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210-074
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' • 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. °,,L 0 - Q 7 14- Well History File Identifier Organizing (done) ❑ Two -sided III III II III III ❑ Rescan Needed 1 11111 I RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Di kettes, No. ❑ Maps: �eyscale Items: Other, No/Type:C,I) NO.i ❑ Other Items Scannable by a Large Scanner oor Quality Originals: 1 P OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: /s/ at_P Project Proofing III 111111 1111 BY: Date: '/ /s/ t Scanning Preparation ( x 30 = 30 + 0 = TOTAL PAGES SO n (Count does not include cover sheet) BY: Date: �. d I 1 /s/ Production Scanning I Stage 1 Page Count from Scanned File: 5 1 (Count does include cove heet) Page Count Matches Number in Scanning Pre aration: V YES NO l BY: Maria) Date: ova Li. 1 /s/ r1410 / Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111111111 I ReScanned II MI11111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111 I 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA JUL 1 7 2013 r AL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 0GCC 1.Operations Performed: Abandon r Repair w ell Ri Rug Perforations r Perforate r Other Alter Casing r Pull Tubing j Stimulate-Frac "`°` Waiver r Time Extension r Change Approved Program Operat. Shutdown r Stimulate-Other E Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development . Exploratory r 210-074-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21932-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25523,25631 31-11A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 9490 feet Plugs(measured) 6156, 6406 true vertical 6251 feet Junk(measured) none Effective Depth measured 9490 feet Packer(measured)6040,6146,6422 true vertical 6251 feet (true vertical) 5879, 5977,6230 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116 116 SURFACE 3348 9.625 3383 3383 PRODUCTION 6728 7 6761 6294 A LINER 1890 2.375 9490 6251 Perforation depth: Measured depth: 7614'-9490' HGw N13 b 2YV3 True Vertical Depth: 6228'-6251' Tubing(size,grade,MD,and ND) 3.5, L80,6017 MD,5858 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 6040 MD and 5879 ND PACKER-BAKER 84-SAB-40X32 RETAINER PROD. PACKER @ 6146 MD and 5977 ND PACKER-BAKER 85-40'F1' PERMANENT PRODUCTION PACKER @ 6422 MD and 6230 ND NIPPLE-CAMCO DS NIPPLE @ 491 MD and 491 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development PT` Service F Stratigraphic 16.Well Status after work: Oil 5.7• Gas r WDSPL Daily Report of Well Operations XXX GSTOR r WINJr WAG r GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Paul Chan (a,263-4759 Email Paul.Chan(a.contractor.conocophillips.com Printed Name Paul Chan` Title Wells Engineer Signature Phone:263-4759 Date -7( t(p 1 13 0 �VF RBDMS JUL 2 3 20& Form 10-404 Revised 10/2012 /�) l 13 Submit Original Only KUP 31-11A ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska.I Wellbore API/UWI Field Name Well Status Intl(°) MD(ftKB) Act Btm(ftKB) ca,oceptviaps 500292193201 KUPARUK RIVER UNIT PROD 9,490.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "- SSSV:NIPPLE 200 10/10/2011 Last WO: 6/30/2013 35.91 4/4/1989 Well Con(41:-31-11A 7/2/2013 7:53.18 AM Schemati c-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WORKOVER osborl 7/1/2013 HANGER,31 a; Casing Strings ( Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd R .y CONDUCTOR 16 15.062 36.0 116.0 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 95/8 8.765 35.0 3,383.4 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 33.0 6,761.5 26.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd WINDOW A 7 6.000 6,396.0 6,406.0 9.30 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR, A LINER 2 3/8 1.995 7,599.6 9,490.0 4.43 L-80 STL 35116 Liner Details NIPPLE,491 Top Depth Nomi... (TVD) Top Intl Comment ID(i^) Top(ftKB) (ftKB) (°) Item Description 7,599.6 BILLET ANCHORED BILLET 1.000 8,096.1 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 GAS LIFT, Tubing Strings latt 2,501 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING WO 2013 3 1/2 2.992 31.3 6,016.8 9.30 L-80 EUE 8rd completion Details j; Top Depth 1 (ND) Top Inc! Nomi... Top IRKS) (RKB) (°) Item Description Comment ID(in) `. 31.3 HANGER FMC TUBING HANGER 3.500 SURFACE, k, An, 491.1 NIPPLE CAMCO DS NIPPLE w/2.875"Profile 2.875 353,383 6,006.0 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY spaced out 7.21'from top of 3.000 Packer Tubing Description String 0... String ID...Top(5KB) Set Depth(L.'Set Depth(ND)...String Wt...String...String Top Thrd [ STACK PACKER 3 1/2 2.992 6,016.8 6,148.0 9.30 L-80 EUE 8rd GAS LIFT, ` 2013 3.734 - _ MEI MIN Completion Details Top Depth � (TVD) To 1 I ID d.. GAS.691 P^o 4,691 F ° Top(ftKB) (ftKB) (°) Item Description Comment 6,016.8 PBR BAKER O i NIPPLE 6,082.5 6,039.9 PACKER CAMCO R BKER 0 FHL PACKER DS4N NIPPLE w/2.812" 2.813 6,145.5 SEAL ASSY BAKER GBH-22 MOLDED SEAL ASSEMBLY 2.990 GAS LIFT, Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 6'399 TUBING WO 2009 I 31/2 I 2.992 I 6,146.4 6,427.5 I 9.30 I L-80 EUE Completion Details Top Depth . (TVD) Top Inc! Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 6,146.4 PACKER Baker 84-SAB-40x32 Retainer Prod.Packer 3.250 GAS LIFT, ' 6,156.3 NIPPLE HALLIBURTON'X'NIPPLE 2.813 5,961 6,419.8 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY w/LOCATOR 3.000 SEAL ASSY, Tubing Description 1String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...I String...!String Top Thrd 6,0^6 PACKER ASSY 5 4.000 6,422.1 ! 6,438.0 ! ACME PBR,6,017 PACKER,6,040 '..' Completion Details �- Top Depth (TVD) Top Intl Nom,... Top(ftKB) (ftKB) (°) Rem Description Comment ID(,n) 6,422.1 PACKER BAKER 85-40'F1'PERMANENT PRODUCTION PACKER 4.650 NIPPLE,6,062 6,425.4 SBE BAKER 80-40 SBE(5'Long)w/XO Sub 4.000 6,429.9 XO-Reducing X-Over Sub 5"BTC x 3.5"EUE 3.000 6,433.4 NIPPLE CAMCO'D'NIPPLE 2.750 6,437.1 SOS SHEAR OUT SUB w/WLEG 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY,_ x Top Depth 6.146 ND PACKER,6,146 ; (ND) To(Intl Comment ( ) l' Top(ftKB) ( (°) Description Run Date ID in li-- -1 6,154.0 CaCO3 DUMP BAILED CaCO3 ON TOP OF PLUG 6/9/2013 0.000 CaCO3,6,154 6,156.0 PLUG 2.81"XX PLUG(OAL=53') 6/9/2013 0.000 PLUG,6,156 - 6,396.0 WHIPSTOCK BAKER MONOBORE RWS WHIPSTOCK Sits atop CIBP 7/26/2010 NIPPLE,6,156 6,406.0 PLUG CAST IRON BRIDGE PLUG TO ISOLATE LATERAL 6/22/2010 0.000 WHIPSTOCK, 6,396 WINDOW A. - ' 6,396-6.406 PLUG.6,406 SEAL ASSY, 6,420 PACKER,6,422 IMn Mandrel Details SBE,6,425 • Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run k' N...Top(ftKB) (5KB) (°) Make Model (10) Sery Type Type On) (psi) Run Date Corn... NIPPLE,6,433 1 2,500.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/26/2013 2 3,733.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/26/2013 SOS,6,437 PRODUCTION. 3 4,691.2 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0 6/26/2013 33.6,761 SLOTS. 4 5,399.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/26/2013 6,2439,078 SLOTS, 5 5,951.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/26/2013 7,614$086 SLOTS, 8,097-9,490 SOTTED I AL2 SLOTTED LINER.979 6,180.9,079 A LINER. 7,600.9.490 TD(31-11A), 9,490 KUP • 31-11A Conoco`Phiiiips \ } , Alaska,Inc Ccm<oPh6lIps KB-Ord(ft) Rig Release Date ••• 35.91 4/4/1989 Well Confi9:'.-31-11A,7/22013 7:53:18 AM - --- ' Schematic-Actual HANGER.31 1 ) Perforations&Slots ( - J Shot - 1 I Top(TVD) Btm(TVD) Dens iiiiimr Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (eh.- Type Comment 7,614.0 8,096.0 A-2,31-11A 7/28/2010 32.0 SLOTS SLOTTED LINER-0.125"x2.5"@ 4 circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends 8,097.0 9,490.0 A-2,A-3,A-2, 7282010 32.0 SLOTS SLOTTED LINER-0.1255(2.5"@ 4 31-11A circumferential adjacent rows,3" CONDUCTOR, centers staggered 18 deg,3' 36-tin non-slotted ends NIPPLE,491 Notes:General&Safety End Date Annotation III 5/18/2009 NOTE:WORKOVER 2/32010 NOTE:31-11 ATTEMPTED LATERALS ABANDONED;WELL SIDETRACKED 7/19/2010 GAS LIFT, 7/19/2010 NOTE:SIDETRACK A,AL7,AL2 9501 8/6/2010 NOTE:VIEW MULTI-LATERAL SCHEMATIC w/Alaska Schematic9.0 11/2/2012 NOTE:FOUND TUBING LEAK @ 5688' SURFACE. 36-3.383 GAS LIFT, 3,734 GAS LIFT, 4,691 GAS LIFT, 5,399 I GAS 5 LIFT, ,951 k SEAL ASSV,_ 6,006 PER.6,017 `{ 1 PACKER,6,040 0` --7,`' NIPPLE,6,082 I [- SEAL ASSY. ------- 6,146 PACKER,6,146 c1I 1' 1 CaCO3,6,154 -' PLUG,6,156- .V 4.. NIPPLE,6,156 WHIPSTOCK, 6.396 WINDOW A 6,3966,406--':-, PLUG,6,406 SEAL A 4 2 6,. 0 42 PACKER,6,422 SBE,6,425 NIPPLE.6.433 L` SOS,6,437 I PRODUCTION, 33.6,761 -. --- SLOTS, 6,243-9,078 SLOTS, 7,614-8,096 SLOTS, 8,097-9,490 AL2 SLOTTED LINER. 6,180.9,079 _ ALINER, 7,fiW.9,490 -TO(31-11A), �"° 9,490 3I-11A Pre-Rig Well Work DATE SUMMARY • • 4/20/2013 (PRE RWO) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, FUNCTION TESTED T LDS'S (ALL GOOD), MIT-OA PASSED TO 1800 PSI. 6/9/2013 Measured BHP (4359 psi) @ 6180' RKB; Set 2.81"XX Plug @ 6156' RKB; Confirmed set w/Check Set; Dump Bailed -5 of CaCO3 on top of Plug @ 6156' RKB. Complete(Ready for BPV) • • Conoco hillips Time Log & Summary We/Mew Web Reporting Report Well Name: 31-11 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/21/2013 9:30:00 AM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/20/2013 24 hlr Summary Release rig f/3A-14, move to 31-11. First modules on 31 @ 21:00. 19:00 20:45 1.75 0 0 MIRU MOVE MOB P Blow down and disconnect power, remove rockwasher and powerpack. 20:45 22:30 1.75 0 0 MIRU MOVE MOB P Move powerpack f/3A-14 to 31-11 and stage. 22:30 00:00 1.50 0 0 MIRU MOVE MOB P Move pipe sheds and load same, move sub off 3A-14. 06/21/2013 Move rig onto well 31-11. Kill well, N/D tree, N/U BOPE, R/U to test BOPE. 00:00 01:30 1.50 0 0 MIRU MOVE MOB P PJSM, move sub base&pipesheds from 3A pad to 31-11A. 01:30 03:30 2.00 0 0 MIRU MOVE MOB P Spot sub over well 31-11A. 03:30 04:00 0.50 0 0 MIRU MOVE MOB P Set matting boards for complexes and pipeshed. 04:00 06:30 2.50 0 0 MIRU MOVE MOB P Set complexes and pipeshed. 06:30 09:30 3.00 0 0 MIRU MOVE RURD P Work on rig acceptance checklist. Hook up electrical lines, steam, water, air lines, berm, rockwasher, boiler house,trim all herculite, install skate rail. gas alarms tested. (Rig accepted @ 09:30) 09:30 10:45 1.25 0 0 MIRU WHDBO RURD P PJSM,take on 14.3 ppg kill weight mud to pits, R/U hardline and tiger tank, R/U flanges on tree and IA. 10:45 12:00 1.25 0 0 MIRU WHDBO RURD P PJSM, Pull BPV via lubricator. (OA= 275 psi, IA=2000 psi,tbg=2200 psi) 12:00 13:30 1.50 0 0 MIRU WHDBO RURD P PJSM, Continue R/U Circ flanges& hoses for well kill. 13:30 17:00 3.50 0 0 MIRU WELCTL KLWL P PJSM, Blow air through lines, pressure test lines to 3500 psi, kill well w/14.3 ppg mud surface to surface @ 2 bpm, ICP= 1900 psi, FCP=650 psi, pump 345 bbls total w/345 bbls in tiger tank. 17:00 18:00 1.00 0 0 MIRU WELCTL OWFF P Shut in well, monitor pressures for 5 min(no pressure build), open well to Tiger tank, monitor @ tiger tank until FMC arrives. (static) 18:00 18:45 0.75 0 0 MIRU WH13BO PRTS P PJSM, Set BPV, attempt to test the same via IA,would not hold pressure, consulted w/town, decision made to cont with plan forward, SIMOPS load pipeshed with 210 joints 3.5"tubing and process same. rag: 1 of 8 Time Logs 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 20:00 1.25 0 0 MIRU WHDBO RURD P PJSM, Flush lines and Blowdown tiger tank, R/D same, R/D scaffolding, bleed control line, bleed OA from 1200 psi to 250 psi. 20:00 20:45 0.75 0 0 MIRU WHDBO NUND P PJSM, N/D tree and adapter spool, install blanking plug 20:45 22:45 2.00 0 0 MIRU WHDBO NUND P PJSM, N/U DSA flange&BOPE. 22:45 00:00 1.25 0 0 MIRU WHDBO RURD P R/U to test BOPE,fill lines and take measurements to ensure rams close without obstruction. 36/22/2013 BOPE test.Attempted to pull tubing free. R/U E-Line,string shot, hang up @ SSSV, POH&R/D Eline. R/U slickline open SSSV, R/D. 00:00 02:30 2.50 0 0 MIRU WHDBO BOPE P PJSM,Test BOPE w/3.5 Test joint to 250/3500 psi for 5 min. Top pipe rams, C.V.#1,#12,#13,#14 and manual kill line, Upper IBOP, C.V. #5,#8,#10. Dart Valve, C.V.#5,#8, #10. Dart Valve, C.V.#4,#6,#7. Floor Valve and CV#2. HCR choke and 4"Kill Line DEMCO valve. Manual Choke.Annular preventer, lower pipe rams. Blind rams. 02:30 03:00 0.50 0 0 MIRU WHDBO BOPE P Accumulator test: System pressure=3000 psi, Pressure after closing=1600 psi,200 psi attained=38 sec, full pressure attained=197 sec. 5 bottle average pressure=2000 psi.Test witness waived by AOGCC Bob Noble 20:10 6/20. 03:00 04:30 1.50 0 0 COMPZ RPCOM RURD P Back out blanking plug, drain stack, and R/D test equipt. Blow down choke, choke line, kill line and T.D. 04:30 05:15 0.75 0 0 COMPZ RPCOM RURD P PJSM, P/U casing tool and control line spooler from beaver slide. 05:15 05:45 0.50 0 0 COMPZ RPCOM P Service Top drive. 05:45 06:00 0.25 0 0 COMPZ RPCOM P Pull BPV as per FMC rep. 06:00 06:30 0.50 0 0 COMPZ RPCOM P M/U XOs and pup joints to hanger. (Kelly up T.D.) 06:30 10:00 3.50 0 0 COMPZ RPCOM P Attempt to pull hanger free. Pull 200k several times with no success,turn on pumps and pump @ 3 bpm,425 psi,work pipe several up to 200k no success. Decision made to R/U E-line and string shoot. 10:00 10:15 0.25 0 0 COMPZ RPCOM RURD P R/D Circ equipt, blow down T.D. 10:15 12:00 1.75 0 0 COMPZ RPCOM RURD P Spot HES Eline trucks and prep tools for run. SIMOPS prep drill pipe in pipeshed. 12:00 14:15 2.25 0 2,212 COMPZ RPCOM ELNE P PJSM, Continue Prep tools for run, M/U string shot assembly and RIH, Fire shots, POOH w/E-Line. :;Page*2 pf Time Logs ' • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 16:15 2.00 2,212 0 COMPZ RPCOM ELNE T Firing head hung up in SSSV, establish circ @ 1-4 bpm,250-700 psi,work e-line free, POOH w/same, R/D E-Line. 16:15 20:00 3.75 0 0 COMPZ RPCOM PULL T Attempt to pull seal assembly free, straight pull to 200k several times, no success. 20:00 21:30 1.50 0 0 COMPZ RPCOM RURD T PJSM R/U slickline, (Monitor hole via trip tank, static) 21:30 00:00 2.50 0 0 COMPZ RPCOM SLKL T RIH#1 w/gauge ring, 2.84"OD,Tag SSSV @2204'Slick line MD, POOH, L/D Gauge Ring, P/U Deformation tool, RIH run#2(pressure up and work tool to deform), POOH w/run #2, Monitor hole via trip tank, Static), Deformation tool had 2 positive indicators of success. Drifted SSSV w/2.77"to verify, rig down slickline. Losses for day 4.4 bbl 36/23/2013 R/U E-Line, RCT cut, POOH&R/D E-Line, pull completion. BOPE test. Fish seal assy. 00:00 00:15 0.25 0 0 COMPZ RPCOM SLKL T PJSM, RIH w/2.77"gauge ring,work through SSSV several times with no problems. 00:15 00:45 0.50 0 0 COMPZ RPCOM RURD T R/D Slickline 00:45 02:00 1.25 0 0 COMPZ RPCOM RURD T Wait on E-Line. SIMOPS work on MP-2s. 02:00 03:45 1.75 0 0 COMPZ RPCOM RURD T Spot HES Eline trucks and prep tools for P/U. 03:45 05:00 1.25 0 0 COMPZ RPCOM RURD T PJSM P/U and R/U E-line as per HES rep. Set 28k tension on tubing string in slips. 05:00 05:15 0.25 0 0 COMPZ RPCOM ELNE P RIH w/2.5"RCT, electromagnetic anchor and CCL to cut tubing as per program. 05:15 05:45 0.50 0 0 COMPZ RPCOM ELNE P POOH, add extension to RCT/CCL string. 05:45 07:30 1.75 0 0 COMPZ RPCOM ELNE P RIH w/2.5" RCT electromagnetic anchor and CCL, Cut tubing @ 6107' MD as per program. 07:30 08:15 0.75 0 0 COMPZ RPCOM RURD P R/D E-Line 08:15 08:45 0.50 0 6,083 COMPZ RPCOM PULL P Pull hanger to rig floor, Break off landing joint and disconnect control line. P/U wt=80k. 08:45 09:00 0.25 6,083 6,083 COMPZ RPCOM RURD P PJSM, R/U to reverse circulate. 09:00 09:45 0.75 6,083 6,083 COMPZ RPCOM CIRC P Reverse Circulate, CBU x2 @ 3 bpm, 425 psi, FCP=500 psi. 09:45 10:00 0.25 6,083 6,083 COMPZ RPCOM OWFF P Monitor well(static) 10:00 12:00 2.00 6,083 4,757 COMPZ RPCOM PULL P L/D 3.5"tubing and control line. Actual fill=3.23 bbls, Calc fill=3.14 bbls. 12:00 12:45 0.75 4,757 3,915 COMPZ RPCOM PULL P PJSM, Cont L/D 3.5"tbg, L/D SSSV, 74 SS Bands recovered 12:45 13:00 0.25 3,915 3,915 COMPZ RPCOM RURD P R/D control line spooler, L/D same. Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 16:15 3.25 3,915 0 COMPZ RPCOM PULL P Cont L/D 3.5"tbg, Cal= 16.33 bbls, Act= 19.55, Cut jt 189= 18.69' 16:15 17:00 0.75 0 0 COMPZ RPCOM RURD P R/D Casing equipment, clean and clear rig floor, un-load 3.5"tubing from pipeshed, load 9 ea,4.75"drill collars in pipeshed. 17:00 17:30 0.50 0 0 COMPZ RPCOM RURD P PJSM, R/U to test w/4"test joint. 