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Home My WebLink About205-045 · . 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. aD5. - 0 lj5 Well History File Identifier Organizing (done) D Two-sided ""'11111111"111I D Rescan Needed '" II 11111111 II 1111 RES CAN ~Ior Items: ~reYSCale Items: ~ ~ D Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date :Ç~D/()7 D Other:: BY: ~ /5/ mP Oate6~O 107 / x 30 = 3D + oa,e?;;-/30/07 11111111/1111' ,,11/ Project Proofing BY: ~ /5/ mp Scanning Preparation BY: éMaria ) dv{) = TOTAL PAGES SD P (Count does not include cover sheet) I\M /5/ r ' I 1111/111111111 "III Production Scanning Stage 1 Page Count from Scanned File: 5 I (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ~ oateS/30JD7 If NO in stage 1, page(s) discrepancies were found: YES NO Stage 1 /5/ wvr NO BY: BY: Maria Date: /5/ /IJ 1111111111I1111I Scanning is complete at this point unless rescanning is required. ReScanned 1111/11111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked III "1111111 "11111 1 0/6/2005 Well History File Cover Page. doc ;Lc)~ DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2050450 Well Name/No. KUPARUK RIV UNIT 1B-13L2 Operator CONOCOPHILLlPS ALASKA INC S¡· Vl¿ I t.f !).p ~ f API No. 50-029-22468-61-00 MD 9503 --' TVD 6497 / Completion Date 4/20/2005·"'- Completion Status 1-01L Current Status 1-01L ~,.,.",.._~-_.- '~. ~~~C ..~ C t:~,A-- . .. REQUIRED INFORMATION Mud Log No Samples No Directional surv~ - <::, ~._-~. DATA INFORMATION Types Electric or Other Logs Run: MWD, GR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name v€D C 14020 Induction/Resistivity ~;. 14020 LIS Verification :,Gg 14020 Gamma Ray ¡.;(og 14020 Gamma Ray (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval Start Stop 7364 9503 - OH/ CH Open Received Comments 8/14/2006 LIS Verication w/Graphics and Image Files~ LIS verification ~ 25 Blu 25 Blu 7364 9503 7364 9503 7364 9503 Open Open Open 8/14/2006 8/16/2006 8/16/2006 GR 19-Apr-2005 ~ GR 19-Apr-2005 ~ L~______,__.__ --~---,~,--- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION J!. ., ì..r- ~ Daily History Received? Q-K Çþ -- Well Cored? .-" Chips Received? Y / N Formation Tops Analysis Received? WN -,---~-- Comments: Compliance Reviewed By: ~ Date: ;2<; ~~7 . Transmittal Form INTEQ To: . '&ill BAKER HUGHES Anchorage GEOScience Center AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: RECE\VEO AUG 1 4 20G6 ('pt\I\'issiOIl Alaska Oil & Gas cons. Ânc\1orat.1 Robin Deason Reference: IB-13L2 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 878703 Sent By: Deepa Joglekar /) / Received By: cJ c ~/L-- Date: Aug.l0,2006 Date: ~«1()0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 CJt [j6S- -()L£ 5~ /(;080 rr==::---::_:::::=--=.:::.::.-::-'- ~'II.'.Utlf!(!II f--o;"~='l ,".,1:·';' _'EC _ .. "" ,",., : .. '. i~.i :;: .-.;~ ... ,...( ....., ~-~-_. -;;;~~~~-~~-:~. ,..... ."r _ . " d. ,_. .... ""1"''''''''''., -~ -- .. .' .'.... .'~... '::'-'~---:::-::--;'~~:-;'.. ,.. ," I :~=~:::-'::-~'~J i¿1:~,!Üá }... ·t·.'·'__ f\ IE D. "f . _ STATE OF ALASKA .. ALAS~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG MÞ,y 2 5 2005 1a. Well Status: IS! Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 499' SNL, 605' WEL, SEC. 09, T11 N, R10E, UM Top of Productive Horizon: 1166' SNL, 3934' WEL, SEC. 09, T11N, R10E, UM Total Depth: 756' SNL, 427' WEL, SEC. 08, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549~±__ y- 5969647 Zone- ASP4 TPI: x- 546511 y- 5968959 Zone- ASP4 Total Depth: x- 544736 y- 5969358 Zone- ASP4 __~______n__~___________ ______________________n_. ______________________ 18. Directional Survey IS! Yes 0 No 21. Logs Run: MWD, GR One Other 5. Date Comp., Susp., or Aband. 4/20/2005 - 6. Date Spudded 4/14/2005 '< 7. Date T.D. Reached 4/19/2005 8. KB Elevation (ft): 102' 9. Plug Back Depth (MD+ TVD) 9503 + 6497 10. Total Depth (MD+TVD) ,,9503' + 6497 11. Depth where SSSV set 1908' MD 19. Water depth, if offshore N/ A MSL CASING SIZE 16" 9-5/8" 7" x5" 2-3/8" GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE Top BoTTOM Top BoTTOM SIZE Surface 121' Surface 121' 24" Surface 4540' Surface 4070' 12-1/4" Surface 7367' Surface 6403' 8-1/2" 7336' 9489' 6378' 6494' 3" 22. WT. PER FT. 62.5# 40# 26# /18# 4.6# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-3/8" Slotted Section MD TVD MD TVD 7622' - 9476' 6542' - 6492' 26. Date First Production: April 23, 2005 Date of Test Hours Tested PRODUCTION FOR 5/16/2005 20:42 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 212 1,251 24-HoUR RATE 24. SIZE 3-1/2",9.3#, J-55 e Üt t~rh::..ni~e 1b. Well Class: . IS! Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 205-045 13. API Number 50- 029-22468-61-00 14. Well Name and Number: KUP 1B-13L2 15. Field / Pool(s): Kuparuk River Unit Ft 16. Property Designation: Ft ADL 025647 17. Land Use Permit: 20. Thickness of Permafrost 1670' (Approx.) -í/t():-£r..d ~K) ? 3';'"1' m.D ¿~ c.(o 3' 'fr c> ,4 5" 2.<;0 'i CEMENTING RECORD 200 sx Arcticset I 920 sx AS III, 420 sx Class 'G' 350 sx Class 'G' Uncemented Slotted Liner AMOUNT PUllED TUBING RECORD DEPTH SET (MD) 7132' PACKER SET (MD) 7094' 25. ACID, FRAÇTURE, CEMENrSauEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7363' Set whipstock Freeze Protected w/ Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Oll-BBl GAs-McF WATER-BBl 1 ,584 3 454 Oll-BBl GAs-McF WATER-BBL 1,854 3 532 27. CHOKE SIZE I GAS-Oil RATIO 35/64" 1746 Oil GRAVITY-API (CORR) 22.4 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". ---':iTl ~ COMPLETìON\ None RBDMS \ DÞ,TE¡ BFL MA Y 2 5 Z~. r \ ~E~~;;~~'\ ¡ j t ~.__.~ '1 "--"i' t......... L".,..,-"",.',.,..",~..··...T---·+ Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE GF' 28. GEOLOGIC MARKE. NAME MD Kuparuk 83 7398' Kuparuk 82 7440' Kuparuk 81 7485' Kuparuk A6 7553' Kuparuk A5 7570' Kuparuk A4 7620' Kuparuk A4 8010' 29. .ORMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 6427' None 6457' 6486' 6519' 6525' 6541' 6543' 30. List of Attachments: Summary of 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. ~",,' W flU T erne Hubble /" [0 III' 0 .l , , X1'f.J\l¿ KUP 18-13L2 205-045 Well Number Title Technical Assistant Date OS /~Lf los Permit No. I Approval No. INSTRUCTIONS Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Aras Worthington, 240-5780 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only . . Well: Field: API: Permit: 1 B-13L1 / L2 Kuparuk River Unit 50-029-22468-60 /61 205-044 & 205~045 Accept: Spud: Release: Rig: 04/04/05 04/07/05 04/20/05 Nordic #2 PRE-RIG WORK 03/24/05 PULLED 2.81" WRDP-4E, 9'2", SERIAL#HYS-545, RUN SBHP GAUGES TO 1 ST STOP AT 7398' MD (2028 PSI 160 DEG), 30MIN., 2ND STOP 15 MIN 7273' MD (1986 PSI), PULL STA# 1,2,4 AT 2641', 4361',6386' RKB, SET DMY AT STA# 2 4361' RKB. RESUME IN AM, LDFN. 03/25/05 SET STA# 1, 4 DMV AT 2641', 6386' RKB, SET CA-2 2.75" TIP AT 7115' RKB, PULL OV AND SET DMV AT 7048' RKB AFTER LOADING TUBING AND lA, MITT 3000# (GOOD), MIT lA, 2500# (GOOD) PULL TTP AT 7115' RKB. 03126/05 PUMP 2-45BBL CAC03 PLUGS TO SQUEEZE PERF CHANNELS. UNSUCCESSFUL, WELL ON VACUUM. NO SQUEEZE PRESSURE COULD BE OBTAINED. 03/30/05 TAGGED AT 7339' RKB. PLUGGED C-SAND PERFS FROM 7,218' - 7,278' WITH 19.6 BBL PILL OF 12 PPG ROCK SALT PILL. PUMPED 30 BBLS OF DIESEL FLUSH AT 4.5 BPM W/2,200# IWHP. LOWERED INJECTION RATE TO .5 BPM. PERFS INITIAL SIGNS OF PLUGGING OFF AT 35 BBLS FLUSH AWAY. PUMPED A TOTAL OF 45.7 BBLS DIESEL FLUSH WITH A MAX PRESSURE OF 3850#. TOP OF PILL APPROX. AT 5352' MD. 03/31/05 GAUGED TBG WITH 2.5" CENT & 1.75" SAMPLE BAILER. TOOLS SLOWED AT 5880'; MAKING 2 FPM AT 6824' RKB WITH NO SPANG ACTION. RECOVERED SAMPLE, VERY THICK FLUID. 04/02105 CLEANED OUT ROCK SALT TO 7339' CTD WITH DIESEUDIESEL GEL. FOLLOWED WITH C-SAND 'INJECTIVTY TEST OF 0.7 BPM AT 2500#. LAYED IN 24 BBLS OF 9.8 PPG CALCIUM CARBONATE, SQUEEZED 4.5 BBLS AT 1600# INTO C-SAND PERFS. COMPLETED JOB BY CLEANING DOWN TO HARD TAG/OBSTRUCTION AT 7518' CTD WITH DIESEUDlESEL GEL. . . BP EXPLORATION Operations Summary Report Page 1 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 1 8-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/3/2005 20:30 - 00:00 3.50 MOB P PRE Hold PJSM with rig hands, security, tool service hands. Back rig off Z-22B. Move camps from Z to 1B Pad. Prep to move rig. Problems with #2 hydraulic moving system pump. Call for Nordic 1 electrician. Trouble shoot control circuits. 4/4/2005 00:00 - 03:30 3.50 MOB P PRE Continue to trouble shoot hydraulic pump #2 electrical circuits. Pump will start but will not keep running for more than a few seconds. Suspect electrical short or break somewhere in power control circuitry. 03:30 - 06:00 2.50 MOB P PRE Move off Z pad on to Spine Road. Head towards KRU. 06:00 - 11 :00 5.00 MOB P PRE Rig on spine road at V pad tumoff at 06:00. 11 :00 - 12:00 1.00 MOB P PRE Rig on spine road at 1 D pad in Kuparuk at 11 :00. Recieve handover of well from CPF1 PE, Ryan Dunn. 12:00 - 12:30 0.50 MOB P PRE Rig arrives on 1 B pad Kuparuk. Move rig down pad, and spot in front of well 1 B-13. Hold pre rig pad inspection with 1 B pad operator. 12:30 - 13:45 1.25 RIGU P PRE Hold pre spud meeting with rig crew, mud man, rig management team, and Arus Worthington of CPAI. Also hold PJSM for moving over well. 13:45 - 14:15 0.50 RIGU P PRE Spot herculite around wellhead. Prepare to move rig over well. Accept rig at 1400 hrs on 4/4/05 14:15 - 14:45 0.50 RIGU P PRE Move rig over weIl1B-13. Adjacent well1B-04 is shut in. 14:45 - 16:45 2.00 BOPSUB P PRE Knock off swab cap, NU BOP stack. Brace BOP stack to 4 corners of the cellar with chain binders to ensure stack is vertical and secure against movement. 16:45 - 17:00 0.25 RIGU P PRE PJSM prior to picking up reel. 17:00 - 18:00 1.00 RIGU P PRE Pick up reel of E-coil into reel house. 18:00 - 19:00 1.00 RIGU P PRE Hold pre spud mtg with all hands and A. Worthington. Review well plan, hazards, H2S, contingencies and more. 19:00 - 21 :30 2.50 RIGU P PRE RU kill line. Modify mousehole. Spot and RU flow back tanks (tiger & open top.) RU KWF and extra upright mud tanks on location. Change variable rams to 2-318" combis. 21 :30 - 00:00 2.50 RIGU P PRE Rig up hard line choke in cellar to replace flex shock hose. Take on 450 bbls 9.2 ppg flopro and 220 bbls 12.8 ppg formate KWF. 4/5/2005 00:00 - 03:30 3.50 RIGU P PRE Continue to RU choke hardline in cellar. RU hard line and J box insidel reel. Install lubricator to BOPs. Remove old slickline from spooler. Install catch pools around well head. 03:30 - 06:00 2.50 RIGU N RREP PRE Body and function test BOPs. Ram door leaking. Replace seal. Test again. Lubricator leaking. Replace o-rings. 06:00 - 07:30 1.50 BOPSUF N RREP PRE Perform body test again. 2 leaks from graytock fittings. Tighten same. Repeat body test. graylock fittings still leaking. This rigup needs discussion and changes. We've been messing with it since 21 :30 last night. Shut down work on BOP's. Work on other rig up tasks. 07:30 - 08:15 0.75 BOPSUF N RREP PRE Change work assignernent for rig crew. Abort further work on BOP's until we can make morning call. Work on making up SL lIubricator and SL unit. 08:15 - 14:30 6.25 BOPSUF N RREP PRE Change out part of graylock hardline in cellar. Reinstall 3" shock hose and a portion of graytock fittings from Choke side HCR to shock hose. Continue to rig up SL spooler unit. Re-build HCR on kill side. 14:30 - 15:30 1.00 BOPSUF< P PRE Fill stack with water for body pressure test. Tighten a few Printed: 4/25/2005 10:06:43 AM . . BP EXPLORATION Operations. Summary Report Page 2 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/5/2005 14:30 - 15:30 1.00 BOPSUP P PRE fittings and stop leaks. Body test to 4500 psi good. 15:30 - 20:00 4.50 BOPSUF P PRE Begin BOP test. Witness waived by J. Jones. 20:00 - 21 :30 1.50 RIGU P PRE MU lubricator assy w/ slickline head 21 :30 - 23:30 2.00 RIGU P PRE PU injector and prep. Install internal grapple and PT. Pull CT to floor and stab. Replace packoff. Cut off CT to find good round pipe. Stab onto lub 23:30 - 00:00 0.50 RIGU P PRE Rev circ while fill CT w/ fresh water over closed swab at 0.5 bpm 4/6/2005 00:00 - 04:00 4.00 RIGU P PRE Continue rev circ filling CT w/ FW at 0.5 bpm. Increase rate to 2.7/4000 psi for one CT vol. Check for slack and none. Repeat at 2.8/4300 psi. Cut off 22' CT before finding end of wire 04:00 - 07:00 3.00 CLEAN P WEXIT Dress CT stub. Install Kendall CTC and BHI connector and test. PT 35k, prs test to 4000 psi. Ok. Set injector over bung hole. Circulate. 07:00 - 07:45 0.75 CLEAN P WEXIT Hold PJSM to review Pressure Deployment procedure. Review procedure step by step. Assign tasks and positions. Discuss hazards and contingencies. Deployment will be live as well has 400-600 psi at surface. 07:45 - 08:30 0.75 CLEAN P WEXIT Complete slack management by circulating forward 2 coil vol at 1.6 bpm. 08:30-11:15 2.75 CLEAN P WEXIT Pressure deploy BHA #1 (straight mtr w/2.74" DSM). Find 475 psi on well head. PU two 3' sections of lubricator. 11:15-13:15 2.00 CLEAN P WEXIT RIH. Hold 600 psi WHP. Begin swap to mud while RIH. HOld 500 psi WHP while circ at 0.54 bpm. 13:15 - 13:45 0.50 EVAL P WEXIT Log gr tie in from 7180' to 7230'. Minus 21' correction. Baker tested fast data rate which allowed 600 fph vs 300 fph logging speed. Faster rate worked well. 13:45 - 16:00 2.25 CLEAN P WEXIT Clean out to 7536'. 