig Release: 8/112005 Rig Name: NORDIC 2 Rig Number: Date i ' From - To !Hours ! ' Task ~ ~ Code ~~ NPT ' Phase ~ Description of Operations _ 7!29!2005 08:00 - 09:30 1.50 DRILL P PROD2 chipped or missing, but significantly worn. (2-2-I) 09:30 - 14:00 4.50 BOPSU P PROD2 Bi-weekly BOP pressure test. Witness waived by AOGCC J. Crisp. 14:00 - 15:30 1.50 DRILL P PROD2 Hold PJSM. MU BHA #13 (1.1 mtr w/ new HCC bi-cent). 385 psi SIWHP once master & swab were opened. Stab coil. Get on well. 15:30 - 17:45 2.25 DRILL P PROD2 Run in hole. Follow BHP pressure schedule and circ at minimum rate. 17:45 - 18:00 0.25 DRILL P PROD2 Log gr tie in from i 1,210'. Corr -12' 18:00 - 18:30 0.50 DRILL P PROD2 Wiper to TD tagged at 12551', clean PVT 320 18:30 - 21:25 2.92 DRILL P PROD2 Drill from 12551' 1.53/1.48/3630/808 w/ 100-300 psi dill, 1-2k wob, w/ 4080 psi DHP/12.4 ECD at 84 deg at 60'/hr. Losses increased at 12660' to 1.53!1.37 or about 10 bph, and then to 1.5211.25 at 12695' (vicinity of C4/C3 interface as well as fault). Drill to 12700' (6348' TVD) 21;25 - 23:15 1.83 DRILL P PROD2 Wiper to window, clean both ways 23:15 - 00:00 0.75 DRILL P PROD2 Drill from 12700' 1.53/1.40/3580/85L w/ 100-500 psi dill, 0.5-1.5k wob w/ 12.3 ECD at 84 deg at 50-60'/hr. Drill o 12747 (6352' TVD) PVT 266 7/30/2005 00:00 - 00:10 0.17 DRILL P PROD2 100' wiper to remove TF change dogleg while swap pumps to change leaking swab 00:10 - 02:30 2.33 DRILL P PROD2 Drill from 12747' 1.5/1.38/3650/60L wt 100-350 psi dill, 0.5-1.5k wob w/ 4090 psi DHP/12.4 ECD at 85 deg to 12850' (6358' TVD) PVT 244 02:30 -04:20 1.83 DRILL P PROD2 Wiper to window, clean both ways PVT 225 04:20 - 06:00 1.67 DRILL P PROD2 Drill from 12850' 1.50/1.40/3700/85L w! 100-350 psi dill, 0.5-1.5k wob w! 12.5 ECD at 90 deg 06:00 - 08:15 2.25 DRILL P PROD2 Dri11 ahead from 12,920 3700 psi fs Cam? 1.5 in/1.45 out. 100-200 dpsi. DHWOB: O.Sk# -2.Ok#. WHP/BHP.ECD: 15!4145/12.6 ppg. IA/OA/PVT: 125/3391209 bbls. I N C/AZM/TF: 86.5/44.7/85L. 08:15 - 09:30 1.25 DRILL P PROD2 Wiper trip to 10,800', Hole smooth. 09:30 - 09:45 0.25 DRILL P PROD2 Log gr tie in at RA tag. Add 5' correction. 09:45 - 10:45 1.00 DRILL P PROD2 Continue wiper trip back to bottom. Hole smooth. 10:45 - 13:30 2.75 DRILL P PROD2 Drill ahead from 13,000'. PVT: 180 bbls. Begin displacement to new 8.6 ppg mud. Circ pressure dropped 400 psi f/ 3900 psi to 3500 psi. ECD dropped from 12.6 to 11.9 ppg. ROP and weight transfer improved as well. 13:30 - 15:15 1.75 DRILL P PROD2 Drill ahead from 13,100'. PVT: 377 bbls. 15:15 - 17:15 2.00 DRILL P PROD2 Wiper trip to window. Hole smooth in both directions. PVT 371. 17:15 - 20:30 3.25 DRILL P PROD2 Drill ahead from 13,150' 1.60/1.58/3530/1108 w! 200-400 psi dill, 0.5-1.Ok wob w/ 3950 psi DHP/12.0 ECD at 87 deg. Drill to initial TD of 13300' (6385' TVD) 20:30 - 21:45 1.25 DRILL P PROD2 Wiper to/thru window, clean 21:45 - 22:20 0.58 DRILL P PROD2 Wiper to 10800' to remove solids in high angle 1.5/3350 22:20 - 22:30 0.17 DRILL P PROD2 Log tie-in down from 11380', Corr +5' 22:30 - 23:45 1.25 DRILL P PROD2 Wiper to TD. Start 10 bbls 10.4 ppg NaCI/NaBr KWF at 12500' followed by 40 bbls KWF w/ 6 ppb coarse plastic beads (yes, all beads have been plastic, not 'glass'). Tag TD at 13302' w/ +4k surface string wt. Wiper up hole 30k while wo beads to get to bit 23:45 - 00:00 0.25 DRILL P PROD2 Wiper thru OH while lay in KWF 0.9!2065 @ 45'/min Printed: 8(8(2005 7:43:10 AM BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7!31!2005 100:00 - 00:30 00:30 - 02:40 02:40 - 02:55 1 D-36 1 D-36 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 i ~ 1 i Hours ~ Task ;Code j ~~ ___ _ _i 0.50 {DRILL I P 2.171 DRILL I P 0.25! DRILL IP 02:55 - 03:25 0.50 DRILL P 03:25 - 03:35 0.17 CASE P 03:35 - 03:55 0.33 CASE P 03:55 - 05:45 1.83 CASE P 05:45 - 06:30 0.75 CASE P 06:30 - 08:00 1.50 CASE P 08:00 - 09:30 I 1.501 CASE I P 09;30 - 11:30 2.00 CASE P 11:30 - 13:00 1.50 CASE P 13:00 - 15:00 { 2.00 I CASE I P 15:00 - 16:00 I 1.001 STWHIPI P 16:00- 16:15 I 0.25{ STWHIPIP 16:15 - 18:45 { 2.501 STWHIP{ P Page 12 of 13 Spud Date: 9/1/2000 Start: 7/21/2005 End: 8!1/2005 Rig Release: 8/1/2005 Rig Number: NPT ~ Phase ~ Description of Operations PROD2 Continue POOH thru OH laying in 10.4# KWF w! beads 0.9!2080 PROD2 POOH for finer while fin displ to KWF Flag CT at 11300' and 9400' EOP PROD2 Tag up, flow check. PVT 307 Safety mtg re: BHA PROD2 LD drilling BHA RUNPRD Safety mtg re: run liner RUNPRD RU to run liner RUNPRD MU 58 jts 2-318" 4.6# L80 STL R2 solid and slotted liner w! BTT deployment sub RUNPRD MU MWD assy. Stab coil. Get on well. PVT: 309 bbls. RUNPRD Run in hole with L2 liner assembly. Tie into EOP flag at 9400'. Subtract 19' correction. 31 k# up, 8.5k# do RUNPRD Run through window ok. 5.1 k# surfacel3.4k# DHWOB at 13,000' while RIH at 2 fpm. Log GR tie in from 11,185'. Add 7' correction. Continue to run in hole. Log RA tag. No correction. Clrc at 1.35 bpm ~ 4300 psi. PU and attempt to release. Unable to do so an depth. Repeat several times. No release. PU into casing. Release and push liner back on depth. 25k# up wt once released. Liner top at 11,375' Liner btm at 13,210'. Liner top RA tag at 11,377'. RUNPRD Pull out of hole with running assembly. RUNPRD At surface. Flow check. Unstab coil. Get off well. PVT: 298 bbls LD Baker tools. LD Inteq DPS & DGS. PJSM with Weatherford & crew. MU box tap, disc, motor, jars & Inteq tools. RUNPRD Run in hole with WS recovery BHA #15 Kick while tripping drill. Nordic Pit watcher and SLB Supervisor responded immediately, and investigated sourcelnature of pit increase (accomplished manually by placing a cup of water under one of the pit level sensors). WEXIT Wt check: 7k# dn, 28k# up. Close EDC. Correct -12' as per past runs. 3690 psi fs ~ 1.3 in/.73 out. RIH at 10 fpm. Tag fish at 11,380'. Stall at 3-4k# dn. PU. No catch. Repeat while RIH at 5 fpm. PU. No catch. RIH slower (2 fpm. Take wt at 11366'. Work over fish with pump and wt. PU to 26k#. Have fish. Pull up to 43k#. Still latched. Cock jars and PU to 35k#. Fire jars. PU to 42k#. No release. Re-set jars. PU to 37k#. Jars fired. PU to 42k#. No release. Re-set jars. PU to 38k#. Jars fired. PU to 43k#. No release. WEXIT Re-set jars. PU to 39k#. Jars fired. PU to 43k#. No release. Re-set jars. PU to 39k#. Jars fired. PU to 41 k#. RE-set jars. PU to 41 k#. Jars fired. PU to 42k#. No release. Re-set jars. PU to 43k#. Jars fired. PU to 43k#. No release. Re-set jars. PU to 43k# Jars fired. PU to 44k#. No release.. Reset jars.PU to 45k#. Jars fired. Something came free. Cannot tell what. Open EDC. PVT 308 WEXIT Pull out of hole. Printed: 8/8/2005 7:43:10 AM gp Page 13 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21!2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8f1/2005 Rig Name: NORDIC 2 Rig Number: i i Date 1 From - To ~ Hours ~ Task ~ Code ~ NPT '~ Phase ~ Description of Operations 7(31(2005 18:45 - 19:00 0.25 STWHIP P WEXIT Tag up, flow check Safety mtg 19:00 - 19:30 0.50 STWHIP P WEXIT LD WIS WS and WS fishing tools. The {ower 1" of external surface of box tap had scars from rotation on bottom of window 19:30 - 21:30 2.00 BOPSU P POST RIH w/ nozzle assy to displ wellbore circ 0.5/1250 w/ KW F 21:30 - 23:15 1.75 BOPSU P POST POOH 25k displacing wellbore to SW 1.5/2950 while recover KWF following pressure schedule. POOH from 2500' displacing wellbore to diesel 23:15 - 23:25 0.17 BOPSU P POST Tag up w( 1000 psi. Monitor WHP for 10 min and stabilized at 820 psi for 5 min 23:25 - 00:00 0.58 RIGD P POST Bleed off press. RU and pump SW thru ail surface lines prior to maintenance Meanwhile, MIRU SWS N2 and cool down 8/112005 00:00 - 00:10 0.17 RIGD P POST Safety mtg re: N2 00:10 - 01:45 1.58 RIGD P POST PT SWS ~ 3500 psi. Blow down reel wf N2 to tiger tank and bleed off 01:45 - 05:30 . 