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Home My WebLink About204-145 e e 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. ~ lJ. - L 4:-.;5 Well History File Identifier Project Proofing BY: ~ D Two-sided 111111111111111111I D Rescan Needed 11111111111" 11I11I DIGITAL DATA OVERSIZED (Scannable) D Diskettes, No. D Maps: D Other, NolType: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: Date uLßjob D Other:: Mf 151 11111111111111 1111I YWP Date: 14'~/ob 151 I 30 + ~ = TOTAL PAGES!iii- Count does not include cover shee Date: 151 1111111111111111111 Organizing (done) RE~N ¢éolor Items: D Greyscale Items: D Poor Quality Originals: D Other: NOTES: BY: ~ Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: 50 (Count does include cover sheet) Page Count Matches Number in scan¡"ng p,¡pa,ation: 1 YES ~ Date: II 1\3/0(, If NO in stage 1, page(s) discrepancies were found: YES NO BY: 151 MP Stage 1 NO BY: Maria Date: 151 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111I11 1111I BY: Maria Date: 151 Comments about this file: Quality Checked 1IIII1I111111111111 10/6/2005 Well History File Cover Page. doc • • ~, .. . ~: ~~, ~_ .~- MICROFILMED .03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc ~ tJ *" 2~~Cp DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041450 Well NamelNo. KUPARUK RIV UNIT 1 D-30L 1 Operator CONOCOPHILLlPS ALASKA INC ),tCJ.¡L ) I~~t{ API No. 50-029-22965-60-00 MD 13715""- TVD 6534 /' Completion Date 9/8/2004·'-- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ -~. DATA INFORMATION Types Electric or Other Logs Run: GR 1 ROP / PRESS / WOB / NB Well Log Information: (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments 11658 13715 Open 11/8/2004 11672 13710 Open 10/26/2005 GR ROP 11710 13710 Open 1 0/26/2005 GR ROP 11710 13710 Open 10/26/2005 GR ROP Sample Set Number Comments . Log/ Data Type ~ ~ ,}tog Þ.Og I Electr Digital Dataset Med/Frmt Number Name Directional Survey Gamma Ray Gamma Ray Gamma Ray Log Log Scale Media Run No C Lis 13334 25 Blu 5 Blu MO TVD Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? ~ Chips Received? "T I 14 - Daily History Received? (Ji/N 6/N . Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: L I Date: 3(j~~~~ RECEIVED OCT 2 {} 2005 Alaska Oil &. Cnìl"" C .. 'J! ". . ,.r.mmISSU)I1 r'irhUrtr:"~':~";":.....11 BAKER :""" ::~;..~." HUGHES ::.. :_H~: ~ _, -:;-0 ~--~:f~'--""7:--"~---;-;;-¡ Calgary GEOScience Center _. _~"':' ~ _, i :=::--~:~:. ":- . . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: ID-30Ll Contains the following: 1 LDWG Compact Disc 11 :,)~ (Includes Graphic Image files) 1 LDWG lister summary - 1 blueline - GR/Directional Measured Depth Log TVD - LAC Date: Oct 5, 2005 Date: ')...,7 a~ðd \- Received By: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (403) 537-3767 Baker Hnghes INTEQ 1000,401 9th Ave S.W. Calgary, Alberta T2P 3C5 Direct: (403) 537-3644 FAX: (403) 537-3767 ~ Ð"¡ -t '-10' -~ ==,¡¡; Q/!"1I;_"~' , -._---- ._-~-,._~~----;"----;~!: ;r;œ;,IO\"lIol';" - ... .J _(j _'''''K'' _..... . - . Ell I ~.a , ..a STATE OF ALASKA . ALASKJWR., AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECËI\/E.b OCT 1 2 Z004 c ~su:m Alaska Oil & G35 CaPoz. ormmf 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: Am;horage 20AAC 25.105 20AAC 25.110 181 Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number Conoco Phillips Alaska Inc. 9/8/2004 .. 204-145 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 8/31/2004 ~ 50- 029-22965-60-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/6/2004 ... Kuparuk 1D-30L 1 387' SNL, 419' WEL, SEC. 23, T11N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 101' SNL, 1612' EWL, SEC. 30, T11N, R11E, UM 105.3' Kuparuk River Field I Kuparuk River Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 271' SNL, 3561' EWL, SEC. 30, T11 N, R11 E, UM 13715 + 6534 Ft 4b, Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 560671 y- 5959279 Zone- ASP4 . 13715 + 6534 . Ft ADL 028248 TPI: x- 568026 y- 5954349 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 569976 y- 5954196 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNo N/A MSL 1668' (Approx.) 21. Logs Run: .,/ "-'~~ il" '"1/0' n1;> .Æ> GR / ROP / PRESS / WOB / NB ¡PI' 5/¿> I rv I> ¡,> -. ~ 122. CASING, liNER AND CEMENTING RECORD P~Ti~G ' SerrlNG JEP"rHMP> I ~E1"TII'ß IEÞTHTVD ~~~> .6.........,,,,,,. WT., PER FT: GRAPE: TOP II:SOTTOM .--OP I:SOTTOM ....::::..c. 16" 62.5# H-40 Surface 110' Surface 110' 20" 16.5 cu yds AS I, Type III 9-5/8" 40# L-80 Surface 6873' Surface 4341' 12-1/4" 710 sx AS III Lite, 460 sx LiteCrete 7" 26# L-80 Surface 11305' Surface 6327' 8-1/2" 180 sx Class 'G' 3-1/2" 9.3# L-80 11153' 11710' 6257' 6510' 6-1/8" 212 sx Class 'G' 2-3/8" 4.7# L-80 11466' 13516' 6400' 6534' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. ", TUSiNG....;. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2",9.3#, L-80 11179' 11161 ' MD TVD MD TVD 11479' - 13503' 6406' - 6534' 25. -A,..,,,"'" -,. yt:Mt;I'II ,e"t"þ. \.- "yu" , > DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11727' Set Standing Valve 11710' Set (Flow-by) Whipstock 2000' Freeze Protected with Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): September 15, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBl CHOKE SIZE GAS-Oil RATIO 9/20/2004 6 TEST PERIOD ~ 735 47 1,524 176 2,073 Flow Tubing Casing Pressure CALCULATED ~ Oll-BBl GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 454 600 24-HoUR RATE 2,942 188 6,097 24 Deg. 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". r-;';,; ;~~ -;-n ON 1 I"~ None. ta ; , L~,t: \ . -0 ~j..:" ;,. ,'iJ -'.1 ...... -At',l r, F \.1,. ORIGINAL ~ -VEP¡'-·ED " ~_';\'\"i'J. / r, ~"'~J.!J .~-¡ . 1/ 1 ~ lJ "',, .. ""..,.~" """".,"..,.',:_.>,~___.,,,-.,Oj ·">il Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ¿; , 28. GEOLOGIC MARKERS 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk C (above window) 11694' C3 11760' C2 11900' C1 12100' Base C2 12290' C3 13220' 6503' None 6529' 6555' 6573' 6575' 6552' RE '0 'I '2 Z004 .1 Alaska 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 10· J ;{-o Kuparuk 1 D-30L 1 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Thomas McCarty, 564-4378 204-145 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, SubmersibJe, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ORIG\f~J~L ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . 1 D-30L 1 Kuparuk River Field & Pool 50-029-22965-60-00 204-145 Accept: Spud: Release: Ri: PRE-RIG WORK 07/16/04 DRIFT TBG 2.732" & TAGGED @ 11805' RKB, EST. 11' FILL. MEASURED SBHP @ 11,788' RKB & GRADIENT @ 11,565' RKB. SBHP DATA INVALID, WELL HAD NOT BEEN PREVIOUSLY SI. 08/08/04 DISPL TBG WI 110 BBLS DSL, SET 2.81" SV @ 11242' RKB, PULLED GLV'S @ 3030',6037',7859', 9366', RKB, PULLED OV @ 10574' RKB, SET DV @ 3030' RKB, IN PROGRESS. 08/09/04 SET DV'S 6037',7859',9366', DISPL TBG & IA WI 275 BBLS SW & 110 DSL, SET DV @ 10574' RKB, MITIA FAILED, IN PROGRESS. 08/10/04 PULLED OV FROM GLM @ 11083' RKB & SET DV IN SAME. 3000 PSI MITT GOOD, 3000 PSI MITIA GOOD, PULLED SV @ 11242' RKB, COMPLETE. 08/16/04 DRIFT TBG W I WEATHERFORD DUMMY WHIPSTOCK (11' X 2.70") TO 11807' SLM. RAN PDS CALIPER SURVEY FROM 11800' SLM TO 10800' SLM. OBTAINED GOOD DATA. 08/24/04 LOAD WELL WITH SEAWATER IN PREP FOR SETTING STANDING VALVE PRE CTD. SET WEATHERFORD COMPOSITE STANDING VALVE WITH TOP AT 11727'. 08/28/04 PRESSURE TEST SWAB VALVE - PASSED. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 8/28/2004 09:00 - 00:00 15.00 MOB P PRE Move rig off 1Y-24. Set mats for move to Spine Road. Order extra loaders from Deadhorse, Wells Group, Drilling Tool House. Move rig down Pad and park at entrance by 1430 hrs. Standby 1 hr for tour-group bus. Enter Spine at 1530 hrs and move to CPF3 intersection by 1630 hrs. Standby for field crew change. Resume move down Spine at 1900 hrs. Arrive KOC at 2200 hrs. Wait on matting boards to be placed on Spine at 1 C/KIC intersection 09:00 - 00:00 15.00 MOB P PRE Move rig off 1Y-24. Set mats for move to Spine Road. Order extra loaders from Deadhorse, Wells Group, Drilling Tool House. Move rig down Pad and park at entrance by 1430 hrs. Standby 1 hr for tour-group bus. Enter Spine at 1530 hrs and move to CPF3 intersection by 1630 hrs. Standby for field crew change. Resume move down Spine at 1900 hrs. Arrive KOC at 2200 hrs. Wait on matting boards to be placed on Spine starting at 1 C/KIC intersection 8/29/2004 00:00 - 08:00 8.00 MOB P PRE Wait on KOC pad while mats are laid on Spine from 1C/KIC intersection. Move forward over 200 mats over the worst of the low/wet area. Wait on mats to be picked up and trucked around 1 C Pad to cover culverts on the Spine. Rig on location at 0800 hrs. 08:00 - 12:00 4.00 MOB P PRE RU BOPS in cellar. Leave tree platform in place to aid in NU. Spot rig mats & pit liner around cellar. Spot rig over well. 12:00 - 13:00 1.00 MOB P PRE Install e-coil in reel house. Secure cellar area with lumber, tree spiil dike, and handy-berm. Accept rig at 1300 hrs. 13:00 - 15:45 2.75 MOB P PRE Install e-coil in reel house. Secure cellar area with lumber, tree spiil dike, and handy-berm. Re-position camp to acquire comm link with Milne Point tower. (Rig is almost directly between camp & Milne). Take on cold fresh water for BOP test. Change o-rings on coil lubricator. Body test BOPS. 15:45 - 16:00 0.25 BOPSU P PRE Hold PJSM before starting full test. Discuss test procedure. Get rig paperwork in order. 16:00 - 21 :30 5.50 BOPSU P PRE Test BOP equipment & gas alarms. J. Crisp with AOGCC on hand to witness. Sim ops: rigging up reel hardware & e-cable Continue to rig up location(dumpsters, flow back tanks, MI, TL, Inteq cabins, etc). 21 :30 - 22:45 1.25 MOB P PRE Install internal grapple. Pull CT off reel and stab. Prep eline 22:45 - 00:00 1.25 MOB P PRE Reverse fill CT w/ 8.7# biozan milling fluid at 1.0 bpm, then reverse slack back at 3.0/3800 8/30/2004 00:00 - 02:00 2.00 MOB P PRE Cut off 22' CT. Install CTC. PT 35k. Install BHI head and test. PT 3500 psi 02:00 - 02:40 0.67 KILL P WEXIT MU nozzle assy. Stab on and pump slack forward 2.74/3460. IA680 02:40 - 04:50 2.17 KILL P WEXIT Open swab and master (17) to 2130 psi. Bleed off gas to 1200 psi to flowback tank to allow RIH. RIH w/ BHA #1 0.25/1160 maintaining 400-600 psi bp taking gas and diesel returns to flowback tank. Let WHP fall too low and realized well was flowing at 380 psi for 10 min. Incr bp to 1000 psi while RIH 04:50 - 06:00 1.17 KILL P WEXIT Park at 11700'. Circ 1.6/1500 while hold 1000 psi for first circ. At end of first circ 1.6/1940. Circ additional 1 /2 volume and at end was 1.6/2060. Red bp to 500 psi and circ additional 1/2 volume and at end was 1.6/2130. Fill poorboy degasser and was mostly crude. . . Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 8/30/2004 06:00 - 06:30 0.50 KILL P WEXIT Shut in well. Discuss plan forward to complete well kill. Bleed IA from 705 to 250 psi 06:30 - 09:30 3.00 KILL P WEXIT Circulate additional 153 bbls. Hold 500 psi WHP, circ pressure 2250 psi. Pump 20 bbls before whp began to increase. Take rtns out side. Check fluid samples in rtns. Fairly clean bio after 150 bbls. SHut in well. Zero coil pressure. 60 psi on wellhead. 09:30 - 12:00 2.50 KILL N FLU 0 WEXIT Monitor WHP. Initial: 60 psi. Final: 65 psi. Bleed well. WHP: zero. Continue to monitor flow while waiting on fluid from Deadhorse. 