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Home My WebLink About212-004 T R A N S M I T T A 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 – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit Colville CD1-01A 50-103-20299-01 212099_CD1-01A_PERF_23Jul22 212099_CD1-01A_WFL_23May2022 CD1-04 50-103-20346-00 200117_CD1-04_PLUG_27Aug2022 CD1-33 50-103-20357-00 222105_CD1-33_Puncher_21Sep2022 CD1-48A 50-103-20592-01 212004_CD1-48A_LDL_28Jul2022 CD2-02 50-103-20513-00 205109_CD2-02_LDL_11Oct2022 205109_CD2-02_LDL_12Jul2022 205109_CD2-02_Patch_07Nov2022 205109_CD2-02_PLUG_23Aug2022 CD2-15 50-103-20386-00 201159_CD2-15_LDL_06Oct23 CD2-310 50-103-20826-00 220028_CD2-310_DHSIT_10Aug2022 220028_CD2-310_USIT_25Apr2022 CD2-404 50-103-20530-00 206054_CD2-404_Patch_30Dec2021 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 T38291 T38292 T38293 T38294 T38295 T39296 T38297 T38734 200-212 CD1-48A 50-103-20592-01 212004_CD1-48A_LDL_28Jul2022 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:54:09 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-07_22040_CRU_CD1-48A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22040 CRU CD1-48A 50-103-20592-01 Caliper Survey w/ Log Data 07-Aug-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:212-004 T36882 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.17 09:19:55 -08'00' ! 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)RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Meredith Guhl at 4:26 pm, Jan 07, 2022 Travis T. Smith Digitally signed by Travis T. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. dƌĂǀŝƐ͕ tŚĂƚŝƐƚŚĞKƉƌĞƐƐƵƌĞŚŝƐƚŽƌǇ͍ǆƉůĂŝŶǁŚǇƚŚĞKƐŚŽĞƐŚŽƵůĚďĞĐĞŵĞŶƚĞĚǁŝƚŚƚŚĞĚƌŝůůŝŶŐŽĨtͲϬϯ͘ sŝĐƚŽƌŝĂ Victoria Loepp 6HQLRU3HWUROHXP(QJLQHHU 6WDWHRI$ODVND 2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ :WK$YH $QFKRUDJH$. :RUN 9LFWRULD/RHSS#DODVNDJRY CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMION • z REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment ❑.i 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 212-004 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20592-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372096, 372097, 025559 CRU CD1-48A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 18112 feet Plugs measured None feet true vertical 7163 feet Junk measured None feet Effective Depth measured 17420 feet Packer measured 12089 feet true vertical 7119 feet true vertical 7083 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 3132' 9.625" 3160' 2395' Intermediate 12376' 7" 12403' 7110' Production Liner 5332' 4.5" 17420' 7119' RECEIVED Perforation depth Measured Depth: 13080'- 17371' tr1� SEP 0 9 2016 SCANNED True Vertical Depth: 7123'-7120' feet FEB 1 62017 Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 12135' MD, 7089'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker HRD ZXP Liner Top Packer, 12089' MD, 7083'TVD SSSV: Camco TRMAXX-5E, 2427' MD, 2000'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12403'- 18112' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 455 328 209 889 152 Subsequent to operation: 503 316 413 1269 153 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development ❑� Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ 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: N/A Contact Kerry Freedman Email Kerry.C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature Phone 265-6579 Date 6 tot VTI- G/ZG //G c q Form 10-404 Revised 5/2015 , f(2-,46 RBDMS \A/ SEP 1 2 2016 Submit Original Only • • CD1-48A Scale Inhibition Treatment 8/11/16—8/12/16 Hybrid Scale Inhibitor Squeeze Job pumped from 17:15 on 8/11/16 to 09:30 on 8/12/16. LRS= Little Red Services - Initial pressure TBG/IA/OA- 14/865/543 - LRS pumped 208 bbls Diesel/M209/WAW5206 pre-flush at 2 bpm,TBG/IA/OA-0/870/648 - LRS pumped 208 bbls Seawater/SCW3001WC scale inhibitor main treatment at 2 bpm, TBG/IA/OA—0/874/686 - LRS pumped 2,148 bbls Dead Oil/M209 over-flush at 2.2-3 bpm,TBG/IA/OA—578/916/815 Interval treated: 12,403'—18,112' ,i.-, • WNS PROD • CD1-48A ConoccPhilhips '&DM Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(') MD(ftKB) Act Btm(ftKB) t,x,.,.r,ct„Il,n, 501032059201 ALPINE PROD 92.53 13,01371 18,112.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Data HORIZONTAL-CD1.48A,2/26/201510.57.49 AM SSSV:TRDP Last WO: 3/23/2012 8.50 2/15/2009 Vertical schernat c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - Last Tag:SLM 11,703.0 7/22/2011 Rev Reason:SET WRDP lehallf 2/26/2015 HANGER',23.3 'roil. Casing Strings g. Casing Description OD(in) ID(in) Top(ftKB) Set Depth MB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread '{L "a CONDUCTOR 16 15.250 28.0 108.0 108.0 62.50 H-40 WELDED lir ti Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread SURFACE 95/8 8.921 27.7 3,159.9 2,395.3 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR;28.0-108.0 INTERMEDIATE 7 6.276 27.5 12,403.0 7,110.5 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...Wt/Len(L..Grade Top Thread WINDOW A 7 6.000 12,325.0 12,335.0 7,106.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WRDP;2,426.0 LINER 41)2 3.958. 12,088.5 17,420.0 7,119.3 12.60 L-80 Hyd 563 SAFETY VLV;2,4268 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 12,088.5 7,083.3 83.33 PACKER BAKER HRD ZXP LINER TOP PACKER 4.350 SURFACE;27.7-3,159.9-J 12,108.5 7,085.6 83.36 NIPPLE BAKER RS NIPPLE 4.350 12,111.4 7,085.9 83.41 HANGER BAKER FLEX LOCK LINER HANGER 4.350 GAS LIFT;5.006.4 12,122.0 7,087.1 83.58 SBE BAKER 80-40 20'SEAL BORE EXTENSION 4.000 12,236.9 7,098.2 85.10 NIPPLE HES XN NIPPLE 2.813 12,497.0 7,116.0 86.54 Swell Packer TAM SWELL PACKER w/5.875" 3.958 GAS LIFT;9,019.2 CEMENTRALIZERS III 12,596.4 7,121.8 87.28 Swell Packer TAM SWELL PACKER w/5.875" 3.958 CEMENTRALIZERS GAS LIFT;11,503.7 13,080.4 7,122.5 91.13 FRAC PORT BALL ACTUATED FRAC SLEEVE w/2.073"SEAT 2.125 FOR 2.125"BALL 13,600.9 7,130.3 88.47 Swell Packer TAM SWELL PACKER#3 FREECAP FSC-14 w/ 3.958 NIPPLE;11,6504 s 5.875 CEMENTRALIZERS 14,086.0 7,135.2 89.23 FRAC PORT 'BAKER BALL-ACTUATED FRAC SLEEVEw/2.011" 2.063 SEAT FOR 2.063"BALL 14,610.7 7,133.8 92.22 Swell Packer TAM SWELL PACKER#2,FREECAP-I FSC-14 w/ 3.958 GAUGE;12,0356 2.875"CEMETRALIZERS 14,927.2 7,127.1 89.39 FRAC PORT BAKER BALL-ACTUATED FRAC SLEEVE w/1.948" 2.000 SEAT FOR 2.00"BALL 15,241.6 7,125.8 91.68 Swell Packer TAM SWELL PACKER#1,FREECAP-I FSC-14 w/ 3.958 I 5.875"CEMENTRALIZERS LOCATOR;12,093.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 4.5"x3.5" 3 1/2 2.992 23.3 12,134.61 7,088.5 9.30 L-80 EUE8RD Completion Details SEAL ASSY;12,123.1 -_- Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(*) Item Des Com (in) ■ 23.3 23.3 0.00 HANGER FMC TUBING HANGER 4.500 133.3 133.3 0.46 XO Reducing CROSSOVER 4.5",12.6#,L-80 x 3.5" 2.992 2,426.8 2,000.1 56.53 SAFETY VLV CAMCO TRMAXX-5E w/2.812"X PROFILE w/1.4" 2.812 CONTROL LINE LOCKED OUT 2/9/2015 11,650.4 6,994.0 71.41 NIPPLE HES X NIPPLE 2.813 12,035.6 7,077.1 83.33 GAUGE CAMCO SOLID GAUGE MANDREL 2.867 WINDOW A;12,325.0.12,335.0 12,093.0 7,083.8 83.33 LOCATOR BAKER UPPER LOCATOR 2.990 INTERMEDIATE;27.512,403.0- 12,123.1 7,087.2 83.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY w/FULL MULE 2.990 SHOE I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 2,426.0 1,999.7 56.54 WRDP WRDP-1(SN C145-0874)w 2.83"pkg htm pkg stack 2/18/2015 1.562 Sup,10-ring,2down;upper pkg 5down,10-ring 2 up FRAC;13,080.0 PERFP;13,000.0-13,084.0 • g Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f a_ Top(ftKB) Bter(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 13,080.0 13,084.0 7,122.5 7,122.4 3/18/2012 1.0 PERFP Frac Port-Single 4" slot/FRAC Port PERFP;14,086.0.14.089.0 FRAC;14,086.01-aI i1 14,086.0 14,089.0 7,135.2 7,135.3 3/18/2012 1.0 PERFP Frac Port-Single 4" slot/FRAC Port 14,927.0 14,931.0 7,127.1 7,127.2 3/18/2012 1.0 PERFP Frac Port-Single 4" slot/FRAC Port 15,534.2 15,539.0 7,121.0 7,121.1 3/18/2012 1.0 PERFP Pre-Perrd pup jt w/6ea 1/2"holes 15,821.3 15,826.1 7,123.9 7,123.9 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea PERFP;14,927.0.14,931.0 444--- 1 1/2"holes FRAC;14,927.051 ■ a J l 16,106.0 16,110.8 7,122.8 7,122.8 3/18/2012 1.0 PERFP Pre-Perfd pup jtw/6ea 1/2"holes 16,390.6 16,395.4 7,121.8 7,121.7 3/18/2012 1.0 PERFP Pre-Perld pup jt w/6ea - - 1/2"holes 16,717.1 16,721.9 7,125.6 7,125.6 3/18/2012 1.0 PERFP Pre-Perld pup jt w/6 ea 1/2"holes PERFP;15,534.2-15.539.0 17,043.9 17,048.7 7,126.0 7,126.0 3/18/2012 1.0 PERFP Pre-PerrdP P u jt w/6 ea 1Y2"holes PERFP;15,821.315,828.1 I 17,366.2 17,370.9 7,120.5 7,120.4 3/18/2012 1.0 PERFP Pre-Per/d pup jt w/6ea PERFP;16,106.0.16.110.8 1/2"holes PERFP;16390.6-16395.4.x. I Stimulations&Treatments FRAC;15,534.0 PERFP;16,717.1-16,721.9Min Top Max Btm Depth Depth Top(TVD) Btm(ND) PERFP;17,013.9-17,048.7 I I (ftKB( (ftKB) (ftKB) (ftKB) Type Date Com 13,080.0 17,371.0 7,122.5 7,122.4 FRAC 4/17/2012 PUMPED 16/20 CARBOLITE PERFP;17,366.2-17,370.9 I I 13,080.0 17,371.0 7,135.2 7,135.3 FRAC 4/17/2012 PUMPED 16/20 CARBOLITE LINER;12,088.617,420.0 J l ti WNS PROD • CD1-48A onoco 114 CPhillips m Alaska,Inc. IF cvtocdt irgra • HORIZONTAL-CDM AEA,2126/2015 10:57 50 AM Vertical schematic(actual) IIIMBIMMMMMJMLLMOZIIIMOLMMIMRIJIIIIIIIIIIIMAI HANGER.23.3— Iteriktai:: Stimulations&Treatments 1 1 Min Top Max Btm 'lie J Depth Depth Top(ND) Btm(ND) €I VI (ORB) (ftKB) (ftKB) (MO) Type Date Com J 13,080.0 17,371.0 7,127.1 7,127.2 FRAC 4/17/2012 PUMPED 16/20 CARBOLITE 13,080.0 17,371.0 7,121.0 7,120.4 FRAC 4/17/2012 PUMPED 16/20 CARBOLITE CONDUCTOR;28.0408.0 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run WRDP;2.426.0r N Top(ftKB) (ftKB) Make Model OD(inl Sets T T SAFETY VLV;2,426.81 ypeType (in) (psi) Run Date Com 5,006.4 3,408.6 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,948.0 4/25/2012 2 9,019.3 5,601.3 CAMCO KBMG 1 GAS LIFT GLV BK-5 0188 1,989.0 4/24/2012 3 11,503.8 6,940.5 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 1/30/2015 SURFACE;27.7-3,159.9— Notes:General&Safety End Date Annotation 2/18/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;5,006.4 3/23/2012 NOTE:WELL SIDETRACKED TO'A' GAS UFT;9,019.2 GAS LIFT;11,503.7 NIPPLE;11,650.4 aNis GAUGE;12,035.6 -- 7 C LOCATOR;12,053.0 d II II I SEAL ASSY;12,123.1 — illi ■ WINDOW A;12,325.0-12,335.0 S INTERMEDIATE;27.5-12.403.0—s• 4` •U- FRAC;13,080.0 PERFP;13,080.0.13,084.0 ®. I • PERFP;14,088.0.140890 FRAC;14,086.0E III PERFP;14927.0-14,931.0 [ i FRAC;14,927.01 . ® 1 PERFP;15,534.2-15,539.0 PERFP;15,821.3-15,826.1 PERFP;16,106.0-16,110.8 I I PERFP;16,390.6-15395.4I I FRAC;15,534.0 I I PERFP;16,717.1-15721.9— PERFP;17,043.9-17.048.7— I I PERFP;17,366.2-17,370.9— I I LINER;12,0855-17,420.0 1 STATE OF ALASKA . AL .A OIL AND GAS CONSERVATION CON. ,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing 1- Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Scale Inhibitor Treatmentl� 2.Operator Name. 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development p' Exploratory r 212-004-0 3.Address 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20592-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372096,372097,025559 CRU CD1-48A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 18112 feet Plugs(measured) none true vertical 7163 feet Junk(measured) none Effective Depth measured 17420 feet Packer(measured) 12089 true vertical 7118 feet (true vertical) 7083 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108 108 SURFACE 3132 9.625 3160 2395 INTERMEDIATE 12376 7 12403 7110 f .'