3.75 RIGD P POST Unstab CT from injector. Cut off CTC. Pull back onto reel and load out .Clean pits, remove packoff from injector, general RD 05:30 - 06:00 0.50 RIGD P POST ND BOPE. 06:00 - 15:00 9.00 RIGD P POST Continue prep for move to 1 B Pad. Clean pits. Continue ND of BOPS. NU and test tree cap. Disconnect ESD from adjacent well. Lay down deployment lubricator. Remove PIP tags from whipstock. Unload pipe shed. Prep to pick up berm under rig (in place for painting). Finish cleaning pits and cuttings box. Extra thorough cleaning to prep for inspections & painting. SLB began to dissassemble hard line in reel house for inspection. Release rig at 1500 hrs on 8-1-05. Printed: 8!8/2005 7:43:70 AM Conoc Phillips ~aker Hughes INTEQ ~ BA ~"r ~~ Baker Hu hes INTE Surve Re ort g Q Y P l!'rt~.{~ Company: ConocoPhillips Alaska, Inc Date: 815!2005 Time: 11:55:56 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Welt: 36, True North Site: Pad 1 D Vertical (TVD) Reference: WeNhead(106`) 106.0 Well: 36 Section (VS) Reference: User (O.OON,O.OOE,30.OOAzi) Weitpath: 1D-36L1 Survey Caicuiatioo Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA 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: Pad 1D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 36 Slot Name: We-1 Position: +NI-S -477.23 ft Northing: 5959188.94 ft Latitude: 70 17 56.622 N +E/-W -420.10 ft Easting : 560670.73 ft Longitude: 149 30 31.154 W Position Uncertainty: 0.00 ft Wellpath: 1 D-36L1 Drilled From: 1 D-36 Copy Lamar's Plan#8 Tie-on Depth: 11275.03 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4!412005 Declination: 24.40 deg Field Strength: 57597 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 30.00 Survey Program for Definitive Wellpath Date: 8/1/2005 Validated: Yes Version: 3 Actual From To Survey Toolcode Tooi Name ft ft 202.80 11275.03 MWD w/IFR<0 - 11660'> (202.80-11660.00 )P(I~'yD+SAG+IFR MWD+SAG+IFR (AK) 11300.00 13548.00 MWD (11300.00-13548.00) MWD MWD -Standard Annotation MD TVD. ft ft 11275.03 6359.88 TIP 11410.00 6425.50 KOP 13548.00 6588.07 TD Survey: MWD Start Date: 7/19/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Ind' Azim TVD SS TVD N/S E/W MapN MapE "VS DLS Tool ft deg deg ft ft ft ft $ ft ft degl100ft 11275. 03 60.85 170.00 6359.88 6253. 88 -7283. 92 2776.66 5951928 .37 563505.84 -4919.73 0.00 MWD 11300. 00 60.85 170.03 6372.04 6266. 04 -7305. 40 2780.44 5951906 .93 563509.79 -4936.44 0.10 MWD 11370. 85 60.85 170.13 6406.56 6300. 56 -7366. 35 2791.10 5951846 .07 563520.94 -4983.89 0.12 MWD 11400. 00 61.16 170.18 6420.69 6314. 69 -7391. 47 2795.46 5951820 .99 563525.50 -5003.47 1.07 MWD 11410. 00 61.26 170.20 6425.50 6319. 50 -7400. 10 2796.95 5951812 .37 563527.07 -5010.20 1.02 MWD 11440. 05 69.83 164.00 6437.94 6331. 94 -7426. 71 2803.10 5951785 .81 563533.43 -5030.17 34.13 MWD 11473. 42 79.74 157.19 6446.70 6340. 70 -7457. 01 2813.82 5951755 .60 563544.39 -5051.05 35.62 MWD 11502. 38 84.30 143.63 6450.73 6344. 73 -7481. 88 2827.96 5951730 .86, 563558.73 , -5065.51 48.96 MWD 11532. 33 90.57 132.51 6452.08 6346. 08 -7504. 08 2847.92 5951708 .81 563578.66 -5074.77 42.58 MWD 11563. 07 92.78 117.32 6451.17 6345. 17 -7521. 62 2873.04 5951691 .48 563604.12 ' ~ -5077.40 49.91 MWD 11590. 37 90.72 105.31 6450.34 6344. 34 -7531. 52 2898.41 5951681 .79 563629.57 -5073.28 44.61 MWD Conoc Phillips ~aker Hughes INTEQ ~ ~ ~°'"~ Baker Hughes INTEQ Survey Report ~~.I-~~ Company: ConocoPhi4lips Alaska,. inc Date: 8/5/2005 Time: 11:55:56 Page: 2 Field: Kupanak River Unit Co-ordinste(NE) Reference: Well: 36, True North Site: Pad 1D Vertical ('TVD) Reference: WeUhead(106') 106.0 Well: 36 Section (VS) Reference: User (O.OON,O.OOE,30.OOAzi) Wellpath: 1 D-36L1 Survey Calculation Mett+od: Minimum. Curvature Db: Oracle Survey MD Incl. Azim TVD SS TVD N/S ft deg deg ft ft ft 11621.95 87.68 87.81 6450.78 6344.78 -7535.11 11650.97 92.10 75.80 6450.84 6344.84 -7530.99 11679.57 91.58 68.43 6449.92 6343.92 -7522.21 11709.85 94.72 58.46 6448.25 6342.25 -7508.72 11743.58 91.74 55.66 6446.35 6340.35 -7490.41 11776.89 91.89 48.92 6445.29 6339.29 -7470.06 11804.57 87.80 43.24 6445.37 6339.37 -7450.87 11838.01 90.57 41.42 6445.84 6339.84 -7426.15 11870.59 91.09 36.95 6445.37 6339.37 -7400.91 11899.52 89.19 31.80 6445.30 6339.30 -7377.04 11930.37 90.57 27.54 6445.37 6339.37 -7350.24 11960.03 93.24 27.69 6444.38 6338.38 -7323.98 11990.88 92.26 21.54 6442.90 6336.90 -7295.98 12021.07 92.23 16.02 6441.71 6335.71 -7267.43 12050.59 89.34 11.87 6441.31 6335.31 -7238.79 12079.02 89.55 7.92 6441.59 6335.59 -7210.79 12112.43 89.58 1.85 6441.84 6335.84 -7177.52 12140.25 89.19 359.15 6442.14 6336.14 -7149.70 12171.85 91.06 358.40 6442.07 6336.07 -7118.11 12207.18 92.04 359.78 6441.11 6335.11 -7082.80 12239.74 90.32 2.81 6440.44 6334.44 -7050.26 12272.33 89.86 5.30 6440.39 6334.39 -7017.75 12305.14 88.27 11.85 6440.93 6334.93 -6985.33 12335.82 89.40 17.22 6441.55 6335.55 -6955.65 12365.03 90.29 18.45 6441.63 6335.63 -6927.85 12386.49 88.73 19.53 6441.81 6335.81 -6907.56 12421.06 87.65 23.10 6442.91 6336.91 -6875.37 12458.90 84.20 25.64 6445.60 6339.60 -6841.00 12488.26 85.28 29.78 6448.29 6342.29 -6815.12 12519.78 83.77 33.03 6451.30 6345.30 -6788.35 12548.91 83.09 35.36 6454.63 6348.63 -6764.41 12579.87 82.20 38.43 6458.59 6352.59 -6739.86 12607.59 85.93 44.05 6461.46 6355.46 -6719.14 12644.91 86.30 48.14 6463.99 6357.99 -6693.33 12671.31 85.44 51.56 6465.89 6359.89 -6676.35 12700.64 83.77 54.30 6468.65 6362.65 -6658.75 12733.51 84.92 58.25 6471.89 6365.89 -6640.60 12762.83 87.16 61.45 6473.92 6367.92 -6625.91 12791.20 85.51 66.46 6475.73 6369.73 -6613.48 12822.46 86.49 73.54 6477.92 6371.92 -6602.82 12850.00 83.93 76.98 6480.22 6374.22 -6595.84 12880.79 84.33 81.76 6483.37 6377.37 -6590.19 12913.00 87.50 87.34 6485.66 6379.66 -6587.15 12940.22 82.20 89.69 6488.10 6382.10 -6586.44 12971.89 82.42 87.67 6492.34 6386.34 -6585.72 13006.46 83.93 84.97 6496.45 6390.45 -6583.51 13044.85 84.70 79.13 6500.26 6394.26 -6578.23 13082.44 86.45 75.90 6503.16 6397.16 -6570.13 13116.35 85.37 77.07 6505.58 6399.58 -6562.23 13143.91 84.57 74.03 6507:99 6401.99 -6555.38 131.76.41 84.70 71.19 6511.03 6405.03 -6545.71 13208.65 85.74 68.22 6513.72 6407.72 -6534.56 13241.07 84.57 63.66 6516.46 6410.46 -6521.40 E/W MapN MapE ft ft ft 2929.66 5951678.45 563660.84 2958.32 5951682.80 563689.47 2985.50 5951691.80 563716.58 3012.51 5951705.51 563743.47 3040.77 5951724.04 563771.58 3067.09 5951744.60 563797.73 3087.02 5951763.95 563817.50 3109.53 5951788.84 563839.81 3130.11 5951814,25 563860.18 3146.44 5951838.25 563876.32 3161.70 5951865.17 563891.37 3175.44 5951891.54 563904.89 3188.27 5951919.64 563917.49 3197.98 5951948.26 563926.97 3205.09 5951976.95 563933.85 3209.97 5952004.99 563938.50 3212.82 5952038.28 563941.08 3213.06 5952066.09 563941.10 3212.38 5952097.68 563940.17 3211.82 5952132.98 563939.32 3212.56 