17:30 19:00 1.50 0 0 COMPZ RPCOM BOPE P PJSM,test BOPE w/4"test joint, test upper and lower VBR 2.875"x 5"and annular preventer,250/3500 psi for 5 min. 19:00 20:00 1.00 0 0 COMPZ RPCOM RURD P R/D test equip,set wear ring 6.125" ID, Mob fishing tools to rig floor. 20:00 21:30 1.50 0 302 COMPZ RPCOM PULD P PJSM, M/U fishing BHA. 21:30 00:00 2.50 302 2,912 COMPZ RPCOM TRIP P RIH w/4"DP from pipeshed to 2912' MD, Calc disp= 18.37bbls,Actual disp= 17.34 bbls. 36/24/2013 Fish 27'seal assembly,twisted off. Fish remaining seal, K anchor pulled free with carbon/sand cemented conglomerate. M/U junk basket for cleanout. 00:00 02:30 2.50 2,912 6,091 COMPZ RPCOM TRIP P PJSM, Single in hole from 2912' MD to 6091' MD.Act disp=20.57, Calc disp= 19.98 02:30 04:00 1.50 6,091 6,100 COMPZ RPCOM JAR P Break circ and establish parameters. P/U wt= 116k, S/O wt= 102k, Rot wt= 105k, 30 rpm=2k TQ.Wash down from 6080'MD to 6200'MD. Engage fish @ 6100'MD,jar on fish w/no movement. Jarring 90k over P/U wt. pulled 150k over to 275k. sand coming back over the shakers. Circ 150 gpm, 800 psi,flow 53%. 04:00 04:30 0.50 6,100 6,091 COMPZ RPCOM FISH P Release off fish, rot 30rpm,TQ 3k- 10k,work pipe several times, had to ream off fish. popped free after 10'of backreaming. 04:30 05:30 1.00 6,091 6,091 COMPZ RPCOM CIRC P Decision made to circulate until sand cleaned up. Circ 5 bpm, 1500 psi, 54%flow. 05:30 06:30 1.00 6,091 6,091 COMPZ RPCOM OWFF P Monitor well, slight flow down to static. (L/D single from 6100'to 6091' MD). Blow down T.D. SIMOPS perform post jarring derrick inspection and T.D. inspection. 06:30 08:30 2.00 6,091 302 COMPZ RPCOM TRIP P L/D single, POOH from 6091' MD. Actual fill=40.46 bbls, calc fill= 37.38 bbls 08:30 10:30 2.00 302 0 COMPZ RPCOM OWFF P Monitor well(STATIC).change elevators and rack back 3 stands of drill collars. L/D fish as per Baker rep. (Fish=27.07')fish twisted off. 10:30 11:30 1.00 0 0 COMPZ RPCOM OTHR P Clean and clear rig floor. 11:30 12:00 0.50 0 0 COMPZ RPCOM SVRG P Lubricate rig, SIMOPS work on MP2s 12:00 12:45 0.75 0 303 COMPZ RPCOM PULD T PJSM, M/U BHA 2, spear assembly. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 14:30 1.75 303 6,061 COMPZ RPCOM TRIP T RIH w/BHA 2, Cal=37.21 bbls,act 40.63 bbls, P/U = 113k, S/O=82k 14:30 15:15 0.75 6,061 6,115 COMPZ RPCOM WASH T Wash from 6061'MD to 6115'MD @ 155 gpm,2450 psi. 15:15 15:45 0.50 6,115 6,115 COMPZ RPCOM CIRC T CBU @ 155 GPM,2450 psi. 15:45 16:30 0.75 6,115 6,115 COMPZ RPCOM JAR T RIH to engage fish w/1.5 bpm, 550 psi, noted pressure increase @ 6121' MD,take weight @ 6124'MD, P/U to 150k, s/O to 90 k to confirm fish on, jar on seal assembly from 160k to 210k, Straight pull from 200k-250k, Jar @ 210k several times, Jar seal assembly free. 16:30 17:15 0.75 6,115 6,115 COMPZ RPCOM CIRC T CBU @ 4bpm, 2400 psi, SIMOPS post jarring derrick inspection. 17:15 17:30 0.25 6,115 6,115 COMPZ RPCOM OWFF T Monitor well static, B/D top drive. 17:30 21:45 4.25 6,115 0 COMPZ RPCOM TRIP T PJSM, POOH from 6115'MD to 303' MD, Monitor well at the collars, (Static), Rack back collars, Pull fish to rig floor, recovered remaining seal 9 9 assembly still inside PBR, PBR as well as Anchor seal assembly(14.27' total), L/D Spear, Seal assembly, PBR and anchor seal assembly. Cal =37.12 bbls,Actual=41.67 bbls. Components cemented together with combination sand,scale, silica, carbon conglomerate. 21:45 00:00 2.25 0 0 COMPZ RPCOM OTHR T Consult w/town engineer, upload pictures and W.O.O., clean and clear rig floor, monitor well on trip tank,wait on reverse circulating junk basket and string magnets. 06/25/2013 M/U&RIH w/RCJB t/6135' Drop ball work string, POOH L/D BHA, (2 dies recovered), R/U slickline RIH w/ 3.265" magnet POOH, (3 dies recovered) RIH w/3.265" magnet POOH (metal shavings)RIH w/Centralized 2.61"magnet POOH(metal shavings) RIH w/3.265"magnet centralized POOH(2 dies recovered) R/D slickline, R/U t/run completion. 00:00 00:15 0.25 0 0 COMPZ RPCOM SVRG T PJSM,Wait on Baker Reverse Circ Junk Basket. SIMOPS work on MP2s and clean rig. 00:15 00:30 0.25 0 44 COMPZ RPCOM PULD T M/U BHA RCJB as per Baker rep. 00:30 00:45 0.25 44 312 COMPZ RPCOM PULD T P/U 3 stds.drill collars,change elevators. 00:45 03:30 2.75 312 6,071 COMPZ RPCOM TRIP T RIH w/4"drill pipe from 312'MD to 6071'MD.Act=38.93 bbls, calc =38.27 bbls. 03:30 04:15 0.75 6,071 6,135 COMPZ RPCOM FISH T Drop Baker Ball, Pump down @ 2 bpm,450 psi, 26%flow, observe pressure increase to 500 psi. Turn pumps up to 6 bpm 2425 psi,7 bpm 2850 psi. RIH from 6071'MD to 6135' MD,tag up,set 5k down,work up and down 4 times from 6125' MD to 6135'MD as per Baker rep. Page Tim e Logs L • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 6,135 6,135 COMPZ RPCOM OWFF T Monitor well(Static). 04:30 04:45 0.25 6,135 6,071 COMPZ RPCOM TRIP T POOH from 6135'MD to 6071'MD. (Blow down T.D.) 04:45 06:45 2.00 6,071 312 COMPZ RPCOM TRIP T POOH from 6071'MD to 312'MD. Act=42.8 bbls, calc fil=38.27 bbls 06:45 07:15 0.50 312 312 COMPZ RPCOM OWFF T Monitor well. (slight flow down to static) 07:15 08:15 1.00 312 0 COMPZ RPCOM PULD T Rack back 3 stands of collars, L/D fishing BHA#3 as per baker rep.2 slip dies recovered. 08:15 08:30 0.25 0 0 COMPZ RPCOM RURD T Clean and Clear rig floor. 08:30 08:45 0.25 0 0 COMPZ RPCOM RURD T PJSM, R/U and running slickline. 08:45 09:30 0.75 0 0 COMPZ RPCOM PULD T P/U and M/U slickline as per Halliburton rep. 09:30 11:30 2.00 0 0 COMPZ RPCOM SLKL T RIH w/3.265"magnet on slickline. 3 slip dies recovered. 11:30 12:00 0.50 0 0 COMPZ RPCOM SLKL T RIH w/3.265"magnet on slickline. 12:00 13:15 1.25 0 0 COMPZ RPCOM SLKL T PJSM, Cont RIH with 3.265"magnet, recovered metal shavings. 13:15 16:00 2.75 0 0 COMPZ RPCOM SLKL T RIH w/2.61"magnet, magnet hanging up on collars, add centralizers to string, RIH, could not enter packer at 6135'wireline MD, POOH, recovered metal shavings. 16:00 18:45 2.75 0 0 COMPZ RPCOM SLKL T RIH w/2.61", added 2 knuckles and bow string centralizer,to 6144' wireline MD, POOH w/same, recovered metal shavings. 18:45 21:15 2.50 0 0 COMPZ RPCOM SLKL T RIH w/3.625"Magnet w/ centralizers, POOH recover last 2 peices of anchor. Monitor hole on trip tank. 21:15 22:00 0.75 0 0 COMPZ RPCOM RURD P R/D slickline, Clean&clear floor. 22:00 23:15 1.25 0 0 COMPZ RPCOM OTHR P Pull wear ring, R/U completion equipment. 23:15 00:00 0.75 0 0 COMPZ RPCOM SVRG P Service rig Top drive&draworks. 06/26/2013 RIH w/31/2 completion, set plug, set packer, space out,circ in 9.6 inhibited brine, hangoff,test tbg&IA, N/D BOP, N/U tree 00:00 00:30 0.50 0 0 COMPZ RPCOM P PJSM, M/U Seal assembly and packer per baker rep. 00:30 06:00 5.50 0 5,644 COMPZ RPCOM RCST P RIH w/3.5"tubing as per plan t/ 5644'act disp=20.91, calc disp=20.19 bbls. 06:00 07:45 1.75 5,644 5,644 COMPZ RPCOM RCST T Bad threads on DS nipple or tubing, could not M/U, gaulded threads(wait . 9 ( on DS nipple) : g6of8 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:45 1.00 5,644 6,144 COMPZ RPCOM RCST P M/U new"DS"nipple, Cont RIH w/ 3.5"tubing,tagging top of packer @ 6144' MD, pick up turn pumps on to 5 gpm, 170 psi,slack off and observe pressure increase to 225 psi @ 6144' MD. Turn pump off,slack off to no-go. pressure held 225 psi. bled pressure off. 08:45 09:30 0.75 6,144 6,139 COMPZ RPCOM RURD P PJSM on R/U and pumping inhibited fluid. 09:30 10:00 0.50 6,139 6,144 COMPZ RPCOM CRIH P Pump 35 bbls corrosion inhibited 14.3 ppg mud, chased with 49 bbls 14.3 ppg mud @ 3 bpm, 500 psi, 49%flow. 10:00 10:15 0.25 6,144 6,144 COMPZ RPCOM RURD P R/D Circ eqpt, clean and clear rig floor. 10:15 10:45 0.50 6,144 6,144 COMPZ RPCOM RURD P PJSM P/U and R/U slickline equip. 10:45 12:00 1.25 6,144 6,144 COMPZ RPCOM SLKL P RIH w/CA2 plug on slick line as per Halliburton Rep. 12:00 13:00 1.00 6,144 6,144 COMPZ RPCOM SLKL P Cont RIH w/CA2 plug on slickline. 13:00 13:15 0.25 6,144 6,144 COMPZ RPCOM RURD P R/D slickline 13:15 14:15 1.00 6,144 6,006 COMPZ RPCOM PACK P R/U Circ hoses to set packer, pump down tbg to 2000 psi, line and to pressure test IA to 2500 psi for 10 min, charted, attempt to release from packer,observed no extra P/U weight, slack off to packer set point, line up and pressure up to 2500 psi, bleed pressure to 100 psi, P/U to release from packer observed, 30k overpull, P/U 7'space out. 14:15 16:00 1.75 6,006 6,006 COMPZ RPCOM CRIH P PJSM, R/U to displace well via reverse circ 9.6 brine& 160 bbls inhibited brine, pump @ 5 bpm, ICP = 1000 psi, FCP=650 psi. 16:00 17:00 1.00 6,006 0 COMPZ RPCOM RCST P B/D lines&R/U same, R/U&L/D 3 jts tbg for space out, M/U 10.18', 10.12'and 4.12'pup jts, M/U jt# 191 &hanger, B/D choke and kill lines, drain and flush stack, RIH and land hanger, RILDS, P/U wt=78k, S/O wt=76k. 17:00 19:15 2.25 0 0 COMPZ RPCOM PRTS P R/U&test tubing to 3000 psi for 30 min., bleed pressure to 2500 psi, test IA to 2500 psi for 30 min, bleed IA&tbg pressure to zero,all test charted. Pressured up on IA t/2500 psi to shear SOV. 19:15 20:00 0.75 0 0 COMPZ RPCOM RURD P PJSM, R/D landing&Circ hoses,set BPV per FMC rep, Line up and test from below 1000 psi for 10 min, charted. 20:00 21:15 1.25 0 0 COMPZ WHDBO RURD P PJSM, N/D BOPE ., 4, r. `. Page7or$ / t f Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 0 0 COMPZ WHDBO PRTS P PJSM, N/U adapter flange&tree, test hanger void,test tree to 250 low and 5000 high. DATA SUBMITTAL COMPLIANCE REPORT 2/16/2011 Permit to Drill 2100740 Well Name /No. KUPARUK RIV UNIT 31 -11A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21932 -01 -00 MD 9490 TVD 6251 Completion Date 8/5/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION ID Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH _ Received Comments ED C Asc Directional Survey 6000 9490 Open 4 Directional Survey 6000 9490 Open ./ED C Lis 20244 ./' /ED 6220 9490 Open 11/1/2010 MPR logs in pdf tL4g Induction /Resistivity 2 Col 6394 9490 Open 11/1/2010 MD MPR, GR tL.6g Induction /Resistivity 5 Col 6394 9490 Open 11/1/2010 TVD MPR, GR Lc Induction /Resistivity 5 Col 6394 9490 Open 11/1/2010 MD MPR, GR Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y kb Daily History Received? N Chips Received? -N-'. Formation Tops 6 N Analysis `N-d Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 2116/2011 Permit to Drill 2100740 Well Name /No. KUPARUK R!V UNIT 31 -11A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029- 21932 -01 -00 MD 9490 TVD 6251 Completion Date 8/5/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N Compliance Reviewed By: _.__--- ._------- . -._. • - _ - _ ----- ._ -._ -- Date: 4 • I Company ConocoPhillips, Alaska, Inc. Fait II BAKED Well Name 3I -11A /U ° ' (A HUGHES Date 10/12/2010 ( 9-p IINTEQ ConocoPhillips Alaska Greater Kuparuk Area * ** Data Distribution RECIPIENTS No other distribution is allowed without , OH FINAL 01-1 FINAL ' '3 C� i1`; written approval from ConocoPhillips Image files and /or Digital Data . - -., ,, contact: Lisa Wri • ht, 907 263 -4823 hardco , • rints S ConocoPhillips Alaska, Inc. ;tl Sharon Allsup -Drake a : ,,, ... Drilling Tech, ATO- 1530._. ConocoPhillips Alaska, Inc. 1 Hardcopy Prini 'r` NSK Wells Aide, NSK 69 +a1,I ATTN: MAIL ROOM 700 G Street, " Anchorage, AK 99501. ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk * / i ■ - ! _ _ - _ - _ ' , ' e a e File * * / * ** Electronic 700 G Street, CGM / TIFF LIS ,. 1 : ftp: / /b2bftp.conocophillips.com * * * * , AOGCC 1 Hardcopy Print, ; fl • * . Christine Mahnken 1 Graphic image file 1 Disk * / ` 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS l , ti;' B P 1 Hardcopy Print, ,,,`° -' C���r, � ,.; Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk * / ; David Douglas in lieu of sepia ** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 Hardcopy Print, ?rev -' Glenn Fredrick 1 Graphic image file 1 Disk*/ 1 P.O.Box 196247 in lieu of sepia ** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT ; "'.7?"" i State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ , ,,i1o, 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS DS Engineer / Rig Foreman TOTAL . Hardcop Prints 4 -` Page 1 of 4 II II + FD STATE OF ALASKA E' 0 3 MO ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO Tk a CrNOissifl 1 la. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: La, ., 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test El 2. Operator Name: 5 Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August 5, 2010 210 - 0740 / 3. Address: 6. Date Spudded: 13. API Number: P. 0. Box 100360, Anchorage, AK 99510 - 0360 July 22, 2010 50 029 - 21932 - 01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM July 28, 2010 31 - 11A Top of Productive Horizon: 8. KB (ft above MSL): 76' RKB 15. Field /Pool(s): 735' FNL, 1034' FEL, Sec. 6, T12N, R9E, UM GL (ft above MSL): 40' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2754' FNL, 2440' FEL, Sec. 6, T12N, R9E, UM 9490' MD / 6251' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 507830 y 6007088 Zone 4 9490' MD / 6251' TVD ADL 25523, 25631 TPI: x - 507371 y - 6006205 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 505974 y 6004185 Zone 4 2212' MD / 2212' TVD 2559, 2564 18. Directional Survey: Yes Q 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) 1650' MD / 1650' 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 GR/Res 6395' MD / 6206' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 Surf. 116' Surf. 116' 24" 250 sx CS II 9.625" 36# J -55 Surf. 3383' Surf. 3383' 12.25" 330 sx Class G, 544 sx AS III, 175 sx AS L I 7" 26# J -55 Surf. 6408' Surf. 6141' 8.5" 250 sx Class G, 175 sx AS I 2.375" 4.7# L -80 7600' 9490' f 6229' 6251' 3" slotted liner 24. Open to production or injection? Yes Q 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) 3.5" 6143' 6146' MD / 5977'TVD slotted liner: 6422' MD / 6230' TVD 7614' -8095' MD 6228' -6218' TVD C O�flPLE71 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8097 MD 6218' - 6251' TVD y DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none mina:, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 11, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 8/28/2010 i 17.5 hours Test Period - -> 256 899 1123 104 Bean 3922 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 168 psi 1303 24 -Hour Rate -> 315 1234 1481 24 deg. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 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. NONE RBDMS SEP 07 201 =. Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 43'/0 • • 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 1650' 1650' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk A 6428' 6235' Kuparuk A2 6467' 6263' N/A Formation at total depth: Kuparuk A2 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: / Jill Lon @ 263 - 4093 Printed Na a Ca Title: Alaska Wells Manager Signature ■••• Phone 265 -6306 Date / 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 la: 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 wet 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 31 -11A, AL1, & AL2 CTD Sidetrack Schematic Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) Updated: 9- Aug -10 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface KEY 3-1/2" Camco MMG gas lift mandrels (5) @ Equipment and perforations set in parent wellbore 2512', 3702', 4760', 5668', & 6074' am Equipment set and lateral drilled 16" 62# H -40 shoe during first CTD project @ 116' MD X' landing nipple @ 6123' MD (2.813" min ID) Baker 3-1/2" seal assembly 6131' - 6143' MD Equipment set and laterals drilled 80-40 PBR at 6132' - 6145' during second CTD project 9-5/8" 36# J -55 Baker KBH Anchor Seal Assy at 6145' MD shoe @ 3383' MD Baker SAB 40-32 packer @ 6146' MD 'X' landing nipple @ 6156' MD (2.813" min ID) Liner top @ slap' MD - Holes shot in 3-1/2" straddle at -6408' -6413' & 6213' MD 31 -11A L2PB1 (A3 sand) 31 -11A L2 Whipstock @ 6396' I ;I Kickoff from 31 -11 A @ 7423' (A3 sand Baker F1 permanent packer @ 6422' MD (e - line set) t sand) MD - 80 Sealbore extension (6425 TD @ 8500' Kickoff from 31 -11 AL2 PB1 @ 7930' (Baker monobore = v... - - ( ) Anchored billet @7930' Shorty deployment sleeve @ 6180' ` hins}n kl Solid liner from 6181 -6243' 3 straddle ' landing nipple @ 6433' MD (2.750" min ID) Slotted linerfrom TD @ 6292749' • 3'to 9079' <40 o cemented in place �Y , .ccc ticoo WLEG @ 6438' MD / Cast Iron Bridge Plug @ -6406' Q' ,t � FISH: 3 -1/2„ � ............ ----- - monobore N "} _ 31 -11A 0 whipstock at 6422' f,.� / (A2 sand (TOWS) •.