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Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: SBHPT Survey: 2N-327 Run Date: 11/12/2018 IZAMMA1 FEB 0 5 2019 AOGCC 30329 January 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-327 Digital Data in LAS format, Digital Log Image file 50-103-20548-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: 0 0 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 '- �{ EVI ^Y 0 RE: Production Profile: 2N-327 ' Run Date: 9/24/2015 2 D1- 0(,j ZG 5 3 -1 December 3, 2015 DATA LOGGED \z l30/2015P M.K.BENDER The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 2N-327 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20548-00 Production Profile Log 50-103-20548-00�� 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed:'a'n0�' G✓V��N' WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 'ZD -1- DG 0) 2-53`12. January 20, 2015 DATA LOGGED /201 Z/ NT. REND g; .5 2-015 RE: Perforating Record: 2N-327 Run Date: 12/29/2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 2N-327 Digital Data in LAS format, Digital Log Image file 50-103-20548-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: / ,� 0 STATE OF ALASKA AL _KA OIL AND GAS CONSERVATION CON. ,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair well IF Plug Perforations IF Perforate r Other ry Frac Stimulation After Casing r" Pull Tubing r Stimulate - Frac r% Waiver r Time Extension r - Change Approved Program rOperat. Shutdown r Stimulate - Other Re-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Ro Exploratory r' Stratigraphic r- Service r' 207-069 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20548-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 375074 KRU 2N-327 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary. Total Depth measured 6836 feet Plugs (measured) none true vertical 6195 feet Junk (measured) none Effective Depth measured 6740 feet Packer (measured) 5646 true vertical 6100 feet (true vertical) 5020 Casing Length Size MD ND Burst Collapse CONDUCTOR 115 16 146 146SURFACE 2568 7 625 2599 2385 RECEIVED INTERMEDIATE 5826 5855 5223 LINER 1188 4.5 6834 6193 JAN 15 2015 AOGCC Perforation depth- Measured depth: 6020'-6030', 6140'-6160', 6560'-6580' True Vertical Depth: 5386'-5396', 5505'-5525', 5921'-5941' Tubing (size, grade, MD, and TVD) 3.5, L-80, 5695 MD, 5067 TVD Packers 8 SSSV (type, MD, and TVD) PACKER - BAKER C-2 ZXP LINER TOP PACKER @ 5646 MD and 5020 TVD NIPPLE - CAMCO DS NIPPLE w/ 2.875 PROFILE @ 491 MD and 490 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 6020'-6030' Treatment descriptions including volumes used and final pressure: 255020# Of 16/20 proppant 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r' Development r Service r Stratigraphic r 16. Well Status after work: Oil r Gas IF WDSPL IF Daily Report of Well Operations XXX GSTOR (— WINJ r WAG r- GINJ r' SUSP r' SPLUG r- 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 314-590 Contact Tyson Wiese (@_ 263-4250 Email Tyson. M.Wiese(cD-conocoph i I lips. com Printed Name T son Wiese Title Sr. Wells Engineer Signature Phone: 263-4250 Date _Iq — I_OI5 \,) v L77- 1 `J_ Form 10-404 Revised 10/2012 RBDMS--'kk JAN 16 1015 Submit Original Only 2N-327 WELL WORK SUMMARY DATE SUMMARY 12/11/2014 TAG HYDRATES @ 846' SLM. PUMPED 65 BBLS DN IA. WORKED ICE PLUG TO 1020' SLM. IN PROGRESS 12/16/2014 RIH TAG AT 918', COME ONLINE WITH MOTOR AND MILL, MAKE IT TO 2500' SHUT WELL IN AND INJECT, PUMP 50 BBLS DIESEL DOWN THE TUBING, TURN WELL OVER TO SLICKLINE 12/17/2014 DRIFT W/ 2.77" G -RING & BRUSHED D -NIP @ 5617' RKB; TAGGED FILL @ 6551' SLM; SET 2.75" CA -2 PLUG @ 5617' RKB. SET BAITED PULLING TOOL ON PLUG; PULLED OV @ 5462' RKB. CIRC OUT TBG & IA W/ 152 BBLS INHIB SEAWATER FOLLOWED BY 77 BBLS DIESEL (U -TUBE FP). SET DV @ 5462' RKB. (LRS LEFT ON LOC PERFORMING MIT -T & MIT -IA --BOTH PASSED). IN PROGRESS 12/18/2014 PULLED 2.75" CA -2 PLUG @ 5617' RKB. READY FOR COIL 12/24/2014 Pump 20 bbl sand plug slurry to cover Purple perfs. Well went on vacuum during pumping and micro -motion meter gave inaccurate readings. Due to late finish, unable to wait on sand to fall out, get a tag and pump second pill before everyone timed out. Job in progress. 12/25/2014 RIGGED UP CEMENT PUMP, FLUSHED LINES TO TANKS AT 4 BPM, HAD CEMENTERS PUMP DOWN THE COIL TO VERIFY MICROMOTION CALIBRATION ON CTU AND CEMENT TRUCK, APPEARS THEY ARE BOTH WORKING FINE, RIH TO TAG TOS @ 6558' CTMD (6568" RKB), PUMPED 5 BBL GEL SWEEP,LAYED IN 21.8 BBL SAND PLUG TO COVER PURPLE PERFS WITH 11.3 PPG SLURRY THEN PUMP FINAL 5 BBL GEL PILL, POOH, WELL LEFT F/P TO PERFS, READY FOR S/L TAG TOMORROW, JOB IN PROGRESS. 12/26/2014 TAGGED D NIPPLE @ 5600' SLM, 5617' RKB. TAGGED SAND PLUG @ EST. 6105' RKB. DUMP BAILED — 20' SAND. READY FOR E/L. 12/29/2014 PERFORATE INTERVAL 6020'-6030' USING 2.5" HSC LOADED 6SPF, PHASED 60 DEG, 11 GM TITAN PROSPECTOR CHARGES. LOG CORRELATED TO HES RMT LOG DATED 22 JUN 2014. READY FOR INJECTIVITY TEST. 12/30/2014 PERFORMED INJECTIVITY TEST FROM 0.5 BPM TO 1.0 BPM. AT 6.3 BBLS AWAY, SHUT DOWN AS WELL STOPPED TAKING FLUID UPON REACHING MAX PRESSURE OF —3400 PSI. 1/1/2015 TAG SAND PLUG @ 6068' SLM. TAG D NIPPLE FOR A 21' CORRECTION, EST SAND TOP @ 6089' RKB. JOB COMPLETE 1/3/2015 Performed injectivity test beginning @ 0.5 bpm. Pressure climbed quickly to 3700 psi at which point it broke over. Established stable rate of 5.6 bpm @ 1740 psi (25 bbls diesel pumped at this rate, 40 bbls total). Note: On schedule to frac in the A.M. 1/5/2015 Performed fracture stimulation treatment of the Bermuda at 20 bpm placing 255,020# of 16/20 carbolite in 1-8 ppa stages. Well freeze protected w/ 14 bbls of diesel. Note: See attached SLB treatment reports in WV 1/9/2015 RIH WITH JET SWIRL NOZZLE, TAG AT 5816' CTMD, UNABLE TO MAKE ANY HOLE, POOH AND SWAP JSN FOR A DOWN JET NOZZLE, RIH TO TAG AT 5817' CTMD, BROKE THROUGH HARD AREA AND FCO DOWN TO 6085' CTMD WHILE PUMPING DIESEL AND DIESEL GEL SWEEPS AT 1.8 BPM MAINTAINING 1:1 RETURNS, LIGHT SAND CONCENTRATIONS OBSERVED IN RETURNS, CHASE FINAL SWEEP OOH AT 80%, WELL LEFT F/P TO 6085' CTMD, READY FOR S/L TO LOG, JOB IN PROGRESS. 1/10/2015 TAG FILL @ 6070' SLM; RUN SPECTRA SCAN MEMORY LOG FROM 5520'-6067' RKB (OBTAINED GOOD DATA TRACER SEEN @ 6020-6030); SET 2.75" CSV @ 5617' RKB. IN PROGRESS. 1/11/2015 PULLED DV & SET OV @ 5462' RKB (OBTAIN GOOD PT ON TBG); PULL CAT SV @ 5617' RKB & MEASURE BHP @ 6067' RKB. SBHP OF 2032 PSI MEASURED. READY FOR CTU ****AFTER BERMUDA PRODUCTION TESTING**** KUP PROD 2N-327 Con000Phijjips Well Attributes Max Angle & MD TD Alaska Inc Wellbore API/UW Field Name Wellbore Status ) MD (ftKB) Alt Btm (ftKB) 501032054800 TARN PARTICIPATING AREA PROD 32.88 1,971.52 6,836.0 .• Comment HIS (ppm) Date SSSV: NIPPLE 78 12/21/2013 Annotation Entl Date Last W0: KB-Grd (ft) Rig Release Date 34.69 8/14/2007 2NJ27, 1/8201510:38'.10 AM emca sc a tz aqua Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 6,551.0 12/17/2014 I Rev Reason: PERFORATIONS, FRAC lehalIf 1/8/2015 Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... W111 -el (I... Grade Top Thread CONDUCTOR 16 15.250 31.0 146.0 146.0 00H-40 WELDED HANGER; 26.0- Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread SURFACE 95/8 8.835 31.0 2,598.7 2,385.4 40.00 L-80 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread INTERMEDIATE 7 6.276 28.3 5,854.5 5,223.0 26.00 L-80 BTCM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread LINER 412 3.958 5,646.1 6,834.0 6,193.4 12.60 L-80 IBTM Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 5,646.1 5,020.1 16.11 PACKER Baker C-2 ZXP Liner Top Packer, Size 5" x 7". 11.40' 4.410 L x 5.25" ID Tie Back Stem at top 5,663.9 5,037.2 15.49 HANGER Baker Flex -Lock Liner Hanger, Size 5"x 7" 4.410 Ml CONDUCTOR; 31 0.146.0 5,673.7 5,046.6 15.20 SBE Seal Bore Ext, Size 80-40, 5" BTC Box X Pin 5" OD, 4.000 4.00" ID Seal Bore NIPPLE: 490.6 Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) I. Wt (Ibl(t) Grade Top Connection IUHING 312 2.992 26.0 5,694.7 5,066.9 9.30 L-80 ABM-EUE I Completion Details Nominal ID Top (ftKB) Top (ND) (ftKB) Top Incl (`) Item Des Com (i n) 26.0 26.0 0.00 HANGER FMC TUBING HANGER 2.992 490.6 490.3 5.56 NIPPLE CAMCO DS NIPPLE w/ 2.875 PROFILE 2.875 SURFACE; 31.0-2,598.7 5,544.5 4,923.6 20.11 SLEEVE -C CMU SLIDING SLEEVE w/2.812" DS PROFILE (Closed) 2.812 GAS LIFT; 2,659.6 5,617.4 4,992.6 17.29 NIPPLE CAMCO D NIPPLE NO GO 2.750 5,656.0 5,029.6 15.73 LOCATOR Baker Locator Sub / NoGo, 5.00" OD Loc, 3.00" ID) 3.000 GAS LIFT; 3,775.2 5,679.9 5,052.7 15.02 1 LOCATOR LOCATOR 3.000 5.691.4 5,063.8 14.61 SEAL ASSY I BAKER 80-40 BONDED SEAL ASSEMBLY 3.000 Perforations & Slots GAS LIFT, 4,734.4 Shot Dens Top (TVD) Btm (TVD) (shots/f Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date t) Type Com CHEMICAL: 5.380.4 6,020.0 6,030.0 5,386.3 5,396.2 BERMUDA, 12/292014 6.0 APERF 2.5" HSC, 6SPF, 60 2N-327 Degree phasing, 11 GM Titan Prospector GAS LIFT. 5.462.5 Charges 6,140.0 6,160.0 5,505.0 5,524.8 BERMUDA, 12/302007 6.0 APERF 2.5"HS-HSD Bermuda 2N-327 I I I Sand SLEEVE -c: 5.544.5 6,560.0 6,580.0 5,921.3 5,941.2 ESKER, 2N- 10/24/2007 6.0 (PERF 2.5" HJ 2506 ESKER 1 327 1 1 I Sand Stimulations & Treatments NIPPLE; 5,617.4 in Top Mal Btm Depth Depth Top (TVD) Btm (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 6,560.0 6,580.0 5,921.3 5,941.2 FRAC 10/26/200 ESKER SAND FRAC 298900# CARBOLITE w/12 ppa .� - 7 ON FORMATION 6,140.0 6,160.0 5,505.0 5,524.8 FRAC 1/31/2008 BERMUDA SAND FRAC-PLACED 288,221# OF LOCATOR; 5656.0 16/20 CARBOUTE BEHIND PIPE F; ,020.0 6,030.0 5,386.3 5,396.2 FRAC 1/52015 BERMUDA SAND FRAC USING 16/20 PROPANT IN 1-8 STAGES, 255,020# Mandrel Inserts st ad LOCATOR; 5.678.9 on Top (TVD) Vale Latch Port Size TRO Run N Top (ftKB) (ftKB) Make Model OD (in) Sew Type Type (in) (psi) Run Date Com 2,659.6 2,437.0 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 8/13/2007 6:30 SEALASSY; 5,691.4 2 3,775.2 3,393.9 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 8/13/2007 4:00 3 4,734.4 4,214.9 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 8/132007 2:00 4 5,380.4 4,772.0 CAMCO LTS- 1 CHEM DMY BK -5 0.000 0.0 8/13/2007 INJ CIM 9:30 5 5,462.5 4,847.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/17/2014 1:30 Notes: General & Safety End Date Annotation 8/12/2008 NOTE: View Schematic w/ Alaska Schematic9.0 INTERMEDIATE; 26.35,85/.5- 1/1/2015 NOTE: TAGGED SAND PLUG at 6085 SLM, PLUG FROM 6085 TO 6551 SUM APERF; 6,020.04,030.0 FRAC; 6,020.0 I APERF; 6,140.04.160.0 FRAC; 6,140.0 (PERF. 6.560.06.560.0 FRAC: 6,560.0 I LINER; 5,646.14,834.0 Hydraulic Fracturing Fluid Product Component Information Disclosure Well Name and Phillips n 2N-327 2N-327 _ . 6510 West Sam Houston Parkway North 6510 WestPnoTectmiS m Hou 50-103-20548 Houston, Texas 77041 Ax _ Phone: 713-328-2320 North Slope Fax: 713-32&2163 Maximum Ingredient Maximum Ingredient www.corelab.com r� QSIMI1 CTTR@AT10 Hydraulic Fracturing Fluid Maximum Ingredient Maximum Ingredient Chemical Abstract Ingredient Mass of Product Supplier Purpose Ingredients Service Number (CAS Concentration in Concentration in HF Comments Volume Additive S.G Component Additive Fluid Information p) % b mass)** ( y ) (% by mass)** Pumped Pumped Disclosure Chemical Frac Tracer ProTechnics Diagnostics Sodium Salt Proprietary 10.00% 0.000 gal 0.000 lb 1.50000 Water 7732-18-5 91.00% 0.000 gal 0.000 Ib 1.00000 ZeroWashs Tracer ProTechnics Diagnostics Ceramic Pro ant proprietary 14.00% 0.020 gal 0.423 lb 2.60000 Water (major) 7732-18-5 70.00% 0.227 gal 1.895 lb 1 Methanol major 67-56-1 30.00% 0.123 gal 0,810 lb O.7gT8- Dipropylene glycol meth I ether minor 34590-94-8 1.00% 0.003 gal 0.027 Ib 0.948 Xanthan gum (minor) 11138-66-2 1.00% 0.004 gal 0.027 lb 0.8524 Oil Frac Tracer ProTechnics Diagnostics Proprietary Proprietary 25-100% 0.000 gal 0.000 Ib 1.70000 Proprietary Proprietary 0-75% 0.000 gal 0.000 Ib 0.88 Gas Frac Tracer ProTechnics Diagnostics 1 Proprietary I Proprietary 1 100.00% 0.000 gal 0.000 Ib 1.70000 i Hydraulic Fracturing Fluid Product Component Information Disclosurex�sp Job Start Date: 1/5/201 Job End Date: 1/5/201 State: Alaska County: Harrison Ba API Number: 50-103-20548-00-0 Operator Name: ConocoPhillips Company/Burlington Resource Well Name and Number: 2N-32 Longitude: -150.3190340 Latitude: 70.1700020 Datum: NAD8 Federal/Tribal Well: N True Vertical Depth: 6,19 Total Base Water Volume (gal):1 95,31 Total Base Non Water Volume: Hydraulic Fracturing Fluid Composition: F -i Chemical Disclosure Registry dtt,CtzCtrt CO'v'xCti ^ Oil&Gas is 4 Maximum Maximum Chemical Ingredient Ingredient Abstract Service Trade Name Supplier Purpose Ingredients oncentration in oncentration in Comments Number Additive HF Fluid (CAS #) (% by mass)** (% by mass)** F127ST:WF127 Schlumberger7dditive, am Agent, ctant , Breaker, linker, Gelling , Scale Inhibitor, Bactericide, Propping Agent ater (Including Mix Water A 75.2589 Supplied by Client eramic materials and wares, 6402-68-4 97.51929 24.12731 hemicals uar gum 000-30-0 0.95361 0.2359 1, 2, 3 - Propanetriol 6-81-5 0.37440 0.0926 Diammonium peroxodisulphate 727-54-0 0.32588 0.0806 Sodium tetraborate decahydrate 1303-96-4 0.22464 0.0555 Ethylene glycol 107-21-1 0.14374 0.0355 Propenoic acid, polymer with 129898-01-7 0.13445 0.0332 odium phosphinate Vinylidene 5038-72-6 0.07065 0.0174 hloride/methylacrylate 0 of mer ropan-2-ol 7-63-0 10.05203 0.0128 butoxyethanol 111-76-2 10.05201 0.0128 is 4 Sodium chloride 647-14-5 0.0271 0.0067 inear C11 alcohol ethoxylate 7eo 4398-01-1(7EO) 0.02601 0.0064 12-15 alcohol ethyoxylated 8131-39-5 0.02601 0.0064 inear C11 alcohol ethoxylate 3eo 4398-01-1(3EO) 0.02601 0.0064 ALCIUM CHLORIDE 10043-52-4 0.0137 0.0033 Sodium hydroxide (impurity) 1310-73-2 0.0133 0.0033 Diatomaceous earth, calcined 1053-39-3 0.0059 0.0014 on-crystalline silica (impurity) 631-86-9 0.0023 0.0005 Magnesium silicate hydrate (talc) 14807-96-6 0.0021 E 0.0005 2"-oxydiethanol (impurity) 111-46-6 0.0014 0.0003 Magnesium nitrate 10377-60-3 0.0011 0.0002 oly(tetrafluoroethylene) 002-84-0 0.00091, 0.0002 chloro-2-methyl-2h- sothiazolol-3-one 6172-55-4 0.0006z 0.0001 Magnesium chloride 786-30-3 0.0005 0.0001 Dimethyl siloxanes and silicones 3148-62-9 0.00050 0.0001 otassium chloride (impurity) 447-40-7 0.00044 0.00011 iloxanes and Silicones, di-Me, eaction products with silica 7762-90-7 0.00032 0.0000 methyl-2h-isothiazol-3-one 682-20-4 0.00019 0.0000 ristobalite 14464-46-1 0.00012 0.0000 rystalline silica 14808-60-7 0.00012 0.0000 Sorbitan stearate 1338-41-6 0.00006 0.0000 -Propenoic acid, 2-ethylhexyl ster, polymer with 2- drox eth 12- ro enoate 6089-45-9 0.00003 0.00001 atty acids, C18-unsatd., mers, ethoxylated ro ox fated 8308-89-4 0.00003 0.00001 iloxanes and Silicones, di-Me, -hydroxypropyl Me, ethoxylated ro ox fated 8937-55-3 0.00003 0.00001 odium carboxymethylcellulose 004-32-4 0.00001 orbitan monooleate, thox lated 005-65-6 0.00001 odium nitrite 632-00-0 0.00001 1,2-benzisothiazolin-3-one 634-33-5 um, xanthan 11138-66-2 0.00001 etrahydro-3,5-dimethyl-1,3,5- hiadiazine-2-thione 33-74-4 0.00001 * Total Water Volume sources may include fresh water, produced water, and/or recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 4 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. < C Q 7 - 0.6 9 Well History File Identifier Organizing (done) RESCAN V/Color Items: ❑ Greyscale Items: ❑ Poor Quality Originals: ❑ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: Maria Production Scanning �.wo.ded iiumimiuuu 7Dis ALDATA kettes, No. ' ❑ Other, No/Type: Date: Date_ q1_9 RescanNeeded III IIIIIIIIIIIIIII OVERSIZED (Scannable) ❑ Maps: ❑ Other Items Scannable by a Large Scanner OVERSIZED (Non -Scannable) ❑ Logs of various kinds: ❑ Other:: ., v�P iiiiumimiuu� I]_ x 30 = 33 + L17_ = TOTAL PAGES—za_4' (Count does not include cover sheet) Date: �° , /s/ III II�IIIIIIII IIIII Stage 1 Page Count from Scanned File: J w (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: include NO BY: Maria Date: �.a 4/ff/01 /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ III IIIII Scanning is complete at this point unless rescanning is required. III II III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II'II) III II'I II 10/6/2005 Well History File Cover Page.doc OF T THE STATE Alaska 1041 an' Ga& ,.- A, i GOVERNOR SEAN PARNELL Justin Brady Graduate Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-327 Sundry Number: 314-590 Dear Mr. Brady: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 44��� Daniel T. Seamount, Jr. Commissioner DATED this _ day of November, 2014. Encl. SW Nov 13 2014 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 031-A APPLICATION FOR SUNDRY APPROVALS ti 20 AAC 25.280 NOV 04 2014 1. Type of Request: Abandon F Rug for Redrill Perforate New Pool Repair w ell r° Change Appr v 1 Suspend Rug PerforationsPerforate• Pull Tubing r7, Time Extension r Operational Shutdow n Re-enter Susp. Well Stimulate rv– , Alter casing I— Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory" Development W, Stratigraphic � Service 207-069, 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20548-00 7. If perforating, .21.t9 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO y30A Will planned perforations require spacing exception? Yes No f7o, ML,_ 2N-327 . 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 375074 Kuparuk River Field /Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6836 - 6195 � 6740' 6100' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 146' 146' SURFACE 2568 9.625 2599' 2385' INTERMEDIATE 5826 7 5855' 5223' LINER 1188 4.5 6834' 6193' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6140'-6160', 6560'-6580' 5505'-5525', 5921'-5941' 3.5 L-80 1 5695 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKERC-2 ZXP LINER TOP PACKER MD= 5646 TVD=5020 , NIPPLE - CAMCO DS NIPPLE w/ 2.875 PROFILE MD= 491 TVD= 490 . 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r- BOP Sketch F Exploratory Stratigraphic [ Development , Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/22/2014 Oil W - Gas WDSPL F Suspended VVINJ r- GINJ WAG F Abandoned 16. Verbal Approval: Date: Commission Representative: GSTOR r SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Justin Brady @ 265-6029 Email: Justin. B. Brady(a)conocophillips.com Printed Name Justin Brady Title: Graduate Engineer Signature u Phone: 265-6029 Date Commission Use Only Sundry Number: c� " l G Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r— BOP//Test Mechanical Integrity Test [— Location Clearance Other: POST' InCOrM0.-i�0ll +o+he ",oj4v. Tr0.cfac s. or chemt cot dts �cos��e rear, sfl� . v Spacing Exception Required? Yes ❑ No E Subsequent Form Required: 10— 404 APPROVED BY p 1 `� Approved by: COMMISSIONER THE COMMISSION Date: �� Hpprcye�c�e�Qjl lgn� y� yp 1L fn0-118 11 In U c uacc orm 10-403 (R vised 10/2012) U K I N Lj 5 t aNlrr Uvar. Submit Form and Attachments in Duplicate IN A ../,/_ . ARr Ali Nnv -7 29 KUP PROD 2N-327 ConocoPhillips Well A aAaac Arigie,8 , `,` Alaska Inc.Wellbore API/UWI Field Name Wellbore Status Ind 501032054800 TARN PARTICIPATING AREA PROD C) MD (ftKB) Act at. (ftKB) 32.88 1,971.52 6,836.0 Comment H2S (ppm) I Date SSSV: NIPPLE I Annotation End Date Last WO: KB-G!d (ft) Rig Release Date 34.69 8/142007 2N-327, 5/24/20142:57:22 PM (: enc. a,atw(actual) AnnotationDepth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 6,554.0 62/2013 Rev Reason: Mandrel Orientations lehallf 5252014 Casing Description OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WULen (I... Grade Top Thread CONDUCTOR 16 15.250 31.0 146.0 146.0 65.00 HAO WELDED HANGER; 260- Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... Wt/Len (I... Grade Top Thread SURFACE 95/8 8.835 31.0 2,598.7 2,385.4 40.00 L-80 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... Wt/Len (1... Grade Top Thread INTERMEDIATE 7 6.276 28.3 5,854.5 5,223.0 26.00 L-80 BTCM i' Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread LINER 412 3.958 5,646.1 6,834.0 6,193.4 12.60 L-80 IBTM Nominal ID Top (ftKB) Top (ND) (ftKB) Top 1-1 (°) Item Des Com (in) 5,646.1 5,020.1 16.11 PACKER Baker C-2 ZXP Liner Top Packer, Size 5" x 7". 11.40' 4.410 L x 5.25" ID Tie Back Stem at top 5,663.9 5,037.2 15.49 HANGER Baker Flex -Lock Liner Hanger, Size 5" x 7" 4.410 5,673.7 5,046.6 15.20 SBE Seal Bore Ext, Size 80-00, 5" BTC Box X Pin 5" OD, 4.000 CONDUCTOR; 31.0-146.0��,�y 4.00" ID Seal Bore 11 NIPPLE; 490.6 Tubing Description String Ma... ID (in) Top (ftKB) Set Depth trt Set Depth I, (... Wt (Iblft) Grade Top Connection TUBING 312 2.992 26.0 5,694.7 5,066.9 9.30 LA0 ABM-EUE CtlMnpi@tiort Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (') Item Des Com (in) 26.0 26.0 0.00 HANGER FMC TUBING HANGER 2.992 490.6 490.3 5.56 NIPPLE CAMCO DS NIPPLE w/ 2.875 PROFILE 2.875 SURFACE; 310-2,5987- 5,544.5 4,923.6 20.11 SLEEVE -C CMU SLIDING SLEEVE w/ 2.812" DS PROFILE (Closed) 2.812 5,617.4 4,992.6 17.29 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT; 2,659.6 5,656.0 5,029.6 15.73 LOCATOR Baker Locator Sub / NoGo, 5.00" OD Loc, 3.00" ID) 3.000 5,679.91 5,052.71 15.02 1 LOCATOR LOCATOR 3.000 GAS LIFT; 3,775.2 5,691.4 5,063.8 14.67 SEAL ASSY I BAKER 80-40 BONDED SEAL ASSEMBLY 3.000 Perforations 4,'Sloft W, Shot GAS LIFT; 4,734.4 Dens Top (TVD) at. (TVD) (shotslf Top (ftKB) at. (ftKB) (ftKB) (ftKB) Zone Date Q Type Com CHEMICAL; 5,380.4 6,140.0 6,160.0 5,505.0 5,524.8 BERMUDA, 2N-327 127302007 6.0 APERF 2.5" HS-HSD Bermuda Sand 6,560.0 6,580.0 5,921.3 5,941.2 ESKER, 2N- 327 10/242007 6.0 IPERF 2.5" HJ 2506 ESKER Sand GAS LIFT; 5,462.5 Stimulations & Treairnents Min To Max at. Depth (ftKB) Depth Top (TVD) Btm (TVD) (ftKB) (ftKB) (ftKB) Type Date Com SLEEVE -C; 5,544.5 6,560.0 6,580.0 5,921.3 5,941.2 FRAC 10/262007 ESKER SAND FRAC 298900# CARBOLITE w/12 ppa ON FORMATION 6,140.0 6,160.0 5,505.0 5,524.8 FRAC 1/31/2008 BERMUDASAND FRAC-PLACED 288,221# OF 1620 CARBOLITE BEHIND PIPE NIPPLE; 5,617.4 Mandrel Inserts at at! on Top (TVD) alve Latch Port Size TRO Run N Top (ftKB) (ftKB) Make Model OD (in) Sam ype Type (in) (psi) Run Date Com LOCATOR;5656.0 jDMY 2,659.6 2,437.0 CAMCO KBMG 1 GAS LIFT BK -5 0.000 0.0 8/13/2007 6:30 2 3,775.2 3,393.9 CAMCO KBMG 1 GAS LIFT Y BK -5 0.000 0.0 8/1320074:00 3 4,734.4 4,214.9 CAMCO KBMG 1 GAS LIFT Y BK -5 0.000 0.0 8/13/2007 2:00 4 5,380.4 4,772.0 CAMCO LTS- 1 CHEM DMY BK -5 0.000 0.0 8773/2007 INJ CIM 9:30 5 5,462.5 4,847.2 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 6/14/2008 1:30 LOCATOR; 5,679.9 !/lots$''. safety End Date Annotation 8/12/2008 NOTE: View Schematic w/ Alaska SchematiC9.0 SEAL ASSY; 5,691.4 INTERMEDIATE; 28.35,854.5- APERF; 6,140.0-6,1600 FRAC; 6,1402 I IPERF; 6,560.0-6,560 0 FRAC; 6,550.0 I LINER; 5,646.1-6,834.0 2N-327 Sundry Application TARN Bermuda Frac PTD #: 207-069 In October of 2007, TARN producer 2N-327 was completed with 4.5" liner across the Bermuda and Esker sands. After completion, the Purple and the Esker sands were perforated and fractured. The plan forward is to frac the Bermuda sand above the Purple and Esker sands without creating communication to the Bermuda directly below. A sand plug will be used to isolate the perforated Purple and Esker intervals. Proposed Procedure: Schlumberger Pumping Services: (Tarn Bermuda -sand Perf and Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre-existing conditions. 40sr— 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. `.PIT 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 1,116 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 5,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the Frac job by following schedule @ 20 bpm with a maximum expected treating pressure of 4,000 psi.M • 440 bbls Schlumberger fluid Pad • 160 bbls Schlumberger fluid w/ 1 ppa • 160 bbl Schlumberger fluid w/ 2 ppa • 170 bbls Schlumberger fluid w/ 3 ppa • 180 bbls Schlumberger fluid w/ 4 ppa • 180 bbls Schlumberger fluid w/ 5 ppa • 200 bbls Schlumberger fluid w/ 6 ppa • 240 bbls Schlumberger fluid w/ 7 ppa • 250 bbls Schlumberger fluid w/ 8 ppa • Flush with 52 bbls of linear fluid and 18 bbls of freeze protect • Total Sand: Approx. 253,000 lbs of 16/20 CarboLite 10. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. BE 11. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). Cement Evaluation of 2N-327 and wells within'/4 mile of 2N-327 2N-327: 4 1/2" liner cement job was pumped on 8/11/2007 as designed, indicating competent cement operations. The cement was displaced with 77bbls. The plug was bumped and the liner hanger was set. The packer was set and pressure tested to 2000lbs. A CBL run on 10/13/2007 confirms competent cementation around the liner. 2N-342: 7" casing cement job was pumped on 7/7/2007 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement and the floats held. Summary Based on an engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. oo 2N-327 Schematic: KUP PROD 2N-327 C Or10t ;Ptglhps IMeMAttrlbWes Ma% Anle & Mo ^. SQ at.M12?MTiCIOKTIV.iAAEk - PRw0 ! 'i a;63G0 kl+eA Colima Strwas wwc _ p4t .. 9P r L`:Y10GtTCR�- ^"'�' ,". •—� XOE ;ssta moat fall 1, 14W" i—1 "'. 5.2?3: .s7G L RFt �'�:• HTG! -€i,�: L40 Liner Oetails': r:c:nKe•. Tubing St1191Q5 , pct a:L - *--c== • 3 }.1 :E4 n .JEu.G 2i.= 35?17 cornpletion oema.... r TLL mae; raa marmKm 109ea11awaCi+ r cs* 000 +±X,15 -t- a9:.4 4iG5 ss@'a°.Lo,E "- ,.SEnl.r . -. !perforations& slots a.» 104'S41N8) 8M mK81 RK6 RfrtRB; 2Me4 aM � #1 TY" 8:9;s. 5 •b:. S,sD30 L.s2(.$. '..P3uk. 'ii?i3'c"fa d Cv A z4as sMe,9 ;, S W S.._' Stimulations &.Treatmems j.5, raorm sj"15,a mal#sacat mase,■e# s, r,9i o-ra e� '.3 h7.,, ?L�`xn JiiZ. p Mandrel Inserts vvrti�.f:ffi!.a 2 JN Tena, TMW 1ffiM PL1m) 4.. M TLLit1884 �RN81 Mato MaLY ODiMI 4n T T- YMI Sfax ft.c- Co. �Zwql Z010 0{,,, F,E"Cy., W:tF:. .tlYek3 ork ao S7S :':37 S. _'J+'•.x 9st.; 3,fl 2 am*, CA....,, _'3 S C,tSvr CR4,d En» A.XI: -_Yi:T ao-p.... ,4 S -;,a _� Emr *. 'viS .'FT 0t4'•r eh -s 0-X S I2 r" zoo 4 i 4, :A ._ -,fe" 0141 SK4. r.'= f i .117 144 4.3] S. Motes: General & Safety ..,sr.., Te.�xcr.. �_ Z199i 44�4� is+t. L4'1> ,f[0.,[�A4MLL :Wat tk9t.•4:psL Stimulation Surface Rig -Up: glum t Tattin Tale Tank Nsrtl1 diJtld POP-Qff Tank �N �Z} f7 NQ' m cp. F- J m o. c m adz c� y • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. P,30 Off Tank ri wip Trek Stimulation Tree Saver OPEN POSITION CLOSED POSITION JPRIOR TO M&NDREL INSERTION} (MANDREL INSERTED) FRAC IRON /CONNECTION MOTE ECRATED MAMR VALVE f i O a MANUAL OPERATED 6 1 MASTER VALVE Stinger Stinger www r '! F VENT .0 VALVE OPEN FLOW TEE AND VENT VALVE WELLHEAD VALVES CLOSEDjN TLJBIPNG WELLHEAD VALVES OPEN a r is OUAD PACKOFf ASSEMBLY IN PLACE IN TUBING u • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 I/z tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm Iffl.- 00W.=1M, 210.146 1 %IPPUI.410, V.OVA�W V C -2s" W LOT, 14" 4M 4WI' , CAU, .51 IS&AZZY 1-0, 11-ITSI"IZ 41-- :S-H�m APW 4,!40,0414C POACAAAC MVV SlAr clessc vk,kc c "t --y-- 1-- �.- Casing SStrings caemg, Dabialptlon OD C OND U -- TOR (In I 1s Z fin) 15250 11 3*DWJijftKff-t 3017 V44AM f L., O(M Casing O"WIft" 00 SURFkOE fial 9Ss8 fbj 8.835 a TOpjftK) *Do Graft Top, T IN7E'P.f,IEI)!A:7E W4-141 U471ft Top - 3 Casing WOPT#-- fin) Topiffiffl— 1*5WIFIRY-.51 LIBER 3,9581 5,S4S.11 8,SS4,0 Liner Detail T:r 'TtKal TOpjTA)jjTtKOj TOPInVi'l ltwr. Bas za, HANGER 4,470 t:- n!'7 Tubing Strings Peep. to ift --- w L4 -, t2 J,n 1 TUBING Details Top JIM31 T*j:jTMjjftK5j TOrmvill itvrl D" "inj _Zi HANGER TJi. SK N I V:; -E S IOXI Perforations & Slots S!t at ulna "15 Top ftK8 Stn 4Ttn%JT Too iftK81Aij 13JIM9 IVD1 Zane �Ytq t I a I tj V 611140.0 S,16 :- 5'5mo 5,524;B BERMUDA- '2111.,52:.,-.17 15,11 AP=-FZr 7 S'O ,M,O 6=,O 5,7Z3 x+.94',2 ESKEP-2N- 32", Stimulations & Treatments min Top Max stfr, Diopm DOP-th ittKel JTIKSJ Topiritil Ift ittKill jTvDj JiUal Date YACAA FRA- v'26= E! Si -N D PAC 1 BaK TIEyr 12 =4� 7 "'Q 14ATJ�N 777 77 OWOR Iwo FRAC =-=RIA0nA$*1fAC Mandrel Inserts att N TopiTtIC01 T-^; i T"D I I ;TWSI Vstog Lattft Pvt Ws TRO Run Max* mmsl OD,111 swv TNT,# Ty" 13111 IRO91 Run Date Cc -T 2,659's 2,4137v CA'AC J,� I GAsL(F7 WAY EK -5 MD 0,0 8.''a'. "'or S 'K GAS LIFT OtAY SX -5 0-114C aAS LIFT OMY SK -5 0,1D vw-!�M7 V 20D 7 INJ JGASLIF- JOV '.2K Notes: General& Safety 04t 2-332 2N-320 «®�r ............. «�,yl =329,.. CPAI* CPA[ A= . ;SQA& » ., 580053 ... 134 .. CPAI.....>».»»..,..axe. ®:a G .x p.sir+.< CPAI 5075 . 2N.§N.. � <gW �4 A�«.°.« ....SL37« » , ,,,,' RDL390982 st oil F 2N-327 214 «?�I Irl owl' 2N -337A,= . 2 7 2N- 42 709148 517 CPAI ADL390984 Legend Ej 1/4 Mile Radius PERF_ STATUS,PERF_EVENT 9IE IPERF SIE APERF Well Type • Producer * MWAG + P+A CPAI Operated Units LEASE OPERATOR and NUMBER 070&148 CPAI Conor ?Phillips Alaska, Inc. 2N-327 1/4 Mile Radius CPAI N ADL390983 i f- i Ex 0 0.25 0.5 Miles Tam2L-3148ase.mxd CSR 5-20-2014 2N-327 Frac Model Frac Design 1 stage Job Description Step Name Pump Rate (bbl/mi n) Fluid Name Step Fluid Volume (gal) Gel Conc. (Ib/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Pad 20 YF127ST 440 25.0 0.00 1.0 PPA 20 YF127ST 160 25.0 CarboLite 16/20 1.00 2.0 PPA 20 YF127ST 160 25.0 CarboLite 16/20 2.00 3.0 PPA 20 YF127ST 170 25.0 CarboLite 16/20 3.00 4.0 PPA 20 YF127ST 180 25.0 CarboLite 16/20 4.00 5.0 PPA 20 YF127ST 180 25.0 CarboLite 16/20 5.00 6.0 PPA 20 YF127ST 200 25.0 CarboLite 16/20 6.00 7.0 PPA 20 YF127ST 240 25.0 CarboLite 16/20 7.00 8.0 PPA 20 YF127ST 250 25.0 CarboLite 16/20 8.00 Flush 20 WF127/FreezeProtect 49 25.0 0.00 YF127ST WF127 Freeze Protect CarboLite 16/20 Totals (1stages) 1,980 bbis 31 bbis 18 bbis 253,000 I bs 40 Model Results Initial Fracture Top TVD Initial Fracture Bottom TVD Propped Fracture Half -Length EOJ Hyd Height at Well Average Propped Width 5,376 ft 5,430 ft 209 ft 261 ft 0.309 in Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 0 2 2014 RE: Multi Finger Caliper (MFC): 2N-327 AOGCC Run Date: 4/20/2014 DATA LOGGED ro/3 /2014 M K BENDER May 20, 2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 2N-327 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20548-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: SCANNED OCT 31 2014 Signed: � i. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc r 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501, RE: Production Profile: 2N-327 Run Date: 12/9/2009 January 27, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N-327 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20548-00 Production Profile Log 1 Color Log 50-103-20548-00 Production Array Log (CAT -RAT) 1 Color Log 50-103-20548-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barretQ@halliburton.com Date: ,go --� , &'_0 � � �3o1 Signed: ConocoPhillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01808 TO: Howard Okland ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: KRU 2N-327 DATE: 9/23/2009 Kuparuk River Unit, North Slope, Alaska 2N-327 (Core analysis requested via e-mail* Dean Stark Routine Core Analysis, 2N-327; .las file and .xls spreadsheet Lisa Wright_E �- N 0 V '�- ti 20CS Please sign, scan and return transmittal via e-mail promptly CC: Lisa Wright, CPA[ Geologist Well transmittal folder Receipt: �e±..� �V��JI� Date: ;;L:N GT5-7"echnical Data Management I ConocoPhilliPs I Anchorage, Alaska 1 Ph: 907265-6947 Sandra. D. L emke(&ConocophA1ips, com x Fmrn- Gkl nd, Sow_irdD; A)(rn�€ls r; ho a€d,a�' rd aias a, a] Sent Wednesday, Septembe 16, 2M 1-:00 AM To: Lem .e, Se &a D SuLiect KWJ Twin 2W327 sw,y to Ca ijr, yo€: zgalr. VV '¢±yas 3 Conamtona€ core:-11aly Wne or he rsF.0 Tam 2N 2. ;-`3-1t3-M54I- orr was yore. wedo ncl live a copy. TNX 0ward DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070690 Well Name/No. KUPARUK RIV U TARN 2N-327 Operator CONOCOPHILLIPS ALASKA INC MD 6836 TVD 6195 Completion Date 8/14/2007 Completion Status 1 -OIL Current Status 1 -OIL REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR?Res?Dens?Neutron, FMI, Dipole Shear Sonic, CBL Well Log Information: Log/ Electr Data Digital Dataset Log Log Run API No. 50-103-20548-00-00 UIC N Directional Survey ( Yes (data taken from Logs Portion of Master Well Data Maint Interval OHI Type Med/Frmt Numoer Name scaie Meala No start stop kIn Kecervea Lomments og Sonic 5 Col 1 5800 6833 Case 8/27/2007 Sonic Scanner FMI, 8 -Aug - 2007 14D D Asc Directional Survey 0 6836 Open 9/12/2007 et/og Sonic 5 Col 1 5800 6833 Case 8/27/2007 Sonic Scanner FMI, 8 -Aug - 2007 pt 15504 LIS Verification 204 6720 Open 10/3/2007 LIS Veri, ROP, GR, RPD, FET, NPHI, FCNT, NCNT, ' � RHOB,DRHO D C Lis 15504 I" nduction/Resistivity 204 6720 Open 10/3/2007 LIS Vert, ROP, GR, RPD, FET, NPHI, FCNT, NCNT, RHOB, DRHO w/Graphics DC 15536 See Notes 0 0 Open 10/12/2007 Multi Graphics in PDF and EMF - BAT, EWR, POR Rpt 15566 Report: Final Well R 0 0 Open 10/23/2007 Final Well Report Table of Contect, Equip and Crew, Well Details, Geo Data, Drilling Data, Pres/Form Strength Data, Daily Report w/ LAS, PDF, DML graphics o'Log 15566 See Notes 2 Col 80 6836 Open 10/23/2007 MD Formation Log Log 15566 See Notes 2 Col 80 6836 Open 10/23/2007 TVD Formation Log og 15566 See Notes 2 Col 80 6836 Open 10/23/2007 MD Combo Log og 15566 See Notes 2 Col 80 6836 Open 10/23/2007 TVD Combo Log DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070690 Well Name/No. KUPARUK RIV U TARN 2N-327 Operator CONOCOPHILLIPS ALASKA INC MD 6836 TVD 6195 Completion Date 8/14/2007 Completion Status 1 -OIL Current Status 1 -OIL API No. 50-103-20548-00-00 UIC N og 15566 See Notes 2 Col 80 6836 Open 10/23/2007 MD Gas Ratio Log 15566 See Notes 2 Col 80 6836 Open 10/23/2007 TVD Gas Ratio og 15566 See Notes 2 Col 80 6836 Open 10/23/2007 MD Drilling Dynamics Log 15566 See Notes 2 Col 80 6836 Open 10/23/2007 TVD Drilling Dynamics og Cement Evaluation 5 Col 1 5400 6687 Case 10/26/2007 SCMT, 2.5" HJ2506 Gun 23 -Oct -2007 og Perforation 2 Blu 1 5450 6680 Case 10/26/2007 Perf Record 2.5" HJ2506 Gun 24 -Oct -2007 og e 5 Blu 6200 6650 Open 12/21/2007 Oilphase Sampler 4-600 YeDOrt.: CC 15 -Dec -2007 'ED C 15566 Final Well R 0 0 Open 10/23/2007 Final Well Report Table of Contect, Equip and Crew, Well Details, Geo Data, Drilling Data, Pres/Form Strength Data, Daily Report w/ LAS, PDF, DML graphics og Sonic 5 Col 1 5800 6833 Case 1/22/2008 Sonic Scanner Form Micro Imager 8 -Aug -2007 ED C Lis 15888tormation Micro Ima 5707 6859 Open 1/22/2008 LIS Veri, GR, FMI, ix*og Production 5 Blu 100 6569 Case 3/13/2008 PPL, Pres, Temp, Gradio, Spin, Deft 8 -Mar -2008 og Production 5 Blu 6050 6440 Case 7/1/2008 PPL, Pres, Temp, Gradio, Spin, Deft 17 -Jun -2008 D C Pds 16548` Production 6050 6440 Case 7/1/2008 PPL, Pres, Temp, Gradio, Spin, Deft 17 -Jun -2008 03 416rx D C 16653 "See Notes Open 7/28/2008 Core Lab tosst+ag.� photos in JPG Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Core Chips 0 0 — DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070690 Well Name/No. KUPARUK RIV U TARN 2N-327 Operator CONOCOPHILLIPS ALASKA INC MD 6836 TVD 6195 Completion Date 8/14/2007 ADDITIONAL INFORMATION Well Cored? (y / N Cord-O.Lt"VA ;n , R� V,vd- Chips Received? Y / N Analysis Y / N Received? Comments: Completion Status 1 -OIL Current Status 1 -OIL Daily History Received? O% / N Formation Tops & N API No. 50-103-20548-00-00 UIC N Compliance Reviewed By: Date: �0 �_11�Cl 0 Conoc��ilfips TRANSMITTAL Kupaizlk River Unit Tarn development well data FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7m Ave, Suite 100 RE: KRU 2N-327 Anchorage, Alaska 99501-3539 Permit: 207-069 DATE: 07/22/2008 North Slope, Alaska Kuparuk River Unit 2N-327 I am Field Permit 207-069 CDROM digital images Core Labs Color Core Photos, 2N-327 Tarn South Field; Overview and half -scale format; Cores 1-9, December 18, 2007; Report HOU-070660. CC: Derik K*acel er, CPA[ Geolooist Receipt.-,, Date: j Ai?r a, Sandra,®,com schlumbeppit Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4759 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/25/08 IG -14 r 1 � If P [d e NO. 4759 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/25/08 IG -14 11964620 INJECTION PROFILEr,: -- -j f 06/13/08 1 1 3A-16 11964621 LDL -' t ,` 06/14/08 1 1 113-14 12061702 LDL a/EY 06/15/08 1 1 214-327 12061704 PRODUCTION PROFILE Yd' -1 {/ .r - 06/17/08 1 1 1B-04 12061705 INJECTION PROFILE ,^ �:_-. : '" /rt`r._ ` ' - 06/18/08 1 1 213-05 11964625 INJECTION PROFILE/LDL �-_ - -.- ra''L 06/18/08 1 1 1E-12 11964628 GLS 06/20/08 1 1 3A-06 12061708 INJECTION PROFILE (y'' -O_ `,5 -,,: 2 i �� r•> 06/21/08 1 1 2A-08 1L-11 11964629 11964630 INJECTION PROFILE d,l: C-, PRODUCTION PROFILE 06/21/08 06/23/08 1 f 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 6 IV 0 s plumb ge Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: BethIL----- r 4 � NO. 4624 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/12/08 IA -12 1E-1128 SAND LATERAL 11964583 11978443 LDL V -re_ MEM INJECTION PROFILE 02/28/08 03/03/08 1 1 1 R-04 11964585 USIT Z j- — 03/02/08 1 21--330 11837544 OH EDIT (SONIC SCANNER) ' }- 11/27/07 1 1 31-01 11994626 LDL 03/06/08 1 2N-327 11994628 PRODUCTION PROFILE 03/08/08 1 1Y-28 11994629 PRODUCTION PROFILE 03/10/08 1 3S -08C 40016310 OH MWD EDIT VISION SERVICE 01/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RECEIVED STATE OF ALASKA • FEB 2 0 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION3ska Oil & Gas Com CommissiOs 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑Q Other Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown[:] Perforate Q Re-enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCoPhilllps Alaska, Inc. Development El Stratigraphic ❑ Exploratory ❑ Service ❑ 207-069 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20548-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 26', AMSL 149' 2N-327 ° 8. Property Designation: 10. Field/Pool(s): ADL 375074 Kuparuk River Field / Tarn Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 6836' feet true vertical 6195' feet Plugs (measured) Effective Depth measured 6702' feet Junk (measured) true vertical 6062' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 84' 16" 110' 110' SURFACE 2573' 9-5/8" 2599' 2386' PRODUCTION 5829' 7" 5855' 5155' LINER 1188' 4-1/2" 6834' 6193' Perforation depth: Measured depth: 6140'-6160', 6560'-6580' true vertical depth: 5505'-5525', 5921'-5941' Tubing (size, grade, and measured depth) 3-1/2", L-80, 5694' MD. Packers & SSSV (type & measured depth) C-2 ZXP liner pkr Gm 5646' Camco'DS' nipple @ 490' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6140'-6160' Treatment descriptions including volumes used and final pressure: 306739# of 16/20 carbolate 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casinq Pressure I Tubina Pressure Prior to well operation 247 1571 428 -- 253 Subsequent to operation 736 1176 447 -- 362 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development Service ❑ 16. Well Status after work: Daily Report of Well Operations _X Oil❑✓ Gas ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Schwartz/ Signature 5 itle Phone Wells Engineer Date C::,?— 115—'0 g Prepared Sharon Allsu -Drak 263-4612 rZ1. { EH 2906 Form 10-404 Revised 04/2 06 a1 Submit Original Only ,40—r �/�� • 2N-327 Well Summary • DATE Summary 11/22/07 TAG AT 6702' SLM W/ 10'x 2 1/8" DRIFT AND 2.72" SWAGE. JOB COMPLETE. 11/29/07 SET DHSIT @ 5617' RKB, ( CLOSE 12/6/07 @ 12:35PM, OPENS 12/9/07 @ 12:35PM) W/ QUARTZ GAUGES, ( NEEDS 23" TO KNOCK KOBE OFF, NOT TO EXCEED 25", RDMO. 12/10/07 CLEANED UP HYDRATES @ 1120' SLM. PULLED EST & GAUGES @ 5617' RKB. COMPLETE. 12/14/07 GAUGED TBG TO 2.50". TAGGED @ 6709' RKB. READY FOR E/L SAMPLING. 12/15/07 OILPHASE SAMPLING TOOL. WELL PLACED ON PRODUCTION AT 07:45. SAMPLES OBTAINED AT 6500'(2) AND 6485.5'(1). SECOND SET OF SAMPLES TAKEN AT 6500'(4) AND 6485.5' (3). FLOWING BOTTOM HOLE PRESSURE AT 6680' EQUALED 1150 PSI. DID NOT TAG TD. 12/25/07 SPOTTED SAND PLUG IN 4.5" LINER, UNCORRECTED SAND TOP AT 6365' CTMD, WELL LEFT SHUT IN AND LOADED WITH DIESEL, TOTAL OF 4000# 20-40 MESH SAND PUMPED, READY FOR SLICK LINE. 12/26/07 DRIFT TUBING W/ 20' OF 2.6" DMY GUN, TAG TOP OF SAND @ 6244' SLM. SET 2.75" CA -2 PLUG @ 5617' RKB. PULLED OV @ 5463' RKB. PUMPED 195 BLS DIESEL DOWN TUBING UP IA TO FLOWLINE. P/T IA 3500 PSI, GOOD. SET DV @ 5463' RKB. *****PLUG STILL IN HOLE***** LDFN. 12/27/07 PULL 2.75" PLUG @ 5601' SLM. JOB COMPLETE. 12/30/07 RUN 2.5" HYPERJET, 6 SPF, 60 DEG PHASING AND PERFORATE INTERVAL 6140 - 6160 FT ACROSS THE T1 SANDS. TAG PBTD AT 6268'. 1/5/08 SET CAT STANDING VALVE @ 5617' RKB. PULLED DGLV @ 5463' RKB AND SET HES) SPARTECK SPMG. MIT IA TO 3500 PSI (PASSED). PULLED CAT STANDING VALVE @ 5617' RKB. DRIFTED TBG. DOWN TO 50' SLM W/ 2.89 CENT., V STEM, AND 2.90 GAUGE RING. 1/29/08 SET CATCHER SUB @ 5617' RKB. PULLED, RE -PROGRAMMED, & RERUN SPARTEK SPG @ 5463' RKB. MIT IA 3500 PSI, PASSED. PULLED CATCHER. WELL READY FOR FRAC. 1/31/08 COMPLETED HYDRAULIC FRACTURE STIMULATION OF THE BERMUDA SAND. PUMPED A TOTAL OF 306,739# OF 16/20 CARBOLI PE, 90% OF DESIGN. SCREENED OUT WITH 100 BBLS OF 12 PPA ON FORMATION, 35 BBLS FROM FLUSH. PUMPED A TOTAL OF 3889 BBLS OF SW @ AN AVERAGE TREATING PRESSURE OF 3352 PSI. BRACKET FRAC WAS TRACED WITH ANTIMONY, 1 PPA THROUGH 9 PPA STAGES TRACED WITH IRIDIUM AND THE 10 PPA AND 12 PPA STAGES TRACED WITH SCANDIUM. LEFT 70% OF THE TREESAVER RUBBER IN HOLE. 2/1/08 Post Frac FCO down to 6270' CTMD. RIH 70ft/min pumping 2 BPM getting heavy Frac sand/Gel returns to surface, good 1:1 returns using SSW. Well started coming on strong after 5500' CTMD, WHP increased from 60 psi to 600 psi. Strong sand returns to surface down to 6270' CTMD (100' rathole). Spot/chase Gell pill while POOH slowly, switch to diesel, wash GLM. Returns had a light trace of sand while POOH with gas/diesel. Well Freeze protected. 2/2/08 TAGGED a 6075' RKB (BERMUDA: 6140-6160). SET CATCHER @ 5617' RKB. PULLED 1" SPG @ 5463' RKB, REPLACED WITH 5/16" OV (BRINGING BACK HYDRATES IN LUBRICATOR & STUFFING BOX). IN PROGRESS. 2/3/08 PULLED CATCHER SUB @ 5617' RKB. TAGGED @ 6058' SLM WITH PUMP BAILER. RECOVERED 1 GAL FINE FRAC SAND. COMPLETE. 0 0 KRU 2N-327 dz ConocoPhillips Alaska, Inc. Schlumbepgep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # yn Kp Y 1Jk. JAN , 1 20M Log Description Ai a NO. 4537 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 12/27/07 214-327 11837491 OH LDWG EDIT (SONIC SCANNER) f5 -b& 08/08/07 1 1 2N-310 11850433 OH LDWG EDIT (SONIC SCANNER) 09/16/07 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. schl mher er Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description 9 NO. 4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Date BL Kuparuk Color CD 12/20/07 1J-105 1A-06 1Q-05 11837540 11837542 11837537 INJECTION PROFILE ,'W4 -(j3':--_ RST WFL LDL C - ( 11/20107 11/22/07 11/17/07 1 1 1 113-12 11970607 INJECTION PROFILE J T 12/04/07 1 2N-327 11996582 OILPHASE SAMPLER Q-4- (a 12/15/07 1 1D-132 11994588 SBHP SURVEY Lyrd- 12/17/07 1 3H-1013 11996580 PATCH EVALUATION = 12/13/07 1 3N -02A 11970609 LDL 118-3- 12/05/07 1 1C-125 11964553 INJECTION PROFILE - Lqfl 12/01/07 1 2M-15 N/A PRODUCTION PROFILE tIq 1 " 12/10/07 1 2M-11 N/A PRODUCTION PROFILE 12/08/07 1 3A-0313 11970604 SCMT 1 12/01/07 1 2T -217A 11978431 SCMT - 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11/27/07 1 21--330 11837544 SONIC SCANNER 11/27/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 0 0 November 12, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2N-327 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2N-327. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad NOV 2 0 2001 ,Aloska Oil Q44 004,,trriaxg MMOCIVIIZU 01;00_4�110 STATE OF ALASKA NOV 2 U 2007 ALASKA OIL AND GAS CONSERVATION COMMISSI011aska LillCA h,� tt11T1jIaSioA WELL COMPLETION OR RECOMPLETION REPORT) aFeBd 1a. Well Status: Oil ❑✓ Gas LJ Plugged ❑ Abandoned 17 Suspended 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: 1b. Well Class: Development ❑✓ Exploratory ❑ Service ❑ StratigraphicTest ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., f orAband.: August 14, 2007 12. Permit to Drill Number: 207-069/ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 12, 2007 13. API Number: 50-103-20548-00 4a. Location of Well (Governmental Section): Surface: 82' FNL, 850' FEL, Sec. 3, T9N, R7E, UM Top of Productive Horizon: 2419' FNL, 1617' FEL, Sec. 3, T9N, R7E, UM Total Depth: 2517' FNL, 1688' FEL, Sec. 3, T9N, R7E, UM 7. Date TD Reached: August 7, 209;r" 14. Well Name and Number: 2N-327 ' 8. KB (ft above MSL): 26' RKB Ground (ft MSL): 149' AMSL 15. Field/Pool(s): Kuparuk River Field Tarn Oil Pool 9. Plug Back Depth (MD + TVD): 6740' MD / 6100' TVD 4b. Location of Well (State Base Plane Coordinates): Surface: x-460743 y- 5911926 ` Zone- 4 TPI: x-459967 y- 5909593 Zone -4 Total Depth: x- 459896 - 5909496 Zone -4 10. Total Depth (MD + TVD): 6836' MD / 6195' TVD 16. Property Designation: ADL 375074 11. SSSV Depth (MD + TVD): nipple @ 490' MD / 490' TVD 17. Land Use Permit: 4293 18. Directional Survey: Yes ❑✓ No ❑ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1150' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res/Dens/Neutron, FMI, Dipole Shear Sonic, CBL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM SETTING DEPTH TVD HOLE CEMENTING RECORD TOP BOTTOM SIZE AMOUNT PULLED 16" 164.9# X-42 31' 110' 31' 110' 24" 266 sx AS 1 9.625" 40# L-80 31' 2599' 31' 2386' 12.25" 495 sx AS Lite, 185 sx DeepCRETE 7" 26# L-80 31' 5855' 31' 5155' 8.75" 235 sx Class G 4.5" 12.6# L-80 5646' 6834' 5020' 6193' 6.125" 173 sx Class G 23. Open to production or injection? Yes Q No If Yes, list each Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): 6560'-6580' MD 5921'-5941' TVD 6 spf 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET 3.5" 5656' 5664' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6560'-6580' 298900# carbolite 26. PRODUCTION TEST Date First Production November 3, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 11/10/2007 Hours Tested 24 hours Production for Test Period --> OIL -BBL 130 GAS -MCF 1522 WATER -BBL 352 CHOKE SIZE not available GAS -OIL RATIO 11669 Flow Tubing press. 232 psi Casing Pressure 1058 Calculated 24 -Hour Rate -> OIL -BBL 150 GAS -MCF 1500 WATER -BBL 351 OIL GRAVITY - API(corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ✓ No ❑ Sidewall Cores Acquired? Yes U 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. GUMtPL'Hl('N Refer to attached summary ". fZ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE fM SMS SR j ,T� 0 2 ,vi`b !�' 12., (91,-? Ah r--1 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface ground surface Permafrost - Bottom 1154' 1150' needed, and submit detailed test information per 20 AAC 25.071. T-7 5438' 4825' T-5 5612' 4988' T-4.1 5729' 5100' T-3.1 5917' 5285' T-2 6067' 5433' T-1 6096' 5461' C-35 6239' 5603' K-3 6274' 5637' N/A Formation at total depth: T-3 30. LIST OF ATTACHMENTS Summary of Daily Operations, final directional survey, cement detail report, core descriptions, schematic 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name--> Ra Thomas Title: Drillino Team Leader t O Signature - Phone Date L%� AL3 Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10407 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 2/2007 KRU 2N-327 dL ConocoPhlilips Alaska, Inc. Halliburton Company DEFINITIVE Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/15/2007 Time: 15:38:15 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2N-327, True North Site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N-327: Actual RTE 148.6 Well: 2N-327 Section (VS) Reference: Well (O.00N,O.00E,198.1'8Azi) Wellpath: 2N-327 Survey Calculation Method: Minimum Curvature 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: bggm2007 Well: 2N-327 Slot Name: API 50-103-20548-00 Well Position: +N/ -S -44.84 ft Northing: 5911926.34 ft Latitude: 70 10 13.155 N +E/ -W -189.43 ft Easting : 460742.60 ft Longitude: 150 18 57.408 W Position Uncertainty: 0.00 ft Wellpath: 2N-327 Drilled From: Well Ref. Point API 50-103-20548-00 Tie -on Depth: 30.00 ft Current Datum: 2N-327: Actual RTE Height 148.60 ft Above System Datum: Mean Sea Level Magnetic Data: 7/11/2007 Declination: 22.84 deg Field Strength: 57573 nT Mag Dip Angle: 80.64 deg Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction ft ft ft deg 30.00 0.00 0.00 198.18 Survey Program for Definitive Wellpath Date: 7/12/2007 Validated: Yes Version: 13 Actual From To Survey Toolcode Tool Name ft ft 81.00 536.00 2N-327 Gyro (81.00-536.00) CB -GYRO -SS Camera based gyro single shot 655.98 6776.12 2N-327 IIFR+MS+Sag (655.98-677 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 30.00 0.00 0.00 30.00 -118.60 0.00 0.00 5911926.34 460742.60 TIE LINE 81.00 0.23 47.83 81.00 -67.60 0.07 0.08 5911926.41 460742.68 CB -GYRO -SS 168.00 0.12 26.51 168.00 19.40 0.27 0.25 5911926.61 460742.85 CB -GYRO -SS 256.00 0.25 197.61 256.00 107.40 0.17 0.23 5911926.51 460742.83 CB -GYRO -SS 343.00 1.23 204.28 342.99 194.39 -0.87 -0.21 5911925.48 460742.38 CB -GYRO -SS 446.00 3.68 207.43 445.89 297.29 -4.81 -2.19 5911921.54 460740.39 CB -GYRO -SS 536.00 7.48 210.85 535.45 386.85 -12.40 -6.53 5911913.97 460736.01 CB -GYRO -SS 655.98 11.86 205.84 653.69 505.09 -30.21 -15.91 5911896.21 460726.54 MWD+IFR-AK-CAZ-SC 740.61 13.39 204.46 736.28 587.68 -46.96 -23.76 5911879.51 460718.60 MWD+IFR-AK-CAZ-SC 835.90 12.67 203.17 829.11 680.51 -66.61 -32.44 5911859.90 460709.82 MWD+IFR-AK-CAZ-SC 932.10 14.75 203.41 922.57 773.97 -87.55 -41.46 5911839.01 460700.69 MWD+IFR-AK-CAZ-SC 1027.71 17.19 201.49 1014.48 865.88 -111.87 -51.47 5911814.75 460690.56 MWD+IFR-AK-CAZ-SC 1122.59 18.72 200.92 1104.74 956.14 -139.14 -62.04 5911787.54 460679.84 MWD+IFR-AK-CAZ-SC 1215.85 21.84 199.47 1192.20 1043.60 -169.48 -73.17 5911757.26 460668.56 MWD+IFR-AK-CAZ-SC 1311.12 23.63 198.28 1280.07 1131.47 -204.32 -85.07 5911722.48 460656.48 MWD+IFR-AK-CAZ-SC 1404.97 26.58 197.12 1365.04 1216.44 -242.26 -97.15 5911684.61 460644.20 MWD+IFR-AK-CAZ-SC 1499.53 27.04 197.85 1449.44 1300.84 -282.93 -109.97 5911644.01 460631.18 MWD+IFR-AK-CAZ-SC 1592.18 30.56 197.47 1530.62 1382.02 -325.46 -123.50 5911601.56 460617.43 MWD+IFR-AK-CAZ-SC 1685.39 31.42 196.83 1610.52 1461.92 -371.32 -137.65 5911555.78 460603.04 MWD+IFR-AK-CAZ-SC 1781.30 31.93 196.73 1692.14 1543.54 -419.54 -152.18 5911507.64 460588.26 MWD+IFR-AK-CAZ-SC 1874.21 32.47 196.97 1770.76 1622.16 -466.92 -166.54 5911460.33 460573.66 MWD+IFR-AK-CAZ-SC 1971.52 32.88 197.18 1852.67 1704.07 -517.14 -181.96 5911410.20 460557.98 MWD+IFR-AK-CAZ-SC 2065.90 31.91 197.03 1932.37 1783.77 -565.47 -196.84 5911361.96 460542.85 MWD+IFR-AK-CAZ-SC 2160.31 31.74 197.22 2012.58 1863.98 -613.05 -211.49 5911314.46 460527.95 MWD+IFR-AK-CAZ-SC 2254.57 32.29 197.66 2092.51 1943.91 -660.72 -226.47 5911266.87 460512.73 MWD+IFR-AK-CAZ-SC 2345.01 31.50 198.70 2441.73 31.33 198.70 2169.29 2251.83 2020.69 2103.23 -706.12 -753.87 -241.38 -257.54 5911221.55 5911173.89 460497.59 460481.18 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 2538.59 31.77 198.99 2334.38 2185.78 -801.83 -273.91 5911126.02 460464.56 MWD+IFR-AK-CAZ-SC 2619.03 32.16 198.25 2402.62 2254.02 -842.19 -287.51 5911085.74 460450.76 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report 11 Company: ConocoPhillips Alaska Inc. Date: 8/15/2007 Time: 15:38:15 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2N-327, True North Site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N-327: Actual RTE 148.6 Well: 2N-327 Section (VS) Reference: Well (O.00N,O.00E,198.18Azi) Wellpath: 2N-327 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2706.36 31.44 197.79 2476.84 2328.24 -885.95 -301.74 5911042.05 460436.29 MWD+IFR-AK-CAZ-SC 2805.34 31.08 197.85 2561.45 2412.85 -934.85 -317.46 5910993.24 460420.32 MWD+IFR-AK-CAZ-SC 2899.91 30.74 197.63 2642.59 2493.99 -981.12 -332.26 5910947.05 460405.28 MWD+IFR-AK-CAZ-SC 2994.00 30.69 196.72 2723.48 2574.88 -1027.03 -346.46 5910901.22 460390.86 MWD+IFR-AK-CAZ-SC 3092.17 30.02 196.75 2808.19 2659.59 -1074.54 -360.74 5910853.79 460376.33 MWD+IFR-AK-CAZ-SC 3187.07 31.20 197.48 2889.87 2741.27 -1120.72 -374.97 5910807.69 460361.86 MWD+IFR-AK-CAZ-SC 3282.02 30.78 197.28 2971.26 2822.66 -1167.38 -389.57 5910761.11 460347.02 MWD+IFR-AK-CAZ-SC 3377.13 30.26 196.86 3053.19 2904.59 -1213.55 -403.75 5910715.02 460332.60 MWD+IFR-AK-CAZ-SC 3472.04 31.22 197.88 3134.77 2986.17 -1259.85 -418.24 5910668.80 460317.87 MWD+IFR-AK-CAZ-SC 3567.65 30.49 197.49 3216.85 3068.25 -1306.56 -433.14 5910622.17 460302.74 MWD+IFR-AK-CAZ-SC 3662.09 31.89 197.79 3297.63 3149.03 -1353.17 -447.96 5910575.65 460287.67 MWD+IFR-AK-CAZ-SC 3757.11 31.48 197.42 3378.49 3229.89 -1400.74 -463.05 5910528.16 460272.33 MWD+IFR-AK-CAZ-SC 3852.67 30.86 196.80 3460.26 3311.66 -1448.01 -477.61 5910480.97 460257.54 MWD+IFR-AK-CAZ-SC 3948.03 31.56 198.71 3541.82 3393.22 -1495.06 -492.68 5910434.00 460242.22 MWD+IFR-AK-CAZ-SC 4044.17 30.93 198.61 3624.01 3475.41 -1542.31 -508.64 5910386.84 460226.02 MWD+IFR-AK-CAZ-SC 4138.90 i 30.35 198.97 3705.52 3556.92 -1588.01 -524.19 5910341.22 460210.23 MWD+IFR-AK-CAZ-SC 4234.84 30.90 198.27 3788.07 3639.47 -1634.33 -539.79 5910295.00 460194.39 MWD+IFR-AK-CAZ-SC 4327.53 32.16 197.93 3867.08 3718.48 -1680.40 -554.85 5910249.01 460179.10 MWD+IFR-AK-CAZ-SC 4418.24 31.65 197.86 3944.08 3795.48 -1726.02 -569.58 5910203.47 460164.13 MWD+IFR-AK-CAZ-SC 4515.40 30.86 198.51 4027.14 3878.54 -1773.92 -585.31 5910155.66 460148.16 MWD+IFR-AK-CAZ-SC 4609.35 30.47 198.14 4107.95 3959.35 -1819.40 -600.37 5910110.26 460132.86 MWD+IFR-AK-CAZ-SC 4704.06 31.76 197.58 4189.04 4040.44 -1865.98 -615.38 5910063.76 460117.61 MWD+IFR-AK-CAZ-SC 4804.48 31.02 197.70 4274.76 4126.16 -1915.83 -631.23 5910014.00 460101.51 MWD+IFR-AK-CAZ-SC 4894.84 31.39 196.30 4352.05 4203.45 -1960.60 -644.91 5909969.31 460087.59 MWD+IFR-AK-CAZ-SC 4988.04 31.11 195.90 4431.72 4283.12 -2007.05 -658.32 5909922.93 460073.94 MWD+IFR-AK-CAZ-SC 5082.79 31.99 197.95 4512.47 4363.87 -2054.47 -672.76 5909875.59 460059.26 MWD+IFR-AK-CAZ-SC 5177.82 31.37 197.30 4593.34 4444.74 -2102.03 -687.87 5909828.11 460043.90 MWD+IFR-AK-CAZ-SC 5275.08 28.32 200.01 4677.70 4529.10 -2147.89 -703.30 5909782.33 460028.24 MWD+IFR-AK-CAZ-SC 5370.56 24.92 196.31 4763.05 4614.45 -2188.49 -716.70 5909741.81 460014.62 MWD+IFR-AK-CAZ-SC 5465.49 22.49 196.20 4849.96 4701.36 -2225.13 -727.39 5909705.23 460003.75 MWD+IFR-AK-CAZ-SC 5559.41 19.66 196.51 4937.59 4788.99 -2257.53 -736.89 5909672.88 459994.08 MWD+IFR-AK-CAZ-SC 5653.68 15.80 195.63 5027.37 4878.77 -2285.11 -744.86 5909645.35 459985.97 MWD+IFR-AK-CAZ-SC 5748.75 12.96 197.52 5119.45 4970.85 -2307.74 -751.56 5909622.75 459979.16 MWD+IFR-AK-CAZ-SC 5831.07 10.84 202.42 5200.00 5051.40 -2323.70 -757.29 5909606.82 459973.34 MWD+IFR-AK-CAZ-SC 5907.71 9.75 205.31 5275.40 5126.80 -2336.23 -762.81 5909594.32 459967.76 MWD+IFR-AK-CAZ-SC 5955.38 9.14 208.33 5322.43 5173.83 -2343.22 -766.33 5909587.36 459964.20 MWD+IFR-AK-CAZ-SC 5977.74 8.80 209.70 5344.51 5195.91 -2346.26 -768.02 5909584.32 459962.49 MWD+IFR-AK-CAZ-SC 6072.71 8.26 212.36 5438.43 5289.83 -2358.34 -775.27 5909572.29 459955.18 MWD+IFR-AK-CAZ-SC 6167.73 8.57 214.89 5532.43 5383.83 -2369.91 -782.98 5909560.76 459947.42 MWD+IFR-AK-CAZ-SC 6261.98 8.88 214.71 5625.59 5476.99 -2381.65 -791.14 5909549.06 459939.20 MWD+IFR-AK-CAZ-SC 6357.03 7.49 214.82 5719.67 5571.07 -2392.77 -798.85 5909537.98 459931.43 MWD+IFR-AK-CAZ-SC 6450.92 6.34 213.24 5812.87 5664.27 -2402.13 -805.19 5909528.66 459925.04 MWD+IFR-AK-CAZ-SC 6550.90 6.16 217.96 5912.26 5763.66 -2410.97 -811.51 5909519.85 459918.67 MWD+IFR-AK-CAZ-SC 6651.13 6.99 222.66 6011.83 5863.23 -2419.70 -818.95 5909511.16 459911.19 MWD+IFR-AK-CAZ-SC 6751.21 6.65 223.90 6111.20 5962.60 -2428.35 -827.10 5909502.55 459903.00 MWD+IFR-AK-CAZ-SC 6776.12 6.57 223.99 6135.95 5987.35 -2430.42 -829.09 5909500.49 459901.00 MWD+IFR-AK-CAZ-SC 6836.00 6.57 223.99 6195.43 6046.83 -2435.35 -833.85 5909495.59 459896.21 PROJECTED to TD LI Core #1 • 6033' = 90% SILTSTONE, 10% SANDSTONE = medium light gray to light gray, moderate induration, dense, some crumbly with force, overall stiff, moderate cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, gritty to silty texture, micro laminations of very fine grained sandstone with abundant overgrowths, interbedded mica, no show of fluorescence or cut. 6036' = 100% SANDSTONE = pale yellowish brown, clast size ranges from fine upper to very fine upper, sub round, poor sorting, moderate developed sphericity, pitted texture, submature to mature texture, dominant grain support with minor clay matrix, dominant grain overgrowths, fair porosity and permeability, 100% bright yellow even sample fluorescence on fresh cuttings, 60% patchy light brown oil stain, instant bright blue white cloudy fluorescent cut with moderate increase to cloudy to milky blue white cut, faint straw visible residue stain. Best oil show of core #1. 