12:00 - 13:00 1.00 KILL P WEXIT KWF on location. Pump down coil with choke open. Monitor returns. 1.83 bpm in at 2666 circ pressure. Take rtns to pits. Increase rate ro 2.52 bpm @ 3720 psi circ press. Slow rate to 1.5 bpm in. Micro shows 1.32 bpm out. Circulate fluid until 9.0 ppg rtns at surface. 13:00 - 15:00 2.00 KILL P WEXIT POOH with nozzle assembly. 15:00 - 15:30 0.50 KILL N FLUD WEXIT Discuss standing valve issue with town. Decide to continue ops as is with leaking valve. 15:30 - 17:30 2.00 WHIP P WEXIT At surface. Get off well. Unstab coil. LD nozzle. MU coil track mwd. Orient whipstock to mwd (Inteq & Weatherford) Stab coil. Get on well. 17:30 - 20:15 2.75 WHIP P WEXIT RIH w/ BHA #2 0.2/380 at 80'/min. At 10000' return volume should have been 54 bbls, but was 18 bbls (ECD 10.04). Rediscuss fluid losses and means to control them and decide again to live with them 20:15-21:10 0.92 WHIP P WEXIT Park at 11500'. Log tie-in to geo PDC log while RIH 180'/hr 0.26/0.14/490, ECD 9.7, PVT 258. Carr -87' due to BHA length (67.3') not being entered before RIH 21:10-21:20 0.17 WHIP P WEXIT RIH 6k and tag composite plug at 11730' and stack 3k. PUH 28.2k 21 :20 - 21 :35 0.25 WHIP P WEXIT Relog tie-in down from 11530'. Corr +3' 21 :35 - 22:05 0.50 WHIP P WEXIT RIH w/ WS. Log down from 11690' to verify tbg collar is at 11645' and see it at 11647.5'. RIH to 11722' CTD and park. Orient WS to 15L. Closed EDC. Pressure CT to 1100 psi, then to 2400 psi and lost pressure. Incr press to 3600 psi and had returns, assume tool stroked. Stack 3k. Open EDC PVT 247 Top of WS is at 11710' by geo PDC log. RA pip at 11715.7' 22:05 - 00:00 1.92 WHIP P WEXIT POOH 8/31/2004 00:00 - 00:10 0.17 WHIP P WEXIT Fin POOH. Lost 8 bbls over hole fill 00:10 - 01:10 1.00 STWHIP P WEXIT LD WS setting tool, intact. MU 2.74" window mill and used SR on BHI BHA 01:10 - 03:00 1.83 STWHIP P WEXIT RIH w/ BHA #3 circ thru EDC at 0.3/500 Lost 10 bbls while RIH 03:00 - 03:45 0.75 STWHIP P WEXIT Park at 11700'. Close EDC. RIH and dry tag at 11739.0'. PUH 29k. Start motor 1.5/2580. Ease back down and first motor work at 11737.6'. Corr to 11710.0' and flag, then stalled. PUH 28.5k PVT 223 03:45 - 05:20 1.58 STWHIP P WEXIT Ease back down. Begin milling 1.55/1.22/2600 from first MW at 11709.6' ECD 10.5. Real touchy and 4 stalls at same spot over an hour 05:20 - 05:40 0.33 STWHIP N SFAL WEXIT Milling. Park at 11709.9' while fix CTDS and reset depths PVT Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 8/31/2004 05:20 - 05:40 0.33 STWHIP N SFAL WEXIT 187 05:40 - 07:30 1.83 STWHIP P WEXIT Mill from 11709.9' 1.61/1.36/2700 and CTDS counter is still working erratic 07:30 - 10:45 3.25 STWHIP P WEXIT Mill to 11711.4'. 2990 psi circ prs, 1.61 in/1.39 out. WOB: 2.2k#. ECD: 10.6/3514 psi. Continue time milling. Take on additional 8.7 ppg biozan fluid into pits. Appear to exit liner at 11713'. 10:45 - 11 :45 1.00 STWHIP P WEXIT Drill open hole to 11724'. Ream and back ream window. Dry tag TO. Stop pumping to get static hydrostatic pressure. Static BHP with 8.7 ppg mud column is 3090 psi. Order 580 bbls 8.7 ppg used formate mud from MI. 11 :45 - 13:30 1.75 STWHIP P WEXIT POOH with window mill. Open edc to circulate OOH. 13:30 - 14:00 0.50 STWHIP P WEXIT LD milling assy. Mill and SR were 2.73" no-go and mill had center wear 14:00 - 14:45 0.75 DRILL P PROD1 MU drilling BHA (HYC bi bit, 1.3 deg) 14:45 - 16:55 2.17 DRILL P PROD1 RIH w/ BHA #4 16:55 - 17:20 0.42 DRILL P PROD1 Log tie-in down from 11500', corr -16'. Close EDC 17:20 - 17:45 0.42 DRILL P PROD1 RIH thru window, clean and tag at 11729" CTD. PUH, clean 28k. Start pump 1.6/2480. Ease back down to first motor work at 11728' 17:45 - 19:40 1.92 DRILL P PROD1 Drill from 11728' 1.6/1.38/2500/15L ECD 10.5 with Bio water. Started mud swap at 11751 ff Drilled past at RA marker at 11723 It uncorrected. 19:40 - 19:50 0.17 DRILL P PROD1 PUH to 11700 It to tie and log in corrected depth mode. 19:50 - 20:05 0.25 DRILL P PROD1 Tie-in to RA Marker (Corrected -4 It) 20:05 - 20:10 0.08 DRILL P PROD1 PUH to 11700 It 20: 1 0 - 20:35 0.42 DRILL P PROD1 RIH logging corrected depth as per RA Marker TOW @ 11710.3 It BOW @ 11714.3 It RA Marker @ 11716 It 20:35 - 22:00 1.42 DRILL P PROD1 Drilling. P= 3200/3350psi; Qp=1.53/1.13 bpm; BHP = 3729 psi; EDC = 11.31 ppg. With 8.7ppg around, the LC increased from 18 bph to 23 bph A V decreased from 320 22:00 - 00:00 2.00 DRILL P PROD1 Drilling. P= 3200/3350psi; Qp=1.53/1.32 bpm; ROP=30 FPH; BHP =3942 psi; EDC = 11.84 ppg. Alter circulating 2 times, shearing the mud, the losses reduced to 13 bph. 9/1/2004 00:00 - 01 :50 1.83 DRILL P PROD1 Drilling at 155L TF. P= 3200/3369psi; Qp=1.53/1.36 bpm; ROP=10-30 FPH; BHP =3920 psi; EDC = 11.74 ppg. Drilling at 10 to 30 fph with lots of stalls, hard sand. Ordered 580 bbl used mud, after shearing the LSRV needs to be 35k to reduce EDC 01 :50 - 02:05 0.25 DRILL P PROD1 ROP picked up, Could be in the C2 Sand Drilling at 75 fph from 10 to 30 fph. TF @ 150L Qp= 1.54/1.40 bpm. BHP = 3930 psi, EDC = 11.76ppg 02:05 - 02:45 0.67 DRILL P PROD1 Hit the wall again, ROP slowed down 19 fph. Turn TF to 58 R 02:45 - 03:00 0.25 DRILL P PROD1 Wiper trip clean 03:00 - 05:55 2.92 DRILL P PROD1 Drilling at 63R TF. P= 3200/3495psi; Qp=1.50/1.33 bpm; BHP =3934 psi; EDC = 11.77 ppg. Drilling at 10 to 55 fph 05:55 - 06:40 0.75 DRILL P PROD1 Drilling at 1 05L TF. P= 3200/3595psi; Qp=1.50/1.32 bpm; Den = 8.65/8.69ppg; BHP =3925 psi; EDC = 11.73 ppg. Drill to 12034' and stacking and had little progress in 30 min 06:40 - 07:05 0.42 DRILL P PROD1 Wiper to window, clean PVT 350 Printed: 9/13/2004 10: 16: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-30 1 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/1/2004 07:05 - 07:55 0.83 DRILL P PROD1 Drill from 12034' 1.56/1.43/3480/11 OL ECD 11.8 and still slow drilling w/3.5k wob, but better WI transfer. Penetration rate picked back up after another 15 minutes to 60'/hr 07:55 - 08:35 0.67 DRILL P PROD1 Wiper to window for tie-in while geo correlates markers to ensure we are not too deep. No corr. RBIH, clean 08:35 - 09:30 0.92 DRILL P PROD1 Circ, while WOO. New target/plan is to be 3' TVD above plan at 12200' PVT 325 09:30 - 12:00 2.50 DRILL P PROD1 Drill from 12087' 1.66/1.41/3540/80L and find another hard spot at 12107' which was 10' and 50 minutes. Penetration rate picked up to 80-90'/hr and assume this is the C1. Swap to 90L @ 12200' and holding 90 deg to get 200' of this. Drill to 12235' 12:00 - 12:40 0.67 DRILL P PROD1 Wiper to window, clean PVT 290 12:40 - 14:15 1.58 DRILL P PROD1 Drill from 12235' 1.66/1.51/3500/70-90L ECD 11.9 at 80-100'/hr 14:15 - 14:50 0.58 DRILL P PROD1 Wiper to window, clean PVT 270 14:50 - 16:00 1.17 DRILL P PROD1 Drill from 12385' 1.63/1.48/3530/90L at 91 deg, ECD 12.0 at 100-120'/hr 16:00 - 16:30 0.50 DRILL P PROD1 Wiper to window, clean 16:30 - 16:45 0.25 DRILL P PROD1 Log tie-in down from 11710' 0.4/1500, no corr 16:45 - 17:05 0.33 DRILL P PROD1 Wiper to TO, clean PVT 252 17:05 - 18:25 1.33 DRILL P PROD1 Drill from 12535' 1.6/1.45/3500/90-120R at 92 deg, ECD 12.03 at 1 OO'/hr Stacking, ordered Mud swap 18:25 - 19:25 1.00 DRILL P PROD1 Wiper to 11720 ft. EDC = 12ppg = 4018 psi BHP 19:25 - 20:15 0.83 DRILL P PROD1 Drill from 12639 ft Qp = 1.75/1.45 bpm CTP = 3500psi TF 90-100R ECD 12.03 at 100' to 20 fph Drilling with several stall due to siderite sand, having to work CT to get 2-3k WOB 20:15 - 21:35 1.33 DRILL P PROD1 Drilling and started mud swap at 12663 ft Qp = 1.77/1.60 bpm CTP int = 3900psi TF 90-100R ECD 12.2ppg New mud around, LSRV 1st cir = 41k 21:35 - 23:15 1.67 DRILL P PROD1 Drilling Qp = 1.77/1.60 bpm CTP int = 3757/3900psi TF 90-120R ROP @ 15 to 90 fph ECD @ 12.1 ppg, BHP = 4069 psi Bit stacking 23:15 - 00:00 0.75 DRILL P PROD1 Wiper trip to window after drilling 117 ft 9/2/2004 00:00 - 00:25 0.42 DRILL P PROD1 RIH and tagged at 12757 ft / 00:25 - 01 :35 1.17 DRILL P PROD1 Drilling Qp = 1.61/1.56 bpm CTP int = 3757/3900psi TF 90-120R ROP @ 15 to 90 fph Drilling with negative WOB 1.67k on WOB sub ECD @ 12.1 ppg, BHP = 4057 psi 01:35 - 02:10 0.58 DRILL P PROD1 Drilling Qp = 1.60/1.50 bpm CTP int = 3757/3900psi TF 90 L ROP @ 15 to 90 fph. Drilling with negative WOB (-6k)and 0.22k on WOB sub. This occurred after turning the TF from 90R to 90L ECD @ 12.2ppg, BHP = 4087 psi 02:10 - 02:50 0.67 DRILL P PROD1 Wiper trip to tie in and started to bring L T up to 5% by volume 02:50 - 03:47 0.95 DRILL P PROD1 Tie-in at RA Marker11716 ft (11720 ft) (-2 ft) ECD at 0.56 bpm = 10.97ppg while logging Bobble at 12700 ft, 180 TF change 03:47 - 04:15 0.47 DRILL P PROD1 Drilling Qp = 1.60/1.50 bpm CTP int = 3757/3900psi TF 90 L ROP @ 2-15 fph. Drilling with negative WOB (-5k)and 1.84k on WOB sub. ECD @ 12.0ppg, BHP = 4030 psi. Lost motor work, tried to stall motor, unable Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/2/2004 04:15 - 06:50 2.58 DRILL P PROD1 POOH, bit an motor change out Qp= 1.51/1.29 bpm at 37fpm Open EDC at 11600 ft Qp = 2.00 bpm Tag up, RBIH 100' circ'ing. POOH dry 06:50 - 07:30 0.67 DRILL P PROD1 Flow check for 15 min and well was flowing. RIH to 560'. Park and monitor 0.1 bpm returns at 8.7 ppg. Est total gain of less than 4 bbls 07:30 - 08:15 0.75 DRILL P PROD1 SI well. After 10 min WHP was 250 psi and stabilizing. After 20 min was 275 psi and holding. Discuss in am call and will pressure undeploy 08:15 - 08:30 0.25 DRILL P PROD1 Safety mtg re: discuss undeploy procedure 08:30 - 09:00 0.50 DRILL P PROD1 SIWHP 275 (nope, CTDS was locked up, actual WHP 326 psi. POOH wi CT, close EDC. Maintain 325-450 psi while POH 09:00 -11:10 2.17 DRILL P PROD1 Tag up, space out, set 2-3/8" combis and lock in. Bleed off WHP above combis and CTP. SIWHP is 334 psi, IA 320, OA 294. Strip injector oft BHI tool. Close BV's and open bleed oft port. Bleed oft press, but double ball valves continued to leak thru bleed oft port (probably another factor in not being able to drill if body is washed out). Break quick connect and set back injector. RU elevators on blocks. PU lubricator. Strip oft 60' of wire, rehead. Attach no-go and MU to BHI BHA-pull test. Stab full lubricator. Fill wi mud and PT to new SIWHP of 386 psi. Open combis, pull up BHA wi slickline. SI swab. Breakdown BHA. Bit was like new, flapper checks were shot 11: 10 - 13:00 1.83 DRILL P PROD1 MU same bit on another 1.3 deg motor with another ball valvelbleed oft assy. MU BHI BHA and pressure deploy w/415 psi on well, IA 294, OA 186. Lower BHI tool in lubricator to the no-go plate. PU to proper MU spot. Close combis. Bleed oft pressure above combis, but noticed SIP was zero. Found that WL had crossed itself and rewound so that tool didn't RIH to proper depth. So, combis weren't closed on tool and had beld oft WHP instead (in a very short time-PVT showed 3 bbls). Fix slickline and do it again. After bleed oft and unstabbing lub found that double BV was leaking thru bleed oft valve again. Undeploy with 380 psi 13:00 - 15:00 2.00 DRILL P PROD1 Pressure test 3rd and last set of double BV's and install in BHA. Pressure deploy wi 444 psi WHP 15:00 - 17:05 2.08 DRILL N DPRB PROD1 RIH wI BHA #5 circ'ing 0.2/1500 thru EDC and holding 500 psi BP thru Swaco choke PVT 384. Got crude and gas back at 1500'. Swap to Tri-flo choke and take returns to flowback tank. All gas by 5000' and choke was shut wi 440 psi wi ECD at 13.4 by 8000' (assume fluid has gone south thru leaking