3750 psi @ 1.57 in/1.35 out fs. Never saw any fill or debris. POOH and monitor shakers. Some sand, no debris. POOH at 10 fpm up to tbg tail at 7132'. 16:00 - 16:30 0.50 CLEAN P WEXIT Hold PJSM with crew inOps cab to review pressure un-deploy procedure. 16:30 - 16:45 0.25 CLEAN P WExrt Monitor well for flow-sli loss. 16:45 - 18:30 1.75 CLEAN P WEXIT Pressure un-deploy BHA #1. LD motor and mill-both in same condition as run 18:30 . 19:20 0.83 STWHIP P WEXIT MU WS assy w/ RA pips 7.35' below TOWS PVT 301 19:20 - 21:00 1.67 STWHIP P WEXIT RIH w/ BHA #2 (WS assy) 0.35/1400 thru EDC Reboot SWS PC after lockup at 5500' 21 :00 - 21 :40 0.67 STWHIP P WEXIT Log tie-in down from 7170' at 150'/hr to 7270' 0.31/0.27/1460 PVT 319 Corr -17' 21:40 - 21:55 0.25 STWHIP P WEXIT RIH to 7440' 21 :55 - 22:00 0.08 STWHIP P WEXIT Log collars down from 7380' to 7450' at 720'lhr 0.3/1480 and see 7404' and 7447' on depth 22:00 - 22:10 0.17 STWHIP P WEXIT PUH to set depth 20.2k while orient WS to 30R 22:10 - 22:20 0.17 STWHIP P WEXIT Close EDC while parked at 7423'. Pressure up to 2820 psi and tool stroked and pressure bled to 1530 psi at 0.36 bpm. PUH 20.2k for 15', clean. RIH w/o pump and stack 2k solid. PUH, clean PVT 317 Left TOWS at 7410', BOWS at 7423', RA tag at 7417.4' 22:20 - 23:30 1.17 STWHIP P WEXIT Open EDC. POOH for milling assy 1.0/2300 PVT 284 23:30 - 00:00 0.50 STWHIP P WEXIT LD WS setting assy and load out 4f712oo5 00:00 - 00:15 0.25 STWHIP P WEXIT Fin load out WS setting tools Printed: 4/25/2005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 3 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/7/2005 00: 15 - 00:50 0.58 STWHIP P WEXIT MU window milling assy PVT 284 00:50 - 02:25 1.58 STWHIP P WEXIT RIH w/ BHA #3 (2.74' window mill and 2.74' SR) 0.45/1380 PVT 306 02:25 - 02:50 0.42 STWHIP P WEXIT Close EDC. RIH 8k and tag at 7431' w/o pump. PUH w/2k overpull Start pump 1.5/1.27/3500 ECD 11.5 @ 3765 psi DHP. RIH looking for MW and found it at 7430.7'. Corr to 7412.8' (pinch point) which is -18' corr. Flag CT 02:50 - 05:00 2.17 STWHIP P WEXIT Begin milling window from 7412.8' 1.5/1.38/3500 ECD 11.5 PVT 284 05:00 - 06:00 1.00 STWHIP P WEXIT Mill from 7414.8' 1.48/1.45/3530 ECD 11.5 06:00 - 08:45 2.75 STWHIP P WEXIT Continue to mill ahead. 3732 psi at 1.48 in/1.46 out. 3756 psi /11.46 ECD BHP. IAlOAlPVT: 996/0/283 bbls. Bleed IA to 580 psi. Parted CT drill 08:45 - 10:45 2.00 STWHIP P WEXIT Through casing at 7419'. Drill formation to 7429'. Top Window: 7412.8 Btm Window: 7418.6' RA Tag: 7417.3' Make three back ream passes. Shut in 500 psi WHP (to get drilling BHA of 3750. Dry drift through window. 10:45 - 12:30 1.75 STWHIP P WEXIT POOH following constant BHP schedule. Paint white EOP flag at 7278'. Continue to POOH. Tag up. Shut in 650 psi WHP. 12:30 - 14:30 2.00 STWHIP P WEXIT Hold PJSM to review un-deploy proc. RIH 1.8'. Undeploy BHA. 650 psi WHP. WHP bled down to 200 psi in a few minutes. Continue un-deployment. Mill wear across entire face. Gauge between 2.73' to 2.74'. 14:30 - 17:30 3.00 DRILL P PROD1 MU orienter and test MWD tools. Pressure deploy build assembly. BHA will not fall through BOP stack due to high angle mtr. Bleed well to zero (from 120 psi). Open hole deploy BHA. 17:30 - 18:40 1.17 DRILL P PROD1 Run in hole with BHA #3 (2.8 extrem w. HTC bi-cent). Hold WHP/BHP as per schedule. 18:40 - 19:00 0.33 DRILL P PROD1 Log tie-in down from 7160' (while new crew practices with Swaco choke and Swaco hand is on location for adjustments). Corr -17' 19:00 - 19:20 0.33 DRILL P PROD1 RIH thru window at min rate and tag at 7432' CTD. PUH 18.5k and start pump 1.5/1.45/3380/30R ECD 11.4 RIH and tag at 7431' PVT 242 19:20 - 20:20 1.00 DRILL P PROD1 Drill build from 7431' 1.49/1.47/3380/40R ECD 11.39, DHP 3736 at usual slow progress initially PVT 239 20:20 - 21 :25 1.08 DRILL P PROD1 Drill from 7447' 1.53/1.51/34oo/60R ECD 11.41 at 15-30'/hr in shale. See RA tag at 7418+'. Drill to 7470' 21 :25 - 23:50 2.42 DRILL P PROD1 Drill from 7470' to 7513' in shale PVT 229 Kick while drilling drill (tabletop) 23:50 - 00:00 0.17 DRILL P PROD1 Wiper to tie-in due to 7' SWS and BHI depth difference Pull thru window, clean at min rate holding 3600 psi DHP w/ 250 psi on choke 4/8/2005 00:00 - 00:35 0.58 DRILL P PROD1 Log tie-in down from 7160' to tie-in to mother wellbore. Corr-7' (BHI on depth, SWS off depth) PVT 228 Add used mud to system 00:35 - 00:55 0.33 DRILL P PROD1 RIH, then log tie-in down from 7430' to RA pip to complete tie-in 0.4/1800 w/250 psi WHP, 3750 DHP See RA pip at Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operation~ Summary Report Page 4 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2005 00:35 - 00:55 0.33 DRILL P PROD1 7419' which is 1.7' deep from planned setting depth 00:55 - 01 :00 0.08 DRILL P PROD1 Fin wiper to TD, clean and tag at 7513' PVT 422 01 :00 - 04:00 3.00 DRILL P PROD1 Resume drilling from 7513' 1.46/1.42/3380/85R w/11.46 ECD, 3800 DHP at 20'/hr in shale PVT 415 04:00 - 05:10 1.17 DRILL P PROD1 Drill from 7580' at 30-50'/hr and then hit a hard spot. Drill to 7620' PVT 423 05:10 - 05:25 0.25 DRILL P PROD1 Have gained 8 bbls in last hour. PUH 20' and park. SI well w/ 600 psi to check DHP and had slow bleed off from 550 psi to 530 psi=3600 psi DHP. Determine new mud is being aired up by centrifuge-will shear after a circ or two 05:25 - 07:30 2.08 DRILL P PROD1 Drill from 7620' 1.4611.4613350/60R ECD 11.53, DHP 3850 w/ 100 psi diff, 3k wob at <10'/hr 07:30 - 09:45 2.25 DRILL P PROD1 Drill ahead from 7664'. 3275 psi fs at 1.46 in/1.145 out. 150-250 psi mw. BHP/ECD: 3850/11.49. IAlOAlPVT: 779/0/419 bbls. INC/AZ/TF: 63.5/2.77/45R. 09:45 - 10:15 0.50 DRILL P PROD1 Wiper trip to above window. Log tie in. _14' correction. Hole smooth. 10:15·14:00 3.75 DRILL P PROD1 Drill ahead from 7780'. I NC/AZ/TF: 93/19/180R. 416 bbl PVT. 3844 psi BHP/11.47 ECD. Turn TF straight down to break build tendency. This will cause well bore to swing wide of plan, but still well inside polygon. Dog legs in build averaged 45, dog leg in turn only +/-30 deg. 14:00 - 17:00 3.00 DRILL P PROD1 Drill ahead from 7845'. 3350 psi at 1.51in/1.51 out fs. 150-250 psi mw. INC/AZ/TF: 87.7/50.2/105R. WOB/ROP: 3-4k#/15-45 fph. IAlOAlPVT: 925/0/406 bbls. BHP/ECD: 3855/11.46 ppg. Continue to get 28 deg dogleg turn. ROP slowed to <5 fph. 17:00 - 18:25 1.42 DRILL P PROD1 POOH to check and adjust AKO. Maintain pressure as per schedule. 18:25 - 18:50 0.42 DRILL P PROD1 Park at 500'. SD pump w/600 psi induced on well. Close EDC Safety mtg re: pressure undeploy WHP bled to 350 psi in 25 min and continuing to bleed off 18:50 - 19:00 0.17 DRILL P PROD1 Fin POOH maintaining 500 psi PVT 366 19:00 - 20:00 1.00 DRILL P PROD1 Pressure undeploy w/ 500 psi initial, zero psi after 1 hour 20:00 - 20:30 0.50 DRILL P PROD1 Change motor bend and replace bit. Bit was 3-1-1 w/ chipped nose cutters 20:30 - 20:50 0.33 DRILL P PROD1 Safety mtg re: pressure deploy 20:50 - 22:20 1.50 DRILL P PROD1 Induce 500 psi WHP for practice deploy Pressure deploy drilling BHA. WHP bled to zero after 1 hour 22:20 - 23:45 1.42 DRILL P PROD1 RIH w/ BHA #5 (1.5 deg motor, HCC bi bit) to 200' w/ choke SI, WHP 200 psi. Open EDC. PVT 365. RIH at min rate following pressure schedule PVT 388 23:45 - 00:00 0.25 DRILL P PROD1 Close EDC. Log tie-in to RA pip from 7420', _2' corr (SWS changed out counter today) 4/9/2005 00:00 - 00:35 0.58 DRILL P PROD1 Precautionary slow ream 1.5/3240 at drilled TF to TD. Set downs at 7480' and 7580'. Tag TD at 7867' PVT 391 00:35 - 03:20 2.75 DRILL P PROD1 Drill from 7867' 1.46/1.4613230/150R ECD 11.46, DHP 3842 w/ 250 psi diff, 2.75k wob at 5-10'lhr @ 6467' rvD PVT 385 03:20 - 05:35 2.25 DRILL P PROD1 Drill from 7900' 1.45/1.43/3250/85R ECD 11.58, DHP 3885 w/ 250 psi diff, 1.75k wob at 45-65'lhr to 8020' PVT 381 05:35 - 07:00 1.42 DRILL P PROD1 Wiper to window. Hole smooth in and out. 07:00 - 09:15 2.25 DRILL P PROD1 Drilling ahead at 8050'. 3750 psi fs @ 1.65 in/1.67 out. WOB/ROP: 1.0k#/50 fph. INC/AZ/TF: 86.6/93.6I120R. IAlOAlPVT: 713/0/378 bbls. BHP/ECD: 3876/11.8 ppg. Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 5 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/9/2005 07:00 - 09:15 2.25 DRILL P PROD1 Getting up to 20 deg doglegs. Reduce WOB and increase pump rate to try and reduce doglegs. Swap to left at 8129' 09:15 - 10:00 0.75 DRILL P PROD1 Plow into 250 API+ gr shale. Short trip and call town to discuss directional plan. Hole smooth. 10:00 - 12:15 2.25 DRILL P PROD1 Drill ahead from 8150'. INC/AZfTF: 84.9/110.2/5L. Back up through shale. ROP varying from 15 to 150 fph. Swap to right at 8285' 12:15 - 13:45 1.50 DRILL P PROD1 Wiper trip to window. Log gr tie in. No correction. RIH. Bobbles at 7570-80'. Otherwise, hole was smooth. 13:45 - 16:00 2.25 DRILL P PROD1 Drilling ahead at 8300'. 3650 psi fs @ 1.57 in/1.56 out. 100-200 psi mw. WOB/ROP: 1.5k#/60 fph. I NC/AZfTF: 90.46/105.57/105R. INONPVT: 825/0/367 bbls. BHP/ECD: 3960/11.77 ppg. Drill to 8365'. Alternating slow and fast drilling. 16:00 - 18:00 2.00 DRILL P PROD1 Drilling ahead from 8365-8390'. Hard spot. PVT 362 18:00 - 21 :40 3.67 DRILL P PROD1 Back in good digging for a short time 1.58/1.58/80L ECD 11.89, DHP 4000 w/ 200-400 psi MW. Starting to drill w/ neg wt and will need mud swap before too long, but no vac trucks available .'. . Get on another hard spot at 8430' and spend an hour to get 5' PVT 370 due to centrifuge change 21 :40 - 22:40 1.00 DRILL P PROD1 Wiper to window, clean both ways PVT 368 22:40 - 00:00 1.33 DRILL P PROD1 Resume drilling on left side 1.5/1.5/3400/95L ECD 11.6, DHP 3900 w/1 00-300 psi diff, 1-4k wob. Drill more hard stuff to 8443'. Several 50' backreams and slow reams to dress 180 deg TF change in hard spot PVT 365 4/10/2005 00:00 - 03:00 3.00 DRILL P PROD1 Continue drilling on a hard spot from 8443' at 5'/hr w/ several 50' wipers PVT 361 03:00 - 04:20 1.33 DRILL P PROD1 Break out of hard stuff (ankerite) at 8458' and drilling 100'/hr w/ 300 psi diff, 1.3k wob w/ pos string wt 1.5211.5213440/85L ECD 11.7, DHP 3940 Drill to 8560' Solids increased ECD to 11.89 PVT 359 04:20 - 05:00 0.67 DRILL P PROD1 Wiper to window, start new mud. Hole was clean 05:00 - 05:10 0.17 DRILL P PROD1 Log tie-in down to RA pip from 7430'. Corr +2' 05:10 - 05:50 0.67 DRILL P PROD1 Wiper to TD, clean 05:50 - 08:00 2.17 DRILL P PROD1 Drill from 8560' w/ fresh mud 1.47/1.47/3200/100L ECD 11.37, DHP 3820 08:00 - 13:00 5.00 DRILL P PROD1 Drill ahead from 8585'. 3350 psi fs at 1.61 in/1.64 out. 200-300 psi mw. 3.5-4.0k# DHWOB. 10-15 fph ROP. INCUAZfTF: 86.4/91.0/270L. WHP/BHP/ECD: 44/3870/11.52 ppg. INONPVT: 649/0/338 bbls. Slow drilling. Wt transfer good. 13:00 - 15:15 2.25 DRILL P PROD1 Continue drilling ahead at 8670'. Drilled up and back down through shale in lower A5 zone. Swap to right at 8630' INC/AZfTF: 84.1/81.6/150R. 15:15 - 17:00 1.75 DRILL P PROD1 Wiper trip to window. Hole smooth on trip out. Had to work through tight spot from 8560'-80' while RIH. Reduced pump rate and coil speed. Bounced through. 17:00 - 18:00 1.00 DRILL P PROD1 Drill ahead from 8710'. 3500 psi fs at 1.61 in/1.64 out. 200-300 psi mw. 1.0-3.0k# DHWOB. 15-5Ofph ROP. INCUAZfTF: 84.9/84.8.0/150R. WHP/BHP/ECD: 46/3925/11.74 ppg. INOAlPVT: 791/0/332 bbls. Wt transfer good PVT 259 18:00 - 19:10 1.17 DRILL P PROD1 Drill ahead in another hard spot from 8740' PVT 257 Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operation~ Summary Report Page 60t 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description ot Operations 4/10/2005 19:10 - 19:20 0.17 DRILL P PROD1 Wiper to 8500' to check the A5. 5k overpull at 8605', no MW (top of BHA). 10k overpull at 8538' w/ MW 19:20 - 19:50 0.50 DRILL P PROD1 Wiper back to TD and set down twice at 8545' w/ 6k overpulls. Red rate to 1.0 bpm and get thru w/ no MW. Backream w/ 8k overpull and MW. RIH at 1.0 bpm thru 8545' to 8620', clean. Fin wiper to TD, clean PVT 255 19:50 - 21 :50 2.00 DRILL P PROD1 Resume drilling in hard spot from 8749' 1.49/1.47/321 0/60R ECD 11.38, DHP 3830 at <5'/hr PVT 251 Too slow of progress 21 :50 - 22:50 1.00 DRILL P PROD1 Wiper to window, 6k overpull and MW at 8535'. Rest of hole was clean. Pull thru window at min rate, then wipe 5' liner thru bit at 1.5 bpm 22:50 - 23:50 1.00 DRILL P PROD1 Open EDC at EOT. POOH for bit at 1.5 bpm following pressure schedule 23:50 - 00:00 0.17 DRILL P PROD1 Park at 500' and trap 600 psi. Close EDC PVT 218 Safety mtg re: undeploy w/ new crew WHP bled from 575 psi to 410 psi in 10 min 4/11/2005 00:00 - 01 :50 1.83 DRILL P PROD1 Fin POOH maintaining 600 psi WHP at min rate and SD pump w/575 psi WHP Undeploy. WHP bled to zero in one hour 01 :50 - 03:00 1.17 DRILL P PROD1 LD MWD assy. Change out motor and bit (bit was 4+1 and starting to ring out on nose). MU drilling BHA over open hole PVT 217 03:00 - 04:20 1.33 DRILL P PROD1 RIH w/ BHA #6 (1.3 deg, DS100) following pressure schedule 04:20 - 04:35 0.25 DRILL P PROD1 Close EDC. Log tie-in down from 7400', corr -2' 04:35 - 05:30 0.92 DRILL P PROD1 Wiper to TD. A few set downs 7480-7580' due to lower motor bend and one at 8670'. Rest of hole was clean (reduced pump rate thru 8550' shale area) Tag at 8751' PVT 249 05:30 - 08:00 2.50 DRILL P PROD1 Resume drilling ahead in a hard spot 1.51/1.51/3340/45R ECD 11.7, DHP 3930 08:00 - 12:00 4.00 DRILL P PROD1 Drill ahead from 8762'. 