6039' = 50% SANDSTONE, 50% SILTSTONE = continued oil shows from sandstones with thinly laminated siltstones displaying silty clay to silty very fine grained sandstones, planar orientation with continued moderate to bright patchy yellow oil fluorescence, slight light brown oil stains in sandy laminations. 6041' = 100% SILTSTONE = medium light gray to light gray, moderate induration, stiff overall, moderate cohesiveness, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, gritty to silty texture, micro laminations of very fine grained silty to clayey sandstones, planar fracturing along silty clay laminations, no show of fluorescence or oil cuts. 6044' = 100% SILTSTONE = same as 604,1' but no visible laminations, appears homogeneous in nature with no show of fluorescence or oil cuts. 6047' = 100% SILTSTONE = same as 6044' with a trace amount of mica. 6050' = 100% SILTSTONE = same as 6047' 6053' = 50%SANDSTONE, 50% SILTSTONE = continued siltstones with thinly laminated very fine grained sandstones, very distinct even bright yellow oil fluorescence in planar orientation, very light brown patchy oil stain along laminations, sandstones are very light gray to very pale yellowish brown, fair to poor visible porosity and permeability, instant dull light blue fluorescent cut, slow streaming with slow development to moderate hazy to cloudy blue white oil cuts, very faint straw visible residue stain, poor cuts overall. 6056' = 60% SANDSTONE, 40% SILTSTONE = Sandstones are medium light gray to light gray, clast size ranges from very fine upper to very fine lower grading to siltstone, subround, moderate developed sphericity, poor sorting, pitted texture, submature nature, dominant grain support with secondary slight silty matrix, scattered laminations, poor 0 0 visible porosity and permeability, abundant overgrowths, thin laminations of bright yellow even oil stains, 40% moderate to bright patchy yellow oil fluorescence, instant dull hazy slow streaming cuts with slow increase to moderate light blue oil cuts, very poor visible residue stains. 6059' = 70% SILTSTONE, 30% SANDSTONE = silts are medium light gray to light gray, moderate to well indurated, dense to stiff, moderate cohesiveness, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, silty to gritty texture, composed of 70% silt and 30% very fine grained sandstone, micro laminations of mica and detrital material, no show of fluorescence or oil cuts. 6062'= 70% SILTSTONE, 30% CLAYSTONE/MUDSTONE = silts are becoming darker: medium gray to medium light gray, moderate to well indurated, dense to stiff, moderate to good cohesion, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, silty texture, grading to a silty mudstone, composed of 70% silt. 30% silty clay with no show of fluorescence or oil cuts. 6065' = 100% SILTSTONE = becoming darker medium dark gray to medium gray, moderate to dark earthy luster, very homogeneous silt with very slight light micro laminations of clay, composed of >95% silt with no show of fluorescence or oil cuts. 6068'= 70% SILTSTONE, 30% CLAY/MUDSTONE = same as 6065 with scattered micro laminations of light hued silty clays with no show of fluorescence or oil cuts. 0 0 CORE #2 6071' = 100% SILTSTONE = medium gray, moderate to well indurated, dense to stiff, moderate to good cohesion, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty to gritty textures, homogeneous bed of siltstone, composed of 70% silt, 30% Claystone/Mudstone, no show of fluorescence or oil cuts. 6075' = 100% SILTSTONE = medium gray, moderate to well indurated, dense to stiff, moderate to good cohesion, non adhesion, sub planar fracture, sub platy habit, dull earthy luster, silty to gritty texture, grading away from silty mudstone to siltstone with occasional very fine grain lower sands inter beds, composed of 80% silt, 20% very fine grain sand. No show of fluorescence or oil cuts. 6078' = 100% SILTSTONE = same lithology as 6075' but noted scattered carbon fines. 6081' = 100% SILTSTONE = medium gray to medium dark gray (note slight colour change) same lithology as 6078' but silts are becoming finer with continued carbon fines scattered in silt matrix. Composed of 90% silt, 10% very fine lower sands. 6084' = 50% SILTSTONE, 50% SANDSTONE = distinct wavy laminations of very light gray sandstone and medium gray siltstones. Sandstones are very light gray, clast size ranges from fine lower to very fine lower grading to silt size at contact points, abundant size faction is very fine upper, sub round, overall moderate to some well developed sphericity, pitted texture, submature nature, non to very slight visible matrix material, dominant grain support with dominant grain overgrowths, poor to fair visible porosity and poor permeability, no show of fluorescence or cut. 6087' = 100% MUDSTONE/CLAYSTONE = medium dark gray to medium gray, hard, dense to stiff, good cohesion, non adhesion, planar fracture, platy habit, dull earthy luster, slight sparkly luster with micro mica's in part, sub gritty texture, homogeneous appearance, overall a silty mudstone composed of 50% clay, 50% silt, no show of fluorescence or oil cuts. 0 0 CORE #3 6121' = 100% SANDSTONE = medium light gray, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, slight clay/ash matrix, dominant grain support, some grain overgrowths, fair to good porosity and permeability, very slight petroleum odor, cuttings are easy to break apart, very faint yellow oil stain, 100% patchy bright yellow sample fluorescence, instant dull hazy to cloudy blue white slow streaming cut with a very slow increase to cloudy moderate blue white cut, very faint straw residue stain, poor oil cuts. 6124' = 100% SANDSTONE = same sandstone as 6121' with a better oil cut: slight petroleum odor, cuttings are easy to break apart, faint yellow even oil stain, 100% even bright yellow sample fluorescence, instant moderate blue white cloudy fluorescent cut with moderate streaming oil cuts and a moderate increase to milky moderate blue white cuts, very faint straw residue stain. 6127' = 100% SANDSTONE = medium gray, clast size ranges from very fine upper to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, slight clay/ash matrix, dominant grain support with abundant grain overgrowths, poor porosity and permeability, no petroleum odor, no show of oil fluorescence or oil cuts. 6130' = 100% SANDSTONE = medium light gray, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, slight clay/ash matrix, dominant grain support, slight decrease in grain overgrowths, fair to good visible porosity and permeability, slight petroleum odor, faint yellow even oil stain, 100% even bright yellow sample oil fluorescence, instant moderate to bright blue white moderate streaming oil cut, moderate increase to cloudy to milky blue white oil cut, faint straw residue stain. 6133' = 100% SILTSTONE = medium gray, moderate to well indurated, dense to stiff, moderate to very cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty texture, homogeneous bed of silt, generally a silty mudstone, interbedded mica, pyrite carbon specs and various detrital material with no show of oil fluorescence or oil cuts. 6136' = 100% SANDSTONE = medium gray to medium light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, very slight clay/ash matrix, dominant grain support, scattered grain overgrowths with fair to good porosity and permeability, no oil odor, slight bright light yellow even sample oil fluorescence, no oil stain and a very poor oil cut. 6139' = 100% SANDSTONE = medium light gray to light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished texture, mature naturer, very slight clay/ash matrix, dominant grain support, scattered grain overgrowths, fair porosity and poor permeability, no show of oil fluorescence or oil cuts. 6142' = 100% SANDSTONE = medium light gray to light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, very slight clay/ash matrix, dominant grain support with scattered grain overgrowths, poor to fair porosity and poor permeability, interbedded with mica and various detrital material with no show of oil fluorescence or oil cuts. 6145' = 100% SANDSTONE = light yellowish gray to medium light gray, clast size ranges from fine upper to very fine upper, sub round, moderate sphericity, moderate sorting, polished texture, mature nature, slight decrease in very slight clay/ash matrix material, dominant grain support with scattered grain overgrowths of volcanic glass, fair to good porosity and fair permeability, fair to good petroleum odor from cuttings, 100% grayish yellow even oil stain, 100% bright yellow oil fluorescence, easy to break apart cuttings, instant bright fast streaming milky oil cuts, best oil cuts in core #3, faint straw residue oil stain. 6147.8'= 10% CARBONACEOUS MATERIAL, 30% SILTSTONE, 60% SANDSTONE = medium light gray to medium gray, clast size ranges from very fine upper grading to silt, sub round, moderate sphericity, polished texture, submature nature, moderate silty to clayey matrix, both grain and local matrix support, gradational sands, silts and micro laminations of carbon material, detritalish, poor to possibly fair porosity with poor permeability, 20% trace to spotty oil fluorescence with a very poor oil cut. 6148.4' = 100% SANDSTONE = yellowish gray (oil stains) to medium light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished textures, mature nature, very slight clay matrix, dominant grain support with grain overgrowths noted, fair porosity and permeability, moderate petroleum odor, even yellow oil stain, 100% bright yellow even sample oil fluorescence, instant cloudy to milky bright blue white oil cut with a fast increase to moderate milky blue white, faint straw residue stain. CORE # 3 6091'= 50% SILTSTONE, 10% CARBONACEOUS SHALE AND CLAY, 30% SANDSTONE = medium light gray to light gray, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, poor to moderate sorting, polished to pitted texture, mature nature, dominant grain overgrowths of volcanic glass shards, no visible matrix material, poor porosity and permeability, thin beds of sand laminations, contacts with silty mudstones with interbedded carbonaceous fragments and grading to carbonaceous mud. 6094' = 100% SANDSTONE = light gray to medium light gray, clast size ranges from fine lower to very fine lower, sub round to some rounded grains, moderate occasionally well developed sphericity, moderate with some poor sorting, polished texture, mature nature, dominant grain support with less grain overgrowths than 6091', no visible matrix material, fair to good porosity and permeability, grain to grain contact noted with very slight sample fluorescence with no oil cuts. 6097' = 100% SANDSTONE = same description as 6094' with added mica flakes and various detrital material, very slight sample fluorescence with no oil cuts. 6100' = 100% SANDSTONE = same description as 6097' with a slight increase in a clay matrix with dominant grain support, no show of oil fluorescence or cut. 6103' = 100% SANDSTONE = light gray to a subtle "salt and pepper" appearance with black lithic content, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, dominant grain support with a slight increase in a clay/ash matrix, scattered grain overgrowths, fair to good porosity and permeability, very slight petroleum odor from cuttings, very faint yellow brown even oil stain, 100% bright yellow even sample oil fluorescence, instant dull light blue hazy sample oil cut with slow to moderate streaming cuts, slow increase to dull to moderate hazy to cloudy cuts, very faint straw residue stain. 6106' = 100% SANDSTONE = medium gray to yellowish gray (in oil stains), clast size ranges from fine lower to very fine lower, moderate developed sphericity, moderate sorting, polished texture, mature nature, dominant grain support, interbedded mica, very slight clay/ash matrix material, fair to good porosity and permeability, slight to moderate grain overgrowths, slight petroleum odor to cuttings, faint yellow hued oil stains, 100% bright yellow even sample oil fluorescence, cuttings are easy to break apart, instant cloudy moderate blue white moderate streaming cuts, slow to moderate increase to moderate blue white cloudy to milky fluorescence, very faint straw residue stain. 6109' = 100% SANDSTONE = medium gray, clast size ranges from fine lower to very fine lower with an abundant faction being very fine grains, cuttings are easy to break apart, sub round to rounded, moderate to well developed sphericity, moderate sorting, polished texture, mature nature, non to very slight calcareous slight clay matrix, dominant grain support, scattered grain overgrowths, fair to good porosity and permeability, slight i petroleum odor to cuttings, bright yellow even sample fluorescence, cuttings exhibit oil fluorescence banding/laminations under ultra violet light, instant light blue slow streaming oil cuts with a slow increase to dull hazy cuts with a very faint pale straw residue stain. 6112' = 100% MUDSTONE = medium gray, hard, dense to stiff, very cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, sub smooth to sub matte texture, homogeneous mudstone composed of 70% clay, 30% silt with no show of fluorescence or oil cuts. 6115' = 100% SANDSTONE = medium gray to medium light gray, clast size ranges from fine lower to very fine lower, cuttings are easy to break apart, sub round, moderate occasionally well developed sphericity, moderate sorting, polished texture, mature nature, non to very slight calcareous in very slight clay matrix, dominant grain support, scattered grain overgrowths, scattered interbedded mica, fair to good porosity and permeability, very slight petroleum odor from cuttings, bright yellow even sample oil fluorescence, cuttings exhibit oil fluorescence laminations and banding under ultra violet light and not visible in white light, instant dull light blue slow streaming oil cuts with slow increase to a dull hazy blue cut with a very faint straw residue stain. 6117' = 100% SANDSTONE = light brownish gray to medium light gray, clast size ranges from fine upper to very fine lower with abundant faction being very fine upper, cuttings are easy to break apart, subround, moderate with some well developed sphericity, moderate sorting, polished texture, mature nature, non to very slightly calcareous in a very slight clay matrix, dominant grain support with a slight increase in grain overgrowths and a slight decrease in the mica content, overall appears tight, fair porosity and permeability, no petroleum odor from the cuttings and no show of oil fluorescence or oil cuts. 6118.8' = 100% SANDSTONE = light gray to light yellowish gray (oil stain), clast size ranges from very fine upper to very fine lower, sub round, moderate to well developed sphericity, moderate sorting, polished texture, mature nature, non to very slightly calcareous clay matrix 0 0 CORE #4 6148.4' =100% SANDSTONE = yellowish gray (oil stains) to medium light gray clast size ranges from fine lower to very fine upper sub round moderate developed sphericity moderate sorting polished textures mature nature very slight clay matrix dominant grain support with grain overgrowths noted fair porosity and permeability moderate petroleum odor even yellow oil stain 100% bright yellow even sample oil fluorescence instant cloudy to milky bright blue white oil cut with a fast increase to moderate milky blue white faint straw residue stain. 6151' = Carbonaceous siltstone = medium dark gray with a slight brownish yellow secondary hue; hard, slightly shaly, very slightly fissile slightly sandy; dull earthy luster slightly gritty sandy texture; trace very fine to fine mica flakes; trace to common very fine pyrite; common small medium brown to dark brown carbonaceous inclusions some of which are obvious plant remains; very slight oil odor; trace dull yellow fluorescence; very slow medium yellow white crush cut very slight yellow residual fluorescence; trace calcareous. 6154' = 100% SANDSTONE = medium light gray, hard, clast size ranges from very fine lower to very fine upper, very silty, moderate to well rounded; moderate to well developed sphericity, common dark mineral grains, dominant grain support with crystalline silic cement and grain overgrowths, poor porosity and permeability; no visible stain, no odor, 40% patchy to scattered light yellow green sample fluorescence, instant light yellow white to blue white slow streaming fluorescent cut, very slow developing cut, overall poor cut. 6157' = 100% SANDSTONE = medium light gray, clast size ranges from fine lower to very fine upper with a slight "salt and pepper" appearance, continued silt content, moderate to well rounded, moderate to well developed sphericity, dominant grain support with grain overgrowths, fair to poor porosity with poor permeability, trace petroleum odor, no visible stain, 50% moderate yellow patchy to scattered oil fluorescence, slight to moderate calcareous, slow dull streaming cuts, no increase with "crush cuts", poor overall oil cuts. 6160' = 100% SANDSTONE = light gray to medium light gray and various hues of both and a distinct yellowish secondary hue (oil stain), clast size ranges from fine lower to very fine upper, non calcareous, sub round to round, moderate to well developed sphericity, dominant grain support with some overgrowths, fair porosity and permeability, moderate petroleum odor, 80% even light yellow oil stain, 100% bright yellow even sample oil fluorescence, instant moderate to bright blue white cloudy oil cut with moderate increase to moderate milky blue white cut with a faint straw residue stain, best oil cut for Core #4. 6163' = 100% SILTSTONE = light gray, well indurated, trace fracture fills noted, dense to stiff, scattered interbedded mica, some very fine grained sands interbedded in parts, slight ashy matrix, non calcareous, no odor noted, no oil stains, no fluorescence or oil cuts. 6166' = 100% SILTSTONE = very light gray, well indurated, dense to stiff, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, homogeneous with some silic appearance, non calcareous, moderate scattered brown mica, slightly ashy in parts, no petroleum odor or stain, no show of oil fluorescence or cut. 6169' = 100% SANDSTONE = very light gray, clast size ranges from very fine upper to very fine lower, sub round, moderate to well developed sphericity, moderate sorting, polished texture, sub mature nature, slight ashy matrix, dominant grain and grain overgrowth support, poor porosity and permeability, no stain or petroleum odor, no show of oil fluorescence or oil cuts. 6172' = 100% MUDSTONE = medium gray to light gray, easy to break apart, brittle to firm, planar fracture, platy habit, non to trace calcareous, very clean, no silt or sands interbedded, no inclusions, homogeneous bed of silic mudstone, no oil stain or petroleum odors, no show of oil fluorescence or oil cuts. 6175' = 20% CARBONACEOUS SILT, 80% SILTSTONE = dark gray to brownish gray, moderate to well indurated, poorly laminated in carbonaceous sections, overall silty with clayey to slightly shale in parts, non calcareous, planar fracture, platy habit, dull earthy luster, silty texture, thin laminations of very fine grained lower sand, clay and ash, no show of oil. 6178' = 100% CARBONACEOUS SHALE, SILT AND CLAY = dark gray, brittle to moderate induration, silty, fractures along platy laminations, non calcareous, common black to dark brown carbonaceous inclusions, no show of oil fluorescence or oil cuts. 6180'= 10% CARBON SHALE, 10% SANDSTONE, 80% SILTSTONE = medium dark gray, moderate induration, moderate cohesiveness, non adhesive, planar fracture along laminations of silt, very fine sand and carbon material, platy habit, dull earthy luster, silty to matte texture, interbedded with mica and carbonaceous specs, some fine ash laminations, no show of oil fluorescence or oil cuts. 6183' = 100% CARBONACEOUS SILTY SHALE = medium light gray to light brownish gray and various hues of both, dense to stiff some brittle in parts, planar fracture, sub platy to blade like habits, dull earthy luster, smooth texture, homogeneous bed of silty shale. 6186' = 100% SANDSTONE = medium gray to light brownish gray, well consolidated, clast size ranges from fine lower to very fine lower, moderate some well sorting, moderate to well developed sphericity, trace mica, trace black and brown carbon material 0 inclusions, non calcareous, poor to fair porosity, poor permeability, abundant grain overgrowths, no show of oil fluorescence or cut. 6189' = 100% CARBONACEOUS MATERIAL = dark gray mottled light gray with an overall hue of dark grayish brown, coarsely fissile, silty in parts, planar fracture, platy habit, earthy luster, mottled texture, abundant coarse irregular gray brown and brownish black carbonaceous inclusions, non calcareous, no show of oil fluorescence or cut. 6192' = 20% SANDSTONE, 80% SILTSTONE = light gray, moderate to well indurated, dense to stiff, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, homogeneous slightly sandy siltstone composed of >90% silt, 10% very fine grained sand, overgrowths of volcanic glass noted, no show of oil fluorescence or oil cuts. 6195' = 20% SANDSTONE, 80% SILTSTONE = continued lithology as 6192' with interbedded black specs in volcanic glass overgrowths, general silty matrix with some very fine grain sand interbedded. No show of oil fluorescence or oil cuts. 6198'= 10% MUDSTONE, 90% SILTSTONE = continued lithology as 6195' but becoming denser and stiff with a decrease in sand content and slight amount of silic mudstone. No show of oil fluorescence or oil cuts. 6201' = 100% MUDSTONE = medium dark gray, firm, dense to stiff in parts, moderate cohesiveness, non adhesiveness, planar fracture, sub platy to platy habit, dull earthy luster, smooth to matte texture, homogeneous bed of silic mudstone composed of 70% clay, 30% silt, no show of oil fluorescence or oil cuts. 6204' = 20% SANDSTONE, SILTSTONE 80%.= medium light gray, well indurated, dense to stiff, good cohesion, non adhesion, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, homogeneous silts with abundant grain overgrowths, trace interbedded carbon specs, sharp edge fractures along broken core fragments, no show of oil fluorescence or oil cuts. 6207' = 10% MUDSTONE, 90% SILTSTONE = medium gray, well indurated, dense, stiff, good cohesion, non adhesion, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, becoming slightly more silic with grain overgrowths of silt size, scattered brown carbonaceous thin fragments, grading to a silty mudstone. 6208' = 30% SILTSTONE, 70% CLAYSTONE = very light gray, soft, crumbly, slight to moderate cohesion, non adhesion, easy to break apart with hands, earthy fracture, sub nodular habit, moderate to bright earthy luster, silty to clayey texture, composed of 50% clay, 40% silt, 10% various detrial material, no show of oil fluorescence or cut. Core 5 Note: Sample surfaces exposed to mud during coring operation are contaminated with oil. 6209 = Tuffaceous Sandstone = light gray, hard to very hard; very fine upper to fine and medium lower sand and volcanic debris in a matrix of well indurated white ash, larger particles are light gray lithic/volcanic debris, smaller size grains consist of translucent white, clear quartz and volcanics, larger grains are irregular angular in shape and appear un- weathered/transported. Grains in the fine to very fine size range are very tightly held in matrix but appear to be more rounded/spherical. Trace dark mineral/lithics, trace carbonaceous inclusions and trace mica. Matrix material is silica cemented well indurated white ash, trace to non calcareous. No fluorescence, odor, stain or cut. 6211= Tuffaceous Sandstone = Medium light gray, very hard to hard, compositionally very similar to the sandstone above but almost entirely in the very fine lower to fine lower grain size range and without the larger light gray lithic particles. Material is very slightly more calcareous than that above but still in the trace calcareous range. No fluorescence, stain, odor or cut. 6214 = Tuffaceous siltstone = medium gray, very hard, dull earthy luster overall with somewhat brighter luster at magnification. Slightly sandy, slightly shaly, coarsely fissile along bedding planes, abundant carbonaceous inclusions in the very fine lower sand size range and smaller, trace mica, trace volcanic fragments. Non calcareous, no oil stain, odor, fluorescence or cut. 6217 = Carbonaceous shale = dark gray, very hard, very poorly fissile, sub planar fracture along bedding planes, dull earthy luster, slightly gritty texture, slightly silty, micro laminated with lighter colored silt/ash. Contains trace mica inclusions and common large black carbonaceous inclusions as well as abundant carbonaceous fines. Sample was bisected by an irregular lamina of silty very fine lower sand. Non to trace calcareous, no fluorescence, oil stain, odor or cut. 6220 = Carbonaceous shale = medium dark gray, very hard, non fissile, slightly more homogenous than above sample, slightly to moderately silty, no significant large carbonaceous inclusions noted. Non to trace calcareous, no fluorescence, oil stain, odor or cut. 6223 = Tuffaceous Sandstone = Medium gray, hard, brittle, compositionally very similar to the sandstone above, fine lower to very fine upper grain predominates, trace fine upper light gray lithic grains, sub rounded to sub spherical to sub -angular grains, trace mica, common fine grain dark gray and black mafic mineral/carbonaceous inclusions; poor visible porosity, primarily grain supported but well lithified in silicic cement, non calcareous. Very vague dull yellow green fluorescence, no visible cut but has a very slight dull yellow residual fluorescence. No oil odor or stain noted. 6226 = Carbonaceous shale = dark gray, very hard, poorly fissile, dull earthy luster, smooth shaly texture, poor sub -conchoidal fracture, common dark gray to black, medium lower to fine upper carbonaceous inclusions as well as abundant carbonaceous fines. Non to very slightly calcareous, no fluorescence, oil stain, odor or cut. 6229 = Tuffaceous siltstone = medium dark gray, very hard, dull earthy luster overall with somewhat brighter luster at magnification. Slightly sandy, very shaly, poorly fissile does not fracture cleanly, common carbonaceous inclusions in the very fine lower sand size range and smaller, abundant mica, trace volcanic fragments. Very slightly calcareous, no oil stain or odor, slight trace bright yellow point source fluorescence and attendant fast streaming cut may be contaminant. 6232 = Carbonaceous shale = dark to medium gray, very hard, poorly fissile, dull earthy luster, smooth shaly texture on bedding planes, gritty sandy texture on cross bedding fracture, thinly bedded/interbedded with very hard light to medium gray silty sandstone as above described, common dark gray to black, medium lower to fine upper carbonaceous inclusions as well as abundant carbonaceous fines, abundant very fine mica inclusions in the sand interbeds. Shale is very slightly calcareous, interbedded sand is non calcareous no fluorescence, oil stain, odor or cut. 6233 = Tuffaceous Sandstone = Medium gray, hard, brittle, well lithified, identical to the sandstone above, medium lower to fine upper grain predominates, abundant fine upper light gray lithic grains, sub rounded to sub spherical to sub -angular grains, common fine mica, common fine grain dark gray and black mafic mineral/carbonaceous inclusions; poor visible porosity, primarily grain supported but well lithified in silicic cement, some very light gray ash matrix support, non to trace calcareous. Very vague dull yellow green fluorescence, no visible cut but has a very slight dull yellow residual fluorescence. No oil odor or stain noted. • CORE #7 E Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. 6575' = 100% MUDSTONE = medium light gray, firm, stiff, moderate cohesiveness, non adhesive, sub planar fracture, sub platy to sub blocky habit, dull earthy luster, smooth texture, homogeneous, able to "groove" surfaces with sharp tools, not dense, composed of >90% clay and minor silts, not a developed shale. 6578' = 20% SANDSTONE, 80% SILTSTONE = light brownish gray, poor to moderate induration, crumbly to crunchy, stiff in parts, sub planar fracture, sub platy habit, earthy to sub sparkly luster, gritty to silty texture, gradational silts and very fine grain lower (sands) interbedded, very weak thin sandy laminations, overall a sandy siltstone, very slight petroleum odor, very faint light brown oil stain, 50% dull to moderate spotty yellow sample fluorescence, oil laminations visible under UV light, instant moderate hazy to milky blue white streaming cuts with a slow increase to moderate milky cuts, very faint straw residue stain, best oil cut of core #7. 6581' = 100% MUDSTONE = medium gray to light brownish gray, soft to slightly firm, some becoming stiff, slightly cohesive, non adhesive, planar fracture, platy habit, dull earthy luster, matte to smooth texture, homogeneous, composed of >80% clay, 20% silt, sparkly mica noted, trace black carbon specs interbedded, no show of oil fluorescence or oil cuts. 6584' = 100% MUDSTONE = same lithology and description as 6581'. No change. 6587' = 100% SANDSTONE = medium gray, clast size ranges from very fine upper to very fine lower, sub round, moderate with some well developed sphericity. Moderate sorting overall, pitted texture, sub mature nature, very calcareous, slight clay matrix, dominant grain support with moderate grain overgrowths, fair to poor porosity, poor permeability, interbedded mica, very poor oil fluorescence with an instant hazy moderate light blue white hazy cut with a slow increase in brighter fluorescence, average cut, very poor residue stain. 6589.4' = 20% SILTSTONE/SANDSTONE, 80% MUDSTONE = medium gray, soft to firm, surfaces can be easily "grooved" with tools, sub blocky fracture, sub blocky habit, dull earthy luster, silty to matte texture, grading to a silty mudstone in parts, very thin planar laminations of silt and very fine grained sandstone, laminations contain dull to moderate light yellow green oil fluorescence as the non laminated structures "do not contain oil fluorescence", instant dull hazy light blue white cut with a very slow increase to a hazy milky cut and a very poor residue stain. 6589.8'= 50% SILTSTONE, 50% MUDSTONE = same description as 6589.4', but grading to more siltstones with continued spotty oil fluorescence. Core appears "washed out" displaying a sub triangular shape. Core samples from 6590' to 6595' were "lost" in core drilling and tripping. The following sample descriptions were made of cuttings brought to surface while coring. Sample quality is very poor. 6590' = 50% MUDSTONE, 50% SILTSTONE = medium gray, poor to some moderate induration, sub blocky fracture, sub nodular habit, dull earthy luster, silty to smooth textures, overall a silty mudstone, abundant cavings and trip trash throughout samples, spotty oil fluorescence (20%) throughout the sample but unsure if mud contamination or cavings, very poor oil cuts. 6595' = 50% MUDSTONE, 50% SILTSTONE = same description as 6590'. CORE #8 Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. 6594' = 100% SILTSTONE = light brownish gray, poor induration, crumbly, slight cohesiveness, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty texture, easy to break apart, homogeneous silt with micro mica and light brown micro laminations of clay or ash, laminations are even, composed of >90% silt with no show of oil fluorescence or oil cuts. 6597' = 100% SILTSTONE = medium gray to light brownish gray, poor induration, easy to scour with tools, slightly crumbly, slightly cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty to gritty texture, easy to break apart, homogeneous silt, some slightly grading to a very fine grained sandy siltstone (interbedded), composed of 90% silt, 10% very fine grain sand, interbedded with mica and micro carbonaceous specs with no show of oil fluorescence or oil cuts. 6600' = 100% SILTSTONE = medium gray to light brownish gray, poor induration, easy to scour with tools, slightly crumbly, slight cohesiveness, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty texture, easy to break apart, gradational silts, mudstone and very fine lower sand, micro laminations, increased detrital material with common mica and black carbonaceous specs throughout, no show of oil fluorescence or oil cuts. 6603' = 30% SANDSTONE, 70% SILTSTONE = medium gray, poor induration, crumbly, splits apart along planar laminations, slight cohesiveness, non adhesive, distinct planar fracture, platy habit, earthy to sparkly luster, silty to gritty texture, gradational laminations of silty and very detrital sands, abundant mica and carbonaceous material, very dirty overall, faint light green sample fluorescence from drilling mud. 6606' = 100% SILTSTONE = medium gray, poor induration, crumbly to brittle in parts, splits along planar fractures, sub platy habit, slight cohesiveness, non adhesive, distinct planar fracture, earthy luster, silty texture, homogeneous silt with rare disminated pyrite circles, continued mica and carbon fines but in less quantity than 6603', composed of >90% silt. 6609' = 100% SILTSTONE = medium gray to light brownish gray, poor induration, slightly crumbly, sub planar fracture, sub platy habit, dull earthy luster, silty texture, homogeneous silt, slightly grading to a silty mudstone, abundant micro mica and slight carbon specs, less fissile than 6603 to 6606', no show of oil fluorescence or oil cuts. 6611' = 100% SILTSTONE = sample lithology as 6609' no change. 6612.2' = 100% SANDSTONE = medium light gray to light gray, clast size ranges from very fine upper to very fine lower, sub round, moderate developed sphericity, moderate sorting, pitted texture, sub mature to mature nature, non calcareous, slight clay matrix, dominant grain support, slight to moderate grain overgrowths, fair to poor porosity, poor permeability, very weak petroleum odor, 30% slight spotty very light brown oil stain, 70% dull yellow green patchy oil fluorescence, instant moderate hazy light blue moderate streaming oil cut, slow increase to moderate hazy to cloudy blue white oil cut, slight faint straw residue stain. Core footage: 6613 to 6624' was lost with no recovery in the core barrel. Footage 6613 to 6624' was based on ditch cuttings collected during coring as a back up. Cuttings quality is very poor with abundant cavings, pipe dope and yellow paint from the outside of the core barrel. 6613' to 6624'= 30% SANDSTONE, 20% MUDSTONE, 50% SILTSTONE = medium gray to medium light gray, poor induration, sub planar to sub blocky habit, sub platy to sub nodular habit, dull earthy luster, silty texture, some fragments of very fine grained sandstone scattered, abundant cavings: yellow paint chips, pipe dope, LCM calcite crystals, rounded silts and mudstones from up hole and general mud contaminations, 50% dull light green sample fluorescence from drilling mud, no fresh cuttings to cut, undetermined oil from unproven cuttings. Overall very poor quality. • • Note: Slight medium dull greenish yellow oil fluorescence from mud contamination on all fractures and surfaces exposed to mud circulation. 6625' = SANDSTONE 30%, SILTSTONE 70%; Sandstone = medium gray to dark gray with a slight brownish secondary hue; hard to very firm , moderately well sorted; fair to poor visible porosity; very fine upper to very fine lower to trace fine lower clear to translucent white quartz sand predominates, 20 to 30% dark mafic mineral/lithics and carbonaceous inclusions impart a dirty pepper in salt appearance; trace mica; generally matrix supported in an off white to light gray clay/ash matrix; partially grain supported; moderately overgrown; moderately well indurated; matrix is moderately hydrophilic and expands visibly on application of clear water, more rapidly in weak HCl solution; thinly bedded/interbedded with associated siltstone; trace calcareous; trace very slight dead oil stain; trace very dull yellow green fluorescence may be due to contamination from mud; no cut from rock fragments; no odor noted; grades to and interbedded with hard medium to hard dark gray Siltstone/Mudstone; silty texture; dull earthy luster in hand samples, micro -sparkly luster due to very fine mica inclusions noted under magnification; abundant silt and clay size carbonaceous inclusions; trace micro -thin carbonaceous laminations and fine to very fine carbonaceous inclusions; non calcareous; no stain odor, fluorescence or cut. 6628' = 100% SILTSTONE = dark to medium gray overall with a marked brownish secondary hue; silty texture; dull earthy to slightly sparkly luster in hand samples, micro - sparkly luster due to very fine mica inclusions noted under magnification; abundant silt and clay size carbonaceous inclusions; common very fine lower sand laminations; trace micro -thin carbonaceous laminations; abundant fine to very fine carbonaceous inclusions; non calcareous; no stain odor, fluorescence or cut. 6631' = 100% SILTSTONE = dark gray with a slight brownish secondary hue; moderately hard; brittle; breaks into long bladed fragments; moderately shaly; poorly to moderately fissile; silty to shaly texture; micro -sparkly luster; non calcareous; no fluorescence found in rock fragments, no odor, stain or cut. 6634' = SANDSTONE 20%, SILTSTONE 80% = Sandstone = medium brownish gray; moderately hard; very fine upper to very fine lower quartz sand as above described; moderately well sorted; very abundant fine carbonaceous inclusions; fair to poor visible porosity; 100% very dull yellow oil fluorescence; slow streaming cut improves on crush; good medium yellow-orange residue fluorescence; no stain or odor noted; grading to and thinly bedded/interbedded with: Siltstone = dark gray with a slight brownish secondary hue; hard to very hard; silty to sandy texture; dull mottled earthy luster; slightly to moderately sandy; super abundant fine sand size carbonaceous inclusions; abundant very fine mica; very slightly calcareous; no stain odor fluorescence or cut. 6637' = SILTSTONE 100% = Identical to siltstone described at 6634'. 6640'= SANDSTONE/CARBONACEOUS SANDSTONE 90%, SILTSTONE 10% _ Moderately hard brownish gray sandstone generally as described in the 6634' sample however sand size tending to very fine upper to fine lower and carbonaceous inclusions are more abundant; 100% dull yellow fluorescence; very slow cut with very slight streaming, improves with crush as above; good medium yellow-orange residue fluorescence; slight oil odor; brownish hue may be due to oil stain; non calcareous. 6643' = SILTSTONE/MUDSTONE 100% = Medium gray to medium gray brown; moderately hard; dull earthy luster; silty to slightly sandy texture; immature; common fine carbonaceous inclusions, common large planar to irregular lumpy carbonaceous inclusions; trace to common brown rhombohedral calcite, some showing internal fracture striations; very vague dull yellow fluorescence; no notable cut; very slight dull orange - yellow residue fluorescence; slightly calcareous. 6646' = SANDSTONE 100% = Medium gray -brown to medium gray; moderately hard; slightly brittle; well sorted; very fine upper to very fine lower quartz sand; very silty/clayey; primarily matrix supported; no visible porosity/permeability; matrix is light brownish gray clay/ash; common to locally abundant fine upper size flattened lenticular carbonaceous inclusions are oriented in segregated bands parallel to bedding; very slight oil odor; general 100% dull yellow fluorescence broken by narrow black carbonaceous bands; moderate slow cut gradually becomes slow streaming cut, improves on crush; good dull orange -yellow residue fluorescence; fast streaming orange yellow residue cut; brownish hue may be due to oil residue; very slightly calcareous. 6649' = SANDSTONE 100% = Medium gray; moderately hard; well sorted, very fine upper to very fine lower grain; well rounded quartz sand; trace fine lower lithic grains; trace dark mafic mineral/lithic grains; common very fine carbonaceous material; trace micro -thin carbonaceous laminar fragments; trace mica; generally grain supported; mature; moderately well indurated; trace clay/ash matrix; non to very slightly calcareous; very vague dull yellow fluorescence; trace dull yellow residual fluorescence/cut; no stain or odor. 6652' = SANDSTONE 100% = Medium gray with a slight brownish secondary hue; moderately hard; moderately well to well sorted; very fine upper to fine lower to very fine lower grain; well to moderately well rounded quartz sand; trace light gray lithic grains in part; slight trace dark mafic mineral/lithic grains and common carbonaceous inclusions in well segregated bands parallel to bedding; poor visible porosity; noticeable oil odor; pervasive medium yellow fluorescence; fair instantaneous yellow white cut begins slight streaming cut; good yellow residual fluorescence; good yellow white residual cut; slight brownish secondary hue may be due to oil stain; non to very slightly calcareous. Note: resemblance of the fluorescence in this sample to that imparted by contaminant oil from Bermuda shows may indicate that this material has aspirated oil from the drilling fluid. - 1 Cement Summary 2N-327 Primary Job Type Job Category AFE / RIFE/ Maint.# Actual Start Date Spud / KO Date End Date DRILLING ORIGINAL DRILLING 10188595 7/11/2007 7/12/2007 8/14/2007 Wellbore Name Profile Type Kick Off Depth (ftKB) Vertical Section Direction (°) 2N-327 Directional 350.0 198.18 IMMIMMM IN, -M-11-11 EMMo[kc i3 KB MA -M=UM COND1 20 0.0 110.0 SURFAC 121/4 0.0 2,610.0 iNTRM1 8314 2,610.0 5,870.0 PROD1 61/8 5,854.01 6,514.0 PROD2 61/8 6,514.0 6,836.0 Type Install Date D scn`ptiori4. -. 4 „ Ty1' � ;�==., � „r � _ . € � SCP. o- • , �'� a.> _ e Casing Description Wellbore Run Date Set Depth (ftKB) Stick Up (ftKB) Set Tension (kips) Conductor 2N-327 7/3/2007 110.0 0.0 Centralizers Count Scratchers Count 0 0 5 -�'-`-'� eOENSMI io!n 'JW�I 2 Casing Joints 1 161 15.2501 65.00111H-40 weld 110.00 0.0 110.0 WR 2;5 8:7�tK rt r Casing Description Wellbore Run Date Set Depth (ftKB) Stick Up (ftKB) Set Tension (kips) Surface 2N-327 7/15/2007 2,598.7 0.0 Centralizers Count Scratchers Count 17 1'6 d 6IteaQeP!4, �� a... _ ODiln „.z:- I(in$ fin!® {lbs _ a.e_ _ .i± aR{ftB ry B 1 RT to Landing Ring - Nordic Rig 3 95/8 95/8 BTC 31.00 0.0 31.0 1 Casing Hanger 95/8 9518 BTC 2.30 31.0 33.3 59 Casing Joints - 9-5/8" 95/8 8.835 40.00 L-80 95/8 BTC 2,483.80 33.3 2,517.1 1 Float Collar 95/8 95/8 BTC 1.50 2,517.1 2,518.6 2 Casing Joints - 9-5/8" 95/8 8.835 40.00 L-80 95/8 BTC 78.45 2,518.6 2,597.1 1 Float Shoe 95/8 95/8 BTC 1 1.70 2,597.1 2,598.8 Casing Description Wellbore Run Date Set Depth (ftKB) Stick Up (ftKB) Set Tension (kips) Intermediate 2N-327 7/20/2007 5,854.5 0.0 Centralizers Count Scratchers Count 20 to .'escnPtloStv.`,�'s OQ i(tn.h T S !! x ,a w •' 1 RT to Lower LDS - Nordic 3 7 28.25 0.0 28.3 1 Casing Hanger - FMC Gen 5 7 6.276 7 BTCM 1.00 28.3 29.3 1 Casing Pup Joint - on Hanger, Pin 7 6.276 26.00 L-80 7 BTCM 1.27 29.3 30.5 x Pin 140 Casing Joints - 7" ,26#, L-80, 7 6.276 26.00 L-80 7 BTCM 5,737.49 30.5 5,768.0 BTCM 1 Float Collar 7 7 BTCM 1.31 5,768.0 5,769.3 2 Casing Joints - 7",26#, L-80, 7 6.276 26.00 L-80 7 BTCM 83.70 5,769.3 5,853.0 BTCM 1 Float Shoe 7 1 7 BTCM 1.46 5,853.0 5,854.5 --a r-11,11113501 WE" Casing Description Wellbore Run Date Set Depth (ftKB) Stick Up (ftKB) Set Tension (kips) Liner 2N-327 8/11/2007 6,834.0 -5,646.1 Centralizers Count Scratchers Count 36 �aRi DesCnpfion s OD;im} W-3T`9?'a$;,.b.' Y � w'� -1Grade, <A` i!n) op,Thread [en (ft1 ' '. To ', ftKB, ; BtmLft6Z 1 Baker C-2 ZXP Liner Top Packer, 5 4.410 17.82 5,646.1 5,663.9 Size 5" x 7" 1 Baker Flex -Lock Liner Hanger, 5 4.410 5 BTC 9.78 5,663.9 5,673.7 Size 5" x 7" /II R Cement Summary 2N-327 � �• �r�[)'e ,Pio tm ,:��-�_, � --- ,�V�ills/f( ��Grac(' ! ��� Tread I - ,�?C�k*;. 19.19 T,p & ,' 5,673.7 � it,�.. 5,692.9 1 Seal Bore Ext, Size 80-40, 5" BTC 5 4.000 5 BTC Box X Pin 1 XO, 5" BTC Box X 4-1/2" IBT Pin 5 3.930 5 BTC 1.80 5,692.9 5,694.7 1 Pup Joint - 4-1/2", 12.6#, L-80, 41/2 3.958 12.60 L-80 41/2 IBTM 3.79 5,694.7 5,698.5 IBTM - SCC 34 Liner-4-1/2", 12.6#, L-80, IBTM- 41/2 3.958 12.60 L-80 41/2 IBTM 1,041.68 5,698.5 6,740.1 SCC 1 Landing Collar 41/2 3.958 41/2 IBTM 0.84 6,740.1 6,741.0 1 Liner-4-1/2", 12.6#, L-80, IBTM- 41/2 3.958 12.60 L-80 41/2 IBTM 30.32 6,741.0 6,771.3 SCC 1 Float Collar 41/2 3.958 41/2 IBTM 1.57 6,771.3 6,772.9 2 Liner-4-1/2", 12.6#, L-80, IBTM- 41/2 3.958 12.60 L-80 41/2 IBTM 59.51 6,772.9 6,832.4 SCC 1 Float Shoe 41/2 3.958 41/2 IBTM 1.62 6,832.4 6,834.0 Cementing Start Date Cementing End Date Wellbore 7/15/2007 7/16/2007 2N-327 Evaluation Method Cement Evaluation Results Returns to Surface Comment After regaining circ. prior to cement job. Had good returns thru out cement job. Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (bbl) Top Plug? Bottom Plug? 0.0 2,598.0 Yes , 275.0 Yes Yes Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbi/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 3 3 3 420.0 920.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) Yes 12.00 1 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Fluid Description Amount (sacks) Class Volume Pumped (bbl) Fluid Type Lead Cement 495 ASL 403.0 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft'/sack) Mix H2O Ratio (gal/sack) 0.0 1,816.0 300.0 4.63 21.75 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 10.70 1 6.00 WAR, .11 wl_rrt Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl) Tail Cement 185 Crete 80.0 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft'lsack) Mix H2O Ratio (gal/sack) 1,816.0 2,598.0 50.0 2.49 8.39 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 12.00 4.39 6' Antifoam C a f71s ersanrMINIMS' Dispersant _ Cementing Start Date Cementing End Date Wellbore 7/20/2007 7/21/2007 2N-327 Evaluation Method Cement Evaluation Results Comment Cement Summary 2N-327 • • r' v Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (bbl) Top Piug? Bottom Plug? 4,854.0 5,854.0 Yes 100.0 Yes Yes Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 6 2 5 495.0 1,000.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) Yes 10.00 1 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date. Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl) Primary Cement 235 G 47.0 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft'/sack) Mix H2O Ratio (gal/sack) 4,854.0 5,870.0 50.0 1.17 2.91 Free Water (%) Density (lb/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 15.80 4.22 Dispersant �; e'au de Antifoam D144 I I ex errr n , c_ Ia9 a WIN . Cementing Start Date Cementing End Date Wellbore 8/11/2007 8/11/2007 2N-327 Evaluation Method Cement Evaluation Results Full returns Comment <s . -1 Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (bbl) Top Plug? Bottom Plug? 5,645.0 6,836.0 Yes 12.0 Yes Yes Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 3 3 3 1,200.0 3,200.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) Yes 5.00 1 No Depth tagged(ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl) Primary Cement 173 G 36.2 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft'/sack) Mix H2O Ratio (gal/sack) 5,645.0 6,836.0 50.0 1.17 5.19 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 15.80 3.36 - �e Antifoam fflvffKdffl"10-w1a-��1 RN Dispersant 47 BMW ROUR ffff 'i UT 1111 =1 Mud Push v /11/2007 7/12/2007 12&&0 ,1 .. /13/2007 7/14/2007 l 1412007 ...11151 007 /15/2007 7/16/2007 7/18/2007 Daily Operations Summary Report 2N-327 Job: DRILLING ORIGINAL Move rig off 2N-342 & move over well # 2N -327 -spot rig & rig up diverter-load pipe shed & picking up 5" DP. nrsh ncic� p i rtg back " d rack & tt`311y 9 `rnetce ups from 11(1 to Drlg. directional hole from 685' to 2035'. Made trip to adjust motor frim 1.8 deg. to 1.5 deg. Fr f 2610' GBt 1 -wiper tris -BC i3f IOy loots=rig up err `Al,�, Finish running 9 5/8" csg. Circ. well bottoms up X 3. lost circ. -recover circ. & cement well. #3, Swap mud system, test csg, drill out / perform LOT to 16 ppg MWE, Drill ahead. 7/21/2007 ;7/22/2007 Cement 7" Int csg, install pack -off, c/o pipe rams x 2 sets, freeze protect 7" x 9 5/8" annulus, load and strap DP, PU BHA and RIH. 7123/2007 PU " , RIHy P test Osg, Drill ,Perform FtT t pg.F Drift to tsr Pt 603i' MD. 7/23/2007 7/24/2007 Swap mud system to Flo -Pro, POOH w/ drilling BHA, lay out. PU core assembly, RIH & condition mud for coring. 1242OQ7 '7125l06 POC)ti girl C1,tlt? ravery ' "ire. Fit neine'bairel. RttifFaun #2. 7/25/2007 7/26/2007 ... . Core run #2 ended when pump pressure dropped off. POOH to diagnose, reason for pressure drop not discovered. LD core #2, PU new inner barrel, Bit OK, re -run. TIH f/ core run #3, core drill. 712WOD7 ; 7127/2007 Qrilled Gore f1' 6•'102' ;61 POOH, LD core, PU no f §arrels, TI cant rxtud t0 Contin 7/27/2007 7/28/2007 .a. Drilled Core #4 f/ 6145'- 6207'. Start TOH. 712/2p07 7/2912007 . Drilled Cure45 ft' ......', "barrels, 7/29/2007 7/30/2007 Ended Core Run #5 prematurely at 6233' due to slow drill rate (1 ft/hr). POOH, lay down core stand back in derrick. Rig up to test BOPE, noted well percolating. RIH w/ DP for possible well kill operations. Circulate out gas on choke. Increase mud wt to 10.2 ppg, observe well. 0/3 1/2007,,, 18112/tRl �r rah I log. ' RD SWS. RU & ran �t-112" 1r� : CBU cams •. 8/12/2007 18/13/2007 Finish laying down 4" dp & rig up to run 3.5" tbg. Running same. /1312Ct07 NN 'un 3-1/2" completion. Space ocrt,,di pla !,1 Mme nipple -t€,€0" up• y 8/14/2007 8/15/2007 y NU FMC adapter & tree, test. Freeze protect tubing & IA w/ 100 Bbls diesel. Set BPV. Secure well. Release rig @ 0700 hrs, 8/14/07. _dr) Sv Page 1/1 Report Printed: 10/19/20071 7/30/2007 1 7/31 /2007 Daily Operations Summary Report 2N-327 Job: DRILLING ORIGINAL BOPE test. Test low to 250 psi and high to 3500 psi. All tests were good. PU and RIH w/ drillin assembly to drill to Esker core pt. LWD MADD pass Bermuda formation cored in previous core runs. Drill. RIPII i4351� GBt) POI la dow1HR ick u .core tabl & lH Cor#, frorri35t4 ., , P, Cutting core #6 from 6531 to 6574'. Break core -pump dry job & POH. K -OW 8/5/2007 18/6/2007 CBU-POH-hole not taking fluid-RIH CBU 4200 units gas on bottoms up. POH make up core bbl. RIH cut core # 9. €1007 8/7/2107 Lay down corerecouered 27' of 1" core Maittp BRIHft fra 6651x' t0 6vTfl° :Drlg new , % hole. 8/7/2007 8/8/2007 Finish drlg. to TD @ 6836.-madd pass & run Geo -Tap Points. CBU-POH to shoe. RIH CBU. 8/ /2f107 t3/9/2007 Flr► , monitorl " "s-POH lay clown EMA. Drain stack -well flowing -M raising Wd wt: & mo)*dMq well 8/9/2007 8/10/2007 CBU monitor well trip to shoe & back to bottom. CBU POH for logs. Page 1/1 ReportPrinted: 10/19/20071 0 0 2N-327 Well Events Summary DATE Summary 9/30/07 DRIFTED TBG WITH 15'X 2.72" DMY GUN & TAGGED @ 6716' SLM. PULLED & REPLACED SOV WITH 1" DMY VLV (BK LATCH) @ 5463' RKB. MITT & IA TO 3500 PSI (PASS). 10/6/07 RIH performing FCO/Mud Swap. Ran the 1-3/4" CT connector,check valve, 2-1/8" IGS Data Coil memory tool and 2-1/8" JSN. Tagged the BOT ceramic landing insert/single valve float collar @ 6733' CTMD (6740'RKB). Circulated wellbore volume with Sea -water, clean returns to surface. Swap to 60/40 and POOH freeze protecting 3000' to surface. Shut in swab, freeze protect surface lines, rig down CTU and notify DSO. Job completed. 10/23/07 CEMENT BOND LOG - SLIM CEMENT MAPPING TOOL USED FOR CBL, LOGGED 5650'-6700' WITH WHP AT 0 AND 3000 PSI, CEMENT SHOWS GOOD ISOLATION, WILL BE BACK IN THE AM TO PERFORATE INTERVAL 6560'-6580', LOGGED TWO PRESSURE STOPS: 6570' AND 5458' 10/24/07 PERFORATE ESKER SAND FROM 6560'-6580' WITH 3000 PSI OVERBALANCE ON WHP, WHP DROPPED IMMEDIATELY TO 1650 PSI AFTER SHOOTING, STATIC BOTTOM HOLE PRESSURES: 6570'= 2515.7 PSIA, 158.0 DEGF / 5458'= 2027.6PSIA, 125.6 DEGF, WELL LEFT SHUT IN 10/24/07 INSTALL SIDE POCKET GAUGE AT 5463' RKB (1" SPG HES). PT IA TO 3000#. GOOD TEST. JOB COMPLETE. 