composite plug). Choke still shut at 11500' wi 360 psi and ECD 12.5 ppg 17:05 - 17:50 0.75 DRILL N DPRB PROD1 Park at 11700'. Incr rate to 1.5/3450 ECD 12.9 while circ thru EDC and circ out influx. Use 12.5-13.0 ECD as guideline for opening choke PVT 350 After one cìrc 1.54/3350 ECD 12.6 PVT 284 wi 400 psi bp IA 294, OA 205 17:50 - 18:30 0.67 DRILL N DPRB PROD1 0= 11700MD I 6400ft TVD Cir btms up #2 BHP = 4075ps, EDC = 12.29ppg, WHP 410psi on superchoke 18:30 - 18:45 0.25 DRILL N DPRB PROD1 SO pump and choke, trap 430 psi WHP. Vp = 210 bbl Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/2/2004 18:30 - 18:45 0.25 DRILL N DPRB PROD1 15 min WHP 620 psi BHP 3617 psi "stable" 18:45 - 19:30 0.75 DRILL N DPRB PROD1 Open well on 450 psi and cir to TT to check mud density. Den = 8.7ppg pressureized and <6.5ppg at atmosphere. oilylgas cut mud Lossing 25% returns. SO pump and wait on mud from MI Deadhorse 19:30 - 21 :25 1.92 DRILL N DPRB PROD1 Monitor well while waiting on mud WHP = 557 psi, BHP = 3440 psi, dropped 100 psi in 2 hrs on WHP & PWD sub Density tkr = 8.6ppg 21 :25 - 22:30 1.08 DRILL N DPRB PROD1 Cir new 8.7 ppg mud, adjusting the WHP from 445 to 200 psi while maintaining a BHP of +4000. EDC's in the 12.0 ppg range. Q= 2.00 bpm; CTP = 3842 psi. Volume SurflSurf = 96 bbl Checked mud sample at 100 bbl pumped, Density = 8.7 to 8.4 ppg out Checked mud sample at 120 bbl pumped, Density = 8.7 to 8.3+ ppg out Contacted Kup OS Operator, no gas injection on 10 Pad 22:30 - 00:00 1.50 DRILL N DPRB PROD1 SO and tried to get on Super Choke, gas alarms went off due to gas cut mud, SO, lined out to flow through rig choke and buster. Cir well through gas buster into pits at 1.89 bpm. Density 8.7 I 8.3+ ppg BHP = 4082 psi EDC = 12.32ppg Lossing 30% returns with 330 psi WHP. 9/3/2004 00:00 - 01:10 1.17 DRILL N DPRB PROD1 SO and monitored BH & WH pressure WHP constant at 750 psi and BHP dropped 260 psi, Gas is still expanding at surface with 12.3 EDC while circulating. Bleed WHP down to 435 psi to monitor build up. BHP dropped 125 psi. WHP stablized at 450 psi for30 minutes. Bleed WHP down to 300 psi. Monitor BHP/wHP after 30 mim, BHP stablized close to 3370 psi 01:10- 05:30 4.33 DRILL N DPRB PROD1 Circulated through buster at 2 bpm, maintaining 300 psi WHP EDC at 12.3ppg 30 minutes, lost 40 bbl, Red Qp to 1 bpm. CBHP 3920 psi EDC = 11.9 ppg Density = 8.7 I 8.3+ppg, mud gas cut. Lossing 12-17bph at 1 bpm Waiting on 265 bbl of 8.8 ppg mud from MI Deadhorse. After circulating 3-1/2 hrs, the density is 8.3+ out. EDC constant at 11.8ppg. Lossing 12 to 18 bph. RU Vac 05:30 - 08:10 2.67 DRILL N DPRB PROD1 Cir new mud down CT Qp = 1.9 bpm while maintaining 3950 psi BHP EDC = 11.9ppg Gradually open choke to maintain 12.0 ECD equiv and return MW is getting near normal @ 8.75 ppg in, 8.5 ppg out thru buster at 1.9 bpm and 75 psi bp. PVT 350 after offloading truck wi 8.7+ ppg mud 08:10 - 08:45 0.58 DRILL P PROD1 Log tie-in down from 11700' while circ thru EDC 1.77/3515 ECD 12.04 ppg wi 100 psi bp IA 320, OA 360 Reduce rate to 1.6/3240 ECD 12.05 wi 200 psi bp all thru rig choke (Tri-flo) Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/312004 08:10 - 08:45 0.58 DRILL P PROD1 Corr depth -29' 08:45 - 09:30 0.75 DRILL P PROD1 MW out 8.4 ppg. PUH and park with bit at 11720' and CBU thru EDC 1.6/3260 ECD 12.1 wi 200 psi bp PVT 340 09:30 - 10:20 0.83 DRILL P PROD1 MW out is still 8.4 ppg. TTSOGOTP. SI well wi 570 psi to close EDC. DHP 3920, ECD 11.8 PVT 325 RIH 23'/min while circ thru bit 1.65/3840 ECD 12.1 holding 200 psi bp and perform wiper to TO tagged at 12850' PVT 290 r 10:20 - 11 :00 0.67 DRILL P PROD1 Drill ahead from 12850' while circ out open hole gassy fluid 1.67/3840 ECD 12.2 holding 200 psi bp thru rig choke and gas buster. Drill wi neg WI at <20'/hr for first BU circulation PVT 275 11 :00 - 12:00 1.00 DRILL P PROD1 Start second CBU while drill at <20'/hr from 12853' 1.55/3630/90L, ECD 12.15 wi 200 psi bp and continue to circ out gassy returns thru buster at 8.4 ppg. Penetration rate increased to 70'/hr at 12855' for a couple feet. ., PVT 249 12:00 - 13:00 1.00 DRILL P PROD1 Start fourth CBU while drill at <20'/hr frorn 12858' 1.55/3630/90L, ECD 12.24 wI 200 psi bp and still getting gassy returns, but 'out' MW is now 8.5 ppg PVT 215 13:00 - 13:20 0.33 DRILL P PROD1 Drill ahead albeit very slow at avg 4'/hr from 12862' 1.56/3650/90L, ECD 12.26 wi 200 psi bp and returns are not too gassy. Swap to Swaco choke and maintain 200 psi bp and get 8.7 ppg returns PVT 211 13:20 - 13:40 0.33 DRILL P PROD1 PUH 20k and park. SO pump and close choke trapping initial 500 psi WHP 707 psi, DHP 3918 psi after 5 min WHP 725 psi, DHP 3840 psi after 10 min WHP 725 psi, DHP 3756 psi after 15 min Didn't monitor any longer since didn't want to start over on another well kill since fluid is still going south. . 13:40 - 13:50 0.17 DRILL P PROD1 Resume drilling from 12864' and get to 12865' w/-5k surface WI and 1.84k wob 13:50·15:15 1.42 DRILL P PROD1 Wiper to window both ways was clean. Tag at 12865' PVT 161 15:15·16:55 1.67 DRILL P PROD1 Drill from 12865' 1.57/1.11/3660/90L, ECD 12.28 wI 200 psi bp wi -5k surface WI and 1.51 k wob at <5'/hr. Reduce bp to 150 psi and had 12.22 ECD wI 1.56/1.18 Reduce bp to 100 psi and had 12.15 ECD wI 1.56/1.24 wi 8.7 ppg inlout PVT 109 16:55 - 17:35 0.67 DRILL P PROD1 Drilling break at 12873' and penetration rate increased to 100'/hr. Drilled to 12929' and ran into another brick wall-probably the same one as before. . . 17:35 - 17:50 0.25 DRILL P PROD1 100' wiper after stacking. Density dropped 8.6 ppg to 8.4ppg btm up from prior drilling break PVT 90 Begin adding 9.4 ppg mud to increase volume 17:50 - 19:25 1.58 DRILL P PROD1 Drill from 12929' in brick wall <4'/hr Drilling w/-9k CTW I 0.92 klbf WOB sub With 9 bbl out, fluid loss at 0.4 bpm. Full open choke. EDC inc, red Qp to 1.35bpm Qp = 1.36/0.85 bpm, AV - 197fpm Ordered the 9.5 bbl to be diluted back t08.8ppg 19:25 - 19:45 0.33 DRILL P PROD1 Drill from 12943' in brick wall <4'/hr Drilling w/-9k CTW I 0.92 klbf WOB sub Qp = 1.3710.55 bpm. Lossing 0.83 bpm. BHP = 4190 psi EDC = 12.5ppg Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/312004 19:25 - 19:45 0.33 DRILL P PROD1 9.00 ppg mud around, Den = 9.4/9.3ppg at 12943, Qp = 1.35/0.49bpm, losses inc, to 0.86 bpm 19:45 - 22:00 2.25 DRILL N DPRB PROD1 PUH to above WS to reduce Qp and wait on fluid from MI Deadhorse Logisitic becoming a problem concerning vac trucks. 22:00 - 00:00 2.00 DRILL N DPRB PROD1 0= 11650 ft Open EDC. Cir at 0.95/0.54 bpm waiting on 8.9ppg mud Vp = 265 bbl. Once mixed 9.5/8.8 ppg mud resulant density = 8.95ppg Qp = 0.95 I 0.79 bpm Vp = 200 bbl's. BHP = 3872psi EDC = 11.74ppg 9/4/2004 00:00 - 01:15 1.25 DRILL N DPRB PROD1 Cir 8.9ppg mud around waiting on 8.8ppg fluid from MI Deadhorse Qp = 1.55 I 1 .15 bpm Close EDC and orient TF to HS 01 :15 - 01 :40 0.42 DRILL N DPRB PROD1 RIH to 11,725 ft to Tie-In Qp = 0.35/0.34 bpm -----BHP = 3724psi EDC = 11.21 ppg Corrected -2 ft 01 :40 - 02:30 0.83 DRILL N DPRB PROD1 Inc Qp to 1.58 I 1.02 bpm RIH 02:30 - 03:10 0.67 DRILL P PROD1 Drilling at HS TF. Qp = 1.51 I 1.16 bpm (0.36 bpm losses) BHP = 4147 psi at 12.4ppg. WOB = 1.46klbf and CT = -9klbf. ROP to start at 14 fph Drilled through brick wall, finally ROP inc to 75 fph from 12 fph at 12935 ft 03:10 - 04:00 0.83 DRILL P PROD1 Drilling at 80L TF Q= 1.53/1.06 Density = 8.89 I 9.01 ppg BHP = 4150psi wI EDC @ 12.38ppg. ROP = 51 fph Vp = 464 bbl 04:00 - 05:15 1.25 DRILL P PROD1 Drilling at 100L TF Q= 1.50 I 1.23 Density = 8.92 I 8.95 ppg BHP = 4086 psi wi EDC = 12.25ppg. ROP = 13 fph Vp = 445 bb, Lossing 18 bph ROP at 13,008 ft 2 ft hard streak "Like pushing a rope up a hill" 05:15 - 06:40 1.42 DRILL P PROD1 Drilling at 100L TF Q= 1.50 I 1.22 Density = 8.92 I 8.92 ppg BHP = 4048 psi wi EDC = 12.14ppg. ROP = 9-13 fph Working through siderite streaks 06:40 - 07:40 1.00 DRILL P PROD1 Wiper to window was clean, but had 200 psi MW from 12100-12000' (belly/slow drilling area), fin CBU from TO 07:40 - 08:05 0.42 DRILL P PROD1 Park above window at 11650', SO pump and monitor well for flow to isolated pit and gained 3.5 bbls and seeing 0.15 bpm thru 'out' MM Initial conditions MW inlout 8.92/8.92 0741 WHP 7, PVT 388, IA 319, OA 376 0801 WHP 7, PVT 392, IA 314, OA 366 08:05 - 08:45 0.67 DRILL P PROD1 RIH thru window, clean. Wiper to TO was clean. Tag at 13029' PVT 372 08:45 - 09:00 0.25 DRILL P PROD1 Drill from 13029' 1.51/1.28/3580/90L holding 93 deg. Stack 8.1 k surface wi 1.5k wob and get 50 psi diff, ECD 12.15. Circ thru Swaco choke wi no bp. Look for influx and must have been mud since 'out' MM density did not change 09:00 - 10:00 1.00 DRILL P PROD1 Drilling break at 13032' and back to 80-11 O'/hr. Swap to 90R at 13075'. Drill to 13120' and started stacking PVT 343 10:00 - 11 :20 1.33 DRILL P PROD1 Wiper to window, clean. Red rate to 1.3 bpm/3100 while RIH to reduce losses. Tag at 13120' PVT 320 11 :20 - 12:35 1.25 DRILL P PROD1 Drill from 13120' 1.5/1.19/3550/90R holding 93 deg at 6455' TVD, ECD 12.15 Stack 7.1k surface wi Uk wob and drill Printed; 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/412004 11 :20 - 12:35 1.25 DRILL P PROD1 another hard streak for a few feet, then back to 60-120'/hr. GR is 60-75 api and suggests C2, but siderite exists more in C3. Drill to 13197' and got sticky PVT 280 12:35 - 12:50 0.25 DRILL P PROD1 200' wiper 12:50 - 13:10 0.33 DRILL P PROD1 Drill from 13197' 1.53/1.18/3600/90R holding 93 deg at 6449' TVD, ECD 12.25 Back to drilling in spurts wi neg wt, but now getting stalls (not sliding uphill real well) Drill to 13210' 13:10-14:40 1.50 DRILL P PROD1 Wiper to window was clean both ways. Tag at 13210' PVT 245 14:40 - 17:00 2.33 DRILL P PROD1 Drill from 13210' 1.52/1.24/3600/45R holding 93 deg at 6449' TVD, ECD 12.19 and in another hard spot PVT 190 17:00 - 19:00 2.00 DRILL P PROD1 Drill from 13242' 1.52/1.20/3620/1 OOR holding 93 deg at 6448' TVD, ECD 12.2 Start adding fresh mud. Swap to 100L at 13250' 19:00 - 20:45 1.75 DRILL P PROD1 Make BHA wiper and try to get through this area. Drilling in siderite stringer TF = 60L Qp = 1.51 11.30 bpm, BHP = 3958psi wi EDC @ 11.72 ppg EDC dropped below 12 after blending in the new 8.8ppg mud. Den = 8.77 I 8.76 ppg. Vp at 1900 hrs = 466 bbls Broke through at 13273 ft for 10ft and then back to siderite stringer. Drill inlout sidetrite stringers 20:45 - 22:20 1.58 DRILL P PROD1 Drilling Q = 1.51 I 1.27 bpm Vp at 2045 = 434 bbls, 11 bph losses BHP = 4008 psi EDC = 12.05 ppg 22:20 - 23: 10 0.83 DRILL P PROD1 Wiper trip and conducted ECD test, Closed Choke, open EDC 23:10 - 00:00 0.83 DRILL P PROD1 Cir to clean tubing Qp = 2.02 11.72 bpm; Den = 8.8 I 8.8 ppg ECD Test Q = 0.75 I 0.69 bpm EDC = 11.04 ppg 9/5/2004 00:00 - 01:10 1.17 DRILL P PROD1 Depth = 11697' MD I 6398.8' TVD Stepped down from 0.75 to 0.55 and lossing small amount of fluid Q = 0.30 I 0.30 bpm; EDC = 10.63 ppg BHP = 3520 psi No fluid loss. 15 min stable. Q = 0.24 I 0.24 bpm; EDC = 10.55 ppg BHP = 3495 psi No fluid loss. 15 min stable. Q = 0.12 I 0.12 bpm; EDC = 10.35 ppg BHP = 3428 psi No fluid loss. 15 min stable. The lowest possible BHP achieved was 3428 psi. The high Shear Rate Values I Gel Strengths of Formate mud, while circulating through the small annular, is the reason for not being able to get lower than 3428 psi BHP. 01:10-01:50 0.67 DRILL P PROD1 SO pump and closed