5952165.52 563939.79 3214.86 5952198.04 563941.84 3219.75 5952230.50 563946.46 3227.45 5952260.23 563953.92 3236.39 5952288.11 563962.64 3243.38 5952308.45 563969.45 3255.93 5952340.73 563981.75 3271.50 5952375.23 563997.04 3285.10 5952401.21 564010.42 3301.44 5952428.12 564026.55 3317.70 5952452.18 564042.62 3336.13 5952476.88 564060.85 3354.30 5952497.74 564078.84 3381.12 5952523.77 564105.45 3401.25 5952540.90 564125.44 3424.54 5952558.69 564148.59 3451.74 5952577.06 564175.64 3477.03 5952591.95 564200.80 3502.46 5952604.58 564226.13 3531.74 5952615.48 564255.32 3558.28 5952622.67 564281.80 3588.37 5952628.56 564311.84 3620.34 5952631.87 564343.78 3647.43 5952632.79 564370.86 3678.80 5952633.77 564402.22 3713.05 5952636.25 564436.45 3750.87 5952641.83 564474.22 3787.45 5952650.23 564510.74 3820.34 5952658.40 564543.55 3846.92 5952665.46 •564570.08 3877.80 5952675.38 564600.87 3907.93 5952686.76 564630.91 3937.42 5952700.17 564660.29 VS DLS Toot ft deg1100ft -5060.77 56.23 MWD -5042.86 44.09 M W D -5021.67 25.82 MWD -4996.48 34.47 MWD -4966.50 12.11 MWD -4935.71 20.23 MWD -4909.13 25.28 MWD -4876.47 9.91 MWD -4844.32 13.81 MWD -4815.49 18.97 MWD -4784.64 14.51 MWD -4755.03 9.02 MWD -4724.37 20.16 MWD -4694.79 18.27 MWD -4666.43 17.13 MWD -4639.74 13.91 MWD -4609.50 18.17 MWD -4585.29 9.81 MWD -4558.27 6.38 MWD -4527.97 4.79 MWD -4499.42 10.70 MWD -4470.12 7.77 MWD -4439.60 20.54 MWD -4410.05 17.88 MWD -4381.50 5.20 MWD -4360.43 8.84 M W D -4326.28 10.78 MWD -4288.73 11.31 MWD -4259.52 14.52 MWD -4228.16 11.33 MWD -4199.30 8.28 M W D -4168.82 10.25 MWD -4141.80 24.24 MWD -4106.03 10.98 MWD -4081.27 13.33 MWD -4054.38 10.90 MWD -4025.05 12.46 MWD -3999.69 13.30 MWD -3976.21 18.56 MWD -3952.34 22.81 M W D -3933.03 15.53 MWD -3913.09 15.50 MWD -3894.47 19.88 MWD -3880.31 21.28 MWD -3864.00 6.36 MWD -3844.97 8.90 MWD -3821.48 15.27 MWD -3796.17 9.75 MWD -3772.88 4.69 MWD >3753.66 11.36 MWD -3729.85 8.71 MWD -3705.13 9.73 MWD -3678.99 14.47 MWD `Conoc Phittips ~aker Hughes INTEQ ~ ~ ~`~ Baker Hughes INTEQ Survey Report ivT~t~ Company: ConocoPhiliips Alaska, Inc Date: 8/5/2005 Time: 1.1:55:56 Page:. 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 36, True Notth Site: Pad 1 D Vertical (1'VD) Reference: Wellhead(106') 106.0 Well: 36 Section (VS) Reference: User (O.OON,O. OOE,30.OOAzi) Weilpath: 1D-36L1 Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey MD Ind Azim TVD SSTVD N/S iE/W MapN MapE VS I)LS Too( ft deg deg ft ft ft ft ft ft ft deg/100ft 13276.03 83.57 57.65 6520.08 6414.08 -6504.37 3967.71 5952717.44 564690.44 -3649.09 17.34 MWD 13309.86 83.19 53.07 6523.98 6417.98 -6485.27 3995.35 5952736.76 564717.93 -3618.73 13.49 MWD 13345.86 78.37 49.71 6529.75 6423.75 -6463.11 4023.11 5952759.14 564745.50 -3585.66 16.25 MWD 13379.16 77.28 44.32 6536.77 6430.77 -6440.93 4046.92 5952781.51 564769.12 -3554.55 16.16 MWD 13412.59 77.87 37.23 6543.98 6437.98 -6416.22 4068.22 5952806.38 564790.23 -3522.50 20.79 MWD 13441.28 76.17 29.99 6550.43 6444.43 -6392.96 4083.69 5952829.77 564805.51 -3494.62 25.29 MWD 13472.02 70.33 22.07 6559.30 6453.30 -6366.56 4096.62 5952856.27 564818.22 -3465.29 31.13 MWD 13500.25 67.16 18.04 6569.53 6463.53 -6341.86 4105.65 5952881.04 564827.05 -3439.39 17.41 MWD 13548.00 67.16 18.04 6588.07 6482.07 -6300.02 4119.27 5952922.99 564840.33 -3396.34 0.00 MWD n ~ ~ ~ ~ ~31 l ~ ~ ~ ~ erg ' ~1~j ! ~ ~ ,t ! ~ ~ ~ i , t (i ~ V ,, ,~s, ~~ ~ ~~ ~ 7 i ,i3 ~ ~ ~ ~ d m7h ~ i 3~ ', a i? ~~.~ 1 ~~ ' ~ ~ , ~ ~'°;~a ~ I~;~ ~ s ~~ ~',~ ~"~~ ~ FRANK H. MURKOWSKI, GOVERNOR ~. ~r ~ ~-a ~~ OI~ ~ Vro-7 ~~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQATI011T COl-i1rIISSIOI~T '~ ANCHORAGE, ALASKA 99501-3539 PHONE 907 279-1433 ( ) F AX (907) 276-7542 Scott Kolstad CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6b 12 Re: Kuparuk 1D-36L1 ConocoPhillips Alaska, Inc. Permit No: 205-084 Surface Location: 477' FNL, 420' FEL, SEC. 23, Tl 1N, R10E, UM Bottomhole Location: 1563' FNL, 3535' FWL, SEC. 25, T11N, R10E, UM Dear Mr. Kolstad: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to i ess any required test. Contact the Commission's petroleum field inspector at (907) f 59-3 07 ager). DATED this fQ day of June, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i STATE OF ALASKA ALASKA AND GAS CONSERVATION COSSION PERMIT TO DRILL 20 AAC 25.005 ~ ~~ _ ~ ,,,:e 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ ulti~le 2oitie ^ Stratigraphic Test ^ Service ^ Development ~., d 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 1~D~~~L• 1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 13375 - TVD 6420ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 477' SNL 420' WEL SEC 23 T11N R10E UM 7. Property Designation: ADL 025661 River Pool , , . , , , lop of Productive Horizon: 2553' SNL, 2364' EWL, SEC. 25, T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: July 10, 2005 Total Depth: 1563' SNL, 3535' EWL, SEC. 25, T11N, R10E, UM 9. Acres in Property: 2560 ~ 14. Distance to Nearest. Property: 4250' 4b. Location of Well {State Base Plane Coordinates): Surface: x- 560671 ~ y- 5959189 ' Zone- ASP4 10. KB Elevation (Height above GL): 105.3 feet 15. Distance to Nearest Well Within Pool 1 D-37 is offset by 1735' 16. Deviated Wells: Kickoff Depth: 11410 feet Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3264 Surface: 2622 18. Casing Program: Size Specifications Setting Depth To Bottom uantity o ' ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-318" 4.6# L-80 STL 1900' 11400' 6315' 13300' 6437' Uncemented Slotted Liner 19. PRESENT W ELL CONDITION SUMMARY (To be completed for Redrill AND Ae-entry Operations) Total Depth MD (ft): 11658 Total Depth TVD (ft): 6542 Plugs (measured): None Effective Depth MD (ft): 11589 Effective Depth TVD (ft): 6510 Junk {measured): None Casin Len th Size Cement Volume MD TVD r o c o 121' 20" 14 cu ds ABI T III 121' 121' 7047' 9-518" 50 sx AS III Lite, 415 sx LiteCrete 7047' 4297' 11038' 7" 170 sx Class 'G' 11038' 6245' Pro c ion i 771' 3-112" 174 sx Class 'G' 10885' - 11656' 6170' - 6541' Perforation Depth MD (ft): 11410' - 11484' Perforation Depth TVD (ft): 6426' - 6461' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Kolstad, 564-5347 Printed Name ott Kolstad Title CT Drilling Engineer Preparetl By Name/Number: Si nature Phone 564-5347 Date Terrie Hubble, 564-4628 Commission Use Only Permit To Drill __ Number: ~-,- `z' ~, API Number: 50- 029-22973-60-00 Permit Approval Date: ~ ~ ~ See cover letter for other requirements Conditions of Approval: Sample quired ~~ Yes ~No Mud Log Required ~J! Yes '~'No Hydr en ' (fide Measures 'Yes =~; No Directional Survey Required y~{Yes " No Other: -3~ ~ \ v~ w~. Q b~ ~c.S~ . APPROVED BY tD ~~ A roved `~ {"~ THE COMMISSION Date Form 10-401 R~Tised 06/~A64 ~ `..~° ' "~, z ~;? ~ I ~ $~'°'j ~ /Subrdt In Duplicate KRU 1 D-36L1 and 1 D-36L2 Sidetracks -Coiled Tubin Drillin 9 g Summary of Operations: Coiled tubing drilling will dri112 laterals in producer KRU 1D-36 using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). These horizontal laterals will target Kuparuk C sand reserves for production. CTD Drill and Complete 1D-36L1 & 1D-36L2 program: Planned for .Tuly 10, 2005 1. 2. 3. 4. 5. 6. 1D3~~-1 7. 8. 9. 