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206-163
RECEIVED ' STATE OF ALASKA JAN 0 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANI7t1QCC 1a.Well Status. Oil ❑ Gas ❑ SPLUG ❑ Plugged Mv Abandoned Err 11}0 uspended ❑ 1b Well Class 20AAC 25.105 ri)lsl 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service E StratigraphicTest❑ 2 Operator Name5 Date Comp.,Susp, 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orban December 7,2014 206-163/314-432 ' 3.Address 6.Date Spudded 13 API Number P.O.Box 100360,Anchorage,AK 99510-0360 February 18,2007 50-103-20262-02 4a Location of Well(Governmental Section) 7.Date TD Reached 14 Well Name and Number Surface: 117'FNL,996'FEL,Sec.3,T9N, R7E, UM March 4,2007 KRU 2N-337B ' Top of Productive Horizon 8. KB(ft above MSL): 151'RKB 15 Field/Pool(s) 2533'FSL,2239'FEL,Sec.4,T9N, R7E,UM GL(ft above MSL): 123'AMSL Kuparuk River Field Total Depth 9.Plug Back Depth(MD+TVD) 2416'FSL,2603'FEL,Sec.4,T9N,R7E, UM 2852'MD/2312'TVD Tarn Oil Pool ' 4b Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+TVD) 16 Property Designation Surface' x-460597 y- 5911892 Zone-4 9950'MD/5506'TVD ADL 375074 - TPI• x-454065 y- 5909299 Zone-4 11.SSSV Depth(MD+TVD) 17.Land Use Permit Total Depth: x-453700 y- 5909184 Zone-4 none 4293 18 Directional Survey Yes ❑ No❑✓ 19 Water Depth,if Offshore. 20 Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1222'MD/1198'TVD 21 Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22 Re-drill/Lateral Top Window MD/TVD caliper, CBL not applicable 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.6# _ H-40 28' 108' 28' 108' 24" 103 sx AS 1 7.625" 29.7# L-80 28' 2858' 28' 2313' 9.875" 274 sx AS III LW,240 sx CI G,60 sx AS I 5.5" 15 5# L-80 29' 9932' 29' _ 5492' 6.75" 240 sx Class G 2993.53' 3.5" 9.3# L-80 27' 9151' 27' 4913' 6.75" included above 3250' 24 Open to production or injection? Yes ❑ No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/TVD) _4"`A .1" 3.5" 3250'-9141' none perforations plugged off ' I 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC -12e.,M r Was hydraulic fracturing used during completion? Yes Not y F� , DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i.. _! • -�,.�,.,,,� cement retainer @ 9110' 15 bbls Class G Cement plug @ 4500' 83 bbls Class G CIBP @ 3046' kickoff plug 25 bbls 17.0 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) plugged Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE 1 filly Form 10-407 Revised 10/2012 177-1- 2`b// CONTINUED ON REVERSE 1' 4 II)/) Submit original only i( %_ A$£!vi JAN - 8 2U1Svu 29. GEOLOGIC MARKERS(List all formations and ma,.. .s encountered) 30 FORMATION TESTS NAME MD TVD Well tested? Yes E✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1222' 1198' needed,and submit detailed test information per 20 AAC 25 071 T-3 9366' 5065' T-2 base 9660' 5286' N/A Formation at total depth: Bermuda 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Scott Brunswick @ 263-4249 Email Scott A BrunswickL conocophillips.com Printed Name G. L.Alvord Title. Alaska Drilling Manager Signature A Phone 265-6120 Date t 45-12. 1.••;- INSTRUCTIONS 5-12tINSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29. Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Tarn 2N-33r 13 RigAbandonment ConocoPhillips p uFMC Kup Tarn Gen V Bruns.',ick x,2'15 16" Existing Cemented Conductor: 16" 62.6# H-40 108' MD , , RKB Reference 30 ft (Nordic 3) Existing 7-518"Stage Collar @ 1,450'(be aware when trippiny iii P &out) 4- 17.0 ppg cement plug TOC©2,658'MD Existing Surface Casing: 5-1/2" Casing Cut#2 @ 2,635' MD 7-518"29.7# L-80 BTCM 17.0 pg 2,858.4' MD/ 2,312.7' TVD @ 68° ,,, Cement Kickoff Plug LOT to 14.3 ppg EMW 12/6/2014 5-1/2" Casing Cut#1 @— 3,026' MD(10 ft above bottom of joint#144) CIBP @—3,046' MD (10' below top of joint 143) 9.8 ppg KWF circulated in by rig 1=1 Cut 3.5" Tubing @ 3,250' RKB KUP PROD 2N-337B ConocoPhillips n Well Attributes Max Angle&MD TD Alaska Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Atm(ftKB) r rxxrr;minit.r 501032026202 TARN PARTICIPATING AREA PROD 70.42 3,102.59 9,950.0 ••• Comment H2S(ppm) Date Annotation End Date KB-G,d(R) -Rig Release Date 2N-337B,11/19201490937 AM SSSV:NIPPLE 30 7/1/2008 Last WO: 3/14/2007 29.25 3/14/2007 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..................................................... _ ..........Last Tag:SLM 9,750.0 6/27/2014 Rev Reason:CEMENT,TBG PUNCH, hipshkf 11/18/2014 HANGER;27.0 I t1 I 1 PERFORATE,CUT TBG Casing Strings Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 7 CONDUCTOR 16 15.062 29.2 108.0 108.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -1- SURFACE 75/8 6.875 29.3 2,858.4 2,312.7 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...'Grade Top Thread LINER 5 5"x 3.5" 5 1/2 4.950 29.2 9,931.9 5,492.3 15.50 L-80 BTC Mod Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) ,A.A.0 CONDUCTOR;29.2-108.0 292 29.2 0.00 HANGER FMC Casing Hanger&pup 4.950 9,138.2 4,904.5 48.12 SBE 'Baker 80-40 Seal bore Extension 4.000 Tubing Strings NIPPLE;518.3 Tubing Description String Ma...ID(in) Top IftKB) Set Depth Ift...Set Depth(ND)I...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 27.0 9,150.5 4,912.7 9.30 L-80 IBT Completion Details Nominal ID Top(ftKB) Top(TIM)(ftKB) Top Incl(') Item Des Com (in) 27.0 27.0 0.00 HANGER FMC Gen 5 Csg Hgr 3.500 / 516.3' 515.8 7.19 NIPPLE Camco 2.875'DS"Nipple EUE BxP 2.875 9,015.7 4,824.7 50.56 SLEEVE-C Baker Slide Sly CMU w/2.812"DS Profile(Closed) 2.812 A9,066.9 4,857.6 49.58 LOCATOR 80-40 Seal Assy Locator 2.992 9,067.3 4,857.8 49.57 SEAL ASSY 80-40 Seal Assy-SPACED OUT 2 FT 3.000 SURFACE;29.32,658.1-A 9,069.4 4,859.2 49.53 PBR 80-40 Polish Bore Receptacle 3.000 TUBING CUT;3,250.0 9,0829 4,8680 49.27 ANCHOR KBH22 Anchor Seal Assy 2.780 9,083.7 4,868.4 4926 PACKER SABL-3 PKR 3-1/2 X 5-12 2.780 9,131.8 i 4,900.2 48.26 NIPPLE HES XN Nipple.2.75",w/2.635"NO GO 2.750 GAS LIFT;3,391.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) APERF;3.965.0J,975,0 3,250.0 2,452.0 70.04 TUBING CUT JET CUT TUBING W/2.7"JET CUTTER 11/15/2014 8,405.0 4,497.2 64.77 TUBING SHOT TBG PUNCH FROM 8405-8415,4SPF,0 11/5/2014 PUNCH DEG PHASING GAS LIFT;6,230.1 9,110.0 4,885.7 48.72 CEMENT CEMENT RETAINER 11/1/2014 RETAINER Perforations&Slots GAS LIFT;8,225.6 Shot Dens Top(ND) Btm(TVD) (shotsrf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 3,965.0 3,975.0 2,729.1 2,733.5 S-3,2N-337B 11/12/2014 4.0 APERF 2"CIRCULATION TUBING PUNCH;8,405.0 CHARGES,4SPF,00 DEG PHASING 9,600.0 9,615.0 5,240.7 5,252.1 S-3,2N-337B 4/1112007 6.0 IPERF 2"HSD HJ,60 deg phase(9615'MD=5250' GAS LIFT;8,993.6 TVD) Stimulations&Treatments Min Top Max Btm SLEEVE-C;9.015.7 Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 9,600.0 9,615.0 5,240.7 5,252.1 FRAC 5/7/2007 248,764 8 16/20 CL 12ppa ON PERFS Cement Squeezes Top(ND) Btm(ND) LOCATOR;9066.9 Top(MB) Btm(ftKB) (ftKB) MB) Des Start Date Com SEAL ASSY;9,067.3 9,110.0 9,931.0 4,885.7 5,491.6 Cement Plug 11/1/2014 PUMP 15 BBLS THROUGH RETAINER.,4.4 BELS IN TUBING AND 6 BBLS IN IA PM;9,069.4 4,500.0 9,100.0 2,951.8 4,879.1 Cement Plug 11/82014 PUMP 83 BBLS OF CLASS G CEMENT DOWN TBG. ANCHOR;9,082.9 APPROX TO 4500'IN TUBING AND 4800'IN IA PACKER;9.063.7 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run CEMENT RETAINER;9,110.0 N Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,391.5 2,500.8 CAMCO KBG-2- 1 Gas Lift DMY DK-1A 0.000 0.0 3/12/2007 9 2 6,230.1 3,656.2 CAMCO 'KBG-2- 1 Gas Lift DMY DK-1A 0.000 0.0 3/12/2007 9 NIPPLE;9,131.8 3 8,225.6 4,423.7 CAMCO KBG-2- 1 Gas Lift DMY DK-1A 0.000 0.0 3/12/2007 9 4 8,993.6 4,810.7 CAMCO KBG-2- 1 Gas Lift OPEN BTM 0.000 0.0 6/29/2014 19 Notes:General&Safety TUBING SHOE;9,140.9 End Date Annotation 3/14/2007 NOTE:MONOBORE SIDETRACKED WELLBORE'B' 4/10/2007 NOTE:IDENTIFIED DAMAGED XN NIPPLE;DRIFTED THRU w/2.68"GAUGE RING 1/13/2011 NOTE:View Schematic w/Alaska Schematic9.0 (PERF;9,600RAC;9,A9,615.0 F600.0 LINER 5.5.x 3.5';29.2-9,931.9- rx 2N-337B WELL WORK SUMMARY DATE SUMMARY 5/11/2014 (AC EVAL)T POT PASSED, T PPPOT PASSED, BLEED AL LINE FOR BUR (AL LINE HEADER VALVE, BLOCK VALVE LEAK BY). IN PROGRESS. 5/21/2014 (AC EVAL) : SI TIFL (IN PROGRESS). 6/27/2014 TAGGED @ 9750' SLM; MEASURED BHP © 9770' RKB: MAX BHP 3715 PSI; BRUSH N FLUSH TBG (WITH 42B0 )TO 9130' RKB ( DID NOT SIT DOWN IN CMU);' DRIFT WITH 10' X 2 1/8" & 4'X 2.77' DUMMY DRIFT UNABLE TO GET PAST ANCHOR SEAL ASSEMBLY @ 9082' RKB. IN PROGRESS. 6/28/2014 DRIFT TO XN @ 9132' RKB WITH 10'X 2 1/8' & 6' x 2.75" DUMMY DRIFT; PERFORM SRIT UP TO 2BBLS/MIN (SEE PUMP REPORT) SET 2.75"XXN PLUG © 9132' RKB. IN PROGRESS. 6/29/2014 PERFORMED MITT (PASS); SET CATCHER © 9131' RKB & PULL OV @ 8994' RKB. JOB SUSPENDED UNTIL CIRC OUT CAN BE DONE. IN PROGRESS. 7/2/2014 STAGED EQUIP WHILE LRS LOADS TBG & IA WITH 200 BBLS DSL. LRS TO CMIT TO 2000 PSI. IN PROGRESS. 7/3/2014 PULLED CATCHER &2.75"XXN PLUG @ 9131' RKB. JOB COMPLETE. 10/30/2014 RIH LOCATE XN, CORRECT TO THE NIPPLE. PICK UP PAINT WHITE FLAG @ 9121.5, EOP @ FLAG 9112.5 PUMP 10 BBL'S DIESEL DOWN THE COIL UP THE IA TAKING RETURNS TO THE TIGER TAN K RETURN IN THE MORNING TO PUMP CEMENT. 11/1/2014 RIH SET CEMENT RETAINER AT 9110' MID ELEMENT, PUMP 15 BBL'S THROUGH THE RETAINER, UN STING AND LAY IN 4.4 BBL'S IN THE TUBING, PUMP 6BBLS INTO THE IA. CLEANED OUT DOWN TO 8484' CHASE OUT OF HOLE AT 80% SLOWING FOR ALL JEWELRY. LEAVE SHUT IN FOR 48 HRS BEFORE TAGGING ****TURN OVER TO DSL**** 11/4/2014 TAGGED CMT @ 8678' SLM. MITd TBG & IA EACH, 2000 PSI, PASSED. DRIFTED TBG FOR GYRO TO 8678' SLM. READY FOR E/L. 11/5/2014 LOGGED AN RCBL FROM 8665'TO 8000'. DETERMINED TOP OF CEMENT TO BE AT APPROXIMATELY 8500'. LOGGED REPEAT PASS FROM 8665'TO 8400'. RAN IN WITH A 10' TUBING PUNCH PERF GUN, AT 4 SPF AND 0 DEG PHASING. PERFORATED INTERVAL 8405' TO 8415'. FIRED GUN AT A CCL STOP DEPTH OF 8401.1 WITH A CCL TO TOP SHOT OFFSET OF 3.9'. A PRESSURE CHANGE IN THE TUBING FROM 1000 PSI TO 500 PSI WAS OBSERVED AFTER FIRING THE GUN. 11/6/2014 INJECTIVITY TEST TUBING TO IA ESTABLISHED RATE OF 2 BPM WITH 1400 PSI PUMP PRESSURE. JOB COMPLETE 11/7/2014 PERFROM GYRO SURVEY WITH GYRODATA GYRO TOOLS. SURVEYED GYRO FROM SURFACE TO 8438', AND PERFORMED REPEAT GYRO SURVEY FROM 8438'TO SURFACE. 11/8/2014 PUMPED 83 BBLS OF 15.8 PPG CLASS G CEMENT DOWN TBG TAKING RETURNS FROM IA TO TANKS. CHASED CEMENT WITH 34 BBLS OF DIESEL LEAVING CEMENT TOP IN TBG @ —4500'. WOC FOR —48 HOURS FOR TAG &TEST. NOTE: IA STILL FREEZE PROTECTED WITH DIESEL. IN PROGRESS. 11/9/2014 (PRE RWO): FUNCTION TEST LDS'S AND GN'S (ALL FUNCTIONED). T-POT (PASSED), T- PPPOT (PASSED), IC-POT (PASSED), IC-PPPOT (PASSED). 11/10/2014 MIT TBG PRE MIT=T/I/O 0/50/260 INITIAL MIT=T/I/O 2040/5u/260 15 MIN PSI =T/I/O 2000/50/260 30 MIN PSI =T/I/O 1990/50/260 MIT TBG PASSED JOB COMPLETE MIT IA PRE MIT=T/I/O 0/50/260 INITIAL MIT T/I/O 250/2025/320 15 MIN PSI =T/I/O 250/2000/320 30 MIN PSI =T/I/O 250/2000/320 MIT IA PASSED BLEED TBG AND IA BACK TO PRE MIT PSI JOB COMPLETE. ***SW WAIVED*** 11/12/2014 RUN 1: RIH W/ RCBL, GR, CCL. TAG TOP OF CEMENT IN TUBING AT 4060'. LOG RCBL FROM TAG TO 3250', NO CEMENT OBSERVED IN IA ABOVE 4060'. RUN 2: PERFORATE TUBING W/2" CIRCULATION CHARGES FROM 3965'TO 3975', PRESSURE ON TUBING DECREASED FROM 1000 PSI TO 400 PSI, IA INCREASED FROM 50 PSI TO 300 PSI IMMEDIATELY AFTER FIRING. LOGS CORRELATED TO TUBING DETAIL RECORD DATED 13 MAR 2007 AT 3394' GLM. READY FOR PUMPING. 11/13/2014 INJECTIVITY TEST RIGGED UP TO TREE CAP PUMPED .8 BBL TBG PRESSURED UP TO 1900 PSI IA PRESSURED UP TO 1900 PSI WAITED 30 MINUTES...PRESSURES THE SAME BLEED OFF PRESSURES RDMO CALL DSO WITH RESULTS JOB INCOMPLETE 11/13/2014 INJECTIVITY TEST/ PUMPED 25 BBLS DIESEL DOWN TBG. TAKING IA RETURNS TO 3N-339 /JOB COMPLETE 11/13/2014 DECISION MADE TO MOBILIZE OUT TO CUT AT A LATER DATE DUE TO DELAYS IN JOB 11/15/2014 MAKE TUBING CUT AT 3250'WITH 2.7"JET CUTTER. MAKE CUT AT CCL STOP DEPTH OF 3244.9' WITH A CCL TO CUT OFFSET OF 5.1'. JOB COMPLETE. READY FOR BPV. 11/28/2014 Continue rig move - Spot pit complex- Set cutting tank- Install berms - Hook up service lines - Take on brine- Install valves on OA& IA- Test mud lines - Pull BPV- RU to displace freeze protect diesel - Held Pre sud meeting - Displace freeze protect diesel w/9.8 ppg brine- Set TWC &test 11/29/2014 ND tree- NU BOP- change btm rams-Test BOPE- Pulled blanking plug &TWC- RU to pull 3 1/2"tbg - Service rig 11/30/2014 MU landing jt. into tbg hanger- Back out LDS - Pull tbg hanger to rig floor PU wt 52K- Pulled & LD 3 1/2"tbg - RU & Test hydril &VBR's w/4" & 5 1/2"test jts.- RU E line & run gauge ring/Junk Bskt- Change tools RIH & set Baker CIBP @ 3046' - POOH - RD E line- Pull wear bushing - RU to pull pack-off 11/30/2014 ***NABORS 9ES RIG JOB*** RUN 1: DRIFT 5.5" CASING WITH 4.75" DRIFT RING AND JUNK BASKET TO 3113'. LOG CCL/GR CORRELATION OUT OF HOLE. CORRELATE TO 5.5" CASING TALLY. RUN 2: SET BAKER 4.30" CIBP AT 3046' WITH BAKER 20 SETTING TOOL, LOG CORRELATED TO 5.5" CASING TALLY. RUN 3: CUT 5.5" CASING AT 3026' USING WELLTEC MECHANICAL CUTTER. LOG CORRELATED TO 5.5" CASING TALLY. 12/1/2014 RU & Pull Pack-off- RU Dutch riser- RU E line & RIH w/WellTech cutter& cut casing © 3026' - POOH & RD- MU landing jt to csg hanger- Displace well w/9.8 ppg brine &work casing free - Shut in well Observed 350 psi on DP side & 340 psi on Csg - Circ well © 5 bbls/min Surface to Surface thru choke - Shut in - DP side 390 psi Csg 390 psi (lost 63 bbls) build volume - Confer w/Drilling engineer& Drilling Superintendent 12/2/2014 Monitor well & pump every mins to avoid freeze up-Circ w/9.8 ppg attempting to lower Dp & csg pressure-Open chok )led off 6 bbls-Circ btms up no gas- BI( 17 bbls in 14 mins Bled off 7 bbls/in 18 mins. pressures coming down -Opened Annular preventer- monitor well -circ btms up- LD landing jt&csg hanger- Blow down TD- Install Xo &TIW valve-circ&wt up to 10.0 ppg -observed well Static foe 11 mins- began oozing down flow line-Wt up to 10.2 ppg_ observed well static for 20 mins. then bagan to ooz down flow line 12/3/2014 Wt up to 10.4 ppg in pits- Displace well f/ 10.2 00g brine to 10.4 ppg brine- Monitor well 1 hr. Well static- Pull & LD 5 1/2" csg -Test BOPE - RU to run 3 1/2" cmt stinger 12/4/2014 RIH w/3 1/2"tbg (cmt stinger)to 902' PU & RIH w/4" DP to 3016'- Slip & cut drill line &service rig - RIH to 3041' Circ for cmt job- Set KO plug f/3041'to 2658' (calc top)w/25 bbls 17.0 ppg cmt POOH to 2616' -Close Hydril & hold pressure on cmt- POOH & LD 3 1/2"cmt stinger- MU Dutch riser for wireline 12/4/2014 LOGGED A 40 ARM CALIPER SURVEY FROM 1700'TO SURFACE 12/5/2014 RU E line & ran csg caliper log f/ 1600'- RD WL- PU &Std back 4" DP f/shed 90 jts- MU mule shoe- RIH picking up remaining 4" DP f/shed -Tagged top of cmt plug © 2635'- Circ btms up- RU & pressure test 7 5/8" Casing & cmt plug to 2500 psi- Leaked off to 1800 psi in 30 mins. POOH w/ DP & mule shoe 12/6/2014 RIH w/Bakerpacker& set @ 2608'- Pressure test 7 5/8"csg above packer to 2500 psi (Good Test) POOH & LD packer-Clean &service rig -MU BHA# 1 - RIH to 1578'; Shallow test MWD tools- RIH to 2635' (top of cmt- Clean out cmt f/2635'to 2722' 12/7/2014 Drilled cmt f/2722'to 2886' (off of plug)drilled 20' new hole to 2906'-Change well over f/ 10.4 ppg brine to 9.8 ppg LSND- Performed LOT to 14.3 ppg EMW- Drill 6 3/4"x 7 1/2" hole f/2906' to 3450'-Opened UR @ 2858' Image P~ect Well History File Co~r 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. ~;" ~ - L ~~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: ;~.,cea iuuiiiiiuiiuui ~ R~~a~~,~,~ iiiuimwuiiuii DiG TAl. DATA OVERSIZED (Scannable) Diskettes, No. 1 ^ Maps: ^ Other, No/Type: ~ther Items Scannable by Y a Large Scanner ~~,~, l~ ~r ~~C~~ OVERSIZED (Non-Scannable) Date: ~~// ~-./ Project Proofing gY: Maria Date: `~ ~ Scanning Preparation _~ x 30 = BY; Maria ~ Date: ,~ Production Scanning ^ Logs of various kinds: ^ Other:: /s/ /s/ + ~ ~ =TOTAL PAGES~~ {Count does not include cover sheet) p/~/~ ~' /s/ t' f Stage 1 Page Count from Scanned File: ~~'!` ~ (Count does include cover sheet) Pa a Count Matches Number in Scanning Preparation: YES NO g ~ ~ /s/ ~ . BY: Maria Date: ~ ~ ~. Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s/ Scannin is com late at this point unless rescanning is required. III I I ~I () I II II I I III 9 P ReScanned III 111111 IIIII II III BY: Maria Date: /s~ Comments about this file: Quality Checked III II'I~I If~ II~t ~II 10/6/2005 Well History File Cover Page.doc • ! ~. ~ ,~ t _. ,,, ~_~ - ~~° 1p~ ` ~~:: y -. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 1~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2061630 Well Name/No. KUPARUK RIV U TARN 2N-337B Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20262-02-00 MD 9950 TVD 5506 Completion Date 4/11/2007 Completion Status 1-OIL Current Status 1-OIL UIC N - - _ _____ REQUIRED INFORMATION L' Mud Log No Samples No Directional Survey ~~ DATA INFORMATION Types Electric or Other Logs Run: GR / RES, DENS / NEU Well Log Information: Log/ Electr Data Digital Dataset T Med/Frmt Number Name D D Asc Directional Survey og Cement Evaluation C,ED C Las 15118~d Log I' pt 15118 Report: Final Well R „~og 15118 Formation h4iero-tma ~iog 15118 Formation Miere-I~a Log 15118 Lithology Cog 15118 Lithology tog 15118 Gas Analysis GL~og 15118 Gas Analysis ~g 15118 See Notes ~g 15118 See Notes C Lis 15135 zllnduction/Resistivity __ Log Log Run Scale Media No 5 Col 1 2 2 2 2 2 2 2 2 Col Col Col Col Col Col Col Col (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 2824 9950 Open 4/23/2007 9000 9760 Case 4/20/2007 SCMT, 2' HSD, SBHP 11- Apr-2007 2750 9950 Open 5/8/2007 Mud Log Data/Final Well Report, w/Graphics PDF, TXT, LAS 0 0 Open 5/8/2007 Final Well Report, Table of Content, Equip * Crew, Well Details, Geo Data, Press/Form Stregth, Drilling Data, Daily Reports, Formation Logs 2800 9950 Open 5/8/2007 MD Formation Log 2800 9950 Open 5/8/2007 TVD Formation Log 2800 9950 Open 5/8/2007 TVD Lithology Log 2800 9950 Open 5/8/2007 MD Lithology Log 2800 9950 Open 5/8/2007 MD Gas Ratio Log 2800 9950 Open 5/8/2007 TVD Gas Ratio Log 2800 9950 Open 5/8/2007 TVD Drilling Dynamics Log 2800 9950 Open 5/8/2007 MD Drilling Dynamics Log 2801 9950 Open 5/16/2007 LIS Veri, GR, FET, NPHI, NCNT,ROP DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2061630 Well Name/No. KUPARUK RIV U TARN 2N-3378 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20262-02-00 MD 9950 TVD 5506 Completion Date 4/11/2007 Completion Status 1-OIL 15135 LIS Verification _ _ __ i og Production (~og Induction/Resistivity og Induction/Resistivity ED C 17300t/See Notes Well Cores/Samples Information: Name 5 Blu 1 25 Col 25 Col Current Status 1-OIL UIC N 2801 9887 Open __ 5/16/2007 -- _ _- -_ __ 1 LIS Veri, GR, FET, NPHI, NCNT,ROP L 100 9605 Open 8/27/2007 PPL, Spin, Gradio, Pres, Temp 6-Aug-2007 2858 9950 Open 12/12/2008 MD ROP, EWR, DGR, ALD, CTN 6-Mar-2007 2311 5504 Open 12/12/2008 TVD EWR, DGR, ALD, CTN 6-Mar-2007 0 0 12!1212008 PDS, EMF and CGM of MD and TVD EWR logs Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y I~V Chips Received? ~7TT" Analysis 1~7'I~ Received? Comments: Daily History Received? ^ N Formation Tops ~ N Compliance Reviewed By: _ Date: ~__ ~ ~ o ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 2N-337B November 13, 2008 AK-MW-4878300 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-337B 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-103-20262-02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-103-20262-02 Digital Log Images 1 CD Rom 50-103-20262-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3.536 l o`~ Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~j ~ Si ned: ~`~`~~-_ ~ : ~'V i 26~ -lCv3 ~ 1 ~3~~ .. • • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ f~3 ~~, 33~ l~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 5, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, on Arend SAP 1 '~ 2007 Alaska Oii & Gacs~ e~eCwnmiss~on An ConocoPhillips Well Integrity Field Supervisor f. ~ E • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/7/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2N-320 199-001 4" n/a 4" n/a 2 9/5/2007 2N-321 198-173 6" n!a 6" n/a 2 9/5/2007 2N-323 198-071 1" n/a 1" n/a 1 9/5/2007 2N-325 198-163 10" n/a 10" n/a 2 9/5/2007 2N-326 200-155 9" n/a 9" n/a 3.5 9/5!2007 2N-337 206-163 6" n/a 6" n/a 1 9/5/2007 2N-339 198-100 8" n/a 8" n/a 2.5 9/5/2007 2N-341 198-103 3" n/a 3" n/a 1 9/5/2007 2N-342 207-068 18" n/a 18" n/a 4.5 9/5/2007 2N-343 198-092 4" n/a 4" n/a 2 9!5/2007 2N-345 204-034 9" n/a 9" n/a 3.5 9/5/2007 ~~~~~~'~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # E ~ ~ ~ ~~~~ ~,~(~ r 't 2007 ,~< < ~ ,~~ t:'~~rz~i~,i.~~i~aa7 ,.~~ ~ ,- ;,, ,, Log Description G~„~---- N0.4384 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 08/22/07 1R-27 11850425 FPIT 09/-/Oa 08/18/07 1 31-08 11839638 LDL 07128107 1 2M-19 11813070 INJECTION PROFILE 07129/07 1 3G-26 11813071 LDL - 07/30107 1 1R-18 11837482 SBHP/DDL ~- 07131107 1 1Y-01 11813072 INJECTION PROFILE UZC - 3 b 07131/07 1 2C-08 11813073 INJECTION PROFILE' 08101/07 1 3H-32 11837483 LDL 08/01/07 1 1Y-10 11837485 INJECTION PROFILE ' (~ / - 08/03107 1 3G-08 11813075 PRODUCTION PROFILE' _ (~ 08/04/07 1 1A-06 11837486 INJECTION PROFILE I-- 08104107 1 2N-337B 11837489 PRODUCTION PROFILE 08106/07 1 2U-08 11813076 LDL -- 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE /`6 - I 08/07107 1 2N-343 11745232 MEM INJECTION PROFILE ~ / 08108/07 1 2N-327 11837491 SONIC SCANNER ~ 08/08/07 1 2N-327 11837491 SONIC SCANNER-FMI 08/08/07 1 3K-01 11632749 PRODUCTION PROFILE (o - p 08112107 1 2X-04 11846430 INJECTION PROFILE - 1 08/13/07 1 2Z-29 11850419 SBHP SURVEY f - 08/13107 1 2X-19 11850420 SBHP SURVEY S"- 08113/07 1 1A-20 11850421 SBHP SURVEY 08/14/07 1 1F-13 11850422 SBHP SURVEY 08114/07 1 1H-10 11846432 SBHP SURVEY - 08/14/07 1 1Q-10 11846431 SBHP SURVEY - 08114107 1 2U-OS 11846433 INJECTION PROFILE 08/15107 1 2D-12 11846434 PRODUCTION PROFILE c - 08/16/07 1 2H-06 11846435 LDL 08/17/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. a~" Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, July 06, 2007 4:12 PM Ta: Jason Brink Cc: Thomas, Randy L Subject: 2N-3378 (206-163) Jason and Randy, 1 am reviewing the completion report for this well. Looks like there was fun fora{l throughout the rig work. No notice was needed regarding afl the difficulties encountered white drilling. Jason did send a message with regard to testing the annular after the weltbore squeeze. When it became necessary to ga to the major eEeanout operations though, 1 think some notice should have been given. This obviously was a change of plans. An email notice would have sufficed. En the future, when there are additions to plans such as this please make contact. CatE or message with any questions. Tom Maunder, PE AOGCC 10/19/2007 ConocoPhillips May 21, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Weli Completion Report for 2N-3376 Dear Commissioner: • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 r~~v~~'~ ~~~=~:`,' ~ ~ ?007 :': ~``~~ ~a~~="• Commission ~~~~~~ora~e ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Kuparuk well 2N-3376. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~_~ ~ IVED WELL COMPLETION OR RECOMPLETION REPOR1~~1aN~l~~r-~~~t~~ ~U~~~ossion 1a. Well Status: Oil a Gas Plugged ^ Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class;,,;,, C UfB~L~ Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. ~f 5. Date Comp., Susp., A~,i ~ ~~~ ~ / or Aband.: Mar 7 12. Permit to Drill Number: 206-163 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ,~f.0 February 18, 2007 13. API Number: 50-103-20262-02 4a. Location of Well (Governmental Section): Surface: 117' FNL, 996' FEL, Sec. 3, T09N, R07E, UM' 7. Date TD Reached: March 4, 2007 ~ 14. Well Name and Number: 2N-3376 At Top Productive Horizon: 2533' FSL, 2239' FEL, Sec. 4, T09N, R07E, UM 8. KB (tt above MSL): 151' AMSL ~ Ground (ft MSL): 123' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2416' FSL, 2603' FEL, Sec. 4, T09N, R07E, UM 9. Plug Back Depth (MD + ND): 9781' MD / 5377' ND Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 460597 ' y- 5911892 Zone- 4 10. Total Depth (MD + ND): - 9950' MD i 5506' TVD 16. Property Designation: ADL 375074 ' TPI: x- 454065 y- 5909299 Zone- 4 Total Depth: x- 453700 ° - 5909184 - Zone- 4 11. SSSV Depth (MD + ND): nipple @ 518' 17. Land Use Permit: ALK 4293 18. Directional Survey: Yes 0 No ^ (Submit electronic and printed information per 20 AAC 15.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1198' ND ' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): t~„P ~~ ~/~D ~ ~ ~'~ /7'~y GR/Res, Dens/Neu I~ „i1D f'•L~':C'7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.6# H-40 28' 108' 28' 108' 24" 103 sx AS 1 7-5/8" 29.7# L-80 28' 2858' 28' 2311' 9.875" 274 sx AS III LW, 240 sx Class G, 60 sx AS 1 5.5" 15.5# L-80 28' 9137' 28' 4904' 6.75" 240 sx Class G 3.5" 9.3# L-80 9158' 9932' 4918' 5492' 6.75" see above 23. Open to production or injection? Yes ^ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD + ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 9151' 9084' 9600'-9615' MD 5241' - 5252' ND 6 spf ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production May 17, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 5/17/2007 Hours Tested not available Production for Test Period --> OIL-BBL 69 GAS-MCF 44 WATER-BBL 20 CHOKE SIZE not available GAS-OIL RATIO not available Flow Tubing press. 253 psi Casing Press: not available Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD + ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. v_. r~; 9or~ NONE ~ vE~,i VEfi iED Form 10-407 Revised 2/2007 CONTINUCOxxg~V R$E~IDE' ,dd s`~- ' < {~ (),7711--CC~~ ~'~ ~ •~ ~ ~ e>'1 G 28. _ 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results.. List intervals tested, and Permafrost -Top Surface surface attach detailed supporting data as necessary. If no tests were Permafrost -Bottom 1222' 1198' ~ conducted, state "None". T-3 (top) 9366' 5065' T-2 (bottom) 9660' 5286' N/A ` Formation at total depth: T-3 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265-6419 Printed Na Ra hom s Title: Greater Kuoaruk Area Dritlino Team Leader ~ ~2-.f ~~~ Si ~~ ' -~ gnature Phone ~~ ~ ~ ~ ~ Date (% INSTRUCTIONS Prepared by Sharon Allsup-Drake 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 abour mean low fow 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2007 Halliburton Company Survey Report Company: ConecoPhillips Alaska Inc. Date: 4/1 112 0 0 7 Time: 11:10:44 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE)Reference: Well: 2N-337.; Tr ue North - Site: Kuparuk 2N Pad Ve rtical (TVD) Re icrencr. 2N-3376:151.1 1Ve11: 2N-337 Section (VS) Reference: Well (O.OON,O.OOE,253.OOAzi) Wellpath: 2N-3376 Su rvey Calculation Method: Minimum Curvat ure ~ Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~ Well: 2N-337 Slot Name: j Well Position: +N/-S -79.34 ft Northing: 5911892.60 ft Latitude: 70 10 12.816 N +E/-W -335.35 ft Easting : 460596.52 ft Longitude: 150 19 1.635 W Position Uncertainty: 0.00 ft ~ --- Wellpath: 2N-3376 Drilled From: - 2N-337 ~ 1032026202 Tie-on Depth: 2826.53 ft ~ I Current Datum: 2N-3376: Height 151.07 ft Above System Datum: Mean Sea Level Magnetic Data: 2/13/2007 Declination: 23.18 deg Field Strength: 57577 nT Mag Dip Angle: 80.66 deg Vertical Section; Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg j 30.17 0.00 0.00 253.00 ~ Survey Program for Definitive Wellpath _ __ Date: 4/11/2007 Validated: No V ersion: 4 Actual From To Survey Toolcode Tool Name ft ft 253.17 2826.53 2N-337 (253.17-106 57.27) (0) MWD MWD -Standard 2891.00 9904.79 2N-3376 ( 2891.00-9904.79) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey III) lncl ~1zim TVll Sys TVD NiS E/W ~iapN MapE i l ool ft deg deg ft ft ft ft ft ft 30.17 0.00 0.00 30.17 -120.90 0.00 0.00 5911892.60 ° 460596.52 ' TIE LINE 253.17 0.67 142.46 253.16 102.09 -1.03 0.79 5911891.56 460597.31 MWD 343.91 1.88 183.94 343.88 192.81 -2.94 1.02 5911889.66 460597.52 MWD A 434.60 4.16 198.23 434.44 283.37 -7.55 -0.12 5911885.05 460596.36 MWD l 523.19 7.44 200.71 522.57 371.50 -15.97 -3.15 5911876.65 460593.29 MWD i 610.10 10.40 208.49 608.42 457.35 -28.13 -8.88 5911864.52 460587.49 I MWD 701.79 14.01 205.01 698.02 546.95 -45.47 -17.53 5911847.23 460578.76 MWD 792.45 16.01 197.19 785.59 634.52 -67.36 -25.86 5911825.38 460570.31 MWD 882.72 15.80 199.98 872.41 721.34 -90.80 -33.74 5911801.98 460562.31 MWD 973.75 15.43 200.52 960.08 809.01 -113.79 -42.22 5911779.04 460553.71 MWD 1064.37 16.20 198.91 1047.27 896.20 -137.04 -50.54 5911755.84 460545.27 MWD 1156.04 16.29 200.42 1135.28 984.21 -161.19 -59.17 5911731.74 460536.51 MWD 1247.46 19.29 203.95 I 1222.32 1071.25 -187.01 -69.78 5911705.97 460525.78 MWD 1341.09 21.32 212.44 1310.15 1159.08 -215.52 -85.19 5911677.55 460510.22 MWD 1436.84 2. 4 21.9 2 7 8 5 2 1398 9 1247.85 -244. 