.. z w LINER 5332 4.5 17420 7119 �F _1UfJ 0 15 Perforation depth: Measured depth: 13080'-17371' c r A 1.1 NEU J U L 0 92015 aO G C C True Vertical Depth: 7123'-7120' �74f�1` Tubing(size,grade,MD,and TVD) 3.5, L-80, 12135 MD,7087 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HRD ZXP LINER TOP PACKER @ 12089' MD and 7083'TVD SSSV-CAMCO TRMAXX-5E @ 2427'MD and 2000'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12596'-18112' Treatment descriptions including volumes used and final pressure. see attached summary 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 519 416 172 995 144 Subsequent to operation 620 583 225 1192 150 14.Attachments(required per 20 AAC 25.070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil R.7 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 1 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 Kerry Freedman a,265-6579 Email Kerry.C.Freedman@_conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature6.A.Aj Phone:265-6579 Date 6 /q I art 6//s/i.7 RBDMS JUN 1 1 2015 Form 10-404 Revised 5/2015 Submit Original Only CD1-48A Scale Inhibition Treatment 5/11/15 Hybrid Scale Inhibitor Squeeze Job pumped 5/11/15 08:00 to 18:30. LRS= Little Red Services - Initial pressure TBG/IA/OA—137/799/538 - LRS pumped 208 bbls Diesel/M209/WAW5206 preflush at 1.5-5 bpm,TBG/IA/OA— 38/799/622 - LRS pumped 208 bbls Seawater and SCW3001WC scale inhibitor main treatment at 3—5 bpm, TBG/IA/OA—63/819/688 - LRS pumped 2080 bbls Dead Crude/M209 overflush at 2.9-4.5 bpm,TBG/IA/OA—502/812/738 Interval treated: 12,596'—18,112' , 1.-- s WNS PROD CD1-48A ConocoPhillips ry • • Well Attributes Max Angle&MD TD Alaska,Inc. WellboreAPIIUWI Field Name Wellbores tus Pnel(') MD(RKB) Act c�caoand6pa 501032059201 ALPINE PROD I 92.53 13,013.71 18,112.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date HORIZONTAL-CD1-48A 2/26/2015 10 SSSV:TRDP Last WO: 3/23/2012 8.50 2/15/2009 Vertical schemal,c(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag'.SLM 11,703.0 7/22/2011 Rev Reason:SETWRDP lehallf 2/26/2015 ,,,,„,,,,,,„, .„,,,,,,..,,,,,m,,,,,m,,,,,,,,,,,,,,,,,,,,,,,,.,.,,m.,,,, RANGE R;23.3-11rTgAir Casing Strings I` 1f Casing Description OD(in) 10(In) Top(RIB) Set Depth(RKB) Set Depth(ND)...WBLen(1...Grade Top Thread es CONDUCTOR 16 15.250 28.0 108.0 108.0 62.50 H-40 WELDED iylCasing Description OD(in) 'ID(in) Top(RKB) Set Depth(MB) Set Depth(ND)...W#Len(I...Grade Top Thread SURFACE 95/8 8.921 27.7 3,159.9 2,395.3 36.00 J-55 BTC Casing Description OD(In) ID(in) Top(MB) Set Depth MB) Set Depth(ND)...WtlLen 0...Grade Top Thread CONDUCTOR;28.0.108.0 INTERMEDIATE 7 6.276 27.5 12,403.0 7,110.5 26.00 L-80 BTCM Casing Description OD(in) ID(In) Top(RKB) Set Depth(RKB) Set Depth(ND)...WULen(I...Grade Top Thread WINDOWA 7 6.000 12,325.0 12,335.0 7,106.0 Casing Description (In) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WRDP;2,426.0 . LINER 41/2 3.958 12,088.5 17,420.0 7,119.3 12.60 L-80 Hyd 563 SAFETY VLV;2,426.81 'l ' Liner Details Nominal ID • Top(ft68) Top(ND)(RKB) Top Incl(°) Item Des Com (In) 12,088.5 7,083.3 83.33 PACKER BAKER HRD ZXP LINER TOP PACKER 4.350 SURFACE;27.7-3,1599--• • 12,108.5 7,085.6 83.36 NIPPLE BAKER RS NIPPLE 4.350 12,111.4 7,085.9 83.41 HANGER BAKER FLEX LOCK LINER HANGER 4.350 GAS LIFT;5,006.4 12,122.0 7,087.1 83.58 SBE BAKER 80-40 20'SEAL BORE EXTENSION 4.000 12,236.9 7,098.2 85.10 NIPPLE HES XN NIPPLE 2.813 12,497.0 7,116.0 86.54 Swell Packer TAM SWELL PACKER w/5.875" 3.958 CEMENTRALIZERS GAS LIFT;9,019.2 t: WNS PROD CD1-48A ConocoPhillips Alaska,Inc. omociiiiTps HORIZONTAL-CD1-486,2/26/2015 10-5750 AM Vertical schema.(actual) HANGER;23.3—' ',LIIp,$ n,n• Stimulations&Treatments ¢�jj, Min Top Maxetm ��J�AJcrMMhM tea Depth Depth (M(B)) Btm(B) i+. (ftKB) (ttKB) (tIKB) (MB) Type Date Com ■ 13,080.0 17,371.0 7,127.1 7,127.2 FRAC 4/17/2012 PUMPED 16/20 CARBOLITE 13,080.0 17,371.0 7,121.0 7,120.4 FRAC 4/17/2012 PUMPED ma CARBOLITE CONDUCTOR;28.0-108.0 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Site TRO Run WHOP;2,426.0 N Top(ttKB) (ttKB) Make Model 00(in) Sem Type Type (In) (psi) Run Date Com SAFETY VLV;2,426.8 1' 5,006.4 3,408.6 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,948.0 4/25/2012 2 9,019.3 5,601.3 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,989.0 4/24/2012 3 11,503.8 6,940.5 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 1/30/2015 Notes:General&Safety SURFACE;27.7.3.159.9— End Date Annotation • 2/18/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;5,008.4 3/23/2012 NOTE:WELL SIDETRACKED TO'A' • GAS UFT;9,019.2 GAS LIFT;11,503.7 NIPPLE;11,650.4 GAUGE;12.035.8 - C LOCATOR;12,093.0 SEAL ASSY;12,123.1 ■ WINDOW A 12,325.0-12,335.0 INTERMEDIATE;27.5-12,403.0-- FRAC;13,080.0 PERFP;13,080.0-13.084.0 [IE • PERFP;14.0566.0-14,089.0, FRAC;14,086.0 PERFP;14.927.014,931.0 FRAC;14,927.01-[� PERFP,15,534.2-15.539.0 I I PERFP;15.821.3-15,826.1— PERFP,16.108.0-16,110.13— PERFP:16,390.6-16,395.4-.._ FRAC;15,534.0 PERFP;16,717.1-18,721.9 — I I I PERFP;17,013.9-17,048.7 • PERFP;17,368.2.17,370.9— UNER;12.088.5-17.420.0 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. la - 0014- Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: or Items: ❑ Ma s: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Date: CO/ /s/ Ili Project Proofing BY: C Maria) Date: U / t_ /s/ --- Scanning Preparation 3 x 30 = go + 5- = TOTAL PAGES i BY: 4111, Date: (Count does not include cover sheet) 71811 ! /s/Production Scanning Stage 1 Page Count from Scanned File: q tO (Count does include cover heet) t Page Count Matches Number in Scanning Preparation: YES NO BY: Maria ) Date: 9/4 / /s/1 " r Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o E a m 0 9 a) V. U- 8 a o2 N as maw w o Z 0 p Not) c 0 00) u m 2i IL- sM U ) JpI Oa - aO 0, 0 y EJo a 2to mrn rx N co E (1)00_:EoM 00 O J Q o Z U =a= Pi d( pm 25 d coli _ c + C C > N N N N O O J N W tl N N N N Q O r .- .N- .N- Q N 2 C C C C E 11 Q co m Y 0U O 0 0 0 o O re Q C U co2 co O. N r ,. M Oa. d 7 N « co a) y y z z J U a R N ao ao o c o a W = :: M co Ln i (I) z Ce 0 CICO,) M M O U d)I( a W Z v > O J > a) U 0 a N Z C a a 0 O 2 Z I-- < 1`0 co O C N O J aOm 1 CO _ .m U coil _ _ t'' >, EA o ZI J 0 ( ,C M G N a) N a au)) a) I.0 to O m co J N N N O E J co Q Cl) `l` 0 2 p r F- N — V) Z O l0 > ") C CO N — M Wj J a) CO J 0 w Q 0 o Q o ZI v) w 0 z o > '> '> �I N 0 c .N C .y .N E to i a) o a) a) r z 7 0 j a (..) a a C 9. C C —y a) OO O co E E f) > U U E 1 CO O z o o o w j N. Q.' o — — — E z o p z o 5 y c'' O �. O md > O J y a C,)„pH H y V B E .;- C '0 N ~ >- 3N Q zYcwoz y N m 0 0 2 m 0 m O 1IL ( a a) a (. >? reLL E Ev v, R m0 Z J J 1 CO Z Q p. '0 jp 7700 W ` a) O m a) w v c3 tvU \ O O a O N - E \a U U_ a >,•( E a`m 0 a s a o o D pp a) 's c ate) o 0a w a J J Q U ¢a U U Iprx RECEIVED ConocoPhillips Alaska FEB 12 2014 P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 January 30, 2014 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped in the spring of 2007. The corrosion inhibitor/sealant was pumped in the month of January 2014. The attached spreadsheet presents the well name,top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 1/30/2014 CD1&2 PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-10 50103203530000 2001710 18" na 18" na 15.3 1/20/2014 CD1-12 50103205010000 2042050 4" na 4" na 4.5 1/20/2014 CD1-14 50103203710000 2010380 4" na 4" na 3.5 1/20/2014 CD1-18 50103205020000 2042060 4" na 4" na 2.7 1/20/2014 CD1-26 50103203050000 1990880 6" na 6" na 6.4 1/20/2014 CD1-35 50103202970000 ,1990380 4" na 4" na 3.5 1/20/2014 CD1-45 50103203070000 ."1991010 4" na 4" na 3:7 1/20/2014 CD1-48A 50103205920100 2120040 SF na 5" na 2.8 1/20/2014 CD1-49 50103206610000 2121770 12" na 12" na 2.4 1/20/2014 CD2-1 50103205140000 2051180 4" na 4" na 4.6 1/27/2014 CD2-3 50103205120000 2050920 4" na 4" na 4.4 1/27/2014 CD2-5 50103204950000 2040970 4" na 4" na 3.5 1/27/2014 CD2-19 50103204230000 2021120 4" na 4" na 4.9 1/27/2014 CD2-21 50103205040000 ,2042450 6" na 6" na 4.2 1/27/2014 CD2-22 50103204210000 2020920 27" na 27" na 11.5 1/27/2014 CD2-32 50103204110000 2020290 4" na 4" na 2.7 1/27/2014 CD2-34 50103203930000 2011910 6" na 6" na 2.7 1/27/2014 CD2-36 50103204470000 2030140 7' 0.95 5" 3/21/07 5.7 1/27/2014 CD2-39 50103203870000 2011600 34" na 11" na 17.9 1/27/2014 CD2-49 50103204010000 2012490 8" na 8" na 5.2 1/27/2014 CD2-52 50103204590000 2030930 57" 0.80 4" 3/21/07 3.5 1/27/2014 CD2-54 50103204990000 2041780 8" na 8" na 5.4 1/27/2014 CD2-57 50103204920000 2040720 8" na 8" na 2.7 1/27/2014 CD2-72 50103205460000 2070570 6" na 6" na 4.3 1/27/2014 CD2-73 50103205900000 2081960 4'5" na 4'5" na 24.2 1/27/2014 CD2-465 50103205830000 2081450 19" na 19" na ,9.3 1/27/2014 1 RECEIVED Halliburton JAN 16 2013 Sperry Drilling 6900 Arctic Blvd AOGCC Anchorage, AK 99518 AOGCC Jan. 10, 2013 AOGCC Makana Bender © 333 W. 7th Ave., Suite 10 � b � Anchorage, AK 99501 0\-/ ` 0 Dear Sir or Madam(/' ra Subject: CD3-119/CD3-128/CD -4: A /CD4-03 Definitive Survey Reports Enclosed are one hard copy (NAD83 and NAD27) of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit©Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK •1.18 Received by:alai�I_�I 0f/fitl Date: Please contact me at 907.263.465 with questions or concerns. Regards, D,- it,„„ ), 307 Avinash Ramjit '-- STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 23,2012 212-004/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 March 7,2012 50-103-20592-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 559'FNL,2244'FWL,Sec.5,T11N,R5E, UM March 15,2012 CD1-48A Top of Productive Horizon: 8. KB(ft above MSL): 46.8'RKB 15.Field/Pool(s): 641'FSL, 1736'FEL,Sec.8,T11N, R5E,UM GL(ft above MSL): 19.5'AMSL Colville River Field Total Depth: 9.Plug Back Depth(MD+TVD): 4301'FNL,4224'FEL,Sec. 16,T11N,R5E,UM 17420'MD/7119'ND Fiord Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-385667.5 y- 5975572.6 Zone-4 18112'MD/7163'ND ADL 372096,372097,025559 TPI: x-386855 y- 5966194 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-389587 y- 5961212 Zone-4 2427'MD/2000'ND none 18.Directional Survey: Yes ❑� No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1601'MD/1495'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 12325'MD/7105'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# H-40 28' 114' 28' 114' 24" Portland Type II 9.625" 36# J-55 28' 3160' 28' 2440' 12.25" 462 sx AS Lite,256 sx Class G 7" 26# L-80 28' 12043' 28' 7111' 8.75" 257 sx Class G,187 sx Class G 4.5" 12.6# L-80 12088' 17420' 7082' 7119' 6.125" pert pups w/blank pipe 24.Open to production or injection? Yes ❑ No a If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 13080'-13084'MD 7122'-7122'ND 1 spf 4.5"x3.5" 135'x12135' 12088'MD/7082'ND, 14086-14089'MD 7135'-7135'ND 1 spf 5 swell packers 14927-14931'MD 7127'-7127'ND 1 spf 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 15534'-15539'MD 7121'-7121'ND 1 spf DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 15821'-15826'MD 7124'-7124'ND 1 spf 16106'-16111'MD 7122'-7122'ND 1 spf more perfs: 16391'-16395'MD 7122'-7122'ND 1 spf 17044'-17049'MD 7127-7127'ND 16717'-16722'MD 7126-7126'ND 1 spf 17366-17371'MD 7121'-7120'ND 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory anal tical results per 20 AAC 25.071. DECEIVED ,,,,4_,...,,,,.4- NONE APR 2 4 2012 pBDMS APR 24 1011m AOGCC Form 10-407 Revised 12/2009 CONTINUED ON REVERSE n � 1 `� Submit original only � (�jv C 28. GEOLOGIC MARKERS(List all formations and 1.._,Kers 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 1601' 1495' needed,and submit detailed test information per 20 AAC 25.071. top Alpine C 12325' 7105' bottom Alpine C 18112' 7163' N/A Formation at total depth: Alpine C 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Weifepg,Dai @ 263-4324 WWfEV Printed Name / ! Alvord Title: Drilling Manager �J Signature Phone 265-6120 Date ` (V?)2•41 L- I NSTRUCTIONS INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23:If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 r 4 WNS CD1-48A ConocoPhillips Well Attributes Max Angle&MD TD AlaskaInc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) CorwmPfJlilps 501032059201 ALPINE PROD 92.53 13,013.71 18,112.