- i is -- ..... ........... ... ....... .... .... .. Kickoff from 31 - 11 @ 6394.2' � ' "_ Slotted liner 7600 to 9490 I �°^� TD @ 9490' monobore l�l • "_._,::: : ::::.............. J • Anchored billet @ 7600' FISH: 3 -1/2" whipstock @ unknown depth A sand perfs .n OOP Gl) 31 -11AL1 A3: 6437' - 6454' • 31 -11 L1 (Al sand) (A2 sand) Kickoff from 31 -11A @ 7597' A2: 6457' - 6486' N Kickoff from 31 -11 @ 6409' Liner top billet @ 7423' Al: 6494' - 6503' \ L Openhole from 6409' -7590' Slotted liner from 7423' to TD ` \' Shorty deployment sleeve @ 7590' TD @ 8071' " - --- r Slotted liner from 7590 to TD TD @ 9437' • 7" 26# J -55 shoe @ 6761' MD • KU 31 -11A Co oPh flips Well Attributes Max Angle & MD TD Al y . . " -. 'e'.w Wellbore API/UWI (Field Name Well Status Inc() MD (ftKB) Act Btm (ftKB) Lon:Ks/Kbakt>s 500292193201 '.KUPARUK RIVER UNIT PROD 1 _ 9,500.0 ' •' Comment ' H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date wen •,,,,,• ,3,AT -Ln _ °.1 AN SSSV. TRDP , 150 6/22/2009 Last WO: 35.91 4/4/1989 "" " "" A oration Depth (ftKB) End Date Annotation Last Mod ... End Date _ __ Shcenmtle -AOWai ._. Last Tag: Rev Reason: SIDETRACKS Imosbor 8/7/2010 HANGER, 31 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 36.0 116.0 62.50 H % !< Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ' I, yl , ..SURFACE 9 5/8 8.765 35.0 3,383.4 36.00 J - 55 Casing Description String 0... String ID ... Top (fIKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 33.0 6,761.5 26.00 J - 55 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thtd d .. WINDOW A 7 6.000 6,396.0 6,406.0 9 - 30 ° Casing Description String 0... String ID ... Top (ftKB) Set Depth (f_. Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR,__ A LINER 23/8 j 1.995 7,599.6 9,490.0 443 I L80 _ ... STL 36-116 .._._.... Liner Details Top Depth' SAFETY MN, ' (ND) Top Inc! Nomi... 2,212 _-- Top (HKB) (ftKB) ( °) Item Description Comment ID (in) 1 7,599.6 BILLET ANCHORED BILLET 1.000 ', 8,096.1 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 Tubing Strings GAS LIF T, _____ :r. Tubing Des iption Str ng 0... li Str ng ID ... Top (ftKB) Set Depth (f... Set Depth (ND) . 1String Wt... Str g ... String Top Thrd 2,5 TUBING - Upper 3112 7...2992 310 61430 � i 930 L-80 EUE Completion Details Top Depth (TVD) Top Inel Nomi... Top (HKM) (ftKB) (1 Item Description Comment ID (in) 31.0 HANGER FMC 6" x 3 1/2" Gen IV Tubing Hanger w/ pup 2.992 SURFACE, 35 Z212.3 3 SAFETY VLV Camco 3 1/2" x 2.813" 'X' Profile TRMAXX -5E SCSSV 2.813 lit 6,123.0 NIPPLE Haliburton 3 1/2" x 2.813" 'X' Nipple 2.813 GAS LIFT, 6,131.0 SEAL ASSY Baker 80 -40 Seal Assembly (2' Space out) 3.000 3 Tubing Descnptl String O... String ID ... Top (ftKB) `Set Depth (f... Set Depth (TVD) . String ... String ... String Top Thrd TUBING - Mid 31/2 2.992 6,1321 64275 93 Wt L80 EUE r Section 1 I Comp tionDetails i;IMri 7,1 6r ,..; , r. s 1 , ,..»" r GAS LIFT, _ Top D epth 4,760 (ND) Top Inc/ Nomi... Top (ftKB) (ftKB) ( °) item Description Comment ID (in) 6,132.1 PBR Baker 80.4OPBR 3.000 6,145.5 SEAL ASSY Baker KBH -22 80-DA-40 Anchor Seal Assy 3.000 GAS LIFT, '°' 6,146.4 PACKER Baker 84-SAB-40x32 Retainer Prod. Packer 3.250 5,668 `,: 6,151.3 XO Reducing X-over Sub, 4 1/2' LTC pin x 3 1/2' EUE pin 3.010 !,. 6,156.3 NIPPLE Haliburton 2.813 "'X' Nipple 2.813 r 6,419.8 SEAL ASSY Baker 80-40 GBH -22 Seal Assy w /Locator 3.000 OAS LIFT, - 6,074 Tubing Description String 0... String ID ..Top (ftKB) Set Depth (f... Set Depth (TVD) ... [String Wt... Str ... String Top Thrd it PACKER ASSY 5 4 000 _ 6,422 1 6,438.0 ref _ l ACME It Completion Details _ Top Depth NIPPLE, 6,123 - 11 (ND) Top Intl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 6,422.1 PACKER Baker 85 'F1' Permanent Production Packer 4.650 SEAL ASSY, - _ -- s,131 �_ h PBR, 6,132 - 6,425.4 SBE Baker 80-40 SBE (5 Long) w/ XO Sub 4.000 I — 6,429.9 XO - Reducing X-Over Sub 5" BTC x 3.5" EUE 3.000 SEAL 6,145 SSY, _ 6,433.4 NIPPLE Cameo 31/2" x 2.75" 'D' Nipple 2.750 PACKER, 6,148 6,437.1 SOS Shearout Sub w/ WLEG 3.000 ':` Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth NIPPLE, 6,156 (TVD) Top Intl WHIPSTOCK, _ Top &( (ftKB) ( ° ) Description Comment Run Date ID (In) WINDOW n - _ 6,396 WHIPSTOCK BAKER MONOBORE RWS WHIPSTOCK - Sits on top of 7/26/2010 6,396-6,406 CIBP PLUG, 6,406 CEMENT Sot, 6,406 PLUG CAST IRON BRIDGE PLUG TO ISOLATE LATERAL 6/22/2010 0.000 6,213 Perforations & Slots Shot Top (ND) Btm (TVD) Dens Top (ftKB) Ben (ftKB) (ftKB) (HKB) Zone Date (sh"-- Type Comment SEAL ASSY, (' 7,614 8,096 A -2, 31 -11A 7/28/2010 32.0 SLOTS SLOTTED LINER - 0.125 "x2.5" @ 4 6,420 circumferential adjacent rows, 3" PACKER, 6,422 - 1 `!off centers staggered 18 deg, 3' - J. - - _ - non slotted ends SBE,6,425 - 8,097 9,490 A -2, A-3, A -2, 7/28/2010 32.0 SLOTS SLOTTED LINER - 0.125'x2.5" @ 4 31 -11A circumferential adjacent rows, 3" it centers staggered 18 deg, 3' non - slotted ends NIPPLE,6,433 SOS, 6,437 - Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sere TYM Type (in) (psi) Run Date Corn... 1 2,511.6 Camco MMG 1 1/2 GAS LIFT DMY R - 20 0.000 0.0 6/18/2010 PRODUCTION, 33.6,761 2 3,702.1 Camco MMG 1 1/2 GAS LIFT DMY R -20 0.000 0.0 2/19/2010 3 4,760.5 Camco MMG 1 1/2 GAS LIFT DMY R -20 0.000 0.0 6/19/2010 4 5,667.8 Camco MMG 1 1/2 GAS LIFT DMY R -20 0.000 0.0 6/21/2010 i I 5 6,074.0 Camco MMG 1 1/2 GAS LIFT DMY RDO... 0.000 0.0 6/20/2010 I I SLOTS, 7,614.8,096 SLOTS, 8,097 -9,490 A LINER, • 7,600 -9,490 TD (31 -11A), .. 9,500 ,. > . • KUP 31 -11A Conoc , hips g 4J.ITsd 0...pr wiw KB -Grd (11/ Rig Release Date 35.91 4/4/1959 WeIIC fig-31-i1A 817x29 09'.55:'2 AM -- - Sclleralc AC,ua1 HANGER, 31 - Notes: General & Safety End Date Annotation — 8/6/2010 NOTE: VIEW MULTI - LATERAL SCHEMATIC w /Alaska Schematic9.0 r ..; CONDUCTOR, 36 -116 SAFETY VLV,__ ___.. _ 2,212 I T GAS LIFT -_ -_ 2,512 It ar El i SURFACE, J 1 35 -3,383 illt GAS LIFT, - 3,702 1 .1 GASLIFf,_ 4,760 fa GAS LIFT, 5,668 lit it GAS LIFT, At 6,074 ilk NIPPLE,6,123 -- 1T : SEAL ASSY, - ' i 6,131 -I }, PBR, 8,132 ' }__ k- SEAL ASSY, 6,145 _Y^ _- PACKER, 6,146 NIPPLE, 6,156 WHIPST 6,3 WINDOW A, U 6,406 PLUG, G,6QZ, -d CEMENT ,213 6,213 SEAL ASSY, \- --,' 6,420 PACKER, 6,422 SBE, 6,425 NIPPLE, 6,433- y, SOS, 6,437 ' .!r ' ._._.. -- PRODUCTION, AI L 33 -6,761 i i i y � t STS, .t 7,614 -8 096 SLOTS, 8,097 -9,490 _. -1-. -L., A LINER, , 4a 7,600 - arrow 9 ,500 conochiJIips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 31 Pad 3I -11A 50 -029- 21932 -01 Baker Hughes INTEQ BAKER Definitive Survey Report HUGHES 11 August, 2010 f ConocoPhillips fail i Conoco Phillips gyp$ Definitive Survey Report BAKER . HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 - 11 I Project: " Kuparuk River Unit TVD Reference: 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 - 11 North Reference: TRUE ( Wa 31 - 11 Survey Calculation Method: Minimum Curvature Design: 31 -11 Database: EDM Alaska Prod v16 1 Project Kuparuk River Unit 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 31-1 Well Position +NI 0.00 ft Northing: 6,007,088.16ft Latitude: 70° 25' 50.121 N +E/ - 0.00 ft Easting: 507,830.23ft Longitude: 149° 56' 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft . Welibore ,, 3I -11A Magnetics Model Name Sample Date Declination Dip Angie Field Strength ( °) (0) (nT) .. BGGM2009 7/23/2010 17.05 79.85 57,389 Design 31 -11A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,300.00 i Vertical Section: Depth From (TVD) +N /-S +E/ -W Direction (ft) (ft) (ft) ( 76.00 0.00 0.00 212.65 Survey Program Date From To Survey Survey (ft) Survey (Wellbore) ' Tool Name , Description SfartDate End Date 100.00 6,300.00 31 -11 (31 -11) BOSS -GYRO Sperry-Sun BOSS gyro multishot 1/12/2001 6,394.00 9,452.80 31 -11A (31 -11A) MWD MWD - Standard 7/25/2010 7/28/2010 I 8/11/2010 8:47:34AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips tea. Conoco Phillips Definitive Survey Report ,ONES; Alaska i Compan € ^ ConocoPhillips(Alaska) Inc. Local Co -ordinate Reference: 31 -11 Project: Kuparuk River Unit TYD Reference: 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 © 76.00ft (31 -11) Well: 31 -11 North Reference: TRUE Wellbore: 31 -11 Survey Calculation Method: Minimum Curvature Design: 31 -11 Database: EDM Alaska Prod v16 6Ir Survey Map Map', Vertical nft) 1 Az1 1 T (ft) +(ft) + /W Northing Eas (1D 0 S ec t i on Survey Tool Name, Annotat 6,000.00 23.60 202.80 5,842.77 5,766.77 - 702.75 - 380.08 6,006,385.08 507,450.93 0.20 ( 796.76 BOSS -GYRO (1) • 6,100.00 23.27 202.60 5,934.52 5,858.52 - 739.44 - 395.42 6,006,348.38 507,435.62 0.34 835.93 BOSS -GYRO (1) t 6,200.00 23.38 203.19 6,026.35 5,950.35 - 775.92 - 410.83 6,006,311.89 507,420.26 0.26 874.95 BOSS -GYRO (1) P 6,300.00 23.10 205.69 6,118.23 6,042.23 - 811.83 - 427.15 6,006,275.96 507,403.98 1.03 913.99 MWD (2) TIP 6,394.00 22.04 209.91 6,205.04 6,129.04 - 843.74 - 443.94 6,006,244.04 507,387.22 2.06 949.92 MWD (2) KOP; Top of Window 6,420.07 31.02 204.12 6,228.34 6,152.34 -854.14 -449.13 6,006,233.64 507,382.04 35.81 961.47 MWD (2) Interpolated AZI 6,450.40 44.80 200.55 6,252.22 6,176.22 - 871.36 - 456.11 6,006,216.41 507,375.08 45.99 979.74 MWD (2) Interpolated AZI 6,476.63 55.52 198.53 6,269.00 6,193.00 - 890.32 - 462.81 6,006,197.44 507,368.40 41.29 999.32 MWD (2) 6,505.18 67.94 211.30 6,282.54 6,206.54 - 912.94 - 473.50 6,006,174.81 507,357.74 58.58 1,024.13 MWD (2) 6,535.12 78.35 218.08 6,291.22 6,215.22 - 936.43 - 489.81 6,006,151.31 507,341.45 40.95 1,052.71 MWD (2) 1 6,565.57 81.87 230.61 6,296.47 6,220.47 - 957.82 - 510.75 6,006,129.90 507,320.54 42.14 1,082.01 MWD (2) 6,595.44 85.73 243.52 6,299.71 6,223.71 - 973.92 - 535.62 6,006,113.78 507,295.69 44.86 1,108.99 MWD (2) C 6,625.41 92.98 255.45 6,300.04 6,224.04 - 984.39 - 563.61 6,006,103.28 507,267.70 46.56 1,132.91 MWD (2) 6,655.55 92.82 262.85 6,298.52 6,222.52 - 990.05 - 593.16 6,006,097.58 507,238.17 24.53 1,153.62 MWD (2) t 6,685.68 90.52 266.71 6,297.64 6,221.64 - 992.79 - 623.14 6,006,094.81 507,208.19 14.91 1,172.10 MWD (2) i I 6,715.44 91.93 270.60 6,297.00 6,221.00 - 993.49 - 652.88 6,006,094.09 507,178.46 13.90 1,188.73 MWD (2) i 6,745.56 95.16 275.14 6,295.14 6,219.14 - 991.99 - 682.89 6,006,095.56 507,148.45 18.47 1,203.66 MWD (2) 6,775.55 95.38 275.57 6,292.39 6,216.39 - 989.20 - 712.63 6,006,098.31 507,118.71 1.61 1,217.36 MWD (2) 6,805.54 95.35 270.41 6,289.58 6,213.58 - 967.64 - 742.43 6,006,099.84 507,088.91 17.13 1,232.13 MWD (2) 6,835.65 95.81 264.98 6,286.65 6,210.65 - 988.85 - 772.37 6,006,098.60 507,058.98 18.01 1,249.29 MWD (2) 6,865.62 96.25 260.78 6,283.50 6,207.50 - 992.54 - 801.93 6,006,094.88 507,029.42 14.01 1,268.35 MWD (2) 6,895.78 95.90 256.22 6,280.31 6,204.31 - 998.52 - 831.31 6,006,088.87 507,000.05 15.08 1,289.24 MWD (2) 6,925.94 96.46 251.25 6,277.06 6,201.06 - 1,006.91 - 860.09 6,006,080.45 506,971.28 16.49 1,311.83 MWD (2) 6,955.87 96.74 245.83 6,273.61 6,197.61 - 1,017.79 - 887.75 6,006,069.55 506,943.64 18.01 1,335.91 MWD (2) l 6,985.49 95.47 240.08 6,270.46 6,194.46 - 1,031.17 - 913.97 6,006,056.13 506,917.44 19.77 1,361.33 MWD (2) 7,015.70 95.72 238.61 6,267.52 6,191.52 -1,046.50 6,006,040.78 506,891.59 4.91 1,388.19 MWD (2) 7,045.61 96.43 244.09 6,264.35 6,188.35 1,060.76 - 965.92 6,006,026.50 506,865.52 18.37 1,414.27 MWD (2) 7,075.62 95.44 248.15 6,261.24 6,185.24 -1,072.84 - 993.21 6,006,014.39 506,838.25 13.85 1,439.16 MWD (2) t 7,105.92 94.58 254.00 6,258.60 6,182.60 - 1,082.62 - 1,021.75 6,006,004.58 506,809.72 19.44 1,462.80 MWD (2) ! 7,135.50 95.41 258.60 6,256.02 6,180.02 -1,089.60 - 1,050.37 6,005,997.57 506,781.11 15.74 1,484.11 MWD (2) j L 8/11/2010 8:47:34AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips g ConocoPhillips Definitive Survey Report BAKER HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 - 11 Pro Kuparuk River Unit TVD Reference: 31 -11 © 76.00ft (31 -11) I Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 - 11 North Reference: TRUE i Wellbore: 31 - 11 Survey Calculation Method: Minimum Curvature Design: 31 -11 Database: EDM Alaska Prod v16 r ..---- vey -.., c Map Map Vertical MD Inc A4 TVD TVDSS +N/-S +EI-W Northing Easting DU Section Survey Tool Name Annotation ( ': (1 (°) (ft} (ft) (ft) (ft) (ft) (ft) /100) , (ft) 7,165.42 94.89 263.46 6,253.33 6,177.33 - 1,094.24 - 1,079.80 6,005,992.89 506,751.69 16.27 1,503.90 MWD (2) • 7,195.55 95.38 269.19 6,250.63 6,174.63 - 1,096.17 - 1,109.73 6,005,990.94 506,721.76 19.01 1,521.67 MWD (2) 7,225.64 95.77 274.18 6,247.71 6,171.71 - 1,095.29 - 1,139.66 6,005,991.79 506,691.84 16.56 1,537.07 MWD (2) 7,255.65 96.08 275.62 6,244.61 6,168.61 - 1,092.74 - 1,169.40 6,005,994.31 506,662.10 4.88 1,550.97 MWD (2) 7,285.72 95.04 270.92 6,241.69 6,165.70 - 1,091.03 - 1,199.27 6,005,995.98 506,632.23 15.94 1,565.65 MWD (2) 7,315.34 94.67 265.79 6,239.19 6,163.19 - 1,091.88 - 1,228.76 6,005,995.10 506,602.74 17.30 1,582.28 MWD (2) 7,345.56 96.09 260.72 6,236.35 6,160.35 - 1,095.41 - 1,258.63 6,005,991.54 506,572.88 17.35 1,601.37 MWD (2) 7,375.71 95.01 256.79 6,233.43 6,157.43 - 1,101.26 - 1,288.05 6,005,985.66 506,543.46 13.46 1,622.17 MWD (2) 7,405.30 92.15 251.77 6,231.59 6,155.59 - 1,109.26 - 1,316.47 6,005,977.63 506,515.06 19.50 1,644.24 MWD (2) 7,435.51 91.44 247.18 6,230.64 6,154.64 - 1,119.85 - 1,344.74 6,005,967.02 506,486.80 15.37 1,668.40 MWD (2) 7,465.60 90.28 241.40 6,230.19 6,154.19 - 1,132.89 - 1,371.83 6,005,953.94 506,459.72 19.59 1,694.00 MWD (2) 7,495.37 89.82 234.77 6,230.16 6,154.16 - 1,148.62 - 1,397.09 6,005,938.19 506,434.49 22.32 1,720.87 MWD (2) 7,525.54 90.98 228.95 6,229.95 6,153.95 - 1,167.25 - 1,420.81 6,005,919.54 506,410.79 19.67 1,749.35 MWD (2) 7,555.57 90.83 222.53 6,229.48 6,153.48 - 1,188.19 - 1,442.30 6,005,898.58 506,389.32 21.38 1,778.58 MWD (2) 7,585.68 90.95 215.18 6,229.01 6,153.01 - 1,211.62 - 1,461.17 6,005,875.13 506,370.47 24.41 1,808.49 MWD (2) 7,615.75 91.90 209.41 6,228.26 6,152.26 - 1,237.02 - 1,477.23 6,005,849.72 506,354.45 19.44 1,838.54 MWD (2) 7,645.58 91.32 201.87 6,227.42 6,151.42 - 1,263.88 - 1,490.12 6,005,822.84 506,341.58 25.34 1,868.11 MWD (2) 7,675.67 91.63 200.57 6,226.64 6,150.64 - 1,291.92 - 1,501.01 6,005,794.79 506,330.73 4.44 1,897.60 MWD (2) 7,705.60 90.80 204.77 6,226.01 6,150.01 - 1,319.53 - 1,512.54 6,005,767.18 506,319.23 14.30 1,927.06 MWD (2) 7,735.59 90.77 207.99 6,225.60 6,149.60 - 1,346.39 - 1,525.86 6,005,740.31 506,305.93 10.74 1,956.86 MWD (2) 7,765.39 90.46 214.85 6,225.28 6,149.28 - 1,371.80 - 1,541.39 6,005,714.88 506,290.44 23.04 1,986.64 MWD (2) 7,795.54 89.88 220.44 6,225.19 6,149.19 - 1,395.66 - 1,559.79 6,005,691.00 506,272.06 18.64 2,016.66 MWD (2) 7,825.51 89.57 218.08 6,225.33 6,149.33 - 1,418.87 - 1,578.76 6,005,667.78 506,253.12 7.94 2,046.43 MWD (2) 7,855.63 89.60 210.50 6,225.55 6,149.55 - 1,443.73 - 1,595.72 6,005,642.90 506,236.19 25.17 2,076.51 MWD (2) 7,885.44 90.43 205.03 6,225.54 6,149.54 - 1,470.10 - 1,609.60 6,005,616.52 506,222.34 18.56 2,106.20 MWD (2) 7,915.65 89.63 199.70 6,225.53 6,149.53 - 1,498.03 - 1,621.09 6,005,588.58 506,210.88 17.84 2,135.92 MWD (2) 7,947.89 90.58 194.65 6,225.47 6,149.47 - 1,528.82 - 1,630.60 6,005,557.78 506,201.39 15.94 2,166.98 MWD (2) 7,975.87 91.23 190.05 6,225.03 6,149.03 - 1,556.14 - 1,636.59 6,005,530.46 506,195.44 16.60 2,193.21 MWD (2) 8,005.67 90.92 183.47 6,224.47 6,148.47 - 1,585.71 - 1,640.09 6,005,500.89 506,191.97 22.10 2,220.00 MWD (2) [ 8,035.00 93.56 176.70 6,223.32 6,147.32 - 1,615.00 - 1,640.14 6,005,471.60 506,191.95 24.76 2,244.68 MWD (2) L. 8,065.23 95.44 171.24 6,220.95 6,144.95 - 1,644,96 - 1,636.97 6,005,441.65 506,195.15 19.05 2,268.20 MWD (2) 8/11/2010 8:47:34AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips KA ConocoPhillips Definitive Survey Report BAKER ES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 - 11 Project: Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 © 76.00ft (31 -11) Well: 31 - 11 North Reference: TRUE Wellbore:'; 31 - 11 Survey Calculation Method: Minimum Curvature Design: 31 - 11 Database: EDM Alaska Prod v16 L Survey MD Inc Azi ND T +N/S +E/ -W Map Map DLS (ft) ( °) ( °) n Vertical Northing Easting ° ((g ' Section survey Tool Name Annotation () ( (�) (ft) (ft) Iftl. ) (ft) 8,095.08 96.80 166.14 6,217.76 6,141.76 -1,674.05 6,005,412.56 506,200.99 17.59 2,289.55 MWD (2) 8,125.05 99.10 160.48 6,213.61 6,137.61 -1,702.47 - 1,622.64 6,005,384.16 506,209.54 20.22 2,308.89 MWD (2) i 8,155.79 97.32 154.76 6,209.22 6,133.22 - 1,730.59 - 1,611.06 6,005,356.05 506,221.15 19.30 2,326.31 MWD (2) 8,185.48 94.39 151.33 6,206.19 6,130.19 - 1,756.91 - 1,597.67 6,005,329.75 506,234.56 15.15 2,341.25 