cir sub, RIH to Tie-in Tie in at 11,716 ft I 11,725 ft, Corrected -4 ft 01 :50 - 02:35 0.75 DRILL P PROD1 RIH, tagged at 13209 ft TF problem PU, RIH 02:35 - 06:50 4.25 DRILL P PROD1 Drilling TF 85 to 30L, Qp = 1.54/1.25 bpm; BHP = 4024 psi at 12.04 ppg EDC. Density = 8.83 I 8.86 ppg. WOB = 1.56 I -8k 06:50 - 09:00 2.17 DRILL P PROD1 Drill from 13440' 1.5/1.26/3340/90L at 6435' ECD 12.04 and in another hard streak. GR showing 75-140 api from 13390' and drills like a formation change area, but w/6-8k stacked surface wt and 1 k wob it's hard to tell for sure-keep drilling in spurts. Swap to 90R at 13450' and shoot to be 90 deg at 13500' at 6429' TVD. Drill to 13500' PVT 250 09:00 - 10:10 1.17 DRILL P PROD1 Wiper to window, clean wi 8.88 ppg inlout PVT 230 Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/512004 10:10 - 10:45 0.58 DRILL P PROD1 Open EDC and park wi bit at 11700'. Start 9.4 ppg mud down CT (to check if this MW is enough overbalance) 1.5/1.3/3040 11.7 ECD (3890 DHP), IA 360, OA 500. Vac off 8.9 mud from pits 10:45 - 11 :45 1.00 DRILL P PROD1 With 9.27 ppg mud at EDC log tie-in down from 11700', no corr 1.50/1.40/3087 ECD 11.76 (3898 psi) initial 1.37/1.18/2900 ECD 11.85 (3927 psi) after 20 bbls 1.27/1.03/2760 ECD 11.87 (3934 psi) after 35 bbls 1.15/0.83/2550 ECD 11.92 (3960 psi) after 50 bbls 1.05/0.77/2415 ECD 11.89 (3941 psi) after 57 bbls and returns were 9.15 ppg 1.04/0.77/2415 ECD 11.91 (3948 psi) after 65 bbls was 9.25 ppg 11:45 - 12:05 0.33 DRILL P PROD1 0.52/0.4211620 ECD 11.46 (3804 psi) after 10 min 0.15/0.11/1120 ECD 10.90 (3615 psi) after 10 min Safety mtg re: table top discussion on parted pipe responsibiities 12:05·13:10 1.08 DRILL P PROD1 SO pump and flowcheck PVT 43 10 min ECD 10.45 (3450 psi) 40 min ECD 10.15 (3366 psi) still a few dribbles over shaker. Open Whitey on lub and get a blow which quit and no more dribble 13:10 - 13:50 0.67 DRILL P PROD1 PUH 50' to 11645' and record 60 min reading 60 min ECD 10.04 (3316 psi), IA 308, OA 356 100 min ECD 10.13 (3344 psi), IA 304, OA 326 Muse, muse. Can't explain PWD readings. .. mud inlout was 9.27 ppg (3126 psi at 6486' TVD) 13:50 - 15:45 1.92 DRILL P PROD1 Fill hole from BS wi charge pump and took less than a bbl PVT 43 Begin displacement back to 8.88 ppg 1.0/0.7/2340 and took 3 bbls before mud sheared and then had normal returns at 11.7 ECD. Recip CT and park at 11700'. Fin circ out 9.27 ppg mud. Close EDC 15:45 - 16:55 1.17 DRILL P PROD1 RIH thru window and precautionary ream to TO. Set down at 13360' twice at correct TF. RIH to TO tagged at 13500' 16:55 - 18:20 1.42 DRILL P PROD1 Drill from 13500' 1.53/1.24/3400/95R ECD 12.15 wI 7k stacked surface WI and 0.5k wob 18:20 - 21 :20 3.00 DRILL P PROD1 Drilling wi sporadic ROP's TF @ 105 R Q = 1.53 11.21 bpm Den = 8.87 I 8.89 ppg; Vp = 179 bbp BHP = 4067 psi at 12.2ppg EDC. IA/OA = 341 1435 psi 21 :20 - 22:45 1.42 DRILL P PROD1 Drilling wi sporadic ROP's TF @ 105 R Q = 1.54 I 1.20 bpm Den = 8.89 I 8.91 ppg; Vp = 139 bbl Start time BHP = 4072 psi at 12.21ppg EDC. IA/OA = 342 I 438 psi 22:45 - 00:00 1.25 DRILL P PROD1 Drilling wi sporadic ROP's TF @ 105 R Q = 1.52 I 1.22 bpm Den = 8.91 18.92 ppg; Vp = 97 bbl Start time BHP = 4094 psi at 12.28ppg EDC. IAlOA = 342 I 432 psi Transfering 290 bbl of 8.8ppg into mud pits 376 pit volume Printed: 9/13/2004 10: 16: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 8/27/2004 9/8/2004 2 Spud Date: 8/27/2004 End: 9/612004 00:00 - 00:30 0.50 DRILL P PROD1 Turned TF 180 from 105 R to 90 L Drilling @ TF of 90L Q = 1.52 I 1.34 bpm Den = 8.86 I 8.83 ppg; Vp = 354 bbl Start time BHP = 3956 psi at 11.86ppg EDC. INOA = 320 I 336 psi 00:30 - 02:50 2.33 DRILL P PROD1 Wiper trip to window. BHP = 3954 psi @ 11.85ppg EDC Tagged slightly at 13,360 ft RIH, lots negative WI below 13,100 ft 02:50 - 05:00 2.17 DRILL P PROD1 Drilling @ 90 L TF Q = 1.52 I 1.26 bpm Den = 8.87 I 8.87 ppg; Vp = 305 bbl Lost 30 bbl on wiper trip BHP = 4015 psi at 12.04ppg EDC. INOA = 321 I 365 psi 05:00 - 06:30 1.50 DRILL P PROD1 Drilling @ 30 L TF Q = 1.52 / 1.26 bpm Den = 8.86 I 8.88 ppg Vp = 268 bbl BHP = 4008 psi at 12.02ppg EDC. INOA = 321 1365 psi / 06:30 - 06:50 0.33 DRILL P PROD1 Stack at 13721'. PUH fairly clean, but have trouble getting by 13690'. Get back to TO, but stacking full WI and go nowhere 06:50 - 08:30 1.67 DRILL P PROD1 Wiper to window was clean. Wiper back in hole to 12500' and receive word that requirements have been met (TO called). Wiper back to window 08:30 - 10:00 1.50 DRILL P PROD1 Open EDC at 11700' and start circ at 2.0/3800. Wiper to top of 60 deg hole inclination at 3000' following pressure schedule 10:00 - 11 :40 1.67 DRILL P PROD1 RBIH from 3000' following pressure schedule at 1.8/3800 No additional solids seen from tubing cleanout 11:40-12:10 0.50 DRILL P PROD1 Log tie-in down from 11700' (top of Kup sands and RA pip), corr -10' 12:10 - 13:30 1.33 DRILL P PROD1 Wiper trip back to TO was clean to 13510' and had set down wi TF 180 out. Had to use red pump rate of 1.1 bpm while RIH or losses were over 0.3 bpm. Last 200' was at barely positive surface WI at 20'/min. RIH to tag at 13710' which is TO 13:30 - 14:15 0.75 DRILL P PROD1 Wiper to 13300' while swap to fresh 8.8# mud wi 5% L T and 6 ppb KG, 26k up WI. Wiper to TO 14:15 - 15:15 1.00 DRILL P PROD1 Wiper back to window with fresh mud 8.75# mud at bit 1.47/3200. Swap to 9.5 ppg mud 15:15-16:50 1.58 DRILL P PROD1 Park at 11690' and open EDC. Fin circ 9.41 ppg mud to surface. Red rate to keep ECD <12.0. Final rate wi 9.4 ppg mud back was 1.010.53/2500, ECD 12.0. Fill pit #3 for gauge tank w/1 00 bbls. SI well and line up to charge pump (for positive pressure) 16:50 - 17:10 0.33 DRILL P PROD1 Start 90 psi charge pump and DHP 3496. POOH and WHP incr to 500 psi due to swabbing. Will have to fill hole by circ thru CT and take returns to pit #3 17:10 - 17:40 0.50 DRILL P PROD1 POOH at 0.4 bpm 70'/min painting flags at 11,000' and 10,000' EOP. At both stops, lost returns at this rate. Had proper hole fill when pulling. Will have to circ at a higher rate when POOH to keep mud sheared 17:40 - 21 :40 4.00 DRILL P PROD1 At 10,050', circ btm's up at 1.010.54/2550, ECD 12.2ppg; Vp = 41 bbl Reduced Q to 0.2710.15 bpm to cir btms up. RU vac truck 260 bbl 9.4#/gl mud Printed: 9/13/2004 10: 16: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 9/612004 21 :40 - 00:00 2.33 DRILL P PROD1 Fill pits, Inc Qp to 1.3 I 0.69 bpm. POOH at 50 fph Stopped at 5150 ft checked flow. No flow, Started Pump and no fluid losses. POOH 9/7/2004 00:00 - 00:25 0.42 DRILL P PROD1 POOH with correct CT displacement 00:25 - 00:55 0.50 DRILL P PROD1 Monitor well 30 minutes. The flow increased in the shaker from dribble to > 1" stream at shake and then started to come out the whitney valve on the lubricator. Well flowing 00:55 - 01 :35 0.67 DRILL P PROD1 Open EDC and RIH Ordered 511 bbl used 10.1 ppg mud and liner pill 01 :35 - 04:35 3.00 DRILL N DPRB PROD1 Stopped at 3,500ft for pressure buildup, Doyan 16 has MI tanks in use 10 min = 22 psi 100 min = 104 psi 20 min = 44 psi 110 min = 105 psi 45 min = 81 psi 120 min = 106 psi 50 min = 88 psi 130 min = 107 psi 60 min = 92 psi 140 min = 109 psi = 9.72 ppg EMW 70 min = 95 psi 150 min = 109 psi 80 min = 99 psi 160 min = 110 psi 90 min = 102 psi 180 min = 110 psi = 9.73 ppg EMW MI building 10.1 ppg mud system ppg 04:35 - 05:55 1.33 DRILL N DPRB PROD1 Line up through rigs choke and gas buster, RIH Q= 1.02 bpm. 05:55 - 06:20 0.42 DRILL N DPRB PROD1 Log tie-in down at 11700', corr -14'. Close EDC. PVT 260 of 9.4 ppg mud 06:20 - 07:50 1.50 DRILL N DPRB PROD1 RIH thru open hole at 0.6/1950, ECD 11.9 circ'in thru rig choke and gas buster-a little gas in returns (not able to monitor return rate or density other than PVT-need a MM in this line!-an action item long past due! Need a complete rebuild of return path including Swaco choke return path) Had 3-4k extra positive string wt thru-out openhole wi no set downs or wt bobbles PVT 237 07:50 - 11 :00 3.17 DRILL N DPRB PROD1 Tag at 13715'. Wiper back to 11730' while wo higher wt mud at 0.7/2315 ECD 12.00 PVT 167=222 after including pit #2 11 :00 - 12:35 1.58 DRILL N DPRB PROD1 Wiper back to TO 0.54/1980 ECD 11.90 while wo 10.1 ppg mud Start 10.1 # slick fresh mud down CT while RIH to TO 12:35 - 13:35 1.00 DRILL N DPRB PROD1 PUH laying in 10.1 ppg liner pill 5% Lubetex 13:35 - 16:50 3.25 DRILL N DPRB PROD1 Above WS, Open EDC Changed flow to MM because we can't see the returns while running through rigs choke and buster. POOH, Qp 1.04 I 0.53 bpm. Lossing 0.30 bpm to formation BPM. Pulled a little heavy at 11,180 ft. Turned mud to pits at 6775 ft Density = 10.1 I 10.1 ppg Qp = 1.26 I 0.81 bpm 16:50 - 18:00 1.17 DRILL N PROD1 Closed EDC and monitor well 18:00 - 18:20 0.33 DRILL P PROD1 Allow crews to do a good complete swap out, and continue to monitor well. Well is dead. Does not appear to be taking any fluid. 18:20 - 18:35 0.25 DRILL P PROD1 Lay down BHA #5, final drilling BHA. Bit recovered balled up with clay, and was graded 1,2 with the same chipped cutter on the gauge that it had when RIH. 18:35 - 18:55 0.33 RUNCO RUNCMP Safety meeting prior to running liner. Discuss well control safety with respect to the difficult conditions on this well. Discuss hazards, and mitigations to hazards. Safety meeting attended by all hands on rig. Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 19:50 - 20:45 20:45 - 21 :40 21 :40 - 22:30 22:30 - 23:50 23:50 - 00:00 9/8/2004 00:00 - 00:10 00: 10 - 00:45 00:45 - 01 :45 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 0.17 0.17 RUNCO 0.58 RUNCO 1.00 RUNCO Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: MU/Run liner. Liner BHA Bot-Top: Steel Crayola Guide Shoe, 10' blank pup, Baker O-Ring sub, 64 joints of 2-3/8" predrilled liner, 10' blank pup, Baker Deployment sleeve, Baker GS, BHI MWD BHA. Total length of Iiner=2050'. RUNCMP Fluid level being monitored as we run liner. Started out down 15' below rig floor, Pipe displacement brought it up to the rig floor. Continuing to monitor for flow during each connection. Well is not taking fluid, or flowing. RUNCMP All liner in the hole. Hole gave us proper displacement while running liner. It was not taking or givning up any fluid. Good job on well kill during the day tour! MU Baker deployment sleeve, and hydraulic GS. MU BHI coiltrack BHA. Stab on injector. Check the BHI tool electrically, it checks ok. RUNCMP Stationary at surface, circulate at minimum rate. 0.210.2/700 psi. Getting 1 for 1 returns. RIH with liner on 2" coil. Initial RIH data at 70 fpm, 0.24/.47/900 psi. Pit vol=150 bbls. IAP=284 psi, OAP=170 psi. RUNCMP As we RIH, well started taking fluid slightly. 