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••Well Genf&:HORIZONTAL-CD1-48A.4/13/2012 9:56:17 AM S--, SSV:TRDP Last WO: 3/23/2012 8.50 2/15/2009 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod... End Date Last Tag:SLM 11,703.0 7/22/2011 Rev Reason:Set FRAC SLV,Pull RHC,Set Gauge osborl 4/13/2012 HANGER,23 g -.1 Casing Strings Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd rr CONDUCTOR 16 15.250 28.0 108.0 108.0 62.50 H-40 WELDED Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String WL.. String... String Top Thrd SURFACE 9 5/8 8.921 27.7 3,159.9 2,395.2 36.00 J-55 BTC i illrj Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd CONDUCTOR, INTERMEDIATE 7 6.276 27.5 12,403.0 7,110.5 26.00 L-80 BTCM 28-108 Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String.-. String Top Thrd LINER 4 1/2 3.958 12,088.5 17,420.0 7,119.3 12.60 L-80 Hyd 563 SAFETY VLV, Liner Details 42mit SLEEVE,2.2,427 Top Depth ;C (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (1 Item Description Comment ID(In) 12,088.5 7,083.2 83.04 PACKER BAKER HRD ZXP LINER TOP PACKER 4.350 SURFACE, 12,108.5 7,085.6 83.36 NIPPLE BAKER RS NIPPLE 4.350 28-3,160 12,111.4 7,085.9 83.41 HANGER BAKER FLEX LOCK LINER HANGER 4.350 GAS S 006 {r 12,122.0 7,087.1 83.58 SBE BAKER 80-40 20'SEAL BORE EXTENSION 4.000 12,236.9 7,097.8 84.93 NIPPLE HES XN NIPPLE 2.813 12,497.0 7,116.0 86.55 Swell Packer TAM SWELL PACKER w/5.875"CEMENTRALIZERS 3.958 12,596.4 7,121.6 87.11 Swell Packer TAM SWELL PACKER w/5.875"CEMENTRALIZERS 3.958 13,080.4 7,121.6 89.58 FRAC PORT BALL ACTUATED FRAC SLEEVE w/2.073"SEAT FOR 2.125"BALL 2.125 GAS LIFT, 9,019 - 13,600.9 7,129.9 87.51 Swell Packer TAM SWELL PACKER#3 FREECAP FSC-14 w/5.875 3.958 CEMENTRALIZERS MI 14,086.0 7,135.2 89.23 FRAC PORT BAKER BALL-ACTUATED FRAC SLEEVE w/2.011"SEAT FOR 2.063" 2.063 GAS LIFT, ' BALL 11,504 GAUGE,11,504 n ''" 14,610.7 7,133.8 92.22 Swell Packer TAM SWELL PACKER#2,FREECAP-I FSC-14 w/2.875" 3.958 CEMETRALIZERS 1111111 1111111 14,927.2 7,127.1 89.05 FRAC PORT BAKER BALL-ACTUATED FRAC SLEEVE w/1.948"SEAT FOR 2.00" 2.000 NIPPLE,11,650 1116 BALL - 15,241.6 7,127.1 92.69 Swell Packer TAM SWELL PACKER#1,FREECAP-I FSC-14 w/5.875" 3.958 - CEMENTRALIZERS NIPPLE,12,036 ;[ `; Tubing Strings Tubing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd MEN TUBING 4.5"x3.5" 3 1/2 2.992 23.3 12,134.6 7,088.4 9.30 L-80 EUE8RD Completion Details - ` Top Depth LOCATOR, 12,093 '`1 (ND) Top Incl Nomi... .-� Top(ftKB) (ftKB) (1 Item Description Comment ID(in) 23.3 23.3 -0.05 HANGER FMC TUBING HANGER 4.500 I. 133.3 133.3 0.46 XO Reducing CROSSOVER 4.5",12.6#,L-80 x 3.5" 2.992 SEAL ASSY, r 2,426.8 2,000.1 56.53 SAFETY VLV CAMCO TRMAXX-5E w/2.812"X PROFILE w/1.4"CONTROL LINE 2.812 12,123 11,650.4 6,993.8 71.41 NIPPLE HES X NIPPLE 2.813 12,035.6 7,077.1 83.33 NIPPLE CAMCO SOLID GAUGE MANDREL 2.867 I 12,093.0 7,083.7 83.11 LOCATOR BAKER UPPER LOCATOR 2.990 12,123.1 7,087.2 83.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY w/FULL MULE SHOE 2.990 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth NTERMEDIATE, , (ND) Top Incl 28-12.403 Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 2,426.9 2,000.2 56.53 SLEEVE FRAC SLEEVE SET IN TRDP(OAL=57")-PRE FRAC 4/11/2012 2.265 mi11,503.8 6,940.5 66.69 GAUGE SPARTEK GAUGE SET IN MANDREL 4/11/2012 0.000 Perforations&Slots Shot Top(ND) Btm(ND) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh••- Type Comment ® 13,080.0 13,084.0 7,121.6 7,121.6 3/18/2012 1.0 PERFP Frac Port-Single 4"slot/FRAC Port PERFP, 13,080-13.084 ■ - 14,086.0 14,089.0 7,135.2 7,135.3 3/18/2012 1.0 PERFP Frac Port-Single 4"slot/FRAC Port 14,927.0 14,931.0 7,127.1 7,127.1 3/18/2012 1.0 PERFP Frac Port-Single 4"slot/FRAC Port 15,534.2 15,539.0 7,121.1 7,121.1 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea 1/2"holes ■ 15,821.3 15,826.1 7,123.8 7,123.8 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea 1/2"holes 16,106.0 16,110.8 7,122.0 7,122.1 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea 1/2"holes PERFP, 14,086-14.089 16,390.6 16,395.4 7,121.9 7,121.8 3/18/2012 1.0 PERFP Pre-Perfd pup jtw/6 ea 1/2"holes 16,717.1 16,721.9 7,125.6 7,125.6 3/18/2012 1.0 PERFP Pre-Perfd pup jtw/6 ea 1/2"holes 17,043.9 17,048.7 7,126.7 7,126.5 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea 1/2"holes 17,366.2 17,370.9 7,120.5 7,120.4 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea 1/2"holes Notes:General&Safety End Date Annotation PERFP, 3/23/2012 NOTE:WELL SIDETRACKED TO'A' 14,927-14.931 Mandrel Details , . Top Depth Top Por __ (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (In) (psi) Run Date Com... 1 5,006.4 3,408.6 55.12 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/15/2012 15,534-1 PERFP,9 5,53 : a 2 9,019.3 5,601.4 57.18 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/15/2012 l PERFP, 'I I iii j 3 11,503.8 6,940.5 66.68 CAMCO KBMG 1 GAS LIFT Gauge BK 0.000 0.0 4/11/2012 , 15 821-15.828 m PERFP, 1_i I 16,10 P, 16,391PERF-16.395 1 I PERFP, 16,717-16.722 I PERFP, l 17,044-17.049-------13 M PERFP, 17,366-17,371MI=i t L LINNER,R, 12,088-17.420 TO(CD1-48A), l 18,112 Conoco Phillips Time Log & Summary Wellview Web Reporting Report Well Name: CD1-48 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 2/20/2012 6:00:00 AM Rig Release: 3/23/2012 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/18/2012 24 hr Summary Rig down and move off of Shark Tooth#1.Move Boiler, Motors, Pumps, Pits to CD1 Alpine, and the sows were back before 22:00 Hrs. 06:00 11:00 5.00 0 0 MIRU MOVE MOB P Rig down on Shark Tooth#1, prepare for rig move to CD1-48. PJSM. Lay down mouse hole. Unload pipe shed, pull skate.Continue to clean pits and rock washer,disconnect service lines between modules. Glycol, water,steam,air,electrical. Disconnect Tioga. 11:00 12:00 1.00 0 0 MIRU MOVE MOB P Jack up pipesheds,stage sheds on pad. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Hook up to and move, Boiler module, Motor module, Pit module, Pump module. Begin rolling to Alpine.4 sows. Back to Shark Tooth with the Sows by 22:00 hrs. Hook up to the sub base,2 pipe shed modules, rock washer. 02/19/2012 Move pipe shed modules, rock washer,sub base from Shark Tooth#1 to CD1-48. 00:00 00:00 24.00 0 MIRU MOVE MOB P Move sub base, pipe shed, rock washer to CD1-48.Spot sub base over CD1-48. Position rig modules around sub and hook up interconnect lines.Air,water,steam, hydraulic. Assemble rig and prepare for rig acceptance.Camp began blow down @ 17:00 hrs, began last trip with truck shop and camp @ 20:00 hrs. 02/20/2012 Berm in boiler module, sub base,tioga heater, rock washer. Hook up all interconnect lines, prepare pits to take on brine. Rig Acceptance 6:00 hrs.Change liners in#2 pump 6 to 5W. Displace well to 9.1 PPG brine. ND tree. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P PJSM.Continue to work on Rig Acceptance check list. Berm in boiler complex&enviroshack,work on mud pumps, install drain plugs in centrifugal pumps, rig up cellar pump,turn on water and waste heat system.Trim off all excess herculite. RIG ACCEPTED @ 06:00 HRS. 06:00 09:30 3.50 0 0 SLOT WELLPF RURD P Change out#2 pump liners from 6"to 5W. Bring XO's to rig floor,stage BOP adaptor flange in cellar, Pick up FMC lubricator. Set up berming for two 500 barrel outside tiger tanks, choke skid, lay out hardline. Page 1 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:30 1.00 0 0 SLOT WELLPF RURD P Rig up lubricator,test to 2,000 PSI, pull BPV. 50 PSI on tubing. OA and IA both showed 160 PSI. 10:30 12:00 1.50 0 0 SLOT WELLPF RURD P Rig up circulating line to well from choke house on the inner annulus. _Rig up mud pumps to tubing. 12:00 13:00 1.00 0 0 SLOT WELLPF PRTS P PJSM. Rig up to pressure test lines from mud pumps to Tiger tanks,to 2,000 PSI. 13:00 13:30 0.50 0 0 SLOT WELLPF PRTS P Pressure test lines to 250 PSI. Good.Test lines to 2500 PSI.Good. Test lines to 4000 PSI from mud pumps to rig floor. Found leak at __mud manifold on rig floor. 13:30 14:45 1.25 0 0 SLOT WELLPF PRTS P Removed cement manifold to attempt to fix leak. Decision made to isolate manifold and rig up lines from pump room to production tree until manifold gets repaired. 14:45 15:30 0.75 0 0 SLOT WELLPF PRTS P Pressure test lines from pump room to cellar to 2,000 PSI. Good. Notify Alpine security of the upcoming operations,well displacement,and possible gas venting.Alpine security made a field wide announcement. 15:30 15:45 0.25 0 0 SLOT WELLPF SFTY P Prejob safety meeting on displacing the well to 9.3 PPG brine,from dead crude and diesel. 15:45 19:45 4.00 0 0 SLOT WELCTL CIRC P Displace well with 9.1 PPG Kill Weight brine @ 2 BPM through the choke house and into the tiger tanks. Pumped 461 barrels, returned 461 barrels. 19:45 21:00 1.25 0 0 SLOT WELLPF RURD P Blow down and rig down lines to tiger tanks.SIMOPS:Monitored well for 30 mins. Install BPV on dry rod.Test in direction of flow to 1000 PSI for 5 mins.Co-Man, Driller witness. Good. 21:00 22:00 1.00 0 0 SLOT WELLPF OWFF P Rig down lines, blow down to pump room. Observe Inner Annulus for 30 mins. 22:00 00:00 2.00 0 0 SLOT WELLPF NUND P PJSM. Nipple down production tree. Install blanking plug, install speed clamp, nipple down adapter flange on bottom of BOP stack. 02/21/2012 ND tree. NU BOPE and test. Open plug in XN nipple. Attempt to pull packer.Would not release. Circulate out oil and gas from rathole through choke. 00:00 03:30 3.50 0 0 SLOT WELLPF NUND P PJSM-N/U Speed adaptor and BOPE.Cut 1'off riser. Prep and load 4"drill pipe in shed 03:30 06:45 3.25 0 0 SLOT WELLPF OTHR P Cont.V load 4"drill pipe in shed, strap pipe. SIMOPS-weld 2"weldlet on standpipe manifold,C/O liners in MP#2to51/2". Page 2 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 09:45 3.00 0 0 SLOT WELLPF OTHR P Set 4 1/2"test joint. R/U test equipment,flood stack and choke manifold w/water. SIMOPS-cont U change out liners on MP#2. 09:45 18:00 8.25 0 0 SLOT RPCOM BOPE P Test BOPE,Test all rams and choke valves U 250 PSI Low,3500 PSI High and annular to 2500 PSI with 3.5",4" and 4.5"test joint. Had to add packing U valve 10&12,bonnet had minor drips. Pull test jt and test blinds,250 PSI Low and 3500 PSI High. Perform accumulator test to 3000 PSI start. Function valves and stabilized at 1700 PSI. Took 45 sec for 250 PSI recovery,215 sec for full recovery. 18:00 21:45 3.75 0 0 SLOT WELLPF BOPE P RD Test Equipment. Pull blanking plug. Pull BPV. PU landing jt. and MU into tubing hanger. 21:45 22:00 0.25 0 0 SLOT WELLPF OPNW P PU tubing to 3000 PSI w/annulus valve closed. Shear open XPO plug in tailpipe @ 11,496'. Bleed off tubing. 22:00 00:00 2.00 0 0 SLOT WELLPF RTWH P Back out Lock Down Screws. PU hanger from tubing head. Work pipe up to 130k back to 100k. Increase PU by 20k each time to 200k max pull. Would not release. Continue to work pipe. 02/22/2012 Cont.to kill well. Wt. up from 9.1 to 9.8 ppg. Well dead. RU slickline to pull sleeve and lock out SSSV. 00:00 00:30 0.50 0 0 SLOT WELLPF RTWH P Continue to work pipe with max pull to 200K. Packer would not release. _Observed pit gain. Line up to CBU 00:30 01:30 1.00 0 0 SLOT WELLPF KLWL P CBU at 2 BPM through open GLM at 11359'. Had 7.5 BBL pit gain during circulation. SI well and had 10 psi on DP and 60 psi on Csg. 01:30 06:00 4.50 0 0 SLOT WELLPF KLWL P After 20 min had 170 psi on DP, 120 psi on csg. Circ @ 20 SPM using drllers method. Recovered oil and gas returns through poor boy degasser. After one full circulation, SI and had 30 psi on DP, 10 psi on csg. Dumped 82 bbl of curde cut brine druing circulation. After 10 min had 100 psi on DP,90 psi on csg. 06:00 12:45 6.75 0 0 SLOT WELLPF KLWL P Wt up to 9.4 ppg through choke at 2.6 BPM with 360 psi on DP, 160 psi on csg. SD and monitor well. 30 psi on DP, 10 psi on csg. Open choke and gained 9 bbls in 1.25 hr.while evaluating for breating. Decide to weight up to 9.6 ppg. Page 3 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 17:45 5.00 0 0 SLOT WELLPF KLWL P Weight up to 9.6 ppg through choke with 240 psi on DP, 50 psi on csg. (10.25 bbl LOSS) SD with 9.6 ppg around and monitor well. Gained 4 bbl in 1.3 hrs. Decide to weight up to 9.8 ppg. 17:45 21:00 3.25 0 0 SLOT WELLPF KLWL P Open up annular and circulate through flow line at 3 BPM weighting up to 9.8 ppg. Observe well for 30 min. Well is dead. LOST 13 BBL WHILE CIRCULATING. 