3350 psi fs at 1.51 in/1.54 out. 200-300 psi mw. 2.0-3.1k# DHWOB. 0-5 fph ROP. INCUAZfrF: 84.2/93.2/60R. WHPIBHP/ECD: 22/3888/11.55 ppg. IAlOAlPVT: 793/0/319 bbls. Very slow drilling. Wt transfer still adequate, adding fresh mud from pits to active system. 12:00 - 12:30 0.50 DRILL P PROD1 Drill ahead from 8777'. 12:30 - 13:00 0.50 DRILL P PROD1 Wiper trip to 8500 to check condition of shale. No trouble pulling through or running in hole. 13:00 - 17:00 4.00 DRILL P PROD1 Drill ahead from 8783'. 3400 psi fs at 1.51 in/1.53 out. 200-300 psi mw. 2.0-301k# DHWOB. 5-100 fph ROP. INCUAZfrF: 88.8/104.3I150R. WHP/BHP/ECD: 22/3994/11.86 ppg. IAlOAlPVT: 861/0/300 bbls. ROP picked up. Adding additional 2% lubtex and 2 ppb klagard. 17:00 - 22:00 5.00 DRILL P PROD1 Drilling ahead at 8850' in another hard spot (ankerite) with painfully slow progress until NB incl verified building trend PVT 307 22:00 - 23:00 1.00 DRILL P PROD1 Wiper to window-no overpulls, minor MW in spots. Pull thru window at min rate, then wipe 5' liner at 1.5 bpm thru bit PVT 300 23:00 - 00:00 1.00 DRILL P PROD1 Open EDC at EOT. POOH for bit at 1.5 bpm following pressure schedule Safety mtg re: pressure undeploy Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 7 of17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/12/2005 00:00 - 00:10 0.17 DRILL P PROD1 Park at 500' and trap 600 psi on well. Close EDC. Fin POOH PVT 272 00:10-01:40 1.50 DRILL P PROD1 Pressure undeploy w/ initial 585 psi-100% improvement over previous undeploy (175 psi on well when swab was SI after 40 min) Change bit and orientor (bit was 2-2-1 w/ slightly worn cutters in all areas and none were chipped) Weekly function test of all rams 01 :40 - 02:40 1.00 DRILL P PROD1 Pressure deploy (practice) w/70 psi induced from 100 psi lubricator test. WHP bled to zero in 20 min PVT 272 02:40 - 04:10 1.50 DRILL P PROD1 RIH w/ BHA #7 (1.3 deg, DS100 w/ tuff edge and T-rex cutters) following pressure schedule 04:10 - 04:25 0.25 DRILL P PROD1 Close EDC. Log tie-in down from 7425', carr +2' 04:25 - 05:35 1.17 DRILL P PROD1 Wiper to TD with a few set downs 7530-70' Rest of hole was clean. Tag at 8861' PVT 305 05:35 - 08:00 2.42 DRILL P PROD1 Resume drilling in a hard spot 1.47/1.47/3380/60R ECD 11.78, DHP 3971, 200 psi diff, 2k wob 08:00 - 11 :00 3.00 DRILL P PROD1 Drill ahead from 8870'. 3400 psi fs at 1.55 in/1.59 out. 200-300 psi mw. 2.0-3.0k# DHWOB. 5-10 fph ROP. INCUAZ/TF: 89.5/11 0.0/330LOR. WHP/BHPIECD: 29/3914/11.61 ppg. IAlOAlPVT: 820/0/348 bbls. 11 :00 - 16:10 5.17 DRILL P PROD1 Drill ahead from 8884' to 9050'. broke out of slow drilling around 8890'. WOB at 9050 2.5k avg 15-20'/hr last 50'. 16:10 - 17:10 1.00 DRILL P PROD1 Wiper and conditoning trip. MW coming out around 8550' area 17:10 - 17:40 0.50 DRILL P PROD1 Log tie-in +2' correction. 17:40 - 21:15 3.58 DRILL P PROD1 Wiper to bottom. Clean trip in. Tagged bottom at 9,049.8 ft MW = 9.16/9.19ppg, BHP = 3,973 psi @ 11.84ppg ECD Painted EOP at 5,600 ft PUH and unloaded liner pill into pits. Pumped 50 bbl pill down CT and PUH spotting from 9050 ft to 7400 ft. At 7,200 ft, open EDC, trapped 250 psi on wellhead 21:15 - 22:40 1.42 DRILL P PROD1 POOH following pressure schedule. Closed EDC @ 500 FT 22:40 - 22:50 0.17 DRILL P PROD1 PJSM on Un-deploying BHA 22:50 - 00:00 1.17 DRILL P PROD1 Undeploying BHA with 600 psi WHP as per precedure. 90 psi on well when shutting the MV & SV after 45 minutes 4/13/2005 00:00 - 00:15 0.25 DRILL P PROD1 LD BHA, install cap and open well to monitor WHP PJSM on well control and running 2-318' liner. 00:15 - 01 :20 1.08 CASE P RUNPRD Fill hole, monitor pit volume, no loss or gain, SD pump and monitor flow 15 minutes, RU to run liner 01:20 - 03:15 1.92 CASE P RUNPRD Ran 51 jts solid/predrilled liner, well stayed full. 03:15 - 04:15 1.00 CASE P RUNPRD Secured well, RUlPU BHI MHA & BHA EDC open, blow down kill line 04:15 - 05:50 1.58 CASE P RUNPRD RIH as per pressure schedule. Corrected at EOP flag (-5.2 ft) Conducted wt check at 7400 ft 22k up RIH set down at 7486 ft, PUh and indexed shoe 7 times and RIH 05:50 - 08:05 2.25 CASE P RUNPRD Working liner Increasing WHP to 400-800psi. Make it through shale section down to 8730'. Work pipe. Numerous setdowns work pipe 8-10 times and make another 10'_15' continue working down to 8860'. Pinching choke to increase WHP until finally closed holding 900psi on well 0.30 pump rate 2150psi PP working pipe to 9000'. Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 8 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/13/2005 08:05 - 08:30 0.42 CASE P RUNPRD Close EoC. Bring rate up to 1.0 bpm 4200psi PU off liner up wt 18.8k pull up to 7050'. 08:30 - 09:50 1.33 CASE P RUNPRD Log tie-in at 1 OOO'lhr from 7030' to 7370' make +5' correction. RIH tag top of liner at 7421' Some depth discrepancies. Relog from 7150' to 7370' EOP. Make no correction to BHi depth. Correct SLB depth -17' to correlate with BHi. RIH tag top of liner at 7408.7' which is 4' above top of window and where it should be based on liner lengths run and setting depth. This looks good for future production. 09:50 - 11 :20 1.50 CASE P RUNPRD TOH following pressure schedule. 11 :20 - 11 :40 0.33 CASE P RUN PRO PJSM review plans forward to I/d BHA. Perform slack management on 2' e-liine coil. Cutting coil. Reheading. Also observed well for flow during meeting. Dead. 11:40 -12:10 0.50 CASE P RUNPRD UD BTT CTLRT equip and BHi tools. 12:10 - 15:30 3.33 STWHIP P WEXIT Cut-off BHi CTC. Perform slack management. Cut-off 300' coil. Re-head BHi CTC. 15:30 - 16:15 0.75 STWHIP P WEXIT MU BHA #9 w/ Baker Gen II TT Whipstock. 3 RA's are installed I 7.35' below top of WS. Will set at 7363' and for highside exit. Surface test tools. 16:15 - 17:40 1.42 STWHIP P WEXIT RIH 17:40-18:10 0.50 STWHIP P WEXIT Tie-in from 7,200 ft to 7,335 ft Corrected -4 ft 18:10 - 18:25 0.25 STWHIP P WEXIT RIH and placed TOW at 7363 ft, closed EoC and oriented TF to HS 18:25 - 18:32 0.12 STWHIP P WEXIT Set WS as per BOT SOP's. Sheared at 2700 psi, set down 1500 psi, set. TOWS at 7,363 ft. 5R HS Open EDC. 18:32 - 19:50 1.30 STWHIP P WEXIT POOH Painted EOP flag at 7,100 ft 19:50 - 21 :30 1.67 STWHIP P WEXIT LD WS setting tool and PU window exit BHA 21 :30 - 22:00 0.50 STWHIP P WEXIT Set counters to 38.3 ft and RIH with EoC open Corrected -3.1ft at 7, 100ft EOP Wt check at 7,300 ft = 20k up RIH and tagged wo/ pumps at 7367.9 ft Pinch pt 2.8 ft from TOWS 22:00 - 23:30 1.50 STWHIP P WEXIT PU, closed EDC and bring pump up to 1.5 bpm CTP = 3,677psi 1.56 bpm off bottom. BHP = 3800psi = 11.65 ppg ECD RIH to aquire 1st stall at 7,366.7 ft 23:30 - 00:00 0.50 STWHIP P WEXIT Milling window as per BOT SOP's Qp = 1.57/1.59 bpm, CTP 3677/3730 psi; BHP = 3798 psi / 11.64 ppg EoC 4/14/2005 00:00 - 06:30 6.50 STWHIP P WEXIT Milling window from 7366.7 ft to 7372.8 ft (6.1 ft) as per BOT SOP's Qp = 1.57/1.59 bpm, CTP 3677/3730 psi; BHP = 3798 psi / 11.64 ppg EoC 06:30 - 07:40 1.17 DRILL P WEXIT Drilling formation f/ 7372.8' 1.58/1.63 pp=3700fs 200psi mw ann=3783 ecd=11.59 preparing to change out mud system to new Flo-Pro. 07:40 - 08:30 0.83 DRILL P WEXIT Ream and back ream window area. Swapping mud. Run through wo/pump. Window looks good. 08:30 - 09:50 1.33 DRILL P WEXIT TOH following pressure schedule. Trapped 600psi on well. Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 9 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/14/2005 09:50 . 10:05 0.25 DRILL P WEXIT PJSM review pressure deployment procedures. 10:05 - 12:00 1.92 DRILL P WEXIT Rehead Deployment slickline and pull test to 15001bs. UD BHA #10 WHP down to 240psi after 1 hr. Close in well. 12:00·12:15 0.25 DRILL P PROD1 PJSM for Pressure Re-Deployment 12:15·13:45 1.50 DRILL P PROD1 P/U BHA #11 (open well after 3hrs 60psi) 13:45 - 15:05 1.33 DRILL P PROD1 RIH to 7230'. 15:05 - 15:20 0.25 DRILL P PROD1 Log tie-in -3' 15:20 - 15:35 0.25 DRILL P PROD1 RIH close EDC. Tagged at 7381'. 15:35 - 18:18 2.72 DRILL P PROD1 Directionally drill build section. 1.66/1.71 9.219.2 FS=3640psi BHP= 3720psi (open choke) ecd=11.42ppg pit vol=362bbls IA=345psi 18:18 - 20:17 1.98 DRILL P PROD1 Directional drilling build section in B2 Shale @ 38deg RHS, ROP 8 to 50 fph Qp = 1.67/1.71 bpm Pp = 3600/3702 psi BHP = 3744 psi at 11.38ppg ECD. WHP 33 psi Vp = 360 bbl 20:17 - 21:40 1.38 DRILL IP PROD1 Directional drilling build section in B 1 @ 44deg RHS ~ ROP 8-35 fph Qp = 1.67/1.70 bpm Pp = 3,600/3,702 psi BHP = 3,776 psi at 11.42ppg ECD. WHP 33 psi Vp = 357 bbl Held JSAwith rig crews on Well Control issues prior to drilling through fault area 21 :40 - 21 :55 0.25 DRILL P PROD1 Wiper trip to tie-in to RA Marker 21:55 - 22:15 0.33 DRILL P PROD1 Logging down w/ EDC open from 7214 ft Corrected + 2 ft 22:15 - 22:30 0.25 DRILL P PROD1 RIH, close choke to build WHP to 600 psi and closed EDC 22:30 - 22:35 0.08 DRILL P PROD1 LogRA Marker Corrected TOWS @ 7363.6 ft TOW @ 7366.7 ft RA @ 7371.2 ft BOW @ 7372.8 ft 22:35 - 22:45 0.17 DRILL P PROD1 RfH to drill 22:45 - 00:00 1.25 DRILL P PROD1 Directional drilling build section in B1 @ 50-60deg RHS ROP 8-35 fph Qp = 1.67/1.75 bpm Pp = 3,680/3,813 psi BHP = 3,770 psi at 11.43ppg ECD. WHP 33 psi Vp = 359 bbl 4/15/2005 00:00 - 02:30 2.50 DRILL P PROD1 Directional drilling build section in A6-A5 @ 70-80 deg RHS ROP = 8-23 fph Qp=1.67/1.71 bpm Pp = 3,680 /3,750 psi BHP = 3,770 psi at 11.43 ppg ECD. WHP 33 psi Vp = 356 bbl 02:30 - 03:20 0.83 DRILL P PROD1 Directional drill build section in A5 @ 8D-90 deg RHS ROP <10 to 4Ofph, Building angle with 90RTF Qp = 1.67/1.71 bpm Pp = 3,680/3,768 psi BHP = 3,783 psi at 11.37 ppg ECD. WHP 33 psi Vp = 355 bbl Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operation~ Summary Report Page 10 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/15/2005 03:20 - 03:32 0.20 DRILL P PROD1 Mini wiper trip, clean 03:32 - 05:45 2.22 DRILL P PROD1 Directional drill build section in A5 @ 90 -105 deg RHS ROP started @ 70 fph w/2,500Ib WOB then reduced to 50fph at 7,606 ft ROP red further from <20ph to 40 at 7,623 ft Op = 1.67/1.72 bpm Pp = 3,680/3,728 psi BHP = 3,790 psi at 11.35 ppg ECD. WHP 33 psi Vp = 353 bbl 05:45 - 06:00 0.25 DRILL P PROD1 Wiper trip to window. No problems 06:00 - 09:30 3.50 DRILL P PROD1 Directional drill build section in A5 ROP <10'/hr w/2k wob TF 285 incl 61 1.69/1.72 9.2/9.2 BHP = 3780psi ECD = 11.33ppg Pit vol = 352 bbls 09:30 . 10:00 0.50 DRILL P PROD1 Wiper trip to 7370'. Shutdown pump and trap 700psi on well. 10:00 - 10:15 0.25 DRILL P PROD1 Log tie-in to RA tags pump min rate holding 800 on well 10:15 - 10:35 0.33 DRILL P PROD1 Open choke. Wiper trip to bottom 1.71/1.85 11.53 ECD. Small bump at 7570' otherwise clean to bottom. 10:35 - 13:30 2.92 DRILL P PROD1 Continue drilling ahead f/7860' 1.72/1.763840 psi 11.42 ECD 1.5-2k WOB 70-80'/hr At 7900', start holding 250psi on backside. ECD = 12.05ppg BHP=4032psi Pump = 1.71/1.72 4050psi May have drilled across fault at 8012'. Motorstall at 8000'. No changes to annular pressures seen nor lost circulation. 13:30 - 14:00 0.50 DRILL P PROD1 Wiper trip. No problems. 14:00 - 18:00 4.00 DRILL P PROD1 Drill ahead f/ 8021' 1.66/1.683900 psi BHP = 4040 ECD = 12.10 WOB = 2.8k 10-15'/hr WHP 253 psi Drilling back up through ankerite. At 8042 ft loosing small amount of returns 1.64 /1.54 ECD 12.03 holding 250psi on well. Healing up quickly by 8,046' 18:00 - 21 :00 3.00 DRILL P PROD1 Directional drill lateral (inverted) section in A4 TF @ 92R HS ROP <1 O'/hr w/ 5k WOB Op = 1.64/1.64 bpm Losing 0.1 bpm Density = 9.2/9.2ppg WHP / BHP = 253/4037psi ECD = 12.1 ppg. Pit vol = 326 bbls 21 :00 - 22:20 1.33 DRILL P PROD1 Directional drill lateral (inverted) section in A4 TF @ 92-105R HS ROP <15'/hr w/6k WOB Op = 1.64/1.67 bpm Density = 9.2/9.2ppg WHP / BHP = 256/4064psi ECD = 12.2ppg. Pit Vol = 321 bbls 22:20 - 00:00 1.67 DRILL P PROD1 Tumed TF to Left Side @ 8,133 It Directional drill lateral (inverted) section in A4 TF @ 92L HS ROP <10'/hr w/2-5k WOB Op = 1.64/1.67 bpm Density = 9.2/9.2ppg WHP / BHP = 245 /4044psi ECD = 12.1 ppg. Pit Vol = 320 bbls 4/16/2005 00:00 - 03: 1 0 3.17 DRILL P PROD1 Directional drill inverted section in A4 TF @ 9D-7Odeg L HS Hole angle at 100 deg ROP <15'/hr w/5k WOB Printed: 4/25/2005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 11 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/16/2005 00:00 - 03:10 3.17 DRILL P PROD1 Op = 1.64/1.67 bpm; Density = 9.2/9.2ppg WHP / BHP = 250 /4071psi ECD = 12.2ppg. Pit Vol = 316 bbls 03:10 - 03:20 0.17 DRILL P PROD1 ROP picked up finally @ 8,165 ft Directional drill inverted section in A4 TF @ 90-70deg L HS ROP 40-50'/hr w/ 2k WOB Op = 1.64/1.66 bpm; Density = 9.2I9.2ppg WHP / BHP = 256/4071psi ECD = 12.23ppg. Pit Vol = 315 bbls 03:20 - 04:15 0.92 DRILL P PROD1 Wiper trip at 8,170 ft. Op = 1.65 /1.54 bpm EDC = 12.12 Small bump at 7,571 ft with motor work 04:15 - 05:00 0.75 DRILL P PROD1 Directional drill in A4 TF @ 80-90 deg L HS ROP 50 to 100 ftIhr w/2-3k WOB Op = 1.64/1.67 bpm; Density = 9.2/9.2ppg WHP / BHP = 245/4053psi ECD = 12.2ppg. Pit Vol = 313 bbls 05:00 - 06:00 1.00 DRILL P PROD1 Turned TF down to drop angle to 90 deg. Drilling ahead at >100fph TF at 170L ROP > 100 ftIhr w/ 2-3k WOB Op = 1.64/1.68 bpm; Density = 9.2/9.2ppg WHP / BHP = 245/4076psi ECD = 12.2ppg. Pit Vol = 313 bbls 06:00 - 06:30 0.50 DRILL P PROD1 Continue drilling ahead f/8310' to 8360'. Geologist wanting to climb another few feet to target 6385'tvd by 8500'md. Have scheduled a trip to change motor AKO to 1.1 deg to reduce DLS in lateral section. Projections indicated this can be accomplished with less motor bend. 06:30 - 09:30 3.00 DRILL P PROD1 TOH following Pressure Schd. See increase motor work at TT 7132' or at 2.751D nipple at 7115'. Drop back down to window depth and clean-up 5" annular space from 7132' to TOW at 7366'. 