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Box 100360,Anchorage,AK 99510-0360 April 5,2011 50-029-23443-0000 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1858'FSL,2475'FWL,Sec.34,T12N,R11 E,UM April 16,2011 Ignik Sikumi#1 Top of Productive Horizon: 8. KB(ft above MSL): 30.7'RKB 15.Field/Pool(s): 1850'FSL,2480'FWL,Sec.34,T12N, R11 E,UM GL(ft above MSL): 52.9'AMSL Prudhoe Bay Field Total Depth: 9.Plug Back Depth(MD+TVD): 1848'FSL,2478'FWL,Sec.34,T12N, R11 E,UM surface 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-584119 y- 5977590 Zone-4 2597'MD/2597'TVD ADL 28239 TPI: x-584123 y- 5977582 Zone-4 11.SSSV Depth(MD/TVD): 17.Land Use Permit: Total Depth: x-584121 y- 5977579 Zone-4 nipple©1927'MD/1927'TVD na 18.Directional Survey: Yes ❑ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1760'MD/1760'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD none not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# B-35 31' 108' 31' 108' 24" 185 sx ArcticSet 1 10.75" 45.5# L-80 31' 1473' 31' 1473' 13.5" 299 bbls ArcticLite Crete,128 bbls DeepCrete 7.625"x 29.7# L-80 29' 1964' 29' 1964' 9.875" 153 bbls LiteCrete I 4.5" 12.6# L-80 1964' 2592' 1964' 2592' 9.875" included above`cement to surface 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5" 1986' none 2243'-2273'MD 2243'-2273'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ll +.w a DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 RECEIVED MAYS 2012, 27. PRODUCTION TEST AOGCC Date First Production Method of Operation(Flowing,gas lift,etc.) na plugged and abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RSDMS MAY 22 201Z,., "(,)r Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 7e y•3o ,Z q/($4._ 6 + v 28. GEOLOGIC MARKERS(List all formations and n s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑� No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1760' 1760' needed,and submit detailed test information per 20 AAC 25.071. Sagavanirktok Upper C 2214' 2214' Sagavanirktok Upper C 2240' 2240' Sagavanirktok Lower C 2278' 2278' N/A Formation at total depth: Upper/Lower C 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,photos of abandonment 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Kralick @ 265-6870 Printed Name, 6t._11vord Title: Alaska Drilling Manager Signature Phone 265-6120 Date S(24(26 f 2_ 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 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. • Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 PBU IGNIK SIKUMI 1 ConocoPhillips O$ Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm MB) may« '` 500292344300 PRUDHOE BAY UNIT EXPLOR 0.53 2,457.02 2,597.0 """ Comment H2S(ppm) Date Annotation End Date KB-Grd(RI Rig Release Date "Well ConIg:VERTICAL-IGNIK SIKUMI 1.51 A20121'.27'.17 PM �SSSV:NIPPLE Last WO: 34.60 4/28/2011 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 2,350.0 4/30/2011 Rev Reason:WELL REVIEW osborl 5/11/2012 Casing Strings _ __ Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd HANGER,ze- CONDUCTOR 16 15.062 32.0 108.0 108.0 62.50 H-40 WELDED_- .. ___ . VI Caning Description String 0... String ID...Top(RKB) Set Depth(L..Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 103/4 9.950 30.9 1,473.1 1,473.1 45.50 1 L-80 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt,..String...String Top Thrd _ __-__ _ _ _-__-_PRODUCTION 75/8 6.875 28.7 2,592.3 2,592.3 29.70 L-80 BTCM 7 7.625x4.5 Tubing Strings - Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 41/2 3.958 26.5 1,985.9 1,985.9 12.60 L-80 IBT-M _ TUBING PUP, Completion Details 29 Top Depth - -- (TVD) Top Incl Noel... Top(RKB) (RKB) (°) Item Description Comment ID(in) CONDUCTOR, -- 26.5 26.5 0.00 HANGER FMC TUBING HANGER 4.500 32-10e 1,927.1 1,927.1 0.15 NIPPLE CAMCO DB NIPPLE w/3.875"PROFILE 3.910 1,942.1- 1,942.0 0.18 NIPPLE CAMCO DB NIPPLE w/3.843"PROFILE 3.812 1,956.7 1,956.6 0.20 NIPPLE CAMCO DB NIPPLE w/3.750"PROFILE 3.750 1,967.9, 1,967.8 0.22 LOCATOR LOCATOR 3.880 II 1,968.9' 1,968.9 0.22 SEAL ASSY SEAL ASSEMBLY 3.890 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE, Top Depth 31-1,473 (TVD) Top Incl Top(RKB) (RKB) (°) Description Comment Run Date ID tl2)._ 1,942.1 1,942.1 0.18 PUMP 3"JET PUMP(S/N:PH-1108,6C RATIO)w/SPACER PIPE 3/22/2012 &STINGER ASSEMBLY,OAL=200" 1,956.7 1,956.7 0.20 VALVE WEATHERFORD STANDING VALVE/POLISH BORE 3/22/2012 NIPPLE.1.927 ,1 ASSEMBLY CHEMICAL. lii4 2,224.0 2,224.0 0.44 SCREEN 3.687"DB LOCK SPACER PIPE SANDSCREENS AND 2/16/2012 1,929 SEAL ASSEMBLY Perforations&Slots - NIPPLE.1,942 Shot PUMP,1,942" Top(ND) Btm(TVD) Dens Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date (ah.- Type Comment GAS LIFT, 2,243.0 2,273.0 2,243.0 2,273.0 2/15/2012Omega 2.0 IPERF 2.88"PJ gun,0/180 phased, 1,944 - shots orientated 90 deg from blast VALVE,1,957 protectors NIPPLE,1,957 e=' I LOCATOR. 1,968 SEAL ASSY, 1,959 r e,/ cs 11, t II SCREEN,2,224\ IPERF, 2,243-2.273• • f '1 Mandrel Details= Top Depth Top Port ®� (TVD) Incl OD Valve Latch Size TRO Run Stn Top(RKB) (KKB) (°) Make Model (in) Sery Type Type lin) (psi) Run Date Corn... 1 1,928.7 1,928.6 0.15 CAMCO KBMG-LTS 1 CHEM DMY BK 0.000 0.0 4/25/2011 2 1,943.6 1,943.6 0.18 CAMCO KBMG 1 GAS LIFT DMY BK 0.000' 0.0 4/30/2011 • PRODUCTION • • 7.825x15, 29-2,592 , A Ilk. TD.2.597 I � Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 09:00 3.00 SURPRI FLOWT PRDT P Well head 250-260 psi. Flow rates: declining from 35-25 MSCFD gas. Water consumed 1.7 bbl. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge #2, increasing 460-477 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. 09:00 12:00 3.00 SURPRI FLOWT PRDT P Well head 175-250 psi. Flow rates: 35-25 MSCFD gas. Water consumed 2.5 bbls. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2, increasing 450-525 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. Trace solids after tank swap at the High Pressure Pump(HPP)inlet. Incident at 09:30 while swapping power fluid supply/return tanks the suction line to the HPP was frozen and jet pumping was temporarily down. Crews swapped back to the original configuration,diagnosed and rectified the issue. 12:00 15:00 3.00 SURPRI FLOWT PRDT P Well head 250 psi. Flow rates:-25 MSCFD gas. Water produced 3 bbls. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2,502-511 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. trace solids at the HPP suction. 15:00 18:00 3.00 SURPRI FLOWT PRDT P Well head 250-225 psi. Flow rates: 20-25 MSCFD gas. Water produced 0 bbls. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2,510-485 psi. Jet pumping at 11-12 gpm and 1000-1050 psi at the IA. trace solids at the HPP suction. 18:00 21:00 3.00 SURPRI FLOWT PRDT P Well head 225-200 psi. Flow rates: 27-20 MSCFD gas. Water produced 0. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2,485-475 psi. Jet pumping at 11-12 gpm and 1010-1000 psi at the IA. trace solids at the HPP suction. 21:00 00:00 3.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1000 psi at the IA. Slowly working BHP down. 03/25/2012 Normal jet pump operations gas flow trending down from 11 to 7.5 MSCFD. Jet pump rate increased to 13 gpm.Gas rates increased then trended lower—14-13 MSCFD Total gas produced from midnight to 20:00 9.3 MSCF. Water production 8.3 bbls as of 20:00. BHP @ XPIO 2 420 psi. Solids production zero. Page 49 of 64 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 03:00 3.00 SURPRI FLOWT PRDT P Well head 175-160 psi. Flow rates: —11-8 MSCFD gas. BS&W 0.0%. Managing flow by target pressure of 490 psi on XPIO gauge#2,average 500 psi. Jet pumping at 11-12 gpm and 1070 psi at the IA. Trace solids at the High Pressure Pump(HPP) inlet. 03:00 06:00 3.00 SURPRI FLOW' PRDT P Well head 160-150 psi. Flow rates: —8-7.5 MSCFD gas. BS&W 0.0%. Managing flow by target pressure of 490 psi on XPIO gauge#2,average 500 psi. Jet pumping at 11-12 gpm and 1070 psi at the IA. Trace solids at the High Pressure Pump(HPP) inlet. 06:00 09:00 3.00 SURPRI FLOWT PRDT P Well head 150-250 psi. Flow rates: —8-14 MSCFD gas. BS&W 0.0%. Managing flow by target pressure of 440 psi on XPIO gauge#2. Increased rate to drop bottom hole pressure 1300 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. 09:00 12:00 3.00 SURPRI FLOW' PRDT P Well head 250-220 psi. Flow rates: —15 MSCFD gas. BS&W 0.0%. XPIO gauge#2,average 435 psi. Jet pumping at 1300 psi at the IA. Trace solids at the High Pressure Pump(HPP)inlet. 12:00 15:00 3.00 SURPRI FLOWT PRDT P Well head 220 psi. Flow rates:—15 MSCFD gas. BS&W 0.0%. XPIO gauge#2,average 425 psi. Jet pumping at 1317. Trace solids at the High Pressure Pump(HPP)inlet. 15:00 18:00 3.00 SURPRI FLOWT PRDT P Well head 215 psi. Flow rates:—13 MSCFD gas. BS&W 0.0%. XPIO gauge#2, average 425 psi. Jet pumping at 1315 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. 18:00 00:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 1317 psi at the IA. Preassure at XPIO2 420 psi. 12 MSCF gas. 03/26/2012 Normal jet pump operations gas rates increased from—10 to 17 MSCFD on increase of jet pump rate and lowering of BHP via the choke. Water production is 5 bbls as of 21:00. BHP @ XPIO 2 equals 375 psi. Solids Droduction zero. Temp at the perforation is—35 F at the coolest. 00:00 07:30 7.50 SURPRI FLOWT PRDT P Well head 200 psi. Flow rates:— 11-10 MSCFD gas. BS&W 0.0%. XPIO gauge#2=430 psi. Jet pumping at 11-12 gpm and 1317 psi at the IA. Trace solids at the High Pressure Pump(HPP)inlet. Page 50 of 64 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:30 08:36 1.10 SURPRI P Increased jet pumping rate to 54% —13 gpm. Dropping well head with a target of no less then 34 F at the perforations. Well head—200 psi. BS&W 0.0%. XPIO gauge#2=415 psi. Trace solids at the High Pressure Pump(HPP)inlet. 08:36 12:24 3.80 SURPRI P Well head—200 psi. Flow rates: increasing from 1-18 MSCFD gas. BS&W 0.0%. XPIO gauge#2 dropped gradually to 380 psi. Jet pumping at—13 gpm and 1340 psi at the IA. Trace solids at the High Pressure Pump(HPP)inlet. 12:24 13:18 0.90 SURPRI P Issue with Gaschromatograph supply line freezing off in the Gas Mixing Skid at the regulator. Diagnosed and fixed problem. GC back on line. 13:18 20:18 7.00 SURPRI P Well head—200 psi. Flow rates: 17 MSCFD gas. BS&W 0.0%. XPIO gauge#2—376.5 psi. Jet pumping at 13 gpm and 1340 psi at the IA. Trace solids at the High Pressure Pump(HPP)inlet. 20:18 00:00 3.70 SURPRI P Jet pumping at 1340 psi at the IA. Preassure at XPIO2 375-376 psi. 17 MSCF gas. 03/27/2012 Opened choke,gas rate went from 17 mscf/d to 19 mscf/d.WHP from 193 to 190 psig. 00:00 12:53 12.89 SURPRI Well head—200 psi. Flow rates: 17-16 MSCFD gas. BS&W 0.0%. �~ XPIO gauge#2 375-374 psi. Jet pumping at 13 gpm and 1340-1336 psi at the IA. Trace solids at the High Pressure Pump(HPP)inlet. 12:53 15:38 2.75 SURPRI Lowered backpressure enough to bring WHP down from 201 to 192 psig, choke from 16.5 to 16.75, rate didn't change much from 16 mscf/d, FBHP went from 376 to 366 psia. 15:38 20:03 4.42 SURPRI Opened choke to 17.25 to drop WHP rate went from 17 mscf/d to 19 mscf/d ,WHP from 193 to 190 psig , FHBP at XPIO2 from 365 to 358 psia. Volume cumulatives Midnight: 517 mscf produced,593 BW 18:38: 530 mscf produced,610 BW From midnight to 18:40, 13 mscf and 17 bbls of water. 20:03 00:00 3.95 SURPRI GC data stopped being updated, stopped the Diablo software and restarted,first good sample completed at 21:01. Page 51 of 64 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03/28/2012 24 hr Summary Normal jet pump operations gas rates increased from 19MSCFD to 21 MSCFD lowering of BHP via the choke. Water production is 18 bbls as of 19:00. BHP @ XPIO 2 equals 342 psi. Solids production zero. Temp at the perforation is—34.4 F at the coolest.Gas 16 mscf. 00:00 04:19 4.32 SURPRI FLOWT PRDT P Spike in water production associated with stoppage in gas flow lasted about 14 minutes. No obvious cause,gas rates rose and accumulated gas rate over the hour appeared normal,but the water volume rose by 4 bbls between tank straps. 04:19 07:25 3.10 SURPRI FLOWT PRDT P Opened choke from 17.25 to 17.75, BHP at XPIO2 dropped from 359 to 352 psia,gas rate rose from 19 mscf/d to 20 mscf/d,then over the next couple of hours fell back to 19. Coldest point on DTS trace-34.4°F. 07:25 10:28 3.05 SURPRI FLOWT PRDT P Opened choke from 17.75 to 18.25, BHP at XPIO2 dropped from 351 to 344 psia,WHP dropped from 177 to 167 psig,gas rate rose from 19 mscf/d to 20.5 mscf/d.Coldest point on DTS trace-34.3°F 10:28 00:00 13.54 SURPRI FLOWT PRDT P Opened choke from 18.25 to 18.75. BHP at XPIO2 dropped from 345 to 342 psia,WHP dropped from 170 to 163 psig,gas rate initially rose from 22.5 to 23.5 mscf/d but then fell back to 21 mscf/d.Coldest point on DTS trace-34.4°F. 03/29/2012 Continued jet pumping operation and monitor data. 00:00 02:28 2.47 SURPRI FLOWT PRDT P Opened choke from 18.75 to 19.25, BHP at XPIO2 dropped from 343 to 338 psia,WHP dropped from 164 to 156 psig,gas rate went from 22 mscf/d to 23.5 mscf/d for about 25 minute and then declined back to 22. Coldest point on DTS trace- 34.2°F. 02:28 03:29 1.02 SURPRI FLOWT PRDT P Swapped from one HPP to the other. Temporary dip in BHP pressures of about 35 psi, resulted in a gas surge about 45 minutes later before everything returned to normal. 03:29 00:00 20.52 SURPRI FLOWT PRDT P Interval at top of perfs dropped below 34°F,during gas surge to 25 mscf/d. Midnight to 20:00hrs=18,000 scf and 20 bbls wtr. 03/30/2012 Contilnue jet pumping operation and monitor data. Page 52 of 64 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT PRDT P No events of note,choke remained at 19.25 all day. BHP stayed between 319 and 325 psia all day. BHT measured at XPIO2 dropped from 35°F to 34.89°F which it has read for the last 6 hours. Most of the day 6 to 10 feet of the DTS string read less than 34°F with occasional periods above 34°F interspersed throughout. Generally rising gas rate from 22 mscf/d to 24.5 mscf/d. SURPRI Total Midnight to 8 pm. 20.6 mscf 20.8 bbls of water 03/31/2012 00:00 00:00 24.00 SURPRI FLOWT PRDT P No events of note,choke remained at 19.25 all day. BHP stayed between 317 and 322 psia all day. BHT measured at XPIO2 remained at 34.9°F all day. For the second day,6 to 10 feet of the DTS string read less than 34°F with occasional periods above 34°F interspersed throughout. Generally steady gas rate between 24 mscf/d and 25 mscf/d with three short spikes above 26 mscf/d. SURPRI Total Midnight to 8 pm. 20.5 mscf 24.1 bbls of water 04/01/2012 Normal jet pump operations.WHP remained between 153 and 165 psig, and BHP stayed between 316 and 322 psia all day. 00:00 00:00 24.00 SURPRI FLOWT PRDT P No events of note,choke remained at 19.25 all day. WHP remained between 153 and 165 psig,and BHP stayed between 316 and 322 psia all day. BHT measured at XPIO2 rose about 0.03°F during the day, remaining around 34.9°F. For the third day,6 to 10 feet of the DTS• string read less than 34°F with the periods above 34°F increasing in number throughout the day. Generally steady gas rate between 24 mscf/d and 25.5 mscf/d. SURPRI Total Midnight to 8 pm. 20.6 mscf 23 bbls of water 04/02/2012 Choke remained at 19.25 all day.Generally steady gas rate between 23.8 mscf/d and 25.4 mscf/d. Page 53 of 64 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI The number of variations in GC total measured percentage(e.g.CH4 swinging between 94 and 101%) continued to rise today,but calibrations continued to match the calibration gas. Higher inlet pressure may be the cause.This causes some error in the computed "corrected"gas rate presented in InterACT(about 2-3%). Gas mass flow rates continued to be very smooth. Choke remained at 19.25 all day. WHP remained between 151 and 164 psig,and BHP stayed between 316 and 321 psia all day. BHT measured at XPIO2 rose about 0.02°F during the day,remaining around 34.9°F. For the fourth day,6 to 10 feet of the DTS string read less than 34°F in the evening with this interval being slightly above 34 most of the time from midnight to 10 am. Generally steady gas rate between 23.8 mscf/d and 25.4 mscf/d. SURPRI Total Midnight to 8 pm. 20.3 mscf 24 bbls of water 04/03/2012 Choke remained at 19.25 all day.Generally steady gas rate between 23.6 mscf/d and 24.8 mscf/d.WHP remained between 151 and 165 psig, and BHP stayed between 316 and 320 psia all day 00:00 00:00 24.00 SURPRI FLOWT PRDT P Choke remained at 19.25 all day. Generally steady gas rate between 23.6 mscf/d and 24.8 mscf/d with larger variations between 4 am and 10 am with no obvious cause.WHP remained between 151 and 165 psig, and BHP stayed between 316 and 320 psia all day. BHT measured at XPIO2 rose about 0.02°F during the day ending at 34.94°F. For the fourth day,6 to 10 feet of the DTS string near the top of the perfs read less than 34°F, now down to about once per hour,showing the very slight overall increase in temperature. SURPRI Total Midnight to 8 pm. 20.1 mscf 22 bbls of water 04/04/2012 Opened choke from 19.25 to 19.75 beans, Raise power fluid from 55-56%of pump drive max. in effort to get temp.down to 33°. 00:00 08:33 8.55 SURPRI FLOWT PRDT P Opened choke from 19.25 to 19.75 beans, BHP at P2 dropped from 318 to 315 psia,temperature dropped 0.02°F/ 08:33 14:21 5.81 SURPRI FLOWT PRDT P Raise power fluid pump drive rate from 54 to 55%, BHP at XPIO2 dropped about 7 psi,but rate was very unstable Page 54 of 64 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 14:21 20:00 5.65 SURPRI FLOWT PRDT P Raise power fluid from 55-56%of pump drive max. BHP dropped from 316 psia before the first power fluid rate increase at 14:20 to 300 psia. Temperature dropped from 34.94 to 34.80 in the first two hours. Power fluid flow rate rose from 450 BPD to about 465 BPD,but the rate variation went from+/-5 BPD to+/-60 BPD. Power fluid pressure rose from 1301 to 1452 psig. 20:00 00:00 4.00 SURPRI FLOWT PRDT P Temperature still declining after increase in jet pump rate and choke opening. Has dropped from about 34.2 to 33.75°F(measured by DTS at coldest point in perfs)since this morning at 8 am. Gas rate rose about 3 mscfd. Total Midnight to 8 pm. 20.2 Mscf 26 bbls of water 04/05/2012 Continued lowering bottom hole pressure to bring BHT down. BHT at XPIO2 dropped 0.2°F and coldest point in perfs now below 34.5°F according to DTS. Gas rate rose from 26 mscf/d to 29 mscf/d. 00:00 04:30 4.50 SURPRI FLOWT PRDT P Raised Jet pump drive rate from 56 to 57%. BHP at XPIO2 dropped 9 psi. Power fluid rate went from 465 to 472 BPD. 04:30 16:47 12.29 SURPRI FLOWT PRDT P Raised Jet pump drive rate from 57 to 58%. BHP at XPIO2 dropped 8 psi. Power fluid rate rose from 472 to 479 BPD. 16:47 23:59 7.21 SURPRI P Continued lowering bottom hole pressure to bring BHT down. BHT at XPIO2 dropped 0.2°F and coldest point in perfs now below 34.5°F according to DTS. Gas rate rose from 26 mscf/d to 29 mscf/d. SURPRI Totals Midnight to 8 pm. 23.0 mscf 26 BW 04/06/2012 Continuing to lower the bottomhole pressure to bring BHP down. Gas rate has risen from 29 mscfd to nearly 30 mscfd. 00:00 06:06 6.10 SURPRI FLOWT PRDT P Continuing to lower the bottomhole pressure to bring BHP down. Gas rate has risen from 29 mscfd to nearly 30 mscfd. Raised Jet pump drive rate from 58 to 59%. BHP at XPIO2 dropped 4 psi. Power fluid rate rose from 478 to 486 BPD. Page 55 of 64 Time Logs, Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:06 00:00 17.90 SURPRI FLOWT,PRDT P Changed from pump number 1 to pump 2,stayed at 59%. PFP dropped from 1675 to 1650psig but the PFR only dropped from 486 to 483 BWPD. BHP at P2 rose from 285 to 287 psia. SURPRI Total production midnight to 8 pm 27 BW 25 mscf 04/07/2012 Continuing to lower the bottomhole pressure to bring BHP down.Contilnue jet pumping operation and monitor data. 00:00 00:54 0.91 SURPRI FLOWT PRDT P Raised jet pump drive rate from 59 to 60%. Power fluid rate rose from 483 to 491 BWPD. BHP started at 286 psia and Power fluid pressure at 1690 psig 00:54 02:01 1.13 SURPRI P Raised power fluid pump drive rate from 60 to 61%. Power fluid rate rose to 497 BWPD. BHP leveled off at 281 psia at a power fluid pressure of 1978 psig 02:01 09:34 7.55 SURPRI P During electrical generator swap, measured power fluid pressure dropped by about 100 psi,but returned to normal over the next 10 minutes. 09:34 23:58 14.41 SURPRI P Raised power fluid pump drive rate from 61 to 62%. Power fluid rate rose from 497 to 503 BWPD and pressure rose from 1796 to 1868 psig SURPRI P Produced from midnight to 8 pm 25.9 mscf 29 BW Gas chromatograph software performance in selecting Nitrogen separately from Methane improved today,so volumetric estimates were better than previous days. 04/08/2012 Continue jet pumping operation and monitor data. Remained at approximately 504 barrels of power fluid all day. The bottomhole pressure remained near 277 psia and the coolest interval measured by the DTS remained at approximately 34.5°F. 00:00 00:00 24.00 SURPRI FLOWT PRDT P Remained at approximately 504 barrels of power fluid all day. The bottomhole pressure remained near 277 psia and the coolest interval measured by the DTS remained at approximately 34.5°F. SURPRI Midnight to 8 pm production volumes. 26605 scf 27 BW 04/09/2012 Opened choke to wide open, lowered back pressure on separator to 25 psig. Gas flow peaked at 140 mscf/d and dropped back to 40 mscf/d. DTS records temperature at 2446 to be below 33°F. XPIO ROC 2 temperature reading has dropped from 34.5 to 34.2°F. 00:00 06:30 6.50 SURPRI FLOWT PRDT P Objective,go for lowest possible pressure Page 56 of 64 Time Logs Date From To Dur S.Depth E.Deoth Phase Code Subcode T Comment 06:30 08:40 2.18 SURPRI FLOWT PRDT P EXPRO collected triplicate water samples from upstream of choke, water leg of separator and power fluid charge pump of GMS. Atmospheric air samples collected at each location. 08:40 09:59 1.33 SURPRI FLOWT PRDT P Delivered sand and ISOTUBE samples to Kuparuk shipping and receiving for distribution. 09:59 12:50 2.86 SURPRI FLOWT PRDT P Opened choke to wide open, lowered back pressure on separator to 25 psig. Gas flow peaked at 140 mscf/d and dropped back to 40 mscf/d. 12:50 16:08 3.30 SURPRI FLOWT PRDT P DTS records temperature at 2446 to be below 33°F. XPIO ROC 2 temperature reading has dropped from 34.5 to 34.2°F. 16:08 19:58 3.84 SURPRI FLOWT PRDT P temperature decrease has levelled off at about 34.1°F on XPIO ROC 2. BHP has dropped from 277 psia prior to choke opening(at 1250 hrs)to 237 psia. Wellhead pressure has dropped from 184 psig to 27 psig. Gas rate has risen from 32 to 39 mscf/d. 19:58 23:58 4.00 SURPRI FLOWT PRDT P Midnight to 8 pm production volumes. 29.5 mscf 35 BW 04/10/2012 Produced steadily at 40 MSCFD. Initiated removal of insulation on surface lines and stick build scaffold hooches in preparation for rig down and demob of well test equipment. 00:00 01:00 1.00 SURPRI FLOWT PRDT P Raising outlet gas pressure enough to take ISOTUBE sample caused well flow rate to read zero,then spike as pressure dropped.This is not a formation/tubing change. 01:00 07:45 6.75 SURPRI FLOWT PRDT P Produced at 40 MSCFD with the well head pressure at-31 psi while jet pumping at-1875 psi. 07:45 08:30 0.75 SURPRI FLOWT PRDT P Raising outlet gas pressure enough to take ISOTUBE sample caused well flow rate to read zero,then spike as pressure dropped.This is not a formation/tubing change. 08:30 13:30 5.00 SURPRI FLOWT PRDT P Produced at 40 MSCFD with the well head pressure at-31 psi while jet pumping at-1875 psi. 13:30 19:12 5.70 SURPRI FLOWT PRDT P Started removing blue board insulation from surface lines. Continued to produce at 40 MSCFD with the well head pressure at-31 psi while jet pumping at-1875 psi. Page 57 of 64 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 19:12 19:42 0.50 SURPRI FLOWT PRDT P Changed from using EXPRO heater as the surface storage volume for glycol circulation to the 125 bbl open top in order to heat glycol in open top in preparation for shutdown. Temperature in circulation pumps dropped to 6F,then rose back to 65°F in the first half hour. Scaffold crew on location. Walk down stick built hooches,fuel tank stairs, and well house. Discuss planned work and initiate removal of tank farm hooch, Expro Atigun house hooch and CO2 tank railing. 19:42 00:00 4.30 SURPRI FLOWT PRDT P Truck off 290 bbls of returns to 1R-18 for disposal. Continued to produce at 40 MSCFD with the well head pressure at—31 psi while jet pumping at—1875 psi. BS&W has been zero for the past 24 hrs. Midnight to 8 pm production volumes. 33 mscf and 29 BW 04/11/2012 Freeze protect IA,tubing,chemical injection line,and heater string from jet pump to surface. Blow down surface lines and equipment. Dispose of returns and initiate rig down procedure. 00:00 04:00 4.00 SURPRI FLOWT PRDT P Swap from pumping produced water "power fluid" down the IA to 60/40 Tritherm glycol to freeze protect well. Displace IA to glycol taking returns up the tubing through the Expro stack pack separator. Drawing glycol from Expro serarator bath, 125 glycol tank,and SLB line heater. 04:00 06:00 2.00 SURPRI FLOWT PRDT P Glycol at the jet pump. Increase v choke setting to hold 700 psi back pressure in effort to stall jet pump and bull head glycol into tubing/ perforations. No indication on DTS temperature trace that any glycol went below the jet pump. Attempt to pump glycol down the chemical injection line. Pressure up to 2200 psi instantly. Bleed line to 70 bbl sand jet tank. Pump 80 gal glycol down the heater string. Page 58 of 64 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 06:00 07:30 1.50 SURPRI FLOWf PRDT P Reduce choke setting to circulate glycol up the tubing while keeping the jet pump stalled and well killed. Bleed off chemical injection line to 70 bbl sand jet tank while pumping glycol into the IA at 1100 psi. Returns from CI line at 30 gallons away are clear and appear to be water sample caught 07:45. Returns from the CI line at 40 gallons away down the IA appear to be 60/40 glycol. Sample pulled at 07:47. 18 bbls glycol left in the 125 bbl tank. 07:30 08:18 0.80 SURPRI FLOWf PRDT P Lost HPP#2,switch to#1 resume displacing well to glycol at 10 gpm and 1143 psi on the IA taking returns to the Expro separator. Start to cool down N2 pump. 08:18 08:54 0.60 SURPRI FLOWf PRDT P Lost prime on pump while drawing down SLB line heater bath. Out of surface glycol. Shut in well. Line up to start blowing down surface lines with N2. 08:54 11:00 2.10 SURPRI FLOWf PRDT P Blow down Expro lines,separator, and hoses to tanks. Blow down surface HPP lines. Down on N2. All valves on well head shut and flagged. Begin RD 11:00 20:00 9.00 DEMOB PLUG DMOB P Start to rig down all Expro/SLB treating lines. Remove spill containment under all treating lines. Disconnect Gas chromatograph lines. Haul off all remaining returned surface fluid for disposal at 1R-18. Stage portable heaters on pad for release. Scaffolding crew removed large tank farm hooch. Palletize SLB treating iron for storage in connex. Rig down all SLB treating lines from well head. 20:00 00:00 4.00 DEMOB PLUG DMOB P Continue to rig down all test equipment. 04/12/2012 Rigged down and inventoried all SLB treating lines and stored in connex. Rigged down and staged all Expro treating lines for shipment. Turned off well site power and removed all power leads. Staged and released non mobile equipment, heaters/light plants/compressors. 00:00 06:00 6.00 DEMOB PLUG DMOB P Cut all long hoses to—25'lengths and stack on pallets. Stage all SLB iron and hoses in front of storage connex. Rig down propane tank and prep for transport to Brooks Range. 06:00 09:00 3.00 DEMOB PLUG DMOB P load SLB connex with treating lines. Truck propane tank to Brooks Range. Page 59 of 64 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:00 12:00 3.00 DEMOB PLUG DMOB P Drain and remove SSV pannels. return to CPF1. Staged all non mobile equipment for removal. Hand -y-berm removed all revetment supports. Shut off well site power unit. Cut all power leads to well site equipment. 12:00 15:00 3.00 DEMOB PLUG DMOB P Rig down Expro treating Iron and stage for loading to back haul. Trucked off 4 heaters,2 air compressors, one light plant. Spooled up well site electrical lines. 15:00 18:00 3.00 DEMOB PLUG DMOB P Banded up lumber,insulation blue board,and returned to DTH. DTH removed Atigun house scaffolding. 18:00 00:00 6.00 DEMOB PLUG DMOB P Continue to rig down all test equipment. 04/13/2012 Removed all Expro treating lines and ancillary equipment from location. Notified AOGCC of pending P&A. Crane on hold until tomorrow due to rig 27 broken down in road. 00:00 06:00 6.00 DEMOB PLUG DMOB P Drilling tool house crew removed the scaffolding in front of the Expro Atigun house and picked up all exposed revetment plus plywood. Rig 27 stuck at the kuparuk river west bridge blocking all dead horse traffic. 06:00 12:00 6.00 DEMOB PLUG DMOB P Removed Cormorant WMD and choke skid from Atigun house. 12:00 18:00 6.00 DEMOB PLUG DMOB P Rig moving and trailers allowed past however BP security unwilling to provide escort for 200 crane travel from dead horse to location. Rebook crane for tomorrow. Load all expro treating equipment on trailers. Notified AOGCC State inspectors of pending P&A activities(John Crisp) 18:00 00:00 6.00 DEMOB PLUG DMOB P Lynden spotted 4 trailers on site for tomorrow picks. CH2 slowly removing released heaters from pad. 04/14/2012 Removed all major well test equipment from pad less well site generators. Built temporary well head scaffold for slickline and coiled tubing intervention. 00:00 06:00 6.00 DEMOB PLUG DMOB P sleep! 06:00 08:00 2.00 DEMOB PLUG DMOB P Pre job to discuss lift plan. wait on crine and twin steer 08:00 08:45 0.75 DEMOB PLUG DMOB P Crane and twin steer on location. Hold pre job and start spotting for fist pick. 08:45 09:45 1.00 DEMOB PLUG DMOB P Rig up to well house. Cut DTS fiber optic lines 08:56. Remove well house. HES packed up DTS computers and hauled off. Page 60 of 64 • Time Logs Date From To Dur S. Depth E.Deoth Phase Code Subcode T Comment 09:45 10:45 I 1.00 DEMOB PLUG DMOB P Moved Atigun house with twin steer. Spotted same on trailer and trucked to peak yard for storage until the haul road weight restrictions are lifted. Lay down sand trap with crane. Loaded trap and trucked off. DTH removing 500 bbl tiger tanks and returning to Tanko yard. 10:45 11:15 0.50 DEMOB PLUG DMOB P Rig CO2 tank. Pick and set on trailer for back haul to SLB deadhorse. 11:15 12:15 1.00 DEMOB PLUG DMOB P Pick N2 tanks and spot on trailers for back haul. COlville fuel tanker and pump truck on location to drain and haul off excess fuel from well site tanks. Credit received for 4964 gal ULSD. 12:15 13:15 1.00 DEMOB PLUG DMOB P Pick Schlumberger Gas mixing skid and spot on truck for back haul. Pick Expro Stairs and lay down for demob. 13:15 14:15 1.00 DEMOB PLUG DMOB P Lay down flare stack. Haul two 400 BBL uprights tanks to wash bay for cleaning. Load SLB work connex and storage connexes on trailers for transport to Deadhorse. 14:15 15:00 0.75 DEMOB PLUG DMOB P Pick SLB line heater and spot on trailer for back haul. SLB crews left location. 15:00 18:00 3.00 DEMOB PLUG DMOB P DTH removed well platform and SSV wing valves. 18:00 00:00 6.00 DEMOB PLUG DMOB P DTH night crew cleaning up plywood and herculite from site. Hauling off all remaining equipment. Scaffold crew on location 20:47 to demo fuel tank stairs and build well platform. Updated BP planners with demob P&A schedule. 04/15/2012 Attempted to fish jet pump. Beat up for a total of two hrs and 30 minutes. Removed AZTAC and CPAI comms from camp. Staged well site generators for back haul. Return in the morning to try to retrieve jet pump assy. 00:00 06:00 6.00 DEMOB PLUG DMOB P no night operations Page 61 of 64 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:00 12:00 6.00 DEMOB PLUG DMOB P SLick line unit arrived on location 07:00. Found departing crews had removed bleed fittings from sand jet tank. called out wells goup to instal new bleed port. Rig up SLU w/0.125 wire, 8'x 2.625"Stem, KJ, LSS. RIH w/QC,2'x 1.875"STEM,2.85" GAUGE RING,TAG @ 1919'SLM, POOH,set down in station#1, bobble past, POOH. Added 5'x 2.625"stem, RIH w/4 1/2 PRS,(brass pin),to 1920'SLM,beat up for 50 min, sheer off POOH.;tool sheared. AZTAC and CPAI communications crews removing all comm systems from location. 12:00 18:00 6.00 DEMOB PLUG DMOB P Cut 200'wire, had to rebuild PRS to repin and clean. RIH w/QC,4 1/2 PRS TO 1920'SLM, latch, beat up for 50 min. Shear off, POOH cut 100' wire. RIH w/same. Beat for 46 min, POOH SIBD,cut wire. Picked up catcher RIH. Slips catching repeatedly setting down 800'. POOH RD for night. Return with rebuilt PRS (new collets)and catcher W/out slips. DTH assisting Peak Precision power to remove louvers from well site generators and stage same for back haul. 18:00 00:00 6.00 DEMOB PLUG DMOB P ASRC Drilling Tool House Loader operating on pad suffered a hydraulic hose failure. Security called. PIR mailed. CPAI Wells SUPT notified. 04/16/2012 Pulled dummy valve A 1928'RKB,pulled jet pump,S/N: PH-1108 ration 6C(OAL 200")from 1942'RKB, pulled Weatherford seal assembly and gutted CAT SV from 1956'RKB. 00:00 06:00 6.00 DEMOB PLUG FISH P no night operations 06:00 12:00 6.00 DEMOB PLUG FISH P SL crew traveled to location, inspected equipment,performed pre-job safety meeting. RU SLU, .125 wire,TS=8'x 2.625"stem, KJ, LSS. RIH w/4 1/2"GS(3/16"Brass) 4 1/2 bait sub as catcher sub 12"OAL)set on 3.812 DB-6 lock @ 1918'SLM/1942'RKB. RIH w/4 1/2 OM-K, 1.25"JD to STA#1 @ locate @ 1908'SLM, latch @ 1910' SLM/1928'RKB,pulled, POOH, OOH w/1"DV on BK latch. RIH w/4 1/2 GS, latch 4 1/2 bait sub @ 1942' RKB, POOH,OOH bait sub empty.... Page 62 of 64 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12:00 18:00 6.00 DEMOB'PLUG FISH P RIH w/4 1/2 PRS to 1919'SLM, latch, beat up 1900#s for 1 hour, hit down 3 times,sheared, POOH,OOH w/sheared PRS,cut 200'wire. RIH w/4 1/2 PRS to 3.812 DB lock&3" RC jet pump (s/N: PH-1108 ratio 6C (OAL 200"), latch @ 1919'SLM,beat up for 1 hour,came free,pulled POOH slow,OOH,carbolite in lowest stinger. Brass marks around top of DB-6 lock mandrel. RIH w/4 1/2 PRS latch to 1934'SLM,/1956' RKB, pulled 3.75"DB-6 lock mandrel w/weatherford seal bore assembly and gutted CAT SV. RDMO. 18:00 00:00 6.00 DEMOB PLUG FISH P DTH load up last remaining Delta Leasing heater and hauled to Kuparuk. Cleaned up oil from loader spill on 4-15-12, loaded into transport tank and trucked to Kuparuk for disposal. Dropped off envirovac for camp demob. Break down deluge system. 04/17/2012 Disconnected XPIO data acquisition box from well. 00:00 00:00 24.00 DEMOB PLUG OTHR P Disconnected the XPIO data collection box from the well. Camp continues to rig down for move. 05/01/2012 Perform Full-Bore Cement Job 15:30 16:00 0.50 DEMOB PLUG CMNT P MIRU Cement Pump unit and cement tankers 00:30 00:45 0.25 DEMOB PLUG CMNT P Pre-Job Safety Meeting 00:45 01:15 0.50 DEMOB PLUG CMNT P Pressure Test hardline. 01:15 01:30 0.25 DEMOB PLUG CMNT P Line up well to pump down tubing and take returns up the IA. Pump approx.7 bbls of Freshwater down the tubing to establish flow. Commence batching cement to job specs. 01:30 02:15 0.75 DEMOB PLUG CMNT P Pump 81 bbls of cement down the. tubing and take returns uo thea - until at surface. 02:15 02:30 0.25 DEMOB PLUG CMNT P Close IA and line tree up to take returns up the flat pack until cement is at surface. 02:30 02:45 0.25 DEMOB PLUG CMNT P Close valve to flat pack and line up tree to take cement up the chemical injection line to surface. 02:45 03:15 0.50 DEMOB PLUG CMNT P Shut in well and flush surface lines with 35 bbls of fresh water. 03:15 04:15 1.00 DEMOB PLUG CMNT P RDMO.Secure Location. 05/03/2012 Begin Plug&Abandon Procedures. Excavate around cellar box and remove; begin excavation to get a minimum of 5 below tundra level. Page 63 of 64 • Time Logs Date< From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 DEMOB PLUG SFTY P Pre-Tower Meeting; PJSM. 01:00 04:00 3.00 DEMOB PLUG MOB P Transport equipment to location and stage. 04:00 05:00 1.00 DEMOB PLUG OTHR P Obtain Hot Work and Unit Work Permits. 05:00 07:00 2.00 DEMOB PLUG OTHR P Begin to excavate around the cellar box to facilitate cutting and removal. 07:00 11:00 4.00 DEMOB PLUG OTHR P After cellar box is removed,begin excavating around the wellhead to a depth of 5"below tundar level.Cut in a walking ramp to ease egress. 11:00 12:00 1.00 DEMOB PLUG SISW P Set barricades and secure location for the night. 05/04/2012 Continue with Plug&Abandon Procedures.Cut off and remove wellhead, Have AOGCC Inspector sign off, weld on cap and backfill with spolis. 06:00 07:00 1.00 DEMOB PLUG SFTY P Pre-Tour Meeting and PJSM. 01:00 02:30 1.50 DEMOB PLUG OTHR X Travel to location and clean up road entrance due to blowing snow. Free stuck vehicle in roadway. 02:30 03:00 0.50 DEMOB PLUG OTHR P Obtain How Work and Unit Work Permits. 03:00 03:30 0.50 DEMOB PLUG SFTY P Hold PJSM with welder and excavator operator. 03:30 07:00 3.50 DEMOB PLUG RTWH P Begin window cutting procedures. Drill and cut windows in casings and tubing.Varify no gas or fluids and good cement to surface. 07:00 07:30 0.50 DEMOB PLUG RTWH P Cut conductor until free and set off to the side. 07:30 08:00 0.50 DEMOB PLUG OTHR P Verify good cement and obtain pictures with AOGCC!inspector, John Crisp. Receive confirmation and weld cap to 16"conductor. 08:00 08:30 0.50 DEMOB PLUG RURD P Release and rig down GBR Welder and close out Hot Work Permit. 08:30 10:30 2.00 DEMOB PLUG OTHR P Backfill hole with existing spoils and observed that more fill was needed. 10:30 15:00 4.50 DEMOB PLUG OTHR X Haul 3 loads(25 yds.each)of gravel and 2 loads(25 yds each)of overburden to location. Backfill to 4' above ice level to allow for settling. Total of 150 yards of extra backfill hauled and used on location. 15:00 16:00 1.00 DEMOB PLUG RURD P Release equipment and secure location with barricades. Page 64 of 64 71-2 liC 4) 5.49%16? , '...,:•:,ej.M.:1 , i !ira, .74 ..5 ill ,,.'''''.'. '1?;::.„,,,....,,:,..s....,s,.•••;,•,;' '' '''''',C: '',,,iiset."4C-ft ,i!j.,,,i,',.• c,.:,,z: : ti. it ,-.,. A'' •..... .• '',.:,,t,i,.••,:-..---• -,- :,,„,,,,..f•,,;• -' • •,. .-•:',..,...;;,,,.,,,,-•....,•::Aim, -....t, a, 4.- IX Cl.= .. .l' r p '' !. '',c, '•‘,'„,: ,,..— ,,,,° ' -le Z = In 0 0 .0 : . 11 ...... Q. MI 0 i +,. NifilLIW1/44it R k v . 6, m 0 ,.. , cif} i... (01 "E ,s... .- . ,4-e, , , I •-i a o 41111iisPi t C C 0.,t .7. - 1 7 7it . , v 4a: f: , . . . . ,, ,....... ,. :a:,a ;.,.., ::. tk , . ' .. .1," . , " ',III '' ' II (......„ ,., 41,111. lit i t . . ........—. , . I *s , i L 1.0 .- . , c-_---, , N, '•.'4 _ • , i . . , , . , It L',., ; u--.'., 1-riw..., .,,, : ,. -, ,,‘-.1 b 1010\krrA (:"\ii ,1/4.. _. war''. 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''',1-,.:'.,._';',..,t.`". - .. • . -7,-71-,..',,,. -,.,-.,',-...r,..',... ,,';',.,.,',....'„J'.... • Fe... -,-,t1:1, ..,i'li.-Z,. .1.t4''"..:.•.',..? • •t 4 ,4fila.• ,, ' -.11111101E:L...r • , , • ., ,•''' '...;:',:„..,-- ici'!",,,',t,:§lik. ,T','Z, 'r411001*,' ,. 1• . • ' ,,- `4, 11 .....„'"'S 4 4 41 •V:W44' '' . ' i• -/ - +..--% •:.,` i , * ' ' ", 444 , ','.•''''''"•••'RL 1.6 70' 0/'. -41', I. ,... - .• 11114 i t ' 0t' - 44,r_ , ilk‘"ti, 1„0 .• / ,: , 4 • I,t = wili _ *S . ' '• .,4'. '1 • • .--"' ' 15 Pi . . i , • I C .. ...„, A..„,„ ' - ,'. o „:.15. .t..• 0 0.. 101/4/° CC: ,,, ,t. 4, 166..V ,..• 0 Iv'. 1* . .• a .. ... _,, . • • 4 ' ' 4 , .4 la . •9 *1', %! , ' , , .„,,,,itiet. $.,,! -- , f,. i , , „..k 4 1 r. , ,1-1?,''•' , '- 4.;.** ' , . 4 ,. .„, ...., . ,, , .., 441-$ ' il''Llitt, :: :,..°"':frIt,..*rl ,*;44. 1„, l' 411% ( i "" • '* , 4.a PIa . I i g 4., , • ' a .a'' i a' 4 ,, I,' ..r '414t,1 %- , ..: i j 4 M i , Li of 7 C Y a AA - AO Y Q 3 I d Q . t Coe I , L OQ :i. 00. C '. u LI a a C p dr ZII. CA LI X t d 6 1 , U a a C # ,au o 5 a a a oa v.*,, a •, u v u a r. °c ac 0 61 CIIII IC yr u • f i1 ' IF:"---'''''' .•', '-"... ". . m• ..„...,.., �. x u. .a -1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1'E1`F 5IZ:311-zV DATE: May 04, 2012 P. I. Supervisor FROM: John Crisp, SUBJECT: P&A Report Petroleum Inspector PBU Ignik Sikumi #1 ConocoPhillips Alaska PTD 2110270 May 04, 2012: I traveled to ConocoPhillips Ignik Sikumi #1 to witness final plug & abandonment work (Sundry 312-131). Casing strings were cut off approximately 5' below tundra level as found with Inspector witnessing transition from Ice Pad to Tundra. Hard cement to surface in all casing strings. Marker plate welded to outermost casing string. Summary: I witnessed successful final Plug & Abandonment on Conoco Phillips Alaska Ignik Sikumi #1 that meets regulation 20 AAC 25.120 (a) (b) & 20 AAC 25.170 (a) (1) Attachments: 6 Photos Non-Confidential Final P&A PBU Ignik Sikumi-1 jc 5-4-12 Page 1 of 4 Surface Abandonment— PBU Ignik Sikumi #1 (CPAI) PTD 2110270 Photos by AOGCC Inspector J. Crisp May 4, 2012 4109 oi- ' r}.... * 4,100 Wellhead tiw ,•fig � •w ytfix. Casing cut • t a a Y-s Final P&A PBU Ignik Sikumi-1 jc 5-4-12 Page 2 of 4 tt ti• � i' •.... ; *to.X14.._ . t ■ r • y ? + 1 '''' . ';''to' . ,.4...A;A:\ Cementing ,i'''' 4 '9! ' pii-•*,"lir, ' 4.. 'ii. . 'V •'.•0 '• . r '` , • V t,' • `' ■ • Wit` 1 /1 1�{. rhe. It f. { :1.�1 r7� ,.. . ,,..)„,„it,,,,,,k,,. r1x ..Ar , , . .s. ,7 ''''''',•: . .1; % 7 ...1, i w M, Cement to r F:tr., . ^ . '��, ?'' 'VI"-k'• . s:, surface 1,,,la ' ,-...70 .`.',.-.' ' . ji,Air ,•.` �'ry. ' y y '; ` Aja. t3 ,tk .. �:;a j. Final P&A PBU Ignik Sikumi-1 jc 5-4-12 Page 3 of 4 P f, Itlir • K Marker plate "W' ' "--1-• ,:1,1V: 1., ...._ .-,r.; . • • 1. �;t ' - 11 4 a s ,s - ... 1. - • ,:,,,,.....ix,,,,,,,,, R air. la •n s ty dad ` s+a Vii! ' -� i .Y 1 46 ,.. .,�'. .r/ i4 y- , t. Installing ii ' marker plate Pr ) . . lit 'A / {F • Final P&A PBU Ignik Sikumi-1 jc 5-4-12 Page 4 of 4 Page 1 of 2 Schwartz, Guy L (DOA) From: Maunder, Tom E [Tom.E.Maunder@conocophillips.com] Sent: Wednesday, May 02, 2012 4:05 AM To: Schwartz, Guy L (DOA) Subject: Success?? Hi Guy, Not sure you can say anything, but it looks like some success was had on the hydrate project. Tom http://fuelfix.com/blog/2012/05/02/568971/ Promising tests prompt DOE project on methane trapped in ice U.S. Energy Secretary Steven Chu The Department of Energy will launch new research into technologies for unlocking methane gas trapped in ice-like crystals on Alaska's North Slope, following promising tests earlier this year. Energy Secretary Steven Chu is set to announce the planned $6.5 million research project Wednesday in Washington, ahead of a presentation by Deputy Assistant Secretary Christopher Smith at the Offshore Technology Conference in Houston. The move follows tests by ConocoPhillips,the Energy Department and Japan Oil, Gas and Metals National Corp., on a method for extracting gas from methane hydrates found in the Arctic and along the Gulf Coast. Chu hailed the research as a potential breakthrough that"could potentially yield significant new supplies of natural gas."He likened it to federally funded research in shale gas during the 1970s and 1980s that paved the way for today's natural gas boom. The new research focuses on unlocking the potential of methane hydrates, ice-like solids with gas molecules trapped inside. Typically found in high-pressure, low-temperature environments, including the depths below Alaska's thick permafrost, they hold tremendous promise as an energy source if researchers can figure out how to extract the gas economically. ConocoPhillips' tests earlier this year—of a technique called molecular replacement—involved injecting carbon dioxide and nitrogen into a reservoir and swapping it for methane molecules in the solid-water hydrate lattice that stores the natural gas. The Energy Department says the process yielded a steady flow of natural gas. The technique has potential not only as an energy extraction method, but also as a way to store carbon dioxide, a greenhouse gas linked to climate change, inside the methane hydrates' lattice- like structure. The Energy Department said ongoing analysis of the initial tests will focus on assessing the efficiency of simultaneously storing carbon dioxide in the reservoir. The Energy Department anticipates the next phase of research will include assessment on the environmental impacts of methane hydrate production as well as studies of deep-water gas hydrates. The Obama administration also has asked Congress to provide another$5 million for further gas hydrates research in the U.S. and with foreign partners. Those studies could include a longer duration test of methane hydrate extraction on the North Slope. The initial tests in the Prudhoe Bay region began in January and concluded in early April. The U.S. Geological Survey has estimated that methane hydrates may contain more energy than 5/7/2012 v - Page 2 of 2 all of the world's fossil fuels combined. Energy Department researchers have been searching for ways to unlock the trapped gas in methane hydrates for more than two decades, and it has partnered with industry on other related projects. 5/7/2012 a E _ C O• N .t.,..,---), , ~ K -a N O, O 9 to ..6 ,.0 0 r o• c o. '2 2 2 2 O 4-4 • m _ _ o = 5 E o 7}Ay 4 U h o =C- > a c o o oa • a o-u W▪ a3 o N c z z : O 0 O r _ D z N Z a = _r N m `o . E O O E vi 3 0 c a 0E .11 E z c°)vv CO 0 ¢ E — 5 m ..... a c d p C c b O U Q n rU O• to _ O � -- a �R m 0 4 — m Z V 2' 0 = o °i co c Z O o Q N Q Qwcc Q V N n N M M Q (7 LL 1) B LL Z O . W O E �c i- (i) a T o e s Z ri a .. • N Y fi T J CO E O 406 o O Q. c d W E 0 n Y �41 v) Q . N — �C 7 O C < J H b V z o z m Qa g Li c b co d N a_ y N G 2▪ 10 m QI 0, a N N n 2 A N. c 0 c O F E a) gi L o W ,4 0 W C 8- -0 O o_ a> '-▪ E } W 14 X b S 2 ,,, _ N C J a' m I Y T43 I -O > > V N N > N a t Y •-o o c 0 m J 8 m m CNC Nx+ @ )a. J L C C V C a a n • d o a� . W [L C LL 0 OF z a I- - Cr o a O N M V V) 1D i- m .c • t0 l- c0 Qi - N 1 CL. t; li5 Q O ce+ o LLO I.al A � N ^r >, d 0— •p15o >,J co O o U, CI L o) o o f a 0 ,- —z °o. 03< x ,o c ta ro c _ 0 N Q d ++ A N N V a 0 Q C V E U `O L N. O z (0 vs a a. aN C Q U Q U) Q 0 0 L V 0 O .n M o E g o z N a) U am NI «0 00 N Q c) I E 8 ,L (0 o - u) o- ;7L O O _0 E E o X d Z c Z I 0 �' z ° 0 z o a, a o u. it O a I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4/30/12 P. I. Supervisor FROM: Bob Noble SUBJECT: Bottom Plug Test Petroleum Inspector CPA Ignik Sikumi #1 PTD 211-027 4/30/12 I met with CPA Rep. Mark Adams and we went over the procedure they were going to us to test the bottom plug. I witnessed them set an iron bridge plug at 2209 feet with coil tubing. They set back down on it with the coil to verify the depth and that is was set. The coil was then brought to surface. There was an open orifice at 1944 feet, so the tubing and IA will track together on pressure test. The well was cold (as in the same temp. as the perma frost). They had 100 deg. seawater in the well. I feel there were some temperature stabilization issues in the test. The test went as follows: Pre T/I/0=25/20/0 Initial T/I/0=1602/1583/1 15 min T/I/0=1506/1492/1 30 min T/I/0=1452/1437/1 96 lbs loss in the first 15 min. 54 lbs loss in the second 15 min. 150 lbs loss in 30 min. I suggested that we do another test because of the temperature differences between the well and the fluid pumped. So we bumped it up and the results are as follows: Pre T/I/0=1452/1437/1 Initial T/I/0=1558/1541/1 15 min T/I/0=1505/1490/0 30 min T/I/0=1463/1449/0 53 lbs loss in the first 15 min. 42 lbs loss in the second 15 min. 95 lbs loss in 30 min. Ignik Sikumi 1 Plug test 4-30-12 bn.doc I of 3 Sheet/Calculations 01/29/10 LG MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg K,���f S ��Iv DATE: 4/30/12 P. I. Supervisor l FROM: Bob Noble SUBJECT: Bottom Plug Test Petroleum Inspector CPAI PBU Ignik Sikumi #1 PTD 211-027 4/30/12: I met with CPA representative Mark Adams and we went over the procedure they were going to us to test the bottom plug. I witnessed them set an iron bridge plug at 2209 feet with coil tubing. They set back down on it with the coil to verify the depth and that is was set. The coil was then brought to surface. There was an open orifice at 1944 feet, so the tubing and IA will track together on pressure test. The well was cold (as in the same temp. as the permafrost). They used 100 degree F seawater in the well for the test. I feel there were some temperature stabilization issues in the test. The test went as follows: Pressures Pre T/I/0=25/20/0 Initial T/I/0=1602/1583/1 15 min T/I/0=1506/1492/1 (96 psi loss in 1st 15 min) 30 min T/I/0=1452/1437/1 (54 psi loss in 2nd 15 min) Total pressure loss during 30 minute test: 150 psi I suggested that we do another test because of the temperature differences between the well and the fluid pumped. So we bumped it up and the results are as follows: Pressures (Retest) Pre T/I/0=1452/1437/1 Initial T/I/0=1558/1541/1 15 min T/I/0=1505/1490/0 (53 psi loss in 1st 15 min) 30 min T/I/0=1463/1449/0 (42 psi loss in 2nd 15min) Total pressure loss during 30 minute retest: 95 psi Summary: I witnessed a successful placement, verification (tag), and pressure test of the bottom abandonment plug in PBU Ignik Sikumi #1. Attachments: none 2012-0430_Plug PBU Ignik Sikumi I_bn Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 11, 2012 8:36 AM To: 'Kralick, Jack T' Cc: Allsup-Drake, Sharon K; Kanady, Randall B j/- 2-q- Subject: RE: revised procedure for Ignik Sikumi Jack, Very similar procedure and still meets 20 AAC 25.112 requirements ... you have verbal to proceed per your updated procedure. Make sure you document the pressure test on the bottom plug on step 11.3 (Chart/30min) I believe your sundry has been picked up by the courier already. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) • 444-3433 (cell) From: Kralick, Jack T [mailto:Jack.T.Kralick@conocophillips.com] Sent: Tuesday, April 10, 2012 2:46 PM To: Schwartz, Guy L (DOA) Cc: Allsup-Drake, Sharon K; Kanady, Randall B Subject: RE: revised procedure for Ignik Sikumi Hey Guy! We revised a procedure for Permanent Abandonment of the Ignik well. Haven't seen an approval on the original yet so please give us a verbal on this revised copy if you don't mind. Should be shutting in the well tonight and start rigging down. P/A should start as soon as most of the pad is cleared. How's the new wife and the old kids? Thanks Guy, Jack From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 10, 2012 10:59 AM To: Allsup-Drake, Sharon K Cc: Kralick, Jack T Subject: [EXTERNAL]RE: revised procedure for Ignik Sikumi • Just send me an amended procedure ... I think it is approved already. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] 4/11/2012 Page 2 of 2 Sent: Tuesday, April 10, 2012 10:16 AM To: Schwartz, Guy L(DOA) Cc: Kralick, Jack T Subject: revised procedure for Ignik Sikumi Guy— We need to revise the P&A procedure for the sundry we sent to AOGCC for well Ignik Sikumi 1. Should we send in another 10-403 sundry to cover the changes? Thank you, Sharon 263-4612 4/11/2012 _ z? ConocoPhi I I ps VP) Alaska, Inc. I 'gnikSikumi #1 CO2 Injection and Well Test t Procedure - 16 Permanent Abandonment Issue Issue Date Revision Description Prepared By Reviewed By 1 09-Jan-12 Original B.E. Smith J. Kralick 13-Jan-12 Reviewed and Vance Yoakum 21-Jan-12 Approved 2 28-Mar-12 Updated B.E. Smith J. Kralick 02-Apr-12 Reviewed and Brian O'Dell 02-Apr-12 Approved 3 4-Apr-12 Freeze Protect& Rig B.E. Smith J. Kralick 04-Apr-12 Down 4 10-Apr-12 Set BP above perfs B.E. Smith J. Kralick 10-Apr-12 Tag &PT BP K. L. Martin CT cmt&Circ cmt 10-Apr-12 Reviewed and B.E. Smith Vance Yoakum 10-Apr-12 Approved Procedure No 16_Permanent Abandonment.doc page 1 of 8 Table of Contents 1 Objective 4 2 Notification & Permit 5 3 Shut Down Production & Prep for P&A 5 3.1 Swap the Jet Pump Power Fluid 5 4 Rig Down 6 4.1 Expro 6 4.2 Schlumberger 6 4.3 Tanks 6 4.4 Wellhouse 6 4.5 Generators 6 4.6 Camp 6 5 RU Scaffold for Slickline &CT 6 6 Wellbore Details 6 7 Pull Jet Pump & DV 7 7.1 RU Slickline 7 7.2 Drift tubing 7 7.3 Pull Jet Pump 7 7.4 Pull DV from CIM 7 7.5 RD Slickline 7 8 Notify AOGCC of Abandonment 7 8.1 24 Hour Notice to AOGCC 7 9 Coiled Tubing Wellbore Displacement& Clean Out 8 9.1 RU CTU with Cementing Swirl Nozzle 8 9.2 Displace to warm SW(-100F) & RIH to 2,000' MD 8 9.3 Clean out to Top of Sand Screen Assembly 8 10 Set Bridge Plug with CT 9 10.1 Make up Baker K-1 Bridge Plug on Model J hydraulic setting tool 9 10.2 RIH and tag the top of the Sand Screen assembly 9 10.3 PU and Set Bridge Plug 10 11 Tag Bridge Plug with CT & Pressure Test 10 11.1 MU & RIH with Cementing Swirl Nozzle 10 11.2 Tag K-1 Bridge Plug 10 11.3 Pressure test the Bridge Plug 11 11.4 Circulate while preparing for CT cementing 11 12 Lay Cement on Bridge Plug 11 12.1 RU Hot Oil Truck 11 12.2 Establish Reverse Circulation with Hot Oil Truck 11 12.3 Lay Cement on Bridge Plug with CT 11 12.4 RD CTU 13 12.5 SD & RD Hot Oil Truck 13 13 Cement 4-1/2" Tubing and Annulus 13 13.1 Mix Cement 13 13.2 Circulate Cement in 4-1/2" Tubing and Annulus 13 13.3 WOC 13 14 RD Scaffolding &Cut off wellhead 14 14.1 Rig Down Scaffolding 14 14.2 Excavate wellhead to at least 6' below tundra level 14 14.3 Cut windows in the casing strings 14 14.4 Cut Off the Wellhead at least 3' below tundra level 14 15 Weld Plate Cover 15 16 Fill in hole 15 17 Close out pad 16 17.1 Pad cleaned up and closed out 16 17.2 Pad Entrance blocked 16 17.3 Summer clean-up plan in place 16 Procedure No 16_Permanent Abandonment.doc page 2 of 8 1 Objective Leave the well in a permanently abandoned state with the perforation zone isolated, all tubing and annulus strings filled with cement to the surface and the wellhead cut off at least 3' below tundra level. A plate with well information is to be welded to the top of the well stub after agency approval of the cement job. The well stub will be buried with overburden with a small mound of dirt left on the surface for settling. 2 Notification & Permit • Notify BP Operations at GC2 and BP's L pad of the intent to work on the well. Assure all personnel working on-site have completed BP required training to work in their field. Work permits may be required from BP—radio communication with BP operations may also be required during work activities. Other requirements at BP's discretion may need to be followed. • Assure all AOGCC permits have been attained for permanent abandonment. 3 Shut Down Production & Prep for P&A 3.1 Swap the Jet Pump Power Fluid • Convert to glycol/water mixture for jet pumping, continue at pump rates for 80 bbls. • Choke back returns as necessary to stall jet pump and inject below pump • Circulate the remaining glycol to assure glycol mixture from surface to as near the perfs as possible. 4 Rig Down 4.1 Expro 4.2 Schlumberger 4.3 Tanks 4.4 Wellhouse 4.5 Generators 4.6 Camp 5 RU Scaffold for Slickline & CT Procedure No 16_Permanent Abandonment.doc page 3 of 8 6 Wellbore Details ..•'tel; ✓�!; �... :.