MWD (2) 8,215.59 90.71 143.81 6,204.85 6,128.85 - 1,782.27 - 1,581.55 6,005,304.41 506,250.71 27.78 2,353.91 MWD (2) 8,245.50 90.86 144.35 6,204.44 6,128.44 - 1,806.49 - 1,564.01 6,005,280.21 506,268.27 1.87 2,364.84 MWD (2) 8,275.64 93.04 152.30 6,203.41 6,127.41 - 1,832.11 - 1,548.20 6,005,254.61 506,284.10 27.33 2,377.87 MWD (2) 8,305.74 92.03 157.72 6,202.08 6,126.08 - 1,859.35 - 1,535.51 6,005,227.39 506,296.83 18.30 2,393.96 MWD (2) 8,335.75 91.69 163.44 6,201.11 6,125.11 - 1,887.63 - 1,525.54 6,005,199.12 506,306.83 19.08 2,412.39 MWD (2) 8,365.48 91.32 168.69 6,200.32 6,124.32 - 1,916.46 - 1,518.38 6,005,170.30 506,314.01 17.70 2,432.81 MWD (2) 8,395.42 89.72 173.95 6,200.05 6,124.05 - 1,946.05 - 1,513.87 6,005,140.72 506,318.56 18.36 2,455.28 MWD (2) 8,425.09 87.57 177.43 6,200.75 6,124.75 - 1,975.62 - 1,511.64 6,005,111.15 506,320.82 13.78 2,478.98 MWD (2) 8,455.39 88.16 182.59 6,201.88 6,125.88 - 2,005.89 - 1,511.64 6,005,080.89 506,320.84 17.13 2,504.47 MWD (2) 8,490.51 87.48 188.56 6,203.22 6,127.22 - 2,040.80 - 1,515.05 6,005,045.98 506,317.47 17.10 2,535.70 MWD (2) 8,520.15 88.56 193.98 6,204.25 6,128.25 - 2,069.84 - 1,520.84 6,005,016.93 506,311.72 18.63 2,563.27 MWD (2) 8,550.36 87.94 199.56 6,205.17 6,129.17 - 2,098.74 - 1,529.55 6,004,988.03 506,303.04 18.58 2,592.30 MWD (2) 8,580.37 87.30 205.51 6,206.42 6,130.42 - 2,126.42 - 1,541.03 6,004,960.34 506,291.58 19.92 2,621.81 MWD (2) 8,610.31 88.22 210.62 6,207.59 6,131.59 - 2,152.81 - 1,555.10 6,004,933.93 506,277.54 17.33 2,651.62 MWD (2) d 8,640.18 87.85 215.38 6,208.61 6,132.61 - 2,177.84 - 1,571.36 6,004,908.89 506,261.32 15.97 2,681.46 MWD (2) I 8,670.22 88.07 222.13 6,209.68 6,133.68 - 2,201.24 - 1,590.14 6,004,885.48 506,242.56 22.47 2,711.30 MWD (2) ilk 8,700.26 87.67 226.56 6,210.80 6,134.80 - 2,222.70 - 1,611.12 6,004,863.99 506,221.61 14.80 2,740.68 MWD (2) t 8,730.36 87.45 232.35 6,212.08 6,136.08 - 2,242.24 - 1,633.96 6,004,844.43 506,198.79 19.23 2,769.46 MWD (2) 1 8,760.30 87.97 236.65 6,213.28 6,137.28 - 2,259.61 - 1,658.31 6,004,827.04 506,174.46 14.46 2,797.22 MWD (2) 8,790.01 88.07 236.82 6,214.31 6,138.31 - 2,275.90 - 1,683.13 6,004,810.73 506,149.65 0.66 2,824.33 MWD (2) 8,820.26 88.40 231.96 6,215.24 6,139.24 - 2,293.50 - 1,707.71 6,004,793.10 506,125.10 16.10 2,852.41 MWD (2) 8,850.21 88.65 226.71 6,216.01 6,140.01 - 2,313.00 - 1,730.41 6,004,773.58 506,102.42 17.54 2,881.08 MWD (2) 8,880.36 88.10 220.87 6,216.86 6,140.86 - 2,334.74 - 1,751.26 6,004,751.81 506,081.60 19.45 2,910.63 MWD (2) 8,910.43 88.10 216.60 6,217.86 6,141.86 - 2,358.18 - 1,770.06 6,004,728.36 506,062.82 14.19 2,940.51 MWD (2) 8,940.71 88.37 211.05 6,218.80 6,142.80 - 2,383.32 - 1,786.90 6,004,703.21 506,046.01 18.34 2,970.76 MWD (2) 8,972.14 89.57 205.85 6,219.36 6,143.36 - 2,410.94 - 1,801.86 6,004,675.58 506,031.08 16.98 3,002.09 MWD (2) 9,000.28 91.66 201.06 6,219.06 6,143.06 - 2,436.74 - 1,813.06 6,004,649.76 506,019.91 18.57 3,029.85 MWD (2) 8/11/2010 8:47:34AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips � � ConocoPhillips Definitive Survey Report BAKER S Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Refe rence: 31 -11 Project: Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 -11 North Reference: TRUE W@libore :', 31 -11 Survey Calculation Method; Minimum Curvature Design: 31 -11 Database: EDM Alaska Prod v16 Survey Map Map, Vertical MD Inc Az' TVD TVDSS +PUS +E1-W Northing smiting D Section Survey Tool Name Annotation (ft) 42 93.47 (*) , ( f 217.71 (ft) (ft) (ft) (ft) (ft)- ( /100 ($) () 6,141.71 - 2,465.24 - 1,822.73 6,004,621.25 506,010.27 16.48 3,059.07 MWD (2) 9,060.42 89.11 198.01 6,217.03 6,141.03 - 2,493.88 - 1,831.61 6,004,592.61 506,001.42 15.46 3,087.98 MWD (2) 9,090.22 88.65 202.69 6,217.62 6,141.62 - 2,521.81 - 1,841.97 6,004,564.67 505,991.09 15.78 3,117.08 MWD (2) 9,119.97 88.50 207.74 6,218.36 6,142.36 - 2,548.71 - 1,854.64 6,004,537.76 505,978.46 16.98 3,146.56 MWD (2) 9,150.06 88.16 205.91 6,219.23 6,143.23 - 2,575.55 - 1,868.21 6,004,510.91 505,964.91 6.18 3,176.48 MWD (2) 9,180.20 87.94 200.45 6,220.26 6,144.26 - 2,603.23 - 1,880.06 6,004,483.22 505,953.09 18.12 3,206.18 MWD (2) 9,210.11 86.81 195.32 6,221.63 6,145.63 - 2,631.65 - 1,889.23 6,004,454.79 505,943.95 17.54 3,235.06 MWD (2) 9,240.35 84.31 191.84 6,223.97 6,147.97 - 2,660.95 - 1,896.31 6,004,425.49 505,936.90 14.14 3,263.55 MWD (2) 9,270.39 83.32 187.43 6,227.21 6,151.21 - 2,690.39 - 1,901.31 6,004,396.05 505,931.93 14.96 3,291.03 MWD (2) 9,300.20 83.26 182.13 6,230.70 6,154.70 - 2,719.88 - 1,903.78 6,004,366.56 505,929.50 17.66 3,317.19 MWD (2) 9,330.26 83.63 176.69 6,234.13 6,158.13 - 2,749.73 - 1,903.47 6,004,336.71 505,929.84 18.02 3,342.16 MWD (2) 9,370.23 84.03 169.81 6,238.43 6,162.43 - 2,789.17 - 1,898.80 6,004,297.28 505,934.55 17.14 3,372.85 MWD (2) 9,390.20 84.07 166.53 6,240.50 6,164.50 - 2,808.61 - 1,894.73 6,004,277.85 505,938.64 16.34 3,387.02 MWD (2) 9,415.26 84.43 161.92 6,243.01 6,167.01 - 2,832.59 - 1,887.95 6,004,253.87 505,945.44 18.36 3,403.56 MWD (2) 9,445.63 83.70 156.62 6,246.16 6,170.16 - 2,860.84 - 1,877.26 6,004,225.64 505,956.16 17.52 3,421.57 MWD (2) 9,452.80 83.69 155.33 6,246.94 6,170.94 - 2,867.35 - 1,874.36 6,004,219.14 505,959.06 17.88 3,425.48 MWD (2) 9,490.00 83.69 155.33 6,251.03 6,175.03 - 2,900.94 - 1,858.93 6,004,185.56 505,974.53 0.00 3,445.45 PROJECTED to TD 8/11/2010 8 :47 :34AM Page 6 COMPASS 2003.16 Build 69 31 -11 Well Events Summary DATE SUMMARY • 6/11/10 LOG GR /CCL /PRESS/TEMP FOR PRE SIDETRACK REFERENCE LOG. LOGGED BHPS: 6400'= 3962 PSI, 156 DEGF & 6300'= 3927 PSI, 152 DEGF. 6/14/10 DRIFT TBG W/ 2.78" DMY PLUG (OAL = 46 ") TO 6170' RKB. PULLED GLV @ 5668' RKB, LOST TOOL STRING @ —5200' SLM. TAG FISH W/ 2.74" LIB @ 5607' SLM (CLEAN ROPE SOCKET W/ WIRE PRESENT) FISH IN GLM @ 5668' RKB. FISH IN HOLE= 37.5' OAL & —30' OF .108 WIRE. IN PROGRESS. 6/15/10 ATTEMPTED PULL 37.5' TOOLSTRING FROM 5607' SLM. PUMPED 11 BBL DSL, T & IA TRACKED TO 2500 PSI; APPARENT SAND BRIDGE IN TBG. MOVED FISH UPHOLE 28' TO 5579' SLM. IN PROGRESS. 6/16/10 RECOVERED —30' WIRE & TOOLSTRING LOST 6/14/2010. 1.5" GLV PULLED 6/14/2010 MISSING IN WELL. IN PROGRESS. 6/17/10 RECOVERED GLV LOST 6/14/10. BAILED THROUGH SAND BRIDGES @ 6095' & 6122' SLM. TAGGED WITH 2.79" GAUGE @ 6391' SLM. BRUSHED X NIPPLE @ 6123' RKB & SET 2.813" XX PLUG @ SAME. IN PROGRESS. 6/18/10 SET CATCHER ON XX PLUG @ 6123' RKB. PULLED GLVs @ 4760', 3702' & 2511' RKB. SET DVs @ 5667', 4760', 3702' & 2511' RKB. BLED IA TO VERIFY VALVES ARE SET; TBG TRACKING IA. PULLED OV @ 6074' RKB, CHECK OK. IN PROGRESS. 6/19/10 VERIFIED DVs SET WITH HOLEFINDER. CIRCULATED 50 BBL DSL TO LOAD WELL. SET DV @ 6074' RKB. TESTED TBG 2000 PSI, PASSED. DRAW DOWN TEST ON IA, PASSED. MITIA 2500 PSI, PASSED. PULLED CATCHER SUB. IN PROGRESS. 6/20/10 PULLED 2.81" XX PLUG @ 6123' RKB. DRIFTED & TAGGED @ 6395' SLM, EST. 6418' RKB, WITH 2.63" CENT, BLB & 2.77" LIB (OAL =55 "). LIB INDICATES FILL. CLOSURE TESTED TRMAXX -5E SSSV, GOOD. READY FOR E /L. 6/22/10 SET BAKER 3.5" CIBP. TOP OF CIBP SET AT A DEPTH OF 6405 R5'. BOTTOM OF CIBP SET AT A DEPTH OF 6407'. CCL TO BOTTOM OF CIBP MEASURED 14.96'. CCL STOP DEPTH RECORDED AT 6392'. 6/28/10 PERFORM POS/ NEG TESTS ON CIBP. DRIFTED TBG WITH DUMMY WHIPSTOCK (2.65" x 18.3') TO ((e/ TOP OF CIBP @ 6406' RKB. COMPLETE. VV 7/7/10 T -POT (PASSED), T -PPPOT (PASSED), IC -POT (PASSED), IC -PPPOT (PASSED), MITOA (PASSED), PT & DD TEST ON SV (PASSED), MV (PASSED), SSV (PASSED) 2 8/9/10 GAUGED TBG WITH 2.80" GAUGERING TO 6180' RKB. PERFORMED 30 MIN SBHPS @ 6180' RKB = 3861 PSI, 143 DEG F. 20 MIN GRADIENT STOP @ 6060' = 3798 PSI.SET CATCHER SUB ON LINER TOP @ 6180' RKB.REPLACED 1.5" DV WITH 1/4" ORFICE @ 6074' RKB.PULLED 1.5" DV @ 5667' RKB.IN P65 PROGRESS 8/10/10 SET GLV @ 5667' RKB. REPLACED DVs WITH GLVs @ 4760', 3702', AND 2511' RKB. DRAWDOWN IA, (4� GOOD. PULLED CATCHER FROM LINER TOP. READY FOR FLOWBACK OPERATIONS. C� I ConocoPhitlips Time Log & Summary Wel/view Web Reporting Report s e Well Name: 31 -11 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 7/20/2010 7:00:00 AM Rig Release: 8/6/2010 4:00:00 PM Time Logs ` F; Date From To Dui' S. Depth E. Depth Phase Code ! Subcode T Comment 07/19/2010 24 hr Summary Rig Released from 1R-06, travel to 31 -11 10:00 21:30 11.50 MIRU MOVE MOB T Move from 1R-06 to 31 -11 21:30 00:00 2.50 MIRU MOVE MOB T Arrive at 31, remove jeeps from units, site inspection with DSO. Spot Sub module over well. 07/20/2010 Test BOP's, remove BPV, start cutting CT 00:00 07:00 7.00 MIRU MOVE MOB T MIRU, 07:00 08:00 1.00 MIRU WHDBO NUND T Rig Accepted. Nipple up second swab and wing valves 08:00 10:30 2.50 MIRU WHDBO NUND T Nipple up BOP stack fP 10:30 20:30 10.00 MIRU WHDBO BOPE P BOP testing 20:30 00:00 3.50 SURPRI WELLPF SLPC P LD test joint, RU remove BPV. ?�Zo Prepare to cut CT 07/21/2010 Complete BOP testing, cut 3300' CT, PU/MU and RIH WS setting at 6394.6' TOWS. POOH. PU /MU milling BHA, RIH at 4650' CTMD Injector making loud scraping noises. POOH to repair 00:00 03:00 3.00 SURPRI WELLPF SLPC P Cutting CT 03:00 03:45 0.75 SURPRI WELLPF SFTY P Stop operations due to floor hand getting struck in cheek with E -line. Send worker to medic. Hold PJSM on incident. Discuss operation procedure and what to do different in order for cable not to strike anyone. Cut E -line with every CT cut 03:45 07:00 3.25 SURPRI WELLPF SLPC P Continue cutting CT 07:00 08:00 1.00 SURPRI WELLPF SLPC P RU to pump slack, replaced all o -rings on lubricator, pump slack 08:00 08:30 0.50 SURPRI WELLPF SLPC P Cut addtional 38' to find wire. Cut total of 3290' CT 08:30 11:00 2.50 SURPRI WELLPF SLPC P Install CTC and pull test to 40K. MU e -line head and PT to 4000 PSI. PT both PDLs to 4000 PSI. PT tiger tank line to 4000 PSI 11:00 12:00 1.00 SURPRI WELLPF SLPC P Stab injector to well and pump forward 1.5 CT volume at 1.5 BPM 12:00 13:00 1.00 PROD1 RPEQP1PULD T MU whipstock BHA 13:00 15:00 2.00 PROD1 RPEQP1TRIP T RIH, Tie in at 6240, +11'. 28K PUW, 20K RIW. Tag CIBP at 6404.7 with 2.4K WOB. PU and tag at 6404.5 with 800 WOB. Set WS with .5 BPM, 3000 PSI. TOWS at 6394.6 Page 1 of 15 • • Time Logs Date From . To =... .: Dur S. Depth E. Depth Phase Code > Subcode " T Comment 15:00 15:30 0.50 PROD1 RPEQPI CIRC T Circulate well over to 9.4 flo -pro for milling operations. 15:30 17:00 1.50 PROD1 RPEQP1TRIP T POOH 17:00 18:00 1.00 PROD1 RPEQP1PULD T Lay down 18:00 18:30 0.50 PROD1 RPEQP1SFTY P Crew Change, PJSM 18:30 19:30 1.00 0 0 PROD1 WHPST PULD T PU /MU Milling BHA, Service injector head. 19:30 20:30 1.00 71 4,675 PROD1 WHPST TRIP T RIH 20:30 21:00 0.50 4,675 4,675 PROD1 WHPST TRIP T Loud abnormal noises coming from injector head, Skate bearings broke in skates. ** * * *NABORS down time * **** 1/2 hour billable repair time, 2 1/2 hours non billable. 21:00 00:00 3.00 4,675 0 PROD1 WHPST TRIP T POOH 07/22/2010 Complete repairs on injector, PU milling BHA mill window 00:00 01:00 1.00 1,650 595 PROD1 WHPST TRIP T Stop POOH, Injector making loud crunching noises. Inspect. Bearings crunching. 01:00 02:00 1.00 595 0 PROD1 WHPST TRIP T Continue POOH 5 -10 FPM, with extreme caution, monitoring for pipe damage. 02:00 02:15 0.25 0 0 PROD1 WHPST SFTY T At surface, hold PJSM 02:15 02:45 0.50 0 0 PROD1 WHPST PULD T ,LD BHA 02:45 03:00 0.25 0 0 PROD1 RIGMNT RGRP T PJSM, Prepare to unstab CT 03:00 04:00 1.00 0 0 PROD1 RIGMNT RGRP T Prepare to unstab CT 04:00 04:30 0.50 0 0 PROD1 RIGMNT RGRP T Unstab CT 04:30 15:00 10.50 0 0 PROD1 RIGMNT RGRP T Repair skates from injector head 15:00 17:00 2.00 0 0 PROD1 RIGMNT RGRP T Install CTC, pull test to 40K, install e -line head /UQC, PT to 4000 psi. 17:00 18:15 1.25 0 0 PROD1 RIGMNT RGRP T PJSM, MU milling BHA . 18:15 19:00 0.75 73 4,675 PROD1 WHPST TRIP T RIH 19:00 19:42 0.70 4,675 6,259 PROD1 WHPST TRIP T Continue RIH * ** *Nabors back on billable time * * * ** ✓ Total of 19 hours of non - billable repair time for the day 19:42 19:48 0.10 6,259 6,286 PROD1 WHPST DLOG T Tie in depth, correct +6' Perform weight check 15.5K, RIH 19:48 20:00 0.20 6,286 6,394 PROD1 WHPST MILL T Dry tag pinch point 6394.4', PU online with pumps 1.4BPM, 2378 CTP, 361 off bottom Diff PSI, RIH Page 2 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment . 20:00 00:00 4.00 6,394 6,397 PROD1 WHPST MILL T Start milling 6394.2..5 -2.5K WOB. 80 -175 diff psi, 1 FPH keeping diff psi lower than 300 psi. U /123/2010 Milled TOW from 6394.2' to 6403'. Mill additional 7' of formation to 6410.2'. Back ream & dry run were clean. Swap mud, POOH. 00:00 00:30 0.50 6,397 6,398 PROD1 WHPST MILL T Indication mill is in center line of _j 3.5 ", WOB increasing, motor work decreasing, Continue to mill .5 -1 D FPH, 80 -175 diff psi, 2 -3K WOB with WOB dropping off and diff psi �' A increasing. slowing ROP at times to let mill off 00:30 02:45 2.25 6,398 6,400 PROD1 WHPST MILL T Indication mill has made contact with 7 ", WOB and motorwork increasing together, stop milling. Back ream up and down 3 times, Looks good. Offline with pumps, dry run up and down, Looks good. 02:45 04:42 1.95 6,400 0 PROD1 WHPST TRIP T POOH 04:42 07:00 2.30 0 74 PROD1 WHPST PULD T Flow check well and swap BHA, with crew change out 07:00 08:48 1.80 73 6,240 PROD1 WHPST TRIP T RIH. Taking thermal images at variable speeds and traction pressure settings 08:48 09:06 0.30 6,240 6,399 PROD1 WHPST DLOG T Tie in, 09:06 14:06 5.00 6,399 6,403 PROD1 WHPST MILL T Start time milling, 2500 CTP, 530 PSI DH differential pressure at free spin, 12K RIW, 22K PUW 14:06 14:51 0.75 6,403 6,404 PROD1 WHPST MILL T Lose WOB, Indication milling bottom of window, Continue milling 1 FPH 14:51 18:51 4.00 6,404 6,409 PROD1 WHPST MILL T 15% formation in returns confirming casing exit. start closing MP choke to 300psi. Add 50psi every 1 foot drilled. Continue drilling formation 1 FPH. 18:51 20:51 2.00 6,409 6,410 PROD1 WHPST MILL T Increased to 2 fph while drilling formation down to 6410.2' 20:51 22:30 1.65 6,410 6,410 PROD1 WHPST REAM T Backreaming passes - 1st pass HS slight weight drag @ 6399', second pass - clean. 45 ROHS - slight motor work - clean weight 45 LOHS - slight motor work - weight drag @ 6405' - due to roliing TF all the way around. 45 LOHS - slight motor work - clean weight 22:30 23:00 0.50 6,410 6,300 PROD1 WHPST CIRC T Dry run - clean. P/U to 6350' and perform mud swap. 23:00 00:00 1.00 6,300 2,000 PROD1 WHPST TRIP T POOH to change BHA 07/24/2010 Drill build to 6635', log RA tag @ 6401'. TOW = 6394.6', BOW = 6403.6'. Pull BHA # 6 due to motor failure. Window drifts are clean. 00:00 01:00 1.00 2,000 74 PROD1 WHPST TRIP T POOH. CT @ surface, hold pre -job for undeploying. Page 3 of 15 Time Logs Date: From . To Dur S. Depth E. Depth Phase ..Code Subcode T Comment 01:00 02:30 1.50 74 0 PROD1 WHPST PULD T Undeploy Milling BHA. Bit 2.79" No -go. 02:30 03:30 1.00 0 0 PROD1 DRILL EQRP T Pull apart MP choke assembly due to medal shaving from window milling - stem & seat washed out. Service injector. Inspect BHA & CT connector. 03:30 04:00 0.50 0 0 PROD1 DRILL SFTY P Hold Pre -spud with new crew. 04:00 05:30 1.50 0 0 PROD1 DRILL PULD T Begin P/U Build BHA with 2.4 AKO a §sembly 05:30 07:00 1.50 0 6,250 PROD1 DRILL TRIP T RIH 07:00 07:06 0.10 6,250 6,274 PROD1 DRILL DLOG T Tie in depth, +5' correction, closed EDC 07:06 07:36 0.50 6,274 6,410 PROD1 DRILL TRIP T RIH to drill 07:36 11:51 4.25 6,410 6,550 PROD1 DRILL DRLG T Drill Ahead 1.3 BPM, 3250 CTP, 410 WHP, 1.5K -2K WOB, 8 -10K CTW, 12.9 ECD, 20 -50 FPH 11:51 12:06 0.25 6,550 6,550 PROD1 DRILL WPRT T Wiper tri p to window, 16.5K PUW 12:06 13:36 1.50 6,550 6,635 PROD1 DRILL DRLG T Drill Ahead 1.3 BPM, 3350 CTP, 407 WHP, 1.5K -3K WOB, 7 -10K CTW, 12.9 ECD, 20 -50 FPH 13:36 15:36 2.00 6,635 0 PROD1 DRILL TRIP T Land build section, POOH, 16.5K PUW, Pull heavy picking up through window. RIH. PUH through window no problem. POOH 15:36 15:51 0.25 0 0 PROD1 DRILL SFTY P PJSM 15:51 17:21 1.50 0 0 PROD1 DRILL PULD T Undeploy BHA 17:21 18:21 1.00 0 72 PROD1 DRILL PULD T Deploy BHA # 6 18:21 20:00 1.65 72 6,400 PROD1 DRILL TRIP T RIH following MP schedule. - gamma tie in +5 ft correction. Close EDC. 20:00 20:30 0.50 6,400 6,635 PROD1 DRILL TRIP T RIH through window - clean. Make up down pass through window- clean. Tie into RA tag - 6401'. TOW - 6394.6 - BOW 6403.6'. 20:30 21:30 1.00 6,635 6,400 PROD1 DRILL ELOG T On bottom - no BHP change- CT weight 3K & WOB 2.7K, Looks like bypass leak on bottom. 