5200', 0.24/0.43/970 psi. Pit vol=159 bbls. 7000',0.24/0.38/1050 psi. Pit vol=162 bbls. 8000', Pit Vol=163 bbls 9000', Pit Vol=164 bbls 10000', Pit Vol=164 bbls. 11000', Pit Vol=164 bbls. RUNCMP Weight check above window. Up weight=30 klbs. Continue RIH. Smooth thru window. RUNCMP Continue RIH in open hole. RIH string wt=5500 Ibs at the window. Check depth at 10000' EOP flag on the fly. Found it 46' deep. Continue RIH with no depth adjustment. RIH at 100 fpm. Pumping 0.2710.18/1285 psi. RUNCMP Catch EOP flag at 11000' on the fly. Found it 45' deep, did not make a depth correction. Continue RIH. String weight dropping as we climb the hill. 13000'=3000 Ibs string wt. RIH at 125 fpm. Stacked out at 13369'. Drop pump rate to O. PU, RIH with -7800 Ibs negative weight. Made it to 13400'. PU at 41 klbs. RIH, stack out at 13407'. PU, Stack out at 13407'. Repeat at 13412'. Able to creep in the hole at 50 fpm, -8000 Ibs string wt to 13432' before stacking out. PU/RIH, stack out at 13432',13433',13440',13463',13461',13457',13463',13465', 13463', 13465', 13474', 13488', 13489', 13489', 13488', 13489', 13488', 13488'. PU 50', and get a run at it. Set down at 13478'. Continue hammering away at it. Set downs at 13490', 13488', 13476', 13488', 13490'. RUNCMP Continue PU/RIH, stacking out consistantly now at 13490' CTM uncorrected depth. Call town and discuss situation. Continue to work pipe. Kick on pumps and see if it makes a difference. No Luck. Circulate for 5 minutes. Drop rate to 0, RIH made a little, then stackout at 13530', 13530'. Stack weight, bring pumps on for 5 minutes. PU/RIH to 13531', 13533', 13528', 13526', 13527'. Kick on pumps and circulate again for 5 minutes. SO pumps, 13542', 13540', 13540'. Pumps on again for 5 minutes, RIH and set down at 13558'. Pumps for 5 minutes, 13559'. Pumps for 5 minutes, PU at 39 klbs. RIH, Printed: 9/13/2004 10:16:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 0-30 1 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2004 Rig Release: 9/8/2004 Rig Number: 2 Spud Date: 8/27/2004 End: 01:50 - 04:15 2.42 RUNCO 04: 15 - 04:35 0.33 RUNCO 04:35 - 04:55 0.33 RUNCO 04:55 - 05:30 0.58 WHSUR P 05:30 - 07:25 1.92 WHSUR P 07:25 - 08:50 1.42 WHSUR P 08:50 - 11 :00 2.17 WHSUR P 11 :00 - 14:30 3.50 DEMOB P 14:30 - 17:00 2.50 DEMOS P RUNCMP 13561'. Unable to make any further significant progress. Do not appear to be pushing something in front of us. We appear to be at coil lockup, and are simply unable to RIH, shoving the liner uphill and get it in the hole over the hump to TO. Bring on pumps to 1.5/0.5/3600 psi. Circulate for several minutes to ensure the coil is fluid packed. PU, and got 38 klbs. May not be released. RIH, resume pumping at 1.64/0.6/4300 psi. PU at 24 klbs. Released from liner ok. Corrected liner depths; Bottom of liner at 13516' Top of liner 11466'. POH, pumping at 1.01.6212700 psi. Pulling at 70 fpm to avoid swabbing well. Hold PJSM while POOH re well control and BHA swap out. Check well for flow. Confirmed, no flow. ./ Rig down Baker GS and BHI MWD tool. MU nozzle BHA. RIH with BHA #7 to swap well to SeawaterlDiesel. Displacing well with SW while hold WHP from 10 psi With 80 bbl pumed PUH laying in SW from 500 psi to 700 psi to 2000 ft, turned hole over to diesel from 2000 ft to surface. Cir diesel to surface OOH, closed Master and swab valve, released pressure Clean Pits, demob rig. PJSM Prep EOP to pull across. Pulled CT to reel house and lower to lowboy. NO SOP's Finished cleaning pits and cutting box. Hauled usable fluids to MI for reconditioning Installed and PT to 4500 psi tree cap. Tested good Fluid lost to formation = 3400 bbl RUNCMP RUNCMP POST POST POST POST POST POST RIG RELEASED AT 1700 HRS 9-8-2004 "GOOD JOB" Printed: 9/13/2004 10:16:12 AM . BP-GDB Baker Hughes INTEQ Survey Report . B.. ..... INT&Q Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 GeoDatum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: 5959249.42 ft Latitude: 70 17 57.217 N From: Map Easting: 560670.61 ft Longitude: 149 30 31.143 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.46 deg Well: 1 D-30 Slot Name: 10-30 Well Position: +N/-S 29.66 ft Northing: 5959279.08 ft Latitude: 70 17 57.509 N +E/-W 0.98 ft Easting : 560671.35 ft Longitude: 149 30 31.115 W Position Uncertainty: 0.00 ft Wellpath: 1D-30L 1 500292296560 Current Datum: 10-30 Magnetic Data: 9/2/2004 Field Strength: 57575 nT VerticaJ Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1 D-30 11710.00 ft Mean Sea Level 24.66 deg 80.75 deg Direction deg 95.00 Height 105.30 ft Survey Program for Definitive Wellpath Date: 9/8/2004 VaJidated: Yes Actual From To Survey ft ft 11710.00 13715.00 MWD (11710.00-13715.00) Version: 3 Toolcode Tool Name MWD MWD - Standard Annotation 11658.83 11710.00 13715.00 6486.95 6509.92 6533.93 TIP KOP TO Survey: MWD CoilTrak Company: Baker Hughes INTEa Tool: MWD;MWD - Standard Start Date: 9/6/2004 Engineer: Tied-to: From: Definitive Path Survey 11658.83 63.47 127.23 6486.95 6381.65 -4975.03 7285.49 5954363.51 567996.07 7691.37 0.00 11710.00 63.18 126.45 6509.92' 6404.62 -5002.44 7322.09 5954336.39 568032.88 7730.21 1.48 ., 11742.68 69.05 122.54 6523.15 6417.85 -5019.33 7346.71 5954319.70 568057.64 7756.22 21.03 11774.19 73.75 119.02 6533.20 6427.90 -5034.60 7372.36 5954304.65 568083.41 7783.10 18.29 11806.21 78.38 115.63 6540.91 6435.61 -5048.85 7399.96 5954290.62 568111.12 7811.84 17.74 11852.83 82.71 110.21 6548.57 6443.27 -5066.74 7442.30 5954273.08 568153.60 7855.57 14.75 11882.90 82.23 103.39 6552.52 6447.22 -5075.35 7470.82 5954264.70 568182.18 7884.73 22.54 11913.75 84.61 106.34 6556.05 6450.75 -5083.21 7500.43 5954257.07 568211.86 7914.92 12.24 11944.16 85.19 110.59 6558.76 6453.46 -5092.80 7529.16 5954247.72 568240.65 7944.37 14.05 11976.09 85.04 116.03 6561.48 6456.18 -5105.39 7558.36 5954235.37 568269.96 7974.56 16.98 12012.19 84.94 111.19 6564.63 6459.33 -5119.79 7591.30 5954221.24 568303.01 8008.64 13.36 12043.27 84.54 105.67 6567.49 6462.19 -5129.57 7620.65 5954211.69 568332.44 8038.73 17.73 . BP-GDB Baker Hughes INTEQ Survey Report . -.I: INTEQ 12076.20 83.06 101.42 6571.04 6465.74 -5137.23 7652.47 5954204.29 568364.31 8071.09 13.59 12106.91 88.08 99.83 6573.41 6468.11 -5142.88 7682.56 5954198.89 568394.44 8101.55 17.14 12136.52 91.49 94.28 6573.53 6468.23 -5146.51 7711.93 5954195.49 568423.83 8131.13 22.00 12166.92 89.59 90.72 6573.24 6467.94 -5147.84 7742.29 5954194.41 568454.20 8161.49 13.27 12203.05 88.69 93.36 6573.78 6468.48 -5149.12 7778.39 5954193.42 568490.31 8197.56 7.72 12234.01 88.97 98.63 6574.41 6469.11 -5152.35 7809.16 5954190.43 568521.10 8228.50 17.04 12266.55 89.34 103.80 6574.89 6469.59 -5158.68 7841.07 5954184.37 568553.06 8260.84 15.93 12308.22 89.98 108.53 6575.14 6469.84 -5170.28 7881.08 5954173.09 568593.15 8301.71 11.45 12354.57 90.75 102.05 6574.85 6469.55 -5182.49 7925.76 5954161.24 568637.93 8347.28 14.08 12389.03 89.80 97.17 6574.68 6469.38 -5188.24 7959.73 5954155.76 568671.94 8381.62 14.43 12429.72 91.58 90.38 6574.19 6468.89 -5190.92 8000.30 5954153.41 568712.53 8422.27 17.25 12462.84 90.44 85.29 6573.61 6468.31 -5189.67 8033.38 5954154.93 568745.59 8455.12 15.75 12494.59 92.01 79.08 6572.93 6467.63 -5185.36 8064.81 5954159.50 568776.99 8486.05 20.17 12529.42 93.36 74.04 6571.29 6465.99 -5177.27 8098.64 5954167.85 568810.74 8519.05 14.96 12570.80 94.28 67.43 6568.53 6463.23 -5163.66 8137.59 5954181.78 568849.58 8556.67 16.09 12602.52 92.13 72.11 6566.76 6461.46 -5152.71 8167.30 5954192.96 568879.20 8585.31 16.21 12632.62 93.12 77.33 6565.38 6460.08 -5144.79 8196.29 5954201.12 568908.13 8613.50 17.63 12657.15 89.46 78.79 6564.83 6459.53 -5139.72 8220.28 5954206.38 568932.07 8636.96 16.06 12693.73 88.76 84.52 6565.40 6460.10 -5134.41 8256.46 5954211.98 568968.20 8672.53 15.78 12725.18 86.73 90.53 6566.64 6461.34 -5133.06 8287.84 5954213.59 568999.56 8703.67 20.16 12760.49 87.84 97.67 6568.31 6463.01 -5135.58 8322.99 5954211.36 569034.73 8738.92 20.44 12795.42 88.70 103.55 6569.37 6464.07 -5142.00 8357.29 5954205.21 569069.08 8773.65 17.01 12820.98 89.03 109.00 6569.87 6464.57 -5149.16 8381.82 5954198.25 569093.66 8798.70 21.36 12868.98 89.13 104.75 6570.64 6465.34 -5163.09 8427.73 5954184.69 569139.68 8845.66 8.86 12898.60 92.13 100.74 6570.32 6465.02 -5169.62 8456.61 5954178.39 569168.61 8874.99 16.91 12924.80 91.61 95.67 6569.46 6464.16 -5173.36 8482.52 5954174.87 569194.55 8901.13 19.44 12952.47 91.98 91.02 6568.60 6463.30 -5174.97 8510.12 5954173.48 569222.16 8928.77 16.85 12980.17 92.93 87.85 6567.41 6462.11 -5174.70 8537.79 5954173.97 569249.82 8956.31 11.94 13011.87 94.16 80.99 6565.45 6460.15 -5171.63 8569.26 5954177.30 569281.26 8987.39 21.94 13041.62 94.53 76.25 6563.19 6457.89 -5165.78 8598.34 5954183.38 569310.28 9015.84 15.94 13071.40 93.24 74.48 6561.17 6455.87 -5158.27 8627.08 5954191.12 569338.97 9043.82 7.34 13101.02 94.41 80.19 6559.20 6453.90 -5151.79 8655.90 5954197.83 569367.73 9071.97 19.64 13131.05 94.10 86.04 6556.97 6451.67 -5148.20 8685.62 5954201.66 569397.42 9101.27 19.45 13163.50 92.53 91.64 6555.09 6449.79 -5147.55 8718.00 5954202.57 569429.78 9133.46 17.89 13193.69 93.67 98.16 6553.45 6448.15 -5150.12 8748.02 5954200.24 569459.82 9163.59 21.89 13224.93 91.67 102.48 6552.00 6446.70 -5155.71 8778.71 5954194.90 569490.55 9194.65 15.22 13257.38 89.86 105.39 6551.56 6446.26 -5163.52 8810.19 5954187.35 569522.10 9226.70 10.56 13293.68 92.87 99.22 6550.70 6445.40 -5171.25 8845.63 5954179.90 569557.59 9262.67 18.91 13320.87 95.05 94.65 6548.82 6443.52 -5174.53 8872.55 5954176.84 569584.53 9289.77 18.58 13354.84 95.24 87.47 6545.77 6440.47 -5175.16 8906.35 5954176.49 569618.34 9323.50 21.06 13382.86 96.68 81.05 6542.86 6437.56 -5172.37 8934.07 5954179.50 569646.03 9350.87 23.36 13415.36 95.46 73.83 6539.42 6434.12 -5165.35 8965.59 5954186.78 569677 .49 9381.66 22.41 13444.72 94.22 68.48 6536.94 6431.64 -5155.90 8993.26 5954196.45 569705.08 9408.41 18.64 13474.49 92.50 73.26 6535.19 6429.89 -5146.16 9021.33 5954206.41 569733.07 9435.52 17.04 13507.56 90.51 81.09 6534.32 6429.02 -5138.83 9053.54 5954214.00 569765.21 9466.97 24.42 13536.96 91.52 88.02 6533.80 6428.50 -5136.04 9082.78 5954217.02 569794.43 9495.86 23.82 13571.02 89.98 95.74 6533.35 6428.05 -5137.16 9116.80 5954216.18 569828.45 9529.84 23.11 13602.16 89.59 102.71 6533.47 6428.17 -5142.15 9147.51 5954211.44 569859.20 9560.87 22.42 13632.10 88.20 106.77 6534.05 6428.75 -5149.77 9176.46 5954204.06 569888.20 9590.37 14.33 13674.06 90.72 97.20 6534.44 6429.14 -5158.47 9217.45 5954195.69 569929.26 9631.96 23.58 , 13715.00 90.72 97.20 6533.93 / 6428.63 -5163.60 9258.06 5954190.89 569969.91 9672.87 0.00 ~on~cOPhnIiPs Alaska, Inc. Pa",nt WaUpath: Tie onMD: 10-30l1 500292295560 10~ 11110JlO LEGEND 1t),.30,1D~30L1,P!a #3 i[}..3Q (10-30) 1o..30l1 MWO T M Azimuths to True North Magnetic North: 24.66' Magnetic Field Strength: 51575n T Dip Angle: 80]5' Date: 9/212004 Model: bggm2004 Survey: MWD {1D~30/1D~30l1) Created By: Brij Potnís Date: 9127/2004 ~ig: Ref. Oatum: V.Section Angle 95.00' Nordic 2 10-30 105.301t Origin Origin Starting +NI.S +EI-W From TVD 0.00 0.00 0.00 REFERENCE INFORMATION Well Centre: 10-30, True North System: Mean Sea level Slot· (O.OON,O.OOE) 1!)..30 105.30 Minimum Curvature TARGETÐE:l:AR$ TVD MD 6381;65 11-658,83 TtP 6404,6211710_00 KOP 6428;£3- 13715.00 TO ->fj,W Sj¡¡¡¡w 1700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8000 9000 9100 West(-)/East(+) [1 DDft/in] STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report S u bm it to: llm...EQfJ.n.@ªg.rni.Q.'.§.~ª!Q:.f*:.