��' Well Bore Schematic Ignik Sukumi 7.625 Ignik Sukurri#14.5" Jewelry-PipTag_Log_ Ignik Sikurri#1.pdf inch x 4.5 inch prod c Tubing Completion.pc 24-Apr-2011.PDF 7 Pull Jet Pump & DV 7.1 RU Slickline 7.2 Drift tubing Drift tubing to top of pump assembly @ 1929' MD with 3.5" gauge ring 7.3 Pull Jet Pump • Pull jet pump assembly from DB nipple at 1942' • Pull lower DB-6 lock, and seal bore receptacle at 1957' MD Note: There is no valve in the GLM, leave the pocket open 7.4 Pull DV from CIM Pull Dummy valve from the chemical injection mandrel at 1,929' 7.5 RD Slickline 8 Notify AOGCC of Abandonment 8.1 24 Hour Notice to AOGCC Inform AOGCC of upcoming Bridge Plug pressure test(24 hours notice) 9 Coiled Tubing Wellbore Displacement & Clean Out 9.1 RU CTU with Cementing Swirl Nozzle 3-1/2" OD nozzle Note: The nozzle needs to be larger than the CT end connector, and larger than the 2.25" ID of the DB-6 lock on the top of the sand screen assembly 9.2 Displace to warm SW(-100F) & RIH to 2,000' MD • With CT at surface, pump warm sea water(SW)down the tubing taking returns up the IA to displace the cold glycol water from the tubing and IA(calculated volume =81 bbls) • RIH with CT to 2,000' MD, pumping warm SW taking returns up the IA • Take 2 bbls returns up the flat pack heater strings • Take 1 bbl returns up the chemical injection line 9.3 Clean out to Top of Sand Screen Assembly Note: Expect a hydrate column or Glycol/Water below the DB nipple at 1,957' • Circulate warm SW at max rate Procedure No 16_Permanent Abandonment.doc page 4 of 8 • Stage into hydrate (if encountered) in small bites, less than 30' • Tag the top of the sand screen assembly, locked in the DB nipple at 2,224' Note: There is a DB-6 lock on the top of the sand screen assembly with a 2.25" ID, and the minimum ID through the sand screen is 2.188" • Sand Screen Assembly Detail, open file below: LI Procedure No 7_Sand Screen Prepa • Circulate the hole clean at the top of the sand screen assembly, POOH with CT 10 Set Bridge Plug with CT 10.1 Make up Baker K-1 Bridge Plug on Model J hydraulic setting tool CIBP Hook Up.pdf 10.2 RIH and tag the top of the Sand Screen assembly • Circulate minimum rate down the CT with warm SW • Tag the top of the sand screen assembly, locked in the DB nipple at 2,224' 10.3 PU and Set Bridge Plug • Position the top of the K-1 Bridge Plug at 2,208' (middle of 9.78' pup joint) • Circulate 1/2" ball down to actuate the Baker Model J hydraulic setting tool • Set the Bridge Plug • POOH with Baker Model J hydraulic setting tool Note: DO NOT set down and tag the Bridge Plug with the setting tool • Circulate minimum rate down CT with warm SW while POOH 11 Tag Bridge Plug with CT & Pressure Test 11.1 MU & RIH with Cementing Swirl Nozzle • Circulate minimum rate down the CT with warm SW 11.2 Tag K-1 Bridge Plug • Set down and firmly tag the Bridge Plug • PU 10' 11.3 Pressure test the Bridge Plug Pressure test the Bridge Plug by applying 1,500 psi at surface (4-1/2"Tbg & IA) 11.4 Circulate while preparing for CT cementing • Circulate minimum rate down the CT with warm SW Procedure No 16_Permanent Abandonment.doc page 5 of 8 12 Lay Cement on Bridge Plug • Design slurry to set at 40 F with a thickening time of 3-4 hours • Run lab tests to verify thickening time and UCA compressive strength 12.1 RU Hot Oil Truck Rig Up Hot Oil Truck to reverse circulate down the IA and up the 4-1/2" tubing 12.2 Establish Reverse Circulation with Hot Oil Truck • Establish reverse circulation with warm SW down the IA, taking returns up the 4-1/2"tubing at—1 BPM (to prevent cement from entering the IA) 12.3 Lay Cement on Bridge Plug with CT • Position Cementing Swirl Nozzle 10' above Bridge Plug • Pump spacer(if recommended by Schlumberger) • Mix & Pump 10 bbls Arctic Set#1 (15.7 lb/gal) , on the fly • Pump spacer(if recommended by Schlumberger) • Displace with warm SW • As the cement exits the nozzle, POOH 1:1 and lay in cement to 2,000' MD • Increase circulation to max rate down the CT with warm SW • Reciprocate the nozzle slowly between 1,950' -2,000' MD until all cement has been circulated out of the well Note: Increase the pump rate with the Hot Oil Truck if necessary to achieve annular velocity of at least 180 ft/min between the CT and the 4-1/2" tubing. • POOH jetting 4 1/2"tubing at max rate • Freeze protect the CT • Close the swab valve 12.4 RD CTU 12.5 SD & RD Hot Oil Truck 13 Cement 4-1/2" Tubing and Annulus 13.1 Mix Cement Mix 100 Bbls of Arctic Set 1 cement(15.7 lb/gal), on the fly 13.2 Circulate Cement in 4-1/2" Tubing and Annulus • Open the 3/" heater strings • Open the 3/<"chemical injection line Circulate 100 bbls Arctic Set#1 down the 4-1/2"tubing, through the open GLM and take returns up the 7-5/8" annulus and flat pack tubes. Make sure cement is circulated to surface. • Monitor returns up the flat pack tubes for cement returns, then shut in the flat pack tubes, taking the remaining returns out the 7-5/8" annulus Procedure No 16_Permanent Abandonment.doc page 6 of 8 r , 13.3 WOC Wait on cement as determined by Schlumberger personnel 14 RD Scaffolding & Cut off wellhead 14.1 Rig Down Scaffolding 14.2 Excavate wellhead to at least 6' below tundra level Utilize Drilling Toolhouse personnel to excavate as they have the experience to do a safe job 14.3 Cut windows in the casing strings Fire extinguishers and fire watch should be in place during each step • Weld a nipple on the 10 3/" casing to install a full opening ball valve (3/4") • Drill a hole in the 10-3/4" casing, then continue to drill into the 7-5/8" casing, and the 4-1/2" tubing, to assure there is no trapped pressure • Torch cut windows in the casing and tubing strings 14.4 Cut Off the Wellhead at least 3' below tundra level • Inform AOGCC of upcoming final abandonment inspection • Rig up a crane to the wellhead • Use Wach saw to cut through the casing and tubing strings • Take pictures of the cut off well and casing/tubing strings • Assure cement to the surface—if not call out DHD cement mixer to top off strings to the surface • Dispose of wellhead in bone yard at Kuparuk 15 Weld Plate Cover Weld plate with a weep hole to cover all casing and tubing strings with the following information: ConocoPhillips Ignik Sikumi#1 PTD#211- 027 API# 50-029-23443-00 Take pictures of welded plate and store in S Drive folder for future reference 16 Fill in hole • Leave a small mound of dirt for settling • No excess cement chunks should be in the fill dirt as it could be a Notice of Violation (NOV)according to the Alaska Department of Conservation. Consult the Environmental Coordinator for details Procedure No 16_Permanent Abandonment.doc page 7 of 8 17 Close out pad 17.1 Pad cleaned up and closed out Walk through done by the appropriate Environmental Coordinator and Wells Supervisor 17.2 Pad Entrance blocked No vehicle entry after Pad closeout 17.3 Summer clean-up plan in place Inspection plan overseen by Environmental Coordinators Procedure No 16_Permanent Abandonment.doc page 8 of 8 -' , Hole Size Csg/Tbg Lb/ft Grade Thread MD 414 13-1/2 10 9/. 45.5 L-80 BTC 1,473 9-7/8" 7-5/8" 29.7 L-80 BTCM 1,974 9-7/8" 4-% 12.6 L-80 IBTM 1,996-2,592 40 11 7-5/8"Csg 4-'/ Tbg 12.6 L-80 IBTM 1,986 • 1 DTS Cable Electronic Cable PIT Gauge @ 2,034' Sensor @ 2039.48' 'A Coiled Tbg ,1 'A Coiled Tbg Ii D Sand 2,061 2,110 • i 1 DB nipple(3.875"min ID) 2 Chemical Injection Mandrel ( 3 DB nipple(3.813"min ID) 4 Gas Lift Mandrel 5 DB nipple(3.75"min ID) 6 P/T Gauge 7 DB nipple(3.687"min ID) 8 PIT Gauge 9 Polish Bore(3.625"min ID) 1: ' 10 PIT Gauge 11 Packoff Bushing(Cmt g) 7 A - 1,473' ia DB Nipple @ 2,224' P/T Gauge @ 2,226' Sensor @ 2,231.72' it'' 1 DB Nipple @ 1,927' Upper C Sand 2 CIM @ 1,929' =_-- 2,240 2,274 3 DB Nipple @ 1,942' 4 GLM @ 1,944' 1 9 C Polish Bore @ 2,278' k PIT Gauge @ 2,285' 5 DB Nipple @ 1,957' 10 Sensor @ 2,291.67' EOT @ 1,986' 11 Packoff Bushing @ 2,371' 10i -4411 2,403'Float Collar 6 PIT Gauge @ 2,034' Sensor @ 2,039.48' 2,597'TD .., ... Baker Hughes Thru -Tubing Services Well Number: Connections O.D. I.D. Length Coiled Tubing Connector Material Number H132003103 • Serial Number 2 % Regular Pin 3.02" 1.00" 0.94' I Tensile 80,000# Dual Back Pressure Valve Material Number H132043103 2 %" Regular Box 3.04" 1.00" 1.57' Serial Number 2 %" Regular Pin Tensile 150,000# Highload Disconnect Material Number H13133402 2 3/s" Regular Box Serial Number 2 3/a" Regular Pin 3.38 0.81 1.50, - Tensile 94,000# 1 7/8"Disconnect Ball I Cross Over 2 3/8" Regular Box 3.125" 1.000" 0.55' 5 Pitch Pin J-Hydraulic Setting Tool 5 Pitch Box 2.750" N/A 6.06' %"ball seat Stub Acme II K-1 Bridge Plug Adapter Kit Stub Acme 3.59" N/A 1.92' 1 1 K-1 Bridge Plug N/A 3.59" N/A 1.85' Total Tool String Length 14.39' ,7 ,-4, 1 OIF ALASEA ,, yj ----r SEAN PARNELL, GOVERNOR ALASKA OIL A1VJ) GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMDIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Jack Kralick 01 Wells Engineer — d ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, Ignik Sikumi 1 Sundry Number: 312-131 Dear Mr. Kralick: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, / ' _ 4Q Cathy '. Foerster Chair DATED this 111 day of April, 2012. Encl. S r STATE OF ALASKA /!�/lz ' COM.:A OIL AND GAS CONSERVATION CO . .,ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon 17 , Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations y,- Perforate r Pull Tubing r Time Extension r 7.Operational Shutdown r Re-enter Susp.Well r y.�c Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 211-027 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23443-00- 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No FY Ignik Sikumi 1 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28239 . Prudhoe Bay 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): 2597 2597 • 2597' 2597' i -- ----- — Casing Length Size MD TVD l Burs Conductor 77' 16" 108' 108' RECEIVE j Surface 1442' 10.75" 1473' 1473' Production 1935' 7.625" 1964' 1964' APR Q 2012 Production 628' 4.5" 2592' 2592' Alaaku Oil&Gas Ccns. Cornmissior Anchorage Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2243'-2273' 2243'-2273' 4.5 L-80 1986 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no Packer nipple©1927'MD,1927'TVD 12.Attachments: Description Surrrary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r • Exploratory Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/16/2012 Oil r Gas r WDSPL r Suspended 1 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r — 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Kralick @ 265-6870 Printed Name Jack KralickfTitle: Wells Engineer Signature , fr"f-'�Y'`-`- Phone:265-6870 Date :3I2.02 Commission Use Only �f Sundry Number:5 i / .,fj2 1 Conditions of approval: Notify Commission so that a representative may witness v Plug JA°‘ BOP Test r Mechanical Integrity Test r Location Clearance SL.aFrr�er Zell Other: AL �r5 5' e c---471,-- 4S /h X 1; Subsequent Form Required: /0_L`) 7 / �7 APPROVED BY alalApproved by: C MISSIONER THE COMMISSION Date: l 40 I v I yS"iz. Form 10-403 Revi ed Ffignms APR 11 20e I G I N A L Submit in Duplicate ?ICl/ ConocoPhillips Alaska, Inc. Ignik Sikumi #1 CO2 Injection and Well Test Procedure - 16 Permanent Abandonment • Issue Issue Date Revision Description Prepared By Reviewed By 1 09-Jan-12 Original B.E. Smith J. Kralick 13-Jan-12 Reviewed and Vance Yoakum 21-Jan-12 Approved 2 .28-Mar-12 Updated B.E. Smith J. Kralick 02-Apr-12 Reviewed and Brian O'Dell 02-Apr-12 Approved Procedure No 16_Permanent Abandonment.doc page 1 of 7 Table of Contents 1 Objective 3 2 Notification & Permit 3 3 Shut Down Production & Prep for P&A 3 3.1 SD the Jet Pump 3 3.2 Displace top of 4-1/2"Tbg with N2 3 4 Initial Slickline and Pumping: 3 4.1 RU Slickline 3 4.2 Drift tubing 3 4.3 Pull Jet Pump 3 4.4 Pull DV from CIM 3 4.5 Displace tubing and casing annulus to water(-100 F) 3 4.6 RD Slickline 4 5 Coiled Tubing Clean Out 4 5.1 RU CTU with 2"Cementing Swirl Nozzle 4 5.2 Clean out to 2,350' MD 4 6 Cement Perforated Interval 4 6.1 Mix Cement 4 6.2 Squeeze Perforated Interval 5 6.3 RD CTU 5 7 WOC&Circulate the 4-1/2"Tbg and the IA 5 7.1 24 Hour Notice to AOGCC 5 7.2 Circulate the 4-1/2"Tbg and the IA 5 7.3 WOC 5 8 Tag Cement 5 8.1 RU Slickline 5 8.2 RIH and Tag cement 5 8.3 RD Slickline 5 9 Cement 4-1/2"Tubing and Annulus 5 9.1 Mix Cement 5 9.2 Circulate Cement in 4-1/2" Tubing and Annulus 6 9.3 WOC 6 9.4 Pull Wellhouse and attached equipment 6 10 Cut off wellhead 6 10.1 Excavate wellhead to at least 6' below tundra level 6 10.2 Cut windows in the casing strings 6 10.3 Cut Off the Wellhead at least 3' below tundra level 6 11 Weld Plate Cover 6 12 Fill in hole 7 13 Close out pad 7 13.1 Pad cleaned up and closed out 7 13.2 Pad Entrance blocked 7 13.3 Summer clean-up plan in place 7 Procedure No 16_Permanent Abandonment.doc page 2 of 7 1 Objective • Leave the well in a permanently abandoned state with the perforation zone isolated with cement, all tubing and annulus strings filled with cement to the surface and the wellhead cut off at least 3' below tundra level. A plate with well information is to be welded to the top of the well stub after agency approval of the cement job. The well stub will be buried with overburden with a small mound of dirt left on the surface for settling. 2 Notification & Permit • Notify BP Operations at GC2 and BP's L pad of the intent to work on the well. Assure all personnel working on-site have completed BP required training to work in their field. Work permits may be required from BP—radio communication with BP operations may • also be required during work activities. Other requirements at BP's discretion may need to be followed. • Assure all AOGCC permits have been attained for permanent abandonment. 3 Shut Down Production & Prep for P&A 3.1 SD the Jet Pump 3.2 Displace top of 4-1/2" Tbg with N2 Inject N2 to displace the top 500 ft of the 4-1/2"tubing 4 Initial Slickline and Pumping: 4.1 RU Slickline 4.2 Drift tubing Drift tubing to top of pump assembly @ 1929' MD with 3.5"gauge ring " 4.3 Pull Jet Pump • Pull jet pump assembly from DB nipple at 1942' • Pull lower DB-6 lock, and seal bore receptacle at 1957' MD • Note:There is no valve in the GLM, leave the pocket open 4.4 Pull DV from CIM Pull Dummy valve from the chemical injection mandrel at 1,929' 4.5 Displace tubing and casing annulus to water(-100 F) • Circulate 2 bbls 9.2#warm brine down the flat pack • Circulate 1 bbl 9.2#warm brine down the chemical injection line / • Circulate 100 bbls 9.2#warm brine down tubing and up 7 5/8"x 4 %2"annulus through a choke to tanks Procedure No 16_Permanent Abandonment.doc page 3 of 7 4.6 RD Slickline 5 Coiled Tubing Clean Out 5.1 RU CTU with 2" Cementing Swirl Nozzle Be aware of jewelry hazards in the sand screen assembly and the Packoff Bushing. Verify that all shoulders are chamfered on the CT BHA(CT end connector, nozzle, and any crossovers). The seal assembly on the bottom of the sand screen assembly has a 45 muleshoe, but could be problematic for re-entry from below. The Packoff Bushing at 2,371' has a square shoulder and re-entry from below could be problematic. See embedded detail of the Sand Screen seal assembly and Packoff Bushing below: FGF4 BOT equip Ignik Sikumi 1.pdf Notes: • Minimum ID is 2.188" @ 2,237' (2-7/8" D nipple in sand screen assembly) • The sand screen assembly is not shown in the schematic, however the sand screen detail is in Procedure No 7_Sand Screen Preparation and Installation Procedure No 7_Sand Screen Prepa li • The sand screen assembly straddles the perforation interval from the 3.687" ID DB nipple at 2,224' to the 3.625" ID Polish Bore at 3.625" ID • All wellbore detail files are located at S:\Longterm\Drilling&Wells Ops\G K A\Hydrate Well- Ignik Sikumi\2012 Operations\Wellbore Details 5.2 Clean out to 2,350' MD Note: Expect a hydrate column from the DB nipple at 1,957'through the perforations from 2,243'—2,273', and expect sand from the base of the perforations to PBTD. It is not necessary to clean out through the Packoff Bushing, and re-entry from below the Packoff Bushing could be problematic. • Circulate 9.2#warm brine at max rate • Pump 1.5 lb/bbl biozan sweeps as necessary to carry out sand • Stage into hydrate and sand in 50 foot bites • Circulate the hole clean at 2,350' • POOH to 1,900'to verify that there are no problems pulling back through the sand screen assembly and completion jewelry 6 Cement Perforated Interval • Design slurry to set at 40 F with a thickening time of 3-4 hours • Run lab tests to verify thickening time and UCA compressive strength >1,500 psi 6.1 Mix Cement Batch mixer—Mix 10 Bbls of Arctic Set 1 cement • 15.7 lb/gal • Mixed slurry temperature—65-70 F Procedure No 16_Permanent Abandonment.doc page 4 of 7 01Y- 6.2 Squeeze Perforated Interval 0 • RIH with 2"cementing nozzle to clean out depth of 2,350' MD • PU to 2,340'MD • Pump a 5 Bbl fresh water spacer • Pump 10 bbls Arctic Set#1 • Pump a 5 Bbl fresh water spacer • Pump 20 Bbls of 1.5 lb/bbl biozan • Displace with 9.2#warm brine • As the cement exits the nozzle, POOH 1:1 and lay in cement to 2,000' MD • POH to at least 1,800', apply 200 psi squeeze pressure for 30 minutes • Establish circulation at max rate • Wash down and dress off the cement to 2,000' MD • POOH jetting 4 1/2"tubing at max rate • Freeze protect the CT • Close the swab valve 6.3 RD CTU 7 WOC & Circulate the 4-1/2" Tbg and the IA 7.1 24 Hour Notice to AOGCC Inform AOGCC of upcoming cement pressure test of producing zone(24 hours notice) 7.2 Circulate the 4-1/2" Tbg and the IA Circulate down the 4-1/2"tubing and up the IA while WOC to make sure any cement that may have passed through the GLM is diluted and does not set up • Circulate 9.2#warm brine at 2 Bbl/min 7.3 WOC • Wait on cement as determined by Schlumberger cement design 8 Tag Cement Art- f:/ 4_ yet. el. 8.1 RU Prcss. %t (Si f- - 8.2 RIH and Tag cement 8.3 RD Slickline 9 Cement 4-1/2" Tubing and Annulus 9.1 Mix Cement Batch mixers—Mix 100 Bbls of Arctic Set 1 cement • 15.7 lb/gal Procedure No 16_Permanent Abandonment.doc page 5 of 7 • Mixed slurry temperature—65-70 F 9.2 Circulate Cement in 4-1/2" Tubing and Annulus • Open the 3/4"heater strings • Open the 3/4"chemical injection line Circulate 100 bbls Arctic Set#1 down the tubing, through the open GLM and take returns up the 7-5/8" annulus and flat pack tubes. Make sure cement is circulated to surface. • Monitor returns up the flat pack tubes for cement returns, then shut in the flat pack tubes, taking the remaining returns out the 7-5/8"annulus 9.3 WOC Wait on cement as determined by Schlumberger personnel 9.4 Pull Wellhouse and attached equipment 10 Cut off wellhead 10.1 Excavate wellhead to at least 6'below tundra level Utilize Drilling Toolhouse personnel to excavate as they have the experience to do a safe job 10.2 Cut windows in the casing strings Fire extinguishers and fire watch should be in place during each step • Weld a nipple on the 10 3/4"casing to install a full opening ball valve (3/4") • Drill a hole in the 10-3/4"casing, then continue to drill into the 7-5/8"casing, ' and the 4-1/2"tubing, to assure there is no trapped pressure • Torch cut windows in the casing and tubing strings 10.3 Cut Off the Wellhead at least 3'below tundra level • Inform AOGCC of upcoming final abandonment inspectionj ,, 7 X5• • Rig up a crane to the wellhead • Use Wach saw to cut through the casing and tubing strings ,r • Take pictures of the cut off well and casing/tubing strings its / Cf • Assure cement to the surface—if not call out SLB cement van to top off strings to the surface with AS 1 cement I cis. • Dispose of wellhead in bone yard at Kuparuk 11 Weld Plate Cover Weld plate with a weep hole to cover all casing and tubing strings with the following information: ( ConocoPhillips Ignik Sikumi#1 PTD#211-027 A2330j0 Take pictures of welded plate and store in S Drive folder for future reference Procedure No 16_Permanent Abandonment.doc page 6 of 7 12 Fill in hole • Leave a small mound of dirt for settling • No excess cement chunks should be in the fill dirt as it could be a Notice of Violation (NOV)according to the Alaska Department of Conservation. Consult the Environmental Coordinator for details 13 Close out pad 13.1 Pad cleaned up and closed out Walk through done by the appropriate Environmental Coordinator and Wells Supervisor 13.2 Pad Entrance blocked No vehicle entry after Pad closeout 13.3 Summer clean-up plan in place Inspection plan overseen by Environmental Coordinators Procedure No 16_Permanent Abandonment.doc page 7 of 7 4 1/16-5K (R-39) II I o -® � _ --14.84iVJiF 37694 j ; r4i.e) ,(-_ ,. ties 47 11.94 2 I/16-5K (R-24) 2 9/16-5K (R-27) miss SEAL SLEEVE PORT -+iLl.. .. qry gn O } �,a!q 1 -N��,� 10 LOCKDOWN SCREWS 7.69ei.,,,Q ' II-SK (RX-54) �1/40" _ �.."-----1-27} 10' I 26.41 2 /16-5K MI20 GV �n'I I ,®' SEAL SLEEVE PORT 670.81 _ 1* I O SEAL SLEEVE PORT O r d ! �� 0 �'�Le . TOP VIEW a ,•,j , 111.5_ �uq� j� �C) `�J, �'. TUBING HANGER -HIM '.�� I CS (((( �j, �I��' = Olin ', �"` ' 0r : '� 64.00 I 1f .J i, '1 A I ►•,'� J .,�� '�- 07.44 //00°. „, 3/4'LP PORT 1625.6 3.28 2 I/16-5K MI20 GV 1j IO 337.31 © (it oa .16 TEST PORT 3/4'LP PORT `Y 10' 4.06 ,�: ► / w• - \� 3/4'LP PORT -ice;E. � - � � "' GROUND LEVEL 1 _ - 11i f� :'''''' BOTTOM VIEW - � '` �w����'I�� 10 LOCKDOWN SCREWS TUBING HANGER -Iii o 'III„II,I - ei let 5K (R 54) IXj _- 2 I/16-5K MI20 GV 4•' 9 CI 22.75 GSI 11 -G d - I� li 0 ,,-- g 577.85Cil REWS ={51.1 it 3 61:200 �� R J o --ii -I # r„i - - 9.15 U. 232.41 111) 0 3.26 6.10 0 82.93 154. t!; ii '1 i IITEMII PART NUMBER I DESCRIPTION 0 I I 13-300-030 DIVERTER LANDING RING,20 X 18.75 BOWL 2 P166050 10 3/4 CASING HANGER 3 (P164819) CASING HEAD ASSY,11-5K,W/ LOCK SCREWS 1 4 13-300-718 GEN 5 TUBING HEAD ASSY,11-5K X 11-5K 5 (P1000060777) 7 5/8 CASING HANGER 6 (P1000009887) TUBING HANGER ASSY,TC-IA-EMS,II X 4 1/2 j 7 (PI19036-0002) ADAPTER ASSY,A-4-M,II-5K X 4 I/16-5K 8 12-090-160 10 3/4 C-21 CASING HANGER 9 P166636 10 3/4 BELL NIPPLE -----5.----"----20'OD CASING -...\_,,__IO 3/4'OD CASING - -7 5/8'OD CASING `�4 1/2'0D TUBING REF:DM100049826-2 REV D PRIVATE AND CONFIDENTIAL REVISIONS DESCRIPTION .EL REVIER INS MUM A.40 ALL IK 160,01.6 MUM HMI NE De A 11-12-10 BY B II-24-10 GAS HYDRATE WELL RATIN MAROUEZ 11-12-10 MISS NUM 01116112111.16 VIC 609.6041ES.THIS�N�E.N� 16XT IS .R4N.R,.NEMEW .. C 12-23-10 GENERATION 5 WELLHEAD LRAFT.LREVIEW Mt MARQUEZ 11-12-10 20 X 10 3/4 X 7 5/8 X 4 1/2 DESILN MVO, OXIMOir SHALL 6(641610 NC 102.1166.61.0616 AN MT IDPITIM MAO 0 WITS DOW SAW HOT TVAMF666911-5K COMPLETION RAMAVANAN 11-12-10 DRAWING mneER ,.AR16NUM,NZ.,RN.IN.NL.a.PC1 HAMILTON 11-12-10 DM100098736 ConocoPhillips WELL NAME:IGNIK_SIKUMI_#1 iT90 AT60 AT30 L4 SH_AUM IBJ. CR DTCO lEala SH_DTVPMDB,,• um AT10 RHOZ • DEPTHIllerM MEM,• T..._KTIM MEMEM' I Gi ci i FEET v/V I'...1 MD 1..00 'S_1ll�1A1:��. TC' SH_CMR KSDR iSliiCi• filikkiii ®_ate giiifiL'ia II ging TIMM11. illR � BIMINI ki P �; i I II IiMhiIi� �Z . �: _ _ .— &-41..— - 1 — 1750k--- --,. ys iiiiiIIii =4. Perl'na' ,....,_ j ird: -.-7-' ; . : . itifit,i iii NI ; ,.. , ,--- 1, • _ _ _ _ 2000 —A— Il[v] i 4111 , ,, 1 ; ,, - ;miii. _Alliy Gi:2F Y2250�mmm; r ' 11111 11 ' 1 • 1 . il 1Ciii `� l . .... i 9 Ingik Sukumi#1 production Casing Well: Ignik Sukumi 1 ConocoPhillips 7-5/8"29.7 ppf 1-80 BTC-m x 4-1/2"IBT-m casing Date: 4/24/2011 Alaska,Inc. Rig: Nordic 3 r t i Depth Jt Number N�tsof 11JJ(+ 111 Well Equipment Description and Comments Length Tops Page 1 ..g floor to lower __ .down screws 28.7(Load shoulder 29. Rig floor to lower lock down screws 28.70 FMC 7-518"casing hanger .71 28.70 7518"pupa29.7ppf L-80 BIC Pin xFin 1.96 29.41 Jts 15 to 59 45 Jts 7-58"29,7 tet L-80 BTC-m cosi .• 1932.84 31.37 ``.Ie ;-;.: :1 €', 10.10 1964.21 a s©vm 7®518'"29,7 ppf L-89 BI --tli box x S=1/12"17 ppf L-89 1ST '-�;1 1.76 1974.31 tr 199,4? Casing Sohl Borg 8-AO"f3TC Pb' X Pin so��+<"ID) 18.251 1976.07 i sower 9.112"17 ppf L- IITC=M b 41/2"lPT-11:i r?'n 1.42 1994.32 : 12,E 1 4 09 illi Pkip 9.79 1995.74 Jts 14 to 14 1 Jts 4.1//2" i1.6 ppf L=8i1J I61"-rn ung 28.22 2005.53 Mrtnad%GuAgo 04111i6r'(pass thr11)4442"12.E mf L-;®lBT ►P* 10.13 2033.75 Jts 9 to 13 5 Jts ,rim " 155.32 NON 41/212.,E 1pf LAO 11 T-Am Pop(7.83', 3.83',9.78', 3.82') 25.26 2199.20 CAkli@@ 1®5"No,-04 Nim It.titr immiwom ID,$-1//2"161,41k 1.53 na4.4o Pir act Guam Pdrritt WU tltrto 4-1/(2"12•.1 Kiff L- lIBfio►P*P 10.13 nnw 4=1//"12.1 +-s L-60 161-,ffl ' =(3.78') 3.78 2236.12 Jts 8 to 8 1 Jts /2" 12.6 ppf _`rO lei r cry irr, 30.91 la' ' . 6 tot LAO IRV 10 1~. 5.83 2270.81 ii"2" -^-:-1,%'.', ..--.• - - .95 2276.64 5.37 2277.59 41=1/ "124 to L--N@ Minfi 1.85 Ma.94 POW&i k @ iNrffrWr l *110 41=1/ '12:%11 L r. 4tfi-01 )f(P 1 10.13 2284.81 44-1W' it 124 001-80'11311-m Pups(3.83'+9.82') 13.65 2294.94 Jts 6 to 7 2 Jts 41.1// h 12..%pet L-40 im tratiist 62.21 2308.59 Baktti Nate tokina1.33 2370.80 11/41'i2•.t tot L % itfi- +1 PIRA WiwrlRiifftlt 31.05 z7I•11ii l*tcithiyhtzi4=11//2"'lolitrtO Abalt ttillYr„lel 4ks2 1.35 2403.18 Jts 1 to 5 5 Jts 41=1//''q2,%to i:�Mifirm @ail st 155.10 2404.53 *Vie 12.4 tot 144 ltd fel Plat&toeJjdiftt 31.11x` 631 F4X4thtlftliti 4.14th kafixlrl Piktat%Me,WOW 1.60 2590.74 2592.34 2592.34 ::NW i$U F U411 Alkftwihitt2592.34 Ft*i we is nor% itiAtatkM taktiftrikii0i4 iiiikorml 2592.34 PO paimittAi Wilk*, 2592.34 litaiThIM: TIb=MY YrIORMO=NW tm WA *kik 11031ilt"tlfbe0WNW) i1RtdkAt Yak Supervisors:Dale Rowell/Scott Heim/Steve Shultz I f ' Casing OR Tubing OR Drilling Detail Well: Ignik#1 4.5"IBT-M Special Clearance tubing UPPER COMPLETION Date: 4/25/2011 ConocoPhillips Rig: Nordic 3 Alaska,Inc. Depth Jt Number Joints 0101Well Equipment Description and Comments Length Tops 0$11. F:?;.P RKB To Rotary Table-26.4.. RKB To Rotary Table-26.46' 26.46 FMC Tubing Hanger&4 1/2"12.6#1-80 IBT-M Pup 31.05 26.46 41/2"12.6#1-60 IBT-M Tubing Pups(9,93`,9,95')ID=3,958" 19.88 57.51 Jts 1 to 60 60 Jts 41/2"12141-80 IBT-M Tubing ID it 3.958" 1845.92 77.39 41/2"12m1-80 IBT-M Tubing Pup ID=3,958" 3.78 1923.31 -� 4112"CAW °"DB"Nipple with 3,87V Rutile IBT-M 1.56 1927.09 4 KBMG-LTB Chemical In$cti®ri Mandrel leT-M 7.68 1928.65 4 I12"12,501-80 IBT-M Tubing Pup ID=U)58" 5.72 1936.33 -v. 41I"Came"DB"Nipple with 3.813"Raft IBT-M 1.56 1942.05 4112"k 1"Gemco KBMD GLM*1 with SOV lnstallad 4 Latch 7.22 1943.61 41/f2"12•.i'L-89 IBT-M Tubing Pup ID= " 5.83 1950.83 --3,414/4"Dame"DB"NiIppta with 31;'r,"Pr® ii@ IBfi'=M 1.58 1956.66 414r lam L.843 Tubiim Pup ID=3•.'=e'" 3.77 1958.24 41//x" I=mo IBT=M TAkka Puip ID=3. " 5.85 1962.01 4 lir 12•.9*L--99 IBT=M Lacat Skia 1.05 1967.86 41//2"al2•.t x-80 IBT=M Seal lD= .': '." 17.01 1968.91 1985.92 1985.92 1985.92 1985.92 1985.92 AftrIPANIk 1985.92 1985.92 1985.92 1985.92 viii te4i=°%.i@ i1985.92 1985.92 ?$ 11 tWiiti @it CAltri / Reitip widftitwi witta. 1985.92 1985.92 1985.92 ktIft1 t@iMI gif M PrAt Ril *MAMA. 1985.92 lit )%ki4irftiwis Sktia 1985.92 1985.92 1985.92 1985.92 l` At i.r+Ifc All collars are Special Clearance-4.92" 4WIXtit Pp,If( All tubing drifted to 3.91" tredkUtt Ik Note:Corrected Pipe tally by 10.90' Supervisors:Scott Heim/Dale Rowell Hole Size Csg/Tbg Lb/ft Grade Thread MD 13-'/2" 10-%" 45.5 L-80 BTC 1,473 9-7/8" 7-5/8" 29.7 L-80 BTCM 1,974 r 9-7/8" 4-W 12.6 L-80 IBTM 1,996 -2,592 7-5/8" Csg 4-Y"Tbg 12.6 L-80 IBTM 1,986 € : ( r ' DTS Cable Electronic Cable P/T Gauge @ 2,034' :- Sensor @ 2039.48' I3/1"Coiled Tbg '/"Coiled Tbg HH D Sand 2,061 -2,110 '_ Ubi/ff OM -DB nipple(3.875"min ID) v 2—Chemical Injection Mandrel �.7 .3.6151)' '01531 al 3—DB nipple(3.813"min ID) 45Hi '4' .02421 36_I 4—Gas Lift Mandrel —DB nipple(3.75"min ID) 6—P/TGauge GEIS 7—DB nipple(3.687"min ID) 8—P/T Gauge 9—Polish Bore(3.625"min ID) 10—PIT Gauge 11 —Packoff Bushing(Cmt'g) } 1,473' Mt 7 DB Nipple @ 2,224' P/T Gauge @ 2,226' Sensor©2,231.72' 1 C • DB Nipple @ 1,927' _ Upper C Sand 2 CIM @ 1,929' 2,240-2,274 G C .. • DB Nipple @ 1,942' Ter -- ea" ' 4 GLM @ 1,944' ' Polish Bore @ 2,278' mi..••••— PIT Gauge @ 2,285' DB Nipple @ 1,957'/ Sensor @ 2,291.67' /- , l ' SceX grin MEM Packoff Bushing @ 2,371' EOT @ 1,986' 2,403'Float Collar P!T Gauge @ 2,034' 1. , Sensor @ 2,039.48' 2,597'TD E Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 11, 2012 8:36 AM To: 'Kralick, Jack T' Cc: Allsup-Drake, Sharon K; Kanady, Randall B Subject: RE: revised procedure for Ignik Sikumi Jack, Very similar procedure and still meets 20 AAC 25.112 requirements ... you have verbal to proceed per your updated procedure. Make sure you document the pressure test on the bottom plug on step 11.3 (Chart/30min) I believe your sundry has been picked up by the courier already. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Kralick, Jack T [mailto:Jack.T.Kralick@conocophillips.com] Sent: Tuesday, April 10, 2012 2:46 PM To: Schwartz, Guy L (DOA) Cc: Allsup-Drake, Sharon K; Kanady, Randall B Subject: RE: revised procedure for Ignik Sikumi Hey Guy! We revised a procedure for Permanent Abandonment of the Ignik well. Haven't seen an approval on the original yet so please give us a verbal on this revised copy if you don't mind. Should be shutting in the well tonight and start rigging down. P/A should start as soon as most of the pad is cleared. How's the new wife and the old kids? Thanks Guy, Jack From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 10, 2012 10:59 AM To: Allsup-Drake, Sharon K Cc: Kralick, Jack T Subject: [EXTERNAL]RE: revised procedure for Ignik Sikumi Just send me an amended procedure ... I think it is approved already. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophillips.com] 4/13/2012 Page 2 of 2 Sent: Tuesday, April 10, 2012 10:16 AM To: Schwartz, Guy L(DOA) Cc: Kralick, Jack T Subject: revised procedure for Ignik Sikumi Guy— We need to revise the P&A procedure for the sundry we sent to AOGCC for well Ignik Sikumi 1. Should we send in another 10-403 sundry to cover the changes? Thank you, Sharon 263-4612 4/13/2012 McMains, Stephen E (DOA) From: Luelf, Kelly [Kelly.D.AllenLuelf@conocophillips.com] Sent: Tuesday, April 03, 2012 8:16 AM To: McMains, Stephen E (DOA) Cc: Pruitt, Stephanie R Subject: Ignik (Hydrate Well) Flaring cDTD. )1k Good Morning! You had asked that I shoot you a note once we figure out what happened with this well this month. Here's what I know. In March, 2012 (between March 4 and March 31)we flared the following volumes (at STP, 60°F & 14.696 psi): CH4: 530 mcf N2: 146.6 mcf CO2: 19 mcf These numbers seem very small to me. What volume is normally classified as de minimis under 20 AAC 25.235 (d) (4)? Also, assuming these events were greater than an hour, do they require a written supplement? We weren't sure since this is the exploratory"science fair project". Thanks Steve! Kelly Luelf ConocoPhillips Supervisor Revenue&Regulatory-Alaska 315 S.Johnstone;POB 930-G Bartlesville, OK 74004 kelly.d.allenluelf@ConocoPhillips.com Phone:918-661-1687 Fax:918-662-0162 AVE Ka ST", 1-e -. ,-/d3 r 11 ,2_ .2\ n LUL ( -F• j -e rA3 t 0-R_ iItte (3 In fR s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION❑ Other ❑ ETION OR RECOa ❑MPLETIOUNen ❑ I REPORT AND LOG la.Well Status: Oil Hydrates Well 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory D GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska,Inc. orAband.: April 28,2011 211-027/311-364 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 April 5,2011 50-029-23443-0000 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1858'FSL,2475 FWL,Sec.34,T12N,R11 E,UM April 16,2011 Ignik Sikumi#1 Top of Productive Horizon: 8.KB(ft above MSL): 30.7'RKB 15.Field/Pool(s): 1850'FSL,2480'FWL,Sec.34,T12N, R11 E, UM GL(ft above MSL): 52.9'AMSL Prudhoe Bay Field Total Depth: 9.Plug Back Depth(MD+TVD): 1848'FSL,2478'FWL,Sec.34,T12N, R11 E, UM 2597'MD/2597'TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-584119 y- 5977590 Zone-4 2597'MD/2597'ND ADL 28239 TPI: x-584123 y- 5977582 Zone-4 11.SSSV Depth(MD/ND): 17.Land Use Permit Total Depth: x-584121 y- 5977579 Zone-4 nipple @ 1927'MD/1927'ND na 18.Directional Survey: Yes ❑ No 0 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1760'MD/1760'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MDTTVD none not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# B-35 31' 108' 31' 108' 24" 185 sx ArcticSet 1 10.75" 45.5# L-80 31' 1473' 31' 1473' 13.5" 299 bbls ArcticLite Crete,128 bbls DeepCrete 7.625"x 29.7# L-80 29' 1964' 29' 1964' 9.875" 153 bbls LiteCrete I 4.5" 12.6# L-80 1964' 2592' 1964' 2592' 9.875" included above*cement to surface 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5" 1986' none A �f .® 2243'-2273'MD 2243'-2273' _a°�"+.,'' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. � � DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1S GO\S.Gym 27. P\aSKQ0 \t w`�otP�.OBCIGTION TEST Date First Production Method of Ope ' lowing,gas lift,etc.) February 12,2012 production flow test started 2/12/2012 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No 0 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. i NONE --'` r� J, "F(t .. .,- RSDMS APR 0 2 2012 44g;frk\ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE J Submit original only -i L .# f4ot/y 28. GEOLOGIC MARKERS(List all formations and r s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? U Yes E✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1760' 1760' needed,and submit detailed test information per 20 AAC 25.071. Sagavanirktok Upper C 2214' 2214' Sagavanirktok Upper C 2240' 2240' Sagavanirktok Lower C 2278' 2278' N/A Formation at total depth: Upper/Lower C 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Kralick @ 265-6870 Printed Name G.L.Alvord Title: Alaska Drilling Manager // Signature � Phone 265-6120 Date 304(2('(2-- Sharon i,(LSharon 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 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 ,..pt,� PBU IGNIK SIKUMI 1 ConocoPhillips Well Attributes Max An le&MD TD Alaska.Inc. Wellbore API/DWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) 500292344300 PRUDHOE BAY UNIT EXPLOR 0.53 2,457.02 2,597.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •Well Conlin:VERTICAL-IGNIK SIKUMI 1,3/24/20122:56.37 PM -$SSV:NIPPLE Last WO: 34.60 4/28/2011 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 2,350.0 4/30/2011 Rev Reason:Add Polish Bore Assy&Jet Pump ninam 3/24/2012 Casing Strings _- Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(TVD)... String Wt...String...String Top Thrd HANGER,26ri..- CONDUCTOR 16 15.062 32.0 108.0 108.0 62.50 H-40 WELDED - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 103/4 9.950 30.9 1,473.1 1,473.1 45.50 L-80 BTC (-- T Casing Description String 0... String to...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ______ __-_PRODUCTION 75/8 6.875 28.7 2,592.3 2,592.3 29.70 L-80 BTCM 7.625x4.5 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 41/2 3.958 26.5 1,985.9 1,985.9 12.60 L-80 IBT-M r 29 Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (RKB) (') Rem Description Comment ID(in) CONDUCTOR, 26.5 26.5 0.00 HANGER FMC TUBING HANGER 4.500 32-166 1,927.1 1,927.1 0.15 NIPPLE CAMCO DB NIPPLE w/3.875"PROFILE 3.910 1,942.1 1,942.0 0.18 NIPPLE CAMCO DB NIPPLE w/3.843"PROFILE 3.812 1,956.7 1,956.6 0.20 NIPPLE CAMCO DB NIPPLE w/3.750"PROFILE 3.750 p () 1,967.9 1,967.8 0.22 LOCATOR LOCATOR 3.880 II 1,968.9 1,968.9 0.22 SEAL ASSY SEAL ASSEMBLY 3.890 l Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) k ;. SURFACE, Top Depth 31-1.473 (TVD) Top Incl Top(ftKB) (RKB) (") Description Commend Run Date ID(In) 1,942 1,942.1 0.18 PUMP 3"JET PUMP(S/N:PH-1108,6C RATIO)w/SPACER PIPE 3/22/2012 &STINGER ASSEMBLY,OAL=200" 1,957 1,956.7 020 VALVE WEATHERFORD STANDING VALVE/POLISH BORE 3/22/2012 NIPPLE.1.927- - ..L.I: ASSEMBLY CHEMICAL, _S 2,224 2,224.0 0.44 SCREEN 3.687"DB LOCK SPACE PIPE SANDSCREENS AND SEAL 2/162012 1.929 .. ASSEMBLY Perforations&Slots NIPPLE,1,912 _ Shot PUMP,1,942\ Top(TVD) Btm(TVD) -vim Dens Top(MB) Btm(MB) (ftKB) (ftKB) Zone Drte -reType Comment GAS Ly 2,243 2,273 2,243.0 2,273.0 2/15/2012 )2.0 IPERF 2.88"PJ Omega gun,0/180 phased, MI .....' shots orientated 90 deg from blast VALVE.1,957 protectorsNIPPLE.1.957 ems' I LOCATOR, - 1,966 SEAL ASSY, 1,969 f Ilii • III SCREEN,2,224 IPERF, 2,243-2,273 1 II�'l , Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Sue TRO Run Stn Top(ftKB) (RKB) 1"1 Make Model lin) Sere Type Type (in) (psi) Run Date Com... 1 1,928.7 1,928.6 0.15 CAMCO KBMG-LTS 1 CHEM DMY BK 0.000 0.0 4/25/2011 2 1,943.6 1,943.6 0.18 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/302011 OE PRODUCTION 7,625x4.5. 29-2,592 TD,2,597 ConocoPhillips Time Log & Summary Weflview Web Reporting Report Well Name: IGNIK SIKUMI 1 Rig Name: CPAI IGNIK WELL TEST Job Type: TEST-LOG-PROFILE Rig Accept: 1/12/2012 12:00:00 AM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/12/2012 24 hr Summary Attended morning PJSM at Ignik Camp with camp personell and Prec. Power Electrician, Simplex Grannell. Spot Precision Power equipment(2 gen sets,2 fuel tanks,switch shack,equip.shed)in containment area. Applied heat to warm up equip.Set Wellhouse and applied heat to warm up tree. Continued working on camp.Wiring up alarm system(smoke detectors),telephones and computers. Bullcooks continue to prep rooms and kitchen. Super-chlorinated water has been circulated thru water system,waiting 24 hrs before flushing and testing. Lined up 3rd party services for potable water and waste water. Held pre-planning Gen-set installation duct work meeting. 00:00 00:00 24.00 SURPRI FLOWT RURD P Attended morning PJSM at Ignik Camp with camp personell and Prec. Power Electrician,Simplex Grannell. Spot Precision Power equipment(2 gen sets,2 fuel tanks,switch shack, equip.shed)in containment area. Applied heat to warm up equip.Set Wellhouse and applied heat to warm up tree.Continued working on camp. Wring up alarm system(smoke detectors),telephones and computers. Bullcooks continue to prep rooms and kitchen. Super- chlorinated water has been circulated thru water system,waiting 24 hrs before flushing and testing. Lined up 3rd party services for potable water and waste water. Held pre-planning Gen-set installation duct work meeting. 00:00 00:00 0.00 SURPRI RPEQPI PULL P 1-4-12 Pulled BPV and confirmed no VR plugs in annulus valves. Installed integral flanges and associated jewelry. 01/13/2012 Spot PP GenSets, Fuel Tanks, Switch Shack&apply heaters to warm up. Continue prepping camp. 00:00 00:00 24.00 SURPRI FLOWT RURD T All outside work ceased due to Phase weather conditions. Continued on inside camp work(fire detection system and water).Sent water samples to Lab for potable water. Install fire detection control panel. 01/14/2012 Weather hold Phase II.Continue on camp inside work. 00:00 00:00 24.00 SURPRI FLOWT RURD T Weather day,all outside work on hold for high winds and cold temps. 01/15/2012 Prep WH for Skimpy Panels,Spot rig mats for CO2 tanks.Move snow Page 1 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD T Clear snow after blizzard. Set rig mats&cribbing prepping for floats. Start installing duct work on Gen Sets. Precision Power connected fuel tanks to Gen Sets, preped Gen Set and Swich Gear Shear for start up.Continued prepping camp for move in. 31/16/2012 Clear snow from pad from blow. Spot two floats and rig mats for setting CO2&N2 tanks. Install platform inside wellhouse and install Skimpy Panels for both SSV's. Continued hookups for Prec. Power GenSets. Shut down all outside work because of Phase II weather. 00:00 00:00 24.00 SURPRI FLOWT RURD T Clear snow from pad from blow. Spot two floats and rig mats for setting CO2&N2 tanks. Install platform inside wellhouse and install Skimpy Panels for both SSV's. Continued hookups for Prec. Power GenSets. Shut down all outside work because of Phase II weather. 01/17/2012 Weather hold,25-35 MPH winds/Phase I/II. Continued working on Hook ups to Gen sets until weather hold. Civil crew worked on permanent well head platform and hung one Skimpy pannel. Spotted rig mats and floats for cryo tanks. 00:00 00:00 24.00 SURPRI FLOWT RURD T On weather hold, Phase conditions. Plan to perform camp safety inspection pending weather. 01/18/2012 Attempted to reach camp mid day for safety inspection convoy turned around at 1D pad due to poor driving conditions. Winds reduced during the night DTH able to remove snow with dozer and loader. 00:00 00:00 24.00 SURPRI FLOWT RURD T All outside work shut down due to Phase II weather. Camp alarm installation completed and tested. 01/19/2012 CPAI Safety performed camp safety inspection. Camp is approved for occupancy. Civil crew Installed second surface safety valve panel and continued work on permanent well head platform. Spotted SLB N2 tanks, CO2 tank, GMS, Line Heater,and SLB tool house Page 2 of 45 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT SFTY P Performed camp safety inspection mid morning with Al Bergh-Gary Gauthier CPAI safety and Keith Dukowitz Nordic camp manager. Camp is approved for occupancy. Precision power back up genset (power to block heaters on mains) went down during the blow. Back up has been taken in for servicing. Construction need to build stairs and a cat walk to fuel the Precision power tanks. Ordered out additional snow removal around precision power equipment and SLB staging sites. Two light plants and one heater down, requested service. Lynden delivered SLB equipment standing by for Peak crane. Civil crew continues to work on permanent well head platform. Second skimpy panel mounted. 3:50 pm spot crane to pic N2 tanks, CO2 tank,GMS, Line Heater,and SLB tool house. 01/20/2012 Off loaded remaining palletized SLB equipment from trailers. Installed temporary power the GMS unit for lights and heat. Unloaded GC, GMS computers,and Well Site Data Hub. Installed exhaust louver on Well site Gen set#1. 00:00 00:00 24.00 SURPRI FLOWT RURD P Phase 1 Level 1. Contacted SimOps for scaffolding crew to build stairs and catwalk to access fuel hatch during fueling of well site generators. 9:00 Held prejob safety meeting with Al Bergh CPAI safety, loader operator, SLB crews. Discussed off loading of remaining pallets from Lynden trailers, installation of well site gen set louvers. John Brooks Precision power to investigate temp power to GMS unit and SLB skid until main gen sets can be fueled. SLB crews pulled shipping plywood from GMS and removed snow from revetments around the 400 bbl upright tanks and 125 bbl Glycol tank and begin rigging up fittings. Precision power was able to run a temp power line to the GMS. The lights are on and the unit is warming up. One exhaust louver was successfully installed on Gen set#2. SLB transported the Gas Chromatograph, GMS computers, and the Well Site Data Hub to location. Phase 1 canceled at 5:30 pm Scaffold crew scheduled to walk down job site at 7:00 am. Page 3 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/21/2012 24 hr Summary Held pre job safety meeting. Unloaded and staged construction material. Installed exhaust louver on well site generator#2. Scaffold crew walked down job will return to construct stairs to access fuel tanks. Crews installed SLB treating line revetments. GMS unit is warm.Well head platform work ongoing. 00:00 00:00 24.00 SURPRI FLOWT RURD P 06:00, held pre job safety meeting in conference room. DTH loader operator stuck behind rig move showed up after 9:00 with trailer of construction material. Unloaded and staged construction material. Installed exhaust louver on well site generator#2 and fuel lines to both generators. Civil crew also stuck behind rig move showed up after 9:00 begin working on permanent well head platform. Platform required extensive modification due to tree design with double SSVs above the deck. Scaffold crew showed up —10:00 to walk down job and left. Hand-Y-Berm&SLB crews laid out treating line revetment for all SLB lines. Temporary gen set on GMS and Precision Power main generator block heaters failed. Gen set rigged down, removed and replaced. Temp Power to GMS back on entire unit is warm. Civil crew rigged down for the day, platform work ongoing. Held post job safety/planning meeting 19:00. 01/22/2012 Held prejob safety meeting. On weather hold, ambient temp below-35. DTH loader opperated under variance 7 to assist in trenching. installed SLB and HES fiber optic leads from camp to well house and GMS. Terminated SLB leads in camp and at GMS. Terminated HES leads at camp. Page 4 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 ISURPRI FLOWT RURD P 0600 pre job safety meeting.Wind chills-50-conducted safety assessment. 0700 HES crew on location prepping to lay fiber optic cable. 0730 ambient temp dropped to-36 all hydraulic equipment idled, per support groups cold weather operating policy. Canceled trenching operations regrouped and held ops meting. 0800 SLB mechanic and Precision power electrician on site moving forward with burner installation. 0900 cold weather variance signed with DTH allowing loader operations below-35F ambient. DTH dispatched with materials for insulated containment and loader mounted trenching device. 1030-38 F ambient. HES setting up DAS DTS equipment. 1515 making up 1"jointed conduit to burry SLB and HES lines. Gouged out a 4" trench from camp to the well house. Made up 1"rigid conduit,snaked HES and SLB lines through conduit to well head and GMS unit, lay conduit in trench and packed ice back in the trench. Terminated SLB leads in the GMS and camp. Terminated the HES leads in camp. -42 F. 01/23/2012 Held pre job safety meeting.Wind chills-80,-51 F ambient. Found ATF leak on pad after truck backed away from containment. Vehicle secured,Security notified and PIR e-mailed. Scaffold crew installed stairs to fuel tanks. Watered in the trench containing the fiber optic lines to the well. Crews laid out blue board insulation for all SLB surface lines and installed the 1502 high pressure treating iron gas line from the GMS to the well. SLB lost connectivity between their fiber optic line some time between 1100 and 1200. SLB mechanic installed the line heater burner assembly and Peak precision power hooked up temporary power. Attempted to test fire the burner but had issues with the controller. Page 5 of 45 Time Logs Date From To ` - Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD P 0600 pre job safety meeting.Wind chills-80,-51 F ambient-conducted safety assessment 0844 found ATF leak on pad in front of camp. Found Peak truck#K307 with transmission leak. Truck turned off,containment pool placed under transmission and tow truck called. Security notified and PIR e-mailed out. 0945 scaffolding crew on location setting stairs to fuel tank. 0952 watering in the trench containing the fiber optic runs to the well. SLB crew drove to DTH to cut support blocks for treating iron. 1200 scaffold crew finished stairs and catwalk to fuel tanks. Bulk fuel truck ordered, ETA 0800 1-24 Crews laid out blue board insulation for all SLB surface lines and installed the 1502 high pressure treating iron gas line from the GMS to the well. SLB lost connectivity between their fiber optic line some time between 1100 and 1200. Efforts were made to reestablish connectivity through all 6 pairs but failed. HES aided by measuring the distance of the continuous fiber optic line. It appears as if the break is near the well head. . SLB mechanic installed the line heater burner assembly and Peak precision power hooked up temporary power. Attempted to test fire the burner but had issues with the controller. SLB is scheduled to call burner manufacturer in the am. Temperatures continue to be very cold all outside work is very slow with warm ups. 31/24/2012 Held pre job safety meeting.Wind chills-80,-51 F ambient. Discussed continued cold weather and plan forward. All outside labor shut down unless work can be carried out with an enclosure and use of direct fired heaters to provide protection from the elements. SLB safety presented COP cutting policy,foul weather policy,traction policy, impact gloves,and when to go to the medic to the crew. Burner on the line heater fired successfully. No success reestablishing connectivity in the SLB fiber optic lines. Page 6 of 45 Time Logs Date From' To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD T 0600 safety/ops meeting. Discussed continued cold weather and plan forward. Well site fuel tank prepped for fuel delivery,wind break set up and nut plug down. 0800 call from town to discuss cold weather operations. All outside labor shut down unless work can be carried out with an enclosure and use of direct fired heaters to provide protection from the elements. Walking traffic allowed between the camp and GMS,work allowed in the GMS,well house,equipment connex,and line heater hooch,with hand tools, no power tools, large hammers or saws. On weather hold. Called CH2Mhill dispatch and canceled bulk fuel delivery until the weather breaks. Non mobile fuel continues as well as trucking of potable and waste water. 1328 SLB established connectivity to the Well Site Data Hub through the COP network. 1517 Peak wrecker leaving location with peak box van# K307. 1530 SLB safety held safety presentation covering COP cutting policy,foul weather policy,traction policy, impact gloves, and when to go to the medic. Burner on the line heater fired successfully. No success reestablishing connectivity in the SLB fiber optic lines. Water found in the conduit may have expanded and damaged the cable. 01/25/2012 Held pre job safety meeting.Wind chills-80,-51 F ambient. Found ice free conduit 70'back from the well head but unable to move cable.Mounted Isco syringe pump in GMS. Crew change. Extreme cold weather v' hold. 00:00 00:00 24.00 SURPRI FLOWT RURD P Held pre job safety meeting.Wind chills-80,-51 F ambient. 0729 found ice free conduit pipe 70'back from the well head attempting to move wire. It wiggles freely but will not pull by hand. Took 100'of 3"soft hose to KIC to warm it up in the shop. Mounted Isco syringe pump in GMS. Precision Power electrician checked fluids on the temp power gen set. Crew change. 01/26/2012 Continue to wait on weather. Reviewed site control/safe work area with crews. Fiber optic line pulled free in conduit. Held pre job meeting to discuss reinstalling cable then pulled additional cable to well head through new conduit. Reestablished connectivity to the GMS skid though the SLB fiber optic line. Established connectivity with XPIO,Gauge#1 937.602 psi Temp 41.004F,Gauge#2 909.061 psi Temp 40.236F,Gauge #3 816.561 psi Temp 36.557F While fueling temp generator riser burped spilling1/2 gal diesel into secondary containment. Diesel cleaned from containment with adsorbent and bagged for disposal. Page 7 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD P 0600 ops/safety meeting, new crew orientation. 0630 engineering ops call in. 0700 site control/safe work are review with crews. 0824 GMS temp gen set went down' tank of fuel, GMS still warm. 0900 lost three heaters. 0930 water truck attempting delivery frozen off, returning to shop to thaw. Fill in camp manager and staff alerted. Comm with crews to conserve water. 1100 attached cable clamp and com along to SLB fiber optic bundle. Applied a small amount of tension and cable popped loose,entire string is moving freely. Crews in for lunch and warm up. 1247 pre job meeting to discuss reinstalling cable. replacement heaters on location. Performed Visible fault locator(VFL) check of SLB cable,checked ok. Cleared trough of drifted snow and residual ice. Lay out replacement conduit. 1500 temp gen set back online. water delivered to camp. 1530 pulled additional cable to well head trough new conduit. 1545 new fiber pulled to GMS and well house. Checked SLB with VFL,checked ok. Pulled HES line into well house and SLB cable into GMS break for warm up. Spliced connectors onto the end of SLB fiber. 1900 connectivity to the GMS skid though the SLB fiber optic line. Temp gen set to GMS back down. Called electrician to replace GMS generator. No spare gen set at this time. Bringing new alternator. Established connectivity with XPIO,Gauge#1 937.602 psi Temp 41.004F, Gauge#2 909.061 psi Temp 40.236F, Gauge#3 816.561 psi Temp 36.557F.2100 electrician on site fueler on site. While fueling temp generator riser burped spillingl/2 gal diesel into secondary containment. Diesel cleaned from containment with adsorbent and bagged for disposal. Well Supt, notified,security notified, PIR emailed. 01/27/2012 HES acquiring data with DTS and DAS. Optimation established conection from GMS through Well Site data Hub to Interact server and transferred data. Modified Precision power temp gen set fuel fill riser. Had safety/ ops meeting with CH2M Hill fuelers Filled temp gen set with no issues. Page 8 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD P 0600 ops/safety meeting, new crew orientation. 0630 engineering ops call in. Water truck and fuel truck on location. Filling camp and non mobile equipment then bulk generator fuel tank. Additional safety/spill discussion outlining fill procedure and spill mitigations regarding temp generator and bulk well site fuel tank. 0900 HES at well head terminating DTS and DAS lines. Optimation established connectivity from GMS through Well Site Data Hub(WSDH)to SLB interact server in Sedalia. Precision power on location, installed shorter fuel riser-'4",stood by for fueling procedure,flagged and attached long fuel riser to generator for reinstallation before temp gen set is moved. Gen set fueled with no issues,elevated the front end, installed 4"riser. Discussed fueling the generator bulk tank. This is not the bulk hose,they have no connection to dry lock. Abort attempt until proper hose with dry lock can be used. Held safety ops meeting with CH2M Hill fuelers regarding 5000 gal bulk tanks fill procedure. 2"dry lock male to be installed on ULSD generator tank. 3" male dry lock to be installed on LEPD tank for line heater. Small fuel truck to be used for filling camp, non mobile equipment,and well site generators. Large bulk truck will be used to fill SLB line heater. 1425 HES terminating their fiber optic cable at the camp. 1500 acquiring DAS data. 1600 acquiring DTS data. 1800 SLB crew performed walk around. Temp GMS gen set still operating. 01/28/2012 Valve crew serviced tree valves and filled flow back SSV with hydraulic fluid. Rigged iron from GMS to edge of well house on fluid side and from well house to 125 bbl tank on flow back side. Hooched and heated main power spools Page 9 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD P 0600 ops/safety meeting. 0630 engineering ops call in. Phase 1 driving conditions due to slick roads, drifting snow,and lack of maintenance. Scheduled Down Hole Diagnostics(DHD)crew to perform MITT/MITIA on 1/22/12. Contacted valve shop re service tree valves. Discussion over wind chill as it relates to equipment. Scheduled to service tree as soon as reasonably possible. Lost 3 heaters during the night. 0900 day mechanic on location to start loader. Requested Peak Precision power bring grinder and ground plates for bonding. 1320 loader up and running waiting on DTH operator. 1400 valve crew on location to service tree. 1420 loader operator on location spotting power cables. 1530 valve crew serviced tree valves and filled flow back SSV with hydraulic fluid. Attempted to fill injection side SSV with hydraulic fluid,exterior mounted dump valve failed and was leaking by to dump reservoir. Rigged iron from GMS to edge of well house on fluid side and from well house to 125 bbl tank on flow back side. Hooched and heated main power spools. Loader operator smelling fumes in cab suspects heater core leak. No drips apparent. Stopped loader,attached drip pan to loader with sash cord and returned the loader to KOC shop for PM/ repair. 01/29/2012 Pulled wire to all SLB equipment, ongoing. Lay out and rigged up hard hose, ongoing. Performed MIT-T- Passed, MIT-IA, passed. IA shows communication with the chemical injection line. Drift well to 3.58"to 2350' Page 10 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD 0600 ops/safety meeting. 0630 engineering ops call in. 0800 DHD on location, held pre job, issues with wellbore sync, reviewed well bore schematic and procedure with crew.0926 DTH on location delivering cut plywood for revetment base. Peak Precision power on location running small gauge wire. 0930 DTH update on loader approximately 1 hr out. 1030 DHD on location to perform MITT/MITIA. Fluid levels at surface,T/I/O=0/0/40 C1=0 Heater =0 Pumped IA to 400 and tubing to 3000 psi. Start T/I/O=3000/440/40 CI=420, Heater 510. 15 min T/I/0=2900/400/40 CI=445 Heater 500. 30 min T/I/O=2850/400/40 CI=440 Heater 400. 45 min T/I/O= 2850/400/40 C1=325 Heater=390. Tubing passed. Bleed CI line, IA tracked. Bleed Tubing. MITIA initial T/I/O=600/75/40/CI =0 Heater= 50. Start T/I/O=100/3000/40 CI 2950 Heater=2950. 15 min T/I/O= 1050/2800/40 CI=2800 Heater= 2810. Bumped pressure,T/I/O= 1100/3000/40 C1=3000 Heater= 3000. 15 min 1/1/0=1100/2960/40 C1=2960 Heater=2950.30 min T/I/O = 1100/2950/40 C1=2940 Heater= 2950 Passes IA to T but CI in communication with the IA. Bleed CI line,T/I/O 1080/2525/40 C1=2500 Heater=2500. Bleed CI line second time T/I/O 980/1950/40 CI=1925 Heater 1960. Shut down stung into test port with test tool,void at 0 psi, clean test fluid. Tried to bleed CI again will not bleed down,frozen line at bleed tank. Thaw lines and pump 10 gal diesel down CI line. Rig down DHD. Run power lines to all electrical. SLB equipment and begin to terminate lines. Lay hard hose from 125 bbl tank to GMS continue to build insulated boxes. Slick line on location, RU,drift W 3.58"to _ 2350' RDMO 01/30/2012 Temps dropped to-40 F. Filled well site generator tank. Installed discharge hoses from GMS to SLB line heater and GMS to 125 bbl tank. Staged tree iron in well house.Terminated GMS power lead at switch shack and both leads of SLB connex. Page 11 of 45 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 SURPRI FLOWT RURD P 0600 ops/safety meeting. 0630 engineering ops call in. 0700 walked through possible wellview reporting issues with support. Can't find a problem. Note,some time log entries on second page of report because they are too long and not broken out. 0745-35F winds calm. 0859 cold weather alert-36F all hydraulic driven equipment need Supt variance to operate. 0915 alerted that the camp has no water service.Water back up,then down, then up again. Fueled the well site generator main tank 3700gal. Constructed and installed all discharge hose from SLB line heater to GMS and GMS to 125 bbl open top tank. Valves and T's placed to tie into Expro treating lines once on location. Heated all high pressure valves on SLB heater,shut in bypass,opened suction and discharge valves.Staged tree iron in well house. 1245-40 F ambient crews traveled to KOC for CPA Supt orientation meeting and to construct hard hoses in KOC shop. Precision power terminated GMS power leads at switch shack and both leads of SLB connex. 01/31/2012 Unloaded 3700 gals. USLD fuel for Glycol Heater.Continue building blue board boxes for hoses. Accepted dilivery of 4000 gals N2 and loaded into N2 tanks. . Hardwire CO2 tank electrical plug. Optimation worked on Inter-Act channels for data transfer. 00:00 12:00 12.00 SURPRI FLOWT OTHR T Cold weather alert-36F all hydraulic driven equipment need Supt variance to operate.Current conditions-44F Winds SW 6 mph. Unloaded 3700 gals. USLD fuel for Glycol Heater. Continue building blue board boxes for hoses. 12:00 00:00 12.00 SURPRI FLOWT RURD P Accepted dilivery of 4000 gals N2 and loaded into N2 tanks. Discovered that CO2 tank plug is incorrect. Made dicission to hardwire CO2 tank (original plan).Optimazation worked on Inter-Act straightening out channels. 02/01/2012 Attend morning PJSM.Continue SLB hookup as much as possible under weather conditions. Peak ordered disconnects for transfer house. 00:00 12:00 12.00 SURPRI FLOWT OTHR T Cold weather alert-36F all hydraulic driven equipment need Supt variance to operate.Current conditions @ 0600 hrs -46F Winds SW 6 mph, temps dropped to-51 F. Page 12 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 SURPRI FLOWT OTHR P Continued blue board construction. Change out day for SLB. Built blanking caps for PT lines w/N2. Hang fall retractable harness on line heater. Put double thread 206 on suction and discharge of 125 bbl tank for Expro hookup. Worked on connex.Work on N2 guages. Made supply and return hoses for N2 and CO2. Peak ordered disconnects for transfer house.Waiting on parts for finishing electrical. 02/02/2012 Electricians pulled wire, relocate and reconnect transformer. Ground all equipment present on location . SLB continued blue board boxes. Pressure test all lines. Pressure test all lines and work on blue board. 00:00 12:00 12.00 SURPRI FLOWT RURD P Temps warmed up this morning-29 F. Resumed work. Electricians pulled out 500 MCM cable from GMS skid. Relocaated 50 amp fuse disconnect.C/O transformer to SLB tool house. Reconnect heaters to 50 amp disconnect to SLB tool house power feeder. Everything on site except Expro equipment(not arrived) has been grounded. Mounted 100 amp disconnect to CO2 tank. Parts have been Goldstreeked today. ETA =Friday. 12:00 00:00 12.00 SURPRI FLOWT RURD P SLB, pressure test hoses&secure to hard line.Work on blue board. Expro crew arrived,set in on Kuparuk Orientation and issued badges. 