1.50 bpm, 2800psi, BHP 4186psi, Bore pressure 4240 psi, Differntial 60psi, ECD 12.9, Mad pass while POOH. 21:30 23:00 1.50 6,400 73 PROD1 DRILL TRIP T POOH to surface following MP. 23:00 00:00 1.00 73 0 PROD1 DRILL PULD T Undeploy BHA. - P- tested CT connector 350 & 3500 no leaks. Complete Undeploying BHA to troubleshoot BHA - Motor failed. 07/25/2010 Round trip to surface for BHA failure (EDC). Continue Drilling ahead in A lateral. 00:00 01:30 1.50 0 72 PROD1 DRILL PULD T Deploy BHA # 7 01:30 03:30 2.00 72 6,635 PROD1 DRILL TRIP T RIH, tie in +5 ft, close EDC. Drifted through window clean. Continue RIH - noticed pressures problems again... 03:30 05:30 2.00 6,635 0 PROD1 DRILL TRIP T POOH to replace entire BHA. Page 4 of 15 • Time Logs Date From. To ; s" ".. Our S. Depth E. Depth Phase -Code Subcode T Comment 05:30 05:45 0.25 0 0 PROD1 DRILL SFTY T at surface, PJSM 05:45 08:45 3.00 0 0 PROD1 DRILL PULD T Undeploy BHA 7, Deploy BHA 8 BHA 7 diangnosed with failed EDC 08:45 08:54 0.15 0 500 PROD1 DRILL TRIP T RIH 08:54 10:09 1.25 500 6,265 PROD1 DRILL TRIP T Test BHA, test good, continue RIH 10:09 10:27 0.30 6,265 6,285 PROD1 DRILL DLOG T Tie in depth, +5' correction 10:27 12:39 2.20 6,635 6,785 PROD1 DRILL DRLG T Drill Ahead 1.3 BPM, 3171 CTP, 295 WHP, 4165 BHP, 6K CTW, 1.5K -2.5K WOB, 60 -100 FPH 12:39 13:09 0.50 6,785 6,785 PROD1 DRILL WPRT T Wiper Trip back to window, 17K PUW 13:09 14:39 1.50 6,785 6,935 PROD1 DRILL DRLG T Drill Ahead 1.3 BPM, 3171 CTP, 295 WHP, 4165 BHP, 6K CTW, 1.5K -2.5K WOB, 80 -150 FPH 14:39 15:09 0.50 6,935 6,935 PROD1 DRILL WPRT T w 15:09 16:39 1.50 6,935 7,085 PROD1 DRILL DRLG T Drill Ahead 1.3 BPM, 3367 CTP, 255 WHP, 4165 BHP, 6 -7K CTW, 1.5K -2.5K WOB, 80 -150 FPH 16:39 17:09 0.50 7,085 7,085 PROD1 DRILL DRLG T Wiper trip to window, 16.5K PUW 17:09 17:39 0.50 7,085 7,085 PROD1 DRILL DLOG T Tie into RA marker +4 ft correction. RIH 17:39 19:30 1.85 7,085 7,235 PROD1 DRILL DRLG T Drilling ahead - 1.30 bpm, 3500 psi, BHP 4200, ECD 13.3, WHP 310, ROP 140 fph, losses = 2 bph. 19:30 20:30 1.00 7,235 7,235 PROD1 DRILL WPRT T Wiper to window. P/U weight 17K 20:30 22:00 1.50 7,235 7,385 PROD1 DRILL DRLG T Drilling ahead - 1.30 bpm 3500, BHP 4200, ECD 13.2, WHP 200, ROP 130, losses 2 bph. Good A -2 Sand in returns. 22:00 23:00 1.00 7,385 7,385 PROD1 DRILL WPRT T Wiper trip 17K off bottom. 23:00 00:00 1.00 7,385 7,517 PROD1 DRILL DRLG T Drilling ahead - 1.30 bpm, 3550psi, BHP 4170, ECD 13.1, WHP 200, ROP 140, WOB 2.2K, CT weight 3K. 07/26/2010 Continue drilling ahead in A lat. Mud swap with 1812' on system. 00:00 00:30 0.50 7,517 7,535 PROD1 DRILL DRLG T drilling ahead 00:30 01:30 1.00 7,535 7,535 PROD1 DRILL WPRT T Wiper trip - P/U weight 17K. Tie in -1 ft. 01:30 03:00 1.50 7,535 7,685 PROD1 DRILL DRLG T Drilling ahead - 1.30 bpm, 3700 psi, BHP 4250, WHP 200, ECD 13.3, ROP 130, WOB 1.9, CT weight 5K. 03:00 04:30 1.50 7,685 7,685 PROD1 DRILL WPRT T Wiper trip - P/U weight 17K 04:30 05:30 1.00 7,685 7,835 PROD1 DRILL DRLG T Drilling ahead -1.35 bpm, 3600 psi, BHP 4256, WHP 150, ECD 13.3, ROP 140, WOB 1.9K, Ct weight 4K. 05:30 07:00 1.50 7,835 7,835 PROD1 DRILL WPRT T Wiper trip to window, 17K PUW 07:00 08:15 1.25 7,835 7,985 PROD1 DRILL DRLG T Drilling ahead - 1.35 bpm, 3600 psi, BHP 4256, WHP 240, ECD 13.3, ROP 140, WOB 1.9K, Ct weight 0 -3K. Page 5 of 15 • Time Logs Date From To Our . S. Depth E. Depth Phase Code ? Subcode T Comment 08:15 09:15 1.00 7,985 7,985 PROD1 DRILL WPRT T Wiper trip to window, 17K PUW 09:15 09:30 0.25 6,425 6,425 PROD1 DRILL DLOG T Tie in depth to RA marker +2' correction, RIH 09:30 11:00 1.50 7,985 8,135 PROD1 DRILL DRLG T Drilling ahead - 1.35 bpm, 3600 psi, BHP 4256, WHP 240, ECD 13.3, ROP 100 -140, WOB 1.5 -2.5K, Ct weight 0-4K. 11:00 13:00 2.00 8,135 8,135 PROD1 DRILL WPRT T Wiper trip to window, 16K PUW 13:00 14:00 1.00 8,135 8,285 PROD1 DRILL DRLG T Drilling ahead - 1.35 bpm, 3400 psi, BHP 4256, WHP 202, ECD 13.3, ROP 100 -150, WOB 1.5 -2.5K, Ct weight -4K. Swap out mud 14:00 16:00 2.00 8,285 8,285 PROD1 DRILL WPRT T Wiper Trip to window, 16K PUW 16:00 17:00 1.00 8,285 8,439 PROD1 DRILL DRLG T Drilling ahead - 1.35 bpm, 3470 psi, BHP 4325, WHP 400, ECD 13.6, ROP 100 -150, WOB 1.5 -2.5K, Ct weight -4K. 17:00 19:30 2.50 8,439 8,439 PROD1 DRILL WPRT T Wiper trip to window, 16K PUW, Tie into RA marker +3 19:30 21:00 1.50 8,439 8,590 PROD1 DRILL DRLG T Drilling ahead - Pump Low /high sweep prior to wiper trip. 21:00 23:30 2.50 8,590 8,590 PROD1 DRILL WPRT T Wiper trip - P/U weight 18K. 23:30 00:00 0.50 8,590 8,649 PROD1 DRILL DRLG T Drilling ahead - 1.30 bpm, 3600 psi, BHP 4350, WHP 300, ECD 13.6, CT weight -1K, WOB 1.8K, ROP 90. 07/27/2010 Continue drilling ahead - WOB transfer starting to affect ROP, pump low /high sweeps to help with hole cleaning. 00:00 01:00 1.00 8,649 8,740 PROD1 DRILL DRLG T Drilling ahead. 01:00 04:00 3.00 8,740 8,740 PROD1 DRILL WPRT T Wiper trip - P/U weight 17K 04:00 06:00 2.00 8,740 8,890 PROD1 DRILL DRLG T Drilling ahead - 1.35 bpm, 3640 psi, BHP 4350, WHP 300, ROP 120, WOB 1.9K, CT weight -3K. Fault crossing @ 8820', ROP slowed and CT weight gain. P/U 17K - drill ahead. 06:00 09:00 3.00 8,890 8,890 PROD1 DRILL WPRT T Wiper Trip do window, 17K PUW 09:00 10:30 1.50 8,890 9,040 PROD1 DRILL DRLG T Drilling ahead - 1.35 bpm, 3640 psi, BHP 4350, WHP 300, ROP 120 -150, WOB 1.5 -2.5K, CT weight -3K. 10:30 13:30 3.00 9,040 9,040 PROD1 DRILL WPRT T Wiper Trip to window Pump 5bbrl low /high sweep 100' off bottom 13:30 14:30 1.00 9,040 9,139 PROD1 DRILL DRLG T Drilling ahead - 1.3 bpm, 3530 psi, BHP 4300, WHP 380, ROP 100, WOB 1.9K, CT weight -5 to -8K. 14:30 14:42 0.20 9,139 9,139 PROD1 DRILL WPRT T BHA wiper weight stacking, lost diff psi. Pump low /high sweep Page 6 of 15 • lime Logs Date From To Dur . S. Depth E. Depth Phase Code Subcode .. T Comment 14:42 15:27 0.75 9,139 9,181 PROD1 DRILL DRLG T Drill ahead 1K WOB, 50FPH, 0 to -8K CTW, 330 WHP 15:27 15:42 0.25 9,181 9,181 PROD1 DRILL WPRT T PU 100', Stacking. PUW 16K PUW, RIH to drill 15:42 16:42 1.00 9,181 9,200 PROD1 DRILL DRLG T Drill Ahead 30 -50 FPH, 1.2K WOB, -8K CTW, 3350 CTP, 238 WHP, 1.3 BPM, 4380 BHP 16:42 20:00 3.30 9,200 9,200 PROD1 DRILL WPRT T Wiper trip back to window, 16K PUW 20:00 22:00 2.00 9,200 9,347 PROD1 DRILL DRLG T Drilling ahead - 1.30 bpm, 3500 psi, BHP 4400, WHP 300, ECD 13.7, ROP 80, CT weight -3K, WOB 1.6K. Pumped Hi -Lo sweep, stacking, tried working. - Pull wiper 15 ft early 22:00 00:00 2.00 9,347 9,347 PROD1 DRILL WPRT T P/U weight 18K. Tie in +3 ft correction 07/28/2010 TD A lateral @ 9490', pump KWF and P/U and run first liner string to TD. 00:00 02:00 2.00 9,347 9,347 PROD1 DRILL WPRT T Tie in +3 ft. - RIH starting to stack @ 9100', work pumps to bottom. 02:00 04:00 2.00 9,347 9,490 PROD1 DRILL DRLG T Drilling ahead - 1.30 bpm, 3600 psi, BHP 4380, WHP 300, ECD 13.7, �) ROP 60, CT weight -6K, WOB 1.56K 4 5 , 04:00 06:30 2.50 9,490 9,490 PROD1 DRILL WPRT T TD lateral - Pump Low /High sweep - Final wiper trip - 19K off bottom. 06:30 06:42 0.20 6,430 6,430 PROD1 DRILL DLOG T Tie into RA marker +1 correction, 06:42 08:12 1.50 6,430 9,491 PROD1 DRILL TRIP T RIH, Tag TD 08:12 08:57 0.75 9,491 8,071 PROD1 DRILL TRIP T POOH laying Liner running pill 08:57 09:27 0.50 8,071 6,600 PROD1 DRILL TRIP T Paint EOP flag 8000' Continue POOH laying in Liner running pill 09:27 10:27 1.00 6,600 4,971 PROD1 DRILL TRIP T Start laying in 13.1 KWF, Continue POOH 10:27 11:27 1.00 4,971 0 PROD1 DRILL TRIP T Paint 4900 EOP flag, continue POOH 11:27 11:42 0.25 0 0 PROD1 DRILL SFTY P At surface, PJSM, 11:42 11:57 0.25 0 0 PROD1 DRILL OWFF T Perform flow check, Good 11:57 12:42 0.75 0 0 PROD1 DRILL PULD T LD BHA 12:42 13:27 0.75 0 0 PROD1 DRILL PULD T Prepare to run liner Perform BOP function test 13:27 13:42 0.25 0 0 COMPZ CASING SFTY P PJSM 13:42 16:12 2.50 0 1,439 COMPZ CASING PUTB T PU/MU Liner (43jnts). 16:12 18:42 2.50 1,439 9,490 COMPZ CASING RUNL T RIH - Clean through window +2 ft correction at flag. Heavier Polymer over shakers while RIH. Clean through OH down to 9100 & 9250' slight weight bobbles. Tag bottom 9490' - P/U weight 24K 18:42 19:00 0.30 9,490 8,096 COMPZ CASING CIRC T Bring pumps up to 1.1 bpm - 3900 psi, WOB 6K, P/U weight 15K, release liner Page 7 of 15 I • Time Logs Date From To Our S. Depth E. Depth Phase Code Subcode T ' Comment 19:00 21:30 2.50 8,096 45 COMPZ CASING TRIP T Stop -reset counter, set & pump across the top while POOH to window. Flag pipe for second run. Continue POOH to surface pumping KWF down CT. Clean KWF over shakers. 21:30 22:00 0.50 45 0 COMPZ CASING PULD T Flow -check then Lay down BHA. 22:00 22:30 0.50 0 0 COMPZ CASING SFTY T Set up rig floor & pre -job safety meeting for Liner run. 22:30 00:00 1.50 0 550 COMPZ CASING PUTB T P/U 15 jnts of liner with anchored U billet. 07/29/2010 RIH with OH Liner & Billet. Set TOB @ 7598'. POOH - 6395' Stuck in window. Worked free with 12K on DH weight. POOH. P/U Crayola Mill - Circ out KWF - back reaming was clean other than 45 degree LOHS. 6394 - Stuck BHA - worked free & dressed window to 30 degree LOHS. POOH - No marks on mill 2.80" No -go. 00:00 00:30 0.50 550 559 COMPZ CASING PULD T P/U Coil trac BHA. & make up injector. 00:30 02:30 2.00 559 8,093 COMPZ CASING RUNL T Open EDC RIH pumping .3bpm. Flag correction +2.2 , Stop pumping, close EDC. P/U weight 17.5K. RIH. 02:30 03:00 0.50 8,093 7,597 COMPZ CASING CIRC P Orientate TF to 160 ROHS - tagged low liner. P/U weight 21K, sit down 1K. F' /U neutral weight. Start pumping - tool set @ 3200 psi, P/U weight 18K. Continue POOH. 03:00 04:00 1.00 7,597 6,396 COMPZ CASING TRIP P TOB - 7597' - Pump across the top, POOH to window. Tie into PIP tag +3 ft correction. Overpull @ window from 19K to 24K. Try to orientate - torque up on HOT 04:00 04:30 0.50 6,396 6,396 COMPZ CASING TRIP T Set up to pump down CT - try move CT slowly up & down. No movement on BHA. -5K to +5K within 3ft. Pump .5 bpm, 1300 psi. no movement +5 to -7K quickly - stop pumping. Call town to discuss. 04:30 04:45 0.25 6,396 6,393 COMPZ CASING TRIP T Try pumping 1 bpm, 3100 psi, working CT stirng, returns @ surface. Work it up /down 5 times. Stop and sit. Stop pumping. 04:45 07:15 2.50 6,393 6,393 COMPZ CASING CIRC T Pump minimum rate, Wait on discussion from town 07:15 07:15 0.00 6,393 6,393 COMPZ CASING TRIP T Try push more wieght down, -5K WOEI increasing to -10K WOB, slowly. No luck 07:15 07:45 0.50 6,393 6,393 COMPZ CASING TRIP T PU to 5K over, Stuck, RIH 10 15, 20, _ 25, 30 FPM to -10K WOB, No luck. 07:45 08:15 0.50 6,393 6,393 COMPZ CASING TRIP T PUH, 30K surface weight 10K over. Stuck RIH 35 FPM -12K WOB, Hold down weight. 08:15 08:45 0.50 6,393 6,393 COMPZ CASING TRIP T Get free, orient keyway on setting tool HS PUH 10 -15 FPM, PUH through window clean 08:45 10:30 1.75 6,393 0 COMPZ CASING TRIP P POOH 10:30 10:45 0.25 0 0 COMPZ CASING OWFF P At surface PJSM, flow check good Page 8 of 15 • • • Time Logs Date . Fr To s' Dur S. Depth E. Depth Phase Code `` Subcode T Comment 10:45 12:00 1.25 0 0 COMPZ CASING PULD T LD BHA, All components of BHA are in good shape with normal wear. 12:00 14:15 2.25 0 0 PROD2 WHPST PULD T PU/MU BHA #11. 14:15 15:15 1.00 0 6,250 PROD2 WHPST TRIP T RIH 15:15 15:30 0.25 6,250 6,250 PROD2 WHPST DLOG T Tie in depth + 4' correction, RIH 15:30 15:45 0.25 6,250 6,600 PROD2 WHPST TRIP T Slide through window no problem. RIH to 6600' performing weight checks every 50'. 15:45 18:45 3.00 6,600 6,600 PROD2 WHPST CIRC T PUH above window pumping 9.8ppg flo -pro to bit. RIH Displace well back t o flo -pro from 6600'. 18:45 20:00 1.25 6,600 6,394 PROD2 WHPST REAM T Begin Milling passes up /down at milled TF. Two clean passes no motor work. 1 pass 45 ROHS - light motor work. 1st pass 45 LOHS - torqued up @ 6394' - stop pumping, _ RIH instant WOB, Orient HS. Hung up- P/U Orient 45 ROHS - sit down 5K and popped free 20:00 20:30 0.50 6,400 6,400 PROD2 WHPST REAM T HS - Make pass up /down - 1/2 fpm - start 15 LOHS - clean, 30 LOHS - clean, 30 ROHS - slight work. Discuss with town - Make 2 HS dry passes. - clean. 20:30 23:00 2.50 6,400 71 PROD2 WHPST TRIP T Open EDC - POOH. 23:00 00:00 1.00 71 0 PROD2 WHPST PULD T Undeploy BHA with crayola mill. Crayola came out 2.80" No -go, clean. 07/30/2010 Milled off anchored billet at 7600' and drillled to 8071'. TD well due to poor quality Al sands in this area. Lay in liner running pill and KWF. 00:00 01:00 1.00 0 0 PROD2 STK SVRG P Service injector & Inspect CT con nector . 01:00 02:30 1.50 0 72 PROD2 STK PULD P Deploy BHA # 12 02:30 05:00 2.50 72 7,597 PROD2 STK TRIP P RIH with EDC open, tie in+ 4ft correction. Smooth through window HS. Dry tag TOB @ 7597.1' 05:00 07:30 2.50 7,597 7,610 PROD2 STK MILL P Bring pumps on -line 1.40 bpm, 3500psi, BHP 420 0, ECD 13.2, WOB .7K, CT weight 7K. 1 FPH for 1 ' 31 2 FPH for 1' AL 3 FPH for 1' 15 FPH for 5' 07:30 07:42 0.20 7,610 7,610 PROD2 STK MILL P Peform dry drift through ST, Looks good 07:42 08:42 1.00 7,610 7,760 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3600 CTP, 1 2K WOB, 4 -5K CTW, 300 WHP, 4220 BHP 1 50 FPH 08:42 10:27 1.75 7,760 7,760 PROD2 DRILL WPRT P Wiper trip back to window 16K PUW 10:27 11:57 1.50 7,760 7,910 PROD2 DRILL DRLG P Dr Ahead 1.4 BPM, 3600 CTP, 1 -2K WOB, 4 -5K CTW 300 WHP, 4 288 BHP, 100 -150 FPH 11:57 13:42 1.75 7,910 7,910 PROD2 DRILL WPRT P Wiper trip to window 17K PUW Page 9 of 15 • Time Logs Date From To ` Dur S. Depth E. Depth Phase Code Subcode T !. Comment 13:42 15:42 2.00 7,910 8,060 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3600 CTP, 1 -2K WOB, 4 -5K CTW, 300 WHP, 4288 BHP, 100 FPH 15:42 17:18 1.60 8,060 6,440 PROD2 DRILL WPRT P TD lateral perform wiper trip chasing low /high sweep to window, 20K 17:18 17:30 0.20 6,440 6,440 PROD2 DRILL DLOG P Tie in depth to RA marker, +2' 17:30 18:42 1.20 6,440 8,071 PROD2 DRILL WPRT P RIH 18:42 19:42 1.00 8,071 6,600 PROD2 DRILL DISP P Lay in liner running pill 19:42 21:00 1.30 6,600 0 PROD2 DRILL TRIP P POOH laying in KWF. Paint flag at 5600 EOP 21:00 21:12 0.20 0 0 PROD2 DRILL SFTY P PJSM for laying down drilling BHA 21:12 21:48 0.60 0 0 PROD2 DRILL PULD P Lay down drilling BHA 21:48 22:48 1.00 0 0 COMPZ CASING PUTB P Rig up floor for liner running 22:48 00:00 1.20 0 0 COMPZ CASING PUTB P Run 20 joints slotted liner 07/31/2010 Ran liner to td at 8071' and left liner top billet at 7423'. Milled off billet and drilled AL2 lateral to 7775'. Mud swap after milling off billet 00:00 01:12 1.20 0 693 COMPZ CASING PUTB P Continue PU liner and make up Inteq tools. 01:12 02:36 1.40 693 6,292 COMPZ CASING RUNL P RIH 02:36 03:18 0.70 6,292 8,071 COMPZ CASING RUNL P Correct at flag, +2.5'. Weight check 18K PUW, 13K RIW. Continue RIH 03:18 05:33 2.25 8,071 0 COMPZ CASING RUNL P Tag at 8071', pump 1.2 BPM ant_ release liner. POOH pumping down backside. At window line up pump down CT and continue POOH 05:33 06:30 0.95 0 0 COMPZ CASING PULD P At surface, PJSM. LD BHA 13, PU BHA 14 06:30 07:33 1.05 0 0 PROD3 STK PULD P PU BHA # 14 07:33 08:48 1.25 0 6,250 PROD3 STK TRIP P RIH 08:48 09:03 0.25 6,250 6,250 PROD3 STK DLOG P Tie in depth, +3'. Closed EDC, 09:03 11:33 2.50 6,250 6,600 PROD3 STK DISP P RIH to 6600' displacing KWF out of well 11:33 14:03 2.50 7,423 7,436 PROD3 STK MILL P Start ST Bring pumps on -line 1.30 bpm, 3546psi, BHP 4266, ECD 13.2, WOB .7K, CT weight 7K. 1 FPHfor1' 1-* ( I 2 FPH for 1' J 3 FPH for 1' ALz 10 FPH for 5' ��� 14:03 14:18 0.25 7,436 7,436 PROD3 STK MILL P Perform dry drift through ST, Good. 14:18 15:48 1.50 7,436 7,580 PROD3 DRILL DRLG P Drill Ahead 1.3BPM, 3600 CTP, 4285 BHP, 1.5 -2K WOB, 300 WHP, 4 -5K CTW Start mud swap 15:48 17:30 1.70 7,580 7,580 PROD3 DRILL WPRT P Wiper trip to window 16K PUW 17:30 21:12 3.70 7,580 7,730 PROD3 DRILL DRLG P Drilling ahead, 3300 CTP, 420 WHP, 4270 BHP 21:12 22:00 0.80 7,730 6,670 PROD3 DRILL WPRT P Wiper to window, 18K PUW Page 10 of 15 • • Time Logs Date " From To .'" " Dur S. Depth E. Depth Phase Code Subcode " T Comment 22:00 22:54 0.90 6,670 6,430 PROD3 DRILL DLOG P Mad pass build section to verify gamma tool readings. Found that a correction had been put in for the higher potasium. When this correction is removed the logs are correct. 22:54 23:30 0.60 6,430 7,730 PROD3 DRILL WPRT P Wiper trip inhole 23:30 00:00 0.50 7,730 7,775 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 08/01 /2010 Drill AL2 lateral to 8500', POOH for sidetrack. 