10/26/07 Frac Esker Zone, FLUSH JOB TO COMPLETION, WITH 40 bbls FREEZE PROTECTION. Pumped a total of 298900# of Carbolite with 12 PPA on formation 3113 BBL of SW, with an average pressure of 2976 psi. Frac pumped to completion. ISIP= 1678 psi, 5 min pressure = 1430 psi. 10/27/07 RECOVERED 1.25" TREE SAVER ELEMENT. FOUND FRAC SAND AND FRAC GEL STRUNG OUT IN TUBING @ 4000'. TOOLS FALLING SLOWLY/STOPPING DUE TO HVY THICK FLUIDS/SAND. UNABLE TO PUMP INTO WELL. JOB SUSPENDED. 10/29/07 Perform Post Frac Fill Clean Out, RIH with 2.25 DJN, Tagged sand @ 6130 CTMD, Cleaned down to hard tag of 6711 CTMD (150' below bottom perfs) using diesel/diesel gel & duo vis. Freeze protected well. Left S/I. 10/31/07 TAG BOTTOM @ 6727' SLM. 147' EST RATHOLE. SET 2.8" CATCHER @ 5598' SLM. PULLED 1" BKSPG @ 5463' RKB. LDFN. CATCHER IS STILL IN HOLE & STA #5 IS OPEN. 11/1/07 PULLED CATCHER @ 5617' RKB. SET 2.75" CA -2 PLUG @ 5617' RKB. SET CATCHER @ 5595' SLM. CIRC DOWN TUBING & UP IA W/ 190 BLS DIESEL. SET 1" BKOV (5/16" PORT) @ 5463' RKB. TEST VALVES, GOOD TEST. PULLED EMPTY CATCHER @ 5594' SLM. PULLED CA -2 PLUG @ 5617' RKB. JOB COMPLETE. A ConocoPhillips December 12, 2007 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Supplemental report for 2N-327 isJ. Eggemeyer Engineering Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 Dear Mr. Maunder: Attached is the supplemental report to the form 10-407 for well 2N-327 as you requested. The original 10-407 was submitted on November 12, 2007. If you have any questions regarding this matter, please contact me at 265-6049. incerely, J. Eggemeyer Engineering Team Leader CPAI Drilling/ Wells J E/skad RECEI AED "C 1 2 2007 41a&ka oil GasCons, o+xtmissinr>i Anchorage 0 0 ConocoPhillips WelMew Web Reporting Well Name: 2N-327 Job Type: DRILLING ORIGINAL Time Log Summary 07/11/2007 00:00 03:00 3.00 0 0 MIRU MOVE DMOB P Moving Rig from 2N-342 to 2N-327. Spot rig over well & set down same. (Rig accepted @ 03:00 7-11-07 03:00 10:30 7.50 0 0 MIRU MOVE MOB P Rig up diverter-Berm rig -Spot rock washer -Hook up com lines -Fill mud tanks with spud mud. 10:30 15:00 4.50 0 0 MIRU MOVE MOB P PJSM-loading pipe shed w/ 5" DP & 20 HWDP. (Function test diverter-test gas detectors -accumulator drill. Witnessed by Lou Grimaldi AOGCC 15:00 16:00 1.00 0 0 MIRU MOVE RGRP T Work on starting rig back up -all batteries dead. 16:00 18:00 2.00 0 0 MIRU MOVE MOB P Finish loading pipe shed w/ 5" DP & HWDP. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P PJSM=Make up & stand back 5" DP. 07/12/2007 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Finish picking up & standing back 5" DP & HWDP 03:00 10:30 7.50 0 0 MIRU MOVE OTHR P Rack & tally 9-5/8" Surface Casing in pipe shed. 10:30 11:30 1.00 0 0 MIRU MOVE OTHR P Hang tree in cellar. PU & hang sheave for Gyro surveys in derrick. 11:30 13:00 1.50 0 0 MIRU MOVE OTHR P PJSM. PU & MU 12-1/4" bit & 8" Mud Motor, BHA #1. 13:00 14:30 1.50 0 220 SURFAC DRILL DDRL P Break circulation, wash down to conductor shoe. Spud well and drill from 110' to 220' MD. 14:30 15:00 0.50 220 42 SURFAC DRILL TRIP P POOH to 42'. 15:00 18:30 3.50 42 220 SURFAC DRILL PULD P PU & MU Sperry MWD tools, upload tools, orient motor and MWD tools to UBHO sub. PU & MU 3 Non -Mag flex DC. Orient and take Gyro surveys. MU XO & 1st stand of HWDP. Circulate and pulse test MWD tools, OK. Orient tool face. RIH with BHA #1 and tag bottom. 18:30 00:00 5.50 220 685 SURFAC DRILL DDRL P Drill from 220' to 685' MD 680' TVD. up 75k do 75k rot 75k rpm 60 wob 10-15k pp 1440 psi spm 160 tq 1600. art .90 ast 1.84 (Drills) stripping -fire & kick while drl . 07/13/2007 00:00 13:00 13.00 685 1,664 SURFAC DRILL DDRL P Drlg. 12 1/4" directional hole from 685' to 1664' MD. 13:00 14:00 1.00 1,664 1,664 SURFAC DRILL CIRC P Pump sweep & cbu clean hole. 185 spm 1800 psi. 14:00 16:00 2.00 1,664 0 SURFAC DRILL TRIP P POH to reset motor. 07/13/2007 16:00 17:30 1.50 0 0 SURFAC DRILL OTHR P Download MWD -adjust motor angle to 1.5 -clean bit & stabs. 17:30 18:30 1.00 0 1,664 SURFAC DRILL TRIP P RIH-wash down last stand -no fill. 18:30 00:00 5.50 1,664 2,035 SURFAC DRILL DDRL P Drlg. 12 1/4" directional hole from 1664' to 2035' MD 1905 TVD. up 110k do 90k rt 96k wob 15k rpm 80 pp 2150 psi 200 spm 590 gpm tq on 3900 off 3200. art 9.22 ast 3.54 hrs. 07/14/2007 00:00 09:00 9.00 2,035 2,610 SURFAC DRILL DDRL P Drlg. 12 1/4" directional hole from 2035' to 2610' MD 2395' TVD.TQ on 4680 off 3150 spm 220 gpm 650 pp 2570 up 120k do 100k rot 105k. 09:00 10:30 1.50 2,610 2,610 SURFAC DRILL CIRC P Circ. weighted nut plug sweep. CBU X 13. 10:30 12:30 2.00 2,610 2,610 ISURFACDRILL TRIP P Wiper trip to 1559 & back. 10 to 20k overpull from 2139' to 1559'. 12:30 14:30 2.00 2,610 2,610 �SURFACDRILL CIRC P Circ. -condition hole to run 9 5/8" csg. Pump sweep. 14:30 17:00 2.50 2,610 300 SURFAC DRILL TRIP P Monitor well & poh to flex collars. 17:00 18:30 1.50 300 0 SURFAC DRILL PULD P Lay down flex collars & down load MWD. 18:30 20:00 1.50 0 0 SURFAC DRILL PULD P Drain motor -break bit -lay down mud motor & MWD tools. 20:00 22:30 2.50 0 0 SURFAC CASIN( CIRC P Clean floor -kick out tools -rig up to run 9 5/8" 40# L-80 BTC csg. 22:30 00:00 1.50 0 546 SURFAC CASIN( RNCS P PJSM-Run 9 5/8" csg. to 546 MD. 07/15/2007 00:00 00:30 0.50 546 546 SURFAC CASIN( SFTY P PJSM=topic=running csg. 00:30 02:30 2.00 546 1,683 SURFAC CASIN( RNCS P Run 9 5/8" csg. from 546' to 1683'. 02:30 03:00 0.50 1,683 1,683 SURFAC CASINJ CIRC P Circ. capacity of csg. @ 6 bpm 420 psi. 03:00 04:30 1.50 1,683 2,599 SURFAC CASIN( RNCS P Run 9 5/8" csg. from 1683' to 2599'. Make up landing t. & hanger. 04:30 05:30 1.00 2,599 21599 ISURFACCASIN( RURD P Rig down csg. handling equipment & rig up cement head for circulating. 05:30 07:00 1.50 2,599 2,599 SURFAC CASIN CIRC P Circ. & reciprocate pipe @ 6 bpm 480 psi 140k up 110k dn. ( circ. bottoms up X 3.5 times. 07:00 08:00 1.00 2,599 2,599 SURFAC CASIN( OTHR T Lost circ. Attempt to regain same, slowing pump rate @ 2-1- & 1/2 bpm. No returns. 08:00 12:00 4.00 2,599 2,599 SURFAC CASIN OTHR T Working pipe -build volume in pits. Mixing LCM. Nut plug pill -losing 2.5 bph static. 140k up 110k dn. (Pill consists of 40 ppb caco-20 ppb nut plug .5 ppb celloflake total 80-90 barrel ill. 12:00 14:30 2.50 2,599 2,599 SURFAC CASIN OTHR T Monitorwell. 14:30 17:00 2.50 2,599 2,599 SURFAC CASIN( OTHR T Break circ. -stage pump up to 50 spm -pump LCM pill -lost 120 bbl. circ. total 388 bbls. 07/15/2007 17:00 19:00 2.00 2,599 2,599 SURFAC CASIN( RURD T Rig down cement head & equipment -rig up elevators -Rig back up cement head. 19:00 23:00 4.00 2,599 2,599 SURFAC CASIN CIRC T Break circ. -work pipe 135k up 105k do stage pump to 3 bpm 180 psi -losses slowed & maintaing volume. 23:00 00:00 1.00 2,599 2,599 SURFAC CEMEIN DISP P PJSM-load plugs in cement head -test lines 3000 psi & pump cement as per program. 07/16/2007 00:00 01:00 1.00 2,599 2,599 SURFAC CEMEN CIRC P Cement 9-5/8" Surface Casing Pump 655 bbls. lead @ 3 bpm -75 bbls. of tail 3 b m. 01:00 03:30 2.50 2,599 2,599 SURFAC CEMEN DISP P Drop top plug -pump 20 bbls. water -followed w/ 171 bbls. mud. Bump plug & pressure 500# over. Bleed back & floats held. 03:30 04:00 0.50 2,599 2,599 SURFAC CEMEIS OTHR P Clean up cement from around cellar & flush diverter. 04:00 05:00 1.00 2,599 2,599 SURFAC CEMEN OTHR P Rig down all cement equipment & lay down landing 't. 05:00 09:00 4.00 2,599 2,599 SURFAC WELCT NUND P Nipple down diverter. 09:00 12:00 3.00 2,599 2,599 SURFAC WELCT OTHR P Assemble & make up well head equipment & test. 12:00 17:00 5.00 2,599 2,599 SURFAC WELCT NUND P Nipple up 11"5k BOPE. 17:00 22:00 5.00 2,599 2,599 SURFAC WELCI OTHR P Test BOPE 250-3500 psi. Pull test plug & set wear ring. (Witness test waived by Bob Noble AOGCC. 22:00 00:00 2.00 2,599 2,599 ISURFACDRILL PULD P PJSM-Pick up BHA. 07/17/2007 00:00 00:30 0.50 2,599 2,599 SURF DRILL PULD P Cont PU BHA 00:30 02:30 2.00 2,599 2,599 SURFAC DRILL PULD P Program, test and shallow test MWD 02:30 03:00 0.50 2,599 2,599 SURFAC DRILL PULD P PJSM, install radioactive sources in LWD tools. 03:00 04:30 1.50 2,599 2,599 SURFAC DRILL TRIP P TIH w/ BHA t/ 2277ft. 04:30 06:00 1.50 2,599 2,599 SURFAC RIGMN SVRG P Slip and cut drill line. 06:00 07:30 1.50 2,599 2,599 SURFAC RIGMN SVRG P Service Rig 07:30 08:30 1.00 2,599 2,599 SURFAC RIGMN SVRG T Adjust compensator clamps. 08:30 09:30 1.00 2,599 2,599 SURFAC DRILL TRIP P Cont RIH f/ 2277'- 2509'. RU's TD on std #18 and washed to 2509'. 09:30 12:30 3.00 2,599 2,599 SURFAC DRILL CIRC P Circulate and displace out spud mud w/ 9.7 pg LSND @ 2 bpm. 12:30 15:00 2.50 2,599 2,599 SURFA CASIN( DHEQ P RU and perform csg test @ 3000 psi f/ 30 min, OK. RD test equipment. Test recorded on chart recorder. 15:00 15:45 0.75 2,599 2,610 SURFAC CEMEI� COCF P Drill out float collar, cmt and float shoe. 15:45 16:00 0.25 12,610 2,630 SURFAI DRILL DDRL IP Drill 20 ft of new hole from 2610' MD to 2630' MD (2412' TVD) 07/17/2007 16:00 18:00 2.00 2,630 2,630 SURFAC DRILL CIRC P Circulate and condition mud for FIT. Perform FIT to 16 ppg MWE. Mud Wt 9:7 18:00 00:00 6.00 2,630 3,209 INTRM1 DRILL DDRL P Dir Drill ahead w/ 8 3/4" bit f/ 2630'- 3209' MD (TVD 2908') PU 140 klbs, SO 103 klbs, Rot Wt 120 klbs. Torq ONB 5500 ft-lbs, Torq OFB 4500 ft-lbs. ECD's 10.72 ppg MWE. 07/18/2007 00:00 06:00 6.00 3,209 3,798 INTRM1 DRILL DDRL P Dir Drill ahead f/ 3209'- 3798' MD 3410' TVD 06:00 12:00 6.00 3,798 4,302 INTRM1 DRILL DDRL P Dir Drill ahead f/ 3798'- 4302' MD (3846' TVD). PU 157 klbs, SO 112 klbs, Rot Wt 128 klbs, ONB Torq 7700 ft-lbs, OFB Torq 6810 ft-lbs. ECD's 10.72 pg- 12:00 18:00 6.00 4,302 4,824 INTRM1 DRILL DDRL P Dir Drill ahead f/ 4302'- 4824' MD 4291' TVD). 18:00 00:00 6.00 4,824 5,315 INTRM1 DRILL DDRL P Dir Drill ahead f/4824 - 5315' MD (4711' TVD). PU 193 klbs, SO 125 klbs, Rot Wt 153 klbs, ONB Torq 8700 ft-lbs, OFB Torq 9000 ft-lbs. ECD's 10.85 ppg, Max Gas 255 units. 07/19/2007 00:00 07:00 7.00 5,315 5,870 INTRM1 DRILL DDRL P Drill f/ 5315'- 5870' MD ( 5238' TVD). PU 210 klbs, SO 138 klbs, Rot Wt 167 klbs. ONB Torq 9110 fl-lbs, OFB Tor 8920 ft-lbs. ECD's 10.74 07:00 08:30 1.50 5,870 5,870 INTRM1 DRILL CIRC P Circulate, pump sweeps w/ rotate and recip pipe to clean hole in prep for wiper trip. 08:30 12:00 3.50 5,870 5,870 INTRM1 DRILL TRIP P PJSM, BD Top Drive, and POOH f/ 5870' - 2565' for wiper trip. 12:00 12:30 0.50 5,870 5,870 INTRM1 RIGMN SVRG P Service and lube rig. 12:30 14:30 2.00 5,870 5,870 INTRM1 DRILL TRIP P TI t/ 5787', wash f/ 5787' - 5870'. Hole condition good. 14:30 17:00 2.50 5,870 5,870 INTRM1 DRILL CIRC P CBU x 3 w/ pumping 2 sweeps, increase mud wt to 9.9 ppg as slight flow noticed. Well stable. 17:00 18:00 1.00 5,870 5,870 INTRM1 DRILL PULD P PJSM, POOH w/ laying down 5" DP f/ 5870'- 5409'. Monitor well for flow. 18:00 18:30 0.50 5,870 5,870 INTRM1 DRILL CIRC P Pump dry job, flow check well, OK. BD top drive. 18:30 00:00 5.50 5,870 5,870 INTRM1 DRILL PULD P Continue POOH w/ laying down 5" DP f/ 5409'- 859'. 07/20/2007 00:00 02:30 2.50 5,870 5,870 INTRM1 DRILL PULD P Continue POOH to top of MWD. 02:30 04:30 2.00 5,870 5,870 INTRM1 DRILL PULD P PJSM, remove radioactive sources from MWD. Lay down MWD tools 04:30 06:00 1.50 5,870 5,870 INTRM1 DRILL PULD P Finish layout of remaining BHA. Flush motor and lay down. 06:00 08:30 2.50 5,870 5,870 INTRM1 WELCT EQRP P Drain stack, pull wear ring, set test plug. Change out lower pipe rams to 7" f/ cs . 08:30 09:00 0.50 5,870 5,870 JINTRM1 WELCT EQRP P Test 7" rams 250 / 3500 psi, OK. 0 07/20/2007 09:00 12:00 3.00 5,870 15,870 INTRM1 CASIN( RURD P Pull test plug and rig up to run 7" csg. PJSM w/ crews and start running csg. 12:00 21:00 9.00 5,870 5,870 INTRM1 CASIN RNCS P Run 142 jts (5286') of 7" 26# L-80 BTCM csg, land at 5854.5 ft. Top fit shoe at 5853', 2 jts 7" csg, top flt clr at 5768', then 140 jts to surface. Turbolizers installed on jts 1 & 2, bow spring centralizers installed jts 3 - 14, centering guides installed jts 130, 133, 136, 139, 141 & 142. Casing in place 2100 hrs w/ circulation established @ 2580', 3480', 4300', 5110' and 5850'. Final PU 197 klbs, Final SO 125 klbs. 21:00 21:30 0.50 5,870 5,870 INTRM1 CASIN CIRC P CBU @ 5 bpm & 380 psi. Hole condition good, 100 % returns. 21:30 22:00 0.50 5,870 5,870 INTRM1 CASIN( RURD P Rig down spiders, blow down top drive, nq up cmt head. 22:00 00:00 2.00 5,870 5,870 INTRM1 CEMEIN CIRC P Circulate and condition mud f/ cement job @ 5 bpm & 330 psi. PJSM, batch up cmt, pump 5 bbls H2O, ptest cmt lines 3500 psi. 07/21/2007 00:00 01:30 1.50 5,870 5,870 INTRMI CEMEI� DISP P Pump 29 bbls 13 ppg wash, drop bottom plug, mix/pump 47 bbls 15.8 ppg "G" cement, drop top plug, displace 5 bbls w/ cmt pumps, switch over and displace remainder w/ rig. Calculated displacement to bump plug, 220.7 bbls, Actual displacement 219.2 bbls to bump plug. Bumped plug w/ 1000 psi over displacement pressure @ 0115 hrs. Hold pressure 15 minutes, release pressure to check floats, OK. Cement in place at 0130 hrs. 01:30 04:30 3.00 5,870 5,870 INTRM1 CASIN( RURD P RD cementers and cmt eq. Drain and remove cmt head, RD lines. RD and remove csg running equipment. Kick -out unused 7" casing from pipe shed. Drain Stack. Back out landing 't and lay down. 04:30 05:30 1.00 5,870 5,870 INTRM1 WELCT EQRP P Drain and flush stack, prepare to installpack-off in 7" x 9 5/8" csg head. 05:30 09:30 4.00 5,870 5,870 INTRM1 WELC OTHR P Install 7" x 9 5/8" pack -off in wellhead, c/o upper and lower rams to 4" in stack. Freeze protect 7" x 9 5/8" annulus, flush w/ 110 bbls seawater, dis lace w/ 85 bbls diesel. 09:30 11:00 1.50 5,870 5,870 INTRM1 WELM BOPE P RU & test upper & lower pipe rams, floor and dart valves to 250 / 3500 psi, OK. 11:00 16:00 5.00 5,870 5,870 INTRM1 DRILL PULD P Load and tally 4" DP, HWDP, BHA, c/o saver sub on top drive, prepare to PU and RIH. 16:00 17:00 1.00 5,870 5,870 INTRM1 DRILL RURD P Change out rig tongs. 17:00 17:30 1 0.50 15,870 15,870 INTRM1 I DRILL IRURD IP I Install wear bushing 07/21/2007 17:30 19:00 1.50 5,870 5,870 JINTRM1 DRILL I PULD P I RIH w/ 36 jts to make up 12 stands for drilling. 19:00 19:30 0.50 5,870 5,870 INTRM1 DRILL TRIP P ITOH and rack back 12 stands. 19:30 21:00 1.50 5,870 5,870 INTRM1 DRILL PULD P PJSM, PU and MU BHA. 21:00 22:30 1.50 5,870 5,870 INTRM1 DRILL OTHR P Upload MWD, RU pump to shallow test, OK. 22:30 00:00 1.50 5,870 5,870 INTRM1 DRILL PULD P RIH w/ picking up 4" DP singles t/ 1058'. 07/22/2007 00:00 07:00 7.00 5,870 5,870 INTRM1 DRILL PULD P RIH w/ 6 1/8" Bit t/ 5750' w/ picking up 4" DP singles. Broke circulation at 3403'. Tagged cmt at 5750'. 07:00 10:30 3.50 5,870 5,870 INTRM1 DRILL CIRC P Kelly up, start displacing out mud and bring mud wt to 9.5 ppg and condition for csg test. 10:30 11:30 1.00 5,870 5,870 INTRM1 CASIN( OTHR P PJSM, RU and pressure test 7" casing to 3000 psi f/ 30 minutes, recorded on chart. OK. 11:30 12:00 0.50 5,870 5,870 INTRM1 CASIN RURD P RD test lines used for testing csg. 12:00 15:00 3.00 5,870 5,870 INTRM1 CEME� COCF P Wash f/ 5750' to 5765', tag float collar. Drill out float collar, shoe track and shoe. 15:00 15:30 0.50 5,870 5,890 INTRM1 DRILL DDRL P Drill 20 feet of new hole to 5890'. 15:30 16:30 1.00 5,890 5,890 INTRM1 DRILL CIRC P Circulate and condition mud, prepare for FIT. 16:30 18:00 1.50 5,890 5,890 INTRM1 DRILL FIT P Perform FIT to 16 ppg MWE. Rig down test equipment. 18:00 22:30 4.50 5,890 6,030 PROD1 DRILL DRLG P Drill ahead f/ 5890'- 5970'. Penetrate 10 ft of top of Bermuda. Perform flow check, none. Continue drlg to planned core point of 6030' MD (5396' TVD). Pump sweep, CBU, flow check, none. Validate 9.5 ppg mud sufficient to hold back formation fluids, order out 9.5 ppg FLO-PRO mud s stem. 22:30 23:00 0.50 6,030 6,030 PROM DRILL TRIP P POOH 2 stands into shoe. Perform flow check, none. 23:00 00:00 1.00 6,030 6,030 PROM DRILL WOSP P Wait on mud delivery while cleaning mud pits and loading liner in pipe shed. 07/23/2007 00:00 02:30 2.50 6,030 6,030 PROM DRILL WOSP P Clean mud pits, slip and cut drill line w/ wait on new mud system for core operations.. 02:30 05:00 2.50 6,030 6,030 PROM DRILL WOSP P Continue clean pits, wait on mud 05:00 08:00 3.00 6,030 6,030 PROW DRILL CIRC P Wash back to bottom w/ 2 stds pulled, pump sweep, prepare to displace out LSND mud system w/ FLO-Pro. Pump sweep, displace mud w/ FloPro System. 08:00 10:30 2.50 6,030 6,030 PROD1 DRILL TRIP P POOH f/ 6030'- 5794', Fill trip tank and pits. PU 138 klbs, SO 102 klbs. Rot Wt 132 klbs. 07/23/2007 10:30 14:00 3.50 6,030 1 6,030 PROM DRILL TRIP P Continue TOOH f/ 5794'- 54'. 14:00 14:30 0.50 6,030 6,030 PROM DRILL DHEQ P Download MWD 14:30 15:00 0.50 6,030 6,030 PROW DRILL PULD P Lay down BHA 15:00 18:00 3.00 6,030 6,030 PROW CORING PULD P PJSM, RU to run Core Barrels. PU core barrels. 18:00 19:00 1.00 6,030 6,030 PROM CORING PULD P PU HWDP off racks 19:00 22:00 3.00 6,030 6,030 PROM CORING TRIP P TIH w/ core barrel for core run #1 t/ 5837' 22:00 00:00 2.00 6,030 6,030 PROM CORIN CIRC P Circulate at shoe w/ condition mud to adjust rheology. 07/24/2007 00:00 00:30 0.50 6,030 6,030 PROM CORINi CIRC P Treat mud properties. 00:30 01:00 0.50 6,030 6,030 PROD1 CORIN TRIP P RIH w/ last two stands w/ circulating and prepare to begin coring operations. 01:00 04:30 3.50 6,030 6,068 PROM CORING OTHR P Drill w/ core bit f/ 6033'- 6068'. Unable to core further, decision made to POOH to retrieve core and inspect barrel and bit. (NOTE: Start core depth adjusted deeper to account for deeper tag up w/ core bbl. Exp of jar and bumper sub not accounted for in drill-off depth of last bit run). 04:30 06:00 1.50 6,068 6,068 PROM CORIN TRIP P TOH w/ core barrel #1. 06:00 12:00 6.00 6,068 6,068 PROM CORING TRIP P Continue POOH w/ Core Barrel f/ Core Run #1. 12:00 19:00 7.00 6,068 6,068 PROM CORING TRIP P Continue POOH w/ Core Barrel f/ Core Run #1 19:00 21:00 2.00 6,068 6,068 PROM CORING PULD P Examine core bit, Ok. Break and lay down bit. Break out and lay down inner core barrels, 100% core retrieved (35'). PU and install new inner barrels. MU bit, PU BHA and prepare to RIH for Core Run #2. 21:00 00:00 3.00 6,068 6,068 PROM CORIN TRIP P TIH w/ core BHA for Core Run #2 t/ 5837' 07/25/2007 00:00 01:00 1.00 6,068 6,068 PROW CORIN OTHR P Wash to bottom. 01:00 08:00 7.00 6,068 6,087 PROD1 CORIN OTHR P Core f/ 6068' - 6087'. Note pump press loss. 200 psi / 1 hr. 08:00 09:00 1.00 6,087 6,087 PROD1 CORING OTHR T Troubleshoot surface equip for press loss. Determine possible washout in drill string / core assy. Lose addtnl 400 psi / 10 min while troubleshoot. Decision POH for inspection. 09:00 16:00 7.00 6,087 6,087 PROD1 CORINi TRIP T PJSM, POH for washout inspection. No washout discovered. 16:00 19:00 3.00 6,087 6,087 PROM CORIN PULD T Break bit, inspect, OK. Break out inner core barrels. 100% recovery, (19 ft core). Install new inner core barrels, MU bit, prepare to RIH f/ core run #3 07/25/2007 19:00 22:00 3.00 6,087 6,087 PROD1 CORINi TRIP T f/ core run #3 t/ 5935'w/ stops to �TIH circulate and get baseline pressure / rate data. 22:00 22:30 0.50 6,087 6,087 PROW CORIN CIRC T Wash f/ 5935'- 6087'. 22:30 23:00 0.50 6,087 6,087 PROW CORINi CIRC T Drop ball, pump @ 60 spm, 880 psi. Pressure to 1160 w/ ball seat. 23:00 00:00 1.00 6,087 6,102 PROD1 CORINi OTHR P Core drill f/ 6087'- 6102' 07/26/2007 00:00 04:15 4.25 6,102 6,145 PROD1 CORINi OTHR P Core to 6145', TD Core Run #3. Max gas 2533 units, ave gas 200 units. At TD, gas 1600 units and holding. De asser on-line. 04:15 05:00 0.75 6,145 6,145 PROD1 CORINi CIRC P I Break core, circulate bottoms up, gas holdina at 1600 units. 05:00 05:30 0.50 6,145 6,145 PROD1 CORINi CIRC P Reduce pump rate to 51 gpm, circulate at reduced rate to analyze for flow f/ 30 minutes, no increase in flow, as increased to 1800 units. 05:30 06:00 0.50 6,145 6,145 PROW CORING CIRC P Return to full drlg circ rate to evaluate bottoms up gas levels. Preparing for potential mud wt increase. Gas 7200 units at 30 spm. 06:00 08:00 2.00 6,145 6,145 PROD1 WELCT CIRC P Wt up system to 9.8 ppg. Cont circ! stabilize drill fluids. Note gas decrease to from 7500 to 240 units and stable with wt increase. 08:00 08:30 0.50 6,145 6,145 PROD1 WELCT OWFF P PJSM, flow check. Fluid column static. 08:30 17:00 8.50 6,145 6,145 PROD1 CORIN TRIP P POOH f/ core removal following prescribed trip program. Stop at 250' to allow for gas expansion. 17:00 17:15 0.25 6,145 6,145 PROD1 CORINI OTHR P Wait 15 minutes at 250' to allow for gas expansion and pressure equalization in cores. 17:15 18:15 1.00 6,145 6,145 PROD1 CORINi PULD P Break apart barrels, lay down cores. 100% recovery 60 ft). 18:15 20:15 2.00 6,145 61145 PROD1 CORIN( PULD P PU new inner barrels, make up bit, prepare to RIH for core run # 4. Gas breaking out at surface in wellbore. 20:15 21:45 1.50 6,145 6,145 PROD1 CORINi TRIP P RIH w/ coring BHA, w/ stops at 4000 ft and shoe to fill pipe. Significant gas and oil show at surface on TIH due to displacement of DP. Gas 7000+ units at surface. 21:45 00:00 2.25 6,145 6,145 PROD1 CORIN CIRC P Noted 3 bbls gain, well starting to flow, break circulation, monitor well, well stable w/ pumping, wash f! 6030'- 6145', well flow stopped, volume/ flow stable. Ramp up to 60 spm w/ circulating out gas, gas levels to 8000 units, reduced rate to 20 spm to maintain at manageable levels. No improvement seen in levels, begin bump mud wt to 10.0 ppg• 07/27/2007 00:00 02:30 2.50 6,145 6,145 PROD1 CORING CIRC P Circulate w/ condition mud and build wt to 10 ppg. Max gas 5000 units at start, 400 units when complete mud system treated. 02:30 06:00 3.50 6,145 6,170 PROD1 CORIN OTHR P Core drilling f/ 6145'- 6170'. 06:00 21:00 15.00 6,170 6,207 PROW CORIN OTHR P Core drilling f/ 6170'- 6207', core barrel full. Noted 6 bbls loss in 1 1/2 hrs. 21:00 22:00 1.00 6,207 6,207 PROD1 CORING CIRC P Circulate w/ monitor well bore. At drilling stop, & circ at 60 spm, slight fluid loss, reduce rate f/ 60 spm - 35 spm, well returned 1 bbl mud then stabilized, at 20 spm, 1 bbl mud returned then stable At pumps off, no flow, well static. Prep to POOH f/ core barrel change. Break core. 22:00 00:00 2.00 6,207 6,207 PROD1 CORIN TRIP P TOH w/ core barrels for retrieval. 07/28/2007 00:00 07:00 7.00 6,207 6,207 PROD1 CORIM TRIP P TOH w/ Core #4. Normal drag, hole fill. No gain / loss. Wait on gas at 240 ft. 07:00 08:00 1.00 6,207 6,207 PROD1 CORINi RECR P Flow check, lay do core and core assy. 100% recovery. 08:00 09:00 1.00 6,207 6,207 PROD1 CORING PULD P PJSM, MU core assy #5, RIH same. 09:00 11:00 2.00 6,207 6,207 PROD1 CORING TRIP P Flow check, follow core barrel with 4" DP to 6126 ft. 11:00 11:30 0.50 6,207 6,207 PROD1 CORIN CIRC P Fill pipe, cont displace gas cut mud. 11:30 12:30 1.00 6,207 6,207 PROD1 CORING WOP NP Wait on Baker core hands to arrive. 12:30 13:00 0.50 6,207 6,207 PROD1 CORIN CIRC P Drop ball, pump do same. BU gas 3400 units max decreasing and stabilizing at 240 units. 13:00 00:00 11.00 6,207 6,230 PROD1 CORING OTHR P Flow check, commence core ahead 6-1/8 X 2-5/8, 6207 - 6230'. 07/29/2007 00:00 02:00 2.00 6,230 6,233 PROD1 CORINI OTHR P Core drilling f/ 6230'- 6233'. Decision made by geology to forgo remaining 7 ft of core drilling due to slow ROP. 02:00 02:30 0.50 6,233 6,233 PROW CORINi CIRC P Prepare for TOH w/ core #5. Check mud, reduce pump rate and evaluate for breathing / flow, none. SD pumps, flow check, none. 02:30 10:00 7.50 6,233 6,233 PROW CORINi TRIP P TOH per trip speed schedule for pulling cores f/ 6233 ft. Normal drag, no gain / loss. Correct hole fill. 10:00 10:30 0.50 6,233 6,233 PROD1 WELCT OWFF P Flow check at BHA, wellbore stable. 10:30 12:00 1.50 6,233 6,233 PROD1 CORING TRIP P Handle BHA, lay do core. 12:00 13:00 1.00 6,233 6,233 PROD1 WELCT BOPE P Prepare for BOPE test. 13:00 14:00 1.00 6,233 6,233 PROD1 WELCT OWFF T Note well percolating (no flow), while set test plug. LD test plug, fill stack, observe for flow. Continued percolation with no flow. Decision to trip to btm for circulation. Flow check in 5 std increments. 14:00 16:00 2.00 6,233 6,233 PROW CORINi TRIP T PJSM, flow check, (column dropping slightly as gas escapes), RIH for C/C fluids. 16:00 20:00 4.00 6,233 6,233 PROD1 WELCT CIRC T PJSM, circ gas cut mud through choke as precaution, max gas 988 units through gas buster. No gain / loss. Building mud wt to 10.2 20:00 22:30 2.50 6,233 6,233 PROD1 WELCI CIRC T Open Choke, observe well, static, inc pump rate to evaluate well stability. While pumping @ 5 bpm, steady loss to 15 bbls, back off pump rate to 4 bpm, stable, back rate to 1.5 bpm, flow back, at 1 bpm, recd all fluid pumped away, back. SD pumps to observe well. X, /',off 22:30 23:00 0.50 6,233 6,233 PROW WELCT OWFF T Monitor well f/ 1/2 hr, steady slow flow, 1 bbl / 30 min, decide to CBU for determination of influx type if any. 23:00 00:00 1.00 6,233 6,233 PROD1 WELCT CIRC T CBU @ 2.5 bpm, 640 psi, well stable. Bottoms up had 414 units gas, vol in = vol out, mud out good condition wl correct wt on BU. 08/11/2007 00:00 01:30 1.50 0 0 COMPZ EVALFI PLT P Continue logging out of hole with FMI / Dipole Shear Sonic from 6833' to 5800' ELM. Rig down SWS & load out tools. 01:30 02:30 1.00 0 0 COMPZP CASIN( RURD P Rig up to run 4.5" liner. 02:30 08:30 6.00 0 1,200 COMPZJ CASIN( PUTB P PJSM picking up 4.5" liner. Maker up PBR hanger & packer. 50k up 50 k dn. 08:30 09:30 1.00 1,200 1,200 COMPZ CASIN( OTHR P Crane work. (load out sperry Geo -Tap unit & load injection line spooler on floor. 09:30 14:00 4.50 1,200 5,854 COMPZ CASIN RUNL P RIH w/ 4.5" liner on drill pipe to shoe 5854'. 125k up 90k dn. 14:00 16:00 2.00 5,854 5,854 COMPZ CASIN( CIRC P Circ. capacity of liner & dp & circ. out as 3650 units on bottoms up. 16:00 17:00 1.00 5,854 5,854 COMPZ CASIN( OTHR P Break down top drive -make up cement head while monitoring well. 17:00 17:30 0.50 5,854 6,830 COMPZ CASIN( RUNL P RIH from 5854' to 6830' on 4" dp. 17:30 21:00 3.50 6,830 6,836 COMPZ CASIN( CIRC P Rig up cement head break circ. stage pumps up to 3 bpm -hole taking fluid pumping more than 3 bpm. Circ. & reciprocate 135k up 100k dn. 21:00 22:00 1.00 6,836 6,836 COMPZ CEME OTHR P Pump cement as per program. 22:00 22:30 0.50 6,836 6,834 COMPZJ CEME DISP P Displace cement w/ 77 bbls. bump plug & set liner hanger w/ 3200 psi @ 6834' Top of liner 0) 5646'. X, /',off 08/11/2007 22:30 23:30 1.00 6,834 6,834 COMPZ CEMEN CIRC P Set packer -release tool. Reverse out cement @ 6 bpm. Recovered 12 bbls. cement. Circ. additional 145 bbls. @ 6 bpm to wash cement out of drill pipe prior to laying down same. 23:30 00:00 0.50 6,834 6,834 COMPZ CEMEn OTHR P Pressure test liner top packer to 2000# & rig down cement head. 08/12/2007 00:00 01:00 1.00 6,833 6,833 COMPZ CEMEN RURD P PJSM Continue rigging down cement head & equipment. 01:00 02:30 1.50 6,833 6,833 COMPZP RIGMN SVRG P PJSM Slip & cut drlg. line. 02:30 09:00 6.50 6,833 0 COMPZP DRILL TRIP P Pump dry job. Blow down top drive & POH laying down 4" DP. 09:00 09:30 0.50 0 0 COMPZP DRILL PULD P Break running tool & lay down stinger. 09:30 11:00 1.50 0 1,670 COMPZP DRILL TRIP P PJSM RI w/ 10 stands dp & HWDP to 1670'. 11:00 12:00 1.00 1,670 1,670 COMPZP RIGMN SVRG P Service rig & top drive. 12:00 14:30 2.50 1,670 0 COMPZP DRILL TRIP P Lay down 4" dp & HWDP. 14:30 15:30 1.00 0 0 COMPZP DRILL OTHR P Pull wear ring & set test plug. 15:30 17:30 2.00 0 0 COMPZ WELCT BOPE P PJSM Change bottom rams to 3.5" & test same. Rig down testing equipment. 17:30 19:30 2.00 0 0 COMPZP RPCOJ RURD P Rig up handling equipment & injection lines ooler to run 3.5" tb . 19:30 00:00 4.50 0 1,900 COMPZP RPCON PULD P PJSM RIH w/3.5" completion as per program. 08/13/2007 00:00 06:00 6.00 1,900 5,659 COMPZP RPCOh PULD P Continue running 3.5" completion string from 1900' to 5659' Tag with No -Go. 06:00 08:00 2.00 5,659 5,659 COMPZJ RPCOb HOSO P Locate seals & space out. 08:00 08:30 0.50 5,659 5,600 COMPZJ RPCOh OTHR P Make up landing jt. & hanger. 08:30 11:00 2.50 5,600 5,600 COMPZP RPCOh CIRC P Displace well to seawater @ 7 bpm & spot 10 bbls. corrosion inhibitor. 11:00 13:30 2.50 5,600 5,656 COMPZP RPCOK DHEQ P Land hanger run in lock down screws rig up & test tbg. & annulus to 2500-3000 psi 30 mins. & chart same. Rig down testing equipment & tongs. (Tbg. landed w/ no-go 3.28' above no-go tag. Landed @ 5656'. 13:30 17:00 3.50 5,656 5,656 COMPZP RPCOh NUND P Change out upper & lower pipe rams to 5". Remove 4" XT -39 saver sub. 17:00 22:30 5.50 5,656 5,656 COMPZP RPCOh NUND P Nipple down 11" BOPE. 22:30 00:00 1.50 5,656 5,656 COMPZP RPCON NUND P Nipple up adapter flange. 08/14/2007 00:00 02:30 2.50 0 0 COMPZP RPCOII NUND P NU FMC tubing head adapter flange & tree. Test adapter void & tree to 5000 psi. Test Chemical Injection line Dackoff. OK. Pull TWC. ConocoPhillips Time Log Summary WetivWew Web Reposing �.. � 77' 777 . MET Well Name: 2N-327 Job Type: DRILLING ORIGINAL 999h \E DMth Mik... 1%86:� ,•� T'; �\�:. , ���� ' /Vary 07/30/2007 00:00 01:30 1.50 6,233 6,233 PROM WELC CIRC T pump rate w/ observe volumes. Diagnose well issue as breathing problem. Back off pump rate to 10 spm while letting well stabilize, prepare dry job to POOH. 01:30 06:00 4.50 6,233 6,233 PROM WELCI TRIP T Pump dry job, pull 4 stands, monitor well, static. Let pits equalize, strap all its and POOH for BOPE test. 06:00 09:30 3.50 6,233 6,233 PROM WELCT BOPE P PJSM, Test BOPE, all components, 250 / 3500 psi. Perform time / volume / press test accumulator. All tests successful, no re -tests. Witness waived by Mr Chuck Scheve AOGCC. 09:30 13:00 3.50 6,233 6,233 PROD1 DRILL I PULD P PJSM, MU BHA #12 (6-1/8 rotating/ MWD / Data Lo 13:00 16:00 3.00 6,233 6,233 JPROD1 DRILL TRIP P Flow check at BHA, R1 4" DP to 6231 ft. 16:00 17:00 1.00 6,233 6,233 PROD1 DRILL CIRC P C/C drlg fluids, circ BU gas (5010 units 17:00 17:30 0.50 6,233 61233 PROM WELCI OWFF P Flow check. 17:30 20:30 3.00 6,233 6,233 PROD1 EVALFI DLOG P Prepare and POH MADD pass 129 f h, 6233 - 5830 bit depth. 20:30 21:30 1.00 6,233 6,233 PROW DRILL TRIP P Trip w/ circ f/ 5830'- 6233'. Prepare to drill ahead. 21:30 00:00 2.50 6,233 6,316 PROM DRILL DRLG P Drill ahead f/ 6233'- 6316' MD. 07/31/2007 00:00 05:30 5.50 6,316 6,514 PROM DRILL DRLG P Drill f/ 6316'- 6514' MD (Esker Core Pt. 05:30 07:30 2.00 6,514 6,514 PROD1 DRILL CIRC P CBU, reduce pump rate CBU and allow wellbore breathing to stabilize. Ramp do to 30 SPM 15 min. 07:30 08:00 0.50 6,514 6,514 PROD1 WELCT OWFF P Flow check, wellbore stable. 08:00 10:30 2.50 6,514 6,514 PROM CORIN TRIP P PJSM, POH to BHA. Normal drag. No gain / loss. Correct hole fill. 10:30 12:30 2.00 6,514 6,514 PROM CORING PULD P PJSM, handle BHA. download MWD, LD BHA. 12:30 13:30 1.00 6,514 6,514 PROD1 CORIN PULD P MU BHA #12, (6-1/8 X 2-5/8 Core assy), flow check, RIH same. 13:30 16:00 2.50 6,514 6,514 PROM CORIN TRIP P Flow check, follow BHA with 4" DP to 6500 ft. No do drag, no gain / loss. Correct pipe displacement. 16:00 17:30 1.50 6,514 6,514 PROD1 CORINJ CIRC P Circ / cond gas cut mud. Cont circ BU.(Max gas 1942 units) drop ball, prepare for cores. 07/31/2007 17:30 00:00 6.50 6,514 6,531 PROD1 CORING OTHR P Commence core 6514 -6531' (PP 1220 psi 59 spm 144 gpm 15-18k wob 70 rpm tq 4600 ART 11.01 hrs. 08/01/2007 00:00 12:30 12.50 6,531 6,574 PROD1 CORING OTHR P Coring Core #6 from 6531' to 6574 ft. Full core bbl. No gain / loss. Max BG as 64 units. 12:30 13:30 1.00 6,574 6,574 PROD1 CORING CIRC P Break core, mix / pump dry job. 13:30 00:00 10.50 6,574 1963 PROD1 CORIN TRIP P Flow check, POH for core from 6574' to 963'. 08/02/2007 00:00 03:30 3.50 963 0 PROD1 CORING TRIP P POH w/ core #6 as per program 03:30 05:30 2.00 0 0 PROD1 CORIN RECR P Lay down core. Recovered 14' core. appears bbl. jammed. Bearings in inner bbl. locked up. Change same & make up new inner bbl. & stand core bbl. in derrick. 05:30 07:00 1.50 0 0 PROD1 CORINI PULD P Make up clean out BHA, 6-1/8 bit, RIH same 07:00 09:00 2.00 0 5,833 PROD1 CORIM TRIP P Flow check, RIH 4" DP to 5833 ft. 09:00 10:30 1.50 5,833 5,833 PROD1 RIGMN SVRG P PJSM, Cut drlg line, service rig. 10:30 11:00 0.50 5,833 6,497 PROW CORIN TRIP P Flow check, RIH 4" DP to 6497 ft. 11:00 12:00 1.00 6,497 6,497 PROW WELCT CIRC P PJSM, C/C fluids, circ BU gas out of wellbore. Max 5480 units. No attending flow. 12:00 12:30 0.50 6,497 6,574 PROD1 CORIN WASH P Wash 6497 - 6574. 1-1/2 ft fill. 12:30 13:00 0.50 6,574 6,575 PROD1 CORING OTHR P Drill one addtnl ft for cleanup. (Trip Gas 5385 units. 13:00 17:00 4.00 6,575 6,575 PROD1 CORING TRIP P PJSM, POH to BHA for core bbl. 17:00 17:30 0.50 6,575 0 PROW CORING PULD P Flow check, handle BHA, LD bit. 17:30 19:30 2.00 0 0 PROD1 CORING PULD P PJSM-Break apart core bbl.lay down core bbl. & inner bbl.. 19:30 21:00 1.50 0 0 PROD1 CORING OTHR T Hang blocks & repair brakes. (Brake block on drillers side came off due to bolts broke in same. Install brake block & new bolts. Install guards back Ion drawworks. 21:00 22:30 1.50 0 60 PROD1 CORING PULD P PJSM-make up new core bbl. & inner bbl. make up bit. 22:30 00:00 1.50 60 2,710 PROD1 CORINi TRIP P RIH w/ HWDP & dp to 2710'. w/ Core bbl. V. 08/03/2007 00:00 02:00 2.00 2,710 5,835 PROD1 CORINi TRIP P RIH from 2710' to 5835' for Core V. 02:00 03:00 1.00 5,835 6,562 PROD1 CORINI WASH P Cautious wash from 5835' to 6562'. 03:00 09:00 6.00 6,575 6,594 PROD1 CORINJ OTHR P Set parameters-wash down to 6575' & cutting core #7 from 6575' to 6594 ft. Note erratic pump press / ROP. Decision to POH for core bbl 08/03/2007 09:00 17:00 8.00 6,594 0 PROD1 CORING TRIP P PJSM, flow check, break core, POH as per trip schedle. 17:00 18:00 1.00 0 0 PROW CORING RECR P PJSM-Remove inner bbls. & lay down same. Recovered 16' core. 18:00 20:00 2.00 0 0 PROD1 CORIN( PULD P Make up core bbl. assembly w/ 30' bbl. 20:00 21:00 1.00 0 0 PROW CORIN OTHR P Service top drive -blocks & swivel. 21:00 23:30 2.50 0 6,564 PROW CORINJ TRIP P RIH w/ core assembly #8 to 6564'. 23:30 00:00 0.50 6,564 61564 PROD1 CORIN CIRC P Break circ. -circ. out gas. Max units 3870. Up wt. 150k do 100k rot 120k. 08/04/2007 00:00 00:30 0.50 6,564 6,594 PROW CORING CIRC P Circ. out gas prior to coring. (max gas 3880 units. Set parameters. & run to bottom @ 6594'. 00:30 11:00 10.50 6,594 6,624 PROD1 CORIN, OTHR P Cutting core #8 from 6594' to 6624'. MD. 5985 TVD. 11:00 11:30 0.50 6,624 6,624 PROD1 CORIN( CIRC P Break core & CBU. 11:30 19:00 7.50 6,624 0 PROW CORIN TRIP P Monitor well & POH as per trip schedule. 19:00 20:00 1.00 0 0 PROW CORIM PULD P Break bit & lay down core bbl. Make up new core bbl. & lay down. Recovered 18' of 30' core. 20:00 20:30 0.50 0 0 PROD1 CORING PULD P PJSM=Make up clean out assembly. 20:30 23:30 3.00 0 6,592 PROD1 CORIN TRIP P RIH to 6592'. 23:30 00:00 0.50 6,592 6,625 PROD1 CORING CIRC P Break circ. Set parameters. wash down & tag fill @ 6619'.. Clean out fill & drill 1' from 6624 to 6625'. Up wt 150k do 100k Rot 120k. pp 1650 psi 100 spm rpm 80 Max gas 3800. 08/05/2007 00:00 00:30 0.50 6,625 6,625 PROD1 CORING CIRC P PJSM-CBU 20 bbls. loss on drlg. mud. 00:30 01:00 0.50 6,625 6,625 PROD1 CORIN OTHR P Blow down top drive & monitor well. well static 01:00 01:30 0.50 6,625 5,833 PROD1 CORINI TRIP P POH to 5833'. Hole not taking fluid. Monitor well @ shoe. Gained 2 bbls. 01:30 02:00 0.50 5,833 6,625 PROD1 CORING TRIP P RIH to 6625' 02:00 03:00 1.00 6,625 6,625 PROD1 CORINI CIRC P CBU @ 140 gpm 850 psi. 4200 units as on bottoms up. Hole static. 03:00 06:00 3.00 6,625 800 PROD1 CORING TRIP P POH for core # 9 to BHA. No gain / loss. 06:00 06:30 0.50 800 0 PROD1 CORING TRIP P Flow check, handle BHA, break bit. 06:30 07:30 1.00 0 800 PROD1 CORING TRIP P MU core assy, RIH same. 07:30 10:00 2.50 800 6,600 PROD1 CORINI TRIP P Flow check, follow BHA with 4" DP to 6600 ft. 10:00 11:00 1.00 6,600 6,600 PROD1 CORING CIRC P Circ gas cut mud to surface. Max gas 3450 units. No attending flow. 11:00 00:00 13.00 6,625 6,656 PROD1 CORINI OTHR P Core 6625 -6656'. Core # 9. Up wt 150k do 100k rot 120k pp 1050 psi 62 spm 5500 tq wob 15k rpm 60 max gas 100 units. 08/06/2007 00:00 07:30 7.50 6,656 0 PROD1 CORINi TRIP P Break core # 9 & POH as per tripping schedule 07:30 08:30 1.00 0 0 PROD1 CORIN RECR P Flow check, handle BHA, LD core. 27 ft recovery. 08:30 12:30 4.00 0 926 PROD1 DRILL PULD P PJSM, MU BHA, 6-1/8 drill bit, MWD, lGeo-Tap, Nuke, DGR/RES. RIH same. 12:30 16:00 3.50 926 5,800 PROD1 DRILL TRIP P Flow check, follow BHA with 4" DP to 7" shoe at 5800 ft. 16:00 17:00 1.00 5,800 5,800 PROW RIGMN SVRG P Flow check, slip / cut drlg line. 17:00 17:30 0.50 5,800 6,600 PROD1 DRILL TRIP Flow check, RIH to 6600 ft. 17:30 18:00 0.50 6,600 6,656 PROD1 DRILL CIRC FP Wash 6600 - 6656 ft, 2 ft fill. CBU, max as 3554 units. 18:00 21:00 3.00 6,656 6,656 PROD1 EVALFI DLOG POH, Commence MADD pass 6656 -6510' MD.RIH to 6656'. 21:00 00:00 3.00 6,656 6,721 PROD1 DRILL DDRL P Drlg. new hole from 6656' to 6721'.0 MD 6081' TVD. 08/07/2007 00:00 10:00 10.00 6,721 6,836 PROD1 DRILL DDRL P Drlg. 6 1/8" hole from 6721' to 6836'. MD 6195' TVD. WOB 20k tq 6490 rpm 95 pp 2280 psi 90 spm ecd 12.27 up 163k do 110k rot 125k. 10:00 11:00 1.00 6,836 6,836 PROD1 DRILL CIRC P Pump hi vis pill & CBU. 11:00 11:30 0.50 6,836 6,836 PROD1 EVALF1 PLT P Madd pass from 6656' to 651 T. 11:30 17:30 6.00 6,836 6,836 PROD1 EVALFI PLT P Geo-Tap as per schedule. Test 15 points PP 1650 psi 85 spm. No good sets-all tight or no seals. 17:30 18:00 0.50 6,836 16,836 PROD1 DRILL TRIP P RIH from 6129' to 6836'. 18:00 22:00 4.00 6,836 6,836 PROD1 DRILL CIRC P CBU weight up mud system to 10.5# 22:00 23:00 1.00 6,836 5,854 PROD1 DRILL TRIP P Monitor well & POH from 6836' to 5854'. pulled 15k over string wt. @ 5996' & 5900'. Monitor well @ shoe. Hole not taking correct amount of fluid. 23:00 23:30 0.50 5,854 6,836 PROD1 DRILL TRIP P RIH from 5854' to 6836'. took 5k string wt. 6000'. 23:30 00:00 0.50 6,836 6,836 PROW DRILL CIRC P CBU @ 62 spm 1300 psi. 454 units as on bottoms up. 08/08/2007 00:00 01:00 1.00 6,836 6,836 PROD1 DRILL CIRC P CBU prior to trip for E-Line logs. 01:00 06:00 5.00 6,836 0 PROW DRILL TRIP P POH for wire line logs. 06:00 07:00 1.00 0 0 PROD1 DRILL PULD P Download MWD. 07:00 08:30 1.50 0 0 PROD1 DRILL PULD P Lay down BHA. 08:30 09:00 0.50 0 0 PROD1 DRILL OTHR P Drain Stack. (Well flowing small strem 09:00 13:30 4.50 0 0 PROD1 DRILL OWFF P Monitor well for flow. (flowing .5 bph) 13:30 16:30 3.00 0 6,813 IPROD1 DRILL TRIP T PJSM-Make up bha & RIH to 6813'. 08/08/2007 16:30 20:00 3.50 6,813 6,836 PROD1 DRILL CIRC T Wash down to 6836. Circ. & build mud wt. to 10.7# (4200 units gas on bottoms u . 20:00 22:30 2.50 6,836 6,836 PROD1 DRILL CIRC T Monitor flow -still flowing -build mud wt. to 10.8#. 22:30 00:00 1.50 6,836 6,836 PROD1 DRILL CIRC T Lost 27 bbls. to hole while circ. & building mud wt. Gained back 25 bbls. while monitoring well. (pumped new mud wt. around @ 140 gpm 1000psi.) 08/09/2007 00:00 03:00 3.00 6,836 6,836 PROD1 DRILL CIRC P CBU @ 34 spm 2 bpm 700 psi. 03:00 05:00 2.00 6,836 5,845 PROD1 DRILL TRIP P Lay down single blow down top drive & POH slow to 5845'. Hole not taking ri ht amount of fluid. 05:00 05:30 0.50 5,845 5,845 PROW DRILL OWFF P Monitor well -small flow. 05:30 06:30 1.00 5,845 6,830 PROW DRILL TRIP P RIH from 5845' to 6795'. Pick up single & wash to 6830'. 06:30 10:00 3.50 6,830 6,830 PROD1 DRILL CIRC P CBU rotate & reciprocate. Up 157k do 110k rot 127k 25 spm 580 psi 40 rpm. 10:00 10:30 0.50 6,830 6,830 PROD1 DRILL OWFF P Shut down pumps & monitor well. Well static. (Production had shut down well # 2N-331 Gas Injection. 10:30 13:00 2.50 6,830 5,850 PROD1 DRILL TRIP P Lay down single. POH pumping @ 1 bpm rot 40 rpm to 5850. 13:00 14:30 1.50 5,850 5,850 PROW DRILL OWFF P Monitor pit volumes & well. Well static. 14:30 18:30 4.00 5,850 0 PROD1 DRILL I TRIP P POH slow hole taking right amount of fluid. 18:30 19:00 0.50 0 0 PROD1 DRILL SFTY P Clear floor. PJSM with schlumberger crew. Monitor well. 19:00 00:00 5.00 0 0 PROD1 EVALFI PLT P Make up logging tools. Rig up SWS. RIH w/ logging tools to 5935 WLM Spud on tight spot.. POH & remove 2 SWS centralizers & RIH. 08/10/2007 00:00 01:30 1.50 0 0 PROD1 EVALFI PLT T POH with logging tools from 5935' Bride Lay down logging tools. 01:30 05:00 3.50 0 5,900 PROW DRILL TRIP T Make up clean out assembly & RIH to 5900' filling pipe every 20 stds. 05:00 07:00 2.00 5,900 5,955 PROD1 DRILL CIRC T Wash down & clean out Bridge @ 5935' took 20k wt. work & wash hole from 5864' to 5955'. up 132k do 100k rot 115k pp 620 40 rpm. 07:00 11:00 4.00 5,955 6,836 PROD1 DRILL CIRC T RIH to 6836'& circ. condition hole. 11:00 13:30 2.50 6,836 5,854 PROD1 DRILL TRIP T POH pumping @ 1.5 bpm rot @ 40 rpm to shoe @ 5854'. 13:30 14:00 0.50 5,854 5,854 PROD1 DRILL OWFF T Monitor well. (Static) 14:00 16:00 2.00 5,854 6,836 PROD1 DRILL TRIP T RIH from 5854' to 6836'. (Work & wash tight spots @ 5908'5935'& 5956'. Untill clean. & CBU. 16:00 17:00 1.00 6,836 5,854 PROD1 DRILL TRIP T POH to shoe on elevators. 17:00 17:30 0.50 5,854 5,854PROW DRILL OWFF T Monitor well. (Static) 0 Page 1 of 1 Maunder, Thomas E (DOA) From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophiliips.com] Sent: Tuesday, December 11, 2007 8:20 AM To: Maunder, Thomas E (DOA) Subject: RE: 2N-327 (207-069) just let me know where I can help. jce From: Maunder, Thomas E (DOA) [maitto:tom.maunder@alaska.gov] Sent: Tuesday, December 11, 2007 8:06 AM To: Eggemeyer, Jerome C. Subject: RE: 2N-327 (207-069) Importance: High Thanks Jerome. As I get other items reviewed, I will send similar requests. Tom From: Eggemeyer, Jerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com] Sent: Tuesday, December 11, 2007 4:26 AM To: Allsup -Drake, Sharon K Cc: Maunder, Thomas E (DOA) Subject: FW: 2N-327 (207-069) Importance: High Sharon, Can you please send the summary reports for 2n-327 to tom. Thanks, Jerome From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska-gov] Sent: Monday, December 10, 2007 3:31 PM To: Eggemeyer, Jerome C. Subject: 2N-327 (207-069) Importance: High Jerome, Further to our message and short discussion last week, would you please submit the more detailed operations summary for the subject well. Thanks in advance. Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC 12/11/2007 RE: Well 2N-327 CJ Maunder, Thomas E (DOA) From: NSK Prod Engr Tech [n1139@conocophillips.com] Sent: Friday, November 02, 2007 8:07 PM To: Maunder, Thomas E (DOA) Subject: RE: Well 2N-327 Tom, 0 Thanks for the reply. You went the extra mile replying late on a Friday! I'll try and word my inquiries better in the future. I always want to double check when I find out we're going to produce a new well the next day. Bob Buchholz / Bob Christensen Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, November 02, 2007 7:51 PM To: NSK Prod Engr Tech Cc: Guy.Schwartz@conocophillips.com Subject: RE: Well 2N-327 Page I of 2 Bob, I think I remember talking with Guy Schwartz about this well and you are correct that producing the Esker interval is described. Again, I don't believe that the 407 has been filed. The way you describe the plans, production is planned for more than 30 days. There really isn't a foul if the 407 is filed for an injector and you produce for more than 30 days. I hope this helps. Sorry it is a little late. Tom Maunder, PE AOGCC -----Original Message ----- From: NSK Prod Engr Tech[mailtoml1_39@conocophillips.com] Sent: Fri 11/2/2007 5:03 PM To: Maunder, Thomas E (DOA) Subject: FW: Well 2N-327 Tom, I see the "Flow Testing" of the well is describe in line #25 in the application for Permit to Drill Document. «2N-327 PERMIT IT.doc>> If I understand the process correctly, we should submit 10403 before 30 days if the decision is to continue produce the well. Thanks, Bob Buchholz 11/3/2007 RE: Well 2N-327 CJ Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager(907)659-7000 (924) > From: NSK Prod Engr Tech > Sent: Friday, November 02, 2007 4:05 PM > To: Thomas Maunder > Cc: CPF2 Prod Engrs > Subject: Well 2N-327 > Tom, > New Tarn 2N-327 (PTD 2070690) is being prepped for temporary > production flow test of the Esker interval for a period of 5 to 14 > days. > After the test is complete, the Esker formation will be isolated in > the wellbore and the Bermuda Formation will be completed and produced > as normal TARN production. The Esker formation lies under the Bermuda > Formation. > > Permission is requested to produce test 2N-327 for 5 to 14 days. > Call or send message with any questions, > > Bob Buchholz / Bob Christensen > Greater Kuparuk Area > Production Engineering Technician > Office (907) 659-7535 NSK-69 > Pager(907)659-7000 (924) 11/3/2007 L� Page 2 of 2 Schlumbogep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4468 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2N-327 11839673 PERF/SBHPjy �-ZC 10/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE 1 — 09/03/07 1 1A-23 11837520 PRODUCTION PROFILE C) I —OOPI 10/04/07 1 2M -09A 11846446 WFL -X-C — 10104/07 1 31-08 11837517 LDL — 10/02/07 1 2M-24 11839670 PRODUCTION PROFILE 10103/07 1 1J-102 11846451 INJECTION PROFILE UZC — ( 10/10/07 1 1Y-02 11837516 INJECTION PROFILE — 10101/07 1 1E-112 11846450 INJECTION PROFILE 10/10/07 1 2T -12A 11839669 LDL 10/02/07 1 213-07 11837522 INJECTION PROFILE (—)TC 10105/07 1 1E-12 11846447 DDL — C&n O 10/08/07 1 2N-327 11839671 SCMT —0(019 10/23/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 13 10/25/07 +Conoccuilli s RffbVED U� .2 4 TRANSMITTAL Alaska Oil & Gas Con CONFIDENTIAL DA TA 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-327 DATE: 10/23/2007 Lemke del ive r n itt Tarn 2N-327 Report, color mudlog prints, CDROM Epoch End of Well Report, 2N-327, L. Browne, Jr./Lundy 08/09/2007; table of contents, equipment and crew, well details, geological data, pressure/formation, drilling data; daily reports; formation logs: Formation MD, TVD; LWD Combo MD and TVD; gas ratio MD and TVD; Drilling dynamics MD and TVD. CD contains: Final well report, morning reports, LAS data, pdf files, DML data; remarks files. Please check off each item as received, promptly sign and return transmittal if not done at time of data delivery. To all data recipients: A/l data is confidential until State ofAlaska ees Hated AOGCC release date CC: Derik Kleibacker, CPA[ Geologist RECEI ED Receipt: Date: OCT 2 4 2007 Alaska Oil Gas tons. Cotnmissi GIS -Technical Data Management I &*Whillips I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.Lemkenu eonocQphil/ips com 070 ` —c)(A ;Pt 15570 Esker/Cairn zone (2N-310 and 2N-327)0 Page 1 of 1 Maunder, Thomas E (DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophillips.com] Sent: Tuesday, October 23, 2007 9:26 AM To: Maunder, Thomas E (DOA) Cc: Walters, Martin N. Subject: Esker/Cairn zone (2N-310 and 24-U7}, —� �"1—rJ Co IZI doh-o�0 Tom, 1 checked into the Tarn Pool rules and these two zones (Esker and Cairn) are covered within that document. We will of course send out 407's after the flow test of these zones and let you know our long term plans. There is a chance they will stay open to production but if P & A is needed will submit a sundry. Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO -1512 guy. i.schwartz@conocophillips.com 10/24/2007 0 0 WELL LOG TRANSMITTAL To: State of Alaska September 26, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-327 AK -MM -5064632 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-327: Digital Log Images: 50-103-20548-00 1 CD Rom Please acknowledge receipt by signing and returning a copy of the transmittal letter to the attention o£ Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. An k i ,49518 3 Date: Signed: 0., 06? 0 15553(. • WELL LOG TRANSMITTAL • To: State of Alaska September 27, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2N-327 AK -MW -506463 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20548-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: a I Signed: ads-v�� � rss�y 16 -Aug -07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-327 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie -on Survey: Window/ Kickoff Survey: Projected Survey: 30.00' MD 0.00' MD (if applicable) 6,836.00' 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 Signed 9a sil Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) Conoco�Phillips Maska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 09, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 76' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: {DECEIVED SEP 1 2 2007 ,Altka Oil & Gas Cons. Commission Anchorage Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 8, 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, J?Arend Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 9/9/2007 Well Name PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2N-327 207-069 12" n/a 12" n/a 3.5 9/8/2007 2N-329 198-067 24" n/a 24" n/a 6 9/8/2007 2N-331 198-117 26" n/a 26" n/a 2 9/8/2007 2N-332 200-079 8" n/a 8" n/a 2 9/8/2007 2N-333 206-025 29" n/a 29" n/a 8.5 9/8/2007 2N-349 200-139 3" n/a 3" n/a 1 9/8/2007 2N-350 201-175 11" n/a 11" n/a 4.5 9/8/2007 2P-438 201-082 1 4' 10" 1 n/a 4' 10" n/a 2 9/8/2007 Schlumbe'gop Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 0 Well Job # pp�(�NO. 4384 041 7007 Company: Alaska Oil & Gas Cons Comm OmA(8 OR 0*1 Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 08/22/07 1 R-27 11850425 FPIT /q/ -/pa 08118/07 1 31-08 11839638 LDL 07/28/07 1 2M-19 11813070 INJECTION PROFILE 07/29/07 1 3G-26 11813071 LDL 07/30/07 1 1R-18 11837482 SBHP/DDL 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U - 1,63 b 07/31/07 1 2C-08 11813073 INJECTION PROFILE' 08/01/07 1 31-1-32 11837483 LDL 08/01/07 1 1Y-10 11837485 INJECTION PROFILE ' ogj-4 / - 08103/07 1 3G-08 11813075 PRODUCTION PROFILE" _ (r, 08/04/07 1 1A-06 11837486 INJECTION PROFILE 08/04/07 1 2N-33713 11837489 PRODUCTION PROFILE 08/06/07 1 2U-08 11813076 LDL Id M 1 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE /t - J12ja 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE / 08/08/07 1 2N-327 11837491 SONIC SCANNER 08/08/07 1 2N-327 11837491 SONIC SCANNER-FMI 08/08107 1 3K-01 11632749 PRODUCTION PROFILE (o - 08/12/07 1 2X-04 11846430 INJECTION PROFILE -j( 08113/07 1 22-29 11850419 SBHP SURVEY % 08/13/07 1 2X-19 11850420 SBHP SURVEY �"- 08/13107 1 1A-20 11850421 SBHP SURVEY 08/14/07 1 1F-13 11850422 SBHP SURVEY 08/14/07 1 1H-10 11846432 SBHP SURVEY - 08/14/07 1 10-10 11846431 SBHP SURVEY - 08/14/07 1 2U-05 11846433 INJECTION PROFILE - 08/15/07 1 2D-12 11846434 1PRODUCTION PROFILE -09 08/16/07 1 21-1-06 11846435 ILDL 16A 08117/07 1 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�" 2 ME OT ALASEA / SARAH PALIN, GOVERNOR daA KA OIL AND CIAN 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMUSS 0—N ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Tarn Oil Pool, 2N-327 ConocoPhillips Alaska, Inc. Permit No: 207-069 Surface Location: 82' FNL, 850' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 2491' FNL, 1645' FEL, SEC. 3, T9N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service 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)„659-3607 (pager). DATED this / 3 day of June, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 23, 2007 Alaska Oil and Gas Conservation Commission 333 West 7b Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill 2N-327 Dear Commissioners, RECEIVE® MAY 2 5 2007 Alaska oii" 11S Cons, COMission Anchorgo ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore injection well 2N-327. The well will be drilled and completed using Nordic Rig #3. The planned spud date for 2N-327 is July 15tH 2007. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Mike Greener at 907-263-4820. Sincerely, 7/d A,-, C45' Randy Thomas Kuparuk Drilling Team Leader 0 STATE OF ALASKA0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION (� MAY 2 5 2007 PERMIT TO DRILL "daska Oil & Gas Cons. Commission 20 AAC 25.005 Anrhnragp 1 a. Type of Work: 1 b. Current Well Class: Exploratory El Development Oil ❑ 1 c. Specify if well is proposed for: Drill ❑✓ Re -drill ❑ Stratigraphic Test ❑ Service ❑✓ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re-entry ❑ Multiple Zone El Single Zone ❑ Shale Gas ❑ Operator Name: 5. Bond: : Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 * 2N-327 Address: P.O. Box 100360 Anchorage, AK 99510-0360 i. Location of Well (Governmental Section): Surface: 82' FNL, 850' FEL, Sec. 3, T9N, R7E, UM ip of Productive Horizon: 2423' FNL, 1624' FEL, Sec. 3, T9N, R7E, UM dal Depth: 2491' FNL, 1645' FEL, Sec. 3, T9N, R7E, UM MD: 6779' - TVD: 6128' - Property Designation: ADL 375074 ALK 4293 Acres in Property: 2560 Kuparuk River Field Tarn Oil Pool 3. Approximate Spud Date: 7/15/2007 4. Distance to162--cl - ,eJt).2– Nearest Property: %�'���';'�_J?6cj$ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460743 y- 5911926 Zone- 4 10. KB Elevation (Height above GL): 149' AMSL feet 1,5../Dii%annce-to/N�earest 1 % W �fFt Pdb: ©"42 70 �V ell wi in I: 2N-342 16. Deviated wells: Printed Name Ra y Thomas Title Drilling Team Leader Kickoff depth: Maximum Hole Angle: 350 ft. 32° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2395 psig Surface: 1810 psig 18. Casing Program Size aron All Specifications Setting Depth Top Bottom Quantity of Cement c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80' surf. surf. 120' 120' 266 sx AS 1 12.25" 9-5/8" 40# L-80 BTC 2616' surf. surf. 2616' - 2400' 480 sx AS Lite, 170 sx DeepCRETE 8.75" 7" 26# L-80 BTCM 5870' surf. surf. 5870'5223' 210 sx GasBLOK w/ Class G 6.125" 4.5" 12.6# L-80 IBTM 1109' 5670' 4990' 6779' 6128' 1 sx GasBLOK w/ Class G I(o Q sx q' F 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): 1rotal Depth TVD (ft): I Plugs (measured) Effective Depth MD (ftyl Effective Depth TVD (41 Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee U BOP Sketch LJ Drilling Program L✓J Time v. Depth Plot U Shallow Hazard Analysis U Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑� 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Ra y Thomas Title Drilling Team Leader SignaturePhone Date 14., C aron All Commission Use Only Permit to Drill API Number: / 1t� Permit Approv � See cover letter Number: 0�� 50- �(73 Zo5s�8 " c.�V Date: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hyd s, or gas contained in shales: %1\NV -CV'ja'LV� Samples req'd: Yes ❑ No Q' M log req'd: Yes ❑ No [� Cctr\'ZV\: `C3S Other: Y H2S measures: Yes F?r/No al svy req'd: Yes [•�]� No ❑ `M)� %i� '3 v--,- 'all Q> k'e-,k - APPROVED BY THE COMMISSION DATE: I K I A COMMISSIONER Form 10-401 Revised 12/2005 in Duplicate �t P. ;o -o7 • Permit It — Kuparuk Well 2N-327 Application for Permit to Drill Document Table of Contents Ation for Permit to Drill, Well 2N-327 Saved: 24 -May -07 1. Well Name.................................................................................................................................2 Requirementsof 20 AAC 25.005 69 ........................................................................................................................ 