68 -106.08 11648.50 460489.18 59 MWD i 1531.94 25.33 225.21 1485.78 1334.71 -273.39 -131.99 5911619.93 460463.12 MWD ~ 1625.50 29.03 229.10 1569.00 1417.93 -302.36 -163.36 5911591.12 460431.60 MWD 1720.20 32.88 228.72 1650.20 1499.13 -334.38 -200.06 5911559.30 460394.74 MWD 1815.80 35.91 229.19 1729.07 1578.00 -369.83 -240.79 5911524.07 460353.83 MWD 1911.30 39.76 229.54 1804.48 1653.41 -407.96 -285.24 5911486.17 460309.19 MWD 2006.37 42.92 230.64 1875.85 1724.78 -448.23 -333.42 5911446.15 460260.81 MWD 2098.67 46.32 231.94 1941.54 1790.47 -488.75 -384.01 5911405.90 460210.01 MWD 2194.14 50.23 235.27 2005.08 1854.01 -530.96 -441.38 5911364.00 460152.43 MWD 2288.91 54.04 235.82 2063.24 1912.17 -573.27 -503.06 5911322.01 460090.53 MWD 2381.93 57.86 237.48 2115.32 1964.25 -615.61 -567.44 5911280.01 460025.94 MWD 2477.78 61.89 238.43 2163.41 2012.34 -659.58 -637.70 5911236.42 459955.45 MWD 2571.48 65.42 239.52 2204.99 2053.92 -702.84 -709.65 5911193.54 459883.29 MWD 2664.78 67.66 239.74 2242.13 2091.06 -746.10 -783.49 5911150.66 459809.23 MWD ~' 2759.95 69.03 240.81 2277.25 2126.18 -789.96 -860.30 5911107.21 459732.20 MWD ,~\ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4111!2007 Times 11:10:44 Pa~c: 2 Field: KuparukRiver Unit Co-ordinate(NE) Reference: Well: 2N-337, true North Site:' Kuparuk2NPad Verfical(1'VD)Reference: 2N-3378:151.1 ~M1'ell: 2N-337 Section (VS) Reference: Well (O.OON,O.OOE,253:OOAzi) Wellpath: 2N-337B Survey Calculation Method: Minimum Curvature D6: 0~8CIe __ _ __ __ Survcv MD [ncl Azim TVD SysTVD' 3'V/S° E/~V MHpN MapT. Tooi 'i ft deg deg ft ft ft ft ft ft ____ __ __ _ _ _ _ _ __ _ _ __ _ __ -1 j 2826.53 68.76 241.33 2301.22 2150.15 -820.00 -914.67 5911077.45 459677.69 MWD ~ 2891.00 69.13 239.89 2324.39 2173.32 -849.53 -967.09 5911048.20 459625.12 MWD+IFR-AK-CAZ-SC 2943.36 66.79 242.60 2344.04 2192.97 -872.88 -1009.62 5911025.07 459582.47 MWD+IFR-AK-CAZ-SC j 3102.60 70.42 244.22 2402.12 2251.05 -939.21 -1142.19 5910959.44 459449.57 MWD+IFR-AK-CAZ-SC 3197.20 70.20 251.83 2434.04 2282.97 -972.51 -1224.71 5910926.57 459366.88 MWD+IFR-AK-CAZ-SC 3292.07 69.91 249.65 2466.40 2315.33 -1001.93 -1308.90 5910897.60 459282.56 MWD+IFR-AK-CAZ-SC 3387.00 69.60 248.59 2499.25 2348.18 -1033.67 -1392.11 5910866.29 459199.18 MWD+IFR-AK-CAZ-SC 3482.99 69.00 248.71 2533.18 2382.11 -1066.36 -1475.74 5910834.04 459115.39 MWD+IFR-AK-CAZ-SC 3575.16 67.68 248.44 2567.20 2416.13 -1097.65 -1555.48 5910803.17 459035.50 MWD+IFR-AK-CAZ-SC 3669.88 65.98 248.17 2604.47 2453.40 -1129.84 -1636.39 5910771.41 458954.43 MWD+IFR-AK-CAZ-SC 3768.11 65.40 249.13 2644.91 2493.84 -1162.43 -1719.77 5910739.25 458870.90 MWD+IFR-AK-CAZ-SC 3863.14 64.51 249.68 2685.14 2534.07 -1192.71 -1800.36 5910709.39 458790.16 MWD+IFR-AK-CAZ-SC ' 3959.48 64.33 251.42 2726.74 2575.67 -1221.65 -1882.29 5910680.89 458708.08 MWD+IFR-AK-CAZ-SC 4053.84 63.91 251.85 2767.92 2616.85 -1248.40 -1962.86 5910654.56 458627.38 MWD+IFR-AK-CAZ-SC 4151.21 64.77 252.80 2810.09 2659.02 -1275.04 -2046.48 5910628.35 458543.63 MWD+IFR-AK-CAZ-SC 4245.01 66.25 253.75 2848.97 2697.90 -1299.60 -2128.23 5910604.22 458461.76 MWD+IFR-AK-CAZ-SC 4340.86 65.98 253.29 2887.78 2736.71 -1324.46 -2212.27 5910579.80 458377.60 MWD+IFR-AK-CAZ-SC 4433.72 66.44 254.16 2925.24 2774.17 -1348.28 -2293.84 5910556.42 458295.92 MWD+IFR-AK-CAZ-SC 4523.08 66.37 254.69 2961.01 2809.94 -1370.26 -2372.72 5910534.84 458216.93 MWD+IFR-AK-CAZ-SC 4623.61 66.19 252.95 3001.45 2850.38 -1395.91 -2461.11 5910509.66 458128.42 MWD+IFR-AK-CAZ-SC 4718.48 65.94 253.28 3039.94 2888.87 -1421.09 -2544.08 5910484.91 458045.33 MWD+IFR-AK-CAZ-SC 4813.74 65.41 253.68 3079.18 2928.11 -1445.78 -2627.30 5910460.66 457961.99 MWD+IFR-AK-CAZ-SC 4908.88 64.83 253.07 3119.20 2968.13 -1470.47 -2710.00 5910436.40 457879.17 MWD+IFR-AK-CAZ-SC 5004.20 65.44 253.57 3159.29 3008.22 -1495.29 -2792.84 5910412.02 457796.20 MWD+IFR-AK-CAZ-SC i 5099.03 66.60 254.66 3197.83 3046.76 -1519.00 -2876.18 5910388.74 457712.75 MWD+IFR-AK-CAZ-SC 5194.14 66.71 254.00 3235.52 3084.45 -1542.59 -2960.26 5910365.60 457628.56 MWD+IFR-AK-CAZ-SC 5289.24 66.65 253.72 3273.16 3122.09 -1566.86 -3044.15 5910341.76 457544.56 MWD+IFR-AK-CAZ-SC 5384.34 66.53 253.31 3310.95 3159.88 -1591.63 -3127.83 5910317.43 457460.75 MWD+IFR-AK-CAZ-SC 5478.89 66.78 253.22 3348.41 3197.34 -1616.62 -3210.96 5910292.87 457377.50 MWD+IFR-AK-CAZ-SC 5574.55 66.62 252.68 3386.25 3235.18 -1642.38 -3294.96 5910267.55 457293.38 MWD+IFR-AK-CAZ-SC 5670.41 65.97 252.51 3424.79 3273.72 -1668.64 -3378.71 5910241.74 457209.50 MWD+IFR-AK-CAZ-SC 5765.20 64.71 252.78 3464.34 3313.27 -1694.34 -3460.93 5910216.47 457127.15 MWD+IFR-AK-CAZ-SC 5860.37 65.56 252.85 3504.36 3353.29 -1719.85 -3543.43 5910191.39 457044.54 MWD+IFR-AK-CAZ-SC 5955.49 65.73 253.36 3543.58 3392.51 -1745.03 -3626.34 5910166.64 456961.50 MWD+IFR-AK-CAZ-SC 6049.43 65.61 253.60 3582.28 3431.21 -1769.37 -3708.40 5910142.73 456879.32 MWD+IFR-AK-CAZ-SC 6145.92 65.83 253.22 3621.96 3470.89 -1794.48 -3792.70 5910118.06 456794.90 MWD+IFR-AK-CAZ-SC 6239.61 66.16 252.81 3660.08 3509.01 -1819.49 -3874.55 5910093.49 456712.93 MWD+IFR-AK-CAZ-SC 6334.83 68.54 251.58 3696.74 3545.67 -1846.36 -3958.21 5910067.05 456629.14 MWD+IFR-AK-CAZ-SC j 6430.42 69.01 251.51 3731.35 3580.28 -1874.57 -4042.73 5910039.29 456544.48 MWD+IFR-AK-CAZ-SC 6526.35 69.10 251.93 3765.64 3614.57 -1902.67 -4127.80 5910011.63 456459.28 MWD+IFR-AK-CAZ-SC 6621.64 68.99 251.45 3799.72 3648.65 -1930.63 -4212.28 5909984.12 456374.66 MWD+IFR-AK-CAZ-SC 6716.78 69.18 251.85 3833.68 3682.61 -1958.60 -4296.63 5909956.58 456290.17 MWD+IFR-AK-CAZ-SC 6811.62 66.68 253.38 3869.32 3718.25 -1984.87 -4380.50 5909930.76 456206.18 MWD+IFR-AK-CAZ-SC 6906.80 66.62 253.53 3907.04 3755.97 -2009.76 -4464.26 5909906.31 456122.29 MWD+IFR-AK-CAZ-SC i 7001.80 66.82 252.90 3944.59 3793.52 -2034.96 -4547.81 5909881.55 456038.62 MWD+IFR-AK-CAZ-SC 7096.94 66.82 252.53 3982.04 3830.97 -2060.94 -4631.32 5909856.00 455954.99 MWD+IFR-AK-CAZ-SC 7191.02 67.14 252.27 4018.83 3867.76 -2087.13 -4713.85 5909830.25 455872.33 MWD+IFR-AK-CAZ-SC 7285.67 67.67 251.86 4055.20 3904.13 -2114.03 -4796.99 5909803.78 455789.06 MWD+IFR-AK-CAZ-SC 7380.80 67.47 253.64 4091.49 3940.42 -2140.11 -4880.97 5909778.14 455704.96 MWD+IFR-AK-CAZ-SC 7476.08 66.42 254.00 4128.81 3977.74 -2164.54 -4965.16 5909754.15 455620.64 MWD+IFR-AK-CAZ-SC 7571.22 66.88 253.40 4166.52 4015.45 -2189.06 -5049.00 5909730.07 455536.69 MWD+IFR-AK-CAZ-SC 7666.36 67.35 253.52 4203.51 4052.44 -2214.01 -5133.02 5909705.56 455452.55 MWD+tFR-AK-CAZ-SC j Halliburton Company Survey Report __ _ _ _ __ Company: ConocoPhiilips Alaska Inc. Date: 4/11/2007 Cimc: 11;1.0:44 Pn~;e: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2N-337, True North Site: Kuparuk 2N Pad Vertical (TVD) Rcfcrcnce: 2N-3376 : 151.9 ''' Welk: 2N-337 Section (VS) Reference: Well (O.OON,O.OOE,253.OOAzi) Wellpath: 2N-3376 purvey (nlculation Method: Minimum Curvature Db: Oracle ___ Survct~ __ __ _ - __ ---_ ------ MD lucl azim TVD spa I!"D S/S t.,~V MapN MapF Too! ft deg deg ft ft ft ft ft ft 7761.60 66.61 254.05 4240.76 4089.69 -2238.49 -5217.19 5909681.52 455368.26 MWD+IFR-AK-CAZ-SC 7856.70 67.12 253.74 4278.12 4127.05 -2262.75 -5301.21 5909657.70 455284.12 MWD+IFR-AK-CAZ-SC 7951.80 67.27 253.53 4314.98 4163.91 -2287.45 -5385.32 5909633.45 455199.89 MWD+IFR-AK-CAZ-SC 8047.66 67.84 253.15 4351.58 4200.51 -2312.85 -5470.20 5909608.49 455114.89 MWD+IFR-AK-CAZ-SC i 8142.47 65.24 252.99 4389.32 4238.25 -2338.17 -5553.40 5909583.60 455031.57 MWD+IFR-AK-CAZ-SC 8236.97 65.92 253.08 4428.39 4277.32 -2363.28 -5635.70 5909558.93 454949.15 MWD+IFR-AK-CAZ-SC 8331.78 66.25 253.31 4466.83 4315.76 -2388.34 -5718.67 5909534.30 454866.06 MWD+IFR-AK-CAZ-SC 8427.02 64.32 253.39 4506.64 4355.57 -2413.12 -5801.55 5909509.95 454783.05 MWD+IFR-AK-CAZ-SC 8521.90 60.53 254.13 4550.56 4399.49 -2436.65 -5882.28 5909486.85 454702.21 MWD+fFR-AK-CAZ-SC 8616.27 59.76 253.44 4597.54 4446.47 -2459.50 -5960.87 5909464.41 454623.51 MWD+IFR-AK-CAZ-SC 8712.38 57.79 253.86 4647.36 4496.29 -2482.64 -6039.73 5909441.68 454544.54 MWD+IFR-AK-CAZ-SC 8807.90 55.28 253.88 4700.03 4548.96 -2504.78 -6116.27 5909419.95 454467.89 MWD+IFR-AK-CAZ-SC ', 8903.03 53.61 253.33 4755.34 4604.27 -2526.62 -6190.52 5909398.50 454393.54 MWD+IFR-AK-CAZ-SC 8998.17 50.89 253.30 4813.58 4662.51 -2548.21 -6262.57 5909377.28 454321.39 MWD+IFR-AK-CAZ-SC 9093.65 49.07 252.43 4874.98 4723.91 -2569.75 -6332.44 5909356.11 454251.41 MWD+IFR-AK-CAZ-SC 9188.34 47.05 253.39 4938.26 4787.19 -2590.45 -6399.76 5909335.75 454183.99 MWD+IFR-AK-CAZ-SC 9281.73 44.43 252.81 5003.43 4852.36 -2609.89 -6463.75 5909316.66 454119.90 MWD+IFR-AK-CAZ-SC 9377.11 42.60 251.66 5072.60 4921.53 -2629.91 -6526.29 5909296.96 454057.27 MWD+IFR-AK-CAZ-SC I 9473.74 40.39 252.12 5144.97 4993.90 -2649.82 -6587.14 5909277.37 453996.33 MWD+IFR-AK-CAZ-SC 9568.35 40.83 252.09 5216.80 5065.73 -2668.74 -6645.74 5909258.76 453937.63 MWD+IFR-AK-CAZ-SC 9663.58 40.96 251.87 5288.78 5137.71 -2688.03 -6705.02 5909239.78 453878.25 MWD+IFR-AK-CAZ-SC 9757.99 41.05 252.42 5360.03 5208.96 -2707.02 -6763.99 5909221.10 453819.20 MWD+IFR-AK-CAZ-SC 9853.14 40.37 252.95 5432.16 5281.09 -2725.49 -6823.23 5909202.94 453759.86 MWD+IFR-AK-CAZ-SC 9904.79 40.17 252.10 5471.57 5320.50 -2735.52 -6855.08 5909193.08 453727.97 MWD+IFR-AK-CAZ-SC 9950.00 40.17 252.10 5506.11. 5355.04 -2744.48 -6882.83 5909184.26. 453700.17 - PROJECTED to TD I, Ca-nocoPhilips Time Log Summary . ~~~~~~, d~~~ R~~~~ ~~ - - __ - - Well Name: 2N-337 Job Type: DRILLING SIDETRACK Time Logs ~ Date From To _Dur S. Depth E_, DeE~th Phase Code Subcode T_ COM __ ___ 02/10/2007 06:00 06:30 0.50 COMPZ MOVE DMOB P PJSM, Move Rig off 1 E-168 06:30 08:30 2.00 COMPZ MOVE DMOB P RD 13 5/8" Stack from sub, Re-instsall 11" 5M stack. 08:30 00:00 15.50 COMPZ MOVE MOB P Moving Rig 1 E pad to 2N pad 02!11/2007 00:00 05:00 5.00 9,707 9,707 COMPZ MOVE MOB P Move rig onto 2N pad, spot rig over well and prepare for well work activities. 05:00 06:00 1.00 9,707 9,707 COMPZ MOVE PSIT P Set tree in cellar, PJSM, move over well. Spot and level rig. Rig accepted at 0600 hrs, 11-Feb-07. 06:00 08:00 2.00 9,707 9,707 COMPZ MOVE RURD P Drop tarps, berm cellar, PU lubricator and ull BPV. 08:00 12:00 4.00 9,707 9,707 COMPZ MOVE RURD P RU circ lines to tree, spot highline trlr, take on fluids for well kill o erations. 12:00 14:00 2.00 9,707 9,707 COMPZ WELCT NUND P PJSM, RU circ hoses & lines to kill well. Pre-kill gauge readings: OA 175 psig, IA 100 psi. Tubing and IA same due to revious tubin cut rocedure. 14:00 15:30 1.50 9,707 9,707 COMPZ WELCT EORP NP Thaw frozen valves and lines on rig. 15:30 17:00 1.50 9,707 9,707 COMPZ WELCT CIRC P Circ. 8.5 ppg seawater down tubing and w/ IA returns at 2 bpm & 350 psi. Stage up rate to 4 bpm at 1500 psi. circ well clean w/ 250 bbls brine. 17:00 20:00 3.00 9,707 9,707 COMPZ WELCT NUND P RD hoses, break down hard line, set BPV. ND tree, install blanking plug in tb han er. 20:00 00:00 4.00 9,707 9,707 COMPZ WELCT NUND P NU BOP stack. 02/12/2007 00:00 01:00 1.00 9,707 9,707 PROD1 WELCT NUND P Finish NU of BOPE and prepare for testin of same. 01:00 06:00 5.00 9,707 9,707 PROD1 WELCT BOPE P PJSM, Test BOPE 250 / 3500, all components, perform time /volume / press test accumulator, Witness test waived by Chuck Scheve w/ AOGCC at 0100 hrs. 06:00 06:30 0.50 9,707 9,707 PROD1 WELCT BOPE P Pull TWC, flow check. 06:30 07:00 0.50 9,707 9,707 PROD1 RPCOh PULD P PJSM, Work 3-1/2 tbg string / tbg hgr. Pull free with 125K total pull. Flow check, ull h r to floor, LD same. 07:00 08:00 1.00 9,707 9,707 PROD1 RPCO CIRC P Flow check, circ wellbore clean with seawater. Take unclean returns to truck and dis ose. ~'<~c~ ? caf 2t7 Time Los Date_ From__ To___ __Dur S. Depth E Depth Phase Code Suhcode T COM -- _ -- 02/12/2007 08:00 21:00 13.00 9,707 9,707 PROD1 RPCOh PULD P PJSM, prepare floor, POH 3-1/2 tbg, stand bk 12 stds in mast for cmt stin er, resume POH, LD in sin les. 21:00 22:00 1.00 9,707 9,707 PROD1 RPCOh PULD P Strap remainder of pulled tubing in pipeshed and pulled jewelry, remove from rig, clear floor for next phase. Total length tbg and jewelry pulled 9542 ft for tbg total 268 jts + 12 stands for 304 'ts ulled. 22:00 00:00 2.00 9,707 9,707 PROD1 PLUG MPSP P PJSM, install wear bushing, RU eline, RIH w/ CCL and junk basket and 4.725" gauge ring to 3650ft, no obstructions. POOH. 02/13/2007 00:00 00:30 0.50 9,707 9,707 PROD1 PLUG MPSP P Continue POOH w/ eline w/gauge ring and CCL. 00:30 03:00 2.50 9,707 3,420 PROD1 PLUG MPSP P PJSM. RD pack-off, LD gauge ring and junk basket. Install CIBP, re-install pack-off and RIH w/ eline. Successfully set CIBP at 3420'. PU and RIH w/ set tool and tag w/ eline to veri location, OK. POOH w/ eline. 03:00 04:00 1.00 3,420 3,420 PROD1 PLUG MPSP P RD eline and remove pack-off w/ lubricator from ri floor. LD. 04:00 06:00 2.00 3,420 3,420 PROD1 RPCOh SFEO P PJSM, set test plug, C/O top set of rams in BOP to 5 1/2". Function test. Install 5 1/2" Id ~t. 06:00 07:00 1.00 3,420 3,420 PROD1 WELC BOPE P Test 5-1/2 rams !door seals 250 / 3500 si. 07:00 08:00 1.00 3,420 3,420 PROD1 WELCT BOPE P Clear floor, LD BOPE test equip, remove test Iu ,flow check. 08:00 11:00 3.00 3,420 3,420 PROD1 WELCT OTHR P PJSM, bleed 5-1 /2 X 7-5/8 ann. Initial 170 psi, final "0" psi in 1 hr. Observe annulus, no ress build /flow. 11:00 13:00 2.00 3,420 3,420 PROD1 RPCOh PULD T Attempt pull 5-1/2 pkf. Pkf stuck in wellhead. Doublecheck LD screws. Cont work /rotate loose. Pull to floor, LD pkf /running tool. Pkf scarred / damaged from LDSs. Screws out completely. Repair tentative for later date. After cmt lu 13:00 13:30 0.50 3,420 3,420 PROD1 RPCOh PULD P Pull tension in 5-1/2 60K total), set in sli sunder tension. 13:30 15:30 2.00 3,420 3,420 PROD1 FISH ELNE P PJSM, Rig up Schlum E-line, place jet cutter a ui ri floor, RU same. 15:30 17:30 2.00 3,420 3,420 PROD1 FISH ELNE P RIH jet cutter on E-line, correlate depth with CCL, fire cutter at 3058 ft. POH E-line, note cutter fired, RD Schlum a ui ,clear floor. 17:30 18:30 1.00 3,420 3,420 PROD1 RPCO RCST P PJSM, flow check, wellbore stable, attempt break 5-1/2 free. Work string with and without torque. Can not free, artial or no cut. 18:30 19:00 .0.50 3,420 3,420 PROD1 RPCOh RURD P PJSM, Load Geopilot skid onto rig floor. 19:00 22:00 3.00 3,420 3,420 PROD1 WELCT BOPE P PJSM, Change upper pipe rams f! 5 1/2 to 2 7/8. F.A~... _~. ~~. ~ ..~ ~__._..._..~.. ~<3~~ ~ of ~'~ Time Logs __ I Date From 7o bur 5. Depth E Depth Phase Code Subcode _ T COM 02/13/2007 22:00 23:30 1.50 3,420 3,420 PROD1 WELCT BOPE P Test 2 7/8 upper pipe rams to 250 psi/3500 psi, RD & BD Test E ui ment. 23:30 00:00 0.50 3,420 3,420 PROD1 WELCT BOPE P Install wear bushing. 02/14/2007 00:00 01:00 1.00 3,420 3,420 PROD1 FISH RURD P Install stabbing guide on top drive drive. 01:00 04:30 3.50 3,420 3,420 PROD1 FISH TRiP P RIH w! 5 1/2 Baker mechanical cutter on 2 7/8 PAC. 04:30 06:00 1.50 3,420 3,420 PROD1 FISH RURD P Adust torque limit on top drive, break circ 1.6 bpm / 100 psi. Up 60, do 55. Commence cut 5-1l2 csg as per BOT re . 06:00 09:30 3.50 3,420 3,420 PROD1 WELCT KLWL T Gas cut returns (bubbling with no flow), PJSM, circ 2-7/8 X 5-1l2 annulus, displace with 9.6 ppg mud. Line up /bullhead 53 bbls 9.6 mud to 5-1 /2 X 7-5/8 annulus. 1bpm / 890 psi, final = 1 bpm / 460 psi. Open well, flow check, well static. 09:30 10:30 1.00 3,420 3,420 PROD1 FISH CPBO P PJSM, resume cut 5-1/2 csg. Confirm cut with ress / wt test. Flow check. 10:30 12:00 1.50 3,420 3,420 PROD1 RPCOM1 CIRC P Monitor well, circulate clean w/ 9.6 mud w! 1,300 si 4 b m. 12:00 12:30 0.50 3,420 3,420 PROD1 RPCOh OWFF P PJSM, BD Top Drive, Monitor Well static . 12:30 14:30 2.00 3,420 3,420 PROD1 RPCOh TRIP P POH w/ 5 1/2 mechanical cutter on 2 7/8" DP f/ 3,069'. 14:30 15:30 1.00 3,420 3,420 PROD1 WELCT EORP P Change upper pipe rams f! 2 7/8" to 5 1 /2". 15:30 16:00 0.50 3,420 3,420 PROD1 WELC BOPE P Pull wear bushing, run test plug. 16:00 17:00 1.00 3,420 3,420 PROD1 WELC BOPE P Test upper pipe rams to 250 psi/3,500 si, blow down to drive. 17:00 18:30 1.50 3,420 3,420 PROD1 RPCOti PULD P PJSM, MU Idg jt with run /retrieve tool to 5-1 /2 hgr. Drain stack, observe well, flow check. Begin take pull on 5-1 /2 to free csg cut. Stage pulls in 10K overpull intervals, resulting in final pull at 275K. (Buoyed wt at cut 41 K, max to yield 404K) 275K - 35K top drive = 240K total pull. Total stretch 6.5 ft. No success with pull. Press 5-1 /2 with 1500 psi, attempt "hydraulic" string free. Press. holding, packed off. Cont re-cip pipe two 5 ft strokes. String free, moving slowly, press bleeding with upward movement. Pump 3 jts out, press bleeds to "0" psi. Pull two more jts to 7-5/8 shoe. Fluid dropping in csg to BOP level. Flow check. 18:30 19:00 0.50 3,420 3,420 PROD1 RPCOh CIRC P CBU X 2 @ 5 bpm w/ 220 psi. Shaker clean. No abnormal quantity /quality cuttin s returns. No ain !loss. .._~ - ~e _m~e ~.0_. _ ~'~c~~ 3 ~f ~~ ~~ Time Los _ 9___- _-_- _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 02/14/2007 19:00 19:30 0.50 3,420 3,420 PROD1 RPCOft OWFF P Blow down Top Drive, monitor well static . 19:30 23:30 4.00 3,420 3,420 PROD1 RPCOft PULD P POH, LD 5 1!2" casing, strap in pipe shed. 23:30 00:00 0.50 3,420 3,420 PROD1 RPCOft PULD P PJSM, LD 2 7/8" PAC drill pipe f! derrick in mousehole. 02/15/2007 00:00 04:00 4.00 3,420 3,420 PROD1 RPCOft PULD P LD 2 7/8" DP f/derrick in mousehole. 04:00 06:30 2.50 3,420 3,420 PROD1 RPCOft PULD P Remove 2 7/8" DP f/ pipe shed, load & tall 4" DP 06:30 09:30 3.00 3,420 3,420 PROD1 RPCOft PULD P PJSM, change lower rams to 3-1/2, lower rams to 4". 09:30 10:30 1.00 3,420 3,420 PROD1 WELCT BOPE P PJSM, test rams /door seals 250 / 3500 si. Test successful, no re-tests 10:30 13:00 2.50 3,420 3,420 PROD1 RPCOft OTHR P C/O saver sub top drive to 4" DP. 13:00 17:30 4.50 3,420 3,420 PROD1 RPCOft PULD P PJSM, flow check, PU 4" DP in singles for clean out run to tag top 5-1/2 stub at 3055 ft. 17:30 20:00 2.50 3,420 3,420 PROD1 RPCOft CIRC P Pump 2 Hi-Vis sweeps surface to surface. Hole cleaned u . 20:00 20:30 0.50 3,420 3,420 PROD1 RPCOft OWFF P Blow down top drive, monitor well static . 20:30 22:30 2.00 3,420 3,420 PROD1 RPCOft TRIP P POH w/ DP 22:30 23:30 1.00 3,420 3,420 PROD1 RPCOft RURD P RU to run 3 1/2 tubing stinger f/ balanced lu 23:30 00:00 0.50 3,420 3,420 PROD1 RPCOft TRIP P PJSM, RIH w/ mule shoe & 1,141' of 3 1/2 tubin 02/16/2007 00:00 01:00 1.00 3,420 3,420 PROD1 RPCO RURD P PJSM, RU 4" DP handling equipment. 01:00 02:00 1.00 3,420 3,420 PROD1 RPCOft TRIP P RIH w/ 4" DP, Tagged up 3,145. No indication pass through 5-112 stub at 3058. 02:00 04:30 2.50 3,420 3,420 PROD1 RPCO FCO P MU Top Drive, rack back stand & wash to cement retainer @ 3,422'. 4bpm ! 250 psi. Trace sands /clay returns to shaker. Cont circ clean. No ain /loss. 04:30 05:00 0.50 3,420 3,420 PROD1 RPCO CIRC P Cont circ shaker clean for cmt plug. 05:00 06:30 1.50 3,420 3,420 PROD1 CEME~ RURD P PJSM, RU to cement, PJSM, prime u cement van, RU floor for cmt lu . 06:30 07:00 0.50 3,420 3,420 PROD1 CEME PLUG P PJSM, Commence set cmt plug. Pump 5 bbls H2o, test lines 3000 psi, Mix /pump 33 bbls, 17 ppg, "G", follow with 2.3 bbls H2o for balanced interface, displace with 24 bbls drlg mud. ICP = 169 psi, FCP = 119 psi, 100% returns, no ain /loss. 07:00 08:00 1.00 3,420 3,420 PROD1 CEME~ TRIP P Break cmt lines (slight vacuum), POH to 2376 ft. (TOC 2558 ft). Fluid dro in , no flow back. 08:00 09:00 1.00 3,420 3,420 PROD1 CEME~ CIRC P Circ DP clean @ 6 bpm / 180 psi. Approx .5 cu ft contanimate to surface. Blow down to drive. ~ __ ~ ~~ ~ (__~ I~~~~ a tzf ~ r T Time Logs Date From_To Dur S. De th E. De th Phase Code Subcode T COM 02/18/2007 04:30 05:30 1.00 3,420 3,420 PROD1 STK PULD P MU Top Drive, shallow test MWD tools OK ,blow down To Drive. 05:30 06:30 1.00 3,420 3,420 PROD1 STK PULD P Install nuclear source in LWD tools. 06:30 07:30 1.00 3,420 3,420 PROD1 STK PULD P MU dretnl BHA / HWDP RIH same. 07:30 08:30 1.00 2,469 2,469 PROD1 STK TRIP P Flow check, follow BHA with 4" DP to 2469 ft. 08:30 09:00 0.50 2,469 2,469 PROD1 STK CIRC P Run Geo Pilot seals with rotation ! circ. 09:00 09:30 0.50 2,469 2,586 PROD1 STK OTHR P Wash 2469 - 2586 ft to tag cmt plug, 250 gpm. 20K on plug. Will not wash awa . 09:30 10:00 0.50 2,586 2,646 PROD1 CEME~ COCF P Drill cmt 2586 - 2646 ft. Medium hard initial) becomin harder at 2646 ft. 10:00 10:30 0.50 2,646 2,646 PROD1 STK CIRC P Circ shaker clean for csg test. 10:30 12:30 2.00 2,646 2,646 PROD1 STK OTHR P PJSM, test 7-5/8 csg 2500 psi / 30 min. Test successful. RD test a ui . 12:30 18:00 5.50 2,646 2,891 PROD1 CEME~ C CF P Resume drill cmt plug 2646' to 2891'-Drilling parameters: up wt=80K, down wt=70K, rot wt=75k, pump _ pressure 900 psi @ 6 bpm, _ for ue=2400 ft/Ibs. 18:00 18:30 0.50 2,891 2,941 PROD1 DRILL KOST P Drill ahead 6-3/4 hole f/ 2891' to 2941'-Sidetrack f/ old wellbore. 18:30 19:00 0.50 2,941 2,941 PROD1 DRILL CIRC P CBU, MWin = MWout, 9.7 ppg, shakers cleaned up, no excessive or unusual cuttin s observed. 19:00 19:30 0.50 2,941 2,941 PROD1 DRILL LOT P Blow down top drive, RU to perform LOT 19:30 20:30 1.00 2,941 2,941 PROD1 DRILL LOT P Perform LOT as per well program (MD 2949, TVD 2340) Leaked off @ 400 psi w/ 9.7 ppg MW = 13 ppg EMW. Pum ed 3.6 bbl, bled back 2 bbl. 20:30 21:00 0.50 2,941 2,941 PROD1 RIGMN SVRG P RD test equipment, adjust Top Drive for ue to 10K. 21:00 00:00 3.00 2,941 2,983 PROD1 DRILL DDRL P Drill ahead 6-3/4 hole dretnl, f/ 2941' to 2983' MD, 2357' TVD w/the following parameters: up wt=82K, down wt=65K, pump pressure 1090 psi @ 6.5 bpm, torque=3180 ft/Ibs on bottom, 2720 ft/Ibs off bottom. Max as observed 2350 units. 02/19/2007 00:00 12:00 12.00 2,983 3,312 PROD1 DRILL DDRL P Drill ahead 6-3/4 hole dretnl, w/ Sperry Geopilot f/ 2983' to 3312 ft. SPP 1580, SPM 130, GPM 322 gpm, WOB 5/10, RPM 130 / 140 Up 80, Dn 65, Rot 75, ART = 13.42 hrs, ECD 10.8, Max gas 32 No gain /loss. Cuttings return normal quantity /quality. ROP low 15 - 30 ft/hr at worst, vary parameters, pump nut plug, "dril zone" Pre are tri for BHA. 12:00 13:00 1.00 3,312 3,312 PROD1 DRILL CIRC P Pump hi-vis sweep, circ shaker clean. No ain /loss. ~d __.. ~ ..~~ e l~€d~ ~ of 2t~ A ,~~~~ r~ Time Logs i Date ____ From To Dur 5. Depth E. Depth_ Phase Code Subcode T COM --- --- 02/22/2007 00:00 01:30 1.50 6,191 6,284 PROD1 DRILL DDRL P Directional Drill from 6,191" MD to 6,284' MD, 3,676' TVD. 125 K# PU, 73 K# SO, 87 K# Rot. Wt. 85 RPM, 5 to 8 K# WOB, TO 6,400 ft-Ib on btm, TQ 5,500 ft-Ib off btm., 11.1 ECD, 110 SPM, 6.4 BPM, 271 GPM, 2160 psi on btm, 1750 psi off btm. 400 Units Max. Gas. 1.5 hrs ADT, 1.5 hrs ART, 0.0 hrs AST. 01:30 03:00 1.50 6,284 6,284 PROD1 DRILL CIRC P Circulate sweep surface to surface + 1 additional BU. Shakers cleaned up good, no signficant increase in amount of cuttin s while circulatin swee u . 03:00 05:30 2.50 6,284 6,284 PROD1 DRILL TRIP P POH to 7 5/8 shoe @ 2,858'-Flow check well above Camp sand @ 3,350' & Shoe Static . 05:30 06:30 1.00 6,284 6,284 PROD1 RIGMN SVRG P Service top drive, blocks, swivel, drawworks-clean & clear ri floor. 06:30 07:00 0.50 6,284 6,284 PROD1 RIGMN SVRG P Change out top drive saver sub. 07:00 09:00 2.00 6,284 6,284 PROD1 DRILL TRIP P RIH w/ 4" DP f/ 2,858' to 6,284', MU top drive, break circulation, wash to bottom, no fill. 09:00 10:00 1.00 6,284 6,300 PROD1 DRILL DDRL P Directional Drill f/ 6,284' to 6,300', 130K PU, 73K SO-Stopped drilling, obvious failure of downhole tool. Gas maxed @ 963 units-came up early, not from bottom of wells. 10:00 11:30 1.50 6,300 6,300 PROD1 DRILL CIRC T Pump HiVis sweep surface to surface 6.5 b m w! 1730 si. 11:30 17:00 5.50 6,300 6,300 PROD1 DRILL TRIP T Monitor well (static), blow down top drive, POH f/ 6,300' to 109'-Monitored well at Camp Sand @ 3,350' & 7 5/8 shoe 2,858' static). 17:00 20:30 3.50 6,300 6,300 PROD1 DRILL PULD T Clean & clear floor, PJSM w/ Sperry on removing nuclear sources, download MWD/LWD, Neutron-Density data would not download, tool to be sent to Deadhorse for further analysis, backup tool to be ran in hole. 20:30 21:00 0.50 6,300 6,300 PROD1 DRILL PULD T Stand back directional tools, drain & LD mud motor drive shaft failure . 21:00 23:00 2.00 6,300 6,300 PROD1 DRILL WOEO T Wait on bit salesman to deliver jets to location. 23:00 00:00 1.00 6,300 6,300 PROD1 DRILL PULD T MU BHA #3-PU Neutron-Density Tool / u load MWD/ LWD. 02/23/2007 00:00 03:00 3.00 6,300 6,300 PROD1 DRILL PULD T Upload MWD/LWD, install nuclear sources in LWD tools, MU remainder of BHA, shallow test MWD/LWD, blow down to drive,. 03:00 04:00 1.00 6,300 6,300 PROD1 DRILL TRIP 7 RIH w/ 20 stands of 4" DP (2,386') & fill drill i e, blow down mud line. 04:00 06:30 2.50 6,300 6,300 PROD1 DRILL TRIP T RIH w/ 4" DP f/ 2,386' to 6,200' filling i e eve 20 stands. 06:30 07:00 0.50 6,300 6,300 PROD1 DRILL CIRC T MU top drive & wash to 6,300'-No fill. {~~~es_. _ °a ®® m ...~.... Titus Logs __ _ Date From T_o Dur S De th E. Depth _ Phase Code__ S~Fbcode T COM 02/23/2007 07:00 12:00 5.00 6,300 6,549 PROD1 DRILL DDRL P Directional Drill from 6,300' MD to 6,549" MD, 3,772' ND. 130 K# PU, 75 K# SO, 95 K# Rot. Wt. 85 RPM, 5 to 8 K# WOB, TO 6,900 ft-Ib on btm, TO 4,500 ft-Ib off btm., 11.0 ECD, 130 SPM, 7.5 BPM, 2,350 psi on btm, 2,200 psi off btm. 670 Units Max. Gas. 34.35 hrs ADT, 3.91 hrs ART, 0.44 hrs AST. 12:00 00:00 12.00 6,549 7,238 PROD1 DRILL DDRL P Directional Drill from 6,549' MD to 7,238 MD, 4,035' ND. 135 K# PU, 78 K# SO, 95 K# Rot. Wt. 85 RPM, 5 to 10 K# WOB, TO 7,100 ft-Ib on btm, TQ 5,240 ft-Ib off btm., 11.0 ECD, 130 SPM, 7.5 BPM, 2,300 psi on btm, 2,150 psi off btm. 60 Units backround gas. 9.15 hrs ADT, 8.79 hrs ART, 0.36 hrs AST. 02!24/2007 00:00 12:00 12.00 7,238 7,997 PROD1 DRILL DDRL P Directional Drill from 7,238 MD to 7,997' MD, 4,330' ND. 150K# PU, 75K# SO, 100K# Rot. Wt. 85 RPM, 5 to 8 K# WOB, TO 7,900 ft-Ib on btm, TQ 6,300 ft-Ib off btm., 11.0 ECD, 120 SPM, 7.0 BPM, 296 GPM, 2,250 psi on btm, 2,040 psi off btm. 42 Units Max. Gas. 9.54 hrs ADT, 8.68 hrs ART, .86 hrs AST. 12:00 00:00 12.00 7,997 8,662 PROD1 DRILL DDRL P Directional Drill from 7,997 MD to 8,662' MD, 4,619' ND. 150K# PU, 75K# SO, 100K# Rot. Wt. 85 RPM, 5 to 8 K# WOB, TO 7,900 ft-Ib on btm, TQ 6,300 ft-Ib off btm., 11.0 ECD, 120 SPM, 7.0 BPM, 296 GPM, 2,460 psi on btm, 2,080 psi off btm. 148 Units Max. Gas. 8.36 hrs ADT, 6.36 hrs ART, 2.0 hrs AST. 02/25/2007 00:00 12:00 12.00 8,662 9,088 PROD1 DRILL DDRL P Directional Drill from 8,662 MD to 9,088' MD, 4,870' ND. 160K# PU, 80K# SO, 108K# Rot. Wt. 85 RPM, 5 to 10 K# WOB, TQ 8,000 ft-Ib on btm, TO 6,600 ft-Ib off btm., 11.3 ECD, 120 SPM, 7.0 BPM, 296 GPM, 2,440 psi on btm, 2,200 psi off btm. 80 Units Max. Gas. 10.12 hrs ADT, 7.19 hrs ART, 2.93 hrs AST. Jar Hrs. 88.93 12:00 16:00 4.00 9,088 9,260 PROD1 DRILL DDRL P Directional Drill from 9,088 MD to 9,260' MD, 4,977' ND. 160K# PU, 80K# SO, 108K# Rot. Wt. 85 RPM, 5 to 12 K# WOB, TQ 7,600 ft-Ib on btm, TO 6,700 ft-Ib off btm., 11.3 ECD, 115 SPM, 280 GPM, 2,510 psi on btm, 2,310 psi off btm. 57 Units Max. Gas. 3.08 hrs ADT, 2.08 hrs ART, 1.0 hrs AST. Jar Hrs. 92.01 ~ ~_ _ e ~_ ~ ®~ _~ ~ ar~~ ~ ~f eft ~...._~ Time Logs Date From To Dur S De th E. De th Phase_ Code Subcode_ T COM 02/25/2007 16:00 19:00 .3.00 9,260 9,260 PROD1 DRILL CIRC P Stand back stand & PU working joint f/ pipe shed, circulate sweep surface to surface while rotating & reciprocating while adjusting pump rates to avoid surge pressure: Continue circulating f/ a total of 3 bottoms up (15,000 stks.). No significant cuttings increases noted, losing mud over shakers continually, appears most cutting going into solution. 19:00 00:00 5.00 9,260 9,260 PROD1 DRILL TRIP P LD working single, blow down top drive, monitor well (static), POH w/ first stand monitoring visua-ly for swabbing (none), POH f/ 9,260' to 5, 7,15'. 02!26/2007 00:00 02:00 2.00 9,260 9,260 PROD1 DRILL TRIP P POH f/ 5,715' to shoe @ 2,858', performed flow checks @ 3,350' (Cam sands & shoe both static . 02:00 03:30 1.50 9,260 9,260 PROD1 DRILL CIRC P Make up top drive & circulate until MWin=MWout, Circulating @ 292 s m w/ 1,600 si f/ 6,500 stks. 03:30 04:30 1.00 9,260 9,260 PROD1 DRILL LOT P Performed LOT @ shoe (2,858' MD, 22311' TVD), started w! #2 pump, appeared to be a problem with pump, shut down and repeated test w/ #1 pump. Well leaked off at 380 psi w/ 9.9 ppg MW. LOT= 13.0 ppg EMW. Pumped 2.5 bbl, pressure bled to 340 si/10 min., bled back 1 bbl. 04:30 06:00 1.50 9,260 9,260 PROD1 RIGMN' SVRG P Service Rig, Cut & Slip Drill Line 06:00 08:00 2.00 9,260 9,260 PROD1 RIGMN' SVRG P Service top drive, blocks, swivel, drawworks. Change out grabber dies and saver sub on top drive. Service crown. 08:00 12:00 4.00 9,260 9,260 PROD1 DRILL TRIP P RIH from 2800' to 9233' MD. PU a sin le, break circulation. 12:00 14:00 2.00 9,260 9,260 PROD1 DRILL CIRC P Wash to bottom at 9260' MD. Circulate hole clean, 125 GPM, 850 psi, max gas 580 Units. Reciprocate & rotate pipe, 158K# PU, 83K# SO, 128K# Rot Wt. 14:00 16:30 2.50 9,260 9,260 PROD1 DRILL CIRC P Pump spacer/sweep followed by 11.4 ppg LSND mud loaded with wellbore strengthening material. 150 GPM, 60 SPM, 1050 psi. Returns to pits when 11.1 ppg mud surfaced. 12.0 ppg ECD with 11.1+ ppg returns. Continued circulating until aII new mud off vac trucks, approx. 675 Bbls total. R & R pipe, 128K# Rot Wt at start, 108K# Rot Wt with 11.4 ppg around. 12.0 ppg to 12.2 ppg ECD. No a arent losses to hole. m ~ _~_~ ____._~ ~~~ ? fl c~~ 2 C~ Time Logs ', D~te_ _ From_ To _ Dur S. De th E._Depth Phase _ _ Code _ Subcode T_ C_OM _- -- -- -- 02/26/200716:30 22:00 5.50 9,260 9,260 PROD1 DRILL CIRC P Continue circulating thru pits /active system. 150 GPM, 60 SPM, 1100 psi. Treat and shear new mud system. No mud loss. Rotating & Reci rocatin . 22:00 23:00 1.00 9,260 9,260 PROD1 DRILL CIRC P Stage pumps up f/ 275 gpm to simulate 13.0 ppg EMW as follows: 200 gpm w/ 1600 psi = 12.53 ppg EMW w/ no losses, 250 gpm w/ 2,160 psi = 12.64 ppg EMW w/ no losses, 275 gpm w/ 2,480 psi = 12.71 ppg EMW w/ no losses. 23:00 00:00 1.00 9,260 PROD1 DRILL CIRC P Weight up mud f! 11.4 ppg to 12.4 pph in .5 ppg increments w/ 16.0 ppg spike fluid containing WBS treatment. Pum in 150 m & 1200 si s 02/27/2007 00:00 06:00 6.00 9,260 9,260 PROD1 DRILL CIRC P Continue weight up mud f/ 11.4 ppg to 12.4 ppg in 0.5 ppg increments w/ 16.0 ppg spike fluid containing WBS treatment. Pumping @ 150 gpm & 1050 si initial to 1250 si. 06:00 06:30 0.50 9,260 9,260 PROD1 DRILL CIRC P Perform weltbore test by increasing pump rates: 150 GPM, 60 SPM, 1250 psi, 13.25 ppg ECD; 200 GPM, 80 SPM, 1730 psi, 13.41 ppg ECD; 250 GPM, 100 SPM, 2370 psi, 13.59 ppg ECD; 260 GPM, 105 SPM, 2500 psi, 13.65 ppg ECD. 9260' MD, 4975' TVD. 06:30 08:00 1.50 9,260 9,260 PROD1 DRILL CIRC P Circulate to condition and shear 12.4 ppg LSND mud with WBS materials, 260 GPM, 105 SPM, 2500 si. 08:00 13:30 5.50 9,260 9,374 PROD1 DRILL DDRL P Drill from 9260' MD to 9374' MD, 5070' TVD. 145K# PU, 85K# SO, 110K# Rot Wt. 80 RPM, 3K-15K WOB, 6300 ft-Ib Torque on bottom, 6200 ft-Ib Torque off btm, 86 SPM, 210 GPM, 2100 psi on bottom, 1760 psi off bottom, 13.68 ECD, 140 Units max as, 25 Units back round as. 13:30 15:00 1.50 9,374 9,374 PROD1 DRILL CIRC P Circulate and establish well conditions near top of Bermuda. 