00:00 00:54 0.90 7,775 7,880 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 00:54 02:00 1.10 7,880 6,420 PROD3 DRILL WPRT P Wiper to window, 19K PUW 02:00 02:12 0.20 6,420 6,440 PROD3 DRILL DLOG P Tie in, +2' 02:12 03:00 0.80 6,440 7,880 PROD3 DRILL WPRT P Wiper back in hole, 11K RIW 03:00 04:42 1.70 7,880 8,030 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 04:42 06:57 2.25 8,030 8,030 PROD3 DRILL WPRT P Wiper to window, 18K PUW 06:57 08:27 1.50 8,030 8,180 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 08:27 10:27 2.00 8,180 8,180 PROD3 DRILL WPRT P Wiper to window, 18K PUW 10:27 12:12 1.75 8,180 8,330 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3450 CTP, 400 WHP, 4280 BHP, 4K RIW, 1 - 3K WOB, 200 - 400 PSI motor work 12:12 14:27 2.25 8,330 8,330 PROD3 DRILL WPRT P Wiper to window, 18K PUW, Tie in depth to RA marker +1'. 14:27 16:57 2.50 8,330 8,500 PROD3 DRILL DRLG P Continue drilling, 1.35 BPM, 3850 CTP, 200 WHP, 4280 BHP, 4K RIW, neg 1 - neg 3K WOB, 200 - 400 PSI motor work. 60 -80 FPH ROP. 16:57 20:12 3.25 8,500 0 PROD3 DRILL TRIP T POOH for sidetrack, drilled into A4 /A5 20:12 21:42 1.50 0 0 PROD3 DRILL PULD T Lay down drilling BHA P51- 21:42 23:48 2.10 0 0 PROD3 STK PULD T MU anchored billet BHA 23:48 00:00 0.20 0 200 PROD3 STK TRIP T RIH 08/02/2010 Set anchored billet at 7930', test BOP, mill off billet and drill AL2 00:00 01:12 1.20 200 6,260 PROD3 STK TRIP T Continue RIH with anchored billet 01:12 01:24 0.20 6,260 6,290 PROD3 STK DLOG T Tie into formation, +3' 3A-1( 01:24 02:12 0.80 6,290 7,941 PROD3 STK TRIP T Continue to RIH, 11K RIW, window ��� was clean Page 11 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase ` Code „ Subcode T Comment 02:12 02:24 0.20 7,941 7,930 PROD3 STK WPST T Set anchored billet at 7930 top of billet, 7941.23 bit depth. 02:24 04:48 2.40 7,930 0 PROD3 STK SVRG T POOH, clean through window 04:48 05:48 1.00 0 0 PROD3 STK PULD T Undeploy BHA 05:48 06:18 0.50 0 0 PROD3 STK SFTY T Crew change, PJSM 06:18 07:03 0.75 0 0 PROD3 STK PULD T Continue Undeployment/LD BHA 07:03 07:48 0.75 0 0 PROD3 WHDBO BOPE P Remove check valves, flush lines on rig and stack 07:48 08:48 1.00 0 0 PROD3 WHDBO SVRG P Grease tree 08:48 09:03 0.25 0 0 PROD3 SURFEC SVRG P PJSM 09:03 16:33 7.50 0 0 PROD3 WHDBO BOPE P Start BOP testing 16:33 17:30 0.95 0 0 PROD3 WHDBO CIRC P BOP testing complete, displace CT I4 back to Flo -Pro 17:30 18:00 0.50 0 0 PROD3 WHDBO SVRG P Install check valves 18:00 20:30 2.50 0 0 PROD3 STK PULD T Deploy BHA 20:30 21:48 1.30 0 6,260 PROD3 STK TRIP T RIH 21:48 22:00 0.20 6,260 6,290 PROD3 STK DLOG T Tie in, +3,. close EDC 22:00 22:42 0.70 6,290 7,931 PROD3 STK TRIP T Continue RIH, Clean through window and down to tag at 7931', 20K PUW, 7K RIW 22:42 00:00 1.30 7,931 7,932 PROD3 STK KOST T Start time milling off billlet at 1 FPH. 1.4 BPM, 3640 CTP, 4280 BHP, 200 WHP. Increase to 2 FPH after a foot 08/03/2010 Complete drill by billit @ 7931, Swap Mud, Drill Ahead to 8830' 00:00 01:00 1.00 7,932 7,934 PROD3 STK KOST T Continue time milling, 1.4 BPM, 3640 CTP, 4280 BHP, 200 WHP. 2 FPH, increase to 3 FPH for one foot. 01:00 01:30 0.50 7,934 7,965 PROD3 DRILL DRLG T Continue drilling ahead at 15 FPH for 2' then drill ahead. 1.4 BPM, 3640 CTP, 4300 BHP, 200 WHP 01:30 03:00 1.50 7,965 8,080 PROD3 DRILL DRLG T Drift past billet clean, continue drilling. 1.4 BPM, 3640 CTP, 4290 BHP, 200 WHP 03:00 05:15 2.25 8,080 8,080 PROD3 DRILL WPRT T Wiper to window, 18K PUW 05:15 07:00 1.75 8,080 8,240 PROD3 DRILL DRLG T Continue drilling ahead 1.4 BPM, 3640 CTP, 4300 BHP, 200 WHP 07:00 09:00 2.00 8,240 8,240 PROD3 DRILL WPRT T Wiper trip to window 09:00 10:36 1.60 8,240 8,381 PROD3 DRILL DRLG T Continue drilling ahead 1.4 BPM, 3640 CTP, 4300 BHP, 200 WHP 10:36 11:54 1.30 8,381 6,420 PROD3 DRILL WPRT T Wiper to window, 18K PUW 11:54 12:06 0.20 6,420 6,460 PROD3 DRILL DLOG T Tie in to RA, +4' correction 12:06 13:00 0.90 6,460 8,383 PROD3 DRILL WPRT T Wiper back in hole, 10K RIW 13:00 14:00 1.00 8,383 8,500 PROD3 DRILL DRLG T Continue drilling ahead 1.4 BPM, 3640 CTP, 4310 BHP, 200 WHP. Start new mud down coil Page 12 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:30 0.50 8,500 8,530 PROD3 DRILL DRLG P Back on planned time. Continue drilling ahead 1.4 BPM, 3550 CTP, 4310 BHP, 380 WHP 14:30 17:15 2.75 8,530 8,530 PROD3 DRILL WPRT P Wiper to window, 16K PUW 17:15 18:45 1.50 8,530 8,680 PROD3 DRILL DRLG P 8530', Drill ahead 1.4 BPM @ 3400PSI FS BHP =4329 DHWOB =1.8K, RIW = -2K 18:45 20:30 1.75 8,680 8,680 PROD3 DRILL WPRT P Wiper to window 17K PUW 20:30 23:30 3.00 8,680 8,830 PROD3 DRILL DRLG P 8680' Drill Ahead 1.41 BPM @ 3534PSI FS BHP =4220 DHWOB =2.2K RIW = -2K 23:30 00:00 0.50 8,830 8,330 PROD3 DRILL WPRT P Wiper to window with Tie In Midnight Depth 8830 08/04/2010 TD AL2 Lat 9279. Condition hole, Lay in Beaded Liner Pill POOH 00:00 01:30 1.50 8,330 6,415 PROD3 DRILL WPRT P On wiper trip with Tie in slight overpull @ 8707 with little motor work 01:30 01:36 0.10 6,415 6,440 PROD3 DRILL DLOG P Log RA marker, +2' correction 01:36 02:54 1.30 6,440 8,830 PROD3 DRILL WPRT P Wiper trip back to bottom. Clean trip with no setdowns saw nothing @ 8707 02:54 06:00 3.10 8,830 8,981 PROD3 DRILL DRLG P 8830' Drill Ahead 1.4 BPM @ 3537PSI FS BHP =4325 06:00 09:00 3.00 8,981 8,981 PROD3 DRILL WPRT P Wiper trip, 18K PUW, pulled 23K at 8886' with now motor work, clean trip uphole. 11K RIW with a steady decrease during trip inhole. Stacked out to -10K at 8860' to 8880', clean PU at 17K. dropped pump rate to .9 BPM and RIH clean. 09:00 12:12 3.20 8,981 9,130 PROD3 DRILL DRLG P Continue drilling, 1.3 BPM, 3600 CTP, 4340 BHP, 300 WHP. 12:12 15:24 3.20 9,130 9,130 PROD3 DRILL WPRT P Wiper trip to window, 17K PUW. Some weight stacking at 8980', dropped pump rate to 1 BPM and continued w /out picking up 15:24 17:54 2.50 9,130 9,279 PROD3 DRILL DRLG P Continue drilling, 1.3 BPM, 3650 0 CTP, 4380 BHP, 300 WHP. -4K /` Surface weight while drilling with 1 - 3K WOB TD Well @ 9279 17:54 20:48 2.90 9,279 6,415 PROD3 DRILL WPRT P Pump to -hi sweeps, chase to window for RA tie in 20:48 20:57 0.15 6,415 6,437 PROD3 DRILL DLOG P Log RA marker, +2' correction 20:57 22:57 2.00 6,437 9,279 PROD3 DRILL WPRT P Wipe to bottom to lay in beaded liner running pill Stacking out @8860 with full pump rate to 9010. Back ream 180 degrees out of as drilled 22:57 23:39 0.70 9,279 9,279 PROD3 DRILL REAM P Back ream shales up to 9000, Start Beaded pill PUW =18K RIW -6K Page 13 of 15 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ': Comment 23:39 00:00 0.35 9,279 8,703 PROD3 DRILL TRIP P Trip out of well laying in beaded liner pill / spacer / KWF 08/05/2010 M/U and Run AL2 Liner, Correct to flag -1 ", set liner, PUH tie into formation, TOL =6180, BOL =9079 00:00 02:30 2.50 8,703 0 PROD3 DRILL TRIP P Continue out of well. Overpull at window. Orientation was correct as we entered window area but rolled 45 left as we attempted to run throughl0 FPM @ Min Rate, RBIH oriented to 1OR came through @ 18FPM clean pass through. Paint EOP Flags @ 6200 and 3400' 02:30 03:45 1.25 0 0 PROD3 DRILL PULD P At Surface, PJSM, Flow check well, Lay down BHA #16 Prep floor for liner pick up 03:45 04:00 0.25 0 0 COMPZ CASING SFTY P PJSM, Pick Up Liner 04:00 09:48 5.80 0 2,943 COMPZ CASING PUTB P PU liner string 09:48 10:42 0.90 2,943 6,343 COMPZ CASING RUNL P RIH with liner 10:42 17:24 6.70 6,343 8,977 COMPZ CASING RUNL P Corrected depth -1 @ EOP flag. wt ck 19k. continue RIH, 12.5k RIW. Started stacking weight at 7979', progressivly worse on the way in until only getting about 1 foot per pick up. 17:24 18:24 1.00 8,977 8,977 COMPZ CASING CIRC P Circulate in KWF with 1% safe -tube at 1 BPM at 3900 psi 18:24 21:54 3.50 8,977 9,079 COMPZ CASING RUNL P Continue to work liner 21:54 22:09 0.25 9,079 9,079 COMPZ CASING CIRC P Circulate lube pill around coil 22:09 23:18 1.15 9,079 9,081 COMPZ CASING RUNL P Work liner, unable to gain any ground, Confer with town set liner herQTOL below nipple @ 6156 23:18 23:24 0.10 9,081 8,978 COMPZ CASING RUNL P Release from Liner 1.1 BPM @ 4495 PUW =20K Pull up hole to tie into formation 23:24 23:36 0.20 8,978 6,176 COMPZ CASING DLOG P Log into formation for -2' correction Re r lengh left in well BOL =9079 TOL =6180 23:36 00:00 0.40 6,176 6,170 COMPZ CASING CIRC P Pump hig vis s pacer followed by seawater 08/06/2010 Swap well to seawater, Freeze protect from 2000', Set BPV, RDMO 00:00 01:45 1.75 6,170 6,170 COMPZ CASING CIRC P Swapping well to seawater / recover KWF 01:45 03:21 1.60 6,170 0 COMPZ CASING FRZP T POOH, Pump 25 BBIs Diesel freeze protect on way out @ 2000' 03:21 05:06 1.75 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA# 17 05:06 07:18 2.20 0 0 DEMOB WHDBO NUND T Set BPV, cut orings on firsst attempt, SSV was slightly closed, good set on second attempt 07:18 10:18 3.00 0 0 DEMOB WHDBO CTOP T Blow down CT 10:18 13:18 3.00 0 0 DEMOB WHDBO CTOP T R/U and pull CT back to reel and secure. Page 14 of 15 Time Logs Date From To -: Dur - S. Depth E. Depth Phase Code Subcode T - Comment 08/06/2010 24 hr Summary Swap well to seawater, Freeze protect from 2000', Set BPV, RDMO 13:18 16:00 2.70 0 0 DEMOB WHDBO NUND T PJSM, Rig down MP line, Rig up top drive to lifting cap Vac Mouse Holes, Nipple down stack. Nipple up tree cap flange and PT to 4K * * * * * * ** RIG RELEASE @ 16:00 * * * * * * * ** Page 15 of 15 1 r i SIRE OT nil:LSKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3I -11A ConocoPhillips Alaska, Inc. Permit No: 210 -074 Surface Location: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM Bottomhole Location: 2571' FSL, 2292' FWL, Sec. 6, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel . Seamount, Jr. D4 Chair DATED thi day of June 2010. y , cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2010 PERMIT TO DRILL Alaska Oil & as Cons. Commission 20 AAC 25.005 Anchorage la. Type of Work: t p lb. Proposed Well Class: Development - Oil El • Service - Winj ❑ Single Zone p + lc. Specify if well is p posed for: Drill Ef j; Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry U Exploratory ❑ Service - WAG ❑ 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 . 3I - 11A • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9200' • TVD: 6157.5' • Kuparuk River Field 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Surface: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM ADL 25523, 25631 - Kuparuk River Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1111' FNL, 1860' FEL, Sec. 6, T12N, R9E, UM 2559, 2564 14*120lo 7/6a Total Depth: 9. Acres in Property: 14. Distance to 2571' FSL, 2292' FWL, Sec. 6, T12N, R9E, UM 2560 Nearest Property: 18560 • 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: • 76 feet 15. Distance to Nearest Well Open Surface: x - 507830 • y - 6007088 • Zone 4 GL Elevation above MSL: 16.5 feet to Same Pool: 31 -13 , 1500 16. Deviated wells: Kickoff depth: 6397 • ft. 17. Maximum Anticipated Pressgres in psig (see 20 AAC 25.035) Maximum Hole Angle: 98° deg Downhole: 4452 psig ‘ Surface: 3800 psig • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole I Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L - 80 ST - L 1800' 7400' 6151' 9200' 6157.5' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 6772' 6560' 6680' 6473' 6422' Casing Length Size Cement Volume MD TVD Conductor/Structural 116' 16" 250 sx CS 11 116' 116' Surface 3348' 9.625" 330 sx Class G, 3383' 3383' Intermediate 544 sx AS III, 175 sx AS 1 Production 6728' 7" 250 sx Class G, 175 sx AS 1 6761' 6550' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 6437- 6454', 6457- 6486', 6494' -6503' 6245- 6261', 6264'- 6291', 6298' -6306' 20. Attachments: Property Plat ❑ BOP Sketch Q Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 151 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263 - 4093 4 p�p��+'io Printed Name V. Cawvey Title Alaska Wells Manager Signature ar 4dl∎ , Y n zs5 6 3o6 Date � / � 1L Ca L /l O Com l Pho ion Use Only Permit to Drill API Number: C Permit Approval See cover letter Number: 2 I _ ���() 50 -�)2 G l 2 - ��L�� �� Date: (0:31,10 for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: g 4 4. '1Soa psi /5c f .s f Samples req'd: Yes ❑ , No U Mud log req'd: Yes ❑ . No a Other: -> . Zg'" ` / 4 h „ 7 F C i J Syeasures: Yes g No ❑ Directional svy req'd: Yes d No ❑ �j7 ' �� APP ROVED BY THE COMMISSION OMMISSION 6 /W (� Plat, � COMMISSIONER i Form 10-401 (Revised 7 /2009) This permit is valid fo h • , a' dka val (20 AAC 25.005(g)) _. z Submit in Dup to . r • i ConocoPhillips Alaska RED; E , ....T., P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 JUN 1 2010 June 11, 2010 Alaska Oi 4aas Cons. Commission Anchorage Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill three lateral sidetracks out of • Kuparuk Well 31 -11 using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 31 -11 as early as July 2010. The CTD objective is to drill three lateral sidetracks (3I -11A, 31- 11AL1, 3I- 11AL2) to access reserves in the Al, A2 and A3 sands south of 31 -11 that are currently unswept. In October 2009, Permit to Drill (PTD) applications were approved for CTD sidetracks 3I-11L1 (PTD# 209 - 1210), 3I- 11L1 -01 (PTD# 209 - 1220), and 3I- 11L1 -02 (PTD# 209 -1230) with the same objectives as the laterals proposed in the attached applications. Work on those sidetracks began in January 2010, however, due to operational issues, only the 3I-11L1 lateral was drilled and completed. The approved permits for the 3I-11L1- ` 01 and L1 -02 laterals were officially withdrawn on June 3, 2010. Because the first attempt at drilling the CTD sidetracks was unsuccessful, the work proposed in this application packet is essentially the same as previously permitted. The reservoir targets and objectives have not changed, nor have the rig operations. The only difference is that production from the parent wellbore will be isolated prior to drilling the proposed laterals. Plugging the parent wellbore perforations is necessary because of the need to . isolate the 3I-11L1 lateral to prevent solids production from the unlined, openhole section. Sundry applications for the plugging of the two wellbores have been submitted separately from these PTD applications. Attached to this application are the following documents: — Permit to Drill Application Forms for 3I -11A, 3I- 11AL1, and 31 -11AL2 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic If you have any questions or require additional information please contact me at my office 907 - 263 -4093 or on my cell phone 907 - 230 -7550. Sincerely, Jill Long Coiled Tubing Drilling Engineer • • Permit to Drill Summary of Operations KRU 31-1 1A, 31-1 1AL1, & 31-1 1AL2 Laterals Coiled Tubing Drilling Well History Well 31 -11 was originally drilled and completed as an A -sand producing, single completion well in 1989 with 2- 7/8" tubing. A workover was performed in May 2009 to replace leaking tubing. At that time the well had already been . identified as a CTD candidate so the tubing was upsized from 2 -7/8" to 3 -1/2" and a subsurface safety valve (SSSV) was installed in preparation for the sidetracks. The original objective of the CTD sidetracks was to drill three lateral sidetracks out of the 31 -11 parent wellbore targeting the Al, A2 and A3 sands to access reserves from currently undrained areas to the south. The laterals were planned and permitted as 3I-11L1 (PTD# 209 - 1210), 3I-11L1-01 (PTD# 209 - 1220), and 3I-11L1-02 (PTD# 209 -1230) because the perforations in the parent wellbore were going to remain open to production. Nabors CDR2 rigged up on 31 -11 in January 2010 and began drilling operations. Unfortunately, after drilling the 3I-11L1 lateral and partially lining what had been drilled, the window became inaccessible. Drilling operations • were suspended on February 13, 2010, to diagnose the problem with the window and acquire additional 13.1 ppg potassium formate completion fluid. Laterals 31- 11L1 -01 (PTD# 209 -1220) and 3I- 11L1 -02 (PTD# 209- 1230) were neither drilled or completed prior to rig release. Post -rig diagnostics confirmed the whipstock had . released and moved downhole. After completing diagnostics on the window, 3I-11L1 was opened to flow to tanks in an attempt to bring the well pressure down before returning with the rig again. Initial production tests had —850 BLPD at 62.4% WC, 21.5 API, 0.75% solids at 950 WHP. As drawdown on the well was increased, the openhole lateral eventually collapsed and the tubing filled with solids. A fill cleanout was performed in April 2010 and the well has remained shut -in since then. Plan Forward The plan forward for this well is to set a plug in the 3 -1/2" tubing above the previously drilled window prior to attempting the CTD sidetracks again. This will isolate the 31 -11 parent wellbore perforations in addition to the 31- 11 L1 lateral and prevent solids production which could potentially plug the tubing again and prohibit production from the new sidetracked laterals. A whipstock will also be set pre -rig. Once the CTD rig arrives, a dual string window (3 -1/2" x 7 ") will be milled from which the three lateral sidetracks will then be drilled. The laterals will be named and permitted as 3I -11A, 3I- 11AL1, and 3I- 11AL2. • Operational Outline Pre -Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Set a cast iron bridge plug in the 3.5" tubing at —6406' 3. Set a 3.5" monobore whipstock at —6397' 4. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. P� 2. 31 -11A Lateral (A2 Sand) • , a. Mill 2.80" 2- string window with high -side orientation off of the whipstock set at 6397' MD. b. Drill 2.70" x 3" bi- center lateral in the A2 sand to a TD of 9170' MD. ,v Page 1 of 4 6/11/2010 ' P r a • L PTD Applications KRU 3I -11A 31 -11AL1 , and 31 -11AL2 c. Load well with completion kill weight fluid. Run 2 %" slotted liner from TD at 9170' MD up to 7400' MD. An anchored aluminum billet will be set at 7400' MD for kicking off the 31 -11AL1 lateral. 3. 31 -11AL1 Lateral (Al Sand) a. Kick off of the anchored aluminum billet set in the 3I -11A lateral at 7400' MD. b. Drill 2.70" x 3" bi- center lateral in the Al sand to a TD of 9160' MD c. Load well with completion kill weight fluid. Run 2%" slotted liner from TD up to 7360' MD. An aluminum liner -top billet placed at 7360' MD for kicking off the 31 -11AL2 lateral. 4. 31 -11AL2 Lateral (A3 Sand) . a. Kick off of the aluminum billet set in the 31 -11AL1 lateral at 7360' MD. b. Drill 2.70" x 3" bi- center lateral in the A3 sand to a TD of 9180' MD. c. Load well with kill weight fluid. Run 2%" slotted liner from TD up to 6385' MD, inside the 3 %" tubing. A deployment sleeve will be placed on top of the liner. 5. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Handover to Production group. Post - Rig Work 1. Obtain SBHP 2. Flowback for well cleanup 3. Begin production Operational Details Hazards — The window exit will occur in the top of the C4 sands, very close to the D shale. • — The close proximity to the previously drilled 31-11L1 wellbore is an important risk to be aware of when • kicking out of 31 -11 and drilling the build section of 3I -11A. The center -to- center separation of the directional plans has been reviewed and the separation is within the range that past wells having similar circumstances have been drilled. — Shale stability is a potential problem, particularly in the build section where the A5 sand will be encountered. Potential sloughing problems will be mitigated by drilling this interval at a hole angle less than 60° and by holding a constant 13.2 ppg EMW on the formation throughout drilling • operations. — Lost circulation was not a significant issue while drilling 31-11L1 and thus is not expected to be an issue in • 3I -11A, AL1, orAL2. — Over - pressured zones are a potential hazard in 31 -11. Choke pressure will be maintained while drilling, both for maintaining well control and borehole stability. — Well 31 -11 has 150 ppm H as measured on 6/22/09. Well 31 -12 is located 25' to the left side and 31 -10 is 25' to the right side of the 31 -11 surface location. The 31 -12 has no measured H since it is an injector. The H measured in 31 -10 is 120 ppm (1/2/09). The maximum H level on the pad is 160 ppm from wells 31 -04 (12/17/08) and 31 -17 (1/10/09). All H monitoring equipment will be - operational. Page 2 of 4 G 6/11/2010 PTD Applications • KRU 31 -11A • 31 -11AL1 and 31 -11AL2 Fluids Program - Chloride -based Biozan brine (8.6 ppg) will be used for window milling operations.. - Chloride -based Flo -Pro mud (10.0 ppg) for drilling operations. . - The SSSV in 31 -11 is inoperable so completion kill weight fluid will be needed. Due to the high reservoir pressures, 13.1 ppg Potassium Formate will be used for running completions. Disposal - No annular injection on this well. - Class 11 liquids to KRU 1R Pad Class 11 disposal well - Class 11 drill solids to Grind & Inject at PBU Drill site 4 - Class 1 wastes will go to Pad 3 for disposal. New Completion Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 31 -11A 7400' 9200' 6151' 6158' 2% , 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 31 -11AL1 7360' 9165' 6152' 6193' 2 , 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 31 -11AL2 6300' 9180' 6042' 6140' 2%', 4.7 #, L -80, ST -L solid /slotted liner; deployment sleeve on top. Existing Casing /Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H -40 Welded 0 116 0 116 1640 630 Surface 9%" 36 J -55 BTC 0 3383 0 3383 3520 2020 Casing 7" 26 J -55 BTC 0 6762 0 6550 4980 4320 Tubing 3 % " 9.3 L -80 EUE 0 6438 0 6246 10160 10540 Directional Planning - See attached directional plans for each of the three laterals. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 31 -11A 18560 • 31 -11 AL1 18560 31 -11 AL2 18560 - Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset Well 31 -11A 1500 31 -13 31 -11AL1 1342 31 -13 3I -11AL2 1450 31 -13 Page 3 of 4 t L 6/11/2010 PTD Applications • KRU 31 -111A • 31 -11AL1 , and 31 -11AL2 Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. • Reservoir Pressure — The most recent static BHP survey in well 31 -11 was taken February 16, 2009, after 3I-11L1 was drilled. The reservoir pressure was measured at 4150 psi at 6400 'MD/ 6135' TVDSS, corresponding to 13.0 ppg EMW. — The highest pressure from surrounding wells is 4250 psi at 6168 TVDSS in offset injector 31 -13. The / . pressure reading was taken in December 2009. Well 31 -13 had been shut -in since May 2009 to assist in reducing the pressure in the area. /'` 0.k • Well Control — Two well bore volumes ( -223 bbl) of KWF will be within a short drive to the rig during drilling operations. ' — BOP diagram is attached for operations with 2" coil tubing. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum potential surface pressure expected while sidetracking out of 31 -11 is 3800 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest, most recent measured bottomhole pressure in the vicinity, which is from offset injector 31 -13. The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by • using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2 pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure • measurements while drilling and shale behavior. Page 4 of 4 OR 1 GI N \ L 6/11/2010 • • ConocdPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 31 Pad 31 -11 31 -11A Plan: 31 -11A wp01 Standard Planning Report 10 June, 2010 AI ER HUGHES I?C IN L s ConocoPhilli m ConocoPhilli 5 Conoco Phillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 31 - 11 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31-11 © 76.00ft (31-11) Site: Kuparuk 31 Pad North Reference: True Well: 31 -11 Survey Calculation Method: Minimum Curvature Wellborn: ` 31 Design: 31 - 11 A_wp01 Project Kuparuk River Unit 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 Kuparuk 31 Pad Site Position: Northing: 6,007,285.49ft Latitude: 70° 25' 52.059 N From: Map Easting: 508,056.44ft Longitude: 149° 56' 3.597 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.06 ° Well 31 - 11 Well Position +N / -S 0.00 ft Northing: 6,007,088.16ft Latitude: 70° 25' 50.121 N +E/ - 0.00 ft Easting: 507,830.23 ft Longitude: 149° 56' 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: if Ground Level: 0.00ft Welibore 31 - 11A t Magnetics Model Name Sample Date Declination Dip Angle Field Strength (") (') (nT) BGGM2009 7/15/2010 17.05 79.85 57,388 Design 31- 11A_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,300.00 Vertical Section: Depth From (TVD) +WS +E/ -W Direction (ft) (ft) (ft) r) 0.00 0.00 0.00 217.00 6/10/2010 11 :30 :39AM Page 2 COMPASS 2003.16 Build 69 1 IG(NA • • ConocoPhillips ,f ConocoPhillips Planning Report BAKER Alaska HUGHES Databases EDM Alaska Prod v16 Local Co- ordinate Reference: Well 31 - 11 Company: ConocoPhillips(Alaska) Inc. 111/3 Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 31 -11 © 76.00ft (31 -11) =Site: Kuparuk 31 Pad North Reference: True Welt:: 31-11 Survey Calculation Method: Minimum Curvature Wellbore: 3I Design: 31 - 11 A_wpO1 Plan Sections Measured TVD Below Dogleg Build . Turn Depth Inclination Azimuth System +NI-S +E! W Rate Rate , . Rate TFO (ft) ( °} ( °} (ft) (ft) (ft) ( ° /100ft) ( °t100ff ( °11ot . ( °) Target 1 6,300.00 23.10 205.69 6,042.23 - 811.83 - 427.15 0.00 0.00 0.00 0.00 6,397.00 22.01 210.05 6,131.82 - 844.72 - 444.50 2.06 -1.12 4.49 125.10 6,417.00 29.01 210.05 6,149.86 - 852.17 - 448.81 35.00 35.00 0.00 0.00 6,482.00 58.26 210.05 6,196.39 - 890.57 - 471.03 45.00 45.00 0.00 0.00 6,517.00 71.51 219.50 6,211.25 - 916.43 - 489.15 45.00 37.84 27.00 35.00 6,578.09 90.00 240.21 6,221.13 - 954.69 - 534.97 45.00 30.27 33.90 50.00 6,640.09 94.77 245.92 6,218.54 - 982.74 - 590.15 12.00 7.70 9.21 50.00 i 6,810.09 94.82 266.39 6,204.17 - 1,023.05 - 753.75 12.00 0.03 12.04 89.00 1 7,090.09 95.12 232.66 6,179.18 - 1,119.17 - 1,011.27 12.00 0.11 -12.05 272.00 7,250.09 98.12 251.76 6,160.57 - 1,192.98 - 1,151.15 12.00 1.87 11.93 80.00 7,418.00 88.12 234.22 6,151.37 - 1,268.84 - 1,299.69 12.00 -5.95 -10.45 241.00 7,678.00 88.39 203.00 6,159.48 - 1,469.41 - 1,459.85 12.00 0.10 -12.01 270.00 7,778.00 96.41 211.95 6,155.28 - 1,557.91 - 1,505.84 12.00 8.02 8.94 48.00 7,928.00 95.79 193.85 6,139.22 - 1,694.72 - 1,563.62 12.00 -0.42 -12.06 269.00 8,128.00 91.93 170.11 6,125.57 - 1,892.68 - 1,570.37 12.00 -1.93 -11.87 261.70 8,208.00 87.87 178.81 6,125.71 - 1,972.21 - 1,562.65 12.00 -5.08 10.87 115.00 8,508.00 87.69 214.83 6,137.75 - 2,254.44 - 1,647.96 12.00 -0.06 12.01 91.00 8,638.00 86.43 230.40 6,144.46 - 2,349.69 - 1,735.59 12.00 -0.97 11.98 95.00 8,788.00 89.67 212.69 6,149.60 - 2,461.45 - 1,834.58 12.00 2.16 -11.81 280.00 9,200.00 88.27 163.26 6,157.50 - 2,856.84 - 1,889.99 12.00 -0.34 -12.00 268.00 6/10/2010 11.30:39AM Page 3 COMPASS 2003.16 Build 69 6 ..t GI NAL • • ConocoPhillips rat VI ConocoPhillips Planning Report BAKER Alaska Database: EDM Alaska Prod v16 Local Co Reference: Well 31 -11 Company:. ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference:' 31 -11 © 76.00ft (31 -11) ' Site: Kuparuk 31 Pad North Reference:. - - - . True Well: 31 - 11 Survey Calculation Method: Minimum Curvature Wellbore 31 - 11A Design: 31 wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth In Az System- +NiS +EI.W Section Rate Azimuth Northing Eastinit (R) (,) ( °) (ft) (ft) (R) (ft) t°HOOft) ( (ft) (ft} 6,300.00 23.10 205.69 6,042.23 -811.83 - 427.15 905.42 0.00 0.00 6,006,275.96 507,403.98 TIP 31 - 11 ; 6,397.00 22.01 210.05 6,131.82 - 844.72 - 444.50 942.13 2.06 125.10 6,006,243.06 507,386.66 KOP 6,400.00 23.06 210.05 6,134.59 - 845.71 - 445.07 943.27 35.00 0.00 6,006,242.07 507,386.09 6,417.00 29.01 210.05 6,149.86 - 852.17 - 448.81 950.67 35.00 0.00 6,006,235.61 507,382.36 End DLS 35 6,482.00 58.26 210.05 6,196.39 - 890.57 - 471.03 994.72 45.00 0.00 6,006,197.18 507,360.18 4 6,500.00 65.00 215.17 6,204.95 - 903.89 - 479.57 1,010.49 45.00 35.00 6,006,183.86 507,351.65 6,517.00 71.51 219.50 6,211.25 - 916.43 - 489.15 1,026.27 45.00 32.56 6,006,171.31 507,342.09 5 6,578.09 90.00 240.21 6,221.13 - 954.69 - 534.97 1,084.40 45.00 50.00 6,006,133.00 507,296.32 1 End +DLS 45 1 6,600.00 91.69 242.22 6,220.80 - 965.24 - 554.16 1,104.38 12.00 50.00 6,006,122.44 507,277.13 6,640.09 94.77 245.92 6,218.54 - 982.74 - 590.15 1,140.01 12.00 50.03 6,006,104.90 507,241.17 7 6,700.00 94.86 253.13 6,213.50 - 1,003.60 - 646.04 1,190.31 12.00 89.00 6,006,083.98 507,185.31 6,800.00 94.84 265.18 6,205.02 - 1,022.31 - 743.72 1,264.04 12.00 89.61 6,006,065.17 507,087.66 6,810.09 94.82 266.39 6,204.17 - 1,023.05 - 753.75 1,270.66 12.00 90.63 6,006,064.42 507,077.63 8 6,900.00 95.11 255.57 6,196.36 - 1,037.07 - 842.08 1,335.02 12.00 -88.00 6,006,050.31 506,989.32 i 7,000.00 95.22 243.52 6,187.32 - 1,071.82 - 935.22 1,418.82 12.00 -88.94 6,006,015.47 506,896.23 j 7,090.09 95.12 232.66 6,179.18 - 1,119.17 - 1,011.27 1,502.41 12.00 -90.03 6,005,968.04 506,820.24 9 7,100.00 95.33 233.84 6,178.28 - 1,125.07 - 1,019.17 1,511.88 12.00 80.00 6,005,962.13 506,812.34 7,200.00 97.26 245.76 6,167.28 - 1,175.00 - 1,104.91 1,603.34 12.00 80.11 6,005,912.12 506,726.67 7,250.09 98.12 251.76 6,160.57 - 1,192.98 - 1,151.15 1,645.54 12.00 81.42 6,005,894.09 506,680.45 10 7,300.00 95.18 246.50 6,154.79 - 1,210.64 - 1,197.45 1,687.50 12.00 - 119.00 6,005,876.39 506,634.17 7,400.00 89.20 236.09 6,150.95 - 1,258.56 - 1,284.92 1,778.42 12.00 - 119.61 6,005,828.38 506,546.76 7,418.00 88.12 234.22 6,151.37 - 1,268.84 - 1,299.69 1,795.52 12.00 - 120.01 6,005,818.08 506,532.00 11 7,500.00 88.15 224.37 6,154.05 - 1,322.23 - 1,361.74 1,875.49 12.00 -90.00 6,005,764.64 506,470.01 7,600.00 88.26 212.36 6,157.19 - 1,400.45 - 1,423.67 1,975.23 12.00 -89.68 6,005,686.36 506,408.17 7,678.00 88.39 203.00 6,159.48 - 1,469.41 - 1,459.85 2,052.09 12.00 -89.30 6,005,617.36 506,372.07 12 7,700.00 90.16 204.96 6,159.76 - 1,489.51 - 1,468.79 2,073.52 12.00 48.00 6,005,597.26 506,363.15 7,778.00 96.41 211.95 6,155.28 - 1,557.91 - 1,505.84 2,150.44 12.00 47.98 6,005,528.83 506,326.18 1 13 7,800.00 96.36 209.29 6,152.84 - 1,576.72 - 1,516.97 2,172.16 12.00 -91.00 6,005,510.01 506,315.06 7,900.00 95.95 197.23 6,142.08 - 1,667.89 - 1,556.16 2,268.56 12.00 -91.30 6,005,418.80 506,275.98 ' 7,928.00 95.79 193.85 6,139.22 - 1,694.72 - 1,563.62 2,294.48 12.00 -92.59 6,005,391.97 506,268.55 14 8,000.00 94.48 185.28 6,132.76 - 1,765.37 - 1,575.52 2,358.06 12.00 -98.30 6,005,321.31 506,256.72 8,100.00 92.51 173.42 6,126.65 - 1,864.99 - 1,574.38 2,436.93 12.00 -99.07 6,005,221.70 506,257.97 8,128.00 91.93 170.11 6,125.57 - 1,892.68 - 1,570.37 2,456.63 12.00 -99.79 6,005,194.02 506,262.01 15 8,200.00 88.27 177.94 6,125.44 - 1,964.22 - 1,562.88 2,509.26 12.00 115.00 6,005,122.50 506,269.57 8,208.00 87.87 178.81 6,125.71 - 1,972.21 - 1,562.65 2,515.50 12.00 115.01 6,005,114.51 506,269.81 ■ 16 8,300.00 87.71 189.85 6,129.27 - 2,063.74 - 1,569.58 2,592.77 12.00 91.00 6,005,022.98 506,262.98 6/10/2010 11:30.39AM Page 4 COMPASS 2003.16 Build 69 1 i i \ii 11 • • ConocoPhillips Fedki CanocoPhdlhps Planning Report BAKER .Alaska HUGHES Database: - EDM Alaska Prod v16 Local Co-ordinate Reference: Well 31 - 11 Company:. - ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 31 -11 © 76.00ft (31 -11) Site: Kuparuk 31 Pad North Reference: True Well: 31 - 11 Survey Calculation Method: Minimum Curvature Wellb•re: 31 -11A Design: 31 - 11 A_wp01 Planned Survey : y Measured TVD Below. Vertical Dogleg Toolface Map Map Depth Inclination Azimuth SY i +N/.S +E/•W won Rate =_ , Azimuth Northing= Eastin (ft) (6) (°) (ft) , (ft) (ft) (ft) ( °tlo0ft} (°) (ff), (ft)- 8,400.00 87.65 201.86 6,133.33 - 2,159.68 - 1,596.83 2,685.79 12.00 90.57 6,004,927.02 506,235.83 8,500.00 87.68 213.87 6,137.42 - 2,247.85 - 1,643.45 2,784.26 12.00 90.08 6,004,838.82 506,189.30 8,508.00 87.69 214.83 6,137.75 - 2,254.44 - 1,647.96 2,792.25 12.00 89.59 6,004,832.21 506,184.80 17 8,600.00 86.77 225.85 6,142.21 - 2,324.38 - 1,707.35 2,883.84 12.00 95.00 6,004,762.22 506,125.49 8,638.00 86.43 230.40 6,144.46 - 2,349.69 - 1,735.59 2,921.05 12.00 94.47 6,004,736.88 506,097.28 18 8,700.00 87.75 223.07 6,147.62 - 2,392.10 - 1,780.65 2,982.04 12.00 -80.00 6,004,694.43 506,052.27 8,788.00 89.67 212.69 6,149.60 - 2,461.45 - 1,834.58 3,069.88 12.00 -79.63 6,004,625.04 505,998.41 19 8,800.00 89.62 211.25 6,149.68 - 2,471.63 - 1,840.94 3,081.83 12.00 -92.00 6,004,614.85 505,992.07 8,900.00 89.22 199.25 6,150.69 - 2,561.90 - 1,883.51 3,179.55 12.00 -91.99 6,004,524.54 505,949.59 9,000.00 88.85 187.26 6,152.39 - 2,659.04 - 1,906.40 3,270.91 12.00 -91.87 6,004,427.38 505,926.81 9,100.00 88.53 175.26 6,154.69 - 2,758.81 - 1,908.59 3,351.90 12.00 -91.67 6,004,327.62 505,924.73 9,200.00 88.27 163.26 6,157.50 - 2,856.84 - 1,889.99 3,419.00 12.00 -91.39 6,004,229.62 505,943.43 TD 6/10/2010 11.30.39AM Page 5 COMPASS 2003.16 Build 69 ! 1 • • ConocoPhillips yrav Conoco Phillips Planning Report BAKER Alaska HUGHES Database.