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 .........................................................3 Requirements of 20 AAC 25.005 (c)(5).................................................................................................................. 3 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 Requirements of 20 AAC 25.005 (c)(13)................................................................................................................ 5 2N-327 APD Page 1 of 7 Printed: 24 -May -07 ORIGINAL .7 Vion for Permit to Drill, Well 2N-327 Saved: 24 -May -07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.......................................7 Requirements of 20 AAC 25.005 (c)(14)................................................................................................................ 7 15. Attachments..............................................................................................................................7 AttachmentI Directional Plan.............................................................................................................................. 7 Attachment 2 Drilling Hazards Summary............................................................................................................. 7 Attachment3 Well Schematic................................................................................................................................ 7 Attachment 4 Cement Summary............................................................................................................................. 7 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique AN number assigned by the commission under 20 AAC 25.040(b). 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-327. 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 onfile with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the 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. (B) 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 Top of Productive Interval (Bermuda) 2,423' FNL, 1,624' FEL, Sec 3, T9N, R7E, UM NGS Coordinates Northings: 5,909,589 Eastings: 459,961 Location at Surface 82' FNL, 850' FEL, Sec 3, T9N, R7E, UM -,' Total Vertical Depth, SS: 5,175' NGS Coordinates Northings: 5,911,926 Eastings: 460,743 IRKB Elevation 147.1' AMSL Pad Elevation I 117.1' AMSL Location at Top of Productive Interval (Bermuda) 2,423' FNL, 1,624' FEL, Sec 3, T9N, R7E, UM NGS Coordinates Northings: 5,909,589 Eastings: 459,961 Total Vertical De th, RKB: 6,128' Measured Depth, RKB: 5,970' Total Vertical Depth, RKB: 5,323' Total Vertical Depth, SS: 5,175' Location at Total Depth 2,49 P FNL, 1,645' FEL, Sec 3, T9N, R7E, UM .11 NGS Coordinates Northings: 5,909,522 Eastings: 459,939 Measured Depth, RKB: 6,779' Total Vertical De th, RKB: 6,128' Total Vertical Depth, SS: 5,980' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 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. 2N-327 APD Page 2 of 7 ORIGINAL Printed: 24 -May -07 • The Applicant is the only affected owner. A�tion for Permit to Drill, Well 2N-327 Saved: 24 -May -07 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) 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: (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; Please reference BOP schematics on file for Nordic 3. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) 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: (4) information on drilling hafards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Offset well data on injector 2N -349A indicates a max BHP of 2,941 psi at 5,350' TVD. Equivalent Mud Weight @TD = 2,941/(5,350*.052) = 10.6 ppg The maximum potential surface pressure (MPSP) while drilling 2N-327 is calculated using the predicted 2,941 psi reservoir pressure, a 0.11 psi/ft gas gradient, and an Bermuda top TVD of 5,323'. MPSP = (5,323 ft TVD)*(0.45 - 0.11 psi/ft) = 1,810 psi (B) data on potential gas (ones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation cones, and .:ones that have a propensityfor differential sticking; Please see Attachment 2 - Drilling Hazards Summary 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(); Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2N-327 APD Page 3 of 7 ORIGINAL Printed: 24 -May -07 • Vion for Permit to Drill, Well 2N-327 Saved: 24 -May -07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) 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: (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 Surface Interval Hole Mud Tye Spud Mud LSND Density (ppg) TOP Btm Funnel Viscosity(sec) Csg/Tbg Size Weight 30-50 22-28 Length MD/TVD MD/TVD 10 sec. Gel (lb/100 sfi OD (in) (in) (Iblft) Grade Conn. ft (ft) (ft) Cement Program +10 <5% Driven 16 24 62.5 H-40 Welded 80' Surf 120'/ 120' Cemented to Surface with 9-5/8 12-1/4 40.0 L-80 BTC 2,616' Surf 2,616'/ 2,400' 480 sx ASLite Lead, 170 sx Dee CRETE Tail Cement Top planned @ 4,870' MD / 7 8-3/4" 26.0 L-80 BTCM 5,870' Surf 5,870'/ 5,223' 4,285' TVD. Cemented w/ 210 sx GasBLOK w/ Class "G" Cement Top planned @ 5,470' MD / 4-1/2 6-1/8 12.6 L-80 IBTM 1,109' 5,670'/ 4,990' 6,779'/ 6,128' 4,838' TVD. Cemented w/ 160 sx GasBLOK w/ Class "G" 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 description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h) (2); Please reference diverter schematic on file for Nordic 3. 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; Drilling will be done using mud systems having the following properties: *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. r 21V-327 APD Page 4 of 7 ORIGINAL Printed: 24 -May -07 Surface Interval Production Interval Mud Tye Spud Mud LSND Density (ppg) 8.5-10.2 9.5-10.7 Funnel Viscosity(sec) 150-250* 45-55 Yield Point (CP) 30-50 22-28 Plastic Viscosity (lb/100 sj) 20-60 14-25 10 sec. Gel (lb/100 sfi 10-35 5-9 API Filtrate (cc) NC -6 4-6 pH 8.5-9.5 9-9.5 Solids (%) +10 <5% *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. r 21V-327 APD Page 4 of 7 ORIGINAL Printed: 24 -May -07 Vion for Permit to Drill, Well 2N-327 0 Saved: 24 -May -07 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 identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpredicted abnormally geo pressured strata as required by 20 AAC 25.033(fl; 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); N/A - Application 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: (]])for a well 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(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) 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: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}Iaave 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 file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Nordic 3 on 2N-327 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (2,616' MD/ 2,400' TVD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 9-5/8" 40.09 L-80 BTCM casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi.. Nipple up BOPE and test to required pressure as per AOGCC approved permit to drill. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT.. 9. Directionally drill 8-3/4" hole to 5,870' MD / 5,223' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Run 7" 26# L-80 BTCM casing to 5,870' MD / 5,223' TVD. Pump cement and displace with mud, land casing hanger and bump plug. 2N-327 APD Page 5 of 7 Printed: 24 -May -07 ORIGINAL Ation for Permit to Drill, Well 2N-327 Saved: 24 -May -07 11. PU 4-3/4" packed drilling assembly and 6-1/8" bit and clean out to shoe. Shut in BOP and test casing to 3,000 psi. Record results. Drill 20' minimum to 50' maximum of new hole. Perform LOT. 12. Drill into top of Bermuda and use LWD to pick core point. POOH and PU 4-3/4" core barrel 13. RIH and core +/- 270' of the Bermuda formation. 14. Stop coring at the base of the Bermuda and POOH to PU new packed assembly with 6-1/8 15. RIH and drill +/- 300' to 2nd core point. 16. POOH and PU 4-3/4" core barrel. 17. RIH and core +/- 90'. POOH and PU packed assembly and RIH and drill 40 — 60' of rat hole. Make mad pass over all the open hole section. 18. POOH and run open hole logs plus USIT in cased section to check for cement bond. 19. Lay down logs and run 4-1/2" liner completion and cement same. 20. Run 3-1/2" tubing with GLMs and chemical injection mandrel with control line attached for paraffm inhibition) to OD of tbg. Land 3-1/2" completion tubing string in the seal bore in the 4-1/2" liner top and pressure test to 3000 psi. Record results. 21. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 22. Pressure up to shear out valve in lowest GLM and freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 23. Clean location and RDMO. 24. MIRU coiled tubing. Displace mud from well with brine. 25. RU E -Line, perforate well. Flow test well. 26. RU Dowell, frac well. 27. RD Dowell, secure well, handover to production 2N-327 APD Page 6 of 7 Printed. 24 -May -07 ORIGINAL • Vion for Permit to Drill, Well 2N-327 Saved: 24 -May -07 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 he 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 authori_ation 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. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment I Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2N-327 APD Page 7 of 7 Printed: 24 -May -07 O' N L 9onocoPhillips Alaska, Int. CPAI Plan Report Plan: 2N-327wp09 Date Composed: 2/21/2007 Extended TD Version: 5 Principal: Yes Tied -to: From Well Ref. Point 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 Site: Kuparuk 2N Pad Site Position: Northing: 5911970.20 ft Latitude: 70 10 13.596 N From: Map Easting: 460932.24 ft Longitude: 150 18 51.920 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.30 deg Well: Plan: 2N-327 Slot Name: Well Position: +N/ -S -44.84 ft Northing: 5911926.34 ft Latitude: 70 10 13.155 N +E/ -W -189.43 ft Easting : 460742.60 ft Longitude: 150 18 57.408 W Position Uncertainty: 0.00 ft Wellpath: Plan: 2N-327 Incl Drilled From: Well Ref. Point TVD +N/ -S +E/ -W Tie -on Depth: 30.00 ft Current Datum: 2N-327wp07 Height 148.60 ft Above System Datum: Mean Sea Level Magnetic Data: 3/13/2006 ft Declination: 23.56 deg Field Strength: 57556 nT 0.00 Mag Dip Angle: 80.64 deg Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 0.00 ft ft ft deg 0.00 30.00 0.00 0.00 198.18 Survey Program for Definitive Wellpath 550.00 4.00 210.00 Date: 2/21/2007 Validated: No -3.49 Version: 4 2.00 Actual From To Survey 800.00 Toolcode Tool Name ft ft 797.78 -32.88 -18.99 2.50 2.50 0.00 0.00 1524.86 31.66 Plan Section Information MD Incl Azim TVD +N/ -S +E/ -W DLS Build Turn TFo Target ft deg deg ft ft ft deg/100ft deg/1;00ft deg/100ft deg 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 550.00 4.00 210.00 549.84 -6.04 -3.49 2.00 2.00 0.00 210.00 800.00 10.25 210.00 797.78 -32.88 -18.99 2.50 2.50 0.00 0.00 1524.86 31.66 197.68 1471.02 -272.87 -110.11 3.00 2.95 -1.70 -17.59 5209.20 31.66 197.68 4607.02 -2115.38 -697.49 0.00 0.00 0.00 0.00 5970.94 5.00 197.68 5323.60 -2341.57 -769.60 3.50 -3.50 0.00 -180.00 2N-327wp07 T3 6523.04 5.00 197.68 5873.60 -2387.42 -784.21 0.00 0.00 0.00 0.00 6779.01 r 5.00 197.68 6128.60. -2408.68 -790.99 0.00 0.00 0.00 0.00 OR.IGINAL I -2 -2 -3 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 West( -)/East(+) [500ft/in] 0 KOP; 2 DLS, 210 TFO __ '0° . Build; 2.5 DLS ... � -_- -- Build; 3_DLS 1000 °. 0 ....... ........ --- Sail; 3684' 31.66° inc ....... _ 2000-- 000 95 9 5/8" x 12 1/4" 500 o � v3 _ O 3ti - 000 .....- --- - ---- - ---- -- _ . . . ...... - - - -. -- - -- ... 4000 -- -- ---- .................................... ..----..- . . . --------------- . _ ---- . _. -- .................t . ... 5400 3.5 DLS 7"x 5000 _. ........ .... __ ...,inc Hold; 808'(&,S° 5© 41/2 x 6 1/8" 6000 TD; 6779' MD, 6128' TVD - --- _ 2N -327w 09 . 1 -3000 6000 -2000 -1000 0 1000 2000 3000 4000 5000 Vertical Section at 198.18° [1000ft/in] 0 9onocoPhillips Alaska, InL! CPAI Plan Report Company::, ConocoPhillips Alaska Inc. Date: 5/22/2007 Time: 08:50:48 Page: 2 Field: Kuparuk River UnitCo-ordinate(NE) Reference: Well. Plan: 2N-327, True )Jorth Site; Kuparul( 2N Pad Vertical (TVD) Reference: 2N -327W p07 148.0 Well: Plan: 2N-327 Section (VS) Reference: Well (D OON,0.00E,198.18A0)- Wellpath: Plan: 2N-327 Survey Calculation Method: Mininiurrt Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W; MapN , ! Mapg DLS1 TF© Comment ft deg deg it ft ft ftft ft deg1100ft ! deg 30.00 0.00 0.00 30.00 -118.60 0.00 0.00 5911926.34 460742.60 ' 0.00 0.00 100.00 0.00 0.00 100.00 -48.60 0.00 0.00 5911926.34 460742.60 0.00 0.00 200.00 0.00 0.00 200.00 51.40 0.00 0.00 5911926.34 460742.60 0.00 0.00 300.00 0.00 0.00 300.00 151.40 0.00 0.00 5911926.34 460742.60 0.00 0.00 350.00 0.00 0.00 350.00 201.40 0.00 0.00 5911926.34 460742.60 0.00 0.00 KOP; 2 DLS, 210 400.00 1.00 210.00 400.00 251.40 -0.38 -0.22 5911925.96 460742.38 2.00 0.00 500.00 3.00 210.00 499.93 351.33 -3.40 -1.96 5911922.95 460740.62 2.00 0.00 550.00 4.00 210.00 549.84 401.24 -6.04 -3.49 5911920.32 460739.08 2.00 0.00 Build; 2.5 DLS 600.00 5.25 210.00 599.67 451.07 -9.54 -5.51 5911916.83 460737.05 2.50 360.00 700.00 7.75 210.00 699.02 550.42 -19.34 -11.16 5911907.06 460731.34 2.50 0.00 800.00 10.25 210.00 797.78 649.18 -32.88 -18.99 5911893.56 460723.45 2.50 0.00 Build; 3 DLS 900.00 13.14 206.01 895.70 747.10 -50.81 -28.42 5911875.68 460713.92 3.00 342.41 1000.00 16.07 203.45 992.46 843.86 -73.73 -38.92 5911852.82 460703.31 3.00 346.32 1100.00 19.02 201.66 1087.80 939.20 -101.58 -50.44 5911825.03 460691.64 3.00 348.80 1200.00 21.99 200.34 1181.45 1032.85 -134.29 -62.96 5911792.39 460678.95 3.00 350.50 1300.00 24.96 199.32 1273.16 1124.56 -171.76 -76.45 5911755.00 460665.26 3.00 351.74 1400.00 27.94 198.50 1362.69 1214.09 -213.89 -90.87 5911712.94 460650.63 3.00 352.68 1500.00 30.92 197.83 1449.78 1301.18 -260.58 -106.17 5911666.34 460635.09 3.00 353.41 1524.86 31.66 197.68 1471.02 1322.42 -272.87 -110.11 5911654.07 460631.09 3.00 353.99 Sail; 3684'@ 31.6 1600.00 31.66 197.68 1534.98 1386.38 -310.45 -122.09 5911616.56 460618.91 0.00 180.00 1700.00 31.66 197.68 1620.09 1471.49 -360.46 -138.03 5911566.64 460602.71 0.00 180.00 1800.00 31.66 197.68 1705.21 1556.61 -410.47 -153.97 5911516.72 460586.51 0.00 180.00 1900.00 31.66 197.68 1790.33 1641.73 -460.48 -169.92 5911466.80 460570.31 0.00 180.00 2000.00 31.66 197.68 1875.45 1726.85 -510.49 -185.86 5911416.87 460554.11 0.00 180.00 2100.00 31.66 197.68 1960.56 1811.96 -560.50 -201.80 5911366.95 460537.91 0.00 180.00 2200.00 31.66 197.68 2045.68 1897.08 -610.50 -217.74 5911317.03 460521.71 0.00 180.00 2300.00 31.66 197.68 2130.80 1982.20 -660.51 -233.69 5911267.11 460505.51 0.00 180.00 2400.00 31.66 197.68 2215.91 2067.31 -710.52 -249.63 5911217.19 460489.31 0.00 180.00 2500.00 31.66 197.68 2301.03 2152.43 -760.53 -265.57 5911167.27 460473.11 0.00 180.00 2600.00 31.66 197.68 2386.15 2237.55 -810.54 -281.52 5911117.35 460456.91 0.00 180.00 2616.27 31.66 197.68 2400.00 2251.40 -818.68 -284.11 5911109.22 460454.28 0.00 180.00 9 5/8" x 12 1/4" 2700.00 31.66 197.68 2471.26 2322.66 -860.55 -297.46 5911067.43 460440.71 0.00 180.00 2720.37 31.66 197.68 2488.60 2340.00 -870.74 -300.70 5911057.26 460437.41 0.00 180.00 C80 (K10) 2800.00 31.66 197.68 2556.38 2407.78 -910.56 -313.40 5911017.51 460424.51 0.00 180.00 2900.00 31.66 197.68 2641.50 2492.90 -960.57 -329.34 5910967.59 460408.31 0.00 180.00 3000.00 31.66 197.68 2726.62 2578.02 -1010.58 -345.29 5910917.67 460392.11 0.00 180.00 3100.00 31.66 197.68 2811.73 2663.13 -1060.59 -361.23 5910867.74 460375.91 0.00 180.00 3200.00 31.66 197.68 2896.85 2748.25 -1110.60 -377.17 5910817.82 460359.71 0.00 180.00 3300.00 31.66 197.68 2981.97 2833.37 -1160.61 -393.11 5910767.90 460343.51 0.00 180.00 3400.00 31.66 197.68 3067.08 2918.48 -1210.62 -409.06 5910717.98 460327.31 0.00 180.00 3500.00 31.66 197.68 3152.20 3003.60 -1260.62 -425.00 5910668.06 460311.11 0.00 180.00 3600.00 31.66 197.68 3237.32 3088.72 -1310.63 -440.94 5910618.14 460294.91 0.00 180.00 3700.00 31.66 197.68 3322.44 3173.84 -1360.64 -456.88 5910568.22 460278.71 0.00 180.00 3800.00 31.66 197.68 3407.55 3258.95 -1410.65 -472.83 5910518.30 460262.51 0.00 180.00 3900.00 31.66 197.68 3492.67 3344.07 -1460.66 -488.77 5910468.38 460246.31 0.00 180.00 4000.00 31.66 197.68 3577.79 3429.19 -1510.67 -504.71 5910418.46 460230.11 0.00 180.00 4100.00 31.66 197.68 3662.90 3514.30 -1560.68 -520.66 5910368.54 460213.91 0.00 180.00 4200.00 31.66 197.68 3748.02 3599.42 -1610.69 -536.60 5910318.61 460197.71 0.00 180.00 4300.00 31.66 197.68 3833.14 3684.54 -1660.70 -552.54 5910268.69 460181.51 0.00 180.00 4388.66 31.66 197.68 3908.60 3760.00 -1705.04 -566.68 5910224.43 460167.14 0.00 180.00 C50 4400.00 31.66 197.68 3918.25 3769.65 -1710.71 -568.48 5910218.77 460165.31 0.00 180.00 4500.00 31.66 197.68 4003.37 3854.77 -1760.72 -584.43 5910168.85 460149.11 0.00 180.00 4600.00 31.66 197.68 4088.49 3939.89 -1810.73 -600.37 5910118.93 460132.91 0.00 180.00 100nocoPhillips Alaska, InO CPAI Plan Report Survey 4600.13 31.66 197.68 4088.60 3940.00 -1810.79 -600.39 5910118.86 460132.89 0.00 180.00 C40 4700.00 31.66 197.68 4173.61 4025.01 -1860.74 -616.31 5910069.01 460116.71 0.00 180.00 -2341.57 4752.86 31.66 197.68 4218.60 4070.00 -1887.17 -624.74 5910042.62 460108.14 0.00 180.00 C37 4800.00 31.66 197.68 4258.72 4110.12 -1910.74 -632.25 5910019.09 460100.51 0.00 180.00 4900.00 31.66 197.68 4343.84 4195.24 -1960.75 -648.20 5909969.17 460084.31 0.00 180.00 5000.00 31.66 197.68 4428.96 4280.36 -2010.76 -664.14 5909919.25 460068.11 0.00 180.00 5100.00 31.66 197.68 4514.07 4365.47 -2060.77 -680.08 5909869.33 460051.90 0.00 180.00 5200.00 31.66 197.68 4599.19 4450.59 -2110.78 -696.02 5909819.40 460035.70 0.00 180.00 5209.20 31.66 197.68 4607.02 4458.42 -2115.38 -697.49 5909814.81 460034.21 0.00 180.00 Build; 3.5 DLS 5300.00 28.48 197.68 4685.59 4536.99 -2158.73 -711.31 5909771.55 460020.17 3.50 180.00 5400.00 24.98 197.68 4774.89 4626.29 -2201.58 -724.97 5909728.77 460006.29 3.50 180.00 5469.62 22.55 197.68 4838.60 4690.00 -2228.30 -733.49 5909702.09 459997.63 3.50 180.00 T7 5500.00 21.48 197.68 4866.76 4718.16 -2239.15 -736.95 5909691.26 459994.12 3.50 180.00 5600.00 17.98 197.68 4960.88 4812.28 -2271.32 -747.20 5909659.15 459983.70 3.50 180.00 5700.00 14.48 197.68 5056.88 4908.28 -2297.95 -755.69 5909632.57 459975.07 3.50 180.00 5800.00 10.98 197.68 5154.40 5005.80 -2318.94 -762.38 5909611.61 459968.27 3.50 180.00 5870.22 8.53 197.68 5223.60 5075.00 -2330.28 -766.00 5909600.30 459964.60 3.50 180.00 7"x 8 3/4" 5875.27 8.35 197.68 5228.60 5080.00 -2330.98 -766.22 5909599.59 459964.37 3.50 180.00 T4 5900.00 7.48 197.68 5253.09 5104.49 -2334.23 -767.26 5909596.35 459963.32 3.50 180.00 5970.94 5.00 197.68 5323.60 5175.00 -2341.57 -769.60 5909589.02 459960.94 3.50 180.00 2N-327wp07 T3 6000.00 5.00 197.68 5352.55 5203.95 -2343.99 -770.37 5909586.61 459960.16 0.00 0.00 6100.00 5.00 197.68 5452.17 5303.57 -2352.29 -773.02 5909578.32 459957.47 0.00 0.00 6200.00 5.00 197.68 5551.79 5403.19 -2360.60 -775.66 5909570.03 459954.78 0.00 0.00 6206.83 5.00 197.68 5558.60 5410.00 -2361.16 -775.84 5909569.47 459954.60 0.00 0.00 T2 Base Reservoir 6300.00 5.00 197.68 5651.41 5502.81 -2368.90 -778.31 5909561.74 459952.09 0.00 0.00 6317.25 5.00 197.68 5668.60 5520.00 -2370.33 -778.77 5909560.31 459951.63 0.00 0.00 C-35 (K-3) 6400.00 5.00 197.68 5751.03 5602.43 -2377.20 -780.96 5909553.45 459949.40 0.00 0.00 6500.00 5.00 197.68 5850.65 5702.05 -2385.51 -783.60 5909545.16 459946.71 0.00 0.00 6523.04 5.00 197.68 5873.60 5725.00 -2387.42 -784.21 5909543.25 459946.09 0.00 0.00 6600.00 5.00 197.68 5950.27 5801.67 -2393.81 -786.25 5909536.87 459944.02 0.00 0.00 6700.00 5.00 197.68 6049.89 5901.29 -2402.11 -788.90 5909528.59 459941.33 0.00 0.00 - 6779.01 5.00 197.68 6128.60 • 5980.00 -2408.68 -790.99 5909522.04 459939.21 0.00 0.00 4 1/2" x 6 1/8" Targets Annotation MD TVD it Map,: Map Latitude - <--- Longitude - y Name; Description TVD +N/ -S +E/ -W Northing Easting Deg Min See Deg Min See Dip. Air. ft' ft ft ft ft 4607.02 Build; 3.5 DLS 2N-327wp07 T3 5323.60 -2341.57 -769.60 5909589.02 459960.94 70 9 50.125 N 150 19 19.697 W -Plan hit target 2N-310wp04 T3 5323.60 -2341.57 -769.60 5909589.02 459960.94 70 9 50.125 N 150 19 19.697 W -Plan hit target Annotation MD TVD it ft, 350.00 350.00 KOP; 2 DLS, 210 TFO 550.00 549.84 Build; 2.5 DLS 800.00 797.78 Build; 3 DLS 1524.86 1471.02 Sail; 3684'@ 31.66° inc 5209.20 4607.02 Build; 3.5 DLS 5970.94 5323.60 Hold; 808'@ 5° inc 6779.01 6128.60 TD; 6779' MD, 6128' TVD G I iN' A L 9onocoPhillips Alaska, Int CPAI Plan Report Casing Points MD TVI) Diameter tole Size Name ft ft in in 2488.60 2616.27 2400.00 9.625 12.250 9 5/8" x 12 1/4" 5870.22 5223.60 7.000 8.750 7'x 8 3/4" 6779.01 6128.60 4.500 6.125 4 1/2" x 6 1/8" Formations MD TVD Formations Lithology Dip Angle"Dip Direction T ft ft deg deg 2720.37 2488.60 C80 (K10) 0.00 0.00 4388.66 3908.60 C50 0.00 0.00 4600.13 4088.60 C40 0.00 0.00 4752.86 4218.60 C37 0.00 0.00 5469.62 4838.60 T7 0.00 0.00 5875.27 5228.60 T4 0.00 0.00 5970.94 5323.60 T3 Top Resevoir 0.00 0.00 6206.83 5558.60 T2 Base Reservoir 0.00 0.00 6317.25 5668.60 C-35 (K-3) 0.00 0.00 OPIGHNAL tonocoPhillips Alaska, Int. Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 2N-327wp09 & NOT PLANNED PR Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 30.00 to 6779.01 ft Scan Method: Trav Cylinder North Maximum Radius: 874.90 ft Error Surface: Ellipse + Casing Casing Points MD Reference SMD ft TVD Diameter Hole Size Name ft 2N-311 ft in iniA 240.94 2616.27 2400.00 9.625 12.250 9 5/8" x 12 1/4" 5870.22 5223.60 7.000 8.750 7"x 8 3/4" 6779.01 6128.60 4.500 6.125 4 1/2" x 6 1/8" Plan: 2N-327wp09 Date Composed: 2/21/2007 Extended TD Version: 5 Principal: Yes Tied -to: From Well Ref. Point Summary ---------------- --- Offset Wellpa#b------------ > Site Well Wellpatb Reference SMD ft Offset' MD ft Ctr-Ctr No Go Distance Area ft ft. Allowable Deviation ft nFVarmng' Kuparuk 2N Pad 2N-311 2N-311 V1 372.29 375.00 240.94 6.72 234.22 Pass: Major Risk Kuparuk 2N Pad 2N-311 2N -311A V6 372.86 375.00 240.95 6.73 234.22 Pass: Major Risk Kuparuk 2N Pad 2N-313 2N-313 V2 562.02 575.00 204.92 8.46 196.45 Pass: Major Risk Kuparuk 2N Pad 2N-314 2N-314 V3 534.21 550.00 187.51 8.33 179.17 Pass: Major Risk Kuparuk 2N Pad 2N-315 2N-315 V2 608.22 625.00 171.44 9.59 161.85 Pass: Major Risk Kuparuk 2N Pad 2N-316 2N-316 V9 628.99 650.00 159.23 9.53 149.69 Pass: Major Risk Kuparuk 2N Pad 2N-317 2N-317 V2 398.09 400.00 149.62 6.68 142.95 Pass: Major Risk Kuparuk 2N Pad 2N-318 2N-318 V4 632.96 650.00 126.11 8.85 117.26 Pass: Major Risk Kuparuk 2N Pad 2N-319 2N-319 V2 398.43 400.00 119.09 6.65 112.43 Pass: Major Risk Kuparuk 2N Pad 2N-320 2N-320 V2 341.81 350.00 106.75 5.95 100.80 Pass: Major Risk Kuparuk 2N Pad 2N-321 2N-321 V2 519.02 525.00 82.80 8.37 74.42 Pass: Major Risk Kuparuk 2N Pad 2N-321 2N -321A V4 519.02 525.00 82.80 8.37 74.43 Pass: Major Risk Kuparuk 2N Pad 2N-323 2N-323 V2 496.27 500.00 55.17 8.04 47.13 Pass: Major Risk Kuparuk 2N Pad 2N-325 2N-325 V2 424.31 425.00 26.68 6.50 20.19 Pass: Major Risk Kuparuk 2N Pad 2N-326 2N-326 V3 418.13 425.00 10.34 6.80 3.54 Pass: Major Risk Kuparuk 2N Pad 2N-326 Plan 2N -326A V1 Plan: 413.89 425.00 10.32 6.73 3.59 Pass: Major Risk Kuparuk 2N Pad 2N-329 2N-329 V2 550.76 550.00 28.08 7.40 20.68 Pass: Major Risk Kuparuk 2N Pad 2N-331 2N-331 V2 299.79 300.00 61.39 5.41 55.98 Pass: Major Risk Kuparuk 2N Pad 2N-332 2N-332 V6 220.49 225.00 75.96 3.83 72.12 Pass: Major Risk Kuparuk 2N Pad 2N-332 2N-332PB1 V4 220.49 225.00 75.96 3.83 72.12 Pass: Major Risk Kuparuk 2N Pad 2N-333 2N-333 V4 343.93 350.00 93.83 6.68 87.15 Pass: Major Risk Kuparuk 2N Pad 2N-335 2N-335 V2 1030.40 1025.00 74.31 14.08 60.22 Pass: Major Risk Kuparuk 2N Pad 2N-337 2N-337 V1 1475.88 1425.00 155.75 26.64 129.11 Pass: Major Risk Kuparuk 2N Pad 2N-337 2N -337A V1 1475.88 1425.00 155.75 26.64 129.11 Pass: Major Risk Kuparuk 2N Pad 2N-337 2N -337B V5 1473.78 1425.00 155.37 26.57 128.81 Pass: Major Risk Kuparuk 2N Pad 2N-339 2N-339 V8 454.27 450.00 178.78 7.32 171.46 Pass: Major Risk Kuparuk 2N Pad 2N-341 2N-341 V9 402.43 400.00 212.46 6.38 206.09 Pass: Major Risk Kuparuk 2N Pad 2N-343 2N-343 V11 376.31 375.00 239.69 6.28 233.42 Pass: Major Risk Kuparuk 2N Pad 2N-345- 2N-345 V1 644.39 625.00 267.49 9.04 258.45 Pass: Major Risk Kuparuk 2N Pad 2N-345 2N -345A V2 642.02 625.00 267.47 8.90 258.57 Pass: Major Risk Kuparuk 2N Pad 2N-348 2N-348 V18 398.35 400.00 316.33 7.10 309.23 Pass: Major Risk Kuparuk 2N Pad 2N-349 2N-349 V4 1325.04 1300.00 314.02 17.66 296.36 Pass: Major Risk Kuparuk 2N Pad 2N-349 2N -349A V5 1325.04 1300.00 314.02 17.66 296.36 Pass: Major Risk Kuparuk 2N Pad Plan: 2N-310 Plan: 2N-310 V3 Plan: 372.90 375.00 254.98 7.41 247.57 Pass: Major Risk Kuparuk 2N Pad Plan: 2N-322 Plan: 2N-322 VO Plan: 398.43 400.00 75.19 8.25 66.95 Pass: Major Risk Kuparuk 2N Pad Plan: 2N-322 Prelim: 2N-322ST VO PI 398.43 400.00 75.19 8.25 66.95 Pass: Major Risk Kuparuk 2N Pad Plan: 2N-327 Prelim: 2N-327PB1 V2 30.00 31.20 0.00 No Offset Stations Kuparuk 2N Pad Plan: 2N-342 Plan: 2N-342 (Tam Sou 1688.65 1625.00 205.75 26.46 179.29 Pass: Major Risk Kuparuk 2N Pad Plan: 2N-342 Prelim: 2N-342 (Beta) 5961.27 6700.00 3.04 102.68 -99.64 FAIL: Major Risk Kuparuk 2N Pad Plan: 2N-342 Prelim: 2N-342PB1wp03 1688.65 1625.00 205.75 26.35 179.40 Pass: Major Risk ORIGINAL REFERENCE INFORMATION CaoNrt�ete (N/E) Re/marc,'. Well CIOO Plan'. 2N-327. True Nmt6 _1(TVD) Ral— 2W321wp0114860 Secti,n(VS)Re/coerce: SM- (OWN.O.WE) Meaty Depth Re/ererce: 2N-321wp01 148.60 C.k.Wt Me0w4: MiMmam Curvature 2N 32 150 N-231 (2N-331 u 6(Tarn h) 2N-341 2N-34 ) 2N-33 �I- 39) zaJ COMPANY DETAILS CaaocpPlcillips Altace Ice. Engiaecnng CalculaUan MNwd: Minimum C -.1 - En,, Srstem: ISC WSA ScaaWdwd. Tin C3'Iindcr Nanh EmrSmtace'. EBiplical+C_9 Warring Melhod'. Rales Based 2N-323 (2N-323) Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation II00ft/in[ 0 ANTI -COLLISION SETTINGS t t a Interpolation Method:NID Interval: 25.00 Depth Range From: 30.00 To: 6779.01 Maximum Range: 874.90 Reference: Plan: 2N-327wp09 From Colour To MD 30 250 250 500 500 750 750 1000 1000 1250 1250 0 N � Q 2N-3221 1500 1750 0 2000 2000 2500 31464N.319}.... 3000 2ND,I 73500 3 00 33Q�� __ 0 00 5000 6000 �-+tri 7000 8000 9000 Ice 10000 +N/ -S +EI -W 12000 TF- 14000 13000 a�16000 16000 2���jf3-ID. 18()-p 20000 0.00 25000 I 30 0.00 0.00 0.00 329 (2N-329) Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation II00ft/in[ 0 �1■.► � t t a �/ SURVEY PROGRAM \ Depth Fm Depth To Survey/Plan 1 r�i'�J► ��' � ` Tool 311.00 1000.00 Planned: 2N-327wpO9 V5 /►! CB -GYRO -SS 100.00 6779.01 Planned: 2N-327wp09 V5 MWD+IFR-AK-CAZ-SC fy • / Z �-+tri SECTION DETAILS Sec MD Ice An TVD +N/ -S +EI -W DLeg TF- vsm T.Bel 13000 0.00 0.00 30.00 0.00 0.00 o 00 0.00 0.00 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 3 550.00 4.00 21000 549.84 fiO4 -3.49 2.00 21000 6.83 4 800.00 1015 210.00 797.78 -32.88 -18.99 2.50 0.00 37.17 5 1524.86 31.66 197.68 1471.02 -272.87 -110.11 3.00 -17.59 293.61 6 520910 31.66 19768 4607.02 -2115.38 -697.49 0.00 000 222740 7 5970.94 5.00 197,68 5323.60 -2341.57 -769.60 3.50 -180.00 2461.80 2N-327wp07 T3 8 6523.04 5.00 197.68 5873.60 -2387.42 -784.21 000 0.00 2512.92 9 6779.OI 5.00 197.68 6128.60 -2408.68 -790.99 0.00 0.00 2535.23 �1■.► � t t a �/ \ �� �, 1 1 1 r�i'�J► ��' � ` 1 111 /I,, I /►! fy • / Z �-+tri 11 i� 111 .A •. _ (j1f .A 11 •:1 �- .111 1 +51,'111 111 7,BI JI •111 ' ' �"111 '� 1111 11 111 411 '111 X11 •111 ' :11 V Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20tUin] 2000 Plan. Prelim: 2N-322ST Plan. 326 � 2N-323 2N- 2N-318 2N-31' 2N-3 2N-313 2N-313 2N-332 2a-32- 7o77'�_ - I =Plan-2N-310 Plan: 2N-310 1000 _ _ - 2N-329 2N-329 2N-349 2N -349A 2N-331 2N-331 -345A 2N-349 2N-349 0— 2N-333 2N-333 2N-345 2N-345 2N-341 2N-341 o -1000 — - - _ _. -- t 2N-343 2N-343 -- ....... ._ 2000--- 2N-335-- 2N-335 ............. �_ . ..... --- _....._ _ ........ 2N -339(2N -339)2N -327w 09 i c° 2N-337 2N -337B 3000 -3000— -- -- -'- 2N-337 2N -337A .............. -4000 Z�< 2N-337 2N-337 .. _ . _� _ f -- _5000— 5000 ..... I � . -2 Plan: Plan: 2N-342 Tarn South -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 West( -)/East(+) [1000ft/in] CD G7 ConocoPhillips PLAN DETAILS Alaska 2N-327wp09 Extended TD HALLIOURTON Version 5 2/21/2007 Quarter Mile (1320 feet) radius plot I 2N-327 Drilling Hazards Summary Surface Hole Risks Event Risk Level Mitigation Strategy / Contingency Broach of conductor Low Monitor cellar & pad continuously during interval Gas Hydrates Moderate Minimum mud weight of 10.0 ppg. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, addition of Lecithin Running sands & gravel Moderate Maintain planned mud parameters, Increase mud (50 ft TVD below C-80) weight/viscosity, Use weighted sweeps, monitor fill Low OH LOT /High reservoir Low on connections Hole swabbing/Tight hole on Moderate Circulate hole clean prior to trip, proper hole filling trips (use of trip sheets), pumping out of hole as needed Production Hole Risks Event Risk Level Mitigation Strategy / Contingency Insufficient or undetermined Low Importance of LOT communicated to all parties, all LOT parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 16 ppg MW equivalent Swabbing Campaignian sands Moderate Minimum mud weight of 9.6 ppg, mandatory flow (50 ft TVD below C-80) check above sands on all trips Low OH LOT /High reservoir Low Open hole LOT to be performed before drilling into pressure the Bermuda, wellbore strengthening can be performed if OH LOT is not sufficient to drill into Bermuda. 7" contingency top set available if WBS is not successful High ECD / Tight hole on trips/ Moderate Condition mud & clean hole prior to trips. Monitor Swabbing ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Lost circulation Moderate Keep hole clean — use PWD to monitor hole cleaning. If losses occur — reduce pump rates and mud rheology, use LCM • 2N-327 Injector Top Set 3-1/2" Completion String 30" x 16" 62.6# @ +/- 80' MD 9-5/8" TAM Port Collar @ 1000' MD Surface csg. 9-5/8" 40# L-80 BTC -/- 2,616' MD / 2,400' TVD ConocoPhillips 31/2" Camco'DS' nipple w/ 2.875" No -Go Profile 31/2" x 6'L-80 EUE 8rd handling pups installed above and below, set at +/- 500' MD Completion, from hanger to `DS' nipple, to be be drifted to 2.91". 31/2" x 1" Cameo'KBMG' mandrels with dummy valves 3 ''/z" x &L-80 with EUE 8rd handling pups installed above and below. GLM #1 at +/- 2.530' MD/ +/- 2.326' TVD GLM #2 at 4,530' MD/ 4.028' TVD Camco Chemical Inj Mandrel at two jts above lowest GLM #3 GLM 43 at two joints above sliding sleeve Lowest 3 '/2" x 1" Cam co'KBMG' mandrel w/ shear valve, pinned for 2000 psi shear two jts above sleeve. Load rest of GLMs with dummy valves 3 '/z" Baker'CMU' sliding sleeve w/ 2.813" Cameo DS profile EUE 8rd, with 3 '/2" x 6' L-80 EUE 8rd handling pups installed two jts above 2.75" no-go profile 3 '/z" Cameo 'D' nipple w/ 2.75" No Profile. 3 '/z" x 6' L-80 EUE 8rd handling pups installed above and below, set at one jt above seals 3 '/2" Baker 80-40 GBH -22 casing seal assembly w/ 15' stroke, 3 '/z" x 6' L-80 EUE 8rd crossover handling pup installed on top 7" 26# L-80 BTCM Baker Seal Liner top, with ZXP packer and SBE set at +/- 200' MD @ 5,870' MD / 5,223' TVD above 7" casing shoe Production Liner 4 ''/z" 12.6# L-80 IBT Mod +/- 6,779' MD / 6,128' TVD 4/13/07 ORIGINAL Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 5/22/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,560' MD (1,500' TVD) < Top of Tail at 1,816' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 2,616' MD (2,400' TVD) Mark of Schlumberger 2N-327, V2 emCADE' Preltmina Schlumbepgop 9 9 5/g" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 1,816' MD. Lead Slurry Minimum pump time: 230 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.4895 ft3/ft x (80') x 1.00 (no excess) = 119.2 ft3 0.3132 ft3/ft x (1560'- 80') x 4.00 (300% excess) = 1854.1 ft3 0.3132 ft3/ft x (1816'- 1560') x 1.50 (50% excess) = 120.3 ft3 119.2 ft3 + 1854.1 ft3+ 120.3 ft3 = 2093.6 ft3 2093.6 ft3 /4.45 ft3/sk = 470.5 sks Round up to 480 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 180 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3132 ft3/ft x (2616'- 1816') x 1.50 (50% excess) = 375.8 ft3 0.4257 ft3/ft x 0' (Shoe Joint) = 34.1 ft3 375.8 ft3 +34 . 1 ft3 = 409.9 ft3 409.9 ft3/ 2.47 ft3/sk = 166 sks Round up to 170 sks BHST = 50F, Estimated BHCT = 65F. (BHST calculated using a gradient of 2.2F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Slurry 7 380 54.3 87.6 Tail Slurry 7 75 10.7 98.3 Drop Top Plug 5.0 103.3 Water 5 20 4.0 107.3 Switch to Rig Pumps 5.0 112.3 Displacement 6 152 25.3 137.6 Slow Rate 3 20 6.7 144.3 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv = 17-21, Ty = 20-25 Centralizers: Recommend 1 per joint across zones of interest, and 2 per joint for bottom 8 joints for proper cement placement. OD GINA L 0 Schlumberger CemCAD E*well cementing recommendation for 9 5-8" Surface Operator : ConocoPhillips Alaska Well 2N-327 Slant Producer Country : United States of America Field Tarn State : Alaska Prepared for : Mike Greener Location 2N Pad Proposal No. : V2 (vvp07) Service Point Prudhoe Bay Date Prepared : 05-21-2007 Business Phone (907) 659-2434 FAX No. (907) 659-2538 Prepared by Phone E -Mail Address Maureen Torrie 1-907-265-6336 mtorrie@slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger 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 Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may 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 conditions affecting them. If the Operator is aware of any conditions whereby a neighboring I well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to 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. Actual charges may 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 o��siNnL Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 95-8 District Prudhoe Bay Country United States of America Loadcase Surface Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2616.0 ft BHST : 50 degF Bit Size : 12 1/4 in Previous String MD OD Weight ID N in Ib/ft in 80.0 16 65.0 15.250 Landing Collar MD : 2536.0 ft Casing/liner Shoe MD : 2616.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2616.0 95/8 40.0 40.0 8.835 L-80 3090 5750 BTC Mean OH Diameter : 12.250 in Mean Annular Excess :195.9 % Mean OH Equivalent Diameter: 16.203 in Total OH Volume : 646.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 1560.0 12.250 300.0 17.954 2616.0 12.250 50.0 13.371 Page 2 2N-327 Cement.cfw; 05-22-2007; LoadCase Surface; Version wcs-cem45 89 ORIGINAL Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 95-8 District Prudhoe Bay Country United States of America Loadcase Surface Max. Deviation Angle : 32 deg Max. DLS : 3.003 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de deg) Dogleg Sev. (deg/1 00ft 0.0 0.0 0.0 0.0 0.000 30.0 30.0 0.0 0.0 0.000 130.0 130.0 0.0 0.0 0.000 230.0 230.0 0.0 0.0 0.000 330.0 330.0 0.0 0.0 0.000 430.0 430.0 1.6 210.0 -1.600 530.0 529.9 3.6 210.0 2.000 630.0 629.5 6.0 210.0 2.400 730.0 728.7 8.5 210.0 2.500 830.0 827.2 11.1 208.5 2.622 930.0 924.8 14.0 205.1 3.001 1030.0 1021.2 17.0 202.8 2.993 1130.0 1116.1 19.9 201.2 3.003 1230.0 1209.2 22.9 200.0 3.002 1330.0 1300.2 25.9 199.0 2.998 1430.0 1389.1 28.8 198.2 3.002 1530.0 1475.4 31.7 197.6 2.846 1630.0 1560.6 31.7 197.6 0.000 1730.0 1645.7 31.7 197.6 0.000 1830.0 1730.8 31.7 197.6 0.000 1930.0 1815.9 31.7 197.6 0.000 2030.0 1901.0 31.7 197.6 0.000 2130.0 1986.1 31.7 197.6 0.000 2230.0 2071.3 31.7 197.6 0.000 2330.0 2156.4 31.7 197.6 0.000 2430.0 2241.5 31.7 197.6 0.000 2530.0 2326.6 31.7 197.6 0.000 2616.0 2399.8 31.7 197.6 0.000 MD ft Frac. (lb/gal Formation Pore (lb/gal) Data Name Lithology 1560.0 12.50 8.20 Base Permafrost Sandstone 2550.0 12.50 8.20 C80 Sandstone 4210.0 12.50 8.20 C50 Sandstone 4425.0 12.50 8.20 C40 Sandstone 4580.0 12.50 8.20 C37 Sandstone 5480.0 12.50 8.20 T7 Sandstone 5725.0 12.50 8.20 T4 Sandstone 5820.0 12.50 8.20 - T3 Sandstone 5870.0 12.50 8.20 7 TD Sandstone 6065.0 12.60 11.70 T2 Sandstone 6190.0 12.60 11.70 C35 Sandstone 6823.0 12.60 11.70 4 1-2 TD Sandstone 2N-327 Cement.cfw; 05-22-2007; LoadCase Surface; Version wcs-cem45_89 nn 161NAL SI roar Page 3 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 95-8 District Prudhoe Bay Country United States of America Loadcase Surface Geothermal Temperature Profile MD TVD Temperature Gradient ft (ft) (de F) (de F/100ft) 0.0 0.0 25 0.0 1560.0 1501.0 30 0.3 2616.0 2399.8 50 1.0 ft degF ft o- 0 0 o- O O O M. 1 Temperature 11 Lr CI C C kr C C< r C C C � r V- C` O O O C Lf tr r Schlumbargcr CV Hori. Departure 2N-327 Cement.cfw; 05-22-2007 ; LoadCase Surface; Version wcs-cem45_89 ORIGINAL it Page 4 i i Client ConocoPlant s Alaskeduce Schlumb rgcr Well 2N-327 Slant Producer String 9 5-8 District Prudhoe Bay Country United States of America Loadcase Surface Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2561.0 ft Casing Shoe :2616.0 ft NB of Cent. Used :34 NB of Floating Cent. :34 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Centralizer Placement Restoring OD OD (in) Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft 1733.28 Joint % ft 1371.0 0 0/0 0.0 1389.1 2411.0 26 1/1 541 - ANJO-9 5/8-6-36 (.171") 2.7 1391.0 2571.0 8 2/1 541 - ANJO-9 5/8-6-36 .171" 89.7 2421.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) Ibf 541 - ANJO-9 5/8-6- 95/8 13.252 9.846 No Houma 12.250 299.00 1733.28 36 (.171 ") (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 5 2N-327 Cement .cfw; 05-22-2007; LoadCase Surface; Version wcs-cem45_89 ORIGINAL DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY MUDPUSH II DESIGN Client ConocoAlaska Phillips Fluid No: 3 : 2.47 ft3/sk I : 10.50 Ib/gal Rheo. Model Well 2N-327 Slant Producer k : 3.95E-2 IV. s^n/ft2 At temp. r r String 95-8 Ty District Prudhoe Bay Country United States of America : (Ibf/100ft2) Loadcase Surface Job volume : 50.0 bbl Section 3: fluid description 12 ppg DeepCRETE DESIGN Mud DESIGN Fluid No: 4 Fluid No: 1 Density :9.50 Ib/gal Rheo. Model : BINGHAM PV : 20.000 cP At temp. : 80 degF Ty : 30.00 Ibf/100ft2 n Gel Strength : (Ibf/100ft2) _ MUD Ty :15.121bf/100ft2 Mud Type : WBM Job volume : 172.3 bbl Water Type : Fresh CW100 DESIGN Fluid No: 2 Density : 8.33 Ib/gal Rheo. Model : NEWTONIAN At temp. : 80 degF Viscosity : 5.000 cP Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY MUDPUSH II DESIGN : 8.149 gal/sk Fluid No: 3 : 2.47 ft3/sk Density : 10.50 Ib/gal Rheo. Model : HERSCHEL_B. k : 3.95E-2 IV. s^n/ft2 At temp. : 80 degF n : 0.366 Ty :10.19lbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl 12 ppg DeepCRETE DESIGN Fluid No: 4 Density : 12.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 1.18E-2 Ibf.s^n/ft2 At temp. : 64 degF n : 0.797 Ty :15.121bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 8.149 gal/sk Yield : 2.47 ft3/sk Porosity :44.2 % Density :8.32 lb/gal Job volume : 73.0 bbl Quantity : 166.12 sk Solid Fraction :55.8 % Base Fluid : 8.149 gal/sk Page 6 - 2N-321 Cement.dw ; 05-22-2007; LoadCase Surface; Version wcs-cem45_89 ORIGINAL Client ConocoPAlaska Well 2N-327 Slant Producer c l rg r String 95-8 District Prudhoe Bay Country United States of America Loadcase Surface ASL lead DESIGN Fluid No: 5 Density :10.70 Ib/gal Rheo. Model : HERSCHEL_B. k : 3.24E-2 Ibf.s^n/ft2 At temp. : 66 degF n :0.431 Ty : 18.75 lbf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 21.150 gal/sk Yield : 4.49 ft3/sk Porosity :62.9 % Density :8.32 lb/gal Job volume : 362.5 bbl Quantity : 453.06 sk Solid Fraction : 37.1 % Base Fluid : 20.569 gal/sk 2N-327 Cement.cfw ; 05-22-2007 ; LoadCase Surface ; Version wcs-cem45_89 Page 7 0 • Client ConocoPhillips Alaska ��I rg�r Well 2N-327 Slant Producer String 95-8 District Prudhoe Bay Country United States of America Loadcase Surface Section 4: fluid sequence Job Objectives: Bring cement to surface. Original fluid Mud 9.50 Ib/gal Pv : 20.000 cP TY: 30.00 Ibf/100ft2 Displacement Volume 192.3 bbl Total Volume 727.8 bbl TOC 0.0 ft Name Volume bbl Ann. Len ft Top ft Fluid Sequence Density (lb/gal) Rheology Pore CW100 50.0 0.0 2796 psi 8.33 viscosity:5.000 cP 5750 psi at 0.0 ft MUDPUSH II 50.0 0.0 80 10.50 k:3.95E-2 Ibf.s^n/ft2 n:0.366 TY:10.19 Ibf/100ft2 ASL lead 362.5 1816.0 0.0 10.70 k:3.24E-2 Ibf.s^n/ft2 n:0.431 TY:18.75 Ibf/100ft2 12 ppg DeepCRETE 73.0 800.0 1816.0 12.00 k:1.18E-2 Ibf.s^n/ft2 n:0.797 TY:15.12 Ibf/100ft2 Water 20.0 ASL lead 2272.2 8.32 viscosity:3.000 cP 362.5 80 Mud 172.3 7.0 0.0 9.50 Pv:20.000 cP 80 TY:30.00 Ibf/100ft2 Static Security Checks : Flow Rate (bb(/min) Volume (bbl) Frac 7 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 2796 psi at 2536.0 ft Burst 5750 psi at 0.0 ft CSg.Pump out 34 ton 0.0 Section 5: pumping schedule Name Flow Rate (bb(/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. degF) Comments CW100 5.0 25.0 5.0 25.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure Test Lines CW100 5.0 25.0 5.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 50.0 8.3 50.0 80 ASL lead 7.0 362.5 51.8 362.5 80 12 ppg 7.0 73.0 10.4 73.0 80 DeepCRETE Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to Rig Pumps Mud 6.0 148.9 24.8 148.9 80 Mud 3.0 20.0 6.7 168.9 80 Slow to Bum Total 02:21 724.4 bbl hr:mn Dynamic Security Checks: Frac 6 psi at 80.0 ft Pore 1 psi at 80.0 ft Collapse 2803 psi at 2536.0 ft Burst 5476 psi at 0.0 ft Page 8 2N-327Cement.cfw;05-22-2007; LoadCase Surface; Version wcs-cem45_89 ORIGINAL ft 8 o�—� O O 0 0 o - N O O M - m m O Fluid Sequence lb/gal 10 12 14 • Mn, Hydrostatic 0 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 95-8 District Prudhoe Bay Country United States of America Loadcase Surface ft 8 o�—� O O 0 0 o - N O O M - m m O Fluid Sequence lb/gal 10 12 14 • Mn, Hydrostatic 0 Oj — Max. Dynarric — Mn. Dynarric — Frac Pbre -y Hydrostatic CLOd N S O Dynamic Well Security 0 400 800 Pumped Volume (bbl) 0 0 400 800 Pumped Volume (bbl) Ue to = Zb16 ft Pseudo Hydrostatic ... ..1.. f 3 100 200 300 400 500 600 700 Pumped Volume (bbl) 7 0 100 200 300 400 500 600 700 800 Pumped Volume (bbl) schlum6crgcr Page 9 2N-327 Cement.cfw; 05-22-2007; LoadCase Surface; Version wcs-cem45_89 ORIGINAL Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 5/22/2007 Prepared by: Maureen Tome Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 9 5/8", 40.0# casing at 2,616' MD < Top of Tail at 4,870' MD < 7", 26.0# casing in 8 3/4" OH TD at 5,870' MD (5,160' TVD) � r»CA5 Prei rnir ary Jfl Design 2N-327, V2 Schlumberger 7�' �ner-medieteesin Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail slurry is designed for 1000' MD above the intermediate casing shoe (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be 14.7 ppg. Tail Slurry Minimum thickening time: 190 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D60OG + 0.1 % 13155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.1503 ft3/ft x 1000' x 1.50 (50% excess) = 225.5 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 225.5 ft3 + 17.2 ft3 = 242.7 ft3 242.7 ft3/ 1.17 ft3/sk = 207.4 sks Round up to 210 sks 15.0 BHST = 111 F, Estimated BHCT = 75F. (BHST calculated using a gradient of 2.2F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) Drop Bottom Plug 10.0 10.0 MudPUSH II 5 25 5.0 15.0 Tail Slurry 6 44 7.3 22.3 Drop Top Plug 5.0 27.3 Pump Water 4 20 &0 32.3 Switch to Rig Pump 5.0 37.3 Displacement 5 1 152 30.4 1 67.7 Slow Rate 3 1 50 1 16.7 1 84.4 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv < 15, Ty < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* II, Pv = 19-22, Ty = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. Schlumberger CemCAD E*well cementing recommendation for 7" Intermediate Operator : ConocoPhillips Alaska Well 2N-327 Slant Producer Country : United States of America Field Tarn State : Alaska Prepared for : Mike Greener Location 2N Pad Proposal No. : V2 (vvp07) Service Point Prudhoe Bay Date Prepared : 05-21-2007 Business Phone (907) 659-2434 FAX No. (907) 659-2538 Prepared by Phone E -Mail Address Maureen Torrie 1-907-265-6336 mtorrie@slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger 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 Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may 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 conditions affecting them. 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 responsibility to 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. Actual charges may 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 ORIGIfd:1L Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 5870.0 ft BHST : 112 degF Bit Size : 8 3/4 in Previous String MD OD Weight ID ft in Ib/ft in 2616.0 95/8 40.0 8.835 Landing Collar MD : 5790.0 ft Casing/liner Shoe MD : 5870.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 5870.0 7 40.0 26.0 6.276 L-80 5410 7240 BTC Page 2 2N-327Cement.cfw; 05-22-2007; LoadCaseIntermediate ; Version wcs-cem45_89 0 • Client Conoc2N-327 Plant reduce sc I plop Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate Mean OH Diameter : 8.750 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 9.505 in Total OH Volume : 285.6 bbl (including excess) Max. Deviation Angle : 32 deg Max. DLS : 3.500 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 30.0 30.0 0.0 0.0 0.000 130.0 130.0 0.0 0.0 0.000 230.0 230.0 0.0 0.0 0.000 330.0 330.0 0.0 0.0 0.000 430.0 430.0 1.6 210.0 -1.600 530.0 529.9 3.6 210.0 2.000 630.0 629.5 6.0 210.0 2.400 730.0 728.7 8.5 210.0 2.500 830.0 827.2 11.1 208.5 2.622 930.0 924.8 14.0 205.1 3.001 1030.0 1021.2 17.0 202.8 2.993 1130.0 1116.1 19.9 201.2 3.003 1230.0 1209.2 22.9 200.0 3.002 1330.0 1300.2 25.9 199.0 2.998 1430.0 1389.1 28.8 198.2 3.002 1530.0 1475.4 31.7 197.6 2.846 1630.0 1560.6 31.7 197.6 0.000 1730.0 1645.7 31.7 197.6 0.000 1830.0 1730.8 31.7 197.6 0.000 1930.0 1815.9 31.7 197.6 0.000 2030.0 1901.0 31.7 197.6 0.000 2130.0 1986.1 31.7 197.6 0.000 2230.0 2071.3 31.7 197.6 0.000 2330.0 2156.4 31.7 197.6 0.000 2430.0 2241.5 31.7 197.6 0.000 2530.0 2326.6 31.7 197.6 0.000 2616.0 2399.8 31.7 197.6 0.000 2630.0 2411.7 31.7 197.6 0.000 2730.0 2496.9 31.7 197.6 0.000 2830.0 2582.0 31.7 197.6 0.000 2930.0 2667.1 31.7 197.6 0.000 3030.0 2752.2 31.7 197.6 0.000 3130.0 2837.3 31.7 197.6 0.000 3230.0 2922.4 31.7 197.6 0.000 3330.0 3007.6 31.7 197.6 0.000 3430.0 3092.7 31.7 197.6 0.000 3530.0 3177.8 31.7 197.6 0.000 3630.0 3262.9 31.7 197.6 0.000 3730.0 3348.0 31.7 197.6 0.000 3830.0 3433.1 31.7 197.6 0.000 3930.0 3518.3 31.7 197.6 0.000 4030.0 3603.4 31.7 197.6 0.000 4130.0 3688.5 31.7 197.6 0.000 4230.0 3773.6 31.7 197.6 0.000 4330.0 3858.7 31.7 197.6 0.000 4430.0 3943.9 31.7 197.6 0.000 Page 3 2N-327Cement.cfw; 05-22-2007; LoadCaseIntermediate ; Version wcs-cem45_89 n3 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate MD ft Directional Survey Data TVD Deviation Azimuth ftde de Dogleg Sev. de /100ft 4530.0 4029.0 31.7 197.6 0.000 4630.0 4114.1 31.7 197.6 0.000 4730.0 4199.2 31.7 197.6 0.000 4830.0 4284.3 31.7 197.6 0.000 4930.0 4369.4 31.7 197.6 0.000 5030.0 4454.6 31.7 197.6 0.000 5130.0 4539.7 31.7 197.6 0.000 5230.0 4625.1 30.9 197.6 -0.730 5330.0 4712.4 27.4 197.6 -3.500 5430.0 4802.5 23.9 197.6 -3.500 5530.0 4895.1 20.4 197.6 -3.500 5630.0 4989.8 16.9 197.6 -3.500 5730.0 5086.3 13.4 197.6 -3.500 5830.0 5184.2 9.9 197.6 -3.500 5870.0 5223.7 8.5 197.6 -3.500 MD ft Frac. (lb/gal Formation Pore (lb/gal) Data Name Lithology 1560.0 12.50 8.20 Base Permafrost Sandstone 2550.0 12.50 8.20 C80 Sandstone 4210.0 12.50 8.20 C50 Sandstone 4425.0 12.50 8.20 C40 Sandstone 4580.0 12.50 8.20 C37 Sandstone 5480.0 12.50 8.20 T7 Sandstone 5725.0 12.50 8.20 T4 Sandstone 5820.0 12.50 8.20 T3 Sandstone 5870.0 12.50 8.20 7 TD Sandstone 6065.0 12.60 11.70 T2 Sandstone 6190.0 12.60 11.70 C35 Sandstone 6823.0 12.60 11.70 4 1-2 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1560.0 1501.0 30 0.3 5870.0 5223.7 112 1.7 2N-327Cement.cfw;05-22-2007; LoadCaseIntermediate; Version wcs-cem45_89 ORIGINAL Page 4 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate ft o- 0 0 o- Lf7 N 0 0 0 0 Ln O 0 0 47 f~ degF Temperature Lr, C C U- C C, ❑ Lf C C) C C7 o r x u C, C c U c C 4 U 47 Schlumhcrgcr (x 1000) ft Hori. Departure 2N-327Cement.cfw;05-22-2007; LoadCaseIntermediate ;Versionwcs-cem45-89 ORIGINAL Page 5 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :5860.0 ft Casing Shoe :5870.0 ft NB of Cent. Used :79 NB of Floating Cent. :79 Schlumberger Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) Ibf (Ibf) 1121670-7-6-16 7 8.752 8.000 No Houma 8.500 254.03 1494.98 1/8" B (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Page 6 2N-327 Cement .cfw;05-22-2007; LoadCaseIntermediate; Version wcs-cem45_89 ORIGINAL Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 2830.0 23 1/3 1121670-7-6-16 (1/8")B 0.0 2811.9 4750.0 0 0/0 0.0 2830.0 5870.0 56 2/1 1121670-7-6-16 1/8")B 0.0 4758.1 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) Ibf (Ibf) 1121670-7-6-16 7 8.752 8.000 No Houma 8.500 254.03 1494.98 1/8" B (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Page 6 2N-327 Cement .cfw;05-22-2007; LoadCaseIntermediate; Version wcs-cem45_89 ORIGINAL Client ConocoPhillips Alaska Irgr Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate Section 3: fluid description Fluid No: 3 Rheo. Model : HERSCHEL_B. At temp. : 120 degF MUDPUSH II DESIGN Density k n Ty Gel Strength Job volume Mud DESIGN Fluid No: 1 Density : 10.00 Ib/gal Rheo. Model : BINGHAM PV : 14.000 cP At temp. : 80 degF Ty : 22.00 Ibf/100ft2 Ty :17.951bf/100ft2 Gel Strength : (Ibf/100ft2) MUD DESIGN Mud Type : WBM Job volume : 201.5 bbl Water Type : Fresh Dry Density : 199.77 Ib/ft3 Yield : 1.17 ft3/sk Fluid No: 3 Rheo. Model : HERSCHEL_B. At temp. : 120 degF MUDPUSH II DESIGN Density k n Ty Gel Strength Job volume : 12.00 Ib/gal :2.42E-1 Ibf.s^n/ft2 :0.181 :1.601bf/100ft2 : (Ibf/100ft2) : 25.0 bbl G $ Gasl3LOK DESIGN Fluid No: 7 Density : 15.80 Ib/gal Rheo. Model : HERSCHEL_B. k : 1.76E-2 IV. s^n/ft2 At temp. : 107 degF n :0.651 Ty :17.951bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name :G Mix Fluid : 5.196 gal/sk Job volume : 43.2 bbl Dry Density : 199.77 Ib/ft3 Yield : 1.17 ft3/sk Quantity : 208.29 sk Sack Weight :94 Ib Porosity :59.2 % Solid Fraction :40.8 % BASE FLUID Type : Fresh water Density : 8.32 Ib/gal Base Fluid : 2.961 gal/sk Additives Code Conc. Function D047 0.200 gal/sk blend antifoam D065 0.350 %BWOC dispersant D60OG 2.000 gal/sk blend GASBLOK 8155 0.060 %BWOC retarder Page 7 2N-327 CementOw ; 05-22-2007; LoadCaseIntermediate ; Version wcs-cem45_89 k"'RIGINAL Client ConocoPhillips P Alaska ac i nar Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate Section 4: fluid sequence Job Objectives: Set Casing 30' above Bermuda top, isolate weaker zones from production zone (Bermuda). Original fluid Mud 10.00 Ib/gal Pv : 14.000 cP TY: 22.00 Ibf/100ft2 Displacement Volume 221.5 bbl Total Volume 289.8 bbl TOC 4870.0 ft Static Security Checks : Checks Frac Fluid Sequence Name Volume Ann. Len Top Density Rheology 4791 psi bbl ft ft (lb/gal) MUDPUSH II 25.0 622.5 4247.5 12.00 k:2.42E-1 Ibf.s^n/ft2 n:0.181 Tr:1.60 Ibf/100ft2 G & GasBLOK 43.2 1000.0 4870.0 15.80 k:1.76E-2 Ibf.s^n/ft2 n:0.651 Tv:17.95 Ibf/100ft2 Water 20.0 10.0 0.0 5267.3 8.32 viscosity:3.000 cP Mud 201.5 25.0 0.0 10.00 Pv:14.000 cP Tr:22.00 Ibf/100ft2 Static Security Checks : Checks Frac 312 psi at 2616.0 ft Pore 224 psi at 2616.0 ft Collapse 4791 psi at 5790.0 ft Burst 7240 psi at 2930.0 ft Csg.Pump out 51 ton Section 5: pumping schedule Total 01:24 289.8 bbl hr:mn Dynamic Security Checks Pumping Schedule Frac 11 psi at 5870.0 ft Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments at 5790.0 ft (bbl/min) (bbl) (min) (bbl). Temp. degF Temperature Results Pause 0.0 0.0 10.0 0.0 80 Pressure Test, Drop Plug MUDPUSH II 5.0 25.0 5.0 25.0 80 G & GasBLOK 6.0 43.2 7.2 43.2 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 4.0 20.0 5.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to Rig Pump Mud 5.0 151.5 30.3 151.5 80 Mud 3.0 50.0 16.7 201.5 80 Total 01:24 289.8 bbl hr:mn Dynamic Security Checks Frac 11 psi at 5870.0 ft Pore 224 psi at 2616.0 ft Collapse 4791 psi at 5790.0 ft Burst 6482 psi at 0.0 ft Temperature Results API BHCT 98 degF Simulated BHCT 75 degF CT at TOC 75 degF I Simulated Max HCT 112 degF Max HCT Depth 5870.0 ft Max HCT Time 00:00:00 hr:mn:sc Page 8 2N-327Cemen1.cfw;05-22-2007; LoadCaseIntermediate; Version wcs-cem45_89 ORIGIN^,i- Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate ft C) 0 0 CD - LO N O O N t- Ibfgal 10 12 14 Nin. Hydrostatic �j —Ca1c. FLnp Press. — Max. Dynamic —Calc. WFP — Mn. Dynarric Frac Pore N Hydrostatic a 0 200 400 Pumped Volume (bbl) C De�Velocity 0 ft N An C E U O N C Q 0, 0 200 400 Fluid Sequence Dynamic Well Security Pumped Volume (bbl) O De = 5870 ft oCollapse = Burst .. ... x I— Dynanic M ME Schlumdorger ca O 0 40 80 120 160 200 240 280 32C Pumped Volume (bW) DeDth = 5870 ft Frac _ ._._.....I Pore _....1._ Dynamic i n An An 190 160 200 240 280 32C Pumped Volume (bW) Page 9 2N-327 Cement .cfw;05-22-2007; LoadCamlntermediak;Versionwcs-cem45_89 ORIGINAL. 0 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 7 District Prudhoe Bay Country United States of America Loadcase Intermediate Section 6: WELLCLEAN II Simulator ft 0 50 100 0 100 0 Std Betw .Cent. -Mud Conta.nation o -Cement Coverage - Uncontamnated Slurry 0 0 CD - Fluid Sequence Cement Coverage Fluids Concentrations Z 4000 6400 4200- 4200 4x00- 1400 4603- 1600 4eoa- laoo n 5000- 4600- 5400 a 1600 A a s2oa- d800 s2oo 5400- 5400 a 5400 5600- -5600 5400- 9800- 5400 5800 O ; 0 _A 560x- 0 ® Mud Q G & GasBLOK 0 Wift MUDPUSH II • 01111 ! bepoer deg Uncontaminated Slurry Deviation Risk Mud on the Wall o � 4o0a 1400 4200— 1200 4do3-1 I 1400 4600- t r 1600 4000- d800 s 5000-j { C[ 5400 a n •i.11 C3 5200- 5200 5400- 5400 5600- 5600 560x- 5800 � o � Q H igh Low 0 Medium ® None Page 10 2N-327Cement.cfw;05-22-2007; LoadCase Intermediate; Version wcs-cem45-89 ORIGINAL Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 5/22/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at < 5,470' MD < Liner Top at 5,670' MD Previous Csg. 7", 26.0# casing at 5,870' MD < 4 1/2", 12.6# casing in 6 1/8" OH TD at 6,823' MD (6,025' TVD) Mark of Schlumberger 2N-327, V2 Cem AD Pre ift, ry Job_ fles gn Schlumbepp �i i4 = 4 �2" Liner �'':a! Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 4.5"- 16.6# drill string. Cementjob is designed to seal off liner top by bringing cement 200' above liner top, with 15.8 ppg G cement (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be ppg. Tail Slurry Minimum thickening time: 160 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk Liner Cap: 10.0 0.1044 ft3/ft x 200'x 1.00 (no excess) = 20.9 ft3 Liner Lap: 3.0 0.1044 ft3/ft x (5870' - 5670') x 1.00 (no excess) = 20.9 ft3 Annular Volume: Drop Top Plug 0.0942 ft3/ft x (6823'- 5870') x 1.50 (50% excess) = 134.7 ft3 Shoe Volume: 97 32.3 0.0854 ft3/ft x 80'x 1.00 (no excess) = 7.7 ft3 Totals: 20.9 ft3+20.9 ft3 +134.7 ft3 +7.7ft3 = 184.2 ft3 184.2 ft3/ 1.17 ft3/sk = 157.4 sks Round up to 160 sks BHST = 1307, Estimated BHCT = 104F. (BHST calculated using a gradient of 2.2F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) Pressure Test 10.0 - MudPUSH II 5 15 3.0 3.0 Tail Slurry 5 33 6.6 9.6 Drop Top Plug 3.0 12.6 Displacementl 3 97 32.3 44.9 MUD REMOVAL Recommended Mud Properties: 12 ppg, Pv < 15, Ty < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* II, Pv = 19-22, Ty = 22-29 Centralizers: Recommend 1 per joint from 5950' MD to TD, and 2 per joint from 5870' MD to 5940' MD for proper cement placement. ORIGINIU 0 Schlumberger CemCAD E*well cementing recommendation for 4.5" Liner Operator : ConocoPhillips Alaska Well 2N-327 Slant Producer Country : United States of America Field Tarn State : Alaska Prepared for : Mike Greener Location 2N Pad Proposal No. : V2 (wp07) Service Point Prudhoe Bay Date Prepared : 05-21-2007 Business Phone (907) 659-2434 FAX No. (907) 659-2538 Prepared by Phone E -Mail Address Maureen Torrie 1-907-265-6336 mtorrie@slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger 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 Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may 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 conditions affecting them. 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 responsibility to 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. Actual charges may 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 ORIGI NIAL r L Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner Section 1: well description Configuration : Liner Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 6823.0 ft BHST : 133 degF Bit Size : 6 1/8 in Previous String MD OD Weight ID ft in Ib/ft in 5870.0 7 26.0 6.276 schlumhPlep Drill Pipe MD OD Weight ID Grade Collapse Burst ft (in) Ib/ft in(psi) psi 5670.0 41/2 20.0 3.640 X-95 16410 15890 Liner Hanger : 5670.0 ft Landing Collar MD : 6743.0 ft Casing/liner Shoe MD : 6823.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft Ib/ft in(psi) (psi) 6823.0 41/2 40.0 12.6 3.958 L-80 7500 8430 IBT Page 2 2N-327Cement.dTw; 05-22-2007; LoadCaseLiner; Version wcs-cem45_89 0 1 G a� s L Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner Mean OH Diameter :6.125 in Mean Annular Excess :50.0 % Mean OH Equivalent Diameter: 6.793 in Total OH Volume : 42.7 bbl (including excess) Max. Deviation Angle : 32 deg Max. DLS : 3.500 deg/100ft MD ft Directional Survey Data TVD Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 30.0 30.0 0.0 0.0 0.000 130.0 130.0 0.0 0.0 0.000 230.0 230.0 0.0 0.0 0.000 330.0 330.0 0.0 0.0 0.000 430.0 430.0 1.6 210.0 -1.600 530.0 529.9 3.6 210.0 2.000 630.0 629.5 6.0 210.0 2.400 730.0 728.7 8.5 210.0 2.500 830.0 827.2 11.1 208.5 2.622 930.0 924.8 14.0 205.1 3.001 1030.0 1021.2 17.0 202.8 2.993 1130.0 1116.1 19.9 201.2 3.003 1230.0 1209.2 22.9 200.0 3.002 1330.0 1300.2 25.9 199.0 2.998 1430.0 1389.1 28.8 198.2 3.002 1530.0 1475.4 31.7 197.6 2.846 1630.0 1560.6 31.7 197.6 0.000 1730.0 1645.7 31.7 197.6 0.000 1830.0 1730.8 31.7 197.6 0.000 1930.0 1815.9 31.7 197.6 0.000 2030.0 1901.0 31.7 197.6 0.000 2130.0 1986.1 31.7 197.6 0.000 2230.0 2071.3 31.7 197.6 0.000 2330.0 2156.4 31.7 197.6 0.000 2430.0 2241.5 31.7 197.6 0.000 2530.0 2326.6 31.7 197.6 0.000 2616.0 2399.8 31.7 197.6 0.000 2630.0 2411.7 31.7 197.6 0.000 2730.0 2496.9 31.7 197.6 0.000 2830.0 2582.0 31.7 197.6 0.000 2930.0 2667.1 31.7 197.6 0.000 3030.0 2752.2 31.7 197.6 0.000 3130.0 2837.3 31.7 197.6 0.000 3230.0 2922.4 31.7 197.6 0.000 3330.0 3007.6 31.7 197.6 0.000 3430.0 3092.7 31.7 197.6 0.000 3530.0 3177.8 31.7 197.6 0.000 3630.0 3262.9 31.7 197.6 0.000 3730.0 3348.0 31.7 197.6 0.000 3830.0 3433.1 31.7 197.6 0.000 3930.0 3518.3 31.7 197.6 0.000 4030.0 3603.4 31.7 197.6 0.000 4130.0 3688.5 31.7 197.6 0.000 4230.0 3773.6 31.7 197.6 0.000 4330.0 3858.7 31.7 197.6 0.000 4430.0 3943.9 31.7 197.6 0.000 2N-327Cement.dw; 05-22-2007; LoadCase Liner; Version wcs-oem45 89 Y r) & . . , k..j R, I G I INI A L hIrger Page 3 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner MD (ft) Directional Survey Data TVD Deviation Azimuth ft de de Dogleg Sev. de /100ft 4530.0 4029.0 31.7 197.6 0.000 4630.0 4114.1 31.7 197.6 0.000 4730.0 4199.2 31.7 197.6 0.000 4830.0 4284.3 31.7 197.6 0.000 4930.0 4369.4 31.7 197.6 0.000 5030.0 4454.6 31.7 197.6 0.000 5130.0 4539.7 31.7 197.6 0.000 5230.0 4625.1 30.9 197.6 -0.730 5330.0 4712.4 27.4 197.6 -3.500 5430.0 4802.5 23.9 197.6 -3.500 5530.0 4895.1 20.4 197.6 -3.500 5630.0 4989.8 16.9 197.6 -3.500 5730.0 5086.3 13.4 197.6 -3.500 5830.0 5184.2 9.9 197.6 -3.500 5870.0 5223.7 8.5 197.6 -3.500 5930.0 5283.2 6.4 197.6 -3.500 6030.0 5382.7 5.0 197.6 -1.430 6130.0 5482.3 5.0 197.6 0.000 6230.0 5582.0 5.0 197.6 0.000 6330.0 5681.6 5.0 197.6 0.000 6430.0 5781.2 5.0 197.6 0.000 6523.0 5873.8 5.0 197.6 0.000 6823.0 6172.7 5.0 197.6 0.000 MD ft Frac. (lb/gal Formation Pore (lb/gal) Data Name Lithology 1560.0 12.50 8.20 Base Permafrost Sandstone 2550.0 12.50 8.20 C80 Sandstone 4210.0 12.50 8.20 C50 Sandstone 4425.0 12.50 8.20 C40 Sandstone 4580.0 12.50 8.20 C37 Sandstone 5480.0 12.50 8.20 T7 Sandstone 5725.0 12.50 8.20 T4 Sandstone 5820.0 12.50 8.20 T3 Sandstone 5870.0 15.00 8.20 7 TD Sandstone 6065.0 15.00 11.70 T2 Sandstone 6190.0 15.00 11.70 C35 Sandstone 6823.0 15.00 11.70 4 1-2 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1560.0 1501.0 30 0.3 6823.0 6172.7 133 1.7 2N-327Cement.dw; 05-22-2007; LoadCaseLiner; Version wcs-cem45_89 Se I pgep Page 4 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner ft o- 0 0 0 ko 0 0 0 0 Ln 0 0 0 Ln I- - degF Temperature o Cr 0,1 L< u- r- (x 1000) ft Schlumbcrgcr Hori. Departure Page 5 2N-327 Cement.dw: 05-22-2007; LoadCase Liner; Version wcs-cem45_89 ORIGINAL Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner Section 2: centralizer placement Top of centralization :5870.0 ft Bottom Cent. MD :6803.0 ft Casing Shoe :6823.0 ft NB of Cent. Used :24 NB of Floating Cent. :0 Sclpcp Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 5943.0 2 2/1 P1104641-4 1/2-4-46 (3/16")B 43.6 5913.0 6823.0 22 1/1 P1104641-4 1/2-4-46 (3/16")B 78.7 5983.0 Centralizer DescriptionCentralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force P1104641-41 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Page 6 2N-327 Cement.dw; 05-22-2007; LoadCase Liner; Version wcs-cem45_89 ORII GINJAI Section 3: fluid description Fluid No: 1 Rheo. Model : BINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type : Fresh Mud DESIGN Density PV Ty Gel Strength Job volume • SIrger 12.00 Ib/gal 14.000 cP 22.00 Ibf/100ft2 (Ibf/100ft2) 89.3 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 13.00 Ib/gal Rheo. Model : HERSCHEL_B. k :2.42E-1 Ibf.s^n/ft2 At temp. : 120 degF n :0.181 Ty :1.60lbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 15.0 bbl 10 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner Section 3: fluid description Fluid No: 1 Rheo. Model : BINGHAM At temp. : 80 degF MUD Mud Type : WBM Water Type : Fresh Mud DESIGN Density PV Ty Gel Strength Job volume • SIrger 12.00 Ib/gal 14.000 cP 22.00 Ibf/100ft2 (Ibf/100ft2) 89.3 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 13.00 Ib/gal Rheo. Model : HERSCHEL_B. k :2.42E-1 Ibf.s^n/ft2 At temp. : 120 degF n :0.181 Ty :1.60lbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 15.0 bbl Page 7 2N-327Cement.cfw;05-22-2007; LoadCase Liner; Version wcs-cem45_89 ORM ! NI A . G cement DESIGN Fluid No: 7 Density : 15.80 Ib/gal Rheo. Model : HERSCHEL_B. k :7.15E-3 Ibf.s^n/ft2 At temp. : 119 degF n : 0.707 Ty :21.18 1 bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 5.155 gal/sk Job volume : 32.6 bbl Dry Density : 199.77 Ib/ft3 Yield : 1.17 ft3/sk Quantity : 157.21 sk Sack Weight : 94 Ib Porosity :59.2 % Solid Fraction :40.8 % BASE FLUID Type : Fresh water Density : 8.32 Ib/gal Base Fluid : 2.955 gal/sk Additives Code Conc. Function D047 0.200 gal/sk blend antifoam D065 0.350 %BWOC dispersant D60OG 2.000 gal/sk blend GASBLOK B155 0.100 %BWOC retarder Page 7 2N-327Cement.cfw;05-22-2007; LoadCase Liner; Version wcs-cem45_89 ORM ! NI A . Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner Section 4: fluid sequence Job Objectives: Seal off liner top by bringing cement 200' above liner top. Schlrgcr Original fluid Mud 12.00 Ib/gal Pv : 14.000 cP TY: 22.00 I01002 Displacement Volume 89.3 bbl Drill Pipe Volume 73.0 bbl Total Volume 136.9 bbl TOC 5470.0 ft Static Security Checks : Frac 119 psi Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) MUDPUSH II 15.0 806.8 4663.2 13.00 k:2.42E-1 Ibf.S^n/ft2 n:0.181 Tv:1.60 Ibf/100ft2 G cement 32.6 1353.0 5470.0 15.80 k:7.15E-3 lbf.s^n/ft2 n:0.707 TY: 21.18 Ibf/100ft2 Mud 89.3 0.0 0.0 12.00 Pv:14.000 cP Tr:22.00 Ibf/100112 Static Security Checks : Frac 119 psi Frac 663 psi at 6823.0 ft Pore 235 psi at 6065.0 ft Collapse 6759 psi at 6743.0 ft Burst 8430 psi at 6743.0 ft Cs .Pump out 45 ton Section 5: pumping schedule Total 00:54 136.9 bbl hr:mn Dynamic Security Checks Frac 119 psi Pumping Schedule Pore 85 psi Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) Pause 0.0 0.0 10.0 0.0 80 Pressure Test MUDPUSH II 5.0 15.0 3.0 15.0 80 G cement 5.0 32.6 6.5 32.6 80 Pause 0.0 0.0 5.0 0.0 80 Drop dart Mud 3.0 89.3 29.8 89.3 80 Total 00:54 136.9 bbl hr:mn Dynamic Security Checks Frac 119 psi at 6823.0 ft Pore 85 psi at 6065.0 ft Collapse 6759 psi at 6743.0 ft Burst 8095 psi at 5670.0 ft API BHCT 112 degF Simulated BHCT 104 degF CT at TOC 101 degF Temperature Results Simulated Max HCT 133 degF Max HCT Depth 6823.0 ft Max HCT Time 00:00:00 hr:mn:sc Page 8 2N-327 Cement.cfw; 05-22-2007; LoadCase Liner; Versionwcs-cem45_89 ft Ibrgal 8 12 16 O N O LO i5 rn av Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner ft Ibrgal 8 12 16 O N O LO i5 rn av • Sc61rlcr 0 50 100 150 Pumped Volume (bbl) o Depth= 6823 ft CCD' -Annular Velocity i N j0 c� c _ Q o 0 50 100 150 Fluid Sequence Dynamic Well Security Pumped Volume (bbl) Ve ui = oozo Ti Collapse Pseudojlydrostatic Dynamic 25 50 75 100 125 Pumped Volume (bbl) 0 25 50 75 100 125 150 Pumped Volume (bbl) Page 9 2N-327 Cement.cfw; 05-22-2007; LoadCase Liner; Version wcs-cem45_e9 ORIGINAL Mn. Hydrostatic - Max. Dynanic Mn. Dynamic p rn O - Frac _O Pore X Hydrostatic _QD •y O a eco �o • Sc61rlcr 0 50 100 150 Pumped Volume (bbl) o Depth= 6823 ft CCD' -Annular Velocity i N j0 c� c _ Q o 0 50 100 150 Fluid Sequence Dynamic Well Security Pumped Volume (bbl) Ve ui = oozo Ti Collapse Pseudojlydrostatic Dynamic 25 50 75 100 125 Pumped Volume (bbl) 0 25 50 75 100 125 150 Pumped Volume (bbl) Page 9 2N-327 Cement.cfw; 05-22-2007; LoadCase Liner; Version wcs-cem45_e9 ORIGINAL 0 Client ConocoPhillips Alaska Well 2N-327 Slant Producer String 4.5 District Prudhoe Bay Country United States of America Loadcase Liner Section 6: WELLCLEAN II Simulator ft % % 75.0 100.0 0 100 0 Std BOW. CeM. Mud Contanination Cement Coverage I Uncontamnated Slurry O O LO • deg 20 Schlumhcrgcr 40 Fluid Sequence Cement Coverage Uncontaminated Slurry Deviation Fluids Concentrations Risk Mud on the Wall 5000 6000 6400- 64GG 6t00 6100 6t 00- 6100 6200 6200 6200- 6200 6300 6300 Y F 6300- 6300 6400 6400 -5 :!E 6400- 6400 T Q O CL i i 0 6500 6500 0 O 6500- C500 6600 6600 6600- 6600 6700 8700 8700- 8700 6800 6800 6800- 6800 o `o z z Mud Q High Low G cement Medium None D MUDPUSHII Page 10 2N-327 Cennent.dw ; 05-22-2007; LoadCaseLiner; Version wcs-cenn45_89 ORIGINAL EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 0 5950000 5900000 5850000 - 400000 500000 600000 700000 0 SH77 CpNOCOPHILLIPARON K. ALLSUPS•DRAKE ; , ATO I 3o 1184 arta sr, ANCHORAGEAK .99501 DATE %� FArr0THE � VT J -+- 66-1551/441 ORDER OF SG J P � . $ /00.0j wlorganChase 6LLARs 8 .�. JPMorgan Chase Bank, N.A. Valid Up To p Columbus, OH Dollars MEMO r0 4 411 S 5 lr• 1:S26747L9 07927u•1L84 • 0 TRANSMITTAL LETTER CHECKLIST WELL NAME. PTD# 2'0 7 Development " Service Exploratory p ry Strahgraphic Test Yon -Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK j ADD-ONS WHAT (OPTIONS) APPLIES MULTI LATERAL (If last two digits in API number are between 60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing well Permit No. , AP[ No. 50 - Production should continue to be reported as a function of the original API number stated above. PILOT HOLE i In accordance with 20 AAC 25.005(f), all records, data and logs j acquired for the pilot hole must be clearly differentiated in both !well name ( PH) and API number (50- - -`) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ( 25.055. Approval to perforate and tzoduce /inject is contingent i upon issuance of a conservation order approving a spacing j I exception. ' assumes the i liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to dw-Commission must be in SA.%4PLE i no greater than 30' sample intervals from below the permafrost or Ifrom where samples are first caught and 10' sample intervals 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 I V1%eU for (name of well) until after (Company Name,) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the I Commission to obtain advance approval of such water well testing program. I Rev: 1!2j/O6 C:'iody\transmima1_ch eckl ist so ;',^ Field & Pool_ KUPARUK RIVER, TARN OIL - 490165 Well Name: KUPARUK RIV U TARN 2N-327_ Program SER _.__ Well bore seg ❑ PTD#:2070690 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 -Permit-fee attached ------------------------------------------------------------------------------------------------------------------------------------- Yes 2 Lease number appropriate_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - - - Entire well -lies within_ADL375074, which encompasses Sec's -3,4,9 8, 10 of_T9N, R7E. _However,_only Sec 4 & the 3 Unique well -name and number _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ _ N/2 —SW/4 of Sec_3 lie within the AWand the Tarn_PA. The ini_interval &_T -D- lie about 150' from the KRU_and _ _ 4 Well -located in_adefined -pool ---------------------------------------- Yes - _ - - - - - Tarn PA boundaries,_but there are_no correlative rights -issues as_ownership of the KRU and -the remainder of _ _ _ 5 Well -located proper distance from drilling unit_boundary- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - ADL375074 are the same, The adjacent lease ADL 390982 1624' t4 E has a slight change of ownership, but the 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ _ _ well a_splanned confor_m_s to spacing regulations of CO 430A._ - _ _ _ - - - - - _ - _ _ _ _ - - - - - - _ _ _ _ _ _ _ - - - 7 Sufficient acreage- available in_drilling unit- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ - - Nearest well -lies 1/2 mile to -NW.- Proposed well -2N7327 will be the_only well in the_NE/4 of -Sec 3 -- - - - - - - - - - - 8 If deviated, is wellbore plat_included------ ------ -------------- -- - - - - -- Yes--- ------------------------------------------------------------------------ 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 Operator has -appropriate bond in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit can be issued without conservation order Yes -- - - - - - - - -- Appr Date !12 -Permit- can be issued without administrative approval - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ _ _ - - - - - _ _ _ _ - - - - - _ _ _ _ - - - - - _ _ _ _ _ - - - - - - - _ _ _ - - - - - - _ _ _ _ _ - - - - - - - - _ _ _ - - _ - _ - SFD 5/30/2007 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and -strata authorized by Injection Order # (put 10# in_comments)_ (For_ -Yes - - - - _ _ _ AIO.16. Inj interval lies 1-1/2_mil_es from nearest exterior boundary_ of AIO 16. - _ - - - - - - - - - - - - - - - - - - - - 15 All Wells _within_1/4_mile area -of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _ None_ _ _ _ _ _ - - _ _ _ _ _ _ _ - _ _ _ _ _ _ _ - - - _ _ _ _ - - - - - _ _ _ - - - - - - _ - _ _ _ _ _ - - - - - - _ _ _ - - - - - 16 _P_re-produced injector: -duration-of pre -production less than 3 months- (For service well only) - _ Yes - - - - _ _ - Mike Greener,. CPAI:_we_ll will_bepre-producedfor_a couple of_months. .... _ .. _ . 17 _N_onconven. gas -conforms to AS31.05.030(.1.A),(y2.A-D) - - - - - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductor string_provided--------------------- ----------- -- -- - - -- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - --- ------------------------------------------ 19 Surface casing protects all -known USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ NA_ - - - - - - - All aquifers exempted,_40 CFR_ 147.102(b)(3)._ - - - - - - _ _ _ - - - - - - _ _ . 20 CMT v_ol adequate_ to circulate- o_n conductor & surf csg - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ - - - - - - _ _ _ _ _ --------------------------------------------------------- 21 _GMT- vol adequate_ to tie-in -long string to -surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - - _ _ - - - All hydrocarbons will be covered. Annular disposal—may—be proposed._ - - _ _ _ 122 CMT_will coverall known productive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ - - - - - - _ _ _ - - - - - - - _ _ _ - - - - - _ _ _ - - - _ - - _ _ - _ _ _ _ - - - - - _ _ 23 Casing designs adequate for C,_T,B&permafrost ---------------- - - -- - -- Yes ----------------------------------------------------------------- 24 Adequate -tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - - - Rig —is—equipped—with steel -pits. - No reservepit_planned. All waste to- approved disposal well(s)-- - - - - - - _ _ _ _ _ 25 If_a_re-drill, has- a- 10-403 for abandonment been approved - - - - - - - - - - - - - - - - - - - - - NA _ _ - - - - _ _ _ _ , --------------------------------------------------------- 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _Proximity_ analysis performed, Traveling cylinder path calculated, Gyros possible_in surface hole, _ _ _ _ _ _ _ _ _ _ 27 If_diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ Yes - - _ - - _ _ _ - - - - - _ _ - _ _ - - - _ _ _ _ _ - - - - - _ _ _ _ _ _ _ - - - - _ _ _ _ - - - - - _ _ _ - - - - - - - - _ - _ _ _ _ _ _ - - Appr Date 28 Drilling fluid_ program schematic_& equip_listadequate- - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ . Maximum expected formation pressure _10 6 EMW._ Planned MW 10.7 pp -or as needed. TEM 6/13/2007 29 B -PEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - n�� 1 30 BOPE_press rating appropriate; test to -(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASP calculated_at 1810 psi, 3500_psi_minimum_BOP test appropriate. _ _ _ - _ _ - _ 31 Choke_manifold complies w/API RP -53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ - - - - - _ - _ _ - - - - - _ _ - - - - - - - - _ _ _ - - _ 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ .. _ _ _ - - - - _ _ _ _ _ - - - - - _ _ _ - - _ - - - - - - _ _ _ - - - _ - _ _ _ _ _ - - - - - - - _ _ _ _ _ - - - - - - - - - - - 33 Is presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ - - - H2S is present at_2_N. Mud should preclude H2S on rig. _ Rig has _sensors- and alarms. - _ - - _ - - - - - - - - - - - _ 34 Mechanical_condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - Yes - _ _ - - - - No wells in AOR- _ _ - - - - - _ _ _ _ Geology 35 Permit can be issued w/o hydrogen sulfide measures - - - - - - - - - - - - - - - - - - - - - No_ _ _ - _ - - - H2S is present in wells from 2N -Pad in quantities measuring >20_ ppm, - - - - - - - - _ - - - _ 36 Data resented n potentialoverpressure p - _ _ o p to _ _ zones_ _ _ _ _ _ _Yes _ - _Expected reservoir -press Lire is 10.6ppg. _Will be drilled with mud weights to 10.7 ppg------------------- Date 37 -SeismiC_analy$1$ of shallow gas zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA - _ _ - - - - Hydrates _may -he encountered.- Mitigation measures discussed in Drilling_ Hazards Summary._ - - - - - - _ _ _ _ _ _ SFD SFD 5/30/2007 I 38 Seabed condition survey -(if off. -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ 39 Contact name/phone for weekly_ progress reports [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - _ - - .. _ Geologic Engineering Pu 'c Date: Date Date Injection well drilled to the south of 2N -Pad. TD of well will lie within 150' of external boundary of KRU and the Tarn PA. ry Commissioner: is Commissioner: Co ner 7 6_�� However, the remainder of the lease (ADL 375074) has the same ownership as the KRU, so there are no spacing issues. _off 0 0 s Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 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-327.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 25 12:15:45 2007 Reel Header Service name.............LISTPE Date . ...................07/09/25 Ori in...................STS Ree Name. .... ........UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. scientific Technical services Tape Header Service name.............LISTPE Date . ...................07/09/25 origin...................STS Tape Name. .... ........UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN comments.................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: MWD RUN 1 MW -000506463 A. MENEZES D. BREEDEN MWD RUN 4 Mw -000506463 T. ONYEKWELU D. BREEDON MWD RUN 6 Mw -000506463 0. OBI D. BREEDEN scientific Technical services 2N-327 501032054800 ConocoPhillips Alaska, Inc. Sperry Sun 25 -SEP -07 MWD RUN 2 MWD RUN 3 MW -000506463 MW -000506463 A. MENEZES A. MENEZES D. BREEDEN D. BREEDEN MWD RUN 5 Mw -000506463 0. OBI D. MORRIS 3 Page 1 MAD RUN 5 MW -000506463 0. OBI D. MORRIS 0 2N-327.tapx TOWNSHIP: 9N RANGE: 7E FNL: 82 FSL: DEPTH (FT) FEL: 850 FWL: 80.0 ELEVATION (FT FROM MSL 0) 8.750 KELLY BUSHING: .00 DERRICK FLOOR: 148.60 GROUND LEVEL: 118.60 WELL CASING RECORD 1. ALL DEPTHS ARE MEASURED DEPTHS (MD), UNLESS OTHERWISE NOTED, AND REFERENCE BIT DEPTH. 2. MWD RUNS 1, 2, & 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER -MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR-4). 3. MWD RUNS 3,5 & 6 ARE DIRECTIONAL WITH DGR, EWR-4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO -DENSITY (ALD), AND BIMODAL ACOUSTIC TOOL (BAT). GAMMA RAY AND EWR DATA IN THE INTERVAL 5854'MD - 6030'MD/5223'TVD-5379'TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE PULLING OUT OF THE HOLE PRIOR TO MWD RUN 5. LWD DATA IN THE INTERVALS 5854'MD-6234'MD/5223'TVD-5598'TVD, AND THE INTERVAL 6513'MD -6656'MD/5875'TVD-6017'TVD WAS ACQUIRED ON MAD PASSES PRIOR TO MWD RUNS 5, AND 6, RESPECTIVELY. 4. LOG CURVE DATA IS CONSIDERED PDC PER THE E-MAIL FROM DERIK KLEIBACKER OF CONOCOPHILLIPS ALASKA, INC. TO B BRYANT OF SPERRY DRILLING SERVICES, DATED 17 -AUG -2006. 5. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP, GAMMA RAY, AND BAT, WHICH ARE SMOOTHED TO A 1.1 FT WINDOW. 6. MWD RUNS 1-5 REPRESENT WELL 2N-327 WITH API #: 50-103-20548-00. THIS WELL REACHED A TOTAL DEPTH (TD) Page 2 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 80.0 2ND STRING 8.750 9.625 2599.0 3RD STRING 6.125 7.000 5854.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD), UNLESS OTHERWISE NOTED, AND REFERENCE BIT DEPTH. 2. MWD RUNS 1, 2, & 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER -MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR-4). 3. MWD RUNS 3,5 & 6 ARE DIRECTIONAL WITH DGR, EWR-4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO -DENSITY (ALD), AND BIMODAL ACOUSTIC TOOL (BAT). GAMMA RAY AND EWR DATA IN THE INTERVAL 5854'MD - 6030'MD/5223'TVD-5379'TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE PULLING OUT OF THE HOLE PRIOR TO MWD RUN 5. LWD DATA IN THE INTERVALS 5854'MD-6234'MD/5223'TVD-5598'TVD, AND THE INTERVAL 6513'MD -6656'MD/5875'TVD-6017'TVD WAS ACQUIRED ON MAD PASSES PRIOR TO MWD RUNS 5, AND 6, RESPECTIVELY. 4. LOG CURVE DATA IS CONSIDERED PDC PER THE E-MAIL FROM DERIK KLEIBACKER OF CONOCOPHILLIPS ALASKA, INC. TO B BRYANT OF SPERRY DRILLING SERVICES, DATED 17 -AUG -2006. 5. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP, GAMMA RAY, AND BAT, WHICH ARE SMOOTHED TO A 1.1 FT WINDOW. 6. MWD RUNS 1-5 REPRESENT WELL 2N-327 WITH API #: 50-103-20548-00. THIS WELL REACHED A TOTAL DEPTH (TD) Page 2 2N-327.tapx OF 6836'MD/6195'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPC'G). 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. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SS MATRIX, VARIABLE/FIXED HOLE SIZE. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' NEUTRON COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' NEUTRON COUNT RATE. SBD2 = SMOOTHED BULK DENSITY -COMPENSATED (LOW COUNT RATE BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW COUNT RATE BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR. ACAL = SMOOTHED ACOUSTIC CALIPER (MWD RUN 3). SGRC = SMOOTHED GAMMA RAY COMBINED. DTCP = SMOOTHED COMPRESSIONAL WAVE SLOWNESS - POST WELL PROCESSED. DTSP = SMOOTHED SHEAR WAVE SLOWNESS - POST WELL PROCESSED. VP/VS = RATIO OF COMPRESSIONAL TO SHEAR WAVE VELOCITIES. PARAMETERS USED IN POROSITY CALCULATIONS: HOLE SIZE: 8.75"/6.125" NOMINAL (VARAIBLE HOLE SIZE RUN 3) MUD WEIGHT: 9.7-10.4 PPG MUD SALINITY: 300 PPM CHLORIDES (RUN 3) - 25,000 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSL2B.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 3 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD REMARKS: 0 DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BIT RUN NO MERGE TOP MERGE BASE 1 204.0 2N-327.tapx 2 1664.0 2610.0 FILE SUMMARY 2610.0 5870.0 PBU TOOL CODE START DEPTH STOP DEPTH RPS 204.0 6822.5 RPX 204.0 6800.0 RPM 204.0 6822.5 RPD 204.0 6822.5 FET 204.0 6822.5 GR 212.0 6815.5 ROP 256.0 6836.0 DTC 2493.5 6722.0 GALA 2589.0 5776.5 PEF 2589.5 6802.5 DRHO 2599.5 6803.0 RHOB 2599.5 6803.0 FCNT 2599.5 6787.5 NPHI 2599.5 6787.5 NCNT 2599.5 6787.5 DTSH 2616.5 6720.0 SORA 2616.5 6720.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD REMARKS: 0 DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BIT RUN NO MERGE TOP MERGE BASE 1 204.0 1664.0 2 1664.0 2610.0 3 2610.0 5870.0 4 5870.0 6030.0 5 6030.0 6513.0 6 6513.0 6836.0 MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type ..... 0 Logging Direction.................Down Optica l log depth unit s........... Feet Data Reference Point..............Undefined Frame Spacing....... ...........60 AIN Max frames per record.............Undefined Absent value ......................-999.25 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU S 4 1 68 32 9 Page 4 0 0 First Reading For Entire File.......... 204 Last Reading For Entire File ........... 6836 File Trailer Service name... ........STSLIB.001 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 Page 5 2N-327.tapx FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD IN 4 1 68 56 15 DTC MWD USPF 4 1 68 60 16 DTSH MWD USPF 4 1 68 64 17 SORA MWD 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 204 6836 3520 13265 204 6836 ROP MWD FT/H 0.13 1995.67 133.239 13139 256 6836 GR MWD API 11 260.59 105.295 13208 212 6815.5 RPX MWD OHMM 0.12 2000 9.10759 13075 204 6800 RPS MWD OHMM 0.07 2000 13.8365 13119 204 6822.5 RPM MWD OHMM 0.51 2000 25.0339 13119 204 6822.5 RPD MWD OHMM 0.62 2000 26.0284 13119 204 6822.5 FET MWD HR 0.12 189.85 4.09171 13119 204 6822.5 NPHI MWD PU S 17.65 56.75 32.841 8217 2599.5 6787.5 FCNT MWD CNTS 123.02 1665.17 767.361 8217 2599.5 6787.5 NCNT MWD CNTS 12928.5 146976 97574.9 8217 2599.5 6787.5 RHOB MWD G/CM 1.829 3.106 2.37687 8275 2599.5 6803 DRHO MWD G/CM -0.023 0.608 0.0683617 8275 2599.5 6803 PEF MWD BARN 1.94 18.4 3.62098 8314 2589.5 6802.5 CALA MWD IN 8.68 10.27 9.10253 6351 2589 5776.5 DTC MWD USPF 48.66 139.98 101.878 8458 2493.5 6722 DTSH MWD USPF 112.81 307.23 204.161 7947 2616.5 6720 SCRA MWD 1.43 2.43 1.97726 7939 2616.5 6720 First Reading For Entire File.......... 204 Last Reading For Entire File ........... 6836 File Trailer Service name... ........STSLIB.001 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 Page 5 EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET RAT MERGED DATA SOURCE PBU TOOL CODE MWD 2N-327.tapx clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH STOP DEPTH 5844.0 6008.5 5854.0 6015.0 5854.0 6015.0 5854.0 6015.0 5854.0 6015.0 5854.0 6015.0 5854.0 6025.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 5 1 5725.0 6513.0 REMARKS: MERGED MAD PASS. 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 .1IN Max frames per record.............undefined Absent value ......................-999.25 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 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5844 6025 5934.5 363 5844 6025 RAT MAD FT/H 89.96 177.6 136.725 343 5854 6025 GR MAD API 70.41 201.85 149.608 330 5844 6008.5 RPX MAD OHMM 0.99 353.62 4.51006 323 5854 6015 RPS MAD OHMM 0.46 8.43 3.56805 323 5854 6015 RPM MAD OHMM 1.12 1926.19 18.9132 323 5854 6015 RPD MAD OHMM 1.18 1871.27 19.7952 323 5854 6015 FET MAD OHMM 189.9 277.75 202.727 323 5854 6015 First Reading For Entire File.......... 5844 Last Reading For Entire File ........... 6025 Page 6 • File Trailer 2N-327.tapx Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File TyE�e................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 ....... 07/09/25 Maximum Physical Record..65535 File Type. ............Lo Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD 0 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 RPX 204.0 RPS 204.0 RPM 204.0 RPD 204.0 FET 204.0 GR 212.0 ROP 256.0 LOG HEADER DATA DATE LOGGED: 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: STOP DEPTH 1612.5 1612.5 1612.5 1612.5 1612.5 1620.0 1664.0 13 -]UL -07 Insite Memory 204.0 1664.0 11.9 30.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): Page 7 12.250 2N-327.tapx DRILLER'S CASING DEPTH (FT): 80.0 1 68 0 1 BOREHOLE CONDITIONS ROP MWD010 MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 10.00 2 MUD VISCOSITY (S): 250.0 GR MUD PH: 9.4 API MUD CHLORIDES (PPM): 300 8 FLUID LOSS (0): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MWD010 MUD AT MEASURED TEMPERATURE (MT): 1.300 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .891 98.0 MUD FILTRATE AT MT: 1.000 65.0 MUD CAKE AT MT: 1.500 65.0 1 68 16 5 NEUTRON TOOL RPM MATRIX: OHMM MATRIX DENSITY: 1 68 20 HOLE CORRECTION (IN): RPD MWD010 TOOL STANDOFF (IN): 4 1 68 EWR FREQUENCY (HZ): 7 FET MWD010 REMARKS: HR 4 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 AIN Max frames per record.............Undefined Absent value ......................-999.25 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 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 204 1664 934 2921 204 1664 ROP MWD010 FT/H 9.54 594.59 153.653 2817 256 1664 GR MWD010 API 11 103.72 60.9629 2817 212 1620 RPX MWD010 OHMM 1.61 121.59 23.4264 2818 204 1612.5 RPS MWD010 OHMM 1.52 856.51 44.9315 2818 204 1612.5 RPM MWD010 OHMM 1.58 2000 91.8926 2818 204 1612.5 RPD MWD010 OHMM 1.89 2000 89.1563 2818 204 1612.5 FET MWD010 HR 0.16 1.33 0.665522 2818 204 1612.5 First Reading For Entire File.......... 204 Page 8 0 2N-327.tapx Last Reading For Entire File ........... 1664 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.... .07/09/25 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 ....... 07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY 0 VENDOR TOOL CODE START DEPTH STOP DEPTH FET 1613.0 2557.5 RPD 1613.0 2557.5 RPX 1613.0 2557.5 RPS 1613.0 2557.5 RPM 1613.0 2557.5 GR 1620.5 2565.5 ROP 1665.0 2610.0 LOG HEADER DATA DATE LOGGED: 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) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 Page 9 14-JUL-07 Insite 74.11 Memory 1664.0 2610.0 31.3 32.9 TOOL NUMBER 216262 230192 :7 2N-327.tapx 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 (DEGF) 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 AIN Max frames per record*. Undefined Absent value ...................... -999.25 Depth units. .. .. ..... Datum Specification Block sub -type ... 0 0 12.250 80.0 Native/spud Mud 10.20 100.0 4 9.3 0 450 .0 ROP 2.500 68.0 1.601 110.0 2.100 68.0 2.600 68.0 Name Service order Units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 1613 2610 2111.5 1995 1613 2610 ROP MWD020 FT/H 0.13 280.96 94.3205 1891 1665 2610 GR MWD020 API 45.35 132.43 83.298 1891 1620.5 2565.5 RPX MWD020 OHMM 0.69 18.14 6.65402 1890 1613 2557.5 RPS MWD020 OHMM 0.55 21.25 7.23458 1890 1613 2557.5 RPM MWD020 OHMM 0.51 20.28 7.45191 1890 1613 2557.5 RPD MWD020 OHMM 0.62 18.78 7.5999 1890 1613 2557.5 FET MWD020 HR 0.43 6.8 1.10452 1890 1613 2557.5 Page 10 0 0 2N-327.tapx First Reading For Entire File.......... 1613 Last Reading For Entire File ........... 2610 File Trailer Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 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 ....... 07/09/25 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTC 2491.5 5750.0 GR 2566.0 5823.0 PEF 2589.0 5787.0 RPx 2589.0 5815.5 RPM 2589.0 5815.5 GALA 2589.0 5776.5 RPD 2589.0 5815.5 RPS 2589.0 5815.5 FET 2589.0 5815.5 DRHO 2599.0 5787.0 NPHI 2599.0 5773.5 FCNT 2599.0 5773.5 RHOB 2599.0 5787.0 NCNT 2599.0 5773.5 ROP 2610.5 5870.0 SCRA 2614.5 5750.0 2614.5 5750.0 $TSH LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Page 11 19-JUL-07 Insite 72.13 Memory 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 VENDOR TOOL CODE DGR EWR4 CTN BAT 2N-327.tapx 2610.0 5870.0 10.8 32.2 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON BIMODAL ACOUSTIC 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 (0): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 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 70.0 Data Specification Block Type ..... 0 Logginy Direction.................Down 70.0 Optical log depth units ........... Feet Data Reference Point..............Undefined 4 2 Frame Spacing ........ ............60 AIN Max frames per record.............Undefined 68 Absent value ...................... -999.25 Depth Units. .. .. ..... 1 Datum specification Block sub -type ... 0 Name Service order DEPT ROP MWD030 GR MWD030 RPX MWD030 RPS MWD030 RPM MWD030 TOOL NUMBER 120557 96540 185457 1 8.750 2599.0 Polymer 9.70 42.0 9.1 300 .0 1.300 70.0 .730 130.0 1.000 70.0 1.100 70.0 units size Nsam Rep code offset channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 Page 12 0 First Reading For Entire File.......... 2491.5 Last Reading For Entire File ........... 5870 File Trailer service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File TyPe................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name... ........STSLIB.006 service sub Level Name ... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type.. ............LO Previous File Name ....... STSLIB.005 Page 13 2N-327.tapx RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 NPHI MWD030 PU S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 SCO2 MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 CALA MWD030 IN 4 1 68 56 15 DTC MWD030 USPF 4 1 68 60 16 DTSH MWD030 USPF 4 1 68 64 17 SORA MWD030 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2491.5 5870 4180.75 6758 2491.5 5870 ROP MWD030 FT/H 6.43 595.23 149.721 6520 2610.5 5870 GR MWD030 API 43.12 212.45 121.833 6515 2566 5823 RPX MWD030 OHMM 0.83 11.14 3.43363 6454 2589 5815.5 RPS MWD030 OHMM 0.84 9.78 3.48488 6454 2589 5815.5 RPM MWD030 OHMM 0.83 13.36 3.51983 6454 2589 5815.5 RPD MWD030 OHMM 0.88 2000 8.66506 6454 2589 5815.5 FET MWD030 HR 0.28 82.24 1.17515 6454 2589 5815.5 NPHI MWD030 Pu S 18.36 56.75 34.2056 6350 2599 5773.5 FCNT MWD030 CNTS 510.75 1665.17 853.148 6350 2599 5773.5 NCNT MWD030 CNTS 99573.9 146976 118411 6350 2599 5773.5 RHOB MWD030 G/CM 1.955 2.676 2.32348 6377 2599 5787 SCO2 MWD030 G/CM -0.023 0.319 0.0630922 6377 2599 5787 PEF MWD030 BARN 1.94 18.4 3.48981 6397 2589 5787 CALA MWD030 IN 8.68 10.27 9.10253 6351 2589 5776.5 DTC MWD030 USPF 48.66 139.98 105.025 6518 2491.5 5750 DTSH MWD030 USPF 120.39 307.23 212.757 6258 2614.5 5750 SORA MWD030 1.43 2.43 1.99345 6250 2614.5 5750 First Reading For Entire File.......... 2491.5 Last Reading For Entire File ........... 5870 File Trailer service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File TyPe................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name... ........STSLIB.006 service sub Level Name ... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type.. ............LO Previous File Name ....... STSLIB.005 Page 13 • comment Record FILE HEADER FILE NUMBER: 6 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 GR 5823.5 FET 5844.0 RPD 5844.0 RPS 5844.0 RPM 5844.0 RPX 5844.0 ROP 5873.0 LOG HEADER DATA DATE LOGGED: 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: 2N-327.tapx TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 STOP DEPTH 6008.0 6015.0 6015.0 6015.0 6015.0 6015.0 6030.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 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 (0): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 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): Page 14 22-JUL-07 Insite 6.02 Memory 5870.0 6030.0 9.1 9.8 TOOL NUMBER 64004 159439 6.125 5854.0 Polymer 9.50 43.0 9.5 300 .0 1.300 70.0 .931 100.4 1.000 70.0 1.100 70.0 • 2N-327.tapx 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 AIN Max frames per record...........— Undefined Absent value ......................-999.25 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 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 5823.5 6030 5926.75 414 5823.5 6030 ROP MWD040 FT/H 3.33 315.64 75.0135 315 5873 6030 GR MWD040 API 64.96 169.67 134.475 370 5823.5 6008 RPX MWD040 OHMM 0.12 2000 35.1145 343 5844 6015 RPS MWD040 OHMM 0.07 2000 35.9883 343 5844 6015 RPM MWD040 OHMM 0.96 2000 76.9647 343 5844 6015 RPD MWD040 OHMM 1.04 2000 39.7479 343 5844 6015 FET MWD040 HR 0.12 80.84 13.3108 343 5844 6015 First Reading For Entire File.......... 5823.5 Last Reading For Entire File ........... 6030 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 Page 15 0 2N-327.tapx File Type. ............LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTC 5725.0 6411.0 PEF 5844.5 6478.5 NCNT 5854.5 6462.5 DRHO 5854.5 6478.5 RHOB 5854.5 6478.5 FCNT 5854.5 6462.5 NPHI 5854.5 6462.5 DTSH 5872.5 6411.0 SCRA 5872.5 6411.0 GR 6008.5 6491.0 RPD 6015.5 6498.0 RPS 6015.5 6498.0 RPX 6015.5 6498.0 FET 6015.5 6498.0 RPM 6015.5 6498.0 ROP 6030.5 6513.0 LOG HEADER DATA DATE LOGGED: 31-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): 6030.0 BOTTOM LOG INTERVAL (FT): 6513.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 7.5 MAXIMUM ANGLE: 8.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 SLD STABILIZED LITHO DEN 109110 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 ELECTROMAG. RESIS. 4 97552 BAT BIMODAL ACOUSTIC 111111 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 5854.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 71.0 MUD PH: 9.7 Page 16 • MUD CHLORIDES (PPM): 2N-327.tapx25000 FLUID LOSS (0): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .130 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .074 127.0 MUD FILTRATE AT MT: .120 69.0 MUD CAKE AT MT: .150 69.0 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 Logging Direction., ...............Down Optical log depth nits...........Feet Data Reference Point..............undefined Frame spacing ........... 60 AIN Max frames per record.............Undefined Absent value ...................... -999.25 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 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 NPHI MWD050 PU S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 DTC MWD050 USPF 4 1 68 56 15 DTSH MWD050 USPF 4 1 68 60 16 SCRA MWD050 4 1 68 64 17 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 5725 6513 6119 1577 5725 6513 ROP MWD050 FT/H 0.68 308.96 77.8689 944 6030.5 6513 GR MWD050 API 69.89 260.59 143.555 966 6008.5 6491 RPX MWD050 OHMM 1.06 12.03 4.19612 966 6015.5 6498 RPS MWD050 OHMM 1.11 11.86 4.1686 966 6015.5 6498 RPM MWD050 OHMM 1.12 10.25 4.05746 966 6015.5 6498 RPD MWD050 OHMM 1.29 8.91 4.05302 966 6015.5 6498 FET MWD050 HR 0.3 189.85 7.48641 966 6015.5 6498 NPHI MWD050 PU S 17.65 48.24 27.8658 1217 5854.5 6462.5 Page 17 First Reading For Entire File.......... 5725 Last Reading For Entire File ........... 6513 File Trailer Service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name... .......STSL2B.008 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSL2B.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD 2N-327.tapx curves and log header data for FCNT MWD050 CNTS 123.02 971.32 485.309 1217 5854.5 6462.5 NCNT MWD050 CNTS 12928.5 35188.8 26743.9 1217 5854.5 6462.5 RHOB MWD050 G/CM 1.829 3.106 2.53235 1249 5854.5 6478.5 DRHO MWD050 G/CM -0.004 0.608 0.0849015 1249 5854.5 6478.5 PEF MWD050 BARN 1.96 15 4.00911 1269 5844.5 6478.5 DTC MWD050 USPF 71.41 111.56 91.9907 1373 5725 6411 DTSH MWD050 USPF 123.54 223.45 171.1 1076 5872.5 6411 SCRA MWD050 1.63 2.25 1.9103 1076 5872.5 6411 First Reading For Entire File.......... 5725 Last Reading For Entire File ........... 6513 File Trailer Service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name... .......STSL2B.008 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSL2B.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTSH 6395.0 6720.0 SORA 6395.0 6720.0 DTC 6395.0 6722.0 NCNT 6463.0 6787.5 NPHI 6463.0 6787.5 FCNT 6463.0 6787.5 DRHO 6479.0 6803.0 PEF 6479.0 6802.5 RHOB 6479.0 6803.0 GR 6491.5 6815.5 RPM 6498.5 6822.5 RPS 6498.5 6822.5 RPx 6498.5 6822.5 RPD 6498.5 6822.5 FET 6498.5 6822.5 ROP 6513.5 6837.5 Page 18 i LOG HEADER DATA DATE LOGGED: 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: M TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 BAT i 2N-327.tapx 07 -AUG -07 Insite 6.02 Memory 6513.0 6836.0 6.6 7.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON ELECTROMAG. RESIS. 4 BIMODAL ACOUSTIC 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 (0): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 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 .1IN Max frames per record.............Undefined Absent value ...................... -999.25 Depth units. .. .. ..... Datum Specification Block sub -type ... 0 Page 19 TOOL NUMBER 64004 109110 1844674407370955 97552 111111 6.125 5854.0 Polymer 10.40 74.0 9.1 25000 .0 1.900 69.0 1.084 126.0 1.400 69.0 2.400 69.0 0 i 2N-327.tapx Name Service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 NPHI MWD060 PU S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 DTC MWD060 USPF 4 1 68 56 15 DTSH MWD060 USPF 4 1 68 60 16 SCRA MWD060 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6395 6837.5 6616.25 886 6395 6837.5 ROP MWD060 FT/H 0.38 1995.67 101.526 649 6513.5 6837.5 GR MWD060 API 73.71 201.06 122.214 649 6491.5 6815.5 RPX MWD060 OHMM 1.58 7.79 3.64591 648 6498.5 6822.5 RPS MWD060 OHMM 1.56 7.51 3.65516 649 6498.5 6822.5 RPM MWD060 OHMM 1.59 6.89 3.6217 648 6498.5 6822.5 RPD MWD060 OHMM 1.73 6.17 3.68332 648 6498.5 6822.5 FET MWD060 HR 0.41 159.54 46.8121 648 6498.5 6822.5 NPHI MWD060 PU S 20.81 38.4 28.8244 650 6463 6787.5 FCNT MWD060 CNTS 273.81 752.55 457.378 650 6463 6787.5 NCNT MWD060 CNTS 22102.5 33176.2 26637.3 650 6463 6787.5 RHOB MWD060 G/CM 2.451 2.8 2.60227 649 6479 6803 DRHO MWD060 G/CM -0.008 0.16 0.0883082 649 6479 6803 PEF MWD060 BARN 2.63 5.85 4.15577 648 6479 6802.5 DTC MWD060 USPF 78.3 99.1 90.6318 655 6395 6722 DTSH MWD060 USPF 112.81 201.37 174.605 651 6395 6720 SCRA MWD060 1.61 2.1 1.92903 651 6395 6720 First Reading For Entire File.......... 6395 Last Reading For Entire File ........... 6837 File Trailer Service name... .......STSLIB.008 service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name... .......STSLIB.009 Service Sub Level Name... Page 20 Version Number. ........1.0.0 2N-327.tapx Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5844.0 6008.5 FET 5854.0 6015.0 RPx 5854.0 6015.0 RPD 5854.0 6015.0 RPM 5854.0 6015.0 RPS 5854.0 6015.0 RAT 5854.0 6025.0 LOG HEADER DATA DATE LOGGED: 07 -AUG -07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): 5725.0 BOTTOM LOG INTERVAL (FT): 6513.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 7.5 MAXIMUM ANGLE: 8.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 ELECTROMAG. RESIS. 4 97552 CTN COMP THERMAL NEUTRON 1844674407370955 SLD STABILIZED LITHO DEN 109110 BAT BIMODAL ACOUSTIC 111111 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 5854.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 71.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 25000 FLUID LOSS (0): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .130 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .074 127.0 Page 21 0 0 2N-327.tapx MUD FILTRATE AT MT: .120 69.0 MUD CAKE AT MT: .150 69.0 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 Logging Direction.................Down Optica? log depth units ........... Feet Data Reference Point..............Undefined Frame spacing ........ .......... .60 AIN Max frames per record'.. Undefined Absent value ...................... -999.25 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 RAT MAD051 FT/H 4 1 68 4 2 GR MAD051 API 4 1 68 8 3 RPX MAD051 OHMM 4 1 68 12 4 RPS MAD051 OHMM 4 1 68 16 5 RPM MAD051 OHMM 4 1 68 20 6 RPD MAD051 OHMM 4 1 68 24 7 FET MAD051 OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5844 6025 5934.5 363 5844 6025 RAT MAD051 FT/H 89.96 177.6 136.725 343 5854 6025 GR MAD051 API 70.41 201.85 149.608 330 5844 6008.5 RPX MAD051 OHMM 0.99 353.62 4.51006 323 5854 6015 RPS MAD051 OHMM 0.46 8.43 3.56805 323 5854 6015 RPM MAD051 OHMM 1.12 1926.19 18.9132 323 5854 6015 RPD MAD051 OHMM 1.18 1871.27 19.7952 323 5854 6015 FET MAD051 OHMM 189.9 277.75 202.727 323 5854 6015 First Reading For Entire File.......... 5844 Last Reading For Entire File ........... 6025 File Trailer service name... .......STSLIB.009 Service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07/09/25 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.010 Page 22 2N-327.tapx Physical EOF Tape Trailer Service name.............LISTPE Date . ...................07/09/25 origin...................STS Tape Name. .... ........UNKNOWN continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Reel Trailer Service name.............LISTPE Date . ...................07/09/25 Ori gin...................STS Reel Name. .... ........UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN • Library. scientific Technical services Comments.................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File Page 23 Scientific Technical services • ConocoPhillips Alaska, Inc. FINAL WELL REPORT ConocoPhillips Alaska, Inc. TARN 2N-327 82' FNL, 850' FEL Sec 3 — T9N - R7E, UM North Slope, Alaska Compiled by: Lees F. Browne, Jr. John D. Lundy August 9, 2007 sp ��� 0(19 11-1 EPOCH 0 C: COnOCo�"11155 Tarn 2N 327 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW..............................................•....................3 1.1 Equipment Summary ......................................................................................3 1.2 Crew.................................................................................................................4 2. GENERAL WELL DETAILS.....................................................................................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 ......................................................119 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory ................................121 4. PRESSURE / FORMATION STRENGTH DATA ..................................................122 4.1 Formation Integrity/Leak Off Tests ...........................................................122 4.2 Pore Pressure Evaluation Introduction ....................................................122 4.3 Pore Pressure Summary ............................................................................123 S. DRILLING DATA...................................................................................................124 5.1 Daily Activity Summary ..............................................................................124 5.2 Bit Record...................................................................................................130 5.3 Survey Record............................................................................................132 5.4 Mud Record.................................................................................................135 Enclosures 2"=100' Scale 2"=100' Scale 2"=100' Scale 2"=100' Scale Mudlog LWD Combo Log Gas Ratio Log Drilling Dynamics Log is Ci EPOCH 2 0 0 0 ConmCo IIIIPS Tarn 2N 327 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM electric gas trap Flame ionization total & chromatograph detector 2.5 HRS p erm f prost pebble damage. Replace p g p as trap 1-12S Detector (1-12S) Variable resistivity cell. Sample line, drill floor, mud pits & shakers - No Epoch 1-12S detector installed Rate of penetration (ROP) BEI Encoder- Primary draw works block position indicator - No problems Pump stroke counter SPM RIGWATCH Turck Magnetic proximity sensor - Minor adjustments Hook Load HLKD / Weight on bit WOB RIGWATCH Ametek Hydraulic pressure cell - No Problems Torque RTOQ Top Drive Feed - Not receiving Torque signal from Totco Top drive rota RPM Top Drive Feed - Totco Wits feed Standpipe & casing pressure SPP/CSIP Totco Hydraulic pressure cell - Mud flow out FLOW Totco Flow Paddle - Totco Wits Feed Pit levels x 6 Ball Float sensors in all pits & trip tank - Totco Wits Feed Mud logging unit computer system Compac Pentium III - No problems Geologist's workstation Compac Pentium III Totco Workstation (Lost Totco Network from 4070' to 4205' Company Man's workstation Com ac Pentium III - Totco Workstation Tool pushers workstation Com ac Pentium III - Totco Workstation Driller's workstation Epoch Azonix Touch Screen Class I Div II - Totco Workstation 14EPOCH 9 0 0 COr*C4lllipS Tarn 2N 327 1.2 Crew Unit Type Arctic Unit Number : ML012 Mudloggers Years "1 Days On Pad Geotechnicians Years Days On Pad Technician Trainees John Lundy 16 30 Dan K. Hillegeist 1 17 C. H. Friloader 3 8 Mainuddin Chowdhury 1 18 Lees F. Browne Jr. 26 20 Ryan Massey 1 9 *' Years experience as Mudlogger Additional Comments Two 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. The QGM gas trap was routinely cleaned of drilling mud and the gas lines blown back with rig air during connections and bit trips. Pump Pressure was calibrated relative to Totco. Block height was recalibrated to ensure accuracy after every cut and slip, and after casing runs. Calibration of Gas Detection and Chromatograph was checked and recalibrations performed if necessary to confirm accuracy. Calibrations on all equipment held extremely well throughout the well. H EPOCH 4 0 ConocoPFIIIIIPS Tarn 2N 327 2. GENERAL WELL DETAILS 2.1 Objectives 2N-327 is a combination Exploration and Development well whose primary purpose is to evaluate and test the amplitude anomaly in the Bermuda equivalent Tarn South prospect. A secondary objective of the 2N-327 is to drill through and investigate reservoir properties in the slightly deeper Albain aged Esker prospect. This well is designed to obtain open -hole log data across both formations and ultimately be completed as a producer in the Tarn South Reservoir. The wellbore is designed as a producer to capture rate and reserves outboard of the main 2N pad accumulation. Geological and Geophysical analysis indicate this well can be placed in a favourable centralized position to help optimize the fracture stimulation. At this location the estimated Gross Reservoir (T-3 to T-2 interval) is 180' with a net pay of 40' and average perm of 5 and (KH = 200). The well design consists of a 9 5/8" surface casing, 7" x 4-112" cemented production tapered longstring. Potential risks of the surface hole are the hydrates which have occurred in prior wells drilled at Tarn from just below permafrost at 1150' TVD. Shallow gravel and conglomerate sand will deteriorate the shallow hole rapidly with time and can cause hole -cleaning problems. Hole swabbing and tight hole conditions of trips are avoided by good hole circulation and proper hole filling and pumping out of the hole when needed but also the need to minimize circulation time to reduce hydrate thawing. Potential risks of the production hole are swabbing of the Campaignian sands, high ECD, tight hole on trips and lost circulation. Special attention should be given to pick up and slack -off loads to identify if the hole is loading up. The maximum hole inclination of 320, is conducive to cuttings accumulation, avalanche and pack -off. 0 14 Erocx 0 0 0 COnOC ;hiilipS Tarn 2N 327 2.2 Well Summary Well 2N-327 AFE Casing / Liner Classification Exploration Block N/A Rig Name / Nordic Drilling/ Land Surface 82' FNL, 850' FEL, KB Elevation 149' AMSL Pad Elevation 118.4'?? Type Nordic #3 Co -Ordinates S 3, T9N, R7E -5089' T4 9.9 10.84° none 7" 5854' Primary Target Bermuda T-3 Primary Target 5934' MD/ Secondary Esker Secondary 6453' - - Depth 5301' TVD Target Target Depth MD/ 5815' TVD Spud Date 7/12/07 TD Depth 6836' MD/ TD Formation Esker TD Date 8/07/07 6196' SS TVD Completion N/A Suspension N/A Days Drilling 26 Days Testing NA Status Date Hole Section Maximum Depth TD Formation Mud Weight Deviation Coring (ppg) (°Inc) Casing / Liner Shoe Depth FIT (ppg) MDRT ft TVDSS ft MDRT ft TVDSS ft 12.25" 2600' -2238' West Sak 10.3 32,16° none 9-5/8" 2600' -2238' 16.0 8.75" 5870' -5089' T4 9.9 10.84° none 7" 5854' -5089' 16.0 7" 6836 -6196' Esker 10.4 7° YES 4,5" - - - 14 EPOCH • ConocoPhililiPS Tarn 2N 327 Additional Comments: Epoch commenced logging the 2N-327 on 7/12/07 at 80' drilling out of 16" conductor pipe. Samples were caught at 50' intervals to 5870' (100'above the Bermuda formation) with Gas Bags were collected at 500' intervals and at gas kicks to a depth of 5870'. Sample catchers were used throughout the well. Isotubes were collected in 30' intervals through reservoir zones (Bermuda and Esker) starting from 100' above the Bermuda Formation (5870') and a 10' sampling/cuttings program was started with ditch cuttings, alternating to 30' between the two reservoir zones and while drilling rat hole. Mud weight was 9.6 ppg at surface with an increase to 10.3 by 2035' and increased to 10.4 at 2612'. Surface casing was run to 2609'. An FIT was run with an EMW of 16.0 ppg, and the mud system was swapped from Spud mud to LSND at 2609'. Mud weight was 9.6 beneath surface casing, and raised to 9.9 at approximately 100' above the Iceberg Formation. Drilling commenced with an inclination of 00. The hole was kicked off at 343' and the inclination was 320 by 2609' (surface casing). The inclination was held to 5177', in which angle was dropped to 10.840 at 5831'. No hole problems were encountered drilling the surface hole. Permafrost gravel caused minor problems with the gas trap (100' — 700'), with gravel being caught in the agitator 40 spindles. The spindles were replaced several times as drilling continued under the Permafrost and again gas trap problems occurred with massive thick clays plugging off the gas trap and overloading the possum belly (2500-3400'). Rig crew hands were consistently washing down the shale shakers to enhance sample recovery and keep from losing drilling mud fluids off the shale shakers. Running sands and gravel were limited in scope with maintained mud parameters. Sample Catchers checked and cleared the gas trap of clay accumulation at each sample interval, and whenever a change in gas or lithology was noted. Gas hydrates flows displayed a maximum recording of 2964 units. Initial hydrates were recorded from 1208' to 1400' (mud weights between 10.2 and 10.3 and mud temperature of 85 degrees). The flow line temperature increased with depth likely causing further eroding of the hydrates and high background gas readings. No hole problems were encountered while drilling from 2600' to the top of the Bermuda (5934') (Intermediate Hole Section). 