21:00 22:30 1.50 0 0 SLOT WELLPF RTWH P Slack off and reland hanger. PU to 200k to verify packer not released. Slack off, land hanger and run in lock down screws. RD landing joint and PU shorter landing jt for rigging up slickline lubricator. 22:30 00:00 1.50 0 0 SLOT WELLPF SLKL P PJSM with slickline crew. Spot truck and RU slickline. TOTAL LOSSES FOR PAST 12 HRS=23 BBL. 02/23/2012 Lock out SSSV. RD slickline. RU E-line. Run string shot to clean up packer area. Run chem cutter and cut center of Baker PremierP acker. 00:00 02:45 2.75 0 0 SLOT WELLPF RURD P PJSM-Mobilize slick line tools U rig floor. R/U slick line. Hole took 2.5 bbls to fill 02:45 03:30 0.75 0 0 SLOT WELLPF SLKL P RIH w/Slickline w/GR pulling tool, 2.85"OD U 2300'MD. Retrieved frac sleeve. 03:30 05:00 1.50 0 0 SLOT WELLPF SLKL P M/U Deformation tool on Slickline, RIH U 2300'MD.Attempted to lock out SSSV,attempted to jar open No Go). Pressured up and held 1000 PSI and attempted jarring(No Go). Pressured up and held 1500 PSI attempt to lock SSSV by jarring. POOH w/Slickline and L/D Deformation tool,could not confirm SSSV is open. 05:00 05:30 0.50 0 0 SLOT WELLPF SLKL P Inspect Deformation tool.M/U flapper checker tool to confirm SSSV is open 05:30 06:15 0.75 0 0 SLOT WELLPF SLKL P RIH w/flapper checker tool. Confirmed flapper is open. POOH and L/D flapper tool 06:15 07:15 1.00 0 0 SLOT WELLPF RURD P R/D Slickline and L/D running tools and lubricator 07:15 08:15 1.00 0 0 SLOT WELLPF CIRC P R/U Circ line U fill tubing and hole as needed. SIMOPS-Service Draworks, Iron Ruffneck and clean pits 08:15 09:00 0.75 0 0 SLOT WELLPF OTHR T BOLD's, P/U 175K U put tubing in tension and set slips. L/D 4.5"lading joint and P/U shorter 4.5"landing joint. R/U Otis connection on landing joint., monitor well via trip tank Page 4 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 0 0 SLOT WELLPF RURD T PJSM-Mobilze E-Line equipment t/ rig floor. Load and assemble lubricator in pipe shed. R/U E-Line. Hole took 20.5 bbls in 12 hours,Avg loss now 1 bbl/hr 12:00 12:15 0.25 0 0 SLOT WELLPF RURD T PJSM-on RIH w/E-Line 12:15 15:00 2.75 0 0 SLOT WELLPF RURD T P/U lubricator and put in mouse hole. M/U grease head, P/U string shot and rig up on BOP,tie back in derrick 15:00 19:45 4.75 0 0 SLOT WELLPF ELNE T RIH with string shot. Fire shot in packer area. POOH with string shot and LD. 19:45 23:45 4.00 0 0 SLOT WELLPF ELNE T PU Chem cutter and RIH. Tie in and log into position. Set anchors and set cutter. Fire cutter. Good cut indication. 23:45 00:00 0.25 0 0 SLOT WELLPF ELNE T POH with Chem cutter. 28 Bbl loss for past 12 hrs. 02/24/2012 W.O.fresh E-line crew to cut tubing above packer. Perform tubing cut but still could not pull. Tried freepoint calc and didn't get correct amt of stretch. E-line crew timed out until 0800 to run freepoint. 00:00 01:15 1.25 0 0 SLOT WELLPF ELNE T POOH with Chem cutter. Pull tight, work wire @ 11400'MD.Chem cut depth @ 11422'MD 01:15 02:00 0.75 0 0 SLOT WELLPF ELNE T PJSM-UD Chem cutter 02:00 02:15 0.25 0 0 SLOT WELLPF RURD T PJSM-R/D lubricator and E-Line 02:15 11:30 9.25 0 0 SLOT WELLPF RTWH T R/U U pull on tubing, Pull 200K, 210K,220K(NO GO)Cont U work tubing pulling 220K,SIMOPS-take on 200 bbls of 9.8 ppg NaCI brine U pits. Lost 23.47 bbls while keeping the hole full. • 11:30 16:00 4.50 0 0 SLOT WELLPF CIRC P Circ through choke at 3 BPM holding 390 psi on DP and 90 psi on csg. Circ until well balanced at 9.8 ppg. Lost 39 BBL while pumping 16:00 16:45 0.75 0 0 SLOT WELLPF OWFF P Monitor well,fill hole. 16:45 18:45 2.00 0 0 SLOT WELLPF ELNE P Set tubing in slips with 40K over pull prior to e-line. PJSM for e-line RU. RU HES e-line lubr and BOP. 18:45 22:00 3.25 0 0 SLOT WELLPF ELNE P RIH w/RCT cutter on e-line and cut tubing at 11402'e-line MD(middle of pup above Premier packer) POH w/cutter. Move tools and lubr to side. 22:00 23:30 1.50 0 0 SLOT WELLPF RTWH P Pull on tubing with 200 KIPS(70 KIPS over string wt). Worked pipe several cycles with no success. 23:30 00:00 0.50 0 0 SLOT WELLPF RTWH T Tried freepoint calc and didn't get correct amt of stretch. E-line crew timed out until 0800 to run freepoint. 02/25/2012 W.O. E-line crew to run freepoint log. Pull on tubing up to 220 KIPS and circulate BU. RU HES and run freepoint. Log indicated stuck @ 10,733'MD. RIH w/RTC cutter and cut pipe at 10,640'MD. Page 5 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 SLOT WELLPF RTWH T Work tubing to max pull of 90%at 220 KIPS with no success. Attempted to circulate at higher rate, but over 2.5 BPM, lost all returns. Worked pipe while circulating 2.5 BPM with no success. 01:00 09:00 8.00 0 0 SLOT WELLPF RTWH T Work pipe to 220 KIPS every 30 min and roll pump every 15 min.while waiting on E-line. Losses since midnight 20 Bbls. 09:00 12:00 3.00 0 0 SLOT WELLPF ELNE T PJSM with E-line. RU free point tool and RIH. Lost 33 Bbl past 12 hrs. 12:00 20:00 8.00 0 0 SLOT WELLPF ELNE T Cont to RIH with FPT to 11460'. Log up with with tool for pass#1. POH with FPT. PU on tubing to 83 KIPS over string wt and set slips. RIH with run#2 to log up and identify free point. Pipe stuck at 10773'. MD. POH with FPT. 20:00 00:00 4.00 0 0 SLOT WELLPF ELNE T RIH with RCT cutter. Tie in and prep to cut tubing,mid joint 75'above stuck point. Losses past 12 hrs= 26 Bbl. 02/26/2012 POH with cutter. Verify tubing is free. RD E-Line. RU to POH with tubing. Pull tubing. Test BOPs. PU fishing tools on DP and RIH to retrieve cut tubing. 00:00 01:30 1.50 0 0 SLOT WELLPF ELNE T RIH with RCT cutter. Tie in and prep to cut tubing,mid joint 75'above stuck point. Anchors wouldn't set properly. After 3rd attempt, pulled tension until anchors set in connection. After reviewing if revised cut depth would be ok,tubing was cut at 10,637'MD tubing depth(5.4' below collar) Had a positive indication that tubing was cut. POH with cutter. 01:30 05:00 3.50 0 0 SLOT WELLPF ELNE T Rig down lubr in mousehole and verify tubing was free. After verified, begin to RD HES E-Line. 05:00 06:00 1.00 0 0 SLOT WELLPF RTWH T Circulate surface to surface to circ out any crude that cont to migrate up. 06:00 19:30 13.50 0 0 SLOT WELLPF PULL P POH with tubing. Retreived 76 of 76 stainless steel bands. LD 335 jts(# 362 to 28)plus top 5.4'of joint#27. Joints partial#27-#1 left in hole. Cut at 10,637'MD per orig talley. 19:30 21:00 1.50 0 0 SLOT WELLPF PULL P RD casing handling equip and clear floor. 21:00 22:15 1.25 0 0 SLOT WELLPF SLPC P PJSM,Slip&Cut drilling line 22:15 00:00 1.75 0 0 SLOT WELLPF BOPE P RU to test BOPE 02/27/2012 Cont.testing BOPs. PU fishing tools on DP and RIH to retrieve cut tubing fish. Page 6 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:45 5.75 0 0 SLOT WELLPF BOPE P Test BOPE,Test all rams,annular and choke valves t/250 PSI Low, 3500 PSI High with 3.5"and 4" test joints.Valve 12 failed. Greased and retested. Pull test jt and test blinds, 250 PSI Low and 3500 PSI High. Perform accumulator test to 2950 PSI start. Function valves and stabilized at 1700 PSI. Took 29 sec for 200 PSI recovery, 183 sec for full recovery. 05:45 07:00 1.25 0 0 SLOT WELLPF BOPE P RD test equip, pull test plug and set wear bushing. 07:00 10:00 3.00 0 0 SLOT WELLPF RURD P PJSM. Cont.to load pipeshed with 4"DP. RU Halliburton Geo-Span unit. 10:00 14:00 4.00 0 587 SLOT WELLPF PULD P PJSM,M/U BHA#1 fishing assembly from 84'to 587'w/2"drift. 14:00 00:00 10.00 587 7,740 SLOT WELLPF PULD P Single in hole with 4"DP from 587'- 7740'MD. Total loss past 12 hrs= 20.4 Bbl. 02/28/2012 RIH with fishing tools picking up 4"DP to fish stuck tubing. Hooked onto fish and pulled/jarred and circulated several times. Moved up 4'but could not pull fish free. RU E-line to cut tubing above bottom GLM. 00:00 06:00 6.00 7,740 10,514 SLOT WELLPF PULD T Single in hole with 4"DP from 7740' TO 10514' MD. PU= 165K, SO=93K. Circ BU@ 2.5 BPM and 275 PSI. Had gas&oil cut brine returns. SI and monitor well, STATIC. 06:00 12:00 6.00 10,514 10,514 SLOT WELLPF CIRC T Monitor well via trip tank while WOW at-50 deg F. Loss 10 Bbl past 12 hrs. 12:00 15:15 3.25 10,514 10,514 SLOT WELLPF PULD T Monitor well via trip tank while WOW at-50 deg F. Perform pre jarring derrick insp. 15:15 16:30 1.25 10,514 10,634 SLOT WELLPF FISH T Break circ @ 3.5 BPM, 350 PSI. PU = 155K,SO=105K, Rot wt-126K, TQ=5K @ 10 RPM. Wash do and engage fish at 10634. Obs 50 PSI pres. incr. SD pump and work jars up to 100k and overpull with 170 k over string wt. 16:30 17:00 0.50 10,634 10,634 SLOT WELLPF FISH T Circ BU at 4.25 BPM,575 PSI. 17:00 19:15 2.25 10,634 10,630 SLOT WELLPF FISH T Cont to work jars w/same parameters. Total of 4'made. Tried topush down,wouldn't go. Cont to jar with no success. 19:15 19:30 0.25 10,630 10,630 SLOT WELLPF FISH T Discuss options while circulating. 19:30 21:30 2.00 10,630 10,630 SLOT WELLPF FISH T W.O. E-line. Cont.circ. Perform post jarring derrick insp. 21:30 22:30 1.00 10,630 10,630 SLOT WELLPF FISH T Release from fish to place a pup in the string for a-line space-out. Put string in tension w/45K over string wt. Page 7 of 26 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 10,630 10,630 SLOT WELLPF FISH T PJSM,Spot HES E-Line unit @ beaver slide. PU and stage e-line equip on floor. Lost 31.5 BBL in past 12 hrs. 02/29/2012 RIH with RCT cutter on e-line. Make cut above lower GLM. POH with tubing above cut. RIH to fish remainder of completion. 00:00 01:00 1.00 10,630 10,630 SLOT WELLPF FISH T PJSM-Cont. R/U E-LINE. 01:00 04:30 3.50 10,630 10,630 SLOT WELLPF FISH T P/U GREASE HEAD,M/U RCT CUTTER 04:30 04:45 0.25 10,630 10,630 SLOT WELLPF FISH T TEST LUBRICATOR T/1200 PSI(NO LEAKS) 04:45 09:00 4.25 10,630 10,630 SLOT WELLPF FISH T RIH W/E-LINE, FIRE RCT @ 11,325' WIRELINE DEPTH POOH. PJSM-R/D E-LINE.TOTAL LOSS E-LINING=12.75 BBLS 09:00 09:30 0.50 10,630 10,580 SLOT WELLPF FISH T P/U ON STRING BROKE OVER@145 K, PU 50'TO ENSURE STRING FREE P/U=145K S/0=110K 09:30 11:00 1.50 10,580 10,580 SLOT WELLPF FISH T PUMP 20 BBL SWEEP,SWEEP DID NOT BRING BACK ANYTHING, LOST 24 BBLS ON CIRC. 11:00 11:30 0.50 10,580 10,580 SLOT WELLPF FISH T MONITOR WELL,SLIGHT FLOW& SLOWING DOWN, BLOW DOWN TD. 11:30 12:00 0.50 10,580 10,514 SLOT WELLPF FISH T POOH T/10,514'MD.CAL=.54 BLLS,ACTUAL=1 BBL. TOTAL LOSS PAST 12 HRS=38 BBL. 12:00 21:30 9.50 10,514 0 SLOT WELLPF FISH T POOH W/FISH. LD BHA,21 JTS OF 3.5"TUBING,&2 CUT JTS-TOTAL OF 697'OF FISH. 21:30 23:30 2.00 0 0 SLOT WELLPF FISH T CLEAR FLOOR. REDRESS BOT OVERSHOT W/NEW GRAPPLE. 