210 GPM, 86 SPM, 1900 psi, no gain or loss, 12.4 ppg mud in & out. Take slow pump rates. Monitor well with pump off, static. 15:00 21:00 6.00 9,374 9,576 PROD1 DRILL DDRL P Drill from 9374' to 9576' MD, 5223' TVD. Started losing returns, ECD dropped from 13.5+ ppg to 13.0 ppg, return flow decreased, loss started at 9570' MD. Lost about 19 Bbls before sto in . 21:00 22:00 1.00 9,576 9,576 PROD1 DRILL OWFF T PU off bottom, reduce pump rates to 60 SPM, 50 SPM, 40 SPM, to let WBS material work, continue losing significant returns, approx. 95 Bbls lost so far. ~_..~....~.....~.._._.~. -a m _ ~'~~~~ 'f ~ x~f 2Q l J Time Low -_ - __- _ Da_te_ From To Dur S Depth_,E, Depth Phase Code Subcode T COM ____ 02/27/2007 22:00 00:00 2.00 9,576 9,576 PROD1 DRILL OTHR T Set back stand. Monitor losses, keeping hole full with trip tank. Mix Hi-Vs pill. Reciprocate pipe slowly. Will wait for 250 Bbls of mud from mud plant to arrive, before spotting pill. Static losses 6 BPH. Total loss 139 Bbls. 02/28/2007 00:00 03:30 3.50 9,576 9,576 PROD1 DRILL OTHR T Monitor well, keeping hole full with trip tank, 6 BPH static loss. Mix hi-vise pill. Wait for load of mud from mud lant. 03:30 05:30 2.00 9,576 9,576 PROD1 DRILL CIRC T PJSM. Pump 35 Bbls Hi-Vise pill & spot across loss zone on bottom @ 80 SPM, 2050 psi. POOH slow, idle pump to fill in pill, 4-1/2 stands to 9141'. Approx. 85 Bbi loss spotting ill. 05:30 13:00 7.50 9,576 9,576 PROD1 DRILL OTHR T Maintain hole fill with trip tank, static loss slowed to 1+BPH. Mix 5 ppb fine NP into surtace mud and build surtace volume. Order 500 bbls 12.4 ppg mud with 50 ppb WBS and 5 ppb fine NP from mud lant. 13:00 14:00 1.00 9,576 9,576 PROD1 DRILL TRIP T RBIH slow. 14:00 16:00 2.00 9,576 9,576 PROD1 DRILL CIRC T Pump 26 Bbl Hi-Vise pill with 5 ppb fine NP and WBS materials. Spot on bottom at 20 to 30 SPM, 50 TO 73 GPM, 780 psi. POOH slow to 9141', idle pump to fill in pill. Pumped 126 Bbls, lost 72 Bbls. 16:00 00:00 8.00 9,576 9,576 PROD1 DRILL OTHR T Maintain hole fill with trip tank, static loss 1+ BPH. Work pipe slowly. Wait for 500 Bbls new mud and 60 Bbls Form-A-S ueeze ill from lant. 03/01/2007 00:00 00:30 0.50 9,576 9,576 PROD1 DRILL OTHR T Continue to work pipe, monitor losses. Hold PJSM on circulating Forma-S ueeze. 00:30 01:00 0.50 9,576 9,576 PROD1 RIGMN SVRG P Service and tube rig. 01:00 05:00 4.00 9,576 9,576 PROD1 DRILL CIRC T RIH f/ 9141' - 9556', Displace 25 bbls Forma-Squeeze Treatment. Lost 72 bbls mud w/spotting treatment. POOH f/ 9556' - 8820'. Close annular and initiate squeeze w/ 50 psi f/ 10 min, 100 psi f/ 10 minx 2. 1st attempt on 100 psi bled back to 80 psi. Lost 16 bbls mud total during s ueeze rocecure. 05:00 11:30 6.50 9,576 9,576 PROD1 DRILL CIRC T Brk Circulation at 41 spm, 950 psi SPP. No losses noticed but gas in mud returns. Walk up circ rate to 60 spm/ 1300 psi SPP, then 88 spm/2000 psi SPP. RIH f/ 8820' - 9233'. Max Gas on CBU 5000 units. Mud wt 12.5 ppg. Circulate out gas throu h choke and as buster. ~__ ~ ~ ~ _e ~ ~';~ e 1 ~ c~~ 2~ E E Time Logs.. _._ -- -_ _ Date From To, .____ Dur S. De th E. Depth Phase_ _ Code Subcodz__T COM __ ___ _____ _ __I 03/01/2007 11:30 15:00 3.50 9,576 9,576 PROD1 DRILL CIRC T RIH F/ 8820' - 9233'. Brk circulation w/ monitor for gains and losses, ne li able. 15:00 17:30 2.50 9,576 9,576 PROD1 DRILL TRIP T BD top drive, short trip 10 stds, MU top drive and monitor well for Gain/ Loss, OK. BD top drive, RIH w/ 10 stds. Hole condition ood.. 17:30 19:00 1.50 9,576 9,576 PROD1 DRILL CIRC T M/U TD, start pumping w/ stage rate up to 89 spm at 1990 psi. Max gas at 6258 u on BU. Mud wt 12.5 19:00 21:00 2.00 9,576 9,576 PROD1 DRILL CIRC T PU Std #93 and RIH. Circ @ 89 spm & 1920 psi., Max gas at 4000 units at BU. Continue to circulate out gas, start bld mud wt to 12.7 21:00 00:00 3.00 9,576 9,576 PROD1 DRILL CIRC T Circulate w/ wt up mud to 12.7 ppg. Pre are for TOH. 03/02/2007 00:00 02:00 2.00 9,576 9,576 PROD1 DRILL CIRC T Continue circulating and weight up mud to 12.7 ppg, 88 SPM, 215 GPM, 1900 psi. Final Gas 150 units prior to start of TOH. 02:00 03:30 1.50 9,576 9,576 PROD1 DRILL TRIP P Circulate out 5 stands. Monitor well. Pum slu . 03:30 11:30 8.00 9,576 9,576 PROD1 DRILL TRIP P POOH, slow. 11:30 13:30 2.00 9,576 9,576 PROD1 DRILL TRIP P PJSM, Pull radioctive sources from to in tools, download MWD data. 13:30 16:00 2.50 9,576 9,576 PROD1 DRILL TRIP P Break Out & UD MWD and Directional tools. POOH, LD mud motor and bit. 16:00 16:30 0.50 9,576 9,576 PROD1 WELCT BOPE P Wash stack & RU to test BOPE. Recd verbal waiver of test witness requirement by Chuck Sheve, AOGCC ins ector, at 1000 hrs. 16:30 21:30 5.00 9,576 9,576 PROD1 WELCT BOPE P TEST BOPE starting w/ Choke manifold. Test all to 250!3500 psi. OK. Pull wear bushing, drain stack, set test plug and test stack to 250/3500 si, OK. 21:30 22:30 1.00 9,576 9,576 PROD1 WELCT BOPE P B/D all test equipment, Pull test plug and re-install wear bushin . 22:30 00:00 1.50 9,576 9,576 PROD1 WELCT BOPE P PJSM, P/U / MU BHA #4. 03/03/2007 00:00 03:00 3.00 9,576 9,576 PROD1 DRILL PULD P PU / MU BHA #4 w/ Bit #2, RR2. Shallow test MWD, OK. Install radioactive sources in to in tools. 03:00 04:30 1.50 9,576 9,576 PROD1 DRILL TRIP P TIH to Shoe. 04:30 06:30 2.00 9,576 9,576 PROD1 RIGMN SVRG P Hang off blocks and top drive, slip and cut drill line. 06:30 07:00 0.50 9,576 9,576 PROD1 RIGMN SVRG P Service and Lube Rig. 07:00 11:30 4.50 9,576 9,576 PROD1 DRILL TRIP P Cont RIH f/ 2761' - 6666'. Break Circulation 4 BPM / 1600 si. 11:30 14:30 3.00 9,576 9,576 PROD1 DRILL TRIP P Cont RIH f/ 6666' - 9325'. ~.._.. ~ __ ~'~q~ 3 3 cif ~ Time Logs. Date __ From_ To Dur S, Depth E_ Depth Phase Code__ Subcode T _ COM _ _ 03/03/2007 14:30 20:30 6.00 9,576 9,576 PROD1 DRILL CIRC P Kelly up and break circulation. Displace 12.4# mud in and 12.7# trip mud out. Max gas on BU 1370 units. Condition mud in active system for drill-ahead. 20:30 22:00 1.50 9,576 9,576 PROD1 DRILL REAM P Wash /ream to bottom 9321' - 9576'. Hole in ood condition. 22:00 00:00 2.00 9,576 9,670 PROD1 DRILL DDRL P Drill ahead f/ 9576' - 9670' (5302' TVD). Lose 35 bbls / hr. Total mud loss of 41 bbls since start of pumping. Max gas 2551 units when tag up on bottom. 03/04/2007 00:00 08:30 8.50 9,670 9,950 PROD1 DRILL DDRL P Continue drilling from 9670' - 9950' MD, 5330' TVD - TD. Pump hi-visc swee s as needed to clean hole. 08:30 10:30 2.00 9,950 9,950 PROD1 DRILL CIRC P Pump hi-visc sweep and circulate around 104 SPM, 255 GPM, 2500 psi. Rotate & reci rocate i e. 10:30 15:00 4.50 9,950 9,950 PROD1 DRILL OWFF P Monitor well and work pipe. Well breathing, flowed back 25 bbl gain then levelled off, well stable. 15:00 16:30 1.50 9,950 9,950 PROD1 DRILL TRIP P Break circulation, back ream out of hole to 9616' (short trip), wash to bottom @ 9950', hole good shape. Flow Check, OK. 16:30 20:00 3.50 9,950 9,950 PROD1 DRILL OWFF P Monitor well w/ recip and rotate pipe w/ circulating @ 50 spm & 1120 psi & monitorin well. Losin 16 bbls/ hr. 20:00 21:00 1.00 9,950 9,950 PROD1 DRILL CIRC P PJSM, Pump 35 bbls Form-a-squeeze pill @ 50 spm & 950 psi, displace from TD - 9161'. 21:00 23:00 2.00 9,950 9,950 PROD1 DRILL OTHR P Pump out w/ 1 std, BD top drive and POOH w/ 9 addnl stands to 9045'. Squeeze pill w/ 50 psi f/ 10 min & 100 psi fl10 min. Attempted both w/ rotating through shut annular, unable on 100 psi squeeze, so stopped rotating to finish procedure. Lost 18 bbls fluid immediately on displacement, 4 bbls during squeeze rocess. 23:00 00:00 1.00 9,950 9,950 PROD1 DRILL OWFF P Break Circ w/ 1050 psi @ 50 spm. Recip pipe and monitor well for losses / ains. 03/05/2007 00:00 00:30 0.50 9,950 9,950 PROD1 DRILL CIRC P Continue circulating above pill @ 9045', 50 SPM, 1000 psi, 12.4 ppg mud. 00:30 01:00 0.50 9,950 9,950 PROD1 DRILL OWFF P Monitor well. 1 Bbl flowback and died out. 01:00 04:30 3.50 9,950 9,950 PROD1 DRILL CIRC P Circulate and weight up from 12.4 ppg to 12.6 ppg for trip margin. Circulate 86 SPM, 211 GPM, 1750 si. 04:30 07:30 3.00 9,950 9,950 PROD1 DRILL TRIP P RIH, wash & ream slow, to bottom at 9950' MD. 60 SPM, 150 GPM, 1250 si. ®. ~.~ ~~~ _ .~~ .mm ~ ~~~~ 14 vt 2 • Time Logs Data From_ To Dur _ S,_De th E. DEpth Phase Code Subcode T ~ CUM 03/05/2007 07:30 10:00 2.50 9,950 9,950 PROD1 DRILL CIRC P Circulate to condition mud, adding Drispac and increasing pH. Circulated 2 circulations, 82 SPM, 1750 psi, no gain or loss. R & R pipe 90', 60 RPM, 175K# PU, 85K# SO. 10:00 11:00 1.00 9,950 9,950 PROD1 DRILL REAM P Backream 5 stands out of hole from 9950' to 9486' MD. 50 RPM, 90 SPM, 220 GPM, 2000 si. No losses. 11:00 12:00 1.00 9,950 9,950 PROD1 DRILL TRIP P Pu115 stands on elevators to 9011' MD, 167K# PU, 80K# SO. Hole takin fill u Pum d 'ob. 12:00 21:00 9.00 9,950 9,950 PROD1 DRILL TRIP P Continue POOH to top BHA 21:00 22:00 1.00 9,950 9,950 PROD1 DRILL PULD P POOH LD HWDP and Flex Collars. 22:00 00:00 2.00 9,950 9,950 PROD1 DRILL PULD P PJSM, Remove sources from nuke to in tools. Download MWD data. 03/06/2007 00:00 01:30 1.50 9,950 9,950 PROD1 DRILL PULD P Finish downloading MWD data, LD MWD tools and downhole motor. 01:30 06:30 5.00 9,950 9,950 COMPZ WELCT BOPE P Pull wear bushing, C/O upper rams in stack to 5 1/2" for running casing. W/D stack and BD top drive. Test all 250 / 3500 si. 06:30 08:30 2.00 9,950 9,950 COMPZ CASINC RURD P Rig up casing running equipment, move drillin BHA out of i e shed. 08:30 12:00 3.50 9,950 9,950 COMPZ CASIN RNCS P PJSM, PU and RIH w/ 9.2# 3 1/2" IBT Mod casing as follows: (1) 3 1/2" flt shoe, (3) jts 3 1/2" csg, flt collar, (1) jt 3112" csg, (1) 3 1/2" pup jt, plug catcher, (1) 3 1/2" pupjt, (20) jts 3 1/2" cs for total len th of 765'. 12:00 14:00 2.00 9,950 9,950 COMPZ CASINC RURD P PJSM, RD 3 1/2" csg eq, RU eq to run 5 1 /2" cs . 14:00 16:30 2.50 9,950 9,950 COMPZ CASIN RNCS P RIH w/ 5 1/2" 15.5# L-80 BTC csg f/ 762' - 2809'. PU 60k, SO 68k. 16:30 17:00 0.50 9,950 9,950 COMPZ CASINC CIRC P Break circulation at 2809'. CBU 3 b m 500 si s 17:00 20:00 3.00 9,950 9,950 COMPZ CASIN RNCS P RIH f/ 2809' - 5017', PU 90k, SO 55k. Note abnormal up /down drag this de th 5000 ft. 20:00 21:30 1.50 9,950 9,950 COMPZ CASINC CIRC P Re-cip pipe,break circulation. Start circ @ .5 by w/ 400 psi spp, ramp up rate while CBU. Final rate 3 bpm @ 570 psi. Losing mud throughout circulation, shut down. Final returns 10% of volume pumped. Sticking reduced. Normal drag. Large amount sludge /cuttings to surface. SD, monitor well, note flow back, well breathing. Continue RIH, had 5 bbls above dis Iacement then flow sto . 21:30 23:30 2.00 9,950 9,950 COMPZ CASINC RNCS P Continue RIH w/ 5 1/2" 15.5# L-80 BTC csg f/ 5017' - 6505'. PU 115K, SO 55K. Note dra returnin . • Time Lois 1 Date From To ` bur S. De th E Depth -- PhasE__ Code Subcode T _ _COM 03/06/2007 23:30 00:00 0.50 9,950 9,950 COMPZ CASIN( CIRC P Re-cip pipe. Break circulation. Initiate circ at .5 bpm, work rate up to 1.5 bpm. Returns are 10 % of vol pumped. Circ sludge /cuttings to surface. Pi a free. 03/07/2007 00:00 01:00 1.00 9,950 9,950 COMPZ CASINC CIRC P Circulate w/ recip csg. Pump rate 0.5 - 1 bpm & 600 psi w/ partial returns. PU 105K, SO 65K. 01:00 03:00 2.00 9,950 9,950 COMPZ CASIN RNCS P Cont. RIH w/ 5 1/2" Csg F / 6500' - 7985'. 03:00 04:00 1.00 9,950 9,950 COMPZ CASIN( CIRC P Break Circulation w/ recip casing. Pump rate 0.5 - 1 bpm & 480 psi. PU 125K, SO 65K. Partial returns. 04:00 06:30 2.50 9,950 9,950 COMPZ CASINC RNCS P RIH to TD w/ remaining casing F / 7985' - 9931'. PU 165K, SO 70K. 06:30 13:00 6.50 9,950 9,950 COMPZ CASIN RNCS P Break Circulation w/ recip casing. Pump rate 0.5 - 1.0 bpm w/ partial returns & 750 psi. Per orders, displace mud w/dropping mud wt to 12.3 ppg. Final circ rate 2 bpm & 770 si w/ 10% returns decreasin to 2%. 13:00 15:00 2.00 9,950 9,950 COMPZ CEME~ CIRC P PJSM for cmt job. Install cmt head and connect lines, BD to drive. 15:00 17:30 2.50 9,950 9,950 COMPZ CEME~ DISP P PT cmt lines, cmt per grog. Pump 5 bbls them wash, 35 bbls Mud-Push w/ Cemnet, 49.6 bbls "G", drop plugs connected in tandem, flush cmt lines, pump 20 bbls H2o, cmt displaced w/ 204 bbls drlg mud using rig pumps. Had 10 % returns until last 10 bbls mud displacement, then 0%. Steady increase in pump pressure w! cmt around shoe until bump plug @ 770 psi. Press spike at bump. No press buildup. Pump .5 bbl addntl displacement. Total 204.5 bbls. Check flts, OK. Cmt in place at 1730 hrs. Csg landed in hanger. ICP = 335 psi, FCP = 775 psi. (Linear increase in press ICP to FCP) Re-cip pipe entire 'ob. 17:30 18:30 1.00 9,950 9,950 COMPZ CEME~ DISP P RD cmt head, LD landing jt. 18:30 21:00 2.50 9,950 9,950 COMPZ CASINC RNCS P Install 5 1/2" pack-off & test to 5000 psi f/ 15 min, OK. 21:00 22:30 1.50 9,950 9,950 COMPZ CASIN OTHR P C/O Bails /wash out stack. Clear floor while freeze protect 7-5/8 X 5-1/2 annulus to 2300 ft. 40 bbls diesel, 1100 si in' ress at 1.5 b m. 22:30 00:00 1.50 9,950 9,950 COMPZ RPCOA RURD P C/O upper rams in BOP f/ 5 1/2" to 3 1/2" for runnin tom letion. 03/08/2007 00:00 01:30 1.50 9,950 9,950 COMPZ WELC7 BOPE P PJSM, test rams /door seals 250 / 3500 si followin ram Chan e. 01:30 04:30 3.00 9,950 9,950 COMPZ RPCO11 PULD P PJSM, load pipe shed with 3-1/2 tbg, stra /pre are same. 04:30 07:00 2.50 9,950 9,950 COMPZ RPCOti RURD P RU floor for 3-1/2 tbg run. _ ~ ®_ ~. ~~~ e~~. - P~ca~ ?~ t ~Q t s • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/08/2007 07:00 12:00 5.00 9,950 9,950 COMPZ RPCOh RCST P PJSM, commence MU up seal assy, follow with sliding sleeve / GLMs / necessary XOs. Cont RIH 3-1/2 tbg com letion. 12:00 19:00 7.00 9,950 9,950 COMPZ RPCOti RCST P PJSM, Continue RIH w/ completion string f 3947' - 9094'. Tag up at 9106', expected no-go at 9138'. Break circulation 1 bpm 1080 psi, increase pump rate to 2 bpm and 1270 psi. Wash and to at 9106' 19:00 23:00 4.00 9,950 9,950 COMPZ RPCOfv FCO T Tag up at 9106' w/ expected locate at 9138'. Break circulation 1 bpm 1080 psi, increase pump rate to 2 bpm and 1270 psi. Wash and tag at 9106'. Circulate out heavy mud, sand and LCM. Attempt to wash through obstruction. RU T-Drive, work and wash agressively, unable to wash through. Set 10K wt on tbg, no ro ress, Pre are for POOH. 23:00 00:00 1.00 9,950 9,950 COMPZ RPCOh FCO T Blow down top drive, POOH w/ tbg & completion laying down pipe to make room for picking up 2 7/8" PAC pipe clean-out strip . 03/09/2007 00:00 12:00 12.00 9,950 9,950 COMPZ RPCOh PULD T Cont POH laying do 3-1/2 comp assy for 2-7/8 cleanout string. No swab, correct hole fill. Inspect seal assy. Seals partially cut. Wear on body from trip in /out hole. No damage / indications of contact with foreign ob'ect. 12:00 13:30 1..50 9,950 9,950 COMPZ RPCO PULD T Strap /remove 3-1/2 tbg from pipe shed. Make room for 2-7/8 DP. 13:30 16:00 2.50 9,950 9,950 COMPZ RPCOti PULD T PJSM, LD 1000 ft excess 4" DP from mast in re for 2-7/8 DP. 16:00 19:30 3.50 9,950 9,950 COMPZ WELCT BOPE T PJSM, Change pipe rams to 2-7/8. RU & test 250 / 3500 psi. Pull test lu ,set wear rip , RILD. 19:30 00:00 4.50 9,950 9,950 COMPZ RPCOh PULD T Rack & Tally 300 jts 2 7/8" HTPAC DP in i e shed for clean-out run. 03/10/2007 00:00 00:30 0.50 9,950 9,950 COMPZ RPCOh PULD T Continue to load, strap and tally 2 7/8" HTPAC DP in pipeshed. PU, strap BHA Components. PU and ready runnin ear on floor for same. 00:30 04:00 3.50 9,950 9,950 COMPZ RPCOb PULD T PJSM, MU BHA, RIH w/ cleanout BHA #1 to 2004 ft. 04:00 05:00 1.00 9,950 9,950 COMPZ RPCOh CIRC T M/U XO and hook up top drive. Break circulation to cleanup wellbore fluids and remove solids. Observe following pressure trends: @ 3 bpm - 500 psi, 4 bpm - 690 psi, 5 bpm - 900 psi, 6 bpm 1250 psi. T&D values: PU 55k, SO 55k, ROT wt 55k, Torq 800. Circulate 2 complete hole volumes (45 bbls). Observe large amt of LCM & sand at shakers. Clean up at end of circulation. e~ ~e_.® ~~~ ~~~.~~ ~ ' f ~ ; ~..~~~ fix re 1 J_.( • Time Lois ___._ 1 Date From To Dur S. Depth E. De th Phase Code Subcode T COM __ ___ _ _ _ 03/10/2007 05:00 07:00 2.00 9,950 9,950 COMPZ RPCOh PULD T BD Top Drive, Cont PU and RIH w! 2 7/8" HTPAC DP & mill assembly for clean-out o erations to 4000 ft. 07:00 08:00 1.00 9;950 9,950 COMPZ RPCOh FCO T Circ wellbore clean this stage depth 4000 ft. Large amounts solids /trace cmt to surface. 08:00 10:30 2.50 9,950 9,950 COMPZ RPCOh PULD T Resume RIH 2-7/8 DP to 7000 ft. 10:30 11:30 1.00 9,950 9,950 COMPZ RPCOh CIRC T Circ wellbore clean this stage depth 7000 ft. Large amounts solids /trace cmt to surface. @ 2 pbm 800 psi, 3 bpm 1440 psi, 4 bpm 1830psi, 5 bpm 2550psi. PU 95k, SO 67k, Rot Torq 2500 ftlb both re & ost circ. 11:30 14:00 2.50 9,950 9,950 COMPZ RPCO PULD T Resume RIH 2-7/8 DP to tag at 9102 ft. Will not wash dn. Prepare for wash /drill out. PU 115k, SO 65k, 85k Rot. ICP @ 3 bpm 1800 psi, FCP 1610 psi after clean-u . 14:00 17:30 3.50 9,950 9,950 COMPZ RPCOh FCO T Wash /drill out fill, (3 bpm 1900 psi, WOB 5K), reduced to 1590 psi as annulus unloads solids to surface. Cont wash /drill out 9102 - 9132'. Hard tag at 9132', PU and continue circulate /clean wellbore. Parameters @ clean-out: TD Torq - 2600 ft/Ibs @ 30 r m. Circ 4 b m - 2330 si. 17:30 20:00 2.50 9,950 9,950 COMPZ RPCOA FCO T Pump 35 bbls duo-vis sweep, circulate hole clean, prepare for TOH. @ 4 bpm - 2330 psi, 5 bpm - 3160 psi. Observe fragment wiper rubber & small amt metal on shakers. 20:00 21:00 1.00 9,950 9,950 COMPZ RPCOh PULD T LD working Jt, BD Top Drive, Observe well,- static. 21:00 00:00 3.00 9,950 9,950 COMPZ RPCO PULD T POOH w/mill assembly f/ 9132' - 3811'. 03/11/2007 00:00 04:30 4.50 9,950 9,950 COMPZ RPCOh PULD T Finish POOH w/ clean out BHA #5 (4 3/4" Mill). Clean & inspect mill, OK, dump boot baskets and find metal shavings. Clean floor and prepare for next o eration. 04:30 06:00 1.50 9,950 9,950 COMPZ RIGMN OTHR T PJSM, Slip and cut drill line. 06:00 10:30 4.50 9,950 9,950 COMPZ RPCOh PULD T M/U BHA #6, 3.875" Mill w/ boot basket and jars. RIH - 9132', tag up on obstruction at to of SBE. 10:30 12:00 1.50 9,950 9,950 COMPZ RPCOh FCO T Begin clean out cmt /fill, f/ 9132' - 9153' @ 50 rpm, 3 bpm & 1750 psi. Observe remnants of cmt wiper plug and trace cmt at shakers. Mill com lete SBE to XO. 12:00 15:30 3.50 9,950 9,950 COMPZ RPCOh FCO T Circulate hole clean, @ 3 bpm w/ high-vis sweep. Circulate until observe clean returns at shakers. Prepare to POOH. Pay ~~ ~t ~Q ~~ Time Logs --- -- -- Date From To _____ _Dur S Depth E De th Phase Code Subcode T COM 03/11/2007 15:30 20:30 5.00 9,950 9,950 COMPZ RPCOI~ PULD T LD work jt, BD Top Drive, monitor well, static. POOH w/mill (BHA #6) f/ 9153' -surface. 20:30 21:30 1.00 9,950 9,950 COMPZ RPCOh PULD T LD mill and boot basket. No visible wear on mill. C/U floor for RIH. Make up BHA #7 w/ polish mill. At make-up, box on polish mill swelled. Pull out of string and return to BOT for machine work. 21:30 00:00 2.50 9,950 9,950 COMPZ RPCOh WOEO T W/O repaired polish mill. Service rig top drive and general rig maint until parts returned. Install new seal rings in 3-1/2 tb on rack. 03/12/2007 00:00 05:00 5.00 9,950 9,950 COMPZ RPCOh WOEO T W/O rebuilt polish mill for SBE ! CO BHA Run #7. Perform rig maintenance w/ WOP. Cont install new seal rings in 3-1 /2 tbg for com letion. 05:00 08:00 3.00 9,950 9,950 COMPZ RPCOh PULD T Take delivery repaired polish mill. RIH same w/ BHA #7, RIH same to tag at 9132 ft. 08:00 09:00 1.00 9,950 9,950 COMPZ RPCOh FCO T Commence drill out cmt /wiper plug remnants to btm seal bore at 9151 ft. Semi dense fill, rubber particles to surface with some aluminum shavings. 3 b m / 1700 si. 09:00 11:00 2.00 9,950 9,950 COMPZ RPCOh FCO T C/C fluids, circ shaker clean. 11:00. 12:00 1.00 9,950 9,950 COMPZ RPCOh DHEQ P PJSM, RU /test 5 1/2" csg to 3000 psi / 30 min. Test successful, no re-tests. 12:00 12:30 0.50 9,950 9,950 COMPZ RPCO DHEQ P RD test equip, clear floor. 12:30 16:00 3.50 9,950 9,950 COMPZ RPCOh CIRC P PJSM, displace wellbore to seawater, cont circ shaker clean. 16:00 16:30 0.50 9,950 9,950 COMPZ RPCOb OTHR T PJSM, POH laying do 2-7/8 DP. 16:30 00:00 7.50 9,950 9,950 COMPZ RPCOb OTHR T POOH laying down 2 7/8" HTPAC DP to 3428'. 03/13/2007 00:00 05:00 5.00 9,950 9,950 COMPZ RPCOh OTHR T Finish POOH w/ 2 7/8" HTPAC DP, LD BHA, clear floor. 05:00 08:00 3.00 9,950 9,950 PROD1 RPCOh SFEQ T Pull wear bushing, set test plug, swap 2 7/8" DP rams for 3 1/2" pipe rams for running completion string. Test to 250 / 3500 psi. Pull test plug, clear floor. 08:00 09:00 1.00 9,950 9,950 PROD1 RPCOti RURD T RU rig floor for 3-112 completion 09:00 12:00 3.00 9,950 9,950 PROD1 RPCOA RCST T PJSM, Commence RIH w/ comp assy to 1705' on 3 1/2" 9.3# L-80 IBT Tb . 12:00 21:00 9.00 9,950 9,950 PROD1 RPCOh RCST T Continue RIH w/ 3 1/2" completion. Tag SBE @ 9142' drlrs depth. Strng wt 103k u , 63k dn. j Page 9~ ~F 2Cl Time Logs Data From To Dur S.De th E. De th Phase _ _ Code Subcod e T COM 03/13/2007 21:00 22:00 1.00 9,950 9,950 PROD1 RPCOh _ PACK _ P PJSM, verify location of pkr, RU circ hoses, drop ball & rod, test tbg 2500 psi f/ 15 min, OK. Increase pressure to 4500 psi, shear out of tie back seals w/ 130k pull. Set do 35K, confirm PKR set. Space out 2ft, MU hanger & LJ, Land tbg. while sting in PBR. Mule shoe at 9148, SABL-3 PKR 9082 ft. 22:00 00:00 2.00 9,950 9,950 PROD1 RPCOh HOSO P RU circ hose & brine truck spot & displace corrosion inhibitor in lower tb annulus. 03/14/2007 00:00 01:00 1.00 9,950 9,950 PROD1 RPCOti CIRC P PJSM. Pump 10 bbls corrosion inhibitor, displace w 79 bbls seawater into IA. Pump press 650 psi @ 68 s m. 01:00 03:00 2.00 9,950 9,950 PROD1 RPCOh HOSO P Land hanger, RILDS, RU test IA. Test IA to 2500 psi w/ 1500 psi on tbg f/ 30 min. OK. RD lines. 03:00 04:00 1.00 9,950 9,950 PROD1 RPCOh DHEQ P Bleed off tbg, shear out lower GLM @ 8995. Initiate circulation in both directions, clear. Bleed and drain lines. 04:00 06:00 2.00 9,950 9,950 PROD1 RPCOti NUND P PJSM, BD lines, set BPV, ND BOPE 06:00 08:00 2.00 9,950 9,950 PROD1 RPCOh NUND P NU prod tree. 08:00 09:00 1.00 9,950 9,950 PROD1 RPCOh SFEQ P Pult BPV, set TWC, test prod tree to 250 / 5000 psi. Test successful, no re-tests. 09:00 12:00 3.00 9,950 9,950 PROD1 RPCOti FRZP P PJSM, RU /freeze protect 5-1 /2 X 7-5/8 annulus. Pump 70 bbls diesel 2 bpm / 1900 psi. U tube annulus / tbg to static. "0" psi. Set BPV. 12:00 13:30 1.50 9,950 9,950 PROD1 RPCOti RURD P PJSM, RD /prep rig for move. "NORDIC RIG #3 RELEASED THIS DATE 13:30 HRS" ~_ .....w.w._~___ ® ~~€~~ ~~ ~f 2f} • 2N-3376 Well Events Summary DATE Summary 3/20/07 DRIFTED TBG TO 2.75" TO 9128' RKB & PULLED BALL & ROD. PULLED 1" SOV (BTM LATCH) @ 8994' RKB. REPLACED WITH BTM LATCH DMY. IN PROGRESS. 3/21/07 PULLED 2.75" RHC PLUG BODY W/ X-LOCK @ 9132' RKB. TAG FILL @ 9163' RKB. JOB COMPLETE. 3/25/07 Mobe CTU 4 to location perform 1 1/4" ball stage W/ BOP test 3/26/07 Milled up wiper plug at 9,130' CTMD for sever hours. Passed wiper plug milled cement from 9,133'-9213' CTMD. Unable to continue due to weather conditions deteriorating. While POOH coil became detained @ 8,370' CTMD. Unable to dislodge rubber from mud motor bit box. Disconnected from tool string to POOH. 3/27/07 CTU4 STBY Phase 3 Weather conditions 4/4/07 TAGGED OBSTRUCTION AND BAILED 2 PIECES OF ALUMINUM @ 2515' TO 2598' SLM. TAGGED FISH @ 8341' SLM. RAN MODIFIED 2-1/2" GS TO 8341'. ENGAGED FISH, UNABLE TO MOVE SAME. IN PROGRESS. 4/5/07 RAN MODIFIED 2.5" GR TO 8341' WLM. LATCHED FISH, TAPPING DOWN AND UP. POSSIBLY MOVING FISH UP TO 8339' WLM AND DOWN TO 8341' WLM. IN PROGRESS. 4/6/07 ATTEMPTED WORK FISH @ 8339' WLM; NO MOVEMENT APPARENT IN EITHER DIRECTION. JOB SUSPENDED. 4/7/07 Fished motor and mill from 8374'. Ran venturi junk basket to 9224' and recovered aluminium chunks and shavings. In progress. 4/8/07 Milled cemment from 9198' to 9217' CTMD. From 9217' to 9565' milling highly compacted "WBS" Well Bore Strengthening material. Utilized M-1 recirculation skid with a 2# Biozan system. In progress (Landing collar is at 9799.5' drillers depth). 4/9/07 Milled "Well Bore Strengthening" material from 9595 to 9800' at .5 FPM. PT tubing and liner to 2500 psi. FP well with 22 Bbls. diesel. 4/10/07 DRIFTED THROUGH 'D' NIPPLE @ 9132' RKB w/ 2.68" GAUGE RING (POSSIBLE DAMAGE TO NIPPLE). TAG BOTTOM @ 9781' RKB. JOB COMPLETE. 4/11/07 SLIM CEMENT MAPPING TOOL -CEMENT QUALITY DEEMED SUFFICIENT TO PERFORATE /PERFORATE INTERVAL 9600'-9615' -WHP FROM 750 PSI TO 1100 PSI ~ / STATIC BOTTOM HOLE PRESSURE SURVEY -PRESSURE STOP AT 9600' MD: 3585.3 PSI, 130.6 DEGF /DID NOT TAG TD. 4/14/07 PERFORMED MIT-IA TO 3500 PSI. GOOD TEST. 4/21/07 UNABLE TO COMPLETE JOB. FRAC SCREENED OUT DURING BREAKDOWN STAGE. WELL LOCKED UP @ 9400 PSI WHILE PUMPING 6.8 BPM. HELD 9200 PSI ON WELL WITHOUT LEAKOFF TO FORMATION. PUMPED A TOTAL OF 133 BBLS OF 20# LINEAR GEL. UNABLE TO FREEZE PROTECT WELL. 4/22/07 Encountered large chuncks of cement from 9,291' - 9,446.6' CTMD during FCO. Unable to penetrate further. Call for underreamer in the AM. Restart 06:30. 4/23/07 Removed cement sheen from 9,180' CTMD - 9,761.6' CTMD. Well freeze protected to 6,500' RKB. Injection rate = 1 BPM @ 2,215 PSI / 2 BPM @ 2,715 PSI. Liner opened to 2.85" with assistance of 2 1/8" Reeves underreamer. Freeze protected to 8,500' RKB. 4/28/07 MADE DUMMY GUN RUN TO 9650' WITH 2.5" GUN AND 2.6" ROLLERS. PERFORATED FROM 9600'-9615' WITH 2" HSD 6SPF HYPERJET CHARGES. MADE CORRELATION PASSES FROM 9400'-9650' 5/7/07 Frac with YF150D and 16/20 Carbolite, Pumped total of 2910 bbls water 3234 bbls slurry with 248764# 16/20 Carbolite with 246749# in Perfs with 12 ppa on perfs. Job pumped to completion with 50 bbls of Diesel in the flush BHP est at 3430 psi. 5/8/07 FCO to hard tag at 9732' CTMD, bottom pert at 9615'. Coil unit pump went down while POOH, continued to flow to tanks for an additional 170 Bbls, holding 300 WHP. LRS will FP well. • • 2N-3376 We11 Events Summary 5/9/07 DRIFT TUBING W/ 2.55" CENT & SAMPLE BAILER TO 3200' SLM. BAILER FULL OF FRAC SAND. JOB IN PROGRESS. 5/10/07 ATTEMP TO GET DOWN TO BOTTOM FOR TAG, ENCOUNTERED HEAVY FRAC SAND. INITIAL RUN IN HOLE ABLE TO GET TO 9568' WHILE DISPLACING, STUCK MULTIPLE TIMES. 2ND ATTEMPT, TRIED CLEANING UP TBG WHILE DISPLACING, TBG LOCKED UP, UNABLE TO FALL PAST 6200' SLM w/o PUMP ASSIST. 5/12/07 FCO to hard tag at 9733' CTMD with SSW and Duovis sweeps. Bullhead FP @1 BPM and 1500 psi. Well left shut in. 5/13/07 GAUGE TBG TO 2.65" & TAG @ 9747' RKB. EST 132' RAT HOLE. NO SAMPLE RECOVERED. SET 2.75" AVA CATCHER @ 9129' RKB. ATTEMPT TO PULL DMY VLV @ 8994' RKB. JOB IN PROGRESS. 5/14/07 PULLED 1" DMY VALVE @ 8994' RKB. REPLACED WITH 5l16" ORIFICE. PULLED 2.75" AVA CATCHER @ 9129' RKB. JOB COMPLETE. ~ ~ itr`~~~ ~~} C~rtt~~~~hiilips Al~sk~, ~t~~. KRU 2N-3376 WELL LOG TRANSMITTAL To: State of Alaska May 14, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: 2N-3378 AK-MW-4878300 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#:50-103-20262-02 ~~~- l~3 ~t5~r~~ ,~ :~ ~~~ ~- • ~t~r't~C~~'11~~1~5 TRANSMITTAL FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7"' Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: 2N-337B Permit: 206-163 DATE: 05/08/2007 Kuparuk River Unit 2N-337B Tam Field North Slope, Alaska CDROM and Hardcopy report Final Well report, Epoch Mudlogging, Inc.; Browne, Bietting, March 8, 2007 Equipment and Crew; well details; geological data,drilling data; daily reports; pressure/formation strength Data, Formation Logs Co%rp/ots Formation log (MD) and (TVD), LWD Lithology log (MD) and (TVD); Gas Ratio (MD) and (TVD) Drilling logs: Drilling Dynamics (MD) and (TVD) Please check off each item as received, promptly sign and return the transmittal to address below. To all data recipients. AI/data is confidential unti/State ofAlaska designated A4GCC release date CC: CPAI 2N-337B well data transmittal folder REC E 10/E E Receipt: Date: MAY p 8 2007 aiaska Oil &~AGas Cons. Commission: ~~~~- GIS-Technical Data Management ~ con co~si7lips ~ Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.LemkeCc~Conocophi/lips com ~~ --~~3 ~ ~ s«~ 18-Apr-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-3376 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,824.26' MD Window /Kickoff Survey 2,891.00' MD (if applicable) Projected Survey: 9,950.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ 7 Signed O Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 1a ._ - `1 c~lumherger nPU a Zot!~~ ~'+ Schlumberger -DCS 2525 Gambell Street, Suite 400 4°~ Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 900 Anchorage, AK 99501 Field: Date BL Kuparuk Color CD 04/20/07 1A-10 11638846 INJECTION PROFILE 04/05/07 1 2L-3.13 11628996 LDL 04108/07 1 1 D-137 11628997 INJECTION PROFILE 04/09107 1 2N-31.1A NIA USIT 04/06107 1 2N-3376 11638852 SCMT 04111/07 1 1J-184 11638853 SBHP 04112/07 1 1 H-10 11638844 GLS 03/20/07 1 2W-03 11649957 MEM LDUPPROF 04/10107 1 1 E-112 11638856 INJECTION PROFILE 04114/07 1 1 J-156 11638857 INJECTION PROFILE 04115107 1 1J-127 11638859 INJECTION PROFILE 04117107 1 1J-105 11628994 USIT 04106/07 1 1J-164• 11638858 INJECTION PROFILE 04/16107 1 1J-164 ~ 11638860 INJECTION PROFILE 04117/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. l~ Re: 2N-337B Subject: Re: 2N-337B From: Thomas Maunder <tom_matulder@admin.state.ak.us> Date: Mon, OS Mar 2007 10:26:05 -0900 To.