~t~~ aoncc _prudhoe _t;ay@admin.statø.aÏ<.us bob _ f!eGkenste¡ n@adrn¡n.state.flk.us Contractor: NORDIC I SLB Rig No.: 2 DATE: 8/29104 Rig Rep.: Mckeiman I Olsen Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich I Sevcik E-Mail SUADWDRLGNORDIC2TOOLPl!SH~:.R@8P .GOM Well Name: ~ruf< 1D-30A PTD # 214-145 Meridian: UM Location: Section: 23 Township: 11N Range: 10E Operation: Drlg: XXX Workover: Explor. : Test: Initial: XXX Weekly: Other: Test Pressure: Rams: 250/4500 Annular: 250/3500 Valves: 250/4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly 0 Housekeeping: P Dr!. Rig P Lower Kelly 0 PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP 0 BOP STACK: Quantity SizelType P/F MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind I Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams NIA Quantity P/F Choke Ln. Valves 1 31/8" P Inside Reel valves HCR Valves 2 31/8" PP Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve NIA Time/Pressure P/F System Pressure 3000 CHOKE MANIFOLD: Pressure After Closure 2000 Quantity P/F 200 psi Attained 24 sec No. Valves 14 PIP Full Pressure Attained 2 Min 3 sec Manual Chokes 1 P Blind Switch Covers: All stations XX Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2100 Test Results Number of Failures: Q Test Time: 5.5 Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: llLD...E~JJfi@ªQ.rni.Q.'.§Aª!Q,"ª-~,.~E~ Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper.lRig Waived By c - Database Date 8/28/04 Time 0800 c - Trip Rpt File Witness John Crisp c - Inspector Test start 1530 Finish 2100 Coil Tubing BFL 05/29/03 Nordic 2 BOP 08-29-04..xls . . FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 ,FAù< (907)276-7542 Thomas McCarty CT Drilling Engineer Conoco Phillips (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: KUP ID-30Ll Conoco Phillips (Alaska), Inc. Permit No: 204-145 Surface Location: 387' SNL, 419' Sec. 23, TllN, RlOE, UM Bottomhole Location: 253' SNL, 3738' EWL, Sec. 30, TIIN, RIlE, UM Dear Mr. McCarty: 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. The permit is for a new wellbore segment of existing well KRU lD-30Ll, Permit No 200-104, API 50-029-22965-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission wi ness any required test. Contact the Commission's petroleum field inspector at (907) 659 607 ager). Si BY ORDER g.{ THE COMMISSION DATED this"'=¡' day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o end Department of Environmental Conservation w/o encI. STATE OF ALASKA ALASKAe. AND GAS CONSERVATION CO_ISSION PERMIT TO DRILL 20 MC 25.005 ß.¥fJ.> o Drill II Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 387' SNL, 419' WEL, SEC. 23, T11N, R10E, UM ' Top of Productive Horizon: 105' SNL, 1608' EWL, SEC. 30, T11 N, R11 E, UM Total Depth: 253' SNL, 3738' EWL, SEC. 30, T11 N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 . y- 5959279 ' Zone- ASP4 16. Deviated Wells: Kickoff Depth: 11699 - feet Maximum Hole Angle: 94 deqrees 11 b. Current Well Class 0 Exploratory III Development Oil 0 Multiple Zone 1 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 59-52-180 KUP 1 D-30L 1 6. Proposed Depth: 12. Field I Pool(s): MD 13900 ' TVD 6448'" Kuparuk River Field / Kuparuk 7. Property Designation: River Pool ADL 028248 '^ 9. Acres in Property: 2560 13. Approximate Spud Date: August 20, 2004 14. Distance to Nearest Property: 5180' 8. Land Use Permit: 18. _ ._.. '''", _". i:)lze Hole Casina 3" 2-3/8" Weiaht 6.2# Grade L-80 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 105.3' feet 10-32 is 1670' away , 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 2670 Surface: 2026 .' ~etting Dept~ ~ TClp UV'LVII' ~ Couolina Lenath MD TVD MD TVD ~na staae data} STL 2250' 11650' 6378' 13900' 6448' UncemeJtfcf8i¡ . L. ~ -......, ~..f~rd ~~ 0' .:.~, t,; f'I .. _ £k...L . I'! If J4 .,... "-'I' (!¡ r."", ^ ;19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Opera·......... Total Depth MD (ft): Total Depth TVD (ft): \ Plugs (measured): \ Effective Depth MD (ft): \Effective Depth TVD (ft): Jf:iHk (measured): 12044 6661 None 11975 6630 None , . ' .' 'v'v ,. . I VV I Conductor 110' 16" 16.5 cu vds AS I, Tvpe III 110' 110' ~llrf;r.A 6873' 9-5/8" 710 sx AS III Lite, 460 sx LiteCrete 6873' 4341' Int . te 11305' 7" 180 sx Class 'G' 11305' 6327' Production Liner 888' 3-1/2" 212 sx Class 'G' 11153' - 12041' 6257' - 6660' Perforation Depth MD (ft): 11760' - 11816' (by;t) 20. Attachments :. Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 6533' - 6558' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 MC 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 Thomas McCarty, 564-4378 Printed Name Thomas McCarty Title CT Drilling Engineer Prepared By Name/Number: Signature- ./ C_ -_' r ~ ~ Phone 564-4378 Date ~ k .'//>1, Terrie Hubble, 564-4628 1.00'00 ·.··'··)00~·>. '0.····. 2J.0 ~.:;.giG,1).000)0L0>0;.··):0.·:i:0.:r··· ·0.0':;i0,';0(', "·'0)·1' )J;!,0.i);) ......i)0:'..).!> ~~:~~~o Drill. 2DtJ:~~ API Numb~~_029_22965~0 -1'5~~'Ì 6:~~itAPprov~/Q!ótll~~~~:;~i~:~~~~: Conditions of Approval: Samples Required 0 Yes j¡No Mud Log Requiref1 I 0 Yes ~o Other: . Hydr~ ~Ulfjde Measure~ rRYes ~ No Directional ~:rvey Required ~es ( 0 No 4:~_~~. \<D\/~~~h~~~,"\ ~~::::QfPro~~ ~ /,d ADDroved B~ ~t THE COMMISSION Date C7) / / ð'f' Form 10-401 ~d' ~4 ~ 0 R f G ! r~ A 'pubmfln Duplicate _RU 1 D-30L 1 Sidetrack - Coiled T~9 Drilling Summary of Operations: Coiled tubing drilling will sidetrack KRU lD-30 using Managed pressure drilling technique (MPD, see description below). This horizontal lateral will target Kuparuk C sand reserves for production.' The Kuparuk C Sand perforations in the existing well, 1D-30 will be retained and flow past the whipstock. A one way check is planned to be used in the whipstock to avoid losses to the existing perfs yet allowing production. - CTD Drill and Complete ID-30Ll prOi!ram: Planned for AUi! 20, 2004 1. Pre CTD No flow test on SSSV, MIT-IA, MIT-OA 2. Pre CTD Caliper 3-112" liner 3. Pre CTD install mechanical whipstock at approx 11699' 4. MIRV Nordic 2. NU 7-1/16" BOPE, test. 5. Mill window at 11699' md and 10' of openhole. ~ 6. Drill 3" bicenter hole horizontal sidetrack from window to ~ 13900' TD targeting Kuparuk C sand interval. 7. Complete with 2 3/8" pre-drilled liner from TD 13900', up into the 3-112" liner to -11650 ' . 8. Post CTD rig -Run GL V s. Bring on production. Mud Program: · Steps 1-2: 9 ppg Potassium-Formate biozan brine' · Steps 3-10: Potassium-Formate based PIo-Pro (9 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 Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · 1D-30L1: 23/8",6.2#, L-80, STL slotted liner from 11650' md to 13900' md Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for 1D-30L1 · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · The nearest well to 1D-30L1 is 1D-32 which is offset by 1670'. · ID-30 is approx. 5180' from the KRU boundary. Logging · A Gamma Ray log and Resistivity will be run over all of the open hole section. Thomas McCarty 564-4378 office, 748-2598 cell 1/2 _RU 1 D-30L 1 Sidetrack - Coiled Teg Drilling Hazards · No mapped faults in the planned well path; lost circulation risk is low. · Mechanically weak shales will require DOCTD to maintain constant bottom hole pressure. · WelllD-30 has a H2S reading of 70 ppm. ID is an H2S pad, the highest H2S measurement on the pad is/ 120ppm. All H2S monitoring equipment will be operational. Reservoir Pressure · The latest Shut in bottom hole pressure is approx. 2670psi at 6441' TVD 8.0 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2026 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques wilJ be employed to provide constant bottom hole pressure. Managed pressure drilling is similar to dynamically overbalanced drilling but in this case the mud weight we will be using is greater than the required kill weight. Plans are to use 8.7 ppg drilling fluid (reservoir press - 8ppg) in combination with annular friction losses and applied surface pressure to maintain constant bottom hole pressure. Constant BHP will be utilized to reduce pressure fluctuations on mechanically weak shales. In addition the heavier equivalent mud weight is expected to help with shale stability. 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" 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: 2670 psi at 6441' TVD, 8.0 ppg EMW. .. Expected annular friction losses while circulating (ECD): 900 psi Planned mud density: 8.7 ppg equates to 2914 psi hydrostatic bottom hole pressure. While circulating 8.7 ppg fluid, bottom hole circulating pressure is estimated to be 3800 psi When circulation is stopped, a minimum of 900 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities wilJ 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 equivalent fluid weight that is found to work best with the exposed shales during the drilling operation. Thomas McCarty 564-4378 office, 748-2598 cell 2/2 NIP (527-528, 00:3.500) Gas Lift MandrelNalve 1 (3030-3031, Gas Lift Mandrel/Valve 2 (6037-6038, Gas Lift Mandrel/Valve 3 (7859-7860, Gas Lift MandrelNalve 4 (9366-9367, Gas Lift MandrelNalve 5 :10574-10575, 00:5.968) Gas Lift ,"drellOummy Valve 6 :11089-11090, 00:5.968) NIP :11133-11134. 00:3.500) PKR :11160-11161. 00:7.000) TUBING (0-11178, 00:3.500. 10:2.992) Perf :11760-11800) LINER :11153-12041, 00:3.500, Wt:9.30) Perf 11800-11805) FRAC 11800-11805) Perf ·11796-,1816) .- ..- -- =:::=:: ..-- ~ ~500 SSSV~ ~ 11815 5/25/2004 DescriDtion CONDUCTOR SURF CASING PROD CASING LINER I Size I Top ~ 11760 -11796 I 6533 - 6549 1 1 Interv¡3i KRU Anole (â) Angle @ TD 64 deg @ 12044 1 D..30 Well Type: PROD Orig 8/12/2000 Completion: ~ ~ Size TOD BDttom TVD ~ 16.000 0 110 110 ~ 9.625 0 6873 4341 I 40.00 I L-80 BTCM 7.000 0 11305 ~327 26.00 L-80 BTCM 3.5~._ 12041 6660 SLHT I ~ I Wt Thread I 11178 I 6269 I 9.30 8RD Ft SPF~ 36 4 ~2,5"HC, h 9 8 3/26/2001 HC h 11 4 H('.~ Comment 142Mlb~ V Type V 00 Latch Port TRO Rev Reason TAG FILL Last Update 5/28/2004 Zone C-3,C-2 C-2 C-2 Status 8t MD TVD Man Mfr 1 3030 2616 Cameo MMG Cameo GLV 1.5 2 6037 3976 Cameo MMG Cameo GLV 1.5 3 785S1 4775 Cameo MMG Cameo GLV 1.5 .5447 Cameo MMG Camco GLV 1.5 Cameo MMG Cameo OV 1.5 Cameo MMG Cameo DMY 1.5 I TVDe ~ DescriDtion : NIP Nipple wINo Go profìie I 11133 6248 NIP Nipple wINo Go profile ,11160 6260 PKR I Baker 5x7" ZXP Liner Top Packer w/5" RS nipple & TCK coupllnç¡ 11180 6270 SEAL I Baker SSE '80-40' 4" ID w/TKC couplinos 112426298 NIP IXNNíoplew/2.75"NoGo VMfr Date Run 11/3/2001 11/3/2001 11/3/2001 11/3/2001 11/2/2001 151 II ¿UUL RK RK RK RK RK RK 0,188 0,188 0.188 0,188 0.188 0.000 1283 1271 1258 1245 o o Viv Cmnt WICK ID 2.875 2.813 5.000 4,000 2.750 KRU 1 D-30L 1 Producer Proposed Completion 9-5/8" 40# L-80 @ 6873" 7" 26# L-80 @ 11305 MD' E. 3-1/2" Camco DS nipple, 2.875" min 10 at 527' MD 0.3-1/2" 9.3# L-80 EUE 8rd Mod Tubing with MMG mandrels C. 3-%" Camco DS nipple, 2.813" min ID @ 11133' MD B. Baker ZXP liner top packerlSBE/seal assembly at 11160' MD A. 3-W' Camco D nipple, 2.75" min ID at 11242' MD Window in 3-1/2" KOP at 11699' MD 2-3/8" liner top @ +1-11650' MD o 0 o 0 Flowthrough WS wI standing valve 3-1/2" 9.3# L-80 @ 12041 MD' Fill o o 0 0 o 0 0 o o o o o o o 0 o 0 o 0 o o o o o o o o 0 Conoc6PhiUips Alaska, Inc. e e~ C3/C2 Lateral, TD @ 13900' md o o 000 o o o o o o o o o o o o C3/C2 - Sand 2-318" pre-drilled liner, 4 holes/ft, 3/8" hole size DEV 7/14104 e BP-GDB e Baker Hughes INTEQ Planning Report B.. IIAKD IUGIIII -".