23:30 00:00 0.50 0 2,483 SLOT WELLPF FISH T RIH WITH SAME FISHING ASSY TO 2483'. TOTAL LOSS PAST 12 HRS = 19 BBL. 03/01/2012 Ran in hole with OS on fishing BHA and recovered 78'fish consisting of 3-1/2"tubing and GLM. Fish was stuck in fill. MU milling shoe on wash pipe and jarring BHA and RIH to mill over packer slip. 00:00 05:00 5.00 2,843 11,328 SLOT WELLPF FISH T PJSM,CONT. RIH F/2843'MD T/3070'MD,SINGLE IN HOLE F/PIPESHED 72 JTS T/8542'MD, CONT RIH T/11,266' BREAK CIRC WASH T/11,328'@325 PSI. P/U=115K,S/O=110K. ACTUAL=43.25 BBLS CAL=47.14 BBLS 05:00 08:45 3.75 11,328 11,306 SLOT WELLPF FISH T LATCH ON T/FISH@11,328'MD. SET DOWN 20K, PULL UP 175K. START JARRING OPS,WORKING UP TO 275K.WORK FISH UP HOLE 22' BEFORE IT BROKE FREE. P/U=170K, S/O=110K.WORK PIPE TWICE THRU STUCK SPOT NO PROBLEMS. JARRED 150 HITS TOTAL. LOST 10.2 BBLS T/HOLE. Page 8 of 26 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 08:45 10:45 2.00 11,306 11,306 SLOT WELLPF FISH T CIRC SS@4.25 BPM, 525 PSI, PUMP 30 BBL HI-VIS SWEEP, SAW NO INCREASE IN CUTTINGS ON RETURN OF SWEEP. PERFORM DERRICK INSPECTION AFTER JARRING. LOST 34.16 BBLS. 10:45 11:15 0.50 11,306 11,216 SLOT WELLPF FISH T MONITOR WELL, SLIGHT FLOW PULL 1 STAND NO PUMP, BD TD, MONITOR WELL STATIC 11:15 17:30 6.25 11,216 0 SLOT WELLPF FISH T POOH FISH. RACK BACK HWDP &DC'S, UD BHA 17:30 18:00 0.50 0 0 SLOT WELLPF FISH T R/U 3.5' HANDLING EQUIP, UD FISH(CUT#5 JT, 10'PUP,GLM, 10' PUP,JT#4,3'STUB), JT#4 SHOWED SIGNS OF BEING PULLED THROUGH TIGHTLY PACKED FILL(BARITE)R/D HANDLING EQUIP, CLEAR FLOOR 18:00 20:00 2.00 0 0 SLOT WELLPF FISH T DISCUSS PACKER RETREIVAL OPTIONS, READY BOT TOOLS IN SHED F/NEXT RUN. PU BHA. 20:00 00:00 4.00 0 5,823 SLOT WELLPF FISH T PJSM. RIH WITH MILLING SHOE, WASH PIPE AND JARRING BHA TO 5823' 03/02/2012 Cont. RIH w/packer milling BHA. Circ out fill on top of packer. Mill on packer and circ hole clean. POH with packer milling BHA. Minimal wear on mill indicated top sub of packer was spinning. RIH with OS fishing assembly. 00:00 03:00 3.00 5,823 11,278 SLOT WELLPF FISH T PJSM-CONT.RIH T/11,278'MD. P/U=115K,S/0=105K.ACT:49.77 CAL:55.62 03:00 04:00 1.00 11,278 11,409 SLOT WELLPF FISH T BREAKCIRC@/11,278'MD WASH&REAM DOWN T/11,372', ROT-20 RPM,TQ-6K, STAGE UP RPM TO/50RPM WORK STAND,2.5 BPM,250 PSI,WASH DOWN T/11,409'TAG PACKER.SET DOWN 15K, P/U 8'STAGE UP PUMP T/8BPM, 1700 PSI. 04:00 11:00 7.00 11,409 11,410 SLOT WELLPF FISH T START MILLING OPS ON PACKER@11,409'MD, ROT 100/50RPM,TQ-9K,8BPM, 1900 PSI. REDUCE PUMPS T/6BPM, 1190PSI.CONT. MILL PACKER. REDUCE RATE TO 4 BPM, 550 PSI, PUMP HI VIS SWEEP W/MINIMAL RETURNS, REDUCE RATE TO 1.75 BPM, 110 PSI&CONT MILLING TOTAL OF 8"TO 11,410'MD. NO SUCCESS, 11:00 12:45 1.75 11,410 11,410 SLOT WELLPF FISH T PUMP HI VIS SWEEP @ 6BPM. 12:45 13:45 1.00 11,410 11,340 SLOT WELLPF FISH T RACK BACK ONE STAND, MONITOR WELL, SLIGHT FLOW. MONITOR WELL. (LOST 26 BBL WHILE PUMPING SWEEP) SUSPECT BREATHING Page 9 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 16:30 2.75 11,340 9,019 !SLOT WELLPF FISH T LINE UP TO TRIP TANK AND POOH TO 9915. NOT TAKING CORRECT FILL. PUMP OUT TO 9019'. GOOD FILL NOW. 16:30 17:30 1.00 9,019 9,019 SLOT WELLPF FISH T MONITOR WELL(STATIC) 17:30 22:30 5.00 9,019 0 SLOT WELLPF FISH T CONT. POOH ON ELEVATORS. RACK BACK HWDP&DC'S, L/D BHA. MILL WAS NOT WARN AT ALL. APPEARS IT WAS SPINNING THE TOP SUB OF THE PACKER. CLEAN AND CLEAR RIG FLOOR. 22:30 00:00 1.50 0 0 SLOT WELLPF FISH T MU BHA#4. OVERSHOT TO RETRIEVE 3-1/2"TUBING STUB ON _ PREMIER PACKER. 03/03/2012 Cont. RIH with OS fishing assembly and latch up on 3-1/2"tubing stub. Release packer and POH. Pump out of hole due to swabbing. 00:00 01:15 1.25 572 572 SLOT WELLPF FISH T PJSM SLIP AND CUT DRLG LINE. 01:15 01:45 0.50 572 572 SLOT WELLPF FISH T SERVICE TOP DRIVE&DRAW WORKS 01:45 06:30 4.75 572 11,345 SLOT WELLPF FISH T RIH W/OVER SHOT F/572.15'MD T/11,345'MD.OBTAIN PERAMETERS, P/U=155K, 5/0=107K, PUMP 3BPM,200 PSI, 99 GPM, 30%FLOW 06:30 07:00 0.50 11,345 11,410 SLOT WELLPF FISH T RIH F/11,345'T/11,410'MD.TAG FISH PUMP PSI INCREASE T/125 PSI.SHUT DOWN PUMPS,SET 6K. P/U WT INCREASED T/165K. SET DOWN 20K, P/U T/180K. P/U 8' LET ELEMENT RELAX 15 MIN. RIH PAST PACKER DEPTH. ACTUAL=64.26 BBLS, CALC=68.1 BBLWS. 07:00 07:45 0.75 11,410 11,410 SLOT WELLPF FISH T ATTEMPT T/CBU PACKED OFF. WORKED PIPE T/WEAR OUT PACKER RUBBERS. 07:45 09:15 1.50 11,410 11,410 SLOT WELLPF FISH T ESTABLISH CIRC.CBU @ 3BPM, 825 PSI 104 GPM,30%FLOW. 09:15 09:45 0.50 11,410 11,345 SLOT WELLPF FISH T RACK BACK ONE STD. T/11,345'MD. MONITOR WELL (BREATHING) 09:45 10:30 0.75 11,345 10,875 SLOT WELLPF FISH T PUMP OUT 5 STDS. 10,875'MD @ 2 BPM,200 PSI,20% FLOW. 10:30 11:15 0.75 10,875 10,875 'SLOT WELLPF FISH T MONITOR WELL,SLIGHT FLOW. BLOW DOWN TOP DRIVE.CONT MONITOR WELL, SLIGHT FLOW. 11:15 00:00 12.75 10,875 2,469 SLOT WELLPF FISH T DECISION MADE TO CONT PUMPING OUT OF HOLE @ 1.5 BPM, 150 PSI. PULLING AROUND 8-12 STDS/HR. 03/04/2012 Cont. POH with packer and LD same. PU Bit,scraper and rest of fill clean-out BHA and RIH. Reduce MW to 9.6 PPG. 00:00 01:45 1.75 2,469 0 SLOT WELLPF FISH P Continue to pump out of hole due to swabbling @ 2 BPM, 100 PSI. Page 10 of 26 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 01:45 02:00 0.25 0 0 SLOT WELLPF FISH P Monitor Well(Static) 02:00 03:00 1.00 0 0 SLOT WELLPF FISH P Pump out 4 more stands of HWDP, pull remaing on elev. 03:00 04:30 1.50 0 0 SLOT WELLPF FISH P L/D packer and tailpipe. Packer had been milled approx 5"down to just above the slip retainer ring. Remaining top sub on packer was free to spin. Packer rubber was still extruded and not relaxed,causing the swab when POOH. 04:30 05:00 0.50 0 0 SLOT WELLPF FISH P Inspect Top Drive due to recent jarring. All OK. SIMOPS while PU BHA#5 f/shed. 05:00 06:30 1.50 0 0 SLOT WELLPF PULD P PJSM for M/U BHA#5 bit&scraper, etc.for clean-out run per Baker. 06:30 10:15 3.75 0 6,656 SLOT WELLPF TRIP P RIH w/to 6656'MD. Work through ES-Cementer 3 times at 5 BPM,400 PSI. 10:15 15:15 5.00 6,656 11,943 SLOT WELLPF TRIP P Continue to RIH to 11620'MD.Took 10K wt. Wash down at 10 FPM w/ 30 RPM, 10K WOB, 5 BPM @ 800 PSI. Backream each stand. Incr pump rate to 6 BPM,900 PSI on up stroke to 11, 943' 15:15 17:15 2.00 11,943 12,409 SLOT WELLPF TRIP P Continue to wash down w/same rate to 12409'MD. Begin to circulate and scrape from 12183- 12393'MD. Fill across shaker consisting of sand, Calcium Carb,and oily sludge. 17:15 21:45 4.50 12,409 12,409 SLOT WELLPF CIRC P Begin to dilute brine with H2O from 9.8 PPG to 9.6 PPG while circulatin6 at 6 BPM, 1000PSI. 21:45 00:00 2.25 12,409 12,409 SLOT WELLPF CIRC P Rack back one stand. Monitor well. Well out of balance. Perform breathing test. During circ 16 Bbl was pumped away 03/05/2012 Monitor well after reducing MW to 9.6. Evaluate for breathing. Decide to weight up to 9.8 PPG. POH. Test BOPE. 00:00 02:30 2.50 12,409 12,409 SLOT WELLPF CIRC P Perform breathing test. Close annular to evaluate for breathing. Monitor pressure,was 60 PSI. Circulate thru choke and SD. SIDP and SIDP=0 PSI. Open Annular and monitor well. Still had slight _flow. Decide to weight back up. 02:30 09:00 6.50 12,409 12,409 SLOT WELLPF CIRC P Weight up from 9.6 to 9.7 PPG. Monitor,still had slight flow. Weight up from 9.7 to 9.8 PPG. Pumped at 4.5 BPM,400 PSI, 30%flow. 09:00 11:00 2.00 12,409 12,409 SLOT WELLPF CIRC P Monitor well,out of balance. Pumped DP volume. Still out of balance. Mix and pump 17 BBL of 10 PPG slug. Monitor well. (Static) 11:00 18:00 7.00 12,409 0 SLOT WELLPF TRIP P POH on elevators with scraper _assembly and LD BHA. 18:00 20:00 2.00 0 0 SLOT WELLPF BOPE P RU to test BOPE. Page 11 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 0 0 SLOT WELLPF BOPE P Test BOPE,Test all rams, annular and choke valves t/250 PSI Low, 3500 PSI High with 4" test joint. Had leak on valve#13. Service& retested OK. Pull test jt and test blinds,250 PSI Low and 3500 PSI High. Record on chart 03/06/2012 Complete testing BOPE. RIH w/CIBP and set @ 12,393'MD. POOH. Make up Whipstock and RIH. 00:00 01:30 1.50 0 0 SLOT WELLPF BOPE P Cont.testing BOP's.250 PSI low/ 3500 PSI High. Lower pipe rams, Blind rams,Annular test 250 PSI low 2500 PSI High.Accumulator test. System pressure 3000 PSI. Pressure after closed=1800 PSI.200 PSI attained in 46 secs. Full pressure attained in 198 secs. Nitrogen bottles average=2000 PSI. Complete testing BOPE. 01:30 02:00 0.50 0 0 SLOT WELLPF BOPE P R/D test equipment, B/D choke line, kill line, &TD. Install wear bushing. 02:00 02:30 0.50 0 0 SLOT WELLPF PULD P P/U, M/U Bridge plug BHA. 02:30 08:45 6.25 0 12,359 SLOT WELLPF PLUG P RIH w/Bridge plug T/12,359'MD. Establish Parameters,ACT=67.16 bbls, Calc=74.95 bbls. 08:45 09:30 0.75 0 12,393 SLOT WELLPF PLUG P Set Bridge plug @ 12,393'MD as per Baker Rep 09:30 09:45 0.25 12,393 12,393 SLOT WELLPF TRIP P Rack back 1 STD. R/U T/Test Bridge Plug 09:45 10:30 0.75 12,393 12,393 SLOT WELLPF PRTS P Test bridge plug T/3500 psi F/30 min. (Charted) 10:30 10:45 0.25 12,393 12,393 SLOT WELLPF RURD P R/D test equipment, B/D kill& cement line 10:45 12:00 1.25 12,359 10,292 SLOT WELLPF TRIP P POOH on elevators F/12,359'MD T/10,292'MD.ACT Fill=11.56 bbls, Calc=10.8 bbls 12:00 16:30 4.50 10,292 0 SLOT WELLPF TRIP P POOH W/Bridge plug running tool F/10,292'MD, Rack Back HWDP, DC'S&LID Running Tool. Fill F/Trip ACT=77 bbls, Calc 75.4 bbls 16:30 18:00 1.50 0 0 SLOT WELLPF SLPC P PJSM,Cut DRLG line, 9 wraps 18:00 19:00 1.00 0 0 SLOT WELLPF SVRG P Service&Lubricate Rig 19:00 21:45 2.75 0 0 SLOT WELLPF RGRP P Clean&Inspect Brakes on TopDrive, P/U Std of DP F/Derrick, RIH,M/U to T/D,set Brake in auto and pull on rig tongs to 15K. Brake held, rack back stand&reinstall access doors& safety wire. 21:45 22:15 0.50 0 SLOT WELLPF SFTY P PJSM. Picking up whipstock as per Baker rep and Sperry MWD rep. 22:15 00:00 1.75 SLOT WELLPF PULD P BHA#6 Whipstock Milling Run. Pick up Baker mills 03/07/2012 Make up Whipstock BHA.TIH W/Whipstock, Mill Window, and open hole to 12378. 00:00 01:30 1.50 0 0 SLOT WELLPF PULD P M/U Tail pipe,whipstock BHA. P/u 2 STD DC's and 2 STD HWDP Page 12 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:00 0.50 0 698 SLOT WELLPF DHEA P Shallow Test MWD(Good) 02:00 02:15 0.25 698 698 SLOT WELLPF PULD P P/U 3 STDs HWDP BHA 02:15 11:00 8.75 698 12,300 SLOT WELLPF TRIP P RIH W/DP F/696'MD T/12,300'MD, fill every 20 STDs.Act Disp=72.8 bbls,Calc Disp=75.09 bbls 11:00 11:30 0.50 12,300 12,300 SLOT WELLPF WPST P Establish Parameters,Orient Whipstock 11:30 12:00 0.50 12,325 12,325 SLOT WELLPF WPST P Set Whipstock @ 12,325'MD @ 53°Right 12:00 13:00 1.00 12,325 12,325 SLOT WELLPF CIRC P Establish milling parameters. P/U Wt=165k. S/O Wt=85k. Rot Wt=129k. Circulate @ 250 GPM. ICP=2450 PSI. Off Btm TQ=12k. Viscosify mud system to 20 YP. Slack off and tag top of whipstock @ 12,325'MD. 13:00 13:15 0.25 12,325 12,325 SLOT WELLPF CIRC P Rack back one stand and pick up a single of 4"DP from pipe shed. Make up to string, latch back up to stand #124. Run in hole and tag top fo whipstock. Mark pipe as per Baker Milling hand. Begin milling with 80 rpm's. 13:15 16:30 3.25 12,325 12,325 SLOT WELLPF MILL P Mill off whipstock lug @ 80 RPM. 250 GPM. ICP=2450 PSI. 12-15k TQ. 1k WOB. 16:30 00:00 7.50 12,325 12,370 SLOT WELLPF MILL P Mill window: 100 RPM. 12-15k TQ. 5-15k WOB. 300 GPM flow rate P( average.3150 PSI.Top of window=12325'MD. BOW=12338' MD. Milled new hole to 12370'MD. Pumped 2 high vis super sweeps. #1@ 12332'MD,#2@ 12341'MD. Back ream through the window with 120 RPM.Clean. Crew change. Mud losses for tour=41.4 BBLs. 03/08/2012 Mill/Drill rat hole to 12378'MD. Displace well from 9.8 PPG brine to 9.8 PPG Flow Pro. Perform LOT to 12.5 PPG EMW.Slight breathing seen in wellbore. Pump out to 11310'MD. Perform 2nd LOT to 11.7 PPG EMW. Pump out of the hole with the Milling assembly. 