`"Brink, Jason A" <Jason.Brink'~conocophillips.com> Jason, Based on the information you have provided, this "event" will not require the BOP to be tested. However, if you are changing rams to run casing or liner, the changes components should be tested. I believe this is CPAI's standard practice. Call or message with any questions. Tom Maunder, PE AOGCC Brink, Jason A wrote, On 3/5/2007 9:54 AM: Tom Sunday, March 4, Nordic 3 closed the annular preventer around 4" drill pipe during a lost circulation squeeze operation. The well was not attempting to flow. Lost circulation was stopped by spotting an LCM pill on bottom @ 9950' MD and applying 50 psi followed by 100 psi. Do we need to test the annular preventer prior to running casing? Jason Brink Drilling Engineer Phone: 907-265-6419 Office: ATO-1582 1 of 1 3/6/2007 12:30 PM • SARAH PALIN, GOVERNOR 333 W. 71h AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2N-337B ConocoPhillips Alaska, Inc. Permit No: 206-163 Surface Location: 117' FNL, 996' FEL, SEC. 3, T09N, R07E, UM Bottomhole Location: 2881' FNL, 2643' FEL, SEC. 4, T09N, R07E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)59-3607 (pager). re 0 DATED this~day of December, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips « Post Office Box 100380 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.I.thomas@conocophillips.com November 21, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 2N-3376 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 2N-3376, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The expected spud date is January 15, 2007. If you have any questions or require any further information, please contact Jason Brink at 265-6419. Sincerely, 1 ~ 1 Randy Thomas C GKA Drilling Team Leader ~E~G~ V E~ NQV 2 2 2006 Aloska Dil & Gas Cons. Commission Anchorape STATE OF ALASKA RECEIVED ~als Nov 2 2 Zoos ALASKA OIL AND GAS CONSERVATION COMMISSI PERMIT TO DRILL aska Oil & Gas Cons. Clmnmission Anchorage 20 AAC 25.005 1 a. Type of Work: Drill ^ Re-drill Q Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^/ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhiAips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 2N-3376 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10008' ' ND: 5548' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 117' FNL, 996' FEL, Sec. 3, T09N, R07E, UM 7. Property Designation: ADL 375074 ~ Tarn Oil Pool Top of Productive Horizon: 2766' FNL, 2269' FEL, Sec. 4, T09N, R07E, UM 8. Land Use Permit: ALK 4293 13. Approximate Spud Date: 1/15/2007 Total Depth: 2881' FNL, 2643' FEL, Sec. 4, T09N, R07E, UM 9. Acres in Property: 2560 14. Distance to ~ Nearest Property: ,,,f€s 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460597 ~ y- 5911892 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. //Dis~~nc~ ty Nearest ~We1l~hinfPoo~~ 3 3 N~t~~ 16. Deviated wells: Kickoff depth: 2950 • ft. Maximum Hole Angle: 70.8° ~ deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3435 psig Surface: 2873 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica ons pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 6.75" 5.5" 15.5# L-80 BTCM 9172' 28' 28' 9200' 4945' 240 sx GasBLOK 6.75" 3.5" 9.3# L-80 IBTM 810' 9200' 4945' 10008' 5548' see above 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 103 sx AS 1 108' 108' Surface 2830' 7-5/8" 274 sx AS III LW, 2858' 2311' Intermediate 240 sx Class G, 60 sx AS I Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program 0 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jason Brink @ 265-6419 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~`_ ._._ ~ Phone -Z ~ S ~ ~ 3 `? Date ~ r. ~ ~ t ~ ® G -~" Pr h n k Commission Use Only Permit to Drill !/ Number: ,Z,~p ~" ~(0 3 API Number: 50- ~Q~ ~ ~~ Z ~ Q Z. Permit Approval Date: '~~ ~ • ®~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbedrm~ethane as ydrates, or gas contained in shales: ~ Samples req'd: Yes ^ No L!I Mud log req'd: Yes ^ No [~ Other: ~5 C7 O ~ S~ ^•~~ ~ ~ ~ w.v a-'L`'~~ ~ ~ H2S measures: Yes o D' ectional svy req'd: Yes ~ No ^ ~ ~ Q ~ APPROVED BY THE COMMISSION DATE: !~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit in Duplicate .~ /2'p~ ay_~ G ~/y/l~ • Application for Permit to Drill Revision No.O Saved: 21-Nov-06 Permit It Application for Permit to Drill Document nndxiAYizE Well 4fQ1uE Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c) (6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ......................................................................:........................... 5 10 . Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11 . Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding .......................................................................................... . ... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ..................................................................................... 5 2N-3378 061023 PERMIT IT Page 1 of 6 Printed: 21-Nov-06 ORIGINAL .7 Application for Permit to Drill Revision No.O Saved: 21-Nov-06 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments :...........................................................................................................6 Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematic Attachment 4 Cementing Details Attachment 5 Drilling Hazards Summary 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.05'0(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a' suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2N-3376 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)che coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 117' FNL, 996' FEL, Sec 3 T9N, R7E, UM US State Plane 1927, NAD 27, Alaska Zone 04 RKB Elevation 148.8' AMSL Northings: 5,911,892.48 `Eastings: 460,596.61 Pad Elevation 120.9' AMSL Location at Tap of Rroductive Interval 2766' FNL and 2269' FEL, Sec. 4, T9N R7E, UM US State Plane 1927, NAD 27, Alaska Zone 04 Measured De th, RKB: 9412' Northings: 5,909,280.00 Eastings: 454,035.00 Total Vertical De th, RKB: 5098' Total Vertical De th, SS: 4950' Location at Total De th 2881' FNL, 2643' FEL, Sec. 4, T9N, R7E, UM US State Plane 1927, NAD 27, Alaska Zone 04 Measured De th, RKB: 10,008' Northings: 5,909,167.07 Eastings: 453,660.52 Total Vertical Depth, RKB: 5548' Total Vertical De th, SS: 5400' and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) Ifa well is to be intentionally deviated, the application for a Permit to Drill (Form i0-40i) must (1) include a plat, a'rawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion ~~f the proposed well; 2N-3378 061023 PERMIT /T Page 2 of 6 Printed: 21-Nov-O6 • Please see Attachment: Directional Plan Application for Permit to Drill Revision No.O Saved: 21-Nov-06 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dri(1 must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; The BOFE ~,~ri;l consist of an 11" x 5M 80P stack. Please see information on the Nordic Calista Rig #3 blowout pr2~,~ niion equipment placed on file with the Commission. ConocoPhillips plans to arrange the BOPS: as 011o~~.s: Annular 2-7i8" x 5~ VBR Blind Rams Pipe Rams 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dril! must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho/e pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; B~~,,.~w.~3 resC~~r~~r pressure has been measured with slickline gauge and is currently 12.6 ppg EMW in tr;~ ~-c~:`~:er-"ore of this sidetrack candidate. Production has shut in offset injection to help reduce _~s::re. A s_ati~ BHP will be measured again before sidetrack operations begin. T=~ ~:a~:art;um ;c?niai surface pressure (MPSP) while drilling is calculated using above maximum reser~cr p; ~_sGre; a gas gradient of 0.11 psi/ft, and the Bermuda sand target at 5285' TVD: ~~?~~ _(z~5 t}~(O.~iS - 0.11 psi/ft} _ ~? 3 psi (B) data on potential gas zones; .~ i ;~~ ~.~n~~`.I bore is not expected to penetrate any gas zones between KOP and TD. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; ~-geese see At#~eftment: Drilling Hazards Summary. 2N-3378 061023 PERMIT IT Page 3 of 6 Printed: 21-Nov-O6 ORIGINAL • Application for Permit to Drill Revision No.O Saved: 21-Nov-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); A procedure is on file with the commission for performing LOT. If a 16.0 ppg EMW or the maximum EMW specified in the wellplan is reached without indication of leak- off, then this becomes the data for a formation integrity test (FIT) instead of a leak off test (LOT). 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application fora Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 5 'h 6 3/4 15.5 L-80 BTCM 9200 0 / 0 9200 / 4945 Cement Top planned @ 3'/z 6 3/4 9.3 L-80 IBTM 810 9200 / 4945 10008 / 5549 8900' MD/ 4752' TVD. Cemented w/ 240 sx GasBLOK 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and cescription of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under ZO AAC 25.035(h)(2); No diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Production hole Drilling will be done with an LSND type mud system. Drilling will be done having the following approximate properties over the listed intervals: Production Interval (6.75" Hole) Drilling Fluid System ~LSND 2N-3378 061023 PERMIT IT Page 4 of 6 '`~ ~ ~"'°° ~ ~ ~ ~ Printed:21-Nov-06 . ;•::: Application for Permit to Drill Revision No.O Saved: 21-Nov-06 Key Products Duovis, Caustic, Drispac, Resinex, Desco CF, LOTORQ, Drispac, Screen Kleen Solids ControE Shakers, Mud Cleaner, 5500 Centrifuge Potent"sat Problems Pressure and Packing Off, ECD spikes and Hole stability. Low formation integrity, losses INTERVAL MUD PROPERTIES t?epth MD i~} Mud Wt. Eppgt Yield Point (Ib1100ft~) API Fluid Loss (m1130min) HTHP @ 150° (cc) pH 2.G50`- 5.00 9.6 - 10.0 ~ 15 - 20 4 - 6 Less Than 12 9.0 - 10 5,,500` - Q,10Q' 9.6 - 10.0 ~ 15 - 20 4 - 5 Less Than 12 9.3 - 10 Q,,100' -10,008` 11.4 -12.8 = 24 - 28 3 - 4 Less Than 10 9.3 - 10 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic Calista IZg ~3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifred in t`~e application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0330; N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); I'V/:~ - Anplicaa©n is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be .accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a yell drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); l~/`A -Application is not for an offshore well 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app,~ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifred in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application: 2N-3378 061023 PERMIT IT Page 5 of 6 Printed: 21-Nov-O6 ORIGINAL Please see Attachment: Drilling program. Application for Permit to Drill Revision No.O Saved: 21-Nov-06 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well or by injection into a permitted annulus. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage there and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit for annular disposal of fluids occurring as a result of future drilling operations. 15. Attachments Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematic Attachment 4 Cementing Details Attachment 5 Drilling Hazards Summary 2N-337B 061023 PERMIT IT M1 Page 6 of 6 ~ Printed: 21-Nov-O6 ~' Drilling Program Pre-Rig Well Work: 1) Set retainer (w/ SL) and cement squeeze the existing perforations 2) MIT the cement plug 3) Ensure well is dead in OA/IA/Tbg 4) Cut tubing at 9570' and 5) Prep wellhead for rig Sidetrack (Set BPV/VR) Rig Work:. 1. Move in and rig up Nordic 3. 2. Nipple down tree and tubing head adapter. 'J~4 R `~ ~~~a ~ t P~ 3 ~ ~ -3~~' 3. NU and test the 11" x 5K BOPE to 250 PSI / 3500 PSI. ~-~-~ ~~,`~-1 ~.~ ~~~~ 4. Pull and lay down the tubing hanger. Stand back 12 stands of 3-1/2" tubing and lay down the remainder. ~~~ 5. Rig up E-Line. Make up 5-1/2" cast iron bridge plug and set inside 5-1/2" casing at 3400' MD. 6. Jet cut 5-1/2" casing at 3058' MD which is 200' below the 7-5/8" surface casing shoe. 7. Pull and lay down 5-1/2" casing. 8. Make up 3-1/2" mule shoe, 1000' of 3-1/2" tubing stinger, 4" drill pipe and RIH to plug back total depth. 9. Spot an 850' balanced cement plug on top of cast iron bridge plug with the top of cement inside 7-5/8" casing shoe at approximately 2558' MD. 10. Pull out of hole and lay down 3-1/2" tubing stinger. 11. Pick up drilling BHA, 4" drill pipe, and run in hole to top of cement and tag for cement hardness. Test 7-5/8" casing to 3000 PSI for 30 minutes and record on chart. Start of Drilling operations for New Well Th:tiS ~~~ti~ 12. Drill to kickoff point and drill out 20' to 50' of new hole. Perform LOT. 13. Directionally drill 6-3/4" hole section to about 400' above the over-pressured Bermuda. 14. Perform open hole LOT. Perform Wellbore Strengthening (WBS) treatment to achieve a higher LOT if necessary to drill over-pressured Bermuda pay interval. 15. If WBS treatment fails, then run and cement topset 5-1/2" casing. If WBS is a success, then drill to TD and run and cement 5-1/2" x 3-1/2" tapered casing string. Topset Operation 16. Make up 4-3/4" drilling BHA. Clean out to float collar and perform 30 minute casing test to 3,000 psi. Drill out 20 to 50 feet of new hole and perform LOT. 17. Drill 4-3/4" section to TD at 10,008' MD/ 5548' TVD. 18. Run and cement 3-1/2" 9.2# L-80 IBTM liner. 19. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. ORIGINAL Pressure test completion and pro~ion casing to 3000 psi for 30 minutes an _ ord results. Shear RP shear valve in gas lift mandrel. 20. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV 21. Freeze protect well with diesel by pumping into the annulus, taking returns from tubing and allowing to equalize. Sweep the annulus with water and freeze protect. 22. Set BPV and move rig off. Post Rig Procedure 1. Drift and tag 2. Install DV for frac 3. .Perforate 4. frac 5. flowback 6. Put on Production Uzi ~~!~AL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 2N Pad 2N-337 Plan: ZN-3376 Plan: 2N-337Bwp04 Proposal Report 06 July, 2006 Al,~..1 RTC Sperm Drilling ServirGes ORIGINAL `., ConocoPhillips Calculation Method: Minimum C Error System: ISCWSA S°anMeth°'' Trav.CylinderN". Error Surface: Elliptical Conic Warning Method: Rules Based Kuparuk River Unit A~3sk3 Geodetic Datum: NAD 1977 (NADCON (ONUS) Magrctic Model: BGGM2(105 Kuparuk 2N Pad 2N-337 2N-337Bwp04 HA~,~ISURTQN SpfRy DeNling SnNie~s Ground Level: 0.00 RKB: Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) NorthinglASP Y: 5917892.00 Plan: 2N-3376 2N-3376wp04 1500 ~ - 0 - -- -------;- - ---- ---- --_ __; ~ o _ o° ~,o° p~° + .~ -1500 ? -- --. -- -' O w ~ ' . m~ w 1 .oo A _ ~ ~ ~ , , ', O -3000 - -----~~ ----- 2N-3376wp01 T2 ..! -....-_ i i - . -4500 i -7500 -6000 -4500 -3000 -1500 0 1500 West(-)/East(+ (1500 ft/in) 0 o° ~ 10 o ', 2Q 0 ~ N 2000 ----- ~° ~o 0 Q ' I ~ ~° ~ ~ (~ i I I k o ~ ~Q ~ 4000 ------- - - _ _ ..__......... - .._.._..... -- ~~Q' > ~~3 ~o ~o 2N-3376wp01 T2 ~~° 6000 -- -~--- - - _ -2000 0 2000 4000 6000 0 8000 10000 ~~IViIV/~L #' •.. « ~ARC1CClt~~i~?5 Alaska Database: EDM_2003.11_B48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 2N Pad- Well: 2N-337 Wellbore: PIan:2N-3376 Design: 2N-337Bwp04 Sperry Drilling Services HALl.t~uRTt~ilr~l Planning Report -Geographic ---~-~ Sperry Driiiieg Servic®s Local Co-ordinate Reference: Well 2N-337 TVD Reference: Planned Nordic 3 @ 148.SOft (Nordic 3 (27.9 + 120.9)) MD Reference: Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2N-337 _ _ _ Well Position +N/-S 0.00 ft Northing: 5,911,892.60ft Latitude: 70° 10' 12.816" N +E/-W 0.00 ft Easting: 460,596.52ft ~ Longitude: 150° 19' 01.635" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore PIan:2N-3378 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 7/6/2006 23.59 80.62 57,521 Design 2N-337Bwp04 Audit Notes: Version: Vertical Section: Phase: PLAN Tie On Depth: Depth From (TVD) +N/S +E/-W (ft) (ft) (ft) 148.80 0.00 0.00 Direction (°) 253.00 2,922.24 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/_S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°I100ft) (°/100ft) (°/100ft) (°) 2,922.24 69.31 239.22 2,334.02 -864.81 -994.54 0.00 0.00 0.00 0.00 2,950.00 69.52 239.08 2,343.78 -878.14 -1,016.85 0.89 0.76 -0.50 328.01 2,962.00 70.80 240.43 2,347.85 -883.82 -1,026.61 15.00 10.65 11.23 45.00 3,583.45 66.40 252.92 2,575.34 -1,113.16 -1,556.08 2.00 -0.71 2.01 112.92 8,396.54 66.40 252.92 4,502.22 -2,408.47 -5,772.14 0.00 0.00 0.00 0.00 9,412.56 41.00 252.92 5,098.80 -2,646.99 -6,548.47 2.50 -2.50 0.00 -180.00 10,008.81 41.00 252.92 5,548.80 -2,761.88 -6,922.40 0.00 0.00 0.00 0.00 7ia/2Q06 ~=Z4~~ Page 2 of 5 COMPASS 2003.91 Build 50 Q~ I G I N A L • CQt1000P~'11~~1~35 Alaska Database: EDM 2003.11_648 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 2N Pad Well: 2N-337 Wellbore: Plan; 2N-3376 Design: 2N-337Bwp04 Sperry Drilling Services Planning Report -Geographic • HAILL.IBU1l~TAN Sperry Driliin>~ Services Local Co-ordinate Reference: Well 2N-337 TVD Reference: Planned Nordic 3 ~ 148:80ft (Nordic 3.(27.9 + 120.9)) MD Reference: Planned Nordic 3 @ 148:80ft (Nordic 3 (27.9 + 120.9)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 2N-337Bwp04 -_ _. Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/.W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) lft) (n) (°/100ft) (ft) 200.00 0.34 142.46 200.00 51.20 -0.12 0.09 5,911,892.48 460,596.61 0.00 -0.05 300.00 1.26 174.67 299.99 151.19 -1.24 0.59 5,911,891.36 460,597.10 1.00 -0.20 400.00 3.33 195.38 399.91 251.11 -4.97 0.07 5,911,887.63 460,596.56 2.19 1.39 500.00 6.66 200.34 499.54 350.74 -13.00 -2.68 5,911,879.61 460,593.77 3.36 6.36 600.00 10.13 207.98 598.45 449.65 -26.34 -8.65 5,911,866.31 460,587.73 3.63 15.98 700.00 14.02 204.96 696.22 547.42 -45.01 -18.01 5,911,847.69 460,578.28 3.94 30.38 800.00 15.99 197.49 792.77 643.97 -69.38 -27.10 5,911,823.37 460,569.06 2.75 46.20 900.00 15.72 200.09 888.96 740.16 -95.23 -35.99 5,911,797.57 460,560.04 0.76 62.26 1,000.00 15.67 200.00 985.29 836.49 -120.40 -45.30 5,911,772.45 460,550.60 0.06 78.52 1,100.00 16.24 199.54 1,081.39 932.59 -146.47 -54.46 5,911,746.43 460,541.30 0.58 94.90 1,200.00 17.80 202.35 1,177.21 1,028.41 -173.24 -64.55 5,911,719.72 460,531.07 1.77 112.38 1,300.00 20.43 209.12 1,271.61 1,122.81 -203.08 -78.54 5,911,689.95 460,516.93 3.44 134.48 1,400.00 22.20 216.46 1,364.70 1,215.90 -233.64 -98.46 5,911,659.50 460,496.86 3.20 162.47 1,500.00 24.49 223.29 1,456.60 1,307.80 -263.88 -123.70 5,911,629.40 460,471.46 3.54 195.44 1,600.00 28.10 228.22 1,546.33 1,397.53 -294.47 -155.45 5,911,598.98 460,439.55 4.22 234.75 1,700.00 32.15 228.79 1,632.81 1,484.01 -327.46 -193.25 5,911,566.18 460,401.59 4.06 280.54 1,800.00 35.48 229.13 1,715.82 1,567.02 -364.10 -235.25 5,911,529.76 460,359.40 3.34 331.43 1,900.00 39.40 229.51 1,795.26 1,646.46 -403.67 -281.30 5,911,490.44 460,313.15 3.92 387.03 2,000.00 42.78 230.60 1,870.58 1,721.78 -445.90 -331.69 5,911,448.47 460,262.55 3.46 447.57 2,100.00 46.47 232.07 1,941.76 1,792.96 -489.80 -386.49 5,911,404.87 460,207.52 3.83 512.81 2,200.00 50.56 235.32 2,008.00 1,859.20 -533.97 -446.96 5,911,361.02 460,146.83 4.76 583.54 2,300.00 54.59 236.07 2,068.77 1,919.97 -578.79 -512.48 5,911,316.54 460,081.08 4.07 659.31 2,400.00 58.71 237.69 2,123.74 1,974.94 -624.33 -582.48 5,911,271.38 460,010.86 4.34 739.56 2,500.00 62.81 238.72 2,172.51 2,023.71 -670.33 -656.64 5,911,225.77 459,936.46 4.20 823.94 2,600.00 66.16 239.59 2,215.35 2,066.55 -716.50 -734.29 5,911,180.00 459,858.58 3.44 911.69 2,700.00 68.20 240.16 2,253.95 2,105.15 -762.94 -814.00 5,911,133.98 459,778.64 2.11 1,001.49 2,800.00 68.86 241.14 2,290.19 2,141.39 -808.56 -895.27 5,911,088.79 459,697.14 1.12 1,092.55 2,851.00 68.91 240.75 2,308.61 2,159.81 -831.52 -936.92 5,911,066.05 459,655.38 0.72 1,139.09 7 5/8" 2,900.00 69.18 239.70 2,326.14 2,177.34 -854.24 -976.63 5,911,043.54 459,615.55 2.09 1,183.71 2,922.24 69.31 239.22 2,334.02 2,185.22 -864.81 -994.54 5,911,033.06 459,597.58 2.09 1,203.93 Start DLS 0. 89 TFO 328.01 2,950.00 69.52 239.08 2,343.78 2,194.98 -878.14 -1,016.85 5,911,019.86 459,575.21 0.89 1,229.16 Start DLS 15.00 TFO 45.00 2,962.00 70.80 240.43 2,347.85 2,199.05 -883.82 -1,026.61 5,911,014.22 459,565.43 15.00 1,240.15 Start DLS 2. 00 TFO 112.92 3,000.00 70.50 241.17 2,360.44 2,211.64 -901.31 -1,057.90 5,910,996.90 459,534.04 2.00 1,275.20 3,100.00 69.74 243.14 2,394.44 2,245.64 -945.24 -1,141.05 5,910,953.41 459,450.68 2.00 1,367.55 3,200.00 69.01 245.12 2,429.67 2,280.87 -986.08 -1,225.25 5,910,913.01 459,366.27 2.00 1,460.01 3,300.00 68.29 247.13 2,466.09 2,317.29 -1,023.77 -1,310.41 5,910,875.76 459,280.93 2.00 1,552.47 3,400.00 67.60 249.15 2,503.64 2,354.84 -1,058.28 -1,396.42 5,910,841.71 459,194.74 2.00 1,644.82 3,500.00 66.94 251.20 2,542.28 2,393.48 -1,089.56 -1,483.18 5,910,810.88 459,107.83 2.00 1,736.93 3,583.45 66.40 252.92 2,575.34 2,426.54 -1,113.16 -1,556.08 5,910,787.66 459,034.82 2.00 1,813.54 Start Hald 4813.09 3,600.00 66.40 252.92 2,581.96 2,433.16 -1,117.62 -1,570.57 5,910,783.29 459,020.30 0.00 1,828.71 3,700.00 66.40 252.92 2,622.00 2,473.20 -1,144.53 -1,658.17 5,910,756.83 458,932.58 0.00 1,920.34 3,800.00 66.40 252.92 2,662.03 2,513.23 -1,171.44 -1,745.77 5,910,730.38 458,844.85 0.00 2,011.98 3,900.00 66.40 252.92 2,702.07 2,553.27 -1,198.35 -1,833.36 5,910,703.93 458,757.12 0.00 2,103.62 7!8/2008 524:23PM Page 3 of 5 COMPASS 2003.11 Build 50 ~~~~~.~ `~-' , ~ 4~t7~C.`tJ~~~[~35 p~~ Sperry Drilling Services Planning Report -Geographic ~ HA~i..tBtiRTC~W ~°~ ~~~-~~ ~~~-~-~-~-~~°°° Sperry ©rilling .Services Database: EDM 2003.19 B48 Local Co-ordinate Reference: Well 2N-337 Company: ConocoPhillips Alaska Inca ND Reference: Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) Pro)ect: Kuparuk River Unit MD Reference: Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) Site: Kuparuk 2N Pad North Reference: True Well: 2N-337 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2N-337B Design: 2N-337Bwp04 Planned Survey 2N-337Bwp04 Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ff) (°) (°) (ft) (ff) lft) (ft) (ft) (ft) (°/100ft) (ft) 4,000.00 66.40 252.92 2,742.10 2,593.30 -1,225.26 -1,920.96 5,910,677.47 458,669.40 0.00 2,195.25 4,100.00 66.40 252.92 2,782.13 2,633.33 -1,252.18 -2,008.55 5,910,651.02 458,581.67 0.00 2,286.89 4,200.00 66.40 252.92 2,822.17 2,673.37 -1,279.09 -2,096.15 5,910,624.57 458,493.95 0.00 2,378.53 4,300.00 66.40 252.92 2,862.20 2,713.40 -1,306.00 -2,183.74 5,910,598.12 458,406.22 0.00 2,470.16 4,400.00 66.40 252.92 2,902.24 2,753.44 -1,332.91 -2,271.34 5,910,571.66 458,318.49 0.00 2,561.80 4,500.00 66.40 252.92 2,942.27 2,793:47 -1,359.82 -2,358.94 5,910,545.21 458,230.77 0.00 2,653.44 4,600.00 66.40 252.92 2,982.31 2,833.51 -1,386.74 -2,446.53 5,910,518.76 458,143.04 0.00 2,745.07 4,700.00 66.40 252.92 3,022.34 2,873.54 -1,413.65 -2,534.13 5,910,492.30 458,055.32 0.00 2,836.71 4,800.00 66.40 252.92 3,062.37 2,913.57 -1,440.56 -2,621.72 5,910,465.85 457,967.59 0.00 2,928.34 4,900.00 66.40 252.92 3,102.41 2,953.61 -1,467.47 -2,709.32 5,910,439.40 457,879.86 0.00 3,019.98 5,000.00 66.40 252.92 3,142.44 2,993.64 -1,494.38 -2,796.91 5,910,412.94 457,792.14 0.00 3,111.62 5,100.00 66.40 252.92 3,182.48 3,033.68 -1,521.30 -2,884.51 5,910,386.49 457,704.41 0.00 3,203.25 5,200.00 66.40 252.92 3,222.51 3,073.71 -1,548.21 -2,972.11 5,910,360.04 457,616.69 0.00 3,294.89 5,300.00 66.40 252.92 3,262.55 3,113.75 -1,575.12 -3,059.70 5,910,333.58 457,528.96 0.00 3,386.53 5,400.00 66.40 252.92 3,302.58 3,153.78 -1,602.03 -3,147.30 5,910,307.13 457,441.23 0.00 3,478.16 5,500.00 66.40 252.92 3,342.61 3,193.81 -1,628.95 -3,234.89 5,910,280.68 457,353.51 0.00 3,569.80 5,600.00 66.40 252.92 3,382.65 3,233.85 -1,655.86 -3,322.49 5,910,254.23 457,265.78 0.00 3,661.44 5,700.00 66.40 252.92 3,422.68 3,273.88 -1,682.77 -3,410.08 5,910,227.77 457,178.06 0.00 3,753.07 5,800.00 66.40 252.92 3,462.72 3,313.92 -1,709.68 -3,497.68 5,910,201.32 457,090.33 0.00 3,844.71 5,900.00 66.40 252.92 3,502.75 3,353.95 -1,736.59 -3,585.27 5,910,174.87 457,002.60 0.00 3,936.35 6,000.00 66.40 252.92 3,542.78 3,393.98 -1,763.51 -3,672.87 5,910,148.41 456,914.88 0.00 4,027.98 6,100.00 66.40 252.92 3,582.82 3,434.02 -1,790.42 -3,760.47 5,910,121.96 456,827.15 0.00 4,119.62 6,200.00 66.40 252.92 3,622.85 3,474.05 -1,817.33 -3,848.06 5,910,095.51 456,739.43 0.00 4,211.26 6,300.00 66.40 252.92 3,662.89 3,514.09 -1,844.24 -3,935.66 5,910,069.05 456,651.70 0.00 4,302.89 6,400.00 66.40 252.92 3,702.92 3,554.12 -1,871.15 -4,023.25 5,910,042.60 456,563.97 0.00 4,394.53 6,500.00 66.40 252.92 3,742.96 3,594.16 -1,898.07 -4,110.85 5,910,016.15 456,476.25 0.00 4,486.17 6,600.00 66.40 252.92 3,782.99 3,634.19 -1,924.98 -4,198.44 5,909,989.69 456,388.52 0.00 4,577.80 6,700.00 66.40 252.92 3,823.02 3,674.22 -1,951.89 -4,286.04 5,909,963.24 456,300.80 0.00 4,669.44 6,800.00 66.40 252.92 3,863.06 3,714.26 -1,978.80 -4,373.64 5,909,936.79 456,213.07 0.00 4,761.07 6,900.00 66.40 252.92 3,903.09 3,754.29 -2,005.71 -4,461.23 5,909,910.34 456,125.35 0.00 4,852.71 7,000.00 66.40 252.92 3,943.13 3,794.33 -2,032.63 -4,548.83 5,909,883.88 456,037.62 0.00 4,944.35 7,100.00 66.40 252.92 3,983.16 3,834.36 -2,059.54 -4,636.42 5,909,857.43 455,949.89 0.00 5,035.98 7,200.00 66.40 252.92 4,023.20 3,874.40 -2,086.45 -4,724.02 5,909,830.98 455,862.17 0.00 5,127.62 7,300.00 66.40 252.92 4,063.23 3,914.43 -2,113.36 -4,811.61 5,909,804.52 455,774.44 0.00 5,219.26 7,400.00 66.40 252.92 4,103.26 3,954.46 -2,140.28 -4,899.21 5,909,778.07 455,686.72 0.00 5,310.89 7,500.00 66.40 252.92 4,143.30 3,994.50 -2,167.19 -4,986.81 5,909,751.62 455,598.99 0.00 5,402.53 7,600.00 66.40 252.92 4,183.33 4,034.53 -2,194.10 -5,074.40 5,909,725.16 455,511.26 0.00 5,494.17 7,700.00 66.40 252.92 4,223.37 4,074.57 -2,221.01 -5,162.00 5,909,698.71 455,423.54 0.00 5,585.80 7,800.00 66.40 252.92 4,263.40 4,114.60 -2,247.92 -5,249.59 5,909,672.26 455,335.81 0.00 5,677.44 7,900.00 66.40 252.92 4,303.43 4,154.63 -2,274.84 -5,337.19 5,909,645.80 455,248.09 0.00 5,769.08 8,000.00 66.40 252.92 4,343.47 4,194.67 -2,301.75 -5,424.78 5,909,619.35 455,160.36 0.00 5,860.71 8,100.00 66.40 252.92 4,383.50 4,234.70 -2,328.66 -5,512.38 5,909,592.90 455,072.63 0.00 5,952.35 8,200.00 66.40 252.92 4,423.54 4,274.74 -2,355.57 -5,599.98 5,909,566.45 454,984.91 0.00 6,043.99 8,300.00 66.40 252.92 4,463.57 4,314.77 -2,382.48 -5,687.57 5,909,539.99 454,897.18 0.00 6,135.62 8,396.54 66.40 252.92 4,502.22 4,353.42 -2,408.47 -5,772.14. 5,909,514.45 454,812.49 0.00 6,224.09 Start DLS 2aft TFEk -1 80-00 8,400.00 66.31 252.92 4,503.61 4,354.81 -2,409.40 -5,775.17 5,909,513.54 454,809.46 2.48 6,227.26 8,500.00 63.81 252.92 4,545.77 4,396.97 -2,436.02 -5,861.84 5,909,487.37 454,722.66 2.50 6,317.93 8,600.00 61.31 252.92 4,591.84 4,443.04 -2,462.09 -5,946.67 5,909,461.75 454,637.70 2.50 6,406.67 8,700.00 58.81 252.92 4,641.74 4,492.94 -2,487.54 -6,029.50 5,909,436.73 454,554.74 2.50 6,493.32 S ~~-f' Page 4 of 5 COMPASS 2003.11 Build 50 ORIGINAL Conoco~hillips Alaska Sperry Drilling Services Planning Report -Geographic Database: EDM 2003.11 648 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit. Site: Kuparuk 2N Pad Well: 2N-337 Wellbore: PIan:2N-3376 Design: 2N-337Bwp04 Planned Survey 2N-337Bwp04 i HA~~>is~RTla~ Sperry Drilling Services Local Co-ordinate Reference: Well 2N-337 TVD Reference: Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) MD Reference: Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) North Reference: True Survey Calculation Method: Minimum Curvature Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) (ft) lft) 8,800.00 56.31 252.92 4,695.37 4,546.57 -2,512.32 -6,110.17 5,909,412.37 8,900.00 53.81 252.92 4,752.63 4,603.83 -2,536.40 -6,188.53 5,909,388.71 9,000.00 51.31 252.92 4,813.41 4,664.61 -2,559.71 -6,264.42 5,909,365.79 9,100.00 48.81 252.92 4,877.60 4,728.80 -2,582.23 -6,337.71 5,909,343.65 9,200.00 46.31 252.92 4,945.07 4,796.27 -2,603.91 -6,408.26 5,909,322.35 9,276.47 44.40 252.92 4,998.80 4,850.00 -2,619.89 -6,460.26 5,909,306.64 51/2" 9,300.00 43.81 . 252.92 5,015.70 4,866.90 -2,624.70 -6,475.92 5,909,301.91 9,400.00 41.31 252.92 5,089.34 4,940.54 -2,644.56 -6,540.57 5,909,282.39 9,412.56 41.00 252.92 5,098.80 4,950.00 -2,646.99 -6,548.47 5,909,280.00 Start Hold 596.26 - 2N-3 37Bwp01 T2 9,500.00 41.00 252.92 5,164.79 5,015.99 -2,663.84 -6,603.31 5,909,263.44 9,600.00 41.00 252.92 5,240.26 5,091.46 -2,683.11 -6,666.02 5,909,244.50 9,700.00 41.00 252.92 5,315.73 5,166.93 -2,702.38 -6,728.73 5,909,225.56 9,800.00 41.00 252.92 5,391.21 5,242.41 -2,721.64 -6,791.45 5,909,206.62 9,900.00 41.00 252.92 5,466.68 5,317.88 -2,740.91 -6,854.16 5,909,187.68 10,000.00 41.00 252.92 5,542.15 5,393.35 -2,760.18 -6,916.87 5,909,168.74 10,008.81 41.00 252.92 5,548.80 5,400.00 -2,761.88 -6,922.40 5,909,167.07 TD at 10008.81 - 3 1/2" 'Geologic Targets Plan: 2N-337B TVD (ft) 5,098.80 - Point Prognosed Casing Points Target Name +N/-S -Shape ft 2N-337Bwp01 T2 -2,646.99 Map Fasting DLSEV Vert Section (ft) (°/100ft) (ft1 454,473.95 2.50 6,577.72 454,395.48 2.50 6,659.69 454,319.47 2.50 6,739.09 454,246.07 2.50 6,815.76 454,175.42 2.50 6,889.55 454,123.34 2.50 6,943.96 454,107.66 2.50 6,960.34 454,042.91 2.50 7,027.97 454,035.00 2.51 7,036.24 453,980.08 0.00 7,093.61 453,917.28 0.00 7,159.21 453,854.47 0.00 7,224.82 453,791.66 0.00 7,290.42 453,728.86 0.00 7,356.03 453,666.05 0.00 7,421.63 453,660.52 0.00 7,427.42 +E/-W Northing ft (ft) -6,548.47 5,909,280.00 Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 2,851.00 2,308.61 7-5/8 9-7/8 9,276.47 4,998.80 5-1/2 6-3/4 10,008.80 5,548.79 3-1/2 6-3/4 _ -~ Fasting (ft) 454,035.00 7/62006 5:24:29PM Page 5 of 5 COMPASS 2003.11 Build 50 ~~~ • • ConocoPhillips ~~~ ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 2N Pad 2N-337 Plan: 2N-3376 Anticollision Report 06 July, 2006 Sperry Drilling Services ORIGINAL '~ _ ~~ V I Y ANTIJ:OLLIBION: ConoCOPhilli s 2N-3376wp04 IMerpDMXOn M.IMA MO p C.bNeXa+NeMed: Min Q} k Meal Yi il 2822 To 10008.81 Eyler M.Gal'. IBC Bc.n N.Xwd Tu Ertor BUrfau: Ellil MALLI9URTON wNnin N.am: Rm iQMBr OANMY SRVICM NI'RtF.I' PR(H:R,JtI DNe: 2U11~U]-0hTW:W:W V.Ilderrd: l'n Venbn: ,. ••• ". CorornPNNq NarJ.Inc peplh Frvm Ikph T. NNrvry/PbX 341.90 2922Sd Teel hMU 2922.EJ I000B.B1 2\.33'/RwRW M\'M14R-A A{'AZBC' ea P e SM HuDa ux 2N PeE WeR °J4JJ] D.nm vnll ~b01300 ,;:' -90127 -1201240 -750121 Fr.n cra. T. MO CfItICaI Issues: ~~ / ~- ..