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. Slower trip and connection speeds prevented swab/surge damage to the hole. Good maximum ROP effective rates were obtained to clean the angled hole with assistance of using torque and drag trends, ECD and shale shakers 0 14 EPOCH 7 0 C.on«o�,UIIPS Tarn 2N 327 productivity to establish a clean hole baseline. Drilling progressed to a depth of 6030' and the hole circulated out. Samples and gas indicated the top of the Bermuda formation with increased amounts of silty very fine grained sandstone with the increase of bright light yellow green sample fluorescence from 6005' to an indication of 40% sample fluorescence at 6030'. Sandstone samples had a very slight sweet petroleum odour with a slight light yellowish brown oil stain. Samples had an instant blue white slow streaming cloudy fluorescent cut with a slow increase over time to a cloudy to milky bright blue white cut with a faint straw visible white light residue stain. Gas units before 6000' were a steady 15 units. Once drilling past 6000' gas increased to an average of 45 units with spikes to 79 units at 6030'. C-5 (Pentane) was noted after 6005' increasing to a maximum of 122 ppm at 6030', in which the bit was pulled out of the hole and Core #1 was run to bottom. Core #1 (6033' to 6068') cut 35' of core in 2.5 hours (100% recovery). Core #2 (6068' to 6087') cut 19' of core in 7.1 hours (100% recovery). Core #3 (6088' to 6148') cut 60' of core in 5 hours (100% recovery). Core #4 (6148' to 6209') cut 60' of core in 18.3 hours (100% recovery). Core #5 (6209' to 6235) cut 26' of core in 11.4 hours (100% recovery). Core #6 (6513' to 6573') cut 60' of core in 19.5 hours (no recovery 6628 to 6673'). Core #7 (6575' to 6594' cut 19' of core in 6 hours (no recovery 6590 to 6594'). Core #8 (6594' to 6624') cut 30' of core in 16.5 hours (no recovery 6613 to 6624'). Core #9 (6625' to 6652') cut 30' of core in 12.5 hours (no recovery 5562 to 6655'). Lost recovery of some core sections indicated a very soft formation consistency. This applied to soft mudstones, friable silts and very fine loosely consolidated very fine sandstones. Some core sections displayed a sub triangular shape at the end of the core barrels indicated some wash out factors. 0 E7 EPOCH 8 0 0 0 COnOCoP IIIIPS Tarn 2N 327 3. GEOLOGICAL DATA 3.1 Lithostratigraghy Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist. FORMATION PROGNOSED MDRT TVD/SSTVD ftft DRILLING PICK MDRT TVD/SSTVD ft ft ACTUAL WIRELINE PICK MDRT TVDSS ft ft HIGH/LOW (ft) Permafrost Base n/a n/a n/a n/a n/a n1a n/a 9 5/8" Casinp Shoe 2616' 2400'1-2249' 2600' 23877-2238' -13 C80 K10 2720' 2488'/-2338' 2719' 24887-2339' 0 Camp Sand n/a n/a 2787' 25467-2397' n/a C50 4389' 39097-3759' 4320' 38617-3712' -48 C40 4600' 40887-3938' 4514' 4026/-3877' -62 C37 4753' 42187-4068' 4758' 42357-4086' +17 T7 5469' 4837'/-4687' 5429' 4817/-4668' -20 T4(Iceberg) 5875' 52287-5078' 5877' 52457-5096' +17 T3 Top Reservoir (Bermuda) 5971' 5324'1-5174' 5934' 53017-5152' -23 T2 Base Reservoir 6207' 55587-5408' 6061' 54277-5278' -131 C35 6318' 56697-5519' 6215' 55797-5430' -90 K-3 n/a n/a 6273' 56377-5488' Esker (top) n/a n/a 6453' 58157-5666' Esker (bottom) n/a n/a 6663' 60237-5874' TD 6778' 61287-5978' 1 6836' 1 61957-6046' +67 14 EPOCH D • 3.2 Mudlog Summary CorMcailillipS Tarn 2N 327 The following text provides a brief summary of the defining lithological and drilling characteristics for that part of the well, over which drill cuttings were collected. Surface to 9 5/8" Surface Casing Point 80' to 2600' MDRT (69' to -2238' TVDSS) The surface interval includes sand, claystone, and conglomeratic sands and conglomerate, and some siltstone. Conglomeratic sand and conglomerate is the dominant lithology until approximately 700', and then sand and claystone, with some siltstone and occasional conglomeratic sand, from 700' until casing point. Conglomeratic sand and conglomerate were predominantly light to very light gray with variable secondary hues. This entire section was poorly to moderately sorted in all grain sizes, grading locally from conglomeratic sand to pebble/cobble conglomerate. The formations were generally poorly cemented to loosely or unconsolidated, with trace calcite cement near surface, and some silica cement becoming more predominant with increased depth. Matrix would have been washed into the mud system, but was not significant enough to cause overloading at the shakers. The conglomeratic sands were suspected to be primarily grain supported with some interbeds displaying trace amounts of clay matrix, and the conglomerates assumed to have increasing matrix with poorer sorting. Given the local, the material should be considered as having had a permafrost matrix, at least in the upper sections. Sand size grains were primarily clear to translucent quartz with minority chert and lithic grains. Pebble/cobble material was primarily black lithics at the surface grading to varicolored lithics and clear to translucent quartz/quartzite/chert with increasing depth. Sand was generally angular to sub angular, and sub spheroidal, with some degree of frosting. Pebbles were generally sub mature to mature with common chatter marks and chips. Common angular pebble fragments result from bit action and should not be considered as typical of the formation. Sands were very light gray to light gray with pale green to light green secondary hues, and increasingly salt and pepper in appearance with depth. The formations were firm to unconsolidated, and primarily grain supported, with occasional moderately well cemented fragments at depth. Grains were moderately to poorly sorted, and sub angular to sub rounded with good to moderate sphericity and polished to frosted surfaces, including coarse lower to medium lower and fine upper grains, and locally fine grains grading to very fine and silt, especially deeper. Occasional traces of non hydrophilic clay matrix material were noted near surface, becoming more hydrophilic and expansive as depth increases. Grains were mostly clear to translucent quartz, with chert and dark metamorphic and igneous lithic grains in locally variable quantities. 14 EPOCH io 0 • L` LI CDrVCao NIOS Tarn 2N 327 Claystone was logged as very pale orange to yellowish gray to grayish orange pink initially, noted as mostly very light gray from 1220' to 1750', and pinkish gray to yellowish gray to light gray to casing depth. Claystone was highly reactive in the mud system, lumpy to mushy to pasty on the shakers and in samples, and commonly hydrophilic, especially noted in massive clays. The claystone was non calcareous, with a dull earthy luster; and clayey to ashy texture, occurred as massive beds, to gradational to conglomeratic sand and sand, and in part as matrix for loose sands. Occasional traces of shell fragments were noted below 1250'. Siltstone was pinkish gray to yellowish gray in the upper section, light gray to light brownish gray below 2300', clayey and of similar character to claystone except with a silty to ashy texture. Less common than and often grading to claystone, was more commonly associated with and likely interbedded with sands. A trace of shell fragments was noted with Siltstone below 2550'. Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Average 922 9 159 2964 0 H EPOCH 11 • r 0 Con"C;Ohillips Tam 2N 327 Surface Casing to C-80 2600' to 2719' MDRT (-2238' to -2339' TVDSS) The new bit broke formation into siltstone and claystone, light gray to some yellowish gray and pale yellowish brown. Cuttings were soluble in the mud system and therefore structure less, and mushy and pasty in samples, composed of overall 50% clay and 50% silts and detrital material, such as carbon silts and relic shards, and exhibiting an ashy to silty texture. Drill Rate ft/hr Total Gas Maximum Minimum Avera a Maximum Minimum Average 458 52 1 170 107 0 18 C-80 to C-50 2719' to 4320' MDRT (-2339' to -3712' TVDSS) The C-80 composed of dominant clay and silt to 3900', in which predominantly sand composed the samples. The clay and silt were uniform in description and proportion from 2719' to 3900'. Claystone was light gray with light brown to yellowish brown secondary hues and very soft being moderate to very sticky with shapeless to globular cuttings. The texture was silty to clayey and slimy to pasty with a dull luster. All clays were hydrophilic with a high solubility rate showing poor cohesiveness with fair to good adhesiveness. All clays were non calcareous. All clays are very gradational with slight to moderate amounts of silt interbedded. The siltstones were light brownish gray to medium gray to medium light gray and moderately firm to soft in parts. Overall most silts were moderately soluble and showing a sub blocky to sub platy habit with a moderate to very argillaceousness and grading to very fine grain silty sandstone in parts. Some are occasionally interbedded with cleaner sandstones in local rare laminations. Trace amounts of fine carbonaceous matter and glauconite in very fine grained sands with trace disseminated micro pyrite and aggregated micro pyrite. Slightly calcareous in parts with some loose calcite scattered. Sandstones from 3900' to the top of the C-50 are very light to light gray with a slight yellowish secondary hue in parts. Clast size ranges from fine lower to very fine lower and being poorly consolidated. Sorting ranged from poor overall to some local moderate sorting. Grains displayed a sub angular to sub round shape with larger clasts showing slight erosional frosting and chipping with grains displaying clear to translucent white quartz with trace light gray lithics in a very silty matrix. Sands show a overall grading to siltstone with a primary matrix support with occasional fragments showing slight to H EPOCH 12 COrxxoPhllllPS Tarn 2N 327 moderate grain support. The matrix material consists primarily of clay and silt with some fragments showing distinct off white ashy material with a very faint yellow to yellowish brown mineral fluorescence. Sands from 3900' to 4000' displayed a very slight yellowish white "crush" cut with no discernable odor or stain and a very poor overall oil cut. Drill Rate ft/hr Total Gas % Maximum Minimum Average Maximum Minimum Ave e 560 15 156 269 0 50 C-50 to C-40 4320' to 4514' MDRT (-3712' to -3877' TVDSS) The C-50 is composed of 194' with a silty clay upper grading to carbonaceous shale, carbonaceous silt and carbon clay at its base. Background gases increase as the carbonaceous section is drilled. The upper silts and clays are very gradational between the two with colours being light to very light gray and overall soft to occasionally slightly firm in some siltstones. Cuttings are irregular to occasionally angular to a slightly eroded habit. Lustres are a dull earthy to slightly sparkly in siltier beds. The clays have a clayey texture and silts a gritty texture. Overall cuttings display poor adhesion to being slightly cohesive. Slight thin beds of very slight calcareous silty sandstones are noted which pinch out as the carbonaceous lower section is drilled. The lower carbonaceous section is composed of various beds of gradation carbon silt, clay and shale. Colours are medium gray to light brownish gray and range from brittle to firm. Cuttings are not homogeneous with some very clayey and some very silty. Fractures are blocky to irregular to angular to irregular habits. Slight light grayish white ash and trace white calcite with moderate yellow mineral fluorescence with no oil cuts. Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Average 164 38 140 179 8 84 14 EPOCH 13 0 COrMC411105 Tarn 2N 327 C-40 to C-37 4514' to 4758' MDRT (-3877' to -4086' TVDSS) The C-40 is composed of uniform deposits of siltstone and secondary claystone. The siltstones are composed of light brownish gray to light gray silts with various hues of both with very poor to poor induration. Cuttings are very brittle and are non to very slightly cohesive with adhesion being none. Fractures are earthy to sub platy with sub platy to sub blocky habits and an overall dull earthy luster. Textures are a uniform siltyness with cuttings of very small size with a large amount of silt going into solution. The silt is a massive gradational deposit with abundant detrital material with very thin beds of very fine grained sandstone. Trace amounts of silty shale and hydrophilic silty clays. Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Average 228 43 142 195 41 122 C-37 toT-7 4758' to 5429' MDRT (-4086' to -4668' TVDSS) This interval is mostly siltstone, grading to or interlaminated with very fine sandstone, and some shale at 5050'. Below 5050' and until the T7 (5429') sees an increase in sandstone and sand, including very fine to medium lower grains. Siltstone, sandstone, shale, and very fine sandstone were gradational to interlaminated, very poorly to moderately indurated, non to slightly calcareous, and with color varying from light to medium dark gray to light brownish gray, depending on organic content of clay. Claystone (shale) was overall darker than the siltstone and sandstone, and notably more indurated and shaly than in overlying zones, especially when slightly calcareous. Common accessories, especially claystone and siltstone, included trace to slight carbon silts and fines, trace to slight scattered micro pyrite, and possible micro micas. Some very fine sandstone was grain supported and non organic, and occurred as thin laminations in contrast to darker siltstone and claystone. Argillaceous sandstone tended to be poorly consolidated and matrix supported, and the cleaner very fine grained sandstone grain supported, and moderately consolidated with calcareous cement. Sand and the coarser sandstone below 5050' were medium light gray to light gray, with very pale orange to faint olive hues, very fine upper to medium grains, especially fine to medium lower, sub rounded to sub angular, and well to moderately sorted. Samples included predominantly loose grains, to occasionally poorly to moderately consolidated sandstone with calcareous cement, or poorly consolidated with tan matrix matter (possible siderite) acting as a cementing agent. Composition was 75% quartz; 15-20% H EPOCH 14 0 COnOCCI�hilliPS Tarn 2N 327 dark gray to black to gray to bluish gray to dark green to amber grains including silicates and minor siliceous lithics, of possible volcanic origin in part; and 5-10% tan matter (possible siderite) which occurred as both grain and, as a cementing agent, interstial matter, and occasional clusters of pyrite. Porosities were estimated at fair to good porosity, but no oil was indicated. Drill Rate ft/hr Total Gas % Maximum Minimum Average Maximum Minimum Average 283 25 138 265 7 65 T-7 to T-4 (Iceberg) 5429' to 5877' MDRT (-4668' to -5096' TVDSS) The T-7 is a gradational sequence of shale, claystone, siltstone and very fine grain sandstones. The sandstone tend to grade into a sandstone, sand sequence with minor calcite and decreasing clays. Shale is noted as being medium light gray to medium dark gray, slightly firm to moderately soft, sub splintery to sub blocky with visible fissility and occasional planar cuttings fractures, resinous to earthy to silty texture grading to siltstones, slightly organic in parts, trace to slight carbon silts with trace to slight disseminated micro pyrite and possible micro mica with a rare slight calcareous effervescence. Shale grades into claystones in parts, which show an increased softness and solubility. Siltstones display light gray to very light gray colour, very poor to poor induration, brittle, crumbly to crunchy, non to very slight cohesiveness, non adhesiveness, earthy fracture, sub platy to sub blocky habit, dull earthy luster, silty texture, massive gradational silt, sand, sandstone and clay with various detrital materials. Sandstones are medium to light gray with a moderate brownish gray secondary hues in parts, firm to soft in grading to silty clays, silty to clayey textures, irregular fragments slightly eroded by circulation of the drill mud, moderate to local poor sorting, fine to very fine grain, sub angular to sub rounded, loosely consolidated, generally matrix supported with rare local grain support, trace very light gray white ash, some carbonaceousness in parts, abundant clear to milky white to white calcite fracture fills, cuttings slightly calcareous overall, common light yellow mineral fluorescence with no oil stain or petroleum odors, no oil cuts. Drill Rate ft/hr Total Gas % Maximum Minimum Average Maximum Minimum Average 1 270 36 131 170 11 58 H EPOCH 15 0 • ConocoPhillips Tarn 2N 327 T-4 to T-3 (Top of Production) 5877' to 5934' MDRT (-5096' to -5152' TVDSS) The T-4 is a short sequence of gradational silts, clay and very fine grained sandstones. Overall silt being very light gray to light gray with moderate induration, some mushy to pasty, tacky to slimy in high clay percentages, sub platy to sub blocky fracture and habit, dull earthy luster, silty to clayey textures, overall a massive gradation sequence of silt, clay and minor very fine grained sands. The silts are composed of 50% silt, 50% clay. Drill Rate(ft/hr) Total Gas Maximum Minimum Average Maximum Minimum Average 144 50 80 20 2 10 T-3 (Bermuda) to T2 (Base Reservoir) 5934' to 6061' MDRT (-5152' to -5278' TVDSS) Core #1 (6033' to 6068') cut 35' of core in 2.5 hours (100% recovery). nIM, ti' ConocoPhillips Tarn 2N-327 t►dorth SiaW, Borough, AK I� is Above photo of drill cuttings above Core #1 "a EPOCI-I 0 • ConocoPhillips Tarn 2N 327 Core #1 6033' = 90% SILTSTONE, 10% SANDSTONE = medium light gray to light gray, moderate induration, dense, some crumbly with force, overall stiff, moderate cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, gritty to silty texture, micro laminations of very fine grained sandstone with abundant overgrowths, inter bedded mica, no show of fluorescence or cut. 6036' = 100% SANDSTONE = pale yellowish brown, clast size ranges from fine upper to very fine upper, sub round, poor sorting, moderate developed sphericity, pitted texture, sub mature to mature texture, dominant grain support with minor clay matrix, dominant grain overgrowths, fair porosity and permeability, 100% bright yellow even sample fluorescence on fresh cuttings, 60% patchy light brown oil stain, instant bright blue white cloudy fluorescent cut with moderate increase to cloudy to milky blue white cut, faint straw visible residue stain. Best oil show of core #1. 0 U EPOCH 17 ldw K-. Zlffti • • ConOCOPhillipS Tarn 2N 327 (tips !7 a Borough, AK 14 EPOCH 6039'= 50% SANDSTONE, 50% SILTSTONE = continued oil shows from sandstones with thinly laminated siltstones displaying silty clay to silty very fine grained sandstones, planar orientation with continued moderate to bright patchy yellow oil fluorescence, slight light brown oil stains in sandy laminations. 19 C7 0 ConocoPhillips Tarn 2N 327 r=m[1 LPOCH 6041' = 100% SILTSTONE = medium light gray to light gray, moderate induration, stiff overall, moderate cohesiveness, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, gritty to silty texture, micro laminations of very fine grained silty to clayey sandstones, planar fracturing along silty clay laminations, no show of fluorescence or oil cuts. , F 1�fft 1^MH/ 0844'=1O0968|LTSTONE=same 8sG041'butnovisible laminations, appears homogeneous iOnature with nOshow Offluorescence oroil cuts. 21 • ConocoPhillip5 Tarn 2N 327 GonocoPhillips :;- ': Tarn 2N-327 0 6047' = 100% SILTSTONE = same as 6044' with a trace amount of mica. • 6050'= 100% SILTSTONE = same as 6047' U1"I()( i 3 22 • • 0 Y 4 d EPOCH 6053'= 50%SANDSTONE, 50% SILTSTONE = continued siltstones with thinly laminated very fine grained sandstones, very distinct even bright yellow oil fluorescence in planar orientation, very light brown patchy oil stain along laminations, sandstones are very light gray to very pale yellowish brown, fair to poor visible porosity and permeability, instant dull light blue fluorescent cut, slow streaming with slow development to moderate hazy to cloudy blue white oil cuts, very faint straw visible residue stain, poor cuts overall. A Y 4 d EPOCH 6053'= 50%SANDSTONE, 50% SILTSTONE = continued siltstones with thinly laminated very fine grained sandstones, very distinct even bright yellow oil fluorescence in planar orientation, very light brown patchy oil stain along laminations, sandstones are very light gray to very pale yellowish brown, fair to poor visible porosity and permeability, instant dull light blue fluorescent cut, slow streaming with slow development to moderate hazy to cloudy blue white oil cuts, very faint straw visible residue stain, poor cuts overall. • ConocoPhillip5 Tarn 2N 327 • 6056'= 60% SANDSTONE, 40% SILTSTONE = Sandstones are medium light gray to light gray, clast size ranges from very fine upper to very fine lower grading to siltstone, sub round, moderate developed sphericity, poor sorting, pitted texture, sub mature nature, dominant grain support with secondary slight silty matrix, scattered laminations, poor visible porosity and permeability, abundant overgrowths, thin laminations of bright yellow even oil stains, 40% moderate to bright patchy yellow oil fluorescence, instant dull hazy slow streaming cuts with slow increase to moderate light blue oil cuts, very poor visible residue stains. 24 • COnOCOPhillip5 Tarn 2N 327 • 6059'= 70% SILTSTONE, 30% SANDSTONE = silts are medium light gray to light gray, moderate to well indurated, dense to stiff, moderate cohesiveness, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, silty to gritty texture, composed of 70% silt and 30% very fine grained sandstone, micro laminations of mica and detrital material, no show of fluorescence or oil cuts. 0 5� COnocoPhillips Tarn 2N 327 AK 14 EPOCH 6062'= 70% SILTSTONE, 30% CLAYSTONE/MUDSTONE = silts are becoming darker: medium gray to medium light gray, moderate to well indurated, dense to stiff, moderate to good cohesion, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, silty texture, grading to a silty mudstone, composed of 70% silt. 30% silty clay with no show of fluorescence or oil cuts. 26 • COnocOPhillips Tarn 2N 327 igh, AK • 6065'= 100% SILTSTONE = becoming darker medium dark gray to medium gray, moderate to dark earthy luster, very homogeneous silt with very slight light micro laminations of clay, composed of >95% silt with no show of fluorescence or oil cuts. 27 • ConocoPhillips Tarn 2N 327 ConocoPhillips Tarn 2N-327 North Slope Borough, AK E EPOCH • 6068'= 70% SILTSTONE, 30% CLAY/MUDSTONE = same as 6065 with scattered micro laminations of light hued silty clays with no show of fluorescence or oil cuts. • E4 EPOCH 28 C: • • COnocOPhillips Tarn 2N 327 Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Average 77 3 56 79 3 20 T-2 (Base of Reservoir) to C35 6061' to 6215' MDRT (5278' to -5430' TVDSS) Above photo taken at 6067' 14 EPOCH 29 • CORE #2 ConocoPhillips Tarn 2N 327 CORE #2 6071'= 100% SILTSTONE = medium gray, moderate to well indurated, dense to stiff, moderate to good cohesion, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty to gritty textures, homogeneous bed of siltstone, composed of 70% silt, 30% Claystone/Mudstone, no show of fluorescence or oil cuts. mm E i� P) ; IT 6075'= 100% SILTSTONE = medium gray, moderate to well indurated, dense to stiff, moderate to good cohesion, non adhesion, sub planar fracture, sub platy habit, dull earthy luster, silty to gritty texture, grading away from silty mudstone to siltstone with occasional very fine grain lower sands inter beds, composed of 80% silt, 20% very fine grain sand. No show of fluorescence or oil cuts. 30 ConocoPhillips Tarn 2N 327 ConocoPhillips Tarn 2N-327 North Slope Borough, AK • 6078' = 100% SILTSTONE = same lithology as 6075' but noted scattered carbon fines. 0 ConocoPhillips Tarn 2N-327 North Slope Borough, AK U EPOCH 31 r ---I LJ • ConocoPhillips Tarn 2N 327 6081' = 100% SILTSTONE = medium gray to medium dark gray (note slight color change) same lithology as 6078' but silts are becoming finer with continued carbon fines scattered in silt matrix. Composed of 90% silt, 10% very fine lower sands. CanoioPhilli s 6084'= 50% SILTSTONE, 50% SANDSTONE = distinct wavy laminations of very light gray sandstone and medium gray siltstones. Sandstones are very light gray, clast size ranges from fine lower to very fine lower grading to silt size at contact points, abundant size faction is very fine upper, sub round, overall moderate to some well developed sphericity, pitted texture, sub mature nature, non to very slight visible matrix material, dominant grain support with dominant grain overgrowths, poor to fair visible porosity and poor permeability, no show of fluorescence or cut. 6087'= 100% MUDSTONE/CLAYSTONE = medium dark gray to medium gray, hard, dense to stiff, good cohesion, non adhesion, planar fracture, platy habit, dull earthy luster, slight sparkly luster with micro mica's in part, sub gritty texture, homogeneous appearance, overall a silty mudstone composed of 50% clay, 50% silt, no show of fluorescence or oil cuts. 0 14 EPOCH 32 • COrOCI; MIiPS Tarn 2N 327 -76 11 VI I IE I ITSa Tarn 22N-377 0 N EPOCH 33 • ConocoPhillips Tarn 2N 327 .rte r I r l Lam_ _ Above photo from 6086' • CORE O Ci l', I 'i; jt` , , 34 C] • COnocOPhilliPS Tarn 2N 327 Core #3 (6088' to 6148') cut 60' of core in 5 hours (100% recovery). 6091'= 50% SILTSTONE, 10% CARBONACEOUS SHALE AND CLAY, 30% SANDSTONE = medium light gray to light gray, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, poor to moderate sorting, polished to pitted texture, mature nature, dominant grain overgrowths of volcanic glass shards, no visible matrix material, poor porosity and permeability, thin beds of sand laminations, contacts with silty mudstones with interbedded carbonaceous fragments and grading to carbonaceous mud. 6094'= 100% SANDSTONE = light gray to medium light gray, clast size ranges from fine lower to very fine lower, sub round to some rounded grains, moderate occasionally well developed sphericity, moderate with some poor sorting, polished texture, mature nature, dominant grain support with less grain overgrowths than 6091', no visible matrix material, fair to good porosity and permeability, grain to grain contact noted with very slight sample fluorescence with no oil cuts. 14 EPOCH 35 • ConocoPhillips Tarn 2N 327 6097'= 100% SANDSTONE = same description as 6094' with added mica flakes and various detrital material, very slight sample fluorescence with no oil cuts. is H EPOCH 36 0 ConocoPhillip5 Tarn 2N 327 �&-AL IPOCI I 6100'= 100% SANDSTONE = same description as 6097' with a slight increase in a clay matrix with dominant grain support, no show of oil fluorescence or cut. 0 1-; 1"!l )(:'I-1 37 I _ I "W, I EPOCH 6103' = 100% SANDSTONE = light gray to a subtle "salt and pepper" appearance with black lithic content, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, dominant grain support with a slight increase in a clay/ash matrix, scattered grain overgrowths, fair to good porosity and permeability, very slight petroleum odor from cuttings, very faint yellow brown even oil stain, 100% bright yellow even sample oil fluorescence, instant dull light blue hazy sample oil cut with slow to moderate streaming cuts, slow increase to dull to moderate hazy to cloudy cuts, very faint straw residue stain. 0 UI i'.1'0i',H, 38 • 0 ConocoPhillips Tarn 2N 327 M p Conoco OMI Tarn 2N-327 VL 6106' = 100% SANDSTONE = medium gray to yellowish gray (in oil stains), clast size ranges from fine lower to very fine lower, moderate developed sphericity, moderate sorting, polished texture, mature nature, dominant grain support, interbedded mica, very slight clay/ash matrix material, fair to good porosity and permeability, slight to moderate grain overgrowths, slight petroleum odor to cuttings, faint yellow hued oil stains, 100% bright yellow even sample oil fluorescence, cuttings are easy to break apart, instant cloudy moderate blue white moderate streaming cuts, slow to moderate increase to moderate blue white cloudy to milky fluorescence, very faint straw residue stain. 0 H EPOCH 39 • COnocoPhillips Tarn 2N 327 onocoPhiilips Tarn 2N-327 North Slope Borough, AK M 6109' = 100% SANDSTONE = medium gray, clast size ranges from fine lower to very fine lower with an abundant faction being very fine grains, cuttings are easy to break apart, sub round to rounded, moderate to well developed sphericity, moderate sorting, polished texture, mature nature, non to very slight calcareous slight clay matrix, dominant grain support, scattered grain overgrowths, fair to good porosity and permeability, slight petroleum odor to cuttings, bright yellow even sample fluorescence, cuttings exhibit oil fluorescence banding/laminations under ultra violet light, instant light blue slow streaming oil cuts with a slow increase to dull hazy cuts with a very faint pale straw residue stain. • (48 1',11( )i ,t-1 40 ConocoPhillips Tarn 2N 327 �,P'**H EP0C;H 40 6112'= 100% MUDSTONE = medium gray, hard, dense to stiff, very cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, sub smooth to sub matte texture, homogeneous mudstone composed of 70% clay, 30% silt with no show of fluorescence or oil cuts. 0 14 1'.1'( )t t -i 41 • ConocoPhillip5 Tarn 2N 327 • 6115'= 100% SANDSTONE = medium gray to medium light gray, clast size ranges from fine lower to very fine lower, cuttings are easy to break apart, sub round, moderate occasionally well developed sphericity, moderate sorting, polished texture, mature nature, non to very slight calcareous in very slight clay matrix, dominant grain support, scattered grain overgrowths, scattered interbedded mica, fair to good porosity and permeability, very slight petroleum odor from cuttings, bright yellow even sample oil fluorescence, cuttings exhibit oil fluorescence laminations and banding under ultra violet light and not visible in white light, instant dull light blue slow streaming oil cuts with slow increase to a dull hazy blue cut with a very faint straw residue stain. is €4 F1'()(, -,H 42 • COnocOPhillips Tarn 2N 327 finocoPhillips 11.1 Tarn 2N-327 North?slope Borough, AK OC 1. AIEPH • 6117'= 100% SANDSTONE = light brownish gray to medium light gray, clast size ranges from fine upper to very fine lower with abundant faction being very fine upper, cuttings are easy to break apart, sub round, moderate with some well developed sphericity, moderate sorting, polished texture, mature nature, non to very slightly calcareous in a very slight clay matrix, dominant grain support with a slight increase in grain overgrowths and a slight decrease in the mica content, overall appears tight, fair porosity and permeability, no petroleum odor from the cuttings and no show of oil fluorescence or oil cuts. UI EPOCH 43 • ConocoPhillips Tarn 2N 327 6118.8' = 100% SANDSTONE = light gray to light yellowish gray (oil stain), clast size ranges from very fine upper to very fine lower, sub round, moderate to well developed sphericity, moderate sorting, polished texture, mature nature, non to very slightly calcareous clay matrix • ISA l',L't J'§. a 44 ConocoPhillips Tarn 2N 327 6121'= 100% SANDSTONE= medium light gray, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, slight clay/ash matrix, dominant grain support, some grain overgrowths, fair to good porosity and permeability, very slight petroleum odor, cuttings are easy to break apart, very faint yellow oil stain, 100% patchy bright yellow sample fluorescence, instant dull hazy to cloudy blue white slow streaming cut with a very slow increase to cloudy moderate blue white cut, very faint straw residue stain, poor oil cuts. 14 EPOCH 45 0 PS Tarn 2N 327 KonocoPhil|' Oft ocoPhi I lips Nq)* e Borough, AK ', i�s HEPOCH 6124'=10O% SAN OSTONE= same sandstone asG121'vvithabetter oil cut: slight petroleum odor, cuttings are easy to break apart, faint yellow even oil St@in, 100% even bright yellow sample fluorescence, instant moderate blue white cloudy fluorescent cut with moderate streaming oil cuts and 8 moderate increase to milky moderate blue white cuts, very faint Str8vv residue stain. �41[l`()(`1_3 46 ConocoPhillips Tam 2N 327 le earn 2N-327 North Slope Bord ,- ,AK 6127'= 100% SANDSTONE = medium gray, clast size ranges from very fine upper to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, slight clay/ash matrix, dominant grain support with abundant grain overgrowths, poor porosity and permeability, no petroleum odor, no show of oil fluorescence or oil cuts. COnocoPhillipS Tarn 2N 327 a6130'= 100% SANDSTONE= medium light gray, clast size ranges from fine lower to very fine lower, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, slight clay/ash matrix, dominant grain support, slight decrease in grain overgrowths, fair to good visible porosity and permeability, slight petroleum odor, faint yellow even oil stain, 100% even bright yellow sample oil fluorescence, instant moderate to bright blue white moderate streaming oil cut, moderate increase to cloudy to milky blue white oil cut, faint straw residue stain. 0 [4 EPOCH 48 • • ConocoPhillips Tarn 2N 327 s ConocoPhils. ' Tarn 2N-327 41A, 4 North Slope Borough, AK 'max p. r N 6133' = 100% SILTSTONE = medium gray, moderate to well indurated, dense to stiff, moderate to very cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty texture, homogeneous bed of silt, generally a silty mudstone, interbedded mica, pyrite carbon specs and various detrital material with no show of oil fluorescence or oil cuts. 0 14 EPOCH 49 COnocOPhillips Tarn 2N 327 SonocoPhillip5 Tarn 2N-327 Npft Slope Borough, AK 6136'= 100% SANDSTONE = medium gray to medium light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, very slight clay/ash matrix, dominant grain support, scattered grain overgrowths with fair to good porosity and permeability, no oil odor, slight bright light yellow even sample oil fluorescence, no oil stain and a very poor oil cut. 0�,l'i,3t,i 1 50 • COnocoPh MPS Tarn 2N 327 i6139'= 100% SANDSTONE = medium light gray to light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, very slight clay/ash matrix, dominant grain support, scattered grain overgrowths, fair porosity and poor permeability, no show of oil fluorescence or oil cuts. r 51 • • ConocoPhillips Tarn 2N 327 ConocoPhill' ~ Tarn 2N-32i� North Slope Bordugh, AK qP At r'� 11 W' ' , EI EPOCH 6142' = 100% SANDSTONE = medium light gray to light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished texture, mature nature, very slight clay/ash matrix, dominant grain support with scattered grain overgrowths, poor to fair porosity and poor permeability, interbedded with mica and various detrital material with no show of oil fluorescence or oil cuts. (4 1'. f'C )C , k. 1 52 9 0 ConocoPhilliPS Tarn 2N 327 ConocoPhillips -Tarn 2 Worth S4%�orough, r ^ 6145'= 10096 SANDSTONE = light yellowish gray to medium light gray, clast size n3Ogeo from fine upper to very fine upper, sub round, moderate SphehCitx, moderate sorting, polished Uexture, rn8tun5 notuns, slight decrease in very slight clay/ash matrix nnateh@|, dominant grain support with scattered grain overgrowths of volcanic g|@S8, fair to good porosity and fair permeability, fair to good petroleum odor from cuttings, 100% grayish ye||Oxv even oil stain, 100% bright yellow oil f|uoreScanCe, easy to break apart Cuttin8a, instant bright fast streaming nni|kv oil cuts, best oil cuts in core #3, faint otr@vv residue oil stain. 0 �� i.�)( '" 1 53 • 11 ConocoftillipS Tarn 2N 327 6147.8'= 10% CARBONACEOUS MATERIAL, 30% SILTSTONE, 60% SANDSTONE _ medium light gray to medium gray, clast size ranges from very fine upper grading to silt, sub round, moderate sphericity, polished texture, sub mature nature, moderate silty to clayey matrix, both grain and local matrix support, gradational sands, silts and micro laminations of carbon material, detritalish, poor to possibly fair porosity with poor permeability, 20% trace to spotty oil fluorescence with a very poor oil cut. 0 C-4 }',1'l )(, �7 54 0 ConocoPhillips Tarn 2N 327 • 6148.4'= 100% SANDSTONE = yellowish gray (oil stains) to medium light gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting, polished textures, mature nature, very slight clay matrix, dominant grain support with grain overgrowths noted, fair porosity and permeability, moderate petroleum odor, even yellow oil stain, 100% bright yellow even sample oil fluorescence, instant cloudy to milky bright blue white oil cut with a fast increase to moderate milky blue white, faint straw residue stain. 55 11 ConocoPhillips Tarn 2N 327 10 CORS #4 CORE #4 Core #4 (6148' to 6209') cut 60' of core in 18.3 hours (100% recovery). 6148.4'= 100% SANDSTONE = yellowish gray (oil stains) to medium light gray clast size ranges from fine lower to very fine upper sub round moderate developed sphericity moderate sorting polished textures mature nature very slight clay matrix dominant grain support with grain overgrowths noted fair porosity and permeability moderate petroleum odor even yellow oil stain 100% bright yellow even sample oil fluorescence instant cloudy to milky bright blue white oil cut with a fast increase to moderate milky blue white faint straw residue stain. 6151' = Carbonaceous siltstone = medium dark gray with a slight brownish yellow secondary hue; hard, slightly shaly, very slightly fissile slightly sandy; dull earthy luster slightly gritty sandy texture; trace very fine to fine mica flakes; trace to common very fine pyrite; common small medium brown to dark brown carbonaceous inclusions some of which are obvious plant remains; very slight oil odor; trace dull yellow fluorescence; very slow medium yellow white crush cut very slight yellow residual fluorescence; trace calcareous. C-, 1"i 10( 7r 1 56 • ConocOPhillips Tarn 2N 327 ConocoPhillips Tarn 2N-327 6154'= 100% SANDSTONE= medium light gray, hard, clast size ranges from very fine lower to very fine upper, very silty, moderate to well rounded; moderate to well developed sphericity, common dark mineral grains, dominant grain support with crystalline silic cement and grain overgrowths, poor porosity and permeability; no visible stain, no odor, 40% patchy to scattered light yellow green sample fluorescence, instant light yellow white to blue white slow streaming fluorescent cut, very slow developing cut, overall poor cut. • 57 0 G151 ConocoPhillips Tarn 2N 327 ConocoPhillips Tarn 2N-327 -North Slope Borough, AK • 6157'= 100% SANDSTONE= medium light gray, clast size ranges from fine lower to very fine upper with a slight "salt and pepper" appearance, continued silt content, moderate to well rounded, moderate to well developed sphericity, dominant grain support with grain overgrowths, fair to poor porosity with poor permeability, trace petroleum odor, no visible stain, 50% moderate yellow patchy to scattered oil fluorescence, slight to moderate calcareous, slow dull streaming cuts, no increase with "crush cuts", poor overall oil cuts. 0 €4 1."1'() f i 58 • ConocoPhillipS Tarn 2N 327 6160'= 100% SANDSTONE = light gray to medium light gray and various hues of both and a distinct yellowish secondary hue (oil stain), clast size ranges from fine lower to very fine upper, non calcareous, sub round to round, moderate to well developed sphericity, dominant grain support with some overgrowths, fair porosity and permeability, moderate petroleum odor, 80% even light yellow oil stain, 100% bright yellow even sample oil fluorescence, instant moderate to bright blue white cloudy oil cut with moderate increase to moderate milky blue white cut with a faint straw residue stain, best oil cut for Core #4. 0 UI I.T( )(;i J 59 • ConocoPhillips Tarn 2N 327 ConocoPhiilips Tarn 2N-327 North Slope Borough, AK P 6163' = 100% SILTSTONE = light gray, well indurated, trace fracture fills noted, dense to stiff, scattered interbedded mica, some very fine grained sands interbedded in parts, slight ashy matrix, non calcareous, no odor noted, no oil stains, no fluorescence or oil cuts. 0 L4 FII( )i ..1- ] 60 • COnocOPhillips Tarn 2N 327 onocoPhillips Tarn 2N-327 North Slope Borough, AK • 6166' = 100% SILTSTONE = very light gray, well indurated, dense to stiff, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, homogeneous with some silic appearance, non calcareous, moderate scattered brown mica, slightly ashy in parts, no petroleum odor or stain, no show of oil fluorescence or cut. 0 14 EPOCH 61 0 ConocoPhillips Tarn 2N 327 Wn 2N-327 North Slope Borough, AK 6169' = 100% SANDSTONE= very light gray, clast size ranges from very fine upper to very fine lower, sub round, moderate to well developed sphericity, moderate sorting, polished texture, sub mature nature, slight ashy matrix, dominant grain and grain overgrowth support, poor porosity and permeability, no stain or petroleum odor, no show of oil fluorescence or oil cuts. 0 14 EPOCH 62 ConocoPhillips Tarn 2N 327 ConocoPhillips " Tarn 2N-327 North Slope Borough; AK I 6172' = 100% MUDSTONE = medium gray to light gray, easy to break apart, brittle to firm, planar fracture, platy habit, non to trace calcareous, very clean, no silt or sands interbedded, no inclusions, homogeneous bed of silic mudstone, no oil stain or petroleum odors, no show of oil fluorescence or oil cuts. i C-4 �'.l'i �3i �t�_j 63 • ConocoPhillips Tarn 2N 327 ConocoPhillips Tarn 2N-327 6175'= 20% CARBONACEOUS SILT, 80% SILTSTONE = dark gray to brownish gray, moderate to well indurated, poorly laminated in carbonaceous sections, overall silty with clayey to slightly shale in parts, non calcareous, planar fracture, platy habit, dull earthy luster, silty texture, thin laminations of very fine grained lower sand, clay and ash, no show of oil. 0 • ConocoPhillipS Tarn 2N 327 6177'= 100% CARBONACEOUS SHALE, SILT AND CLAY = dark gray, brittle to moderate induration, silty, fractures along platy laminations, non calcareous, common black to dark brown carbonaceous inclusions, no show of oil fluorescence or oil cuts. • U EPOCH 65 • ConocoPhillipS Tarn 2N 327 6180'= 10% CARBON SHALE, 10% SANDSTONE, 80% SILTSTONE = medium dark gray, moderate induration, moderate cohesiveness, non adhesive, planar fracture along laminations of silt, very fine sand and carbon material, platy habit, dull earthy luster, silty to matte texture, interbedded with mica and carbonaceous specs, some fine ash laminations, no show of oil fluorescence or oil cuts. 0 H EPOCH 66 • ConocoPhillips Tarn 2N 327 qaik- onacoPhl Tarn 2N-327 Norah Slope Borough, 6183' = 100% CARBONACEOUS SILTY SHALE = medium light gray to light brownish gray and various hues of both, dense to stiff some brittle in parts, planar fracture, sub platy to blade like habits, dull earthy luster, smooth texture, homogeneous bed of silty shale. • 1-4 1-] )i , t -i 67 • ConocoPhillip5 Tarn 2N 327 ConocoPhillips Tara 2N-327 North Slope Borough, AK �i 6186' = 100% SANDSTONE = medium gray to light brownish gray, well consolidated, clast size ranges from fine lower to very fine lower, moderate some well sorting, moderate to well developed sphericity, trace mica, trace black and brown carbon material inclusions, non calcareous, poor to fair porosity, poor permeability, abundant grain overgrowths, no show of oil fluorescence or cut. • GMXNNP6 Tam 2N 327 6189' = 100% CARBONACEOUS MATERIAL = dark gray mottled light gray with an overall hue of dark grayish brown, coarsely fissile, silty in parts, planar fracture, platy habit, earthy luster, mottled texture, abundant coarse irregular gray brown and brownish black carbonaceous inclusions, non calcareous, no show of oil fluorescence or cut. 0-(A 1`11 1( , t-1 69 • LI 7= i COnocoftllip5 Tarn 2N 327 CbrfacgPhill ips Tarn 2N-�27 NorttEStope BolRougll, A "No PW tea- FPOC;H 6192'= 20% SANDSTONE, 80% SILTSTONE = light gray, moderate to well indurated, dense to stiff, non adhesive, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, homogeneous slightly sandy siltstone composed of >90% silt, 10% very fine grained sand, overgrowths of volcanic glass noted, no show of oil fluorescence or oil cuts. 0 (4 FT. ) ( l) 70 ConocoPhillips Tarn 2N 327 ConocoPhillips Tarn 2N-327 _ North Slope Borough, AK g+ T 'P ¢ k EI EPOCH 6195'= 20% SANDSTONE, 80% SILTSTONE = continued lithology as 6192' with interbedded black specs in volcanic glass overgrowths, general silty matrix with some very fine grain sand interbedded. No show of oil fluorescence or oil cuts. ConocoPhillips Tarn 2N 327 '7N. ,Y- onocoPhiilips ,.... Tarn 2N-327 .^ North Slope Borough, AK 6198'= 10% MUDSTONE, 90% SILTSTONE = continued lithology as 6195' but becoming denser and stiff with a decrease in sand content and slight amount of silic mudstone. No show of oil fluorescence or oil cuts. (4 F111( )( i 72 ConocOPhillips Tarn 2N 327 �. ConocoPhillips Tarn 2N-327 North Slope Borough, AK II • 6201' = 100% MUDSTONE = medium dark gray, firm, dense to stiff in parts, moderate cohesiveness, non adhesiveness, planar fracture, sub platy to platy habit, dull earthy luster, smooth to matte texture, homogeneous bed of silic mudstone composed of 70% clay, 30% silt, no show of oil fluorescence or oil cuts. i 73 ConocoPhillipS Tarn 2N 327 ConocoPhillips Tarn 2N-327 North Slope Borough, AK 6204'= 20% SANDSTONE, SILTSTONE 80% = medium light gray, well indurated, dense to stiff, good cohesion, non adhesion, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, homogeneous silts with abundant grain overgrowths, trace interbedded carbon specs, sharp edge fractures along broken core fragments, no show of oil fluorescence or oil cuts. 0 14 1"i'( )i" , r J 74 ConocoPhillips Tarn 2N 327 ConocoPhillips . Tarn 2N-327 6207'= 10% MUDSTONE, 90% SILTSTONE = medium gray, well indurated, dense, stiff, good cohesion, non adhesion, sub planar fracture, sub platy habit, moderate earthy luster, matte texture, becoming slightly more silic with grain overgrowths of silt size, scattered brown carbonaceous thin fragments, grading to a silty mudstone. 0 14 EPOCH 75 • COnocoPhilliPS Tarn 2N 327 6208'= 30% SILTSTONE, 70% CLAYSTONE = very light gray, soft, crumbly, slight to moderate cohesion, non adhesive, easy to break apart with hands, earthy fracture, sub nodular habit, moderate to bright earthy luster, silty to clayey texture, composed of 50% clay, 40% silt, 10% various detrial material, no show of oil fluorescence or cut. 10 "" I Pl )l c 1 76 • r ConocoPhilliPS Tarn 2N 327 Con Phillips Tam N-327 . North Slope Bc Core #5 At - Core #5 (6209' to 6235') cut 26' of core in 11.4 hours (100% recovery). Note: Sample surfaces exposed to mud during coring operation are contaminated with oil. Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. 6208.9' = Tuffaceous Sandstone = light gray, hard to very hard; very fine upper to fine and medium lower sand and volcanic debris in a matrix of well indurated white ash, larger particles are light gray lithic/volcanic debris, smaller size grains consist of translucent white, clear quartz and volcanics, larger grains are irregular angular in shape and appear un- weathered/transported. Grains in the fine to very fine size range are very tightly held in matrix but appear to be more rounded/spherical. Trace dark mineral/lithics, trace carbonaceous inclusions and trace mica. Matrix material is silica cemented well indurated white ash, trace to non calcareous. No fluorescence, odor, stain or cut. 0 H EPOCH 77 4 ,mm Core #5 At - Core #5 (6209' to 6235') cut 26' of core in 11.4 hours (100% recovery). Note: Sample surfaces exposed to mud during coring operation are contaminated with oil. Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. 6208.9' = Tuffaceous Sandstone = light gray, hard to very hard; very fine upper to fine and medium lower sand and volcanic debris in a matrix of well indurated white ash, larger particles are light gray lithic/volcanic debris, smaller size grains consist of translucent white, clear quartz and volcanics, larger grains are irregular angular in shape and appear un- weathered/transported. Grains in the fine to very fine size range are very tightly held in matrix but appear to be more rounded/spherical. Trace dark mineral/lithics, trace carbonaceous inclusions and trace mica. Matrix material is silica cemented well indurated white ash, trace to non calcareous. No fluorescence, odor, stain or cut. 0 H EPOCH 77 C("COPhillipS Tarn 2N 327 . , f ConocoPhiiiips y ' Tari -2N- r' N rth sio � o A, • 6211 = Tuffaceous Sandstone = Medium light gray, very hard to hard, compositionally very similar to the sandstone above but almost entirely in the very fine lower to fine lower grain size range and without the larger light gray lithic particles. Material is very slightly more calcareous than that above but still in the trace calcareous range. No fluorescence, stain, odor or cut. H EPOCH 78 ConocOPhillips Tarn 2N 327 n N EPOCH is 6214 = Tuffaceous siltstone = medium gray, very hard, dull earthy luster overall with somewhat brighter luster at magnification. Slightly sandy, slightly shaly, coarsely fissile along bedding planes, abundant carbonaceous inclusions in the very fine lower sand size range and smaller, trace mica, trace volcanic fragments, non calcareous, no oil stain, odor, fluorescence or cut. C COnOCOPhillips Tarn 2N 327 Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Average 60 1 13 7720 3 403 C-35 to K-3 6215' to 6273' MDRT (-5430' to -5488' TVDSS) 6217 = Carbonaceous shale = dark gray, very hard, very poorly fissile, sub planar fracture along bedding planes, dull earthy luster, slightly gritty texture, slightly silty, micro laminated with lighter colored silt/ash. Contains trace mica inclusions and common large black carbonaceous inclusions as well as abundant carbonaceous fines. Sample was bisected by an irregular lamina of silty very fine lower sand. Non to trace calcareous, no fluorescence, oil stain, odor or cut. C4 EPOCH 80 • r CWWQOPt1 W Tam 2N 327 • 6220 = Carbonaceous shale = medium dark gray, very hard, non fissile, slightly more homogenous than above sample, slightly to moderately silty, no significant large carbonaceous inclusions noted. Non to trace calcareous, no fluorescence, oil stain, odor or cut. 0 U EPOCH 81 • tmm 1 1 ConocoPhillips Tarn 2N 327 +r" Co iiiips 4 2N -M North Slope Borough, AK • 6223 = Tuffaceous Sandstone = Medium gray, hard, brittle, compositionally very similar to the sandstone above, fine lower to very fine upper grain predominates, trace fine upper light gray lithic grains, sub rounded to sub spherical to sub -angular grains, trace mica, common fine grain dark gray and black mafic mineral/carbonaceous inclusions; poor visible porosity, primarily grain supported but well lithified in silicic cement, non calcareous. Very vague dull yellow green fluorescence, no visible cut but has a very slight dull yellow residual fluorescence. No oil odor or stain noted. 0 .1'li 82 • • X Vfi p ConocoPhillips Tarn 2N 327 A901 , 1. {Ar A i Y r P I 1 6226 = Carbonaceous shale = dark gray, very hard, poorly fissile, dull earthy luster, smooth shaly texture, poor sub -conchoidal fracture, common dark gray to black, medium lower to fine upper carbonaceous inclusions as well as abundant carbonaceous fines, non to very slightly calcareous with no fluorescence of oil stain, odor or cut. MIK • ConocoPhillips Tarn 2N 327 • 6229 = Tuffaceous siltstone = medium dark gray, very hard, dull earthy luster overall with somewhat brighter luster at magnification. Slightly sandy, very shaly, poorly fissile does not fracture cleanly, common carbonaceous inclusions in the very fine lower sand size range and smaller, abundant mica, trace volcanic fragments. Very slightly calcareous, no oil stain or odor, slight trace bright yellow point source fluorescence and attendant fast streaming cut may be contaminant. 0 '.1'� C .r 84 • COnocOPhilliPS Tarn 2N 327 Con acoPhiftbs • 6232 = Carbonaceous shale = dark to medium gray, very hard, poorly fissile, dull earthy luster, smooth shaly texture on bedding planes, gritty sandy texture on cross bedding fracture, thinly bedded/interbedded with very hard light to medium gray silty sandstone as above described, common dark gray to black, medium lower to fine upper carbonaceous inclusions as well as abundant carbonaceous fines, abundant very fine mica inclusions in the sand interbeds. Shale is very slightly calcareous, interbedded sand is non calcareous no fluorescence, oil stain, odor or cut. • ConocoPhillip5 Tarn 2N 327 a iF M�. 