- " EDM Alaska Prod v16 Local Co-ordinate Reference: _ Well 31 -11 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project, ; Kuparuk River Unit MD Reference: 31 -11 © 76.00ft (31 -11) Site , " Kuparuk 31 Pad North Reference: True Well: 31 -11 Survey Calculation Method: Minimum Curvature Wellbore: 31-11A Design: 31 -11A wp01 Targets Target Name - hiUmiss target Dip Angle Dip Dir. " TVD +WS +E/ -W Northing = . Easting-. - Shape ( °) f) (ft) (ft) (ft) (ft) (ft) Latitude" Longitude 31 -11A, AL1, AL1 -01 F 0.00 0.00 0.00 - 790.15 - 523.89 6,006,297.54 507,307.22 70° 25' 42.349 N 149° 56' 25.610 W - plan misses target center by 6043.05ft at 6300.00ft MD (6042.23 TVD, - 811.83 N, - 427.15 E) - Polygon Point 1 0.00 - 790.15 - 523.89 6,006,297.54 507,307.22 Point 2 0.00 - 1,143.27 - 1,441.33 6,005,943.49 506,390.24 Point 3 0.00 - 1,783.03 - 1,750.00 6,005,303.47 506,082.28 Point 4 0.00 - 2,991.73 - 2,167.25 6,004,094.45 505,666.34 Point 5 0.00 - 3,170.18 - 1,736.39 6,003,916.47 506,097.34 Point 6 0.00 - 1,875.47 - 1,311.05 6,005,211.50 506,521.28 Point 7 0.00 - 1,398.60 - 1,140.56 6,005,688.50 506,691.25 Point 8 0.00 - 1,175.14 - 570.28 6,005,912.54 507,261.24 31 -11A, AL1 fault 5 0.00 0.00 0.00 - 2,306.63 - 2,081.65 6,004,779.58 505,751.21 70° 25' 27.433 N 149° 57' 11.297 W - plan misses target center by 6153.18ft at 8530.13ft MD (6138.68 TVD, - 2272.29 N, - 1661.00 E) - Polygon Point 1 0.00 - 2,306.63 - 2,081.65 6,004,779.58 505,751.21 Point 2 0.00 - 2,432.98 - 1,745.74 6,004,653.59 506,087.22 Point 3 0.00 - 2,576.36 - 1,373.85 6,004,510.62 506,459.22 Point 4 0.00 - 2,432.98 - 1,745.74 6,004,653.59 506,087.22 31 -11A t3 0.00 6,125.00 - 1,939.15 - 1,564.21 6,005,147.56 506,268.21 70° 25' 31.048 N 149° 56' 56.122 W - plan hits target center - Point 31 -11A t4 0.00 6,157.00 - 2,827.87 - 1,898.19 6,004,258.58 505,935.20 70° 25' 22.307 N 149° 57' 5.912 W ' - plan hits target center - Circle (radius 1,350.00) 31 -11A t1 0.00 6,221.00 - 954.16 - 535.07 6,006,133.54 507,296.22 70° 25' 40.737 N 149° 56' 25.937 W - plan hits target center - Circle (radius 1,350.00) 31 -11A, AL1 fault 1 0.00 0.00 0.00 - 912.76 - 902.05 6,006,174.54 506,929.22 70° 25' 41.143 N 149° 56' 36.703 W - plan misses target center by 6061.71ft at 6300.00ft MD (6042.23 TVD, - 811.83 N, - 427.15 E) - Polygon Point 1 0.00 - 912.76 - 902.05 6,006,174.54 506,929.22 Point 2 0.00 - 1,382.78 - 932.52 6,005,704.54 506,899.25 Point 3 0.00 - 1,197.74 - 948.34 6,005,889.54 506,883.24 Point 4 0.00 - 1,382.78 - 932.52 6,005,704.54 506,899.25 31 -11A, AL1 fault 2 0.00 0.00 0.00 - 2,022.61 - 1,134.26 6,005,064.56 506,698.21 70° 25' 30.228 N 149° 56' 43.510 W - plan misses target center by 6140.69ft at 8200.00ft MD (6125.44 TVD, - 1964.22 N, - 1562.88 E) - Polygon Point 1 0.00 - 2,022.61 - 1,134.26 6,005,064.56 506,698.21 Point 2 0.00 - 1,137.61 - 1,040.37 6,005,949.57 506,791.16 Point 3 0.00 512.11 - 599.68 6,007,599.59 507,230.07 Point4 0.00 - 1,137.61 - 1,040.37 6,005,949.57 506,791.16 31 -11A t2 0.00 6,219.00 - 983.10 - 590.10 6,006,104.54 507,241.22 70° 25' 40.452 N 149° 56' 27.552 W - plan hits target center - Point 31 -11A, AL1 fault 3 0.00 0.00 0.00 - 2,059.83 - 1,873.37 6,005,026.57 505,959.21 70° 25' 29.860 N 149° 57' 5.189 W - plan misses target center by 6134.05ft at 8200.00ft MD (6125.44 TVD, - 1964.22 N, - 1562.88 E) - Polygon Point 1 0.00 - 2,059.83 - 1,873.37 6,005,026.57 505,959.21 Point 2 0.00 - 2,206.22 - 1,500.48 6,004,880.59 506,332.22 Point 3 0.00 - 2,330.62 - 1,111.56 6,004,756.61 506,721.23 Point 4 0.00 - 2,206.22 - 1,500.48 6,004,880.59 506,332.22 31 -11A, AL1 fault 4 0.00 0.00 0.00 - 2,213.81 - 1,904.53 6,004,872.57 505,928.21 70° 25' 28.346 N 149° 57' 6.102 W - plan misses target center by 6140.00ft at 8237.30ft MD (6126.82 TVD, - 2001.49 N, - 1562.94 E) 6/10/2010 11:30:39AM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips FARM ConocoPhillips Planning Report BAKER Alaska HUGHES Data EDM Alaska Prod v16 Local Co- ordinate Reference:__, Well 31 -11 Company:._ " _ ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Pro ject" Kuparuk River Un MD Reference: - 31 -11 @ 76.00ft (31 -11) She: Kuparuk 31 Pad North Reference: , Tr Well: 31 - 11 Survey Calculation Method: M Curvature Welibore: ` 31 -11A Design: 31 -11 A_wp01 Polygon Point 1 0.00 - 2,213.81 - 1,904.53 6,004,872.57 505,928.21 Point 2 0.00 - 2,335.11 - 1,618.62 6,004,751.58 506,214.22 Point 3 0.00 - 2,453.49 - 1,249.70 6,004,633.60 506,583.23 Point4 0.00 - 2,335.11 - 1,618.62 6,004,751.58 506,214.22 Casing Points Measured Vertical Casing Hole " Depth Depth Diameter � Diameter (ft) (ft) Name ("1 ("} 9,200.00 6,157.50 2 -3/8" 2 -3/8 3 Plan Annotations Measured Ve rticai Local Coordinates Depth Depth + WS- (ft) (ft) (ft) (ft) Comment . 6,300.00 6,042.23 - 811.83 -427.15 TIP 31 -1 6,397.00 6,131.82 - 844.72 - 444.50 KOP 6,417.00 6,149.86 - 852.17 - 448.81 End DLS 35 6,482.00 6,196.39 - 890.57 - 471.03 4 6,517.00 6,211.25 - 916.43 - 489.15 5 6,578.09 6,221.13 - 954.69 - 534.97 End DLS 45 6,640.09 6,218.54 - 982.74 - 590.15 7 6,810.09 6,204.17 - 1,023.05 - 753.75 8 7,090.09 6,179.18 - 1,119.17 - 1,011.27 9 7,250.09 6,160.57 - 1,192.98 - 1,151.15 10 7,418.00 6,151.37 - 1,268.84 - 1,299.69 11 7,678.00 6,159.48 - 1,469.41 - 1,459.85 12 7,778.00 6,155.28 - 1,557.91 - 1,505.84 13 7,928.00 6,139.22 - 1,694.72 - 1,563.62 14 8,128.00 6,125.57 - 1,892.68 - 1,570.37 15 8,208.00 6,125.71 - 1,972.21 - 1,562.65 16 8,508.00 6,137.75 - 2,254.44 - 1,647.96 17 8,638.00 6,144.46 - 2,349.69 - 1,735.59 18 8,788.00 6,149.60 - 2,461.45 - 1,834.58 19 9,200.00 6,157.50 - 2,856.84 - 1,889.99 TD 6110/2010 11.30:39AM Page 7 COMPASS 2003.16 Build 69 , i G 1 t\I it-‘, 1_ A.. i °TweNMh WELLBORE DETAILS: 31 -11A REFERENCE INFORMATION /""' . _ Project: Kuparuk River Unit Magnet Nolh. 21 s r Site: Kuparuk.31 Pad C oordinate (N/E) Reference: We1131 -11, True North "" Mr N Parent Wellbore: 31 -11 - Wet: 31 -11 Tie on MD: 6300.00 saerwa+: sls s e.3"r Vertical (TVD) Reference: Mean Sea Level C#oco n �yp�py�+/� r y t r , ��� Wellbore: 31.11A DiiMgb:e0.89• Section (VS) Reference: Slot -(0.008,0.00E) o il'ip. s Plan 31-11A wp01(31- 11/31 -11A) g7 Measured Depth Reterenc 31 -11 @76.008(31.11) Lrr Calculation Method MinimumCUrvature HUGHES -400 - - WELL DETAILS: 31 -11 -600 ! TIP31 -ll Ground Level: 0.00 -800 , _ _ - _ . - _ _ - KOP •N / -S +E / -W Northing Easting Latittude Longitude Slot 0.00 0.00 6007088.16 507830 23 70° 25'50.121 N 149° 56'10.241 W 4 End DLS 35 -1000 ...� ^ 3 5 SECTION DETAILS ANNOTATIONS 1- 11 /+1 -11 Sec MD Inc Azi TVDSS 411 -S +E/-W DLeg TFace VSec Target Annotation -1200 1 6300.00 23.10 205.69 6042.23 - 811.83 -427.15 0.00 0.00 905.42 TIP 31 -11 , 10 End DLS 45 2 6397.00 22.01 210.05 6131.82 - 844.72 -444.50 2.06 125.10 942.13 KOP -1400 , 11 3 6417.00 29.01 210.05 6149.86 - 852.17 - 448.81 35.00 0.00 950.67 End DLS 35 c 12 4 6482.00 58.26 210.05 6196.39 890.57 -471.03 45.00 0.00 994.72 4 -1600 13 5 6517.00 71.51 219.50 6211.25 - 916.43 -489.15 45.00 35.00 1026.27 5 6 6578.09 90.00 240.21 6221.13 - 954.69 -534.97 45.00 50.00 1084.40 End DLS 45 ° l a cti 7 6640.09 94.77 245.92 6218.54 - 982.74 -590.15 12.00 50.00 1140.01 7 -1801 15 8 6810.09 94.82 266.39 6204.17 - 1023.05 - 753.75 12.00 89.00 1270.66 8 I 9 7090.09 95.12 232.66 6179.18 - 1119.17 - 101127 12.00 272.00 1502.41 9 + -2000 t 6 10 7250.09 98.12 251.76 6160.57 - 1192.98 - 1151 12.00 80.00 1645.54 10 11 7418.00 88.12 23422 6151.37 - 1268.84 - 1299.69 12.00 241.00 1795.52 11 12 7678.00 88.39 203.00 6159.48 - 1469.41 -1459.85 12.00 270.00 2052.09 12 -2200 lo 4* 13 7778.00 96.41 211.95 6155.28 - 1557.91 -1505.84 12.00 48.00 2150.44 13 14 7928.00 95.79 193.85 6139.22 - 1694.72 - 1563.62 12.00 269.00 2294.48 14 , -2400 19 `.. f 15 8128.00 91.93 170.11 6125.57 - 1892.68 - 1570.37 12.00 261.70 2456.63 15 r 16 8208.00 87.87 178.81 6125.71 - 1972.21 - 1562.65 12.00 115.00 2515.50 16 O 4 •^ 17 8508.00 87.69 214.83 6137.75 - 2254.44 - 1647.96 12.00 91.00 279225 17 07 -2600 GG 18 8638.00 86.43 230.40 6144.46 - 2349.69 - 1735.59 12.00 95.00 2921.05 18 , 19 8788.00 89.67 212.69 6149.60 - 2461.45 - 1834.58 12.00 280.00 3069.88 19 -2800 20 9200.00 8827 163.26 6157.50 - 2856.84 - 1889.99 12.00 268.00 3419.00 TD -- 31- 1131•11A _ ------ - - ---- m 31. 11/31 -]1L1 -3000 - " . -3200 34 -3 200 -30 - -1 - - 1 0 - -600 -400 -200 .. 2 .- r - 00 -2800 2600 -2400 -2200 2000 -1800 -1600 -1400 1200 1000 -800 00 0 0 200 400 West(- )/East( +) (200 ft/in) 58, 1 .. -. _. .. 5920 - -I, 6000 TIP 31 -11 6080 O 11+ +11' 1 -111,1 '..i End DLS 35 "� Il 1 1 -. 1 6160 , - 1 14 15 16 7 Q 6240 - 4 _. 9 10 12 1 -3 _. .. 18 19 _ Y 'o 5 \End I)I,54.5 7 8 31- 11/31 -11A V 6320 '., ',, '� g 6400- _ .. i 31- '.., ,, - 6480 ]I/3] -I1 , - - -- ... - . _ . I 6560 , -- _. 66,1 _. 6720 __ .... _. li 800 880 960 1040 1120 1200 1280 1360 1440 1520 1600 1680 1760 1840 1920 2000 2080 2160 2240 2320 2400 2480 2560 2640 2720 2800 2880 2960 3;40 3120 3200 3280 3360 3440 3520 3600 3680 3760 3840 Vertical Section at 217.00° (80 ft/in) Project: Kuparuk River Unit A[1.41e b T,.. Ncrth WELLBORE DETAILS: 31 -11A MegMC No011 23sr REFERENCE INFORMATION - Site: Kuparuk31Pad MegnencFcu Parent Wellbore'.31 -11 Co-ordinate (N/E) Reference : Welt 31-11, True North - Well: 31 -11 eeerpk57559.3m Tie on MD: 6300.00 i Vertical (NO) Reference: 31 -11 @ 76.00(1 (31.11) BAKER • W e S twre: 31.11A P lan: SI 11A vrp01(SI.11/31 - 11A) Moda �d ' e Section (VS) Reference Slot (0.00N, 0.00E) Conoc 3 11i Ip5 o . �ac cMZoca Measured Depth Reference. 31- 11 (§ 76.00ft(31.11) Calculahon Method: Minimum Curvature HUGH LS '.i -12 I ,1I- -.... _ _ _ _ 1200 / : -1 t,i,lh> ! 3I -03/31 -CB 31- 06/31 -06 s __. _. _.._ _.._._ T s 1000 o ■ 800 / 1. � � . / :. 600 400 :/ / = I 200 o -200 .. - .... ' -400 , -600 _...... ___ _ _.... _...... i _.. ... _. _.... _... -- .:'-- .__. -800- : / " / 31.11 / hS , ,.. % - r 7 31- 0481 -04 .sus ✓ Q .,.�.�.. N -1200- : - ± -1400_ /3' ,,d.'.. , � . . - 3113/31 -13 / `ci \ O -1600- . 1F/ 1::: - I - .. . .. ',,. :. : - -2200; / -2400 _... _ / _ • 2600 _.. : _... � 31 11/31 - 11A -2800 _._ I. - _. .. -_ _ ._. .. -. 61336314 - _ _ t i- il. - 3000 .. ,/ 31 11/31 - 1.11.1 - ht6u - 3200. ;. - ,..... '. - . : .. — 6511. I 177;11 -P' -3400 : _ : rr - 3800- . c,s; -4000 _. _. _ .... .6zoo _.__ - 31 -11 @ 76.006 (31 -11) �_ I ___/ 31 -15/31 is , - 4200 - 642 v l tiel) i -4400 -4200 -4000 -3800 -3600 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1 -1200 -1000 -800 600 -400 -200 0 200 400 600 800 1000 1200 00 1600 1800 2000 2200 2400 2600 2800 3000 West( - )/East( +) (200 ft/in) 31 -11A, AL1, & AL2 Proposed CTD Sidetrack Revision Updated: 10-Jun-10 Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) �= KEY 3-1/2", 9.3# L -80 EUE 8rd -Mod Tubing to surface Equipment and perforations set in WOO ." 3.112" Camco MMG gas lift mandrels (5) @ parent wellbore 2512', 3702', 4760', 5668', & 6074' Equipment set and lateral drilled 16" 62# H -40 shoe during first CTD project @ 116' MD X' landing nipple @ 6123' MD (2.813" min ID) Equipment set and laterals drilled during second CTD project __� `" �_ Baker 3 -1/2" seal assembly 6131' - 6143' MD 9-5/8" 36# J-55 ■ 80 -40 PBR at 6132' - 6145' shoe hoe @ 33833 ' MD �,,�, Baker KBH Anchor Seal Assy at 6145' MD s Baker SAB 40 -32 packer @ 6146' MD Whipstock @ 6397' • 'X' landing nipple @. 6156' MD (2.813" min ID) 31.11A L2 MD = (A3 sand, wp04) Holes shot in 3 straddle at — 6408' - 6413' & 6213' MD Kickoff from 31 - 11 AL1 @ 7360' • (Baker monobore I Full deployment sleeve @ 6300' whipstock) Baker F1 permanent packer @ 6422' MD (e -Ilse set) Soltd liner from 6300 - 6450' - 80 -40 Sealbore extension (6426- 6430') Slotted liner from 6450' to TD 3 -1/2" straddle TD @ 8180' " cemented in place f 'D' landing nipple @ 6433' MD (2.750" min ID) Cast Iron Bridge Plug �?:0. WLEG @ 6438' MD @ -6406 ' - -- FISH: 3-1/2" , r, ..- ' . . monobore }sri s< ,`, 31 -11A whipstock at 6422 ' s ',:s.,., (A2 sand_ wp10) 7 ` (TOWS) t r 0 Liner top billet 7400' ' 71.7 Slotted ` _ ,.u, _ Slotted liner from 7400' to TD FISH:3 -1l2 " •• TD @9200' • monobore 1=-1 whipstock @ unknown depth ■ A sand perfs — _ 31 -11 L1 9 A3: 643T -6454' —`— — (A2 sand) 31-1 1 AL1 A2: 6457' - 6486' e Kickoff from 31 - 11 @ 6409' (Al sand, wp05) Al: 6494' - 6503' Kickoff from 31 -11A @ 7400' "" Shorty deployment sleeve 0 7590' Liner top billet @ 7360' Slotted liner from 7590' to TD Slotted liner from 7360' -TD TD 0 9437' TO 0 9165' • 7" 26# J - 55 shoe 0 6761' MD • • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N Lubricator Riser r Annular/ Blind / Shear 2" Pipe / Stip (CT) Pump into Lubricator L BHA rams > I " - "I■ -1 1 _ 1 Choke 1 2 -3/8" Pipe / Slip (BHA) Choke Equalize Manifold 2 -3/8" Pipe / Slip (BHA) Kill ► <�< L i • J • --- k77 -- 77 • r I Bl / Shear 2" Pipe / Slip (CT) Choke 2 i Swab Valves 1 Wing Valves �ai�0i Tree Flow Cross I`rlVie7 Surface Safety Valve B OPE: 7-1/16", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi 0 Master Valve Kill Line: 2- 1/16 ", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union J R 1G I NA L • • TRANSMITTA L CHECKLIST — /4 WELL NAME �� - - i PTD# '/(_) 0 � � Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: 1. t�:t✓► POOL: ' L 4 l7 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 WELL PERMIT CHECKLIST' Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 3I -11A . Program DEV Well bore seg ❑ PTD#: 2100740 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On /Off Shore On Annular Disposal Administration 1 Permit fee attached NA .2 Lease number appropriate Yes Redrill: kick-off point,top prod interval & TD all lie within APL 25631. 3 Unique well name and number Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, govemed by Conservation Order No. 4320 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit _ " 6 Well located proper distance from other wells Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 4 miles i 7 Sufficient acreage available in drilling unit Yes from an external property line where ownership or landownership changes. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party_ Yes . 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without without administrative Yes 13 Can permit be approved before 15 -day wait Yes SFD 6/15/2010 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA III 11 II wells within 1/4 mile ea of review identified (For service well only) A ar e i ed (F o ry on y) NA 16 Pre- produced injector: duration of pre production Tess than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31,05.0300,1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set_in 31 -11 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in_ 31-11 '20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in 31 -11 21 CMTvol adequate to tie -in long string to surf csg NA Production casing set in 31 -11 22 CMT will cover all known_ productive horizons No Openhole slotted liner is planned. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with Steel pits. _ ,25 If a re- drill, has_a 1.0 -403 for abandonment been approved Yes 310 -177 and 310 -178 _ 26 Adequate wellbore separation proposed - Yes Proximity analysis performed. No issues. 27 If diverter required, does it meet regulations NA Wellhead in place ... BOP to_be_placed on production tree. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max form pressure = 4452 psi (13.9 ppg) Will drill with 10_ppg FloPro... and use MPD. GLS 6/29/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP 3800 psi. Will test BOP to 4500 psi III 31 Choke_manifoid complies w /API RP -53 (May 84). Yes 32 Work will occur without operation shutdown Yes 33 Is presenceof H2S gas probable _ _ Yes H2S on 3I pad... rig has sensors and alarms. 34 Mechanical_condition of wells within AOR verified (For service well only) NA -- 35 Permit can be issued w/o hydrogen sulfide measures No 31 -11 measured 150 pprn H2S in June 2009; measures required. _ Geology 36 Data presented on potential overpressure zones Yes Expected reservoirpressure is between 1.3.0 and 13.2 to as high as 13.9 ppg EMW. Appr Date 37 Seismic analysis of shallow gas zones NA Wellbore will be_ drilled using coiled tubing, 10.oppg mud, and Managed Pressure SFD 6/15/2010 38 Seabed condition survey (if off-shore) NA Drilling technique to maintain well control and wellbore stability,_ 39 Contact name /phone for weekly progress reports [exploratory only] NA . Geologic Engineering Public Re -drill to recover from a previous, unsuccessful attempt at drilling several laterals that failed because the whipstock released Commissioner: Date Co missio er: Date sioner Dat prematurely and moved downhole. 6 30 — (o ` O r ■ -3o —lo