02/03/2012 Filled line heater w/Tritherm 42 bbls.Tested chem. inj. line to 1100 psi(ice plug?). Performed PPOPT test on uper seal seal of W.H. Pressure test hoses with air. Installed knife for connex heat and CO2 tank. Page 13 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 SURPRI FLOWT RURD P PJSM&opts meeting w/SLB& Expro&Pinnacle.Covered all orientations,site control, Kuparuk and the 2012 Denali Ascent. Load SLB line heater w/42 bbls TriTherm. Performed PPPOT Test on top seal of wellhead. Set rack of N2 bottles near wellhouse. Installed a high pressure hose from the IA to the open top tank w/needle valves to control bleed to the bleed tank. Install high pressure hose from the N2 bottles to the Chemical injection valve on the wellhead.Opened N2 bottles to the needle valve on the chem. inj. line(1100 psi bottle pressure)Open needle valve to the chem inj. line and it pressured up immediately to 1100 psi. Held pressure for 10 min. No movement. Closed needle valve,bled press from hoses and disconneted. Bled pressure down from chem. inj. line from 1100 psi to 0.Closed needle valves. RD. 12:00 00:00 12.00 SURPRI FLOWT OTHR P Pressure test discharge hoses. Attempt to run line heater and adjust burners but unable to get fuel from Precision fuel tanks.Applied heater to suction lines. Hooked up pressure sensor cords from GMS to tanks. Pressure test hoses from N2&CO2 tanks. Knife swithch installed for the CO2 tank. Knife switch for the connex heat installed. 02/04/2012 Finish Blue board, work on Fuel Tanks,dial in Heater,install SSV Control in GMS, mounted all disconnet& wired,terminate to GMS& bring Gen on line. 00:00 12:00 12.00 SURPRI FLOWT RURD P PJSM w/both crews(SLB&Expro). SLB clear fuel lines and get fuel flowing from tank to line heater and generators.Start up line heater and adjust burner. Install SSV control in opts cab of GMS. Installed battery covers on valves on N2&CO2 tanks &electric cords. Finished blue board boxes. 12:00 00:00 12.00 SURPRI FLOWT RURD P Mounted and wired 4 disconnects. Terminate to GMS and bring Generators on line. Expro cleaning out tank farm containment removing snow and prepping for arrival of equipment. Page 14 of 45 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02/05/2012 24 hr Summary Received and unloaded Atigun House and two other loads for Expro. Rig up to well for warming ops. Double check that we are able to pump down the flatpack,or the annulus. Also verified we can circulate as planned. PT Hardline for Glycol system Wire in AC to CO2 Tank,Testt Peak CO2 Tank Power Umbilical for CO2 Transport Pressure test HP Glycol lines. Ensure we have valves to circulate through the heating coils. Displace Diesel into 125 BBL Tank 00:00 12:00 12.00 SURPRI FLOWT OTHR P Received and unloaded Atigun House and two other loads for Expro. Rig up to well for warming ops. Double check that we are able to pump down the flatpack,or the annulus.Also verified we can circulate as planned. PT Hardline for Glycol system Wire in AC to CO2 Tank,Testz, Peak CO2 Tank Power Umbilical for CO2 Transport 12:00 00:00 12.00 SURPRI FLOWT OTHR P Pressure test HP Glycol lines. Ensure we have valves to circulate through the heating coils. Displace Diesel into 125 BBL Tank 02/06/2012 Transfer load of CO2 to tank.Continue to circulate warming wellbore.Trouble shoot main generator,and connect up Expro. Expro continue to rig up. 00:00 12:00 12.00 SURPRI FLOWT OTHR P Continue circulating Glycol/water adjusting the circulation temps& rate through the line heater to manage the wellbore temperature. Brought temps up at 60'to 32 F,61 F at the turn around 1968'. 12:00 19:00 7.00 SURPRI FLOWT OTHR P Expro continue rig up and waiting delivery of last two loads of equip. CO2 arrived, purged tank and loaded 22 tons into our tank. PP electrician trouble shoot generator and hard wire power from the gen-set to the heater for the CO2. 19:00 00:00 5.00 SURPRI FLOWT OTHR T Ceased operations to work on CO2 tank.Wait on CO2 transport to return and empty tank.Contacted BP L&V Pad Operator and advised of small CO2 leak and will keep him advised. 02/07/2012 Install guard rails around CO2 tank upwind.Wait on Air Liq.CO2 transport to come back and empty CO2 tank. 00:00 00:00 24.00 SURPRI FLOWT OTHR T Install guard rails around CO2 tank upwind.Wait on Air Liq. CO2 transport to come back and empty CO2 tank.Monitor and keep pressure on CO2 tank above 200 psi. All work on pad on hold until problem is remedied. Page 15 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/08/2012 24 hr Summary Offloaded CO2 onto truck. Depressurized tank. Repaired tank.Started filling CO2 tankw/N2 for PT Built Hootch over CO2 tank to keep warm. Expro cont'd rig up. Electrician trouble shooting generator. 00:00 12:00 12.00 SURPRI FLOWT OTHR P 0300 Air Liquide CO2 truck arrived on location. Off load CO2 from tank to truck. Depressurize CO2 storage tank. Inspected tank in area of leak and found 1 1/2"nipple not screwed into coupling tight enough and nipple was broken in the thread section. Chased threads on collar, replaced 1 1/2'nipple,secured all fittings with proper torque. 12:00 00:00 12.00 SURPRI FLOWT RURD P Re-start circulating Glycol,warming up wellbore.Start filling CO2 tank with N2 for pressure test. Sent CO2 truck to KIC shop to warm up. Built a hootch over the CO2 tank and applied heat to keep tank temp above 0°F. Expro continued rig up. Electrician trouble shooting generator problem. Rig up prep for Coil Tubing. 02/09/2012 Continue warming well bore. Plumb GC unit.Terminate the electrical on the GC unit.Continue to trouble shoot the Primary Generator. 00:00 12:00 12.00 SURPRI FLOWT OTHR P Continue pumping glycol warm the well bore. Plumb in the GC unit and terminate the electrical. 12:00 00:00 12.00 SURPRI FLOWT OTHR P Precision Power(Peak)continue to trouble shoot the Primary Generator. Expro continue rigging up for flowback. 12:00 Reversed Glycol flow to down the annulus and return up the Flat pack. Shut down heating of well bore,temps were over 40°F thru-out the annulus. 02/10/2012 Inspect CO2 Tank.Trouble shoot Generator. CT clean out of well bore. CT lost gear box.Start repair. 00:00 07:00 7.00 SURPRI FLOWT RURD P MIRU, PJSM WITH SLB N2 PUMPERS, LRS,CTS,WELL ENGINEER, WELL SITE SUPERVISOR.COMPLETE RIGGING UP CT, LRS, N2 UNIT AND GMS SKID. PRE-JOB ON PT. PT HARDLINE AND LUBRICATOR WITH LRS TO 350/4000 PSI. PT N2 LINES AND GMS UNIT WITH N2 TO 500/3800 PSI. 07:00 09:00 2.00 SURPRI FLOWT OTHR P DISPLACE CT WITH 30 BBLS, 104 DEGREE SEAWATER. MU SOL ONLINE FOR 8 BBLS 1.1 BPM CIRC PRESS=3000 PSI. 09:00 09:30 0.50 SURPRI FLOWT OTHR P OPEN WELL. ZERO AT TBG HANGER, PUH TO BUMP AT STRIPPER. RIH PUMPING AT 1 BPM. CIRC PRESS=2750 PSI. MU-SOL AT NOZZLE AT 2000 FEET. Page 16 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:15 0.75 SURPRI FLOWT OTHR P INCREASE RATE TO 1.2 BPM PUH AT 60 FT/MIN TAG STRIPPER. 10:15 11:00 0.75 SURPRI FLOWT OTHR P ONLINE WITH SEA WATER RIH TO 2039'CTMD COLD WATER ONLINE AT 140.7 MM TOT. CIRC PRESS= 3850 PSI.WAIT AT 2039' FOR COLD WATER TO EXIT NOZZLE. 11:00 11:30 0.50 SURPRI FLOWT OTHR P RIH TO 2139'AT 30 FPM PER K.L.M.WAIT AND MONITOR TEMPERATURES. 11:30 11:45 0.25 SURPRI FLOWT OTHR P DECREASE RATE TO.8 BPM CIRC PRESS=2037 PSI. DECREASE RATE TO.5 BPM.CIRC PRESS= 1116 PSI. 11:45 12:45 1.00 SURPRI FLOWT OTHR P LINE UP SLB N2 DOWN THE CT TAKING RETURNS UP THE CT ANN.AT 350 SCF. RIH AT 30 FPM. TAG AT 2353.6' PUH 10 FEET AND WAIT ON N2 TO EXIT NOZZLE. PUH DISPLACING H2O FROM TBG AT 35 FPM. 12:45 14:15 1.50 SURPRI FLOWT OTHR T LOST ALL HYDRAULIC PRESSURE TO UNIT.CLOSED PIPE RAMS. AND MANUALLY LOCKED. INCREASED N2 TO 1500 SCF BLOW DOWN CT AND CT ANNULUS.MECHANIC ON LOCATION. DIANOSED PROBLEM UNIT SHUT DOWN PENDING REPAIRS. 14:15 00:00 9.75 SURPRI FLOWT OTHR T Expro continue rig up 90%complete. SLB work on GC w/Keith. Prec. Power trouble shoot Generator. Alaska State Boiler&Vessel Inspector on location and inspected SLB's CO2 Tank with no problems. 02/11/2012 Finished repairs on gearbox of Coil Tubing Unit.Completed wellbore clean out. Purge coil tubing with Nitrogen. Displace 4 1/2"tubing w/traced N2:CO2 blend. 00:00 05:00 5.00 SURPRI FLOWT RURD T Precision Power Electrician waiting on Cummins Technician and parts to repair Primary Generator.SLB repair software delay. Practice,set up for testing.flowed mixed gas out Bruce valve w/tracer,tested with GC. Opened CO2 tank to make sure lines are clear. Expro and Scaffolding crew constructed Hootch over end of Atigun Building.Waiting on crane for setting up flare and adjusting upright tanks.Will share crane with perforators. 05:00 08:30 3.50 SURPRI FLOWT OTHR T WAIT FOR MECHANICS TO COMPLETE REPAIRS TO UNIT. Page 17 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:00 0.50 SURPRI FLOWT OTHR P PJSM AND OPS MEETING, FUNCTION OPEN BOPE,OPEN CHOKE. PUH , RIH ADJUSTING RIH SPEEDS TO FUNCTION CHECK HYDRAULICS. N2 PUMP COOLING DOWN. RIH TAG PO BUSHING CORRECT DEPTH TO 2371'. PUH TO 2361' 09:00 09:45 0.75 SURPRI FLOWT OTHR P PT N2 PUMP TO 500/4000 POUNDS. ONLINE N2 DOWN CTAT 500 SCF. INCREASE RATE TO 1500 SCF. 09:45 10:45 1.00 SURPRI FLOWT OTHR P WHP=150 PSI PUH AT 15 FT/MIN. CIRC PRESS=1475 PSI. PARK CTAT 1994'CIRCULATE N2 DOWN THE CT AND UP THE CT ANN. 10:45 12:00 1.25 SURPRI FLOWT OTHR P SHUT DOWN N2, LINE UP TO REVERSE CIRC DOWN THE CT ANN AND UP THE CT. RIH TAG AT 2371' REVERSE CIRCULATE. WATER AT SURFACE H/L AT TANKS FREEZING HOOKED UP HEATERS HAD METH. DELIVERED.SLIPSTREAM DOWN STREAM OF CHOKE. 12:00 14:30 2.50 SURPRI FLOWT OTHR P POOH TO SURFACE BLEEDING DOWN WELLHEAD AND CT. H/L CONTINUING TO FREEZE OFF. WORK TO BLEED DOWN. CT FROZEN. 14:30 16:30 2.00 SURPRI FLOWT OTHR P PUMP 1 BBL MEOH TO CT. COOL DOWN N2 PUMPERS ONLINE WITH N2 CIRC PRESS=200 PSI INITIAL. PRESS INCREASED TO 2200 PSI. PRESS BROKE OVER TO 1000 PSI. PRESS. INCREASED TO 2100 PSI BROKE OVER TO 1400 PSI. PRESSURE INCREASED TO 2400 PSI. 16:30 17:45 1.25 SURPRI FLOWT OTHR P PRESS. BROKE OVER. GETTING N2 BACK AT TANKS. 17:45 18:15 0.50 SURPRI FLOWT OTHR P PURGE CT.750 SCF INCREASE RATE TO 1000 SCF 18:15 19:00 0.75 SURPRI FLOWT OTHR P CONTINUE PURGING CT CIRC= 1230 PSI.SHUT DOWN N2 FOR PRE JOB 19:00 19:45 0.75 SURPRI FLOWT SFTY P PJSM TO PUMP N2/CO2 BLEND. ON LINE N2 DOWN THE CT AT MIN RATE RIH TAG AT 2364'PU TO 2360' 19:45 20:15 0.50 SURPRI FLOWT OTHR P ONLINE WITH N2/CO2 DOWN THE COIL WHP=500 PSI. DHP AT 2292' MD=555 PSI. RATE=220 KG/HR 20:15 20:45 0.50 SURPRI FLOWT OTHR P WHP=540 PSI, DHP=560 PSI, RATE=220 KG/HR TRACER GAS STILL MONITORING LOW. Page 18 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:15 0.50 SURPRI FLOWT PULL P POOH AT 75 FPM RATE=220 KG/HR, BHP=565 PSI,WHP=540 PSI. 21:15 22:15 1.00 SURPRI FLOWT OTHR P ON SURFACE CLOSE IN CHOKE. INCREASE WHP TO 600 PSI. SHUT IN SWAB.ONLINE WITH N2 DOWN THE CT. 22:15 00:00 1.75 SURPRI FLOWT RURD P RDMO LOCATION STAGE ON PAD 02/12/2012 MIRU E-line and crane. Run tie-in Log&Map cables.Adjust BHP. MU Perforating assy. RIH and Tie-in Perforate. 00:00 04:00 4.00 SURPRI FLOWT RURD P SLB. Bled down CO2 and N2 tanks. Found and repaired leak in the Tracer line.Continued rig up of hoses for Heater string for the upright tanks. BHP=625 psi. 04:00 08:30 4.50 SURPRI FLOWT SFTY P Depart Deadhorse WL shop to Gun Shop and secure 2 ea. 30' guns.Travel to Ignik Sikumi.Arrive on location and obtain clearance to access Ignik Sikumi Pad. Meet SPOC. Tailgate PJSMN and wait on final ramoval of coil tubing set-up equipment. Spot up e-line unit and spot-up third party crane. 08:30 13:30 5.00 SURPRI FLOWT PULD P Make up lubricator;test lift to confirm crane and grease hoses will reach. Finish picking up pressure equipment. Make up tools (completion mapper,WPPT and Gyrodata gyro tool)and perform tool checks.Move to well. Stab on well and line up for pressure testing using field triplex and diesel. PT 500-psi low; 1400-psi high. 13:30 15:00 1.50 SURPRI FLOWT P Bleed/blow down. Break off stack at quick connect.Stab off at quick connect and pump out all excess PT fluid below pump in sub and above swab valve. 15:00 22:30 7.50 SURPRI FLOWT P Open well and RIH WPPT with gyro. Performed completion mapping to 2350'using completion mapper with WPPT and Gyrodata tools. Determined clockwise tool spin(both RIH&PUH)at one full rotation per approximately 210'travelled or 1.7-deg/ft. Confirmed good signature from metal blast protectors on cable outside tubing, but rotation change from centralizer drift requires additional interpretation/investigation. 22:30 00:00 1.50 SURPRI FLOWT P POOH and rig back for night. 02/13/2012 Continued completion mapping logging to confirm toolface orientation for Perforating. Page 19 of 45 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 SURPRI EVALWE ELOG P Continue completion mapping logging to confirm toolface orientation for perforating. 12:00 00:00 12.00 SURPRI FLOWT PULD P Change out AES crane and replaced w/Peak crane for possible 24 hr coverage. Used AES crane for setting up flare stack and putting steps on upright tanks. Set up containment around truck loading area. 02/14/2012 Added 30'section to crane to lubricate long perforating tool string. Replaced primary well site generator control module and started same. Pressure tested SLB GMS to 2000 psi and loaded tubing with traced 77% N2:23%CO2 to 1400 psi. 00:00 12:00 12.00 SURPRI FLOWT OTHR P Changed out at F-wing and drove to location. Peak crane crew added a 30'extension section of lattice. 12:00 00:00 12.00 SURPRI FLOWT OTHR T Peak Precision Power on site with Cummins mechanic to change out the engine control module of the primary well site generator. Generator successfully started and allowed to run. 20:40 SLB E-line arrived on location, performed safety/SimOps meeting. E-line crew MIRU and surface tested tools. 21:00 performed pre job safety and SimOps meeting with SLB wells services crew. Pressure tested SLB GMS and treating iron to the wing valve to 2020 psi. Walked pressure up to 1100 psi shut down and walked treating lines. Pressured up GMS and treating iron to wing valve to 2020 psi and shut in. Test good. Bled tubing to 1000 psi. 21:30 lined up to the tubing and began to load well with mixture of traced 77%N2:23%CO2. 22:37 slowed rate to 200 kg/hr @ 1403 psi. 22:45 down on the pump T= et-4 1425 psi. 02/15/2012 Perforated 2243'-2273'with 2.88"PJ Omega gun loaded 2 SPF 0/1.80 phased., Shots oriented 90 deg from blast protectors. Established injection of SF6 traced gas mixture 77%N2:23%CO2 into zone. 00:00 00:30 0.50 SURPRI PERF PERF P E-line PT'd lubricator to 3000 psi 00:30 02:30 2.00 SURPRI PERF PERF P Bled and drained lubricator. Re shot through tools to confirm communication. Pick up perf guns. Perforating charges 2-7/8"OD Power Jet Omega,2906,0&180 phase,2 spf. Page 20 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 05:00 2.50 SURPRI PERF PERF P RIH tied in and oriented guns in preparation to fire. Encountered electrical issue with GMS unit. N2 soft start relay is tripping. Replacement parts located and Peak electrician dispatched from Deadhorse. 05:00 08:00 3.00 SURPRI PERF PERF T Wait on electrician. 0700 electrician on pad with replacement parts. 0755 Soft start repaired pumps back on line. 08:00 08:30 0.50 SURPRI PERF PERF P 0803 Come on line with SF6 traced N2:CO2 blend venting out the Bruce valve 2"valve closed to well. Tubing pressure 1342 psi at the second gauge. 0815 fired guns, indication of fire noted. CCL to top shot 25.8' CCL stop depth 2217.2' Shot 2243-2273'with 2.88"PJ Omega gun loaded 2 SPF 0/180 phased. Shots oriented 90 deg from blast protectors. Open 2"to well close Bruce valve. E-Line pulling out of hole. 08:30 08:45 0.25 SURPRI CHEMTIOTHR P Down on pumps. Shut in pressure 1390 psi. 2"valved closed. 08:45 09:45 1.00 SURPRI CHEMTI OPNW P Observe pressure fall off to 1351 adn 43 F at gauge#2. WHP 1110 psi. SLB E-line rigged off the well. All shots fired. Released crew. 09:45 10:45 1.00 SURPRI CHEMTI OPNW P Start pumping 1354 psi and 43 F, mass flow 200 Kg/Hr(1 Kg/hr is approx 710 SCF/day). Shut down pumps at 1552 psi and 43 F at second gauge. Monitor pressure and temp @ 10:45 1507 psi and 42F. 10:45 11:15 0.50 SURPRI CHEMTIOTHR P Start pumping at 200 kg/hr with 2" open. At 1598 psi stop pumping 2" closed. 11:15 14:00 2.75 SURPRI CHEMTIOTHR P Monitor pressure fall off to 1391 psi 14:00 16:00 2.00 SURPRI CHEMTIOTHR P start pumping at 50 Kg/hr 1383 psi at gauge#2. Gauge#2 pressure slowly increasing to 1417 psi. at 20:00 16:00 00:00 8.00 SURPRI CHEMTIOTHR P Continue to inject mixed traced gas reducing rate to maintain 1420 psi at gauge#2 02/16/2012 Set sand screen and loaded Nitrogen storage tank#2 with 1900 gal product. Started primary wellsite generator and switched to same. 00:00 05:30 5.50 SURPRI CHEMTIOTHR P Pumping traced,mixed N2:CO2 into formation. 05:30 07:00 1.50 SURPRI CHEMTIOTHR P SLB/Expro morning Safety/Ops meeting and Morning call in Page 21 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:30 3.50 SURPRI CHEMTIOTHR P Slickline on location with sand screen assembly. Hold pre job with crew and third party crane operator. Walk down well head,SLB&Expro equipment with HES slickline crew. Valve crew on location,service swab and injection side wing. Slickline assembling lubricator and screen. 10:30 11:30 1.00 SURPRI CHEMTI OTHR P Problem Wells Supervisor on location to inspect location and prep for Alaska Oil and Gas Commission witnessed Mechanical integrity test of the Inner annulus. Walked down side and discussed procedure. 11:30 13:30 2.00 SURPRI CHEMTI OTHR P Continue to pump traced, mixed N2:CO2 into formation. Start to lift lubricator. Shut down pick due to excessive flex in lubricator. Discuss plan forward. SL crew to source additional 5.5"lubricator. 13:30 15:30 2.00 SURPRI CHEMTIOTHR P Shut down GMS @ 13:16 to swap to primary well site generator and install updated GMS software. 15:30 16:30 1.00 SURPRI CHEMTIOTHR P Primary well site generator on line. GMS well bore heater string circulation back on line 15:01. GMS cryogenic pumps cooled down, pressure up,and operating 15:15. HES Nitrogen tanker on location 16:00. Off loaded 1900 gal liquid N2 into Nitrogen tank#2. 16:30 17:30 1.00 SURPRI CHEMTI OTHR P Picked up SL lubricator and rigged up to the well. Shut in upper master and opened the swab. Pressure tested the lubricator with traced mixed N2:CO2 to 1400 psi. Bled lubricator to 1240 and opened up to well. Drift and tag with 3.60"gauge ring. Tagged at 2371' POOH. Shut swab and bled off lubricator to bleed tank. Lubricator plus surface equipment is 22'of 41/2(ID 3.958") and 60'of 5 1/2(ID 5.00"). Pumping traced mixed N2:CO2 to formation at 20 kg/hr. 17:30 19:30 2.00 SURPRI CHEMTI OTHR P Out of hole, lay down lubricator, make up sand screen,OL 56'8.5", load in lubricator. Third party crane crew changed out from day to night operator. 19:30 21:30 2.00 SURPRI CHEMTIOTHR P 19:15 picking lubricator with sand screen. Pressure tested lubricator to 1310 psi with traced, mixed N2:CO2. 20:06 RIH,set down, hand spang sand screen into seal assembly, pull to establish latch,sheared off 20:38. POOH. 21:07 slickline off the well and rigging down surface equipment. Page 22 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 02:30 5.00 SURPRI CHEMTI OTHR P Continue pumping traced, mixed N2:CO2 into formation @ 1410 psi middle down hole gauge and 20 Kg/ hr. 02/17/2012 Continued pumping traced mixed gas(77% N2:23%CO2)at 17-24 kg/hr to maintain 1420 psi on XPIO gauge @ 2226'MD. Performed Mechanical Integrity Test of the Inner Annulus(MITIA)-failed. Suspect thermal contraction of fluid not a leak.-ongoing 00:00 02:30 2.50 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 18 Kg/hr 1410 psi on XPIO gauge @ 2226'MD 02:30 06:00 3.50 SURPRI CHEMTI OTHR P Bled gas from top of N2 pump. Pumping traced mixed gas(77% N2:23%CO2)at 18 Kg/hr 1411 psi on XPIO gauge @ 2226'MD. 06:00 09:00 3.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 18 Kg/hr 1412 psi on XPIO gauge @ 2226'MD. Increased pump rate to 21 KG/hr to hit target bottom hole pressure of 1420 psi at 0900. 09:00 09:30 0.50 SURPRI CHEMTI OTHR P Walking up pressure to 1420 psi max. Pumping traced mixed gas (77%N2:23%CO2)at 23 Kg/hr 1415 _ psi on XPIO gauge @ 2226'MD. 09:30 10:00 0.50 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 23 Kg/hr 1418 psi on XPIO gauge @ 2226'MD. 10:00 10:30 0.50 SURPRI CHEMTIOTHR P Slow rate to 22 Kg/hr. Pumping traced mixed gas(77%N2:23%CO2) at 22 Kg/hr 1420 psi on XPIO gauge @ 2226'MD. 10:30 11:30 1.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 20 Kg/hr 1421 psi on XPIO gauge @ 2226'MD. Reduce rate to 19 Kg/hr to maintain pressure at 1420. 11:30 14:30 3.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 19 Kg/hr 1420 psi on XPIO gauge @ 2226'MD. 1421 psi @ 14:45. Reduce rate to 18 Kg/hr to maintain pressure at 1420. 14:30 17:30 3.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 17 Kg/hr 1420 psi on XPIO gauge @ 2226'MD. 1421 psi @ 14:45. Pre job for MITIA at 17:10. Open swab to monitor Tubing pressure for MITIA. Tubing pressure at middle gauge dropped to 1418 then 1415 psi. Increased rate to 24 kg/hr to raise tubing pressure. Page 23 of 45 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 17:30 18:30 1.00 SURPRI CHEMTI OTHR P Performed pre witnessed MITIA- failed. Shut down glycol circulating pump. Double blocked returns to the 125 bbl glycol open top tank at the wellhead. Begin o pressure up IA. Mechanical gauge on IA companion valve not reading correctly. Decision made to continue test with GMS pressure gauge. Pressured the IA up to 1919 psi and blocked in at the pump. Pressure dropped 145 psi in the first 15 minutes and 98 psi in the second 15 minutes for a total of 243 psi. Max pressure loss may not exceed 10%in 30 minutes or 5%in the first 15 minutes. Will reatempt the test in the morning with new gauges. 18:30 00:00 5.50 SURPRI CHEMTI OTHR P Continue pumping traced mixed gas (77% N2:23%CO2)at 16 Kg/hr 1420 psi on XPIO gauge @ 2226'MD. 02/18/2012 Continued pumping traced mixed gas(77% N2:23%CO2)at approx 20 kg/hr to maintain 1420 psi on XPIO gauge @ 2226'MD. Performed Mechanical Integrity Test of the Inner Annulus(MITIA)-Passed. Had to shut down GMS du to poor pump control. Adjusted the proportion portion of the Proportion, Integral, Derivative(PID)controller. Gas mixing/pumping issues solved. 00:00 05:00 5.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 17 kg/hr and 1415 psi on XPIO gauge @ 2226'MD. 05:00 10:00 5.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 20 kg/hr and 1419 psi on XPIO gauge @ 2226'MD. 10:00 15:30 5.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 19 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Starting to pump rougher. 15:30 16:00 0.50 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 19 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Discussing shutting down to condition tanks when well site generator accidentally taken off line. Down on the cryogenic pumps. Secondary generator started in 2 minutes and transferred power. Conditioned tanks(N2 and CO2) Transferred liquid N2 from storage tank to working tank and ordered out N2. 16:00 16:30 0.50 SURPRI CHEMTI OTHR P Start pumping mixed gas. Fighting the pumps unable to mix the product on spec. Shut down cryogenic pumps. Page 24 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:00 1.50 SURPRI CHEMTI OTHR P Conditioning tanks and priming pumps in attempt to bring pumps back on line with in spec blend.Started heating well and started pumping traced mixed gas (77%N2:23%CO2)at 15 kg/hr and 1379 psi on XPIO gauge @ 2226' MD. 18:00 19:30 1.50 SURPRI CHEMTI OTHR P Increased rate to 25 kg/hr pressure 1391 at on XPIO gauge @ 2226'MD. Nitrogen transport arrived on location. Need to fill both tanks. Shut down N2 pumping and closed 2"to well. stopped circulation of the IA in preparation for MITIA. 19:30 20:30 1.00 SURPRI CHEMTI OTHR P While transferring N2,perform MITIA -Passed. Pre T/I/0=1200/0/NA. Pumped up IA to 1900 lbs and double blocked in at well head. Initial T/I/0=1200/1900/NA, 15 min 1200/1800/NA, aborted test. Repressure to 1900 psi. Initial T/I/0 = 1200/1950/NA, 15 minute T/I/0= 1200/1870/NA, 30 minute TWO= 1200/1795/NA. Total loss of 155 psi 20:30 21:30 1.00 SURPRI CHEMTI OTHR P Restart circulating heated glycol through the inner annulus and restart injecting traced mixed gas(77% N2:23%CO2)at 100-75 kg/hr and 1347 psi on XPIO gauge @ 2226' MD. 21:30 00:00 2.50 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 30-20 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. Starting to pump very rough again. Large spikes in the N2 and CO2 rates. GC samples indicate N2 concentrations are high at—81%. 00:00 00:30 0.50 SURPRI CHEMTI OTHR P Adjust GMS blend setting to 72%N2 :28%CO to achieve 77% :23% respectively on GC results. 00:30 01:00 0.50 SURPRI CHEMTI OTHR P Continue to fight blending issues. Discuss options. Investigation of pump rate charts suggest that the N2 pump is leading the CO2 pump. As the CO2 pump falls behind the N2 pump drops off to zero output followed by the CO2 dropping to zero creating a saw tooth pattern. Wake up Optimation operator and discuss problem. P in PID changed from 0.25 to 0.01. Rate instantly stabilizes. 01:00 01:30 0.50 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 20 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Rate response is very smooth with the noise at approx+-5kg/hr. Page 25 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/19/2012 24 hr Summary Continued pumping traced mixed gas(77%N2:23%CO2)to maintain 1420 psi on XPIO gauge @ 2226'MD. Performed Mechanical Integrity Test of the Inner Annulus(MITIA)-inconclusive. Continue to pump. All Expro less three put on standby and left the slope. Scheduled to return Feb 29 th for initiation of flow back. 00:00 08:15 8.25 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 18-20 kg/hr and 1418-1420 psi on XPIO gauge @ 2226'MD. 08:15 08:30 0.25 SURPRI CHEMTI OTHR P Shut down glycol pumping. Casing and 2"valves to 125 bbl tank shut in. 08:30 09:00 0.50 SURPRI CHEMTI OTHR P Tubing pressure fell from 1420 to 1412 psi because of thermal contraction. Increased rate to maintain pressure. 09:00 10:00 1.00 SURPRI CHEMTI OTHR P Increased rate to maintain pressure at 1420 psi on XPIO gauge @ 2226' MD. 10:00 11:00 1.00 SURPRI CHEMTI OTHR P Perform AOGCC witnessed MITIA with Chuck Scheve. Passed with regard to total pressure loss but failed to stabilize. State man recorded a Fail Pre 1/1/0=1268/0/NA. Pumped up IA to 1910 lbs and double blocked in at well head. Initial T/I/0= 1269/1910/NA, 15 min 1265/1828/NA,30 min T/I/0= 1264/1770/NA,45 minute T/I/0= 121264/1716/NA, Total loss of 140 psi in 30 minutes however pressure drop was nearly linear. Bled IA and resumed well bore heating. 11:00 12:00 1.00 SURPRI CHEMTI OTHR P Reduced pump rate to 15 kg/hr. Tubing pressure rising because of thermal expansion. decreased rate to maintain pressure. Pumps erratic. 12:00 13:00 1.00 SURPRI CHEMTI OTHR P S/D pumps, heat well bore, condition tanks. 13:00 14:30 1.50 SURPRI CHEMTI OTHR P Bring pumps online at 28 kg/hr and 1409 psi. Adjust rate to achieve 1420 psi. Control screen turned full green. manually shutdown pumps. Screen reverted to normal. 14:30 16:30 2.00 SURPRI CHEMTI OTHR P Transfer liquid N2 from storage tank to working tank. Cool down pumps. start pumping at 44 kg/hr and 1375 psi. 16:30 18:30 2.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 44-22 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 18:30 19:00 0.50 SURPRI CHEMTI OTHR P HES N2 transport on location. 19:00 19:30 0.50 SURPRI CHEMTI OTHR P N2 transport contained 2040 gal. Off loaded and left with 7.5"or 534 gal on board. Off loaded 1506 gal into N2 storage tank. Page 26 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 22:00 2.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 20 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 22:00 00:00 2.00 SURPRI CHEMTI OTHR P Continue pumping traced mixed gas (77% N2:23%CO2)to maintain 1420 psi on XPIO gauge @ 2226'MD. 02/20/2012 Instituted proactive shut down to transfer fluids and condition tanks. Pumps running extremely well under new SOP. N2 pump appears to gas out and loose prime after approximately 8hrs continuous pumping. Initiation of event was anticipated today and successfully mitigated by bleeding gas from the top of the pump chamber. Pumped approx 10.2 MSCF product by 6 pm 77.2 MSCF total. Contacted Jim Regg-AOGCC regarding failed MITIA. Permission to continue injection granted.AOGCC requires a report of operations(pressures and rates)to confirm integrity of IA. 00:00 00:15 0.25 SURPRI CHEMTI OTHR P Experienced a short upset while pumping. Bled the back side of the N2 pumps slowly nad let the GMS PID controlers pump through the upset. 00:15 04:45 4.50 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—21 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 04:45 05:30 0.75 SURPRI CHEMTI OTHR P Shut down pumping to condition N2 tanks&transfer N2.Greased N2 and CO2 pumps. Transfered 160 gal N2 from storage to working. 1730 gal remaining in storage. 05:30 16:30 11.00 SURPRI CHEMTI OTHR P Bring pumps back on line at 1395. Increase rate to 51 kg/hr to reach target of 1420 psi. Pumping traced mixed gas(77% N2:23%CO2)at—20 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 16:30 17:30 1.00 SURPRI CHEMTI OTHR P Shut down pumping to condition N2 tanks&transfer N2. Transferred 101 gal N2 from storage to working. 1629 gal remaining in storage. Cool down pumps. Restart pumps 17:30 00:00 6.50 SURPRI CHEMTI OTHR P Bring pumps back on line at 1395. Increase rate to reach target of 1420 psi. Pumping traced mixed gas (77% N2:23%CO2)at—20 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 02/21/2012 N2 pump still appears to gas out and loose prime after approximately 8hrs continuous pumping. Initiation of event was anticipated again today @ apporx 1330. Pumping continued for a few hrs after the event. Shut down and conditioned tanks to mitigate. Pumped approx 12.2 MSCF product by 7 pm for a total of 92 MSCF. Injection rate has increased slowly today from 22 kg/hr to 25 kg/hr 00:00 01:15 1.25 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at 22 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 01:15 01:30 0.25 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—22 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Forced to bleed off the back side of the pump,fighting the N2 pump. Page 27 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:30 3.00 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 22-24 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 04:30 05:00 0.50 SURPRI CHEMTI OTHR P Shut down pumping to condition N2 tanks&transfer N2.Transferred 238 gal N2 from storage to working. 1500 gal remaining in storage. 05:00 06:15 1.25 SURPRI CHEMTFOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 1420 psi on XPIO gauge @ 2226'MD. 06:15 07:00 0.75 SURPRI CHEMTIOTHR P GMS lost communication to the well site data hub. Optimation crew worked with SLB Interact support to reestablish communication. 07:00 13:00 6.00 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 25 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Removed Tioga heater from CO2 tank @ 09:08 13:00 14:00 1.00 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 1420 psi on XPIO gauge @ 2226'MD. Forced to bleed off the back side of the pump, fighting the N2 pump. 14:00 15:30 1.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 25 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Removed Tioga heater from CO2 tank @ 09:08 15:30 16:30 1.00 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. Added 20 bbls of potable water to glycol tank to compensate for evaporation. 125 bbl tank level 70 bbls. 16:30 00:00 7.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 28 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 02/22/2012 Pumping traced mixed gas(77% N2:23%CO2)at 24-26 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Replaced SF6 tracer with R-114 tracer. Received 20,000 lbs CO2,transferred on the fly while pumping down hole. Pumped approx 12.9 MSCF product by 20:30 for a total of 109 MSCF. Injection rate today was 24 kg/hr to 26 kg/hr. 00:00 05:30 5.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 24-26 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 05:30 05:45 0.25 SURPRI CHEMTIOTHR P Forced to bleed off the back side of the pump,fighting the N2 pump. 05:45 06:00 0.25 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 24-26 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 06:00 06:15 0.25 SURPRI CHEMTIOTHR P Forced to bleed off the back side of the pump,fighting the N2 pump. 06:15 08:30 2.25 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—25 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Page 28 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:15 0.75 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. Purged ISCO tracer pump of SF6 Tracer. Replaced SF6 tracer bottle with R-114 tracer. Flushed ISCO pump with R-114 tracer. Loaded both colunms A and B to 103 ml each. Set pump rate at 0.01 ml/min. 09:15 18:30 9.25 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—25 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Transport of CO2 on location, Pre job safety meeting,transfer from tanker to working tank on the fly, complete 13:00. 18:30 19:15 0.75 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. 19:15 00:00 4.75 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 24-26 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 02/23/2012 Pumping traced mixed gas(77% N2:23%CO2)at 24-26 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Pumped approx 12.4 MSCF product by 19:00 for a total of 124.7 MSCF. Injection rate today was 24 kg/hr to 26 kg/hr. 00:00 03:30 3.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 27-28 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 03:30 04:00 0.50 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. 04:00 15:30 11.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—26 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 15:30 16:15 0.75 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. 16:15 00:00 7.75 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—26 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 02/24/2012 Pumping traced mixed gas(77% N2:23%CO2)at 29-30 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Pumped approx 14.5 MSCF product by 20:00 for a total of 143.9 MSCF. 00:00 00:30 0.50 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. 00:30 03:30 3.00 SURPRI CHEMTIOTHR P Pumps Acting Erratically. Pumping traced mixed gas(77%N2:23%CO2) at—29-30 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 03:30 08:00 4.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—29-30 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 08:00 09:15 1.25 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. Page 29 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 16:30 7.25 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—29-30 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. Refilled ISCO Pump A with R-114. 16:30 17:45 1.25 SURPRI CHEMTf OTHR P Shut down pumping to condition N2 tanks&transfer N2. 17:45 00:00 6.25 SURPRI CHEMTF OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—29-30 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 02/25/2012 Pumping traced mixed gas(77%N2:23%CO2)at 31-33 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Shuttled power from primary well site generator to secondary and back for oil change. Attempted unsuccessfully to update GMS and InterAct software-ongoing. Pumped approx 13.7 MSCF product by 17:00 for a total of 161.3 MSCF. 00:00 05:15 5.25 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—31-32 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 05:15 05:45 0.50 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. 05:45 08:00 2.25 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—31-32 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 08:00 08:07 0.13 SURPRI CHEMTIOTHR P Shut down pumping briefly to swap power from primary generator to secondary well site generator for scheduled oil change. 08:07 08:37 0.50 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—32-44 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 08:37 08:52 0.25 SURPRF CHEMTI OTHR P Shut down pumping briefly to swap power from secondary generator to primary well site generator for scheduled oil change. 08:52 16:59 8.12 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at—32-44 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 16:59 19:59 3.00 SURPRI CHEMTIOTHR P Shut down pumping to condition N2 tanks&transfer N2. Installed new software in GMS unit, coordinated changes with SLB Interact. Unable to effect change. Reloaded original software. 19:59 20:29 0.50 SURPRI CHEMTI OTHR P Glycol pumps on line. Resume well bore heating. Cool down cryogenic pumps. Bring pumps online. 20:29 23:02 2.55 SURPRI CHEMTIOTHR P Pumping traced mixed gas(77% N2:23%CO2)at 1420 psi on XPIO gauge @ 2226'MD. Page 30 of 45 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 23:02 23:59 0.95 SURPRI CHEMTI OTHR P Surface Safety valve tripped inadvertenetly. Reset and resumed pumping traced mixed gas(77% N2:23%CO2)at 1420 psi on XPIO gauge @ 2226'MD. 02/26/2012 Pumping traced mixed gas(77% N2:23%CO2)at 31-33 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Swapped inlet/outlet on heater string with IA. Pumped approx 14.7 MSCF product by 21:00 for a total of 176.0 MSCF. 00:00 05:00 5.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—33 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 05:00 05:30 0.50 SURPRI CHEMTI OTHR P Shut down pumping to condition N2 tanks&transfer N2. 05:30 12:30 7.00 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—33 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Raised SLB line heater from 100 F to 120 F in 10 deg F increments over a 2 hour peroid from 06:45 to 08:45. 12:30 13:00 0.50 SURPRI CHEMTI OTHR P Shut down pumping to condition N2 tanks&transfer N2. 13:00 19:15 6.25 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—33 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 19:15 19:45 0.50 SURPRI CHEMTI OTHR P Swapped inlet/outlet on heater strings while contining mixed gas injection. 19:45 00:00 4.25 SURPRI CHEMTI OTHR P Pumping traced mixed gas(77% N2:23%CO2)at—33 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. 02/27/2012 Pumping traced mixed gas(77%N2:23%CO2)at 33-35 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Pumped approx 21 MSCF product by 23:00 for a total of 205 MSCF Hall Plot volume. 00:00 06:00 6.00 SURPRI P Pumping traced mixed gas(77% N2:23%CO2)at—33 to 34 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. 06:00 06:30 0.50 SURPRI P Shut down pumping to condition N2 tanks&transfer N2. 06:30 18:30 12.00 SURPRI P Pumping traced mixed gas(77% N2:23%CO2)at—34 to 35 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. Raised SLB line heater to 135 F at 08:00. Raised glycol circ rate to _15 gpm. 18:30 19:00 0.50 SURPRI P Shut down pumping to condition N2 tanks&transfer N2. 19:00 22:09 3.15 SURPRI CHEMTI OTHR Pumping traced mixed gas(77% N2:23%CO2)at—35 kg/hr and 1420 psi on XPIO gauge @ 2226'MD. Pumped up both SSV hydralic panels to 4000 psi at 20:00 hrs. Investigating an error that is creating a time delay in the data storge. 22:09 22:45 0.60 SURPRI CHEMTI OTHR Took the GMS offline and attempted to restart the computer to correct the data latency problem. Page 31 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 SURPRI CHEMTI OTHR Resumed pumping traced mixed gas (77%N2:23%CO2)at—35 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. The data latency problem has not been fixed 02/28/2012 Shut iD injection, girLpressute,fall_off. Stand by for weather(currently-44) 00:00 02:00 2.00 SURPRI CHEMTI OTHR P Continued pumping traced mixed gas (77% N2:23%CO2)at—35 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. The data latency problem has not been fixed and is continuing to worsen 02:00 04:00 2.00 SURPRI CHEMTIOTHR T HMI system crashed, injection offline. Optimation troubleshooting and attempt to restart. 04:00 07:45 3.75 SURPRI CHEMTI OTHR P Continued pumping traced mixed gas (77%N2:23%CO2)at—35 kg/hr and 1420 psi on XPIO gauge @ 2226' MD. The data latency problem continuing. Met with project team, decided to halt injection. Minimum injection volume has been met. 07:45 00:00 16.25 SURPRI CHEMT}OTHR T Shut-in iinjection, begin pressure falloff. Stand-by for Weather- current temperature(-44 F,-75 F windchill)below minimum. 02/29/2012 Monitor data and standby for weather warming trend.Optimization working on computer/data issues. 00:00 05:27 5.45 SURPRI CHEMTI OTHR T Monitor data and standby during Cold Weather Shut Down(-42) 05:27 05:57 0.50 SURPRI CHEMTI SFTY P Morning Pre-Job Safety Meeting with SLB and Expro. 05:57 17:27 11.50 SURPRI CHEMTI OTHR T Monitor data and standby during Cold Weather Shut Down 17:27 17:57 0.50 SURPRI CHEMTI SFTY P Evening Pre-Job Safety Meeting with SLB and Expro 17:57 00:00 6.06 SURPRI CHEMTI OTHR T Monitor data and standby during Cold Weather Shut Down 03/01/2012 Data was monitored and on standby until Cold Weather Shut Down was lifted around 1300hrs.. Began completing Procedure#11 . 00:00 13:00 13.00 SURPRI CHEMTI OTHR T Monitor data and standby during Cold Weather Shut Down(-42).#1 glycol pump was shut down due to bad beaing and/or shaft. Parts on order. 13:00 00:00 11.00 SURPRI CHEMTI PRTS P Cold Weather restrictions lifted(-31) and work commenced towrads completing Procedure 11. Expro's hardline and the GC lines were pressure tested successfully. 290 bbls of 140 dgree water was off loaded into uprights. Expro Stack Pac lines were connect3ed and PT'ed and glycol circulated. Page 32 of 45 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/02/2012 24 hr Summary Finish Procedure#11, specifically validating the gas flow meters and GC as well as setting the back pressure valves on the Expro separator. 00:00 13:00 13.00 SURPRI CHEMTI PRTS P Continue making progress in completing Procedure#11. Finish pressure testing lines,setting the back flow valves on the Expro separator,validate the gas flow meters and GC. Increase glycol pump rate to warm wellbore back up. 13:00 00:00 11.00 SURPRI CHEMTI PRTS T Lost Prime on pumps had to recondition Nitrogen tanks and transferr N2. Flow readings on small gas meter match GMS MicroMotion readings. Began testing larger gas meter wirth N2. Large gas meter showing difference of 10 to 7%from GMS MicroMotion. 03/03/2012 Continue working gas metering issues.Moved meter FM 201 from GMS to gas outlet leg of Expro separator and tie in to automation system. 00:00 13:00 13.00 SURPRI FLOWT PRDT T Continue working gas metering issues. 13:00 00:00 11.00 SURPRI FLOWT PRDT T Testing meters with CO2 and still finding offset between thermal conductivity and the MicroMotion in the GMS.While testing still, lost prime and basically emptied the CO2 tank. Had 3,000 gal of N2 delivered and offloaded.Moved MicroMotion meter FM 201 from the GMS to the gas outlet of the Expro separator and tied into the automation system. Began testing with N2 with the new meter in place. 03/04/2012 CompleteTesting of Micro Motion meter rigged up in the Atigun House and evaluate data. Started flowing well back. 00:00 06:00 6.00 SURPRI FLOWT PRDT P Start testing of Micro Motion meter rigged up in Expro Spearator skid. Testing with N2 at four different rates. 06:00 09:30 3.50 SURPRI FLOWT PRDT P Finished testing of the four varying rates and added a fifth rate test which is actually a re-test of the lowest rate test performed previously in order to validate/compare data. 09:30 13:24 3.90 SURPRI FLOWT PRDT P Finished the re-test of the lowest rate and determined this data was acceptable. Shut down testing and lined the Expro separator up for flow. Optimization person was requested to make several changes in software. 13:24 13:54 0.50 SURPRI FLOWT SFTY P Hold Pre-Flow Back Safety Meeting with SLB, Expro, Halliburton hands in the Atigun House. Page 33 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:54 00:00 10.10 SURPRI FLOWT PRDT Open well to commence flow back As of 2005 hrs approximately 4,100 cf of gas has been flowed back. 03/05/2012 Continue with flowback operations and monitor data. 00:00 00:00 24.00 SURPRI Continue with flow back operation. Have flowed back approximately 42mscf gas. BHP started at 1080psi and as of 2030 hrs is around 750psi. Well is loading up. Decision made to start prepping for Procedure#13("Jet Pump Running and Pulling)after 2300hrs. Pump truck and tanker with F/W ordered for after midnight. Slickline tentatively scheduled for am start setting jet pump. 03/06/2012 Continue implementing Procedure#13(Jet Pump Running&Pulling). Flush glycol out of well with N2.After bleeding down N2,pump heated F/W down annulus. Slickline drift&tag,set standing valve,set catcher, pull dummy valve, pull catcher, and run jet pump. 00:00 12:00 12.00 SURPRI Start implementing Procedure#13 (Jet Pump Running&Pulling)by displacing glycol from the IA with N2. Re-rig piping in wellhouse to facilitate this operation. Begin displacing the glycol by taking returns up the hearter string. Bleed down N2 after all gycol out of well. 12:00 16:30 4.50 SURPRI MIRU pump truck and tanker loaded with 200bbls FAN. Begin heating F/W to 175 degrees and pump down annulus in order to equlize pressure at the GLM. 16:30 17:30 1.00 SURPRI RDMO Pump Truck and tanker. 17:30 19:00 1.50 SURPRI MIRU Slickline. 19:00 19:45 0.75 SURPRI PJSM with Halliburton Slickline crew and SLB Night Supervisor. 19:45 00:00 4.25 SURPRI PT Lubricator to 500psi with N2. Bleed down to 250 psi, open well and RIH.Commence slickline operations as per Procedure#13. 03/07/2012 Finish Procedure#13 by setting jet pump and began Procedure#14(Jet Pump Operations).Commence flow back to Upright#1 by starting the jet pump.Monitored BHP and took BS&W samples every 30min. BS&W samples started around 8%and as of 2100hrs samples were reading about.9%and at this time the total amount of produced fluids was 42bbls. 00:00 01:30 1.50 SURPRI Finish Procedure#13 by setting the "5-C"Jet Pump @1919'SLM. 01:30 02:00 0.50 SURPRI RDMO location with the slickline unit. 02:00 02:24 0.40 SURPRI Line up well to flowback through Expro separator and into upright tank #1.Start up jet pump and begin taking returns. Page 34 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:24 03:24 1.00 SURPRI Begin taking samples for the GKBU Lab and the USGS.Samples were moderately"silty". 03:24 06:24 3.00 SURPRI Continue flowing back well and monitoring data. First slug of solids enter separator around 0530hrs. Heavy silt samples taken from separator. 06:24 20:55 14.52 SURPRI Continue flowing back into upright #1. Begin taking BS&W samples. First sample was about 8%solids. Subsequent solids were 7%, 5%, 3.5%2.8%, 1.5%, .5%and eventually went back up around .9% by 2100hrs. Total bbls of fluid produced by 2100hrs is about 42bbls. 20:55 23:59 3.08 SURPRI Continue flowing back well, monitoring data,strapping flowback tank and take samples 03/08/2012 Continue Jet Pump operations, monitoring data,and taking BS&W samples. 00:00 06:27 6.46 SURPRI Continue Jet Pump operations. 06:27 06:46 0.33 SURPRI Air line to air/hydraulic SSV froze off ca suing the SSV to slowly shut in. Clear air line, open SSV and resume flow back operations.Air line was eventually placed inside heated"blue board troughs"and a second air compressor was installed to allow for the compressors to be shut down and the Tanner Gas air dryer re-filled. 06:46 07:01 0.25 SURPRI Flow back was switched to upright #2. 07:01 23:58 16.96 SURPRI Continue Jet Pump operations. A snapshot of BS&W samples from midnight up to 2100 hhrs were from .8, 2..6, 1.3, 4.5, 1.2, 2.2, .6. Total bbls of produced fluids to uprights since startup is now at 96.07 as of 2100hrs as well as 98mscf gas. BHP at midnight was 663psi and at 2100 hrs was 659psi. SURPRI 03/09/2012 Normal Jet Pump operations until 11:00am when separator pressure was lost. No gas in fluids. Implementing different options to maintain BHP and re-establish separator pressure. 00:00 11:00 11.00 SURPRI P Continue flowing back well and monitoring data. 11:00 11:15 0.25 SURPRI P Pressure drops in separator and wellhead.Very little gas coming back with fluids causing the separator to lose charge. Close choke to allow for pressure bulid up. Page 35 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 11:30 0.25 SURPRI P Open choke to minimum flows. No gas. Adjust Jet Pump rate to ensure Jet Pump operating. 11:30 13:15 1.75 SURPRI P Pump N2 across wellhead to Expro separator to re-charge separator up to 125psi approximately. Switch to upright#1 to facilitate tank strapping(too much agitation causing plumb bob strap to give inaccurate readings). 13:15 13:30 0.25 SURPRI P Shut down N2 pump.Continue flowing back well. 13:30 14:37 1.12 SURPRI P Open choke further by two beans. Wellhead pressure dropped off from around 650psi to as low as 545psi and then started to climb towards 700psi resulting in choking back the well. 14:37 15:22 0.75 SURPRI P Pressure slowly falls back. Continue making adjustments with pump and choke to maintain flow. 15:22 17:31 2.15 SURPRI P Well essentially died and failed to produce fluids.Continue making adjustments to regain flow. 17:31 18:31 1.00 SURPRI P Pump started behaving erratically. It was fluctuating between 4&18 gpm. 18:31 19:01 0.50 SURPRI P Shut down pump. Flush lines and remove screen on suction line. Screen and line were clogged with sand. Re-route hoses on uprights tanks to facilitate suction from Tank #1 and flow into Tank #2 in order to allow"settling"of solids. 19:01 23:59 4.98 SURPRI P Restart Jet Pump and establish flow. Continue to monitor data and make adjustments to help retain flow.Start removal of 302 fluid pump in GMS and replace with new pump.As of 2100hrs,well has produced 16mscf and 25bbls of fluid. Snapshot of BS&W samples were 2.0, 1.5, .05, .6, .4, 1.2, .25, .15 03/10/2012 Normal jet pump operations until about 1330hrs when well was shut in so a control valve on separator could be replaced. Resumed flow back operation after valve replacement. 00:00 00:45 0.75 SURPRI P Continue efforts to keep well flowing. Vac arrives and hauls off 110 bbls of returns for disposal. 00:45 01:00 0.25 SURPRI P Shut down power fluid pump 301 in order to remove 302 pump and install new pump. 01:00 06:00 5.00 SURPRI P Resume jet pump operations. 06:00 06:15 0.25 SURPRI P Shut down pumping in order to re-configure pumps 301 &302 piping. (This modification will facilitate a quicker pump installation next time) Page 36 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 13:30 7.25 SURPRI P Resume jet pump operations. Struggle to get well to previous performance level.Make adjustments to improve flow characteristics. 13:30 18:36 5.10 SURPRI P Liquid level control valve on EXPRO separator washes out.Caught early when only a drip.Well shut in and flowline from wellhead to separator blown down with N2. Work commences on swapping out the washed out valve with a similiar valve already bolted in-line, but not being used.This location was blinded off. 18:36 00:00 5.41 SURPRI P Open well and start Jet Pump operations.As of 2100hrs, in the previous 24hrs the well has produced 81 bbls of fluid and 15.5 mscf of gas. 03/11/2012 Finally back to normal jet pump operations. Monitoring data and taking BS&W samples. 00:00 02:00 2.00 SURPRI P Continuing jet pump operations. Gas ceases to flow before midnight. Lower BHP and well begins to flow again with gas around 2:00am 02:00 00:00 22.00 SURPRI P Continue Jet Pump Operations. The well has a tendency to flow for a period of time then lose gas and go to minimum flow or even cease to flow until pressure builds back. Monitor data and continue to flow well.Some of the BS&W samples ranged from.2%, .5%,2.0%,4.0%, 1.4%, .6%, .15%, 1.6%.As of 2100hrs,for the previous 24hr period the well produced 18 bbls of fluid and 12 mscf of gas. 03/12/2012 Continue to lower BHP, monitor data,and take BS&W samples.Troubleshoot GMS HPP issues. 00:00 00:00 24.00 SURPRI P Currently in Jet Pump operations and bringing down BHP. Haul off 175 bbls returns. Snow removal after blow. Shovel out around the buildings and piping. Troubleshoot pump issues. BS&W samples were running from .6, .22, 1.0, .5, 1.6,3.2, 2.8, .2, .01, .15 as of 2100 hrs for the last 24 hrs,the gas flowed back is 7.2 mscf and the fluid produced are 25 bbls. 03/13/2012 Continue to lower BHP, monitor data, and take BS&W samples. Page 37 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 23:30 23.50 SURPRI FLOWT IPRDT P Currently in Jet Pump operations and bringing down BHP. Removed the small backpressure control valve in the Expro low rate metering skid. Controlling rate by holding surface separator pressure as low as possible. BS&W samples continue to range from 0.1 to 3.1%with a daily average of 0.9 and a spike of highest concentrations from 0930-1400 hrs. 10 mscf gas and 50 bbls H2O flowed back over the last 24 hrs as of 2030. Walked down location with CPAI environmental in preparation for ADEC visit tomorrow. 23:30 00:00 0.50 SURPRI FLOWT PRDT T A dump valve in the flow back separator line cut out assumedly due to sand production. The well was shut in and efforts to blow down surface lines initiated. 03/14/2012 Washed out the water dump valve in the Expro test Separator. Shut in well, Displaced power fluid, (fresh water)from the inner annulus with 60/40 Tritherm(triethylene glycol)and initiated well bore heating by circulating down the heater string and taking returns from the Inner annulus casing valve. Waiting on replacement water dump valve. 00:00 04:00 4.00 SURPRI FLOWT PRDT T Blow down surface lines that contained power fluid(fresh water) One small section of riser found to be frozen at the well house door. Thawed same and cleared lines 04:00 07:00 3.00 SURPRI FLOWT PRDT T Pre tower safety/ops meeting to discuss path forward. Drafted procedure to displace inner annulus to 60/40 tritherm(triethylene glycol). Took on 200 gal of liquid N2. 07:00 11:00 4.00 SURPRI FLOWT PRDT T Walked lines and gathered necessary equipment. Broke glycol line at Expro stack pack bath. Added T with valves to facilitate blow down. Lined up lines to be able to take suction from the 125 bbl glycol tank deliver high pressure fluid to the heater string and returns from the IA to the 70 bbl sand jet tank. Returns truck on location. Shot tubing fluid level 703'@ 275 psi. Pressure up tubing with N2 to 700 psi IA at 60 psi. Re shot fluid level at 775'and 700 psi. After 10 minutes T=680 psi and IA=260 psi. 11:00 14:00 3.00 SURPRI FLOWT PRDT T Loaded IA with glycol 1585 psi and 15 gpm taking returns to the 70 bbl sand jet tank. Returns truck took load to 1R-18 for disposal. 14:00 00:00 10.00 SURPRI FLOWT PRDT T Circulating the IA with heated glycol. 929 psi and 16 gpm inlet temp 105 F Page 38 of 45 Time Logs Date From To` Dur S. Depth E. Depth Phase Code Subcode T Comment 03/15/2012 24 hr Summary Replaced washed out water dump valve with different style control valve. Displace glycol from inner annulus (IA)with N2. Load IA with power fluid(fresh water). Start jet pumping and flowing the well at 123 MSCF/D. 00:00 10:18 10.30 SURPRI FLOWT PRDT T Circulating the IA with heated glycol. 10:18 10:30 0.20 SURPRI FLOWT PRDT T Start cooling down N2 pump in SLB GMS. Expro crew replacing washed out water dump valve. 10:30 11:48 1.30 SURPRI FLOWT PRDT T Continue to cool down N2 pump. Shut in high pressure pump. S/I Heater and IA valves. Blow down soft hoses to 125 bbl glycol tank. 11:48 14:48 3.00 SURPRI FLOWT PRDT T Pump N2 down the IA taking glycol returns up the heater string to the 125 bbl tank. Shut down trapping 1151 psi N2 on the IA. 14:48 15:48 1.00 SURPRI FLOWT PRDT T Line up high pressure pump to load the IA with power fluid pumping down the heater string taking N2 returns to the sand jet tank. 15:48 18:18 2.50 SURPRI FLOWT PRDT T load the IA with power fluid while bleeding N2 slowly as fluid rises in the IA to maintain 700 psi hydrostatic pressure at the jet pump /CAT standing valve. 18:18 18:42 0.40 SURPRI FLOWT PRDT T Line up to pump power fluid from tank number 2. Expro flowing back through separator to tank#1. 18:42 20:06 1.40 SURPRI FLOWT PRDT P Come on line with jet pump at 8 gpm. Gas returns to surface. well head pressure 494 psi. take Iso tube sample of gas(N2 29%, CH4 70%, CO2 1%, SF6 0.373 ppm, R114 1.571 ppm). Fluid to surface at 20:00 20:06 00:00 3.90 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1800 psi at the IA. Well flowing 24 MSCF/D gas. Slowly working well head pressure down. Optimized rate 123 MSCF/D gas at 184 well head pressure. 03/16/2012 Normal jet pump operations with 5C pump in hole. Average rate 90 MSCFD gas and 180 BWD. Off loaded 280 bbls of produced fluid. 00:00 06:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1900 psi at the IA. Well flowing 60 MSCFD gas. Slowly working well head pressure down. 06:00 12:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1890 psi at the IA. Well flowing 110 MSCFD gas. Slowly working well head pressure down. 12:00 18:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 11.5 gpm and 1990 psi at the IA. Well flowing 110 MSCFD gas. Slowly working well head pressure down. Page 39 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 11-12 gpm and 1990 psi at the IA. Well flowing 110 MSCFD gas. Slowly working well head pressure down. Rig up vac truck to take returns from upright number 251. Found broken valve stem on upright. Had to empty tank to break connection. Encountered packed sand in the bottom of the 400 bbl upright. Estimate 20 bbls of sand remains in tank and 10 bbls of sand off loaded with produced fluid. Total volume trucked away 280 bbls. 03/17/2012 Normal jet pump operations with 5C pump in hole. Produced 142 MSCFD gas and 148 BWD from 9 pm to 9pm 3/16-17/12. Rebuilt High Pressure Pump(HPP)#1 HPP#2 has approx 50 hrs. Returns averaged 2.19 %sediment. 00:00 06:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1990 psi at the IA. Well flowing—137 MSCFD gas. Slowly working XPIO gauge#2 down from 555 psi. 06:00 12:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1960 psi at the IA. Well flowing—140 MSCFD gas. XPIO gauge#2 550-543 psi. 12:00 18:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1640 psi at the IA. Well flowing—148 MSCFD gas. XPIO gauge#2 543- 537 psi. 18:00 00:00 6.00 SURPRI FLOWT PRDT P Continue jet pumping at 11 gpm and 1740 psi at the IA. Well flowing —148 MSCFD gas. Working XPIO gauge#2 down slowly from 537 psi. Rebuilt High Pressure Pump(HPP) #1. Expect 300-400 hrs with feed water of 0.05%solids. 03/18/2012 Normal jet pump operations with 5C pump in hole. Produced 75 MSCFD gas and 57 BWD from 9 pm to 9pm 3/17-18/12. Ice blockage developed in flare line forcing well to be shut in 1 hr to clear the line. Jet pumping in attempt to restart the flowing. 