10 Pre CTD Positive pressure and drawdown tests on MV and SV Pre CTD MIT-IA, MIT-OA Pre CTD Caliper 3-112" liner Pre CTD drift tubing/liner with dummy whipstock MIRU Nordic 2. NU 7-1/16" BOPE, test. Set 3-112" LSX whipstock C~ 11,410' md. Mill 2.74" window and 10' of open hole. Dri113" bicenter hole horizontal lateral from window to 13,300' TD targeting Kuparuk C1/C2 sands. Kill well w/ brine & Complete with 2 318" slotted liner from TD up into the 3-1/2" liner to ~ 1 l ,400' . W~ W 11. Stab into packer with retrievable 3-112" whipstock, targeting top of whipstock @ 11,366' md. ~Q~ ~. 12. Mill 2.74" window and 10' of open hole. 13. Dri113" bicenter hole horizontal lateral from window to ~ 13,300' TD targeting Kuparuk C31C4 sands. 14. Kill well wl brine & Complete with 2 318" slotted liner from TD, to 5'-10' outside the 3-112" casing exit. 15. ND BOPE. RDMO Nordic 2. 16. Post CTD rig -Run GLVs. BOL. Mud Program: • Step 7: 8.6 ppg chloride-based biozan brine • .Steps 8, 1.0-13: chloride-based Elo-Pro (8.6 ppg) • Steps 9 & 14: Viscosified Naar KWF (10.6 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1D-36L1: 2 3f8", 4.6#, L-$0, STL slotted liner from 11,400' and to 13,300' and • 1D-36L2: 2 318", 4.6#, L-80, STL slotted liner from 11,376' and to 13,300' and Well Control: • Two well bore volumes 0232 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 250 psi and to 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1D-36L1 & 1D-36L2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1D-36L1 is 1D-37 which is offset by 1735'. KPA boundary is 4250' away. • The nearest well to 1D-36L2 is 1D-37 which is offset by 1780'. KPA boundary is 4215' away. l7 -3~ ~... 2. w:~~ b~ ~ ~\' ~t~°J ~~.\ow ~ arc ~~? c~ ~- - 3~ `. a-. p-~T p ~ ~ v~ sF Q c>.c-c~~~ o ~c~. va.~,\ b ~. x ~ p' ~~ . 'w ~\\ t cac\~.s c~.~k ~~cx~~v¢\y ~c~,cc~\\cc\~G~~.~o~~~ ~.3c~9~v~c~¢..5 5 KRU 1 D-36L1 and 1 D-36L2 Sidetracks -Coiled Tubin Drillin g 9 Logging • A MWD Gamma Ray log will be run. ~ Hazards • L1 & L2 will both cross one mapped fault. Lost circulation risk is moderate. High pressure is not expected. • Well 1D-36 has a H2S reading of 36 ppm. 1D is an HZS pad, the highest H2S measurement on the pad is 120 ppm. All H2S monitoring equipment will be operational. ~ Reservoir Pressure • The latest Shut in bottom hole pressure was 3264 psi at 6425' TVD, 9.8 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2622 psi. DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface. pressure will be installed between the BOPE choke 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). This well does not have a tubing retrievable sub-surface safety valve.. The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated reservoir pressure: 3264 psi at 6299' TVD, 10.0 ppg EMW. ' Expected annular friction losses while circulating: 1026 psi Planned mud density: 8.6 ppg equates to 2817 psi hydrostatic bottom hole pressure. While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3843 psi or 11.7 ppg ECD When circulation is stopped, a minimum of 1126 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 while drilling and shale behavior. The production liner will be deployed by swapping the wellbore to the KWF that not only overbalances the well but is found to work best with the exposed shales during the drilling operation (minimum weight = 10.3 ppg for 100 psi overbalance) KRU 1 D-36L1 & L2 Producer Proposed Completion 3-1/2" Camco DB nipple, 2.875" min ID at 545' MD 3-1/2" 9.3# L-80 BTCM Tubing 2-318" liner top ~+/-11,376' MD 3-'/2" Camco MMG GLM ~ 3655', 6481', 8237', 9706', & 10,819' MD 9-5/8" 40# L-80 ~ 7047' 3-'/z" Camco DS nipple, 2.813" min ID ~ 10,871' MD Baker ZXP Packer w/SBE C~3 10,912' MD 7" 2s# L-ao ~ 11038' MD L2 KOP 11,366' MD Window in 3-1/2° ~~~ C3/C4 Sands ; ~ C1/C2 Sand perfs L1 KOP 11,410' MD C1/C2 Sands ~` Packer, 1.25" ID +/-11,381' MD ConocoPhilli s p Alaska, InC. • 3" openhote 1 D-36L2 Lateral, TD ~ 13300' and _~ \Weatherford retrievable whipstock ~ 11 366' and (with plug) 2-3/8" slotted liner 2-3/8" Baker deployment sub ~ 11,400' and 3" openhote ~3-'/z" LSX WS 3-1/2" 9.3# L-80 Fill ~ 11,656' MD 2-3/8" slotted liner 1 D-36L1, TD ~ 13,300' and 03/15/05 Kuparuk DOBCTD BOP configuration • 2" CT Wel I ~1 D-36L1 Floor 7 1/16" 5000 psi, RX-46 Tree Size tifh2" Combi ^ r ~- I4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee SSV Master Valve ase Flange Page 1 BP Amoco t0[uraTM Dlruu n.rw, lo-a{u c.ry L°a.r. n..a nr-u lwlwm 10.]{ TI°w MDR I13TlAa 101. D.a1°°irn' MIN~rCw3{IIO{T 1W.sOM v'~`arl°O° on~t{. ol~1t°M rw..~i ro _ HAO' 0.00 0.00 _0.00 _ _ REFERENCE INFORMATION '~ Co-ordinate (N/E) Re/erence: WeII Centre: 36, True North Vertical (TVD) Relerence'. System: Mean Sea Level Section (VS) Reference: User Defined (O.OON.O.OOE) Measured Depth Reference: Wallhead(106') 106.00 Calculation Method: Minimum Curvature oamow wrau r e ° 11.1 Try. T-o.1 maw a! wlan o±aw a om e]a1.» +° lmaao wr To3 oa°'1t1ia'ii a wm a1~s1'.n +am aT.w xa+.w u1MOTanorls i°""`~ a,m. rv .w .c,.w s-w Tv0 r° Mw1.tlw _ {]10.10 11!10.00 NOr {]3{JO t 1.]0.00 lM {'l1w' DLO {as{Ja 111n.n • rwi~+w~.: e°:i°au eMxro MM.e w.1 {]40.60 ItU3.0) lM 4D'M00'OLt {a]tA0 131{3.0T { {]]130 1]30].01 1 {]{TaT 1xu3.n { -ws.oo un{.oo TD 5750 + + + ~ ~ ~ I I ,, ~ f t f ~ ,fa , ~ ~ ~ i ~ -7200 }, -~ -+ ~-- a F+ t 44 } G i i .li 5800 - i -_ - -7300 ~ ! 1 _ i f 1 I .... TIP ~ I 1 . 1 }. 5850 + ~ - I + r t. I- ~ ' 1 -7400 }- T + ~- . ~ 9•/ioo_oLS j I i t -1 I i , -#_ . i . I I I t ~ i '~ I ~ 6L1 PO ~1 ij I' :I I I.~ : I V ~ i ,~ I 1D-3 Tgl 1+,I +~t i tf}I 6116 I ~ `` _ 5950 t +-~{---~,.t+.-` '+ ~ jfI C5900 ~::~. .. '_ ~I ...I: ;~,', 7600 ,r. _ },..:.i}~' ~~ -.-~..,:} ~ '~ a ~~..;.~ -..:-i I.. ~ I t ~ I , t, t 7 38 1638 i . ', I 6000 t_ '-~ ~ I ~. ~ } ` ~ .. .. ~ [3911G39 ~ ~I I ~' ~ } C I ~'~~ -7700 ~,',1 ~-'6050 1y~ ,-( 1 t,. _~.; .. L I, T I f T~ ~ 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 s,oo i .. (... 1 ~; I ` ~ ' West(-)/East(+) [100ft/in] -fial -~ + ~ t I ' } _ Jf _ --; 1 ~ i f a d 6250 +- L .TIP } ~ ~~ ti ~',-' ,~~ ,~ -} ; 1. ~ : 1 : ~ 1 -! ~ I ' I ~ I: + ~ --~. D 6300 _~__.~ : 1 ~ . ,----- ----'- ~~ ~~ } _. i' . _ ' ~ End 9°1100' DLS .8 T '-' : : t i- r • ` f i End 45°/100' DLSi ~'~ ~... ', 36L1 Ta eI2 ~. LL 8~_ ~ ~ ~~,: 36 (Plenk6, 10-36L~ _ '~, t 6350 4 - - - ~ - ~, : 1D-36L1 Te M3 'I ; t I '~ I ' , ': PlanpB_, 1D 36L1 '~ 6400 a,l:... 1DasL1 6450 ', 36 1P36 t , . i .. _, .-t- 1.. r, 1. _~~, . -"`~ .. Tar9{11' 6500 39 11}39 -5250-5200-5150-5100-5050-5000-4950-4900-4850 4800-4750-4700-4650-4600-4550-4500-4450-4400-4350-4300-4250-4200-4150-4100-4050-4000-3950-3900-3850-3800-3750-3700-3650-3600-3550-3500-3450-3400-3350 Vertical Section at 30.00° [50ftlin] AM • ,, • i ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~.. __»: Company: ConocoPhillips Alaska, Inc Date: 4/7/2005 Time: 09:09:52 Page: 1 Field: Kuparuk River Unit.. Co-ordinate(NE) Referenced WeIL 36, True North Site: Pad 1 D Verticai (TVD) Reference:. Wellhead(1067 106.0 Well: 36 Section (VS) Reference: User (O.OON,O.OOE,30.OOAzi) Wellpath: Plan#8 1D-36L1 Survey Calculation Method: Minimum Curvature Db6 Oracle Field: Kuparuk River Unit North Slope, Alaska USA 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: Pad 1 D North Slope, Alaska Sfte Position: Northing: 5959669. 52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086 .90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 36 Slot Name: Well Position: +N/-S -477.23 ft Northing: 5959188. 