6234' = Tuffaceous Sandstone = Medium gray, hard, brittle, well lithified, identical to the sandstone above, medium lower to fine upper grain predominates, abundant fine upper light gray lithic grains, sub rounded to sub spherical to sub -angular grains, common fine mica, common fine grain dark gray and black mafic mineral/carbonaceous inclusions; poor visible porosity, primarily grain supported but well lithified in silicic cement, some very light gray ash matrix support, non to trace calcareous. Very vague dull yellow green fluorescence, no visible cut but has a very slight dull yellow residual fluorescence. No oil odor or stain noted. • i - _14 1'.i'Z 7i. ',I.) 86 • ConocoPhillips Tarn 2N 327 Conocoftiliips Tam z -327 North Supe Borough, AK r] EPOCH • End of Core #5 at 6235', picked up drill bit and resumed formation drilling through the End of Core #5 at 6235', picked up drill bit and resumed formation drilling through the base of the C-35 with continued siltstone in ditch cuttings. Ditch cuttings consisted of predominantly siltstone medium gray becoming mottled greyish brown at 6270' with micro laminations of carbonaceous clay. Overall, poor to moderate induration and slightly malleable to sectile, mushy to pasty and slimy in parts and stiff in others with cuttings displaying moderate cohesiveness and slight adhesiveness. Common sub blocky to sub platy habits with sub planar fractures were noted with a dull to moderate earthy luster and silty to ashy textures. Overall the section displays a massive grading of silts, clay and carbon clay with planar orientation. Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Average 49 1 28 271 108 164 Core #6 0 " FIX)CH 87 0ConocoPhillilPS Tarn 2N 327 Core #6 (6513' to 6573') cut 60' of core in 19.5 hours (no recovery 6628 to 6673'). Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. 6513'=100% SANDSTONE = medium gray to medium dark gray, clast size ranges from fine lower to very fine upper, sub round, moderate developed sphericity, moderate sorting with some spotty well sorting, pitted texture, sub mature to mature nature, very slight visible matrix clay, dominant grain support, very slight calcareousness under magnification, scattered grain overgrowths, fair porosity, fair to poor permeability, very slight light green spotty sample fluorescence (drilling mud), no visible stain or petroleum odor, no oil cuts. E EPOCH 6516' = 100% SILTSTONE = medium dark gray to dark gray, moderate induration, crumbly in part, slight cohesiveness, non adhesive, planar fracture, platy habit, dull earthy luster, silty texture, homogeneous silt, composed of 50% silt, 50% clay, a silty mudstone, no show of fluorescence or oil cuts. R EPOCH 88 L COnocoPhillips Tarn 2N 327 North Slope Borough, AK • 6519' = 100% SILTSTONE = dark gray, moderate induration, crumbly in part, slight cohesiveness, non adhesive, planar fracture, platy habit, dull earthy luster, silty texture, interbedded carbonaceous shale specs with planar orientation, composed of 60% silt, 40% clay, overall a silty mudstone, no oil stain or odor with no oil cuts. 0 li �'.1' . 4 � i 89 • 0 COnocoPhilliPS Tarn 2N 327 6522'= 100% SANDSTONE = medium dark gray to dark gray, clast size ranges from very fine upper to very fine lower, sub round, moderate occasional well developed sphericity, moderate sorting, pitted texture, sub mature to mature nature, non to very slight clay matrix, dominant grain support, moderate grain overgrowths, non to very slightly calcareous under magnification, poor porosity and permeability, micro laminations of very thin silts and dark minerals, spotty light green sample fluorescence from the drilling mud, no petroleum odor or oil cuts. • ConocOPhillips Tarn 2N 327 Conacophillips Tarn 2N=342 North Slope Borough, AK 6525'= 100% SANDSTONE = medium gray to medium light gray, clast size ranges from very fine upper to very fine lower, sub round to occasionally rounded, moderately to occasionally well developed sphericity, moderately sorted, pitted texture, mature nature, non to very slightly calcareous, dominantly grain supported with some zones have slight clay matrix support, slight grain overgrowth but primarily grain to grain contact, fair to good porosity and permeability, spotty light green fluorescence from mud contamination, no stain odor or cut. 91 ConocoPhillips Tarn 2N 327 • 6527'= SANDSTONE 50%, SILTSTONE 50% = medium to dark gray, clast size ranging from very fine sub -rounded lower sand, grading to siltstone, moderately developed sphericity, poor sorting, pitted texture, sub -mature to immature nature, non calcareous, micro -laminated with and grading to siltstone, moderate grain overgrowths to some clean sands, dark gray siltstone with planar orientation of carbonaceous specs, grading to very fine sandy siltstone, no stain odor fluorescence or cut. 092 • COnocOPhillips Tarn 2N 327 6527 to 6571' core not recovered. Drill crew ran into hole with rotating drill string and #3rr bit, tagged and drilled out the approximately 20 feet of the dropped core, then drilled one additional foot to clean the hole before pulling out to continue the coring program. Cuttings sample descriptions of the drilled up core follow. Samples were taken at the 6560' level and at bottoms up 6572'. Due to uncertainties imparted by dropping the core, actual depth of the "6560"' sample is questionable. 6560' (pulverized core) = 50% SANDSTONE, 40% SILTSTONE AND 10% SHALE Sandstone is medium gray to light gray, very firm to hard; very fine lower to fine lower grain; well sorted to moderately well sorted; sub -rounded to moderately rounded; primarily quartz sand in clay/ash matrix; common fragments display moderate grain support and slight overgrowth between grains; poor to fair visible porosity/permeability; slightly calcareous; grading to and thinly interbedded with dark to light gray siltstone and dark gray shale. Cleaner siltstone is primarily dark gray grading to light gray slightly to very sandy siltstone; dull earthy luster; slightly gritty texture; moderately cohesive / adhesive; tends to clump into small "clay balls". Shale is primarily dark gray; hard; platy; fissile; easily fractures into bladed fragments; trace very light gray clean Claystone; trace limonite residue on bedding planes; Note sample heavily contaminated with safecarb (calcite) mud additive and oil from upper zones; 60% of sample fluoresces medium yellow to dull yellow green with a strong yellow white cut which may be due to contamination. Trace stain on shale partings, no odor noted. 6573' (Freshly drilled footage from 6571 to 6573) = 80% Siltstone 20% Sandstone. Siltstone is medium to dark gray; hard to very firm; dull earthy luster; slightly gritty "I, I,IX93 • CDr*Co hillipS Tarn 2N 327 texture; generally clean; slightly sandy in part; overall, fragments are very thinly laminated; trace micro -thin carbonaceous laminations; trace very fine carbonaceous inclusions; grades to and thinly interbedded with associated sandstone and trace hard dark gray shale; Sandstone is identical in character to that described above; numerous fragments show interbedding contact between sand and silt; grain size is slightly larger; very slightly to slightly calcareous; pervasive dull to medium yellow to yellow green fluorescence throughout the sample; individual fragments pf rock, after light additional wash, displayed no fluorescence; no odor or stain noted. K-3 to Esker (Top) 6273' to 6453' MDRT (-5488' to -5666' TVDSS,) The K-3 section is composed of predominantly silts and mudstones. The siltstones are medium gray to medium light gray with poor to moderate induration. Consistency and tenacity are malleable to sectile, mushy to pasty with some slimy and a slight to moderate cohesiveness and slight to moderate adhesiveness. Cuttings display a sub earthy fracture and a sub nodular habit with a dull to moderate earthy luster. The texture is silty to ashy and the formation displays a massive gradational silt with secondary minor mudstones and trace very fine grained sandstones. • The secondary mudstones are yellowish gray and very soft displaying a mushy to pasty consistency. Cuttings are non to slight cohesive to slight to moderate adhesive with an earthy to amorphous fracture and sub nodular habit. A dominant moderate earthy luster prevails with a hydrophilic and soluble nature noted. Textures are ashy. Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Average 53 21 43 154 65 108 Esker (Top) to Esker (Bottom) 6453' to 6663' MDRT (-5666' to -5874' TVDSS) The top of the Esker is a siltstone grading to a silty mudstone yellowish gray in colour with poor induration and mushy to pasty consistency showing a non to slight cohesiveness and a slight to moderate adhesiveness with a earthy to amorphous fracture and sub nodular habit. Overall; a massive gradational silty mudstone. • CORE #7 LI EPOCH 94 • ConocoPhillips Tarn 2N 327 • Core #7 (6575' to 6594' cut 19' of core in 6 hours (no recovery 6590 to 6594') Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. 6575'= 100% MUDSTONE = medium light gray, firm, stiff, moderate cohesiveness, non adhesive, sub planar fracture, sub platy to sub blocky habit, dull earthy luster, smooth texture, homogeneous, able to "groove" surfaces with sharp tools, not dense, composed of >90% clay and minor silts, not a developed shale. 6578'= 20% SANDSTONE, 80% SILTSTONE = light brownish gray, poor to moderate induration, crumbly to crunchy, stiff in parts, sub planar fracture, sub platy habit, earthy to sub sparkly luster, gritty to silty texture, gradational silts and very fine grain lower (sands) interbedded, very weak thin sandy laminations, overall a sandy siltstone, very slight petroleum odor, very faint light brown oil stain, 50% dull to moderate spotty yellow sample fluorescence, oil laminations visible under UV light, instant moderate hazy to milky blue white streaming cuts with a slow increase to moderate milky cuts, very faint straw residue stain, best oil cut of core #7. • ConocoPhillips Tarn 2N 3277 Y -Conod6Phillips Tarn 2N-342 North Slope Borough, AK • 6581'= 100% MUDSTONE = medium gray to light brownish gray, soft to slightly firm, some becoming stiff, slightly cohesive, non adhesive, planar fracture, platy habit, dull earthy luster, matte to smooth texture, homogeneous, composed of >80% clay, 20% silt, sparkly mica noted, trace black carbon specs interbedded, no show of oil fluorescence or oil cuts. • H EPOCH 96 ConocoPhillips Tarn 2N 327 Gonocoph illi ps Tarn 2N-342. North Slope Borough, ASK AHEPOCH . 6584' = 100% MUDSTONE = same lithology and description as 6581'. No change. • [I EPOCH 97 0 • ConocoPhillips Tarn 2N 327 6587'= 100% SANDSTONE= medium gray, clast size ranges from very fine upper to very fine lower, sub round, moderate with some well developed sphericity. Moderate sorting overall, pitted texture, sub mature nature, very calcareous, slight clay matrix, dominant grain support with moderate grain overgrowths, fair to poor porosity, poor permeability, interbedded mica, very poor oil fluorescence with an instant hazy moderate light blue white hazy cut with a slow increase in brighter fluorescence, average cut, very poor residue stain. Tarn 2N-342 North Slope Borough, AK _ N EPOCH 6589.4'= 20% SILTSTONE/SANDSTONE, 80% MUDSTONE = medium gray, soft to firm, surfaces can be easily "grooved" with tools, sub blocky fracture, sub blocky habit, dull earthy luster, silty to matte texture, grading to a silty mudstone in parts, very thin planar laminations of silt and very fine grained sandstone, laminations contain dull to moderate light yellow green oil fluorescence as the non laminated structures "do not contain oil fluorescence", instant dull hazy light blue white cut with a very slow increase to a hazy milky cut and a very poor residue stain. 0 H EPOCH 98 s r _ N EPOCH 6589.4'= 20% SILTSTONE/SANDSTONE, 80% MUDSTONE = medium gray, soft to firm, surfaces can be easily "grooved" with tools, sub blocky fracture, sub blocky habit, dull earthy luster, silty to matte texture, grading to a silty mudstone in parts, very thin planar laminations of silt and very fine grained sandstone, laminations contain dull to moderate light yellow green oil fluorescence as the non laminated structures "do not contain oil fluorescence", instant dull hazy light blue white cut with a very slow increase to a hazy milky cut and a very poor residue stain. 0 H EPOCH 98 • ConocoPhillips Tarn 2N 327 • 6589.8'= 50% SILTSTONE, 50% MUDSTONE = same description as 6589.4', but grading to more siltstones with continued spotty oil fluorescence. Core appears "washed out" displaying a sub triangular shape. 0 FP )C:E-i 99 r1 ConocoPhillips Tarn 2N 327 Core samples from 6590' to 6595' were "lost" in core drilling and tripping. The following sample descriptions were made of cuttings brought to surface while coring. Sample quality is very poor. 6590'= 50% MUDSTONE, 50% SILTSTONE = medium gray, poor to some moderate induration, sub blocky fracture, sub nodular habit, dull earthy luster, silty to smooth textures, overall a silty mudstone, abundant cavings and trip trash throughout samples, spotty oil fluorescence (20%) throughout the sample but unsure if mud contamination or cavings, very poor oil cuts. 6595'= 50% MUDSTONE, 50% SILTSTONE = same description as 6590'. CORE #8 Core #8 (6594' to 6624') cut 30' of core in 16.5 hours (no recovery 6613 to 6624'). Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. 6594' = 100% SILTSTONE = light brownish gray, poor induration, crumbly, slight cohesiveness, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty texture, easy to break apart, homogeneous silt with micro mica and light brown micro laminations of clay or ash, laminations are even, composed of >90% silt with no show of oil fluorescence or oil cuts. LY 1: l'k ,. i i 100 ConocOPhillips Tarn 2N 327 6597' = 100% SILTSTONE = medium gray to light brownish gray, poor induration, easy to scour with tools, slightly crumbly, slightly cohesive, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty to gritty texture, easy to break apart, homogeneous silt, some slightly grading to a very fine grained sandy siltstone (interbedded), composed of 90% silt, 10% very fine grain sand, interbedded with mica and micro carbonaceous specs with no show of oil fluorescence or oil cuts. 0 H EPOCH 101 0 ConocoPhillips Tarn 2N 327 ConocoPhillips Tarn 2N-342 North Slope Borough, AK )CH 6600' = 100% SILTSTONE = medium gray to light brownish gray, poor induration, easy to scour with tools, slightly crumbly, slight cohesiveness, non adhesive, sub planar fracture, sub platy habit, dull earthy luster, silty texture, easy to break apart, gradational silts, mudstone and very fine lower sand, micro laminations, increased detrital material with common mica and black carbonaceous specs throughout, no show of oil fluorescence or oil cuts. FT It T i 102 • ConocoPhillips Tarn 2N 327 CdhocoPh it ii ps Taut 2l\P342 Nolth Slope Borough, AK 6603'= 30% SANDSTONE, 70% SILTSTONE = medium gray, poor induration, crumbly, splits apart along planar laminations, slight cohesiveness, non adhesive, distinct planar fracture, platy habit, earthy to sparkly luster, silty to gritty texture, gradational laminations of silty and very detrital sands, abundant mica and carbonaceous material, very dirty overall, faint light green sample fluorescence from drilling mud. 103 • ConocOPhillip5 Tarn 2N 327 6606' = 100% SILTSTONE = medium gray, poor induration, crumbly to brittle in parts, splits along planar fractures, sub platy habit, slight cohesiveness, non adhesive, distinct planar fracture, earthy luster, silty texture, homogeneous silt with rare disminated pyrite circles, continued mica and carbon fines but in less quantity than 6603', composed of >90% silt. H EPOCH 104 • COnOCOPhillipS Tarn 2N 327 Slope Borough, AK -AN EPOCH 6609' = 100% SILTSTONE = medium gray to light brownish gray, poor induration, slightly crumbly, sub planar fracture, sub platy habit, dull earthy luster, silty texture, homogeneous silt, slightly grading to a silty mudstone, abundant micro mica and slight carbon specs, less fissile than 6603 to 6606', no show of oil fluorescence or oil cuts. 0 N EPOCH 105 • ConocoPhilliPS Tarn 2N 327 r6611' = 100% SILTSTONE = sample lithology as 6609' no change. 0 ��s€seoRitli�s 106 0 ConocoPhillips Tarn 2N 327 6612.2' = 100% SANDSTONE = medium light gray to light gray, clast size ranges from very fine upper to very fine lower, sub round, moderate developed sphericity, moderate sorting, pitted texture, sub mature to mature nature, non calcareous, slight clay matrix, dominant grain support, slight to moderate grain overgrowths, fair to poor porosity, poor permeability, very weak petroleum odor, 30% slight spotty very light brown oil stain, 70% dull yellow green patchy oil fluorescence, instant moderate hazy light blue moderate streaming oil cut, slow increase to moderate hazy to cloudy blue white oil cut, slight faint straw residue stain. 11 r..nnrwrnPhiilinc Core footage: 6613 to 6624' was lost with no recovery in the core barrel. Footage 6613 to 6624' was based on ditch cuttings collected during coring as a back up. Cuttings quality is very poor with abundant cavings, pipe dope and yellow paint from the outside of the core barrel. 6613' to 6624'= 30% SANDSTONE, 20% MUDSTONE, 50% SILTSTONE = medium gray to medium light gray, poor induration, sub planar to sub blocky habit, sub platy to sub nodular habit, dull earthy luster, silty texture, some fragments of very fine grained sandstone scattered, abundant cavings: yellow paint chips, pipe dope, LCM calcite crystals, rounded silts and mudstones from up hole and general mud contaminations, 50% dull light green sample fluorescence from drilling mud, no fresh cuttings to cut, undetermined oil from unproven cuttings. Overall quality is very poor. r �� I',l'(. 107 • ConocoiiIUlips Tarn 2N 327 CORS #9 Note: Slight medium dull greenish yellow oil fluorescence from mud contamination on all fractures and surfaces exposed to mud circulation. Core descriptions based on small chips collected every three feet from the core as not to damage the continuity of the core. Core #9 (6625' to 6652') cut 30' of core in 12.5 hours (no recovery 5562 to 6655'). 6625'= SANDSTONE 30%, SILTSTONE 70%; Sandstone = medium gray to dark gray with a slight brownish secondary hue; hard to very firm , moderately well sorted; fair to poor visible porosity; very fine upper to very fine lower to trace fine lower clear to translucent white quartz sand predominates, 20 to 30% dark mafic mineral/lithics and carbonaceous inclusions impart a dirty pepper in salt appearance; trace mica; generally matrix supported in an off white to light gray clay/ash matrix; partially grain supported; moderately overgrown; moderately well indurated; matrix is moderately hydrophilic and expands visibly on application of clear water, more rapidly in weak HCI solution; thinly bedded/interbedded with associated siltstone; trace calcareous; trace very slight dead oil stain; trace very dull yellow green fluorescence may be due to contamination from mud; no cut from rock fragments; no odor noted; grades to and interbedded with hard 10 medium to hard dark gray Siltstone/Mudstone; silty texture; dull earthy luster in hand samples, micro -sparkly luster due to very fine mica inclusions noted under magnification; abundant silt and clay size carbonaceous inclusions; trace micro -thin carbonaceous laminations and fine to very fine carbonaceous inclusions; non calcareous; no stain odor, fluorescence or cut. 14 EPOCH 108 • • ConocoPhilliPS Tam 2N 327 onocoPhillips 6628' = 100% SILTSTONE = dark to medium gray overall with a marked brownish secondary hue; silty texture; dull earthy to slightly sparkly luster in hand samples, micro - sparkly luster due to very fine mica inclusions noted under magnification; abundant silt and clay size carbonaceous inclusions; common very fine lower sand laminations; trace micro -thin carbonaceous laminations-, abundant fine to very fine carbonaceous inclusions; non calcareous; no stain odor, fluorescence or cut. 1101 ill 109 h, E � ' pR qy f ConocoPhilliPS Tam 2N 327 onocoPhillips 6628' = 100% SILTSTONE = dark to medium gray overall with a marked brownish secondary hue; silty texture; dull earthy to slightly sparkly luster in hand samples, micro - sparkly luster due to very fine mica inclusions noted under magnification; abundant silt and clay size carbonaceous inclusions; common very fine lower sand laminations; trace micro -thin carbonaceous laminations-, abundant fine to very fine carbonaceous inclusions; non calcareous; no stain odor, fluorescence or cut. 1101 ill 109 • ConocoPhillips Tarn 2N 327 6631' = 100% SILTSTONE = dark gray with a slight brownish secondary hue; moderately hard; brittle-, breaks into long bladed fragments-, moderately shaly; poorly to moderately fissile; silty to shaly texture; micro -sparkly luster; non calcareous; no fluorescence found in rock fragments, no odor, stain or cut. 0 U: i`,l'l )( j 110 C] • ConocoPhillips Tam 2N 327 q_"onoctzP aillips Tarn 2N-342 North Slope Borough, AK --HEPOCH 6634'= SANDSTONE 20%, SILTSTONE % = Sandstone = medium brownish gray; moderately hard; very fine upper to very fine lower quartz sand as above described; moderately well sorted; very abundant fine carbonaceous inclusions; fair to poor visible porosity; 100% very dull yellow oil fluorescence; slow streaming cut improves on crush; good medium yellow-orange residue fluorescence; no stain or odor noted; grading to and thinly bedded/interbedded with: Siltstone = dark gray with a slight brownish secondary hue; hard to very hard; silty to sandy texture; dull mottled earthy luster; slightly to moderately sandy; super abundant fine sand size carbonaceous inclusions; abundant very fine mica; very slightly calcareous; no stain odor fluorescence or cut. 0 14 EPOCH 111 x a Its • 1, AFL `/ .. t . • a V � w YR • COnocoPhillips Tarn 2N 327 6640'= SANDSTONE/CARBONACEOUS SANDSTONE 90%, SILTSTONE 10% _ Moderately hard brownish gray sandstone generally as described in the 6634' sample however sand size tending to very fine upper to fine lower and carbonaceous inclusions are more abundant; 100% dull yellow fluorescence; very slow cut with very slight streaming, improves with crush as above; good medium yellow-orange residue fluorescence; slight oil odor; brownish hue may be due to oil stain; non calcareous. 6643'= SILTSTONE/MUDSTONE 100% = Medium gray to medium gray brown; moderately hard; dull earthy luster; silty to slightly sandy texture; immature; common fine carbonaceous inclusions, common large planar to irregular lumpy carbonaceous inclusions; trace to common brown rhombohedral calcite, some showing internal fracture striations; very vague dull yellow fluorescence; no notable cut; very slight dull orange -yellow residue fluorescence; slightly calcareous. • 14 1, I .l )±_ s 113 • ConocoPhillips Tarn 2N 327 • 6646'= SANDSTONE 100% = Medium gray -brown to medium gray; moderately hard; slightly brittle; well sorted; very fine upper to very fine lower quartz sand; very silty/clayey; primarily matrix supported; no visible porosity/permeability; matrix is light brownish gray clay/ash; common to locally abundant fine upper size flattened lenticular carbonaceous inclusions are oriented in segregated bands parallel to bedding; very slight oil odor; general 100% dull yellow fluorescence broken by narrow black carbonaceous bands; moderate slow cut gradually becomes slow streaming cut, improves on crush-, good dull orange -yellow residue fluorescence-, fast streaming orange yellow residue cut; brownish hue may be due to oil residue; very slightly calcareous. 0 (-a 1'.1'i_ )C, 11, 114 • COnocoPhillips Tarn 2N 327 Conocophillips • "fern 2N-342,_ North Slope gh ! ra 6649'= SANDSTONE 100% = Medium gray; moderately hard; well sorted, very fine upper to very fine lower grain; well rounded quartz sand; trace fine lower lithic grains; trace dark mafic mineral/lithic grains; common very fine carbonaceous material; trace micro -thin carbonaceous laminar fragments; trace mica; generally grain supported; mature; moderately well indurated; trace clay/ash matrix; non to very slightly calcareous; very vague dull yellow fluorescence; trace dull yellow residual fluorescence/cut-, no stain or odor. 115 • COnOCOPhillipS Tarn 2N 327 6652' = SANDSTONE 100% = Medium gray with a slight brownish secondary hue; moderately hard; moderately well to well sorted; very fine upper to fine lower to very fine lower grain; well to moderately well rounded quartz sand; trace light gray lithic grains in part; slight trace dark mafic mineral/lithic grains and common carbonaceous inclusions in well segregated bands parallel to bedding; poor visible porosity; noticeable oil odor; pervasive medium yellow fluorescence; fair instantaneous yellow white cut begins slight streaming cut; good yellow residual fluorescence; good yellow white residual cut; slight brownish secondary hue may be due to oil stain; non to very slightly calcareous. Note: resemblance of the fluorescence in this sample to that imparted by contaminant oil from Bermuda shows may indicate that this material has aspirated oil from the drilling fluid. C4� 1Alkl )( 116 • C7 • ConocoPhillips Tarn 2N 327 Drill Rate ft/hr Total Gas Maximum Minimum Average Maximum Minimum Avera e 67 1 17 524 54 1 98 Esker (Bottom) to TD 6663' to 6836' MDRT (-5874' to -6046' TVDSS) From the bottom of the Esker formation to the total depth, sample quality was poor to very poor with the addition of "LCM" material in the form of Sage Guard and Nut Plug. Samples consisted of gradational silts and mudstones. The rate of penetration slowed down with the increase of mudstones which swelled and were very hydrophilic, thus hampering the drill rate. The mudstones consisted of a medium light gray to light gray and showed poor induration. Consistency and tenacity was: slighty sectile, mushy to pasty, tacky to slimy, non to slight cohesiveness, slight to moderate adhesiveness, earthy fracture, sub nodular habit, moderate earthy luster, ashy to clayey texture. The section is a massive gradational silt and mudstone, with the mudstone becoming very hydrophilic and soluble at 6617'. H EPOCH 117 CDI`10 Ph1111PS Tarn 2N 327 The siltstones were medium gray, moderately firm to firm with a overall earthy luster especially when grading to mudstone. Under magnification sample display a micro sparkly luster due to micro mica inclusions. Samples have a silty to gritty texture, irregular planar fragments with some shaley in parts with some micro carbonaceous laminations, siliceous and moderately indurated and non to trace calcaeousness. Drill Rate ftlhr Total Gas % Maximum Minimum Average Maximum Minimum Average 1 47 4 23 115 14 69 L` H EPOCH 118 0 0 0 COnOC4; hillip5 Tarn 2N 327 3.3 Sampling Program / Sample Dispatch set Type / Purpose Interval Frequency Dispatched to 1 Unwashed (WET) 80'— 5870' 50' Bayview Lab ConocoPhillips Alaska, Inc. Box #1 (80'— 6000') 5870'--6033' 10' 619 Ship Creek Ave., Ste. 100 Anchorage, AK 99501 Box #2 (6000'— 6635') 6033'— 6655' (CORE) 3' Attn: D. Przywojski (907)-263-4859 6655'— 6835' 30' Bayview Lab 1 Washed, screened &dried 80'— 5870' 50,ConocoPhillips Alaska, Inc. Dry Samples 619 Ship Creek Ave., Ste. 100 5870'-6033' 10' Anchorage, AK 99501 Box Set A Attn: D. Przywojski Box #1 80 - 2600' 6033' — 6655' (CORE) 3 (907)-263-4859 Box #2 2600'— 5800' Box #3 5800'— 6835' 6655'— 6835' 30' 2 Washed, screened & dried 80'— 5870' 50' Bayview Lab Dry Samples ConocoPhillips Alaska, Inc. 5870'-6033' 10' 619 Ship Creek Ave., Ste. 100 Box Set B Anchorage, AK 99501 Box #180 - 2600' 6033'— 6655' (CORE) 3' Attn: D. Przywojski Box #2 2600'— 5800' (907)-263-4859 Box #3 5800'— 6835' 6655'— 6835' 30' 1 Gas Bags ISOTECH LABORATORIES Box "A" 1000' — 5500' 500' or gas 1308 Parkland Court kicks Champaign, IL. 61821 1 5870'— 6835' 217-398-3490/FAX 217-398-3493 IsoTubes 30' or gas kicks mail@isotechlabs.com One box of 25 E4 EPOCH 119 Conoco' hIIIIPS Tarn 2N 327 Sample frequency was locally altered according to drill rate constraints. 114 EPOCH 120 • COnOCOP iIIipS Tarn 2N 327 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory Gas Bag # Depth Gas Units IsoTube # Depth Gas Units 1 1000 7 1 5950 9 2 1293 1600 2 5980 12 3 1296 2580 3 6000 19 4 1500 170 4 6030 79 5 2000 147 5 6060 55 6 2500 5 6 6090 25 7 3000 47 7 6119 2383 8 3500 65 8 6128 833 9 4050 63 9 6140 1350 10 4460 180 10 6146 7220 11 4500 133 11 6170 246 12 4785 278 12 6200 150 13 5000 110 13 6230 122 14 5500 61 14 6280 141 15 15 6330 130 16 16 6380 93 17 17 6430 89 18 18 6480 98 19 19 6530 59 20 20 6560 90 21 21 6590 98 22 22 6620 82 23 23 6630 Miss Run 24 24 6650 61 25 26 27 28 29 0 H FTOCH 121 0 CWMC4 hVIIPS Tarn 2N 327 4. PRESSURE / FORMATION STRENGTH DATA 4.1 Formation Integrity/Leak Off Tests Equivalent mud weight (EMW) is calculated from rotary table (RT). MDRT ft TVDSS ft LOT I FIT EM FORMATION 2598.8' -2236' 16.0 CSG SHOE 5890' -5105 16.0 CSG SHOE + 20' 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) 0 H EPOCH 122 r: COnOcc; hilliPs Tarn 2N 327 4.3 Pore Pressure Summary Equivalent mud weight (EMW) is calculated from rotary table (RT). Formation Primary Interval Tops Pore Pressure EM Trend Indicators Source of Quantitative Interval Lithology Estimate MDRT TVDSS Min Max Trend ft ft COMMENCE DRILLING CONG 9.6 10.4 UP -DN BG Gas Hydrates below Perm SS/CLAY - - Gas Hydrates C80 CLAY/SAND 2719 -2339 9.7 9.7 UP BG SD/CLAY/ C50 SILT 4320 -3712 9.7 9.7 EVEN BG Uniform Gas Readings C40 SILT/CLAY 4514 -3877 9.7 9.7 EVEN BG Uniform Gas Readings SILT/CLAY/ C37 SANDSTONE 4758 -4086 9.7 9.7 SL BG Gas decreasing, no CG DECR SILT/CLAY T7 SANDSTONE 5429 -4668 9.8 9.8 EVEN BG Uniform Gas Readings T4 ICEBERG SILTSTONE 5877 -5096 10.0 10.0 DECR BG Decrease Gas SANDSTONE/ T3 (TOP RESEVOIR) SILTSTONE 5934 -5152 9.5 9.5 INCR BG INCR IN BG T2 (BASE) SANDSTONE 6061 -5278 9.6 9.6 INCR MW/BG/TG INCR IN BG/TG SILTSTONE C35 6215 -5430 9.6 10.0 INCR MW/TG/BG INCR TG/WELL FLOWS K-3 SILTSTONE 6273 -5488 10.0 10.2 INCR MW INCR MW ESKER to SANDSTONE 6453 -5666 10.3 10.4 INCR MW/TG INCR TG ESKER base 6663 -5874 1 10.4 10.4 EVEN BG/MW EVEN BG TD 1 1 6836 -6046 1 10.4 1 10.4 EVEN BG/MW EVEN BG Refer to Section 4.3 for explanation of abbreviations used. 14 EPOCH 123 U ConoCoPhalinS Tarn 2N 327 5. DRILLING DATA 5.1 Daily Activity Summary 7/11/07 Rig up Epoch. Nipple up 2n327, pick up pipe/make up and stand back stands in derick and prepare to spud. 7/12/07 Spud well. Drill from 110' to 220'. Pull out of hole to 42' measured depth. Pick up MWD and directional bottom hole assembly. Make up flex. Trip in hole. Take gyro survey. Pulse test MWD. Drill from 220' to 685'. 7/13/07 Drill to 1664'. Pump sweep. Pull out of hole. Lay out MWD and pick up new MWD. Adjust mud motor. Trip in hole to 1661'; wash down to 1664`. Drill ahead to 2035'. 7/14/07 Drill to 2609'. Pump sweep. Circulate out. Short trip. Circulate out. Pull out of hole. Rig up to run 9 5/8" casing. Begin running casing. 7/15/07 Continue running 9 5/8' casing to 2598.8'. Lost returns while circulating. Keep hole full and try to establish returns. Rig up and perform cement job. 7/16/07 Finish cementing casing and nipple down. Cut casing and install well head. Install and test BOP stack. 7/17/07 Complete testing BOP stack and surface equipment. Cut and slip drill line. Make up new bit and BHA. Trip in hole to 2509' then displace hole with 9.7 ppg. LSDN mud. Test casing to 3000 psi. Drill out shoe track and 20 feet of formation. Perform F.I.T. test to 16.0 MW Eq, 1180 psi. Drill ahead to 3190'. 7/18/07 Drill ahead from 3190' to 5315', pumping high viscosity sweeps as necessary. 7/19/07 0 14EPOCH 124 Conoco PAPS Tarn 2N 327 Drilled formation to 5870' and pumped a high viscosity nut plug sweep. Pulled out of the hole to 2565' and serviced the rig. Ran in the hole to 5787' and washed to bottom. Pumped a high viscosity sweep and weighted up the active mud system to 9.9 ppg. Pulling out of the hole to prepare to run 7" casing. 7/20/07 Finish pulling out of the hole laying down 5" drill pipe. Download MWD and breakdown the BHA. Tested the rams and rigged up to run 7" casing. Run 7" casing to 2580' and circulated at 4 bbl/min, with a gas maximum of 16 units. Run in the hole to 3480' gas = 21 units. Run in the hole to 4300' and circulated out 10 units of gas. Run in the hole to 5110' and circulated out 52 units of gas. Run in the hole to 5850' and circulated out 101 units of trip gas. Rig up cement head and circulate and conditioned the drilling mud for cement job. 7/21/07 Pumped cement to the casing and bumped the plug. Rigged down cementers and washed out the stack. Changed out the rams to 4" and tested. Racked and tallied the 4" drill pipe and ran in the hole with 36 joints of drill pipe. Pulled out of the hole and stood back 12 stands of drill pipe. Picked up the BHA and uploaded the MWD and shallow tested and continued to run in the hole. 7/22/07 • Run in the hole with 4" drill pipe to 3403' and test MWD and continue to run in the hole to 5750'. Displace the hole to 9.5 ppg mud and rig up for casing test. Test the casing to 3000 psi and wash down to bottom and drill out the float, shoe and 20' of new hole (trip gas = 42 units). Circulate and condition the hole and run a FIT to 16.0 ppg and drill new formation from 5890' to 6030' and circulate and pump a high viscosity sweep and pull out of the hole to 5807'. Check for flow and circulated the drilling mud and wait on Flo Pro mud from the mud plant. 7/23/07 Cut and slipped new drilling line and wash to bottom and pumped a sweep and displaced the hole with new mud (Flow Pro) and pull out of the hole to 54' and download the MWD tool. Rig up to run Core #1. Make up Core #1 and pick up HWDP and run in the hole to 5837' and circulate and condition the drilling mud at 2 bbl/min. Trip gas was 47 units. 7/24/07 Wash to bottom from 5837' to 6033' and tag bottom, Trip gas was 16 units. Core to 6068' at 59 spm and pulled out of the hole (allowing for gas expansion) and lay down Core #1. Pick up core barrel #2 and run in the hole. 0 N EPOCH 125 • �_ ConocoPh0lip5 Tarn 2N 327 7/25/07 Run in the hole with Core #2 and wash down from 5837' to 6068' and core to 6087'. Pull out of the hole to 250' and wait on gas expansion. Pull out of the hole and lay down Core #2 and pick up Core barrel #3. Run in the hole to 6087' (Trip gas was 223 units) and begin to core. 7/26/07 Core from 6087' to 6148' and circulate bottoms up at 20 spm. Gas increased from 1600 units to over 7000 units (check for flow = negative) and increased the mud weight from 9.5 to 9.8 ppg. Checked flow and was negative. Pull out of the hole to 250' for gas expansion. Pulled out of the hole and lay down Core #3. Picked up Core #4 and trip in the hole and encountered high gas at 1100' through gas migration. Maximum gas was 8300 units, in which the mud weight was raised to 10.0 and the gas buster was turned on, decreasing the background gas to 350 units. 7/27/07 Weight up mud from 9.8 to 10.0 ppg and circulate the drilling mud. Core formation from 6147' to 6207' and pull out of the hole with core #4. 7/28/07 Pull out of the hole with core #4 to 240' and allow for gas expansion. Pull out of the hole . with core #4 and lay down the core and rig up and run core #5. Run into the hole to 6126' and circulate out trip gas of 3340 units. Wait on core hands and run into the hole to 6207' and begin to core. 7/29/07 Core to 6233' and monitor the well. Pull out of the hole and lay down core #5. Pull wear ring and wash the stack. Rig up to test BOPE; well is flowing. Rig down test plug and run in the hole with a short drilling BHA to 6148' and wash down to 6233'. Circulate out 986 units of trip gas at 30 spm. Raise mud weight to 10.2 and circulate and monitor the well at 2.5 bpm. 7/30/07 Continue to circulate the well and then monitor the well at 6235'. Pull out of the hole to 5850'. Monitor the well and pull out of the hole and rig up and test the BOPE. Pick up the BHA and upload the MWD and shallow test the tools. Load the nukes and run in the hole to 6231' and circulate at 6 bpm, trip gas = 5010 units. Monitor the well and make a MAD pass from 6233' to 5827'. Run in the hole to bottom and drill ahead. 7/31/07 Drill formation to 6313' and circulate out samples and monitor the well. Pull out of the hole with the 4" drill pipe to 912' and rack back the HWDP in the derrick. Remove the nukes and download the MWD data and lay down the BHA and make up core #6. Run 0 U EPOCH 126 0 ConocoPhilliPS Tarn 2N 327 in the hole to 6407' and circulate and wash to bottom. The trip gas was 1942 units and start coring the formation. 8/1/07 Core #6 from 6513' to 6573' and pull out of the hole. 8/2/07 Pull out of the hole with core #6 to 240' and allow time for gas expansion. Pull out of the hole and lay down core #6: recovered only 14' of 60' core. Rig up and run in the hole with drilling bit and BHA to 5833' and cut and slip new drilling line and then run in the hole to 6497' and circulate drilling mud and wash down to 6574'. Trip gas was 5385 units. Drill formation to 6575' (1' drilled). Circulate bottoms up and monitor the well. Pull out of the hole and break off the bit and make up core #7 and begin to run in the hole. 8/3/07 Run in the hole with core #7 to 5835' and wash to bottom (6575') and tag. Trip gas was 4222 units. Core from 6575' to 6594', in which the core is bouncing, so pulled out of the hole with core #7 and removed core #7 and lay down and pick up core #8. Run in the hole to 6564' and wash down to 6594'. Trip gas was 3883 units. 8/4/07 Core #8 from 6594' to 6624' and circulate the hole and monitor the well. Pull out of the hole with core and lay down. Recovered 18' out of 30' run in the hole with drill bit and clean out the hole. Drill one foot to 6625'. Trip gas was 3356 units. 8/5/07 Circulate at 6625' and encountered a 20 barrel loss. Monitored the well and pulled out of the hole to 5833' (shoe). Ran back in the hole to 6625' and circulated bottoms up with wiper gas of 922 units and then pulled out of the hole to 799' and racked back the BHA and picked up and made up core #9. Ran in the hole to 6625' and circulated the mud. Trip gas was 3310 units. Core from 6625' to 6655' and circulated the hole clean and begin to pull out of the hole with core #9. 8/6/07 Pull out of the hole with core #9 to 240' and allow for gas expansion. Monitor the well and pull out of the hole from 240' with the core barrel. Lay down the core and clean the rig floor and upload MWD and shallow test MWD. Load the nukes and run into the hole to 5768'. Service the top drive and run into the hole to 6523' and wash down to 6655. Circulate bottoms up and record trip gas of 3554 units. Make a MADD pass over the core interval and survey the hole. Run back to bottom with wiper gas of 310 units and begin to drill formation. 0 C4 EPOCH 127 8/7/07 COM04 hNIIP' Tarn 2N 327 Drill formation to 6836' and pump a high viscosity sweep and circulate bottoms up for samples. Make a MADD pass and Geo -Tap the formation and then run back to bottom and circulate bottoms up, in which the Wiper Gas was 140 units. The mud weight was increased to 10.5 ppg and the well was monitored. Pulled out of the hole to the shoe and the well was breathing slightly. Ran back to bottom and the Wiper Gas was 440 units and the drilling mud was circulated and conditioned. 8/8/07 Continued to circulate the drilling mud and monitor the background gas. Pulled out of the hole and removed the nuke sources and downloaded the MWD data. Laid down the BHA and drained the stack. Monitored the well, the well was flowing '/Z barrel per hour. Made up a BHA and ran in the hole to 6813' and washed down to 6836'. Circulated and conditioned the drilling mud at 62 SPM. The Trip Gas was recorded at 4358 units. The mud weight was raised to 10.8 and the flow was monitored. Lost 27 barrels and gained back 25 barrels. Pumping was shut down for thirty minutes to observe flow and the Down Time Gas was 227 units. A second shutdown of the flow of one hour and forty minutes resulted in a Down Time Gas of 331 units. 8/9/07 Circulated bottoms up and pull out of the hole to 5845' and monitored the well. Run in the hole to 6795' and wash to 6836' and circulate bottoms up with a wiper gas reading of 490 units. Shut pumps down and monitor the well and pull out of the hole pumping out at 1 bbl/min. Pulled out of the hole to 5850' and monitored the pits and hole. Pulled out of the hole slowly and make up the wire line tools and run in the hole with the electric log equipment to 5935'. Pull out of the hole and remove the SWS centralizer and ru8n in the hole to 5900'. 8/10/07 Pull out of the hole with wire line tools and make up drilling BHA and run in the hole to 5864'. Wash down to 5955' and work the drill pipe. Run in the hole to 6830' and circulate and condition the hole. Trip gas was 3581 units. Pull out of the hole to the shoe pumping at 1.5 bpm. Monitor the well and run in the hole to bottom working tight spots at 5908', 5935' and 5956'. Wiper gas was 629 units. Pull out of the hole and monitor the well. Lay down the bit and run in the hole with logging equipment. 8/11/07 Continue logging hole with wire line tools. Briefly stuck pulling out wire line below casing shoe, pull 2000 lbs over to free tool and continue. Pull a -line out of hole and lay down/rig down Schlumberger. Rig up for running liner. Pick up/make up liner and run in hole to shoe. Monitor well 20 minuets and continue RIH to bottom. Rig up and test cement lines. Pump cement. Circulate on top of liner. Set Packer. Pump annulus clean and Pull out of hole. 0 U EPOCH 128 I* 8/12/07 CDrIOCa hillIPS Tarn 2N 327 Released from well. 14 EPOCH 129 • 5.2 Bit Record U COnOCoPhiIhPS Tarn 2N 327 s Bit / Run Make Type Jets / Size Depth In ft Total Footage Bit Hrs Av. ROP ft/hr WOB (kibs) RPM PP (psi) Wear BHA 12.25" HOLE 1 1 HTC I MXL-1 3X15, 1X13 1 110' 2500' 1 23.18 1 109.1 12 85 2100 1 NA 1+2 8.75" HOLE 2 HYCA LOG DTXG19M-02 6X13 2610' 3260' 23.24 148 24 73 2412 1 -1 -CT -G -X -1 -NO -TD 3 CORE BIT#1 N/A 6033' 35' 2.50 15 28 60 1933 N/A Core 6.125" HOLE 3 HYCA DS69FNPV 5X10 5870' 160' 2.18 74 28 99 1113 1 -1 -CT -G -X -1 -JD -CP 4 LOG C61 HYCA CORE BIT#1 N/A 6033' 35' 2.50 15 28 60 1933 N/A Core LOG AXC-425 #1 C132 HYCA CORE BIT#2 N/A 6068' 19' 7.14 13 14 71 967 N/A Core LOG AXC-425 #2 C133 HYCA CORE BIT#3 N/A 6088' 60' 5.09 19 12 55 1156 N/A Core LOG AXC-425 #3 C134 HYCA CORE BIT #4 N/A 6149' 60' 18.3 10 10 65 1125 N/A Core LOG AXC-425 #4 C135 HYCA CORE BIT#5 N/A 6207' 26' 11.43 7 15 74 1084 N/A Core LOG AXC-425 #5 3rr2 HYCA DS69FNPV N/A 6233' 280' 7.02 42 11 81 2421 N/A 5 LOG C136 HYCA CORE BIT #6 N/A 6513' 59' 19.47 5 11 72 1456 NIA Core LOG AXC-425 #6 3rr3 HYLA DS69FNPV 5X10 6573' 1' .1 65 23 138 3211 N/A 6 LOG C67 HYCA CORE BIT#7 N/A 6575' 19' 6 10 18 73 1436 N/A Core LOG AXC-425 #7 C138 HYCA CORE BIT #8 N/A 1 6594' 1 30' 1 16.5 1 4 1 13 1 58 1 1090 1 N/A ICore U EPOCH 130 Cono'coP llil:)s Tarn 2N 327 U EPOCH 131 LOG AXC-425 #8 CB9 HYCA CORE BIT#9 N/A 6625' 30' 12.3 3 26 64 1090 N/A Core LOG AXC-425 #9 3rr HYCA DS69FNPV 5X10 6655' 180' 24 22 92 1312 BHA LOG 1 -1 -WT -A -X -1 -NO -TD #7 U EPOCH 131 ConocoPhilliPs Tarn 2N 327 5.3 Survey Record Measured Depth Inclination Azimuth TVD Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 81.0 0.23 47.83 81 0.11N 0.12E 0.28 168.0 0.12 26.51 168 0.31 N 0.29E 0.14 256.0 0.25 197.61 256 0.21 N 0.27E 0.42 343.0 1.23 204.28 342.99 0.82N 0.17E 1.13 446.0 3.68 207.43 445.89 4.77S 2.15W 2,38 536.0 7.48 210.85 535.45 12.36S 6.48W 4.24 655.98 11.86 205.84 653.69 30.17S 15.86W 3,71 740.61 13.39 204.46 736.28 46,92S 23.71W 1,84 835.90 12.67 203.17 829.11 66,57S 32.39W 0,81 932.10 14.75 203.41 922.57 87,51S 41.41W 2,16 1027.71 17.19 201.49 1014.48 111.83S 51.42W 2.61 1122.59 18.72 200.92 1104.74 139.10S 62.00W 1.62 1215.85 21.84 199.47 1192.20 169.44S 73.13W 3.39 1311.12 23.63 198.28 1280.07 204.28S 85.02W 1.94 1404.97 26.58 197.12 1365.04 242.22S 97.11 W 3.19 1499.53 27.04 197.85 1449.44 282.89S 109.92W 0,60 1592.18 30.56 197.47 1530.62 325.425 123.45W 3.80 1685.39 31.42 198.83 1610.52 371.28S 137.60W 0.99 1781.30 31.92 196.73 1892.14 419.50S 152.14W 0.53 1874.21 32.47 196.97 1770.78 466.88S 166.49W 0,60 1971.52 32.88 197.18 1852.67 517.10S 181.92W 0.44 2065.90 31.91 197.03 1932.67 565.47S 196.84W 1.03 2160.31 31.74 197.22 2012.58 613.04S 211.50W 0.21 2254.57 32.29 197.66 2092.51 660.725 226.47W 0.63 2345.01 31.50 198.70 2169.29 706.125 241.38W 1,06 2441.73 31.33 198.70 2251.83 753.87S 257.54W 0.18 2538.59 31.77 198.99 2334.38 1 801.83S 273.91W 1 0.48 U EPOCH 132 COM0310100 Tarn 2N 327 U EPOCH 133 Measured Depth Inclination Azimuth ND Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 2619 32.16 198.25 2402.62 842.19S 287.51W 0.69 2706 31.44 198.79 2476.64 885.98S 301.75W 0.87 2805 31.08 197.85 2561.45 934.85S 317.46W 0.37 2899 30.74 197.84 2642.59 981.09S 332.35W 0.36 2994 30.69 196.72 2723.48 1026.98S 346.63W 0.61 3092 30.02 196.75 2806.19 1074.49S 360,91W 0.68 3187 31.20 197.48 2889.87 1120.675 375.14W 1.30 3282 30.78 197.28 2971.26 1167.32S 389.74W 0.46 3377 30.26 196.86 3053.19 1213.50S 403.92W 0.59 3472 31.22 197.88 3134.77 1259.795 418.41W 1.15 3567 30.49 197.49 3216.85 1306.51S 433.31W 0.79 3662 31.89 197.79 3297.63 1353.11S 448.13W 1.49 3757 31.48 197.42 3378.49 1400.69S 463.22W 0.48 3852 30.86 196.80 3460.26 1447.96S 477.78W 0.73 3948 31.56 198.71 3541.82 1495.01S 492.85W 1.27 4044 30.93 198.61 3624.01 1542.26S 508.81 W 0.66 4139 30.35 198.97 3705.52 1587.96S 524.36W 0.64 4234 30.90 198.27 3788.07 1634.27S 539.96W 0.68 4327 32.16 197.93 3867.08 1680.35S 555.02W 1.37 4418 31.65 197.86 3944.08 1725.97S 569.75W 0.56 4515 30.86 198.51 4027.14 1773.86S 585.48W 0.88 4609 30.47 198.14 4107.95 1819.355 600.54W 0.46 4704 31.76 197.58 4189.04 1865.93S 615.55W 1.40 4804 31.02 197.70 4274.76 1915.78S 631.40W 0.74 4894 31.39 196.30 4352.05 1960.54S 645.08W 0.90 4988 31.11 195.90 4431.72 2007.00S 658.49W 0.37 5082 31.99 197.95 4512.47 2054.42S 672.93W 1.46 5177 31.37 197.30 4593.34 2101.98S 688.05W 0.74 5275 28.32 200.01 4677.69 2147.84S 703.47W 3.43 5370 24.92 196.31 4763.05 2188.44S 716.88W 3.96 U EPOCH 133 Cowc(;PhilliPS Tarn 2N 327 5465 22.49 196.20 4849.96 2225.08S 727.68W 2.56 5559 19.66 196.51 4937.59 2257.48S 737.06W 3.02 Measured Depth Inclination Azimuth TVD Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 5653 15.8 195.63 5027.37 2285.05S 745.03W 4.10 5749 12.96 197.52 5119.45 2307.74S 751.56W 3.03 5831 10.84 202.42 5200.00 2323.70S 757.29W 2.85 5908 9.75 205.31 5275.40 2336.23S 762.82W 1.57 5955 9.14 208.33 5322.43 2343.22S 766.34W 1.65 5977 8.80 209.70 5344.51 2346.26S 768.03W 1.80 6072 8.20 212.36 5438.44 2358.30S 775.25W 0.76 6167 8.57 214.89 5532.44 2369.83S 782.93W 0.55 6261 8.88 214.71 5625.60 2381.57S 791.09W 0.33 6357 7.49 214.82 5719.67 2392.77S 798.86W 1.46 6450 6.34 213.24 5812.87 2402.135 805,19W 1.24 6550 6.16 217.96 5912.26 2410.975 811.52W 0.54 6651 7.00 222.66 6011.83 2419.70S 818.96W 0.99 6751 6.65 223.90 6135.94 2430.43S 829.10W 0.32 6776 1 6.57 1 223.99 6195.43 2435.36W 833.86W 0 6836 PROJ. 6255.03 14 EPOCH 134 5.4 Mud Record Contractor: LSND MUD to 6030' ConocoPhilliPs Tarn 2N 327 M-1 Drilling Fluids Mud Type: SPUD MUD to 2,610' FLO PRO MUD to 6836' Date Depth NMI Vis PV YP Gels API FL Solids 011IMater Sand PH CI Ca 07/12/07 690 9.6 250 36 80 41/74/81 10.6 7 /93 Nil 9.1 300 80 07/13/07 2035 10.4 100 38 46 17/49/58 6.8 11 1/89 5 9.0 450 400 07/14/07 2613 10.5 118 41 58 21/44/59 5 11 1/89 1 9.1 350 80 07/15/07 2613 10.4 70 26 22 8/13/14 5 10 1/90 .25 8.8 350 80 07/16/07 2613 10.3 40 25 20 8/11113 5 10 1/90 TR 9.0 300 80 07/17/07 3209 9.7 42 9 19 9/11/12 6.6 5 Tr/94 0 9.1 300 80 07/18/07 5315 9.8 40 12 23 8/10/12 5.5 9 1/91 Tr 9.5 350 80 07/19/07 5870 9.9 43 12 18 7/9/10 5 10 Tr/90 Tr 9.3 300 80 07/20/07 5870 10.0 42 11 13 4/5/7 4.6 10 /90 0 9.5 300 80 07121/07 5870 9.5 40 8 17 7/8/10 4.6 7 /93 0 9.0 300 80 07/22/07 6030 9.5 43 8 25 8/12/13 5.5 6 /94 0 9.5 300 80 07/23/07 6030 9.5 80 22 20 519/12 3.2 8 /92 n/a 9.3 17000 200 07/24/07 6070 9.6 110 31 37 8/17/19 3.8 8 1/91 0 9.3 20000 180 07/25/07 6102 9.5 101 31 34 6/15/20 3.2 8 1/91 0 9.3 25000 180 07/26/07 6145 9.8 110 32 32 7/14/16 3.6 8 2/90 0 9.2 20500 160 07/27/07 6207 10.0 84 30 25 4/8/14 3.5 8 2/90 TR 9.4 22500 160 07/28/07 6230 10.0 83 30 27 5/12/18 4 10 2/88 0.1 9.5 25000 140 07/29/07 6233 10.2 80 30 28 5/14/16 3.6 10 2/88 0.1 9.5 25000 160 07/30/07 6433 10.2 71 32 28 6/12/17 3.6 10 2/88 0.1 9.7 25000 120 07/31/07 6531 10.3 100 38 33 7/16/21 3.4 10 2/88 0.1 10.0 24000 120 08/01/07 6574 10.3 74 33 31 6/11/15 3.4 10 3/87 TR 9.7 25000 100 08/02/07 6575 10.3 74 34 29 6/10/15 3.4 10 2/88 TR 9.5 25000 80 08/03/07 6594 10.4 75 30 30 6/10/14 3.6 10 3/88 TR 9.7 25000 80 08/04/07 6624 10.4 74 32 31 6/11/15 3.8 10.5 3/87 TR 9.6 22500 80 08/05/07 6656 10.4 71 29 31 6/12/15 3.8 10.5 3/87 TR 9.3 23500 100 08/06/07 6721 10.4 74 1 27 30 8/16/22 3.8 10.5 3/87 TR 9.1 25000 100 H EPOCH 135 CDrIOC PhilliPs Tarn 2N 327 08/07/07 6836 10.6 72 30 36 10/19/24 3.9 11.5 3/85 TR 9.8 22500 120 08/08/07 6836 10.8 83 32 42 11/21/24 3.8 13 3/84 TR 9.8 23000 120 08/09/07 6836 10.8 96 28 42 11/21/24 4 13.5 3/84 TR 9.8 23000 120 08/10/07 6836 10.8 86 27 33 11/20/23 4 13.5 2/85 TR 9.7 23000 120 1:1 EPOCH 136 C0no0O`Phi11iPS Tarn 2N 327 • • 0 14EPOCH 137 • • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT U4hll kH 2N327 REPORT FOR SCOTT LAPIENE DATE JULY 12, 2007 DEPTH PRESENT OPERATION PICK UP PIPE/MAKEUP STANDS. TIME 24:01 YESTERDAY 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA N/A BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED N/A 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 @ @ 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 N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY RIG UP EPOCH. NIPPLE UP 2N327, PICK UP PIPE/MAKE UP AND STAND BACK STANDS IN DERICK SUMMARY AND PREPARE TO SPUD. EPOCH PERSONNEL ON BOARD 3 DAILY COST $3335 REPORT BY JOHN LUNDY file://C:\Documents%20and%20S ettings\RigUser\My%20Documents\My%20Wells\CON... 7/12/2007 • C Daily Report Page 1 of 1 CONOCO PHILLIPS DAILY WELLSITE REPORT U4 11011 T h_r 2N-327 REPORT FOR MR. SCOTT LAPIENE DATE Jul 13, 2007 DEPTH 682 PRESENT OPERATION DRILL AND SLIDE TO BUILD ANGLE TIME 00:00:00 YESTERDAY 80 24 HOUR FOOTAGE 602 CASING INFORMATION 16" SET TO 80' 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 12.25 HTC MXL-S1 5106232 3 x 15 1 x 13 80 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 922.1 @ 418.00000 42.7 @ 458.00000 292.7 160.52080 FT/HR SURFACE TORQUE 2 @ 640.00000 0 @ 377.00000 0.7 0.30111 AMPS WEIGHT ON BIT 18 @ 439.00000 0 @ 349.00000 9.1 20.15349 KLBS ROTARY RPM 62 @ 346.00000 4 @ 367.00000 24.2 0.00000 RPM PUMP PRESSURE 1439 @ 604.00000 -55 @ 88.00000 983.1 893.37195 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 9 @ 376.00000 0 @ 180.00000 4.3 TRIP GAS N/A CUTTING GAS 0 @ 682.00000 0 @ 682.00000 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 1581 @ 376.00000 59 @ 83.00000 769.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 682.00000 0 @ 682.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 682.00000 0 @ 682.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 682.00000 0 @ 682.00000 0.0 CURRENT BACKGROUND/AVG 6 / 4.3 PENTANE (C-5) 0 @ 682.00000 0 @ 682.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CLAYSTONE 50% CONGLOMERATE SAND 20 % CONGLOMERATE 10% SAND 20% DAILY ACTIVITY SPUD WELL - DRILL TO 220'- POOH TO 42' MD - PICK UP MWD AND DIRECTIONAL BHA - MAKE UP SUMMARY FLEX - TIH - TAKE GYRO SURVEY - PULSE TEST MWD - DRILL FROM 220' TO 682'. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335.00 REPORT BY C. H. Friloux file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\Cono... 7/13/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS NORTH SLOPE DAILY WELLSITE REPORT El'C+r:L 2N-327 REPORT FOR MR. SCOTT LAPIENE DATE Jul 14, 2007 DEPTH 2035.00000 PRESENT OPERATION DRILLING AHEAD TIME 00:00:00 HRS. YESTERDAY 682.00000 24 HOUR FOOTAGE 1353 CASING INFORMATION 16" SET TO 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1971 32.88 197.18 1852.67 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HTC MXL-S1 5106232 3x15 1x13 110' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 319.9 @ 1603.00000 9.0 @ 1520.00000 126.6 61.69137 FT/HR SURFACE TORQUE 5 @ 1254.00000 0 @ 1423.00000 2.4 3.70662 AMPS WEIGHT ON BIT 38 @ 1790.00000 -1 @ 728.00000 19.5 20.15349 KLBS ROTARY RPM 81 @ 1763.00000 53 @ 1251.00000 47.9 78.00000 RPM PUMP PRESSURE 2100 @ 1650.00000 0 @ 0 1702.9 1803.50842 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 2964 @ 1298.00000 2 @ 1082.00000 138.3 TRIP GAS 1060 CUTTING GAS 0 @ 2035.00000 0 @ 2035.00000 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 226681 @ 1294.00000 420 @ 1447.00000 9937.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 10 @ 1385.00000 0 @ 1759.00000 0.6 AVG 0 PROPANE (C-3) 0 @ 2035.00000 0 @ 2035.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2035.00000 0 @ 2035.00000 0.0 CURRENT BACKGROUND/AVG 140 / 138 PENTANE (C-5) 0 @ 2035.00000 0 @ 2035.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 50% CLAYSTONE 20% SAND 30% SILTSTONE DAILY ACTIVITY DRILL TO 1664'- PUMP SWEEP - POOH - LAY OUT MWD - PICK UP NEW MWD - ADJUST MUD MOTOR - SUMMARY TIH TO 1661'- WASH DOWN TO 1664'- DRILL AHEAD TO 2035' EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335.00 REPORT BY C. H. Friloux file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\Cono... 7/14/2007 • C. • Daily Report Page 1 of 1 CONOCO PHILLIPS NORTH SLOPE DAILY WELLSITE REPORT 1 0�TT 2N327 REPORT FOR MR. SCOTT LAPIENE DATE JULY 15 2007 DEPTH 2610 PRESENT OPERATION RUNNING CASING TIME 00:00:00 HRS YESTERDAY 2035 24 HOUR FOOTAGE 575 CASING INFORMATION 16" SET TO 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2441 31.33 191.7 2251.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HTC MXL-S1 5106232 3x15 1x13 110' 2610' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 190.3 @ 2202.00000 8.9 @ 2188.00000 92.2 69.13500 FT/HR SURFACE TORQUE 5 @ 2094.00000 0 @ 2331.00000 4.1 5.14300 AMPS WEIGHT ON BIT 16 @ 2523.00000 2 @ 2255.00000 14 14.26500 KLBS ROTARY RPM 87 @ 2212.00000 1 @ 2329.00000 74.1 77.00000 RPM PUMP PRESSURE 2240 @ 2513.00000 1380 @ 2167.00000 2100 2100.80900 PSI DRILLING MUD REPORT DEPTH 2610 mW. 10.4 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 327 @ 2139.00000 2 @ 2502.00000 41.3 TRIP GAS N/A CUTTING GAS 0 @ 2609.00000 0 @ 2609.00000 0.0 WIPER GAS 90u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 65420 @ 2139.00000 597 @ 2502.00000 8257.