00:00 03:00 3.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1740 psi at the IA. Well flowing—140 MSCFD gas. XPIO gauge#2 533 psi. 03:00 06:00 3.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1740 psi at the IA. Well flow decreasing to 100 MSCFD then climbing to 125 MSCFD gas. XPIO gauge#2 dipping some but averaging 533 psi. 06:00 09:00 3.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1740 psi at the IA. Well flowing—127 MSCFD gas XPIO gauge#2 dipping some but averaging 533-534 psi. 09:00 11:00 2.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1740 psi at the IA. Well flowing—125 MSCFD gas XPIO gauge#2 steady , at 533 psi. Page 40 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 SURPRI FLOWT PRDT T Ice blockage issue discovered in the flare line. Forced to come down on the jet pump at 11:00 and shut the well in. SLB S/I and blew down surface suction and discharge lines. SLB pushed air across the tree to blow down Expro lines by passing the separator to the returns tanks. BOth Expro and SLB cleared the blockage, ice, in the flare line. 12:00 20:00 8.00 SURPRI FLOWT PRDT P Flood GMS HPP lines and initiate et pumping at-8 gpm. Walk jet pump rate up until a pressure of 1950 at the IA-11 gpm. Well NOT flowing gas. XPIO gauge#2 climbing slowly from 550 to 570 psi. Spotted Tank 0 400 bbl upright tank in secondary containment. 20:00 00:00 4.00 SURPRI FLOWT PRDT P Coontinue to pump at-11 gpm and 1950psi. Well NOT flowing gas. XPIO gauge#2 climbing slowly. 03/19/2012 Unable to restart production by jet pumping. Attempted to pull jet pump. Ongoing. 00:00 07:24 7.40 SURPRI FLOWT PRDT P Continue to pump at-11 gpm and 1950 psi. Well NOT flowing gas. XPIO gauge#2 climbing slowly. 07:24 08:09 0.75 SURPRI FLOWT PRDT P Lower rate from- 11 gpm to-8 gpm and. Well NOT flowing gas. XPIO gauge#2 climbing slowly. Monitor pressure and raise rate back to-11 gpm. 08:09 11:09 3.00 SURPRI FLOWT PRDT P Continue to pump at-11 gpm and 1950 psi. Well NOT flowing gas. XPIO gauge#2 climbing slowly. Heating well bore while preparing for slick line intervention. 11:09 12:27 1.30 SURPRI FLOWT PRDT P Cool down N2 pumps. Shut down High Pressure Pump and S/I well. Blow down surface lines from well head through Expro, by passing the separator to return tanks with N2. Block in Expro. Blow down suction and hard line to 70 bbl sand jet tank with air. Come online with N2 to the tubing taking returns to the 70 bbl sand Jet tank. Slick line on location and spotting up to well. 12:27 15:03 2.60 SURPRI FLOWT PRDT P Pump 11932 SCF N2 at 1600 psi to tubing. Shut down with 1600 trapped on the tubing and 400 trapped on the IA. Bleed the tubing to 600 and the IA to zero. 15:03 16:33 1.50 SURPRI FLOWT PRDT P Slick line RIH with 3.5 dump bailer. Tag top of pump at 1919' POH and make up fishing tool string. Page 41 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:33 20:03 3.50 SURPRI FLOWT PRDT P RIH with jet pump fishing tool string and attempt to latch up. After—10 tries able to latch up and started hitting oil jar licks. Unable to move pump up hole. Attempt to sheer off the jet pump for 60 minutes. Slow oil jar action,spang action not visible. Pumped 155 gal of thritherm down the heater string,taking returns to the tubing. Able to break free,sand and silt found on tools at surface. 20:03 22:03 2.00 SURPRI FLOWT PRDT P On surface with tools. Add lubricator and lengthen tool string with longer spangs and more weight bar. 22:03 00:00 1.95 SURPRI FLOWT PRDT P Make up tool string with long spangs and thin the oil in the oil jars. RIH. Hard time latching up again,once latched working wire with indication of good hits. Start attempting to sheer off at 23:00. Free at 23:48. POOH and RD for night. 03/20/2012 Pulled 4 1/2"jet pump assy from 1919'. Attempted to shear knockout in standing valve. Pressure response from well indicated a possible shear however tattle tail on prong was not sheared. Continue to circulate hot glycol down the heater string taking returns from the inner annulus. 00:00 07:36 7.60 SURPRI FLOWT PRDT P Returns truck on location to suck down 70 bbl sand jet tank. Vacuum 30 bbls returned power fluid from 70 BBLs sand jet tank. Line up Inner Annulus(IA)to take returns to the sand jet tank. Come online with the GMS High Pressure Pump(HPP) down the heater string with heated glycol. Pumped 50 glycol to IA,shut in returns to the Sand jet tank and initiated circulation of heated glycol through t SLB line heater. 07:36 08:00 0.40 SURPRI FLOWT PRDT P Cold weather advisory for Kuparuk notification. Called CPA Wells Supt to discuss. -36 F on location. Called out Slick Line(SL)unit. 08:00 09:30 1.50 SURPRI FLOWT PRDT P Continue to circulate IA with heated glycol. Organized resources for potential Coiled Tubing(CT) intervention in case SL intervention failed to retrieve jet pump. SL on location. Pre Job safety discussion. CPAI Cold Weather Equipment Operating Variance reviewed, safety discussion held and document signed. SL crew released to rig up. Expro constructing 20'x20'revetment for sand trap. Sand trap and iron on location. 09:30 12:30 3.00 SURPRI FLOWT PRDT P SL R/U,Cut back 200'of wire, 16'2 5/8"stem, OJ, LSS, and stand by for 2 1/8 jars. Page 42 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:30 1.00 SURPRI FLOWT PRDT P Cold weather advisory lifted-34 F. HES delivered 3000 gal N2. 55' lubricator, 33'tool string. PT w N2 to 700 psi RIH to pull jet pump W 4 1/2 PRS, S/D Latch @ 1919'SLM. Jar 1500-1800 for 45 minutes untill pump assy came free. Drilling Tool House delivered timbers and herculite for sand trap revetment. 13:30 15:00 1.50 SURPRI FLOWT PRDT P OOH W/jet pump assy. Lock missing small piece of packing. Lay down assy and cut 200'of wire. Drop 8'of 2 5/8"stem. 15:00 16:30 1.50 SURPRI FLOWT PRDT P Pump 42 gal of Glycol from the IA to the tubing(T)Glycol tank has 37-38 bbls. RIH W/5'x3"pump bailer W/ Mule shoe ball. S/D @ 1932'SLM stroke bailer a few times. POOH w metal marks on bailer bottom, recovered piece of packing from lock on jet pump assy. No other solids in bailer. Stand by SLU and deliver pump to Y-Pad shop for disassembly. Found 1/2"x 3/8" piece of metal(appears to be shear stock)lodged in the throat of the jet pump. 16:30 18:30 2.00 SURPRI FLOWT PRDT P RIH W 3.50 cent,2'stem,3.25 cent, 47'x 1"prong. Stop at 1850'. Bleed T to 600 psi. S/D @ 1932'SLM, attempt to tap past but unable to. POOH to inspect tools. OOH small amount of sand on tools and marks on prong. 18:30 19:30 1.00 SURPRI FLOWT PRDT P RIH W/3.25 cent, 2'stem, 3.50 cent,XO,XO, 37"prong,distance from bottom centralizer to bottom of prong=44", S/D @ 1933'SLM,jar down attempt to bounce past. Pressure indication on T and down hole XPIO P1 that knockout had sheared. POOH. OOH tattle tail not sheared. 19:30 20:30 1.00 SURPRI FLOWT PRDT P RIH W/4 1/2"PRS,S/D @ 1932' SLM Tap down lightly. Unable to latch up. One friction bite after hand spanging held to'-500 lbs. POOH. OOH tool has silt on it. 20:30 21:00 0.50 SURPRI FLOWT PRDT P RIH W/3.25"cent, 2'stem, 3.50" LIB, S/D @ 1933'SLM,Tap down POOH. Tool has silt on it and no impression. 21:00 21:30 0.50 SURPRI FLOWT PRDT P R/DSL unit 21:30 00:00 2.50 SURPRI FLOWT PRDT P Continue to circulate the IA with heated glycol. Page 43 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/21/2012 24 hr Summary Spotted sand trap in containment, rigged up same. Bailed down to to lock,seal bore assembly,and sanding valve hung at 1957'. Knocked out KOBE saw XPIO#3 rise from 562 psi to 971 psi 00:00 08:00 8.00 SURPRI FLOWT PRDT P Continue to circulate the IA with heated glycol. 08:00 08:15 0.25 SURPRI FLOWT PRDT P Pressure up Tubing with N2 to 700 psi. 40 bbls in glycol tank, S.G. = 1.087 corrected to 60 F 08:15 09:45 1.50 SURPRI FLOWT PRDT P Slick line on location, perform prejob, rig up(0.125 wire),2.125"stem,TS = RS,QC,6',QC,KJ,5',QC,LSS,QC. OAL 280") 09:45 10:45 1.00 SURPRI FLOWT PRDT P PT W N2 to 700 lbs, RIH W/3"x 5' pump bailer,sit down @ 1932'SLM tap down work pump bailer. Work down to 1933'SLM stick bailer tap up to free tools POOH. OOH no marks, recover 1 quart of sand. 10:45 11:15 0.50 SURPRI FLOWT PRDT P PT W N2 to 850 psi 11:15 12:30 1.25 SURPRI FLOWT PRDT P RIH W 3"x 5'pump bailer,sit down @ 1932 slm. Hit down 5 times work pump bailer for 30 min. Hit down 8 more times POOH. OOH recover 1 quart of sand. Good metal marks from the top of the lock. 12:30 12:45 0.25 SURPRI FLOWT PRDT P PT W N2 to 850 psi 12:45 13:30 0.75 SURPRI FLOWT PRDT P RIH W 3.48"CEN 3"X 1.875"stem 3.61"cen barbell and 1 3/4"sample bailer(17"),Zero @ bottom of cen, sit down @ 1931'SLM. Beat down very hard. Unable to make hole. Work tools by hand. POOH,OOH sample bailer full no metal marks. 13:30 13:45 0.25 SURPRI FLOWT PRDT P PT W N2 to 800 psi 13:45 14:45 1.00 SURPRI FLOWT PRDT P RIH W 3.48"CEN 3"X 1.875"stem 3.61"cen barbell and 1 3/4"sample bailer(28"),Zero @ bottom of cen, sit down @ 1931'SLM.Work tools by hand. Make 1'depth. Pull out of lock,sit back down . Work tools. Unable to make hole. POOH, OOH no metal marks very little in bailer. 14:45 15:00 0.25 SURPRI FLOWT PRDT P PT W N2 to 800 psi 15:00 16:00 1.00 SURPRI FLOWT PRDT P RIH W 3.48"CEN 3"X 1.875"stem 3.61"cen barbell and 1 3/4"sample bailer(17"),Zero @ bottom of cen, sit down @ 1932'SLM.Work tools by hand. Worked tools down 1'. Pulled 400 over to pull free. Set down,tap down, make 1 foot, pull free. POOH,OOH no metal marks. Bailer full. Page 44 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:00 1.00 SURPRI FLOWT PRDT P Add 8'2.125"stem and PT to 800 psi W N2. RIH W 3.48"CEN 3"X 1.875"stem 3.61"cen barbell and 1 3/4"sample bailer(28"),Zero @ bottom of cen,sit down @ 1931' SLM.Work tools by hand to 1932.5' SLM. Tap up to free tools. sit back down at 1931'SLM. Tap down on tools to 1932.5'. POOH,OOH no metal marks. Bailer full. 17:00 18:15 1.25 SURPRI FLOWT PRDT P PT to 800 psi W N2. RIH W 3.48" CEN 3"X 1.875"stem 3.61"cen barbell and 1 3/4"sample bailer (28"),Zero @ bottom of cen,sit down @ 1931'SLM.Work tools to 1933'SLM. Tap up to free tools. sit back down at 1931'SLM. Tap down on tools to 1932'. POOH, OOH good metal marks. Bailer full. 18:15 19:30 1.25 SURPRI FLOWT PRDT P PT to 800 psi W N2. RIH W 3.48" CEN 3"X 1.875"stem 3.61"cen barbell and 1 3/4"sample bailer (28"),Zero @ bottom of cen,sit down @ 1931'SLM.Work tools by hand to 1933'SLM. Tap up to free tools. POOH,OOH good metal marks. Bailer full. 19:30 20:45 1.25 SURPRI FLOWT PRDT P PT to 800 psi W N2. RIH W 5'x 3/4"pump bailer. Sit down at 1931' SLM. Tap down and skip past lock. Sit down@ 1934'SLM tap down and work pump. POOH. OOH with pump blue fluid and 1 quart sand. 20:45 22:00 1.25 SURPRI FLOWT PRDT P PT to 800 psi W N2. RIH W 3.48 cent 3'x 1875"stem 3.61"cent and equalizing prong. Sit down @ 1931' SLM. Work to 1934 no pressure change until prong removed from lock and KOBE. See XPIO gauge#2 clime 200 psi. POOH. OOH with good metal marks on prong centralizer. 22:00 22:45 0.75 SURPRI FLOWT PRDT P Watch well, little change in tubing pressure-800 psi. 965 psi on XPIO gauge#3. Shut down SLB HPP and shut in IA returns line at 125 bbl glycol tank. Shut down surface glycol circulation. Open IA to open top tank,48 bbls,check for flow. No flow. Step up to 11 gpm circulating hot glycol down the eater string taking returns up the la to the 125 bbl tank. SLU rigged down for the night. 22:45 00:00 1.25 SURPRI FLOWT PRDT P Continue to circulate the IA with heated glycol. Page 45 of 45 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/22/2012 24 hr Summary Pulled Weatherford standing valve with polished bore @ 1957' RKB. Removed ball and both KOBE knockouts, reset at same. Set 3"RC jet pump(S/N: PH-1108)with spacer pipe and stinger assembly on 3.812 DB lock(OAL 200")@ 1942' RKB. Pushed 43 bbls glycol back to Expro stack pack. Displaced 50 bbls glycol from inner annulus to 125 bbl glycol tank. Loaded IA with power fluid,commence jet pumping activities pumping to the IA taking production from the tubing through the separator to return tanks. 00:00 06:45 6.75 SURPRI FLOWT PRDT P Continue to circulate the IA with heated glycol. 06:45 08:45 2.00 SURPRI FLOWT PRDT P Slick line on location,perform prejob, rig up(0.125 wire),2.625"TS= RS,8',QC,KJ,LSS,QC. (OAL 210") Cut 150'of wire. 08:45 09:45 1.00 SURPRI FLOWT PRDT P PT to 800 psi W N2. RIH W 3.48" CEN 3"X 1.875"stem 3.61"cen barbell and 1 3/4"sample bailer (28"),sit down @ 1932'SLM.Work tools by hand,work down to 1932.5 POOH OOH good metal marks on bailer. Bailer empty. 09:45 11:00 1.25 SURPRI FLOWT PRDT P PT to 875 psi W N2. Open up pressure dropped to 850 psi. RIH W 4.5"PRS sit down latch Weatherford SV @ 1931'SLM. Hit 10 OJ licks& 5 spang licks Pulled SV POOH W standing VLV. 11:00 12:00 1.00 SURPRI FLOWT PRDT P PT to 860 psi W N2. RIH W 3"drive down bailer,sit down @ 2176'SLM/ 2201'RKB tap down once POOH OOH bailer ful of fluid. Expro wrapped sand trap in rino hide reinforced visqueen). 12:00 13:15 1.25 SURPRI FLOWT PRDT P PT to 865 psi W N2. RIH W 4.5"Z-6 &3.75 DB lock,Weatherford seal bore assembly, and standing valve W ball,seat,and both KOBE knockouts removed. Set lock in DB nipple @ 1913'SLM/1957'RKB. POOH OOH W/Z-6,tattle tail indicates good set. 13:15 14:45 1.50 SURPRI FLOWT PRDT P PT to 860 psi W N2. RIH W 4.5"Z-6 &3.812 DB lock&3"RC jet pump S/N: PH-1108 ratio 6C(OAL 200") Stinger tip 1.73"ID. Sit down on stinger @ 1913'SLM tap down work past and set down at 1917'SLM set jet pump,good pull test,shear off POOH OOH tattle talil indicates lock NOT set. 14:45 15:45 1.00 SURPRI FLOWT PRDT P PT to 860 psi W N2. RIH W 4.5" PRS sit down @ 1917'SLM. Hit 5 licks move jet pump up to 1910'SLM beat up on jet pump for 20 min. Pull jet pump free. POOH OOH. Jet pump looks good. 15:45 16:15 0.50 SURPRI FLOWT PRDT P Redress lock,stinger looks good. Page 46 of 50 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 17:45 1.50 SURPRI FLOWT PRDT P PT to 860 psi W N2. RIH W 4.5"Z-6 &3.812 DB lock&3"RC jet pump S/N: PH-1108 ratio 6C(OAL 200") Stinger tip 1.73"ID. Sit down on stinger @ 1913'SLM tap down work tools down and set down at 1919' SLM Beat down Z-6, good pull test, shear off, POOH OOH tattle tail indicates lock good set. 17:45 19:15 1.50 SURPRI FLOWT PRDT P SL Rig down. 19:15 20:00 0.75 SURPRI FLOWT PRDT P Pushed 33 bbls glycol to Expro stack pack tank to replentich Glycol used when loading the IA. 15 bbls glycol remain in the 125 bbl tank. 20:00 23:24 3.40 SURPRI FLOWT PRDT P Line up N2 pump to displace the inner annulus with N@ taking glycol returns to the 125 bbls tank. Returned 39 bbls of glycol to the 125 bbl tank. Estimate 11 bbls of glycol left in the tubing. 23:24 00:00 0.60 SURPRI FLOWT PRDT P Line up to pump N2 across the tree to Expro. Pressure test through sand trap to 1000 psi. Pressure test good. 03/23/2012 Unable to remove hydrate plug in production casing via dissociation. Bull head 250 ga1140 F glycol down tubing via heater string and open pocket at 1944'. Bull head N2 down tubing to open pocket at 1944'taking returns to the 70 bbl sand jet tank. Bring well online under jet pump production. 00:00 03:45 3.75 SURPRI FLOWT PRDT P Blow air through surface lines in direction of supply and back through suction to tanks. Attempt to flood suction lines to HPP. Troubleshoot blockage. Flood lines, prime pumps. 03:45 05:45 2.00 SURPRI FLOWT PRDT P Fill inner annulus with power fluid via the heater string while bleeding at IA to the 70 bbl sand jet tank. Start 795589 gal at 16 gpm. Raise rate to 22 gpm for 45 minutes. Reduce rate to 10 gpm,catch fluid at sand jet tank. Shut down pump 797513 gal- total 1924 gal. 05:45 08:15 2.50 SURPRI FLOWT PRDT P Line up HPP to IA,taking returns& production to Expro. Start HPP. Fluid to surface at 07:21. 28% N2, 70%CH4, 0%CO2,0.423 ppm SF6, 2.144 R114 @ 08:00.Slow HPP rate to 5 gpm for 5 min, increase rate to 10 gpm. 08:15 14:15 6.00 SURPRI FLOWT PRDT P Increase rate to 14 gpm 08:35,slow rate to 12 gpm 0846,slow rate to 10 gpm 08:56, increase rate to 12 gpm 09:07,increase rate to 14 gpm 09:28. Hold rate. Page 47 of 50 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 16:09 1.90 SURPRI FLOWT PRDT P Start cool down of N2 pump. Come down on the HPP. Blow down all surface lines and line up to pump heated glycol to the tubing via the heater string. Pump 250 gal of heated glycol down the heater string while trapping pressure on the tubing and IA. 46 bbls of glycol in 125 bbl _tank. 16:09 18:09 2.00 SURPRI FLOWT PRDT P Lined up N2 pump to the tubing taking returns through the open pocket at 1944'to the 70 bbl bleed tank via the inner annulus. Pumped 11277 SCF,small amount of N2 returns observed at the returns tank. Shut down the pump. 18:09 18:39 0.50 SURPRI FLOWT PRDT P Line up HHP to IA,taking returns& production to Expro. Start HPP at 13 gpm and 1500 psi. Open up the well to the separator. 18:39 19:45 1.10 SURPRI FLOWT PRDT P Draw down well head through separator. 19:45 20:21 0.60 SURPRI FLOWT PRDT P Draw well head to 100 psi,gas rate increased to 236 MSCFD,XPIO2 decreased to 350 psi. Shut in choke to build bottom hole pressure. 20:21 00:00 3.65 SURPRI FLOWT PRDT P Attempt to stabilize rate at 490 psi. 0-150 MSCFD and slugging water. 03/24/2012 Normal jet pump operations gas flow trending down from 50 to 20 MSCFD. Water and solids production trending to zero. BHP c XPIO 2 475-510. 00:00 03:00 3.00 SURPRI FLOWT PRDT P Well head 200-300 psi. Flow rates: —50 MSCFD gas. Water consumed 8.3 bbls. BS&W 0.05%to 0.0%. Managing flow by target pressure of 490 psi on XPIO gauge#2,average 460 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. 03:00 06:00 3.00 SURPRI FLOWT PRDT P Well head 250-300 psi. Flow rates: —40 MSCFD gas. Water produced 2.5 bbls. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2,average 460 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. Page 48 of 50 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 SURPRI FLOWT PRDT P Well head 250-260 psi. Flow rates: declining from 35-25 MSCFD gas. Water consumed 1.7 bbl. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge #2, increasing 460-477 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. 09:00 12:00 3.00 SURPRI FLOWT PRDT P Well head 175-250 psi. Flow rates: 35-25 MSCFD gas. Water consumed 2.5 bbls. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2, increasing 450-525 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. Trace solids after tank swap at the High Pressure Pump(HPP)inlet. Incident at 09:30 while swapping power fluid supply/return tanks the suction line to the HPP was frozen and jet pumping was temporarily down. Crews swapped back to the original configuration,diagnosed and rectified the issue. 12:00 15:00 3.00 SURPRI FLOWT PRDT P Well head 250 psi. Flow rates:-25 MSCFD gas. Water produced 3 bbls. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2,502-511 psi. Jet pumping at 11-12 gpm and 1000-1100 psi at the IA. trace solids at the HPP suction. 15:00 18:00 3.00 SURPRI FLOWT PRDT P Well head 250-225 psi. Flow rates: 20-25 MSCFD gas. Water produced 0 bbls. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2,510-485 psi. Jet pumping at 11-12 gpm and 1000-1050 psi at the IA. trace solids at the HPP suction. 18:00 21:00 3.00 SURPRI FLOWT PRDT P Well head 225-200 psi. Flow rates: 27-20 MSCFD gas. Water produced 0. BS&W zero. Managing flow by target pressure of 490 psi on XPIO gauge#2,485-475 psi. Jet pumping at 11-12 gpm and 1010-1000 psi at the IA. trace solids at the HPP suction. 21:00 00:00 3.00 SURPRI FLOWT PRDT P Jet pumping at 11 gpm and 1000 psi at the IA. Slowly working BHP down. 03/25/2012 Normal jet pump operations gas flow trending down from 11 to 7.5 MSCFD. Jet pump rate increased to 13 gpm. Gas rates increased then trended lower—14-13 MSCFD Total gas produced from midnight to 20:00 9.3 MSCF. Water production 8.3 bbls as of 20:00. BHP @ XPIO 2 420 psi. Solids production zero. Page 49 of 50 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 SURPRI FLOWT PRDT P Well head 175-160 psi. Flow rates: —11-8 MSCFD gas. BS&W 0.0%. Managing flow by target pressure of 490 psi on XPIO gauge#2,average 500 psi. Jet pumping at 11-12 gpm and 1070 psi at the IA. Trace solids at the High Pressure Pump(HPP) inlet. 03:00 06:00 3.00 SURPRI FLOWT PRDT P Well head 160-150 psi. Flow rates: —8-7.5 MSCFD gas. BS&W 0.0%. Managing flow by target pressure of 490 psi on XPIO gauge#2,average 500 psi. Jet pumping at 11-12 gpm and 1070 psi at the IA. Trace solids at the High Pressure Pump(HPP) inlet. 06:00 09:00 3.00 SURPRI FLOWT PRDT P Well head 150-250 psi. Flow rates: —8-14 MSCFD gas. BS&W 0.0%. Managing flow by target pressure of 440 psi on XPIO gauge#2. Increased rate to drop bottom hole pressure 1300 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. 09:00 12:00 3.00 SURPRI FLOWT PRDT P Well head 250-220 psi. Flow rates: — 15 MSCFD gas. BS&W 0.0%. XPIO gauge#2,average 435 psi. Jet pumping at 1300 psi at the IA. Trace solids at the High Pressure Pump(HPP)inlet. 12:00 15:00 3.00 SURPRI FLOWT PRDT P Well head 220 psi. Flow rates:—15 MSCFD gas. BS&W 0.0%. XPIO gauge#2,average 425 psi. Jet pumping at 1317. Trace solids at the High Pressure Pump(HPP)inlet. 15:00 18:00 3.00 SURPRI FLOWT PRDT P Well head 215 psi. Flow rates: —13 MSCFD gas. BS&W 0.0%. XPIO gauge#2,average 425 psi. Jet pumping at 1315 psi at the IA. Trace solids at the High Pressure Pump (HPP)inlet. 18:00 00:00 6.00 SURPRI FLOWT PRDT P Jet pumping at 1317 psi at the IA. Preassure at XPIO2 420 psi. 12 MSCF gas. Page 50 of 50 4 1/16-5K (R-39) i■i iii o ! 1 ����- I • - I I , O� . eo J` I. 1 ' cl, � P. „ . 4.84 -Q------j�i0 /,oil _' Is � 1 Q�� rr_ O 376.94 I' •17– 0 a II l 47 r ,�i=[. L '`0, 2 I/16-5K (R-24) 1®, i 11.94 2 9/16-5K (R-27) • O fcli, � SEAL SLEEVE PORT '� D ' .1 I; �«� 10 LOCKDOWN SCREWS 7.69 0 II-5K (RX-54) (,.,,, 1 10. 10 = 111111 2 I/16-SK M120 GV �n �� ,�1' 1 SEAL SLEEVE PORT 26.41 • �• �i„ .L>� •. ..•� 1 670.81 SEAL SLEEVE PORT i I� g Q -, ! (�� Ae f I TOP VIEW II ■ ® (/4 ■ - to J ISI TUBING HANGER '-,I� I I �" IIt=='�_ �t�t�l - O I 1!�' lU! 64.00 e ! I 07.44r3/4'LP PORT 1625.6 V 33.281 0 2 I/16-5K M120 GV (1'111 r-o, ..... 1) 10'10' 16 TEST PORT 3/4'LP PORT 4.06 ► i 3/4'LP PORT I _ _ . GROUND LEVEL ■;(( m� __ BOTTOM VIEW } -.—_____4,!„... "�i1� r��� �- 10 LOCKDOWN SCREWS TUBING HANGER 11 –i}:!"1 I I-5K (R-54) 2 I/16-5K M120 GV � ` 2275 0 4IiIIi1 s77.as i � �g ,F,03� 15 * INI -i- , _-_ INI 2332.2.41 I 1 I j 3.26 nig 6.10 © 82.93 154.97 ir. ^ } V �� 411 • i 'ITEM II PART NUMBER I DESCRIPTION 8 I 13-300-030 DIVERTER LANDING RING,20 X 18.75 BOWL I 2 P166050 10 3/4 CASING HANGER 3 (P1648191 CASING HEAD ASSY,11-5K,W/ LOCK SCREWS 4 13-300-718 GEN 5 TUBING HEAD ASSY.11-5K X II-5K 5 (P1000060777) 7 5/8 CASING HANGER - 6 (P1000009887) TUBING HANGER ASSY,TC-1A-EMS,11 X 4 1/2 7 (P119036-0002) ADAPTER ASSY,A-4-M,11-5K X 4 I/16-5K 8 12-090-160 10 3/4 C-2I CASING HANGER 9 P166636 10 3/4 BELL NIPPLE ---r----------20'OD CASING –...---...„.._I0 3/4'OD CASING –�-7 5/8'OD CASING _�4 1/2'OD TUBING OAS ENDO R AUTE 'WELD= O N E AT'OOO fM 5 WELLHEAD REF:DM100049826-2 REV D PRIVATE AND CONFIDENTIAL I REVISIONS DESCRIPTION WC REVIEW • A II-12-10 °R<RR b, 8 11-24-10 GAS HYDRATE WELL MAROUEZ 11-12-10 cMCTedlnologia EMU RIM 1,11001MMI 0111t 411.1110 IT PEIPOIT 11,191017 10 1116111.1,o E..,...e MS LttIMXT C 12-23-10 GENERATION 5 WELLHEAD °NARTINOMIEN m,xkwceo 1110101-.0. MAROUEZ II-12-10 ilutnfltS.MIS hor NTKUS WOO IX 4.91.1411i10 DO 20 X 10 3/4 X 7 5/8 X 4 1/2 .1011 REV,EII -0.011 9.N.5100110 rut 70111110111•6510/1.MI 140/1114;MOM OR Mt{MR.MI ROT ID KURFACTICI I I SK COMPLETION RAMAYANAN 11-12-10,,,,,R,E„RER APPROVED 61 ,r , ::""" �„ow,„Z,°„.,,.,, , -,“ AMILTON 11-12-10 DM100098736 ConocoPhillips WELL NAME:IGNIK_SIKUMI_#1 AT90 Onn'.M zoo. I AT6O AT30 [iarT '!_1\I _ ONMM 000 MEIMIal ` 1 GR AT20 DTCO 0 SH_DT X6T_..M1 MOBIle AT10 RHOZ DEPTH SH ARCHIES KTIM IN 12 0000 1000MEM FEET v/v ,.01 MD .. HCAL AS_TOTA!_UN1 SH_CMR KSDR II VIE .��111 L �_ 1�I11111111•1116N11111 1 L!1 11111H. ` . 11 1 _ ___ ___.... 4 .-.. arl ri_,____Iiii 11E"-.1.1C____- _ 1.4p.- Ingo rill _...r. t- - -@Ftiie(rc .1,1 i .. L... I it", :; 111 L -7.-- : t. litt - - ---- . fai II1h!V miw - 1 -,, 2000 --_ ___.. 11,1111--- „ !„._,_.,...... -Ill] I. __ ii SIL _ __ _ _ ,� 1111k l !_,_ _ _ __ __ r _ _. I , ..____ __! ____ i ir ri1 .,..., L:_ .. 1 22soui I--'� I1 I _11'JB 0 �_ _.,_,.., 742....... ...- ...____ I i'lit fl iii ——..... ”'m':'..'-'--.all--=----41;111k141 Fes_ 11P- _ 1 r ibll' .- s Hole Size Csg/Tbg Lb/ft Grade Thread MD 13-'h" 10-3/4" 45.5 L-80 BTC 1,473 1 1 9-7/8" 7-5/8" 29.7 L-80 BTCM 1,974 9-7/8" 4-'h" 12.6 L 80 I BTM 1,996-2,592 7-5/8"Csg 4-%"Tbg 12.6 L-80 IBTM 1,986 I DTS Cable I Electronic Cable Ps/Te Gauge @ 2,034' e Sensor @ 2039.48' ' Coiled Tbg ' : H.: •:•::.:: :.:•:•:.: •:•::::.:.:.:. 3"Coiled Tbg D Sand :•. . . . 2061 —2,110 to.bliff fl/bbl 1 —DB nipple(3.875"min ID) is ' ` 2—Chemical Injection Mandrel �`� 'g5� ,0157-1 0.1 3—DB nipple(3.813"min ID) ii 5"x154" =0247 343.I 4—Gas Lift Mandrel 5—DB nipple(3.75"min ID) 6—PIT Gauge �''� 7—DB nipple(3.687"min ID) 8—P/T Gauge ' 9—Polish Bore 3.625"min ID) I + 10—P/T Gauge ' 11 —Packoff Bushing(Cmt'g) i j 1,473' ,, l DB Nipple @ 2,224' • 8 PIT Gauge @ 2,226' Sensor @ 2,231.72' i .__1 -- 0 DB Nipple @ 1,927' Upper C Sand 2 CIM @ 1,929' 2,240—2,274 DB Nipple @ 1,942' GLM @ 1,944' Polish Bore @ 2,278' DB Nipple @ 1,957' I PIT Gauge @ 2,285' 1° .„.'. Sensor@ 2,291.67' I Packoff Bushing @ 2,371' EOT@ 1,986' 1111111110.1. 2,403'Float Collar P/T @ Gauge 2,034' Sensor @ 2,039.48' • 2,597'TD Ingik Sukumi#1 production Casing Well: Ignik Sukumi 1 1 ConocoPhillips 7-518"29.7 ppf 140 BTC-m x 4-1/Z''IBT-m casing Date: 4/2412011 Alaska,Inc. Rig: Nordic 3 Depth -Plijill I Jt Number N Jtsot ? 11,1�I Well Equipment Description and Comments Length Tops lly�� ig floor to lower lockdown screws 28.7(Load shot.i. .Jr 29.4') Rig floor to lower lock down screws 28.70 FMC 7-518"casing hanger .71 28.70 7-5/8"pup jt 29.7 ppf L-80 BTC Pin x Pin 1.96 29.41 Jts 15 to 59 ;5 Jts 7-518"29J ..11-80 BTC-m cosi . 1932.84 31.37 .•+:;,.r . .. 4 E,, ^,. ...,...; -- 10.10 1964.21 over:7-516"29,7 ppf L-60 Bm Pdk�.N TC. 5.1/2' 17 ppf L-€ I B1�f',M i[aLax 1.76 1974.31 :kor 190-47 Casing S2a1 I'Btm S.M"BTC Pin u Pin I )KM ) 18.25 'WNW -;'e S's©V@t:6-11.2"17 ppf L 80 Bic M c>k 4-11' Ii'T-n-i Pin 1.42 1994.32 / "9,0 ppf L-60 IBT Pup 9.79 1995.74 Jts 14 to 14 1 Jts l4-1/2"12,6 ppt L-60 IBT-tn Casing 28.22 2005.53 Pinnacle Gone C (pan Ow)441l2"12,0 pet �a lu+�1 i u V 6'N ' 10.13 2033.75 Jts 9 to 13 5 Jts �' 155.32 0..a t X4=1/2"120 ppf 140 IBT-m Pups(7.83', 3.83',9.78', 3.82') 25.26 2199.20 Ca "OOP Na.Do Nipple 3,007"kirk'ifnefr1 ID,4=W ISTAin 1.53 M4.411 Pinner&me Cm*( *RI)4=1( "1 :0 10140 ll fi-m P a P 10.13 un-.' 4=1N2"12.0 ppf L-80 IOTA)Nam(3.78') 3.78 2236.12 Jts 8 to 8 ' 4-1/2"12.6 ppf L-80 IBT-m casing 30.91 L 1 4=112" i2:0 ppf L-8018T-Iii tSS111t1 Pup 5.83 2270.81 (01'.¶ �F de 16 .,_ „ .. -.. -.,- -. -- .95 2276.64 f 864000 0 a§m s ,e=: i'... =v'. F`_( :�28"10) 5.37 2277.59 14-1i2" 12,6 plat L-80 IBT-m ossluti PUp 1.85 num Pineals @uage fattier(pass thtti)4-11'12,0 ppf L40 IST ii P aP 1 10.13 2284.81 4.1/2"pup It 110 ppf L40 IBT-m Pups(3,83'+ 9.82') 13.65 2294.94 Jts 6 to 7 2 Jts 4-112" 12,6 ppf L=60 IBT-m casing 62.21 2308.59 Ekoker Pmkoff Bushing 1.33 • 2370.80 4-112"12,6 plat L-80 IBT-m Float Collar joint - 31.05 23aa.113 Weatherford 4-1/2"IBT-m Float collar,iN sl 402 1.35 2403.18 Jts 1 to 5 5 Jts 4-1/2" 12,6 ppf L-80 IBT-m casing 155.10 2404.53 4-1/2"12.6 ppf L-80 IBT-m Float ShoejOfnt 31.11 2559.6 Weatherford 4-1/2"IBT-m Float shoe,Model 303 1.60 2590.74 2592.34 2592.34 Note:"DB"Nipple Is 53 feet from Baker Seal Assembly 2592.34 Pink Line is representative of the perforated interval 2592.34 PIP Tag Collar painted White. 2592.34 Remarks: Up Wt 95K TD at 259T MD,TVD=2597' Dn Wt 95K 10 3/4"Shoe @ 1473'MD Block Wt 35K Supervisors:Dale Rowell/Scott Heim/Steve Shultz 1 Casing OR Tubing OR Drilling Detail Well: Ignik#1 4.5"IBT-M Special Clearance tubing UPPER COMPLETION Date: 4/2512011 ConocoPhillips Rig: Nordic 3 Alaska,Inc. Depth Jt Number Joints 0 Well Equipment Description and Comments Length Tops 00Page Papa 1 3KB To Rotary Table-26.46' RKB To Rotary Table-26.46' 26.461.1.1111 FMC Tubing Hanger&41/2"12.6#L-80 IBT-M Pup 31.05 26.46 4112"12.6#L-80 IBT-M Tubing Pups(9.93',9.95')ID.-13.958" 19.88 57.51 Jts 1 to 60 60 Jts 41/2"12,6#L-80 IBT-M Tubing ID a 3,958" 1845.92 77.39 41/2"12.61 L-80 IBT-M Tubing Pup ID a 3.958" 3.78 1923.31 41/2"Camco"DB"Nipple with 3.875"Pr091e 18T-M 1.56 1927.09 '4112°KBMG=LTS Chemical Injection Mandrel IBT-M 7.68 1928.65 _ 4 1/2" 12,6#L-80 IBT=M Tubing Pup ID -3:958" 5.72 1936.33 - 4 1/2"Catnc"DB"Nipple with 3,813"Prtisle IBT=1W 1.56 1942.05 - 41/x"x 1"Cameo I(8MG GLti141 with SOV installed 4 6etch 7.22 1943.61 41/x"12,60 L40 IBT=M Tubing Pup ID a 3,968" 5.83 1950.83 = 41/r Cato"DB"Nipple With 3,760"Pr® ile IBT=M 1.58 1956.66 41/x"12,6#L=80 IBT=M Tubing Pup ID a 3.95" 3.77 1958.24 41/x"12,6#L40 IBT=M Tubing Pup ID a 3,966" 5.85 1962.01 41/x"12:6#L40 IBT=M Leoeter Sub 1.05 1967.86 411 " 12.6#L40 1ST=M Seel"%terribly ID a UN" 17.01 1968.91 1985.92 1985.92 1985.92 1985.92 1985.92 Attach FlatPak as pee CJS rep, 1985.92 1985.92 1985.92 1985.92 The Casing Seal Bore receptacle top is 6 1976.07' 1985.92 1985.92 install Clamp at every Mid Joint-Keep count on same. 1985.92 1985.92 1985.92 Ran a total of 62 Protector clamps at Mid Joint. 1985.92 Ran 3 Stainless Steel Bands. 1985.92 1985.92 1985.92 1985.92 Remarks: Up Wt 60K All collars are Special Clearance-4.92" Dn Wt 65 K All tubing drifted to 3.91" Block Wt 35 K Note:Corrected Pipe tally by 10.90' Supervisors:Scott Heim/Dale Rowell ti G {1cZ7v Regg, James B (DOA) From: Klein, Perry Dwayne [Perry.D.Klein@conocophillips.com] Sent: Wednesday, March 07, 2012 2:35 PM To: NSK Problem Well Supv; Regg, James B (DOA) Subject: FW: Feb 19,2012 DTS Playback to be presented to the State Attachments: ConocoPhillips Ignik Sukumi Hydrate#1 Feb 19,2012 DTS Playback- Draft.mp4 Jim, Enclosed is the DTS trace during the witnessed MITIA. Simply open and click play. The time stamp is located in the lower left hand side of the screen. It's not terribly exciting to watch but clearly shows the overall drop in temperature from the surface to the end of the flat pack circulating string in the IA at 1900'. The DTS fiber optic package is clamped to the outside of the production casing. Please contact me if you have any questions. Perry Klein ConocoPhillips Wells Supervisor Office 907-659-7891 Cell 907-943-1244 Pager 907-659-7000 934 From: Sam Gorgi [mailto:sam.gorgi@pinntech.com] Sent: Tuesday, March 06, 2012 4:53 PM To: Klein, Perry Dwayne Cc: Hester, Keith C; Martin, Kenneth Lloyd Subject: [EXTERNAL]Feb 19,2012 DTS Playback to be presented to the State Hi Perry, Please see attached DTS Playback as per your request to be submitted to the State inspector. I uploaded the file on FTP site too. It will expire 30 days from today. Please let me know if you need anything else. I will probably be in Houston by the time you come back. But you have my phone number and email as well. Please feel free to contact me anytime. https://ftp3.halliburton.com/ Username: Ignik Password: hydrate Regards, Sam Gorgi Data Analyst Halliburton Energy Services, Inc. Pinnacle Fiber Optics Center of Excellence 1 10110 W Sam Houston Pkwy North Building C-Suite 300 Houston,TX 77064 IEPhone: 832-634-2236 l'Cell: 713-397-8926 W Fax: 832-634-2260 This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient(or authorized to receive information for the intended recipient), please contact the sender by reply e-mail and delete all copies of this message. 2 X i. III J al- , 1 co +4 li\ p il .Y a N 1 ~ 0 CN '� f N N N ( g ,—I 70 r cta CO i U. VII' ' 1 ---:4. CA O ti) w. 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O 0 > co (n < 0 (0 ` X 00 Q. (e0) 0 m &- u) o 0 0 v ma)c) EE a' ro t a I 03 0 0 CI Q o an ccnn 'a oe cn to Q O a N N ain c u C� E � _ o a, m 'r U F F- a in >. cn ofc •-0 Nt C c o 0 ca d O 'c co � -0 'a — Q z LL 0 m co n ° o}}- . Q . U in n = o 0 0 V .D co O Z °,Lo 0 � aN O C NJ Q O I 13 - � to o a. 6 o .a E 2 a Y E Z G z in 0 (0o 'a y E a � 7' 0 o d a o LL (0 n. • P71) Regg, James B (DOA) Z.I��Z7� From: Regg, James B (DOA) lf ZIZ �Z Sent: Thursday, February 23, 2012 12:29 PM To: NSK Problem Well Supv; Ignik Supervisor Cc: Smith, Bruce E (Legacy Energy Ventures, Inc.); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA); Roby, David S (DOA) Subject: RE: Ignik Sikumi (PTD#211-027) notice of failed MITIA Perry and Brent— Impressive project! I have reviewed the information provided for Ignik Sikumi#1 (PTD 2110270) in response to the MITIA"fail" that was witnessed by AOGCC on 2-19-12. You have presented evidence and I agree that the well's IA pressure decline during the witnessed test can be attributed to thermal considerations, and not the lack of mechanical integrity. Please provide the temperature traces that further support your cooling argument. The well may continue to operate without seeking administrative approval under EIRO#5. As you have suggested, adding the well to the monthly injector monitoring report(injection rates, temperatures and pressures) would be appropriate. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, February 21, 2012 4:35 PM To: Ignik Supervisor; Regg, James B (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Cc: Smith, Bruce E (Legacy Energy Ventures, Inc.) Subject: RE: Ignik Sikumi (PTD# 211-027) notice of failed MITIA All, Attached is the form for the witnessed MITIA that was performed below. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907)659-7000 pgr. 909 From: Ignik Supervisor Sent: Tuesday, February 21, 2012 3:34 PM To: 'Jim.Regg@alaska.gov' Cc: NSK Problem Well Supv; Smith, Bruce E egacy Energy Ventures, Inc.) Subject: Ignik Sikumi (PTD# 211-027) n• ice of failed M1TIA Jim, On 2-19-12 Chuck Scheve (AOeCC)witnessed a MITIA of Ignik Sikumi# 1 per the requirements outlined in ERIO-001 Enhanced Recover Injection, rder No 5, rule 6. ( 1 P86( s.-40,4; �( P-r6 2/1 o 2-7o Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, February 22, 2012 12:41 PM �t4 Z ZZ To: 'Ignik Supervisor' Cc: NSK Problem Well Supv; Smith, Bruce E (Legacy Energy Ventures, Inc.) Subject: RE: Ignik Sikumi (PTD#211-027) notice of failed MITIA Yes, please. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-7934236 From: Ignik Supervisor [mailto:IgnikSupervisor@conocophillips.com] Sent: Tuesday, February 21, 2012 4:27 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; Smith, Bruce E (Legacy Energy Ventures, Inc.) Subject: FW: Ignik Sikumi (PTD# 211-027) notice of failed MITIA Jim, I failed to mention the well passed a MITT to 2800 psi and MITIA to 2900 psi on 1/29/12 prior to well bore heating, perforating and injection. Would you like this data submitted on the state form? Ignik Sikumi Supervisor Rick Overstreet/ Perry Klein Office 907-659-7929 Cell 907-943-1244 Pager 907-659-7000 934 Harmony Radio 758-3924 1 Regg, James B (DOA) From: NSK Problem Well Supv[n1617@conocophillips.com] - Sent: Tuesday, February 21, 2012 4:35 PMl 1-17 I7 Z, !ZTo: Ignik Supervisor; Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Cc: Smith, Bruce E (Legacy Energy Ventures, Inc.) Subject: RE: Ignik Sikumi (PTD#211-027) notice of failed MITIA Attachments: MIT Ignik Sukumi 1 02-19-12.xls All, Attached is the form for the witnessed MITIA that was performed below. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907)659-7000 pgr. 909 From: Ignik Supervisor Sent: Tuesday, February 21, 2012 3:34 PM To: 'Jim.Regg@alaska.gov' Cc: NSK Problem Well Supv; Smith, Bruce E (Legacy Energy Ventures, Inc.) Subject: Ignik Sikumi (PTD# 211-027) notice of failed MITIA Jim, On 2-19-12 Chuck Scheve (AOGCC)witnessed a MITIA of Ignik Sikumi# 1 per the requirements outlined in ERIO-001 Enhanced Recover Injection Order No 5, rule 6. The inner annulus dropped from and initial pressure of 1910psi to 1828, 1770, and 1716 psi in fifteen minute intervals over a 45 minute test period. While the test pressure fell less then 10% over 30 minutes as prescribed in rule 6 the pressures did not show stabilization during the 45 min test period. Tubing pressure during the test was 1269, 1265, 1264, and 1264psi at initial 15, 30, and 45 minutes respectively. The injectant was 77:23 mole percent ratio of gaseous N2:CO2 during the test. Injection was approximately 20 kg/hr or 500scf/hr. The PWS supervisor will be submitting the MIT results on the state form. The well was completed with a coiled tubing flat pack strapped to the outside of the 4.5"tubing. Two of the 3/4" strings of coiled tubing are open ended at the bottom of the IA, —1900'. Attached to the outside of the tapered production casing are two fiber optic strings, DTS and DAS to capture real time temperature and vibrations from surface to TD and three high accuracy pressure/temperature gauges. Two above the perforated zone of 2243-2273' and one below. A heated mixture of 60/40 glycol with an inlet temperature of—80 is being pumped down the IA. Returns are taken from the heater string to an open top tank and line heater. The temperature at 1900' is being maintained at 42 F, roughly ten degrees above the natural formation temperature. The IA is being circulated to maintain a constant injection temperature as well as to prevent hydrate formation in the tubing during the injection and production phase. In order to perform the MITIA, heated glycol circulation must be stopped as soon as the annulus is isolated at the well head. The instant the casing valves are shut in the permafrost zone starts cooling the fluid packed IA back to pre circulation temperature. The IA temperature drops rapidly because of the thermal contraction of the glycol mixture causing the test to artificially fail. Ceasing IA circulation for a long duration of time to allow the IA to equilibrate with the permafrost would be detrimental to the scope of the project. Due to the nature of the completion and the specialized surface equipment we have the ability to control injection rates to and temperature for surface and the three bottom hole gauges. The column of glycol on the back side has a specific 1 gravity of 1.101 and a hydrostatic pressure co—900 while pumping. I propose that CPAs supply AOGCC with injection rates and pressures, similar to wells on the monthly failed MIT report, throughout the injection period. In addition we can supply temperature traces that support the cooling argument. Please let me know if this solution is acceptable to you. I've enclosed two schematics for your convenience Sincerely Perry Klein Ignik Sikumi Supervisor Rick Overstreet/Perry Klein Office 907-659-7929 Cell 907-943-1244 Pager 907-659-7000 934 Harmony Radio 758-3924 « File: Ignik Sikumi Schematic-wellview.pdf>> << File: Well Bore Schematic Ignik Sikumi#1.pdf» 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoq@alaska.00v: doa.aoocc.orudhoe.bavraalaska.aov; phoebe.brooks(rDalaska.aov tom.maunder@alaska.gov OPERATOR: ConocoPhillips,Inc. FIELD/UNIT/PAD: Prudhoe Bay/PBU/Ignik Sikumi DATE: 02/19/12 OPERATOR REP: Ives/Jensen AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Ignik Sikumi 1 'Type lnj. G - TVD "1,969' Tubing 1,268 1,269 " 1,265 1,264 1,264 - Interval I P.T.D. 211-027-0 ' Type test P Test psi -1500 Casing 1,910- 1,828_ 1,770 1,716 ' P/F F Notes: Initial witnessed MITIA. OA Well Type Inj. TVD _ Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing _ P/F. Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well, Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT Ignik Sukumi 1 02-19-12 r r PBU IGNIK SIKUMI 1 ConocoPhilliYfs VveII Attributes .ax Angle&MD ,TD Alaska,Inc.~ Wellborn API/UWI Field Name Well Status 'Incl(.1 MD(ftKB) Ant Btm(ftKB) Cogups .' 500292344300 PRUDHOE BAY UNIT EXPLOR 0.53 2,457.01 2,597.0 Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •Well Confl9'VERTICAL-IGNIK SIKUMI t,2/18/2012 9'57'22 AM SSSV:NIPPLE Last WO: 34.60 4/28/2011 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By 'End Date Last Tag:SLM 2,350.0 4/30/2011 Rev Reason:NEW WELL,GLV C/O,TAG mem 5/2/2011 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd CONDUCTOR 16 15.062 32.0 108.0 108.0 62.50 H-40 WELDED HANGER.26 ti Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 10 3/4 9.950 30.9 1,473.1 1,473.1 45.50 L-80 BTC " r Casing Description 0... -Strip ID...Top(RKB Set Depth f Set Depth ) String String...String Top Thrd aa�.. gString 9 ) P (••• p (TVD)... Wt... PRODUCTION 7 5/8 6.875 28.7 2,592.3 2,592.3 29.70 L-80 BTCM ....... .. - ........7.625x4.5 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...(Set Depth(TVD)...(String Wt...(String.. String Top Thrd TUBING 41/2 3.958 26.5 1,985.9 1,985.9 12.60 L-80 IBT-M e .Corn.letion Details TUBI -U', • Top Depth 2ssau, (TVD) Top Incl Noml... Top(f1KB) (RKB) Ii (tam Description Comment _ID(in) 26.5 26.5 0.00 HANGER FMC TUBING HANGER 4.500 I CONDUCTOR, t CAMCO DB NIPPLE w/3.875"PROFILE 3.910 32-108 ''s t 0.18 NIPPLE CAMCO DB NIPPLE w13.843"PROFILE 3.812 / 0.20 NIPPLE CAMCO DB NIPPLE w/3.750"PROFILE 3.750 r.22 LOCATOR LOCATOR 3.880 1,968.9 1,968.9 0.22 SEAL ASSY SEAL ASSEMBLY 3.890 SURFACE, a A 31-1,473 (I'. 4 NIPPLE,1,927 CHEMICAL, 1,929 AL. rNIPPLE,1,942 GI_ GAS LIFT, f I 1,944 NIPPLE,1,957 I■ 1 LOCATOR, It 1.963 I mg SEAL ASSY, 1,969 lit t S ME i Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Sine TRO Run Stn Top(ftKB) (ftKB) 1'1 Make Model lin) Sery Type Type lin) (pal) Run Date Com... 1 1,928.7 1,928.6 0.15 CAMCO KBMG-LTS 1 CHEM DMY BK 0.000 0.0 4/25/2011 2 1,943.8 1,943.6 0.18 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/30/2011 !Iii! '11 L PRODUCTION 7.625'..5, 29-2.4592 ID,2,597 • Size Csg/Tbg Lb/ft Grade Thread MD Hole 13-% 10-% 45.5 L-80 BTC 1,473 9-7/8" 7-5/8" 29.7 L-80 BTCM 1,974 9-7/8" 4-% 12.6 L-80 IBTM1,996-2,592 7-5/8" Csg 4-1A Tbg 12.6 L-80 IBTM 1,986 DTS Cable Electronic Cable PIT Gauge @ 2,034' Sensor @ 2039.48' ' '/. Coiled Tbg g• '/. Coiled Tbg D Sand 2,061 2,110 1 DB nipple(3.875"min ID) 2 Chemical Injection Mandrel 3 DB nipple(3.813"min ID) ;iib 4 Gas Lift Mandrel 5 DB nipple(3.75"min ID) �� 6 PIT Gauge . 7 DB nipple(3.687"min ID) 8 PIT Gaugeiiiigeitt 9 Polish Bore(3.625"min ID) 10 PIT Gauge 11 Packoff Bushing(Cmt g) , 1,473' llgil'j',''',1:11 7 � DB Nipple @ 2,224' j P(T Gauge @ 2,226' Sensor @ 2,231.72' NI 1 DB Nipple @ 1,927' Upper C Sand 2 CIM @ 1,929' 2,240 2,274 9 IM 3 •_ 1 DB Nipple @ 1,942' Polishnsor Bore 2,278' 4 GLM @ 1,944' @ 1 ' P!T Gauge @91.67 2,285' 5 DB Nipple @ 1,957i, Se@ 2,2 Packoff Bushing @ 2,371' moo EOT @ 1,986' 2,403'Float Collar P/T Gauge @ 2,034' Sensor @ 2,039.48' Imo., 2,597'TD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday,February 24,2012 TO: Jim Regg 21 It P.I.Supervisor SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IGNIK SIKUMI 1 FROM: Chuck Scheve PRUDHOE BAY UNIT IGNIK SIKUMI#1 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 112" NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT IGNIK API Well Number: 50-029-23443-00-00 Inspector Name: Chuck Scheve SIKUMI#1 Insp Num: mitCS120222081753 Permit Number: 211-027-0 Inspection Date: 2/19/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IGNIK SIKUMI I Type Inj. G TVD 1969 IA -J 0 1910 • 1828 1770 1716 PTD 2110270 ' TypeTest SPT Test psi 1500 OA Interva INITAL IP/F P Tubing 1268 1269 1265 1264 1264 Notes: Pretest pressures observed and found stable verifying tubing integrity to 1260 psi. IA test pressure would not stabilize due to thermal effect of IA cooling. Friday,February 24,2012 Page 1 of 1 • NETL: Methane Hydrates - 2012 T--iik Sikumi gas hydrate field trial Page 1 of 2 t) 2// -oa 7 Site Map GO> = N= the ?GY lab N=TL Where energy challenges converge and energy solutions emerge N r / , ABOUT NETL KEY ISSUES&MANDATES ,,ie ;gaLionai ,Yrethan� Hydrates ,ux1_; Program ONSITE RESEARCH 2012 Ignik Sikumi gas hydrate ^''t•-'=' TECHNOLOGIE"; Status Report-Jan 30,2012 Oil&Natural Gas =. Site preparation for 2012 well testing at Ignik Sikumi began in i E&P Technologies December with the re-building of an icepad around the wellhead, Gas Hydrates which was completed December 20.Over the subsequent weeks, T&D and Refining `., the facilities and equipment for conducting the work arrived at the 0 Contacts '�•' site,including crew accommodations,power supply,and well- _. Coal&Power Systems service equipment.Installation and interconnection of testing Industrial Capture&Stora•';C equipment to the wellhead is underway. Carbon Sequestration Project Background At the heart of the exchange experiment is a state-of-the-art Gas Participants ENERGY ANALYSIS Mixing Skid(GMS),housed in an Arctic-grade shipping container. Ignik Sikumi Welt Review Specialized pumps, CO2-Ch"Exchange Overview NETL-RUA - ''' "` • - valves,and meters - .,j, are required t TECHNOLOGY TRANSFER I '!� . Ill because standard oilfield equipment cannot move,mix,or measure 47 Viols t=.r iv" injection gases at the pressures,temperatures,and rates required SOLICITATIONS&BUSINESS `"* by the test design.The GMS was designed by ConocoPhillips,with input from key contractors,and manufactured in Texas.The skid EDUCATION # I was tested and commissioned near Houston,before being loaded r onto trucks and driven to Prudhoe Bay on the Alaska North Slope. AWARDS&RECOGNITION -- - Other trucks carried carbon dioxide and nitrogen storage tanks for , NEWSROOM . .,, r the test,as well as wellbore heating,gas measurement,and other peripheral equipment.The attached photo,made during CONTACT NETL commissioning,shows the GMS interior. Status Report-Jan 1,2012 ' 7 .,� The project has completed the majority of preparations for production related field trials.Specialized storage, i t metering and measurement equipment,necessary to carry out planned production testing operations,is on site ".t and beingprepared for use.The project officiallyentered its finalproduction testingphase on December 16, +trrr >.� P i 2011.Plans for the production testing phase of the project are to return to and re-enter the Ignik Sikumi#1 well, at its location adjacent to the L-Pad road within the PBU,from an ice pad,starting in late January 2012.The production testing program will consist of site and well preparations followed by well perforation and the injection of a combination of N2 and CO2 into the methane hydrate reservoir.This injection phase will be followed by an extended period of depressurization and flowback of gas to the surface.Once the exchange test objectives are met,the intent is to use the wellbore for continued production testing,including depressurization,through the remaining time within the test window. Collection of a full suite of data from wellbore instrumentation and the analysis of well flowback will be carried out throughout production testing operations.Following production testing,the current plan is to plug and abandon the Ignik Sikumi#1 well and restore the site. Field operations will be followed by review of the data collected and the initiation of extensive analysis of that data to determine the implications of test results. Status Report-December 2011 I The project has completed the majority of preparations for production related field trials.Final testing of specialized storage,metering and measurement equipment,necessary to carry out planned production testing operations,along with training of personnel on equipment usage,is ongoing with completion planned by the end ,.c 4iiti of December 2011.The project officially entered its final production testing phase on December 16,2011.Plans 3' for the production testing phase of the project are to return to and re-enter the Ignik Sikumi#1 well,at its location 1 http://www.netl.doe.gov/technologies/oil-gas/FutureSupply/MethaneHydrates/rd-program/A... 2/3/2012 • NETL: Methane Hydrates - 2012 ' ~kik Sikumi gas hydrate field trial Page 2 of 2 adjacent to the L-Pad road within the PBU,from an ice pad,starting in January 2012.The production testing program will consist of site and well preparations followed by well perforation,and an initial nitrogen injection. Subsequently,injection of a combination of N2 and CO2 into the methane hydrate reservoir will be carried out over about a two week period.This injection phase will be followed by an extended period of stepwise depressurization and flowback(above hydrate stability pressures)to assess the CH4/CO2 exchange.Once the exchange test objectives are met,the intent is to use the wellbore for continued production testing,including depressurization,through the remaining time within the test window. Collection of a full suite of data from wellbore instrumentation and the analysis of well flowback will be carried out I throughout production testing operations.Following production testing,the current plan is to plug and abandon - I the Ignik Sikumi#1 well and restore the site.Field operations will be followed by review of the data collected and the initiation of extensive analysis of that data to determine the implications of test results. USA.GOV j U.S.DEPARTMENT OF ENERGY DOE OFFICE OF FOSSIL ENERGY DOE OFFICE OF ENERGY EFFICIENCY&RENEWABLE ENERGY I OFFICE OF ELECTRICITY DELIVERY&ENERGY RELIABILITY Disclaimer I Privacy Policy Web Policies FOIA;Privacy Act I Employees Only http://www.netl.doe.gov/technologies/oil-gas/FutureSupply/MethaneHydrates/rd-program/A... 2/3/2012 r.k.:;jI [1,1 \\ „ „ m SEAN PARNELL, GOVERNOR �aT ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL ENHANCED RECOVERY INJECTION ORDER 5.001 Randall Kanady Drilling and Wells ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 RE: Docket # ERIO-12-001, Prudhoe Bay Unit, Ignik Sikumi No. 1 Well (PTD 211-027), "Upper C Sands” of Saganivirktok Formation Dear Mr. Kanady: By email sent January 24, 2012, ConocoPhillips Alaska, Inc. (CPAI) requests the Alaska Oil and Gas Conservation Commission (AOGCC) administratively amend the fluids authorized for injection under Enhanced Recovery Injection Order 5 (ERIO 5)to include two gas tracers to help evaluate the effectiveness of the pilot project authorized under ERIO 5. AOGCC hereby GRANTS CPAI's request. ERIO 5 was issued on January 18, 2012, and authorizes CPAI to conduct a pilot injection project to evaluate the potential of injecting a carbon dioxide/nitrogen (CO2/N2) gas mixture to recover methane gas from a hydrate accumulation. While the use of tracers was discussed during preliminary meetings about the scope of this pilot project they were inadvertently left out of the formal application for the project and subsequently not included as an authorized fluid under Rule 4 of ERIO 5. The specific tracers that CPAI requests authorization to inject as a part of this pilot project are sulfur hexafluoride (SF6) and 1,2-dichlorotetrafluoroethane (R-114). According to CPAI's request these substances were selected "...because they will be trapped in secondary hydrate formation, so their concentrations will help us manage our mass-balance calculations." CPAI proposes to inject 10 pounds of SF6 during the first half of the injection project and 10 pounds of R-114 during the second half of the injection project. The total mass of the CO2/N2 mixture to be injected is 20 tons, so the 20 total pounds of tracers injected would fall in the hundreds of parts per million range and thus would not be expected to pose any compatibility concerns. Adding these tracers to the CO2/N2 injection stream should allow the effectiveness of the project to be more easily evaluated. ERIO 5.001 February 1,2012 Page 2 of 2 Per Rule 11 of ERIO 5, the AOGCC hereby amends Rule 4 of ERIO 5 to read as follows: RULE 4: Authorized Injection Fluid for Enhanced Recovery The pilot project involves injecting no more than 20 tons of mixed CO2/N2, and no more than 10 pounds each of the tracer elements sulfur hexafluoride (SF6) and 1,2- dichlorotetrafluoroethane (R-114), into the hydrate saturated Sagavanirktok "Upper C Sands" to validate laboratory experimental results supporting CO2/CH4(Methane) exchange. The injected CO2/N2 mixture in a gas state will exchange with the methane and remain sequestered in the pre-existing hydrate lattice. All other terms "I c• ditions of ERIO 5 remain unchanged and in full force and effect. OIL ANp DONE at • n orae laska and dated February 1, 2012.- 9k, r 1 4d•u Jo• VP'.N•rman Cath '. Foerster o �'4 . � o Comm' loner Commissioner VATWN'�°� RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. sTrairiE icam ... A SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMDIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Jack Kralick Staff Wells Engineer 1 — D d ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Prudhoe Bay Field, Exploratory Pool, IGNIK SIKUMI 1 Sundry Number: 311-364 Dear Mr. Kralick: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Ur Daniel T. Seamount, Jr. Chair DATED this Z 7day of November, 2011. Encl. It.14r11 Ii,, RECEIVE w, y TATE OF ALASKA F CA OIL AR 4S CONSERVATION CON' >10N NOV 18 2011 ,�-• APF-LICATION FOR SUNDRY APPk VALS ht-,441/ 20 AAC 25.280 aha Oil & G8s4sas. 1.Type of Request: Abandon Rugfor Redrill Perforate New Pool �On yp q r r �' Repair well r, Change Appro����ogram Suspend r Rug Perforations r )124._ Perforate r Rill Tubing r 1�ltC�rti2 efehsion r Operational Shutdown r Re-enter Susp.Well f'f Stimulate EAlter casing p•2Y Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 211-027 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23443-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No gr. IGNIK SIKUMI 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28239 PRUDHOE BAY FIELD , 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): 2597 2597 2597' 2597' Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 108' 108' Surface 1442' 10.75" 1473' 1473' Production 1931' 7.625"x 1964' 1964' 628' 4.5" 2592' 2592' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 4.5" L-80 1986 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NO PACKER NIPPLE-CAMCO DB NIPPLE MD=1927 TVD=1927 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work: 9 u Exploratory Development '";, /,,tt•L Service r Detailed Operations Program r BOP Sketch r 9�"" 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: r,.Je" 11/30/2011 Oil r Gas WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r— WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Kralick @ 265-6870 Printed Name Jack Kralick ,� �, I Title: Staff Wells Engineer Signature o .��j /�, i 1;h4. l Phone:265-6870 Date illtici /LI, Commission Use Only //�/ Sundry Number:3 I (-✓�q Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /d — 4-/Q APPROVED BY r 1 Approved by•A / COMMISSIONER E COMMISSION Date: 11 /41 ` For v' - Miki( 0 R'I I N AtIP, , , Submit in Duplicate".... I c/.2j/e'e 3 Ignik Sikumi #1 Cable Detection & Perforating Procedure E-Line 1.1 Notification & Permit Contact BP Drill Site Operator, notify and inform of operations, sign BP Permit to Work if requested. 1.2 RU Rig up Schlumberger E-Line unit and pressure test as per standard practice 1.3 MU WPP, Run Tie-in Log, & Map Cables Reference Log: 24-Apr-2011 PipTagand JewelryLog, Schlumberger CCL/GR 9 p 9 A. Make up WPP (Wireline Perforating Platform) • Cable Head • Anti-Rotation Centralizer • Motor(rotates tool string at-1 rpm) • CCL&Telemetry • EMF CM (Electro Magnetic Field—Completion Mapper) • 3.60" OD Bow Spring Stand-offs/Centralizers, 1 at each end of the EMF CM B. RIH and Tie-in to PIP Tag at 2,168' RKB C. Log tie-in pass from 2,320' to 1,800' • Turn on and record EMF CM @ 50Hz to detect blast protectors (6' long each) • Make sure the motor is off and the tool is not rotating • Note the CCL may be suppressed by the logging tool centralization D. RIH to 2,320' E. POH, stopping, then rotating the EMF to map the orientation of each Blast Protector(expect 10 total blast protectors) • Full joint 2,240'—2,271' (4 or 5 Blast Protectors) • Mid-joint 2,168'—2,199' (1 Blast Protector) • Mid-joint 2,137'—2,168' (1 Blast Protector) • Mid joint 2,106'—2,137' (1 Blast Protector) • Mid-joint 2,075' —2,106' (1 Blast Protector) • Mid-joint 2,006'—2,034' (1 Blast Protector?) F. POH, stopping, then rotating the EMF to map the orientation of the flat pack • 1,800' • 1,400' • 1,000' • 600' • 200' G. POH 1.4 MU, RIH & Tie-in Perf Guns Perforating charges: 2-7/8" OD PowerJet Omega, 2906, 0&180 phase, 4 spf A. Make up 30 foot gun to the bottom of the WPP B. RIH and tie-in to the PIP Tag at 2,168' C. Position perforating charges to perfora 62,243'—2,27 D. Using the WPP, orient the perforation charges wili the WPP motor-90 degrees away from the blast protectors/cables 1.5 Bleed WH Pressure Bleed N2 pressure from the 4-1/2"tubing until the middle down-hole gauge is —800 psi 1.6 Perforate A. Fire the perforating charges B. POH to 1,800' to move the guns out of the perforating interval to avoid potential hydrate sticking C. Monitor downhole gauge pressures for build-up, and monitor the pressure gradients between the gauges to detect increasing liquid level (4 hours maximum) D. POH monitoring the middle down-hole gauge to ensure it does not drop below 800 psi. Add N2 pressure to the 4-1/2" tubing as necessary to replace the E-line cable voidage. 1.7 RD `., ConocohillipsDrilling Hydrate Well &wells 4-1/2" Completion String ConocoPhillips .i.i..•'. .!..•'. i -. i:.. • 16" 164.82# iiiiii '`' iiiiliili SCH100 . I. @+/- 110'MD 4'/" 12.6#L-80 IBT-mod tubing Two red lines are 3/4"injection lines for circulating hot fluid in 10-3/4" L-80 BTC to annulus. Black background indicates that they are flatpacked 1,475' MD with the 3/4"Chemical injection line that goes to the KBMG-LTS Mandrel t! ,Alik_i i 4'h" Camco'DB'Nipple w/3.843"No-Go Profile,IBT mod, at—1,908'MD(3.813"min ID) 4-1/2"KBMG-LTS Chemical Injection Mandrel with 3/4"line, IBT mod,located 1,968'MD 7-5/8" 29.7# 4-1/2"KBMG GLM with SOV installed,IBT mod,located at L-80 BTCM 1. )71,_ � 1,988'MD To 2,008'MD ' '=== iia • �I �iii_ 4-1/2" x 7 5/8"X-Over(2,008'MD) ' - :: Yellow line is DTS -iE: Black line is electronic if 4'h" Pressure and Temperature Gauge,IBT mod,at—2,025'MD =- 4'h" Cam co'DB'Nipple w/3.785"No-Go Profile,IBT mod, . •T ; _::_:: at-2,184'MD(3.75" min ID) 4'h" Pressure and Temperature Gauge,IBT mod,at 2,190'MD <: +? 4'h" Seal bore receptacle with 3.625"polished bore 2,235'MD 4'h" 12.6#L-80 IBT-mod liner -== _:___= 4'/z" Pressure and Temperature Gauge,IBT mod,at 2,257'MD :I 1_:__ a 4 h Stab in float collar 2,366 MD(PBTD) .:1 2,820'MD i -- 9 7/8"hole 'BU IG SIKUMI 1 ConocoPhilli s , ,.