-"""'---- IN'fEQ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 10 Pad UNITED STATES: North Slope Site Position: Northing: 5959249A2 ft Latitude: 70 17 57.217 N From: Map Easting: 560670.61 ft Longitude: 149 30 31.143 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.46 deg Well: 10-30 Slot Name: 10-30 Well Position: +N/-S 29.66 ft Northing: 5959279.08 ft Latitude: 70 17 57.509 N +E/-W 0.98 ft Easting : 560671.35 ft Longitude: 149 30 31.115 W Position Uncertainty: 0.00 ft Wellpath: Plan#3 1 D-30L 1 500292296560 Current Datum: 10-30 Magnetic Data: 7/20/2004 Field Strength: 57571 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 10-30 11658.83 ft Mean Sea Level 24.72 deg 80.75 deg Direction deg 95.00 Height 105.30 ft Targets 1 0-30 T3.7 6447.00 -5138.64 9649AO 5954219.00 570361.00 70 17 6.910 N 149 2550.008 W 10-30 T3.6 6448,00 -5146.85 9304.29 5954208.00 570016.00 70 17 6.833 N 149 26 0.062 W 10-30 T3.1 6450.00 -5094.07 7473A9 5954246.00 568185.00 70 17 7.372 N 149 26 53.396 W 10-30 T3.5 6468.00 -5157.53 8892.16 5954194.00 569604.00 70 17 6.733 N 149 26 12.069 W 10-30 T3.8 6481.00 -5122.77 10285.61 5954240.00 570997.00 70 17 7.057 N 149 25 31A73 W 10-30 T3.2 6484.00 -5157AO 7885.03 5954186.00 568597.00 70 17 6.745 N 149 2641.408 W 10-30 T3.4 6494.00 -5164.87 8439.04 5954183.00 569151.00 70 17 6.666 N 149 26 25.269 W 10-30 T3.3 6497.00 -5166A9 8143.99 5954179.00 568856.00 70 17 6.653 N 149 26 33.865 W Annotation MD ft 11658.83 6381.65 TIP 11699.00 6399.66 KOP 11713.00 6405.83 End 9 OLS I Begin 14 DLS 11856.63 6444.65 4 12126.63 6470.87 5 12316.63 6486.01 6 12604.87 6497.11 7 12879.87 6494.01 8 13129.87 6483.10 9 13354.87 6468.63 10 13579.87 6456.28 11 e BP-GDB e Baker Hughes INTEQ Planning Report II.. ..... -------.-----. INTEQ Annotation 13754.87 6449.73 12 13900.00 6448.20 TO Plan: Plan #3 Date Composed: 7/20/2004 Identical to Lamar's Plan #3 Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 11658.83 63.47 127.23 6381.65 -4975.03 7285.49 0.00 0.00 0.00 0.00 11699.00 63.24 126.62 6399.66 -4996.60 7314.19 1.47 -0.57 -1.52 246.99 11713.00 64.50 126.62 6405.83 -5004.10 7324.28 9.00 9.00 0.00 0.00 11856.63 84.00 121.49 6444.65 -5080.86 7438.39 14.00 13.58 -3.57 345.00 12126.63 85.26 83.53 6470.87 -5137.91 7695.98 14.00 0.47 -14.06 270.00 12316.63 85.76 110.21 6486.01 -5160.39 7882.31 14.00 0.26 14.04 90.00 12604.87 90.00 70.04 6497.11 -5160.88 8164.42 14.00 1.47 -13.94 275.00 12879.87 91.24 108.53 6494.01 -5157.51 8434.23 14.00 0.45 13.99 88.00 13129.87 93.60 73.57 6483.10 -5162.08 8680.08 14.00 0.94 -13.98 274.50 13354.87 93.59 105.14 6468.63 -5159.58 8901.77 14.00 0.00 14.03 89.00 13579.87 92.54 73.61 6456.28 -5157.11 9123.59 14.00 -0.47 -14.01 269.00 13754.87 91.69 98.11 6449.73 -5144.58 9296.68 14.00 -0.49 14.00 91.50 , 13900.00 89.50 77.91 6448.20 -5139.56 9440.95 14.00 -1.50 -13.92 264.00 "' 11725.00 66.12 126.14 6410.84 -5010.56 7333.06 5954328.36 568043.92 7741.86 14.00 345.00 MWD 11750.00 69.51 125.19 6420.28 -5024.06 7351.87 5954315.02 568062.83 7761.77 14.00 345.20 MWD 11775.00 72.90 124.28 6428.33 -5037.54 7371.31 5954301.70 568082.39 7782.31 14.00 345.56 MWD 11800.00 76.30 123.40 6434.97 -5050.95 7391.33 5954288.44 568102.51 7803.42 14.00 345.85 MWD 11825.00 79.70 122.54 6440.17 -5064.26 7411.84 5954275.31 568123.13 7825.02 14.00 346.09 MWD 11850.00 83.10 121.71 6443.91 -5077.40 7432.77 5954262.34 568144.16 7847.02 14.00 346.26 MWD 11856.63 84.00 121.49 6444.65 -5080.86 7438.39 5954258.93 568149.80 7852.91 14.00 346.39 4 11875.00 84.01 118.90 6446.57 -5090.04 7454.18 5954249.87 568165.66 7869.44 14.00 270.00 MWD 11900.00 84.03 115.38 6449.18 -5101.38 7476.30 5954238.71 568187.87 7892.46 14.00 270.27 MWD 11925.00 84.08 111.86 6451.76 -5111.34 7499.08 5954228.93 568210.73 7916.02 14.00 270.64 MWD 11950.00 84.16 108.35 6454.33 -5119.89 7522.43 5954220.58 568234.14 7940.03 14.00 271.00 MWD 11975.00 84.25 104.83 6456.85 -5126.99 7546.26 5954213.67 568258.03 7964.39 14.00 271.36 MWD 12000.00 84.37 101.31 6459.33 -5132.62 7570.49 5954208.24 568282.30 7989.02 14.00 271.72 MWD 12025.00 84.50 97.80 6461.76 -5136.75 7595.02 5954204.31 568306.86 8013.82 14.00 272.07 MWD 12050.00 84.66 94.29 6464.12 -5139.37 7619.77 5954201.89 568331.63 8038.70 14.00 272.41 MWD 12075.00 84.84 90.78 6466.41 -5140.47 7644.63 5954200.99 568356.50 8063.56 14.00 272.74 MWD 12100.00 85.03 87.27 6468.62 -5140.04 7669.53 5954201.62 568381.39 8088.33 14.00 273.06 MWD 12125.00 85.25 83.76 6470.74 -5138.09 7694.36 5954203.76 568406.20 8112.89 14.00 273.37 MWD 12126.63 85.26 83.53 6470.87 -5137.91 7695.98 5954203.96 568407.82 8114.49 14.00 273.67 5 12150.00 85.27 86.82 6472.80 -5135.96 7719.18 5954206.10 568431.00 8137.43 14.00 90.00 MWD 12175.00 85.30 90.33 6474.86 -5135.34 7744.08 5954206.92 568455.89 8162.19 14.00 89.73 MWD 12200.00 85.34 93.84 6476.90 -5136.24 7768.98 5954206.22 568480.79 8187.07 14.00 89.44 MWD 12225.00 85.40 97.35 6478.92 -5138.67 7793.77 5954203.99 568505.61 8211.98 14.00 89.15 MWD 12250.00 85.48 100.86 6480.91 -5142.61 7818.37 5954200.25 568530.24 8236.83 14.00 88.87 MWD 12275.00 85.57 104.37 6482.86 -5148.06 7842.69 5954195.00 568554.60 8261.53 14.00 88.59 MWD e BP-GDB e Baker Hughes INTEQ Planning Report _íí. ..... --........_-,;---~-- INTEQ 12300.00 85.68 107.88 6484.77 -5154.98 7866.64 5954188.27 568578.59 8285.99 14.00 88.32 MWD 12316.63 85.76 110.21 6486.01 -5160.39 7882.31 5954182.99 568594.31 8302.08 14.00 88.05 6 12325.00 85.87 109.04 6486.62 -5163.19 7890.17 5954180.25 568602.19 8310.15 14.00 275.00 MWD 12350.00 86.19 105.55 6488.35 -5170.61 7913.98 5954173.03 568626.06 8334.51 14.00 275.09 MWD 12375.00 86.52 102.06 6489.94 -5176.56 7938.21 5954167.27 568650.33 8359.17 14.00 275.33 MWD 12400.00 86.86 98.57 6491.39 -5181.03 7962.76 5954163.00 568674.91 8384.01 14.00 275.55 MWD 12425.00 87.22 95.08 6492.68 -5183.99 7987.54 5954160.24 568699.72 8408.96 14.00 275.75 MWD 12450.00 87.58 91.60 6493.81 -5185.45 8012.47 5954158.98 568724.66 8433.92 14.00 275.93 MWD 12475.00 87.96 88.12 6494.78 -5185.39 8037.45 5954159.25 568749.63 8458.80 14.00 276.09 MWD 12500.00 88.34 84.63 6495.59 -5183.81 8062.38 5954161.03 568774.55 8483.50 14.00 276.22 MWD 12525.00 88.73 81.16 6496.23 -5180.72 8087.18 5954164.32 568799.31 8507.93 14.00 276.34 MWD 12550.00 89.13 77.68 6496.69 -5176.12 8111.74 5954169.11 568823.84 8532.01 14.00 276.43 MWD 12575.00 89.52 74.20 6496.99 -5170.05 8135.99 5954175.37 568848.03 8555.63 14.00 276.49 MWD 12600.00 89.92 70.72 6497.11 -5162.52 8159.82 5954183.10 568871.80 8578.72 14.00 276.53 MWD 12604.87 90.00 70.04 6497.11 -5160.88 8164.42 5954184.77 568876.38 8583.15 14.00 276.55 7 12625.00 90.10 72.86 6497.10 -5154.48 8183.49 5954191.33 568895.41 8601.60 14.00 88.00 MWD 12650.00 90.22 76.36 6497.03 -5147.85 8207.59 5954198.15 568919.45 8625.02 14.00 88.00 MWD 12675.00 90.34 79.86 6496.90 -5142.70 8232.05 5954203.50 568943.86 8648.94 14.00 88.01 MWD 12700.00 90.46 83.35 6496.73 -5139.05 8256.78 5954207.35 568968.56 8673.26 14.00 88.03 MWD 12725.00 90.58 86.85 6496.50 -5136.91 8281.68 5954209.69 568993.44 8697.88 14.00 88.05 MWD 12750.00 90.69 90.35 6496.22 -5136.30 8306.67 5954210.50 569018.42 8722.72 14.00 88.09 MWD 12775.00 90.81 93.85 6495.90 -5137.22 8331.65 5954209.78 569043.40 8747.68 14.00 88.12 MWD 12800.00 90.92 97.35 6495.52 -5139.66 8356.52 5954207.55 569068.29 8772.67 14.00 88.17 MWD 12825.00 91.02 100.85 6495.10 -5143.61 8381.20 5954203.80 569093.00 8797.60 14.00 88.22 MWD 12850.00 91.13 104.35 6494.63 -5149.06 8405.59 5954198.54 569117.43 8822.37 14.00 88.28 MWD 12875.00 91.23 107.84 6494.11 -5155.99 8429.60 5954191.81 569141.49 8846.90 14.00 88.35 MWD 12879.87 91.24 108.53 6494.01 -5157.51 8434.23 5954190.33 569146.14 8851.64 14.00 88.42 8 12900.00 91.46 105.72 6493.53 -5163.43 8453.46 5954184.56 569165.41 8871.31 14.00 274.50 MWD 12925.00 91.73 102.23 6492.83 -5169.46 8477.70 5954178.72 569189.70 8895.99 14.00 274.43 MWD 12950.00 91.99 98.73 6492.02 -5174.01 8502.27 5954174.38 569214.30 8920.86 14.00 274.34 MWD 12975.00 92.25 95.24 6491.10 -5177.05 8527.06 5954171.54 569239.11 8945.83 14.00 274.22 MWD 13000.00 92.49 91.75 6490.06 -5178.57 8551.99 5954170.22 569264.05 8970.79 14.00 274.09 MWD 13025.00 92.73 88.25 6488.92 -5178.57 8576.96 5954170.42 569289.02 8995.67 14.00 273.95 MWD 13050.00 92.95 84.75 6487.68 -5177.04 8601.88 5954172.14 569313.92 9020.36 14.00 273.79 MWD 13075.00 93.17 81.26 6486.35 -5174.01 8626.66 5954175.38 569338.67 9044.77 14.00 273.62 MWD 13100.00 93.37 77.76 6484.92 -5169.46 8651.19 5954180.13 569363.17 9068.82 14.00 273.43 MWD 13125.00 93.56 74.25 6483.41 -5163.43 8675.40 5954186.35 569387.32 9092.41 14.00 273.23 MWD 13129.87 93.60 73.57 6483.10 -5162.08 8680.08 5954187.74 569391.99 9096.95 14.00 273.02 9 13150.00 93.64 76.39 6481.83 -5156.87 8699.48 5954193.10 569411.34 9115.82 14.00 89.00 MWD 13175.00 93.69 79.90 6480.23 -5151.75 8723.89 5954198.42 569435.71 9139.70 14.00 89.18 MWD 13200.00 93.72 83.41 6478.62 -5148.13 8748.57 5954202.24 569460.36 9163.97 14.00 89.40 MWD 13225.00 93.73 86.92 6476.99 -5146.03 8773.42 5954204.54 569485.19 9188.54 14.00 89.63 MWD 13250.00 93.74 90.42 6475.36 -5145.45 8798.36 5954205.32 569510.12 9213.33 14.00 89.86 MWD 13275.00 93.72 93.93 6473.74 -5146.40 8823.28 5954204.58 569535.05 9238.25 14.00 90.09 MWD 13300.00 93.70 97.44 6472.12 -5148.87 8848.11 5954202.31 569559.89 9263.19 14.00 90.31 MWD 13325.00 93.66 100.95 6470.51 -5152.85 8872. 73 5954198.52 569584.54 9288.07 14.00 90.54 MWD 13350.00 93.60 104.45 6468.93 -5158.33 8897.07 5954193.23 569608.92 9312.79 14.00 90.77 MWD 13354.87 93.59 105.14 6468.63 -5159.58 8901.77 5954192.03 569613.63 9317.58 14.00 90.99 10 13375.00 93.54 102.31 6467.37 -5164.34 8921.28 5954187.42 569633.18 9337.43 14.00 269.00 MWD 13400.00 93.46 98.81 6465.85 -5168.91 8945.81 5954183.05 569657.74 9362.27 14.00 268.82 MWD 13425.00 93.37 95.30 6464.36 -5171.98 8970.57 5954180.19 569682.52 9387.20 14.00 268.61 MWD 13450.00 93.26 91.80 6462.91 -5173.52 8995.48 5954178.84 569707.44 9412.15 14.00 268.40 MWD e BP-GDB e Baker Hughes INTEQ Planning Report .ii. .... INTEQ 13475.00 93.15 88.29 6461.51 -5173.54 9020.43 5954179.02 569732.39 9437.01 14.00 268.20 MWD 13500.00 93.02 84.79 6460.17 -5172.04 9045.35 5954180.73 569757.29 9461.70 14.00 268.00 MWD 13525.00 92.88 81.29 6458.88 -5169.01 9070.13 5954183.95 569782.04 9486.12 14.00 267.81 MWD 13550.00 92.73 77.79 6457.66 -5164.48 9094.68 5954188.68 569806.55 9510.18 14.00 267.63 MWD 13575.00 92.57 74.29 6456.50 -5158.46 9118.91 5954194.90 569830.73 9533.80 14.00 267.46 MWD 13579.87 92.54 73.61 6456.28 -5157.11 9123.59 5954196.29 569835.40 9538.34 14.00 267.30 11 13600.00 92.46 76.43 6455.40 -5151.91 9143.01 5954201.64 569854.78 9557.24 14.00 91.50 MWD 13625.00 92.36 79.93 6454.35 -5146.80 9167.45 5954206.96 569879.18 9581.14 14.00 91.62 MWD 13650.00 92.25 83.43 6453.35 -5143.18 9192.17 5954210.77 569903.86 9605.45 14.00 91.77 MWD 13675.00 92.13 86.93 6452.39 -5141.08 9217.06 5954213.07 569928.73 9630.06 14.00 91.91 MWD 13700.00 92.00 90.43 6451.49 -5140.50 9242.03 5954213.85 569953.69 9654.89 14.00 92.04 MWD 13725.00 91.86 93.93 6450.65 -5141.45 9266.99 5954213.10 569978.66 9679.84 14.00 92.17 MWD 13750.00 91.72 97.43 6449.87 -5143.93 9291.86 5954210.83 570003.54 9704.82 14.00 92.29 MWD 13754.87 91.69 98.11 6449.73 -5144.58 9296.68 5954210.21 570008.37 9709.69 14.00 92.40 12 13775.00 91.39 95.31 6449.19 -5146.93 9316.66 5954208.02 570028.37 9729.79 14.00 264.00 MWD 13800.00 91.02 91.82 6448.66 -5148.49 9341.60 5954206.67 570053.32 9754.78 14.00 263.92 MWD 13825.00 90.64 88.34 6448.30 -5148.52 9366.60 5954206.83 570078.31 9779.68 14.00 263.85 MWD 13850.00 90.26 84.87 6448.10 -5147.04 9391.55 5954208.52 570103.25 9804.41 14.00 263.80 MWD 13875.00 89.88 81.39 6448.07 -5144.05 9416.36 5954211.71 570128.03 9828.87 14.00 263.77 MWD 13900.00 89.50 77.91 6448.20 -5139.56 9440.95 5954216.40 570152.58 9852.97 14.00 263.77 TO e BOP-Tree e KB Elevation Well Rig Floor IM®®Þ~¡ :;·:WÆijWìÞ~1þ~¡p#i;$i~MMbG~$~$M:¡¡J¡¡M{: _ Il;m!!m!j!!!!?1~1!f?