00:00 01:15 1.25 12,357 12,378 SLOT WELLPF DRLG P PJSM. Drill from 12357'MD to 12378' MD. 01:15 01:30 0.25 12,378 12,378 SLOT WELLPF CIRC P Slide through window twice(No Problems) 01:30 03:45 2.25 12,378 12,378 SLOT WELLPF CIRC P PJSM, Displace well F/9.8 PPG Flow Pro ICP@ 250 GPM=2650 psi, 80 RPM=14K TQ, FCP @ 250 GPM-2350 psi,80 RPM=6K TQ r 03:45 04:00 0.25 12,378 12,320 SLOT WELLPF PULD P UD Pup Jt, Rack back 1 STD. OD 04:00 04:30 0.50 12,320 12,320 SLOT WELLPF OWFF P Monitor Well(Static), B/D TD, R/U ,T/Perform FIT Test 04:30 05:00 0.50 12,320 12,320 SLOT WELLPF FIT P Perform FIT Test, Pressure up to 990 psi. Bleed off into T.T. (3 bbl gain) 05:00 05:15 0.25 12,320 12,247 SLOT WELLPF RURD P 'BD Kill Line, R/D test equipment, UD single Page 13 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 06:30 1.25 12,247 12,247 SLOT WELLPF CIRC P Circ 1600 stks @ 250 GPM=2350 psi,shut down&monitor well= 1.35 bbls gain in 10 min.Cont.T/Circ 06:30 07:45 1.25 12,247 12,247 SLOT WELLPF OWFF P Monitor well, B/D TD(Breathing) 07:45 09:00 1.25 12,247 11,310 SLOT WELLPF TRIP P POOH F/12,247'MD T/11,310'MD @ 1.5 BPM, 160 psi.ACT Fill=7.65 bbls, Calc=5.4 bbls. 09:00 09:30 0.50 11,310 11,310 SLOT WELLPF OWFF P Monitor Well, B/D TD(Breathing) 09:30 10:00 0.50 11,310 11,310 SLOT WELLPF RURD P R/U T/Perform FIT Test 10:00 10:30 0.50 11,310 11,310 SLOT WELLPF FIT P Perform Fit Test. 10:30 10:45 0.25 11,310 11,310 SLOT WELLPF RURD P B/D Kill Line, R/D Test Equipment 10:45 12:00 1.25 11,310 11,310 SLOT WELLPF OWFF P Monitor Well(Breathing)0 bbl Loss F/Tour 12:00 13:15 1.25 11,310 10,368 SLOT WELLPF TRIP P Pump out of Hole @ 1.5 BPM, 300 PSI,65 FPM,W/10 STds F/11,310' MD T/10,368'MD. B/D TD.ACT Fill =6 bbls,Calc=5.4 bbls 13:15 14:00 0.75 10,368 10,368 SLOT WELLPF OWFF P Monitor well(Breathing),Take Returns to TT&Perform breathing test, record gain every 10 min.Very slight flow.15 bbl in 30 min,slowly decreasing 14:00 15:30 1.50 10,368 9,241 SLOT WELLPF CIRC P Attempt to pull on elevators for 2 stands. 10368 to 10177;MD. Improper hole fill. Pump out of the hole 10 stands. 10177 to 9241'MD. 15:30 16:15 0.75 9,241 9,241 SLOT WELLPF OWFF P Monitor well.Very slight flow. Decrease to static. 16:15 16:30 0.25 9,241 9,241 SLOT WELLPF TRIP P Attempt to pull one stand.Stop. Taking improper hole fill. 16:30 18:15 1.75 9,241 7,269 SLOT WELLPF CIRC P Pump out of the hole 20 stands. From 9241'to 7269'MD. Fill= 12.6 BBLS.Calculated Fill=10.8 BBLS. 18:15 19:15 1.00 7,269 7,269 SLOT WELLPF OWFF P Monitor well, .7 BBL gain in 40 mins. Slight flow decrease to static. 19:15 21:00 1.75 7,269 5,855 SLOT WELLPF CIRC P Pump out of hole from 7269'to 5855' MD.Actual Fill=11.2 BBL. Calculated Fill=8.1 BBL. 21:00 22:00 1.00 5,855 5,855 SLOT WELLPF OWFF P Monitor well. Slight flow. Breathing. 1.4 BBLS in 40 mins. Not decreasing. Mud out of balance. 9.7 PPG in. 9.8+PPG out. 22:00 23:30 1.50 5,855 5,855 SLOT WELLPF CIRC P Decide to circulate and balance the mud weight out.Circ.@ 5 BPM. 1375 PSI. Balanced mud weight in and out @ 9.8+PPG. Pumping in and out of pit 5.Total mud loss while pumping 2 BBLS. 23:30 00:00 0.50 5,855 5,855 SLOT WELLPF OWFF P Monitor well. 1/4 barrel gain in 30 mins. total mud loss for tour=8.6 BBLS. Mud loss for well=60.6 BBLS 03/09/2012 Pump out of hole F/5,855'and rack back HWDP&Collars. P/U M/U Clean out run BHA#7.TIH Page 14 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 5,855 5,855 SLOT WELLPF OWFF P PJSM Monitor Well(Slight flow down T/Static).25 bbl gain in first.5 hr, second .5 hr=0 gain. 01:00 07:00 6.00 5,855 630 SLOT WELLPF TRIP P POOH F/5,855'MD T/630'MD @ 1.5 BPM,200 psi.ACT Fill=46.9 bbl,Calc Fill=38.37 bbls. 10.7 bbl loss while pumping. 07:00 08:00 1.00 630 630 SLOT WELLPF OWFF P Monitor Well(Static) 08:00 09:00 1.00 630 0 SLOT WELLPFTRIP P POOH on elevators, Rack back HWDP&Collars 09:00 09:30 0.50 0 0 SLOT WELLPF PULD P L/D Milling BHA(Upper mill in gauge) 09:30 10:30 1.00 0 0 SLOT WELLPF RURD P Clean&Clear Rig Floor 10:30 11:00 0.50 0 0 SLOT WELLPF CIRC P R/U Stack washer&Flush Stack. 11:00 11:30 0.50 0 0 SLOT WELLPF RURD P R/D Stack washer, B/D TD, Pull wear bushing, install wear bushing. 11:30 12:00 0.50 0 0 SLOT WELLPF SVRG P Service TD and Rig Equipment, grease TD 12:00 14:00 2.00 0 0 SLOT WELLPF PULD P PJSM, M/U BHA#7(Clean Out Run) 14:00 14:30 0.50 0 650 SLOT WELLPF PULD P P/U 2 STDs, Collars&4 STDs HWDP 14:30 22:45 8.25 650 12,300 SLOT WELLPFTRIP P RIH F/650'MD T/12300'MD. Filling every 20 STDs. Calculated displacement=74.06 BBLS.Actual displacement=66.96 BBLS 22:45 23:15 0.50 12,300 12,300 SLOT WELLPF CIRC P Fill pipe, begin circulating. Establish parameters. Pump 210 GPM. 1425 PSI. P/U Wt= 145k. S/O Wt= 102k. ROT Wt=126k 23:15 23:30 0.25 12,300 12,340 SLOT WELLPF REAM P Ream down to 12340'MD.210 GPM. 120 RPM.Work mills across ramp. Back and forth.Clean window. No excess torque seen.Good window. 23:30 23:45 0.25 12,340 12,378 SLOT WELLPF PULD P Stop pumping. Pick up single out of the pipe shed.Wash down to bottom. Full gauge hole to TD. 23:45 00:00 0.25 12,378 12,378 SLOT WELLPF CIRC P Begin circulating and conditioning mud system. 03/10/2012 Circ. &Cond. Mud, pump fiber sweep and LCM pill. Pump out of hole for BHA#7. Make up BHA#8 for side _track.TIH 00:00 01:00 1.00 12,378 12,378 SLOT WELLPF CIRC P PJSM Circ&Condition mud due T/Mud coming back heavy @ 6 BPM, 1800 psi, 35%Flow 01:00 02:15 1.25 12,378 12,378 SLOT WELLPF CIRC P Pump 40 bbl fiber sweep @ Circ. Rate(No Metal) 02:15 04:00 1.75 12,378 11,423 SLOT WELLPFTRIP P Pump 23 bbl LCM pill T/Bit. POOH 10 STDs. @ 1 BPM, 250 psi,42 _GPM, 26 fpm. 04:00 05:00 1.00 11,423 11,423 SLOT WELLPF OWFF P Blow Down TD. Monitor Well(Slight flow T/Static) Page 15 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 08:15 3.25 11,423 8,604 SLOT WELLPF TRIP P Attempt T/Pull on Elevators, Swabbing. POOH F/11,423'MD T/8,604'MD, @ 1.5 BPM,200 psi, 36%Flow. 08:15 08:45 0.50 8,604 8,604 SLOT WELLPF OWFF P Blow Down TD. Monitor WEII(Slight Flow, Swabbing) Decision made T/Pump out 30 more STDs. 08:45 11:45 3.00 8,604 5,779 SLOT WELLPF TRIP P POOH F/8,604'MD T/5,779'MD @ 1.5 BPM, 125 psi.ACT Fill=50.1 bbls,Calc Fill=37.8 bbls.Total Losses= 12.3 bbls. 11:45 12:00 0.25 5,779 5,779 SLOT WELLPF OWFF P Blow Down TD, Monitor Well 12:00 12:15 0.25 5,779 5,779 SLOT WELLPF OWFF P Cont.to Monitor Well 12:15 12:45 0.50 5,779 5,209 SLOT WELLPFTRIP P Attempt to Pull on elevators F/5,779' MD T/5,209'MD, puill 6 STDs, hole was still swabbing. Desicion made T/pump out 20 more stands 12:45 15:15 2.50 5,209 3,404 SLOT WELLPF TRIP P POOH F/5,209'MD T/3404'MD @ 70 GPM= 110 psi 15:15 17:45 2.50 3,404 745 SLOT WELLPFTRIP P Attempt to pull on elevators 2 STDs, still swabbing. POOH T/HWDP @ 70 GPM= 110 psi, F/3,119'MD T/745' MD. 17:45 18:00 0.25 745 745 SLOT WELLPF OWFF P Blow Down TD Monitor well @ 745' MD. (HWDP) 18:00 20:30 2.50 745 0 SLOT WELLPF OWFF P UD BHA, Rack Back 3 STDs HWDP, L/D 1 STD HWDP,6 Spiral Collars, Magnets, Boot Baskets, and Mills.ACT Disp=91.1 bbls,Calc= 74.16 bbls, 17 bbls loss for trip. (Recovered 25 lbs metal) 20:30 21:30 1.00 0 0 PROD1 DRILL RURD P Rig up to flush the metal out of the BOP stack.Flush stack while rotating slowly.400 GPM's. Blow down top drive. Lay down tools from the rig floor. 21:30 22:30 1.00 0 0 PROD1 DRILL PULD P Lay down 4 more HWDP. Pick up the jars and rack back in derrick. 22:30 22:45 0.25 0 PROD1 DRILL SFTY P PJSM. Pick up BHA. 22:45 00:00 1.25 PROD1 DRILL PULD P Make up BHA#8. GeoPilot. Flex collar.ADR MWD tool. Bit. Crew change. 03/11/2012 RIH with BHA#8. Drill 6 1/8"Production Hole. Drill from 12378'MD to 12852'MD. 00:00 01:00 1.00 0 0 PROD1 DRILL PULD P Make up the rest of BHA#8. 01:00 01:45 0.75 0 0 PROD1 DRILL DHEQ P Down Load MWD 01:45 03:15 1.50 0 0 PROD1 DRILL PULD P P/U 3jts,flex collars and 1STD HWDp(Spring Ahead 1 HR) 03:15 04:30 1.25 0 381 PROD1 DRILL DHEQ P Break in Geo-Pilot bearings, Shallow pulse test MWD,test Geo-Span lines T/1,500 psi(Good) 04:30 07:45 3.25 381 6,081 PROD1 DRILL TRIP P RIH F/381'MD T/6,081'MD. Filling Pipe every 20 STDs. Page 16 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:15 0.50 6,081 6,081 PROD1 DRILL SVRG P Service Rig 08:15 12:00 3.75 6,081 9,844 PROD1 DRILL TRIP P PJSM, P/U XT-39 Drill Pipe F/6,081' MD T/9,844'MD F/Pipe shed. Filling pipe every 20 STDs. (120 jts.) 12:00 14:15 2.25 9,844 12,291 PROD1 DRILL TRIP P Cont.To single in the hole F/9,1844' MD T/12,009'MD. Fill pipe every 20 STDs&Cont to RIH from derrick T/12,291'MD. 14:15 14:30 0.25 12,291 12,325 PROD1 DRILL TRIP P Kelly up on STD 127, Est. Parameters. Pumps=250 GPM= 1925 psi, P/U= 163K,S/0=107K, Rot=50 RPM,TQ=6K, Stopped ROT.SPR,Time-1415 hrs, 12,300 MD.TVD 7109', MW=9.8+ 14:30 14:45 0.25 12,325 12,378 PROD1 DRILL DDRL P Shut down pumps, no rotation, RIH Through Top of window: 12,325 MD T/12,378'MD,turn pumps on:250 GPM, ROT=50 rpm,TQ=6-7K, Start Drilling. 14:45 18:00 3.25 12,378 12,427 PROD1 DRILL DDRL P Drilling from 12,378'MDT/12,427 'MD.TVD-7,109'Total Jar Hrs= 45.75, Bit Hrs 1.94 P/U Wt=155k. S/0 Wt=109k. Rot Wt=125k.TQ On=7k.TQ Off=6k. ECD=11.46. Flow out=38%. WOB=8-10k. RPM= 100. GPM= 250. PP=2450 PSI. 18:00 00:00 6.00 12,427 12,852 PROD1 DRILL DDRL P Drilling from 12,427'MD T/12,852 'MD.TVD--7,126'Total Jar Hrs= 49.52, Bit Hrs 3.77 P/U Wt=155k. S/0 Wt=109k. Rot Wt=125k.TQ On=7k.TQ Off=6k. ECD=11.58. Flow out=38%. WOB=8-10k. RPM= 100. GPM= 250. PP=2450 PSI. 03/12/2012 Directional drilled from 12852'MD to 14610'MD. Flow check each connection. Slight breathing,to static. Average loss rate=13/4 barrel per hour. 00:00 06:00 6.00 12,852 13,277 PROD1 DRILL DDRL P Drilling from 12,852'MD T/13,277 MD.TVD-7,124'Total Jar Hrs= 54.08, Bit Hrs 10.27 P/U Wt=157k. S/0 Wt=105k. Rot Wt=133k.TQ On=8k.TQ Off=6k. ECD=11.78. Flow out=37%. WOB=10-12k. RPM=120.GPM= 250. PP=2550 PSI. 06:00 12:00 6.00 13,277 13,640 PROD1 DRILL DDRL P Drilling from 13,277'MD T/13,640' • MD.TVD-7,129'Total Jar Hrs= 57.51, Bit Hrs 13.70 P/U Wt=160k. S/O Wt=104k. Rot Wt=132k.TQ On=8k.TQ Off=7k. ECD=11.54. Flow out=38%. WOB=9-10 k. RPM= 120.GPM= 250. PP=2500 PSI.Total loss F/Tour = 15bbl Page 17 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 13,640 14,145 PROD1 DRILL DDRL P Drilling from 13,640'MDT/14,145' MD.TVD-7,136'Total Jar Hrs= 62.37, Bit Hrs 18.56 P/U Wt=158k. S/O Wt=104k. Rot Wt=130k.TQ On=8.5k.TQ Off=6k. ECD=11.48. Flow out=36%. WOB=7-10 k. RPM=120.GPM= 250. PP=2550 PSI. 18:00 00:00 6.00 14,145 14,610 PROD1 DRILL DDRL P Drilling from 14,145'MDT/14,610' MD.TVD-7,133'Total Jar Hrs= 67.76, Bit Hrs 23.95 P/U Wt=159k. S/O Wt=102k. Rot Wt=129k.TQ On=8.5k.TQ Off=6k. ECD=11.48. Flow out=36%. WOB=7-10 k. RPM=120. GPM= 250. PP=2550 PSI. 03/13/2012 Directional drilled from 14,610'MD to 16,329'MD. Flow check each connection. No breathing.Well static. 