`r Well Attributes ';Max Angie&MD TD Alaska Inc '^'^`�,g$$ Wellbore APVUWI Field Name Well Status Incl(°) MD(ftKB)) Act Bim(ftKB) t.W 6I 5UIIW F 500292344300 PRUDHOE BAY UNIT EXPLOR 0.53 2,457.02 _ 2,597.0 ° !CommentI H2S(ppn) Date Annotation End Date KB-G d(ft) Rig Release Dale 8.4K.IK4M1,1.8/220115o s6PmW SSSV�NIPPLE Last O: 34.60 4/28/2011 WSII Cpnlg,VERT/ SO i( /Annotation Depth(CAB) End Data Annotation Last Mod...End Date Last Tag:SLM 2.350.0 4/30/2011 /Rev Reason:NEW WELL,GLV C/O,TAG ninam 5/2/2011 ICasing Strings Casing Description ';String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top The CONDUCTOR 16 15.062 32.0 108.0 108.0 62.50 H-40 WELDED HANGER,26----- ;�' Casing Description $ ng String 0... String ID...Top(ftKB) SN Depth(L..Set Depth(TVD)...String Wb..String...String Top The ' SURFACE 10 3/4 9.950 30.9 1,473.1 1,473.1 45.50 L-80 BTC ._._ Casing D ription String 0... String ID...Top(ftKB) S Sal Depth(i...Set Depth(TVD)...String Wt...String...String Top The PRODUCTION 75/8 6.875 28.7 2,592.3 2,592.3 29.70 L-80 BTCM -- - -'- 7.625x4 5 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD) String Wt...String...String Top The TUBING 4112 L 3.958-_-.26.5_-_ 1,985.9 I 1,985 9 1 12.60 L-80 IBT-M Completion Details - _ Top Depth 29 ; (TVD) Top/net Top(ftKB) (ftKB) el Rem Description Comment ID(In) 26.5 26.5 0.00 HANGER FMC TUBING HANGER 4.500 It CONDUCTOR,___... 1,927 1 1,927.1 0.15 NIPPLE CAMCO DB NIPPLE w/3.875"PROFILE 3.910 324108 _.. ,942.0 0.18 NIPPT --- ----_. ------ -- 1,942.1 11,942. LE CAMCO DB NIPPLE W/3.843"PROFILE 3.812 1,956.7 1,956.6 0.20 NIPPLE CAMCO DB NIPPLE w/3.750"PROFILE 3.750 1,967.9 1,967.8 0.22 LOCATOR LOCATOR 3.880 1,968.9 1,968.9 022 SEAL ASSY SEAL ASSEMBLY -�- _--- 3.890 I 1 1 SURFACE. _--.. ! ''' -'::' ! 31-1,473 • NIPPLE,1,921 CHEMICAL,1,928 NIPPLE,1,942 -- a OAS LIFT,_.. ' 1040 9M NIPPLE,1,957 c �' LOCATOR, 4'. 1,968 SEAL ASSY, `I.I 1,969 1 ` `I_ t Q.„ L /Mandrel Details Top De Pth Top P0,1 (TVD) Incl OD Valve Latch Size 7R0 Run Stn Top(ftKB)' (CAB) lel Make Model tin) Sery Type Type lie) i (Pc,) _Run Date Com.... 1 1,928.7 1,928.6 0 15 i CAMCO KBMG-LTS 1 CHEM PMY BK 0.000 0.0 4/252011 2 1,943.6 1,943.6 0.18ICAMCO KBMG 1 GAS LIFT 1DMY Mill 0.000 0.0 4/30/2011 PRODUCTION LI 7.82504.5. 29-2.592_\,, .' TD,2,597 : ,; . . — — '. ....._--..... _`r ... _ 'a.._`� 1 - 111_I • ommom.o. 4 --_-- -�....___ .. •., .... ._ ----- --- .... • s` � s. . _--_- -I ---__ ...---- -- ..---- ....- ! .- --- ..----- --- - ..... - 4ir -- :' It 11 Jarmo1-7-- -- : - ,.._ qui , . .._ . _ ., _ _......r. _ j og. . ...______....... _ __ _...... m.o. m.,.._---.._ 3 J a d d n ''' Z�� _-_- • �s•- A , ___..4 ___ _ A y is =_ pups-a -- _..- ---- - - - - -- _.... -Lam} .s? 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Wit. ..... - - - - Jaddf - N. ..,� I nen ,....i .--- 00001 SIINn 4 bl NI N 44+4 dWO—HS ----- 80-70A--- 8v\;,- \:',..!•71,7! um-1V1.01—S`dI 1VOH 00004 00 I.00 n/A 0 A/A I 1,i 1 CA AC 10007 wnHo al Y4 NI 6 WlUNN S3IH08V—HS 11Hd H1dH0 Z 0 H 8 O11V S9 l A/A 0 0 VA I nb i/sn 094 !"I7 'A,,m 001 IdNA 0 /di100A-1dX 10-HS HA8 0010 0Z1V 80 . n 0 0 A A I 0004 w41-1O d WId HS MASS 021V 0007 NNHn 7 09J-v nom wwNO 0 61V T #-INnNIS )IIMII• JI V\ IZak SCIIIINd0D0U0D Notice of Public Hearing STATE OF ALASKA - Alaska Oil and Gas Conservation Commission Re: The application of ConocoPhillips Alaska, Inc (CPAI) for an Enhanced Recovery Injection Order for the Ignik Sikumi #1 gas hydrates well, Prudhoe Bay Unit, North Slope Borough, Alaska. CPAI in a letter dated October 14, 2011 has requested an Enhanced Recovery Injection Order (ERIO) to inject CO2 and N2 into the Sagavanirktok "C sandstone" gas hydrates interval to test the resource potential of gas hydrates in the Prudhoe Bay Unit, North Slope, Alaska. The Surface and Bottomhole locations of the well are as follows: Ignik Sikumi# 1 Surface Location: 1858 FSL, 2475 FWL Section 34, T12N, R1lE, U.M. Bottomhole Location: 1848 FSL,2478 FWL Section 34, T12N,R11E,U.M. The Commission has tentatively scheduled a public hearing on this application for November 29, 2011 at 9:00 a.m. at the Alaska Oil and Gas Conservation Commission, at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. To request that the tentatively scheduled hearing be held, a written request must be filed with the Commission no later than 4:30 p.m. on November 9,2011. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the hearing, call 793-1221 after November 15,2011. In addition, written comments regarding this application may be submitted to the Alaska Oil and Gas Conservation Commission, at 333 West 7"' Avenue, Suite 100, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m. on November 28, 2011, except that, if a hearing is held, comments must be received no later than the conclusion of the November 29, 2011 hearing. If, because of a disability, special accommodations may be needed to comment or attend the hearing, contact the Commission's Special Assistant, Jody Colombie, at 793-1221, no later than November 15,2011. I `�� �otatt � ti Daniel T. Seamount,Jr. Chair . limpp,, i,\= ;. ...., , -t- il_Ic v. The Source for Critical Information and Insight® , le 4,.......\_,...........„_ „...,_.,„. .._......„ tw� 9r o. aDrilling WireTM . • (- „ # . Alaska .... 44\ June 23, 201 16 Volume 57, Number 25 es �� x c"60 cii,. ,g. v.st, .1.,, 1 ConocoPhi I l i ps, DOE plan 2011 -2012 test program for North Slopehydrate prospect gas Y __ D \\ - 0D-'1 CoNOCOPHILLIPS Alaska Inc During the coming months, field In the winter season, and the Department of trial participants will review data ConocoPhillips and the Office of Energy's Office of Fossil to determine the optimal param- Fossil Energy's National Energy Energy are planning to test innova- eters for field testing. (Continued on page 4) tive technologies for producing methane gas from gas hydrate deposits at an exploratory well on the North Slope during the winter - 2011-2012 drilling season. National rig count posts slight increase The 1 Prudhoe Bay Unit Ignik Sikumi (Inupiaq for"fire in the AKER HUGHES Ines June 17 (174) and Ohio (11),while Kansas ice"), 34-12n-11e,Umiat Meridian, survey found 1,860 rotary (30),Utah (28)and Wyoming(46) was drilled in April to 2597 ft in the rigs at work in the US.and its each edged up by one. Tertiary Sagavanirktok and encoun- waters,a gain of five from the Losses came in five states this tered 160 ft of methane hydrate- previous week.There were 1,539 rigs week,including New Mexico (78) bearing sandstone reservoirs in four employed nationwide one year ago. which saw a seven-rig decline. separate zones. Small gains in nine states this Pennsylvania's total slid by five to An array of down-hole week were led by Texas (838), 109,a two-unit drop was noted in pressure-temperature gauges were where the tally improved by five. Mississippi(10),and the totals for installed in the well, and a con- Despite muddy road conditions, Colorado (68) and Oklahoma (165) tinuous fiber-optic temperature North Dakota's working rig count both were off by one. sensor outside the well casing posted a four-rig increase, to 163, States with no week-to-week which will monitor the well as it and the total for West Virginia (21) changes are Alaska (6),Arkansas returns to natural conditions was up by three.Two-rig gains were (35), California (43), Florida (1), following the drilling program. reported in Alabama (7),Louisiana (Continued on page 2) D N O Alaska/Section I/June 23, 2011 ConocoPhillips, DOE - continued from page 1 Technology Laboratory will test a occurring compound of methane Hydrate Assessment Unit (AU), 33 technology that involves injecting and water, thought to occur in large percent (28.0 Tcf) is within the carbon dioxide into the sandstone quantities on the North Slope. In Tuluvak-Schrader Bluff-Prince reservoirs containing methane the past, there has been no success Creek Formations Gas Hydrate hydrates. NETL said laboratory extracting them from the subsur- AU, and 43 percent (36.9 Tcf) is in studies indicate that the CO2 face commercially. ConocoPhillips the Nanushuk Formation Gas molecules will replace the methane said gas hydrates in the Prudhoe Hydrate AU. The USGS noted that molecules within the solid hydrate Bay region are found in sandstone since relatively few wells have lattice,resulting in the simultaneous reservoirs less than 3000 ft in penetrated the expected gas sequestration of CO2 in a solid depth. Methane hydrates also occur hydrate accumulations in the three hydrate structure and production of in the subsurface of most continen- AUs, there is "significant geologic methane gas. tal waters with depths of approxi- uncertainty" in the estimates. Following those tests, the mately 1,500 ft or greater. The Northern Alaska Gas remaining time available before the In a 2008 assessment, the Hydrate TPS encompassed by the spring thaw (as much as 40 days) United States Geological Survey USGS report extends from the may be used to test reservoir estimated total undiscovered National Petroleum Reserve- response to pressure reduction in natural gas resources that are Alaska on the west through the the wellbore. This alternative technically recoverable in the Arctic National Wildlife Refuge on methane-production method, Northern Alaska Gas Hydrate the east and from the Brooks P Y termed "depressurization,"recently Total Petroleum System (TPS) Range northward to the state- proved effective during short-term range between 25.2 and 157.8 federal offshore boundary (located testing conducted by the govern- trillion cu ft (95 percent and five three miles north of the coastline). ments of Canada and Japan at a site percent probabilities of greater This area consists mostly of in northwestern Canada, according than these amounts, respectively), federal, state and Native lands and to the DOE. with a mean estimate of 85.4 Tcf. covers nearly 56,000 square miles. Of the mean estimate, about 24 The report is available online at I Background percent (20.6 Tcf) is in the http://pubs.usgs.gov/fs/2008/ Gas hydrates are a naturally Sagavanirktok Formation Gas 3073/pdf/FS08-3073_508.pdf. Page 4 Drilling WireTM Tech Centers Page 1 of 2 TECH CENTERS TCGMNf)IOGY CONNCCT10N3 La. TECH CENTER EVENTS I RSS I HOME I CONTACT PowEre7 by AMG OIL&NATURAL GAS SUPPLY METHANE 11 White Paper-Issues,Current Work and Future ^� HYDRATES Direction Email Tech Alerts "R •Research on methane hydrates • Coming Soon UNCONVENTIONAL RESOURCES has focused on discovering the -- - potential of a vast energy Upcoming Workshops&Webinars resource unknown until the Related Indust' bents 1980s.Methane hydrates No Tech Center events scheduled at this time represent an untapped natural gas resource,which has been ENHANCED OIL RECOVERY(EOR) estimated to hold more than Tech Center Archives twice the global reserves of conventional oil,gas and coal Technology Tidbit of the Month deposits combined. Methane hydrate is found in crystal form SMALL PRODUCERS in Arctic permafrost areas and North Sloe Well Pilots Gas Hydrate Technologies deep continental margin deposits.The U.S.Department A pilot well on Alaska North Slope is testing innovative technologies for methane of Energy began a research hydrate production.The test,funded through ConocoPhillips and the DOE's National and development plan in 2000, Energy Technology Laboratory,is being conducted at Ignik Sikumi gas hydrate field. and has joined in offshore and DEEPWATER/ULTRA-DEEPWATER arctic research with Canada During the test,CO2 will be injected into sandstone reservoirs that contain methane • and Japan.Methane hydrate hydrates.The reservoirs are within the thick permafrost zone where methane compounds are crystalline hydrates exist in a solid hydrate lattice.The hydrate lattice can sequester CO2 and i ir solids containing methane produce methane gas.Gas hydrates in permafrost formations and in deep • molecules trapped in water continental slope deposits are an enormous resource potential for natural gas.Gas molecules.Methane hydrates ENVIRONMENTAL/ are stable in offshore hydrates role in past and future climate change is also an area of environmental WATER ISSUES sediments greater than 300 interest. metanders, surface permafrost sediments several hundreds of Research Field Applications/Case Studies meters thick.Early research concentrated on locating • NETL Technologies potential methane hydrate METHANE HYDRATES resources. The current • RPSEA research target is development • Academic • Pre-commercial/Emerging of drilling and engineering • National Labs • Commercial technologies to efficiently • Industry extract methane hydrate and produce this valuable resource. Did we miss your technology or product? References/Seminal Literature Let us know. • Links to literature/reports Technical Information Databases Let PUC know if there is • Presentations by others additional information that • Annotated bibliography/brief • DOE-Knowledge Management needs to be part of this Tech abstracts Database Center • Related News • SPE OnePetro • AAPG Discovery DOE's Alaska Effort • Producers Test Ways to Draw Hydrates from Alaska's North Slope • The National Methane Hydrates R&D Program,MITAS 2009 Beaufort Sea Expedition • The National Methane Hydrates R&D Program,The Alaska North Slope Stratigraphic Test Well USGS Alaskan Petroleum Studies—Assessment of Gas Hydrate Resources on the North Slope,Alaska,2008—Fact Sheet 2008-30731 Press Release (11/12/08) Podcast(Episode 74)—Slide Presentation(Flash document 10.6 MB) Gas Hydrates Website http://www.pttc.org/tech_centers/methane_hydrates.htm 7/8/2011 NETL: News Release - Newly talled Alaska North Slope Well Will T ` Innovative H... Page 1 of 1 \ A - � Site Map GO> NETL the ENERGY lab Where energy challenges converge and energy solutions emerge OUT NETL KEY ISSUES&11tfAN TES r'uuiicd1.1011s NnWS ReIe tse ONSITE RESEARCH Release Date:May 18,2011 TECHNOLOGIES Newly Installed Alaska North Slope Well Will Test Innovative Hydrate ENERGY ANALYSIS Production Technologies Project Goals Include Injecting and Storing CO2 While Producing Methane Gas NETL-RUA from Hydrate • TECHNOLOGY TRANSFER Washington,D.C.-A fully instrumented well that will test innovative technologies for producing methane gas from hydrate deposits has been safely installed on the North Slope of Alaska.As a result,the"Ignik SOLICITATIONS&BUSINESS Sikumi"(Inupiaq for"fire in the ice")gas hydrate field trial well will be available for field experiments as early as winter 2011-12. EDUCATION AWARDS& OGNITION The well,the result of a partnership between ConocoPhillips and the Office of Fossil Energy's(FE)National Energy Technology Laboratory,will test a technology that involves injecting carbon dioxide(CO2)into NEWSROOM sandstone reservoirs containing methane hydrate.Laboratory studies indicate that the CO2 molecules will replace the methane molecules within the solid hydrate lattice,resulting in the simultaneous sequestration of CONTACT NETL CO2 in a solid hydrate structure and production of methane gas. Methane hydrate consists of molecules of natural gas trapped in an open rigid framework of water molecules.It e s p occurs in sediments within and below thick permafrost in Arctic regions,and in the subsurface of most r continental waters with a depth of—1,500 feet or greater.Many experts believe it represents a potentially vast source of global energy and FE scientists have studied methane hydrate resource potential and production technologies for more than two decades.Researchers are addressing such important issues as seafloor stability,drilling safety,and a range of environmental issues,including gas hydrate's role in changing climates. The recently completed operations include the acquisition of a research-level suite of measurements through the sub-permafrost hydrate-bearing sediments.The data confirm the occurrence of 160 feet of gas-hydrate- bearing sand reservoirs in four separate zones,as predicted,and provide insight into their physical and mechanical properties.An array of down-hole pressure-temperature gauges were installed in the well,as well as a continuous fiber-optic temperature sensor outside the well casing,which will monitor the well as it returns to natural conditions following the drilling program. In coming months,field trial participants will review the data to determine the optimal parameters for future field testing.Current plans are to re-enter the well in a future winter drilling season,and conduct a 1-2 month program of CO2 injection and well production to assess the efficiency of the exchange process.Following those tests,the remaining time available before the spring thaw(as much as 40 days)may be used to test reservoir response to pressure reduction in the wellbore.This alternative methane-production method,"depressurization," recently proved effective during short-term testing conducted by the governments of Japan and Canada at a site in northwestern Canada. Contact: I. FE Office of Communications,202-586-5603 al Printer Friendly USA.GOV I U.S.DEPARTMENT OF ENERGY I DOE OFFICE OF FOSSIL ENERGY DOE OFFICE OF ENERGY EFFICIENCY&RENEWABLE ENERGY I OFFICE OF ELECTRICITY DELIVERY&ENERGY RELIABILITY Disclaimer I Privacy Policy I Web Policies I FOIA/Privacy Act I Employees Only http://www.netl.doe.gov/publications/press/2011/110518-Newly%20Installed%20Alaska%2... 7/8/2011 fud! : ix http://fuelfix.com/blog/2011/10/24/conocophillips-launches-test-to-unlock-methane-gas-potential/ ConocoPhillips launches test to unlock methane gas potential Posted on October 24, 2011 at 1:15 pm by Jennifer A.Dlouhy in Alaska Natural Gas (Photo: Flickr/Kyle May) ConocoPhillips is teaming up with the Energy Department to test a promising method for harvesting energy- rich methane gas deposits trapped in ice-like crystals on Alaska's north slope. Beginning in January, the company is set to begin testing its carbon dioxide-based extraction technique at a trial well installed earlier this year in the Prudhoe Bay region. ConocoPhillips is also working with the Japan Oil, Gas and Metals National Corp. on the project. The initial field tests of the extraction method expand on so-far successful laboratory-based evaluations and will span roughly 100 days,through March 2012,the Energy Department confirmed today.Afterward, researchers will spend one more month evaluating an alternative methane-production method called depressurization that was successfully demonstrated by Japan and Canada in testing in 2008. Methane hydrates are ice-like solids with gas molecules trapped inside. Typically found in high-pressure, low-temperature environments, including the depths below Alaska's thick permafrost,they hold tremendous promise as an energy source—if only someone can figure out how to unlock the gas affordably. The U.S. Geological Survey has estimated that methane hydrates may contain more energy than all of the world's fossil fuels combined. The extraction method ConocoPhillips is testing in Alaska—called molecular replacement—involves injecting carbon dioxide into the reservoir and swapping the CO2 for methane molecules in the solid-water hydrate lattice that stores them. If successful,the technique would not only release the trapped methane gas and keep the lattice-like structure intact, but it would provide a new storage option for carbon dioxide linked to global warming. Energy Department researchers have been searching for ways to unlock the trapped gas in methane hydrates for more than two decades, and it has partnered with industry on other projects. o- WP <• , ConocoPhillips �o -41 'C'7;TTESO1r U.S.Department of Energy Methane Hydrates Production Data eet . Field Trial Methane Hydrates Well l L) 2 it A'7 :lic�- ,5, ,,,z , , u s ConocoPhillips has been selected by the U.S. d.y �,,- '.� k ` ' ^,, 3•'lcc,-.�w` Department of Energy(DOE)to perform the tssy + �k a , > first field trial of a promising technology that - a � ` s.t."1" �s `-,Z;', ' „ would allow the production of methane from ,,rte«' ` ° ,, ' gas hydrates on Alaska's North Slope. ..44.,..,„,,,,..,..„..,„, a r `l What is the purpose,,:w f . _ `,:,� ' - -;•�_ �•'�' - -. P of the trial. �'-?"' r+' This well will be drilled to gain scientific _ a..' i' Carbon Di•oxide -',. .,231..,y---.'?. Y 1.7 , t', knowledge and test a patented production .‘:1'."..-!.;7:7.",.''' • / � �'' �+I7.4"* ""''''''',---.:-..---,-- 4 � . - technology which was developed by Methane ,�="'. "' _ ConocoPhillips and the University of Bergen Permafrost (Norway). ConocoPhillips and the University Permafrost .-,1.1- 1;r7....4-;..:.:.!`.7-4:::'� 'L f have been developing this technology .q, �,-;:. ss protected since 2003. This trial represents the first 1, with chilled experiment outside a laboratory of this ." 4t ,w •. # }, drilling muds production technology in which a carbon • .,,,,,,,-...7.44-,:z.:,_ .,z' dioxide molecule is exchanged for the Hydrates' methane molecule locked up in the hydrate's Layer Y ` ---•_."" � structure. The methane gas is produced, and Carbon dioxide the carbon dioxide is sequestered inside the :y ' j - exchanges with hydrate structure. z''',..1..t .1';- methane „ , • . Who is conducting this trial? This trial will be performed by ConocoPhillips in collaboration with the U.S. Department ►' of Energy through the Methane Hydrate Target Program at the National Energy Technology hydrate-saturated Laboratory. The DOE is recognized as an international leader in methane hydrates sand research. What will the trial accomplish? The trial will answer two basic questions: BEA UFOR Z' SEA First, does the laboratory-proven exchange mechanism work in the field,with minimal 0 10 20 sand and water production?Secondly, what -, t . i ;Mises kind of rates and exchange efficiency is Greater ' \ Greater demonstrated?Although ConocoPhillips has _. • Kuparr k Prudhoe Area repeatedly demonstrated this technology Are L' '\.„____."-------- in a laboratory setting, this will be the first �- ,. real-world test. The results of this trial will I allow ConocoPhillips to establish a forward- • y phased development plan for the technology, including additional field trials. C litr. D NPR-A Why do this trial? cn - ANWR Methane hydrates hold a significant potential F to supply the world with clean fossil fuel. Potential Gas Hydrate Accumulations j Alaska This trial is an important step in developing I Source:USGS . a promising production technology to i, access this potential and ultimately to R j produce methane from gas hydrates while x i sequestering carbon dioxide. It CSH 08 5569738 ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzen ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3590 RE: lgnik Sikumi 1 Permit: 211-027-0 DATE: 05/19/2011 Transmitted: Prudhoe Bay Unit, Alaska Ignik Sikumi 1 (500292344300) CD/digital log data and 1 color log print each Schlumberger Caliper, CMR, HNGS, PEX, XPT, MDT, OBMI, SSCAN, RT-Scan; graphics and data; 4/17/2011 CANRIG Final well report; Mud logging data; Ignik Sikumi#1; Daily reports, DML Data,final well report, LAS files, Log PDF files, Remarks, TIFF color log image files; CD and hardcopy mud log prints CD/ digital log data Halliburton LWD Final processed Data; April 21, 2011; digital graphic logs and digital log data; w/.lis scan hardcopy Circumferential Acoustic Scanning Tool; Cement Bond Log and Advanced Cement Evaluation; 5/1/2011; DLIS data and digital logs Final directional survey data (Halliburton/Sperry); State of Alaska Completion report-form 10-407 w/formation tops noted. *Ignik Sikumi 1 was drilled as an exploration well-All data is confidential until State ofAlaska(ArY317(1 4,.c ',tP,1 IF, c,date Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Ignik Sikumi 1 - e-transmittal well folder David Schod•rbek, COP Gas y rates Director Receipt: ;ill A1l�► Date: oZ_Q) J 05-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.Lemke(aiConocophillios.com i - OX? STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other Abandoned ❑ Suspended 1 b.Well Class: • Hydrates Well 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory 0 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: MIT Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 28,2011 • 211-027 ' 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 April 5,2011 50-029-23443-0000 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1858'FSL,2475'FWL,Sec.34,T12N,R11 E, UM April 16,2011 Ignik Sikumi#1 • Top of Productive Horizon: 8. KB(ft above MSL): 30.7'RKB 15.Field/Pool(s): 1850'FSL,2480'FWL,Sec.34,T12N,R11 E, UM GL(ft above MSL): 52.9'AMSL Prudhoe Bay Field Total Depth: 9.Plug Back Depth(MD+TVD): 1848'FSL,2478'FWL,Sec.34,T12N,R11 E, UM 2597'MD/2597'TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-584119 y- 5977590 Zone-4 • 2597'MD/2597'ND . ADL 28239 ' TPI: x-584123 y- 5977582 Zone-4 11,SSSV Depth(MD/ND): 17.Land Use Permit Total Depth: x-584121 y- 5977579 Zone-4 nipple c 1927'MD/1927'ND na 18.Directional Survey: Yes E No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1760'MD/1760'ND ' 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res/Den Neu/QBAT/MRIL/MDT/Dipole Sonic/CMR/QBMI/XPT not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# B-35 31' 108' 31' 108' 24" 185 sx ArcticSet 1 10.75" 45.5# L-80 31' 1473' 31' 1473' 13.5" 299 bbls ArcticLite Crete,128 bbls DeepCrete c 7.625"x 29.7# L-80 29' 1964' 29' 1964' 9.875" 153 bbls LiteCrete I 4.5" 12.6# L-80 1964' 2592' 1964' 2592' 9.875" included above*cement to surface 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 4.5" 1986' none none 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ICCMPLEl IO ti DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED el ••;_ii j /- V/.. 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) production flow test to be performed in 2012 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ , Sidewall Cores Acquired? Yes ❑ No ❑ • If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVE NONE MAY 17 2011 RBDMS MAY 17 2011 Aloaka Oil & ,as Cogs-gammih ie n Form 10-407 Revised 12/2009 CONTINUED ON REVERSE original only 1 .f i nerilge 5 N�. i le // 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, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1760' 1760' needed,and submit detailed test information per 20 AAC 25.071. Sagavanirktok Upper C 2214' 2214' Sagavanirktok Upper C 2240' 2240' Sagavanirktok Lower C 2278' 2278' N/A Formation at total depth: Upper/Lower C 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz©263-4297 Printed Name G. L.Alvord Title: Alaska DrillingManager 9 Si nature I Phone 265-6120 Date sl!( e a t 9 �� t 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 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 O irp f I w ConocoPhillh . s(Alaska) Inc. Non-Pad Various Non-Pad, Various Ignik Sikumi #1 500292344300 r Sperry Drilling Definitive Survey Report 21 April, 2011 .04 I 0 PA LAt t k 6 7 HAL. IBURTON Sperry Drilling r ;s rip ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well Ignik Sikumi Project: Non-Pad Various TVD Reference: Ignik#1 @ 83.60ft(Nor3(52.9+30.70)) Site: Non-Pad,Various MD Reference: Ignik#1 @ 83.60ft(Nor3(52.9+30.70)) Well: Ignik Sikumi North Reference: True Wellbore: Ignik Sikumi#1 Survey Calculation Method: Minimum Curvature Design Ignik Sikumi#1 Database: CPAI EDM Production Project Non-Pad Various Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Ignik Sikumi,Hydrate Well-Directional Plan from WSak 24 gravel Pad Well Position +N/-S 0.00 ft Northing: 5,977,589.82 ft Latitude: 70°20'55.377 N +EI-W 0.00 ft Easting: 584,118.668 Longitude: 149°19'1.565 W Position Uncertainty 0.00 ft Wellhead Elevation: 0.00 ft Ground Level: 52.90 ft Wellbore Ignik Sikumi#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) i BGGM2010 4/17/2010 21.88 80.93 57,644 L Design Ignik Sikumi#1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 30.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 30.70 0.00 0.00 142.04 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 74.92 1,421.28 Ignik Sikumi(R200)(Ignik Sikumi#1) MWD MWD-Standard 4/12/2011 12:C 1,514.34 1,514.34 Ignik Sikumi(R300)(Ignik Sikumi#1) MWD MWD-Standard 4/14/2011 12:C 1,607.64 2,550.39 Ignik Sikumi(R400)(Ignik Sikumi#1) MWD MWD-Standard 4/18/2011 12:C Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 30.70 0.00 0.00 30.70 -52.90 0.00 0.00 5,977,589.82 584,118.66 0.00 0.00 UNDEFINED 74.92 0.06 85.56 74.92 -8.68 0.00 0.02 5,977,589.82 584,118.68 0.14 0.01 MWD(1) 169.57 0.04 85.56 169.57 85.97 0.01 0.11 5,977,589.82 584,118.76 0.02 0.06 MWD(1) 258.80 0.13 163.22 258.80 175.20 -0.09 0.17 5,977,589.73 584,118.82 0.14 0.17 MWD(1) 353.36 0.02 117.52 353.36 269.76 -0.20 0.21 5,977,589.62 584,118.87 0.12 0.29 MWD(1) 447.81 0.19 167.52 447.81 364.21 -0.36 0.26 5,977,589.46 584,118.92 0.19 0.44 MWD(1) 541.39 0.30 162.95 541.39 457.79 -0.74 0.37 5,977,589.08 584,119.03 0.12 0.81 MWD(1) 634.95 0.19 152.23 634.95 551.35 -1.11 0.51 5,977,588.71 584,119.18 0.13 1.19 MWD(1) 729.27 0.28 151.60 729.27 645.67 -1.46 0.69 5,977,588.37 584,119.36 0.10 1.57 MWD(1) 821.73 0.36 148.69 821.73 738.13 -1.90 0.95 5,977,587.92 584,119.63 0.09 2.08 MWD(1) 915.30 0.36 130.53 915.29 831.69 -2.34 1.33 5,977,587.49 584,120.01 0.12 2.66 MWD(1) 1,009.37 0.45 138.12 1,009.36 925.76 -2.81 1.80 5,977,587.02 584,120.49 0.11 3.32 MWD(1) 4/21/2011 11:04:26AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well Ignik Sikumi Project: Non-Pad Various TVD Reference: Ignik#1 @ 83.60ft(Nor3(52.9+30.70)) Site: Non-Pad,Various MD Reference: Ignik#1 @ 83.60ft(Nor3(52.9+30.70)) Well: Ignik Sikumi North Reference: True Wellbore: Ignik Sikumi#1 Survey Calculation Method: Minimum Curvature Design: Ignik Sikumi#1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,103.12 0.48 129.04 1,103.11 1,019.51 -3.33 2.35 5,977,586.51 584,121.04 0.08 4.07 MWD(1) 1,196.94 0.41 131.21 1,196.93 1,113.33 -3.80 2.91 5,977,586.05 584,121.61 0.08 4.78 MWD(1) 1,291.21 0.35 134.04 1,291.19 1,207.59 -4.22 3.37 5,977,585.63 584,122.07 0.07 5.40 MWD(1) 1,385.74 0.33 158.54 1,385.72 1,302.12 -4.68 3.67 5,977,585.18 584,122.38 0.15 5.95 MWD(1) 1,421.28 0.25 134.71 1,421.26 1,337.66 -4.83 3.77 5,977,585.03 584,122.48 0.40 6.12 MWD(1) 1,514.34 0.31 145.84 1,514.32 1,430.72 -5.18 4.05 5,977,584.68 584,122.77 0.09 6.58 MWD(2) 1,607.64 0.32 144.97 1,607.62 1,524.02 -5.60 4.34 5,977,584.26 584,123.06 0.01 7.09 MWD(3) 1,700.81 0.26 160.64 1,700.79 1,617.19 -6.01 4.56 5,977,583.85 584,123.29 0.11 7.55 MWD(3) 1,794.72 0.26 148.18 1,794.70 1,711.10 -6.40 4.75 5,977,583.47 584,123.47 0.06 7.96 MWD(3) 1,890.54 0.09 171.16 1,890.52 1,806.92 -6.65 4.87 5,977,583.22 584,123.60 0.19 8.24 MWD(3) 1,984.53 0.25 182.92 1,984.51 1,900.91 -6.93 4.87 5,977,582 94 584,123.61 0.17 8.46 MWD(3) 2,078.80 0.32 181.75 2,078.77 1,995.17 -7.40 4.85 5,977,582.47 584,123.59 0.07 8.82 MWD(3) 2,169.71 0.35 194.83 2,169.68 2,086.08 -7.92 4.78 5,977,581.95 584,123.52 0.09 9.18 MWD(3) 2,266.43 0.44 210.71 2,266.40 2,182.80 -8.53 4.51 5,977,581.34 584,123.26 0.15 9.50 MWD(3) 2,363.24 0.45 227.55 2,363.21 2,279.61 -9.10 4.04 5,977,580.76 584,122.80 0.14 9.66 MWD(3) 2,457.01 0.53 228.08 2,456.97 2,373.37 -9.64 3.45 5,977,580.21 584,122.21 0.09 9.72 MWD(3) 2,550.39 0.52 218.59 2,550.35 2,466.75 -10.26 2.86 5,977,579.59 584,121.63 0.09 9.85 MWD(3) 2,597.00 0.52 218.59 2,596.96 . 2,513.36 -10.59 2.60 5,977,579.25 584,121.37 0.00 9.95 PROJECTED to TD 4/21/2011 11:04:26AM Page 3 COMPASS 2003.16 Build 69 PBU IGNIK SIKUMI 1 Iv- CanocoPhillps . . .� Wgll Attributes Max Angle&MQ :TD Aki .11.4., ,.� - "/ Wellbore APUUWI 1F Id N Well Status mel(°) MD(flKB) Act Bim(flKB) �rti'k1C. 500292344300 _ PRUDHOE BAY UNIT EXPLOR 10.53 1 2,457.02 2,597.0 _: CommMt I1-125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:NIPPLE i Last WO: 34.60 4/28/2011 _ Wen.gon(9.KEg3/A4..0s(9(S1KVMli. ..4^./19]],t 1044.,PAI--„�'•' -- - — ,Sgmjgyc A _i Annotation Depth iftKB) End Date Annotation Last Mod...End Date Last lag:SLM 2350.0 4/30/2011 Rev Reason-NEW WELL,GLV C/O,TAG ninam 5/2/2011 Casing Strings Casing Description .String O._ String ID...Top(flKB) Set Depth(f...Set Depth(TVD)...'String Wt...String...String Top Thm CONDUCTOR 16 15.062 32.0 108.0 108.0 62.50 H-40 WELDED HANGER,26- ---- easing Description String 0... String ID...Top(MB) SN Depth(f...Set Depth(TVD)_.Sting WI_.String...String Top That s: SURFACE 10 3/4 9.950 30.9 1,473.1 1,473.1 45.50 L-80 BTC -... -- _ Casing Description String 0... string ID...Top(ftICB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 75/8 6.875 28.7 2,592.3 2,592.3 29.70 L-80 BTCM - --- 7.625x4.5 Tubing Strings Tubing Description [String 0... [String ID...ITop(ORB) Set Depth(6...Set Depth(ND)...String Wt...[String...String Top Thrd TUBING [ 41/2L_ 3958L---265 I1,985.9 I 1,985.91260_-_� L-80 IBT-M .° ,,- .w Completion Details '12,211P.. _ Top Depth 29 Wv (TVD) Top Incl Nomi... • Top(flKB) (ftlCB9 (°) Item Description Comment ID(in) 26.5 26.5 0.00 HANGER FMC TUBING HANGER 4.500 _I 1,927.1 1,927.1 0.15 NIPPLE CAMCO DB NIPPLE wl 3.875"PROFILE 3.910 CONDUCTOR, __.. _ 32-108 ��1,942.1 1,942.0 0.18 NIPPLE CAMCO DB NIPPLE w/3.843"PROFILE 3.812 , I 1,956.7 1,956.6 0.20 NIPPLE CAMCO DB NIPPLE w/3.750"PROFILE 3.750 1,967.9 1,967.8 0.22 LOCATOR LOCATOR 3.880 1,968.9 1,968.9 022 SEAL ASSY SEAL ASSEMBLY 3.890 i' b SURFACE, 4 l 31-1,473 1 111 NIPPLE,1,927-- _—__ 1111 CHEMICAL,. Ir 1,929 if NIPPLE,1,942 A. GAS LIFT,__ li 1.944 .',. NIPPLE.1.957 Ili LOCATOR, to 1,988 SEAL ASSY, 1,969 1 N.SII f !z..:.._ Mandrel Details : _.. `r-r ; inn Top Depth Top Port (ND) Incl OD Valve Lath Size TRO Run Stn Top MO) (flKB) C) Make Model (in) Sery Type TYP. (in) (Ped Run Date Co..... 1 1,928.7 1,928.6 0.15 CAMCO KBMG-LTS 1 CHEM DMY BK 0.000 0.0 4/25/2011 lei 2 1,943.6 1,943.6 0.18 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/30/2011 PRODUCTION 7.629x4.5, 29-2.592 TD,2597 Time Log & Summary ConocoPhillips Wel?view Web Reporting Report Well Name: IGNIK SIKUMI 1 Rig Name: NORDIC 3 Job Type: DRILLING ORIGINAL Rig Accept: 4/5/2011 4:30:00 PM Rig Release: 4/28/2011 9:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/04/2011 24 hr Summary Move rig from 2V pad to CPF-2. Crew changeout. Check air in tires,grease planetaries. Move rig from CPF-2 to Oliktok Y. Standby w/crews for CPAI crew changeout. Move Rig from Oliktok Y to KCC. Set rig down,grease planetaries, check tires. Move rig from KCC towards 1D pad. 09:30 12:00 2.50 MIRU MOVE MOB P Move rig from 2V pad to CPF-2. 12:00 14:00 2.00 MIRU MOVE MOB P Crew changeout. Check air in tires, grease planetaries. 14:00 17:30 3.50 MIRU MOVE MOB P Move rig from CPF-2 to Oliktok Y. 17:30 19:30 2.00 MIRU MOVE MOB T Standby w/crews for CPAI crew changeout. 19:30 22:00 2.50 MIRU MOVE MOB P Move Rig from Oliktok Y to KCC. 22:00 22:30 0.50 MIRU MOVE MOB P Set rig down,grease planetaries, check tires. 22:30 00:00 1.50 MIRU MOVE MOB P Move rig from KCC towards 1D pad. 04/05/2011 Moved Rig to 1J access road. Greased planetaries and check tires, service rig. Moved rig from 1J access road to Milne Pt.turnoff. Check equipment, meet w/security. Move rig f/Milne Pt.turnoff to Ignik Sikumi#1. Lay out herculite&T-mats,stack double rig mats. Continue to double stack rig mats and build ramp. PJSM, move rig over well. Spot&level rig. Rig Accepted at 16:30 hrs on 4/5/11. NU diverter, spot equipment, berm equipment. 00:00 01:30 1.50 MIRU MOVE MOB P Moved Rig to 1J access road. 01:30 02:00 0.50 MIRU MOVE MOB P Greased planetaries and check tires, service rig. 02:00 04:00 2.00 MIRU MOVE MOB P Moved rig from 1J access road to Milne Pt.turnoff. 04:00 04:30 0.50 MIRU MOVE MOB P Check equipment, meet w/security. 04:30 10:30 6.00 MIRU MOVE MOB P Move rig f/Milne Pt.turnoff to Ignik Sikumi#1. 10:30 12:00 1.50 MIRU MOVE PSIT P Lay out herculite&T-mats,stack double rig mats. 12:00 16:00 4.00 MIRU MOVE PSIT P Continue to double stack rig mats and build ramp. 16:00 16:30 0.50 MIRU MOVE PSIT P PJSM,move rig over well. Spot& level rig. Rig Accepted at 16:30 hrs on 4/5/11. 16:30 00:00 7.50 MIRU WHDBO NUND P NU diverter spot equipment, berm, equipment 04/06/2011 Finish NU diverter. Changeout saver sub&grabber box dies. Spot Drill Cool units w/crane&berm up around Drill Cool units. Cont.to spot MI filter unit, MI vac unit,and other 3rd party equipment around rig. Spot upright tanks and berm up. Load MWD tools, load casing spider slips w/crane. Offload 5"HWDP&5" DP. Load 5"drillpipe into pipe shed, rack&tally drillpipe. Load tools,troubleshoot stabbing board, now functioning properly. 00:00 06:00 6.00 MIRU WHDBO NUND P Finish NU diverter. Page 1 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 MIRU DRILL PSIT P Changeout saver sub&grabber box dies. Spot Drill Cool units w/crane &berm up around Drill Cool units. 12:00 18:00 6.00 MIRU DRILL PSIT P Cont.to spot 3rd party equipment around rig, load MWD tools, load casing spider slips w/crane. Offload 5"HWDP&5"DP. 18:00 00:00 6.00 MIRU DRILL RURD P Load 5"drillpipe into pipe shed, rack &tally drillpipe. Load tools, troubleshoot stabbing board, now functioning properly. 04/07/2011 Function test stabbing board. Install wood steps over wires running to MWD shack. Install 4"valve on conductor. PJSM. Pick up drillpipe, calibrate MWD to block height. PU 5"drillpipe,torque up and rack back in derrick. Load 290 bbls spud mud into upright tank. PJSM. Slip&cut drilling line. Test Diverter. RIH tag cement at 96.44'. Est. 12'cement to conductor shoe. PJSM. Rack&tally 5"HWDP. PJSM. Rack&tally 10-3/4"casing. Pressure test mud pumpst to 2000 psi. 00:00 00:30 0.50 MIRU DRILL RURD P Function test stabbing board. Install wood steps over wires running to MWD shack. Install 4"valve on conductor. 00:30 01:30 1.00 MIRU DRILL PULD P PJSM. Pick up drillpipe,calibrate MWD to block height. 01:30 09:30 8.00 MIRU DRILL PULD P PU 5"drillpipe,torque up and rack back in derrick. Load 290 bbls spud mud into upright tank. 09:30 11:00 1.50 MIRU RIGMNT SVRG P PJSM. Slip&cut drilling line. 11:00 12:00 1.00 MIRU WHDBO PRTS P Test Diverter and accumulator system. RIH tag cement at 96.44'. Est. 12'cement to conductor shoe. 12:00 16:00 4.00 MIRU DRILL PULD P PJSM. Rack&tally 5"HWDP. 16:00 00:00 8.00 MIRU DRILL PULD P PJSM. Rack&tally 10-3/4"casing. Pressure test mud pumps to 2000 psi. 04/08/2011 Load casing, rack&tally. MU&break out new HWDP,drift to 2.867. Service top drive,washpipe. Install Totco monitors in mud shack and MWD shack. Load casing equipment, bring cement head to rig floor. Load hanger into pipe shed. Continue to load spud mud into pits. Load 20'casing pup and Landing Joint. PJSM. PU&MU BHA#1,fill hole w/water. Dry run 10-3/4"fluted hanger and land. Top of Landing Ring at 30.88' RKB,top of load shoulder at 31.25'RKB. Work on Totco system,fix stroke counter and flapper sensor. Other Totco functions failed. Stroke counter and gain/loss functions won't zero. Troubleshooting Totco. 00:00 03:00 3.00 MIRU DRILL PULD P Load casing, rack&tally. MU& break out new HWDP,drift to 2.867. 03:00 06:00 3.00 MIRU RIGMNT SVRG P Service top drive,washpipe. 06:00 12:00 6.00 MIRU DRILL RURD P Install Totco monitors in mud shack and MWD shack. Load casing equipment,bring cement head to rig floor. Load hanger into pipe shed. 12:00 13:30 1.50 MIRU DRILL RURD P Continue to load spud mud into pits. Load 20'casing pup and Landing Joint. 13:30 13:45 0.25 MIRU DRILL SFTY P PJSM. 13:45 15:30 1.75 MIRU DRILL RURD P PU&MU BHA#1,fill hole w/water. Page 2 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 MIRU DRILL RURD P Dry run 10-3/4"fluted hanger and land. Top of Landing Ring at 30.88' RKB,top of load shoulder at 31.25' RKB. 16:00 18:30 2.50 MIRU RIGMNT RGRP T Troubleshoot&work on rig Totco system,fix stroke counter and flapper sensor. 18:30 00:00 5.50 MIRU RIGMNT RGRP T Other Totco functions failed after prior problems fixed. Stroke counter and gain/loss functions won't zero. Troubleshooting Totco. 04/09/2011 Continue troubleshooting Totco system. Swapped computer module for older version, reloaded Totco and re-input well info. Totco fixed. Function tested Totco sensors, loaded 10 bbls into trip tank,tested PVT, block height,traveling speed. Verified can zero stroke counter and gain/loss functions. PJSM.Spudded well at 02:45 am. Cleanout conductor shoe track f/96'to 108'. Drilling ahead f/108'to 239'. Back ream out of hole f/239'to 165' Blow down top drive. POOH f/239'to surface. PU&MU BHA#2 and TIH to 132'. Upload MWD. PU single&pulse test. Bring pumps online and survey at 132'. Service Rig. PJSM on radioactive sources. Load MWD radioactive source and RIH to 170'. Survey at 170'. RBIH to 239', Circulate well clean. Auger plugged. Unplug same. Directional drill f/239'to 379'. Auger loaded up w/gravel, belt broken. Replace Belt/unplug auger. Directional drill f/379'to 411'. Auger loaded up again. Noticed grinding in the gear box, begin changing out gear box on auger. Continue to reciprocate and circulate pipe at 1 BPM. 00:00 02:30 2.50 0 0 MIRU RIGMNT RGRP T Continue troubleshooting Totco system. Swapped computer module for older version, reloaded Totco and re-input well info. Totco fixed. Function tested Totco sensors, loaded 10 bbls into trip tank,tested PVT, block height,traveling speed. Verified can zero stroke counter and gain/loss functions. 02:30 02:45 0.25 0 0 SURFA( DRILL SFTY P PJSM. 02:45 03:00 0.25 0 108 SURFA( DRILL DRLG P Spudded well at 02:45 on 4/9/11. , Cleanout conductor shoe track f/96' to 108'. 03:00 05:15 2.25 108 239 SURFA( DRILL DRLG P Drilling ahead f/108'to 239'. 75 RPM, 5K WOB, 500 GPM,500 psi. 48K P/U,50K S/O, ROT 50K. ADT: 1.71 hrs 05:15 05:45 0.50 239 239 SURFA( DRILL REAM P Back ream out of hole f/239'to 165' pumping 500 gpm @ 425 psi. RBIH. Back ream out of hole f/239'to 175' pumping 500 gpm @ 425 psi. Returns cleaning up good. Blow down top drive. 05:45 06:30 0.75 239 0 SURFA( DRILL TRIP P POOH f/239'to surface. Rack back two stands HWDP. 06:30 09:45 3.25 0 132 SURFAt DRILL PULD P PU&MU BHA#2 and TIH to 132'. Upload MWD. 09:45 10:00 0.25 132 132 SURFA( DRILL DHEQ P PU single&pulse test. 10:00 10:30 0.50 132 132 SURFAt DRILL SRVY P Bring pumps online and survey at 132', 500 GPM, 870 psi. 10:30 11:00 0.50 132 132 SURFA( RIGMN1SVRG P Service Rig. 11:00 11:15 0.25 132 132 SURFAC DRILL SFTY P PJSM on radioactive sources. Page 3 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:15 1.00 132 170 SURFA( DRILL PULD P Load MWD radioactive source and RIH to 170'. 12:15 12:30 0.25 170 239 SURFA( DRILL DHEQ P Survey at 170', 1194 psi,600 gpm. RBIH to 239', Circulate well clean. Auger plugged up. 12:30 14:00 1.50 239 239 SURFA( RIGMNT RGRP T Unplug auger. 14:00 17:00 3.00 239 379 SURFA( DRILL DDRL P Directional drill f/239'to 379', 1240 psi,600 gpm. 74K P/U, 70K S/O, 72 rpm's. 17:00 18:30 1.50 379 379 SURFA( RIGMNT RGRP T Auger loaded up w/gravel, belt broken. Replace Belt/unplug auger. 18:30 20:30 2.00 379 411 SURFA( DRILL DDRL P Directional drill f/379'to 411', 1240 psi,600 gpm. 74K P/U,70K S/O, 75 rpm's. 20:30 00:00 3.50 411 411 SURFA( RIGMNT RGRP T Auger loaded up again. Noticed grinding in the gear box, begin changing out gear box on auger. Continue to reciprocate and circulate pipe at 1 BPM. 04/10/2011 Cont.to work on auger system,finished installing new gear box. Driller looked down hole and noticed no flow. Increased pump strokes to 2 BPM and pump pressure spiked to 2500 psi. Shut down pumps and bled off. Top drive frozen. Set pipe in slips, installed TIW valve and 2"circulation hose, confirmed circulation. Lowered top drive to rig floor. Disconnected kelly hose, began flushing ice chunks from kelly hose w/steam. Clear ice from top drive w/steam. Continue steaming ice from kelly hose. Attached 2nd steam hose to pump manifold and applied steam to standpipe. Used infrared temperature sensor to check standpipe temperature. Standpipe temperature 20'off rig floor @ 120°F,40'off rig floor 100°F,then immediately above belly board @ 40'dropped to 20°F. Hoisted rig hand on man-rider to put hands on standpipe and verify frozen. Confirmed. Finished thawing out Kelly hose&standpipe. Circulate down HWDP @ 3 BPM/150 psi. Pressure test kelly hose to 2500 psi. Directional drill f/411'to 1087', backreaming full stand prior to every connection. ADT: 9.26 hrs @ midnight. 00:00 02:00 2.00 411 411 SURFA( RIGMN1 RGRP T Cont.to work on auger system, finished installing new gear box. 02:00 02:30 0.50 411 411 SURFA( RIGMNT RGRP T Getting ready to start drilling. Driller looked down hole and noticed no flow. Increased pump strokes to 28 spm(2 BPM)and pump pressure spiked to 2500 psi. Shut down pumps and bled off. Top drive frozen. Set pipe in slips, installed TIW valve and 2"circulation hose, confirmed circulation. Lowered top drive to rig floor. 02:30 03:30 1.00 411 411 SURFA( RIGMN1 RGRP T Disconnected kelly hose from top drive, inserted steam hose into kelly hose,began flushing ice chunks from kelly hose. Circulated downhole at 2 BPM for 20 min.through TIW valve. 03:30 04:00 0.50 411 411 SURFA( RIGMN1 RGRP T Used steam hose to clear ice from top drive. Confirmed top drive clear w/steam flowing through. Circulated downhole at 2 BPM for 20 min. through TIW valve. Page 4 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 411 411 SURFA( RIGMNT RGRP T Re-inserted steam hose into kelly hose and continued melting ice from kelly hose. Attached 2nd steam hose to pump manifold and applied steam to standpipe. 04:15 04:30 0.25 411 411 SURFA( RIGMNT RGRP T Used infrared temperature sensor to check standpipe temperature. Standpipe temperature 20'off rig floor @ 120°F,40'off rig floor 100°F,then immediately above belly board @ 40' dropped to 20°F. 04:30 05:00 0.50 411 411 SURFA( RIGMN1 RGRP T Hoisted rig hand on man-rider to put hands on standpipe and verify frozen. Confirmed. 05:00 10:30 5.50 411 411 SURFA( RIGMNT RGRP T Continued to steam standpipe and kelly hose. Circulated downhole at 2 BPM for 20 min.through TIW valve every 20 min. 10:30 11:00 0.50 411 411 SURFA( DRILL PRTS P Circulate down HWDP @ 3 BPM/ 150 psi. Pressure test kelly hose to 2500 psi. 11:00 00:00 13.00 411 1,087 SURFA( DRILL DDRL P Directional drill f/411'to 1087'at 1650 psi and 600 gpm, 10K-12K WOB. 95K P/U, 90K S/0,95 RPM's. Backreaming full stand prior to every connection. ADT: 9.26 hrs @ midnight. 04/11/2011 Cont.directional drilling f/1087'to TD at 1482'. Circulate bottoms up. Blow down top drive, monitor well. Static. POOH f/1482'to 300'on elevators,slight hangup at 1020 ft,worked through. RBIH to TD at 1482'. Circulate at 15.5 BPM, raise pump rate to 16.1 BPM, rotate&reciprocate. Continue to circulate at 16 BPM. Pump a 10.9 ppg sweep. Chase sweep with 9.4 ppg mud. Rotate&reciprocate at 45 RPM's. Blow down top drive,monitor well. Static. POOH f/1482'to 975'. RBIH f/975'to 1477'. Circulate new 9.1 ppg mud. Blow down top drive. POOH f/1477'to 220'. PJSM on radioactive sources. Continue POOH laying down 8" MWD tools. Remove nukes,dowload MWD data. Continue to lay down BHA#2. 00:00 08:00 8.00 1,087 1,482 SURFA( DRILL DDRL P Cont.directional drill f/1087'to TD at 1482'at 2000 psi and 650 gpm, 10K-12K WOB. 100K P/U, 103K S/O, 100K ROT,Torque 1400 ft-lbs off bottom,3000 ft-lbs on bottom. Backreaming full stand prior to every connection. ADT:6.07 hrs from midnight to TD. 08:00 08:30 0.50 1,482 1,482 SURFA( DRILL CIRC P Circulate bottoms up at 16 BPM, 2050 psi. 08:30 09:00 0.50 1,482 1,482 SURFA( DRILL OWFF P Blow down top drive, monitor well. Static. 09:00 10:30 1.50 1,482 300 SURFA( DRILL TRIP P POOH f/1482'to 300'on elevators, 70K P/U,74K S/O. Slight overpull at 1020'and 1010', 5K overpull. 10:30 11:30 1.00 300 1,482 SURFA( DRILL TRIP P RBIH,set down 10-15K at 1017 ft, worked through to TD at 1482'. 100K P/U, 103K S/O. 11:30 12:00 0.50 1,482 1,482 SURFA( DRILL CIRC P Circulate 15.5 BPM @ 1980 psi. Raise pump rate to 16.1 BPM @ 2110 psi, rotate&reciprocate. Page 5 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 1,482 1,482 SURFA( DRILL CIRC P Continue to circulate at 16 BPM. Pump a 10.9 ppg sweep at 15.4 BPM and 1960 psi. Chase sweep with 9.4 ppg mud at 15.4 BPM and 1970 psi. Rotate&reciprocate at 45 RPM's. 100K P/U, 103K S/O. 14:00 14:30 0.50 1,482 1,482 SURFA( DRILL OWFF P PJSM. Blow down top drive,monitor well. Static. 14:30 15:30 1.00 1,482 975 SURFA( DRILL TRIP P PJSM. POOH f/1482'to 975', no problems. 90K P/U,94K S/O 15:30 16:30 1.00 975 1,477 SURFA( DRILL TRIP P RBIH f/975'to 1477'. 98K P/U, 95K S/O. 16:30 17:00 0.50 1,477 1,477 SURFA( DRILL CIRC P Circulate new 9.1 ppg mud at 15 BPM and 1760 psi. 17:00 18:30 1.50 1,477 220 SURFA( DRILL TRIP P Blow down top drive. POOH f/1477' to 220'. 95K P/U, 98K S/O. 18:30 00:00 5.50 220 120 SURFA( DRILL TRIP P PJSM on radioactive sources. Continue POOH laying down 8" MWD tools. Remove nukes, dowload MWD data. Continue to lay down BHA#2. 04/12/2011 Ran 10 3/4"Surface Casing Down to 1,473'MD. Circulated 100 bbls of 10.0 ppg Mud Push follow by 299 bbls of 11.2 ppg Arctic Lite Crete, pumped addition 65.2 bbls of 12.0 ppg Deep Crete,chased with 128 bbls of 8.8 ppg OBM, bump plug and pressure up to 1010 psi and held pressure for 5 mins. RDMO Cementing Crew and Equipment. 00:00 00:30 0.50 120 0 SURFA( DRILL PULL P Finish laying down BHA#2. 00:30 02:00 1.50 0 0 SURFA( DRILL PULD P Clean up rig floor. 02:00 06:15 4.25 0 0 SURFA( CASING RURD P RU GBR equipment.Change bales to long casing running bales. 06:15 06:45 0.50 0 0 SURFA( CASING SFTY P Pre job safety meeting on running casing. 06:45 13:30 6.75 0 1,473 SURFA( CASING RNCS P Run 10-3/4"45.5 ppf L-80 BTC surface casing down to 1,473'ft. Up Wt=105k/Down Wt=95k, ran Turbolizer in center of jt#1 and#2 and(2)on jt#23,and ran bow string centralizers on jts#3 thru 22 and jt #33 over the box. Make up FMC hanger and landing joint. RIH/land on starting head. 13:30 14:30 1.00 1,473 1,473 SURFA( CASING RURD P Rig Down Casing Equipment. Blow down Top Drive. Rig Up Cement Head. 14:30 16:30 2.00 1,473 1,473 SURFA( CEMEN-CIRCP Circulate while Reciprocating to set Parameters, 100k up&do weight. Stage rate up f/3 bpm w/120 psi, after 30 bbls go to 4 bpm w/240 psi, after 81 bbls pumped-5 bpm w/280 psi,then after 141 bbls pumped 320 psi at 6 bpm. 16:30 17:15 0.75 1,473 1,473 SURFA( CEMEN-SFTYP Safety meeting with Dowell, crew and 3rd party on cement job while continuing to circulate and reciprocate pipe. Pumped a total of 917 bbls. Page 6 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 17:30 0.25 1,473 1,473 SURFA( CEMEN-PRTS P Dowell pumped 5 bbl mud push(10 ppg) ,test lines to 3000 psi. 17:30 17:45 0.25 1,473 1,473 SURFA( CEMEN-CMNT P Dowell continue pumping mud push w/95 more bbls f/total of 100 bls. SLB pump at 5.0 bpm, 150 psi. Added Red Die to the last 20 bbls of mud push. Shut down and Drop Bottom Plug. 5. 17:45 19:00 1.25 1,473 1,473 SURFA( CEMEN-CMNT P Back on Line pumping Lead Slurry. Pumped 299 bbls of 11.2 nog Arctic " Lite Crete at 4.0 bpm, 200 psi,68.6 degrees slurry temp.Seen Bottom Plug land at 140 bbls away at 200 psi. Continue to Circulate and Reciprocate. 19:00 20:00 1.00 1,473 1,473 SURFA( CEMEN-CMNT P Slow Pump Rate and Started Batching Tail Slurry. Pumped 65.2 bbls of 12.0 ppg Deep Crete at 4 bpm,200 psi. Drop Top Plug follow with 5 bbls of fresh water,turn pumping operation over to rig pump and start displaceing with 8.8 ppg OBM at 4 bpm,480 psi.Seen Plug bump at 1812 stks( 128 bbls)away, 1,000 psi. Held Psi for 5 mins. Bleed off check floats,cement in place.43 bbls of good cement to surface. 20:00 22:00 2.00 1,473 1,473 SURFA( CEMEN-PULDP Rig Down Cement Head and Pumping Equipment.Clean and Clear Floor. 22:00 22:30 0.50 0 0 SURFA( DRILL PULD P PJSM. Off Load 8"Sperry Tool and Load 6 1/4"Tools. 22:30 22:45 0.25 0 0 SURFA( DRILL SFTY P PJSM. Discuss Hazard of Rigging Down Diverter. 22:45 00:00 1.25 0 0 SURFA(WHDBO NUND P Nipple Down Diverter and Flush all Lines. 04/13/2011 Rigged down and Shipped out Diverter. Installed FMC Gen 5 Wellhead System. NU 11"5M BOP's and Crossover flow nipple with Annular. Started BOP testing. 00:00 11:00 11.00 0 0 SURFA(WHDBO NUND P Continue Cleaning and Rigging Down Diverter. Break Down Stock and Placed On Shipping Skid. 11:00 14:00 3.00 0 0 SURFA(WHDBO NUND P Held PJSM with Rig Crew and FMC Rep. Nipple up the FMC Gen 5 Wellhead System. 14:00 20:30 6.50 0 0 SURFA(WHDBO NUND P Held PJSM. Nipple Up 11"5M BOP Stack+XO FLow Nipple with 2 7/8" x 5"VBR's installed in the lower and upper ram body. Installed Hydril Annular Bag. 20:30 21:30 1.00 0 0 SURFA(WHDBO MPSP P Picked up and Installed Test Plug. Filled Stack with test fluid.Test plug Failed to Hold fluid in stack. Pull, clean and inspected test plug. Re-install and filled Bop stack.Test plug seems to be holding. Page 7 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 SURFA(WHDBO BOPE P Held PJSM. Start testing BOP's, Ram's and Choke Manifold components to 250/3500 psi.Testing 9-ne Annular to 2,500 psi.Witness of test Waived by AOGCC inspector Lou Grimaldi. j 04/14/2011 Finish Initial BOP Test. RIH With Production Drilling Assembly and Drilled out the wiper plug,float collier, landing collar and shoe. Drilled addition 30'ft of new hole from bottom of shoe at 1,473'to 1,502'and preform LOT/FIT test.Continue drilling new production hole from 1,502'ft with 8.8 ppg OBM. 00:00 02:00 2.00 SURFA(WHDBO BOPE P Continue with Testing of BOP's and Choke Components. 02:00 03:00 1.00 SURFA(WHDBO RURD P Completed BOP Test. Rig Down Test Equipment. Pull Test Plug, Install Wear Bushing. (3.16'x 10 3/4") 03:00 03:30 0.50 0 0 SURFA( DRILL SFTY P PJSM. Discuss Hazard for Making. Drilling Assembly. 03:30 05:30 2.00 0 95 SURFA( DRILL PULD P MU Prodtction Drilling Assembly# 3. 9-7/8"Smith i G*iitli 1x14, 3x16 Nozzles on a 6-3/4"Sperrydrill Motor. Bit Torque 28k, BHA Torque 32k. Float sub, nm short drill collar, Integral blade stabilizer, DM collar, EWR collar, DGR collar, PWD, HCIM collar, POS Pulsar to 95'. Pick up to upload to MWD. 05:30 06:30 1.00 95 95 SURFA( DRILL PULD P Upload MWD 06:30 07:00 0.50 95 218 SURFA( DRILL PULD P Continue to MU BHA#3.(3)NM drill collars,one stand of 5"HWDP 07:00 07:15 0.25 218 218 SURFA( DRILL SFTY P Pre job safety meeting on service of rig. 07:15 08:00 0.75 218 218 SURFA( RIGMNT SVRG P Service rig. Install a new turnbuckle on top drive torque tube to anchor to the derrick. 08:00 09:00 1.00 218 218 SURFA( DRILL DHEQ P Shallow test MWD tools. Pumping 500 gpm w/1200 psi. Blow down the top drive. 09:00 10:30 1.50 218 1,365 SURFA( DRILL TRIP P Trip in the hole f/218'to 1268',tag top of cement. PU wt 85k,SO wt 90k.Tag cement w/5k. Pickup to 1363'. 10:30 11:30 1.00 1,365 1,365 SURFA( DRILL CIRC P Fill pipe, circulate 200 gpm w/350 psi. Circulated surface to surface volume. Circulated a total of 147 bbls. Rotate 45 rpm+mtr rpm 58. Reciprocate f/1365'to 1311'. 11:30 12:00 0.50 1,365 1,365 SURFA( DRILL OTHR P Blow down the top drive. 12:00 12:30 0.50 1,365 1,311 SURFA( DRILL TRIP P Break down stand#8 to break the top drive from top box. Make stand back up and rack back in the derrick. 12:30 13:30 1.00 1,311 1,311 SURFA( RIGMN1RGRP T Replace dies in the grabber of the top drive. 13:30 14:00 0.50 1,311 1,311 SURFA( DRILL RURD P Rig up to test casing. 14:00 14:30 0.50 1,311 1,311 SURFA( DRILL SFTY P Pre job safety meeting on testing casing Page 8 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:30 2.00 1,311 1,311 SURFA( DRILL PRTS P Pressure test the 10-3/4"45.5 ppf L-80 surface casing to 3200 psi f/30 minutes.Charted test. Lost 100 psi in 30 minutes-good test. Note:Tried testing 1st time and needle valve leaked. Shut down and replaced needle valve. Plan was to test to 3500 psi, but did not have enough weight of drill string,stopped at 3200 psi. 16:30 17:00 0.50 1,311 1,311 SURF/NC DRILL RURD P Rig down testing equipment. Make a top drive connection. 17:00 18:00 1.00 1,365 1,365 SURFA( CEMEN-COCF P Drill cement f/1368'to wiper plugs @ 1393',drill top and bottom wiper plugs,then the weatherford float collar @ 1393'to 1395'. Drill w/5-10k wt on bit. Rotate 40 rpm w/1k ft lbs of torque. Pumping 500 gpm w/1540 psi. Rotating weight 90k. 18:00 20:00 2.00 1,365 1,482 SURFAt CEMEN-DRLG P Continue Drilling from 1,365'to 1,482' to top of Formation 20:00 21:00 1.00 1,482 1,502 SURFAt DRILL DDRL P Start drilling formation @ 1,482'down to 1,502'at 600 GPM,202 SPM, 2,250 psi,with 8.8 ppg OBM.Rotate 50 rpm w/1k ft lbs of torque. Drill w/ _ 15-25k WOB. Drilled 20'of new hole. 21:00 21:15 0.25 1,502 1,502 SURFA( DRILL CIRC P PUH 20'and CBU with 8.8 ppg OBM at 194 SPM,2230 psi. 21:15 22:00 0.75 1,502 1,502 SURFA( DRILL RURD P PJSM. Rig Up testing equipment and hoses For FIT Testing. 22:00 22:45 0.75 1,502 1,502 SURFA( DRILL LOT P Perform LOT/FIT test on new formation Drilled.Test was performed at 1,473 ft,Starting Pressure for test was 300 psi,final pressure after 10 f/7 mins was 240 psi. New EMW is 12.7 ppg. See Integrity Test Form on the Ignik Sukumi S-drive folder. 22:45 23:30 0.75 1,502 1,502 PROD1 DRILL RURD P PJSM. Rig down Testing Equipment. 23:30 00:00 0.50 1,502 1,530 PROD1 DRILL DDRL P Circulate back down to 1,502,shut pump,wait 1 min to store survey on drilling assembly. P/U one stand and Continue drilling new hole @ 575 gpm/194 spm at 2130 psi with 8.8 ppg OBM, ECD 9.23 ppg. ROP at 60 rpm, 1k free torque,6k WOB. Fluid Temp going in 22 degs/Temp out 30 degs. 04/15/2011 Drilled a Total of 647'ft of New 9 7/8"Production Hole. Had problems keeping 8.8 ppg OBM chilled during drilling operation.TOOH to remove mud motor,found cone drag on Bit, replace with new bit with 1 ( 14)and 3(20)nozzle jets. Lay down SperryDrill motor.TIH and continue with Drilling operation until midnight with very little cooling issue.24 hour Drilled Section 1,530'ft to 2,220'ft. 00:00 00:30 0.50 1,530 1,557 PROD1 DRILL DDRL P Continue Drilling From 1,530'to 1,557'at same parameters. Page 9 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:30 1.00 1,557 1,557 PROD1 DRILL CIRC T OMB starting to Heat up,out Temp at 36 deg. PUH off bottom and lower pump rate to 135 SPM 400 gpm), and slowed rotation to 30 rpm to cool OBM. ECD 9.19 ppg. Reciprocate while circulating above shoe until mud cools down. 01:30 01:45 0.25 1,557 1,573 PROD1 DRILL DDRL P Out Temp down to 28 degs. Continue Drilling Operation again.Pump rate at 169 spm 500 gpm)/1760 psi,while rotating at 48 rpm. 5-6k WOB, ECD's 9.23ppg, 1k free torque. 01:45 04:30 2.75 1,573 1,405 PROD1 DRILL CIRC T Fluids starting to Heat up again. CBU, and PUH above the shoe. Lower Pump rate to 300 gpm, 100 SPM. ECD's 9.16 ppg.Temp at 38 degs out and 32 degs in on the fluid. Reciprocate until fluid is at the correct temp before continue with drilling operation. 