94 ft' Latitude: 70 17 56.622 N +E/-W -420.10 ft Easting : 560670. 73 ft ~ Longitude: 149 30 31.154 W Position Uncertainty: 0.00 ft Wellpath: Plan#8, 1 D-36L1 Drilled From: 1 D-36 Copy Lamar's Plan#8 Tie-on Depth: 11275.03 ft Current Datum: Wellhead(106') Height 106. 00 ft Above System Datum: Mean Sea Level Magnetic Data: 4!4/2005 Declination: 24.40 deg Field Strength: 57597 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N!-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 30.00 Ptan: Plan #8 Date Composed: 4/4/2005 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <- Latitude --~ <-- Longitude -> Name DescripHom TVD +N!-S +E/-W Northing Easting Deg.Min Sec Deg Mia ..Sec Dip. Dir. ft ft ft ft ft 1D-36L1 Polygon 106.00 -7471.30 2774.31 5951741.00 563505.00 TO 16 43.137 N 149 29 10.359 W -Polygon 1 106.00 -7471.30 2774.31 5951741.00 563505.00 70 16 43.137 N 149 29 10.359 W -Polygon 2 106.00 -7656.73 2948.84 5951557.00 563681.00 70 16 41.313 N 149 29 5.276 W -Polygon 3 106.00 -7551.22 3259.73 5951665.00 563991.00 70 16 42.349 N 149 28 56.223 W -Polygon 4 106.00 -7334.09 3370.50 5951883.00 564100.00 70 16 44.484 N 149 28 52.994 W -Polygon 5 106.00 -7050.20 3388.79 5952167.00 564116.00 70 16 47.276 N 149 28 52.458 W -Polygon 6 106.00 -6812.06 3993.79 5952410.00 564719.00 70 16 49.616 N 149 28 34.834 W -Polygon 7 106.00 -6420.31 4155.97 5952803.00 564878.00 70 16 53.468 N 149 28 30.104 W -Polygon 8 106.00 -6152.64 4200.14 5953071.00 564920.00 70 16 56.100 N 149 28 28.813 W -Polygon 9 106.00 -5999.39 3924.34 5953222.00 564643.00 70 16 57.609 N 149 28 36.844 W -Polygon 10 106.00 -6225.20 3897.52 5952996.00 564618.00 70 16 55.388 N 149 28 37.629 W -Polygon 11 106.00 -6459.07 3753.61 5952761.00 564476.00 70 16 53.088 N 149 28 41.824 W -Polygon 12 106.00 -6671.97 3241.83 5952544.00 563966.00 70 16 50.997 N 149 28 56.733 W -Polygon 13 106.00 -7055.91 3104.71 5952159.00 563832.00 70 16 47.221 N 149 29 0.732 W -Polygon 14 106.00 -7381.59 3060.07 5951833.00 563790.00 70 16 44.019 N 149 29 2.035 W -Polygon 15 106.00 -7397.03 2866.92 5951816.00 563597.00 TO 16 43.867 N 149 29 7.661 W -Polygon 16 106.00 -7471.30 2774.31 5951741.00 563505.00 70 16 43.137 N 149 29 10.359 W 1D-36L1 Fault 1 106.00 -6172.37 3546.90 5953046.00 564267.00 70 16 55.909 N 149 28 47.841 W -Polygon 1 106.00 -6172.37 3546.90 5953046.00 564267.00 70 16 55.909 N 149 28 47.841 W -Polygon 2 106.00 -6992.82 3590.28 5952226.00 564317.00 70 16 47.840 N 149 28 46.589 W -Polygon 3 106.00 -7595.74 3694.43 5951624.00 564426.00 70 16 41.910 N 149 28 43.564 W 1 D-36L1 Target 2 6438.00 -7008.58 3188.10 5952207.00 563915.00 70 16 47.687 N 149 28 58.302 W 1D-36L1 Target 1 6456.00 -7501.44 2915.09 5951712.00 563646.00 70 16 42.840 N 149 29 6.259 W 1 D-36L1 Target 3 6474.00 -6701.01 3618.64 5952518.00 564343.00 70 16 50.710 N 149 28 45.759 W ~~ w~.°w ConocoP~il{ips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~N:~~~ --- err' • ConocoPhil{ips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~!is~ INTEQ ~~ Company: ConocoPhillips Alaska, Inc Date r 4!7/2005 Time: 09:09:52 Page:. 3 Field: Kuparuk River Unit. Co-ordinate(NE) Reference: :Well: 36, True North Site: Pad 1D Vertical (TVD)Beference: Wellhead(1 06') 106.0 .Well: 36 Section (VS) Reference: User (O.OON,q:00E,30.00Azi) Wellpath: Plan#8, 1 D-3611 Survey Calculation Method: 'Minimum Curvature Dba Oracle Survey MD Incl Azim SS TVD N!S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11682.97 91.38 67.10 6340.50 -7530.19 2986.07 5951683.83 563717.21 45.00 -5028.30 266.34 MWD 11700.00 91.38 64.54 6340.09 -7523.21 3001.60 5951690.92 563732.68 15.00 -5014.49 270.00 MWD 11725.00 91.38 60.79 6339.48 -7511.74 3023.80 5951702.58 563754.79 15.00 -4993.46 269.94 MWD .11750.00 91.36 57.04 6338.89 -7498.84 3045.20 5951715.65 563776.08 15.00 -4971.58 269.85 MWD 11775.00 91.34 53.29 6338.30 -7484.57 3065.71 5951730.08 563796.47 15.00 -4948.97 269.76 MWD 11800.00 91.32 49.54 6337,72 -7468.98 3085.25 5951745.83 563815.88 15.00 -4925.70 269.67 MWD 11825.00 91.29 45.79 6337.15 -7452.15 3103.72 5951762.80 563834.21 15.00 -4901.89 269.58 MWD 11850.00 91.25 42.04 6336.59 -7434.15 3121.05 5951780.94 563851.39 15.00 -4877.64 269.50 MWD 11875.00 91.21 38.29 6336.05 -7415.05 3137.17 5951800.17 563867.36 15.00 -4853.04 269.41 MWD 11900.00 91,17 34.54 6335.53 -7394.94 3152.00 5951820.40 563882.03 15.00 -4828.21 269.33 MWD 11925.00 91.11 30.79 6335.04 -7373.90 3165.49 5951841.54 563895.34 15.00 -4803.24 269.26 MWD 11950.00 91.06 27.04 6334.56 -7352.02 3177.57 5951863.51 563907.24 15.00 -4778.26 269.18 MWD 11975.00 91.00 23.29 6334.11 -7329.40 3188.20 5951886.21 563917.69 15.00 -4753.35 269.11 MWD 12000.00 90.93 19.54 6333.69 -7306.14 3197.32 5951909.55 563926.62 -15.00 -4728.64 269.04 MWD 12025.00 90.86 15.79 6333.30 -7282.32 3204.90 5951933.43 563934.01 15.00 -4704.23 268.98 MWD 12050.00 90.79 12.04 6332.94 -7258.06 3210.91 5951957.73 563939.82 15.00 -4680.21 268.92 MWD 12075.00 90.72 8.29 6332.61 -7233.46 3215.32 5951982.36 563944.03 15.00 -4656.70 268.87 MWD 12100.00 90.64 4.54 6332.31 -7208.62 3218.11 5952007.22 563946.62 15.00 -4633.80 268.82 MWD 12125.00 90.56 0.79 6332.05 -7183.66 3219.27 5952032.19 563947.58 15.00 -4611.59 268.77 MWD 12150.00 90.47 357.04 6331.83 -7158.67 3218.80 5952057,18 563946.91 15.00 -4590.19 268.73 MWD 12175.00 90.39 353.29 6331.64 -7133.76 3216.69 5952082.06 563944.60 15.00 -4569.67 268.70 MWD 12182.97 90.36 352.09 6331.59 -7125.86 3215.68 5952089.96 563943.52 15.00 -4563.33 268.67 MWD 12200.00 90.31 354.65 6331.49 -7108.94 3213.71 5952106.86 563941.42 15.00 -0549.67 91.00 MWD 12225.00 90.25 358.40 6331.37 -7083.99 3212.20 5952131.79 563939.70 15.00 -4528.62 91.01 MWD 12250.00 90.18 2.15 6331.27 -7059.00 3212.32 5952156.78 563939.62 15.00 -4507.11 91.03 MWD 12275.00 90.11 5.90 6331.21 -7034.06 3214.07 5952181.73 563941.17 15.00 -4484.64 91.05 MWD 12282.97 90.09 7.09 6331.20 -7026.15 3214.97 5952189.65 563942.01 15.00 -4477.34 91.06 M W D 12300.00 89.81 9.63 6331.21 -7009.30 3217.45 5952206.52 563944.35 -15.00 -4461.51 96.30 MWD 12325.00 89.40 13.36 6331.39 -6984.80 3222.43 5952231.05 563949.13 15.00 -4437.80 96.30 MWD 12350.00 88.99 17.09 6331.74 -6960.69 3228.99 5952255.21 563955.50 15.00 -4413.64 96.27 MWD 12375.00 88.58 20.82 6332.27 -6937.05 3237.11 5952278.91 563963.42 15.00 -4389.11 96.22 MWD 12400.00 88.19 24.55 6332.98 -6914.00 3246.74 5952302.04 563972.87 15.00 -4364.33 96.14 MWD 12425.00 87.80 28.28 6333.85 -6891.63 3257.85 5952324.50 563983.80 15.00 -4339.40 96.03 MWD 12450.00 87.42 32.01 6334.90 -6870.03 3270.40 5952346.19 563996.17 15.00 -4314.42 95.90 M W D 12475.00 87.05 35.75 6336.11 -6849.30 3284.31 5952367.03 564009.92 15.00 -4289.51 95.75 MWD 12500.00 86.69 39.49 6337.47 -6829.53 3299.55 5952386.92 564024.99 15.00 -4264,78 95.57 MWD 12525.00 86.35 43.23 6338.99 -6810.81 3316.03 5952405.78 564041.32 15.00 -4240.32 95.36 MWD 12550.00 86.02 46.97 6340.66 -6793.20 3333.70 5952423.52 564058.84 15.00 -4216.24 95.14 MWD 12575.00 85.71 50.72 6342.46 -6776.80 3352.47 5952440.08 564077.48 15.00 -4192.64 94.89 MWD 12600.00 85.41 54,47 6344.40 -6761.66 3372.26 5952455.37 564097.15 15.00 -4169.63 94.62 MWD 12625.00 85.14 58.22 6346.46 -6747.85 3393.00 5952469.35 564117.77 15.00 -4147.31 94.33 MWD 12650.00 84.69 61.98 6348.63 -6735.44 3414.59 5952481.93 564139.25 15.00 -4125.77 94.02 MWD 12675.00 84.66 65.74 6350.91 -6724.47 3436.93 5952493.08 564161.51 15.00 -4105.10 93.69 MWD 12700.00 84.45 69.50 6353.28 -6715.00 3459.94 5952502.74 564184.43 15.00 -4085.39 93.35 MWD 12725.00 84.27 73.26 6355.74 -6707.05 3483.51 5952510.87 564207.94 15.00 -4066.72 92.99 MWD 12750.00 84.11 77.03 6358.27 -6700.68 3507.55 5952517.44 564231.92 15.00 -4049.18 92.62 MWD 12775.00 83.98 80.80 6360.87 -6695.90 3531.94 5952522.42 564256.28 15.00 -4032.84 92.24 MWD 12800.00 83.87 84.56 6363.51 -6692.73 3556.60 5952525.78 564280.90 15.00 -4017.78 91.85 MWD 12825.00 83.79 88.34 6366.20 -6691.19 3581,40 5952527.52 564305.69 15.00 -4004.04 91.45 MWD 12832.97 83.77 89.54 6367.07 -6691.04 3589.32 5952527,73 564313.60 15.00 -3999.95 91.04 MWD 12850.00 83.68 86.97 6366.93 -6690.53 3606.24 5952528.38 564330.52 15.00 -3991.05 267,90 MWD 12875.00 83.57 83.20 6371.71 -6688.40 3630.99 5952530.71 564355.25 15.00 -3976.83 268.18 MWD 12900.00 83.50 79.42 6374.52 -6684.65 3655.54 5952534.66 564379.76 15.00 -3961.30 268.60 MWD ~ • Conocof'hiflips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~L~ Company: ConocoPhillips Alaska, lnc Date: 4/7!2005 Time: -09:09:52 Page: 4 Field: KuQaruk River Unit Co-ordinate(NE) Reference: Well: 36, True North Site: Pad 1D Vertical (TVD) Reference: Wellhead(1 06') 106.0 We{I: 36 Section (VS) Reference: User (O.OON,O.OOE,30.OOAzi) We{{path: Plan#8, 1D-36L1 Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Inc! Azim SS TVD , N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 12925.00 83.45 75.65 6377.37 -6679.29 3679.79 5952540.22 564403.97 15.00 -3944.54 269.02 MWD 12950.00 83.42 71.88 6380.23 -6672.34 3703.63 5952547.35 564427.75 15.00 -3926.61 269.45 M W D 12975.00 83.43 68.10 6383.09 -6663.85 3726.96 5952556.04 564451.01 15.00 -3907.58 269.89 MWD 13000.00 83.47 64.33 6385.94 -6653.83 3749.68 5952566.23 564473.65 15.00 -3887.55 270.32 MWD 13025.00 83.53 60.55 6388.78 -6642.34 3771.70 5952577,90 564495.57 15.00 -3866.59 270.75 MWD 13050.00 83.62 56.78 6391.57 -6629.42 3792.91 5952590.99 564516.68 15.00 -3844.79 271.18 MWD 13075.00 83.74 53.01 6394.33 -6615.14 3813.24 5952605.44 564536.88 15.00 -3822.26 271.60 MWD 13100.00 83.88 49.24 6397.03 -6599.54 3832.58 5952621.19 564556.10 15.00 -3799.08 272.01 MWD 13125.00 84.05 45.47 6399.65 -6582.70 3850.87 5952638.17 564574.25 15.00 -3775.35 272.42 MWD 13150.00 84.25 41.71 6402.20 -6564.69 3868.01 5952656.32 564591.24 15.00 -3751,18 272.82 MWD 13175.00 84.47 37.95 6404.66 -6545.59 3883.94 5952675.55 564607.02 15.00 -3726.67 273.20 M W D 13200.00 84.72 34.19 6407.01 -6525.47 3898.59 5952695.78 564621.50 15.00 -3701.93 273.57 MWD 13225.00 84.99 30.43 6409.26 -6504.43 3911.90 5952716.92 564634.64 15.00 -3677.05 273.92 MWD 13250.00 85.27 26.68 6411.38 -6482.56 3923.81 5952738.89 564646.37 15.00 -3652.16 274.26 MWD 13275.00 85.58 22.93 6413.37 -6459.94 3934.26 5952761.59 564656.63 15.00 -3627.34 274.58 MWD 13300.00 85.91 19.18 6415.23 -6436.68 3943.21 5952784.92 564665.40 15.00 -3602.72 274.88 M W D 13325.00 86.26 15.44 6416.94 -6412.87 3950.64 5952808.79 564672.63 15.00 -3578.39 275.16 MWD 13350.00 86.62 11.70 6418.49 -6388.62 3956.49 5952833.08 564678.29 15.00 -3554.46 275.41 MWD / 13375.00 86.99 7.97 6419.88. -6364.03 3960.75 5952857.70 564682.35 15.00 -3531.04 275.65 MWD 10-1 ~- ~ ID 1 l ~ y ~ A ' ~04 '~~ ;,;_-;;,~.-~ ,~~~a: KRU 1D-36L1 y`, ,D-,b_o 1D-t1 117 '~ Proposed 1-Oil '~ ~~`'~ '' `~-- "' '= Kuparuk "C" Sand • . -_ - - `~ _ 2050840 ~: ^ i ~~ r ~ ~ 1' ~~-- ~1`~-.. c~;s Confidential wells are red . tD-123 iD-12~ ' ~ ~\''1• - 3s - ._ _ __ . ,~'' ~~ - `~ SFD 5/27/2005 -,a. -- . ~ l o- .. _ a ~~-~ 1 D , D ~- `----- -- - tE-33P8 -125 10 130 ~,. ,.i5 ~____ ~' 1 -1 3P8 \ ~O f _--- --__ • `18-128 lE 3 ~r i ~ iD-136 iD-11_1 10-1 26 1 D-1 ~. I 1 D 1 33 ,~ 6 t t28 ~ ~~' 1C-137 \ iD-1 2 r10-127 10-131 1D 138 1D-134 -1~2U to-t 27 1D-o7 ~,, tD-n6 $013; n~-mm~Lt \ 1 E- t OSPB 1 ~ ~D-3 7L2 tD- ~ 9~ ---91D-37L1 10-30Lt3U -~ 1D-30 1D-3" ~. 1 D-4 2L1 ~ o000 `'.. ~~_~~ 1 D-3EL 1 O 1 J 9 ,~ ,~ ° v1 4! ~.K RIV ST OB 0 1?~~0 10-38 10-32L1 Ij .32 iD-404 i 10-40 ~ N T11 N, R10E, UM T11 N, R11 E, UM Feet ~~ - ~„ .,, 0 1,000 2,000 3,000 4,000 ,~~~. 29 • Re: KRU 1D-36L1 and -36L2 Subject: Re: KRU ID-36L1 and -36L2 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, 02 Jun 2005 09:07:50 -0800 To: "Kolstad, Scott R" <KolstaSR@BP.com> Hi Scott, I was looking at the tubular details section where the and is given to be 13300 for each lateral. You are correct that the and in boX 6 is 13375. Only other question is, how much "flow area" does the LSX provide?? I will move the permits forward. Tom Maunder, PE AOGCC Kolstad, Scott R wrote: Tom,. I'll answer your questions from the bottom up. - L1 is the lower lateral targeting the Cl/C2 sands. It is not necessary to retrieve the LSX whipstock used for this window exit. The liner for L1 is planned to be just above the whipstock. - The LSX is a Weatherford permanent whipstock (LSX stands for low side exit, but the LSX is not exclusively a low side exit whipstock). This is not a flow through whipstock, but it does not seal against the casing so there is some fluid bypass. - The upper lateral, L2, will use a Weatherford retrievable whipstock stung into a flow through packer. You are correct that this whipstock tray will either need to be retrieved or perforated (depending on whipstock tray used) to gain production from L1. After step 14 of the planned program, please add: 14a. Retrieve whipstock tray. - The and of both laterals is 13,375'. My copy of form 401 has this number in box 6 for both permits. Is there another place? - The pressure deployment technique is a standard that has been used successfully at Kuparuk and Milne for the CTD Dynamically Overbalanced Drilling programs when there is not a SSSV in the well. Hope this answers your questions. Thanks, Scott 564-5347 -----Original Message----- From: Thomas Maunder [mailto:tom maunder~~admin.state.ak.us] Sent: Tuesday, May 31, 2005 9:05 AM To: Kolstad, Scott R Cc: Dan Venhaus Subject: Re: KRU 1D-36L1 and -36L2 Scott, Further to my earlier message. 1. The planned pressure deployment will use the BOP to control pressure. Has this technique been employed in Kuparuk before?? I presume that basically you are stripping the BHA into the well. 2. The directional plan for both wells shows 13375' and as the planned TD. The 401 only has 13300' and shown. Which is it?? Tom Maunder, PE AOGCC 6/2/2005 12:56 PM Re: KRU 1D-36L1 and -36L2 Thomas Maunder wrote: Scott, On the procedure for -36L2, there is no step to retrieve the whipstock. That is necessary isn't it to gain access to -36L1 and the original completion interval?? I was also wondering if you might send some information on the LSX whipstock. As I understand this whipstock is "flow through". Is the upper whipstock also LSX?? Thanks in advance. Tom Maunder, PE AOGCC 6/2/2005 12:56 PM • PERMlT TO 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 shall designate one branch as the primary weflbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. Far each subsequent well branch, the application for a Permit to Dri{I need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/pARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# -~- ~~~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well Kr~~ ~~"~.