- .I NEGATIVE TFO.Ari values hom the Survey Etlimr ar Travelllnp Cylinder Report should be plotted on Ihs IeR side otma Travelling cylinaar. Travelling Cylinder Azimuth (TFO+AZI) [°) vs Centre to Centre Separation [25 Ninl -90 / Tnrellios cyRader AJwlulh I7'F04AZ11 I°I rs Ceorre to Ceptre SepanPoB IS fuinl secTlos oerAlLs Ner \III Inr 1xl T\'II +\'I ti +FJ-N' OI.eR TFarr VXrr l'vRrr 1 2912.2) 6931 249.22 25)).02 -Bti1.N1 -99).4 U.W U.W 120).91 2 295111X1 69.(2 219.ON 2311.)X -X'INIJ -11114X5 U.N9 3TA.111 1329.16 2962.W ]U.NU 2JU.J3 2JJ].& -NR1.ffi -IU2461 i(W 1SW 12)415 J SSMJ.JS 56JU 252.91 25](JJ -111!.16 -ISK.W i.W IIL92 IN13.4 5 X4964 64JU L292 1412.22 -2JWJ) -5']21) XW XW 622J.W 6 9J1 Z.Sh JI MI 252.92 51191LW -26Je.99 -64N.J" 2.511 -IXXW ]036.2) 3\-3J'1Rwp01 Ti 1 IWW.XI JI.W 252.92 54X.W -2]61.tlB -h922W XW UW ]J2].J2 • 7/6/2006 5:22 PM / ~ Sperry Drilling Services Conoc©Ph~l~ps Anticollision Report Alaska Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 2N Pad Site Error: O.OOft Reference Well: 2N-337 Well Error: O.OOft Reference Wellbore Plan: 2N-3376 Reference Design: Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HQL.LIBURTOIV Spe~'y D~illing Servtrces Well 2N-337 Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) Planned Nordic 3 @ 148.80ft (Nordic 3 (27.9 + 120.9)) True Minimum Curvature 2.00 sigma E D M_2003.11 _648 Offset Datum Reference Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen Interpolation Method: MD Interval 100.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Mabmum center-center distance of 1,186.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Prograrn Date 7!6/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 250.90 2,922.24 2N-337 (2N-337) MWD MWD -Standard 2,922.24 10,008.81 2N-3376wp04 (Plan: 2N-3376) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 2N Pad 2N-321 - 2N-321 - 2N-321 483.07 500.00 234.22 6.23 228.03 Pass -Major Risk 2N-321 - 2N-321A - 2N-321A 483.07 500.00 234.22 6.23 228.03 Pass -Major Risk 2N-323 - 2N-323 - 2N-323 571.72 600.00 207.33 8.09 199.25 Pass -Major Risk 2N-325 - 2N-325 - 2N-325 395.18 400.00 177.32 4.45 172.87 Pass -Major Risk 2N-326 - 2N-326 - 2N-326 659.73 700.00 156.73 9.51 147.63 Pass -Major Risk 2N-326 -Plan 2N-326A - 2N-326A (wp02) 656.07 700.00 156.59 9.43 147.57 Pass -Major Risk 2N-329 - 2N-329 - 2N-329 299.61 300.00 120.16 2.95 117.21 Pass -Major Risk 2N-331 - 2N-331 - 2N-331 492.69 500.00 84.50 8.79 75.85 Pass -Major Risk 2N-332 - 2N-332 - 2N-332 584.80 600.00 66.41 7.91 58.81 Pass -Major Risk 2N-332 - 2N-332P61 - 2N-332PB1 584.80 600.00 66.41 7.91 58.81 Pass -Major Risk 2N-333 - 2N-333 - 2N-333 883.14 900.00 54.78 16.63 39.82 Pass -Major Risk 2N-335 - 2N-335 - 2N-335 299.91 300.00 30.38 2.90 27.48 Pass -Major Risk 2N-337 - 2N-337 - 2N-337 2,999.97 3,000.00 1.49 0.53 0.98 Pass - No Errors 2N-337 - 2N-337A - 2N-337A 2,999.97 3,000.00 1.49 0.53 0.98 Pass - No Errors 2N-339 - 2N-339 - 2N-339 703.48 700.00 22.89 10.31 12.79 Pass -Major Risk 2N-341 - 2N-341 - 2N-341 708.91 700.00 63.60 11.30 52.76 Pass -Major Risk 2N-343 - 2N-343 - 2N-343 610.33 600.00 92.45 8.54 84.09. Pass -Major Risk 2N-345 - 2N-345 - 2N-345 711.09 700.04 114.48 10.36 104.20 Pass -Major Risk 2N-345 - 2N-345A - 2N-345A 708.95 700.00 114.38 10.31 104.14 Pass -Major Risk 2N-347 - 2N-347 - 2N-347 397.11 400.00 151.80 4.39 147.42 Pass -Major Risk 2N-348 - 2N-348 - 2N-348 716.48 700.00 164.91 15.89 149.69 Pass -Major Risk 2N-348 - 2N-348 - 2N-348 wp03 716.47 700.00 164.07 15.89 148.80 Pass -Major Risk 2N-349 - 2N-349 - 2N-349 810.23 800.00 189.44 12.38 177.15 Pass -Major Risk 2N-349 - 2N-349A - 2N-349A 810.23 800.00 189.44 12.38 177.15 Pass -Major Risk 2N-350 - 2N-350 - 2N-350 400.38 400.00 192.78 7.17 185.61 Pass -Major Risk 2N-350 - 2N-350 - 2N-350 WP03 618.48 600.00 198.08 11.94 186.39 Pass -Major Risk Plan: 2N-322 - Plan: 2N-322 - 2N-322wp02 393.51 400.00 225.87 5.81 220.06 Pass -Major Risk Plan: 2N-327 - Plan: 2N-327 - 2N-327wp04 489.74 500.00 151.43 7.75 143.70 Pass -Major Risk Plan: 2N-327 - Plan: 2N-327PB1 - 2N-327PB1wp04 489.74 500.00 151.43 7.75 143.70 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/6/2006 5:06:15PM Page 2 of 2 COMPASS 2003.11 Build 50 ORIGINAL 2N-337B ~ETRACK PLAN A Longstring w/ WBS Treatment 8/23/06 7-5/8" 29.7# L80 casing @ 2858' MC / 2311' ND Sidetrack KOP +/- 2950' MD, 2343' TVD 5-'/z" 15.5# Casinc Cut @+/-3058' MC Baker "K-1" CIBF +/- 3400' MD Tubing chemical c~ @ 9500' M D Cement Retainer +/- 9650' MD 5-'/2' X 3-'/2' I String TD @ 1 MD 26.45' )ESCRIPTION i and Cross-over pupjt ~ € intsforspace out as needed 801BT mod boxxEUE pin fipple 3-1 /2" EUE mod box x pin 80 EUE mod boxx IBT pin 3i 3T mod i2-9 (3-1 /2" IBT B x B) w/ DV 3T pin x pin [ ~. `` 3T mod `_ i2-9 (3-1 /2" IBT B x B) w/ DV 3T pin x pin g ~ i 3T mod j ;2-9 (3-1/2" IBT B x B) w/ DV 3T pin x pin 9 3T mod ;2-9 (3-1 /2" IBT B x B) w/ DV 3T pin x pin 9 3T mod i2-9 (IBT B x B) w/ DCK shear valve 3T pin x pin i ~8016T mod boxxEUE pin 12 DS profile 3.5" EUE BxP (closed) ~d ~d 3-1 /2"EUE mod box x pin ng =UE mod for4.125"Tie Back Sleeve E boxx 1/2 mule shoe DESCRIPTION 5.5 # L-80 BTC mod casing Cross-0versub 5.5" BTC mod boxx Stub Acme Box 80-40 Seal Bore Extension Stub Acme pin x pin 20' Cross-over sub stub acme boxx3-1/2" IBT pin " 9.3 # L-80 IBT mod Pup Joint s of liner 3-1/2" 9.2 # L-80 IBT mod s-over pupjoint3-1/2" 9.2#L-8016T mod boxx EUE pin i in Bypass RecepTicle (AKA landing Collar) rover Pup joint3-1/2" 9.2# L-80 EUE boxx IBT pin !" 9.2 # L-80 IBT mod tCollar 3-1/2" IBT mod boxx pin !" 9.3 # L-80 IBT mod VELRY SUMMARY: ~ple @ 500' MD Depth Depth Valve Valve IL/D MD ~D Tvoe 2500 3377 1.00 Dummy 3650 6244 1.00 Dummy 4435 8188 1.00 Dummy 4935 9180 1.00 SOV iandrel should be 1 joi nt above sliding sleeve. Sleeve w/ 2.812" DS profile @ 2 jts above seal assembly e @ 1 jt above seal asse mbly Production Hole Logging: Longstring - LWD Triple Combo Topset -Open hole GR/Res/Neu/Den Estimated BHP 12.6 PPG JAB ~nocoPhiflips '!BI6INAL 5-'/" x 3-'/2' casing point 2N-337B SID ACK • ~r~c~~Ph ~ I 1 ~ PLAN B TOPSET 8/23/06 Original completion Doyon 141 RT to LDS = 26.45' COMMODITY# DESCRIPTION 7-5/8" 29.7# L80 casing @ 2858' MD / 2311' TVD Sidetrack KOP @ +/- 2950' MD, 2343' TVD 5-'/2' 15.5# Casing Cut @+/-3058' MD Baker "K-1" CIBP @ +/- 3400' MD Tubing chemical cut @ 9500' MD 1 FMC FMC Gen V tubing Hanger and Crossover pup jt. 1 CPAI 3-1 /2" 9.3 # L-80 IBT mod Tubing xx CPAI 3-1 /2" 9.3 # L-80 IBT mod pup joints for space out as needed xx CPAI 3-1/2" 9.3 # L-80 IBT mod Tubing 1 CPAI 3-1 /2" Cross-over Pup jt. 9.3 # L-80 IBT mod box x EUE pin 1 Camco 2.875" Camco DS landing nipple 3-1 /2" EUE mod box x pin 1 CPAI 3-1/2" Cross-over Pup jt. 9.3 # L-80 EUE mod box x IBT pin xx CPAI 3-1/2" 9.3 # L-80 IBT mod Tubing 1 CPAI 3-1/2" Tubing Pup jt. 9.3 # L-80 IBT mod 1 Camco GLM Camco 3-1/2" x 1" KBG2-9 (3-1/2" IBT B x B) w/ DV 1 CPAI 3-1 /2" Tubing Pupjt. 9.3 # L-80 IBT pin x pin xx CPAI 3-1 /2" 9.3 # L-80 IBT mod Tubing 1 CPAI 3-1 /2" Tubing Pup jt. 9.3 # L-80 IBT mod 1 Camco GLM Camco 3-1 /2" x 1" KBG2-9 (3-1 /2" IBT B x B) w/ DV 1 CPAI 3-1 /2" Tubing Pup jt. 9.3 # L-80 IBT pin x pin xx CPAI 3-1/2" 9.3 # L-80 IBT mod Tubing 1 CPAI 3-1/2" Tubing Pup jt. 9.3 # L-80 IBT mod 1 Camco GLM Camco 3-1/2" x 1" KBG2-9 (3-1 /2" IBT B x B) w/ DV 1 CPAI 3-1/2" Tubing Pup jt. 9.3 # L-80 IBT pin x pin xx CPAI 3-1/2" 9.3 # L-80 IBT mod Tubing 1 CPAI 3-1/2" Tubing Pup jt. 9.3 # L-80 IBT mod 1 Camco GLM Camco 3-1/2" x 1" KBG2-9 (3-1 /2" IBT B x B) w/ DV 1 CPAI 3-1/2" Tubing Pup jt. 9.3 # 1.-801BT pin x pin xx CPAI 3-1/2" 9.3 # L-80 IBT mod Tubing 1 CPAI 3-1 /2" Tubing Pup jt. 9.3 # L-80 IBT mod 1 Camco GLM Camco 3-1 /2" x 1" KBG2-9 (IBT B x B) w/ DCK shear valve 1 CPAI 3-1 /2" Tubing Pup jt. 9.3 # L-80 IBT pin x pin 1 CPAI 3-1 /2" Crossover Pup jt. 9.3 # L-80 IBT mod box x EUE pin 1 810794430 CMU Sliding Sleeve w/ 2.612 DS profile 3.5" EUE BxP (closed) 1 CPAI 3-1 /2" Pupjt. 9.3# L-80 EUE mod 1 CPAI 3-1/2" Tubing 9.3 # L-80 EUE mod 1 Camco Camco Nipple w/ 2.750 "D" 3-1 /2" EUE mod box x pin 1 CPAI 3-1/2" 9.3 # L-80 EUE mod Tubing 1 CPAI 3-1 /2" Tubing Pupjt. 9.3 # L-80 EUE mod 1 297500147 BOT Bullet Seal Assembly for 4.125" Tie Back Sleeve w/ 15' stroke and 3-1 /2" EUE box x 1/2 mule shoe LINER ASSEMBLY: xx GPAI z-rr8' pritl Pi a to st,rtaGe 1 BOT Rota. GrossavarSub 2-~8" ;aLt~Bt)Hax b ~TrB" t~ Ptn 1 B4T OP Pu JaintwlHRO Runrdn Tool W ratatin da sub 2-7r8" IF Box U includes 3-1r2" linerwi er Iu ahead insfat~d i HNBxxxxxx 15'Tie-Back! Ex~nsian 4118° iQ t 296280579 Baker 3.59.2sx5,515.5•t71F.L-80.Z5CPLinerTa PackerYVrHR&HO 3U1700tsetdawnwei fttatthetaa 1 292231]212 Baker 3.5°9.2tGx 5.5"1d•tI#~ L•8t) HMGLinerHan Br. innedbr+t-25tIQ 5i. 3.5"tBT inxSLHT in XX GPAt 3.1x2"9.2#IBT-MOrJ,L•BQGasin Jts. 1 HhtB131113V 3.1x2" 9.2 tCL-8Q IBT Landi GallarTYpe 1, boxx in 1 GPAt 3-172" 9.2 #11BT-Mod L•80 Galin Joint 1 PESI 3.112" t=~atGobar TUBING JEWELRY SUMMARY: 2.875" DS nipple @ 500' MD Depth Depth Valve Valve Tvoe TVD t~ ~ ,(~ 1 KGB-2 2500 3377 1.00 Dummy KGB-2 3650 6244 1.00 Dummy KGB-2 4435 8188 1.00 Dummy KGB-2 4935 9180 1.00 SOV Cement Retainer set @ +/- 9650' MD 5-'/z' X 3'/z' Long String TD @ 10231' MD Top Liner set at \ 8950' M D Top set 5-''/z' Casing at 9100 MD / 4877 TVD TOC= 8600' MD TD @ 10008 MD/ 5549 NOTE: 4'h mandrel should be 1 joint above sliding sleeve. CMU Sliding Sleeve w/ 2.812" DS profle @ 2 jts above seal assembly 2.75" D nipple @ 1 jt above seal assembly Production Hole Logging: Longstring - LWD Triple Combo Topset -Open hole GR/Res/Neu/Den Estimated BHP 12.6 PPG ~ JAB Schlumberger CemCADE Preliminary Job Design 3 1/2" to 5 1 /2" Lon strin Preliminary Job Design based on limited input data. For estlmate purposes only. Rig: Location: Tarn Client: ConocoPhillips Alaska Revision Date: 11/16/2006 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com ^ revlous sg. 7 5/8", 29.7# casing @ 2858' MD 5 1/2", 15.5# casing < Top of Tail at 8,900' MD Taper at 9,100' MD 3 1/2", 9.3# casing in 6 3/4" OH TD at 10,008' MD (5,549' ND) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail Slurry Minimum thickening time: 200 min. (pump time plus 120 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.04% 6155 + 0.35% D65 + 0.2 gps D47 - 1.16 ft3/sk Annular Volume (5.5"casing): 0.0835 ft3/ft x (9088' - 8900') x 1.50 (50% excess) = 25.1ft3 Annular Volume (3.5"casing): 0.1817 ft3/ft x (10008' - 9088') x 1.50 (50% excess) = 247.5 ft3 Shoe Volume: 0.0488 ft3/ft x 80' x 1.00 (no excess) = 3.9 ft3 Totals: 25.1 ft3+ 247.5 ft3 + 4.4 ft3 = 277.0 ft3 277.0 ft3/ 1.17 ft3/sk = 237 sks Round up to 240 sks BHST = 138, Estimated BHCT = 108`i=. (BHST calculated using a gradient of 2.6/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW 100 3 5.0 1.7 1.7 MudPUSH II 3 30 3.3 5.0 Tail Slurry 3 49.5 16.0 21.0 Drop Top Plug 5.0 26.0 Water 3 20 6.7 32.7 Switch to rig pump 5.0 37.7 Displacement 3 204 67.9 105.6 MUD REMOVAL Recommended Mud Properties: 12.8 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 14.3 ppg MudPUSH'` II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint from 8950' MD to TD for proper cement placement. ORIGINAL ~ ~ Schlumberger CemCAD Ewell cementing recommendation for 51/2x 3 1/2 Longstring Operator : CPAI Well 2N-337B Sidetrack Country :USA Field West Sak State :Alaska Prepared for :Jason Brink Location Proposal No. : V1 ~WP04~ Service Point Prudhoe Bay Date Prepared :November 15, 2006 Business Phone (907) 659-2434 FAX No. (907) 659-2538 Prepared by :Maureen Torrie Phone 1-907-265-6336 E-Mail Address mtorrieQslb.com ~`~~ ~ Q ~G ~~~ ATE Disclaimerkotice: This information is presented in good faith, but no warranty is given by and Schlumbeger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumbergc's best estivate of the actual results that maybe achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hens results, Trey be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditionr affecting Prem. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's regronsibiliry b notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actuaicharges rrey vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ORIGINAL • Client CPAI Well 2N-3376 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :10008.8 ft BHST :143degF Bit Size : 6 3/4 in Previous String MD OD Weight ID ft in Ib/ft in 2858.0 7 5/8 29.7 6.875 Landing Collar MD :9928.0 ft Casing/liner Shoe MD :10008.0 ft Scl~~rg~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 9088.0 51/2 40.0 15.5 4.950 K-55 4040 4810 BTCSH 10008.0 31/2 40.0 9.3 2.992 L-80 10530 10160 EUE Mean OH Diameter :6.750 in Mean Annular Excess :50.0 Mean OH Equivalent Diameter :7.374 in Total OH Volume :377.7 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 9088.0 6.750 50.0 7.295 10008.0 6.750 50.0 7.888 2N- 3376 Sidetrack Cement, Plan A.ciw ; 11-17-2006 ; Loadcase 5.5-3.5 Longstring ; Version wcs-cem45_89 • Page 2 ORIGINAL ~1 Client CPAI Well 2N-3378 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring Max. Deviation Angle : 71 deg Max. DLS :15.025 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.3 142.5 0.000 200.0 200.0 0.3 142.5 0.000 300.0 300.0 1.3 174.7 0.989 400.0 399.9 3.3 195.4 2.197 500.0 499.5 6.7 200.3 3.355 600.0 598.4 10.1 208.0 3.637 700.0 696.2 14.0 205.0 3.940 800.0 792.8 16.0 197.5 2.757 900.0 889.0 15.7 200.1 -0.760 1000.0 985.2 15.7 200.0 -0.056 1100.0 1081.4 16.2 199.5 0.584 1200.0 1177.0 17.8 202.4 1.763 1300.0 1271.5 20.4 209.1 3.436 1400.0 1364.6 22.2 216.5 3.199 1500.0 1456.4 24.5 223.3 3.542 1600.0 1546.1 28.1 228.2 4.216 1700.0 1632.6 32.2 228.8 4.060 1800.0 1715.6 35.5 229.1 3.335 1900.0 1795.0 39.4 229.5 3.927 2000.0 1870.4 42.8 230.6 3.455 2100.0 1941.5 46.5 232.1 3.832 2200.0 2007.8 50.6 235.3 4.759 2300.0 2068.5 54.6 236.1 4.074 2400.0 2123.5 58.7 237.7 4.336 2500.0 2172.3 62.8 238.7 4.197 2600.0 2215.4 66.2 239.6 3.441 2700.0 2254.2 68.2 240.2 2.107 2800.0 2290.8 68.9 241.1 1.126 2851.0 2309.1 68.9 240.7 0.720 2900.0 2326.7 69.2 239.7 2.076 2922.2 2334.5 69.3 239.2 2.101 2950.0 2344.3 69.5 239.1 0.892 2962.0 2348.4 70.8 240.4 15.025 3000.0 2361.0 70.5 241.2 -2.000 3100.0 2395.0 69.7 243.1 -2.002 3200.0 2430.2 69.0 245.1 -1.992 3300.0 2466.6 68.3 247.1 -2.006 3400.0 2504.2 67.6 249.2 -1.995 3500.0 2542.8 66.9 251.2 -2.003 3583.5 2575.8 66.4 252.9 -2.000 3600.0 2582.5 66.4 252.9 0.000 3700.0 2622.5 66.4 252.9 0.000 3800.0 2662.5 66.4 252.9 0.000 3900.0 2702.6 66.4 252.9 0.000 4000.0 2742.6 66.4 252.9 0.000 4100.0 2782.6 66.4 252.9 0.000 4200.0 2822.7 66.4 252.9 0.000 4300.0 2862.7 66.4 252.9 0.000 4400.0 2902.7 66.4 252.9 0.000 4500.0 2942.8 66.4 252.9 0.000 4600.0 2982.8 66.4 252.9 0.000 4700.0 3022.9 66.4 252.9 0.000 ~~I~~~~r~~r 2N- 3376 Sidetrack Cement, Plan A.cfw; 11-17-2006; Loadcase 5.5-3.5 Longstring; Version wcs-cem45_69 • Page 3 ORIGINAL • Client CPAI Well 2N-3378 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring MD (ft) Directional Survey Data ND Deviation Azimuth (ft) de de Dogleg Sev. de /100ft 4800.0 3062.9 66.4 252.9 0.000 4900.0 3102.9 66.4 252.9 0.000 5000.0 3143.0 66.4 252.9 0.000 5100.0 3183.0 66.4 252.9 0.000 5200.0 3223.0 66.4 252.9 0.000 5300.0 3263.1 66.4 252.9 0.000 5400.0 3303.1 66.4 252.9 0.000 5500.0 3343.1 66.4 252.9 0.000 5600.0 3383.2 66.4 252.9 0.000 5700.0 3423.2 66.4 252.9 0.000 5800.0 3463.2 66.4 252.9 0.000 5900.0 3503.3 66.4 252.9 0.000 6000.0 3543.3 66.4 252.9 0.000 6100.0 3583.3 66.4 252.9 0.000 6200.0 3623.4 66.4 252.9 0.000 6300.0 3663.4 66.4 252.9 0.000 6400.0 3703.4 66.4 252.9 0.000 6500.0 3743.5 66.4 252.9 0.000 6600.0 3783.5 66.4 252.9 0.000 6700.0 3823.6 66.4 252.9 0.000 6800.0 3863.6 66.4 252.9 0.000 6900.0 3903.6 66.4 252.9 0.000 7000.0 3943.7 66.4 252.9 0.000 7100.0 3983.7 66.4 252.9 0.000 7200.0 4023.7 66.4 252.9 0.000 7300.0 4063.8 66.4 252.9 0.000 7400.0 4103.8 66.4 252.9 0.000 7500.0 4143.8 66.4 252.9 0.000 7600.0 4183.9 66.4 252.9 0.000 7700.0 4223.9 66.4 252.9 0.000 7800.0 4263.9 66.4 252.9 0.000 7900.0 4304.0 66.4 252.9 0.000 8000.0 4344.0 66.4 252.9 0.000 8100.0 4384.0 66.4 252.9 0.000 8200.0 4424.1 66.4 252.9 0.000 8300.0 4464.1 66.4 252.9 0.000 8396.5 4502.8 66.4 252.9 0.000 8400.0 4504.1 66.3 252.9 -2.601 8500.0 4546.3 63.8 252.9 -2.500 8600.0 4592.4 61.3 252.9 -2.500 8700.0 4642.3 58.8 252.9 -2.500 8800.0 4695.9 56.3 252.9 -2.500 8900.0 4753.2 53.8 252.9 -2.500 9000.0 4814.0 51.3 252.9 -2.500 9100.0 4878.2 48.8 252.9 -2.500 9200.0 4945.7 46.3 252.9 -2.500 9276.5 4999.4 44.4 252.9 -2.498 9300.0 5016.3 43.8 252.9 -2.507 9400.0 5089.9 41.3 252.9 -2.500 9412.6 5099.4 41.0 252.9 -2.468 9500.0 5165.4 41.0 252.9 0.000 9600.0 5240.9 41.0 252.9 0.000 9700.0 5316.3 41.0 252.9 0.000 9800.0 5391.8 41.0 252.9 0.000 9900.0 5467.3 41.0 252.9 0.000 Sc~lrg~r 2N- 3376 Sidetrack Cement, Plan A.cfw; 11-17-2006 ; Loadcase 5.5-3.5 Longstring ; Version wcs-cem45_89 • Page 4 ~'?IGE6~A~ • • Client CPAI Well 2N-3376 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. ft (ft) (deg) de de /100ft) 10000.0 5542.7 41.0 252.9 0.000 10008.8 5549.4 41.0 252.9 0.000 MD ft Frac. Ib/ al Formation Data Pore Name Lithology Ib/ al 1200.0 15.50 9.00 Permafrost 3350.0 15.50 9.00 C-80 6200.0 15.50 9.00 C50 6600.0 15.50 9.00 C40 7000.0 15.50 9.00 C37 8500.0 15.50 9.00 T7 9200.0 15.50 9.00 T4 (Iceberg) 9500.0 15.50 8.50 T3 (Top Bermuda) 9800.0 15.50 9.00 T2 (Base Reservoir) 10010.0 15.50 12.60 C-35 K-3 Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1200.0 1177.0 30 0.4 10008.8 5549.4 143 2.1 10010.0 5550.3 143 2.1 2N- 3376 Sidetrack Cement, Plan A.cfw; 11-17-2006; Loadcase 5.5-3.5 Longstring; Version wcs-cem45_89 S~hlu~~~r~~r Page 5 ",RIGINAL Client CPAI SEhlumherg~r Well 2N-3376 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :9988.0 ft Casing Shoe :10008.0 ft NB of Cent. Used :109 NB of Floating Cent. :107 Bottom MD ft Nbr. Cent. / Joint Centralizer Placement Cent. Name Code Min. STO % @ Depth ft 528.0 4 1/3 SPIRAGLIDER SC-5 1/2-5- 0.0 509.3 SPIRAL650 2688.0 0 0/0 0.0 528.0 2848.0 4 1/1 SPIRAGLIDER SC-5 1/2-5- 0.0 2836.4 STRAIGHT650 8688.0 73 1/2 SPIRAGLIDER SC-5 1/2-5- 0.0 8673.8 STRAIGHT650 9088.0 5 1/2 SPIRAGLIDER-51/2-5- S05R 0.0 9061.9 SPIRAL0650 9928.0 21 1/1 1732731-31/2-4-POSITIVE 0.0 9088.0 10008.0 2 1 /1 1103631-3 1 /2-4-36 1 /8" 1.9 10008.0 (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 6 2N- 3318 Sidetrack Cement, Plan A.cfw ; 11-17-2006: Loadcase 5.5-3.5 Longstring ;Version eves-cem45_89 ORIGINAL L~ Client CPAI Well 2N-3376 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring Section 3: fluid description ~Ir~~r CW100 DESIGN Fluid No: 2 Density : 8.32 Ib/gal Rheo. Model : HERSCHEL_B. k : 6.68E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.177 Ty :O.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 5.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 14.30 Ib/gal Rheo. Model : HERSCHEL_B. k : 1.78E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.507 Ty :5.111bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :30.0 bbl G cement DESIGN Fluid No: 6 Density : 15.80 Ib/gal Rheo. Model : HERSCHEL_B. k : 6.82E-3 Ibf.s^n/ft2 At temp. :119 degF n :0.724 Ty :11.501bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid :5.169 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 1.17 ft3/sk Sack Weight : 94 Ib Porosity :59.3 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Additives Code Conc. Function D047 0.200 gal/sk blend antifoam D065 0.350 %BWOC dispersant 6155 0.040 %BWOC Retarder D600G 2.000 al/sk blend GASBLOK • Job volume :49.5 bbl Quantity :238.69 sk Solid Fraction :40.7 Base Fluid :2.969 gal/sk Fluid No: 7 Rheo. Model : HERSCHEL_B. At temp. :120 degF MUD Mud Type : WBM Water Type :Fresh Mud 12.8 DESIGN Density :12.801b/gal k :3.13E-31bf.s^n/ft2 n :0.723 Ty :5.071bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :203.6 bbl 2N-3376 Sidetrack Cement, PlanA.c(w;11-17-2006; Loadcase 5.5-3.5Longstring; Versionwcs-cem45_89 Page 7 ORIGINAL ~ ! Client CPAI ~~~ Well 2N-3376 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring Section 4: fluid sequence Original fluid Mud 12.8 12.80 Ib/gal k : 3.13E-3 Ibf.s^n/ft2 n :0.723 Tv :5.07 Ibf/100ft2 Displacement Volume 223.6 bbl Total Volume 308.2 bbl TOC 8900.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al CW100 5.0 224.1 7331.4 8.32 k:6.68E-31bf.s^n/ft2 n:0.177 Tv:0.001bf/100ft2 MUDPUSH II 30.0 1344.5 7555.5 14.30 k:1.78E-2 Ibf.s^n/ft2 n:0.507 Tv:5.11 Ibf/100ft2 G cement 49.5 1108.0 8900.0 15.80 k:6.82E-3 Ibf.s^n/ft2 n`0.724 Tv:11.50 Ibf/100ft2 Water 20.0 8554.6 8.33 k:6.94E-31bf.s"n/ft2 n:0.281 Tv:0.071bf/100ft2 Mud 12.8 203.6 0.0 12.80 k:3.13E-3 Ibf.s^n/ft2 n:0.723 Tv:5.07 Ibf/100ft2 Static Security Checks Frac 326 psi at 2858.0 ft Pore 216 psi at 10008.0 ft Collapse 3609 psi at 9088.0 ft Burst 4789 psi at 7555.5 ft Cs .Pum out 31 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments CW 100 3.0 5.0 1.7 5.0 80 Pause 0.0 0.0 15.0 0.0 80 Pressure Test and Drop Plug MUDPUSH II 3.0 30.0 10.0 30.0 80 G cement 3.0 49.5 16.5 49.5 80 Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Water 3.0 20.0 6.7 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to Rig Pumps Mud 12.8 3.0 203.6 67.9 203.6 80 Total 01:57 308.2 bbl hr:mn Dynamic Security Checks Frac 115 psi at 2858.0 ft Pore 50 psi at 10008.0 ft Collapse 3588 psi at 7259.8 ft Burst 3877 si at 0.0 ft 2N- 3376 Sidetrack Cement, Plan A.cfw; 11-17-2006 ; Loadcase 5.5-3.5 Longstring ; Version wcs-cem45_89 Page 8 ~~IGI"J4'~. Client CPAI Well 2N-3376 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring ft 8 o -, ~ 0 O- O V Fluid Sequence N O Collapse o ~ Burst 0 e Dynartic N ao N N N a 00 • Schlumaerger Ib/gal 12 Nfn. Hydrostatic Max. Cynartrc - fv5n. Oynanic Frac Pore Hydrostatic 16 ., 0 200 400 Dynamic Well Security Pumped Volume (bbl) Depth = 10008 ft _ T 'I 0 30 60 90 120 150 180 210 240 270 300 330 Pumped Volume (bbl) ~ Depth = 10008 ft Frac '. ~ ' i~ '. m ~ Hydrostatic '. '. - !,. a ~ Dynamic ~' , ','. N ~, '. Nr I. N N a` ~~ ' i. a N ~_--__ 0 30 60 90 120 150 180 210 240 270 300 330 Pumped Volume (bbl) Page 9 2N- 3376 Sidetrack Cement, Plan A cNv; 11-17-2006; Load Case 5.53.5 Longstring ;Version ~.vcs-rem45_89 ORIGINAL Client CPAI Well 2N-3376 Sidetrack String 51/2x 31/2 Longstring District Prudhoe Bay Country USA Loadcase 5.5-3.5 Longstring Secti on 6: WELLCLEAN II Simulator e% ego 0 50 100 0 100 o ~ Cement Coverage ~ Uncontanirmrta ed Slurry O O _ O V O O_ O W O O O N • Schlumb~rg~r deg Fluid Sequence Cement Coverage Uncontaminated Slurrl Deviation Fluids Concentrations Risk Mud on the Wall z° ~ ~ z° ~ 5500 SS00 5500 5500 6000 6000 5000 4000 5500 6500 5500 6500 _ 7000 7000 _ _ 7000 • -~ • - - - • • 7000 _ +`- 7500 7504 '~ ~- 754G - 7540 ~- ~ ~ c. 6004 ° 8404 n ~ 6004- 8400 a ~ o 6500 o 8500 o - 6500= ~ l o 8500 `}000 9000 9000 - y, ~ 9000 9500 9500 ~ 9500- ~ _ „ 9500 tiD000 10000 yD000 n ~ 10000 ~ a a _ ~ v 2 D Z ®Mud 12.8 Q MUDPUSH II ~ High ®Low ~ ',Alater CVJ100 Q Medium None 0 G cement Page 10 2N- 3378 Sidetrack Cement, Plan A.cfw ; 11 ~17-2006: Loadcase 5.5-3.5 Longstring ;Version wcs-cem45_89 oRi~iNA~ DRILLING HAZARDS SUMMARY 6 3/4" Open Hole & 51/2" x 31/2" Production Casing Interval Event Risk Level Miti ation Strate / Contin enc Swabbing Campaignian Moderate Minimum mud weight of 9.6 ppg, mandatory sands (50 ft TVD below C- flow check above sands on all trips 80 High reservoir pressure Moderate 12.6 ppg minimum mud weight in reservoir. 5- 1/2" contingency top set available. WBS procedure in place and LOT to be performed and evaluated before drillin into hi h ressure. Insufficient or undetermined Moderate Importance of LOT communicated to all parties, LOT all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 16 MW a uivalent High ECD /Tight hole on Moderate Condition mud & clean hole prior to trips. trips/ Swabbing Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, ro er hole fillin use of tri sheets Differential sticking Moderate Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever ossible Barite sag Low Good drilling practices as documented in well Ian Lost circulation Moderate Keep hole clean -use PWD to monitor hole cleaning. If losses occur- reduce pump rates and mud rheolo ,use LCM ^?!61NAL 5-1/2" rams • Subject: 5-112" rams From:-"Brink, Jason A" <Jason.Brink@conocophillips.coin> Date: Tue, OS Dec 2006 10: ~ > : ~' 7 -0900 "I'o: tom maundcrr~i::adinin.state.al:.us Tom Yes, 5-1/2" rams will be in place for cut and pull 5-1/2" casing. The procedural step is #5 below directly from the wellplan. Please reply to let me know you received this. Jason Phase: RIGUP ~~~ ~s 1. Check Tbg, IA, & OA for pressure. Record on IADC report. RU circulating lines on tree and circulate well clean with sea water. Ensure well is dead. 2. BPV should. already be in place. Set blanking plug in tubing hanger lift threads with test joint for BOPE testing. 3. Mark orientation of tree. ND tree and adapter. • Tree: 3-1 /8" 5K • Adapter: A-4-M, 11" 5K std btm x 3-1/8" 5K std top, prep for 7.115 OD EN tbg hgr, SBMS btm prep, NACE CL III BLTG, complete w/ R.G. 4. Send tree to valve shop to be inspected and tested. 5. NU 11" 5M BOP stack with: • Blind Rams • 5-1/2" pipe rams 6. Test ROPE, manifold, valves, rams to 250 PSI low and 3500 PSI high. Test annular to 250 PSI low and 3500 PSI high. • Ensure 5-1/2" test joint crossover and test plug will fit below the 5-1/2" ram during testing • Install 2' drilling spool if necessary to ensure test plug will fit between tbg hanger and rams 7. Pull blanking plug and BPV. 1 of 2 12/5/2006 12:09 PM 5-1/2" rams • i BPV: CIW "H" Jason Brink Drilling Engineer Phone: 907-265-6419 Office: ATO-1582 2 of 2 12/5/2006 12:09 PM • • ' SHARON K: ALLSUP-DRAKE ~ 1163 CONOCOPHILLIPS ATO'1530 700 G ST. ~~~~,,rr~~//~ ANCHORAGE AK 99501 oaTe ~ `%:xer~~i/aai ORDER FE / ~~~ L ~,~'~ t,~ ~"' ~`i`~7 C~ $ ~G~~ vD J' ~U ~ G~ ./LLIJ~pQ~DIILLARS L!1 ~~~~ ~~m JPMor alnChase ~~ ' 9 ~ Valid Up To 5000 Dollars ~ JPMorgan ChaseBank, N.A. Columbus, OH ~ - ///~/ / MEMO L~j/Oy`~~?~~G~_`__ J'-_ E~ ~"`"_ ; ___ ~:044ii55ii~:528747i90792711'ii63 / S • • `~~r.,~.:~ A>~~E L~2~C Z~V- .337.x3 P~-®# Zvi - /~ .3 ®evelopment Service Expfloratory St~-atigraphic Zest lion-Conventional Fell Circle appropriate better i Paragraphs to be Included in Transmittal I/etter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES .MULTI LATERAL ~ The permit is for a new we[lbore segment of existing well (If last two digits in Permit No. API No ~0- ~~ - API number . . are - between 60-69) Production should continue to be reported as a function of the original AP[ number stated above. PLOT HOLE In accordance with 20 A.4C 2~.00~(f), all records, data and logs j acquired For the pilot hole must be clearly differentiated in both; ~, ~ well name ( PH) and API number .~~ (~0- - -_~ from records, data and logsi j 'acquired for well i !SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ?~.0>j. Approval to perforate and produce ;' inject is contingent i upon issuance of a conservation order approving a spacing exception. assumes the I i [iabiiity of any protest to the spacing exception that may occur. DRY D[TCH Aii dry ditch sample sets submitted to the Commission must be in SAYIPLE ! no greater than 30' sample intervals from below the permafrost or from where samples are Frst caught and 10' sample intervals iii through target zones. Non-Conventional 'Please note the following special condition of this permit: ,production or production testing of coal bed methane is not allowed ' ' W e[1 : `for name of well) until after (Com a~nv Name) has designed and implemented a water well testing program to provide baseline data j on water quality and quantity. fCompanv Name) must contact the Commission to obtain advance approval of such water welt testing proffram. Rev- I2~:06 C-`jody`tr3nsmittaf checkli~C WELL PE M[T CHECKLIST Field & Pool KUPARUK RIVER, TARN OIL - 490165 Well Name: KUPARUK RIV U TARN 2N-3 76 Program DEV Well bore seg ^ PTD#:2061630 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ -- - Administration 1 Pe[mitfee attached- _ _ - - Yes - - Sidetrack of existing well KRU 2N-337A _ 2 Lease number appropriate_____ _______________ ______ ____________Yes_ __--.-Entire wellwill_li_ewithinA0L375_.074__-_-_--._____-- 3 Unique well-name and number_________________________ _____________Yes_ ______________._- 4 Well located in a_defined_pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ Yes _ _ - _ - _ - KUPARUK RIVER,_TARN_OIL - 490165, governed by CO 430A. _ _ _ _ _ _ _ _ _ _ _ _ - 5 Well located proper distance-from drilling ur~it.boundary- - - - - - - - - - - - --- - - - - - -Yes Conforms to-Conservation Order_No. 430A_ Rule 3, which specifies 10-acre spacing. 6 Well located proper distance f[o_m other wells. - Yes - _ _ _ - . - Conforms to_Conservation Order-No. 430A- Rule 3, whichspecifies 1aacre s acin . - p 9 7 Sufficient acreage available in-drilling unit - - - ----- - - - - - - - - -Yes Conforms to_Conservation Order-No. 430A_ Rule 3, which specifies 10-acre s acin . p g 8 If deviated,is_wellboreplat.included..-___-____- ________,-Yes_ ________________________ 9 Operator only affected party_____________________ Yes- - -_____________________-- --- 10 Operatorhas_appropriate_bondinforce_..________________ _______.._._Yes_ _____--.-__ 11 Permit_canbeissuedwithoutconseryationorder______________ _____________Yes_ __---__________ Appr Date 12 Permit_canbeissuedwithoutadministrative-appr_oval__-------- ------ ------Yes_ _.-_------_-_--___--___ _____-______.