00:00 06:00 6.00 14,610 14,989 PROD1 DRILL DRLG P Drilling from 14,610'MD T/14,989' MD.TVD-7,125'Total Jar Hrs= 71.16, Bit Hrs 27.35 P/U Wt=160k. S/O Wt=110k. Rot Wt=130k.TQ On=9k.TQ Off=7k. ECD=11.80. Flow out=36%. WOB=13-15 k. RPM=120.GPM= 260. PP=2600 PSI. 06:00 12:00 6.00 14,989 15,386 PROD1 DRILL DRLG P Drilling from 14,989'MD T/15,386' _ MD.ND-7,120'Total Jar Hrs-= 75.06, Bit Hrs 31.25 P/U Wt=163k. S/O Wt=97k. Rot Wt=130k.TQ On=9k.TQ Off=7k. ECD=11.78 Flow out=36%. WOB=10 k. RPM= 120.GPM=260. PP=2750 PSI. 12:00 18:00 6.00 15,386 15,860 PROD1 DRILL DRLG P Drilling from 15,386'MD T/15,860' MD.ND-7,123'Total Jar Hrs= 79.48, Bit Hrs 35.67 P/U Wt=162k. S/O Wt=98k. Rot Wt=127k.TQ On=9.5k.TQ Off=6.5k. ECD=11.74 Flow out=36%. WOB=10 k. RPM=120.GPM=260. PP=2750 PSI. 18:00 00:00 6.00 15,860 16,329 PROD1 DRILL DDRL P Drilling from 15,860'MD T/16,329' MD.ND-7,126'Total Jar Hrs= 83.72, Bit Hrs 39.91 P/U Wt=165k. S/O Wt=95k. Rot Wt=127k.TQ On=9.5k.TQ Off=7k. ECD=11.74 Flow out=36%. WOB=10 k. RPM= 130. GPM=260. PP=2750 PSI. 03/14/2012 Directional drilled from 16329'MD to 18112'MD. Geologist called TD early due to low quality reservoir rock.I Page 18 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 16,329 16,750 PROD1 DRILL DDRL P Drilling from 16329'MD T/16750' MD.TVD-7,130'Total Jar Hrs= 87.88, Bit Hrs 44.07 P/U Wt=168k. S/O Wt=93k. Rot Wt=128k.TQ On=11 k.TQ Off=8.5k. ECD=12.09 Flow out=36%. WOB=10 k. RPM=120. GPM=260. PP=2850 PSI. 06:00 12:00 6.00 16,750 17,126 PROD1 DRILL DDRL P Drilling from 16750'MDT/17126' MD.TVD-7,125'Total Jar Hrs= 91.61, Bit Hrs 47.80 P/U Wt=170k. S/O Wt=92k. Rot Wt=131k.TQ On=11.5k.TQ Off=8.0k. ECD=12.10 Flow out=36%. WOB=10 k. RPM= 120.GPM=260. PP=2950 PSI. 12:00 18:00 6.00 17,126 17,548 PROD1 DRILL DDRL P Drilling from 17126'MD T/17,548' MD.TVD-7,118'Total Jar Hrs 96.24, Bit Hrs 52.43 P/U Wt=170k. S/O Wt=89k. Rot Wt=126k.TQ On=11 k.TQ Off=8.0k. ECD=12.10 Flow out=36%. WOB=10 k. RPM= 120. GPM=260. PP=2975 PSI. 18:00 00:00 6.00 17,548 17,865 PROD1 DRILL DDRL P Drilling from 17,548'MD T/17,865' MD.ND-7,133'Total Jar Hrs= 96.24, Bit Hrs 56.71 P/U Wt=170k. S/O Wt=90k. Rot Wt=127k.TQ On=11 k.TQ Off=8.0k. ECD=12.13 Flow out=36%. WOB=10 k. RPM= 120.GPM=260. PP=2975 PSI. 03/15/2012 Directional drilled to TD by 03:45 AM.CBU 3 x's. Pump out of the open hole into the casing.CBU one time. Monitor well for 30 mins.Static.Slip and Cut.CIO IBOP. Pump out of the hole to 12,291'MD. 00:00 03:45 3.75 17,865 18,112 PROD1 DRILL DDRL P Drilling from 17,865'MDT/18,112' MD.TVD-7,163'Total Jar Hrs= 103.59, Bit Hrs 59.78 P/U Wt=175k. S/O Wt=88k. Rot Wt=130k.TQ On=11 k.TQ Off=8.0k. ECD=12.13 Flow out=36%. WOB=10 k. RPM=130.GPM=260. PP=3000 PSI. 03:45 07:30 3.75 18,112 18,112 PROD1 DRILL CIRC P CBU 3 x's.260 GPM. 130 RPM. 8.5k TO. ECD start=12.3 PPG. End 11.96 PPG. Indicated clean hole ECD. 07:30 11:30 4.00 18,112 15,858 PROD1 DRILL CIRC P Pump out of the hole from 18,112' MD to 15,858'MD.260 GPM. Pulled tight @ 17560'MD.Tried to pack off. Worked back down and back up through. Cleaned up. No other problems.Actual displacement=29.4 BBLS. Calculated displacement= 13.5 BBLS. (Loss 15.9 BBLS) 11:30 12:00 0.50 15,858 15,858 PROD1 DRILL OWFF P Observe well. Static. Crew Change. Total mud loss for tour=27.46 BBLS. Page 19 of 26 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 17:00 5.00 15,858 12,291 PROD1 DRILL CIRC P Pump out of the hole from 15858'MD to 12291'MD.Actual displacement=32.9 BBLS. Calculated displacement=21.6 BBLS. 17:00 18:15 1.25 12,291 12,291 PROD1 DRILL CIRC P Circulate bottoms up.260 GPM. 2100 PSI. 100 RPM. P/U Wt=126k, S/O Wt=104k 18:15 18:45 0.50 12,291 12,291 PROD1 DRILL OWFF P Observe well.Static. Install safety valve in stump. 18:45 19:45 1.00 12,291 12,291 PROD1 DRILL SLPC P PJSM.Slip and cut drilling line. (143'). 19:45 21:45 2.00 12,291 12,291 PROD1 DRILL RGRP T PJSM.Change out Upper IBOP, Lower IBOP, Saver Sub. 21:45 00:00 2.25 12,291 12,291 PROD1 DRILL SFTY T Stand down due to incident. Preliminary investigation.Witness statements. Documention. Safety Stand down with both crews. 03/16/2012 Continue to work on IBOP after Safety Stand down. Clean and inspect TD grabber dies. Change out. UD upper and lower IBOP.Take to shop for rebuild. Discuss Incident with TP. &CM. Make up and install rebuilt IBOP. Saver sub.Wire up all bolts.TIH from 12291'to 18112'MD. Begin circulating.Crew change. 00:00 05:00 5.00 12,291 12,291 PROD1 DRILL RGRP T PJSM, Cont to change out IBOP and saversub. (Wait on parts) 05:00 07:00 2.00 12,291 12,291 PROD1 DRILL RGRP T Clean and inspect top drive grabber dies,dies looked wore out so they where changed out 07:00 09:00 2.00 12,291 12,291 PROD1 DRILL OTHR T Clean and clear rig floor 09:00 11:00 2.00 12,291 12,291 PROD1 DRILL RGRP T Clean old upper IBOP and UD upper and lower IBOP, bring to shop for repair 11:00 12:00 1.00 12,291 12,291 PROD1 DRILL RGRP T P/U new IBOP. Hold PJSM on install new IBOP, have discussion on (lessons learned)on incident.M/U on top drive and torque up 12:00 12:30 0.50 12,291 12,291 PROD1 DRILL RGRP T Cont t/M/U upper IBOP 12:30 13:30 1.00 12,291 12,291 PROD1 DRILL RGRP T R/U and test upper IBOP,tested t/ 5000 PSI(good test) 13:30 14:30 1.00 12,291 12,291 PROD1 DRILL RGRP T R/D test equipment and cont.to M/U clamp and actuator sleeve on upper IBOP 14:30 16:00 1.50 12,291 12,291 PROD1 DRILL RGRP T M/U lower IBOP and saver sub, torque U 42K. M/U clamps and wire. Space out grabber dies,wire up all bolts and double check all work 16:00 16:15 0.25 12,291 12,291 PROD1 DRILL SFTY P PJSM on tripping in the hole, review procedure,fill out hazard cards and talk to crew about pinch points 16:15 16:30 0.25 12,291 12,291 PROD1 DRILL OTHR P Test crown-matic, reset crown-matic to proper height 16:30 21:45 5.25 12,291 18,112 PROD1 DRILL TRIP P RIH f/12,291'MD to 18,112'MD. Fill pipe every 20 stands.Wash down last 3 stands.slight pack off @ 17820'MD to 17840'MD. Calculated displacement=32.4 BBLS.Actual displacement=31.1 BBLS. Page 20 of 26 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:45 00:00 2.25 18,112 18,112 PROD1 DRILL CIRC P Circulate 2 bottoms up volumes.260 GPM. 2850 PSI. Rotate and reciprocate. 130 RPM. ECD start 11.95ppg.end 11.82ppg 03/17/2012 Continue to circulate the hole clean. Monitor well f/flow. POOH w/pump U 12,291'MD.Circulate hole clean. Blow down and drop 2.2"Rabbit, monitor well f/30min. POOH w/pump U11,345',attempt t/POOH on elevators(well swabbing).Continue to Pump out of the hole U 2164'MD.Monitor well,Crew change. c00:00 01:30 1.50 18,112 18,112 PROD1 DRILL CIRC P Cont U CBU @ 18112',72 SPM,6 BPM,2800 PSI, 10_0 RPM,TQ-8K, Up wt.-116K, Down wt.-113K. Lost 6.6 bbl while CBU. 01:30 02:00 0.50 18,112 18,112 PROD1 DRILL OWFF P SPR,S, Monitor well for flow(static) 02:00 12:00 10.00 18,112 12,479 PROD1 DRILL TRIP P Pump out of the hole @ 65 SPM, 2300 PSI.Work tight spot @ 17,400; MD. Pump out f/18,112'MD U 12,479'MD. P/U wt.-165k,S/O wt. -106K. Cal displacement-32.6 bbl, Actual displacement-50.11 bbls 12:00 12:15 0.25 12,479 12,291 PROD1 DRILL TRIP P Cont U POOH w/pump f/12,479'MD U 12,291'MD. Lost 17.5 bbls while pumping from 12:15 13:15 1.00 12,291 12,291 PROD1 DRILL CIRC P CBU @ 12,291'(above window)@ 260 GPM=2100 PSI, 100 RPM 13:15 14:00 0.75 12,291 12,195 PROD1 DRILL OWFF P Blow down Geo-Span and topdrive, drop 2.2"rabbit @ 12,195'MD, Stand 126 and monitor well f/30 min. 14:00 00:00 10.00 12,195 2,164 PROD1 DRILL TRIP P POOH w/pump U 12,195'MD1/ 11,345'MD.Attempt U POOH on elevators,4 stands(swabbing). Cont. U Pump out of the hole to 2164'MD. Calculated displacement=48.6 BBLS.Actual displacement=60.15 BBLS. 12 barrel loss for tour. 03/18/2012 POOH to BHA. Lay down BHA.Test rams and annular preventer with 41/2 TJ. Rig up and run the Lower Completion string to 9138'MD. Crew change. 00:00 01:45 1.75 2,146 381 PROD1 DRILL TRIP P Blow down top drive, POOH on elevators from 2146 to 381'MD. Calculated displacement=9.18 BBLS.Actual displacement=10.88 BBLS.At top of HWDP. 01:45 02:15 0.50 381 381 PROD1 DRILL OWFF P Observe well for flow.Static. 02:15 04:00 1.75 381 0 PROD1 DRILL PULD P Lay down 5 joints HWDP,jars, 3 monel flex collars, MWD,GeoPilot, bit.Calculated displacement=5.43 BBLS.Actual displacement=4.25 BBLS. 04:00 04:30 0.50 0 0 COMPZ RPCOM CIRC P Flush BOP stack in preparation for testing the pipe rams and annular preventer with the 4'/i'test joint. 04:30 04:45 0.25 0 0 COMPZ RPCOM BOPE P Pull wear bushing. 04:45 05:30 0.75 0 0 COMPZ RPCOM PULD P PJSM. Bring casing eqipment to rig floor to warm up while testing BOPE. 05:30 06:00 0.50 0 0 COMPZ RPCOM BOPE P Set test plug as per FMC well head hand. Rig up to test BOPE. Page 21 of 26 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 06:00 07:30 1.50 0 0 COMPZ RPCOM BOPE P PJSM.Test upper and lower pipe rams and annular preventer with 4'/z" test joint. 250 PSI low.3500 PSI high. Record on chart.All good tests. No failures. 07:30 08:15 0.75 0 0 COMPZ RPCOM BOPE P Rig down test equipment. Pull test plug. Set Alpine 9"ID wear bushing as per FMC well head hand. 08:15 09:15 1.00 0 0 COMPZ RPCOM RNCS P Rig up casing equipment. Pick up perforated pups on beavaer slide.7 each. 09:15 12:00 2.75 0 1,473 COMPZ RPCOM RNCS P PJSM. Pick up and run 4%"liner. 12.6#. IBT-M. L-80.36 joints&5 perforated pups. Crew change. 12:00 17:00 5.00 1,473 5,338 COMPZ RPCOM RNCS P PJSM. Pick up the last 18 joints of IBTM and 2 perf. pups.XO to Hydril 563 joints. Run 70 joints of 563. 5 Tam Swell packers. 3 ball actuated frac sleeves, HES XN nipple, Baker HRD ZXP liner top packer/RS nipple/Flex lock hanger/seal bore extension.XO to 4"XT39 drill pipe. 17:00 19:15 2.25 5,338 5,338 COMPZ RPCOM RNCS P Insert ZXP running tool seals.Torque 5"521 connection to 6k ft/lbs. Mix up and pour in Pal Mix to top fo packer. Let set up for 30 mins. 19:15 20:00 0.75 5,338 5,338 COMPZ RPCOM CIRC P Circulate a pipe volume after screwing into first stand. P/U Wt= 75k.S/O Wt=65k. Rot Wt=70k. 20:00 23:30 3.50 5,338 9,138 COMPZ RPCOM RNCS P Continue to trip in the hole with stands from 5338'MD to 9138'MD> Record P/U&S/O weights very 5 stands. 23:30 00:00 0.50 9,138 9,138 COMPZ RPCOM CIRC P Circulate a string volume @ 9138' MD. Pump 210 GPM.930 PSI. Calculated displacement=38.31 BBLS,Actual displacement=38.15 BBLS, P/U Wt=111 k,S/O Wt=86k. 03/19/2012 Circ string volume @ 9138'MD.TIH W/Lower Completion string.4%"Liner. 12.6#. L-80. IBTM&HYD.563. Set hanger and packer.Test to 1000 PSI. Good. Liner top=12,088'MD.Shoe @ 17,420'MD. Pump out of the hole with the running tool. 00:00 00:15 0.25 9,138 9,138 COMPZ RPCOM CIRC P Continue to circulate DP volume @ 9138'MD. 5 BPM. 950 PSI. MW in and out 9.8+. 00:15 03:00 2.75 9,138 12,262 COMPZ RPCOM RNCS P Continue to trip in the hole with Lower Completion string. Run in @ 30 to 35'/min.Good displacement. 03:00 04:00 1.00 12,262 12,262 COMPZ RPCOM CIRC P Break circulation @ 12,262'MD. CBU @ 5 BPM. 1140 PSI. 04:00 09:15 5.25 12,262 17,420 COMPZ RPCOM RNCS P Run in the hole with Lower_ Completion string. From 12262'MQ_ to 17420'MD. Record weights. Up Wt=185k, Down Wt=87k,Actual displacement=46.6 BBLS. Calculated displacement=47.52 BBLS. Page 22 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 10:30 1.25 17,420 17,420 COMPZ RPCOM RNCS P Drop 29/32"ball. Pump down. On seat @ 1387 strokes. 10:30 10:45 0.25 17,420 17,420 COMPZ RPCOM PRTS P _Pressure up to 2400 PSI.Set liner hanger. Set down 50k. Pressure up to 3400 PSI. Release from liner hanger. Bleed off pressure. Confirm release.Slack off and set liner top packer.Verify shear @ 25k.Set 60k down.Confirm with rotation. Pressure up to 4000 PSI to shear out the ball seat. 10:45 11:15 0.50 17,420 17,420 COMPZ RPCOM PRTS P Test packer to 1000 PSI. Record on chart for 10 mins.Good. 11:15 12:00 0.75 17,420 17,420 COMPZ RPCOM CIRC P Pick up out of the top of the liner. 45'.CBU @ 5 BPM. 1200 PSI. 12:00 12:15 0.25 17,420 17,420 COMPZ RPCOM CIRC P Continue to CBU @ 5 BPM. 1200 PSI. 12:15 12:45 0.50 17,420 17,420 COMPZ RPCOM OWFF P Blow down top drive. Monitor well for 30 mins. Static. 12:45 13:00 0.25 17,420 17,420 COMPZ RPCOM TRIP P Attempt to pull on elevators. Improper hole fill. Prepare to pump out of the hole. 13:00 14:00 1.00 17,420 17,420 COMPZ RPCOM CIRC P Pump out. Lay down 21 joints of drill pipe. (Borrowed from D19). 14:00 21:30 7.50 17,420 2,500 COMPZ RPCOM CIRC P Pump out of the hole from 17420'to 2500'MD. Blow down top drive. 100 GPM.400 PSI. 21:30 22:30 1.00 2,500 0 COMPZ RPCOM TRIP P Pull out on elevators to surface. Calculated displacement=69.12 BBLS.Actual displacement=74.05 BBLS. 22:30 22:45 0.25 0 0 COMPZ RPCOM PULD P Lay down running tool. Upon inspection the dog sub was verified to be sheared out. 22:45 23:15 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. Lay down tools and pick up 3%"test joint. 23:15 00:00 0.75 0 0 COMPZ RPCOM BOPE P Drain stack. Pull wear bushing. Set test plug. Fill hole with water. 03/20/2012 Jest BOPE, Set wear ring, LD 4"DP, RU and Run 3-1/2"upper completion 00:00 01:00 1.00 0 0 COMPZ RPCOM BOPS P Continue RU to test BOPE 01:00 07:30 6.50 0 0 COMPZ RPCOM BOPE P Test BOPE,Test all rams,annular and choke valves t/250 PSI Low, 3500 PSI High with 3.5"and 4.5"test joints.Valves 9, 11 &13 failed. Greased and retested ok. Perform accumulator test to 2900 PSI start. Function valves and stabilized at 1725 PSI.Took 38 sec for 200 PSI recovery, 183 sec for full recovery.All gas alarms tested.Witness waived by Bob Noble of AOGCC. 