04:30 06:00 1.50 1,405 185 PROD1 DRILL TRIP T Unable to maintain Cool OBM with current drilling assembly.Temp at 34 degs out/29 degs in. Decision was made to POOH and Change out Nozzles jets on Bit and lay down SperryDrill motor. BD/TD and TOOH. 06:00 06:30 0.50 185 95 PROD1 DRILL PULD T Lay down(3)6-3/4"NM flex drill collars f/185 to 95'. 06:30 07:00 0.50 95 95 PROD1 DRILL PULD T Download MWD. 07:00 09:00 2.00 95 0 PROD1 DRILL PULD T Lay down BHA#3 f/95'. Break off and grade bit, change nozzles in a new bit to(1) 13 and(3)20's. Lay down SperryDrill motor. 09:00 09:30 0.50 0 0 PROD1 RIGMN1 SVRG T Service rig, clean floor. Function blind rams. 09:30 09:45 0.25 0 0 PROD1 DRILL SFTY T Pre job safety meeting on picking up BHA#4/Bit#3. 09:45 10:45 1.00 0 123 PROD1 DRILL PULD T Make up BHA#4: Smith 9-7/8"bit, x-o,bit sub w/float, NM Flex DC, stabilizer, Sperry Sun DM collar, EWR-P4 Collar, DGR collar, PWD, HCIM collar, POS Pulsar, stablizer, NM Flex DC. Lower string back down to 70'to Upload. 10:45 11:30 0.75 123 123 PROD1 DRILL PULD T Upload Sperry Sun MWD 11:30 12:00 0.50 123 245 PROD1 DRILL PULD T Continue to make up BHA#4: MU (2)6-3/4"NM Flex drill collars,then run a stand of 5"HWDP to 245'. 12:00 12:30 0.50 245 245 PROD1 DRILL DHEQ T Shallow pulse test MWD tools. Pumping 500 gpm(169 spm)w/720 psi-48%Totco flow out. ECD's 9.11 PPg• 12:30 13:30 1.00 245 1,372 PROD1 DRILL TRIP T Trip in the hole w/BHA#4 f/245'to 1372'. Page 10 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 1,372 1,467 PROD1 DRILL CIRC T Make a top drive connection on stand#9,Wash down f/1372'to 1467'. Pumping 169 spm(500 gpm) w/1100 psi-49%flow out. SO wt 90k. Circulated a total of 116 bbls after pipe was full. 14:00 14:30 0.50 1,467 1,561 PROD1 DRILL REAM T Make a top drive connection on stand#10. Ream down f/1467'to 1561'. Pumping 500 gpm(169 spm) w/1130 psi-49%flow out. Rot wt 90k.Rotate 40 rpm w/1k ft lbs of torque. 14:30 14:45 0.25 1,561 1,573 PROD1 DRILL REAM T Make a top drive connection on stand#11, ream f/1561'to tag bottom @ 1573'. Pumping 500 gpm w/1130 psi-49%Totco flow out. Rotate 108 rpm w/1k ft lbs of torque. 14:45 20:45 6.00 1,573 2,000 PROD1 DRILL DDRL P Drill 9-7/8"hole f/1573'to 2000. Actual drilling time 4.7 hrs.WOB 10-15k, Rotate 120 rpm w/5 ftlbs of torque. Pumping 504 gpm w/1,220 psi-50%flow out. ECD's 9.53.Temp 31 deg in/38 deg out. Slowed ROP to 100 fph to maintain good samples. 20:45 00:00 3.25 2,000 2,220 PROD1 DRILL DDRL P Drill 9-7/8"hole f/2000'to 2,220'. Actual drilling time 7.5 hrs.WOB 8-10k, Rotate 119 rpm w/4 ftlbs of torque. Pumping 506 gpm w/1260 psi-48%flow out. ECD's 9.6ppg. Temp At Midnight. 35deg in/39 deg out. 04/16/2011 Drilled a Total of 377'of new 9 7/8"hole f/2220'to 2597' .Called TD of well at 2,597 ft after dealing with fluid cooling condition for most of the day while Drilling.Made Several Attempts to keep fluid cool with drill cool unit to proper temp with little success.CBU until clean,while conditioning well bore. Monitor well for flow,well static.Wiper trip to 10-3/4"shoe, no hole problems. POOH f/2,597 to BHA at 92.80'and Downloaded recorded data from LWD tools. Break down and lay down Drilling assembly. 00:00 00:15 0.25 2,220 2,220 PROD1 DRILL CIRC P Drilled down to 2,220'ft.OBM starting to Heat Up Again. Reciprocate While CBU at 500 gpm, 170 spm, 1,260 psi. Rotating Up Wt=96k/Dn Wt=102k.9.59 ECD. Temp 35 deg in/39 deg out, DH temp 43 deg. 00:15 01:15 1.00 2,220 1,434 PROD1 DRILL TRIP T Pull Up Inside CSG to Allow OBM to Cool Down. Non-Rotating Up Wt=95k. 01:15 04:00 2.75 1,434 1,434 PROD1 DRILL CIRC T Park At 1434'ft and Circulate @ 88 spm,300 psi to Cool OBM Down. 04:00 04:45 0.75 1,434 2,210 PROD1 DRILL TRIP T OBM Temp @ 23 deg in/32 degs out.TIH to continue with Drilling Operation. RIH Wt=95k 04:45 05:00 0.25 2,210 2,220 PROD1 DRILL REAM T Back Ream f/2,210'to 2,220 ft at 500 gpm, 169 spm, 1270 psi. Page 11 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 08:45 3.75 2,220 2,428 PROD1 DRILL DDRL P Start Drilling f/2220'to 2428', pumping 168 spm,501 gpm,f/o 49%, 1290 psi,WOB 5-10k,Top drive torque 4k, rotating at 120 rpm, ROP 75-100 fph, ECD 9.55 ppg. Initial Temp,22 deg in/32 deg out, BHA temp 36.4 deg. Drilled until temp out @ shakers was 40 deg, downhole temp 45.2 deg. 08:45 09:00 0.25 2,428 2,428 PROD1 DRILL CIRC T Circulate bottom's up,pumping 500 gpm w/1240 psi-46%flow out. Mud temperature getting too hot to drill, per geologist. 09:00 09:15 0.25 2,428 2,428 PROD1 DRILL OWFF T Monitor well-static. 09:15 10:30 1.25 2,428 1,438 PROD1 DRILL WPRT T Trip f/2428'to 1438'to cool mud. 10:30 12:30 2.00 1,438 1,438 PROD1 DRILL CIRC T Circulate mud, pumping down string @ 200 gpm w/260 psi. Pumped a total of 832 bbls. Drill Cool cooling mud in pits and hole. Final Drill cool temp with 12 deg ambiant temperature: 32 deg pits in/29 deg out at heat exchanger. Glycol exchange temperature 22 deg in 25 deg out. 12:30 13:45 1.25 1,438 2,410 PROD1 DRILL WPRT T Trip in the hole f/1438'to 2410'. 13:45 14:15 0.50 2,410 2,428 PROD1 DRILL CIRC T Circulate bottom's up,pumping 200 gpm w/250 psi-38%TOTCO flow out. Circulate 81 bbls then increase rate to 300 gpm w/500 psi-38% TOTCO flow out. Circulated 185 bbls. Worked string f/2410'to 2423'.Max gas during circulation was 412 units. 14:15 16:15 2.00 2,428 2,597 PROD1 DRILL DDRL P Drill f/2428'to 2597', pumping 168 spm,500 gpm,f/o 48%, 1280 psi, WOB 5-15k,Top drive torque 4k, rotating at 120 rpm, ROP 75-150 fph, ECD 9.55 ppg.Temperature again had increased to 41 degrees coming out of the hole.TD was called at this time. 16:15 17:00 0.75 2,597 2,597 PROD1 DRILL CIRC P Circulate bottom's up at 500 gpm w/ 1280 psi. Pump a second bottom's up @ 600 gpm w/1710 psi-50% TOTCO flow out.Work string f/2597' to 2504'. Rotate 120 rpm w/4k ft-lbs of torque. Hole is clean. 17:00 17:15 0.25 2,597 2,597 PROD1 DRILL OWFF P Monitor well-static. 17:15 17:30 0.25 2,597 2,597 PROD1 DRILL CIRC P Obtain slow pump rates @ 2597'. 17:30 18:45 1.25 2,597 1,438 PROD1 DRILL WPRT P Planned wiper trip to the 10-3/4" casing shoe.While tripping, DrillCool will still be trying to cool mud temp. Last readings in the pit room was: 38 deg mud in the pit, 39 deg mud coming out of the hole. Page 12 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 19:30 0.75 1,438 2,597 PROD1 DRILL TRIP P Trip in the hole f/1438'to 2597'md. RIH Wt=110k 19:30 20:15 0.75 2,597 2,597 PROD1 DRILL CIRC P Back down on Bottom at 2,597'. CBU x2 at 600 gpm, 1,720 psi until well was clean. 20:15 20:30 0.25 2,597 2,597 PROD1 DRILL OWFF P Monitor well for 15 mins-static. Blow down top drive. 20:30 21:30 1.00 2,597 500 PROD1 DRILL TRIP P PJSM. POOH f/2,597'to 500'. Up Wt-105k. 21:30 21:45 0.25 500 500 PROD1 DRILL OWFF P Monitor well for 15 mins-static. 21:45 22:00 0.25 500 92 PROD1 DRILL TRIP P Continue OOH Standing Back Drill pipe and drill collars. 22:00 22:45 0.75 93 93 PROD1 DRILL PULD P Down load Recorded LWD data from Tools.All data downloaded fine. 22:45 23:45 1.00 93 0 PROD1 DRILL PULD P PJSM. Lay Down Production Drilling Assembly. 23:45 00:00 0.25 0 0 PROD1 DRILL PULD P Clean and Clear Rig Floor. 04/17/2011 MIRU Schlumberger Wireline Equipment. MU and RIH logging BHA#1 to 2600', Made main pass log from 2600'to surface,found 10-3/4"CSG on depth at 1,473'. . MU and RIH BHA#2 to 2450'. Perform rad check in CSG, and log correction pass. Measure pressure and mobility with pressure express tool. 00:00 00:45 0.75 0 0 PROD1 EVALFN SFTY P Hold PJSM with Rig Crew and Schlumberger Personal. 00:45 03:15 2.50 0 0 PROD1 EVALFN PULD P Load Logging Tools to Rig Floor. Hang Wireline Sheave. Start Making Up Logging Assembly.Total Tool Length for first logging run 108.2 feet. Toolstring: Cable head,swivel,GR, sonic,gyro,formation imager, (2) knuckle joints,4 arm caliper, resistivity and temperature. 03:15 05:00 1.75 0 0 PROD1 EVALFN ELOG P Start Open Hole Logging Operations,, RIH w/tools to 2600'(Found 10-3/4" casing on depth @ 1473'). Log going down. 05:00 06:30 1.50 0 0 PROD1 EVALFN ELOG P Log main pass while pulling out f/ 2600'to surface. 06:30 07:00 0.50 0 0 PROD1 EVALFN SFTY P Pre job safety meeting while drilling crew change. 07:00 08:00 1.00 0 0 PROD1 EVALFN RURD P Rig down tool string#1. 08:00 08:45 0.75 0 0 PROD1 EVALFN PULD P Pick up tool string#2 and rig up f/ run#2. 08:45 09:45 1.00 0 0 PROD1 EVALFN OTHR T Tool string misconfigured. Reconfigure tool string.Tool string length 88.8'. Tool string consists of:Cable head, Gamma Ray,k Natural Gamma Ray, / Pressure Express, (2) Knuckle joints, Neutron Porosity, VV Density/Porosity/Caliper, Knuckle joint, Magnetic Resonance. 09:45 10:15 0.50 0 0 PROD1 EVALFN OTHR P Load radioactive sources. 10:15 11:30 1.25 0 2,350 PROD1 EVALFN ELOG P RIH w/tool string#2 to 2350',then pull up hole to tie in logs. 11:30 12:15 0.75 2,350 2,450 PROD1 EVALFN ELOG P RIH to 2450'. Page 13 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 14:45 2.50 2,450 PROD1 EVALFN ELOG P Start logging up f/2450'to 1900'@ 560 to 600'/hr. Pull up into the casing @ 1473'. 14:45 16:00 1.25 PROD1 EVALFN ELOG P Schlumberger log analysis in anchorage, rush-process logs and discuss with COP Houston and DOE Stake holder+pick xpt pressure points. 16:00 17:45 1.75 PROD1 EVALFN ELOG P Power-up xpt and perform pad checks in casing. 17:45 18:45 1.00 PROD1 EVALFN ELOG P Run tool string in hole and log correction pass. 18:45 00:00 5.25 2,306 2,091 PROD1 EVALFN ELOG P Measure pressure and mobility with SLB pressure express tool. Made Stop Test @ 2306-2282'-2272'-2267'-2262'-2251-2 243'-2127'-2101'&2091' 04/18/2011 Finish Logging operation with logging assembly#2. Log CMR/PEX/HNGS and 17 pressures with XPT to obtain mobilities in hydrate zone. POOH and lay down logging assembly#2.MU TLC-MDT logging assembly #3 and rih 2,259', SLB adjusted tool setting and logged hole to 1,977',x2. RIH and set packer on depth at 2071-2074 feet,start first stage of Mini-Frac. Release packer and rih and correlated for next packer depth. Stop&parked DP with center of packer at 2202 feet.. 00:00 02:30 2.50 2,091 2,328 PROD1 EVALFN ELOG P Continue With Open Hole Logging operation with Cable head, Gamma Ray,k Natural Gamma Ray, Pressure Express, (2)Knuckle joints, Neutron Porosity, Density/Porosity/Caliper, Knuckle joint, Magnetic Resonance.Continue with OHL operation.Tool string length 88.8'. Stop Test at 2082'-2073'-2064'2030'. Rih and Stop test at 2356-2340'-2328' 02:30 03:00 0.50 2,328 200 PROD1 EVALFN ELOG P POOH with open hole logging tools (Run#2) 03:00 03:30 0.50 200 89 PROD1 EVALFN SFTY P Stop and Clear the rig floor to continue pooh and remove source from tool 03:30 05:00 1.50 89 0 PROD1 EVALFN PULD P Remove and lay down logging assembly(Run#2)from well. 05:00 06:45 1.75 0 0 PROD1 EVALFN PULD P Load Tools to Rig floor for Drill Pipe Conveyed Logging. 06:45 07:15 0.50 0 0 PROD1 EVALFN SFTY P Pre job safety meeting w/Schlumber wireline and crew. 07:15 08:00 0.75 0 82 PROD1 EVALFN PULD P Make up Schlumberger toolstring (Run#3)f/drill pipe conveyed logging (MINI-Frac).Tool string#3: Modular pump out,modular flow control, modular pump out, modular packer assembly, modular pump out, power cartridge, (2)digital telemetry, hostile tension compression sub,downhole wet connect head.Total length of tool string 92.4'. Max OD=7". 08:00 08:30 0.50 82 82 PROD1 EVALFN DHEQ P Schlumberger connect to tools at the rig floor,test tool string. Page 14 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:15 0.75 82 96 PROD1 EVALFN PULD P Make up Schlumbergter top connection to the tool string,then a 3'long 3-1/2"IF pup jt,follow w/a crossover(4-1/2"IF box x 3-1/2"IF pin),then make up a stand of 5" HWDP. 09:15 09:45 0.50 96 472 PROD1 EVALFN TRIP P Run a total of 4 stands of 5"Heavy weight drill pipe from the derrick to 472'(end of logging tools). 09:45 10:30 0.75 472 1,413 PROD1 EVALFN TRIP P Continue to run 5"drill pipe f/472'to 1476'(end of logging tools). Ran a total of 10 stands of 5"drill pipe. 10:30 11:00 0.50 1,413 1,476 PROD1 EVALFN CIRC P Make a top drive connection on stand#11. Run in the hole to 1476'. Circulate, pumping 200 gpm w/110 psi. Circulate surface to surface w/ ports @+/-1394'. Circulate a total of 141 bbls. Max gas reading 50 units. Final mud temp out of the hole was 30 deg. Mud temp in the suction pit was 18 degrees going down hole. 11:00 11:15 0.25 1,476 1,506 PROD1 EVALFN TRIP P Run last single of stand#11 in the hole to 1506'. 11:15 11:30 0.25 1,506 1,506 PROD1 EVALFN SFTY P Pre job safety meeting on hanging sheave in teh derrick f/dp conveyed logging. 11:30 12:30 1.00 1,506 1,506 PROD1 EVALFN RURD P Hang sheave in the derrick f/logging. Make up Schlumberger side entry sub, make up a stand of 5"drill pipe (stand#12). 12:30 12:45 0.25 1,506 1,506 PROD1 EVALFN SFTY P Pre job safety meeting on hanging sheave f/wireline in the derrick. 12:45 13:00 0.25 1,506 1,506 PROD1 EVALFN CIRC P Pump down Schlumberger wet connect @ 168 gpm(57 spm)w/120 psi to latch in to the logging tool string. Pump a total of 40 bbls. 13:00 14:00 1.00 1,506 1,506 PROD1 EVALFN DHEQ P Schlumberger checking tools after connected. Clamp off line at the side entry sub. 14:00 15:00 1.00 1,506 2,259 PROD1 EVALFN TRIP P Trip in the hole w/logging string on 5"drill pipe f/1506'to 2259'(end of logging tools). Stand#19 in the hole. 15:00 15:30 0.50 2,259 1,977 PROD1 EVALFN DLOG P Schlumber adjust tool setting in logging unit. POOH f/2259'to 1977'. Logging hole. Repeat twice, logging 2070'to 1977' (end of tool string). 15:30 15:45 0.25 1,977 2,113 PROD1 EVALFN DLOG P RIH f/1977'to 2070', make a connection and run stand#18 to 2113'. RIH logging and set packers on depth.Stop w/packers @ 2071' to 2074'. Bottom of toolstring @ 2113'. 15:45 23:00 7.25 2,113 2,113 PROD1 EVALFN DLOG P Mni frac w/packers @ 2071'to 2074'. Pressure to closure 1400 psi= 13 ppg EMW. Page 15 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 2,113 2,244 PROD1 EVALFN DLOG P RIH f/2070'to 2356',make a connection and run stand#19&20. PUH from 2356'logging,s/b stand 20 and continue up hole and set packers on depth. Stop w/center of packers @ 2202.6". Bottom of toolstring @ 2244'. 04/19/2011 Finished the second stage of the Mini-Frac and Obtain in-situ measurement.MU Schlumberger TLC-MDT logging assembly#4 and RIH to 2,235'dpmd and started Modular Dynamics Testing with tools setting at 2260'-2263'.After several hours,downhole modular pump not working properly,functioning very slowly.TOOH to swap out with downhole modular pump from logging assembly#3. 00:00 04:45 4.75 2,244 2,244 PROD1 EVALFN DLOG P Start second stage of Mini-Frac to obtain in-situ stress measurement. Center of both packers @ 2202.6". Bottom of toolstring @ 2244'. 04:45 05:00 0.25 2,244 2,244 PROD1 EVALFN SFTY P PJSM. Discuss Hazard with Sim-Ops with SLB while TOOH with Logging Tools. 05:00 06:00 1.00 2,244 1,505 PROD1 EVALFN TRIP P Completed Second stage of Mini-Frac.TOOH S/B Drill Pipe with SLB Logging Assembly#3 06:00 06:45 0.75 1,505 1,505 PROD1 EVALFN OTHR P Stop at 1,505'(Side Entry Port)to un-seat E-Line Cable from Logging Tools.Crew Change Out. 06:45 07:45 1.00 1,505 93 PROD1 EVALFN TRIP P Continue OOH S/B Drill Pipe and Logging Assembly 07:45 08:45 1.00 93 0 PROD1 EVALFN PULD P At surface with Logging assembly #3. Break down logging tool section and lower down to ground trailer. 08:45 09:45 1.00 0 0 PROD1 EVALFN PULD P Load Next Section of SLB Logging Tools 09:45 11:30 1.75 0 135 PROD1 EVALFN PULD P MU SLB Tools. TLC-MDT assembly #4 11:30 12:30 1.00 135 1,544 PROD1 EVALFN TRIP P TIH with 5"DP w/SLB MDT Assembly#4 f/135.40'to 1544'(top of joint 11 ). 12:30 14:00 1.50 1,544 1,544 PROD1 EVALFN PULD P Make up side entry port,and install E-line with the pumpdown wet connector head. 14:00 16:00 2.00 1,544 2,325 PROD1 EVALFN TRIP P Continue in hole and correlate depth. Park DP at 2,325'up wt=79k/do wt=81 k. Pump down e-line and PWC and connect to logging tools. 16:00 22:00 6.00 2,325 2,325 PROD1 EVALFN DLOG P Start Modular Dynamics Testing @ 2260'-2263'. 22:00 22:15 0.25 2,325 2,325 PROD1 EVALFN SFTY P Downhole Modular pump not working properly. Hold PJSM with Rig Crew and SLB personal. 22:15 23:15 1.00 2,325 1,544 PROD1 EVALFN TRIP T TOOH with DP and MDT assembly #4 to inspect or replace Downhole Modular Pump. 23:15 23:45 0.50 1,544 1,544 PROD1 EVALFN OTHR T Stop Drill Pipe at side entry port and remove cramp from a-line. Break Latch on tool connection and let PWCH relax. Remove Side Entry port and pump down wet connector head. Page 16 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 1,544 1,073 PROD1 EVALFN TRIP T Continue OOH with 5"Drill Pipe and Modular Dynamics Testing Assembly#4 04/20/2011 POOH with MDT testing assembly. Remove modular pump from MDT assembly#4 and Replace with modular pump from MDT assembly#3. RIH to 1546'and installed side entry port and pump a-line cable and wet connection head&latched into logging assembly. Correlate depth and position center packer at 2261'ft and start MDT testing.Stage test area 2260'-2263', Unable obtain sample at stage. Release packer and RIH to next stage area, and place center of packer at 2303 ft.Start MDT testing at stage area 2302-2304 ft. 00:00 00:45 0.75 1,073 135 PROD1 EVALFN TRIP T Continue OOH with 5"Drill Pipe and Modular Dynamics Testing tool#4 keeping hole full. 00:45 03:30 2.75 135 0 PROD1 EVALFN PULD T At surface with MDT BHA#4. Lay down BHA to the modular pump in logging assembly. Remove modular pump and install modular pump from tool#3. 03:30 04:00 0.50 135 1,546 PROD1 EVALFN TRIP T TIH with SLB Logging Assembly#4 with modular pump from logging assembly#3. 04:00 05:00 1.00 1,546 1,546 PROD1 EVALFN OTHR T Stop at Stand#13(1546')and install side entry port,cramp and insert down wet connector head. Screw in top drive and pump e-line cable with MDT connection down and latch into logging assembly at 1 bpm, 50 psi. 05:00 06:30 1.50 1,546 2,325 PROD1 EVALFN TRIP T Continue to TIH with DP and Logging assembly#4 and correlate depth. Park Drill pipe at 2325'with center of packer at 2261'ft. !/ 06:30 16:30 10.00 2,325 2,325 PROD1 EVALFN DLOG P Start MDT Testing at 2260'-2263'ft. 16:30 00:00 7.50 2,325 2,271 PROD1 EVALFN DLOG P Unable to obtain a good sample in the test stage area. Relax down hole packer assembly. RIH and park drill pipe at 2271'ft. Place center of packer at 2303.8'ft and test stage area at 2302'-2304'ft. 04/21/2011 Finished Modular Dynamics Testing on desired zone. Rig down and Release SLB logging Crew and Logging Equipment. Started Weekly BOP test and safety alarm system testing. 00:00 12:30 12.50 2,271 2,271 PROD1 EVALFN DLOG P Continue MDT Testing.Center of packer at 2303.8'ft and test stage .area at 2302'-2304'ft. 12:30 12:45 0.25 2,271 2,271 PROD1 EVALFN SFTY P Completed MDT Testing.Release downhole packer and let relax. PJSM with Rig Crew and SLB Logging Crew. 12:45 13:45 1.00 2,271 1,035 PROD1 EVALFN TRIP P TOOH with Drill Pipe and SLB logging assembly to 1035'. Up Weight 90k. 13:45 15:15 1.50 1,035 1,035 PROD1 EVALFN PULD P Un-latch Downhole wet connect from logging assembly,and PUH to side entry port. Remove E-Line cable and _ DWC and side entry port. 15:15 16:00 0.75 1,035 135 PROD1 EVALFN TRIP P Continue OOH standing back drill pipe Page 17 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:30 0.50 135 0 PROD1 EVALFN PULD P At surface with MDT Logging assembly. Break down logging tools and remove from rig floor and load onto SLB logging trailer. 16:30 17:30 1.00 0 0 PROD1 WHDBO BOPE P PJSM. Pull wear bushing and install test plug. 17:30 00:00 6.50 0 PROD1 WHDBO BOPE P Start weekly BOP test.Test Annular 250/2500 psi.Test BOP Ram'and Choke manifold to 250/3500 psi. SpP Ram's tested(2 7/8")(4 1/2")and (5") /(s� 04/22/2011 1� Continue with testing BOP's. Observed upper rams and annular failed.Change out Upper rams and annular bag. Resume testing BOP's.Test Annular Upper pipe rams with 2 7/8",4 1/2", 5"test joints.250/3500 PSI. ,Perform Koomey test. Initial 200 PSI in 18 seconds,with full 3000 PSI in 85 seconds.4 Nitrogen bottle with !and avg PSI of 2075.Witness of test waived by AOGCC rep John Crisp @ 1645 HRS 4/21/11. Make up 9 7/8" 1Cleanout BHA with bit#2RR1,and trip in hole with no issues in open hole, proper displacement. Circulate bottoms up,mix and pump Hi Visc sweep @ 500 GPM's-950 PSI. Reciprocate&rotate drill string. POOH laying down drill pipe and pigging every joint to remove oil base mud before laying DP to storage area. 00:00 02:00 2.00 0 PROD1 WHDBO BOPE P Continue with BOP Testing Operation. Replace the upper pipe ram elements. 02:00 06:30 4.50 0 0 PROD1 WHDBO BOPE T Annular test failed.Troubleshoot. Change out Element on Annular Bag. 06:30 11:30 5.00 0 0 PROD1 WHDBO BOPE P Resume testing BOP's.Test Annular Upper pipe rams with 2 7/8",4 1/2", 5"test joints.250/3500 PSI. Perform Koomey test. Initial 200 PSI in 18 seconds,with full 3000 PSI in 85 seconds.4 Nitrogen bottle with and avg PSI of 2075.Witness of test waived by AOGCC rep John Crisp @ 1645 HRS 4/21/11 11:30 12:30 1.00 0 0 PROD1 WHDBO PULD P Pull test plug. Rig down Test equipment. Install WB-RILDS. 12:30 12:45 0.25 0 0 PROD1 DRILL SFTY P Held PJSM with Crew. Discuss safety&Hazard recognitionissues. Discuss procedure to make up 9 7/8" Cleanout BHA. 12:45 13:45 1.00 0 478 PROD1 DRILL PULD P Make up 9 7/8" BHA. Dumb Iron only. Bit#2RR1.Total BHA length= 478'. 13:45 15:30 1.75 478 2,597 PROD1 DRILL TRIP P Trip in hole with Clean out BHA from 478'-1473'. Fill drill pipe. Continue trip in hole to 2597'MD.Observed proper displacement,and no hole issues. 15:30 18:00 2.50 2,597 2,597 PROD1 DRILL CIRC P Reciprocate&rotate drill string while CBU and pump Hi visc sweep at 500 GPM's-950 PSI. UP WT-95K, SO WT-98K, ROT WT-101K. Observed minimal increase in cuttings across shakers. Mud temperature in 24 Degrees, Out 28 Degrees,. SIMOPS:With Crane, Load the 2 Spooling units onto rig floor for upcoming casing run. Page 18 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:45 0.75 2,597 2,597 PROD1 DRILL SFTY P Crew Change Out. PJSM. Blow down Top Drive. 18:45 00:00 5.25 2,597 900 PROD1 DRILL TRIP P Start TOOH,sucking OBM from drill pipe before laying down and kicking out to outside storage area. Up Wt=90k.Gave AOGCC Notice of Upper Ram change to 7 5/8"at 1940 hrs,John Crisp and Jeff Jones Called back at 1945 hrs and Waived Witness to test of Upper Ram's test is not complete before 0600 hrs on 4/23/11. 04/23/2011 Continue POOH laying down 5"DP. Utilize Vac system to clean OBM from joints before removing from pipe shed. Install&test 7 5/8"Upper rams. Rig up to run 4 1/2"x 7 5/8"casing assembly. Held PJSM with all personnel. Make up shoe track assembly,fill pipe&check floats. Good.Continue RIH picking up 4 1/2" casing installing protector clamps as per detail Make up Pinnacle gauge carriers,and splice TEC wire as needed.Operation at midnight.Just finish the 4 1/2"Completion section of the production string,all three stages of the Pinnacle Gauge assembly is complete and secured. Start making up the 7 5/8"section. 00:00 02:15 2.25 900 0 PROD1 DRILL TRIP P Continue POOH laying down drill pipe and pigging every joint to remove oil base mud before off loading to storage area. 02:15 02:45 0.50 0 0 PROD1 DRILL PULD P Remove and Lay down Clean Out Assembly. 02:45 03:45 1.00 0 0 PROD1 DRILL OTHR P Use Vacuum System to Clean Floor. 03:45 04:30 0.75 0 0 PROD1 DRILL PULD P Lay down and kick out 5 stand of 5" Drill Pipe In mouse hole. 04:30 05:00 0.50 0 0 PROD1 WHDBO MPSP P Pull Wear Bushing and Set Test Plug. 05:00 05:15 0.25 0 0 PROD1 WHDBO SFTY P PJSM. Discuss Hazard of Changing out ram body. 05:15 06:30 1.25 0 0 PROD1 WHDBO NUND P Remove 5"x 2 7/8"VBR's and Install 7 5/8"pipe ram's in upper set of BOPE. 06:30 07:30 1.00 0 0 PROD1 WHDBO BOPE P Rig up testing equipment and Pressure test Upper set of 7 5/8" pipe ram's.Pull Test Plug and Rig _down Testing equipment. 07:30 13:00 5.50 0 0 COMPZ CASING RURD P Rig us to run casino. Set Pinnacle spooling units, and install sheaves. Hang casing runing tongs. Pull all protector clamps to rig floor. Check all equipment. Set computers and _check lines. 13:00 13:30 0.50 0 0 COMPZ CASING SFTY P Held PJSM with crew, Pinnacle reps, Baker rep, and all personnel. Discuss safty&hazard recognition issues. Discuss procedure to make up and run 4 1/2"x 7 5/8"Casing string. Page 19 of 26 Time Logs ✓ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:30 2.00 0 355 COMPZ CASING RNCS P Make up 4 1/2"Weatherford shoe, joint and shoe track with Weatherford Float collar. Fill pipe with OBM,and check floats.Continue run in hole to 355'installing proetctor clamps as per detail. Install Baker Seal bore receptacle and Pinnacle gauge carriers. Make up TQ on 4 1/2" casing 2400-2800 ft/lbs.Observed proper hole fill and displacement. 15:30 16:30 1.00 355 355 COMPZ CASING RURD P Rig up Pinnacle reps to splice TEC wire to pinnacle gauge carrier. Splice wire.Test same. 16:30 17:30 1.00 355 355 COMPZ CASING RNCS P Continue RIH making up 4 1/2" casing installing 3rd Pinnacle gauge carrier, installing protector clamps as per detail. Make up TQ on 4 1/2" casing 2400-2800 ft/lbs. Observed proper hole fill and displacement. 17:30 18:00 0.50 366 366 COMPZ CASING RURD P Rig up Pinnacle reps to splice TEC wire to pinnacle gauge carrier.Splice wire.Test same. 18:00 20:00 2.00 366 366 COMPZ CASING RNCS T Second Pinnacle Gauge Carrier from bottom of completion tally that holds the cable in place is to long, needs to be ground down and cut off. 20:00 20:30 0.50 393 393 COMPZ CASING RNCS P Continue RIH with CSG and Jewelry. Install Camco"DB"No go nipple w/3.686"ID and(4)PUPS. 7.83'-3.83'-9.78'and a 3.82'. DN wt=40k 20:30 21:30 1.00 549 587 COMPZ CASING RNCS P Run(5)Jts of 4 1/2"12.6#CSG( Note:Jt#9 Has the PIP Tag Install in the collar). Stop on jt 10 and fill pipe to test Gauges. Pressure on Guages look good. Installed Blast Protector above collar and centralizer on every joint. (mid joint). 21:30 23:30 2.00 587 587 COMPZ CASING RNCS P Rig up third Pinnacle Gauge Carrier .Hal reps to splice TEC wire to pinnacle gauge carrier. Splice wire. Test same. ( Note: Ran a total of 14 joints of 4 1/2"12.6#CSG) 23:30 00:00 0.50 587 630 COMPZ CASING RNCS P Continue RIH making up 4 1/2" casing installing 7 5/8" Baker Seral Bore assembly with crossover joint to 4 1/2". Make up TQ on 4 1/2" casing 2400-2800 ft/lbs. Make up TQ on 7 5/8"casing-6500ft/lbs. Continue run 7 5/8"casing as per �Sl detail installing protector clamps. (/ Observed proper hole fill and displacement. Page 20 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/24/2011 24 hr Summary Continue run 4 1/2"x 7 5/8"casing string with TEC&DTS wires,attaching protector clamps as per detail. MU Casing hanger and landing joint.Terminate lines for hanger penetration. Secure&test same to 5000 PSI. RIH land casing hanger. UP/DN WT=98K.Verify landed hanger as per FMC. RILDS. RU Schlumberger wireliners, and run GR-CCL log to correlate PIP tag and blank pipe depths.Observed 1/2'foot difference than pipe tally with wireline measurement.WLOH rig down Schlumberger. Nipple down,splitting the spools. . Nipple up,and test void on spools as per FMC to 5000 PSI. Utilize crane to off load all spools from rig floor, and load Flatpak spool with spool&cage. Load Upper 4.5"completion string and jewelry. 00:00 02:45 2.75 630 1,445 COMPZ CASING RNCS P Finished the 4 1/2"Section of production completion,all 3 Pinnacle Gauge are installed and cable secure to that point. C/O CSG handling equipment from 4.5"to 7 5/8". Make up TQ on 7 5/8"casing-4200ft/lbs after a 10 joint average. Continue run 7 5/8"casing as per detail installing protector clamps on every CSG collar and a clamp at mid joint. Observed proper hole fill and displacement. 02:45 03:00 0.25 1,445 1,445 COMPZ CASING OTHR P Make adjustment to HES spooling unit.Clamp needed adjusting. 03:00 05:00 2.00 1,445 2,561 COMPZ CASING RNCS P Continue run 7 5/8"CSG f/1706 ft, filling completion every 3 stands. Installing protector clamps on every collar and clamp at mid joint. RIH wt=70k.All three Pinnacle Gauges Still Working Properly. 05:00 09:00 4.00 2,561 2,561 COMPZ CASING PULD P P/U 7 5/8"Casing Hanger and, landing joint.Terminate The TEC& DTS Wires and strap to 7 5/8"CSG V before landing completion for g �sY protection. Strap 20'of lines below ? � hanger, and 10'of line above hanger. Tested penetrations as per FMC 5000 PSI-10 minutes. 09:00 10:00 1.00 2,561 2,592 COMPZ CASING PULD P Land casing hanger with an RKB of 28.70'. Pull LDS and verify landed as per FMC. RILDS.Torque to 450 ft/lbs. UP WT=98K,SO WT=98K. Pull landing joint and lay down same. 10:00 10:15 0.25 2,592 2,592 COMPZ EVALWE SFTY P Held PJSM with crew and Schlumberger reps. Discuss safety &hazard recognition issues. Discuss procedure to rig up and run Correlation logging tools. 10:15 10:45 0.50 2,592 2,592 COMPZ EVALWE RURD P Rig up sheaves and hang tools. Obtain zero at the rig floor. 10:45 11:30 0.75 2,592 2,592 COMPZ EVALWE ELOG P WLIH with GR-CCL logging tool to, log PIP tag and verify correlation depths. Log from 2300'-2000'WLM. Verified PIP tag on depth as planned. WLOH. 11:30 12:00 0.50 2,592 2,592 COMPZ EVALWE RURD P Rig down Sheaves and wireliners. Release Schlumberger. Page 21 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:15 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with crew. Discuss safety&hazrd recognition issues. Discuss procedure to nipple down BOP's,and terminate the TEC wires to the casing spool as per FMC& Pinnacle reps. 12:15 17:00 4.75 0 0 COMPZ WHDBO NUND P Nipple down stack, and flow riser. Split the tbg spool from the casing spool. Pull wires through the casing �C spool ports as per FMC reps.Secure /) same. Nipple up BOP's and test -1 Split on the spools. '/'',w� SIMOPS: Utilize crane, remove all spools form rig floor and heavy equipment. Pull Flatpak spool and wire to rig floor with spooling unit and cage. Pull tools to rig floor. 17:00 00:00 7.00 0 0 COMPZ WHDBO PRTS P RU Pinnacle to terminate and test lines through the ports on the casing spool,then connect to their monitors to make sure that communication is being made with the downhole gauges. Load&strap 84 joints for the upper 4.5"completion string and jewelry. 04/25/2011 Pull DTS&TEC wires through casing spool side ports as planned.Attach same.Terminate lines,and connect to there monitors to check for communication to the downhole gauges. Loaded and tallied 4.5"Upper completion. Removed 7 5/8"ram's and installed 2 7/8"x 5'vbr's and tested 250/3500 psi. Pickup and run in hole with 2 7/8"fox cementing work string with a baker 2.38"slick stinger down to top of baker packoff bushing at 2370 ft and string into packoff bushing and no-go 10 ft deeper. Establish circulation @ 3-4 bpm and condition chilled mud. Sting into packoff bushing, and establish circulation to 3 BPM for full circulation. Batch mis Mud Push&cement. Pump a total of 75 BBLS of mud push and 153 BBLS of Litecrete cement, observing 10 BBLS of 11.0 PPG cement to surface. CIP at 15:37 HRS. Floats held. Pull stinger, and reverse circulate with no cement returns. Laydown tbgback to 1800'MD. Circulate 90 DegOBM asper rig engineer. Blow down&RD DrillCool units. 00:00 01:30 1.50 COMPZ WHDBO SRVY P Waiting on Pinnacle to terminate and test lines through the ports on the casing spool and install in there monitors,so communication is being made to the downhole gauges. 01:30 02:00 0.50 COMPZ WHDBOOTHR P Install fabricated safety clamps on the spool for the extended nipple sticking out of spool. 02:00 04:00 2.00 COMPZ WHDBO BOPE P Set Test Plug.Drain BOP Stack,pull 7 5/8"rams from upper set and replace with 2 7/8"x 5"VBR's. Fill Stack and test to 250/3500 psi.Test BOP Body,250/3500 psi. Pull Test Plug and rig down testing equipment. Notified AOGCC @ 1830 hrs on 4/24/11 about testing upper ram's. No Call Back. 04:00 04:15 0.25 COMPZ CEMEN"SFTY P Held PJSM with crew&BOT rep. Discuss safety&hazrd recognition issues. Discuss procedure to make up and run stinger assembly for stab in cement job. Page 22 of 26 41110 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 COMPZ CEMEN-PULD P Pull tools to floor. Strap all tools,and check equipment. Make up BOT Slick Stinger with XO and handling pup. 04:30 07:30 3.00 COMPZ CEMENT TRIP P RIH picking up 2 7/8"Fox threaded tubing,drifting every joint @ 2.23", with BOT Slick Stick assembly. Total BHA length=20.90'. 07:30 08:30 1.00 COMPZ CEMENT CIRC P RU to circulate down 2 7/8"above the packoff bushing.4 BPM-740 PSI. 08:30 09:30 1.00 COMPZ CEMENT CIRC P Sting in and space out into packoff bushing with stinger 12'into bushing. UP WT-50K, SO WT-55K 09:30 10:30 1.00 COMPZ CEMENT RURD P Make up all hoses and lines for cement job. Rig up Schlumberger cementers. 10:30 11:30 1.00 COMPZ CEMEN"CIRC P Pump OBM down the 2 7/8"tbg,and returns up the 7 5/8"x 10 3/4" annulus with rates of 3 BPM-500 PSI. 11:30 12:00 0.50 COMPZ CEMEN-CIRC P Shut down pumps.Allow static time on OA as per engineer for cooling mud. Schlumberger batch mix Mud Push. 12:00 12:30 0.50 COMPZ CEMEN-SFTY P Held PJSM with crew,and all personnel. Discuss safety&hazard recognition issues. Discuss procedure to rig up and puimp cement job. Designate Spill champs. Continue batch mix mud push. 12:30 13:30 1.00 COMPZ CEMENT CMNT P Continue batch mix Mud Push& Cement. 13:30 15:45 2.25 COMPZ CEMEN-CMNT P Turn over to Schlumberger. Load lines and pump 5 BBLS of 9.8 ppg OBM mud push @ 57 Degrees. Pressure test lines to 3500 PSI. Good test.Continue pump 45 BBLS of 9.8 PPG OBM Mud Push @ 57 Degrees @ max rate of 3 BPM-338 PSI. Chase with 25 BBLS of 10.6 L/A-1- PPG Water based Mud Push @ 3 BPM-228 PSI, and 57 Degrees. GSQ Continue pumping 11.0 PPG Lite crete cement at 57 DEG,with rate at ti 3 BPM,with pressure building to ,' °�� 1150 PSI indicating good lift �� pressure. Pumped a total of 153 BBLS of Litecrete. Displace cement with Schlumberger, pumping 1 BBL of Mud Push, and then 13.5 BBLS of 9.0 PPG OBM.CIP @ 15:37 HRS Observed atotal of 10 BBLS of 11.0 ►7 PPG cement to surface. 15:45 16:00 0.25 COMPZ CEMEN-CMNT P Bleed pressures.Open valves and check floats. Floats held. Pull stinger free form packoff bushing. Kept stinger 2'above bushing. Page 23 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:15 0.25 COMPZ CEMEN-CIRCP Close annular, reverse circulate 25 BBLS to verify no cement returns @ 1.75 BPM-400 PSI. Shut in. Open annular. 16:15 17:00 0.75 COMPZ DRILL TRIP P POOH laying down 18 joints of 2 7/8" tbg, positioning stinger at 1800'MD. 17:00 00:00 7.00 COMPZ DRILL CIRC P Circulate heated OBM at 90 DEG, down tbg to the IA at 2 BPM-300 PSI, as per rig engineer. No reciprocation. 04/26/2011 Circulated 90 deg heated OBM for a total of 10 hours. RIH w/2 7/8"work string down to 2364 ft. Displacement fluid after mixing surfactant was 57 deg, bring out more fluid, circulate pits to cool to 52 degree. Mix and circulate 40 bbls spacer of safe-surf, circulate 250 bbls of 52 deg.fresh water,displacing OBM until clean returns observed. Displace 7 5/8"to brine, spotting 15 bbls of brine with corrosion inhibitor in the 4.5" casing section. POOH, laying down 2 7/8"work string. Ready rig floor and 4.5"equipment.Make up 4.5"pipe handling equipment. Make up Baker seal assembly and lower completion jewelry as per Baker rep. 00:00 03:00 3.00 1,789 1,789 COMPZ DRILL CIRC P Continue to Circulate heated OBM at 90-120DEG,down tbg to the IA at 2 BPM-300 PSI, as per rig engineer. No reciprocation.Average Temp coming out of well 80 degs. Bottom DH gauge temp(55.2 deg)psi 1067 psi)Middle DH gauge temp 54 degs)psi( 1035 psi)Top DH gauge temp(51.1 degs)psi(951 psi). 03:00 04:15 1.25 1,789 2,364 COMPZ DRILL TRIP P PJSM.Trip in hole with 2 7/8"work string down to just above packoff bushing at 2370'. 04:15 13:00 8.75 2,364 2,364 COMPZ DRILL CIRC P Displacement fluid with surfactant was mixed to 57 Deg. Bring more fluid, circulate pits to cool the fluid to 52 Deg. 13:00 14:30 1.50 2,364 2,364 COMPZ DRILL CIRC P Mix and Circulate 40 bbls spacer of safe-surf-0.Circulate 250 bbls of 57 deg fresh water,displacing OBM until clean returns. 14:30 16:00 1.50 2,364 2,364 COMPZ DRILL CIRC P Displace 7 5/8"to brine,spotting 15 bbls of brine with corrosion inhibitor in the 4 1/2"casing section. 16:00 18:00 2.00 2,364 0 COMPZ DRILL TRIP P POOH, laying down 2 7/8"work string. 18:00 22:30 4.50 0 0 COMPZ RPCOM PULD P Ready ria floor for 4.5"completion, equipment. Make up same pipe handling equipment. 22:30 23:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM with all third party crews involved in completion run. 23:00 00:00 1.00 0 60 COMPZ RPCOM PULD P Make up Baker seal assembly and lower completion equipment as per Baker rep. 04/27/2011 Land 4.5"completion with Chemical injection mandrel,and FlatPak assembly. Install clamps at mid joint as per procedure.Terminate lines to hanger and test lines to 5,000 psi. Pump down each Flatpak line @ 30 GPM-2,150 psi, pump total of 6.2 bbls. RILDS.Test tubing to 3,000 psi for 30 mins,good test,bleed to 2,000 psi.Test IA to 3,000 psi for same,good test. Bleed tubing to zero and shear SOV. ND BOP stack. NU tree and test to 5,000 psi.Start freeze protect of well with diesel. Page 24 of 26 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 05:30 5.50 60 1,976 COMPZ RPCOM RCST P Continue Run in hole with 4 1/2" Completion string.Attach Chemical Injection line, and test same to 1000 PSI.Continue RIH picking up joints from shed.Attch Flatpak clamps at mid joint. RIH to 1976'. 05:30 06:00 0.50 1,976 1,976 COMPZ RPCOM RCST P Make up hose and slowly sting into Casing Seal bore pumping down tubing to verify entry into CSB. Bleed pressure and slack off until land Locator sub on depth. 06:00 07:30 1.50 1,976 1,976 COMPZ RPCOM RCST P Pull 3 joints out of hole. Install space out pups. Make up tubing hanger, and joint. Install Landing joint. UP WT-60K, SO WT-65K. 07:30 09:00 1.50 1,976 1,976 COMPZ RPCOM RCST P Terminate lines to hanger. Pressure test same to 5000 PSI as per FMC and CJS reps. Install test ports to top of hanger. 09:00 11:30 2.50 1,976 1,976 COMPZ RPCOM PRTS P Load 20 BBLS of 60 DEG brine onto Little Red Services. RU LRS, attaching pump lines to ports in hanger. Pump down each Flatpak tube lines to verify rate of 29 GPM- 2100 PSI. Pumped a total of 6.2 BBLS. Bleed lines. Remove test ports on top of hanger and secure same as per FMC. 11:30 12:30 1.00 1,985 1,985 COMPZ RPCOM HOSO P Drain BOP stack,and flush same with fresh water. RIH to land tubing ranoer. RILDS.Observed seals stinging into casing seal bore when slacking off. Locator spaced out above casing seal bore 8'. Seals in CSB 10'. Installed a total of 62 Clamps at mid joint,and 3 Stainless Steel bands. 12:30 14:30 2.00 0 0 COMPZ RPCOM PRTS P Rig test equipment on tbg hanger joint with pump down lines. Pressure down tbg to 3000 PSI for a 30 minute test, recorded on chart. Observed annulus-open no flow. Good test. Bleed pressure to 2000 PSI on tbg. Hold same. Pressure down annulus to 3000 PSI for a 30 minute test recorded on chart. Good test. Bleed tubing pressure to zero, observed shear valve dump for communication to tubing. Bleed all pressures. 14:30 15:00 0.50 0 0 COMPZ RPCOM RURD P Rig down test equipment. Back out and lay down landing joint. 15:00 15:30 0.50 0 0 COMPZ WHDBO NUND P Prep cellar for ND-NU. Install BPV as per FMC rep. 15:30 15:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with crew&FMC rep. Discuss safety&hazard recognition issues. Discuss procedure to ND BOP's and NU Tree. Page 25 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:45 17:00 1.25 0 0 COMPZ WHDBO NUND P Nipple down BOP stack,and lines. Clean pits pumping safe surf-o and _washing same. 17:00 19:30 2.50 0 0 COMPZ WHDBO NUND P Nipple up Tree. 19:30 22:00 2.50 0 0 COMPZ WHDBO PRTS P Pull BPV and set test plug.Test tree to 250/5,000 psi for 15 mins. RD down test equipment. Pull test plug. 22:00 00:00 2.00 0 0 COMPZ DRILL FRZP P RU and pump 2.5 bbls diesel down Flatpak lines. PT surface lines for freeze protect to 3,000 psi. Start pumping diesel down IA @.90 BPM @ 1,750 psi,got 35 bbls away, pressure kept climbing to 2,500 psi, had to shut down let well bleed down. 04/28/2011 Complete freeze protect of well TBG/Casing with diesel. Secure wellhead and test below BPV to 3,000 psi. RDMO Nordic rig. 00:00 04:00 4.00 0 COMPZ RPCOM FRZP P Had to switch pumping to tubing side to free circulating issues.Complete freeze protect of well with diesel to 2,000-ft tbg/casing. Secure wellhead with BPV and test below to 3,000 psi. Bleed to zero. 04:00 18:00 14.00 COMPZ MOVE DMOB P Continue clean pits,secure cellar. Clean cellar box. Utilize crane to remove Flatpak spool and unit from rig floor. Crane to load DrillColl units, and clean up plywood,and pit liners. Remove berms. 18:00 21:00 3.00 COMPZ MOVE DMOB P RDMO Rig Released @ 21:00 HRS. Page 26 of 26 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 23, 2011 8:31 AM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Subject: RE: Bond Log for Ignik Sikumi#1 prD 21 t- o Z 7. Steve, As per our conversation the cement bond log can be done later on the casing... additionally the bond log must prove isolation and doesn't have to physically log over the entire cemented casing. The 200' planned logging interval above the injection zone ( if bonded) should prove adequate isolation. This meets our injection well criteria per 20 AAC 25.412 (d). Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz@contractor.conocophillips.com] Sent: Monday, March 21, 2011 10:16 AM To: Schwartz, Guy L (DOA) Subject: Bond Log for Ignik Sikumi #1 Guy, I just wanted to firm up our conversation on the bond log requirement for the hydrate well. We plan to cement the surface casing to surface as usual (10 3/4"). Then drill a 9 7/8" hole and run a tapered string of 4 1/2"X 7 5/8"casing to +/-2850 TD and cement that string to surface also. The state requires cement to be at least 500 feet above the upper most hydrocarbon bearing zone which in this case would be the hydrate, and if we bring the cement to surface that requirement is covered. On the 4 1/2"X 7 5/8" long string the cross over is going to be approximately 200 feet above the top of the hydrate zone. That crossover will also contain a PBR that will be used with the seal assembly on the 4 1/2" upper completion. This will limit us to only a 200 foot span for running the bond log across the 7 5/8"casing, but as we talked about, if we can get 50 feet of intermittent bond in that 200 feet we will have met the requirement of isolation for the state. The problem we are experiencing is the long set time for the cement with the cold fluid temperatures we plan to pump at. By going ahead with the completion without the bond log this year, we would run the cement bond log next year prior to any perforating and testing. This would give the cement plenty of time setting up and giving us a good compressive strength. Do you concur. Thanks, Steve Shultz ConocoPhillips Drilling and Wells 263-4297 3/23/2011 /SEANPARNELL,GOVERNOR ALASKA OIL AND GASli[x\c{r 11) F EL DI Z 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 G. L. Alvord FAX (907)276-7542 Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Field, Prudhoe Bay-Hydrates Pool, Ignik Sikumi #1 ConocoPhillips Alaska, Inc. Permit No: 211-027 Surface Location: 1858' FSL, 2475' FWL, SEC. 34, T12N, R11E, UM Bottomhole Location: 1858' FSL, 2475' FWL, SEC. 34, T12N, R11E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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. Sincerely, I Daniel T. Seamount, Jr. Chair DATED this I day of March, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) . RECEIVED STATE OF ALASKA FEB 2 2 2011a� // ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Mega 01181 Gas COM,Commission 20 AAC 25.005 a(1IChniagfi 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone / 1 c.Specify if well is proposed for: Drill 0 Re-drill❑ Stratigraphic Test Development-Gaf Service-Supply ❑ Multiple Zone U Coalbed Gas ❑ Gas Hydrates 0 Re-entry ❑ Exploratory Service-WAG LI Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 Ignik Sikumi#1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:2856' TVD: 2856' Prudhoe Bay Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1858'FSL,2475'FWL,Sec.34,T12N,R11 E, UM ADL 28239 Top of Productive Horizon: 8.Land Use Permit 13.Approximate Spud Date: 1858'FSL,2475'FWL,Sec.34,T12N, R11E, UM na 3/11/2011 Total Depth: 9.Acres in Property: 14.Distance to 1858'FSL,2475'FWL,Sec.34,T12N,R11 E, UM 2560 Nearest Property: 1.6 miles 4b.Location of Well(State Base lane Coordinates-NAD 27): 10.KB Elevation above MSL: 81 feet 15.Distance to Nearest Well Open Surface:x- ,p34119 .t..t't-i t y- 5977590 Zone- 4 GL Elevation above MSL: OZ Zye to Same Pool: PBU L-107,166'@ 2764' 16.Deviated wells: Kickoff depth: na ft. 17.Maximum Annated Pressuresrein psig(see 20 MC 25.035) Maximum Hole Angle: 0° deg Downhole.88'psig Surface:706 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 20" 16" 164.8# B-35 Welded 100' Surf Surf 100' 100' Drilled 13.5" 10.75" 45# L-80 BTC 1511' Surf Surf 1511' 1511' 650 sx Arctic LiteCRETE,190 sx DeepCRETE 9-7/8" c 7.625"x 29.7# L-80 BTCM 2006' Skn'f 6u4" 2856' 2856' 470 sx DeepCRETE w/GasBLOK 4.5" 12.6# L-80 IBTM 850' TQC (-t'a.�o€ J c4,s; sfri•D) $2H.// 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Printed Name G. L. Alvord Title Alaska Drilling Manager SignatureC'; LIZ�A1-'�✓-46 Phon 265-6120 Date 2124 /2(}i LZ-ii /--- it t.'fr,-'fl.t,moi) Commission Use Only Permit to Drill API Number: Permit Ap ova See cover letter Number:�/fD,2� 50-0 , 3 Date: 33, 1 5 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed a ane,gas hydrates,or gas contained in sh es: ❑ 71;3S-0o rase 8010 5--f-- Samples req'd: Yes ❑ No Mud log req'd: Yes No ❑ Other: A acdt, psi, /4nn 7 s 14( H2§measures: Yes ❑ No Directional svy req'd: Yes fe' No CIh. ,, $ M1 T F. C/ - re q '-..J`n .K S,(, 1 f'tcas.-�,/�eJ � fe 7 .4-. '5 ape ,.° "5.: APPROVED BY THE COMMISSION DATE: a fllie COMMISSIONER Form 10-401 ( evised 7/2009) This permit is valid 2 th o n h t prove!(20 AAC 25.005(g)) ubmit in Duplicate 2-e d'-0 2/204/ Post Office Box 100360 C o coni Application for Permit I Ignik Sikumi#1 (Hydrate Test Well) Saved:21-Feb-11 Permit It — Ignik Sikumi #1 (Hydrate Test Well) Application for Permit to Drill Document Ta Te Moximlz * W011 Vcilug Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 0 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 Ignik Sikumi(Hydrate Test Well) Page 1 of 7 ORIGINAL Printed:21-Feb-11 Application for Permit II Ignik Sikumi#1 (Hydrate Test Well) Saved:21-Feb-11 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Well Schematic 7 Attachment 4 Cement Summary 7 1. Well Name Requirements of 20 AAC 25.005 09 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(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 designatedfor 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 Ignik Sikumi#1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each qf the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)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 suiface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic.Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1,858'FSL, 2,475"FWL, Sec 34, T12N,R11E,UM NAD 1927 RKB Elevation 81'AMSL Northings: 5,977,590 Eastings: 484,119 Pad Elevation 50'AMSL Location at Top of Productive Interval 1,858"FSL, 2,475"FWL, Sec 34, T12N,R11E,UM Nad 1927 Measured Depth,RKB: 2,231' Northings: 5,977,590 Eastings:484,119 Total Vertical Depth,RKB: 2,231' Total Vertical Depth, SS: 2,150' Location at Total Depth 1,858"FSL, 2,475"FWL, Sec 34, T12N,R11E,UM Nad 1927 Measured Depth,RKB: 2,856' Northings: 5,977,590 Eastings: 484,119 Total Vertical Depth,RKB: 2,856' Total Vertical Depth, SS: 2,775' 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 (I)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. The operator of all offset wells is BP. Ignik Sikumi(Hydrate Test Well) O RI ^IG H IA ( Pagee ER L Printed:21-Feb-11 Application for Permit Ignik Sikumi#1 (Hydrate Test Well) Saved:21-Feb-11 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 far an item already on file with the commission and identified in the application: (3,)a diagram and description of the blowout prevention equipment(BOPE)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 hazards,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; The maximum potential reservoir pressure for Hydrate Test Well to be water gradient. cc> 1` , s Equivalent Mud Weight @ TD=952/(2,206*.052)=8.3 ppg=0.43 psi/ft rvs The maximum potential surface pressure(MPSP)while drilling the Hydrate Test Well is calculated using the predicted 883 psi reservoir pressure,a 0.11 psi/ft gas gradient,and a Hydrate sand top TVD of 2,206'. MPSP =(2,206 ft TVD)*(0.43 -0.11 psi/ft) TD - ° 15(`' ✓• =706 psi V (B)data on potential gas zones; The well bore is not expected to penetrate any oil or gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones,and zones that have a propensity for differential sticking: 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.lbr an item already on file with the connnission and identified in the application: (5)a description of the procedure conducting formation integrity tests,as required under 20 AAC'25.030(f); Drill out surface casing shoe and perform FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. Ignik Sikumi(Hydrate Test Well) Page 3 of 7 ORIGINAL Printed:21-Feb-11 Application for Permit I Ignik Sikumi#1 (Hydrate Test Well) Saved:21-Feb-11 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 Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) ft ft Cement Pro.ram 16 24 164.8 B-35 Welded 100' Surf 100'/100' Drilled and cemented Cemented to Surface with 10-3/4 13-1/2 40 L-80 BTC 1,511' Surf 1,511'/1,511' 650 sx ARCTIC LiteCrete Lead 11.1 ppg, 190 sx Tail DeepCrete Slurry 12.0 ppg 7-5/8 x 2 006' Cement to surface with 4-1/2 9-7/8 26 L-80 BTCM &850' 2,856'/2,856' 470 sx DeepCrete w/GasBLOK 11.0 ppg Note:The cement will be mixed and pumped at 70°F and will go through its normal heat of hydration. 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 far•an item already on file with the commission and identified in the application: (7)a diagram and description of the direrter 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 ofthe 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: Surface WBM 0'—1,511 Density(ppg) 9.6-10.2 Funnel Viscosity(seconds) 75-250 Yield Point(cP) 35-45 pH 9.0-9.5 API Filtrate(cc) NC—8.0 Chlorides(mg/1) <1000 Production 70/30 OBM 1,511'—2,856' Density(ppg) 8.3-9.0 Yield Point(cP) 18-20 HTHP Fluid Loss <5 OWR 70/30 Electrical Stability >600 Temperature 20°F In-30°Out Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. lgnik Sikumi(Hydrate Test Well) ° ` IGINAe 7 Printed:21-Feb-11 11 Application for Permit t I Ignik Sikumi#1 (Hydrate Test Well) Saved:21-Feb-11 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 of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); 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: (l0)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: (I 1)for a well drilled from an of/shore 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 of20 AAC 25.025(Bondinglhave 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 onto ice pad and rig up on Ignik Sikumi#1 Conductor. 2. NU and function test diverter system and prepare spud mud.i/ / 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud 13-1/2"hole and drill a straight hole to the 10-3/4" surface casing point(1,511' MD/ 1,511'TVD). Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. J 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with OBM. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform FIT to 12.5 ppg. 9. Drill 9-7/8"hole to 2,856'MD/2,856'TVD with chilled OBM. Run MWD/LWD logging tools in drill string as required. Ignik Sikumi(Hydrate Test Well) Page 5 of 7 ORIGINAL Printed:21-Feb-11 Application for Permit I I Ignik Sikumi#1 (Hydrate Test Well) Saved:21-Feb-11 10. POOH and rig up wireline logging tools and log well. a. PEX/Rt Scanner(1511'-2,856') b. CMR(1,511'-2,856') c. Sonic Carrier(100'-2,825') d. OBMI(1,511'-2,825') e. XPT 11. RD wireline and run the following DP conveyed log a. MDT 12. POOH and rig down DP conveyed logging tools 13. RIH with drillstring for wiper run and circulate and condition hole to prepare for casing run. 14. POOH with 5"DP and rack back. Run 7-5/8"29.7#L-80 BTCM x 4-1/2" 12.6#L-80 IBTM casing e (XO @ 2,008')to+/-2,856'MD/+/-2,856'TVD. a. A DTS(distributed temperature survey)wire will be run from the casing shoe to surface(externally) b. A 3/8"braided e-line tied into the Pressure/Temperature gauges at+/-2,257',+/-2,190'and+/-2,025' p will be run to surface(externally) c. A 4 1/2"seal bore receptacle w/a 3.625"seal bore for a future sand screen will be situated at+/- 2,235' d. A 4'A"Camco"DB"Nipple w/3.735'No-Go will be situated at 2,184' e. 7-5/8"x 4-1/2 crossover will be at+/-2,008'MD/+/-2,008'TVD. 15. Hang 7 5/8"on the mandrel hanger and split the stack between the tubinghead and the casinghead tor DTS and Pressure/Temperature gauge wires. --i S� I�w�+-� "-bad 60,1 ®���,,,Q a. Thread DTS and Pressure/Temperature wires through specialized lock down screw ports 16. MU stack back to the casinghead and pressure test connection to 3500 psi. 17. PU and run 2-7/8"cementing string with a K-1 retainer in hole,set tool at+/-5'above the float collar. Float collar is at+7-2,366' MD. a. Purpose of the cementing string is to isolate and protect the pressure/temperature gauges in the 4-1/2" casing from the cement. 18. Cement the long string to surface through the 2 7/8"tubing and retainer,displace cement with OBM,unsting from retainer and reverse out,POOH rack back tubing and LD stinger. a. Plan to over dimes lace the shoe by 2_3 bbls ensuring no cement inside of 4 'A"above the float collar (shoe trac has+/-6.9 bbls of volume) 19. LD all of the 5"drill pipe standing in derrick 20. Run a cement bond log of the 7-5/8"x 4-1/2"casing to verify bond. ✓ 21. RIH with 2 7/8"openended tubing to retainer and change well over to brine. 22. POOH and LD 2 7/8"tubing 23. RU and run 4-1/2"upper completion tubing with seal assembly and set in the 7-5/8"x 4-1/2"crossover @ +/-2,008' as follows from bottom to top: a. 4 '/"Seal Assembly @+/-2,008' b. 4'/z", 12.6#,L-80,IBT pup c. 4 'A"Camco"DB"Nipple w/3.785'No-Go @+/-1,998' d. 4'A", 12.6#,L-80,IBT pup Ignik Sikumi(Hydrate Test Well) Ai Pag r i i :21- e of 7 -11 0 �? Printed:21-Feb-11 Application for Permit I Ignik Sikumi#1 (Hydrate Test Well) Saved:21-Feb-11 e. 4 'h"KBMG GLM w/SOV @+/- 1,981' f. 4 'h", 12.6#,L-80,IBT pup g. 4 'h""DB"Nipple w/3.843"No-Go @ 1,969' h. 4 'h", 12.6#,L-80,IBT pup i. 4 ''A"KBMG-LTS Chemical Injection Mandrel with 3/4"line @ 1,952' j. 4 '/s", 12.6#,L-80,IBT pup k. 4 'h"Camco"DB"Nipple w/3.91 No-Go @ 1,940' 1. 4 'h"tubing with flatpack of 3-3/4"tubes to surface 1) one-3/4"tube for N2/CO2 injection 2) two-3/4"tubes for circulating glycol(temperature control) 24. Terminate 3/4"lines through penetrations at 4 'h"tubing hanger,land same and secure 25. Install BPV and ND BOP and rig up tree and test same. 26. Test tree and secure well,rig down and move off location. tJ egi `f 0 3 fb to 14. Discussion of Mud and Cuttings Disposal and Annular Disposal pp.er.A% Bks. Requirements of 20 AAC 25.005(c)(14) An application fora Permit to Drill music be accompanied by each of the following items,except fon-an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization ander 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 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary Ignik Sikumi(Hydrate Test Well) Page 7 of 7 flnDipoiti Printed:21-Feb-11 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Prudhoe Bay Unit Plan: Ignik Sikumi Ignik Sikumi #1 Plan: Ignik Sikumi #1 (wp01) Standard Proposal Report 17 February, 2011 } a HALLIBURTON II Sperry Drilling Services ORIGINAL HALLIBURTON Project: KuparukRiver Unit Prudhoe Site: Prudhoe WELL DETAILS: Plan:Ignik SikumiBay Unit Ground Level: 50.00 Well: Plan: Ignik Sikumi +N/-S +E/-W Northing Easting Latittude Longitude Slot Sperry Drilling Wellbore: Ignik Sikumi #1 0.00 0.00 5977589.61 584118.73 70°20'55.375 N 149°19'1.563 W Plan: Ignik Sikumi#1 (wp01) REFERENCE INFORMATION Co-ordinate(NIE)Reference:Well Plan:Ignik Sikumi,True North Vertical(TVD)Reference:Plan Ignik @ 81.00ft(Planned Elevation) Measured Depth Reference: Plan Ignik @ 81.00ft(Planned Elevation) Calculation Method:Minimum Curvature -250— --- -- ---- --- - - 0 --- -__--._ __--SHL:1858'FSL,2475'FWL-Sec34-T12N-RIIE Guhik- -Sagaranirktok 250 500 750 DDI = 0.000 -4'1000 .__.— _ CASING DETAILS o _ xl250 MD TVD TVDSS Name Size Hole Size C - 1511.00 1511.00 1430.00 10 3/4" 10-3/4 13-1/2 ATd-Eocene Shale Marker -- - 2044.00 2044.00 1963.00 7 5/8" 7-5/8 9-7/8 1500 10 3/4" r 2856.00 2856.00 2775.00 4 1/2" 4-1/2 9-7/8 -Sagm'mrirktok"I,sand __...-- 1750—Base of Permafrost - - _ _Sagavanirkmk"E"sand I I 7 5/8" F,2000—Sagaeanirk/ok"D"sand L __ __ �2f100 Sagamnrrktok"Upper C"sand ` Sagavanirktok 2250 '.. _-- S,,garanhktok"Lover C"sand 2500--.S.i„aranirktok:73”sand --- - --- --- - 2750 412"---4"-J I 2-856- ------ 3000 BHL @ 2856'MD,2856'TVD:1858'FSL,2475'FWL-Sec34-Tl2N-Rl lE - Ignik Sikumi#1(wp01) 3250 Illi III II1111111II liii dill dill Illi lttt lir ] ll llll 111 dill Illi dill Illi lilt lllt lilt liii Illi -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 Vertical Section at 0.00°(750 ft/in) 50 25 tin - SagavanirktoFd BHL @ 2856'MD,2856'TVD:1858'FSL,2475'FWL-Sec34•T12N-RI IE - y 10 3/4" II�"�`7 _ y . Ignik Sikumi# (wp01) --- _ SHL:1858'FSL,2475'FWL-Sec34-712N-RIIE C-25 T rn - ,t, M Azimuths to True North /\ Magnetic North:17.52° Magnetic Field 50 Strength:5'338.1snT Dip Angle:79.83° Date:5/19/2009 Model:BGGM2007 : : l l 1111 111 11 I l l ] 1111 I I I I I l l i 1111 I I I : I I I I 11 I I I -175 -150 -125 -100 -75 -50 -25 0 25 50 75 100 125 150 175 West(-)/East(+)(50 ft/in) ConocoPhillips ORIGINAL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Ignik Sikumi Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan Ignik @ 81.00ft(Planned Elevation) Project: Kuparuk River Unit MD Reference: Plan Ignik @ 81.00ft(Planned Elevation) Site: Prudhoe Bay Unit North Reference: True Well: Plan:Ignik Sikumi Survey Calculation Method: Minimum Curvature Wellbore: Ignik Sikumi#1 Design: Ignik Sikumi#1 (wp01) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Prudhoe Bay Unit Site Position: Northing: 244.11 ft Latitude: 53°45'36.816 N From: Map Easting: -1,140,020.60ft Longitude: 157°35'11.935 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -6.11 ° Well Plan:Ignik Sikumi,Hydrate Well-Directional Plan from WSak 24 gravel Pad Well Position +N/-S 0.00 ft Northing: 5,977,589.61 ft Latitude: 70°20'55.375 N +El-W 0.00 ft Easting: 584,118.73 ft Longitude: 149°19'1.563 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 50.00 ft Wellbore Ignik Sikumi#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2007 5/19/2009 17.52 79.83 57,338 Design Ignik Sikumi#1(wp01) Audit Notes: Version: Phase: PLAN Tie On Depth: 31.