2nd and 3rd run same results at TT. 4th time looks good making 1 more pass to window and back. Looks good continue TOH. Hold PJSM review Undeployment procedures. 09:30 - 10:35 1.08 DRILL P PROD1 Undeploy BHA #11. Initially trapped 1050psi on well. Immediately started bleeding down. 730psi/10min 600psi/15min 570psi/20min 10:35 - 10:50 0.25 DRILL P PROD1 PJSM review Pressure Deployment procedures. 10:50 - 12:00 1.17 DRILL P PROD1 Deploy BHA #12. Open well. 560psi on well for BHP of 10.9ppg EMW. Surface test tools - ok. 12:00 - 14:35 2.58 DRILL P PROD1 Pressure up to 1oo0psi. RIH following pressure schedule. Okay through window. Minor problem going through at 7570'-80'. Rough going thorough f/ 8070'-90' okay to TD Lost 50 bbl fluid during bit trip 14:35 - 18:00 3.42 DRILL P PROD1 Continue drilling ahead f/ 8360' 1.63/1.60 4180psi Ann=4135 ECD=12.48 WHP=250 WOB= 1/1k 90-1oo'lhr TF=45R Pit vol = 271 Back into Ankorite at 8392' <1 O'/hr 2.3k wob. New TVD target 6387'tvd 18:00 - 19:50 1.83 DRILL P PROD1 PU and checked parameters at crew change, Up wt 17.8k up and off bottom CTP = 3950 psi. Printed: 4/25/2005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 12 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 B-13 1 B-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/16/2005 18:00 - 19:50 1.83 DRILL P PROD1 Directional drill in M TF @ 135-165 R HS ROP <10 tVhr w/4.5k WOB Qp = 1.62/1.63 bpm; Density = 9.2/9.2ppg WHP / BHP = 256/4129psi ECD = 12.46ppg. Pit Vol = 260 bbls 19:50 - 20:30 0.67 DRILL P PROD1 Wiper trip to clean out 5" liner and conduct rig service PUH and cycled cutting from TT. Open EDC and circulate well Rig Service on Pilot Valve and air line on rig air compressor 20:30 - 21 :23 0.88 DRILL P PROD1 Circulate well through EDC at 2.00bpm while changing Denison valve in ops cab and installed new air coupling. 21 :23 - 22:15 0.87 DRILL P PROD1 Closed choke, SD pump and closed EDC. RIH 22:15 - 00:00 1.75 DRILL P PROD1 Directional drill in M/Ankerite TF @ 135·165 R HS ROP <15 tVhr w/ 4.0k WOB Qp = 1.62/1.63 bpm; Density = 9.2/9.2ppg WHP / BHP = 245/4105psi ECD = 12.39ppg. Pit Vol = 254 bbls 4/17/2005 00:00 - 03:00 3.00 DRILL P PROD1 Directional drilling in Ankerite / A4 TF @ 135-165 R HS ROP <15 tVhr w/ 4.0k WOB Qp = 1.62/1.63 bpm; Density = 9.2/9.2ppg Pp = 3950 / 4150 psi WHP / BHP = 245/4105psi ECD = 12.39ppg. Pit Vol = 252 bbls 03:00 - 06:00 3.00 DRILL P PROD1 Starting mud swap at 8461 ft while drilling. ROP inc from < 10 fph to >20 fph at 8,467 tV 6,383 ft Directional drilling in Ankerite / A4 TF @ 90 R HS Qp = 1.62/1.63 bpm; Density = 9.2/9.2ppg Pp = 3950/4150 psi WHP / BHP = 245/41 05psi ECD = 12.39ppg. Pit Vol = 247 bbls 06:00 - 09:00 3.00 DRILL P PROD1 Small drilling break at 8499' but only lasting 5'. Could be just on the verge of breaking out. Continue drilling in Ankorite NB inc 90.3 Adjust TF to highside. ROP > at 8509' 50'/hr 1.611/1.64 9.2/9.2 4060psi Ann=4060 WHP= 256 ECD 12.34ppg pit vol 356bbls (2-3-5) ROP > at 8545' 60-70'/hr 1.6k wob rop back to <101'lhr at 8590' drilled to 8610'. 09:00 - 10:15 1.25 DRILL P PROD1 Wiper trip 10:15 - 13:50 3.58 DRILL P PROD1 Directional drilling ahead. 1.61/1.63 Ann = 4100psi EDC = 12.38ppg ROP increase 70-80'/hr fl 8640' - 8776'. 13:50 - 16:30 2.67 DRILL P PROD1 Wiper trip to the tbg tail. Wipe 3 times. RIH tagged at 7550' work through okay, setdown at 8078' TF90R PU to 8040' work down to 8055'. Orient to HS RIH easy to 8080 then stopped. Orient to 120 shutddown pump trapping 1050psi on well. RIH wo pump RIH to 8110' bring on pump continue RIH to bottom okay. 16:30 - 18:00 1.50 DRILL P PROD1 Continue directionall drilling ahead f/8776'. 1.61/1.61 PP= 3950psi 2-3OOpsi motor work MW= 9.2/9.2 Ann= 4090 EDC= 12.39 holding 250psi WHP 1.1 k WOB 11 O'/hr IA= 453 OA= 0 Pit vol= 353bbls TF 90L maintaining 91.5deg at bit. Motor stall at 8832'. ROP< to 10-20'. Gas-cut mud to surface Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 13 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/17/2005 16:30 - 18:00 1.50 DRILL P PROD1 correlates to 8800'. Maintaining 7-8ppm gas cut mud at shaker 1.61/1.65 MW= 9.2/9.08 increase wellhead back-pressure to 300psi Ann= 4160psi ECD 12.61 ppg 18:00 - 19:00 1.00 DRILL P PROD1 At 8,862 ft, motor acts like its failed. Working bit to see response from motor Got it to drill, stacking up hole. Unable to get motor to drill, some rubber coming over shaker. Directional drilling A4 TF @ 105L HS ROP <15 ftIhr w/3.0k WOB Qp = 1.62/1.63 bpm; Density = 9.2/9.2ppg Pp = 3950 / 4150 psi WHP / BHP = 304/4120psi ECD = 12.39ppg. Pit Vol = 351 bbls 19:00 - 19:45 0.75 DRILL P PROD1 POOH following pressure scedule. Alerted AOGGC on upcoming BOP test. John Crisp will witness. Above WS, cycled between TT & WS to clean out 5' liner. 19:45 - 20:45 1.00 DRILL P PROD1 Above WS, cycled between TT & WS to clean out 5' liner. At 7,132 ft packing off at TT. worked and cleaned up using 4 cycles circulating through bit. Open EDC and inc Qp to 2 bph, AV - 144 fpm Having trouble with Super Choke, air will not close, having to use hydraulic pump to control choke. 20:45 - 22:30 1.75 DRILL N DFAL PROD1 POOH following pressure schedule At surface, cycled BHA in hole at 100 fpm to surge cutting at surface. Held PJSM on Pressure undeploment BHA with 1100 psi on wellhead. Talked through the procedure and way to midigate hazards Closed choke with 1059 psi, closed EDC Tagged up and slacked off 1.8 ft. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 Pressure undeploy BHA with 1050 psi on wellhead. Last WHP was 670 psi at 2330 hrs. Good job in pressure undeploying BHA. LD BHA. 4/18/2005 00:00 - 07:30 7.50 BOPSUP P PROD1 PT BOP's 250/4000 psi John Crisp w/ AOGCC witnessed BOP test. The entire test was witnessed by Rig Rep Nordic 2 The 2-3/8' Combi's failed, last test, blow down stack and open TOT doors. Change out combi seals. Retested good. Test Gas and H2S alarm system. RD test equipment 07:30 - 07:45 0.25 DRILL P PROD1 PJSM review and discuss Pressure Deployment procedures. 07:45 - 09:00 1.25 DRILL N DFAL PROD1 Pressure deploy BHA #13. Surface test tools. Open well seeing 670psi on well. No gas. 09:00 - 10:20 1.33 DRILL N DFAL PROD1 Adjust choke to hold 1000psi on well. RIH following pressure schedule. Swaco on location observing Super Choke operation. Working fine. 10:20 - 10:30 0.17 DRILL N DFAL PROD1 Log tie-in f/ 7385' -3' correction 10:30 -11:05 0.58 DRILL N DFAL PROD1 RIH reduce to min rate on pump bump at 7570. TF 60R. Bring pump to 1.6bpm 350WHP TF Highside reduce pump at 8000' to min rate 750whp TF HS slick through all prior trouble spots. 8140' inc rate to 1.6bpm 300psi WHP continue RIH to bottom no problems. 11 :05 - 12:50 1.75 DRILL P PROD1 Directionally drill ahead f/ 8870' Rate= 1.6311.67 9.2 in/out 3850psi free-spin 2-300psi motor work. 300psi WHP Ann=4140psi ECD= 12.55ppg WOB= 1.3k 140-150'/hr 12:50 - 14:30 1.67 DRILL P PROD1 Wiper trip to window. Slight overpull at 8040. Maintained TF's Printed: 4/2512005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 14 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/18/2005 12:50 - 14:30 1.67 DRILL P PROD1 as before and had no problem RIH to bottom. 14:30 - 15:30 1.00 DRILL P PROD1 Directionally drill ahead f/ 9060' Rate= 1.63/1.65 9.22 in/out 3750psi free-spin 100-200psi motor work 300psi WHP Ann= 4145psi ECD= 12.55ppg WOB= .75k 150'/hr ease off rop to 130-140'/hr 15:30 - 18:10 2.67 DRILL P PROD1 Wiper trip. Worked area from window to TT 3 times. RIH min rate f/7800' maintain highside TF went through without problems. 18:10 - 20:00 1.83 DRILL P PROD1 Directional drilling A4 TF @ 130L HS NBA = 89 deg. ROP > 120 fVhr w/1. 70k WOB. PUW = 20k Qp = 1.63/1.63 bpm; Density = 9.19/9.19ppg Pp = 3750 / 3860 psi WHP / BHP = 311/4168psi ECD = 12.64ppg. Pit Vol = 316 bbls. Lost 32 bbl fluid on trip 20:00 - 22:15 2.25 DRILL P PROD1 Wiper trip to wiondow. Clean trip to 7380 ft. RIH, no problem at 8,050 ft with 350 psi at 1,5 bpm 22:15-00:00 I 1.751 DRILL P PROD1 Directional drilling Ankerite/A4 Formation TF @ 110-130 L HS NBA = 83 deg. Qp = 1.68/1.68 bpm; Density = 9.2 /9.2ppg Pp = 3750 / 4025 psi WHP / BHP = 308/4223psi ECD = 12.8ppg. Pit Vol = 312 bbls. Back to drilling with ROP's > 100 fph w/ 2k WOB 4/19/2005 00:00 - 00:35 0.58 DRILL P PROD1 Directional drilling A4 Formation TF @ 105 R HS NBA = 81 deg. Qp = 1.64/1.65 bpm; Density = 9.2/ 9.2ppg Pp = 3750 / 4200 psi WHP / BHP = 290 /4253psi ECD = 12.8ppg. Pit Vol = 303 bbls 00:35 - 02:25 1.83 DRILL P PROD1 Wiper tripe to TT and clean IinerPUH to 7130 ft and cycled 2 times between TT & WS TT clean with 500 psi WHP 02:25 - 02:35 0.17 DRILL P PRODi Log RA Marker for Final Tie-In with 700 psi WHP, EDC @ 12.6ppg Corrected +5.00 ft 02:35 - 03:45 1.17 DRILL P PROD1 RIH using Pressure schedule. No problem at 8050 ft Lost CTDS while TIH. Had to reboot the computer and preset depths from BHI 03:45 - 04:27 0.70 DRILL P PROD1 Tagged at 9,503 ft, work bit and make ready to pump 11.5 ppg ,;" KWF Started 11.5ppg down CT 04:27 - 06:00 1.55 DRILL P PROD1 POOH laying in 11.5ppg KWF at 1:1 in open hole. Lowing WHP to maintain 4200 psi while in open hole. At 8,700 ft BHP = 4200 psi with full open choke. 06:00 - 11 :30 5.50 DRILL N FLUD PROD1 Continue POH laying 11.5pg KWM. Shipping 9.2ppg to vac truck. Stop at 5150' paint EOP flag. Continue TOH finding trip sheet not correlating to calculated tank volumes and fluid density dropping to 11.1 ppg Stop TOH adjust WHP to compensate for lost hydrostatic pressure. Circ min rate maintaining correct BHP. Discover leaking valves on mud tanks allowing 11.5ppg KWM being contaminated with 9.2ppg mud. Also inadvertantly shipping KWM to vac truck along with Printed: 4/25/2005 10:06:43 AM . . BP EXPLORATION Operations Summary Report Page 15 of 17 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-1 3 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/19/2005 06:00 - 11 :30 5.50 DRILL N FLUD PROD1 9.2ppg mud. Ordered another 150bbls 11.5ppg KWM. Circulate and wait. Keep coil moving +/- 5000' 11 :30 - 12:25 0.92 DRILL N FLUD PROD1 Start loading coil with 11.5ppg KWM while RIH back down through trouble area holding 150psi on wellhead. Run to 8150' at min rate and HS toolface. No problems 12:25 - 14:30 2.08 DRILL N FLUD PROD1 TOH 11.6ppg KWM all the way around. Not holding excess WHP. At 3500' picked something up in discharge side of pump. Excessive pump pressure 4800psi with min rate. Close choke continue TOH filling hole with charge pump down kill line. Found large amount of what looks like bumed polymer lumps in vac truck hose. This was the last of the load but most of the stuff is in our mud system and coil. 14:30 - 15:00 0.50 DRILL N FLUD PROD1 Monitor well for flow - dead. UD BHA #13 15:00 - 18:00 3.00 DRILL N FLUD PROD1 Circulate coil over bung hole. Finally reached lock-up on pump pressure. Pull checks from BHi upper quick connect. Stab injector on well. Close Master/Swab valve. Reverse circulate coil. Again pumping very close to max pressure 4850psi. Call for LRS. Have found that warm diesel will break this stuff down. While waiting for LRS continue moving fluid very slowly to avoid freezing coil. 18:00 - 19:30 1.50 DRILL N FLUD PROD1 Pumping at 0.11 bpm, 4750 psi. Reverse circulating with 11.5 ppg KWF, waiting on Little Red to arrive with diesel. 19:30 - 19:50 0.33 DRILL N FLUD PROD1 Held safety meeting with LRS, and rig hands to discuss pumping hot diesel to free up plug in coil. Currently pmping at 3400 psi at 0.12 bpm. 19:50 - 21 :00 1.17 DRILL N FLUD PROD1 Continuing to reverse circulate. Currently pumping at 3450 psi at 0.12 bpm. Caught a sample from the returns, and it looks like a chocolate milkshake. It will not pour out from a cup. From pump pressures, we may have moved the plug close to the reel end of the coil. Shut down pumping, install new packoffs. Rig up LRS to the 1502 on the stack, below the flow cross where the pressure transducer hooks up. 21 :00 - 22:00 1.00 DRILL N FLUD PROD1 It appears that we have reversed out most of the gunk from the coil with the rig pumps, but still need to pump hot diesel with LRS services to ensure that all coil, flowpaths and piping are clear. PT LRS to 500 and 5k psi. Passed ok. Come on line with LRS pumping diesel at 160 degf. Pumping at 1.0 bpm, 1500 psi. 22:00 - 23:15 1.25 DRILL N FLUD PROD1 Pump 1 full coil volume of hot diesel. Got clean diesel returns back to surface. Function all valves and purge all piping of contaminated mud. Pump 10 bbl water spacer. Pump coil volume of new 11.5 ppg KWF thru coil. 23:15 - 23:30 0.25 CASE P RUNPRD Hold PJSM to discuss popping off injector and working on BHI UOC. 23:30 - 00:00 0.50 CASE P RUNPRD Open swab. Fill hole. Took 1.5 bbls. Blow down kill line. Unstab injector. Check BHI UOC. 4/20/2005 00:00 - 00:30 0.50 CASE P RUNPRD Continue to reinstall checks in UQC. 00:30 - 00:50 0.33 CASE P RUNPRD PJSM prior to running liner. 