~'~ ~ ,, ,< -~~d. ~'~ ~ Permit No,Zc°.1~-i3~'API No. ~~ti ~/`~ (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (per records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70180) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. •-~r~ Rev: 04!01/OS C\jody\transmittal_checklist WELL PERMIT CHECKLfST Field & Pool KUPARUK RIVER, KUPARUK RV OIL- 490100 Well Name: KUPARUK RIV UNIT 1D-36L1 Program DEV Well bore seg ^~ PTD#:2050840 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype DEV 1 PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached_-___-__--__-__-__.__ ___________ __ _____ _NA_ --____Multilate[al-wellbor_e;feewaived-per~0_AAC25.005(a)___-____-_-__-__-_-_______--_- 2 Lease number appropriate - - - - - - -Yes - - - - - - - 3 Uniquewellnameandnumbe[_____________________________ ________ Yes _-___.__.- _ 4 Well located in a_defined-pool - _ - - _ _ - Yes _ . - - . Kuparuk River Oil Pool, governed by Conservation Order No. 4320 5 Well located proper distance from drilling unitboundary- _ - _ . Yes - - - - -Conservation Order No. 4320 contains no spacing restrictions with respect tp drilling unit boundaries. - - fi Well located proper distance from other wells_ - Yes - Con_seNation Order No. 4320 has_no,in_ten!aelf spacing_restrictions, - 7 u_ icientacreage available in-drilling unit- - - - - _ - -Yes - _ - Conservation Order No. 4320 has no intenvell_spaeing_restrictions, Wellbore_will be_more than 500' from - - 8 If_deviated, is_wellbore plat-included - _ - - _ - - - - _ Yes _ anexternal prgperty line.where-ownership or-landownership changes. - 9 Operatoronlyaffectedparty--_.-_--____________ _____-- __,_ --_ , Yes -_-____ 10 Ope[atorhasappropriatebondinfQrce- - --- -- -- -- ----- ---- -- Yes - - -- - -- - -- -- --- --- - - --- -- ---- - -- -- -- -- -- - 11 Pe[mitcanbeissuedwithoutGOnservati4norder------------------ -.----- -Yes ---------------,-----.--- -------_-- ----------------,------------_----, Appr Date 12 Permit_ean be issued without administrative-app[oval _ _ - _ - _ - - - Yes - _ - - SFD 5127!2005 13 Can permit be approved before 15~1ay wait Yes 14 Well located within area and strata authorizedbylnjecti9n0[der#(Aut_10#in-comments)-(For -NA_ __________________________ __-____--__,_____-___--___-----_--_-__-_- - 15 Allwells_withinll4,mileareaof[eyiewjdentified(Forservicewellonly)______ ________ _ NA- __.__-__,-__-_-.__-___-__-__-____-_ 16 Pre-produced injector duration of pre p[oduetion less than_ 3 months_ (FOr service well only) - NA_ - - 17 AC_M_P-Finding of Consistency-has been issued-for_this project - . _ NA_ _ - - Engineering 18 Conducto[string_provided-___-_--___-___-______________ _____-_ NA_ __._Conductorset_in mother-bore, 1D-36(200-130).-__-_--__-______-_-__-_____,_____--_ 19 Surface casing_p_rQteetssll_knownUSDWS__-___-------------- -------- -NA_ -.-_--.Allaquifersexempted,40CFR-147.102_(b)(3).-_-_--_-_--_-__--__-_--_--_-.___._--_ 20 CMT_vol adequate-to circulate-on conductor_& surf_csg - - NA_ _ - _ Surface casing set in-mother-bore.. - - ------------------------------------- 21 CMT_vol-adequate-to tie-in longsfringtosurfcsg___________ _______ ________ _NA_ _,____Prooduction-casingsetin_mother-bore.__-_--____,-_____-_--_- _-- -__--__,_--_--_- 22 CMT-will cover all known_p[oductive hgrizons_ - - _ - _ No_ - .. Slotted liner completion planned, Production casing cemented in mother-bore- - - - - - - - - - - - - - - 23 Casing designs adequate for C,T,B&-permafrost___-__,____-__-_ _- _-__ _Yes _.__-_________________ - - - 24 Adequate tankage-or reserve pit - - - - , - - - - - - Yes _ - - _ - -Rig is_equipped with steel_piis. No reseNe_pitplanned, All waste to approved annulus,or disposal wells. - - _ 25 If_a_re-drill,has-a1.0-403 for abandonment been apprgved--_--_______ ________ _ NA_ ___-__--_____.__--____-_ - - - - - 26 Adequate wellbore separationproposed- - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ . _ _ _ Proximity_ analysis performed. Nearest wellbore_is mother-bore, 1 D-36L1_ diver es._ N4 other_wellbores near, 9 - - 27 Ifdive(terrequired,doesitmeetregulatigns___-___-____-.__-___ ______- _ NA_ ____-__BOPstack-willal[eady-be in place,.__--__________________--___________-_- Appr Date 28 Drilling Fluid-program schematic & equip list adequate- - _ Yes - Maximum expected fo[mation pressure 14.0 EMW_ Plan is to drill with dynamic overbalance and_8.6 ppg fluid._ - - TEM 5131/2005 29 BOPES,-do they meet_regulation Yes - - Two hole volumes of kill weight_fluid will be available at the ng she.- _ - - ~~'~ 30 BOPE,p_ress rating appropriate; test to (put prig in comments)- - - Yes _ _ MASP calculated at 2622 si. 3500- si BOP test tanned, p p p - ~i1 31 Ch k if l li / RP 8 e_man o o -53 (May 4)_____________ aPt dcomp eew Yes __--_--_-_____--,__-_--_______-__-_-_- ----_-_ 32 Workvrillgccurwithoutoperationshutdown___-__-_-._--_-_____ ___-__,- _Yes __-__- - - - - - 33 Is presence-of H2S gas_ probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ - _ -1 D pad_has reported H2$, Drilling-fluid should preclude H2S o~ rig. _ Rig has-sensors and alarms. - _ - _ - _ _ - - _ 34 Mechanical condition of wells withinAORyerified~For_se[vicewellonly~____ ___-_--- -NA- _--__-_____________________________-_--_-,_--_-----------__-_--__-_-- -- Geology 35 Pe[mit_ean be issued w!o hydrogen-sulfide measures - - - - - - - - - - - - - - - - - - - - - No_ -- _ _ - 1 D-36 has measured 36_ppmH2S. H2S monitoring equipmentwill be used. - - _ _ _ 36 Data-presented on_ potential overpressure zones- _ - _ - - - - _ - Yes _ Expected reservoirpressure is 10.0 ppg EMW; will be drilled with coiled_tubing_and 8,6-ppg mud using - - - - Appr Date 37 Seismicanalysis of shallow gas-zones_ - - - _ _ - - - _ . - - _ - - - - NA_ - - - - - - ove[balanced pressure drilling techniques to achieve 11.7ppg BCD-- - - - - - - - - - - - - - SFD 5127/2005 38 Seabed condition survey-(ifoff-shore) - - - - NA 39 -Contact name/phone for.weekly progress_reports [exploratory only]- _ NA_ - - - - - - - - Geolagic Engineering Commissioner: Date: Commissioner: Date C i n r Date ~~~ ~ 1 ~1s ~,~,!~, ~ z-~ G ~a ~' • • Well History File APPENDIX information of detai{ed nature that is not parliculariy germane 1o the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efforl has been made to chronologically organize this category of information. • **** REEL HEADER **** MWD 07111/13 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/24 941648 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11401.0000: Starting Depth STOP.FT 13548.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-36L1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.622" N 149 deg 30' 31.154"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 24-Jul-05 API API NYUMBER: 500292297360 Parameter Information Block #MNEM.UNIT Value Description - --------- ----------------- SECT. --- - 23 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 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 aos =o`~~ ~ t5"~4/ (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, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity 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 1D-36L1 wellbore. (7) The 1D-36L1 wellbore was drilled from 1D-36 through a milled window in 3 1/2" liner. Top of Window 11410 ft.MD (6319 ft.SSTVD) Bottom of Window 11416 ft.MD (6323 ft.SSTVD) (8) The interval from 13518 ft.to 13548 ft.MD (6480 ft. to 6482 ft.SSTVD) was not logged due to sensor bit offset at TD. (9) Tied to 1D-36 at 11197 ft.MD (6516 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 63 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-36L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-36L1 APIN FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and 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: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 52 1 Size Length 4 4 4 4 8 Tape File Start Depth = 11401.000000 Tape File End Depth = 13548.