__---- -_____ SFD 11!29!2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-Injection Order # (putJ9# in_comments)_(For_ NA_ - _ _ . ........ - - - ' 15 All wells within114,mileateaofreyiewidentified(Fo[servicewellonly)__ _____________ NA__ ______-___-________,.__________,______-_-__ ---------------------------- 16 Pre-produced injector; duration_of prep[oduction Less than. 3 months. (Far service well only) NA_ 17 Nonconven, gas conforms to A$31.05.030(j.1_.A),(j.2.A-D) - _ _ - - - - NA_ _ _ _ - - - Engineering 18 Conductor string_provided - - _ . _ - , N_A- _ - - _ . _ Conductor_set_in original well, 2N-337_(198-102), 19 Surface casing_protectsoll known USDWs _ NA_ All aquifers exempted, 40 CFR_147.102_ (b)(3).- 20 CMT-vol adequ_ate-to ci[cul_ate_on conducto[& surf_csg - - - _ - NA_ Surface casing set in original well.. 21 CMT_vol_ adequ_ate,to tie-in long string to surf csg_ . - - - ~ - - - - No_ All hydrocarbon_zoneswill- be_crove_red, 22 _C_M_T-willcoyer_allknow_n_productiyehorizons__-__--_-_--____ ____________Yes. -_-___________ 23 Casing designs adequate forC,T6&.permafrost_____- _ -____;______Yes_ _-_.__--__ -________________________________ __________________ 24 Adequate tankage_o_r reserve pit - - Yes - - - Rig is_e_quipped with steel,pits. -No reserve-pitplanned, All waste to approved annulus or disposal well. 25 If a_re-drill, has_a_ 10-403 for abandonment been approved - Yes 30.6-365._ ......... , 26 Adequate wellbore separation_proposed _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - . _ - _ _ Proximity analysis performed, Traveling cylinder path calculated, Nearest well segment is P&Aed section and. - - 27 Ifdiverterrequired,doesitmeetregulations__________________ _____________ NA_- ______BOPStackwillal[eddy_beinplace,_-_______________.__-paths diverge.________________ Appr Date 28 Drilling fluid_program schematic & equip list adequate. - - - - _ _ - _ -Yes Maximum anticipated formation pressure-12:6 EMW in_Bermuda. Planned MW 12.8 ppq or as needed. TEM 12/5/2006 29 BOPES,_d_otheymeetregulation________________________ _____________Yes __.._._,-_ ----------- ~~ 30 BOPE.press rating appropriate; test to_(put prig in comments)- - - - - - Yes _ - - - - MA$P calculated at 2873 psi, 3500_psi_appropriate. CPAI usually-tests to 5000. psi. - - - _ - 31 Choke_manifoldcomp_lieswlAPI_RP-53(M_ay84)_______________ _____________Yes_ _-___-_-_______ - - 32 Work willoccurwithoutoperationshutdown_______________ __ _____________Yes_ ___--.___, 33 Is presence of H2$ gas probable _ _ _ _ - - _ _ _ - - - - Yes - - H2S has bQen_ reported on 2N. Mud should preclude_H2S.on rig.. Rig has sensors and_alarms. 34 Mechanical.condition of wells within AOR verified ~For_service well onrya _ - - _ - - - - NA- _ - _ _ _ _ _ _ - - , Geology 35 Permit can be issued w!o_hydrogen-sulfide measures - No_ - _ _ _ _ _ . H2S is present. KR_U_2N-337 measured 30_ppm_i12S_on-11l11103.Offset well 2N-341.. measured 50 ppm H2S on 1 36 Data presented. on-potential guerpres_sur_e zones. _ . _ _ - - - - - Yes - - - Bermuda_expecled to be pressured to_12,6-ppg EMW; will_be drilled with 12.8 ppgmud, - - - Appr Date X 37 Seismic analysis of shallowgas.zones______________ _-___-______ NA__ ___-_.__-,-.-_-- SFD 11129!2006 38 Seabed condition survey-(ifoff-sho[e)____________ ________ ______--_--_NA_ ___-.----_____ _._- 39 Contact name/pho_ne for weekly-progress reports-[exploratory only] : - NA- - - - Geologic Engineering Publ~ Commissioner: Date: Commissioner: Date Commis ' n r Date h ~ r~ ~.~ ~ 2~ S1,~ ~~~'~~ ~7 .. ~- di6 • • • Well F-iistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 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. ~ ~ 2n-337b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed May 09 10:17:00 2007 Reel Header Service name .............LISTPE Date . ...................07/05/09 Ori9in ...................STS Reel Name. .... .........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................5T5 LIS Writing Tape Header Service name .............LISTPE Date . ...................07/05/09 Origin ...................sTS Tape Name. .... ........UNKNOWN .. Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: 2N-3376 API NUMBER: 501032026202 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 09-MAY-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 706 NUMBER: w-0004878300 w-0004878300 w-0004878300 LOGGING ENGINEER: N. WHITE J. PANTER J. PANTER OPERATOR WITNESS: J. MCDADE D. BREEDEN J. MCDADE MWD RUN 4 JOB NUMBER: w-0004878300 LOGGING ENGINEER: J. PANTER OPERATOR WITNESS: D. BREEDEN SURFACE LOCATION SECTION: 3 TOWNSHIP: 9N RANGE: 7E FNL: 117 FSL: FEL: 996 FWL: Page 1 aC~ -1Co3 ~t~i35 ~~ 2n-337b.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 151.07 GROUND LEVEL: 120.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.750 7.625 2858.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON (CTN), AT-BIT INCLINATION (ABI), AND PRESSURE WHILE DRILLING (PWD). RUN 1 ALSO INCLUDED GEOPILOT ROTARY-STEERABLE BHA (GP), 4. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER PHONE CONVERSATION ON 3/29/07 BETWEEN D. KLEIBACKER (CPAI) AND B. BRYANT (SDS). MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-4 REPRESENT WELL 2N-3376 WITH API#: 50-103-20262-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9950'MD/5503'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). Page 2 2n-337b.tapx SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75~~ MUD WEIGHT: 9.2-9.5 PPG MUD SALINITY: 11500 PPM CHLORIDES FORMATION WATER SALINITY: 19000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2801.0 9887.5 RPS 2845.0 9894.5 RPX 2845.0 9894.5 RPM 2845.0 9894.5 RPD 2845.0 9894.5 FET 2845.0 9550.0 RHOB 2858.0 9874.5 NPHI 2858.0 9859.0 NCNT 2858.0 9859.0 DRHO 2858.0 9874.5 FCNT 2858.0 9859.0 PEF 2858.0 9874.5 ROP 2858.5 9950.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 2801.0 2 3313.0 3 6300.0 4 9576.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3313.0 6300.0 9576.0 9950.0 Page 3 • 2n-337b.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 Name Service Order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM .4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading. DEPT FT 2801 9950 6375.5 14299 2801 9950 FCNT MWD CNTS 94.37 1081.8 261.976 14003 2858 9859 NCNT MWD CNTS 13728.3 33503.5 20053 14003 2858 9859 RHOB MwD G/cM 1.893 3.045 2.34033 14034 2858 9874.5 DRHO MWD G/CM -0.097 0.413 0.0520708 14034 2858 9874.5 RPD MWD OHMM 0.78 2000 7.54771 14100 2845 9894.5 RPM MWD OHMM 0.8 2000 7.50251 14100 2845 9894.5 RPS MWD OHMM 1.41 771.63 5.01751 14100 2845 9894.5 RPX MWD OHMM 1.33 1088.96 5.17135 14100 2845 9894.5 FET MWD HOUR 0.35 98.61 2.31129 13411 2845 9550 GR MWD API 35.76 244.98 120.094 14174 2801 9887.5 PEF MWD BARN 1.91 17.41 3.71749 14034 2858 9874.5 ROP MWD FT/H 0.26 255.83 84.7862 14184 2858.5 9950 NPHI MwD Pu-S 12.93 63.27 35.3166 14003 2858 9859 First Reading For Entire File..........2801 Last Reading For Entire File...........9950 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Page 4 2n-337b.tapx Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2801.0 3256.0 RPS 2845.0 3263.0 RPx 2845.0 3263.0 RPD 2845.0 3263.0 FET 2845.0 3263.0 RPM 2845.0 3263.0 FCNT 2858.0 3227.5 NPHI 2858.0 3227.5 NCNT 2858.0 3227.5 RHOB 2858.0 3243.0 PEF 2858.0 3243.0 DRHO 2858.0 3243.0 ROP 2858.5 3313.0 LOG HEADER DATA DATE LOGGED: 19-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3313.0 TOP LOG INTERVAL (FT): 2858.0 BOTTOM LOG INTERVAL (FT): 3313.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.2 MAXIMUM ANGLE: 70.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 CTN COMP THERMAL NEUTRON 110041 EWR4 Electromag Resis. 4 156401 ALD Azimuthal Litho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 2858.0 Page 5 2n-337b.tapx BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 44.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.500 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.040 85.0 MUD FILTRATE AT MT: 2.600 68.0 MUD CAKE AT MT: 2.300 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWDO10 CNTS 4 1 68 4 2 NCNT MWDO10 CNTS 4 1 68 8 3 RHOB MwD010 G/CM 4 1 68 12 4 DRHO MWDO10 G/CM 4 1 68 16 5 RPD MWDO10 OHMM 4 1 68 20 6 RPM MWDO10 OHMM 4 1 68 24 7 RPS MWD010 OHMM 4 1 68 28 8 RPX MWDO10 OHMM 4 1 68 32 9 FET MWDO10 HOUR 4 1 68 36 10 GR MwD010 API 4 1 68 40 11 PEF MWDO10 BARN 4 1 68 44 12 ROP MwD010 FT/H 4 1 68 48 13 NPHI MwD010 Pu-s 4 1 68 52 14 First Last Name Service Unit Min MdX Mean Nsam Redding Reading DEPT FT 2801 3313 3057 1025 2801 3313 FONT MWDO10 CNTS 94.37 510.36 193.242 740 2858 3227.5 NCNT MWDO10 CNTS 13728.3 26722.6 17973.5 740 2858 3227.5 RHOB MWDO10 G/CM 2.045 3.045 2.21098 771 2858 3243 DRHO MWDO10 G/CM -0.012 0.4 0.0416174 771 2858 3243 RPD MWDO10 OHMM 0.78 1689.76 27.6046 837 2845 3263 Page 6 2n-337b.tapx RPM MWDO10 OHMM 0.8 2000 44.3914 837 2845 3263 RPS MWDO10 OHMM 2.29 771.63 9.96356 837 2845 3263 RPX MWDO10 OHMM 2.12 1088.96 13.2667 837 2845 3263 FET MWDO10 HOUR 0.91 6.12 2.31873 837 2845 3263 GR MWDO10 API 40.12 133.53 98.5781 911 2801 3256 PEF MWDO10 BARN 2.84 6.11 3.76344 771 2858 3243 ROP MWDO10 FT/H 3.72 149.9 52.1949 910 2858.5 3313 NPHI MWDO10 Pu-5 23.63 63.27 41.0088 740 2858 3227.5 First Reading For Entire Fiie..........2801 Last Reading For Entire File...........3313 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 3228.0 6208.5 FONT 3228.0 6208.5 NCNT 3228.0 6208.5 PEF 3243.5 6222.5 DRHO 3243.5 6222.5 RHOB 3243.5 6222.5 GR 3256.5 6236.0 RPS 3263.5 6243.0 FET 3263.5 6243.0 RPx 3263.5 6243.0 RPM 3263.5 6243.0 RPD 3263.5 6243.0 ROP 3313.5 6300.0 LOG HEADER DATA DATE LOGGED: Page 7 22-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 2n-337b.tapx VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EwR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type.. ..........0 Data specification Block Type.....0 Loging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Insite 72.13 Memory 6300.0 3313.0 6300.0 63.9 69.9 TOOL NUMBER 160788 110041 156401 183652 6.750 2858.0 Lignosulfanate 9.70 44.0 9.8 1300 10.2 1.800 68.0 1.320 95.1 2.200 68.0 1.900 68.0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 Page 8 2n-337b.tapx NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MwD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 oHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3228 6300 4764 6145 3228 6300 FONT MWD020 CNTS 121.34 1081.8 252.161 5962 3228 6208.5 NCNT MWD020 CNTS 15337.5 33503.5 20014.9 5962 3228 6208.5 RHOB MWD020 G/CM 1.893 2.546 2.25989 5959 3243.5 6222.5 DRHO MWD020 G/CM -0.039 0.413 0.05385 5959 3243.5 6222.5 RPD MwD020 OHMM 2.3 2000 7.72331 5960 3263.5 6243 RPM MWD020 OHMM 2.26 1548.32 5.60362 5960 3263.5 6243 RPS MWD020 OHMM 2.68 112.87 4.7591 5960 3263.5 6243 RPX MWD020 OHMM 2.62 150.57 4.7029 7 5960 3263.5 6243 FET MwD020 HOUR 0.35 16.5 1.1787 5960 3263.5 6243 GR MwD020 API 35.76 162.76 110.711 5960 3256.5 6236 PEF MWD020 BARN 1.91 6.06 3.06374 5959 3243.5 6222.5 ROP MWD020 FT/H 0.26 206.99 106.337 5974 3313.5 6300 NPHI MWD020 PU-S 12.93 55.31 35.9038 5962 3228 6208.5 First Reading For Entire File..........3228 Last Reading For Entire File...........6300 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Page 9 2n-337b.tapx Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 6209.0 9483.5 FONT 6209.0 9483.5 NPHI 6209.0 9483.5 DRHO 6223.0 9499.0 RHOB 6223.0 9499.0 PEF 6223.0 9499.0 GR 6236.5 9511.5 RPM 6243.5 9518.5 RPD 6243.5 9518.5 FET 6243.5 9518.5 RPX 6243.5 9518.5 RPS 6243.5 9518.5 ROP 6300.5 9576.0 LOG HEADER DATA DATE LOGGED: 27-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT): 9576.0 TOP LOG INTERVAL (FT): 6300.0 BOTTOM LOG INTERVAL (FT): 9576.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.4 MAXIMUM ANGLE: 69.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 CTN COMP THERMAL NEUTRON 231709 EWR4 Electromag Resis. 4 156401 ALD Azimuthal Litho-Dens 10508942 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 2858.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 12.40 MUD VISCOSITY (S): 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 400 FLUID LO55 (C3): 11.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATU RE (MT): 1.900 70.0 MUD AT MAX CIRCULATING TE RMPERATURE: 1.210 113.5 MUD FILTRATE AT MT: 1.700 70.0 MUD CAKE AT MT: 1.600 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: Page 10 2n-337b.tapx HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MwD030 OHMM 4 1 68 20 6 RPM MwD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MwD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MwD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6209 9576 7892.5 6735 6209 9576 FONT MWD030 CNTS 138.54 790.8 263.712 6550 6209 9483.5 NCNT MWD030 CNTS 16078 29949.9 19962.6 6550 6209 9483.5 RHOB MWD030 G/CM 2.126 2.661 2.42194 6553 6223 9499 DRHO MWD030 G/CM -0.097 0.406 0.0498654 6553 6223 9499 RPD MwD030 OHMM 1.77 10.48 5.08109 6551 6243.5 9518.5 RPM MWD030 OHMM 1.57 11.38 4.75685 6551 6243.5 9518.5 RPS MWD030 OHMM 1.41 12.92 4.57476 6551 6243.5 9518.5 RPX MWD030 OHMM 1.33 14.2 4.52976 6551 6243.5 9518.5 FET MWD030 HOUR 0.53 42.29 2.41561 6551 6243.5 9518.5 GR MWD030 API 65.13 244.98 131.152 6551 6236.5 9511.5 PEF MwD030 BARN 2.33 17.41 3.75689 6553 6223 9499 ROP MWD030 FT/H 1.06 255.83 73.0109 6552 6300.5 9576 NPHI MwD030 PU-s 16.19 51.96 34.9616 6550 6209 9483.5 First Reading For Entire File..........6209 Last Reading For Entire File...........9576 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name... Page 11 2n-337b.tapx version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9484.0 9859.0 FCNT 9484.0 9859.0 NPHI 9484.0 9859.0 DRHO 9499.5 9874.5 RHOB 9499.5 9874.5 PEF 9499.5 9874.5 GR 9512.0 9887.5 RPx 9519.0 9894.5 FET 9519.0 9894.5 RPD 9519.0 9894.5 RPM 9519.0 9894.5 RPS 9519.0 9894.5 ROP 9576.5 9950.0 LOG HEADER DATA DATE LOGGED: 04-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9950.0 TOP LOG INTERVAL (FT): 9576.0 BOTTOM LOG INTERVAL (FT): 9950.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.2 MAXIMUM ANGLE: 41.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 231709 EWR4 Electromag Resis. 4 159436 Page 12 • 2n-337b.tapx ALD Azimuthal Litho-Dens 10508942 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 6.750 2858.0 Lignosulfanate 12.40 50.0 9.3 700 4.5 1.300 65.0 .800 110.4 1.100 65.0 1.500 65.0 Name service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MwD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 oHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MwD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 RoP MwD040 FT/H 4 1 68 48 13 NPHI MwD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 13 2n-337b.tapx DEPT FT 9484 9950 9717 933 9484 9950 FCNT MWD040 CNTS 235.15 823.33 392.49 751 9484 9859 NCNT MWD040 CNTS 19266.3 31787.4 23193 751 9484 9859 RHOB MWD040 G/CM 2.166 2.594 2.39932 751 9499.5 9874.5 DRHO MWD040 G/CM 0.023 0.118 0.0679294 751 9499.5 9874.5 RPD MWD040 OHMM 1.67 11.44 5.31977 752 9519 9894.5 RPM MWD040 OHMM 1.51 13.36 5.41229 752 9519 9894.5 RPS MWD040 OHMM 1.61 14.89 5.41739 752 9519 9894.5 RPX MWD040 OHMM 1.62 17.4 5.46225 752 9519 9894.5 FET MWD040 HOUR 0.79 98.61 16.6113 752 9519 9894.5 GR MWD040 API 75.19 209.95 124.189 752 9512 9887.5 PEF MwD040 BARN 6.26 11.28 8.51393 751 9499.5 9874.5 ROP MWD040 FT/H 5.61 129.29 55.4629 748 9576.5 9950 NPHI MwD040 PU-s 17.34 37.45 28.1426 751 9484 9859 First Reading For Entire File..........9484 Last Reading For Entire File...........9950 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/09 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/05/09 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................07/05/09 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF writing Library writing Library. Page 14 Scientific Technical Services scientific Technical services 2n-337b.tapx End Of LIS File Page 15 ConocoPhillips q,a=ka , FINAL WELL REPORT ConocoPhillips Alaska, Inc. TARN 2N-3376 117' FNL, 996' FEL Sec 3 - T9N - R7E, UM North Slope, Alaska Approved by: Compiled by: Lees F. Browne, Jr. Mark Bietting March 8, 2007 ~ EPOCH ~ ~ ~~3 ~ ~S~i ~ C:a'to~~l~~ Tam 2N 337B • • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT &CREW ..................................................................3 1.1 Equipment Summary ....................................................................................3 1.2 Grew ..............................................................................................................4 2. GENERAL WELL DETA{LS ....................................................................................5 2.1 Objectives .....................................................................................................5 2.2 Well Summary ...............................................................................................6 3. GEOLOGICAL DATA ..............................................................................................9 3.1 Lithostratigraphy ..........................................................................................9 3.2 Mudlog Summary .......................................................................................10 3.3 Sampling Program /Sample Dispatch ......................................................17 3.4 Cali Bond Gas Bag Sample and IsoTube lnventory .................................18 4. PRESSURE /FORMATION STRENGTH DATA ...................................................19 4.1 Formation integrity/Leak Off Tests ...........................................................19 4.2 Pore Pressure Evaluation Introduction .....................................................19 4.3 Pore Pressure Summary ............................................................................2d 5. DRILLING DATA ...................................................................................................21 5.1 Daily Activity Summary ..............................................................................21 5.2 Bit Record ...................................................................................................24 5.3 Survey Record ............................................................................................25 5.4 Mud Record ................................................................................................28 Enclosures 2"=100' Scale 2"=100' Scale 2"=100' Scale 2"=100' Scale Mud{og LWD Combo Log Gas Ratio Log Drilling Dynamics Log ~ EPOCH 2 Conoco~Ph~ll~ps Tarn 2N 3376 MUDLUGGING EQUIPMENT ~ CREW 1.1 Eauipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM electric gas trap Flame ionisation total & chromato raph detec#or 30 mins. Frozen gas lines inside rig. Rou hneck left door o en. H2S Detector (H2S) Variable resistivity cell. Sample line, drill floor, mud its & shakers - Rate of penetration (ROP) t3El Encoder- Primary draw works block position indicator - Pum stroke counter (SPM) RIGWATGH Turck Ma netic roximit sensor - Hook Load (HLKD / Wei ht on bit WOB) RIGWATGH Ametek Hydraulic ressure cell - Tar ue (RTOQ To Drive Feed - Not receivin Tor ue si nal from Totco Tap drive rotary RPM) To Drive Feed - Totco Wits feed Standpipe & casing pressure SPP/CSiP) Totco H draulic ressure cell - Mud flow out (FLOW) Totco Flow Paddle - Totco Wits Feed Pit levels x 6 Batl Float sensors in all its & trip tank - Totco Wits Feed Mud to in unit com uter s stem Com ac Pentium III - Geolo fist's workstation Compac Pentium III Totco Workstation Com an Man's workstation Compac Pentium III - Totca Workstation Tool usher's workstation Com ac Pentium III - Totco Workstation Dritler's workstation Epoch Azonix Touch Screen Class 1 Div II - Totco Workstation • ~'Fi~" f Conoco~iiips Tarn 2N 337B 1.2 Crew Unit Type Arctic Unit Number : ML012 Mudloggers Years .~ Days •2 Geotechnicians Years Days Technician Days Trainees Days Lees F. Browne Jr. 26 15 Dan K. Hillegeist 1 15 Steve Forrest 4 Mark A. Biettin 1 15 Mainuddin Chowdhury 1 15 ~' Years experience as Mudlogger .2 Days at wellsite between spud and total depth of well Additional Comments Twa spare poly-flow gas lines were run through a heated umbilical to insure non freezing for the gas lines and rig air lines to the unit. Minorfrozen gas lines occurred when a rig hand left a door open resulting in condensation freezing in the poly-flow. Lines were rerun away from the daor and the problem was solved. The QGM gas trap was routinely cleaned of drilling mud and the gas lines blown back with rig air. • ~ E~;H ~' CArtocoPhillips Tarn 2N 3378 2. GENERAL WELL DETAILS 2.1 Objectives The 2N-337 was spud on June 6, 1998 and drilled to a depth of 1 Q,595' MD on June 14, 1998. The well was subsequently plugged back and sidetracked to the 2N-337A alternate bottom hole location due to a lack of reservoir quality sand in the original well bore. The well was put in production and experienced hydrate, paraffin and sand production problems. The 2N-3376 sidetrack is to capture rates and reserves as originally planned. The bottom hole location is targeting the turbidite deposits of the Bermuda reservoir and restoring production to the 2N-337A and 337 area on the southern edge of the Tarn Field and to determine productivity of the 337 area. Potential risks are reservoir quality and thickness, lateral continuity and pressure support from offset injectors. • ~nnru 5 • • • 2.2 Well Summary ConocoPhillips Tarn 2N 3378 Well Well name AFE Classification Exploration Block N/A Rig Name / Nordic Drilling/ Land Surface 11T FNL, 996' FEL, RKB Elevation 148.8' AMSL PAD Elevation 120.9'" Type Nordic #3 Co-Ordinates S 3, T9N, R7E, UM AMSL Primary Target Bermuda T3, T2 Primary Target 9366 MD/ Secondary None Secondary None Depth -4912 SS TVD Target Target Depth Spud Date 2118/07 TD Depth 10,008 MD/ TD Formation C-35 (K-3) TD Date 3/4/07 -5,400 SS TVD Completion Suspension NIA Days Drilling 14 Days Testing N/A Status Ran 5'/" Liner Date Hole Maximum Depth TD Formation Mud Weight Deviation Coring Casing Shoe Depth FIT Section MDRT (ft} TVDSS (ft) (ppg} (°inc) / Liner MDRT (ft) TVDSS (ft) (ppg) 6.75" 9950' -5,353' C-35 9.6-12.4 65° - 41 ° none 7 5/8" / 5 '/z" 2858' 2311' 13.0 [~ EPOCH C~oCO~Phrlhps Tam ZN 3378 Additional Comments: Epoch commenced logging the 2N-3376 {sidetrack of the 2N-337A} on 2/18/07 at 2800' drilling ou# cement from the 2N-337A well. Samples were caught at 50' intervals to 300' above the Bermuda {9260'}. Gas bags were collected at 500' intervals and at gas kicks. Sample catchers were used throughout the weN. IsoTubes were collected in 30' intervals starting from 300' above the Bermuda Formation {9260'} and a #en foot sampling program was started with ditch cuttings. Drilling kicked off the old well bore of 2N-337A at 70° drilling with aGeo-Pilot and the inclination was brought down to 65° by 3669'. The inclination was held to 8400', in which angle was dropped to 40° at 9473'. The Geo-Pilot was tripped ou# of the hole at 3313' and replaced with a mud motor and drilling and sliding progressed #0 300' above the Bermuda Top with no hole problems. Gas contamination from the 2N-337A well resulted in high C-4 (butane) and C-5 {Pentanes) readings as drilling progressed out of the old well bore. These high "heavyn gases were in the mud system until 3200', in which they were absorbed into the mud system and giving no further problems. No hole problems were encountered while drilling from 2800' to the #op of the Bermuda. Good hole cleaning techniques were used drilling the deviated hole with high viscosity sweeps and good flow rates. Each connection allowed circulating time to clean the hole of cuttings above the BHA. All hole trips showed no drag or sticking. Well Bore Strengthening {WBS} was commenced at 9560'. Mud weight was increased from 9.9 to 12.4 ppg. From 7500' sample quality diminished with the addi#ion of mud additives and the general softness of the forma#ion. Sample returns on the shaker screens were reduced by 75°to with most of the formation going into solution and through the shaker screens. Samples were composed of very soft hydrophilic clays, silts and very fine grained sands. Upon starting of ten foo# samples (and a controlled drill rate) cuttings were diminished ever further. The increasing of the mud weight to 12.4 ppg and the addition of Calcite and Graphite to the mud sys#em enhanced the poor sample quality. Various sample catching techniques were tried with all giving poor results. The high mud weight with large amounts of mud additives and the slow ROP wi#h the softness of the cuttings resulted in very poor sample quality. Drilling continued to 9575', in which circulation was lost. Samples and gas from 9545' to 9575' were lost to the formation. Mud losses totaNed 139 bbls in 24 hours with cumulative losses in 48 hours of 324 bbls. The system was moni#ored and a 25 bbl high viscosity pill was spotted and the bit was pulled five stands out to 9141' and ran back in the hole to 9520' and spotted 25 bbls high viscosity pill and pulled out to 9141' and worked the drill pipe and monitored the well. Tripped back into the hole to 9556' and pumped a "squeeze job" and pulled out of the hole to 8820' and squeezed the pill into the formation and circulated the • hole for losses (Wiper Gas = 4580 units). Ran back into the hole #0 9233' and worked the r~ ~nnru /~~~~~P' Tam 2N 3378 - dnil pipe and circulated the hole clean while checking for losses (Wiper Gas - 5119 units}. Continued to work the drill pipe and circulated the hole clean and checked for losses. A Wiper Trip of 10 stands was pulled and run back to 9233' (Wiper Gas = 6256 units). Continue to circulate the mud and raise the mud weight from 12.5 to 12.7 ppg and tripped out of the hole for MWD, sources and BHA. Tripped back to bottom with trip gas recorded at 2284 units. Sample cuttings were very poor showing abundant graphite, calcite and "nut plug" LCM in the mud system. Drilling progressed to a total depth 9950' with mud losses to the formation at roughly 35 bblslhr and cumulative losses of 1142 bbls at total depth plus 24 hours. • r~ nnnr~u ~ ConocoP'hdhps Tarn 2N 3378 3. GEOLOGICAL DATA 3.1 Lithostratipraphy Drilling picks & actual wireline tops refer to provisional picks provided by the weilsite Geologist. FORMATION PROGNOSED DRILLING PICK ACTUAL WIRELINE PICK HIGH/LOW MDRT (ft) TVDSS (ft} MDRT ft) TVDSS (ft) MDRT (ft) TVDSS (ft) (ft) C-80 3300' -2, 325' 3221' -2, 327 2 Deep C-50 6600' -3,615' 648T -3,600 -15 Shallow C-40 7000' -3,800' 6950' -3,772 -28 Shallow G37 7400' -3,950' 7348' -3,927 -23 Shallow T-7 8800' -4,560' 8792' -4,539 -21 Shallow T-4 ICEBERG) 9200' -4,800' 9161' -4,769 -31 Shallow T-3 (TOP RESERVOIR 9412' -4,950' 9366' -4,912 -38 Shallow T-2 BASE RESERVOIR) 9700' -5,155' 9660' -5,134' -21 Shallow C-35 K-3) NA NA 9743' -5,146' NA Total Depth 1000$' 9950' -5,353' - - - • ~~~{I~pS Tarn 2N 337B 3.2 Mudlog Summary The following text provides a brief summary of the defining lithoiogical and drilling characteristics for that part of the well, over which drill cuttings were collected. Kick off to C-80 2,800' to 3,221' MDRT (-1,973}' to -2,327' TVDSS The 2N-337B kicked off as a sidetrack of the 2N-337A well under the surface casing depth of 2858'. Formation was encountered at 2865' and 100°lo by 2915' with excess cement of the 2N-337A diminished Formation comprised of predominantly of claystone: very light gray to yellowish gray, very soft, lumpy to clumpy, clustered to clotted, gelatinous with some becoming mushy to pasty and slimy. Samples were non to very slightly cohesive and slight to moderate adhesive with a general amorphous fracture and a massive habit. The clays are very hydrophilic with most going into solution leaving globs on the shale shakers for samples. The clays have a moderate to bright satin and earthy lustre showing a colloidal to sub clay texture. Secondary silts and minor unconsolidated sands {in the fine to very fine grain size} noted throughout the section. Mud weight was 9.6 ppg. With a Leak Off Test at 2941' wi#h an EMW of 13.0 ppg and the mud weight was raised to 9.7 at 2983'. Drilling out of the old well bore {2N-337A}; both Butane and Pentane gases were recorded. These readings were most likely left over from the old well bore as they were first noted drilling the cement. By 3130' these gases were no longer present in the mud system. Down Time Gas {DTG} of 2358 units was recorded after the LOT, which included high Butane and Pentane readings, further proof of contamination from the old well bore. Abundant t_CM "Nut Plug" was added to the mud system at 3164', with the solubility of the clays, left poor sample quality for the base of the zone. Drill Rate {ftlhr) Total Gas {°~) Maximum Minimum Avera a Maximum Minimum Avera e 220 5 59 1049 17 55 ®~~H 10 ~~}hP' Tam 2N 337B c-sa to c-sa 3221' to 6487" MDRT {--2.327' to -3,60Q' TYDSS~ The C-80 sand interval {3482-3492') was comprised of predominantly unconsolidated sand: clear and colourless with occasionally a milky white frosting on the grain surfaces with some pale yeflowish orange grains. Grain size ranges from very fine grains to very fine sub angular to sub rounded with visible remnant non calcareous cement along the grain margins. Grains are predominan#ly quartz with up to 5°!o glauconite and rare feldspar. Samples are well sorted and show dominant grain support with an estimated fair to good porosity and permeability. No show of oil indicators. Below the C-80 sand samples graded into ciaystone, very #ight gray to light gray in colour. Its tenacity and consistency varied from lumpy to dominantly clumpy consistency with rounded nodular to clotted cuttings and all being very soluble and hydrophilic. Poor cohesion and adhesion noted with samples being mushy to pasty and slightly malleable when in rare firm spots. The textures were slightly gritty to silty from suspended sift sized grains to an irregular fracture. Clay showed a dull earthy lustre in massive gradational bedding. Trace