00:50 - 03:00 2.17 CASE P RUNPRD MU 2-3/8' liner. Picked up Unique crayola guide shoe attached to Unique 1.0 deg bent sub. There was no discernable offset to the guide shoe nose, and the 'bit to bend' distance was only Printed: 4/25/2005 10:06:43 AM . . Page 16 of 17 BP EXPLORATION Operation~ Summary Report RUNPRD 12". Break off guide shoe and pick up Baker 1.45' long pump joint between guide shoe and bent sub. This gave an appropriate offset to simulate our drilling BHA, and the "bit to bend" was 33", which compares very well to the 36" on our drilling BHA. Run remainder of liner as per program to put liner top at 7350.39', with TD at 9503'. Total length of liner run was 1854' of slotted liner at 8 holes per foot, with a total liner length including solid joints of 2152.61'. Note - Bend was oriented away from draw works, and monitored during runnig the liner. MU Baker tools, BHI tools, scribe BHI tool to bend using draw works as orientation. Note that accuracy of scribe is probably no better than +/- 45 degrees. Stab Injector. RIH with liner on coil. EDC is open. Circulating down coil at 0.35 bpm, 500 psi. RIH weight at surface is +3300 psi. Stop at flag, make a + 1.4' correction. Up weight at window = 27 klbs. Orient to high side. RIH weight at window is +11000 Ibs. RIH at 35 fpm. Slick thru the window. RIH with weight bobbles around 8100', slick down to 8440', set down. PU, orient to 125 R (as drilled tool face). RIH, bounced thru to 8457'. Work pipe. Orient back to high side, and got thru. Ratty from 8460'-8524'. Set down at 8524'. Work pipe, and made it thru. Set down 8547', work pipe, and try several different tool face orientations around the clock. No luck. RUNPRD Continue to work pipe. Fell thru to 8578', set down, worked it to 8592'. Pickups clean at 32 klbs. Work pipe. Got down to 8638'. Work pipe, and got thru. Set down at 8679'. Work pipe went to 8711', work pipe at these intervals 8793', 8840'. Put well on choke 200psi. work to 8859, increase to 300psi work to 8904'. maintain 300 psi 13.0ECD, work to 8904,8972, loss ground here back to 8910' orienting TF's go back to HS work back to 8910 RIH switch to high geat RIH 120+ fpm stopped at 9262'. Seem to be running out of push. Pull back to 9100' work down to 9240' at 100fpm. Continue working again. Having touble now getting back down to 9140' Drop all pressure on coil. Work this way with less results. Close EDC and circ at 1 bpm thru the 9 jts of solid. EOP at 9157' EO solid at 7006'. Stop circ P/U to 9020. Try running in hole 3 times with close EDC and circ thru soild. Not any better making it to 9140' help. Close EDC. TF 80L WHP 500 pull back to 9020' (this is the start point where liner is free to travel down) make it to 9176'. Pull back to 9120 repeat cycles make it back to 9259' Able to work free pipe betweeen 9200 and 9235, encouraging. Work orienter torque trying to get 60R TF. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1B-13 1B-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 4/20/2005 2.17 CASE P 00:50 - 03:00 03:00 - 03:45 0.75 CASE P RUNPRD 03:45·05:00 1.25 CASE P RUNPRD 05:00 - 05:45 0.75 CASE P RUNPRD 05:45 - 10:50 5.08 CASE P Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Description of Operations RUNPRD Continue working liner at 9289' HS to 90R toolface. Close choke set for 800psi WHP set pump trips for 4k. Pump while PU and let trips shutdown pump while RIH. No returns. Max WHP 670psi. Make it to 9321', cycling pipe to 9332, 9372, 9380,9387,9395, working pipe in 10-20' intervals no over pulls, 9406', 9432', 9450, difficult getting back to 9450 stop at 9441 ' call town. 10:50 - 12:15 1.42 CASE P Printed: 4/25/2005 10:06:43 AM . . Page 17 of 17 BP EXPLORATION Operations Summary Report RUNPRD If possible would like to get deeper for future perforation of lower C1 sand. Parked at 9441' circulate thru closed EDC for 5 min. 1 bpm/3550psi. Open EDC. Set choke for 500psi PU RIH went to bottom 9487' (this is bottom according to UDAC counter on horse head. Go figure. Pull to neutral wt close EDC. Ramp up to 1.2bpm 3700psi pick-up release from liner PU wt 21k. Ahh! Since closing choke back at 1050hrs pumped away 95bbls into well Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-13 18-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 4/20/2005 12:15 - 12:45 0.50 CASE P 12:45 - 13:30 0.75 CASE P 13:30 - 14:30 1.00 CASE P 14:30 - 15:00 0.50 CASE P 15:00 - 16:00 1.00 WHSUR P 16:00 - 18:00 2.00 WHSUR P 18:00 - 19:30 1.50 RIGD P 19:30 - 20:00 0.50 RIGD P 20:00 - 20:45 0.75 RIGD P 20:45 - 21 :45 1.00 RIGD P 21 :45 - 23:00 1.25 RIGD P 23:00 - 00:00 1.00 RIGD P RUNPRD RUNPRD RUNPRD POST POST POST POST POST POST POST POST Start: 4/3/2005 Rig Release: Rig Number: 2 Spud Date: 4/3/2005 End: Description of Operations Pull up and place GR sensor at 7170' log down. rate= .78/.79 2325psi make +7' correction. RIH tag TOL at 7338' bottom 9489' TOH UD BHA #14 PU BHA #15 (10.30') and RIH to 7330' Displace 11.5ppg Flo-Pro KWM from with 8.4ppg 2% KCL to 2500'. Tag up at surface, break off injector. Rig down BHI eq. Blow back coil with air. Safety meeting prior to pulling coil back to reel. Un stab pipe from injector and secure back on reel. Pipe was blown back with 4 bbls of air, and a valve was attached to the end of coil to ensure there would be no spills. Rig down injector and secure off to the side of the rig floor for workovers. Rig down slickline lubricator. Nipple down BOP stack. NU tree cap. PT to 500 and 4500 psi. Passed ok. Rig released at Midnight. Further telex entries carried on 3H-16 MR. Printed: 4/25/2005 10:06:43 AM Well: Field: API: Permit: . . 04/04/05 04/07/05 04/20/05 Nordic #2 04/22/05 INSTALLED GL DESIGN POST CTD SIDETRACK. PULL DV AT 2641',4361',5543'; PREPLACE WITH GLV. PULL DV AT 6386' REPLACE WITH OV. 1 B-13L 1 / L2 Kuparuk River Unit 50-029-22468-60 / 61 205-044 & 205-045 Accept: Spud: Release: Rig: POST RIG WORK 05/07/05 ATTEMPTED TO UNPLUG CONTROL LINE, UNSUCCESSFUL. SET K-VALVE ON 2.81" B-7 LOCK AT 1909' RKB. Company: Field: Site: Well: Wellpath: ConocoPhillips Alaska, Inc Kuparuk River Unit Pad 18 13 18-13L2 . " Baker Hughes INTEQJ ,.! 2005 Baker Hughes INTEQ Survey R~port r' . ~, ;~;\ i¡ i~ ij ~} /,",_': ~i'; Date: 5/10/2005 Ti.J11\S~¡W;:¡ar! CCH)rdinate(NE) Reference: Well: 13, True North Vertical (fVD) Reference: Wellhead(102') 102.0 Section (VS) Reference: User (0.00N,0.00E,275.00Azi) Survey Calculation Method: Minimum Curvature Db: ... Conoc;p.,illips Ria. .~"$ ___~_·~,_m__~__ ¡; un I: ¡!fNi'~Q Page: Oracle Field: Kuparuk River Unit North Slope, Alaska USA 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: Pad 1 B Site Position: From: Map Position Uncertainty: Ground Level: Northing: Easting: 5970149.71 ft 550434.96 ft Latitude: 70 19 Longitude: 149 35 North Reference: Grid Convergence: 45.173 N 27.418 W True 0.39 deg 0.00 ft 0.00 ft Well: 13 Stot Name: Well Position: +N/-S -498.65 ft Northing: 5969647.07 ft Latitude: +EI-W -603.24 ft Easting: 549835.14 ft Longitude: Position Uncertainty: 0.00 ft 70 19 40.269 N 149 35 45.028 W Wellpath: 18-13L2 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1B-13 7140.86 ft Mean Sea Level 24.40 deg 80.77 deg Direction deg 275.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: Wellhead(102') 3/14/2005 57593 nT Depth From (TV D) ft 0.00 Height 102.00 ft Survey Program for Definitive Well path Date: 3/15/2005 Validated: Yes Actual From To Survey ft ft Version: 3 Toolcode Tool Name Annotation MD TVD ft 1'1 7140.86 6220.09 TIP 7364.00 6400.37 KOP 9503.00 6496.54 TO Survey: MWD Start Date: 4/14/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD+SAG;MWD + Sag correction Tied-to: From: Definitive Path Survey MD Incl ADm TVD SS TVD NIS E/W MapN MapE VS DLS Tool 1'1 deg deg ft ft ft ft 1'1 ft ft degl100ft 7140.86 36.11 261.27 6220.09 6118.09 -681 .77 -2997.86 5968945.47 546842.17 2927.03 0.00 MWD+SA<Ð 7200.00 36.11 261.22 6267.87 6165.87 -687.08 -3032.31 5968939.94 546807.76 2960.89 0.05 MWD+SA<Ð 7300.00 36.11 261.12 6348.66 6246.66 -696.12 -3090.54 5968930.50 546749.59 3018.11 0.06 MWD+SAG 7364.00 36.11 261.07 6400.37 6298.37 -701.96 -3127.81 5968924.42 546712.37 3054.72 0.05 MWD+SA<Ð 7397.95 40.87 265.58 6426.94 6324.94 -704.37 -3148.78 5968921.87 546691.41 3075.41 16.27 MWD+SAG 7433.17 46.09 269.40 6452.49 6350.49 -705.39 -3172.97 5968920.69 546667.23 3099.42 16.59 MWD+SAG 7465.57 51.34 272.36 6473.86 6371.86 -704.99 -3197.30 5968920.92 546642.90 3123.69 17.59 MWD+SA<Ð 7495.06 55.54 274.72 6491.42 6389.42 -703.52 -3220.94 5968922.24 546619.26 3147.37 15.62 MWD+SAG 7525.79 61.35 280.92 6507.51 6405.51 -699.92 -3246.84 5968925.67 546593.33 3173.49 25.54 MWD+SAG 7555.47 67.99 288.04 6520.21 6418.21 -693.17 -3272 .77 5968932.24 546567.36 3199.90 31.14 MWD+SA<Ð 7585.60 72.01 294.81 6530.53 6428.53 -682.82 -3299.09 5968942.42 546540.97 3227.03 24.97 MWD+SA<Ð 7615.80 71.23 301.66 6540.06 6438.06 -669.28 -3324.33 5968955.79 546515.65 3253.35 21.68 MWD+SA<Ð ) t \- _ iJ.q.t¿f y . . ... " ConocoPhillips Baker Hughes INTEQ -- Baker Hughes INTEQ Survey Report ~".<-,------ INTEQ Company: ConocoPhillips Alaska, Inc Date: 5/1 012005 Time: 09:17:10 Page: 2 Field: Kuparuk River Unit ClHÞrdinate(NE) Reference: Well: 13, True North Site: Pad 1 B Vertical (TVD) Reference: Wellhead(102') 102.0 WeD: 13 Section (VS) Reference: User (0.00N,O.00E,275.00Azi) Wellpath: 1B-13L2 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SS TVD NIS EIW MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 7651.20 75.69 308.42 6550.15 6448.15 -649.79 -3352.07 5968975.09 546487.78 3282.68 22.22 MWD+SAG 7680.47 80.61 305.76 6556.16 6454.16 -632.53 -3374.92 5968992.20 546464.83 3306.95 19.02 MWD+SAG 7712.97 82.92 298.99 6560.82 6458.82 -615.32 -3402.07 5969009.23 546437.57 3335.49 21.81 MWD+SAG 7743.22 85.96 294.04 6563.75 6461.75 -601.89 -3429.00 5969022.48 546410.55 3363.49 19.14 MWD+SA<Ø 7771.44 89.16 288.76 6564.95 6462.95 -591.61 -3455.24 5969032.58 546384.25 3390.53 21.86 MWD+SA<Ø 7802.78 92.23 281.99 6564.57 6462.57 -583.30 -3485.43 5969040.69 546354.00 3421.33 23.72 MWD+SA<Ø 7832.89 93.85 273.99 6562.97 6460.97 -579.13 -3515.18 5969044.67 546324.22 3451.33 27.07 MWD+SAG 7862.40 94.53 267.89 6560.81 6458.81 -578.64 -3544.59 5969044.95 546294.81 3480.67 20.74 MWD+SAG 7894.48 96.16 259.81 6557.82 6455.82 -582.06 -3576.32 5969041.33 546263.11 3511.98 25.59 MWD+SAG 7935.71 97.38 267.44 6552.95 6450.95 -586.61 -3616.98 5969036.51 546222.49 3552.09 18.61 MWD+SAG 7958.70 96.75 273.05 6550.12 6448.12 -586.51 -3639.79 5969036.46 546199.68 3574.82 24.37 MWD+SAG 7986.69 98.02 279.13 6546.52 6444.52 -583.57 -3667.37 5969039.22 546172.08 3602.56 22.01 MWD+SAG 8017.72 100.39 286.33 6541.55 6439.55 -576.83 -3697.23 5969045.76 546142.18 3632.89 24.14 MWD+SAG 8049.85 99.45 292.4 7 6536.01 6434.01 -566.32 -3727.07 5969056.07 546112.28 3663.53 19.05 MWD+SA<Ø 8079.28 99.18 297.66 6531.25 6429.25 -554.02 -3753.36 5969068.19 546085.90 3690.80 17.43 MWD+SA<Ø 8108.84 99.93 303.57 6526.33 6424.33 -539.18 -3778.44 5969082.86 546060.73 3717.07 19.88 MWD+SA<Ø 8143.77 100.26 296.76 6520.20 6418.20 -521.91 -3808.15 5969099.93 546030.91 3748.17 19.22 MWD+SA<Ø 8173.58 100.65 292.00 6514.79 6412.79 -509.81 -3834.84 5969111.85 546004.14 3775.82 15.76 MWD+SA<Ø 8206.65 101.02 284.77 6508.57 6406.57 -499.58 -3865.65 5969121.88 545973.27 3807.39 21.50 MWD+SAG 8239.34 97.43 279.99 6503.33 6401.33 -492.67 -3897.15 5969128.58 545941.73 3839.38 18.13 MWD+SAG 8281.26 93.11 273.32 6499.47 6397.47 -487.84 -3938.58 5969133.13 545900.27 3881.07 18.90 MWD+SAG 8314.73 94.77 265.58 6497.17 6395.17 -488.16 -3971.94 5969132.59 545866.92 3914.28 23.60 MWD+SAG 8351.65 91.24 255.87 6495.23 6393.23 -494.10 -4008.28 5969126.41 545830.62 3949.96 27.95 MWD+SAG 8385.48 93.58 255.71 6493.81 6391.81 -502.40 -4041.04 5969117.90 545797.92 3981.88 6.93 MWD+SAG 8415.55 95.98 259.22 6491.30 6389.30 -508.90 -4070.28 5969111.20 545768.72 4010.44 14.11 MWD+SAG 8445.57 93.45 263.39 6488.83 6386.83 -513.42 -4099.85 5969106.48 545739.19 4039.50 16.21 MWD+SAG 8474.04 91.86 268.33 6487.51 6385.51 -515.4 7 -4128.21 5969104.24 545710.85 4067.57 18.21 MWD+SAG 8504.50 90.94 271.27 6486.77 6384.77 -515.58 -4158.65 5969103.93 545680.41 4097.89 10.11 MWD+SAG 8535.26 94.04 274.31 6485.43 6383.43 -514.08 -4189.34 5969105.23 545649.71 4128.59 14.11 MWD+SA<Ø 8581.24 92.35 279.65 6482.87 6380.87 -508.50 -4234.89 5969110.50 545604.13 4174.46 12.16 MWD+SAG 8620.51 91.80 284.73 6481.44 6379.44 -500.22 -4273.24 5969118.53 545565.74 4213.38 13.00 MWD+SAG 8649.74 95.96 288.89 6479.47 6377.47 -491.79 -4301.14 5969126.77 545537.78 4241.91 20.10 MWD+SA<Ø 8692.85 91.64 290.93 6476.61 6374.61 -477.15 -4341.57 5969141.15 545497.25 4283.4 7 11.08 MWD+SA<Ø 8722.22 91.58 286.22 6475.78 6373.78 -467.80 -4369.39 5969150.31 545469.37 4312.00 16.03 MWD+SA<Ø 8765.36 92.01 280.24 6474.43 6372.43 -457.93 -4411.35 5969159.89 545427.36 4354.65 13.89 MWD+SA<Ø 8801.84 91.52 274.24 6473.31 6371.31 -453.34 -4447.51 5969164.25 545391.18 4391.07 16.49 MWD+SA<Ø 8833.55 91.92 269.86 6472.35 6370.35 -452.21 -4479.17 5969165.17 545359.50 4422.72 13.86 MWD+SA<Ø 8867.35 89.55 265.73 6471.92 6369.92 -453.51 -4512.94 5969163.64 545325.75 4456.24 14.09 MWD+SA<Ø 8907.75 92.23 271.90 6471.29 6369.29 -454.34 -4553.30 5969162.54 545285.40 4496.37 16.65 MWD+SA<Ø 8946.46 90.14 277. 