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 31.00 0.00 0.00 0.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 31.00 0.00 0.00 31.00 -50.00 0.00 0.00 0.00 0.00 0.00 0.00 2,206.00 0.00 0.00 2,206.00 2,125.00 0.00 0.00 0.00 0.00 0.00 0.00 2,541.00 0.00 0.00 2,541.00 2,460.00 0.00 0.00 0.00 0.00 0.00 0.00 2,856.00 0.00 0.00 2,856.00 2,775.00 0.00 0.00 0.00 0.00 0.00 0.00 2/17/2011 1:12:34PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLI URTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Ignik Sikumi Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan Ignik @ 81.00ft(Planned Elevation) Project: Kuparuk River Unit MD Reference: Plan Ignik @ 81.008(Planned Elevation) Site: Prudhoe Bay Unit North Reference: True Well: Plan:Ignik Sikumi Survey Calculation Method: Minimum Curvature Wellbore: Ignik Sikumi#1 Design: Ignik Sikumi#1 (wp01) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -50.00 31.00 0.00 0.00 31.00 -50.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 SHL:1858'FSL,2475'FWL-Sec34-T12N-R11E 82.00 0.00 0.00 82.00 1.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Gubik 100.00 0.00 0.00 100.00 19.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 181.00 0.00 0.00 181.00 100.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Sagavanirktok 200.00 0.00 0.00 200.00 119.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 300.00 0.00 0.00 300.00 219.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 400.00 0.00 0.00 400.00 319.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 500.00 0.00 0.00 500.00 419.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 600.00 0.00 0.00 600.00 519.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 700.00 0.00 0.00 700.00 619.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 800.00 0.00 0.00 800.00 719.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 900.00 0.00 0.00 900.00 819.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,000.00 0.00 0.00 1,000.00 919.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,100.00 0.00 0.00 1,100.00 1,019.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,119.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,219.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,319.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,431.00 0.00 0.00 1,431.00 1,350.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Mid-Eocene Shale Marker 1,500.00 0.00 0.00 1,500.00 1,419.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,511.00 0.00 0.00 1,511.00 1,430.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 10 3/4" 1,571.00 0.00 0.00 1,571.00 1,490.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Sagavanirktok"F"sand 1,600.00 0.00 0.00 1,600.00 1,519.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,619.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,781.00 0.00 0.00 1,781.00 1,700.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 IBase of Permafrost 1,800.00 0.00 0.00 1,800.00 1,719.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,819.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 1,901.00 0.00 0.00 1,901.00 1,820.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Sagavanirktok"E"sand 2,000.00 0.00 0.00 2,000.00 1,919.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,044.00 0.00 0.00 2,044.00 1,963.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 7 5/8" 2,046.00 0.00 0.00 2,046.00 1,965.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Sagavanirktok"D"sand 1 2,100.00 0.00 0.00 2,100.00 2,019.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,206.00 0.00 0.00 2,206.00 2,125.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Sagavanirktok"Upper C"sand-Sagavanirktok 2,231.00 0.00 0.00 2,231.00 2,150.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 a "Upper C"PAY 2/17/2011 1:12:34PM 0agg3 COMPASS 2003.16 Build 69 Halliburton -Sperry i l r, v 1,.:. I isi i. iti'', -' 1 ' R :\;., Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Ignik Sikumi Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan Ignik @ 81.00ft(Planned Elevation) Project: Kuparuk River Unit MD Reference: Plan Ignik @ 81.00ft(Planned Elevation) Site: Prudhoe Bay Unit North Reference: True Well: Plan:Ignik Sikumi Survey Calculation Method: Minimum Curvature Wellbore: Ignik Sikumi#1 Design: Ignik Sikumi#1(wp01) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,190.00 2,271.00 0.00 0.00 2,271.00 2,190.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Sagavanirktok"Lower C"sand 2,300.00 0.00 0.00 2,300.00 2,219.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,400.00 0.00 0.00 2,400.00 2,319.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,500.00 0.00 0.00 2,500.00 2,419.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,541.00 0.00 0.00 2,541.00 2,460.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 Sagavanirktok"B"sand 2,600.00 0.00 0.00 2,600.00 2,519.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,700.00 0.00 0.00 2,700.00 2,619.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,800.00 0.00 0.00 2,800.00 2,719.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 2,855.99 0.00 0.00 2,855.99 2,774.99 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 BHL @ 2856'MD,2856'TVD:1858'FSL,2475'FWL-Sec34-T12N-R11 E 2,856.00 0.00 0.00 2,856.00 2,775.00 0.00 0.00 5,977,589.61 584,118.73 0.00 0.00 4 1/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Sagavanirktok 0.00 0.00 2,206.00 5.08 0.69 5,977,594.70 584,119.36 -plan misses target center by 5.13ft at 2206.00ft MD(2206.00 TVD,0.00 N,0.00 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 1,511.00 1,511.00 10 3/4" 10-3/4 13-1/2 2,044.00 2,044.00 7 5/8" 7-5/8 9-7/8 2,856.00 2,856.00 4 1/2" 4-1/2 9-7/8 2/17/2011 1:12.34PM Page 4 COMPASS 2003.16 Build 69 i+ R I G I a ` A 1.... Halliburton -Sperry HALLIBIJRTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Ignik Sikumi Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan Ignik @ 81.00ft(Planned Elevation) Project: Kuparuk River Unit MD Reference: Plan Ignik @ 81.00ft(Planned Elevation) Site: Prudhoe Bay Unit North Reference: True Well: Plan:Ignik Sikumi Survey Calculation Method: Minimum Curvature Wellbore: Ignik Sikumi#1 Design: Ignik Sikumi#1(wp01) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (") (1 2,271.00 2,271.00 Sagavanirktok"Lower C"sand SAND 82.00 82.00 Gubik DIABASIO 2,541.00 2,541.00 Sagavanirktok"B"sand SAND 2,231.00 2,231.00 "Upper C"PAY SAND 2,206.00 2,206.00 Sagavanirktok"Upper C"sand SAND 1,571.00 1,571.00 Sagavanirktok"F"sand SAND 181.00 181.00 Sagavanirktok 1,901.00 1,901.00 Sagavanirktok"E"sand SAND 1,431.00 1,431.00 Mid-Eocene Shale Marker GYPSIFEROUS DOLOMITE 2,046.00 2,046.00 Sagavanirktok"D"sand SAND 1,781.00 1,781.00 Base of Permafrost l _ __ Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 31.00 31.00 0.00 0.00 SHL:1858'FSL,2475'FWL-Sec34-712N-R11 E 2,855.99 2,855.99 0.00 0.00 BHL @ 2856'MD,2856'TVD:1858'FSL,2475'FWL-Sec34-T12N-R11 E 2/17/2011 1:12:34PM 0 rG5i k , L COMPASS 2003.16 Build 69 z 0 E- o� a M ` � L J o Q L L m I N C Nct Q CO a 50 OA N Q-MESE m a t o � t 00 � A w 13. 0 a •• - • U � 0.0 < u,. ,; rA,Aronakw ORIG ! 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T. IIIIIIIIIIIIIIIIIiiiiiiiiiii 11 , 1 T O O O O O h O O O o O h O o O Q EN O r N N N N O (NI Nin = N(u!/ 009)(+)4�oN/( )43noS ORIGINAL • 0 0 0 0 0 • > > > > > p V LC) n V CO • • > 0 o 0 0 N N • • >� J J J J J p • o 0Lo- 0 0 • 4.0Z • 9i J J J J J • " . p W Lri 0 0 0 0 0 /�� O N N Y V/ W J J j J J J COCOMCOMM C : • ' CU a a a a a a ; ' M t— • / •• • • M • • • O 00 r O ii / : 07 co• • • • • • • • O ( , /, '� \\ n ot.10 4/00/ to r-- i ill .1 iligim ;I Y _... .47 :ii • 1 \ en Y 1 C co - \\ • `m to• . _d \ r > �.Y C w \ C O C Y C ,•7; \ \ R 0 tco r 2a� a *k o �m 3 °d� a3 ^ a • If(7) — via'.§1:.'� ' — "." .._. \EyY e>,--:5:- Y X Q U • 2 C z°w O1 C a c c— > c > c ...\ C...-"CM F 0 c V mM.T. O ..1 0 O j T VQ I w ORIGINAL t . I RT N Sperry Drilling Services BP - Alaska Prudhoe Bay (various) Kuparuk River Unit Plan: Ignik Sikumi Ignik Sikumi #1 Ignik Sikumi #1 (wp01) Anticollision Summary Report 01 February, 2011 3bp ORIGiNAL HALLIBURTON Halliburton Company Anticollision Report 0 bp Sperry Drilling Services Company: BP-Alaska Local Co-ordinate Reference: Well Plan:Ignik Sikumi Project: Prudhoe Bay(various) TVD Reference: Plan Ignik @ 81.0ft(Planned Elevation) Reference Site: Kuparuk River Unit MD Reference: Plan Ignik @ 81.0ft(Planned Elevation) Site Error: 0.0ft North Reference: True Reference Well: Plan:Ignik Sikumi Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 3.00 sigma Reference Wellbore Ignik Sikumi#1 Database: .Sperry EDM.16 PRD Reference Design: Ignik Sikumi#1 (wp01) Offset TVD Reference: Offset Datum Reference Ignik Sikumi#1 (wp01) Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.0ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 482.5ft Error Surface: Elliptical Conic Survey Tool Program Date 2/1/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 31.0 2,856.0 Ignik Sikumi#1 (wp01)(Ignik Sikumi#1) MWD+IFR+MS MWD+IFR+Multi Station Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB L Pad L-01 -L-01 -L-01 2,850.7 3,050.0 328.5 52.50 276.3 Pass-Major Risk L-104-L-104-L-104 2,545.6 2,800.0 391.6 50.75 340.9 Pass-Major Risk L-105-L-105-L-105 2,672.2 2,900.0 427.5 51.39 376.2 Pass-Major Risk L-107-L-107-L-107 2,462.1 2,775.0 170.4 53.25 117.3 Pass-Major Risk L-108-L-108-L-108 2,847.0 3,000.0 470.6 49.86 421.8 Pass-Major Risk L-204-L-204-L-204 2,039.0 2,300.0 402.7 42.92 359.8 Pass-Major Risk L-204-L-204L1 -L-204L1 2,039.0 2,300.0 402.7 43.05 359.7 Pass-Major Risk L-204-L-204L2-L-204L2 2,039.0 2,300.0 402.7 42.92 359.8 Pass-Major Risk L-204-L-204L3-L-204L3 2,039.0 2,300.0 402.7 43.06 359.7 Pass-Major Risk / L-204-L-204L4-L-204L4 2,039.0 2,300.0 402.7 43.06 359.7 Pass-Major Risk L-213-L-213-L-213 2,003.6 2,325.0 173.4 45.94 127.4 Pass-Major Risk 2/1/2011 1:28:06PM Pa e 2 of 3 COMPASS 2003.16 Build 71 ORk7NAL HALLIBURTON Halliburton Company Anticollision Report el bp Sperry Drilling Services "t ''' Company: BP-Alaska Local Co-ordinate Reference: Well Plan:Ignik Sikumi Project: Prudhoe Bay(various) TVD Reference: Plan Ignik @ 81.0ft(Planned Elevation) Reference Site: Kuparuk River Unit MD Reference: Plan Ignik @ 81.0ft(Planned Elevation) Site Error: 0.0ft North Reference: True Reference Well: Plan:Ignik Sikumi Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 3.00 sigma Reference Wellbore Ignik Sikumi#1 Database: .Sperry EDM .16 PRD Reference Design: Ignik Sikumi#1 (wp01) Offset TVD Reference: Offset Datum Reference Depths are relative to Plan Ignik @ 81.0ft(Planned Coordinates are relative to:Plan: Ignik Sikumi Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.64° Ladder I , , Plot I I I 600 ' I I I I I I I I I I I I I I I I I I I I I I I J J _ _ __ J_ _ __ __ _ J J _ _ __J __ I I I I I I I I I I I I I I I I I 1 I I I I . w 450 ' 0 I I I I ..) Lf) I I I I :.:,:.i .. 0 I L. I I I I I C I I 1 I I p _ _ ___ J _ _ __J J _ _ _ I 1 I 1I c` I I I I (BI I I I I r)o I ; Q I I I I I (-l) 300 cu I I I I I I I 1 I I I I C I I I 1 I *y as I I I 1 I I V J J -_ __J _ _ __ J_ _ __ _ I1._J_ __ _ _ J _ _ O I I I I I / I I I I I I I w I I I I I I c I I I I I z I co I I I I U I I I I 1 I I I I I I I 1 I I 1 I I I I I I 1 I .. J J J J _ _ __ J_ _1 I I 1 I 1 I I I I I I I I I I I I I I I I I I 0 I 0 500 1000 1500 2000 2500 3000 Measured Depth(500 f/n) LEGEND L-01,L-01.L-01 V14 L-108,L-108,L-108 V18 L-204,L-20 4L3,L-20 4L3 V5 L-104,L-104,L-104 V7 ?4- L-204,L-204,L-204 bB .- - L-204,L-204L4,L-20 4L4 V5 —¢y- L-105,L-105,L-105' --0,-- L-204,L-204L1,L-204L1 V5 - L-2 13,L-2 13,L-213 VI L-107,L-107,L-107V14 -Ei L-20 4,L-20 4L2,L-204L2 V7 --5- ignkSkumik1(wp01) 2/1/2011 1:28:06PM Page 3 of 3 COMPASS 2003.16 Build 71 ORIGINAL Drilling Hazards and Summaries SURFACE SECTION Interval Risks: I. Conductor broaching concerns. Risk potential—(LOW). Monitor continuously during interval. See attachment at end of this well plan for cementing plan if conductor broaching occurs during drilling of surface hole. II. Gas Hydrate Problems—(MODERATE)Minimum mud weight of 10.0-10.2 ppg at base of permafrost at 1,700'TVD. If hydrates observed;control drill,reduce pump rate,reduce drilling fluid temperature,addition of Lecithin. III. Running gravel. Risk potential—(MODERATE). Elevated mud viscosity from spud,high density sweeps. IV. Hole swabbing,tight hole on trips. Risk potential—(LOW). Circulate hole clean prior to trip,proper hole fill(use of trip sheets),pump out of hole as needed PRODUCTION SECTION Interval Risks: I. Gas Hydrate Problems—(MODERATE)Minimum mud weight of 9.0 ppg at base of permafrost at 1,700' TVD. If hydrates become an issue; control drill,reduce pump rate, reduce drilling fluid temperature,addition of Lecithin. II. Running gravel. Risk potential—(LOW). Elevated mud viscosity from spud,high density sweeps. III. Hole swabbing,tight hole on trips. Risk potential—(LOW). Circulate hole clean prior to trip,proper hole fill(use of trip sheets),pump out of hole as needed ORIGIN ! Hydrate Well ConocoPhillips &ravens 4-1/2" Completion String ConocoPhilbps • 16" 164.82# @+/- 110'MD 4 'h" 12.6#L-80 IBT-mod tubing I Two red lines are 3/4"injection lines for circulating hot fluid in annulus. Black background indicates that they are flatpacked with the 3/1"Chemical injection line that goes to the KBMG-LTS 10-3/4" L-80 BTC to :r :;: Mandrel 1,511' MD 4'/z" Camco'DB'Nipple w/3.91"No-Go Profile,IBT mod, j at 1,940'MD(3.875"min ID)-Requires tubing to be special drifted above `'`'• ` 4-1/2"KBMG-LTS Chemical Injection Mandrel with 3/4"line, 65t IBT mod,located 1,952'MD 4 '/z" Camco'DB'Nipple w/3.843"No-Go Profile,IBT mod, .� at-1,969'MD(3.813"min ID) a _ 4-1/2"KBMG GLM with SOV installed, IBT mod,located at iE 7-5/8"29.7# 1,981'MD L-80 BTCM D . - 4 'h" Camco'DB'Nipple w/3.785"No-Go Profile,IBT mod, To 2,008'MD i I ( i at 1,998'MD(3.750"min ID) IIiMMiII4-1/2"x 7 5/8"X-Over(2,008'MD) 7 : 4..,,,,/ Yellow line is DTS Black line is electronic j'? 4 '/z" Pressure and Temperature Gauge,IBT mod,at-2,025'MD 4 '/s" Camco'DB'Nipple w/3.735"No-Go Profile,IBT mod, m 4 at 2,184'MD(3.687"min ID) 1 11- 4 '/z" Pressure and Temperature Gauge,IBT mod,at 2,190'MD 4''/" 12.6# I M 4 %2" Seal bore receptacle with 3.625"polished bore 2,235'MD L-80 IBT-mod Fe- an .:. 4 '/2" Pressure and Temperature Gauge,IBT mod,at 2,257'MD ii='-' -----I 4 '/2" Stab in float collar 2,366'MD(PBTD) iEEMEEEEEEE...:I 3GINi L 2,856'MD ::::::::::::::::-----i �, 9.7e8 -hole I s nik Sikumi #1 H drate Well Schlumberger CemCADE Preliminary Job Design 7 5/8" x 4 '/2" Production Longstring V4 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Nordic 3 Location: North Slope Client: CPAI Revision Date: 02/17/2011 Volume Calculations and Cement Systems Prepared by:Jeff Long Volumes are based on 10% excess. The top of the slurry is designed to be at surface. Location:Anchorage,AK Phone: (907)273-1778 Mobile:(907)223-0093 email:Jlongl©slb.com Slurry Minimum pump time: -210 min. (pump time plus 120 min.) 11.0 ppg DeepCRETE with additives- 1.87 ft3/sk Top of Cement to Surface 0' 0.212 ft3/ft x(1511')= 320.33 ft3 '/ 0.2148 ft3/ft x (2008'-1511')x 1.1 (10% excess)= 117.43 ft3 / 0.4214 ft3/ft x (2856'-2008')x 1.1 (10% excess)= 393.08 ft3 0.08548 ft3/ft x 454' (Shoe track)= 38.79 ft3 320.33 ft3+ 117.43 ft3+ 393.08 ft3 + 38.79 ft3= 870ft3 - IS- `b4'- Previous Csg. 870 ft3/ 1.87 ft3/sk= 465 sks < 10-3/4",51.#casing Round up to 470 sks at 1,511'MD t,700' ase of Permafrost BHST= 56°F, Estimated BHCT= 62°F (CT at TOC 42°F) MD (BHST calculated using a gradient of-2.0°F/100 ft. below the permafrost)dU (BHCT calculated assuming 30°F mud ahead, and 65°F slurry) 41 <--//7 5/8"29.7#casing in 9-7/8"OH PUMP SCHEDULE (.0 at 2,008 MD Stage Cumulative Pump Rate Stage Time Stage (bpm) Volume (min) Time (bbl) (min) MUDPUSH OBM II 5.0 50.0 10.0 10.0 MUDPUSH II 5.0 25.0 5.0 15.0 Line Up Cement 0.0 0.0 5.0 20.0 /1‘ DeepCRETE Slurry 3.0 120.0 40.0 60.0 �. DeepCRETE Slurry 1.0 34.1 34.1 94.1 Drop top Dart 0.0 0.0 5.0 99.1 - MUDPUSH II 1.0 1.0 1.0 100.1 Line up Mud 0.0 0.0 3.0 103.1 I Mud 1.0 10.0 10.0 113.1 I Slow for ECD 0.5 2.9 5.8 118.9 Bump Dart 0.0 0.0 0.0 118.9 < 4.5"12.6#casing in 9-7/8"OH MUD REMOVAL at 2,856'MD Expected Mud Properties:9.0 ppg, Pv< 25, Ty< 15. TD at 2856'MD (2856'TVD) Spacer 1 Properties:9.5 ppg MudPUSH* II, Pv= 20-25, Ty= 25- 35 Spacer 2 Properties: 10.5 ppg MudPUSH* II, Pv= 25-30, Ty= 30-40 Centralizers: As per COP program / Mark of Schlumberger G I L I.nik Sikumi #1 H drate Well Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casin• V1 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Nordic 3 Volume Calculations and Cement Systems Location: North Slope Volumes are based on 250%excess. ,/ Client: CPAI Revision Date: 02/15/2011 The top of the tail slurry is designed to be at-1,310' MD. Prepared by:Jeff Long Location:Anchorage,AK Lead Slurry Minimum pump time: 225 min. (Anticipated pump time, +2hrs.) Phone: (907)273-0093 11.1 ppg ARCTIC LiteCRETE-2.4,E t3/sk Mobile: (907)223-0093 email:Jlong1@slb.com 0.4387 ft3/ft x (110') (no excess)= 48.26 ft3 0.3637 ft3/ft x(1310- 110')x 3.5 (250% excess)= 1527.5 ft3 < TOC at Surface[ 48.26 ft3+ 1527.5 ft3= 1576 ft3 1576 ft3/2.45 ft3/sk= 643 sks Round up to 650 sks Have additional ASL on location for Top Out stage, if necessary. Previous Csg. Tail Slurry Minimum pump time: 157 min. (Anticipated pump time, + 2hrs.) 12.0 ppg DeepCRETE + additives- 1.62 ft3/sk < 16", 164.82#casing j at+/-110'MD 0.3637 ft3/ft x (200)x 3.5 (250% excess) = 254.6 ft3 0.5292 ft3/ft x 80' (Shoe Joint)= 42.34 ft3 254.6 ft3+ 42.34 ft3= 297 ft3 297 ft3/ 1.62 ft3/sk= 183 sks Round up to 190 sks BHST= 31°F, Estimated BHCT= 61°F. (BHST calculated using a gradient of 0.9°F/100 ft. from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume me (bpm) (bbl) (min) (Timin) • MUDPUSH II 5.0 100.0 20.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 < Top of Tail at Arctic LiteCRETE 4.0 281.0 70.3 115.3 1,310'MD DeepCRETE 4.0 53 13.3 128.6 Drop top plug 0.0 0.0 5.0 133.6 Water 5.0 5.0 1.0 134.6 Switch to rig 0.0 0.0 3.0 137.6 Mud 8.0 121.5 15.2 152.8 Slow&bump plug 3.0 5.0 1.7 154.5 < 10-3/4",51#casing MUD REMOVAL in 13-1/2"OH Expected Mud Properties:9.5 ppg, Pv< 25, T„< 20 Spacer Properties: 10.0 ppg MudPUSH* II, Pv 20-25, Ty 30-35 TD at 1,511'MD ( 1,511'(TVD) Centralizers: As per CPAi program. `' Mark of Schlumberger D I G l N L. Zit-oz ? To: Guy Schwartz ft4( �Ll Alaska Oil and Gas Conservation Commission There has been some concern about splitting of the stack once we have run the 4 1/2"X 7 5/8" tapered string to bottom on the Ignik Sikumi#1 (Hydrate test well). The reason for doing this is to access the control cables from the monitoring equipment down hole which will be monitoring the pressures and temperatures during the disassociation process of the hydrates. 1. With the mandrel hanger made up to the 7 5/8"casing and prior to actually landing the casing: a. We thread the two control lines through the penetrations on the hanger b. We will slip swedge lock fittings over those control lines c. The swedge lock fittings will be slid down to the top of the penetration in the hanger and screwed in place d. Both control line fittings will be tested to 5000 psi to ensure a pressure seal 2. Running in with the mandrel hanger: a. The mandrel hanger will then be run into the well and landed in the wellhead b. The lock down screws on the wellhead will be screwed into place which will secure the hanger in place and will also energize the packoff below the hanger. This too will be tested to 5000 psi. The well will then be totally isolated from the surface with the two barriers, one of which is the weighted drilling mud in the well, and the second being the mandrel hanger, packoff and swedge lock fittings isolating the well from surface. Steve Shultz ConocoPhillips Drilling Engineer e T L( r IC J f k L �'�S r re kid J 2(1-017 Guy, I have answers to your questions below: 1) On step 15 you mention splitting the stack in order to thread the pressure/Temp cable and DTS . Can you elaborate on the that as far as barriers ( it appears the drilling mud is the only barrier) , any diagrams of the wellhead hardware/install would be helpful. Are there any other options? You may have to request a variance from our BOP policy. On this well we had the option of running a surface casing or not due to the depths that we were drilling to. The total depth of the well will not encroach upon any major hydrocarbon bearing formations. This well is slated for 2,856' TVD while the upper most hydrocarbon zone would be the Ugnu at 3,728' TVD as depicted below. We will be encountering hydrates which is the prime objective of the well but plan on drilling them with chilled mud and prevent any disassociation to free gas. PBU L-106 Shallow Stratigraphy Con000Phillips 1 H-North This BP Bujak Collett -25: F... appin� Prudhoe (2008) USGS t Bay Mt Elbert 1 Gas -so: T c Hydrates C a S-5 t. T p �9 •,ax S-3 SW •tn 0 Ira Saunv#1 - e 5-2 iC o ccs(SSTVD7 .126C ID: T S_1Eocene 1 Ta 17 F carr.ue,u 1 I I-�- 1 Uno SV5,may F.14 sec T� clT8 u E — I San:17261 „RI � 1;'•, ��0 —4)4.4«s WO I� i I t7' w o 2°'' 11f2—ca7as2.2srz01� T-6 Y C LI ueo NNE Cc T-3lSVt Td PETM 8 6,17 -...'ewr. Laid 1. 1 �- UGd T a.- A Milliell 5:3 II K-1s U 800-10001t Y3 c above C o U C °C0 D 8 1 .� d - UGNU C Ugnu ...veers p —....rw.7wUGNLJ A "..""»"" II • _.. S Masstrichtian —....r N lands NC tX WEST SAK In the past we have drilled deeper surface holes then this and have always used a standard diverter which calls for only a one barrier system and in this case we could have opted to go with just one casing string but do to the fact that we had to run an oil base system to drill the hydrates we were required to protect the fresh water sands with a surface casing. If we could have drilled with a fresh water system, we would have just run one casing which would have meant a one barrier system. 2)Whyis the MASP based on 2206' TVD ?should this be 2856' TVD instead. Doesn't really Y change the pressure much but is that a typo? On all of our MASP calculations we choose the zone of production and in this case it is the upper "C" sand which is estimated at 2206' TVD. 3) Please verify the 7 5/8" X 4'/2" casing and 41/2" tubing/IA will be pressure tested and at what step it would occur... What will be your test pressures ? The procedure right now calls for cementing the 7 5/8"X 4 '/2' casing with the 2 7/8"work string and retainer which will be set at the float collar. Once we have the cement in place we will do the following: 1) POOH with the 2 7/8"tubing 2) Run the USIT 3) RIH with open ended 2 7/8" tubing 4) Close the bag and pressure test the 7 5/8"X 4 '/2" casing string to 3000 psi against the retainer 5) Open the bag and change the well over to brine 6) POOH and LD the 2 7/8" work string 7) Run the 4 'A" upper completion 8) Stab into seals and terminate the three 3/4"tubes in the tubing hanger 9) Land the 4 'A" upper completion 10) Install BPV 11) ND BOPE and NU tree 12) Pressure test tubing side to 3000 psi 13) Maintain pressure on tubing and pressure test IA to 3000 psi 14) Bleed off tubing pressure 15) The gas lift shearout valve will shear at±1500 psi differential 16) Freeze protect system with diesel 4) This question has to do with the future work ... How and where will the well be perforated to access the hydrates zones ( I assume it will be below the bottommost Press/Temp carrier and above the float collar) To me it looks like the only place to perforate is somewhere from 2270- 2350' md. Won't you risk damaging the DTS cable since it is run from the casing shoe and if you shoot higher you will damage the cable for P/T ??? The upper"C" sand is the zone of interest which has a top estimated at±2206' TVD. We will have one guage below it and two above. The area of perforations will be from ±2206' to±2235'. The diagram depicts a PBR at 2,235' which will have a screen with seals installed just prior to perforating for sand control. L-106 'tel-- 4 2 MO t i'(PPe✓ 'I - 4.5-.41 5-.40/' z < LOa1-Gy v` " LSH. 4v _< ' L] » }` v 250e _. .l S0� 3000 We have a unique way of discerning where the wires are at. The clamps (Blast Protectors)we will be using have a build up of metal on the hinge side and that is where the wiring will also be. So when they run the perf guns with a special magnetometer they will see where the metal is situated and therefore where the wires are also. We plan on running five on the 4 '/" casing joint we plan to perforate (each are 6 feet long). The guns themselves will be 0 degree phasing and they then have a motor assembly on the top of the guns that they can actuate and turn the guns in the direction away from the metal to fire the guns. This stuff is fairly new technology. See below 7.10•GAP EETW IN CALCULATED // %/ 11 NNING 0. L 0.NO HOLE WAL 1-0.435.O.D.ROUND STOCK(ACROSS ENURE UNTI) 2-0.433'OD.P7TJNU SUNIS 1-0.436'0.1).ROUND STOCK(ACROSS ENTIRE UNTI / I 4.500•PROOUCTON ARANO 600'CALCULAAEO RUNNING a0. /; •�r., / 9.075'DA OPEN HOLE ASSEMBLY PIN:450473F41R3C \ i 9 1•�1 PROCODrav TAMS 5 N A 9At5'DA OPEN HOLE • /�� \ PROTECTOR IS P45TA:LED ON 4.300'. A� ��4 / m PROIXICTION TUBING \ WM 1 -0.430'0.0.ROUND STOCK(ACROSS \ �\ })� ENTRE UNIT) Il 7-o.AJ'Oa.ENCAPSULATED ONES iiimmi 1 1 / 1 ENRRE:UNT) STOCK(ACROSS (/� GICULAIED RLNNNG 0.O.:S.BB' P.O/001,4 CA .01 EO RLNNNG ROUND STDC1CC 4.19'TO HOLE I.O. •/ `�`�;'� UNR WEIGHT:15.00 LES(EST) /� / ..:"'6",..........T4."".":::,, PRCANNON SERVICES, LTD. ,A..H IlO SNI 1309 PH: (261 408-1506 ATFNO.TEXAS nwt FAR(m1 496-S727 END VIEW OF FILMS. l Daum AT 7 w � / LOY 4500-72F-81P-3C MAK Kt \ „�,,,� B PIN-365 A 30= SAP WEAWf>=N CALCULATEDOS N.v ...rt•-1.391.m 1 s 2 IMA 01/16/11 RUN Nco.aHOLE EwAu Am 41�wLK.Ati.�. ... 1ea**As. Added Metal Wires '' 0 : p din 2.77----------------E-cri_ , , __on- 41.41 ..-a.s.....,.. .A._... ..r..a._ _,r.n...��.n.. .,.. .....��,ArA..s._.o .r.,r.�A.�.m..,.,.r..a........_A,.._._��. I) I II ' _i (72.2) °Yna,...V,Z,1, CANNON SERVICES, LTD. N Olmeak,An U Item PA3 80K¶509 PH: (78I)496-7305 . wr STAIR:IRO.MOS 77487 FM(251)466-5727 -.0 :a ...2110. ...mown .aW n1'�' SIDE HEW OF QTY PART NUMBER DESCRPTICN MATERIAL SPECIFICATION nun we.�m ..�! 4500-72F-81P-3C Nam WWI=Alf..11/*PM 3 11005-435 4.350- LEFT COLLAR ASTM-A-1011 wuNNa C. COMM RAs, ta 3 11010-435 4.350' RIGHT COLLAR ASTM-A-1011 - / B PIN-366 A 1 11004-81-72F 0.430'X 72 CHANNEL. ZERO OFFSET. 3 COLLAR ASTM-A-1011 APRPmn 4141.— _-. _._ 1*"."..:: Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 24, 2011 10:02 AM To: Shultz, Steve (Orbis Engineering, Inc.) Cc: Kanady, Randall B Subject: Ignik Sikumi#1 ( PTD 211-027) Steve, In reviewing the PTD I had a few questions come up. This well is somewhat different than a normal KRU well ... in regards to hardware and it ultimate purpose. 1) On step 15 you mention splitting the stack in order to thread the pressure/Temp cable and DTS . Can you elaborate on the that as far as barriers ( it appears the drilling mud is the only barrier) , any diagrams of the wellhead hardware/ install would be helpful. Are there any other options? You may have to request a variance from our BOP policy. 2) Why is the MASP based on 2206' TVD ? should this be 2856' ND instead. Doesn't really change the pressure much but is that a typo? 3) Please verify the 7 5/8"X 4 1/2" casing and 41/2" tubing/ IA will be pressure tested and at what step it would occur... What will be your test pressures ? 4)This question has to do with the future work ... How and where will the well be perforated to access the hydrates zones ( I assume it will be below the bottommost Press/Temp carrier and above the float collar) To me it looks like the only place to perforate is somewhere from 2270-2350' md. Won't you risk damaging the DTS cable since it is run from the casing shoe and if you shoot higher you will damage the cable for P/T ??? Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 5/23/2011 O 0 O 1 0 Co M O .�. O N ` o O o N- . li. o Ce Q LL U 0 JT, o 4/1 r .ALF--rNe E 2,----- CD E a'in 6\i Cfl C ' 1N. 0 = w CI. Q v Cf E . C O X o Wo L CD0 sii LO CTQ Q O CL O W Co O O O O O O 0 O O O O O "I- C:) O O O O O O 00 O 0 O LO 0 O O O O CO CO CD 1.0 LO LOi a e Ignik Sikumi #1 Fiber Optic Cable and TEC Installation Procedure for Hydrate CO2/Methane Exchange Test Well 1. Run 4.5" x 7-5/8" casing with associated fiber optic turn around sub, and gauge carriers strapping the 2 each 1/4' 'cables/TEC' as per the recommended procedures (Cannon cross coupling clamps, Cannon mid-joint clamps, and centralizers)as per Halliburton/Pinnacle procedures. Assure cable severing equipment is on the rig floor for the unlikely event well control issues arise. 2. Continuously monitor the downhole gauges and a fiber in the fiber optic line for damage or problems during casing running (Halliburton/Pinnacle will have monitoring equipment on pad near rig). Splice kits are available for repair of either line. Onsite COP management will determine if a gauge/cable problem will be addressed. 3. Continue in hole to place the perforation target joint of pipe across the desired hydrate formation as determined by open hole logs. 4. Set the casing slips and rig up to RIH with GR/CCL log to confirm casing depth to formation target depth. Calculate proper casing landing space out based on the correlation GR/CCL log. Add necessary 7-5/8" space out pups and casing hanger. Make up casing hanger mandrel such that the cable ports in the hanger are aligned with the pump in valves on the casing head. Pick up and engage the casing hanger landing joint. 5. After confirming integrity of both % cables, measure -25 feet of each cable, secure then cut the cables free of their spools. Wrap cables around the 7-5/8" casing below the hanger to store - 10' of each cable below the casing hanger. Assure cables are not crossed and are tight around the casing. Secure excess cable with SS straps to prevent damage when landing the casing. 6. Straighten the %4" cables using the Halliburton/Pinnacle supplied cable straightener. _ j, itSO i..,. , . ;7: 0,. .0,,2,„,_ 4 R ifi r . _ r- ` f. t a i9! . . ....,, - If lorli ' 14-111 ft c, 7. Strip the protective coating off- 10 foot of each of the cables using the tool provided by Halliburton/Pinnacle. 8. Feed - 10 foot of each cable up through the swage lock fittings on the bottom of the casing hanger mandrel and tighten the fittings to secure and affect a seal. 1 of 5 2/2/2011 r Ignik Sikumi #1 lit r1 1 k :^"`` ' 9. Slide the seal test tool down each cable and pressure test the hanger/cable seals to 5,000 psi for 5 minutes or as directed by COP rig supervisor and Halliburton/Pinnacle guidelines. to ifiltx // . ft F`F 14/ 2 of 5 2/2/2011 Ignik Sikumi #1 10. Wrap and secure both cables around the belly of the casing hanger mandrel to provide 8' of each cable. Be sure to use supplied bending guide for each cable and assure cables are far enough above the lock down shoulder of the casing hanger to prevent damage to the cables when the lock down pins engage the casing hanger mandrel. N as r•• I Volt, - •M 4 �� - 11. Wrap the cables with supplied 'red tape'. Assure cables do not protrude beyond the casing hanger mandrel seal diameters. 12. Assure 10 lock down pin shrouds are properly installed in the casing hanger spool and the pins are backed out and in proper position for landing the casing hanger mandrel. 13. Run in and land the casing. Turn in lock down screws as per COP and FMC guidelines. 14. Pressure test the casing hanger as per COP and FMC guidelines. 15. Upon completion of a successful pressure test and dead well /no flow verification, drain and split the tubing spool from the top of the casing head. 16. Lift BOP stack and tubing spool, then secure to provide -- 3 feet of work space in the exposed casing hanger mandrel area. 17. Remove center lock down pin on each half of the casing head. (90 degrees from the casing valves. 18. Unwind and straighten IA" lines using the Halliburton/Pinnacle supplied tubing straightener as needed. Re-test the integrity of each cable. 3 of 5 2/2/2011 Ignik Sikumi #1 19. Prepare ends of cable for stabbing through the casing head. Wrap one cable - 270 degrees around the casing hanger mandrel and fish cable through the empty lock down screw port and pull the cable through the port. Repeat the process for the other cable through the other lock down screw port. Assure cables are pulled tight against the casing hanger mandrel in the belly area. • a 4 err ti 41111P-il r B 4 b .11 20. Install FMC termination sleeves over the cables and into their respective lockdown screw ports. Make up and test cable seals and bulkheads as per COP and Halliburton/Pinnacle guidelines. 21. Lower the BOP stack and flange the tubing spool onto the casing head. 22. Pressure test the flange and hanger seals to 5,000 psi for 10 minutes as per COP and FMC guidelines. 4 of 5 2/2/2011 Ignik Sikumi #1 23. Complete the cable terminations in the Pinnacle housings. In case of need for emergency casing setting (stuck pipe or unable to reach TD and COP determines that no additional work will be performed to clean out the hole): The upper bowl of the tubing spool will be used for casing slips and seals. 1. Lift up the casing (if free)to allow wrapping and securing -20 feet of cable around the casing as per step 5 above. 2. If casing is stuck, and COP determines that no additional remediation attempts are in order, set the casing slips in the rotary table and rig up to cement the casing string. 3. Take all measures possible to assure casing is centered up in the wellhead. Cement the casing string, then wash the stack through the casing valves. (Note: Cement job may be designed to leave top of cement some distance down the 10-3/4" rather than all the way to surface. This will allow lateral 7-5/8"casing movement range when setting the casing slips). 4. WOC. Pressure test cement job as per COP requirements. 5. Split the tubing spool from the casing head as per steps 15 and 16 above. 6. Secure and cut cables on floor to provide-20' of cable at tubing head height. Pull cables down through the stack. Wrap - 10' of cable around 7-5/8" casing and secure with SS straps. Manipulate remaining loose cables around the casing and through ports and make up cable seals and test as per steps 17 through 20 above. 7. Lower the BOP stack and flange the tubing spool to the casing head. 8. Break BOP's off the tubing spool, elevate BOP's - 3' and secure. Pull casing into tension to remove floor slips and prepare for installing emergency C-29 slip/seal element. 9. Install C-29 slips with energizable seals in tubing spool as per standard FMC procedures. Slack off casing overpull to set the slips and energize the seals. Turn in lock down screws to secure slips. 10. Cut the 7-5/8" casing and dress the stub as per FMC. 11. Install second tubing spool as per FMC. Pressure test as directed by COP and FMC and continue with preparations for running upper completion. C.G. Blount Version 2 2/02/2011 5 of 5 2/2/2011 Alaska Department of Natur'' —esources Land Administration Systerr Page 1 of,3I Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I find Alaska DNR Case Summary File Type: ADL File Number: 28239 a-o- Printable Case File Summary See Township,Range,Section and Acreage? ® Yes 0 No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28239 _."!lay='_._ Search for Status Plat Updates As of 02/23/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 012N Range: 011E Section: 27 Section Acres:640 Search Plats Meridian: U Township: 012N Range: 011E Section: 28 Section Acres:640 Meridian: U Township: 012N Range: 011E Section: 33 Section Acres:640 Meridian: U Township: 012N Range: 011E Section: 34 Section Acres:640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-17 012N-011E-UM 27,28,33,34 2560.00 04-01-1977**UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA'S PRUDHOE BAY UNIT TRACT 18 OIL RIM AND GAS CAP PARTICIPATING AREAS T. 12 N,R. 11 E., UML4T MERIDIAN,ALASKA SECTION 27:ALL, 640.00 ACRES; SECTION 28:ALL, 640.00 ACRES; http://dnr.aaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=2823... 2/23/2011 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME 76/100 c '/II. '1/ *f PTD# 2/,k� Development Service /Exploratory Strati ra hic Test Non-Conventional Well FIELD: .ier/i,4 3,f)/ POOL: �, �,4#/ 1 V-/-74/4P.,T Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs 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 produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed 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 Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 c0i 0 0 � a co 0 v 3 0 m cn 13 r 3 O j I- 30 a) CA T N ° 1 V N W ' N co o m O`°3' co 0 N 0 co d 3 m CO (o o iu o CD - coo co CO W CO W CO CO W W N N N N N N N N N N _, (O OD J O) (.71A W Ni O i CO OD --..1 0) 01 A CO N —, O CO O) v O) 01 . W N —, O (° OD O) U7 A OD N —, O v D m 0 cn 0 0 M K 0 * 0 co co 0 D D 0 0 0 0 cn o -o D * o -o -o O O cn * * c r- v z 0 3 m m o a o o O O = ° m CO m v°' c m = m (D (D a C m m CD 3• n0i m m m o- 3 fl' 3 m m m ° ° —I —i I v a = 0 3 m _ _ _ (� n r n a v (n F m <n (O C nc> a DJ (° * < < c, c 0 — o CD = II) m 0 0 0 0 — o O N o ° co a, w 5' ? = v m n c , (n = 0 0 n 0 0 0 CD o c' Cl v 3 v v o o a o n°i m m * c co < 0 —I 0) O O (D 7 41 O C) 0 (n A, C) —. N = 7 7 O- O N CD CD N — 3 3 O (U 7 O" CD n 3. N O. N 3 (U �. O y. N n O" O" 0- D) • C) n n n - 0- -1 (D -. N d O ? Q 0 6 CO 0 y .o .O 7 n 3 N o (D N N 'O 3' N (� N �� CD ° N m n = . 'c o o >v v m lv -o ( • s N m' 0 '° 4 m uo 0 0 n> 3 w () (n S 0- OS Cl) 0 7 C E. c _ o CO 3 N fl- (D _ 0 d — (D CD 3 'o �n A j' -.°o c c -° n �. (D D D Q (D a N o r sx C c (/) a a 7 o 0 3 m 3 n (n o o o m 0 0 3 m 0 a a CD co ° °<' = o ° ° C Z ° n> c o o (n o (� i' c ° 0 5.. n - < n m v ° ° 0 n a_ o -a o n o m m m o (n _ b n (� o m v F (-) v n m m m g g v N m o cn St ii • N N m m a 0 _ • ? 0 o o C7 c (o CD o * = o 3 (� n o n c n o o (11 co T 2 m • CL m. 2o 0 0 0 0 = co go m °o n < ° c o < v 3 m ° m = 3 3 D O ''. ........:-.%) O O ry 3 3 o (O o O W (D = p C -° (p' N a •7 N O n = o a. z m f�I (° ,moo (D (n O Q c (n O N Z (i CO 3 = O n co N (n (n D w o �. c a 3 Qo 0 O a C 0C •< o m c m 0 (n D co (p n ZJl * K -o _ o j N N N n < 0 N O N � p .37. * O ca W m o (° 0 01 o v 7 3 7 - o (� a N. - m o (D S c cp. o N m m m a oco ' m to c 3 co (n 0 n Q -o m cr o D o I so n c 7 o c �' c w 7, �'1 0 c c o o x uCD o o d ° N m w a iv aco 0 (n 3 ° o (° . m D ,v m 3 a v Z 5 0 ° co m O Z co° v w o •-Z m ° o 3 N -o o m o n ° O 3 co CD 27 A (7 O (D m 3 .o—.. co v 0 0 0 c iv O v T m co (D -, -< Z Z Z -< Z Z z -< -< -< -< -< -< z -< -< -< -< -< Z -< Z Z Z -< -< -< -< -< Z -< -< -< Z -< -< Z Z m CD D D D CD D o O m CD CD C CD CD D m m m (D (D D C D D D (D (D N W N o N 0 CD O CD 0 D D (n (n (/) (.n (n (I) (I) CO (n (I) (n (n (n co (n (n (Y, fn !n (n p, (n N co m X v 71 K o -0 7j. -1 cn z co o c7 cn N m m CD Cx co D O0 v D cas) cn 0 0 0 = N '� O ° N N N o °' 3 z 6 V 3 (n c (° x CD co l o co a v co o o ((Dn m 3 N (� -° 0 Q 7 (D (n V, 7 N _ O CD N n o- m N m N' rn rn D (° CO m TJ CD 0) m = a D N co m N (n oD X 73 A co( n (D c o CD — COO0 —, `< co 0 m 0to co co CO _. m O co * o- o n 2 �l m _ CO u c 3 co _ o w 0 5 (n c 0 co w m CD o 0 y m y Q m C o a m * co ?. (o w N w o 13 3 co -< ° o' (n (n -0 (D n, c * rn C oo co �' u,' 3 = 3 z_ 0)0 p) -o --o co n o 3 (o 7 (0 H_S -O C 0 co D) 7r °' . m 3cn ' cn co o° • c * * m c, j 2. c � • C m * m _ 3 7 N C N c 3 CD - _ a. ca) 3 N nO n Fri • N O O 7' -0 N co 3 O. ) co 47 co o o O 3 O (o 3 m m o w O u X = m a W 30 v m 0 0 0 rn * 5 (D 0 n c 0 5 D : > > m cr) = = C Co) a, o' 0 0 0 m 7 N p (o N ❑P D 1 Vv`elI History File APPENIEX Information of detailed nature that is not particularly gemmane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplrfy 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 infor nation. .tko6e7 - Sperry-Sun Drilling Services \M- $Revision: LIS Scan Utility L 3 $ LisLib $Revision: 4 $ Thu Apr 21 12:45:24 2011 Reel Header Service name LISTPE Date 11/04/21 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/04/21 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Greater Prudhoe Bay MWD/MAD LOGS WELL NAME: Ignik Sikumi #1 API NUMBER: 50029234430000 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 19-APR-11 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: K-MW-000797084 K-MW-000797084 K-MW-000797084 LOGGING ENGINEER: PATRICK WALK JACK KLEINHA JACK KLEINHA OPERATOR WITNESS: GRANVILLE RI GRANVILLE RI GRANVILLE RI SURFACE LOCATION SECTION: 34 TOWNSHIP: 12N RANGE: 11E FNL: FSL: 1858 FEL: Y1(:;7 FWL: 2475 ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 30.70 GROUND LEVEL: 49.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 109.0 2ND STRING 9.880 10.750 1473.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUNS 100 WAS DIRECTIONAL ONLY, ROP DATA FROM RUN MERGED ONTO THE TOP OF MWD RUN 200. 4 . MWD RUN 200 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) ) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 5. MWD RUN 300 AND 400 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , DRILLSTRING DYNAMICS SENSOR (DDSr) . 6. MWD DATA ARE CONSIDERED PDC AS PER AN E-MAIL DATED 20-APRIL-2011 FROM SANDRA LEMKE (CONOCOPHILLIPS) CITING AUTHORIZATION FROM WAYNE CAMPAIGN (CONOCOPHILLIPS) . 7. MWD RUNS 100 - 400 REPRESENTS WELL REPRESENT WELL IGNIK SIKUMI #1 WITH API #50-029-23443-00. THIS WELL REACHED A TOTAL DEPTH OF 2597 ' MD, 2597 ' TVD. MNEMONIC CURVE DESCRIPTION R09P 9in Phase Resistivity R15P 15in Phase Resistivity R27P 27in Phase Resistivity R39P 39in Phase Resistivity EWXT EWR Formation Exp Time ROPA Avg Rate of Penetration DGRC DGR Combined Gamma Ray APEL ALD LCRB Pe Factor ACDL ALD LCRB Comp Density ADCL ALD LCRB Den Correction TNPS CTN Porosity Sandstone TNFA CTN Far Avg Count Rate TNNA CTN Near Avg Count Rate BTCS BAT Comp Slowness BTSS BAT Comb Shear Slowness BVPS BAT VP/VS Ratio ACHD ACAL Hole Diameter ALRPM ALD RPM PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 13.5" FIXED MUD WEIGHT: 8.8 - 9.2 PPG WHOLE MUD CHLORIDES: 450 - 600 PPM CL FORMATION WATER SALINITY: 6, 000 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1. 1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/21 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 109.5 2597. 0 NPHI 128.0 1371. 5 FCNT 128.0 1371. 5 NCNT 128.0 1371.5 DRHO 146.0 1390.0 CALN 146.0 1390.0 RHOB 146.0 1390. 0 PEF 146.0 1390.0 GR 159.0 2531. 0 RPS 169.5 2541.0 FET 169.5 2541.0 RPD 169.5 2541.0 RPX 169.5 2541.0 RPM 169.5 2541.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 109.5 1482.0 MWD 3 1404 .0 1573.0 MWD 4 1500.0 2597 .0 # $ REMARKS: MERGED MAIN 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 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 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 FET MWD HR 4 1 68 20 6 RPX MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPM MWD OHMM 4 1 68 32 9 RPD MWD OHMM 4 1 68 36 10 ROP MWD FPH 4 1 68 40 11 FCNT MWD CPS 4 1 68 44 12 NCNT MWD CPS 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 GR MWD API 4 1 68 56 15 it First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 109.5 2597 1353.25 4976 109.5 2597 RHOB MWD G/CC 1. 13 2.321 1.80692 2489 146 1390 DRHO MWD G/CC -0. 114 0.375 0.0707529 2489 146 1390 CALN MWD IN 12 24 .56 14 . 5067 2489 146 1390 PEF MWD B/E -0.24 2.82 1.46897 2489 146 1390 FET MWD HR 0.46 88.38 3.32179 4646 169.5 2541 RPX MWD OHMM 0.24 1840.35 41.4556 4646 169.5 2541 RPS MWD OHMM 0. 11 2000 128. 107 4646 169.5 2541 RPM MWD OHMM 0.09 2000 195.036 4646 169.5 2541 RPD MWD OHMM 0.07 2000 307.427 4646 169.5 2541 ROP MWD FPH 0 322. 92 79.343 4976 109.5 2597 FCNT MWD CPS 16.03 31.43 20.5581 2488 128 1371.5 NCNT MWD CPS 4110.24 5296.56 4326 2488 128 1371.5 NPHI MWD PU 33.04 105. 67 60.4399 2488 128 1371.5 GR MWD API 17. 94 110.47 59. 6727 4745 159 2531 First Reading For Entire File 109.5 Last Reading For Entire File 2597 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/21 Maximum Physical Record65535 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 11/04/21 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROPA 109.5 1482. 0 TNFA 128.0 1371. 5 TNNA 128.0 1371.5 TNPS 128.0 1371.5 APEL 146.0 1390.0 ACDL 146.0 1390.0 ADCL 146.0 1390.0 AHSI 146.0 1390.0 DGRC 159.0 1403.5 R15P 169.5 1413.5 R27P 169.5 1413.5 R39P 169.5 1413.5 R09P 169.5 1413.5 EWXT 169.5 1413.5 $ LOG HEADER DATA DATE LOGGED: 11-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88 .2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 1482.0 TOP LOG INTERVAL (FT) : 237 .0 BOTTOM LOG INTERVAL (FT) : 1482.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11557008 EWR4 ELECTROMAG. RESIS. 4 228257 CTN COMP THERMAL NEUTRON 11595736 ALD Azimuthal Litho-Dens 11554891 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : 109.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 330.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 3. 400 74 .0 MUD AT MAX CIRCULATING TERMPERATURE: 2.883 88.5 MUD FILTRATE AT MT: 3.250 68.0 MUD CAKE AT MT: 3.500 59.0 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 units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD020 G/CC 4 1 68 4 2 DRHO MWD020 G/CC 4 1 68 8 3 CALN MWD020 IN 4 1 68 12 4 PEF MWD020 B/E 4 1 68 16 5 GR MWD020 API 4 1 68 20 6 FET MWD020 HR 4 1 68 24 7 RPX MWD020 OHMM 4 1 68 28 8 RPS MWD020 OHMM 4 1 68 32 9 RPM MWD020 OHMM 4 1 68 36 10 RPD MWD020 OHMM 4 1 68 40 11 ROP MWD020 FPH 4 1 68 44 12 FCNT MWD020 CPS 4 1 68 48 13 NCNT MWD020 CPS 4 1 68 52 14 NPHI MWD020 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 109.5 1482 795.75 2746 109.5 1482 RHOB MWD020 G/CC 1. 13 2.321 1.80692 2489 146 1390 DRHO MWD020 G/CC -0. 114 0.375 0.0707529 2489 146 1390 CALN MWD020 IN 12 24 .56 14 . 5067 2489 146 1390 PEF MWD020 B/E -0.24 2.82 1. 46897 2489 146 1390 GR MWD020 API 19.39 93. 6 52.0036 2490 159 1403.5 FET MWD020 HR 0.71 19.08 2.77546 2489 169.5 1413.5 RPX MWD020 OHMM 5.38 64.17 28.2102 2489 169.5 1413.5 RPS MWD020 OHMM 8. 12 201.71 62.3763 2489 169.5 1413.5 RPM MWD020 OHMM 9.51 2000 203. 116 2489 169.5 1413.5 RPD MWD020 OHMM 13.53 2000 405.774 2489 169.5 1413.5 ROP MWD020 FPH 3.24 322. 92 77.4704 2746 109.5 1482 FCNT MWD020 CPS 16.03 31. 43 20.5581 2488 128 1371.5 NCNT MWD020 CPS 4110.24 5296.56 4326 2488 128 1371.5 NPHI MWD020 PU 33.04 105. 67 60. 4399 2488 128 1371.5 First Reading For Entire File 109.5 Last Reading For Entire File 1482 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/21 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/21 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 1404.0 1499.5 RO9P 1463.0 1516.5 R27P 1463.0 1516.5 EWXT 1463.0 1516.5 R15P 1463.0 1516.5 R39P 1463.0 1516.5 ROPA 1482.5 1573.0 LOG HEADER DATA DATE LOGGED: 15-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 1573.0 TOP LOG INTERVAL (FT) : 1482.0 BOTTOM LOG INTERVAL (FT) : 1573.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: .3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 121210 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.880 DRILLER'S CASING DEPTH (FT) : 1473.0 BOREHOLE CONDITIONS MUD TYPE: Diesel Mud Base MUD DENSITY (LB/G) : 8.80 MUD VISCOSITY (S) : 84 . 0 MUD PH: .0 MUD CHLORIDES (PPM) : 120000 FLUID LOSS (C3) : .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 . 0 MUD AT MAX CIRCULATING TERMPERATURE: .000 63. 8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 . 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 units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 FET MWD030 HR 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1404 1573 1488.5 339 1404 1573 GR MWD030 API 33.73 106.55 64 .2553 192 1404 1499.5 FET MWD030 HR 1. 99 88.38 37. 1335 108 1463 1516.5 RPX MWD030 OHMM 0.27 1840.35 227.278 108 1463 1516.5 RPS MWD030 OHMM 0. 11 2000 311.468 108 1463 1516.5 RPM MWD030 OHMM 0.09 2000 377 . 641 108 1463 1516.5 I, RPD MWD030 OHMM 0.07 2000 396. 1 108 1463 1516. 5 ROP MWD030 FPH 2.54 184 . 97 55.0599 182 1482.5 1573 First Reading For Entire File 1404 Last Reading For Entire File 1573 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/21 Maximum Physical Record65535 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 11/04/21 Maximum Physical Record65535 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 1500.0 2531.0 R15P 1517.0 2541.0 R09P 1517.0 2541.0 EWXT 1517.0 2541.0 R39P 1517.0 2541.0 R27P 1517.0 2541.0 ROPA 1573.5 2597.0 LOG HEADER DATA DATE LOGGED: 15-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2597.0 TOP LOG INTERVAL (FT) : 1573.0 BOTTOM LOG INTERVAL (FT) : 2597.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: . 1 MAXIMUM ANGLE: .5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 121210 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.880 DRILLER'S CASING DEPTH (FT) : 1473.0 BOREHOLE CONDITIONS MUD TYPE: Diesel Mud Base MUD DENSITY (LB/G) : 9. 00 MUD VISCOSITY (S) : 97 . 0 MUD PH: .0 MUD CHLORIDES (PPM) : 110000 FLUID LOSS (C3) : . 0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 . 0 MUD AT MAX CIRCULATING TERMPERATURE: .000 53.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 FET MWD040 HR 4 1 68 8 3 I 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 I ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1500 2597 2048.5 2195 1500 2597 GR MWD040 API 17. 94 110.47 68.5027 2063 1500 2531 FET MWD040 HR 0.46 15.09 2.20328 2049 1517 2541 RPX MWD040 OHMM 0.24 775.81 47.751 2049 1517 2541 RPS MWD040 OHMM 0. 15 2000 198.288 2049 1517 2541 RPM MWD040 OHMM 0.31 2000 175.597 2049 1517 I 2541 I RPD MWD040 OHMM 0.21 2000 183.286 2049 1517 2541 ROP MWD040 FPH 0 283. 16 84 .0117 2048 1573.5 2597 First Reading For Entire File 1500 Last Reading For Entire File 2597 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/21 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE I Date 11/04/21 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/04/21 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ill - ag_.7 ConocchiIIi ps Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA Ignik Sikumi #1 A4 .. + �X Provided by: CANRIG DR„ ,.i\(, '1 F-c ii\,„,)(,) I.rt). Approved by: David Schoderbek Compiled by: Daniel Grunwald Steven Pike Distribution: 05/5/2011 Date: 04/16/2011 ConocoPhillips Alaska,Inc. Ignik Sikumi#1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT&CREW 2 1.1 Equipment Summary 2 2 WELL DETAILS 3 2.1 Well Summary 3 2.2 Hole Data 3 2.3 Daily Activity Summary 4 3 GEOLOGICAL DATA 6 3.1 Lithostratigraphy 6 3.2 Mudlog Summary • 7 3.3 Connection Gases 17 3.4 Trip(Wiper)Gases 17 3.5 Gas Peaks&Associated Mud Data 18 3.6 Sampling Program/Sample Dispatch 19 4 PRESSURE/FORMATION STRENGTH DATA 20 4.1 Pore Pressure Gradient Evaluation 20 4.2 Quantitative Methods 20 5 DRILLING DATA 21 5.1 Survey Data 21 5.2 Bit Record 22 5.3 Mud Record Contractor: MI SWACO 23 6 DAILY REPORTS 24 Enclosures: 2"/100' Formation Log MD 2"/100' LWD/Lithology Log MD 2"/100' Drilling Dynamics Log MD 2"/100 Mud Temp In/Out Log MD Mudlog Digital Data CD 1 CANRIG ConocoPhiiiips Alaska.Inc. Ignik Sikumi#1 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Total Comments Downtime QGM Agitator and Gas Trap (mounted in mud return trough) gas Ditch Flame ionization total gas 0 and chromatography. Block Height/Bit depth TOTCO WITS Feed 0 Hook Load/Weight on bit TOTCO WITS Feed 0 Mud Flow In Derived from Pump Rates 0 and Pump Output Mud Flow Out TOTCO WITS Feed 0 Mudlogging unit computer HP Compaq Pentium 4 system (x3: DML, Rigwatch, and 0 Sample Catcher station) Pit Volumes, Pit Gain/Loss TOTCO WITS Feed 0 Pump Pressure TOTCO WITS Feed 0 Pump stroke counters TOTCO WITS Feed 0 Rate of penetration TOTCO WITS Feed 0 RPM TOTCO WITS Feed 0 Data delivered as Torque TOTCO WITS Feed 0 thousands of ft-lbs in integer format Crew Unit Type : Arctic Unit Number : ML056 Years Days Years Days Mudloggers *1 *2 Sample Catchers •1 .2 Technician Days Steven Pike 10 21 Jim Foradas 3 14 Howard Lamp 4 Daniel Grunwald 3 21 Harry Bleys 10 14 Debra Bomar 1 7 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down 2 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 2 WELL DETAILS 2.1 Well Summary Ignik Sikumi#1 is an exploratory well designed to locate gas hydrate-bearing sands as part of a project to test the feasibility of CO2 injection and exchange with methane in the absence of produced water. In order to preserve the permafrost as the well was drilled, the mud was chilled to slightly above the freezing point of water. Well: Ignik Sikumi#1 API Index#: 50-029-23443-00 Twn. 12 N, Rng. 11 E, Field: Prudhoe Bay Surface Co-Ordinates: Sec. 34, Umiat Meridian 1858' FSL, 2475' FWL Borough: North Slope Primary Target Depth: 2,215' MD/2,215'TVD State: Alaska Total Depth: 2,598'MD/2,598'TVD Rig Name/Type: Nordic Calista#3 Arctic Triple Suspension Date: NA Primary Target: C sand, Sagavanirktok Fm. License: 211-027 Spud Date: 04/09/2011 Ground Elevation: 49.0'AMSL Completion Date: (not available)* RT Elevation: 83.6'AMSL Completion Status: 4'/"tubing Secondary Target: None Depth: Classification: Exploration TD Date: 04/16/2011 TD Formation: Sagavanirktok Fm. Days Testing: 4 Days Drilling: 6 *Mudloggers released from wellsite prior to completion run 2.2 Hole Data Maximum Mud Shoe Depth Hole Depth TD Dev. Casing/ LOT Section Formation Weight (zinc) Liner MD TVDSS (ppg) MD TVDSS (ppg) (H) (ft) 13'/" 1,482' -1,399' Sagavap irktok 9.2 0.25 103/4" 1,473' -1390' 12.7 9%" 2,598' -2,515' Saga 9.19 1 0.52 7%"x 4'/" 2,593' -2,510' -1390' Additional Comments: tapered production casing string; 4W production tubing within upper 7%" casing. 3 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 2.3 Daily Activity Summary 04/04/2011 Canrig personnel on site for unit ML056 rig up—rig move in progress. 04/05/2011 Secondary containment and berming under construction prior to moving rig over well. 04/06/2011 Mudlogging unit spotted and supplied with electricity. 04/07/2011 Continued rig up; P/U drill pipe; miscellaneous mudlogging activity—mount gas trap,adjust flow rates in gas detection equipment and calibrate gas detection equipment. 04/08/2011 Continued rig up; stack 103/." casing in pipe shed; P/U HWDP; load spud mud; make up dumb iron BHA for short rathole to accommodate LWD toolstring. 04/09/2011 Continued troubleshooting on TOTCO EDR; RIH with dumb iron and tag up slough in conductor at 108';drill ahead to 239'and POOH; P/U BHA#2 with full LWD tool string and RIH;free gravel in auger; drill ahead to 380'; replace auger belt; drill ahead to 411'; replace auger gear box; miscellaneous mudlogging activity—move gas trap in mud trough to avoid gravel accumulations. 04/10/2011 Finish replacing auger gear box;thaw out kelly hose and test to 2500 psi;drill ahead from 411'to 1089'; miscellaneous mudlogging activity—11 IsoTubes and USGS cans collected. 04/11/2011 Drill ahead from 1089'to 1482';pump a survey,CBU,and monitor the well(no losses);wiper trip to HWDP at 320', RIH to 1482', pump a 10.9 ppg sweep, and monitor well(no losses); short trip to 970', RIH to 1482,CBU; POOH and L/D BHA;miscellaneous mudlogging activity-7 IsoTubes and USGS cans collected. 04/12/2011 R/U casing equipment; RIH with 103/4" casing to 1473 ft; R/D casing equipment; circulate and condition mud;R/U cementing equipment,pressure test lines,and pump cement job,bumping the plug with OBM; R/D cementing equipment. 04/13/2011 Nipple down, clean, and break down diverter; clean pits; nipple up well head and BOPE; test BOP's. 04/14/2011 Finish testing BOP's; P/U BHA#3, RIH and tag cement at 1366';work on top drive;test casing to 3200 psi for 30 min.;drill out cement,float collar,and 20'of new formation to 1502';perform leak- off test to 12.7 ppg EMW; drill ahead to 1527'. 04/15/2011 Drill ahead from 1527'to 1557'; pick up off bottom and circulate to lower mud temperature; drill ahead from 1557'to 1573'; POOH to casing shoe and circulate to lower mud temperature;POOH, L/D BHA, change bit and jets to lower mud temperature; P/U BHA, RIH to 1467', and circulate and condition mud; wash down from 1467'to 1557' and drill ahead to 2220'. 04/16/2011 Circulate bottoms-up at 2220', POOH to the shoe, and circulate to cool mud temperature; RIH to 2210',wash down to 2220', and drill ahead to 2428'; CBU, POOH to the shoe, and circulate to cool mud temperature; RIH to 2410', CBU, drill ahead to TD at 2597', and CBU x4; wiper trip to the shoe; RIH to 2597', CBU x2, and POOH. 04/17/2011 Rig up Schlumberger wireline equipment;perform open-hole e-logging and formation testing runs miscellaneous mudlogging activity—samples manifested and delivered to company man, and sample catchers flown to Anchorage. 4 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 Daily Activity Summary(con't.) 04/18/2011 Continue wireline e-logging; rig down wireline operations and rig up for drill pipe conveyed logging; RIH with drill pipe to 1474'; circulate and condition mud; rig up Schlumberger E-line; correlate and set drill pipe at 2113', and perform mini-frac formation test; correlate and set drill pipe at 2244'. 04/19/2011 Perform mini-frac at 2201' and 2204'; POOH with drill pipe-conveyed formation testing tool to 1505' and remove side entry sub; POOH and UD Schlumberger MDT tool; M/U Schlumberger tool for fluid sampling; RIH with drill pipe-conveyed formation testing tool; correlate and set drill pipe at 2325' and perform sampling procedure—pumps fail; POOH to replace pumps. 04/20/2011 POOH and change pump seat on Schlumberger formation testing tool; RIH with drill pipe conveyed formation testing tool; correlate depth and sample formation fluid. 