ßíi1l1mt111~11 :::;::::::;::::;:::;::::::::::::::. li;:j!1§~::$.Q9Q:IiMB*~Mi::;:;:··1 Itt4r.wtji!L.v~ .... ~~~~~;li~~II~I.~:¡ill:¡I::I:¡ Swab Valve Tree Size SSV Master Valve Base Flange Page 1 KRU 1 D~30L 1 Pro -Oil SFD · e TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-611252 131 "Mastercard Check" i'''',Ç"1 C\U -["À-f DATE LJC) - '; ,J ¡ ~~~JRO¿FHE t~ ,gQQ~I/~CC I $ {OO. ðO (")1\ Q '~Y0)\Or£) Cr~¿; U~IÍ U'r:r·--""'~=~~~=~î:X}L'i.~RB~-~_·'4 '-" First National Bank Alaska Anchorage, AK 99501 MEMO \ D-30 L I 1:.25 2000[;OI:qq .1.111[; 2 27111.55[;". 0.:1. · e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER /¿,E?u. / Þ:30L / WELL NAME PTD# 2QC¡ - / C/S- v Exploration Stratigraphic Development Service CHECK WßA T ADD-ONS ~'CLUE". APPLffiS (OPTIONS) MULTI Tbe permit is for a new weJlbore segment of LATERAL existing weD 1< .et{, j:D ~~ l... I vi' Permit No,Zóo '~/ötf API No. 50 d"D'Z.1.- ZZ q/= (1f API number Production. sbould continue to be reported as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .. and API Dumber (50 - 70/80) from records, data and logs acquired for weJl (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample intervals tbrough target zones. S"-6D KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 D-30L 1 Program DEV Well bore seg ~ ALASKA INC Initial ClasslType ----DE~END GeoArea 890 Unit 11160 _ On/Off Shore On Annular Disposal 0 Administration P~rmit fee attache.d .. Yes - - ~ - - - - - - - - - 2 Leas~ .number .appropriate. . - - - - -- - - - - - Yes. Surface Ipcation in APL .0256.50,lA'e]l pas$e~ through AOL. 02566.1, tpp pr.od inte.rv:al 8< TD in.AOL. 026248 . . 3 .U.nique weltn.arn~.a!1d oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s. . SpaCi!1g E:~Cception NP.T.required.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Well JQcat~d in.a define.dpPQI. .Y~s. Kup.aruk River Qil PQol, gQv.emed by CQn.servattoo Ord.er I\IQ. 4326 - - - -- 5 WeJlJocated prpper .distance. from driJlinQ unitb.pundjl(y. . . .Yes. . l\IeaJest Qwnership.&.landpwlJe.rshipchangejs.": 4,8QO' away. betlA'eeo ADL 028248 & Sec. .32.. . . . . 6 WeJI JQcated prpper .distance. from Qther wells. . . . - - - - - Yes TQP.ofthe productive inte(Va'.lA'ill be. - 3,QOO .feet awayfrornthe pool QpeoedJIJ the KRU.1 D~32wel! bQre.. . . 7 .S.ufficient jlcreage.ayailable in. dJilJiog unit · .Y~s I?rp~imalpprtion Qf. KßU 1 0-30l11A'ill be a '~bJanchnof KRU.1D-30, the PlJly prpdu.cing well in. NW£40f Sec.. 3 8 Jf.deviated, is. weJlboJe platincJu.ded . - - - - -- Yes Distatportipo ofKRU 1Q-30L1 will.bethe.only pro.ducing. weJI in.the I\IE:/4 .of section 30.. 9 .Operator only affected party. - - - - - - - - - .Yes - - - - - - - - - - - -- 10 .Operator has.apprppriate.bond in.fQrce . . . . . . . . . . . . . . . . . . . . '.. . . . .. .Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 11 Pe[l1")it c.a!1 be issued without conservation Qrder. . - - - - - - - - - - .Yes - - - - - - - - - - Appr Date 12 Permit c.a!1 be issued without admilJistratÍlle.apprpvaJ . . . . .NA SFD 8/5/2004 13 Can permit be approved before 15-day wait NA e 14 Well JQcated within area and.strata .authQrized by.l!1jectiPIJ Order # (Put 10# in.cpmrneots). (FQr. NA - - - - - - - - - - - -- - - - - - - - 15 .AJI wel)s. withtn .1 £4. llJile.area.of review ideotified (Fpr se.rv:jCcewel! only). . . . . . . . . . . . . . . NA. - - - - -. - - - - - - - - - - - - . - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 16 .Pre-produced. i!1jectQr; .dur~tiQn.of pre-productiplJ I~Ss. than :3 months (FQr.se(VLce well QnJy) . . .NA. - - - -- - - - - - - - - 17 .ACMP finding .of Con$i$te!1cyhas been js.sued. forthis proiect. . . NA Lateral from.e1<isting .wel.!.. . - - - ~ - - - - Engineering 18 .C.Qodu.ct.or s!(ing.pJovided . . - - - - NA CQn.ductQr .string set in. QrigoaJ welt !d-.30.. . . 19 .Surface .ca~ingpJQtec.ts. alLknQwn USQWs . - - - - NA 811 aquifers exempted 40 cm 147. 1.02 (b)(3), . . - - -- 20 .CMTvotadequate.to circ.utate.on.conductor& SUflCSQ . NA Surface ca$iJ1g set .aod cemented to. s.urfaceJn original. well. - - - -- 21 .CMT v.ot adequateto tie-LnJQng .string to surf csg. . . . . . . No WeIJ was. perllJitted. for.AQ. . - - - - - 22 .CMTwill coyer.all klJownpro.ductiye hQrilon.s. . . . - - - - - No. SlottedJioer ptao, lJe.d .7" casjng.tQp set and.cemented.. .3-1/2" Jioer fully ceme.nted.. . . 23 .C.asiog desigos adequa.te {or C,t, B&permafr.ost . . - - - -- . . . .Yes - - - -- - - -- - - - - - - - - - - - - 24 Adequ~te.tan.kage.oJ re.serve pit. - - - - - - - - - - - - - Yes Rig is Etquippe.dwith stee'-pits.. No. resEtrve.pjtpla!1lJed, All waste to.apprppriate.djsposaJ welt. 25 .If.a.re-drilt has.a. 10-403 for abandQnme.nt beeo apPJQved . - - - -- .. No. Original co.mpletiQn. ioterva'-wilt not be. abaod.oned.. . - - - - -- - - - - - - - - - - 26 Adequ~te.lA'eIlQore separatio.n.pro.posed. . . . . . . . . . . . . _ . . . . . . . . . . . . . .Yes l\IeaJest wellþQre is.llJo.tlJeJ bQre.. . . . . . . . . . . . _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . 27 Jf.diverter Jeq.uiJed, dQes it meet reguJatiOlJs. . - - - - -- NA BOp wiJI.be in.p.lace.. . - - - - - - - -- - - - -- Appr Date 28 .DJilliog fluid. prQgram sc.hematic.& eq.uip Jistadequate. . . ... Yes BI::iP expected at8,0.ppg EMW.l'lanJ1ed MW8.7. PP.9pJu.scircuJation frictipo . . . - - -- TEM 8/6/2004 29 .BPPEs,d.ojhey meet reguJation . - - - - - - -- · .Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e JiPr'1 30 .BOPE.PJess ratiog appropriate; test to .(puj psig Ln .comments). .Y~s M8SP calc;uJate.dat 2026 psi, CP.ð.L plans to testBOI? to.4500 psi. - - - - - 31 .C.hoke.manifQld cQmpJies. wIAI?LRI'-53 (May 84>. . . . - - - - Yes - - - - - - - - - - -- 32 Work wi]l pCC.ur withputoperatioJ1.shutdown. . . . . . . . . . Yes - - - - 33 .Is presence Qf H2S gas prQb.able. . . . . . . . . . . . . . . .Yes 1::i2S measured at 7..0.pprn.ilJ motherbore.. Mud should preçlude.1::i2S. Qnthe ri~ .Rig ha.ssensprs.and alarms, 34 MeçhaJlicaLcondjUo!1 p{ WEtIlS wLthin 80R yerified. (For. s.ervice weIJ Qnly) . · .NA - - - - - - - - - ~ - - - Geology 35 Permit cao be issued w/o. hydrogen. s.ulfide meas.ures. . - - - - - · No 1::i2S measur.es re~uired .as KRU.1 D~3P .mejlsured. 7..0 ppm HZ.8.o.n .8/2.8£2003. . . 36 .D.ata.PJeselJted. on. pote.ntial pveJpres.s\,Jre .zone$. . . . . - - - - - ... Y~s Expected resel"\loir pre.sSUJe i$ .8,Oppg EMW; wil'-be .drilled .with coiled. tubiOg an.d. 8.7ppg mud.. Appr Date 37 Sei$mic.analysjs of slJallow gas.zooes. . . .NA SFD 8/5/2004 38 .Seabedconditioo SUl"\ley(if Qff-sh.ore) . . . . .NA. - - - - - 39 . Contact name£phQnefor.weelsly prpgress.reports [exploratp(yonly] NA - - Geologic Date: Engineering Date Public Date Commissioner: Commissioner: ~mer ð)'s ~/6J 1- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infonnation. . . OCT 2~·.·~i }OO¡:¡· f ," ~"'- ..¡J **** REEL HEADER **** MWD 05/10/05 LIS Customer Format Tape {f )) >ul ./ ~ ð ~....) </.5 BHI 01 **** TAPE HEADER **** MWD 05/10/05 747378 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: Idwg .las +-Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11672.0000: STOP.FT 13710.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY . COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 23 TOWN. N llN RANG. 10E PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 105.3 DMF KB EKB .F 105.3 EDF .F N/A EGL .F N/A CASE.F 11710 OSl . DIRECTIONAL -Remarks (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 Coiltrack downhole tools and the Advantage surface system to log this well. 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. 1D-30L1 Kuparuk River Unit 70 deg 17' 57.509" N, 149 deg 30' 31.115" W North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 06-Sep-04 500292296560 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 . . (5) Tools run in the string included Casing Collar Locator, an Electrical Disconnect and Circulation Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit), a Gamma and Directional Sub, and a Hydraulic Orienting Sub with a near bit inclination sensor. (6) The interval from 13682' MD (6429.0' SSTVD) to 13710' MD (6428.7' SSTVD) was not logged due to sensor to bit offset. (7) The side track was drilled from 1D-30 through a milled window in 3 1/2" tubing. Top of window 11710.3 ft.MD (6404.7 ft. TVD) Bottom of window 11715.3 ft.MD (6406.9 ft. TVD) (8) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips instructions, the MWD Gamma Ray is the PDC for this borehole. (9) Tied to 1D-30 at 11696 ft.MD (6398.3 ft.TVD) MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 63 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT 1d-30L1 5.xtf 150 ConocoPhillips Alaska Inc. 1D-30L1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the MWD Gamma Ray is the PDC for this borehole. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 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 2 1 1 AAPI F/HR 4 4 4 4 GR ROP MWD MWD 68 68 ------- 8 Total Data Records: 49 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11672.000000 13710.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 58 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT Id-30L1.xtf 150 ConocoPhillips Alaska In ID-30Ll Kuparuk River Unit North Slope 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 ROPA ---------------------------------------------------- 0.0 0.0 GRAX ROPA GRAX ROPA * 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 2 GRAX MWD ROPA MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 98 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11672.000000 13709.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 107 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/10/05 747378 01 **** REEL TRAILER **** MWD 05/10/05 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subfile 1 is type: LIS . . Tape Subfile 2 is type: LIS DEPTH 11672.0000 11672.5000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13200.0000 13300.0000 13400.0000 13500.0000 13600.0000 13700.0000 13710.0000 GR 115.8600 116.5400 60.2300 77.7000 70.1400 60.0400 80.5900 89.6900 89.2800 88.1900 94.1950 66.4100 72.2200 65.1500 71.2400 59.7000 61.5000 66.4400 64.4000 84.4900 98.4550 100.6900 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . . ROP -999.2500 -999.2500 -999.2500 55.2400 34.3000 92.6500 86.8200 91.2700 100.8100 129.9600 125.7200 121.5400 49.1000 107.2000 91.7600 67.6700 86.6600 110.9300 92.4500 13.6800 13.8300 85.1000 117.0200 -999.2500 11672.000000 13710.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPA 11672.0000 115.8600 -999.2500 11672.2500 115.2500 -999.2500 11700.0000 60.2300 -999.2500 11800.0000 77.7000 55.2400 11900.0000 70.1400 34.3000 12000.0000 60.0400 92.6500 12100.0000 80.5900 86.8200 12200.0000 89.6900 91. 2700 12300.0000 89.2800 100.8100 12400.0000 88.1900 129.9600 12500.0000 94.1950 125.7200 12600.0000 66.4100 121.5400 12700.0000 72.2200 49.1000 12800.0000 65.1500 107.2000 12900.0000 71.2400 91.7600 13000.0000 59.7000 67.6700 13100.0000 61.5000 86.6600 13200.0000 66.4400 110.9300 13300.0000 64.4000 92.4500 13400.0000 84.4900 13.6800 13500.0000 98.4550 13.8300 13600.0000 100.6900 85.1000 13700.0000 -999.2500 117.0200 13709.7500 -999.2500 -999.2500 Tape File Start Depth 11672.000000 Tape File End Depth 13709.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet Tape Subfile 4 is type: LIS . .