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 2609.00000 0 @ 2609.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 2609.00000 0 @ 2609.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2609.00000 0 @ 2609.00000 0.0 CURRENT BACKGROUND/AVG 0 / 41.3 PENTANE (C-5) 0 @ 2609.00000 0 @ 2609.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 90 % CLAYSTONE 10% SILTSTONE DAILY ACTIVITY DRILL TO 2610'- PUMP SWEEP AND CIRCULATE OUT - SHORT TRIP - CIRCULATE OUT- PULL OUT SUMMARY OF HOLE - RIG UP AND BEGIN RUNING CASING EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335.00 REPORT BY C. H. Friloux file://C: \Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\Cono... 7/15/2007 U C: C7 Daily Report Page 1 of 1 CONOCO PHILLIPS NORTH SLOPE DAILY WELLSITE REPORT by110,11T 2N327 REPORT FOR MR. SCOTT LAPIENE DATE JULY 16 2007 DEPTH 2610 PRESENT OPERATION CEMENT CASING TIME 00:00:00 HRS YESTERDAY 2610 24 HOUR FOOTAGE 0 CASING INFORMATION 16" SET TO 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2441 31.33 191.7 2251.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HTC MXL-S1 5106232 3x15 1x13 110' 2610' 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 2610 MW 10.4 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 1006 @ @ TRIP GAS N/A CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 @ AVG 0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 0 115 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS NONE - NO DRILLING ACTIVITY INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 90 % CLAYSTONE 10% SILTSTONE DAILY ACTIVITY FINISH RUNNING CASING - MAX GAS WHILE RUNNING CASING 1006 UNITS. - BEGIN TO CIRCULATE - SUMMARY LOST RETURNS - WORK WITH LOST RETURNS - RIG UP AND BEGIN CEMENT JOB EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335.00 REPORT BY C. H. Friloux file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\Cono... 7/16/2007 �J • 0 Daily Report Page 1 of 1 CONOCO PHILLIPS NORTH SLOPE DAILY WELLSITE REPORT U4 hv "Ot T -T JL JL 2N327 REPORT FOR MR. SCOTT LAPIENE DATE JULY 17 2007 DEPTH 2610 PRESENT OPERATION TEST BOB - CUT AND SLIP DRILL LINE TIME 00:00:00 HRS YESTERDAY 2610 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" SET TO 2610' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2441 31.33 191.7 2251.83 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" 2610' 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 2610 MW 10.4 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 @ @ TRIP GAS N/A CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 @ AVG 0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS NONE - NO DRILLING ACTIVITY INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 90 % CLAYSTONE 10% SILTSTONE DAILY ACTIVITY FINISH CEMEMTING CASING - NIPPLE DOWN - NIPPLE UP - TEST BOP AND SURFACE EQUIPMENT - SUMMARY CUT AND SLIP DRILL LINE - MAX GAS WHILE CEMENTING 26 UNITS. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335.00 REPORT BY C. H. Friloux file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\Cono... 7/17/2007 C] is Daily Report Page 1 of 1 CONOCO PHILLIPS NORTH SLOPE DAILY WELLSITE REPORT hr virl 2N327 REPORT FOR MR. SCOTT LAPIENE DATE Jul 18, 2007 DEPTH 3190. PRESENT OPERATION DRILLING AHEAD TIME 00:00:00 HRS. YESTERDAY 2610. 24 HOUR FOOTAGE 577 CASING INFORMATION 9 5/8" SET TO 2598.8' 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 8.75" HYCALOG 119060 TFA =.778 2610 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 448.6 @ 2613.00000 15.0 @ 3136.00000 182.5 205.90254 FT/HR SURFACE TORQUE 7 @ 2773.00000 0 @ 3142.00000 4.8 5.43035 AMPS WEIGHT ON BIT 26 @ 3146.00000 5 @ 2646.00000 25 24.10954 KLBS ROTARY RPM 81 @ 3131.00000 1 @ 3136.00000 50.2 79.00000 RPM PUMP PRESSURE 2447 @ 2613.00000 1192 @ 2750.00000 1736.7 1993.54065 PSI DRILLING MUD REPORT DEPTH 3190 MW 9.7 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 269 @ 2766.00000 0 @ 2656.00000 58.5 TRIP GAS N/A CUTTING GAS 0 @ 3190.00000 0 @ 3190.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 51243 @ 2766.00000 50 @ 2656.00000 11124.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 3190.00000 0 @ 3190.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 3190.00000 0 @ 3190.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3190.00000 0 @ 3190.00000 0.0 CURRENT BACKGROUND/AVG 54 / 58.5 PENTANE (C-5) 0 @ 3190.00000 0 @ 3190.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 60% CLAYSTONE 30% SAND 10% SILTSTONE DAILY ACTIVITY TRIP IN HOLE TO 2509'- DISPLACE HOLE WITH 9.7 PPG LSND -TEST CASING -DRILL SHOE TRACK AND SUMMARY FORMATION - CIRCULATE AND CONDITION - PERFORM F.I.T. TO 16.0 MW EQ. - DRILL AHEAD TO 3190'. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335.00 REPORT BY C. H. Friloux file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/18/2007 C] • Daily Report Page 1 of 1 CONOCO PHILLIPS NORTH SLOPE DAILY WELLSITE REPORT U4 "Of"T-T 2N327 REPORT FOR MR. SCOTT LAPIENE DATE Jul 19, 2007 DEPTH 5312 PRESENT OPERATION DRILLING AHEAD TIME 00:00:00 HRS. YESTERDAY 3190 24 HOUR FOOTAGE 2122 CASING INFORMATION 9 5/8' SET TO 2598.8' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5177 31.37 197.30 4593.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75" HYCALOG PDC 119060 TFA=0.778 2610' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 560.2 @ 3430.00000 37.2 @ 5062.00000 142.0 125.23482 FT/HR SURFACE TORQUE 9 @ 5294.00000 0 @ 5256.00000 6.2 8.92383 AMPS WEIGHT ON BIT 18 @ 4562.00000 0 @ 4204.00000 22.0 17.90127 KLBS ROTARY RPM 100 @ 4000.00000 1 @ 5245.00000 79.2 97.00000 RPM PUMP PRESSURE 2600 @ 4913.00000 60 @ 3550.00000 2658.6 2673.83447 PSI DRILLING MUD REPORT DEPTH 5312 MW 9.7 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 265 @ 4784.00000 0 @ 3970.00000 62.9 TRIP GAS N/A CUTTING GAS 0 @ 5312.00000 0 @ 5312.00000 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 48962 @ 4784.00000 94 @ 3970.00000 11472.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 902 @ 4784.00000 0 @ 3665.00000 174.2 AVG 0 PROPANE (C-3) 297 @ 4068.00000 0 @ 3967.00000 31.6 CURRENT 0 BUTANE (C-4) 92 @ 4698.00000 0 @ 4068.00000 15.5 CURRENT BACKGROUND/AVG 56 / 62.9 PENTANE (C-5) 37 @ 4698.00000 0 @ 4068.00000 4.9 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CLAYSTONE 30% SAND 20% SHALE 20% SILTSTONE 30% DAILY ACTIVITY SUMMARY DRILL AHEAD TO 5312' PUMPING SWEEPS AS NEEDED EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335.00 REPORT BY C. H. Friloux file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/19/2007 U • • Daily Report Page 1 of 1 CONOCO PHILLIPS DAILY WELLSITE REPORT,��H 2N327 REPORT FOR BREEDENNAAGEN DATE Jul 20, 2007 DEPTH 5870.00000 PRESENT OPERATION LAY DOWN DRILL PIPE TIME 12:01 AM YESTERDAY 5312.00000 24 HOUR FOOTAGE 558' CASING INFORMATION 9.625" @ 2600' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5831.07' 10.84 202.42 5200.00' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75" HYCALOG PDC 119060 TFA=0.778 2610' 5870' 3260 23.24 NA TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 270.1 @ 5609.00000 24.6 @ 5414.00000 131.6 61.31900 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 38 @ 5425.00000 9 @ 5622.00000 19.8 18.51100 KLBS ROTARY RPM 99 @ 5350.00000 1 @ 5422.00000 63.6 96.00000 RPM PUMP PRESSURE 2740 @ 5313.00000 1873 @ 5538.00000 2116.9 2073.57400 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 170 @ 5698.00000 11 @ 5598.00000 54.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 188 @ 5870' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 33985 @ 5698.00000 2061 @ 5598.00000 9846.8 CONNECTION GAS HIGH ETHANE (C-2) 718 @ 5807.00000 36 @ 5598.00000 226.4 AVG PROPANE (C-3) 443 @ 5807.00000 6 @ 5598.00000 83.7 CURRENT BUTANE (C-4) 284 @ 5807.00000 3 @ 5598.00000 49.1 CURRENT BACKGROUND/AVG PENTANE (C-5) 116 @ 5807.00000 0 @ 5598.00000 18.3 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE, CLAYSTONE, SHALE PRESENT LITHOLOGY 5870'= 70% SILT, 20% SAND, 10% SANDSTONE DAILY DRILL FORMATION TO 5870', PUMP A HIGH VIS SWEEP/CLEAN HOLE, WIPER TRIP, PULL OUT OF THE ACTIVITY HOLE TO 2565' AND SERVICE THE RIG, RUN IN THE HOLE TO 5787' AND WASH TO 5870', WIPER GAS = 188 SUMMARY UNITS, CIRCULATE BOTTOMS UP THREE TIMES AND PULL OUT OF THE HOLE LAYING DOWN SINGLE JOINTS OF DRILL PIPE. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/20/2007 • • Daily Report Page 1 of 1 CONOCO PHILLIPS DAILY WELLSITE REPORT hr �H 2N327 REPORT FOR BREEDENNAAGEN DATE Jul 21, 2007 DEPTH 5870.00000 PRESENT OPERATION PREP TO CEMENT 7" CSG TIME 12:01 AM YESTERDAY 5870.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2600' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5831.07' 10.84 202.42 5200.00' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.75" HYCALOG PDC 119060 TFA .778 2610' 5870' 3260' 23.24 1/1 -X -G 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 5870' MW 10.0 VIS 42 PV 11 YP 13 FL 4.6 Gels 4/5/7 CL- 300 FC 1/2 SOL 10 SD 0 OIL 0 MBL 22 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 101 @ 5850' @ TRIP GAS 101 @ 5850' 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 SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CEMENT PRESENT LITHOLOGY CEMENT FINISH PULLING OUT OF THE HOLE LAYING DOWN 5" DRILL PIPE, DOWNLOAD MWD AND BREAKDOWN THE DAILY BHA, TEST RAMS AND RIG UP TO RUN 7" CASING, RUN CASING TO 2580' CIRCULATE @ 4 BBL/MIN GAS = 16 ACTIVITY UNITS, RUN IN THE HOLE TO 3480' CIRCULATE OUT 21 UNITS OF GAS, RUN IN THE HOLE TO 4300' SUMMARY CIRCULATE OUT 10 UNITS OF GAS, RUN IN THE HOLE TO 5110' CIRCULATE OUT 52 UNITS OF GAS, RUN IN THE HOLE TO 5850' CIRCULATE OUT 101 UNITS OF TRIP GAS, RIG UP CEMENT HEAD AND CIRCULATE AND CONDITION THE DRILLING MUD FOR CEMENT JOB. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 0 REPORT BY LEES F. BROWNE JR. file: //C:\DOCUMENTS%20AND%20 SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/21/2007 • is Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT by ,H 2N-327 REPORT FOR BREEDEN/VAAGEN DATE Jul 22, 2007 DEPTH 5870.00000 PRESENT OPERATION RIH w/ SINGLE 4" DP TIME 12:01 AM YESTERDAY 5870.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5831.07' 10.84 202.42 5200' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125" HYCA DS69FNPV 202328 5X10 5870 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 5855' MW 9.5 VIS 40 PV 8 YP 17 FL 4.6 Gels 7/8/10 CL- 300 FC 1/2 SOL 7 SD 0 OIL 0 MBL 20 pH 9.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ 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 NO SHOWS THE LAST 24 HRS. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CEMENT PRESENT LITHOLOGY CEMENT PUMP CEMENT TO THE CASING AND BUMP THE PLUG, RIG DOWN CEMENTERS, WASH OUT STACK AND DAILY DRAIN, CHANGE OUT RAMS TO 4" AND TEST, RACK AND TALLEY 4" DRILL PIPE, RUN IN THE HOLE W/ 36 ACTIVITY JOINTS OF DRILL PIPE, PULL OUT OF THE HOLE AND STAND BACK 12 STANDS OF DRILL PIPE, PICK UP SUMMARY BHA AND UPLOAD MWD AND SHALLOW TEST AND CONTINUE TO RUN IN THE HOLE AT REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/22/2007 r� • • Daily Report Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4 L"rOC� 2N327 REPORT FOR BREEDON/VAAGEN DATE Jul 23, 2007 DEPTH 6030.00000 PRESENT OPERATION CIRC @ 34 SPM @ SHOE TIME 12:01 YESTERDAY 5870.00000 24 HOUR FOOTAGE 160' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6030' 5396' 5907 9.75 205.31 5275' BIT INFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125" HYCA DS69FNPV 202328 5X10 5870 6030 160 2.18 CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 199.3 @ 5873.00000 21.3 @ 6000.00000 74.4 63.35200 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 34 @ 5948.00000 8 @ 5901.00000 27.8 27.31000 KLBS ROTARY RPM 100 @ 5871.00000 96 @ 5900.00000 98.8 98.00000 RPM PUMP PRESSURE 2073 @ 5870.00000 294 @ 5884.00000 1112.9 1248.60800 PSI DRILLING MUD REPORT DEPTH 6030' MW 9.5 VIS 43 PV 8 YP 25 FL 5.5 Gels 8/12/13 CL- 300 FC 1/2 SOL 6 SD 0 OIL 0 MBL 15 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 79 @ 6030.00000 2 @ 5902.00000 16.4 TRIP GAS 42 @ 5870' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10127 @ 6019.00000 560 @ 5902.00000 2548.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 905 @ 6030.00000 29 @ 5902.00000 186.1 AVG 0 PROPANE (C-3) 955 @ 6030.00000 16 @ 5902.00000 142.1 CURRENT 0 BUTANE (C-4) 691 @ 6030.00000 0 @ 5909.00000 81.7 CURRENT BACKGROUND/AVG 3 CIRC PENTANE (C-5) 210 @ 6030.00000 0 @ 5999.00000 19.4 HYDROCARBON SHOWS OIL SHOW BERMUDA TOP INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6005' TO 6030' 50% SANDSTONE 50% BEFORE 15 F LWR - VF LWR, GRAIN SUP, FAIR PORO, 25% BRI YELGRN SILTSTONE MAX 79 PATCH SMPL FLR, INST CLDY SLO STRMG CT, SLO DEVEL TO AFTER CIRC CLDY-MILKY BRI BLU-WHT, FNT STRW RESD STN, SL PETRO ODR, LIGHT OIL STAIN. LITHOLOGY SILTSTONE, SANDSTONE, CLAYSTONE PRESENT LITHOLOGY 6030'= 50% SANDSTONE, 50% SILTSTONE RUN IN THE HOLE WITH 4" DRILL PIPE TO 3403', TEST MWD, RUN IN THE HOLE TO 5750', DISPLACE HOLE DAILY TO 9.5 PPG MUD, RIG UP FOR CASING TEST AND TEST TO 3000, WASH DOWN TO BOTTOM AND DRILL OUT ACTIVITY FLOAT, SHOE AND 20' OF NEW FORMATION, TRIP GAS =42 UNITS, CIRCULATE AND CONDITION HOLE, FIT SUMMARY TO 16.0 PPG, DRILL FROM 5890' TO 6030', CIRCULATE AND PUMP A SWEEP AND PULL OUT OF THE HOLE TO 5807, CHECK FLOW, CIRCULATE MUD @ 2 BBL/MIN AND WAIT ON FLO PRO MUD. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 7/23/2007 Daily Report EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 • REPORT BY LEES F. BROWNE JR. • 0 Page 2 of 2 file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 7/23/2007 • C. • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4hP �;rl 2N327 REPORT FOR BREEDON/VAAGEN DATE Jul 24, 2007 DEPTH 6030.00000 PRESENT OPERATION CIRC MUD @ 2 BBUMIN @ 5847' TIME 12:01 AM YESTERDAY 6030.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6030' 5396' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CORE #1 6.13" BH CORE BIT N/A N/A 6030' 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 6030' MW 9.5 VIS 80 PV 22 YP 20 FL 3.2 Gels 5/9/12 CL- 17000 FC 1/ SOL 8 SD na OIL 0 MBL 8 pH 9.3 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 47 TG @ 6030 @ 3 CIRC TRIP GAS 47 @ 5847' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7691 @ 6030 @ CONNECTION GAS HIGH ETHANE (C-2) 446 @ 6030 @ AVG PROPANE (C-3) 434 @ 6030 @ CURRENT BUTANE (C-4) 345 @ 6030 @ CURRENT BACKGROUND/AVG 3 PENTANE (C-5) 184 @ 6030 @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE PRESENT LITHOLOGY 6030' = 50% SANDSTONE, 50% SILTSTONE DAILY CUT AND SLIP NEW DRILL LINE, WASH TO BOTTOM AND PUMP SWEEP, DISPLACE HOLE WITH FLO PRO, ACTIVITY PULL OUT OF THE HOLE TO 54' AND DOWNLOAD MWD, RIG UP TO RUN CORE, MAKE UP CORE #1, PICK SUMMARY UP HWDP AND RUN IN THE HOLE TO 5837', CIRCULATE AND CONDITION MUD @ 2 BBUMIN, TRIP GAS = 47 UNITS EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%o20DOCUMENTS\MY... 7/24/2007 • Daily Report Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4 Ey0'('T-T 2N327 REPORT FOR MORRISNAAGEN DATE 7/25/07 DEPTH 6068.00000 PRESENT OPERATION CORE #2 TIME 12:01 AM YESTERDAY 6030.00000 24 HOUR FOOTAGE 38' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6068' 5433' BIT INFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #1 6.13" BH CORE BIT N/A N/A 6033' 6068' 35' 2.5 JAM CB #2 6.13" BH CORE BIT N/A N/A 6068' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 63.4 @ 6030.00000 2.9 @ 6035.00000 16.1 12.94900 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 28 @ 6054.00000 22 @ 6032.00000 28.1 27.22000 KLBS ROTARY RPM 98 @ 6030.00000 49 @ 6035.00000 57.5 RPM PUMP PRESSURE 3091 @ 6066.00000 541 @ 6034.00000 1679.4 PSI DRILLING MUD REPORT DEPTH 6068' MW 9.6 VIS 110 PV 31 YP 37 FL 3.8 Gels 8/17/19 CL- 20000 FC 1/ SOL 8 SD 0 OIL 1 MBL 12 pH 9.3 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 79 @ 6030.00000 3 @ 6034.00000 26.2 TRIP GAS 16 @ 6068' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9904 @ 6030.00000 440 @ 6034.00000 2974.3 CONNECTION GAS HIGH ETHANE (C-2) 905 @ 6030.00000 33 @ 6034.00000 259.1 AVG PROPANE (C-3) 955 @ 6030.00000 32 @ 6034.00000 292.5 CURRENT BUTANE (C-4) 691 @ 6030.00000 19 @ 6034.00000 200.8 CURRENT BACKGROUND/AVG 11 PENTANE (C-5) 237 @ 6060.00000 2 @ 6034.00000 78.6 HYDROCARBON CORE #1 OIL SHOWS SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6035-6039'6052- CLEAN OIL STAINED SD @ 6035' OIL BEFORE 5 100% BRIGHT YELLOW EVEN SAMPLE 6057' SHOWS @ 6054' ARE WEAK TO POOR MAX 25 FLUORESCENCE, INSTANT BLUE WHITE AFTER 25 CLOUDY CUT, 60% LTBRN OIL STAIN LITHOLOGY SANDSTONE, SILTSTONE, MUDSTONE PRESENT LITHOLOGY 6068'= SILTSTONE 70%, CLAYSTONE/MUDSTONE 30% DENSE/STIFF DAILY ACTIVITY WASH TO BOTTOM FROM 5837' TO 6033' AND TAG BOTTOM, TRIP GAS= 16 UNITS, CORE TO 6068' @ 59 SUMMARY SPM, PULL OUT OF THE HOLE ALLOWING FOR GAS EXPANSION, LAY DOWN CORE #1, PICK UP CORE #2 AND RUN IN THE HOLE. 0 EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/25/2007 Daily Report • REPORT BY LEES F. BROWNE JR. L' • Page 2 of 2 file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/25/2007 • r J Daily Report Page 1 of 1 CONOCO PHILLIPS DAILY WELLSITE REPORT /;TT 2N327 REPORT FOR MORRIS/VAAGEN DATE Jul 25, 2007 DEPTH 6095.00000 PRESENT OPERATION CORE # 3 TIME 12:01 AM YESTERDAY 6068.00000 24 HOUR FOOTAGE 27' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6095 5460 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #2 6.12" BH CORE BIT N/A N/A 6068 6087 19 7.4 N/A JAM CB #3 6.12" BH CORE BIT N/A N/A 6087 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 36.3 @ 6093.00000 0.9 @ 6081.00000 9.5 8.07010 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 27 @ 6068.00000 2 @ 6092.00000 11.5 5.00000 KLBS ROTARY RPM 71 @ 6080.00000 50 @ 6094.00000 66.0 55.00000 RPM PUMP PRESSURE 3091 @ 6068.00000 687 @ 6070.00000 1004.9 1120.69263 PSI DRILLING MUD REPORT DEPTH 6102' MW 9.5 VIS FV 101 PV 31 YP 34 FL 3.2 Gels 6/15/20 CL- 25000 FC 1/ SOL 8 SD 0 OIL 1 MBL 10 pH 9.3 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 27 @ 6068.00000 3 @ 6081.00000 13.5 TRIP GAS 223 @ 6087' CUTTING GAS 0 @ 6095.00000 0 @ 6095.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 3311 @ 6068.00000 189 @ 6081.00000 1147.9 CONNECTION GAS HIGH ETHANE (C-2) 313 @ 6068.00000 9 @ 6081.00000 95.3 AVG PROPANE (C-3) 384 @ 6068.00000 13 @ 6081.00000 117.6 CURRENT BUTANE (C-4) 273 @ 6068.00000 13 @ 6081.00000 90.4 CURRENT BACKGROUND/AVG 15 PENTANE (C-5) 121 @ 6068.00000 3 @ 6087.00000 29.6 HYDROCARBON SHOWS NO SHOWS IN CORE #2 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SANDSTONE, MUDSTONE PRESENT LITHOLOGY 6087'= 100% MUDSTONE/CLAYSTONE (BASE OF CORE #2) DAILY ACTIVITY RUN IN THE HOLE WITH CORE BBL #2 WASH DOWN FROM 5837' TO 6068', CORE TO 6087', PULL OUT OF SUMMARY THE HOLE TO 250' FOR GAS EXPANSION, PULL OUT OF THE HOLE AND LAY DOWN CORE #2, PICK UP CORE #3, RUN IN THE HOLE TO 6087' TRIP GAS = 223 UNITS, BEGIN TO CORE. EPOCH PERSONNEL ON BOARD 4' DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/26/2007 • 0 • Daily Report Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4 �iOv,H 2N327 REPORT FOR MORRISNAAGEN DATE Jul 27, 2007 DEPTH 6148.00000 PRESENT OPERATION CIRC MUD AT 6148' TIME 12:01 AM YESTERDAY 6095.00000 24 HOUR FOOTAGE 53' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6148' 5512.97' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #3 6.12" BH CORE BIT N/A N/A 6088 6148 60 5.1 N/A CP CB #4 6.12" BH CORE BIT N/A N/A 6149 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 40.0 @ 6142.00000 2.0 @ 6124.00000 18.5 22.34500 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 25 @ 6126.00000 3 @ 6102.00000 13.4 20.59100 KLBS ROTARY RPM 55, @ 6095.00000 54 @ 6148.00000 55.6 54.00000 RPM PUMP PRESSURE 1205 @ 6125.00000 1116 @ 6097.00000 1162.2 1140.25600 PSI DRILLING MUD REPORT DEPTH 6148' MW 9.8 VIS 110 PV 32 YP 32 FL 3.6 Gels 7/14/16 CL- 20500 FC 1/ SOL 8 SD 0 OIL 2 MBL 10 pH 9.2 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 7220 @ 6148.00000 18 @ 6100.00000 832.8 TRIP GAS 8374 @ 6148' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 48382 @ 6133.00000 1296 @ 6100.00000 24763.9 CONNECTION GAS HIGH ETHANE (C-2) 26125 @ 6148.00000 134 @ 6100.00000 7001.3 AVG PROPANE (C-3) 36204 @ 6148.00000 161 @ 6095.00000 9365.3 CURRENT BUTANE (C-4) 61413 @ 6148.00000 121 @ 6095.00000 8296.1 CURRENT BACKGROUND/AVG 1600 PENTANE (C-5) 27175 @ 6148.00000 35 @ 6095.00000 3629.6 HYDROCARBON CORE #3 OIL SHOWS SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6103 TO 6148 SANDSTONE BEFORE 75 MAX 7250 BERMUDA SANDSTONES WITH LAMINATED OIL AFTER 1600 SHOWS. SEE CORE REPORT LITHOLOGY SANDSTONE, SILTSTONE PRESENT LITHOLOGY 6148'= 100% SANDSTONE CORE TO 6148', CIRCULATE BOTTOMS UP @ 20 SPM, GAS INCREASED FROM 1600 UNITS TO OVER 7000, DAILY CHECK FOR FLOW = NO FLOW, INCREASE MUD WEIGHT TO 9.8, CHECK FLOW = NO FLOW, PULL OUT OF ACTIVITY THE HOLE TO 250' AND ALLOW GAS EXPANSION, PULL OUT OF THE HOLE AND LAY DOWN CORE #3, PICK SUMMARY UP CORE #4 AND TRIP INTO THE HOLE, GAS ENCOUNTERED AT 1100' THROUGH GAS MIGRATION UP THE HOLE, MAX GAS WAS 8300 UNITS, MIX UP AND RAISE MUD WEIGHT TO 10.0, GAS ON ITS WAY DOWN TO 350 UNITS AT REPORT TIME. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/27/2007 • • Daily Report EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. Page 2 of 2 file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/27/2007 • • • Daily Report Pagel of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORThvok'jul 2N327 REPORT FOR MORRIS/VAAGEN DATE Jul 27, 2007 DEPTH 6148.00000 PRESENT OPERATION CIRC MUD AT 6148' TIME 12:01 AM YESTERDAY 6095.00000 24 HOUR FOOTAGE 53' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6148' 5512.97' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #3 6.12" BH CORE BIT N/A N/A 6088 6148 60 5.1 N/A CP CB #4 6.12" BH CORE BIT N/A N/A 6149 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 40.0 @ 6142.00000 2.0 @ 6124.00000 18.5 22.34500 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 25 @ 6126.00000 3 @ 6102.00000 13.4 20.59100 KLBS ROTARY RPM 55 @ 6095.00000 54 @ 6148.00000 55.6 54.00000 RPM PUMP PRESSURE 1205 @ 6125.00000 1116 @ 6097.00000 1162.2 1140.25600 PSI DRILLING MUD REPORT DEPTH 6148' MW 9.8 VIS 110 PV 32 YP 32 FL 3.6 Gels 7/14/16 CL- 20500 FC 1/ SOL 8 SD 0 OIL 2 MBL 10 pH 9.2 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 7220 @ 6148.00000 18 @ 6100.00000 832.8 TRIP GAS 8374 @ 6148' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 48382 @ 6133.00000 1296 @ 6100.00000 24763.9 CONNECTION GAS HIGH ETHANE (C-2) 26125 @ 6148.00000 134 @ 6100.00000 7001.3 AVG PROPANE (C-3) 36204 @ 6148.00000 161 @ 6095.00000 9365.3 CURRENT BUTANE (C-4) 61413 @ 6148.00000 121 @ 6095.00000 8296.1 CURRENT BACKGROUND/AVG 1600 PENTANE (C-5) 27175 @ 6148.00000 35 @ 6095.00000 3629.6 HYDROCARBON SHOWS CORE #3 OIL SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6103 TO 6148 SANDSTONE BEFORE 75 MAX 7250 BERMUDA SANDSTONES WITH LAMINATED OIL AFTER 1600 SHOWS. SEE CORE REPORT LITHOLOGY SANDSTONE, SILTSTONE PRESENT LITHOLOGY 6148'= 100% SANDSTONE CORE TO 6148', CIRCULATE BOTTOMS UP @ 20 SPM, GAS INCREASED FROM 1600 UNITS TO OVER 7000, DAILY CHECK FOR FLOW = NO FLOW, INCREASE MUD WEIGHT TO 9.8, CHECK FLOW = NO FLOW, PULL OUT OF ACTIVITY THE HOLE TO 250' AND ALLOW GAS EXPANSION, PULL OUT OF THE HOLE AND LAY DOWN CORE #3, PICK SUMMARY UP CORE #4 AND TRIP INTO THE HOLE, GAS ENCOUNTERED AT 11 00'THROUGH GAS MIGRATION UP THE HOLE, MAX GAS WAS 8300 UNITS, MIX UP AND RAISE MUD WEIGHT TO 10.0, GAS ON ITS WAY DOWN TO 350 UNITS AT REPORT TIME. file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/27/2007 • • Daily Report EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. Page 2 of 2 file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/27/2007 • • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT E Pr 0 C H 2N327 REPORT FOR MORRIS/VAAGEN DATE Jul 28, 2007 DEPTH 6207.00000 PRESENT OPERATION PULL OUT WITH CORE #4 TIME 12:01 AM YESTERDAY 6148.00000 24 HOUR FOOTAGE 59' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6207 5571.23' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #4 6.125 BH CORE BIT AXC-425 7300788 6149 6207 59 18.3 CP CB #5 6.125 BH CORE BIT AXC-425 7300788 6207 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 56.1 @ 6162.00000 0.7 @ 6172.00000 10.5 9.39600 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 20 @ 6148.00000 3 @ 6161.00000 10.1 10.97700 KLBS ROTARY RPM 71 @ 6196.00000 54 @ 6186.00000 64.8 70.00000 RPM PUMP PRESSURE 1163 @ 6165.00000 1018 @ 6196.00000 1124.8 1089.19400 PSI DRILLING MUD REPORT DEPTH 6207' MW 10.0 VIS 84 PV 30 YP 25 FL 3.5 Gels 4/8/14 CL- 22500 FC 1/ SOL 8 SD TR OIL 2 MBL 11.25 pH 9.4 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 7220 @ 6148.00000 145 @ 6203.00000 364.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 44152 @ 6148.00000 526 @ 6185.00000 3772.2 CONNECTION GAS HIGH ETHANE (C-2) 26125 @ 6148.00000 33 @ 6203.00000 959.1 AVG PROPANE (C-3) 36204 @ 6148.00000 125 @ 6203.00000 2294.3 CURRENT BUTANE (C-4) 61413 @ 6148.00000 1079 @ 6203.00000 4089.2 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 27175 @ 6148.00000 1359 @ 6203.00000 2631.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE (FROM DITCH CUTTINGS) PRESENT LITHOLOGY SANDSTONE, SILTSTONE DAILY ACTIVITY WEIGHT UP FROM 9.8 TO 10.0 PPG, CIRCULATE DRILLING MUD, CORE FROM 6147 TO 6207', PULL SUMMARY OUT OF THE HOLE WITH CORE #4 EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/28/2007 • • Daily Report Pagel of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORTEI'(�CT-I 2N327 REPORT FOR MORRIS/VAAGEN DATE Jul 29, 2007 DEPTH 6231.00000 PRESENT OPERATION CORE #5 TIME 12:01 AM YESTERDAY 6207.00000 24 HOUR FOOTAGE 24' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6231' 5594' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #5 6.125 BH CORE BIT AXC-425 7300788 6207 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 59.5 @ 6208.00000 0.9 @ 6215.00000 6.9 1.31616 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 25 @ 6208.00000 9 @ 6210.00000 15.1 14.24415 KLBS ROTARY RPM 72 @ 6216.00000 69 @ 6230.00000 73.3 70.00000 RPM PUMP PRESSURE 1159 @ 6229.00000 958 @ 6210.00000 1080.6 1135.10364 PSI DRILLING MUD REPORT DEPTH 6230' MW 10.0 VIS 83 PV 30 YP 27 FL 4 Gels 5/12/18 CL- 25000 FC 1/ SOL 10 SD 0.1 OIL 2 MBL 10 pH 9.5 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 515 @ 6208.00000 113 @ 6231.00000 260.4 TRIP GAS 3340 @ 6207' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4070 @ 6220.00000 196 @ 6231.00000 1788.8 CONNECTION GAS HIGH ETHANE (C-2) 585 @ 6217.00000 19 @ 6231.00000 220.2 AVG PROPANE (C-3) 2528 @ 6217.00000 177 @ 6207.00000 954.7 CURRENT BUTANE (C-4) 3734 @ 6217.00000 884 @ 6207.00000 2151.1 CURRENT BACKGROUND/AVG 110 PENTANE (C-5) 3072 @ 6208.00000 1064 @ 6207.00000 2071.7 HYDROCARBON SHOWS OIL SHOW CORE #4 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6158' TO 6161' 90%SANDSTONE, 10% BEFORE 284 100% LT YELLO EVEN SAMPLE FLUORESCENCE, OIL SILTSTONE MAX 336 AFTER STAINED, MODERATE TO GOOD OIL CUT, SEE CORE 319 REORT AND DESCRIPTIONS LITHOLOGY SANDSTONE, SILTSTONE, CARBONACEOUS SHALE, MUDSTONE PRESENT LITHOLOGY 6207'= 70% SILTSTONE, 30% MUD/CLAYSTONE DAILY PULL OUT OF THE HOLE WITH CORE #4 TO 240', ALLOW FOR GAS EXPANSION, PULL OUT OF THE HOLE ACTIVITY WITH CORE #4 AND LAY DOWN, RIG UP AND RUN CORE #5 INTO THE HOLE, RUN IN THE HOLE TO 6126' SUMMARY AND CIRCULATE TRIP GAS = 3340 UNITS, WAIT ON CORE HANDS AND RUN IN THE HOLE TO 6207' AND BEGIN TO CORE. • EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CON... 7/29/2007 Daily Report Page 2 of 2 • REPORT BY LEES F. BROWNE JR. • • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20 Wells\CON... 7/29/2007 • • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT 110,,"TI h -F 2N327 REPORT FOR MORRIS/VAAGEN DATE Jul 30, 2007 DEPTH 6233.00000 PRESENT OPERATION CIRCULATE AT TD w/ 10.2 PPG MW TIME 12:01 AM YESTERDAY 6231.00000 24 HOUR FOOTAGE 2' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6233 5596 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #5 6.125 BH CORE BIT AXC-425 7300788 6207 6233 26' 11:43 N/A CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1.3 @ 6231.00000 0.9 @ 6233.00000 1.7 0.94398 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 18 @ 6233.00000 14 @ 6231.00000 26.0 18.98831 KLBS ROTARY RPM 80 @ 6232.00000 70 @ 6231.00000 115.0 80.00000 RPM PUMP PRESSURE 1137 @ 6232.00000 1099 @ 6233.00000 1686.2 1099.22241 PSI DRILLING MUD REPORT DEPTH 6233' MW 10.2 VIS 80 PV 30 YP 28 FL 3.6 Gels 5/14/16 CL- 25000 FC 1/ SOL 10 SD 0.1 OIL 2 MBL 10 pH 9.5 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 153 @ 6233.00000 108 @ 6232.00000 187.8 TRIP GAS 986 @ 6233' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 233 @ 6233.00000 176 @ 6232.00000 302.7 CONNECTION GAS HIGH ETHANE (C-2) 20 @ 6233.00000 16 @ 6232.00000 27.6 AVG PROPANE (C-3) 204 @ 6231.00000 165 @ 6232.00000 283.5 CURRENT BUTANE (C-4) 1136 @ 6233.00000 897 @ 6232.00000 1537.4 CURRENT BACKGROUND/AVG 0 POOH PENTANE (C-5) 1415 @ 6233.00000 1084 @ 6232.00000 1859.9 HYDROCARBON SHOWS NO SHOWS IN CORE #5 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SANDSTONE, MUDSTONE, CARBONACEOUS SHALE PRESENT LITHOLOGY 6233'= CARBONACEOUS SHALE LAMINATED WITH TUFFACEOUS SANDSTONE DAILY CORE #5 TO 6233', MONITOR THE WELL, PULL OUT OF THE HOLE AND LAY DOWN CORE #5, PULL WEAR ACTIVITY RING, WASH STACK, RIG UP TO TEST BOPE, WELL IS FLOWING, RIG DOWN TEST PLUG AND RUN INTO SUMMARY THE HOLE WITH SHORT DRILLING BHA TO 6148' AND WASH TO 6233', CIRCULATE OUT TRIP GAS (986 UNITS) @ 30 SPM, RAISE MUD WEIGHT TO 10.2 AND CIRCULATE AND MONITOPR THE WELL @ 2 1/2 BPM. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/30/2007 • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT -CIT-T 2N327 REPORT FOR MORRIS/VAAGEN DATE Jul 31, 2007 DEPTH 6303.00000 PRESENT OPERATION DRILLING TIME 12:01 AM YESTERDAY 6233.00000 24 HOUR FOOTAGE 70' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6261.98 8.88 214.71 5625.60 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #5 6.125" BH CORE BIT AXC-425 7300788 N/A 6207 6233 26' 11:43 CP #3rr2 6.125" HYCA DS69FNPV 202328 5X10 6233' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 49.4 @ 6270.00000 0.9 @ 6233.00000 39.9 42.23617 FT/HR SURFACE TORQUE 5 @ 6238.00000 4 @ 6235.00000 5.6 5.76833 AMPS WEIGHT ON BIT 18 @ 6233.00000 2 @ 6236.00000 10.0 10.98069 KLBS ROTARY RPM 80 @ 6233.00000 78 @ 6271.00000 80.7 79.00000 RPM PUMP PRESSURE 2549 @ 6236.00000 1099 @ 6235.00000 2473.6 2435.47852 PSI DRILLING MUD REPORT DEPTH 6333' MW 10.2 VIS 71 PV 32 YP 28 FL 3.6 Gels 6/12/17 CL- 25000 FC 1/ SOL 10 SD 0.1 OIL 2% MBL 10 pH 9.7 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 211 @ 6240.00000 115 @ 6278.00000 142.5 TRIP GAS 5010 @ 6235' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 8667 @ 6270.00000 233 @ 6233.00000 5821.4 CONNECTION GAS HIGH 285 @ 6322' ETHANE (C-2) 782 @ 6243.00000 20 @ 6233.00000 538.0 AVG PROPANE (C-3) 3500 @ 6241.00000 197 @ 6233.00000 2062.8 CURRENT 285 BUTANE (C-4) 4413 @ 6236.00000 1136 @ 6233.00000 2891.1 CURRENT BACKGROUND/AVG 99 PENTANE (C-5) 2576 @ 6236.00000 1235 @ 6247.00000 1723.1 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, MUDSTONE, SANDSTONE PRESENT LITHOLOGY 6300'= 70% SILTSTONE, 30% MUDSTONE (ABNT LCM IN MUD SYSTEM = POOR SAMPLES) CIRCULATE AND MONITOR THE WELL AT 6235', PULL OUT OF THE HOLE TO 5850', MONITOR THE WELL, DAILY PULL OUT OF THE HOLE AND RIG UP AND TEST BOPE, PICK UP BHA AND UPLOAD MWD, SHALLOW TEST ACTIVITY TOOL AND LOAD NUKES, RUN IN THE HOLE TO 6231 AND CIRCULATE AT 6 BBL/MIN TRIP GAS = 5010 SUMMARY UNITS, MONITOR THE WELL, MAKE MAD PASS FROM 6233 TO 5827', RUN 19N THE HOLE TO BOTTOM AND DRILL AHEAD. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 is REPORT BY LEES F. BROWNE JR. file://C:\DOCUMENTS%20AND%20 SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 7/31/2007 r �J • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4j 1TT 2N327 REPORT FOR MORRIS/DINK DATE Aug 01, 2007 DEPTH 6534.00000 PRESENT OPERATION CORE # 6 TIME 12:01 AM YESTERDAY 6303.00000 24 HOUR FOOTAGE 231' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6534' 5894.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #3rr2 6.125" HYCA DS69FNPV 202328 5X10 6233' 6513 280 7.02 N/A CP CB # 6 6.125" BH CORE BIT AXC425 7300788 N/A 6513' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 53.4 @ 6344.00000 1.6 @ 6522.00000 38.9 1.71624 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 20 @ 6332.00000 3 @ 6522.00000 10.7 8.75753 KLBS ROTARY RPM 83 @ 6419.00000 59 @ 6518.00000 80.4 76.00000 RPM PUMP PRESSURE 2512 @ 6348.00000 1278 @ 6516.00000 2319.1 1320.66846 PSI DRILLING MUD REPORT DEPTH 6531' MW 10.3 VIS 100 PV 38 YP 33 FL 3.4 Gels 7/16/21 CL- 24000 FC 1/ SOL 10 SD 0.1 OIL 2 MBL 10 pH 10.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 154 @ 6325.00000 54 @ 6534.00000 100.2 TRIP GAS 1942 @ 6313' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7278 @ 6468.00000 66 @ 6520.00000 4113.3 CONNECTION GAS HIGH ETHANE (C-2) 493 @ 6515.00000 41 @ 6534.00000 250.9 AVG PROPANE (C-3) 1449 @ 6304.00000 84 @ 6534.00000 457.2 CURRENT BUTANE (C-4) 3339 @ 6330.00000 257 @ 6534.00000 1409.3 CURRENT BACKGROUND/AVG 60 PENTANE (C-5) 2311 @ 6330.00000 403 @ 6534.00000 1253.1 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, MUDSTONE PRESENT LITHOLOGY SILTSTONE, MUDSTONE, SANDSTONE DAILY DRILL TO 6313', CIRCULATE OUT SAMPLES AND MONITOR THE WELL, PULL OUT OF THE HOLE WITH 4" ACTIVITY DRILL PIPE TO 912', RACK BACK HWDP, REMOVE NUKES, DOWNLOAD MWD DATA AND LAY DOWN BHA, SUMMARY MAKE UP CORE # 6 AND RUN IN THE HOLE TO 6407' AND CIRCULATE, WASH TO BOTTOM TRIP GAS = 1942 UNITS, CORE FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/l/2007 • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT E.�►�-n 2N327 REPORT FOR MORRIS/DINK DATE Aug 02, 2007 DEPTH 6571.00000 PRESENT OPERATION POOH w/ CORE #6 TIME 12:01 AM YESTERDAY 6534.00000 24 HOUR FOOTAGE 37' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6571' 5931.84' 6357.03' 7.49 214.82 5719.67 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #6 6.125 BH CORE BIT AXC-425 7300788 N/A 6513' 6571' 58 19.47 CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 11.5 @ 6571.00000 0.9 @ 6535.00000 4.5 11.48695 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 17 @ 6545.00000 8 @ 6535.00000 14.7 15.65739 KLBS ROTARY RPM 76 @ 6534.00000 64 @ 6559.00000 73.6 69.00000 RPM PUMP PRESSURE 1605 @ 6571.00000 1200 @ 6541.00000 1486.3 1605.30164 PSI DRILLING MUD REPORT DEPTH 6571' MW 10.3 VIS 74 PV 33 YP 31 FL 3.4 Gels 6/11/15 CL- 25000 FC 1/ SOL 10 SD TR OIL 3 MBL 12.5 pH 9.7 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 86 @ 6571.00000 54 @ 6542.00000 70.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 5054 @ 6571.00000 488 @ 6534.00000 2011.0 CONNECTION GAS HIGH 78 @ 6557' ETHANE (C-2) 306 @ 6571.00000 41 @ 6534.00000 113.3 AVG PROPANE (C-3) 182 @ 6571.00000 70 @ 6542.00000 103.7 CURRENT BUTANE (C-4) 273 @ 6550.00000 185 @ 6569.00000 230.6 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 580 @ 6550.00000 365 @ 6569.00000 466.8 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SANDSTONE PRESENT LITHOLOGY 6570'= SILTSTONE, SANDSTONE, MUDSTONE DAILY ACTIVITY SUMMARY CORE #6 TO 6571', PULL OUT OF THE HOLE WITH CORE #6. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/2/2007 is • Daily Report Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT E4 EI' 2N327 REPORT FOR MORRIS/DINK DATE Aug 03, 2007 DEPTH 6575.00000 PRESENT OPERATION TRIP IN WITH CORE #7 TIME 12:01 AM YESTERDAY 6574.00000 24 HOUR FOOTAGE 1' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6357.03' 7.49 214.82 5719.67 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3rr3 6.125" HYCA DS69FNPV 202328 5X10 6574 6575 1 - CP CB #7 6.125" BH CORE BIT AXC425 7300788 N/A 6575' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 61.3 @ 6575.00000 58.2 @ 6574.00000 119.5 61.28700 FT/HR SURFACE TORQUE @ 6574.00000 @ AMPS WEIGHT ON BIT 15 @ 6575.00000 14 @ 6574.00000 30.1 15.23800 KLBS ROTARY RPM 69 @ 6574.00000 69 @ 6575.00000 138.0 69.00000 RPM PUMP PRESSURE 1605 @ 6574.00000 1605 @ 6575.00000 3210.6 1605.30200 PSI DRILLING MUD REPORT DEPTH 6575' MW 10.3 VIS 74 PV 34 YP 29 FL 3.4 Gels 6/10/15 CL- 25000 FC 1/ SOL 10 SD tr OIL 2 MBL 12.5 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 216 @ 6575.00000 196 @ 6574.00000 412.8 TRIP GAS 5385 @ 6574' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 6575.00000 0 @ 6575.00000 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 6575.00000 0 @ 6575.00000 0.0 AVG PROPANE (C-3) 0 @ 6575.00000 0 @ 6575.00000 0.0 CURRENT BUTANE (C-4) 0 @ 6575.00000 0 @ 6575.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 6575.00000 0 @ 6575.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE PRESENT LITHOLOGY SANDSTONE, SILTSTONE PULL OUT OF THE HOLE WITH CORE #6 TO 240', ALLOW FOR GAS EXPANSION, PULL OUT OF THE HOLE DAILY AND LAY DOWN CORE #6, RECOVERED ONLY 14' OF 60' OF CORE, RIG UP AND RUN IN THE HOLE WITH BIT ACTIVITY #3 TO 5833', CUT AND SLIP NEW DRILL LINE, RUN IN THE HOLE TO 6497', CIRCULATE DRILLING MUD AND SUMMARY WASH DOWN TO 6574', TRIP GAS WAS 5385 UNITS, DRILL TO 6575'(l') AND DRILL UP 20' OF CORE RUBBLE AT TD, CIRCULATE BOTTOMS UP AND MONITOR THE WELL, PULL OUT OF THE HOLE AND BREAK BIT AND MAKE UP CORE #7 AND BEGIN TO RUN IN THE HOLE. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 0 REPORT BY LEES F. BROWNE JR. file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/3/2007 • 0 • Daily Report Page 2 of 2 file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENT S\MY... 8/3/2007 • • • Daily Report Page I of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT,, 2N327 REPORT FOR MORRIS/HEIM DATE Aug 04, 2007 DEPTH 6595.00000 PRESENT OPERATION TRIP IN CORE #8 TIME 12:01 AM YESTERDAY 6575.00000 24 HOUR FOOTAGE 20' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6595 5955.63 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #7 6.125" BH CORE BIT AXC-425 7300788 - 6575 6594 19' 6 TQ CB #8 6.125" BH CORE BIT AXC-425 4501420 - 6594 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 61.3 @ 6575.00000 1.7 @ 6584.00000 10.1 14.23000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 26 @ 6580.00000 11 @ 6594.00000 18.0 11.61200 KLBS ROTARY RPM 70 @ 6581.00000 69 @ 6592.00000 72.8 70.00000 RPM PUMP PRESSURE 1605 @ 6575.00000 1264 @ 6593.00000 1429.2 1304.58800 PSI DRILLING MUD REPORT DEPTH 6594' MW 10.4 VIS 75 PV 30 YP 30 FL 3.6 Gels 6/10/14 CL- 25000 FC 1/ SOL 10 SD TR OIL 3 MBL 10 pH 9.7 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 524 @ 6576.00000 93 @ 6589.00000 163.1 TRIP GAS 3883 @ 6594' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 29442 @ 6576.00000 1168 @ 6591.00000 6530.4 CONNECTION GAS HIGH ETHANE (C-2) 6577 @ 6576.00000 590 @ 6591.00000 1774.3 AVG PROPANE (C-3) 10256 @ 6576.00000 2216 @ 6595.00000 3819.0 CURRENT BUTANE (C-4) 6980 @ 6576.00000 2306 @ 6595.00000 4324.6 CURRENT BACKGROUND/AVG 115 PENTANE (C-5) 4434 @ 6580.00000 1010 @ 6589.00000 2037.5 HYDROCARBON CORE #7 OIL SHOWS SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6577-6580 6586-6590 SILTY SANDSTONE SLIGHT 50% DULL TO MOD SPOTTY YELLO SMPL FLR IN THIN (POOR CUTS) INCREASE LAMINATIONS, MOD TO GOOD OIL CUT, SEE CORE REPORT LITHOLOGY SILTSTONE, MUDSTONE, SANDSTONE PRESENT LITHOLOGY 6594'= 50% SILTSTONE, 50% MUDSTONE DAILY RUN IN THE HOLE WITH CORE #7 TO 5835', WASH TO BOTTOM (6575') TAG BOTTOM, TRIP GAS = 4222 ACTIVITY UNITS, CORE FROM 6575 TO 6594', CORE TRG AND BOUNCE, PULL OUT OF THE HOLE WITH CORE #7, SUMMARY REMOVE CORE AND LAY DOWN, PICK UP CORE #8 AND RUN IN THE HOLE TO 6564' AND WASH DOWN TO 6594', TRIP GAS = 3883 UNITS. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/4/2007 • • Daily Report EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. Page 2 of 2 file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/4/2007 C: 1] Daily Report Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT by �,� 2N327 REPORT FOR MORRIS/HEIM DATE Aug 05, 2007 DEPTH 6625.00000 PRESENT OPERATION CLEAN OUT HOLE BEFORE CORE #9 TIME 12:01 AM YESTERDAY 6595.00000 24 HOUR FOOTAGE 30' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6625' 5985.38 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #8 6.125" BH CORE BIT AXC-425 1 4501420 - 6594 6624 30 16.5 - CP #3rr 6.125" HYCA DS69FNPV 202328 5X10 6624 6625 1 - - TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 16.4 @ 6597.00000 1.7 @ 6622.00000 4.2 9.00000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 13 @ 6606.00000 10 @ 6596.00000 12.9 13.00000 KLBS ROTARY RPM 70 @ 6595.00000 54 @ 6613.00000 57.2 55.00000 RPM PUMP PRESSURE 1304 @ 6595.00000 1039 @ 6614.00000 1100.5 1054.99500 PSI DRILLING MUD REPORT DEPTH 6624' MW 10.4 VIS 74 PV 32 YP 31 FL 3.8 Gels 6/11/15 CL- 22500 FC 1/ SOL 10.5 SD tr OIL 3 MBL 12.5 pH 9.6 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 181 @ 6596.00000 81 @ 6621.00000 109.8 TRIP GAS 3356 @ 6624' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9009 @ 6600.00000 1733 @ 6614.00000 3829.2 CONNECTION GAS HIGH ETHANE (C-2) 1983 @ 6600.00000 515 @ 6621.00000 980.9 AVG PROPANE (C-3) 3944 @ 6596.00000 1834 @ 6621.00000 2604.7 CURRENT BUTANE (C-4) 4001 @ 6596.00000 2287 @ 6621.00000 2798.1 CURRENT BACKGROUND/AVG 102 PENTANE (C-5) 2037 @ 6596.00000 1173 @ 6595.00000 1485.6 HYDROCARBON OIL SHOW AT BASE OF CORE #8 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6612' TO 7 100% SANDSTONE - UNKNOWN ENDING = 85 UNITS NO VFGR SS 70% DULL YELGRN PATCHY OIL CORE LOST 6613 TO 6624' CHANGE FLR, MOD HZY CTS, FNT RESIDUE LITHOLOGY SILTSTONE, SANDSTONE PRESENT LITHOLOGY 6612'= 100% SANDSTONE DAILY CORE #8 FROM 6594' TO 6624' CIRCULATE HOLE AND MONITOR THE WELL, PULL OUT OF THE HOLE ACTIVITY WITH CORE #8 AND LAY DOWN CORE, RECOVERED 18' OUT OF 30'(6613 TO 6624 LOST), RUN IN HOLE SUMMARY WITH DRILL BIT AND CLEAN OUT HOLE AND DRILL ONE FOOT TO 6625', TRIP GAS WAS 3356 UNITS. is EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CONO... 8/5/2007 0 C • Daily Report Page 2 of 2 file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CONO... 8/5/2007 • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORTQ,H 2N327 REPORT FOR MORRIS/HEIM DATE Aug 06, 2007 DEPTH 6655.00000 PRESENT OPERATION POOH w/ CORE #9 TIME 00:01:01 YESTERDAY 6625.00000 24 HOUR FOOTAGE 30' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6655' 6015.12' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED CB #9 6.125 BH CORE BIT AXC-425 4501420 - 6625 6655 30' 12.3 CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 9.0 @ 6625.00000 1.6 @ 6638.00000 2.9 1.59000 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 28 @ 6650.00000 13 @ 6625.00000 26.8 27.33400 KLBS ROTARY RPM 69 @ 6627.00000 51 @ 6626.00000 64.4 61.00000 RPM PUMP PRESSURE 1097 @ 6628.00000 1020 @ 6655.00000 1091.0 1020.76500 PSI DRILLING MUD REPORT DEPTH 6655' MW 10.4 VIS 71 PV 29 YP 31 FL 3.8 Gels 6/12/15 CL- 23500 FC 1/ SOL 10.5 SD TR OIL 3/87 MBL 12.5 pH 9.3 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 117 @ 6629.00000 55 @ 6655.00000 76.3 TRIP GAS 3310 @ 6625' CUTTING GAS @ @ WIPER GAS 922 @ 6625' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9281 @ 6629.00000 961 @ 6655.00000 2799.2 CONNECTION GAS HIGH ETHANE (C-2) 1935 @ 6629.00000 110 @ 6655.00000 599.5 AVG PROPANE (C-3) 2722 @ 6629.00000 549 @ 6655.00000 1356.1 CURRENT BUTANE (C-4) 2249 @ 6629.00000 1305 @ 6627.00000 1750.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 1341 @ 6633.00000 737 @ 6627.00000 1207.8 HYDROCARBON SHOWS NO SHOWS DRILLING UP CORE CHIPS CORE #9 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, MUDSTONE, SANDSTONE PRESENT LITHOLOGY 6655'= SILTSTONE, MUDSTONE, SANDSTONE (CORE DITCH CUTTINGS) CIRCULATE @ 6625' = 20 BBL LOSS, MONITOR THE WELL, PULL OUT OF THE HOLE TO 5833' (SHOE), RUN DAILY IN THE HOLE TO 6625 (TD) CIRCULATE BOTTOMS UP WIPER GAS = 922 UNITS, PULL OUT OF THE HOLE TO ACTIVITY 799', RACK BACK BHA, PICK UP AND MAKE UP CORE #9, RUN IN THE HOLE TO 6625' CIRCULATE MUD, TRIP SUMMARY GAS = 3310 UNITS, CORE FROM 6625' TO 6655', CIRCULATE HOLE AND BEGIN TO PULL OUT OF THE HOLE WITH CORE #9. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/6/2007 • • • Daily Report Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4 "01("T -T by 2N327 REPORT FOR MORRIS/HEIM DATE Aug 07, 2007 DEPTH 6719.00000 PRESENT OPERATION DRILLING TIME 12:01 AM YESTERDAY 6655.00000 24 HOUR FOOTAGE 64' CASING INFORMATION 7" @ 5854' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6719' 6079.32 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3rr 6.125" HYCA DS69FNPV 202328 5X10 6655 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 66.6 @ 6660.00000 1.6 @ 6655.00000 29.4 5.82698 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 27 @ 6655.00000 3 @ 6658.00000 9.8 14.86126 KLBS ROTARY RPM 80 @ 6707.00000 61 @ 6655.00000 78.2 80.00000 RPM PUMP PRESSURE 1968 @ 6660.00000 32 @ 6656.00000 1525.1 1126.95032 PSI DRILLING MUD REPORT DEPTH n/a 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 205 @ 6661.00000 14 @ 6704.00000 68.7 TRIP GAS 3554 @ 6655' CUTTING GAS @ @ WIPER GAS 310 @ 6655' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 21673 @ 6713.00000 961 @ 6655.00000 4714.9 CONNECTION GAS HIGH 120 @ 6716' ETHANE (C-2) 2900 @ 6661.00000 110 @ 6655.00000 588.7 AVG PROPANE (C-3) 5224 @ 6661.00000 240 @ 6704.00000 1391.7 CURRENT BUTANE (C-4) 5078 @ 6661.00000 307 @ 6704.00000 1618.2 CURRENT BACKGROUND/AVG 80 PENTANE (C-5) 2966 @ 6661.00000 235 @ 6704.00000 1153.4 HYDROCARBON SLIGHT OIL SHOWS IN CORE #9 SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6646' TO 6652' 100% SILTY TO NO YELLOW SAMPLE FLUOR BROKEN BY NARROW BLACK CARBONACEOUS VERY FINE INCREASE CARBON BANDS,DETRITALISH, POOR TO MODERATE SANDSTONE OIL CUTS, SEE CORE REPORT LITHOLOGY SANDSTONE, SILTSTONE, MUDSTONE PRESENT LITHOLOGY 6620'= 80% SILTSTONE, 10% MUDSTONE, 10% SANDSTONE MONITOR THE WELL, PULL OUT OF THE HOLE WITH CORE #9 TO 240', ALOOW TIME FOR GAS EXPANSION, DAILY MONITOR THE WELL, PULL OUT OF THE HOLE FROM 240' WITH CORE BARREL, LAY DOWN THE CORE, ACTIVITY CLEAN THE RIG FLOOR, UPLOAD MWD AND SHALLOW TEST, LOAD NUKES, RUN IN THE HOLE TO 5768', SUMMARY SERVICE TOP DRIVE, RUN IN THE HOLE TO 6523', WASH DOWN TO 6655', CIRCULATE BOTTOMS UP, TRIP GAS = 3554 UNITS, MAKE A MADD PASS OVER CORE INTERVAL AND SURVEY, RUN BACK TO BOTTOM, WIPER GAS WAS 310' AND DRILL FORMATION. file://C: \DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/7/2007 Daily Report EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 • REPORT BY LEES F. BROWNE JR. is • Page 2 of 2 file: //C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/7/2007 • is Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORTv,� 2N327 REPORT FOR BREEDON/HEIM DATE Aug 08, 2007 DEPTH 6836.00000 PRESENT OPERATION CIRC MUD AT 6836' TIME 12:01 AM YESTERDAY 6719.00000 24 HOUR FOOTAGE 117' CASING INFORMATION 7" @ 5854' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3n-4 6.125" HYCA DS69FNPV 202328 5X10 6655 6836 181' 11.46 N/A TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 46.9 @ 6779.00000 4.0 @ 6721.00000 20.4 7.24600 FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 46 @ 6832.00000 14 @ 6719.00000 28.6 46.44100 KLBS ROTARY RPM 104 @ 6729.00000 80 @ 6726.00000 99.5 94.00000 RPM PUMP PRESSURE 2203 @ 6741.00000 439 @ 6779.00000 1204.3 1334.72500 PSI DRILLING MUD REPORT DEPTH 6836' MW 10.5+ VIS 74 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 86 @ 6741.00000 63 @ 6788.00000 72.8 TRIP GAS CUTTING GAS @ @ WIPER GAS 440 & 140 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 5528 @ 6800.00000 999 @ 6727.00000 3459.1 CONNECTION GAS HIGH 240 ETHANE (C-2) 386 @ 6800.00000 116 @ 6727.00000 245.0 AVG PROPANE (C-3) 1092 @ 6719.00000 186 @ 6831.00000 342.4 CURRENT BUTANE (C-4) 1990 @ 6719.00000 623 @ 6831.00000 998.0 CURRENT BACKGROUND/AVG 56 PENTANE (C-5) 1789 @ 6719.00000 936 @ 6836.00000 1240.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, MUDSTONE PRESENT LITHOLOGY 6836'= 80% MUDSTONE, 20% SILTSTONE DRILL FORMATION TO 6836', PUMP A HI -VIS SWEEP AND CIRCULATE BOTTOMS UP, MAKE A MADD PASS DAILY FROM 6752' TO 6742' AND GEO TAP, RUN BACK TO BOTTOM AND CIRCULATE BOTTOMS UP, WIPER GAS = ACTIVITY 140 UNITS, INCREASE MUD WEIGHT TO 10.5 AND MONITOR THE WELL, PULL OUT OF THE HOLE TO THE SUMMARY SHOE, WELL IS BREATHING SLIGHTLY, RUN BACK TO BOTTOM, WIPER GAS = 440 UNITS AND CIRCULATE MUD. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CONO... 8/8/2007 • • Daily Report Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4 1�'� 2N327 REPORT FOR BREEDON/HEIM DATE Aug 09, 2007 DEPTH 6836.00000 PRESENT OPERATION CIRC @ TD TIME 12:01 AM YESTERDAY 6836.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 5854' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3n-4 6.125" HYCA DS69FNPV 202328 5X10 6655 6836 181' 11.46 1/1 -X -NO 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 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 331 @ 6836 (SWAB GAS) 44 @ 6836 60 TRIP GAS 4358 @ TD CUTTING GAS @ @ WIPER GAS DOWNTIME GAS 227 CHROMATOGRAPHY (ppm) SURVEY DOWNTIME (#2) 331 METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 58 @ 33 SPM PENTANE (C-5) @ @ HYDROCARBON SHOWS NO FOOTAGE DRILLED IN LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 6836'= 80% MUDSTONE, 20% SILTSTONE CIRCULATE DRILLING MUD AT 6836', MONITOR BACKGROUND GAS, PULL OUT OF THE HOLE AND REMOVE NUKE SOURCES AND DOWNLOAD MWD, LAY DOWN BHA AND DRAIN THE STACK, MONITOR THE WELL, DAILY WELL FLOWING 1/2 BARREL PER HOUR, MAKE UP BHA AND RUN IN THE HOLE TO 6813' AND WASH DOWN ACTIVITY TO 6836', CIRCULATE AND CONDITION THE DRILLING MUD @ 62 SPM, TRIP GAS = 4358 UNITS, RAISE MUD SUMMARY WEIGHT TO 10.8 AND MONITOR FLOW, LOST 27 BBLS AND GAINED BACK 25 = HOLE BREATHING, DOWNTIME GAS = 227 UNITS AFTER 30 MINUTES OF NOT PUMPING, DOWNTIME GAS (2ND PEAK) OF 331 UNITS AFTER 1 HR 45 MINS OF NOT PUMPING @ 10.8 MW EPOCH PERSONNEL ON DAILY $2955 (NOTE LOWER DAY RATE) 1 SAMPLE CATCHER BOARD 3 COST LET GO is REPORT BY LEES F. BROWNE file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/9/2007 Daily Report • JR. • • Page 2 of 2 file://C: DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/9/2007 • • 0 Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORTITT -L-ro 2N327 REPORT FOR BREEDON/HEIM DATE Aug 10, 2007 DEPTH 6836.00000 PRESENT OPERATION E -LOG TIME 12:01 AM YESTERDAY 6836.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 5854' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 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 6836' MW 10.8 VIS 96 PV 28 YP 42 FL 4 Gels 11/21/24 CL- 23000 FC 1/ SOL 13.5 SD TR OIL 3 MBL 10 pH 9.8 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 490 WG @ 6836 @ TRIP GAS CUTTING GAS @ @ WIPER GAS 490 @ 6836' 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 LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CIRCULATE BOTTOMS UP AND PULL OUT OF THE HOLE TO 5845', MONITOR THE WELL, RUN IN THE HOLE DAILY TO 6795' AND WASH TO BOTTOM (6836'), CIRCULATE BOTTOMS UP WIPER GAS = 490 UNITS, SHUT PUMPS ACTIVITY DOWN AND MONITOR THE WELL, PULL OUT OF THE HOLE PUMPING OUT @ 1 BBL/MIN, PULL OUT OF THE SUMMARY HOLE TO 5850', MONITOR PIT VOLUMES AND WELL, PULL OUT OF THE HOLE SLOWLY, MAKE UP WIRE LINE TOOLS AND RUN IN THE HOLE WITH E -LOG EQUIPMENT TO 5935', PULL OUT OF THE HOLE AND REMOVE SWS CENTRALIIZER, RUN IN THE HOLE TO 5900' EPOCH PERSONNEL ON BOARD 2 DAILY COST $2575 w/o SAMPLE CATCHERS REPORT BY LEES F. BROWNE JR. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/10/2007 • • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT U4�, ZIT 2N327 REPORT FOR BREEDON/HEIM DATE Aug 11, 2007 DEPTH 6836.00000 PRESENT OPERATION WIRE LINE LOG TIME 12:01 AM YESTERDAY 6836.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 5854' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 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 6836' MW 10.8 VIS 86 PV 27 YP 33 FL 4 Gels 11/20/23 CL- 23000 FC 1/ SOL 13.5 SD TR OIL 2 MBL 10 pH 9.7 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 3581 CUTTING GAS @ @ WIPER GAS 629 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 LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY PULL OUT OF THE HOLE WITH WIRE LINE TOOLS, MAKE UP BHA AND BIT AND RUN IN THE HOLE TO 5864' DAILY AND WASH DOWN TO 5955' AND WORK PIPE, RUN IN THE HOLE TO 6830' AND CIRCULATE AND CONDITION ACTIVITY THE HOLE, TRIP GAS = 3581', PULL OUT OF THE HOLE TO THE SHOE PUMPING AT 1.5 BPM, MONITOR THE SUMMARY WELL - STATIC, RUN IN THE HOLE TO BOTTOM AND WORK TIGHT SPOTS AT 5908', 5935', 5956', WIPER GAS = 629 UNITS, PULL OUT OF THE HOLE AND MONITOR THE WELL, LAY DOWN BIT AND RUN IN THE HOLE WITH LOGGING EQUIPMENT. EPOCH PERSONNEL ON BOARD 2 DAILY COST $2575 REPORT BY LEES F. BROWNE JR. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY... 8/11/2007 Daily Report CONOCO PHILLIPS • TARN 2N327 REPORT FOR BREEDON/HEIM DATE • DAILY WELLSITE REPORT Page 1 of 1 €7 EPOCH Aug 12, 2007 DEPTH 6836.00000 PRESENT OPERATION PUMPING CEMENT TIME 12:01 AM YESTERDAY 6836.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 4.5" @ 6834' 7" @ 5854' TOL @ 5646' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 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 @ @ SURFACE TORQUE @ @ FT/HR WEIGHT ON BIT @ @ AMPS ROTARY RPM @ @ KLBS PUMP PRESSURE @ @ RPM PSI DRILLING MUD REPORT DEPTH 6836' MW 10.8 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 3639 (TG) @ SHOE @ CUTTING GAS @ TRIP GAS 3639 @ 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 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY FINISH ELECTRIC LOGGING, RIG DOWN LOGGERS, RIG UP TO RUN 4.5" LINER, RUN IN HOLE WITH LINER, DAILY MAKE UP HANGER ASSEMBLY, RUN IN THE HOLE WITH 4.5" LINER ON 4" DRILL PIPE TO 5846', CIRCULATE ACTIVITY AT THE SHOE, TRIP GAS = 3639 UNITS WITH GAS MIGRATION UP HOLE, MAKE UP CEMENT HEAD AND SUMMARY MONITOR THE WELL, RUN IN THE HOLE TO 6830' AND RIG UP CEMENT HEAD, GAS 1950 AND BOTTOMS UP GAS AT 6830', PUMP CEMENT AND BUMP PLUG AND SET LINER @ 6834', RIG DOWN CEMENT HEAD. EPOCH PERSONNEL ON BOARD 2 DAILY COST $2575 REPORT BY LEES F. BROWNE JR.. file://C:\DOCUMENTS%20AND%20SETTINGS\RIGUSER\MY%20DOCUMENTS\MY.., 8/12/2007