04/21/2011 Continued downhole fluid sampling; POOH with drill pipe-conveyed sampling tool and rig down Schlumberger E-line equipment; test BOP's. 04/22/2011 Complete BOP testing; P/U cleanout BHA and RIH to TD; circulate bottoms-up and pump a 35 bbl sweep—no significant increase in cuttings; POOH laying down drill pipe. 04/23/2011 Continue to POOH and UD drill pipe; install and test 7%" rams; R/U casing equipment; run 7%"x 4%" casing (still on 4%"casing by midnight). 04/24/2011 Continue to run 7%"x 4%"casing; rig down casing equipment and rig up Schlumberger wireline; log from 2300' to 2000' to locate pip tag; miscellaneous mudlogging activity — rig down mudlogging unit. 5 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops provided by ConocoPhillips Operations Geologist. HORIZON PROGNOSED LWD PICK MD SSTVD MD TVD (ft) (ft) (ft) (ft) Gubik 82' -1' 31' +53' Sagavanirktok 181' -100'(?) 143' -59' Mid-Eocene Shale Marker 1,431' -1,350' 1,473' -1,389' Sagavanirktok "F" sand 1,571' -1,490' 1,572' -1,488' Base of Permafrost 1,781' -1,700' 1,760' -1,676' Sagavanirktok "E" sand 1,901' -1,820' 1,920' -1,836' Sagavanirktok "D" sand 2,046' -1,965' 2,060' -1,976' Sagavanirktok "Upper C" 2,206' -2,125' 2,214' -2,130' sand Sagavanirktok "Upper C" pay 2,231' -2,150' 2,240' -2,156' sand Sagavanirktok "Lower C" 2,271' -2,190' 2,278' -2,194' sand Sagavanirktok "B" sand 2,541' -2,460' (not logged) (not logged) TD 2,831' -2,750' 2,597' -2,513' 6 CANRIG ConOcoPhiilips Alaska.Inc. Ignik Sikumi#1 3.2 Mudlog Summary Gubik Formation (base of conductor)to top of Sagavanirktok Fm. (31' MD to 142' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 728 52 146 7 5 7 The Gubik Formation in this well consists of immature, loose quartz-lithic sand and pebbles with trace woody bits of organics. The sand is poorly sorted and subangular to angular, while pebbles are well rounded and sometimes polished when not chipped. Organics have slight pyrite coatings. Formation gas levels were negligible, although some residual fluid in the mud trough and possum belly contaminated early readings. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Individual sample descriptions are as follows: SAND/CONGLOMERATE(110-240)=Samples consist entirely of loose sand,pebble chips and pebbles up to 2 inches,along with trace amounts of silica cemented sandstone and woody plant remains;the pebbles are rounded with some polished surfaces, and the consist of assorted lithics and chert with lesser quartz; the majority of the lithics are very dark gray and siliceous,while other lithics and the chert are various shades of pale to very pale brown, dark red to reddish brown, and green to blue green; the sand is poorly sorted, with grain sizes ranges from very coarse-to upper fine-grained;grains are angular to subangular with moderate to poor sphericity;the composition of the sand is similar to the pebbles,although with more colored lithics than dark gray ones; woody bits are pyritic. Top of Sagavanirktok Formation to Mid-Eocene Shale Marker(143'to 1,472' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 289 6 95 5 0 2 The upper portion of the Sagavanirktok Formation is characterized by conglomeratic material mixed with loose sand as well as minor clay and scattered woody organics to approximately 1000 feet. At that point, the conglomerates are markedly diminished, and sand and clay content are roughly even. Clays gradually increase to approximately 75%of the formation at the base of this interval. Gas levels are very low. The sand is moderately to poorly sorted higher in the interval and moderately to well sorted in the deeper clayey portion of the interval. It consists of lighter quartz and dark gray siliceous lithics in roughly equal amounts, with slightly more quartz at depth. Quartz grains are subangular to angular while the lithics are subangular to subrounded. Conglomeratic pebbles are dominated by the dark lithics and are rounded to well rounded with polished surfaces. Occasional pyrite coatings on the dark lithics and rare pyrite cementation are visible in the samples. Scattered woody organic bits are often pyritic as well. The clays are medium gray with an amorphous, curd-like habit. Clayey clots are soft but exhibit excellent cohesion and plasticity. 7 CANRIG ConocoPPhillips Alaska.Inc. Ignik Sikumi#1 Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Individual sample descriptions are as follows: SAND/CONGLOMERATE(110-240)=samples consist entirely of loose sand,pebble chips and pebbles up to 2 inches,along with trace amounts of silica cemented sandstone and woody plant remains;the pebbles are rounded with some polished surfaces, and the consist of assorted lithics and chert with lesser quartz; the majority of the lithics are very dark gray and siliceous,while other lithics and the chert are various shades of pale to very pale brown, dark red to reddish brown, and green to blue green; the sand is poorly sorted, with grain sizes ranges from very coarse-to upper fine-grained;grains are angular to subangular with moderate to poor sphericity;the composition of the sand is similar to the pebbles,although with more colored lithics than dark gray ones; woody bits are pyritic. SAND/CONGLOMERATE (250-330) = dark gray, black, grayish black, grayish red, light brown, moderate brown, light gray,white,translucent,clear; predominantly quartz sand matrix;cobble to very coarse to upper fine grain sand; poorly sorted throughout;very well rounded to subrounded with some slightly subangular in places; moderate to high sphericity; some grains appeared to be slightly frosted in places; abundant pyrite crystals throughout; predominantly unconsolidated quartz grain sand with abundant dark colored lithics. SAND/CONGLOMERATE (330 -410) = samples consist of a dark gray slurry composed entirely of loose angular sand and rounded,polished gravel;the sand ranges from lower fine-to lower coarse-grained;pebbles are as large as two inches and grade into very coarse sand grains; pebbles mostly consist of very dark gray lithics with minor pale to dark orange lithics as well as tan to white quartz,chert,and rare sandstone;the sand is composed of quartz and dark gray lithics in roughly equal amounts. CONGLOMERATE/SAND (420-500) = mostly translucent to clear, with some white, light gray, dark gray, black,grayish black,brownish black, medium brown to light brown, light bluish gray and pale yellowish green; quartz grain sand matrix with abundant dark colored lithic fragments throughout;pebble to upper very coarse, with some medium to upper fine;poorly sorted;mostly well rounded quartz sand grains with some subrounded and subangular; moderate to high sphericity;some grains appeared to be slightly frosted in places;abundant secondary pyrite crystals throughout the sample. CONGLOMERATE/SAND (505-590) = clear to translucent, with some white, light gray to dark gray, black, grayish black, light brown to medium dark brown,and brownish gray;predominantly quartz grain sand matrix, with an abundant dark colored lithic fragments; pebble to upper very coarse through lower fine grained sand; poorly sorted; very well rounded to subrounded with some subangular to slightly angular; moderate to high sphericity; abundant secondary pyrite crystallization throughout the sample; some grains appeared to be slightly frosted in places; predominantly loose uncemented quartz sand; no petroleum indicators were observed. SAND(600-680)=predominantly clear to translucent,with some white to light gray with abundant very dark colored lithic fragments; mostly quartz grain matrix throughout; upper fine to coarse,with some very coarse clast size; poorly sorted; very well rounded to very angular with some subrounded to subangular; moderate sphericity; some sand grains appeared to be frosted in places; pyrite crystals and secondary pyrite crystallization abundant throughout the sample; no petroleum indicators were observed. SAND/CONGLOMERATE(680-770)=dark gray to gray,with some grayish black, black,and blackish gray, with translucent, clear, light gray and white, mostly quartz grain sand matrix throughout; large pebble to very coarse and coarse,with some medium and fine grained sand; poorly sorted;well rounded to subrounded with some subangular to very angular; moderate sphericity; abundant pyrite crystals and secondary pyrite crystallization on quartz grains;predominantly loose uncemented quartz sand with abundant dark colored lithic fragments throughout; some quartz grains appeared to be slightly frosted in places; no petroleum indicators 8 CANRIG Conoc Phillips Alaska.Inc. Ignik Sikumi#1 were observed. SAND (770 -900) = samples consist of a dark brownish gray fluid mass of loose sand with scattered one- quarter to half inch clots of light grayish brown clay and rounded pebbles; minor amounts of pyritic woody slivers appear in the bottom half or this interval, grading into shaly lignite with some thin black bituminous laminae; the sand is moderately to well sorted; the bulk of the sand is upper medium-to upper fine-grained, with some coarse-and lower fine-grained sand;the sand is composed of roughly equal amounts of siliceous dark gray lithics and very light gray translucent quartz; trace blue green glauconitic lithics and rare reddish orange lithics;grains are subrounded to subangular,though coarse grains are well rounded,and sphericity is moderate to poor; grains are chipped and abraded, and quartz grains are etched and pitted as well; pyrite coatings are common on organics and occasionally show up on dark lithics. SAND(900-1050)=samples consist of a dark gray fluid mass of loose sand with trace to minor clayey clots, pebbles,and slivers of woody organic material;the sand has a salt and pepper appearance as just over half of it consists of light quartz while the remainder consists of dark siliceous lithics;the sand is moderately to poorly sorted,with grain sizes ranging from fine-to very coarse-grained;the quartz is translucent and very light gray to rarely transparent and colorless, along with scattered light brown to orange grains; the lithics are mostly very dark gray to black,with trace blue green glauconitic lithics;trace amounts of pyrite coat the black lithics and can sometimes be found cementing sand grains together;quartz grains are angular to subrounded,while lithics are subrounded to subangular; coarser grains and pebbles tend to be rounded and polished; quartz grains display both polished and etched surfaces;pebbles are mostly comprised of the dark gray argillite,with lesser lighter chert and rare hard sandstone; the clay clots at the base of the interval are medium gray and exhibit excellent cohesion and plasticity. CLAY/CLAYSTONE(1065-1130)=samples consist of an olive gray fluid mass of clayey clots, loose sand and pea gravel; bulk samples are mushy to pasty, but the clayey curds display excellent cohesion and plasticity; the sand is still a salt and pepper mixture of light quartz and very dark gray lithics with minor blue green glauconite; pyrite is more abundant than in the above sands,to 2 or 3 percent;the gravels still consist of well rounded dark gray lithics with minor quartz and well indurated sandstone. CLAY/CLAYSTONE(1130-1280)=samples consist of an olive gray to grayish brown fluid mass of clayey clots, loose sand and clay in suspension; aggregate samples are pasty and slimy, though the clayey curds exhibit excellent cohesion and plasticity;the clay is extremely pliant,and no structure is apparent;roughly two- thirds of the sand is comprised of translucent very light gray quartz, with the remainder consisting of dark, mostly gray lithics which impart a salt and pepper appearance to the sand; the gray lithics are hard and siliceous,and trace blue green glauconite is also present;the sand is moderately to well sorted, ranging from lower medium- to upper very fine-grained; the quartz is subangular to angular, the lithics are mostly subrounded, and all grains display moderate sphericity on average; quartz grain surfaces are etched and pitted; minor amounts of pyrite are present as crusts on the coarse lithics. SAND (1280 - 1350) = samples consist of a dark olive gray slurry of sand, clayey curds and clay in suspension;the sand is a moderately to well sorted lithic quartz sand with a salt and pepper appearance;the quartz is very light gray while the lithics are mostly very dark gray; the sand is upper medium-to lower fine- grained; grains are subangular to subrounded with moderate sphericity; quartz grains are etched and pitted; minor pyrite occurs as grain coatings and rarely cementing the sand. CLAY(1355-1482) = medium dark gray to light gray with some medium gray and medium bluish gray, and dark gray; pasty to slightly clumpy;very dense to somewhat malleable; irregular fracture;amorphous cuttings habit; predominantly dull to somewhat earthy luster;very clayey texture with some slightly gritty to silty; very thick beds of clay, interbedded with thinning lenses of quartz sand; predominantly the sand consists of white, and clear to translucent, loose uncemented, medium to upper very fine grain quartz sand matrix; no oil indicators were observed. 9 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 Mid-Eocene Shale Marker to"F"sand (1,473'to 1,572' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 247 17 79 4 1 2 The interval of the Sagavanirktok Formation from approximately 1,473 feet MD to 1,572 feet MD is mostly comprised of claystone with laminae of silty shale and thin lenses and/or laminae of sand. Sandy siltstone is abundant at the base of the interval. Gas levels remain very low. The claystones in this section are poorly indurated and medium olive gray when wet,with minor dark grayish brown laminae of silty shale and trace sand. When dry, the claystone is light yellowish gray and brittle to crumbly. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Individual sample descriptions are as follows: CLAYSTONE (1482 - 1580) = Samples consist of 1 to 4 millimeter rounded wedges of medium olive gray claystone with minor finely ground, dark grayish brown flakes of silty shale and trace sand; when dry, the claystone is light yellowish gray and brittle to crumbly;fresh surfaces exhibit an earthy to waxy luster underlain by a smooth texture; microscopic bedding is perceptible, and some cuttings contain shaly laminae. "F" sand to base of Permafrost(1,573'to 1,759' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 201 18 101 16 1 4 The interval of the Sagavanirktok Formation just above the base of the permafrost is comprised of alternating sequences of claystones, siltstones, and sands. Gas levels are still low but very slowly increasing. Sands in this interval consist of well sorted,very fine-grained quartz grading into silt. The typical siltstone in this section is dark grayish brown, poorly indurated and crumbly to pulverulent. Claystones are medium gray and similarly soft and crumbly, though very plastic when wet. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Individual sample descriptions are as follows: SAND (1580-1655) = predominantly clear to translucent with some light gray, white, light brown, moderate brown, medium dark gray, grayish black, and black; mostly quartz grain sand matrix with abundant dark colored lithic fragments throughout; upper very fine to upper fine grain sand; moderate to well sorted; subrounded to rounded with some subangular to very angular; moderate sphericity; thicker beds of sand interbedded with thinning beds of clay/claystone and sandy siltstones;abundant pyrite crystals throughout;no petroleum indicators were observed. 10 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 SAND(1655-1770)=samples consist of a dark brown slurry of loose sand and disaggregated silt with sand- sized cuttings of siltstone; the sand is moderately sorted; though grain sizes range from lower very fine-to lower coarse-grained, the bulk of the sand is upper to lowermost very fine-grained and grades into silt; the sand and silt are almost entirely comprised of very light gray to pale yellow translucent quartz,along with trace to minor amounts of siliceous black lithics and rare pyrite;grains are subrounded to angular with moderate to poor sphericity,and grain surfaces are etched and pitted;samples are largely non-calcareous;intact siltstone cuttings are rounded and amorphous;fresh surfaces are dark brownish gray and display a waxy to resinous luster underlain by a silty texture; very thin bedding is faintly perceptible. Base of Permafrost to "E" sand (1,760'to 1,919' MD) Drill Rate(ft/hr) _ Total Gas(units Maximum Minimum Average Maximum Minimum Average 451 50 145 1471 7 254 The interval of the Sagavanirktok Formation immediately beneath the permafrost is comprised of unconsolidated sand interbedded with and grading into lesser amounts of poorly indurated siltstone. Gas levels continue to slowly rise but are still modest through the upper 100 feet of the interval; in the bottom third of the interval, gas levels rise two orders of magnitude to well 1000 units. The sands in this interval are well sorted, very fine-grained quartz sands with minor lithics. The siltstone is dark grayish brown, poorly indurated, and crumbly to pulverulent. Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 1895' 1488 292737 - - - - - - Individual sample descriptions are as follows: SAND (1770 - 1880) = samples consist of a dark brown slurry of slightly varying amounts of loose, disaggregated silt and sand with scattered small siltstone cuttings; bulk samples exhibit good to fair cohesion and negligible plasticity; when dry the material is pale brown; the sandy lenses and laminae are mostly moderately to well sorted with grain sizes mostly within the range of lower fine-to lowermost very fine-grained, grading into silt; less well sorted laminae contain minor upper fine-to lower coarse-grained sand;the sand and silt are largely composed of very light gray to pale yellow quartz;trace to minor black lithics tend to occur in the coarser fraction of the sand;intact siltstone is microscopic and subtly decreases with depth as gas levels rise. SAND(1880-1990)=samples consist of a dark brown slurry of loose sand with subordinate disaggregated silt and rare intact siltstone cuttings;the aggregate material exhibits poor cohesion and no plasticity;the sand is well sorted;the vast majority of the sand is upper very fine-grained, grading down through lower very fine- grained to silt-sized particles;the sand and silt is almost entirely composed of very light gray to pale yellowish gray translucent quartz; minor black siliceous lithics, trace orange quartz, and rare pyrite and blue green glauconitic lithics are also present; grains are subrounded to angular, and quartz grain surfaces are etched and pitted; very rare siltstone cuttings are very soft and crumbly, with a waxy to earthy luster and a smooth, silty texture; the sands are highly charged with gas hydrates. 11 CANRIG ConocoPhiiiips Alaska,Inc. Ignik Sikumi#1 "E"sand to "D"sand (1,920'to 2,059' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 281 37 127 1708 301 816 The interval of the Sagavanirktok formation from approximately 1,920 feet MD to 2,059 feet MD is comprised of unconsolidated silty sand with subordinate interbedded siltstone. Gas levels are very high,with background levels between 300 units to 700 units, and peaks above 1500 units. The lithologies in this interval are nearly identical to those in the prior interval. Sands are well sorted, very fine-grained quartz sands grading into silt, and siltstones are dark grayish brown and poorly indurated. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 1978' 1708 352215 - - - - - - 2032' 833 146777 - - - - - - Individual sample descriptions are as follows: SAND(1880-1990)=samples consist of a dark brown slurry of loose sand with subordinate disaggregated silt and rare intact siltstone cuttings;the aggregate material exhibits poor cohesion and no plasticity;the sand is well sorted; the vast majority of the sand is upper very fine-grained, grading down through lower very fine- grained to silt-sized particles;the sand and silt is almost entirely composed of very light gray to pale yellowish gray translucent quartz; minor black siliceous lithics, trace orange quartz, and rare pyrite and blue green glauconitic lithics are also present; grains are subrounded to angular, and quartz grain surfaces are etched and pitted; very rare siltstone cuttings are very soft and crumbly,with a waxy to earthy luster and a smooth, silty texture; the sands are highly charged with gas hydrates. SAND(1990-2120)=samples consist of a dark brown slurry of loose sand with lesser disaggregated silt and sparse sand-sized siltstone cuttings; the bulk samples exhibit poor cohesion and no plasticity; samples are light yellowish gray and pulverulent when dry; the sand is a well sorted, very fine-grained quartz sand that grades into silt; aside from quartz, only traces of black and orange lithics can be seen in the sand;the black lithics are also sometimes visible within the rare intact siltstone cuttings;grains are subangular to angular with moderate sphericity on average; quartz grains surfaces are etched and pitted;fresh surfaces of the siltstone are dark grayish brown with a dull, waxy luster underlain by a smooth, silty texture; very thin bedding is perceptible; samples are non-calcareous; the sands are highly charged with gas hydrates. 12 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 "D"sand to "Upper C"sand (2,060'to 2,214' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 231 41 102 2360 301 1067 This interval of the Sagavanirktok formation from approximately 2,060 feet MD to 2,214 feet MD is comprised of interbedded unconsolidated sand and poorly indurated siltstone. The upper half of the interval is sand-rich, while the lower half has slightly more siltstone than sand. Gas levels are extremely high and correspond with sand content. In the sandy upper half,gas plateaus at over 2000 units; in the silty lower half,background gas levels range from roughly 200 units to 400 units. Lithologies continue to be similar to those in the intervals immediately above. Sands in this section are well sorted and consist of very fine-grained quartz which grades into silt. The siltstones are gray and crumbly to crunchy. Peaks Depth . TG Cl C2 C3 iC4 nC4 iC5 nC5 2091' 2360 489432 - - - - - - Individual sample descriptions are as follows: SAND(1990-2120)=samples consist of a dark brown slurry of loose sand with lesser disaggregated silt and sparse sand-sized siltstone cuttings; the bulk samples exhibit poor cohesion and no plasticity; samples are light yellowish gray and pulverulent when dry; the sand is a well sorted, very fine-grained quartz sand that grades into silt; aside from quartz, only traces of black and orange lithics can be seen in the sand;the black lithics are also sometimes visible within the rare intact siltstone cuttings;grains are subangular to angular with moderate sphericity on average; quartz grains surfaces are etched and pitted;fresh surfaces of the siltstone are dark grayish brown with a dull, waxy luster underlain by a smooth, silty texture; very thin bedding is perceptible; samples are non-calcareous; the sands are highly charged with gas hydrates. SAND/SILTSTONE (2120 - 2220) = samples consist of a dark brown slurry of loose sand and silt with scattered tiny, intact cuttings of siltstone; siltstone content increases with depth; the lenses and laminae of sand are well sorted and very fine-grained, grading into the siltstone; bulk samples exhibit moderate to poor cohesion and no plasticity;the sand and silt are predominantly composed of very light gray to yellowish gray quartz with minor black lithics; grains are subangular with moderate sphericity on average, and quartz grain surfaces are etched and pitted; the siltstone is soft and crumbly,with a waxy luster and a smooth texture. 13 CANRIG ConocoPhillips Alaska.Inc. Ignik Sikumi#1 "Upper C"sand to"Upper C" Pay sand (2,215'to 2,239' MD) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum _ Minimum Average 220 60 107 746 137 423 The short interval of the Sagavanirktok Formation from approximately 2,215 feet MD to 2,239 feet MD is comprised of siltstone with sandy lenses and laminae. Gas levels are somewhat high,but are affected on the log by uneven circulation while pulling back to the shoe to circulate and cool the mud. The sands in this interval continue to consist of well sorted, very fine-grained quartz that grades to silt. Siltstones also remain similar to the soft, gray siltstones drilled through thus far. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 2239 746 124017 • - 2223 737 122648 - - - - - - Individual sample descriptions are as follows: SAND/SILTSTONE (2120 - 2220) = samples consist of a dark brown slurry of loose sand and silt with scattered tiny, intact cuttings of siltstone; siltstone content increases with depth; the lenses and laminae of sand are well sorted and very fine-grained, grading into the siltstone; bulk samples exhibit moderate to poor cohesion and no plasticity;the sand and silt are predominantly composed of very light gray to yellowish gray quartz with minor black lithics; grains are subangular with moderate sphericity on average, and quartz grain surfaces are etched and pitted; the siltstone is soft and crumbly, with a waxy luster and a smooth texture. SILTSTONE(2230-2320)=medium dark gray to gray with some light gray and grayish black; slightly stiff to mostly clumpy; very crumbly to crunchy with some slightly brittle in places; mostly amorphous cuttings habit with some slightly platy; greasy to somewhat resinous luster with some slightly dull; predominantly silty with some very gritty; thinner beds of siltstones interbedded with thicker beds of sand; the sand consists predominantly of translucent to clear, very fine to fine grained quartz sand; the sand is mostly loose grain, uncemented throughout; some pyrite crystals throughout; no visible petroleum indicators were observed. "Upper C" Pay sand to"Lower C"sand (2,240'to 2,279' MD) Drill Rate(ft/hr) _ Total Gas(units Maximum Minimum Average Maximum Minimum Average 161 59 108 2101 743 1501 The pay section of the"upper C"sand consists of loose sand and poorly indurated siltstone in roughly equal amounts. Gas levels once again plateau above 2000 units. The sands in this interval are very fine to fine and predominantly consist of quartz, with only minor to trace lithics. The siltstone is medium to dark gray and crumbly to crunchy. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 2276 2101 222709 - - - - - 2253 1569 260594 - - - - - - Individual sample descriptions are as follows: 14 CANRIG ConocoPPhillips Alaska.Inc. Ignik Sikumi#1 SILTSTONE(2230-2320)=medium dark gray to gray with some light gray and grayish black; slightly stiff to mostly clumpy; very crumbly to crunchy with some slightly brittle in places; mostly amorphous cuttings habit with some slightly platy; greasy to somewhat resinous luster with some slightly dull; predominantly silty with some very gritty; thinner beds of siltstones interbedded with thicker beds of sand; the sand consists predominantly of translucent to clear, very fine to fine grained quartz sand; the sand is mostly loose grain, uncemented throughout; some pyrite crystals throughout; no visible petroleum indicators were observed. "Lower C"sand to Total Depth (2,280'to 2,598' MD) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 690 30 136 2102 57 488 The interval of the Sagavanirktok Formation from approximately 2,280 feet MD to the total depth of the well is comprised of alternating sequences of claystones,siltstones,and thinning lenses of sands. The upper portion of this interval contains small pebbles and a slight amount of claystone, and while the sands decrease with depth, the claystone becomes more abundant. Gas levels range from over 2000 units in the upper sandy portion of this interval to background levels slightly over 100 units at total depth. The Sagavanirktok"B"sand was not drilled into. The sands in this interval are moderately to poorly sorted,with grains ranging from small pebbles and pebble chips to very fine sand. Finer sand tends to consist of quartz while coarser grains contain slightly more dark lithics,and the pebbles mostly consist of dark lithics. The siltstone is dark gray,though slightly more indurated than those seen thus far in the well, with some slightly blocky and platy cuttings present. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 2283 2102 222766 - - - - - - 2340 1577 156951 - - - - - - 2583 444 85845 - - - - - - Individual sample descriptions are as follows: SILTSTONE(2230-2320)=medium dark gray to gray with some light gray and grayish black; slightly stiff to mostly clumpy; very crumbly to crunchy with some slightly brittle in places; mostly amorphous cuttings habit with some slightly platy; greasy to somewhat resinous luster with some slightly dull; predominantly silty with some very gritty; thinner beds of siltstones interbedded with thicker beds of sand; the sand consists predominantly of translucent to clear, very fine to fine grained quartz sand; the sand is mostly loose grain, uncemented throughout; some pyrite crystals throughout; no visible petroleum indicators were observed. SAND (2325-2410) = predominantly clear to translucent, with some white, light gray to medium gray, and some dark gray to black; mostly quartz grain sand matrix with abundant dark colored lithic fragments thought the sample; upper very fine to lower medium grain sand with some coarse to very coarse and small pebble; poorly sorted;very well rounded to subrounded with some subangular to angular;moderate sphericity;thicker sand lenses interbedded with sandy siltstones and sandy to somewhat silty claystones;some pyrite crystals; no visible petroleum hydrocarbon indicators were observed. SILTSTONE (2430-2530) = dark gray to medium dark gray, with some light gray and medium light gray; mostly clumpy to somewhat pasty, with some slightly stiff in places; mostly brittle with some crumbly to crunchy; irregular fracture with some slightly blocky; predominantly amorphous cuttings habit with some very slightly platy;very earthy to somewhat dull with some waxy to greasy in places;predominantly silty texture with some very gritty;thicker siltstone beds,interbedded with thinning lenses of loose uncemented quartz sand;the 15 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi#1 sand consists of very fine to medium grained, fair to poorly sorted quartz sand matrix, with abundant dark colored lithic fragments. SAND (2525-2570) = translucent to clear; quartz grain sand matrix; very fine to medium grain sand; moderately sorted; well rounded to subrounded and subangular; moderate sphericity; mostly loose uncemented sand, interbedded with thicker beds of sandy siltstones and sandy claystones; no visible petroleum indicators were observed. 16 CANRIG Conoc Phillips Alaska.Inc. Ignik Sikumi#1 3.3 Connection Gases 1 unit=0.05% Methane Equivalent Depth Gas over BGG (feet) (units) (No connection gases were observed.) 3.4 Trip(Wiper)Gases 1 unit=0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) 2220' MD/2220'TVD 1453' (casing shoe) 734u 41/s hours 2428' MD/2428'TVD 1434' (casing shoe) 412u 4 hours 2598' MD/2598'TVD 1460' (casing shoe) 302u 2%hours 1505' MD/1505'TVD surface 49u 38 hours 2598' MD/2598'TVD surface 275u 140 hours 17 CANRIG tit. ELS I) ° +- C) C) CO M N- 70 2 c5 N- co co N- m (b CC) M c0 co CC) O ti (t) Co 6 N N 3 co o 3 o U, • - 0) CnCn a c •E -a a -0 CD Co "0 t• ) 2 N CO N N:<a 3 N r� rn 0 (p 6 6 s 0) CO CO 0) Ln K L p E •- ao co co 0 a) Y C ca "if) a0 CO cd a0 Ctfre Y Q •- CC) O C N C V a. i I I I i I i i I i i a) E C 0. g V O O C • Y to E Co 2 V Q a . I I i I I i i i I i E 2 La 3 " E 4) U a . , i . . . , . . . C, O C a CO _ E U a I i I I i I i I i i i CO • o a C N S. 0 ao c, E CT V 1 I 1 I I I I 1 1 1 1 -a E c a. m d •- 2 o-a O• 0 c4 Q i i i i i i o OC t V a co13 U .13: O p N- Cr) N- N CA N- 'Cr CO C4 6 N 4- N- N- CO V' c- 0) 0 CD U') N "a e- E CO N N 'V CD O L() N- N- 0) CO Q Co 3 • 0 O- a) N Co a) N Nr O N N CD Co E a co U) co N N a) N N U7 cc 0,5 a N CO e- e- r- N NN e- Y 7 O co > +�' 7 7 7 7 7 7 a C) O C Co N 2, — (70 a O a a a) — N N N H 0 co CO cov. O O Lj CD(a o O ,— ,— N N N L a) (,) -2 l6 O7 CO N e- C") 0) C") t0 iv O M Lo O O p 0) ti C) 0) N C) (f) Is CO 'V CO t CO 0) 0 0 N N N N N M Cf) M c a - e- N N N N N NNNN d0 0) Cb N :- M 0) c) CD Cl O in0 20) ti ) 0) N M () h CCO V• CO CO CO 0 0 N N N N N M N e- e- N N N N N N N N N ConocoPhillips Alaska,Inc. Ignik Sikumi#1 3.6 Sampling Program/Sample Dispatch Washed and dried samples are contained within plastic vials stored within folding trays,and wet samples are in plastic Whirlpak®bags. Gas samples are contained in IsoTubes®, and headspace samples were put in paint cans supplied by the U.S. Geological Survey. All were packaged and affixed with address labels, at which point they were turned over to a ConocoPhillips' representative for delivery. Set Type/Purpose Frequency Interval Dispatched to Washed, screened, 30' 110'— 1,990' CPAI,ABV 100 rinsed and dried Bayview Warehouse A reference samples 15' 1,990'— 2,080' 619 E. Ship Creek Ave. Anchorage,AK 99501 Set owner: CPAI 30' 2,080'— 2,598' Attn: Dan Przywojski (907)263-4859 Washed, screened, 30' 110'— 1,990' CPAI,ABV 100 rinsed and dried Bayview Warehouse B reference samples 15' 1,990'— 2,080' 619 E. Ship Creek Ave., Suite 102 Anchorage,AK 99501 Set owner: CPAI 30' 2,080'— 2,598' Attn: Dan Przywojski (907)263-4859 Unwashed samples 30' 110'— 1,990' Halliburton Energy Services in Whirlpak®bags 6900 Arctic Boulevard C 15' 1,990'— 2,080' Anchorage,AK 99518 Set owner: CPAI Attn: Robert Haverfield 30' 2,080'— 2,598' (907)273-3559 Unwashed samples 30' 110'— 1,990' Halliburton Energy Services in Whirlpak®bags 6900 Arctic Boulevard D 15' 1,990'— 2,080' Anchorage,AK 99518 Set owner: CPAI Attn: Robert Haverfield 30' 2,080'— 2,598' (907)273-3559 Unwashed samples U.S. Geological Survey in cans 60' 110'— 1,482' 345 Middlefield Road, MS 999 E Menlo Park, California 94205 Set owner: USGS 30' 1,482'— 2,590' Attn: Tom Lorenson (650) 329-4186 Gas samples 60' 170'— 1,480' Isotech Laborites, Inc. in IsoTubes® 1308 Parkland Court F 30' 1,480'— 2,590' Champaign, IL 61821 Set owner: CPAI Attn: Steve Pelphrey (and at selected (217) 398-3490 gas peaks) Sample frequency was locally altered according to drill rate constraints and zones of interest. 19 CANRIG u) a) -a ECU c) w u) N 0 N U X ami � o m '- c ct' 2 2 2 2 2 2 2 a) co -a • 1— :,:, O O O O O O O co �° a`°i S c m m m m m m m o = ° ai a E c O > rn - rn - a) c O a� (a _a ._ w w �j IA 0 ami 'o Z Z Z Z = < iQ Z ii W (j = E uu) W w w w 0 w 0 w w a N D 2 H W w W W U 75 V W V C u) L a N W Z Z ti a) a a) C -a o)a ten J O Q d co a) i- y O I- 0_ a (n C a) C C -O co CO y U N .O V U N 0 ao d x a co N co co rn a) co •ia � 3 O - E g a co' O) co co ao ao co E c y c D o ° a E co co w i O O 4) a) .- u) a m .U � c mw rn w c 0) co N co co a) co co O N cc) 3 w c a) L a w of o0 0o co co cd U 0 c 0 M co CD rn 7 V' W � o v o ___ U o'= N N o Co ai as ; rn o o N a) (0 (0 (0 r M O o 0 C 73 u! a) 6 w uj as ; ter L() co (0 W a)) - L) v) 2 � O C C QO Z N r r r r N N �� ° a) a 3 r � � N L �c w -C ''-=' C O C xt Eco N o. o U ai NCO a � moo . L a) H D .-. M co (0 N co r a) C -a• E o N O 41) N 1, Y N CO- >H $ r _ 1- N- N N LO N N E _ ° E a) N J N Z °C o � w a� IX c • c G a r f0 "'' CD W N O O G c a 5 m � U m � 2 0 Cl- U) Q 8. O a) CU �„) C Y co O O O - u) E a N 4) no ti (0 N CD r O 2010 a) E O p N m a 0 " r N- I- 0 N LO 73 N C N cm 0 7 uJ O 4- a� La N 3 N I- L 2 U C 0 3 O t O a 0 -- ai s c aO _ •3 I ( ° mcc � c O OCca co N ~ N 0 CO V) 0 U7 a) U fn N O a • O (O Cr) a r a) a) Z N c O c o o co U) (n o(0 I1 3 __ (p O O C U W O C) r_ v p o 0 0 o O o Oo - CCS Lw 0 ._ N re 0- C OJ M O � 1 M � 0 C � ; a) I- O 0 N co N N c) - 0 (p Y = ". U) Y Tu C N - t N Z C 3 U > ca O - c I c N CO o • \ CU 17 2 a)W O ( N W Q O CCU O .-. MJ J u) J y> a. "a 4 ._ m a) ` , o o N CNd E = v\ U U oo o ' cu u) OQaa � o) o O O m uU mm0 _ - O N LJ C) ai = a II N° - Q" U LLm v y d 8 6 w c N TO E Ca O ` d a N ,-..ti U 0 j N m yNC M o L C O CU .° a N aO co aCjn NoL(I) w -c 10 a c •_ w 9N N m is CvcCn a.' , Ecaid °fccaai W c O ° m CO o a ° Eo °' w UUi . CO Ea0 ON � � ti N tdCU - a N N t et m v ot m z v I- .c < mH ua I- N Conoco hiiiips Alaska.Inc. Ignik Sikumi#1 5 DRILLING DATA 5.1 Survey Data Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth ° ° Vertical Section Rate (ft) ( ) ( ) Depth (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 (tie-in) 30.70 0.00 0.00 30.70 0.00 0.00 0.00 0.00 74.92 0.06 85.56 74.92 0.00 0.02 0.00 0.14 169.57 0.04 85.56 169.57 0.01 0.11 0.021 0.02 258.80 0.13 163.22 258.80 0.09 0.17 -0.09 0.14 353.36 0.02 117.52 353.36 0.20 0.21 -0.20 0.12 447.81 0.19 167.52 447.81 0.36 0.26 -0.36 0.19 541.39 0.30 162.95 541.39 0.74 0.37 -0.74 0.12 634.95 0.19 152.23 634.95 1.11 0.51 -1.11 0.13 729.27 0.28 151.60 729.27 1.46 0.69 -1.46 0.10 821.73 0.36 148.69 821.73 1.90 0.95 -1.90 0.09 915.30 0.36 130.53 915.29 2.34 1.33 -2.34 0.12 1009.37 0.45 138.12 1009.36 2.81 1.80 -2.81 0.11 1103.12 0.48 129.04 1103.11 3.33 2.35 -3.33 0.08 1196.94 0.41 131.21 1196.93 3.80 2.91 -3.80 0.08 1291.21 0.35 134.04 1291.19 4.22 3.37 -4.22 0.07 1385.74 0.33 158.54 1385.72 4.68 3.67 -4.68 0.15 1421.28 0.25 134.71 1421.26 4.83 3.77 -4.83 0.40 1514.34 0.31 145.84 1514.32 5.18 4.05 -5.18 0.09 1607.64 0.32 144.97 1607.62 5.61 4.35 -5.61 0.01 1700.81 0.26 160.64 1700.79 6.03 4.57 -6.03 0.11 1794.72 0.26 148.18 1794.70 6.41 4.75 -6.41 0.06 1890.54 0.09 171.16 1890.52 6.66 4.88 -6.66 0.19 1984.53 0.25 182.92 1984.51 6.94 4.88 -6.94 0.18 2078.80 0.32 181.75 2078.77 7.41 4.86 -7.41 0.07 2169.71 0.35 194.83 2169.69 7.94 4.78 -7.94 0.09 2266.43 0.44 210.71 2266.40 8.55 4.51 -8.55 0.15 2363.24 0.45 227.55 2363.21 9.13 4.04 -9.13 0.14 2457.01 0.53 228.08 2456.97 9.67 3.44 -9.67 0.09 2550.39 0.52 218.59 2550.35 10.29 2.85 -10.29 0.09 21 CANRIG 4t 47t N I a x z x z= m m m m CO N N a 17 0 0 m17 O U ate) Z L' ,a 1 = CO (a r r r `o) W W W O 6 U N N r r N r > - U) •v cco Lo o Qa a v .- O N r N r dco r d) N- Q � ti CO U ' 1 0 -0 Cr N- O r-- < Q Y cNi CD N- ori L Q cc r CA Ocri m m r r r r S- E 1 rJ CO p 0 Y ��+ Fe M CA N8 C O O CA coO Q F- O r ` r LL. £ 0 O C") CONN- r a- N O.0 O MN M 02 N co v in r r OcD ti OCD N SCD O OM O 15 LL. X X�'- N X�r' X XII NX�O F" M r •r M r r r C`') O M- r7, rU) + M C� N y aLJN JN X a) XCe L7)V) rVfn I- U) 273 2L d Xa C C N a) a m m ami p Y .E 'E � CD my rC = t = C cn u) 0 0 m . _W N N M M [Si U) r r O O) I r ++ r N CO m W H y M p � In 0 co r- 00 N- N N (.) . , sr In i . () I._ l. et . , , co • 1 OO OD W ,., 0) 0) W 4., 6 Oi 0 0 0 0 as co I6 OO N (OM ts dtf- O O 00 E rl,.) NNNO COt U N N tf Tr Tr N - LI) In In O to T In In ri N J N C a) U) CD U) 0 0 U o Y Y Y Y Y Y Y Y Y Y 0 V Tr Tr OOOO V 0000000000 p) C U) y (n c6 Tr 6 — C 7 Y U T_ Q O O O r 0 0 N r O 0 0 "0 0 0 Q Met Nr Nr 't c) M � N r = U m — > 'a in In E U U) C r r 0 0 5 W U II — CO M N O M et II D 0 0 0 0 0 0 z M 0 0 0 0 0 0 0 0 0 m 0 O 0 0 0 0 0 0 C N M M M M M M M M M o w 0 CO 0 0 0 0 0 0 0 0) O (O r- N- r- N- N- N- r- O ts pO co v 0 O v) N 7 Or- OIn U0 1.0 () u) U) ) n I E O o LUL M c N• e c c 0 Ceo (6 CO 06 @ I6 I6 /6 I6 66 N C M M N N U. I C C C c c C C C C C .� • g 4t a) >� J CO In et In ODM as J f6 I6 N f6 I6 CO N I6 N N O .C t1�_ • Q Ni et aD lf) O LL _ 73 •C v Y U C C C C c c C C C C C Y 4! N ------:•-• I � 12 QU L^ Y nl) M co Tr a III(O r6u) 6r- M co Nr O 0 y wC4 01 01 01 01 CAI 01 ss 01 01 0v) QU 8 V y O Ln7 T- 00OD0000) 0) Mr (' CO O) Tr r co r O N N M M M N N cy M M N N N N N r CO Tr Tr Tr co NN M Tr N. N N N N r N N N N CL v If) M 0) O a T N In M M In O In r- O V) ). N M Tr In I() N >.. N N N N r N N N M 0 J 0) O 6 et r N. Or (ON 0) 0 M a) rY \ O. N MMMM 0. NrNNNNTNrNN .,'.. � (0 Z_. O 65a) U (n U -a a 00 N N- O O M U) N N- O U) In (O M (4 0 = - 0 S T- 1.0 N> N M ' 5 op0, M 01010001et0 II IjIJ() U) (0 II II II C7LLLLU) CO OO r N N r ODrr00000000 p 2 cO co O) 0) 0) 0) oo rn O) ao 6 ao 6 ao ao co O co — L. 4-• "O G _ CO N N 7 G Co Co Co Co Co Co Co CD Co C r 0) 00 00 c N N_ 0) 0) 0) 0) 0) O 0) 0) 0 G • O C 1.0 In In In U) In U) In U) D >+ C) 0) 0) r r r -0 S r N N N N N N N N N •U .. 0- a � c r cp coNcoN2 0. NN_ OO) 00) 00) 0) 0Co 0) 00) 0) 0)Co Co O U O (n ) Tr O Tr Tt m d Ln In In In O O to O O 0)•<n N C 0 0 r r r O - NNNNNNNN (N fn .0).,n 8 ... O CC 0 O O � a) Ua r r r 10C a-. r r r N C N - _ +m'' N N N N 0 N s' 1;co N N N N N N N N N N N y a s >' El .12 H I6 A- C H I6 ol Q1 OD cn c) N- Cq M 7 '' 0000 r � 0 M � IntOIsoOO) NNNN 12 � II II II ui2 vvvvvv 2 vv vv vvvTrvvc Q2 > a } 6 DAILY REPORTS 24 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Brett Packer Granville Rizek Date: 04/07/2011 Time: 23:59 Current Depth (MD): 110' Current Rigging up Current Depth (TVD): 110' Operations: gg g 24 hr Footage(MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: Max: Mud Properties @ 94' MW: 8.9 FV: 132 PV: 19 YP: 24 FL: 4.6 Gels: 26/44/55 Sol: 4 __ pH: 10.2 Cf450 Ca++: 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: NA Max: NA _.Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) C1 C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases _ (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 NA Lithologies: Current: NA Last 24 hrs: NA Continued rig up; P/U drill pipe; miscellaneous mudlogging activity—mount gas Operational Summary: trap, adjust flow rates in gas detection equipment and calibrate gas detection equipment. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2,610.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Brett Packer Granville Rizek Date: 04/08/2011 Time: 23:59 Current Depth (MD): 110' Current Configuring EDR Current Depth (ND): 110' Operations: 24 hr Footage(MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA _ Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 94' MW: 8.8 FV: 157 PV: 20 YP: 35 FL: 4.5 Gels: 29/44/55 Sol: 7 pH: 10.0 Cf450 Ca++: 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: NA Max: NA Depth (MD/ND): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases _ (none) Gas Peaks Depth (MD/ND) TG _ Cl C2 C3 iC4 nC4 iC5 nC5 NA Lithologies: Current: NA Last 24 hrs: NA Operational Summary: Continued rig up; stack 103,4" casing in pipe shed; P/U HWDP; load spud mud; make up dumb iron BHA for short rathole to accommodate LWD toolstring. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2,610.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Brett Packer Granville Rizek Date: 04/09/2011 Time: 23:59 Current Depth (MD): 411' Current Rig repairs Current Depth (TVD): 411' Operations: 24 hr Footage (MD): 301' Drilling Parameters ROP: Current: NA Max: 731 Torque: Current: NA Max: 7000 WOB: Current NA Max: 12 RPM: Current: NA Max: 93 PP: Current: NA Max: 1369 Lag: Strokes: 848 Time: 4.2 min Surf-Surf: Strokes: 897 Time: 4.4 min ECD: Current: NA Max: NR Mud Properties @ 411' MW: 9.1 FV: 200 PV: 31 YP: 43 FL: 7.4 Gels: 24/54/63 Sol: 8 pH: 9.0 Cr 500 Ca++: 40 MW Change: Depth: 109 From: 8.8 To: 9.1 Reason: Higher vi rCa mud for gravels Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: NA Max: 7u Depth (MD/TVD): 120 Avg BG : 2u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: 50% sand/conglomeratic sand, 50% conglomerate Last 24 hrs: 70% conglomerate, 30% sand/conglomeratic sand Continued troubleshooting on Totco EDR; RIH with dumb iron and tag up slough in conductor at 108'; drill ahead to 239' and POOH; P/U BHA#2 with full LWD tool string Operational Summary: and RIH; free gravel in auger; drill ahead to 380'; replace auger belt; drill ahead to 411'; replace auger gear box; miscellaneous mudlogging activity—move gas trap in mud trough to avoid gravel accumulations. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $2,610.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Brett Packer Granville Rizek Date: 04/10/2011 Time: 23:59 Current Depth (MD): 1089' Current Drilling ahead Current Depth (TVD): 1089' Operations: 24 hr Footage (MD): 678' Drilling Parameters ROP: Current: 82 Max: 1098 Torque: Current: 2000 Max: 9000 WOB: Current 9 Max: 17 RPM: Current: 88 Max: 96 PP: Current: 1792 Max: 1848 Lag: Strokes: 2316 Time: 12 min Surf-Surf: Strokes: 2501 Time: 13 min ECD: Current: 9.54 Max: NR Mud Properties @ 1096' MW: 9.2 FV: 330 PV: 35 YP: 59 FL: 6.5 Gels: 21/51/61 Sol: 10 pH: 9.0 Cr 600 Ca++: 40 MW Change: Depth: 693 From: 9.1 To: 9.2 Reason: inc.sand content Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: _ Current: _ 1u Max: 2u Depth (MD/TVD): 715/715 Avg BG : 2u Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) _ Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases _ (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) _ Lithologies: Current: 60% sand/conglomeratic sand, 40% clay/claystone Last 24 hrs: 60% sand/conglomeratic sand, 20% clay/claystone, 15% conglomerate, 5% siltstone Finish replacing auger gear box;thaw out kelly hose and test to 2500 psi; drill ahead Operational Summary: from 411'to 1089'; miscellaneous mudlogging activity— 11 IsoTubes and USGS cans collected. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,145.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Brett Packer Granville Rizek Date: 04/11/2011 Time: 23:59 Current Depth (MD): 1482' Current R/U casing equipment Current Depth (ND): 1482' Operations: 24 hr Footage(MD): 393' Drilling Parameters ROP: Current: NA Max: 716 Torque: Current: NA Max: 3000 WOB: Current NA Max: 16 RPM: Current: NA Max: 97 PP: Current: NA Max: 2181 Lag: Strokes: 3168 Time: 15 min Surf-Surf: Strokes: 3453 Time: 16 min ECD: Current: NR Max: NR Mud Properties @ 1482' MW: 9.2 FV: 273 PV: 34 YP: 51 FL: 5.8 Gels: 23/46/53 Sol: 7 pH: 9.0 Cr 550 Ca": 40 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: NA Max: 5u Depth (MD/TVD): 1175/1175 Avg BG : 3u Gas Events Trip Gas Depth (MD/ND) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: 60% clay/claystone, 40% sand/conglomeratic sand Last 24 hrs: 60% sand/conglomeratic sand, 20% clay/claystone, 15% conglomerate, 5% siltstone Drill ahead from 1089'to 1482'; pump a survey, CBU, and monitor the well (no losses); Operational Summary: wiper trip to HWDP at 320', RIH to 1482', pump a 10.9 ppg sweep, and monitor well (no losses); short trip to 970', RIH to 1482, CBU; POOH and L/D BHA; miscellaneous mudlogging activity—7 IsoTubes and USGS cans collected. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,145.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Granville Rizek Date: 04/12/2011 Time: 23:59 Current Depth (MD): 1482' Current N/D diverter Current Depth (TVD): 1482' Operations: 24 hr Footage(MD): 0' Drilling Parameters ROP: Current: NA _ Max: NA Torque: Current: NA Max: NA WOB: Current NA _ Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 1482' MW: 9.1 FV: 74 PV: 31 YP: 20 FL: 6.3 Gels: 1 11/19/24 Sol: 6 pH: 9.0 Cr 500 Ca++: 20 MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG _ Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA R/U casing equipment; RIH w/10%"casing to 1473 ft; R/D casing equipment; circulate Operational Summary: and condition mud; R/U cementing equipment, pressure test lines, and pump cement job, bumping the plug with OBM; R/D cementing equipment. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,145.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Granville Rizek Date: 04/13/2011 Time: 23:59 Current Depth (MD): 1482' Current Testing BOP's Current Depth (TVD): 1482' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 1482' MW: NA FV: NA PV: NA YP: NA FL: NA Gels: NA Sol: NA pH: NA Cr: NA Ca++: NA MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Operational Summary: Nipple down, clean, and break down diverter; clean pits; nipple up well head and BOPE; test BOP's. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,145.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Granville Rizek Date: 04/14/2011 Time: 23:59 Current Depth (MD): 1527' Current Drilling ahead Current Depth (ND): 1527' Operations: 24 hr Footage(MD): 45' Drilling Parameters ROP: Current: 89 Max: 257 Torque: Current: 1000 Max: 2000 WOB: Current 4.8 Max: 21 RPM: Current: 60 Max: 74 PP: Current: 2165 Max: 2332 Lag: Strokes: 1499 Time: 7.8 min Surf-Surf: Strokes: 1795 Time: 9.3 min ECD: Current: 9.18 Max: NR Mud Properties @ 1534' MW: 8.8 FV: 84 PV: 21 YP: 15 FL: N/A Gels: l 16/23/26 Sol: 6 pH: NR Cr 120000 Ca++: NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: 80% claystone, 20% shale Last 24 hrs: 75% claystone, 20% shale, 5% sand Finish testing BOP's; P/U BHA#3, RIH and tag cement at 1366';work on top drive;test Operational Summary: casing to 3200 psi for 30 min.; drill out cement,float collar,and 20' of new formation to 1502'; perform leak-off test to 12.7 ppg EMW; drill ahead to 1527'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,445.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Granville Rizek Date: 04/15/2011 Time: 23:59 Current Depth (MD): 2220' Current Drilling ahead Current Depth (TVD): 2220' Operations: 24 hr Footage(MD): 693' Drilling Parameters ROP: Current: 221 Max: 451 Torque: Current: 5000 Max: 6000 WOB: Current 5.0 _ Max: 15 RPM: Current: 112 Max: 124 PP: Current: 1237 Max: 2136 Lag: Strokes: 2191 _ Time: 13.0 min Surf-Surf: Strokes: 2662 Time: 15.8 min ECD: Current: Max: NR Mud Properties @ 2127' MW: 9.1 FV: 97 PV: 19 YP: 22 FL: N/A Gels: 21/28/3 Sol: 7 pH: NR CI' 110000 Ca++: NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 245u Max: 2360u Depth (MD/TVD): 2091'/2091' Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 1899'/1899' 1471 289377 - - - - - 1945'/1945' 1546 280227 - - - - - - 1978'/1978' 1708 352215 - - - - - 2091'/2091' 2360 489432 - - - - - - Lithologies: Current: 70% siltstone, 30% sand Last 24 hrs: 60% sand, 30% siltstone, 10% claystone Drill ahead from 1527'to 1557'; pick up off bottom and circulate to lower mud temperature; drill ahead from 1557'to 1573'; POOH to casing shoe and circulate to Operational Summary: lower mud temperature; POOH, LID BHA, change bit and jets to lower mud temperature; P/U BHA, RIH to 1467', and circulate and condition mud; wash down from 1467'to 1557' and drill ahead to 2220'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,445.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Granville Rizek Date: 04/16/2011 Time: 23:59 Current Depth (MD): 2598' Current L/D BHA Current Depth (TVD): 2598' Operations: 24 hr Footage (MD): 378' Drilling Parameters ROP: Current: NA Max: 732 Torque: Current: NA Max: 7000 WOB: Current NA Max: 18 RPM: Current: NA Max: 125 PP: Current: NA Max: 1319 Lag: Strokes: 2570 Time: 15.2 min Surf-Surf: Strokes: 3125 Time: 18.5 min ECD: Current: NA Max: NR Mud Properties @ 2598' MW: 9.1 FV: 132 PV: 20 YP: _ 25 FL: N/A Gels: 24/30/35 Sol: 6 pH: NR Cf' 110000 Ca"' NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: 2101u Depth (MD/TVD): 2283'/2283' Avg BG : 593u Gas Events Trip Gas Depth (MD/TVD) Cl C2 _ C3 iC4 nC4 iC5 nC5 734 2220'/2220' 146800 - _ - - - - - 412 2428'/2428' 82400 - - - - - - 302 2599'/2599' 60400 - - - - - - Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases _ - (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 228312283' 2102 222709 - - - - - - 2302'/2302' 1915 _ 202992 - - - - - - 2340'/2340' 1578 156951 - - - - - - -2583'/2583' 444 85846 - - - - - - Lithologies: Current: 50% claystone, 30% sand, 20% siltstone Last 24 hrs: 45% siltstone, 40% sand, 15% claystone Circulate bottoms-up at 2220', POOH to the shoe, and circulate to cool mud temperature; Operational Summary: RIH to 2210',wash down to 2220', and drill ahead to 2428'; CBU, POOH to the shoe, and circulate to cool mud temperature; RIH to 2410', CBU,drill ahead to TD at 2599', and CBU x4;wiper trip to the shoe; RIH to 2599', CBU x2, and POOH. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,945.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Granville Rizek Date: 04/17/2011 Time: 23:59 Current Depth (MD): 2598' Current Wireline logging Current Depth (TVD): 2598' Operations: gg g 24 hr Footage(MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 2598' MW: 8.9 FV: 117 PV: 21 YP: 23 FL: N/A Gels: 24/30/35 Sol: 5 pH: NR CI 110000 Ca++: NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Rig up Schlumberger wireline equipment; perform open-hole e-logging and formation testing Operational Summary: runs miscellaneous mudlogging activity—samples manifested and delivered to company man, and sample catchers flown to Anchorage. Calibrations: THA Failures: None Daily Cost: $3,570.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Granville Rizek Date: 04/18/2011 Time: 23:59 Current Depth (MD): 2598' Current Formation testing Current Depth (TVD): 2598' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 2598' MW: 8.8 FV: 130 PV: 21 YP: 23 FL: N/A Gels: 24/30/35 Sol: 5 pH: NR Cf' 110000 Ca++: NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 49 1505'/1505' 9800 - - - - - Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Continue wireline e-logging; rig down wireline operations and rig up for drill pipe conveyed Operational Summary: logging; RIH with drill pipe to 1474'; circulate and condition mud; rig up Schlumberger E_line; correlate and set drill pipe at 2113', and perform mini-frac formation test; correlate and set drill pipe at 2244'. Calibrations: THA Failures: None Daily Cost: $2,615.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Scott Heim Date: 04/19/2011 Time: 23:59 Current Depth (MD): 2598' Current POOH w/drill pipe- Current Depth (ND): 2598' Operations: conveyed logging tool 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 2598' MW: 8.9 FV: 135 PV: 46 YP: 15 FL: N/A Gels: 13/23/27 Sol: 5 pH: NR CI- 110000 Ca"' NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) C1 C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/ND) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Perform mini-frac at 2201'and 2204'; POOH with drill pipe-conveyed formation testing tool to 1505'and remove side entry sub; POOH and L/D Schlumberger MDT tool; M/U Operational Summary: Schlumberger tool for fluid sampling; RIH with drill pipe-conveyed formation testing tool; correlate and set drill pipe at 2325'and perform sampling procedure—pumps fail; POOH to replace pumps. Calibrations: THA Failures: None Daily Cost: $2,615.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Scott Heim Date: 04/20/2011 Time: 23:59 Current Depth (MD): 2598' Current Downhole fluid Current Depth (TVD): 2598' Operations: sampling 24 hr Footage(MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 2598' MW: 8.9 FV: 130 PV: 22 YP: 20 FL: N/A Gels: 22/29/33 Sol: 5 pH: NR Cr 110000 Ca" NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Summary: POOH and change pump seat on Schlumberger formation testing tool; RIH with drill pipe- Operationalconveyed formation testing tool; correlate depth and sample formation fluid. Calibrations: THA Failures: None Daily Cost: $2,615.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Scott Heim Date: 04/21/2011 Time: 23:59 Current Depth (MD): 2598' Current Testing BOP's Current Depth (ND): 2598' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA _ Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 2598' MW: 8.9 FV: 136 PV: 19 YP: 25 FL: N/A Gels: 22/31/- Sol: 5 pH: NR CI110000 Ca++: NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: Ou Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/ND) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Operational Summary: Continued downhole fluid sampling; POOH with drill pipe-conveyed sampling tool and rig down Schlumberger E-line equipment; test BOP's. Calibrations: THA Failures: None Daily Cost: $2,615.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Scott Heim Date: 04/22/2011 Time: 23:59 Current Depth (MD): 2598' Current POOH, L/D drill pipe Current Depth (TVD): 2598' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Properties @ 2598' MW: 8.9 FV: 143 PV: 20 YP: 27 FL: N/A Gels: 23/31/33 Sol: 5.5 pH: NR 110000 Ca" NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: NA Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 275u 2598'/2598' 55000 - - - - -Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Operational Summary: Complete BOP testing; P/U cleanout BHA and RIH to TD; circulate bottoms-up and pump a 35 bbl sweep—no significant increase in cuttings; POOH laying down drill pipe. Calibrations: THA Failures: None Daily Cost: $2,615.00 CANRIG Conoco:hillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Scott Heim Date: 04/23/2011 Time: 23:59 Current Depth (MD): 2598' Current Casing run Current Depth (TVD): 2598' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: , Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: , NA Mud Properties @ 2598' MW: 8.9 FV: 106 PV: 23 YP: 30 FL: NA Gels: 24/31/34 Sol: 5 pH: NR Cr 110000 Ca++: NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: 0 Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) _ Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Operational Summa Continue to POOH and L/D drill pipe; install and test 7%"rams; R/U casing equipment; run p Summary: 7%"x 4W casing(still on 4W casing by midnight). Calibrations: THA Failures: None Daily Cost: $2,615.00 CANRIG ConocoPhillips Alaska,Inc. Ignik Sikumi #1 Daily Report Report for: Dale Rowell Scott Heim Date: 04/24/2011 Time: 12:00 Current Depth (MD): 2598' Current Wireline run Current Depth (TVD): 2598' Operations: 24 hr Footage (MD): 0' Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: NA Time: NA Surf-Surf: Strokes: NA Time: NA ECD: Current: NA Max: NA Mud Pro•erties @ 2598' MW:` NA FV: NA PV: NA YP: NA FL: NA Gels: NA Sol: NA pH: NR Cr NA Ca' NR MW Change: Depth: (none) From: To: Reason: Mud Loss event: Depth: (none) Volume: Gas Data Ditch Gas: Current: NA Max: NA Depth (MD/TVD): NA Avg BG : NA Gas Events Trip Gas Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 (none) Connection Depth (MD/TVD) Cl C2 C3 iC4 nC4 iC5 nC5 Gases (none) Gas Peaks Depth (MD/TVD) TG C1 C2 C3 iC4 nC4 iC5 nC5 (none) Lithologies: Current: NA Last 24 hrs: NA Continue to run 7%"x 41"casing; rig down casing equipment and rig up Schlumberger Operational Summary: wireline;log from 2300'to 2000'to locate pip tag;miscellaneous mudlogging activity—rig down mudlogging unit. Calibrations: THA Failures: None Daily Cost: $2,250.00 CANRIG 0 0 z r 0 G) Drilling Logs