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 61 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-36L1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-36L1 r~ APIN FN Kuparuk River Unit COUN North Slope 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 ------------ ---------------------- -- - GRAX GRAX GRAX 0.0 ROP5 ROPS 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 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 8 Total Data Records: 103 Tape File Start Depth = 11401.000000 Tape File End Depth = 13548.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape 5ubfile: 3 112 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/07/24 941648 01 • **** REEL TRAILER **** MWD 07/11/13 BHI O1 Tape Subfile: 4 2 records... i Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS Tape 5ubfile 2 is type: LIS DEPTH GR ROP 11401.0000 57.8950 -999.2500 11401.5000 60.0717 -999.2500 11500.0000 100.6200 91.3800 11600.0000 91.2100 36.8400 11700.0000 58.5500 56.0000 11800.0000 77.6300 45.5500 11900.0000 89.8233 106.3100 12000.0000 71.3500 316.8000 12100.0000 86.2500 24.8500 12200.0000 91.4800 94.1500 12300.0000 102.4475 24.3800 12400.0000 89.9100 48.7200 12500.0000 77.1000 141.1200 12600.0000 69.9200 92.0300 12700.0000 64.3900 11.3000 12800.0000 70.5700 52.9900 12900.0000 98.5300 64.7300 13000.0000 71.0900 114.6500 13100.0000 81.0200 57.2000 13200.0000 66.9100 17.4400 13300.0000 44.9600 34.5200 13400.0000 70.8300 59.1600 13500.0000 86.5100 17.9500 13548.0000 -999.2500 -999.2500 Tape File Start Depth = 11401.000000 Tape File End Depth = 13548.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 11401.0000 56.8067 -999.2500 11401.2500 57.8950 -999.2500 11500.0000 102.7100 41.4300 11600.0000 81.8100 28.5600 11700.0000 54.6300 59.0000 11800.0000 90.6900 45.7000 11900.0000 89.6500 101.1700 12000.0000 71.8750 316.2200 12100.0000 78.1500 26.4000 12200.0000 87.5600 91.4700 12300.0000 103.7550 29.8600 12400.0000 90.9500 38.7100 12500.0000 86.2500 146.8800 12600.0000 67.7000 84.3900 12700.0000 67.4400 11.3000 12800.0000 72.2700 45.5500 12900.0000 94.6100 63.4100 13000.0000 73.3150 113.6300 13100.0000 83.9000 68.3600 13200.0000 74.7500 17.8000 13300.0000 40.7800 34.6500 13400.0000 69.5300 58.7900 13500.0000 78.9300 18.4500 13548.0000 -999.2500 -999.2500 Tape File Start Depth = 11401.000000 Tape File End Depth = 13548.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LI5 • **** REEL HEADER **** MWD 06/12/22 BHI of LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/24 941648 O1 2.375" CTK *** LIS COMMENT RECORD *** • RECENED JAN ~. 0 Z00~ ,~~ Oii & G S~OY- A !!!!!!!!!! !!!!!!!!! Remark File Version 1.000 ?!?!?!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: CWL5 log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11401.0000: Starting Depth STOP.FT 13548.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-36L1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.622" N 149 deg 30' 31.154"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK BATE. LOG DATE: 24-Jul-05 API API NYUMBER: 5002922997360 Parameter Information Block #MNEM.UNIT Value Description ---- - - ---- - -------------- - - - - - - SECT. 23 Section TOWN.N 11N Township RANG. l0E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 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 aos -v4s~( "!~!3 /~( • • (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, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity 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 1D-36L1 wellbore. (7) The 1D-36L1 wellbore was drilled from 1D-36 through a milled window in 3 1/2" liner. Top of Window 11410 ft.MD (6319 ft.SSTVD) Bottom of Window 11416 ft.MD j6323 ft.SSTVD) (8) The interval from 13518 ft.to 13548 ft.MD (6480 ft. to 6482 ft.SSTVD) was not logged due to sensor bit offset at TD. (9) Tied to 1D-36 at 11197 ft.MD (6516 ft.55TVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units} ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape 5ubfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 63 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-36L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-36L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and 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: 52 Tape File Start Depth = 11401.000000 Tape File End Depth = 13548.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 61 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-36L1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-36L1 FN Kuparuk River Unit r ~ LJ • COUN North Slope 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 GRAX GRAX 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 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 103 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 112 Minimum record length: 54 Maximum record length: 4124 **** TAPE TRAILER **** MWD 05/07/24 941648 O1 11401.000000 13548.000000 0.250000 feet records... bytes bytes • • **** REEL TRAILER **** MWD 06/12/22 BHI 01 Tape Subfile: 4 2 records... • Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape 5ubfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP 11401.0000 57.8950 -999.2500 11401.5000 60.0717 -999.2500 11500.0000 100.6200 41.3800 11600.0000 91.2100 36.8400 11700.0000 58.5500 56.0000 11800.0000 77.6300 45.5500 11900.0000 89.8233 106.3100 12000.0000 71.3500 316.8000 12100.0000 86.2500 24.8500 12200.0000 91.4800 94.1500 12300.0000 102.4475 24.3800 12400.0000 89.9100 48.7200 12500.0000 77.1000 141.1200 12600.0000 69.9200 92.0300 12700.0000 64.3900 11.3000 12800.0000 70.5700 52.9900 12900.0000 98.5300 64.7300 13000.0000 71.0900 114.6500 13100.0000 81.0200 57.2000 13200.0000 66.9100 17.4400 13300.0000 44.9600 34.5200 13400.0000 70.8300 59.1600 13500.0000 86.5100 17.9500 13548.0000 -999.2500 -999.2500 Tape File Start Depth = 11401.000000 Tape File End Depth = 13548.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 11401.0000 56.8067 -999.2500 11401.2500 57.8950 -999.2500 11500.0000 102.7100 41.4300 11600.0000 81.8100 28.5600 11700.0000 54.6300 59.0000 11800.0000 90.6900 45.7000 11900.0000 89.6500 101.1700 12000.0000 71.8750 316.2200 12100.0000 78.1500 26.4000 12200.0000 87.5600 91.4700 12300.0000 103.7550 29.8600 12400.0000 90.9500 38.7100 12500.0000 86.2500 146.8800 12600.0000 67.7000 84.3900 12700.0000 67.4400 11.3000 12800.0000 72.2700 45.5500 12900.0000 94.6100 63.4100 13000.0000 73.3150 113.6300 13100.0000 83.9000 68.3600 13200.0000 74.7500 17.8000 13300.0000 40.7800 34.6500 13400.0000 69.5300 58.7900 13500.0000 78.9300 18.4500 13548.0000 -999.2500 -999.2500 Tape File Start Depth = 11401.000000 Tape File End Depth = 13548.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • • Tape Subfile 4 is type: LIS