amounts of glauconite and pyrite. At 4204' samples generally graded to a siltstone with varied colours: yellowish gray, pale yellowish brown to a light brownish gray with depth. Samples showed poor induration with a few scattered moderate induration, Overall, the samples are very brittle with non to very slight cohesiveness and no adhesiveness and a general earthy fracture and sub nodular habit. The texture was a uniform silt texture in a massive homogeneous silt body grading to very fine grained sandstone and being detritalish. • At 4740' samples generally are grading between siltstone and a very fine grained sandstone. At times it is difFcult to discern between siltstone and sandstone as both are very gradational. The sandstones are light gray {in cleaner sandstones) to pale yellowish brown with lighter orange hues in silty sections. Grain size ranges from very fine upper to very fine lower with a silty matrix and grading to local and regional siltstone. Grains display a sub rounded to sub angular shape with poor to some moderate sorting with depth and moderate developed sphericity. Sorting is overall poor with some local moderate in cleaner sands. Textures are generally polished with minor pitting. Samples show a moderate loosely silt packed matrix to some local clean grain support. Some secondary quartz growth enlargements are scattered. Overall matrix supported with minor secondary grain support in minor thin beds. Composed of predominantly quartz, with secondary carbon fines and traces of frambo and disseminated pyrite when grading to silt. Poor estimated porosity and permeability with no show of fluorescence or oil cuts. Dritl Rate ftthr} Tatal Gas (%} Maximum Minimum Avera a Maximum Minimum Avera e 207 7 102 1161 9 175 C-50 to C-40 >~nnru ~ ~ ~/~~((~P' Tam 2N 337B 6487` to 6950' MDRT (-3,600' to -3,772' TVDSS~ • The C-50 succession is generally a siltstone with secondary carbonaceous silts. The siltstone is light gray to very light gray and occasionally yellowish gray showing poor induration and being brittle to crumbly. Some silts are slightly sectile in sub shale grading to clay in parts. Silts display a very slight cohesiveness to a slight adhesiveness in clay sections. Overall fracturing is sub planar to planar with a sub platy #o platy habit displaying a gradation to carbonaceous silt and increased clay content than the C-50. Samples show a moderate earthy lustre and a silty to colloidal texture as the brittle induration goes into solution. The silts are grading into micro laminated beds of carbonaceous silts with planar orientation starting at 6855' The carbonaceous siltstone is very light gray (such as the siltstone), but is mottled and striated with light brownish gray to pale yellowish brown and various hues of both. As with the siltstone these gradational beds show poor induration and are brittle. Some fragments are slightly crumbly and becoming sectile along carbon laminations. The carbon silt is non to very slightly cohesive to non and very slightly adhesive with planar fractures. The general habit is sub platy with a earthy to slightly greasy lustre in carbons. Textures range from silty to striate with massive micro laminations. Drill Rate (ft/hry Total Gas (°~) Maximum Minimum Avera a Maximum Minimum Avera e 342 22 75 75 3 21 C-40 to C-37 6950' to 7348' MDRT (-3,772' to -3,927' TVDSS~ The C-40 shows a grading away from carbonaceous silts to clays#one and siltstone. The claystone is pale yellowish brown and very soft. Tenacity and consistency are overall lumpy to clumpy, clustered to clotted, gelatinous to occasionally mushy to pasty. Overall, the samples are very "soupy" and very hydrophilic with an amorphous fracture and habit with most going into solution with low returns on the shakers. Samples display a moderate earthy lustre and colloidal texture with massive gradational clay and silt with minor carbonaceous laminations in the silts. The siltstones are gradational with the clays. The colours are very light gray to yellowish gray and various hues of both. Samples show poor and occasional moderate induration with brittle and scattered stiff fragments. Overall the silt is crumbly to crunchy with a slight to moderate cohesiveness and being non adhesive. The fracture is sub planar to planar with a sub platy to platy habit. Samples show a moderate earthy lustre and a silty texture. Overall the section is a massive gradational bed of dominant silt with scattered clays and micro laminations of carbonaceous sil# with planar orientation with trace calcite. Drill Rate (ft/hr) Total Gas (°1oj !~i Fl~(l(~T~ 1 • Cono~oP'h~llips Tam 2N 337B Maximum Minimum Avera a Maximum Minimum Avera e 176 22 82 113 24 66 C-37 to T-7 7348' to 8792` MDRT (-3,927' to -4,539' TVDSS} The C-37 interval is represented by gradational sequences of very fine sandstones, siltstones, claystones and carbonaceous siltstone in micro laminations. Sample returns continued to be only fair with mud additives such as nut plug and the brittleness of the cuttings giving a very mixed return of cuttings. The mud weight was raised from 9.7 to 9.9 (at 8400'} in 10ths in anticipation for the iceberg (T-4} formation. The mud was 9.9 in and out by 8700'. claystones are very light gray with yellowish gray hues to light brownish gray in colour. Cuttings are extremely soft and poorly to moderately cohesive with poor adhesiveness. Overall the clay 'rs highly soluble with a dull earthy lustre showing a mushy to pasty consistency. Fractures are amorphous to irregular with interbedded very fine silt grains. Sandstones range for minor laminations to thin small beds, The sandstone ranges in colour from yellowish gray and mottled white (in parts} to very light gray in cleaner (no clay matrix) zones. Clast size ranges from very fine upper to very fine lower. Cuttings are sub rounded with a moderate developed sphericity. There is no abundant grain faction with poor to moderate sorting. Grain textures are pitted to impacted with a general immature nature. Samples display a slight calcareous cement with a moderate clay matrix that is loosely attached and shows moderate consolidation. Generally matrix supported with secondary local grain support, with some grading to siltstone. Poor porosity is no#ed with two small oil shows at 8450' and 8640'. Both zones displayed 10-20°to dull yellow even sample fluorescence with no oil stain, no petroleum odor and a very poor yellow whispy oil cut with no residue stain. The siltstones are very light gray to yellowish gray with poor to moderate induration. Overall the samples showed a brittle and crumbly tenacity with poor to moderate cohesion and poor adhesiveness. Cuttings were irregular to sub blocky with a hackly fracture. Lustre's were dull to earthy and general cuttings beds displayed a massive gradational system. Drill Rate {ftlhr) Total Gas °~} Maximum Minimum Avera a Maximum Minimum Avera e 382 8 85 101 9 43 • T-7 toT-4 (ICEBERG) ~nnru ~ ConotoPh~ll~ps Tam 2N 337B 8792" to 9161" MDRT (-4,539" to -4,769" TVDSS) The T-7 sequence displayed no real sample change with continued extremely poor cuttings returns due to tar like mud additives and LCM material. Generally the #ormation continued with a sequence of claystone, siltstones and minor carbonaceous claystonefsiltstones. Sandstones were light gray to pale yellowish brown with some lighter orange hues. Grain size ranged #rom fine upper to very fine Power. Grain shapes were sub rounded to sub angular with poor to moderate sorting. The sandstones are composed of a silt packed matrix in small amounts and are dominantly grain supported with rare local matrix support. Rare minor silica cement is most commonly seen along grain boundaries of disaggregated grains and clusters. Clasts are predominantly quartz with scattered minor lithics. Samples display poor apparent porosity and permeability due to tightly packed and local silt matrix and poorly to moderately well developed cement in parts. No true oil shows, but mud additives giving off false oil cuts. Drill Rate (ftfhr) Total Gas (°~) Maximum Minimum Avera a Maximum Minimum Avera e 397 11 53 85 15 35 T-4 to T-3 (TOP RESERVOIR 9161' to 9366' MDRT (-4,769' to -4,912' TVDSS) The T-4 interval is represented by very poor samples. A Well Bore Strengthening (WBS} program was begun at 9560', in which the mud weight was raised from 9.9 to 12.4 ppg. Large amounts of Calcite, Graphite were added to the mud system with shaker screens sizes being 10 and 50's aNowing the mud additives to recycle through the well bore. At first returns sample quality was very poor. Samples contained over 98% mud additives and trace sample cuttings. Several sample collection #raps were tried with poor results. What sample that did not go into solution or through the shaker screens was imbedded in the massive mud additives giving very few cuttings to examine. Ten foot samples were collected and the drill rate was controlled to 50' per hour. Very minor clay, sandstones and shale were noted in the samples. The best preserved (poorly) CUTTINGS were the shale's being dark green to medium dark gray in colour. Cuttings were soft to moderately hard in parts, but overall firm. Cuttings displayed an elongated to tabular to uncommon platy habit with a sub planar fracture along moderate to well developed fissility. Cuttings displayed a dull earthy lustre with a massive to very slightly gritty texture with occasion brownish black to black carbon material. Samples consists of >99% t_CM, graphite and calcite mud additives. Drill Rate ftlhr) Total Gas {%) Maximum Minimum Avera a Maximum Minimum Avera e 172 8 55 139 6 52 Fi~(1('T-T 1 4 ConocoPhrll~p~ Tam 2N 337B T-3 to T-2 (BASE RESERVOIR} 9366' to 9660" MDRT (-4,912' to -5,134' TVDSS), Note: The T-3 was plagued with very poor sample quality throughout the reservoir. Abundant graphite, calcite and scattered LCM nut plug comprised between 95 to 100% of the samples. Good gas increases were noted from 9490' to 9497', 9506 to 9513' and 9525 to 9545', in which circulation was lost. Samples and gas from 9545 to 9575' were lost to the formation. Losses in the first 24 hours were 139 bbls and increasing to 452 bbls after 72 hours. Sandstone from 9450' to 9545' was based on very poor samples, some with only a few fragments of cuttings. Overall, the sandstone was yellowish gray to very light gray in cleaner {non silted) sands. Sandstones had a sub salt and pepper appearance with lithic content. Grain size ranged from very fine upper to very fine lower with a sub round shape and moderate developed sphericity. Sorting was #air with no abundant faction. Textures showed a general polished look and a sub mature nature. Moderate to abundant clay structured matrix was present with pore filling and loosely to moderately attached clays being very argillaceous throughout. The matrix was slightly to moderately acting as a lithification agent and composed of chert and various dark lithic fragments and being quartz poor. Porosity appeared to be poor to fair in gas increased beds. Estimated fair permeability overall. Samples were of very poor sample quality with abundant graphite and calcite mud additives in the mud system. Cuttings displayed one to five percent even moderate to bright green sample fluorescence with a light brown weak oil stain. Trace pin point oil was also noted on sandstone fragments. Sandstones exhibited a instant slow streaming cloudy blue white cut with a very pale weak residue stain. Maximum background gas recorded from 9445' to 9545' was 1652 units with 12.4 mud weight. A squeeze pill was pumped and mud circulated with various wiper trips. Wiper gas increased after each trip from 4580 units, 4984 to 5119 units. A ten stand wiper trip produced 6256 units of gas. The BHA was tripped out and changed and mud losses slowed to a trickle. Trip gas at 9275' was 2289 units and drilling resumed with mud losses at 35 bbls/hr. Samples from 9545' to the base of the gas reservoir were very poor with continued abundant graphite, calcite and LCM nut plug added to the mud system. Two gas kicks were noted at 9603' to 9620' (1244 units} and 9640' to 9690' (1650 units). Samples consisted of sandstone and unconsolidated sand. Both the sand and sandstone were very light gray to very light yellowish gray. Grain size ranged from very fine upper to very fine lower with a sub round and displaying a moderate developed sphericity. Sorting was moderate in gas bearing zones to poor in others. Textures were impacted to pitted with a sub mature nature. Matrix content was slight and loosely attached with some secondary quartz overgrowths at 9580' with poor porosity and permeability with a 2°!0 light yellow green patchy sample fluorescence, which increased to 25% @ 9650' with fair porosity. Sandstones became unconsolidated in part at 9630 to 9670' with oil stains becoming more even and light yellowish, increasing to 40°lo by 9660'. Oil cuts were instant with a slow streaming moderate Fi RUl1(`T~ 1 5 CortornPhilhps Tarn 2N 337B cloudy cut {fair) with a very faint straw residue stain. Drill Rate (ftlhr} Total Gas (%} Maximum Minimum Avera a Maximum Minimum Avera e 122 12 54 1652 27 493 T-2 to C-35 9660' to 9743' MDRT t-5,134' to -5,146' NDSS~ Dominated by siltstones and decreasing sandstones with continued very poor samples with abundant graphite and calcite mud additives. The siltstones are brownish gray to pale yellowish brown and various hues of both colours. The cuttings are very brittle displaying poor induration and becoming crumbly. There are no adhesive qualities with non to very slight cohesiveness. Fractures are earthy to sub blocky with a sub blocky habit. Texture is silty with overall hydrophilic quality with most silt gang into solu#ion. Drill Rate (f#lhr) Total Gas (°I°) Maximum Minimum Avera a Maximum Minimum Avera e 101 12 60 1528 201 507 C-35 to TD {9950') 9743' to 9950' MDRT {-5,353' to -5504' TVDSS~ Below the C-35 comprises a sequence of minor carbonaceous silt with gradational clay and silt with thin sandstone stringers. The carbonaceous shale is dark brown to black with a very brittle quality with very small cuttings size and micro planar fracturing. Cuttings display very smaN cuttings size with a dull earthy lustre and silty to smooth textures. These thin beds grade to siltstone and claystones. Samples continue to be very poor quality with abundant graphite and calcite mud additives resulting in samples displaying less than 5°l0 true cuttings. Drill Ra#e (#tJhr} Total Gas (°~} Maximum Minimum Avera a Maximum Minimum Avera e $9 14 48 302 46 97 • 1~r~n~u i ti ~~~~~~~1~ Tarn 2N 337B 3.3 Sampling Program /Sample Dispatch Set Type /Purpose Interval Frequency Dispatched to A Unwashed (WET} 2800'- 9260' S0' ConocoPhillips Bayview Warehouse 9260' - 9950' 10' Washed, screened & dried 2800'-9260' S0' ConocoPhillips Bayview Warehouse B Dry Sam les 9260'- 9950' 10' Washed, screened & dried 2800'-9260' S0' ConocaPhiilips Bayview Warehouse C D Samples 9260'- 9950' 10' D Gas Bags 2800'-9420' 500' or gas ISOTECH LABORATORIES Box "A" 2940-9000' kicks 1308 Parkland Court Box "B" 9000-9420' Champaign, IL. 61821 ISOTECH LABORATORIES E ISOTUBES 9620'- 9950' 30' 1308 Parkland Court One Box of 25 Champaign, IL. 61821 Sample frequency was locally a-tered according to drillrate constraints. • ~F~'d •' • ConocoPh~II~Ps Tam 2N 337B 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory Gas Bag # Depth Gas Units IsoTube # Depth Gas units 1 2940' 74 1 9300' S7 2 2941' 2200 2 9330' 33 3 3442' 240 3 9360' 100 4 4D17' 190 4 9390' S6 5 4500' 220 5 9450' 290 6 5000' 255 6 9420' 262 7 5525' 165 7 9457' 475 8 6035' 136 $ 9476' 593 9 6284' 900 WG 9 9493' 1045 10 6500' 24 10 9500' 690 11 6890' 46 11 9521' 426 12 6959' 103 12 9530' 1350 13 7001' 64 13 9575' 3500 14 7501' S2 14 9575' 4400 15 8001' 36 15 9575' 5970 16 8500' 35 16 9575' 1100 17 9000' 34 17 9593' 250 18 9190' 77 18 9620' 484 19 9230' 104 19 9650' 1330 20 9259' 186 {WBS} 20 9680' 876 21 9260' 173 {WBS) 21 9712' 234 22 9308' 120 22 9740' 220 23 9361' 115 23 9760' 156 24 9371' 820 24 9790' 76 25 9373' 500 25 9820' 908 26 9397' 120 27 9421' 250 ~ ~nn~u 1 fi • CAnoco`Phtii~ps Tam 2N 3378 4. PRESSURE 1 FORMATION STRENGTH DATA 4.1 Formation Integrityl~eak Off Tests Equivalent mud weight (EMW} is calculated from rotary table (RT}. MDRT (ft) TVDSS {ft) LOTI FIT p EMW FORMATION 3229' -2327' 93A C-80 9260' -4835' 93.0 T-4 iceber ) LOT {Leak Off Test) in bold italics. 4.2 Pore Pressure Evaluation Introduction Trend Indicators • The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of this well; Background Gas (BG} Connection Gas (CG} Trip Gas (TG) Corrected D exponent (DXC) 1 Mud Weight {MW} Hole Conditions (HC) Wireline Density (WDEN) Resistivity (RES) Sonic (SON) Pressure Tests (RFT) r~ ~nnr,u ~ ~ COnoCO/Ph111ipS Tarn 2N 337B 4.3 Pore Pressure Summary Equivalent mud weight (EM1N} is calculated from rotary table (RT). Farmatian Primary Interval Tops Pore Pressure (EMW) Trend Indicators Source of Quantitative Interval Lithology MDRT {ftI TVDSS (ft) Min (ppg) Max (ppg) Trend Estimate C80 CLBT/SLTST 3221' -2,327' 9.7 9.7 EVEN BG HYD C50 SLTST/SS 6487' -3,600' 9.7 9.8 SL INGR CG/TG EXTRAP C40 SLTST/GARB SMALE 6950' -3,772' 9.7 9.8 SL INGR CG/TG EXTRAP C37 SS/SLTST 7348' _g 927 g.7 g,g SL INGR CGlTG RFT T7 SS/SLTST! CLAY 8792' -4,539' 9.9 10.1 INGR MW/CG/TG EXTRAP T4 (ICEBERG SH/CLAY 9161' -4,769' 9.9 10.1 INGR MW/CG/TG EXTRAP T3 (TOP RESEVOIR) SS 9366' -4,912' 9.9 10.3 INGR HC/MW/CG/TG RFT T2 (BASE SS/SLTST 9660' -5,134 12.4 12.6 INGR HC/MW/TG/WG MW C35 SLTST 9743' -5,29T 12.4 12.4 DECR BG/CG MW TOTAL DEPTH SLTST 9950' -5,354' 12.4 12.4 EVEN BG/MW RFT EXTRAP EXTRAP t Refer to Section 4.3 for explanation of abbreviations used. • ~~x ~ • ConocoPhdlips Tarn 2N 3378 5. DRILLING DATA 5.1 Daily Activity Summary 2/19107 Make up Geo-Pilot and trip in the hole and shallow test the MWD tool. Load up the nuke source and make up the rest of BHA #1. Wash down to 2586' and tag cement. Drilled cement to a depth of 2646' and pressure #ested the casing to 2500 psi for 30 minutes at 2636'. Drilled cement to a depth of 2891' and started to drill formation from 2891' to 2941', in which a "Leak Off Test" was run with 9.7 ppg at 400 psi and an EMW of 13.4 and formation drilling resumed. 2/20107 Drilled formation to 3312' and pumped a high viscosity sweep and pulled out of the hole to the shoe. The well was monitored with good results inside the casing. Continued to pull out of the hole and uploaded the nuke sources and down loaded the MWD data. The Geo-Pilot was rigged down, the bit inspected and a new BHA was made up with a mud motor. The nuke source was uploaded and run into the hole and the MWD was shallow tested. A total of 134 units of gas with C-1 #hrough C-5 were noted and the bit was run into the hole. • 2/21107 Ran the bit into the hole to 3046' and surveyed the hole every thirty feet running into the hole to bottom {3313'). Trip Gas was 1383 units and drilling resumed. 2122!07 Drilled and slide formation from 4650' to 6193'. • 2123/07 Drilled and slide formation to 6284' and pulled a wiper trip to 6189'. Pumped a high viscosity sweep and monitored the well with good results. Pulled out of the hole to 3350' and monitored the well with good results. Continued to pull out of the hole to the shoe {2858'} and serviced the rig. Changed out the saver sub and ran back in the hole to bottom {6284'}. Circulated out 963 units of Trip Gas, the gas came in early, probably from the G-80 sands and not from the bottom of the well. Drilled formation to 6300' and pumped a sweep and monitored the weN with good results. Pulled out of the hole to 109' and downloaded the nuke source and stood back the MWD string. The mud motor was drained and replaced. 2/24/07 The MWD string was picked up and the nuke source loaded and the MWD was shallow tested with good results. The bit was run to 6200' and washed to 6300' and circulated out 670 units of Trip Gas. Drilled and slide formation to 7257'. Fnnr,u ~ ~ ~~~~i~Ps Tam 2N 337B 2/25/07 Drilled and slide formation to 8453'. 2126107 Drilled to 9260' and conditioned the hole and stood back one stand of drill pipe. Pumped a sweep and laid down a single joint of drill pipe. Monitored the well with good results and pulled out of the hole to 5756'. Pumped a dry job and continued to pull out of the hole. 2127107 Continued to pull out of the hole to the shoe (2858'} and circulated the drilling mud (maximum gas 40 units}. Rigged up and performed a Leak Off Test" with 9.9 mud weight, 380 psi, EMW of 13.0 and cut and slipped new drill line. Serviced the rig and changed out a saver sub and ran into the hole to 9260'. Start to reciprocate the hole, Wiper gas was 588 units and began to raise the mud weight to 11.9 at report time. 2128107 Raise mud weight from 11.4 ppg to 12.4 ppg and welt bore test the hole. Control drill ahead at 50 ft/hr to 9374'. Circulate and monitor the well with good results. Drill formation to 9375' and lost circulation (samples and gas lost from 9545' to 9575'}. Slow pump rate and monitor returns through the trip tank. Mixed a high viscosity pill and begin to work the drill pipe. 3/1 /07 Continue to work the drill pipe and monitor the mud losses. Run into the hole to 9556' and pump a 25 bbl squeeze pill at 50 spm/1000psi. Pumped out one stand and pulled out of the hole to 8820'. Squeezed the pill into formation and circulated mud and monitor mud losses, in which the Swab gas was 4984 units. Run in the hole to 9233' and circulated out 5119 units of Wiper Gas. Short tripl0 stands and circulate out 6256 units of Wiper Gas. Begin to weight up the mud system from 12.4 to 12.7 ppg. 312107 Weight up to 12.7 and pulled out of the hole to 8853' and monitor the weN (ok}. Pulled out of the hole to change out nukes, down load MWD and change the BHA. Tested the BOP equipment and picked up new directional tools and BHA #4. 313/07 Down load MWD and ran in the hole to 2761' and cut and slipped new drilling line. Servic~i the rig and ran into the hole to 6666' and circulated bottoms up of 560 units. Ran in the hole to 9325' and circulated and conditioned the mud to 12.4 ppg and drilled ahead. Trip Gas was 2289 units. 3/4/07 Drill formation to 9950' (TD} and circulate and condition the drilling mud. Pumped a high viscosity sweep and work the drill pipe. Monitor the well with a 25 bbl gain. Back reamed out of the hole to 9616' and ream to bottom and work the drill pipe and circulate the drilling r~ ~nn~u /~~~~~PS Tam 2N 3378 mud. Wiper gas was 373 units. Continue to circulate the mud and work the drill pipe. Pumped a "squeeze pile' at bottom and pulled out of the hole nine stands to 9045'. Squeezed the pill and held for ten minutes at 50 psi and 100 psi for ten minutes. Losses the past 24 hours are 660 bbls to the formation and cumulative losses of 1142 bbls to the formation. 3/5107 Circulate and condition the drilling mud and hole with Wiper Gas at 314 units. Monitor the well and work the drill pipe. Swab gases noted at 200 and 320 over a background of 50 units. Continue and circulate the well and raise the mud weight to 12.6. Run in the hole, washing down from 8557' to 9950'. Circulate and condition the hole. Wiper Gas was 309 units. Back ream out of the hole to 9486' and pull out of the hole to 9011'. Pump a dry job and pull out of the hole to 488'. Lay down the HWDP and drill collars. Remove the nuke source and down load the MWD data. 316107 Lay down the BHA and wash out the stack and change out the upper rams to 5'/z°. Rig up casing crew to run casing string. Run in the hole with 5 %2" casing to 2809' and circulate bottoms up with 80 units of Trip Gas. Continue to run in the hole to 5017' and circulate bottoms up with 282 units of Trip Gas. Run in the hole to 6650' and circulate. 3/7107 Circulate at 6600' (60 units) and run in the hole to 7985' and circulate at 1 bpm. Circulate up 98 units of trip gas. Run into the hole to 9931' and circulate at 1 bpm at 12.3 ppg mud and circulated up 75 units of trip gas. Rig up cement head and circulate at 1 bpm and reciprocated the hole. Pump cement to the hole and cement in place with zero returns. Rig down cement equipment and install 5 %2n pack off and test. Epoch released from the location. r1 LJ ~nnru ~ :~ COI'1000P~t~I~IpS Tarn 2N 3378 5.2 Bit Record Bit / Run Make Type Jets /Size Depth In (ft) Total Footage Bit Hrs Av. ROP (ftlhr) WOB (klbs) RPM PP (psi) Wear BHA 6.78" hole 1 SEC FMF36421Z 3X19 / 6.75" 2859' 454 13.42 62 $ 94 1141 NA #1 2 HTC HCM5052 5X12 / 6.75" 3313' 6638 94.69 87 5 72 1850 1-1-CT-C-X-I-NQ-TD #2-3-4 ~ EPOCH 24 • • • Cor~ocoPhrii~i~s Tarn 2N 3378 5.3 Survey Record Measured De th Inclination Azimuth ND Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 2891.00 69.13 239.89 2322.93 850.57s 968.93w 2.09 2943.36 66.79 242.60 2342.58 873.92s 1011.47w 6.56 3102.60 70.42 244.22 2400.67 940.25s 1144.04w 2.47 3197.20 70.20 251.83 2432.58 973.55s 1226.56w 7.58 3292.07 69.91 249.65 2464.94 1002.96s 1310.74w 2.18 3387.00 69.60 248.59 2497.79 1034.71 s 1393.96w 1.10 3482.99 69.00 248.71 2531.72 1067.40s 1477.59w 0.64 3575.16 67.88 248.44 2565.74 1098.69s 1557.33w 1.46 3669.88 65.98 248.17 2603.01 1130.87s 1638.24w 1.81 3768.11 65.40 249.13 2643.45 1163.47s 1721.61w 1.07 3863.14 64.51 249.68 2683.68 1193.75s 1802.21w 1.07 3959.48 64.33 251.42 2725.28 1222.69s 1884.14w 1.64 4053.84 63.91 251.85 2766.46 1249.43s 1964.71w 0.61 4151.21 64.77 252.80 2808.63 1276.08s 2048.33w 1.25 4245.01 66.25 253.75 2847.51 1300.64s 2130.08w 1.83 4340.86 65.98 253.29 2886.32 1325.50s 2214.12w 0.52 4433.72 66.44 254.16 2923.78 1349.31 s 2295.69w 0.99 4523.08 66.37 254.69 2959.55 1371.30s 2374.57w 0.55 4623.61 66.19 252.95 2999.99 1396.94s 2462.96w 1.59 4718.48 65.94 253.28 3038.47 1422.15s 2545.92w 0.41 4813.74 65.41 253.68 3077.71 1446.83s 2629.14w 0.68 4908.88 64.83 253.07 3117.73 1471.52s 2711.84w 0.84 5004.20 65.44 253.57 3157.81 1496.35s 2794.69w 0.80 5099.03 66.60 254.66 3196.35 1520.06s 2878.02w 1.61 5194.14 66.71 254.00 3234.04 1543.64s 2962.10w 0.65 5289.24 66.65 253.72 3271.69 1567.92s 3045.99w 0.28 E~ EPOCH 25 • • ~ Corxxo~Phillips Tarn 2N 3378 5384.34 66.53 253.31 3309.47 1592.68s 3129.67w 0.42 5478.89 66.78 253,22 3346.94 1617.68s 3212.81w 0.28 5574.55 66.62 252,68 3384.78 1643.44s 3296.80w 0.54 5670.41 65.97 252.51 3423.32 1669.69s 3380.56w 0.70 5765.20 64.71 252.78 3462.87 1695.39s 3462.78w 1.35 5860.37 65.56 252.85 3502.88 1720.90s _ 3545.27w 0.90 5955.49 65.73 253.36 3542.11 1746.09s 3628.19w 0.52 6049.43 65.61 253.60 3580.81 1770.43s 3710.25w 0.27 6145.92 65.83 253.22 3620.43 1795.54s 3794.54w 0.43 6239.61 66.16 252.81 3658.60 1820.54s 3876.40w 0.53 6334.83 68.54 251.58 3695.27 1847.42s 3960.05w 2.77 6430.42 69.01 251.51 3729.88 1875.62s 4044.57w 0.50 6526.35 69.10 251.93 3764.17 1903.72s 4129.65w 0.42 6621.64 68.99 251.45 3798.25 1931.68s 4214.13w 0.48 ~~_ 6716.78 69.18 251.85 3832.21 1959.66s 4298.48w 0.44 6811.62 66.68 253.38 3867.85 1985.93s 4382.34w 3.03 6906.80 66.62 253.53 3905.57 2010.81 s 4466.11 w 0.16 7001.80 66.82 252.90 3943.12 2036.01 s 4549.66w 0.64 7096.94 66.82 252.53 3980.57 2062.OOs 4633.17w 0.36 7191.02 67.14 252.27 4017.36 2088.18s 4715.70w 0.42 7285.67 67.67 251.86 4053.72 2115.09s 4798.$4w 0.69 7380.80 67.47 253.64 4090.02 2141.16s 4882.$1w 1.74 7476.08 66.42 254.00 4127.33 2165.59s 4967.01w 1.16 7571.22 66.88 253.40 4165.04 2190.11 s 5050. $4w 0.75 7666.36 67.35 253.52 4202.04 2215.06s 5134.87w 0.51 7761.60 66.61 254.05 4239.29 2239.54s 5219.04w 0.93 7856.70 67.12 253.74 4276.65 2263.80s 5303.06w 0.61 7951.80 _ 67.27 253.53 4313.51 2288.50s 5387.17w 0.26 8047.66 67.84 253.15 4350.11 2313.90s 5472.05w 0.70 8142.47 65.24 252.99 4387.85 2339.22s 5555.25w 2.75 8236.97 65.92 253.08 4426.92 2364.33s 5637.55w 0.72 8331.78 66.25 253.31 4465.35 2389.39s 5720.52w 0.41 8427.02 64.32 253.39 4505.17 2414.18s 5803.40w 2.03 8521.90 60.53 254.13 4549.08 2437.70s 5$84.13w 4.05 86126.27 59.76 253.44 4596.06 2460.55s 5962.72w 1.03 8712.38 57.79 253.86 4645.88 2483.69s 6041.58w 2.08 ~ EPOCH 26 • • • ConocaPhi~~~Ps Tarn 2N 3378 8807.90 55.28 253.88 4698.55 2505.83w 6118.12w 2.63 8903.03 53.61 253.33 4753.87 2527.67s 6192.36w 1.82 899$.17 50.89 253.30 4812.11 2549.26s 6264.42w 2.86 9093.65 49.07 252.43 4873.50 2570.80s 6334.29w 2.03 9188.34 47.05 253.39 4936.79 2591.50s 6401.61 w 2.26 9281.73 44.43 252.81 5001.96 2610.945 6465.60w 2.84 9377.11 42.60 251.66 5071.13 2630.96s 6528.14w 2.09 9473.74 40.39 252.12 5143.50 2650.87s 6588.98w 2.31 9757.99 41.05 252.97 5359.80 9950 PROJECTED 5504.60 ~1 EPOCH 27 • • • Conoco~Philiips Tarn 2N 3sTB 5.4 Mud Record Contractor: M-I Drilling Fluids Mud Type : LSND Activity Date Depth MW Vis PV YP Gels API FL Solids Oil/Water Sand PH Cl Ca P/U DP 2/17/07 2858 9.6 44 7 19 9/11/12 8 4 /96 - 9.4 5000 120 Drillin 2/18/07 2983 9.7 40 6 19 7/9/10 6 5.2 /95 - 9.7 4000 120 RIH 2/19107 3313 9.8 43 9 26 12/16/20 5.8 7 1/92 Tr 9.7 4000 320 Drillin 2/20/07 4100 9.7 41 7 19 8!10/11 5.4 7 1/92 Tr 9.6 3000 200 Drillin 2/21/Q7 6191 9.7 44 9 19 7/11/13 4.6 6.5 1/93 Tr 9.8 1300 120 M/U BHA 2/22/07 6300 9.7 47 10 20 8/10/12 5 7 1/92 Tr 9.2 1000 80 Drillin 2/23/07 7238 9.7 48 10 25 12/17/21 5.2 6.5 1/93 Tr 9.3 800 60 Drillin 2/24/07 8662 9.9 50 11 23 11/14/16 5 8 1/92 Tr 9.3 400 40 POOH 2/25/07 9260 9.9 50 12 25 11/15/16 4.8 8 1/91 Tr 9.5 300 20 CIRC 2/26!07 9260 11.4 55 14 28 8/10/12 4 12 7r/88 Tr 9.5 300 40 START WELL BORE STRENGTH PROGRAM AT 9575' Monitor 2/27/07 9575 12.4 49 18 29 8/10/12 4.2 18 Tr/82 10 10.0 400 60 Monitor 2/28/07 9575 12.4 50 18 30 8/10/12 4.2 18 Tr/82 11 9.5 400 60 CIRC 3/1/07 9575 12.6 70 19 33 11/14/18 4 18 Tr/82 10 9.5 400 40 P/U BHA 3/2/07 9575 12.7 48 18 29 11/13/17 4 18 Tr/82 10 9.4 400 60 Drillin 3/3107 9614 12.4 50 16 31 9/12/14 4 18 Tr/82 10 9.5 400 80 Monitor 314/07 9550 12.5 55 19 31 11/15/18 4 18 Tr/82 10 9.8 400 80 POOH 3/5/07 9550 12.6+ 53 19 28 10/14/16 4 19 Tr/81 12 10.5 400 80 ~~~ 26 • i • • • CONOCOPHIILIPS DAILY WELLSITE REPORT ~~~~~ TARN 2N-3376 REPORT FOR JACK MCDADE DATE Feb 19, 2007 DEPTH 2942.