77 6470.49 6368.49 -451.08 -4591.84 5969165.55 545246.84 4535.06 16.09 MWD+SA<Ø 8973.57 89.12 282.67 6470.67 6368.67 -446.27 -4618.51 5969170.18 545220.14 4562.04 18.46 MWD+SAG 9015.42 87.50 288.64 6471.90 6369.90 -434.99 -4658.78 5969181.19 545179.81 4603.14 14.77 MWD+SA<Ø 9051.36 91.27 295.78 6472.29 6370.29 -421.42 -4692.02 5969194.54 545146.48 4637.44 22.46 MWD+SA<Ø 9088.60 90.60 293.19 6471.68 6369.68 -405.99 -4725.90 5969209.74 545112.50 4672.53 7.18 MWD+SA<Ø 9117.29 90.29 288.62 6471.46 6369.46 -395.75 -4752.70 5969219.80 545085.64 4700.12 15.97 MWD+SA<Ø 9146.48 92.38 284.18 6470.78 6368.78 -387.51 -4780.68 5969227.85 545057.60 4728.72 16.81 MWD+SA<Ø 9179.87 91.70 279.81 6469.59 6367.59 -380.58 -4813.31 5969234.57 545024.93 4761.83 13.24 MWD+SA<Ø 9211.44 88.97 274.76 6469.40 6367.40 -376.58 -4844.62 5969238.36 544993.60 4793.36 18.18 MWD+SA<Ø 9251.08 87.77 277.17 6470.53 6368.53 -372.46 -4884.02 5969242.21 544954.17 4832.97 6.79 MWD+SA<Ø 9284.59 87.59 283.31 6471.89 6369.89 -366.51 -4916.95 5969247.94 544921.21 4866.30 18.32 MWD+SA<Ø 9339.81 85.44 292.00 6475.25 6373.25 -349.82 -4969.42 5969264.29 544868.63 4920.03 16.18 MWD+SA<Ø 9370.35 84.39 297.93 6477.96 6375.96 -336.99 -4996.99 5969276.93 544840.98 4948.60 19.64 MWD+SA<Ø 9407.45 83.58 304.32 6481.85 6379.85 -317.93 -5028.56 5969295.78 544809.29 4981.71 17.27 MWD+SA<Ø · Conoc;r;.,illips · Baker Hughes INTEQ . Baker Hughes INTEQ Survey Report Rit. a.'I.. ~",~--""~~~~"~,-- INTEQ Company: Field: Site: WeD: WeDpath: ConocoPhillips Alaska, Inc Kuparuk River Unit Pad 1B 13 1B-13L2 Date: 5/10/2005 Time: 09:17:10 Page: 3 Co-ordinate(NE) Reference: Well: 13, True North Vertical (fVD) Reference: Wellhead(102') 102.0 Section (VS) Reference: User (0.00N,O.00E,275.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft Ind deg Azim deg TVD ft SS TVD ft NIS E/W MapN MapE VS DLS Tool ft ft ft ft ft deg/1 OOft -297.92 -5055.55 5969315.61 544782.17 5010.35 14.38 MWD+SAG -277.53 -5078.95 5969335.84 544758.64 5035.43 15.26 MWD+SAG -257.09 -5100.56 5969356.13 544736.90 5058.74 0.00 MWD+SAG 9441.35 9472.80 9503.00 81.53 80.00 80.00 308.78 313.39 313.39 6486.25 6491.30 6496.54 6384.25 6389.30 6394.54 TUBING (0-7132. 00:3.500, 10:2.992) PBR (7093-7094, 00:3.500) ROOUCTION (O-7115, 00:7.000, Wt:26.00) NIP (7115-7116, 00:3.500) SOS (7131-7132, 00:3.500) Deployment Sub L2 (7336-7337, 00:2.990) LlNER-MAIN LEG (7115-7883, 00:5.000. Wt:18.00) Perf (7621-9476) 11M3l2 API: 500292246861 SSSV Type: LOCKED OUT Annular Fluid: Reference Log: LastTaç¡: Description CONDUCTOR SURFACE PRODUCTION LlNER·MAIN LEG L2 SLOTTED LINER WINDOW L2 Tubing Sirin~ - TUBiNG Top o Perforations Summary Interval I TVD 7621 ·9476 6542 . 6492 Gas Lift MandrelSValves St MD TVD Man Mfr 1 2641 2506 2 4361 3921 3 5543 4905 4 6386 5605 5 7048 6145 Other (Plu9S¡ Depth TVD 1909 1890 KRU 1B-1 Well Type: PROD Orig Completion: 4/21/2005 Last W/O: Ref Log Date: TO: 9503 ftKB Max Hole Angle: 101 dell @J 8207 An\)le @f T8: dell @ Angle @ TO: 80 dell ~ 9503 Rev Reason: Set K·VALVE LastUpdate: 5/17/2005 Size 16.000 9.625 7,000 5.000 2.380 5.000 Bottom TVD Wt Grade Thread 121 121 62,50 H-40 WELDED 4540 4070 40.00 L-80 BTC 7115 6199 26,00 L-80 LTC-MOD 7883 6559 18.00 L-80 LTC 9489 6494 4.60 L-80 STL 7364 6400 0.00 Grade Thread J-55 8rdEUE I Date Comment 4/20/2005 V Type VOD Latch Port TRO Date Run Vlv Cmnt GLV 1.5 TGP 0.200 1252 4/22/2005 GLV 1,0 BK 0,188 1325 4/22/2005 GLV 1,0 BK 0,250 1424 4/22/2005 OV 1.0 BK 0.250 0 4/22/2005 DMY 1,5 TGP 0.000 0 3/25/2005 Top o o o 7115 7336 7363 Man Type VMfr CAMCO MMM MMH FMHO MMH FMHO MMH FMHO CAMCO MMM etc.) . JEWELRY Type VALVE 1909 1890 SSSV 7093 6181 PBR 7094 6182 PACKER 7115 6199 NIP 7131 6212 SOS 7132 6213 m 7336 6378 Deployment Sub L2 7337 6379 SpJinned Spear 7363 6400 Whipstock L2 Description HALLIBURTON K-VALVE ON B-7 LOCK (WILL CLOSE @ 250#, 60 DEG,) set Sf1I2005 CAMCO TRDP-2A (LOCKED OUT 12/1/00) BAKER 'OBH-22' w/1 0' SEAL BAKER 'FB·1' PACKER CAMCO 'D' NIPPLE NO GO CAMCO PE 500 ID 0.000 BAKER DEPLOYMENT SUB TO L2 2.810 3,000 4.000 2.750 2,992 2,992 2.650 BAKER 'OS' SPUNNED SPEAR ASSEMBLY, LATERAL L2 2.250 BAKER GEN II RETRIEVABLE FLOW·THRU WHIPSTOCK TO L2 0,000 General Notes Date I Note 4/20/2005 MULTI-LATERAL WELL: MAIN LEG, TWO LATERALLEGS; THIS VIEW LATERAL L2 · . ~ ~ !Æ ~ E lID J !Æ ~!Æ ~ ~«!Æ / FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. ORAND GAS / COlVSERVATlON COMMISSION , . f 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Kolstad CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk IB-13L2 ConocoPhillips Alaska Inc. Permit No: 205-045 Surface Location: 499' SNL, 605' WEL, SEC. 09, TIIN, RI0E, UM Bottomhole Location: 790' SNL, 449' WEL, SEC. 08, TIIN, RlOE, UM Dear Mr. Kolstad: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit.. Ie se provide at least twenty-four (24) hours notice for a representative of the Commissi to w¡ tness any required test. Contact the Commission's petroleum field inspector 7. (pager). r DATED this L day of ..,-/ cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '. " I ·c.. .. ~ . STATE OF ALASKA . RE EI\IED (~~ ALAS~OIL AND GAS CONSERVATION C~MISSION MAR 22 2005 PERMIT TO DRILL 20 AAC 25.005 11 b. Current Well Class 0 Exploratory III Development o~nrM.le Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 1m Blanket 0 Single Well 11. Well Name and Number: Bond No. 59-52-180 / KUP 1B-13L2 6. Proposed Depth: i.:>i./71 12. Field I Pool(s): MD 9500'¡ TVD~?'5" Kuparuk River Unit 7. Property Designation: Þ1> 1.- ,4t>L . ~?i-o>, 2:,,_,·1t;¡. z.., A~ 025647 . ""'''f':> 1-. ~.:J(·Ò$ 8. Land Use ermit: 13. Alaska Oil & Gas Cons. ",ommission 18. Casing Program: SiZé Casing 2-3/8" o Drill III Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 499' SNL, 605' WEL, SEC. 09, T11 N, R10E, UM / Top of Productive Horizon: 1189' SNL, 3651' WEL, SEC. 09, T11 N, R1OE, UM Total Depth: 790' SNL, 449' WEL, SEC. 08, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549834 / y- 5969647/ Zone- ASP4 16. Deviated Wells: Kickoff Depth: 7360./ feet Maximum Hole Angle: 101 - degrees SPßC.IfIc.a.t1ons Grade Coupling Length L-80 STL 2150' 9. Acres in Property: 2560./ Approximate Spud Date: April 1, 2005 14. Distance to Nearest Property: 22,500' 3" Weight 4.6# 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 102' ./ feet 1A-Q4 is offset by 650' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4000" Surface: 3346"' ~UingDeptn Top.> .... ... ····Bottom MD TVD MD TVD (including stage data) 7350"' .~.. 9500 ~ Uncemented Slotted Liner ¿,3'81 c;, '177 AÞ '3 <Ji· ti> Hole 19. PRESENT WELL CONDITION SUMMARY (To be completéd for RedriJl AND Re-enWOþéråtio!'ÎS) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 7900 6833 None 7551 6552 Casing Length Size Cement Volume MD Structural Conductor Surface Intermediate Production Liner Junk (measured): 7502 TVD 121' 4540' 16" 200 sx Arcticset I 920 sx AS 111,420 sx Class 'G' 121' 4540' 121' 4070' 9-5/8" 7883' 1800' 2-3/8" 350 sx Class 'G' Uncemented Slotted Liner 7883' 7400' - 9200' 6819' 6327' - 6528' 7" x5" Perforation Depth MD (~218' - 7579' 20. Attachments L Filing Fee, $100 1m BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 6282' - 6574' 1m Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 1m Drilling Fluid Program 1m 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name.~ J30tt _Ko~~tad .... / Title CT Drilling Engineer Signature ð~7~~/ Phone 564-5347 Commission Use Onl.y Permit To Drill . /.-1 API Number: 1 Permit Approval J 1 See cover letter for Number: ZOS--DY5 I .. 50- 029-22468-61-00 Date: 4-fI / OS other requirements Conditions of Approval: Sample eq red n Yes .~No Mud Log Required 0 Yes~No Hydr en Su de Measures .~ Yes n No Directional Survey Required øYes 0 No Áo.c,.. \>lo..~ .~~\-,,,'-~~\ ~ \ l-\ ~~'i ~ " Date ~n~C Date: Contact Aras Worthington, 240-5780 Scott Kolstad, 564-5347 Prepared By Name/Number: Date.5"p.~Cj- Terrie Hubble, 564-4628 APPROVED BY THE COMMISSION '--- ^ '. '. . . KiWJ"1 B-13L 1 and 1 B-13L2 Sidetracks - Coiled Tubing Drilling Summary of Operations: Coiled tubing drilling will drill 2 laterals in producer KRU I B-13 using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). This horizontal laterals will target Kuparuk A sand - reserves for production. The Kuparuk C Sand perforations in the existing well, IB-13, will be retained. . CTD Drill and Complete IB-13LI & IB-13L2 proe:ram: Planned for Apr 1,2004 I. Pre CTD MIT -lA, MITT 2. Pre CTD test MV & SV 3. Pre CTD Caliper 5" liner 4. Pre CTD pump CaC03 pill over C-sand perfs & FCO excess 5. Pre CTD drift tubing/liner with dummy whipstock 6. Pre CTD set 5" whipstock @ 7410' md. 7. MIRU Nordic 2. NU 7-1/16" BOPE, test. 8. Mill 2.74" window at 7410' md and 10' of openhole. 9. Drill 3" bicenter hole horizontal lateral from window to ~9000' TD targeting Kuparuk A sands. / 10. Kill welI wi b~ with 2 3/8" slotted liner from Tn 9000', up into the 5" lin~r to ~ ~OO'. II. Set whipstock ~ 7360' md ,/ 12. Mill 2.74" window at 7360' md and 10' of openhole. ,/ 13. DrilI3" bicenter hole horizontal lateral from window to ~9500' TD targeting Kuparuk A sands. / (-:. '7 14. Kill well wi brine & Complete with 2 3/8" slotted liner from TD 9500' to 5' -I 0' outside the 5" casing exit '~'-.~ ~7350'. f-~ 15. ND BOPE. RDMO Nordic 2. 16. Post CTD rig -Run GL V s. BOL. ~ ~ Mud Program: · Step 8: 9.2 ppg Chloride based biozan mud · Steps 9 & 11-13: Chloride based Flo-Pro (9.2 ppg) · Steps 10 & 14: Viscosified potassium formate KWF (12.2 ppg) Disposal: · No annular injection on this well. / · Class II liquids to KRU I R 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: · IB-13Ll: 23/8",4.6#, L-80, STL slotted liner from 7400' md to 9000' md L-.:..' IB-13L2: 23/8",4.6#, L-80, STL slotted liner horn 7350' md to 9500' md /~ Well Control: · Two wellbore volumes (~228 bbls) ofKWF will be location during drilling operations. · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4800 psi. · The annular preventer will be tested to 400 psi and 2500 psi. i Directional · See attached directional plans for lB-13Ll & IB-13L2 · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. / · The nearest well to lB-13Ll is IB-15, which is offset by 1400'. KRU boundary is 21,800' away. · The nearest well to IB-13L2 is IA-04, which is offset by 650'. KRU boundary is 22,500' away. Logging · MWD Gamma Ray will be run. / '. K'1 B-13L 1 and 1 B-13L2 Sidetracks - !Ied Tubing Drilling Hazards · High pressure (-4000 psi) is expected after crossing a mapped fault. /' · Well I B-13 has a H2S reading of 80 ppm. I B is an H2S pad, the highest H2S measurement on the pad is 183 ppm. All H2S monitoring equipment will be operational. "I Reservoir Pressure · The drilling plan includes crossing a fault where the expected pressure is -4000 psi at 6544' TVD, 11.8 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 3346 psi. - DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant / bottom hole pressure by using 9.2 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end ofthe long wellbores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment ofthe BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). This well does not have a functional tubing retrievable sub-surface safety valve (an insert WRDP has been used recently - too small for deployment of CTD tools). The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated reservoir pressure: 4000 psi at 6544' TVD, 11.8 ppg EMW. ,,' Expected annular friction losses while circulating: 675 psi. Planned mud density: 9.2 ppg equates to 3130 psi hydrostatic bottom hole pressure. - While circulating 9.2 ppg fluid, plus 300 psi surface pressure applied via the choke, bottom hole circulating pressure is estimated to be 4100 psi or 12.1 ppg ECD. ' When circulation is stopped, a minimum of 970 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The production liner will be deployed by swapping the wellbore to the KWF that not only overbalances the well but is found to work best with the exposed shales during the drilling operation (minimum weight = 12.1 ppg for 100 psi overbalance) ./ KRU 1 B...13L 1 & L2 Producer Proposed Completion 95/8" 40# @ 4540' MD ~ ----- 3 W' Cameo TROP-4A SSSV (Locked-Out) 3-1/2" 9.3# J-55 8rd EUE Tubing 3-%" Cameo GLMs at 2641',4361',5543',6386', & 7048' MD ConocJ"Phillips Alaska, Inc. . 7" 26# @ 7115' MD BakA Cameo 0 nipple 2.75"10 @ 7115' MD C-Sand Perfs wI CaC02 Plug 3" open hole \ / l2 KOP 7360' MD ,.. Window in 4-1/2" I......... I ... A - Sand ./' L____ .... Baker Gen II ./ retrievable whipstock @ 7360' md -- --- ----- l1 KOP 7410' MD ( 2-3/8" Baker deployment sub @ 7400' md ~ 3" openhole ~ ~ Baker Gen II retrievable whipstock @ 7410' - ~ 2-3/8" slotted liner A - Sand 5" 18#" L·80 @ 7883' MD ~ - '~ ;105"-0 L..i: S-~"/ 1 B-13L2, TD @ 9500' md .,,- ~ ~ 2-3/8" slotted liner ' 1B-13L 1, rD @ 9000' md -j) 02/11/05 · . Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ConocriPhillips INTEQ Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: Pad 1 B Site Position: From: Map Position Uncertainty: Ground Level: Well: 13 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Northing: Easting: 5970149.71 ft 550434.96 ft 45.173 N 27.418 W True 0.39 deg 0.00 ft 0.00 ft Latitude: 70 19 Longitude: 149 35 North Reference: Grid Convergence: Slot Name: Well Position: +N/-S -498.65 ft Northing: 5969647.07 ft Latitude: +E/-W -603.24 ft Easting: 549835.14 ft Longitude: Position Uncertainty: 0.00 ft 70 19 40.269 N 149 35 45.028 W Wellpath: Plan#9,1B-13L2 Current Datum: Magnetic Data: Field Strength: Vertical Section: Wellhead(102') 3/14/2005 57593 nT Depth From (TVD) ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1 B-13 7360.00 ft Mean Sea Level 24.40 deg 80.77 deg Direction deg 275.00 3/14/2005 4 From: Definitive Path Height 102.00 ft +N/-S ft 0.00 Plan: Plan #9 Copy Lamar's Plan#9 Principal: Yes Targets Date Composed: Version: Tied·to: 1B-13L2 Target 6 6441.00 -133.85 -5756.71 5969475.00 544080.00 70 19 38.930 N 149 38 33.079 W 1 B-13L2 Target 5 6471.00 -223.36 -5380.26 5969388.00 544457.00 70 19 38.053 N 149 38 22.087 W 1B-13L2 Target 4 6490.00 -453.24 -4649.70 5969163.00 545189.00 70 19 35.797 N 149 38 0.757 W 1B-13L2 Target 3 6507.00 -522.37 -3879.07 5969099.00 545960.00 70 19 35.121 N 149 37 38.260 W 1 B-13L2 Target 2 6552.00 -599.94 -3644.56 5969023.00 546195.00 70 19 34.360 N 149 37 31.414 W 1B-13L2 Target 1 6565.00 -638.40 -3424.79 5968986.00 546415.00 70 19 33.982 N 149 37 24.998 W Annotation 7140.86 7360.00 7380.00 7420.00 7733.24 7903.24 7953.24 8128.24 8208.24 8403.24 8603.25 6220.09 6397.13 6413.10 6443.24 6565.42 6558.48 6552.01 6518.23 6506.91 6497.26 6494.66 TIP KOP End 9°/100 DLS 4 5 6 7 8 End 18°/100 DLS 10 11 Conocó'Phillips . . Baker Hughes INTEQ Baker Hughes INTEQ Planning Report INTEQ Annotation 8803.24 6492.29 12 9003.24 6490.12 13 9128.24 6487.58 14 9403.24 6479.74 15 9500.00 0.00 TD Plan Section Information 7140.86 36.11 261.27 6220.09 -681.77 -2997.86 0.00 0.00 0.00 0.00 /7360.00 36.11 261.07 6397.13 -701.59 -3125.48 0.05 0.00 -0.09 269.92 7380.00 37.91 261.07 6413.10 -703.46 -3137.37 9.00 9.00 0.00 0.00 7420.00 44.27 266.22 6443.24 -706.29 -3163.47 18.00 15.90 12.88 30.00 7733.24 90.00 303.74 6565.42 -619.38 -3424.19 18.00 14.60 11.98 47.00 7903.24 94.57 273.45 6558.48 -565.79 -3583.24 18.00 2.69 -17.82 279.00 7953.24 100.30 266.45 6552.01 -565.81 -3632.77 18.00 11.47 -13.99 310.00 8128.24 101.38 298.52 6518.23 -529.24 -3798.25 18.00 0.61 18.33 85.00 8208.24 94.83 285.56 6506.91 -499.67 -3871.49 18.00 -8.18 -16.20 244.00 8403.24 90.77 262.49 6497.26 -486.17 -4064.42 12.00 -2.09 -11.83 260.70 8603.24 90.70 286.49 6494.66 -470.64 -4262.34 12.00 -0.03 12.00 90.00 8803.24 90.64 262.49 6492.29 -455.11 -4460.26 12.00 -0.03 -12.00 270.00 9003.24 90.58 286.49 6490.12 -439.58 -4658.18 12.00 -0.03 12.00 90.00 9128.24 91.73 271.53 6487.58 -420.07 -4781.26 12.00 0.92 -11.97 274.50 9403.24 91.45 304.54 6479.74 -336.14 -5039.04 12.00 -0.10 12.00 90.00 9500.00..... 91.42 292.92 6477.31 / -289.72 -5123.72 12.00 -0.03 -12.00 270.00 Survey 7140.86 36.11 261.27 6118.09 -681.77 -2997.86 5968945.47 546842.17 0.00 2927.03 0.00 MWD 7150.00 36.11 261.26 6125.48 -682.59 -3003.18 5968944.62 546836.85 0.05 2932.26 269.92 MWD 7175.00 36.11 261.24 6145.67 -684.83 -3017.75 5968942.28 546822.30 0.05 2946.58 269.93 MWD 7200.00 36.11 261.22 6165.87 -687.08 -3032.31 5968939.94 546807.76 0.05 2960.89 269.94 MWD 7225.00 36.11 261.19 6186.07 -689.33 -3046.87 5968937.59 546793.21 0.05 2975.19 269.96 MWD 7250.00 36.11 261.17 6206.27 -691.59 -3061.43 5968935.23 546778.67 0.05 2989.50 269.98 MWD 7275.00 36.11 261.15 6226.46 -693.85 -3075.99 5968932.87 546764.13 0.05 3003.81 270.00 MWD 7300.00 36.11 261.12 6246.66 -696.12 -3090.54 5968930.50 546749.59 0.05 3018.11 270.02 MWD 7325.00 36.11 261.10 6266.86 -698.40 -3105.10 5968928.13 546735.05 0.05 3032.41 270.04 MWD / 7350.00 36.11 261.08 6287.05 / -700.68 -3119.65 5968925.75 546720.51 0.05 3046.72 270.05 MWD 7360.00 36.11 261.07 6295.13 -701.59 -3125.48 5968924.80 546714.70 0.05 3052.44 270.07 MWD 7375.00 37.46 261.07 6307.15 -702.99 -3134.35 5968923.35 546705.83 9.00 3061.15 0.00 MWD 7380.00 37.91 261.07 6311.10 -703.46 -3137.37 5968922.85 546702.82 9.00 3064.12 360.00 MWD 7400.00 41.06 263.81 6326.54 -705.13 -3149.97 5968921.11 546690.23 18.00 3076.53 30.00 MWD 7416.88 43.77 265.86 6339.00 -706.15 -3161.31 5968920.01 546678.90 18.00 3087.74 27.88 1B-13L2 7420.00 44.27 266.22 6341.24 -706.29 -3163.47 5968919.85 546676.73 18.00 3089.88 26.37 MWD 7425.00 44.89 267.15 6344.81 -706.50 -3166.98 5968919.62 546673.23 18.00 3093.35 47.00 MWD 7450.00 48.08 271.53 6362.02 -706.69 -3185.09 5968919.31 546655.12 18.00 3111.38 46.34 MWD 7460.59 49.48 273.25 6369.00 -706.35 -3193.05 5968919.59 546647.16 18.00 3119.34 43.32 1B-13L2 7475.00 51.42 275.48 6378.18 -705.51 -3204.13 5968920.37 546636.08 18.00 3130.45 42.19 MWD 7491.15 53.65 277.83 6388.00 -704.02 -3216.86 5968921.77 546623.34 18.00 3143.26 40.77 1B-13L2 7500.00 54.89 279.07 6393.17 -702.96 -3223.97 5968922.78 546616.23 18.00 3150.43 39.33 MWD 7521.39 57.93 281.90 6405.00 -699.71 -3241.48 5968925.91 546598.70 18.00 3168.16 38.61 1B-13L2 7525.00 58.45 282.36 6406.90 -699.07 -3244.48 5968926.54 546595.69 18.00 3171.20 37.05 MWD 7550.00 62.09 285.41 6419.30 -693.85 -3265.54 5968931.62 546574.59 18.00 3192.64 36.80 MWD 7575.00 65.79 288.26 6430.29 -687.34 -3287.03 5968937.98 546553.07 18.00 3214.62 35.29 MWD 7600.00 69.54 290.95 6439.79 -679.58 -3308.81 5968945.60 546531.24 18.00 3236.99 34.04 MWD 7625.00 73.33 293.50 6447.74 -670.61 -3330.74 5968954.42 546509.25 18.00 3259.61 33.02 MWD y ConocoPhillips . . Baker Hughes INTEQ Baker Hughes INTEQ Planning Report INTEQ Survey 7633.16 74.58 294.32 6450.00 -667.43 -3337.91 5968957.55 546502.06 18.00 3267.04 32.20 1 B-13L2 7650.00 77.16 295.96 6454.11 -660.49 -3352.69 5968964.39 546487.24 18.00 3282.36 31.98 MWD 7675.00 81.00 298.34 6458.85 -649.29 -3374.52 5968975.44 546465.33 18.00 3305.09 31.57 MWD 7700.00 84.86 300.68 6461.93 -637.07 -3396.11 5968987.52 546443.67 18.00 3327.66 31.12 MWD 7725.00 88.72 302.98 6463.32 -623.91 -3417.31 5969000.54 546422.39 18.00 3349.93 30.84 MWD 7733.24 90.00 303.74 6463.42 -619.38 -3424.19 5969005.02 546415.48 18.00 3357.17 30.71 MWD 7750.00 90.47 300.76 6463.35 -610.44 -3438.36 5969013.87 546401.24 18.00 3372.07 279.00 MWD 7775.00 91.17 296.32 6462.99 -598.50 -3460.31 5969025.66 546379.21 18.00 3394.98 278.99 MWD 7800.00 91.87 291.87 6462.32 -588.30 -3483.12 5969035.71 546356.34 18.00 3418.60 278.92 MWD 7825.00 92.55 287.42 6461.36 -579.90 -3506.64 5969043.95 546332.76 18.00 3442.76 278.81 MWD 7850.00 93.22 282.96 6460.10 -573.36 -3530.73 5969050.33 546308.63 18.00 3467.33 278.63 MWD 7875.00 93.86 278.50 6458.56 -568.72 -3555.24 5969054.81 546284.10 18.00 3492.15 278.41 MWD 7900.00 94.49 274.03 6456.74 -566.00 -3580.02 5969057.36 546259.30 18.00 3517.07 278.13 MWD 7903.24 94.57 273.45 6456.48 -565.79 -3583.24 5969057.55 546256.08 18.00 3520.30 277.81 MWD 7925.00 97.08 270.43 6454.27 -565.05 -3604.88 5969058.14 546234.45 18.00 3541.91 310.00 MWD 7950.00 99.94 266.91 6450.57 -565.62 -3629.59 5969057.41 546209.74 18.00 3566.48 309.69 MWD 7953.24 100.30 266.45 6450.01 -565.81 -3632.77 5969057.20 546206.56 18.00 3569.63 309.17 MWD 7975.00 100.62 270.43 6446.05 -566.39 -3654.16 5969056.48 546185.18 18.00 3590.89 85.00 MWD 8000.00 100.92 275.00 6441.38 -565.23 -3678.68 5969057.48 546160.65 18.00 3615.42 85.72 MWD 8025.00 101.16 279.57 6436.59 -562.12 -3703.02 5969060.42 546136.30 18.00 3639.93 86.58 MWD 8050.00 101.32 284.16 6431.71 -557.08 -3727.00 5969065.30 546112.28 18.00 3664.27 87.45 MWD 8075.00 101.42 288.75 6426.78 -550.14 -3750.50 5969072.09 546088.74 18.00 3688.28 88.35 MWD 8100.00 101.44 293.34 6421.82 -541.34 -3773.37 5969080.73 546065.82 18.00 3711.83 89.25 MWD 8125.00 101.39 297.93 6416.87 -530.74 -3795.45 5969091.18 546043.66 18.00 3734.75 90.16 MWD 8128.24 101.38 298.52 6416.23 -529.24 -3798.25 5969092.66 546040.86 18.00 3737.67 91.07 MWD 8150.00 99.64 294.95 6412.26 -519.62 -3817.36 5969102.16 546021.69 18.00 3757.54 244.00 MWD 8175.00 97.60 290.90 6408.51 -510.00 -3840.12 5969111.63 545998.87 18.00 3781.05 243.35 MWD 8200.00 95.52 286.88 6405.65 -501.96 -3863.61 5969119.51 545975.33 18.00 3805.16 242.74 MWD 8208.24 94.83 285.56 6404.91 -499.67 -3871.49 5969121.75 545967.43 18.00 3813.21 242.28 MWD 8225.00 94.51 283.57 6403.54 -495.47 -3887.66 5969125.84 545951.24 12.00 3829.68 260.70 MWD 8250.00 94.01 280.60 6401.69 -490.25 -3912.03 5969130.90 545926.83 12.00 3854.42 260.54 MWD 8275.00 93.50 277.64 6400.05 -486.29 -3936.66 5969134.69 545902.18 12.00 3879.30 260.32 MWD 8300.00 92.98 274.68 6398.64 -483.61 -3961.47 5969137.20 545877.35 12.00 3904.25 260.12 MWD 8325.00 92.45 271.73 6397.46 -482.22 -3986.40 5969138.43 545852.42 12.00 3929.20 259.96 MWD 8350.00 91.92 268.77 6396.50 -482.11 -4011.38 5969138.38 545827.44 12.00 3954.10 259.82 MWD 8375.00 91.38 265.82 6395.78 -483.29 -4036.34 5969137.03 545802.49 12.00 3978.86 259.70 MWD 8400.00 90.84 262.87 6395.30 -485.75 -4061.21 5969134.40 545777.64 12.00 4003.42 259.62 MWD 8403.24 90.77 262.49 6395.26 -486.17 -4064.42 5969133.97 545774.43 12.00 4006.58 259.56 MWD 8425.00 90.77 265.10 6394.96 -488.52 -4086.05 5969131.47 545752.82 12.00 4027.93 90.00 MWD 8450.00 90.76 268.10 6394.63 -490.00 -4111.00 5969129.82 545727.88 12.00 4052.65 90.03 MWD 8475.00 90.76 271.10 6394.30 -490.18 -4136.00 5969129.48 545702.89 12.00 4077.54 90.07 MWD 8500.00 90.75 274.10 6393.97 -489.05 -4160.97 5969130.45 545677.92 12.00 4102.51 90.11 MWD 8525.00 90.74 277.10 6393.64 -486.61 -4185.84 5969132.72 545653.03 12.00 4127.50 90.15 MWD 8550.00 90.73 280.10 6393.32 -482.87 -4210.56 5969136.29 545628.29 12.00 4152.45 90.19 MWD 8575.00 90.72 283.10 6393.01 -477.85 -4235.04 5969141.15 545603.78 12.00 4177.28 90.23 MWD 8600.00 90.70 286.10 6392.70 -471.55 -4259.23 5969147.29 545579.55 12.00 4201.92 90.27 MWD 8603.24 90.70 286.49 6392.66 -470.64 -4262.34 5969148.18 545576.44 12.00 4205.10 90.31 MWD 8625.00 90.70 283.88 6392.39 -464.94 -4283.34 5969153.74 545555.40 12.00 4226.52 270.00 MWD 8650.00 90.70 280.88 6392.09 -459.58 -4307.75 5969158.93 545530.96 12.00 4251.30 269.97 MWD 8675.00 90.69 277 .88 6391.78 -455.51 -4332.41 5969162.84 545506.27 12.00 4276.23 269.93 MWD 8700.00 90.69 274.87 6391.48 -452.74 -4357.25 5969165.45 545481.41 12.00 4301.21 269.90 MWD 8725.00 90.68 271.87 6391.19 -451.26 -4382.21 5969166.75 545456.45 12.00 4326.20 269.86 MWD ConocJP'hillipS . . Baker Hughes INTEQ Baker Hughes INTEQ Planning Report .,. (NTEQ Survey 8750.00 90.67 268.87 6390.89 -451.10 -4407.20 5969166.75 545431.46 12.00 4351.11 269.82 MWD 8775.00 90.66 265.87 6390.60 -452.25 -4432.17 5969165.44 545406.50 12.00 4375.89 269.79 MWD 8800.00 90.64 262.87 6390.32 -454.70 -4457.04 5969162.83 545381.65 12.00 4400.45 269.75 MWD 8803.24 90.64 262.49 6390.29 -455.11 -4460.26 5969162.39 545378.44 12.00 4403.62 269.72 MWD 8825.00 90.64 265.10 6390.04 -457.46 -4481.89 5969159.90 545356.83 12.00 4424.96 90.00 MWD 8850.00 90.64 268.10 6389.76 -458.95 -4506.84 5969158.25 545331.89 12.00 4449.69 90.03 MWD 8875.00 90.63 271.10 6389.49 -459.12 -4531.83 5969157.90 545306.90 12.00 4474.57 90.06 MWD 8900.00 90.63 274.10 6389.21 -457.99 -4556.80 5969158.87 545281.92 12.00 4499.55 90.10 MWD 8925.00 90.62 277.10 6388.94 -455.55 -4581.68 5969161.14 545257.03 12.00 4524.54 90.13 MWD 8950.00 90.61 280.10 6388.67 -451.81 -4606.39 5969164.72 545232.30 12.00 4549.49 90.16 MWD 8975.00 90.60 283.10 6388.41 -446.79 -4630.88 5969169.58 545207.78 12.00 4574.32 90.19 MWD 9000.00 90.59 286.10 6388.15 -440.49 -4655.07 5969175.72 545183.55 12.00 4598.96 90.23 MWD 9003.24 90.58 286.49 6388.12 -439.58 -4658.18 5969176.60 545180.44 12.00 4602.14 90.26 MWD 9025.00 90.79 283.88 6387.86 -433.88 -4679.18 5969182.16 545159.40 12.00 4623.55 274.50 MWD 9050.00 91.02 280.89 6387.46 -428.52 -4703.59 5969187.36 545134.96 12.00 4648.34 274.47 MWD 9075.00 91.25 277.90 6386.97 -424.44 -4728.24 5969191.28 545110.28 12.00 4673.26 274.42 MWD 9100.00 91.48 274.91 6386.37 -421.65 -4753.08 5969193.90 545085.43 12.00 4698.24 274.36 MWD 9125.00 91.70 271.91 6385.68 -420.17 -4778.02 5969195.22 545060.48 12.00 4723.22 274.29 MWD 9128.24 91.73 271.53 6385.58 -420.07 -4781.26 5969195.30 545057.24 12.00 4726.45 274.21 MWD 9150.00 91.73 274.14 6384.93 -418.99 -4802.98 5969196.23 545035.51 12.00 4748.19 90.00 MWD 9175.00 91.72 277.14 6384.17 -416.54 -4827.85 5969198.52 545010.64 12.00 4773.17 90.08 MWD 9200.00 91.71 280.14 6383.43 -412.78 -4852.55 5969202.11 544985.91 12.00 4798.11 90.17 MWD 9225.00 91.69 283.14 6382.68 -407.74 -4877.02 5969206.99 544961.41 12.00 4822.92 90.26 MWD 9250.00 91.67 286.14 6381.95 -401.42 -4901.19 5969213.14 544937.20 12.00 4847.56 90.35 MWD 9275.00 91.65 289.15 6381.23 -393.85 -4925.01 5969220.56 544913.34 12.00 4871.94 90.44 MWD 9300.00 91.62 292.15 6380.51 -385.04 -4948.39 5969229.21 544889.90 12.00 4896.00 90.52 MWD 9325.00 91.58 295.15 6379.81 -375.02 -4971.28 5969239.08 544866.95 12.00 4919.68 90.61 MWD 9350.00 91.54 298.15 6379.13 -363.81 -4993.61 5969250.14 544844.54 12.00 4942.90 90.69 MWD 9375.00 91.50 301.15 6378.47 -351.45 -5015.33 5969262.35 544822.74 12.00 4965.61 90.77 MWD 9400.00 91.46 304.15 6377.82 -337.97 -5036.37 5969275.69 544801.62 12.00 4987.75 90.85 MWD 9403.24 91.45 304.54 6377.74 -336.14 -5039.04 5969277.50 544798.93 12.00 4990.57 90.93 MWD 9425.00 91.45 301.93 6377.19 -324.22 -5057.24 5969289.30 544780.66 12.00 5009.73 270.00 MWD 9450.00 91.44 298.93 6376.56 -311.56 -5078.78 5969301.81 544759.03 12.00 5032.30 269.93 MWD 9475.00 91.43 295.92 6375.93 -300.05 -5100.96 5969313.17 544736.78 12.00 5055.40 269.86 MWD / 9500.00 91.42 292.92 6375.31 -289.72 -5123.72 5969323.35 544713.96 12.00 5078.97 269.78 MWD -nt f)?? , , Kuparuk D08CTD BOP configuration 2"CT . Well 18-13 Rig Floor KB Elevation I 1,3" 5000 psi v A Lubricator ID = 6.375" with 6" Otis Unions I: 1/16" 5000 psi BOP's. ID = 7.06" 71/16" 5000 psi, RX-46 1.114 Turn L T Valve 71/16" 5000 psi RX-46 ~ 17 1/16" 5000 psi (RX-46) or 4 1/16" 5000 psi (RX-39) It Swab Valve Tree Size -+ SSV I Master Valve _ I Base Flange Page 1 N ~ KRU 1 B..13L2 Proposed Producer 2050450 SFD ~ . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Kiet1 //5 -13 ¿ z- PTD# 2Dç~óc/5 ./" Development Service CHECK WHAT APJ»LJÊS ADD-ONS (OPTIONS) MULTI LATERAL c,// (Jf API Dum ber last two. (2) digits are between 60-69) Exploration Stratigraphic "CLUE"· Tbe permit is for a Dew ~e))þore segmeDt of I eJ:istiDg weD ..~ ID. ~ / 3 . Permit No,I7'~S-APJ No. 5-" ð2."l~2~ ~1:$.ó:J Production. sbould continue to be repoJ1ed as a fUDctioD' of tbe origioal API Dumber. stated above. . HOLE ]0 accordaDce witb' 20 AAC 25.005(1), ~J records, data aDd Jogs acquired .for the pilot bole must be clearly difJereDtiated ïD botb Dame (name OD permit plus PH) .' aDd API Dumber (SO 70/80) from records, data aDd Jogs acquired for well (pame on permit). PD..OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subjed ·to fuU compliaDce witb 20 AAC 25~055~ Approval to peñorate aDd produce is cODtiDleDt UpoD issuance of a copsenatioD order approviDg a spacing . eJ:ceptioD. (Company Name) assumes tbe liability or all)' protest to tbe spaciDg .~J:ceptioD tbat may occur. All dry ditch sample sets submitted to tbe Commission must be iD no greater tbaD 30' sample intervals from below tbe permafrost or from where samples are first caught aDd ] 0' samplebiter-vals through target ~ODes. Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNlr 1 B-13L2 Program DEV PTD#: 2050450 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType DEV / PEND GeoArea 890 _. Unit 11160 On/Off Shore On 1 PfJrmitfee attached_ _ _ _ _ _ _ _ _NA _ _ _ Multilateral WelLbore; fee waived per 20_AAO 25_.Q05(e) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Lease number _appropriate_ _ _ _ _ _ _ _ _ _ _ No _ CorrectfJd omissioll onA07: top _of proctuçtive jlltervaJinADL025648,"(Q io ADi... 025_647 _ 3 .U_nique welln_a!11e_aod oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ 4 Well IQcated ina defined _pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YfJS _ _ _ _ Kuparuk Hiver Qil ~o_ol. governed by Con_servatipo Order 1'10.4320 _ _ 5 WelllQcated properdistaoce from driJliog unitbpundal)'_ _ _ _ _ _ _ _ Yes _ Conservatioo Ord_er 1'10.4320 contain$ no spacing restrictions with respectto drilling _uoit bo_uoctarie!;. _ _ 6 WelUQcated pr_operdistaoce_ from other wells _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ YfJS _ _ _ _ COllservatioo Ord_er 1'10.4320 ha_s_np jnterwellspacillgJe!;trjctiOllse Wellbprewill be more thao 5QO' frQm _ _ 7 _S_utficientacreageavailable indriUiog unjt Yes _ _ _ an_ extemal prope_rty lillewhereownership orJalldOWllership_chan~es. _ _ _ _ _ _ _ _ _ 8 Ifdeviated, is weJlbQre platincJu_ded _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ 90J)er_ator ollly affected party _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _OJ)erator has_apprppriate bond inJorce _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ 11 PfJrmit cao be issued withQut conservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _YfJS _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 PfJrmit cao be issued withQut actministratille_apprpvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ SFD 3/31/2005 13 Can permit be approved before 15-day wait Yes 14 WelUQcaled within area alldstrataauthorized by_lojectipo OrdfJr # (putlO# incommfJots) (for_ NA _ _ _ _ _ _ _ _ 15 _AJlwells_within.1l4_mile_are.a_ofreviewid_eotified(For!;ervjc_ewellonly). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ __ 16 Pre-produ_cect iojeçlor; duration of pre-J)roduction IfJSS than_ 3 mOllths_ (For service well QnJy) . NA 17 ACMP Fïndjng_ofCQnsi$teocy.has been Jssued_for this project _ NA _Multi/ateralwellþpre _ _ _ _ _. _ _ _ _ _ __ 18Cpoductor string_prQvided _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ NA _ _ CQllductorsetio original well, 18-13_0 94_-Q5.5). _ _ 19 .Surface ca!;ing protects alLknowll USQWs _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ NA _ All aquifers ex_empted,AOCFR 147.1 Q2 (b).(3).. 20 .CMT v_ol adequateJo circulateon_conductor_& surfcsg _ . . NA _ _ _ Surface ca.sing setjll Qriginalwell. 21 .CMT vol adequateJo tie-inlQngstring to surf C!;g. _ _ _ _ _ _NA _ _ J=>roduction_ casiog se_t inorginaJ well, 22CMT will cover_all koownproductive hQri¡!:Qn.s_ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ Slotte_dlioer _COJ11pletioo plaoned. 23 _C.asiog desigos adeQuate for C,T~ B _&_ permafrost _ _ _ _ _ _ . _ _ _ _ _ . Yes _ _ _ _ _ _ _ _ _ _ _ _ . _ 24 _Ädequatetankage_one_serve pit _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _Y_es _ Rig is_e_quippedwith $teeLpits. NQ reser\le_pjtJ)lanoed, All waste to_apprpve_d_disPQsal_ well(s). _ _ _ _ 25 Jfare-drill, hasa 10A03 fQr abandOllment befJO apprQved _ . _NA _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . 26 _Adequatewellbore separatjo_n_proJ)osed _ _ _ _ _ _ . . _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ .YfJS _ _ _ _ . _ _ Oire.ctiQnalprQP9Sal include_de _16-.131.,2_ will be_ sJeered_d_ue west._ PrOposfJd Btii... [s_NE_ Qf JA-D4.. _ _ _ _ _ _ _ _ . . 27 Jfdivel"ter.required, dQes itmeel reguJations_ _ _ . _ NA _ _ _ 60~ stack will a1r_eadybejn placee _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 28 Drilliog f]uidprogram sc::.hematic_& eCl-uipJistadeCl-uatfJ_ _ . . _ _ _ _ . . _ _ YfJS _ . _ _ _ EMW_uJ)jo 11.8 expected. Pressures will be CQntrolled uSiog ctyoamic overbalance tech_nique. Re_serve Wtmud _ 29 _BOPEs,do they meet reguJation _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ .YfJS _ _ _ _ _ wilJ be av_aiJaÞlein storage at the.rig._ _ _ _ _ _ _ _ _ _ 30 _BOPE_press ra_tiog approp(Îate;tesHo(puJ psig in_comments)_ . _ _ _ _ _ . . _ _ Yes. . MAS~ calcuJate_d_at 3346psie 40QO_spiBQF> testJ)lanoed, . _ _ _ _ _ . _ _ _ _ _ _ 31 Choke manifold cQmpJies w/APt RF>-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ 32 WQrk will occ_ur withoutoperationshutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 J!;pre!;ence_QfH2Sgas_probable _ _ _ _ _ _ _ _ _ YfJS _ _ _1Bpadi!;an_1-I2Spad._ Mud ShoUld pre_etude tl2Sonrig, High_assellsor$aodalarrns._ 34 Mechanicalcoodjtioo of wells within AOR verifiect (For_ s_ervice welJ only) _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Administration Engineering Appr Date rEM 3/31/2005 þ~ Geology Appr SFD Date 3/31/2005 Geologic Commissioner: lJ/s Well bore seg Annular Disposal ~ . ~ - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e - - - - - - - 35 PfJrmit cao be issued w!o_ hydrogen_ s_ulfide meaS.ures _ _ _ _ _ _ _ _ 36 _D_ata_preseoted on_ pote_ntial pveJpres_sure _Zone$ _ _ _ _ _ _ _ _ 37 _SfJismicanalysjs Qf shaJlow gas_zooes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 38 _SfJabedconditipo survey (if Off-!;hore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ CQntact namelphOlleJor_weelsly prpgre!;s_reports [exploratpl)'only]. _ . . . _ _ _ No _ . . OrigillaJ weILb_ore_h_as measure_d_80 ppm _H2S._ ti2$ measures required, _ _ _ _ . . _ . . YfJS _ _ . . _ _ _ Expected rfJservojr J)ressure is1 j.8 ppg EMW; wiJI be drilled with CQiled Tubing _and 9.2 ppg mud using. NA _ . . ov_erbalaoœd pressure driJling technjques lo_ac/)iev_e.12J J)pg ECO. _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ - - - - - - - - - - - - - Date: Engineering Commissioner: PUbli~~ comm;";b:;- Da~ ~ Date 1-//~ (]tJ- +-1-05" . . 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 simplìfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. .. . . . **** REEL HEADER **** MWD 06/08/09 BHI 01 RECE'\lr~' LIS Customer Format Tape AUG J' 'lip, Alaska Oft &GasCOI i;' Andmorage **** TAPE HEADER **** MWD 05/04/19 878703 01 2.375" CTK .. . '¡'¡v")1,,i; *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! !! ! !!! !!! !! ! ! ! !!!!!!!! ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7371.0000: STOP.FT 9503.0000: 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: ,Farameter Information Block #MNEM.UNIT Value #--------- ------------------------- Remark File Version 1.000 Extract File: ldwg.las 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. 1B-13L2 Kuparuk River Unit 70 deg 19'40.269"N 149 deg 35'45.028"W North Slope Borough Alaska Baker Hughes INTEQ 2.375" CTK 19-Apr-05 500292246861 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks Q06--C:l-lS- I it Od-G 09 llN 10E MSL o RKB 102 KB 102 -'N/A o N/A DIRECTIONAL 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 . . (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is real time data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the ~Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, and Downhole Weight on Bit), a Directional and Gamma Ray Sub, and a Hydraulic Orienting Sub, with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The Sidetrack was drilled from 1B-13 through milled window in 5" liner. Top of Windo~ 7366.4 ft.MD (6300.3 ft.SSTVD) Bottom of Window 7371.2 ft.MD (6304.1 ft.SSTVD) (8) The interval from 9479' MD (6390.3' SSTVD) to 9503' MD (6394.5' SSTVD) was not logged due to sensor bit offset at TD. (9) Tied to 1B-13 at 7200 ft.MD (6180.4' SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10800.8, 10799.7, -1.03906 Tape Subfile: 1 68 records... Mi~illi~~ 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 1B-13L2 5. xtf 150 ConocoPhillips Alaska Inc. 1B-13L2 Kuparuk River Unit North Slope Borough Alaska *** LIS COMMENT RECORD *** .. ' ! !! !!!!!!!!!!! ! ! ! !! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO . . MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR 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) Dat~ 'specification Block Sub-type is: 1 FRANE SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 51 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7371.000000 9503.000000 0.500000 feet **** FILE TRAILER **** Tap~~S~þfile: 2 60 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 IB-13L2 . xtf 150 ConocoPhillips Alaska In IB-13L2 ~ ' . . -. . FN COUN STAT Kuparuk River Unit North Slope Bora 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 ROPS GRAX ROPS 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: 0.250000 Frame spacing units: [F ] N~nb~' 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 ROPS MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 103 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7360.000000 9503.000000 0.250000 feet **** FILE TRAILER **** -. . Tape Subfile: 3 112 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/04/19 878703 01 . **** REEL TRAILER **** MWD , Q6/,oS/09 BHI 01 Tape Sub file: 4 Minimum record length: Maximum record length: .. ' '-"-i... .. \ . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS ~, .. , .. . 'II . . Tapès~bfile 2 is type: LIS DEPTH 7371.0000 7371.5000 7400.0000 7500.0000 7600.0000 7700.0000 7800.0000 7900.0000 8000.0000 8100.0000 8200.0000 8300.0000 8400.0000 8500.0000 8600.0000 8700.0000 8800.0000 8900.0000 9000.0000 9100.0000 9200.0000 9300.0000 9400.0000 9500.0000 9..5,03.0000 GR 105.2500 105.0800 162.4600 155.3100 160.0800 95.0300 66.0900 106.9500 58.6000 174.3800 172 . 0000 74.2600 65.0700 58.9400 117.5100 108.3200 62.6800 65.0700 91. 2900 74.2600 78.0100 103.2100 83.4600 -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 52.2000 77.0700 83.2100 81. 9800 66.4500 78.7000 73.3100 18.0100 98.6800 132.4300 17.8400 92.0000 69.4300 79.2100 101.3600 137.9400 81. 6200 171. 7000 177.4300 113.8400 73.0800 125.8000 -999.2500 7371.000000 9503.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 7360.0000 82.7800 -999.2500 7360.2500 84.2250 -999.2500 7400.0000 162.4600 52.2000 7500.0000 155.3100 77.0700 7600.0000 160.0800 83.2100 7700.0000 95.0300 81.9800 7800.0000 66.0900 66.4500 7'9'00.0000 106.9500 78.7000 8000.0000 58.6000 73.3100 8100.0000 174.3800 18.0100 8200.0000 172.0000 98.6800 8300.0000 74.2600 132.4300 8400.0000 65.0700 17.8400 8500.0000 58.9400 92.0000 8600.0000 117.5100 69.4300 8700.0000 108.3200 79.2100 8800.0000 62.6800 101. 3600 8900.0000 65.0700 137.9400 9000.0000 91. 2900 81. 6200 9100.0000 74.2600 171.7000 9200.0000 78.0100 177.4300 9300.0000 103.2100 113.8400 9400.0000 83.4600 73.0800 9500.0000 -999.2500 125.8000 9503.0000 -999.2500 -999.2500 Tape File Start Depth 7360.000000 Tape File End Depth 9503.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet , . , . .. . ~ . . Tape Subfile 4 is type: LIS .. . .. .