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 2801.00000 24 HOUR FOOTAGE 141 CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 1 6.750" SEC FMF36421Z 10825616RW 3X19 2800 5:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 220.5 @ 2865.00000 7.7 @ 2894.00000 64.6 15.93908 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 14 @ 2937.00000 1 @ 2864.00000 8.7 4.51943 KLBS ROTARY RPM 124 @ 2908.00000 66 @ 2867.00000 80.1 115.00000 RPM PUMP PRESSURE 1219 @ 2884.00000 834 @ 2858.00000 1055.3 1070.13647 PSI DRILLING MUD REPORT DEPTH 2800' MW 9.6 VIS 44 PV 7 YP 19 FL 8 Gels 9111112 CL- 5000 FC 1/ SOL 4 SD - OIL 0 MBL - pH 9.4 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 765 @ 2942.00000 24 @ 2863.00000 82.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY 2350 @ 2941' METHANE (C-1) 26604 @ 2942.00000 196 @ 2801.00000 3793.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 3918 @ 2942.00000 129 @ 2801.00000 483.5 AVG 0 PROPANE (C-3) 4448 @ 2942.00000 161 @ 2863.00000 599.5 CURRENT 0 BUTANE (C-4) 5390 @ 2942.00000 214 @ 2863.00000 775.0 CURRENT BACKGROUND/AVG 30 PENTANE (C-5) 1318 @ 2942.00000 5 @ 2907.00000 33.2 HYDROCARBON GAS SHOW AT 2941' SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 2941' 100% CLAYSTONE BEFORE 75 MAX 2380 AFTER 2380 UNITS OF DOWN TIME GAS AFTER RUNNING L.O.T. CONTAMINATION FROM PREVIOUS WELL BORE (HIGH C-5 CONTENT IN (SILTY) 50 KICK) LITHOLOGY CLAYSTONE, MINOR SILTSTONE AND VARIOUS DETRITAL MATERIAL. PRESENT LITHOLOGV 80% CLAYSTONE, 20 % SILTSTONE DAILY ACTIVITY MAKE UP GEO PILOT, SHALLOW TEST MWD, LOAD NUKES, MAKE UP REST OF BHA, WASH DOWN TO 2586' AND TAG CEMENT, DRILL CEMENT TO 2646', PT CASG TO 2500 PSII30 MINS @ 2636', SUMMARY DRILL CEMENT TO 2891', DRILL NEW HOLE FROM 2891 TO 2941', PREFORM L.O.T. 9.7 @ 400PSI = 13.0 EMW, DRILL FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • CONOCOPHILLIPS DAILY WELLSITE REPORT ~~~ ~~ 2N337B ~`. REPORT FOR MCDAE/MORRIS DATE 02/20/07 DEPTH 3312.00000 PRESENT OPERATION TRIP IN HOLE TIME MIDNIGHT YESTERDAY 2942.00000 24 HOUR FOOTAGE 370' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.75" SEC FMF36421Z 10825616RW 3X19 2800 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 139.3 @ 3202.00000 4.6 @ 3138.00000 54.0 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 32 @ 3152.00000 1 @ 3054.00000 5.9 KLBS ROTARY RPM 127 @ 3012.00000 13 @ 3178.00000 78.8 RPM PUMP PRESSURE 1375 @ 3217.00000 -5 @ 3052.00000 881.8 PSI DRILLING MUD REPORT DEPTH 2983' MW 9.7 VIS 40 PV PV 6 YP YP 19 Fl 6 Gels 7!9/10 CL- 4000 FC 1/ SOL 5.2 SD 0 OIL 0 MBL 7.5 pH 9.7 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1049 @ 2943.00000 17 @ 3147.00000 34.7 TRIP GAS CUTTING GAS 0 @ 3312.00000 0 @ 3312.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 27309 @ 2943.00000 149 @ 2946.00000 3551.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 6599 @ 2943.00000 0 @ 2999.00000 117.2 AVG 0 PROPANE (C-3) 7163 @ 2943.00000 0 @ 3193.00000 81.3 CURRENT 0 BUTANE (C-4) 839fi @ 2943.OOD00 1 @ 3193.00000 106.9 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 2712 @ 2943.00000 11 @ 2949.00000 14.1 I HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOIOGY SILTS AND CLAYS PRESENT LITHOLOGY 3312' = 70 % SILTSTONE, 20% CLAYSTONE, 10 % SAND PUMP A HI VIS SWEEP, PULL OUT OF THE HOLE TO THE SHOE, MONITOR THE WELL INSIDE 7 5/B" CASING, CONTINUE TO PULL OUT OF THE HOLE AND UNLOAD DRILL FORMATION TO 3312' , DAILY ACTIVITY DOWNLOAD MWD DATA, RIG DOWN GEO PILOT, INSPECT BIT, MAKE UP BHA AND UPLOAD NUKE SOURCE, RUN IN THE HOLE AND SHALLOW TEST MWD, CIRCULATED OUT 134 NUKE SOURCE , SUMMARY UNITS OF GAS WITH C-1 TO C-5 NOTED, CONTINUE TO RUN TO BOTTOM AT REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~ ~~y,~ ^i/~ /~~ 2N-3378 . REPORT FOR MORRIS/MCDADE DATE Feb 21, 2007 DEPTH 4650.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 3312.00000 24 HOUR FOOTAGE 1338' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4623.61 66.19 252.95 2999.99 SURVEY DATA 3768.11 65.40 249.13 2643.45 2662.51 67.66 239.74 2239.86 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.75" SEC FMF36421Z 10825616RW 3X19 2800 3313 454 13.42 NA NA 2 6.75" HTC HCM5052 TIVZ923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 206.3 @ 4587.00000 7.9 @ 3957.00000 105.4 110.59229 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 34 @ 3605.00000 1 @ 3627.00000 5.4 7.47520 KLBS ROTARY RPM 94 @ 3447.00000 1 @ 4588.00000 69.2 85.00000 RPM PUMP PRESSURE 1819 @ 3953.00000 1271 @ 4206.00000 1560.8 1502.25500 PSI DRILLING MUD REPORT DEPTH NA MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1161 @ 3487.00000 23 @ 3317.00000 204.1 TRIP GAS 1383 @ 3313' CUTTING GAS 0 @ 4650.00000 0 @ 4650.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 796140 @ 3487.00000 1035 @ 4389.00000 93614.5 CONNECTION GAS HIGH 370 @ 3929' ETHANE (C-2) 1086 @ 3487.00000 7 @ 4570.00000 262.3 AVG 60 PROPANE (C-3) 469 @ 3487.00000 0 @ 3313.00000 32.7 CURRENT 125 BUTANE (C-4) 1154 @ 3487.00000 0 @ 3313.00000 80.3 CURRENT BACKGROUND/AVG 200 PENTANE (C-5) 1051 @ 3487.00000 0 @ 3313.00000 73.2 HYDROCARBON SHOWS GAS SHOW INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 3480 TO 3490 70% SAND 20 % SILT, 10 % CLAY BEFORE 150 MAX 1161 AFTER 225 VERY LIGHT GRAY, VERY FINE TO FINE GRAINS. c-1 TO c-5 LITHOIOGY SILT, CLAY SAND, SANDSTONES PRESENT LITHOLOGY 4650'=80% SILT, 20% CLAY DAILY ACTIVITY SUMMARY RUN IN HOLE TO 3046' SURVEY EVERY 30' TO TD, TRIP GAS = 1383 UNITS, DRILL FORMATION TO REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. .] • .] CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~~~ 2N-3378 REPORT FOR MCDADE/MORRIS DATE Feb 22, 2007 DEPTH 6193.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 4650.00000 24 HOUR FOOTAGE 1543' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75" HTC HCM5052 TIVZ923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 207.0 @ 5943.00000 14.5 @ 5949.00000 106.7 83.92200 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 64 @ 5950.00000 SLIDE @ 5991.00000 14.2 51.06700 KLBS ROTARY RPM 90 @ 5555.00000 SLIDE @ 4960.00000 76.7 SLIDE RPM PUMP PRESSURE 2434 @ 5955.00000 539 @ 4764.00000 1496.8 1809.84800 PSI DRILLING MUD REPORT DEPTH 4100' MW 9.7 VIS 41 PV 7 VP 19 FL 5.4 Gels 8/10/11 CL- 3000 FC 1/3 SOl 7 SD TR OIL 1% MBL 12.5 pH 9.6 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 322 @ 5451.00000 36 @ 6163.00000 177.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12939 @ 4692.00000 1125 @ 6163.00000 5395.4 CONNECTION GAS HIGH 60 ETHANE (C-2) 72 @ 5451.00000 7 @ 4750.00000 37.5 AVG 30 PROPANE (C-3) 0 @ 6193.00000 0 @ 6193.00000 0.0 CURRENT 10 BUTANE (C-4) 0 @ 6193.00000 0 @ 6193.00000 0.0 CURRENT BACKGROUND/AVG 150 PENTANE (C-5) 0 @ 6193.00000 0 @ 6193.00000 0.0 HYDROCARBON SHOWS no shows the last 24 hours INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SANDSTONE PRESENT LITHOLOGY 6200' = 50% SANDSTONE (VERY FINE GRAINS), 50% S ILTSTONE DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. ~- ~ CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~~~ ~^r~ ^/~ 'r 2N-3378 / REPORT FOR BREEDEN/MCDADE DATE Feb 22, 2007 DEPTH 6300.00000 PRESENT OPERATION M/U BHA TIME 14:17:04 YESTERDAY 6193.00000 24 HOUR FOOTAGE 107' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6300' 3682.85' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75" HTC HCM5052 TN2923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 114.0 @ 6291.00000 6.5 @ 6299.00000 66.9 16.67601 FTIHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 51 @ 6193.00000 2 @ 6279.00000 13.1 KLBS ROTARY RPM 88 @ 6282.00000 1 @ 6208.00000 61.9 RPM PUMP PRESSURE 2220 @ 6208.00000 0 @ 6300.00000 1897.3 PSI DRILLING MUD REPORT DEPTH 6191' MW 9.7 VIS 44 PV 9 YP 19 FL 4.6 Gels 7111113 CL- 1300 FC 1l3 SOL 6.5 SD TR OIL 1% MBL 15 pH 9.8 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 161 @ 6217.00000 24 @ fi300.00000 120.5 TRIP GAS CUTTING GAS @ @ WIPER GAS 963 @ 6284' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 5252 @ 6284.00000 1071 @ 6270.00000 3092.7 CONNECTION GAS HIGH ETHANE (C-2) 74 @ 6284.00000 11 @ 6270.00000 30.7 AVG PROPANE (C-3) 17 @ 6284.00000 2 @ 6281.00000 0.4 CURRENT BUTANE (C-4) 0 @ 6300.D0000 0 @ 6300.00000 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 6300.00000 0 @ 6300.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SANDSTONE PRESENT LITHOLOGY 6300' = 50 % SILTSTONE, 50 % SANDSTONE (VERY FINE GRAINED) DRILL TO 6284', (WIPER TRIP), PULL OUT TO 6189', PUMP HI VIS SWEEP AND MONITOR THE WELL, PULL OUT OF THE HOLE TO 3350', MONITOR THE WELL, PULL OUT OF THE HOLE TO THE SHOE DAILY {2858'), SERVICE THE RIG AND CH ANGE OUT SAVOR SUB, RUN IN THE HOLE TO 6284' (TD) AND CIRCULATE OUT 963 UNITS OF WIPER GAS, GAS COMING IN EARLY (C-80?)AND NOT FROM ACTIVITY ~ BOTTOM OF THE WELL, DRILL FORMA TION TO 6300', PUMP SWEEP AND MONITOR THE WELL, PULL OUT OF THE HOLE TO 109' AND DOWN LOAD NUKES AND STAND BACK MWD, DRAIN MUD SUMMARY MOTOR AND LAY DOWN. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~~' T H 2N-3378 REPORT FOR BREEDEN/MCDADE DATE Feb 24, 2007 DEPTH 7257.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 6300.00000 24 HOUR FOOTAGE 95T CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA fi716.78' 69.18 252.23 3832.22' 81T INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75" HTC HCM5052 TN2923 5X12 3313' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 342.9 @ 6767.00000 11.8 @ 6304.00000 76.3 98.87936 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 43 @ 6300.00000 1 @ 6485.00000 12.1 32.06520 KLBS ROTARY RPM 89 @ 6548.00000 22 @ 6865.00000 71.4 84.00000 RPM PUMP PRESSURE 2363 @ 6730.00000 92 @ 6865.00000 2075.4 2207.91821 PSI DRILLING MUD REPORT DEPTH 6300' MW 9.7 VIS 47 PV 10 YP 20 FL 5 Gels 8/10/12 CL- 1000 FC 1/2 SOL 7 SD TR OIL 1 % MBl 17.5 pH 9.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 113 @ 7147.00000 1 @ 6457.00000 37.4 TRIP GAS 670 @ 6300' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 20785 @ 6960.00000 214 @ 6457.00000 6058.5 CONNECTION GAS HIGH 6 ETHANE (C-2) 530 @ 7233.00000 1 @ 6457.00000 115.5 AVG 4 PROPANE (C-3) 132 @ 7233.00000 0 @ 6842.00000 22.3 CURRENT 2 BUTANE (C-4) 131 @ 6949.00000 1 @ 6969.00000 12.2 CURRENT BACKGROUND/AVG 60 PENTANE (C-5) 36 @ 7034.00000 0 @ 7098.00000 2.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOIOGV/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, CLAYSTONE, CARBONACEOUS SILTSTONE PRESENT LITHOLOGY 7250' = 20% CARBONACEOUS SILTSTONE, 20 % CLAYSTONE, 60% SILTSTONE DAILY ACTIVITY UPLOAD MWD, LOAD UP NUKES, SHALLOW TEST EQUIPMENT, RUN IN THE HOLE TO 6200', WASH TO 6300', CIRCULATE OUT 670 UNITS OF TRIP GAS, DRILL FORMATION TO REPORT SUMMARY TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. r~ ~_J • l~ \_ J CONOCOPHILLIPS raRN DAILY WELLSITE REPORT ~~~ ,p^~~ [(~ /~. 2N-3378 ' REPORT FOR BREED EN/MCDADE DATE Feb 25, 2007 DEPTH 8453.00000 PRESENT OPERATION GRILLING TIME MIDNIGHT YESTERDAY 7257.00000 24 HOUR FOOTAGE 1196' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8236.97' 65.92 253.08 4426.92' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 fi.75" HTC HCM5052 TN2923 5X12 3313' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 319.2 @ 8426.00000 12.5 @ 8428.00000 86.5 84.96577 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 78 @ 8394.00000 3 @ 7729.00000 22.4 40.37840 KLBS ROTARY RPM 90 @ 7902.00000 1 @ 8426.00000 76.5 77.00000 RPM PUMP PRESSURE 2465 @ 7437.00000 1436 @ 8422.00000 2064.8 2075.37256 PSI DRILLING MUD REPORT DEPTH 7238' MW 9.7 VIS 48 PV 10 VP 25 FL 5.2 Gels 12/17/21 CL- 800 FC 1/2 SOL fi.5 SD TR OIL 1% MBL 20 pH 9.3 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 101 @ 7736.00000 15 @ 8387.00000 46.9 TRIP GAS CUTTING GAS @ @ W IPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 17357 @ 7736.00000 949 @ 8155.00000 7741.1 CONNECTION GAS HIGH 8 ETHANE (C-2) 644 @ 7805.00000 22 @ 8155.00000 227.4 AVG 0-3 PROPANE (C-3) 241 @ 8087.00000 11 @ 8399.00000 101.1 CURRENT 2 BUTANE (C-4) 206 @ 7953.00000 2 @ 8155.00000 60.6 CURRENT BACKGROUND/AVG 40 PENTANE (C-5) 117 @ 7953.00000 0 @ 8204.00000 10.1 HYDROCARBON SHOWS TRACE OIL SHOWS AT INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8440-8460 8635-8645 SANDSTONE/SILTSTONE NO INCREASES VERY FINE DIRTY SILTY SANDSTONES WITH DULL 20% sample 8uorse cence VERY POOR OIL CUTS LITHOLOGY CLAY, SILT, SANDSTONE PRESENT LITHOLOGY 80% CLAY, 20% SILTSTONE ALL VERY SOLUBLE DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • • CONOCOPHILLIPS tarn DAILY WELLSITE REPORT ~~~~~ 2N-337B REPORT FOR BREEDEN/MCDADE DATE Feb 26, 2007 DEPTH 9260.00000 PRESENT OPERATION POOH TIME MIDNIGHT YESTERDAY 8453.00000 24 HOUR FOOTAGE 807' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9260' 4985.74' SURVEY DATA 9213 26' 47.11 253.25 4953.76 8998.17' 50.89 253.30 4812.11' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 fi.75" HTC HCM5052 TN2923 5X12 3313' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 396.8 @ 8966.00000 7.8 @ 8708.00000 66.5 123.76237 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 97 @ 8579.00000 13 @ 8935.00000 38.3 28.79930 KLBS ROTARY RPM 97 @ 8854.00000 1 @ 8880.00000 63.3 85.00000 RPM PUMP PRESSURE 2443 @ 8496.00000 1225 @ 8622.00000 214fi.7 2064.97681 PSf DRILLING MUD REPORT DEPTH 8662' MW 9.9 VIS 50 PV 11 YP 23 FL 5 Gels 11I14Ii6 CL- 400 FC 1/2 SOL 8 SD TR OIL 1% MBL 20 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 85 @ 9230.00000 9 @ 8477.00000 37.1 TRIP GAS CUTTING GAS @ @ W IPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 15378 @ 8988.00000 1682 @ 8477.00000 6648.3 CONNECTION GAS HIGH ETHANE (C-2) 674 @ 9230.00000 37 @ 8477.00000 200.2 AVG PROPANE (C-3) 368 @ 9230.00000 17 @ 8488.00000 93.2 CURRENT BUTANE (C-4) 280 @ 9230.00000 1 @ 8478.00000 60.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 72 @ 9230.00000 0 @ 8479.00000 12.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE, SILTSTONE, SANDSTONE, CARBON LAMINAE, SHALE PRESENT LITHOLOGY 5960' =SHALE 30%, SANDSTONE 20 % , SILTSTONE 50 % DAILY ACTIVITY DRILL TO 9260', CIRCULATE THE CONDITION THE MUD AND HOLE, STAND BACK ONE STAND OF DRILL PIPE, PUMP AS SWEEP, LAY DOWN A SINGLE, MONITOR THE WELL (OK), PULL OUT SUMMARY OF THE HOLE TO 5756', PUMP A DRY JOB, CONTINUE TO PULL OUT EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. `r~ u • r CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~~~ 2N-3378 REPORT FOR BREEDEN/MCDADE DATE Feb 27, 2007 DEPTH 9260.00000 PRESENT OPERATION WELL BORE STRENGTHEN TIME MIDNIGHT YESTERDAY 9260.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9260' 4985.74' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TIBIC PULLED 2 6.75" HTC HCM5052 TN2923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9260' MW 11.9 VIS PV YP FL Gels - CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 588 WG @ 9260' @ 20 TRIP GAS CUTTING GAS @ @ WIPER GAS 588 @ 9260' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 38111 @ 9260' @ 4068 CONNECTION GAS HIGH ETHANE (C-2) 2963 @ 9260' @ 128 AVG PROPANE (C-3) 784 @ 9260' @ 70 CURRENT BUTANE (C-4) 279 @ 9260' @ 52 CURRENT BACKGROUND/AVG 20 CIRC PENTANE (C-5) 135 @ 9260' @ 1 HYDROCARBON SHOWS NO FOOTAGE DRILLED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY CONTINUE TO PULL OUT OF THE HOLE TO THE SHOE(2858'), CIRCULATE DRILLING MUD = MAX GAS 40 UNITS, RIG UP AND PERFORM LOT w/ 9.9 PPG MW, 380 PSI LOT = 13.0 EMW, CUT AND SLIP NEW DRILL LINE, SERVICE THE RIG AND CHANGE OUT SAVER SUB, RUN IN THE HOLE TO TD (9260'), START TO RECIPROCATE THE HOLE (WIPER GAS 588 UNITS), BEGIN TO RAISE MUD R SUMMA Y WEIGHT, CURRENTLY 11.9 EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~ /~ J 1~ ~ ~ "` 2N-3378 -. . L. ... r".. REPORT FOR BREEDEN/MCDADE DATE Feb 28, 2007 DEPTH 9575.00000 PRESENT OPERATION LOST CIRCULATION TIME MIDNIGHT YESTERDAY 9260.00000 24 HOUR FOOTAGE 315' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9575 5200.12' (PROJ) BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75" HTC HCM5052 TN2923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 915.3 @ 9257.0000 7.9 @ 9268.00000 48.9 47.00000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 91 (SLIDE) @ 9271.00000 2 @ 9415.00000 30.3 85.99258 KIBS ROTARY RPM 65 @ 92fi0.00000 73 @ 9533.00000 65.9 75.00000 RPM PUMP PRESSURE 2280 @ 9376.00000 1608 @ 9270.00000 1996.8 1877.85400 PSI DRILLING MUD REPORT DEPTH 9575' MW 12.4 VIS PV VP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1652 @ 9536.00000 6 @ 9262.00000 290.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 132678 @ 9536.00000 991 @ 9262.00000 26469.3 CONNECTION GAS HIGH ETHANE (C-2) 37971 @ 9536.00000 47 @ 9262.00000 5099.5 AVG PROPANE (C-3) 28235 @ 9536.00000 27 @ 92fi2.00000 4012.3 CURRENT BUTANE (C-0) .24720 @ 9536.00000 20 @ 9262.00000 3949.4 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 6167 @ 9536.00000 4 @ 9262.00000 802.8 HYDROCARBON SHOWS 3 GAS KICKS: A) 9490-9500' B) 9505-9515' C) 9518-9545' (BELOW) INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9518-9545' VERY POOR SAMPLES SANDSTONE <5% OF SAMPLE BEFORE 250 MAX 1fi52 AFTER LOST CIRC. ARGILLACEOUS SANDSTONE: VFGR, VP SMPLS, FAIR OIL CUTS ON LIMITED SAMPLES LiTHOLOGY SANDSTONE, SILTSTONE, CLAYS70NE, SHALE PRESENT LITHOLOGY LOST CIRCULATION @ 9574' LOST 162 BBLS AFTER ALMOST 4 HRS. DAILY ACTIVITY RAISE MUD FROM 11.4 TO 12.4 AND WELL BORE TEST, CONTROL DRILL AHEAD AT 50 FTIHR TO 9374', CIRCULATE AND MONITOR THE WELL, DRILL TO 9375' AND LOST CIRCULATION, (LOST SUMMARY SAMPLES AND GAS FROM 9545' TO 9575'), SLOW PUMPS AND MONITOR RETURNS, MONITOR LOSSES THROUGH TRIP TANK, MIX A HI VIS PILL AND WORK DRILL PIPE. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • • l~ u CONOCOPHILLIPS TARN ~I` _ ~~~T T DAILY WELLSITE REPORT ~,~,~~r--yl` 2N-3378 - REPORT FOR BREEDEN DATE Mar 01, 2007 DEPTH 9575.00000 PRESENT OPERATION SPOT PILL 8 WORK PIPE TIME MIDNIGHT YESTERDAY 9575.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9575' 5220.42' 9473.74 40.39 252.12 5143.50 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE ~ S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75" HTC HCM5052 TN2923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTIHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9575' MW 12.4 VIS 49 PV 18 YP 29 FL 42 Gels 8110/12 CL- 400 FC 1/2 SOL 18 SD 10 OIL TR MBL 4 pH 10.0 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 378 @ 9575' (CIRC) @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 32450 @ 9575 @ CONNECTION GAS HIGH ETHANE (C-2) 5750 @ 9575 @ AVG PROPANE (C-3) 5410 @ 9575 @ CURRENT BUTANE (C-4) 3859 @ 9575 @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 1093 @ 9575 @ HYDROCARBON SHOWS 3859 PPM C/4+1093 PPM C-51N LIMITED CIRCULATED MUD. INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY LOST CIRCULATION PRESENT LITHOLOGY LOST CIRCULATION DAILY ACTIVITY WORKING DRILL PIPE AFTER PUMPING NIGH VIS PILL, SLOW DISPLACEMENT @ 9141', MONITOR THE HOLE OFF THE TRIP TANK, CONTINUE TO WORK DRILL PIPE, RUN IN THE HOLE TO 9250', SUMMARY WORK PIPE AND BREAK CIRCULATION, SPOT VIS PILL ON THE BOTTOM, WORK DRILL PIPE AND MONITOR THE WELL FOR MUD LOSS THROUGH TRIP TANK. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~ 2N-3378 REPORT FOR BREEDENNAAGEN DATE Mar 02, 2007 DEPTH 9575.00000 PRESENT OPERATION CIRCULATE 12.7 MUD TIME MIDNIGHT YESTERDAY 9575.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9575' 5220.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TIBIC PULLED 2 fi.75" HTC HCM5052 TN2923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9575' MW 12.7 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Cap CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 625fi @ 9233' 230 @ 9233' TRIP GAS CUTTING GAS @ @ WIPER GAS 6256 @ 9233' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 42417 @ 9233' 20747 @ 9233' CONNECTION GAS HIGH ETHANE (C-2) 26594 @ 9233' 2207 @ 9233' AVG PROPANE (C-3) 18321 @ 9233' 974 @ 9233' CURRENT BUTANE (C-4) 81712 @ 9233' 3301 @ 9233' CURRENT BACKGROUND/AVG 250 PENTANE (C-5) 40050 @ 9233' 1906 @ 9233' HYDROCARBON SHOWS WIPER GAS AND SWAB GAS KICKS IN ORDER: 4580, 4964, 5119 AND 6256 UNITS INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY LOST CIRCULATION PRESENT LITHOLOGY LOST CIRCULATION RUN IN THE HOLE FROM 9141' TO 9556', PUMP SQUEEZE JOB, (MAX GAS 4580 UNITS), PULL OUT OF THE HOLE TO 8820', SQUEEZE PILL INTO FORMATION, CIRCULATE TO WORK DRILL PIPE , DAILY ACTIVITY ESTABLISH LOSSES (WIPE RUN IN THE HOLE FROM 8820' TO 9233' WORK DRILL PIPE AND CIRCU R GAS = 4984 UNITS) LATE (WIPER GAS = 5119 UNITS), SHORT TRIP 10 STANDS CIRCULATE OUT , SUMMARY 6256 UNITS OF WIPER GAS, RAISE MUD WEIGHT TO 12.7 EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. ;7 r ~~ CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~ ~~~~T ..~ ~j~-•- E[i 2N-3376 '.--' . REPORT FOR BREEDENNAAGEN DATE Mar 03, 2007 DEPTH 9575.00000 PRESENT OPERATION M/U BHA #9 TIME MIDNIGHT YESTERDAY 9575.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7.fi25" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9575' 5220.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/8/C PULLED rr2 6.75" HTC HCM5052 TN2923 5X12 3313 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTlHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9575' MW 12.6 VIS 70 PV 19 YP 33 FL 4 Gels 11!14/18 CL- 400 FC 1/2 SOL 18 SD 10 OIL TR MBL 7.5 pH 9.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 300 @ POOH 25 @ POOH 200 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO ABNORMAL GAS KICKS TRIPPING OUT OF THE HOLE INTERVAL LITHOLOGVIREMARKS GAS DESCRIPTION LITHOLOGY LOST CIRCULATION PRESENT LITHOLOGY LOST CIRCULATION DAILY ACTIVITY ESTABLISH MUD WEIGHT TO 12.7, PULL OUT OF THE HOLE TO 9328' AND MONITOR THE WELL (ok), PUMP A DRY JOB AND PULL OUT OF THE HOLE TO 119', REMOVE NUKES AND DOWN LOAD SUMMARY MWD DATA, BREAK DOWN AND RIG DOWN MWD AND DIRECTIONAL TOOLS, TEST BOPE, PUCK UP AND MAKE UP BHA #4 EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~~~- r 2N-3378 REPORT FOR BREEDENA/AAGEN DATE Mar 04, 2007 DEPTH 9620.00000 PRESENT OPERATION DRILLING 71ME MIDNIGHT YESTERDAY 9575.00000 24 HOUR FOOTAGE 45' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9575' 5220.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOU RS T/8/C PULLED RR2 6.75 HTC HCM5052 TN2923 5X12, 2X75 3313' GRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 112.1 @ 9617.00000 20.0 @ 9583.00000 78.4 49.36917 FT/HR SURFACE TORQUE 8 @ 9620.00000 6 @ 9575.00000 7.9 8.08830 AMPS WEIGHT ON BIT 25 @ 9575.00000 5 @ 9602.00000 10.1 15.26971 KLBS ROTARY RPM 76 @ 9577.00000 66 @ 9620.00000 73.6 66.00000 RPM PUMP PRESSURE 2491 @ 9620.OD000 1822 @ 9583.00000 2144.4 2491.69165 PSI DRILLING MUD REPORT DEPTH 9575 MW 12.4 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1244 @ 9613.00000 242 @ 9595.00000 583.5 TRIP GAS 2289 @ 9575' CUTTING GAS 0 @ 9620.00000 0 @ 9620.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 48105 @ 9579.00000 9897 @ 9620.00000 26642.5 CONNECTION GAS HIGH 800 @ 9614' ETHANE (C-2) 44356 @ 9576.00000 2038 @ 9596.00000 8806.3 AVG 800 PROPANE (C-3) 12453 @ 9576.00000 724 @ 9596.00000 2958.1 CURRENT 800 BUTANE (C-4) 23867 @ 9576.00000 1175 @ 9596.00000 4997.0 CURRENT BACKGROUNDIAVG 200 PENTANE (C-5) 3327 @ 9579.00000 29fi @ 9596.00000 1295.5 HYDROCARBON SHOWS JUST STARTING TO RECEIVE OIL SHOWS @ 9610' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9610' - VERY POOR SAMPLES INCREASING OVER 1000 ABNT GRAPHITE, CALCITE AND NUT PLUG, 5 % TO 20 % YEIGRN SAMPLE FLUOR. VERY SLOW POOR CUTS LITHOLOGY ABNT GRAPHITE, CALCITE AND NUT PLUG PRESENT LITHOLOGY MINOR SAND, SANDSTONE, SILTSTONE DAILY ACTIVITY FINISH MAKING UP BHA #4 AND RUN INTO THE HOLE TO 2761', FILL DRILL PIPE, RUN IN HOLE TO 6666', CIRCULATE BOTTOMS UP, GAS = 560 UNITS, RUN IN THE HOLE TO 9325' WASH TO SUMMARY BOTTOM, TRIP GAS = 2289 UNITS, PREP TO DRILL, DRILL FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • ~~ I CONOCOPHILLIPS TARN ~~~ ~~ DAILY WELLSITE REPORT 2N-3378 REPORT FOR BREEDENNAAGEN DATE Mar 04, 2007 DEPTH 9950.00000 PRESENT OPERATION SQUEEZE PILL AT TD TIME MIDNIGHT YESTERDAY 9620.00000 24 HOUR FOOTAGE 330' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9950' 5504.60 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS Tl8/C PULLED RR2 6.75" HTC HCM5052 TN2923 5X12, 2X15 3313' 9950' 6637' 94.fi9 NA TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 101.4 @ 9716.00000 11.8 @ 9734.00000 54.0 87.58272 FTIHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 31 @ 9733.00000 0 @ 9915.00000 13.2 15.84036 KLBS ROTARY RPM BO @ 9802.00000 60 @ 9915.00000 69.0 72.00000 RPM PUMP PRESSURE 2712 @ 9729.00000 1736 @ 9704.00000 2353.4 2060.81128 PSI DRILLING MUD REPORT DEPTH 9614' MW 12.4 VIS 50 PV 16 VP 31 Fl 4 Gels 9/12/14 CL- 400 FC 1/2 SOL 18 SD 10 Oll TR MBL 10 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1650 @ 9656.00000 46 @ 9875.00000 281,5 TRIP GAS CUTTING GAS @ @ WIPER GAS 373 @ 9950' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 45478 @ 9653.00000 4332 @ 9624.00000 15378.9 CONNECTION GAS HIGH ETHANE (C-2) 20479 @ 9653.00000 402 @ 9875.00000 2946.0 AVG PROPANE (C-3) 6643 @ 9669.00000 165 @ 9939.00000 1292.3 CURRENT BUTANE (C-4) 12763 @ 9653.00000 259 @ 9881.00000 2158.8 CURRENT BACKGROUND/AVG 70 (CIRC) PENTANE (C-5) 3269 @ 9660.00000 99 @ 9884.00000 723.4 HYDROCARBON g600-9620' 9640-9690' (BELOW) SHOWS INTERVAL LITHOLOGV/REMARKS GAS DESCRIPTION 9640-9690' VERY POOR SAMPLES SAND, BEFORE 295 MAX 1650 SAND/SANDSTONE = BCMG UNCONS THRU GAS KICK, 40 % EVEN TO PATCHY YELGRN FLOR, SLO CLOUDY CUTS, V FNT STRAW SANDSTONE AFTER 150 RESD STN, VP SAMPLE QUALITY (>BS% GRAPHITE, CALCITE + NUT PLUG LITHOLOGY SAND, SANDSTONE, SILTSTONE, CLAY, SHALE AND CARBON SHALE PRESENT LITHOLOGY 9950'=70% SILTSTONE, 20% CLAVSTONE, 10% CARBON SHALE DAILY ACTIVITY DRILL FORMATION TO 9950', CIRCULATE AND CONDITION THE HOLE, PUMP A HI VIS SWEEP AND MONITOR THE WELL (OK), WORK THE DRILL PIPE AND PULL OUT OF THE HOLE TO 9616', SUMMARY REAM TO BOTTOM AND WORK PIPE AND CIRCULATE (WIPER GAS 373 UNITS), PUMP A PILL AND PULL OUT OF THE HOLE TO 9045' AND SQUEEZE PILL AND HOLDTEN MINS. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • • • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~ 2N-3376 REPORT FOR BREEDENNAAGEN DATE Mar O6, 2007 DEPTH 9950.00000 PRESENT OPERATION POOH L/D MWD TIME MIDNIGHT YESTERDAY 9950.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9950' 5504.60' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR2 6.75" HTC HCM5052 TN2923 5X12, 2X15 3313' 9950' 6637' 94.69 NA TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARV RPM @ @ RPM PUMP PRESSURE @ @ PSI GRILLING MUD REPORT DEPTH 9950' MW 12.5 VIS 55 PV 19 VP 31 FL 4 Gels 11/15/18 CL- 400 FC 1/2 SOL 18 SD 10 OIL TR MBL 10 pH 9.8 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 100 (CIRC) @ CIRC 25 @ CIRC 50 (CIRCO TRIP GAS CUTTING GAS @ @ WIPER GAS 314 @ 9045' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGV/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAIIV CIRCULATE AND CONDITION MUD AT 8857', WIPER GAS 31q UNITS, MONITOR THE WELL AND WORK THE DRILL PIPE, SWAB GASES OF 200 AND 320 OVER A BACKGROUND OF 50 UNITS NOTED, ACTIVITY CIRCULATE AND RAISE THE M UD WEIGHT TO 12.6, RUN IN THE HOLE WASHING DOWN FROM 8557' TO 9950' (TD), CIRCULATE AND CONDITION THE HOLE WIPER GAS = 309 UNITS, BACK REAM SUMMARV OUT OF THE HOLE TO 9486', P ULL OUT OF THE HOLE TO 9011' AND PUMP A DRY J08, PULL OU7 OF THE HOLE TO 488', LAY DOWN HWDP AND DRILL COLLARS, REMOVE NUKES AND DOWNLOAD MWD. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • • • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~ 2N-3376 REPORT FOR BREEDENNAAGEN DATE Mar O6, 2007 DEPTH 9950.00000 PRESENT OPERATION RUNNING 5 1/2" CASING TIME MIDNIGHT YESTERDAY 9950.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9950' 5504.60' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/8/C PULLED rr2 6.75" HTC HCM5052 TN2923 5X12, 2X15 3313' 9950' fi637' 94.69 111-X-I TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9950' MW 12.6+ VIS 53 PV 19 YP 28 FL 4 Gels 10/14/16 CL- 400 FC 1/2 SOL 19 SD 12 OIL TR MBL 12.5 pH 10.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 282 @ 5017 25 @ TIH 50 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGV PRESENT LITHOLOGV DAILY ACTIVITY LAY DOWN BHA, WASH OUT STACK AND PREP FOR RUNNING CASING, RIG UP CASING AND BEGIN TO RUN IN THE HOLE, RUN IN THE HOLE TO 2809' AND CIRCULATE BOTTOMS UP, TRIP GAS = SUMMARY 89 UNITS, RUN IN THE HOLE TO 5017' AND CIRCULATE BOTTOMS UP, TRIP GAS = 282 UNITS, RUN IN THE HOLE TO 6600' AND BEGIN TO CIRCULATE BOTTOMS UP. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~ ~~~ /~y~ {+/` 'I 2N-3378 .. J REPORT FOR BREDENNAAGEN DATE Mar 08, 2007 DEPTH 9950.00000 PRESENT OPERATION CEMENT IN PLACE TIME MIDNIGHT YESTERDAY 9950.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7.625" @ 2858' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9950' 5504.60' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 98 @ 7985' S @ 9931 18 TRIP GAS 98 @ 7985' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS NIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 22 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGV CIRCULATE AT 1 BPM CIRCULATE UP 98 UNITS OF TRIP GAS, RUN IN THE HOLE TO 9931', CIRCULATE AT 1 BPM AT 12.3 CIRCULATE AT 6600' CIRCULATE UP fi0 UNITS RUN IN THE HOLE 70 7985 DAILY ACTIVITY CIRCULATED OUT 75 UNITS OF MW , , CIRCULATE AT 1 BPM AND RECIPROCATE THE HOLE, PUMP CEMENT, CEMENT IN PLACE WAS ZERO TRIP GAS RIG UP CEMENT HEAD CIRCULATE , , , , SUMMARY RETURNS, RIG DOWN CEMENT HEAD AND LAV DOWN, INSTALL 5 1/2 PACKOFF AND TEST. EPOCH PERSONNEL ON BOARD 4 DAILY COST REPORT BY LEES F. BROWNE JR. •