07:30 08:30 1.00 0 0 COMPZ RPCOM BOPE P RD test equip,blow down choke and kill lines 08:30 09:00 0.50 0 0 COMPZ RPCOM RURD P Set 9"ID wear ring as per FMC 09:00 09:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM on laying down DP Page 23 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 16:45 7.50 0 0 COMPZ RPCOM PULD P Lay down 4"DP from derrick to make room for I-wire and control line spools. 16:45 17:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM on PU tools and RU to run tubing. 17:00 20:15 3.25 0 0 COMPZ RPCOM RURD P RU to run upper completion. 20:15 20:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running tubing 20:30 00:00 3.50 0 960 COMPZ RPCOM RCST P Ran 3 1/2"9.3#L-80 EUE 8rd completion as follows: Baker seal stem assembly w/3 1/2"pup jt-1 jt 3 1/2"9.3#L-80 EUE 8rd tbg-SLB Solid Gauge Mandrel with 3 1/2" hydril 563 x 3 1/2"EUE 8rd XO's and 3 1/2"9.3#L-80 EUE 8rd pup jts top and btm-12 jts 3 1/2"9.3#L-80 EUE 8rd tbg-HES 2.813"X nipple with RHC plug body 3 1/2"9.3#L-80 EUE 8rd pup jts top and btm-4 jts 3 1/2"9.3#L-80 EUE 8rd tbg-Camco KBMG GLM w/DCK-2 SOV w/3 1/2"9.3#L-80 EUE 8rd pup jts top& btm-10 jts 3 1/2"9.3#L-80 EUE 8rd tbg to jt#27 at 960',Cal Disp=2.91 bbls,Actual Disp=2.72 bbls. 03/21/2012 _Ran 3-1/2"upper completion,space out. 00:00 12:00 12.00 960 8,595 COMPZ RPCOM RCST P Continue run 3 1/2"9.3#L-80 EUE 8rd completion as follows:69 more jts 3 1/2"9.3#L-80 EUE 8rd tbg- Camco KBMG GLM w/DV w/3 1/2" 9.3#L-80 EUE 8rd pup jts top&btm -128 jts 3 1/2"9.3#L-80 EUE 8rd tbg-Camco KBMG GLM w/DV w/3 1/2"9.3#L-80 EUE 8rd pup jts top& btm-46 more jts 3 1/2"9.3#L-80 EUE 8rd tbg to Jt#270 at 8595'-Cal Disp=29.16 bbls,Actual Disp= 25.85 bbls. PUW=85K SOW=65K 12:00 13:45 1.75 8,595 9,709 COMPZ RPCOM RCST P Continue run 3 1/2"9.3#L-80 EUE 8rd completion as follows:36 more jts 3 1/2"9.3#L-80 EUE 8rd tbg to Jt #306 at 9709'. 13:45 14:30 0.75 9,709 9,709 COMPZ RPCOM RURD P PJSM, PU control line spools and tools 14:30 15:30 1.00 9,709 9,709 COMPZ RPCOM RCST P RU,test SSSV for proper function, purge line, RU and test line to 6000 psi. 15:30 20:45 5.25 9,709 12,110 COMPZ RPCOM RCST P Continue run 3 1/2"9.3#L-80 EUE 8rd completion as follows:72 more jts 3 1/2"9.3#L-80 EUE 8rd tbg to Jt #378 at 11984'. PU 4 more jts 3.5"to 12110', MU head pin on 5th Jt#383 Page 24 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 00:00 3.25 12,110 12,110 COMPZ RPCOM RCST P Est PUW 107K,SOW 77K, pump dwn at 1 bpm,400 psi,saw PSI inc at 12122',shut down pump,open bleeder,slack off 2'more to jt down at 12124'. Pessure up to 500 psi, no returns,seals in. Cont RIH to tag(no go)at 12099'.Set dwn 15K, LD 5 space out Jts, MU XO, 1 Jt 4.5", ,space out pup. 03/22/2012 Retrieve wear bushing,MU Hgr,terminate lines,displace to 9.8 brine, spot inhibited brine, monitor well, land fir, RILDS, PT annulus to 1000 psi to test seals,drop ball/rod,test tbg to 4000 psi, ann to 3500 psi,shear DCK-2, set TWC,test Hgr seals,test TWC from below, ND BOP's,terminate lines, NU tree. 00:00 01:30 ' 1.50 12,110 12,110 COMPZ RPCOM RCST P Continue space-out TBG, MU bushing puller with landing jt"B", retrieve wear bushing, LD landing jt. 01:30 02:00 0.50 12,110 12,110 COMPZ RPCOM RCST P Bleed off control lines, cut from reel, MU Tbg Hgr and landing joint"A". 02:00 03:30 1.50 12,110 12,110 COMPZ RPCOM RCST P Terminate control line/I-wire,test to 5000 psi. 03:30 07:30 4.00 12,110 12,110 COMPZ RPCOM CIRC P Displace to 9.8 ppg brine at 4 bpm, 650 psi,shut down, line up and spot 20 bbls inhibited brine between packer and bottom GLM. 07:30 08:00 0.50 12,110 12,110 COMPZ RPCOM OWFF P Monitor well static. 08:00 09:00 1.00 12,110 12,134 COMPZ RPCOM RCST P Land tubing/Hgr, RILDS. 09:00 09:30 0.50 12,134 12,134 COMPZ RPCOM PRTS P Pressure test annulus/seals to 1000 psi for 10 min. 09:30 10:00 0.50 12,134 12,134 COMPZ RPCOM OWFF P Monitor well static. 10:00 12:15 2.25 12,134 12,134 COMPZ RPCOM PRTS P Drop ball/rod with rollers, RU,test _tubing to 4000 psi for 30 min, bleed off to 2000 psi, RU,test annulus to 3500 psi for 30 min. 12:15 12:30 0.25 12,134 12,134 COMPZ RPCOM PRTS P Bleed off tubing pressure to shear DCK-2 valve,cont bleed off pressure to O. 12:30 14:00 1.50 12,134 12,134 COMPZ RPCOM OTHR P LD landing joint"A", FMC set TWC. 14:00 15:45 1.75 12,134 12,134 COMPZ RPCOM PRTS P RU landing joint"B"and pressure test hanger seals to 250 psi low for 10 min and 5000 psi high for 10 min. 15:45 16:00 0.25 12,134 12,134 COMPZ RPCOM PRTS P Pressure up on annulus to 3000 psi to test TWC in direction of flow for 10 mins.-bleed off-LD landing jt 16:00 16:30 0.50 12,134 12,134 COMPZ RPCOM OWFF P Monitor well static. 16:30 17:45 1.25 12,134 12,134 COMPZ WHDBOOTHR P Flush MP's,blow down lines, LD landing joint,drain stack. 17:45 20:00 2.25 12,134 12,134 COMPZ WHDBO NUND P PJSM,nipple down BOP stack. 20:00 21:45 1.75 12,134 12,134 COMPZ WHDBO NUND P Terminate I-wire and SSSV control lines. 21:45 22:45 1.00 12,134 12,134 COMPZ WHDBO NUND P NU tree. 22:45 23:00 0.25 12,134 12,134 COMPZ WHDBO PRTS P Pressure test tubing hanger adapter void to 5000 psi. 23:00 00:00 1.00 12,134 12,134 COMPZ WHDBO RURD P RU scaffolding. Page 25 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/23/2012 24 hr Summary Test tree, Pull TWC, LD 4"DP, Freeze protect well,Set BPV, LD 4"DP. 00:00 02:00 2.00 0 0 COMPZ WHDBO PRTS P Cont RU scaffold, PJSM, RU and test tree 250/5000 psi. 02:00 03:00 1.00 0 0 COMPZ WHDBO RURD P RU lubricator and test same. Pull TWC, RD lubricator. 03:00 03:30 0.50 0 0 COMPZ RPCOM RURD P RU circ lines to tree. 03:30 05:30 2.00 0 0 COMPZ MOVE RURD P LD 4"DP via mouse hole. 05:30 06:15 0.75 0 0 COMPZ RPCOM RURD P PJSM, RU Hot Oil, PT lines to 4500 psi. 06:15 08:15 2.00 0 0 COMPZ RPCOM FRZP P Freeze protect well with dead crude down tubing at 1 bpm,600 psi.Take returns out annulus. Pumped 104 bbls down tubing and pressured up to 3650 psi.Shut down pump. 08:15 10:45 2.50 0 0 COMPZ RPCOM FRZP P RU to pump down annulus, bleed off tubing and u-tube back 22 bbls.Shut in and RU to pump down tubing, continue pump crude down tbg. Pumped a total of 164 bbls. FCP= 2500 psi. SIM-OPS, continue lay down 4"DP. 10:45 12:00 1.25 0 0 COMPZ WHDBO RURD P RU lubricator,set BPV, RD lubricator,SIM-OPS clean shakers, trough,and rockwasher. Secure well. 12:00 15:00 3.00 0 0 COMPZ MOVE RURD P Continue LD 4"DP. Release rig at 15:00 hrs. Page 26 of 26 • I ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad CD1-48A 50103205920100 1 Al A A Sperry Drillinc Definitive Survey Report 23 March, 2012 111 11 1'1 kk P fc ypy5�N Amax HALLIBUR ■ ON °'��'" Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-48 Project: Western North Slope TVD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Site: CD1 Alpine Pad MD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Well: CD1-48 North Reference: True Wellbore: CD1-48A Survey Calculation Method: Minimum Curvature Design: CD1-48A Database: CPAI EDM Production Project Western North Slope 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 , I Well CD1-48 Well Position +N/-S 0.00 ft Northing: 5,975,572.62 ft Latitude: 70°20'31.604 N +EI-W 0.00 ft Easting: 385,667.53 ft Longitude: 150°55'40.432 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore CD1-48A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 2/21/2012 20.15 80.82 57,605 Design CD1-48A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,298.19 Vertical Section: Depth From(ND) +N/-S +E/-W Direction ISI (ft) (ft) (ft) (0) 27.25 0.00 0.00 147.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 49.25 1,189.25 CD1-48 Gyro(CD1-48) GYD-GC-SS Gyrodata gyro single shots 1/20/2009 12:C 1,215.30 1,307.11 CD1-48 MWD(CD1-48) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/20/2009 12:C 1,369.25 1,462.25 CD1-48 Gyro(CD1-48) GYD-GC-SS Gyrodata gyro single shots 1/20/2009 12:C 1,539.94 12,298.19 CD1-48 MWD(CD1-48) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/20/2009 12:C 12,325.00 18,043.86 CD1-48A(CD1-48A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/11/2012 12:C Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.25 0.00 0.00 27.25 -19.50 0.00 0.00 5,975,572.62 385,667.53 0.00 0.00 UNDEFINED 49.25 0.28 83.04 49.25 2.50 0.01 0.05 5,975,572.62 385,667.59 1.27 0.02 GYD-GC-SS(1) 99.25 0.24 72.06 99.25 52.50 0.05 0.27 5,975,572.67 385,667.81 0.13 0.10 GYD-GC-SS(1) 175.25 0.72 57.09 175.25 128.50 0.36 0.83 5,975,572.97 385,668.37 0.65 0.15 GYD-GC-SS(1) 270.25 1.67 141.89 270.23 223.48 -0.40 2.18 5,975,572.18 385,669.71 1.85 1.53 GYD-GC-SS(1) 358.25 2.76 152.23 358.16 311.41 -3.29 3.96 5,975,569.27 385,671.44 1.31 4.91 GYD-GC-SS(1) 450.25 4.64 168.51 449.97 403.22 -8.89 5.73 5,975,563.64 385,673.13 2.32 10.58 GYD-GC-SS(1) 542.25 6.16 184.65 541.56 494.81 -17.46 6.08 5,975,555.07 385,673.34 2.32 17.95 GYD-GC-SS(1) 633.25 7.46 188.19 631.92 585.17 -28.18 4.84 5,975,544.37 385,671.94 1.50 26.26 GYD-GC-SS(1) 725.25 8.68 191.77 723.01 676.26 -40.88 2.57 5,975,531.70 385,669.48 1.43 35.69 GYD-GC-SS(1) 3/23/2012 10:44:37AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-48 Project: Western North Slope TVD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Site: CD1 Alpine Pad MD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Well: CD1-48 North Reference: True Wellbore: CD1-48A Survey Calculation Method: Minimum Curvature Design: CD1-48A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 818.25 10.68 189.51 814.68 767.93 -56.25 -0.28 5,975,516.38 385,666.39 2.19 47.02 GYD-GC-SS(1) 910.25 14.00 183.00 904.55 857.80 -75.78 -2.28 5,975,496.89 385,664.10 3.91 62.32 GYD-GC-SS(1) 959.25 16.04 177.64 951.87 905.12 -88.47 -2.31 5,975,484.20 385,663.88 5.03 72.94 GYD-GC-SS(1) 1,004.25 19.92 174.89 994.67 947.92 -102.32 -1.37 5,975,470.34 385,664.61 8.82 85.07 GYD-GC-SS(1) 1,049.25 23.65 174.96 1,036.45 989.70 -118.95 0.11 5,975,453.69 385,665.83 8.29 99.82 GYD-GC-SS(1) 1,096.25 26.73 173.99 1,078.97 1,032.22 -138.86 2.04 5,975,433.76 385,667.46 6.61 117.57 GYD-GC-SS(1) 1,141.25 29.52 172.28 1,118.65 1,071.90 -159.91 4.59 5,975,412.67 385,669.69 6.45 136.62 GYD-GC-SS(1) i4 1,189.25 32.47 171.56 1,159.80 1,113.05 -184.38 8.07 5,975,388.15 385,672.79 6.19 159.03 GYD-GC-SS(1) 1,215.30 33.66 171.55 1,181.63 1,134.88 -198.44 10.16 5,975,374.06 385,674.67 4.57 171.96 MWD+IFR-AK-CAZ-SC(2) 1,307.11 33.73 169.68 1,258.02 1,211.27 -248.69 18.47 5,975,323.70 385,682.20 1.13 218.62 MWD+IFR-AK-CAZ-SC(2) 1,369.25 35.71 171.65 1,309.09 1,262.34 -283.61 24.19 5,975,288.70 385,687.40 3.66 251.03 GYD-GC-SS(3) 1,462.25 36.17 172.73 1,384.39 1,337.64 -337.68 31.61 5,975,234.52 385,693.98 0.84 300.42 GYD-GC-SS(3) 1,539.94 37.17 173.46 1,446.70 1,399.95 -383.74 37.18 5,975,188.38 385,698.86 1.40 342.08 MWD+IFR-AK-CAZ-SC(4) 1,583.98 38.26 175.04 1,481.54 1,434.79 -410.55 39.87 5,975,161.54 385,701.14 3.31 366.03 MWD+IFR-AK-CAZ-SC(4) 1,677.00 41.51 173.60 1,552.91 1,506.16 -469.89 45.80 5,975,102.12 385,706.16 3.63 419.03 MWD+IFR-AK-CAZ-SC(4) 1,769.98 45.32 174.30 1,620.44 1,573.69 -533.43 52.52 5,975,038.50 385,711.91 4.13 475.97 MWD+IFR-AK-CAZ-SC(4) 1,863.38 49.20 174.71 1,683.81 1,637.06 -601.70 59.08 5,974,970.14 385,717.43 4.17 536.80 MWD+IFR-AK-CAZ-SC(4) 1,956.32 52.49 171.80 1,742.50 1,695.75 -673.24 67.59 5,974,898.49 385,724.84 4.29 601.43 MWD+IFR-AK-CAZ-SC(4) 2,049.16 55.09 170.49 1,797.34 1,750.59 -747.24 79.13 5,974,824.32 385,735.25 3.02 669.79 MWD+IFR-AK-CAZ-SC(4) 2,141.14 57.57 172.99 1,848.33 1,801.58 -822.99 90.10 5,974,748.42 385,745.07 3.52 739.29 MWD+IFR-AK-CAZ-SC(4) 2,234.16 58.65 170.64 1,897.48 1,850.73 -901.15 101.35 5,974,670.10 385,755.13 2.44 810.97 MWD+IFR-AK-CAZ-SC(4) 2,326.24 58.09 170.51 1,945.77 1,899.02 -978.49 114.19 5,974,592.58 385,766.78 0.62 882.83 MWD+IFR-AK-CAZ-SC(4) 2,419.57 56.57 169.86 1,996.15 1,949.40 -1,055.90 127.58 5,974,514.98 385,778.99 1.73 955.04 MWD+IFR-AK-CAZ-SC(4) 2,513.29 56.11 171.24 2,048.09 2,001.34 -1,132.85 140.39 5,974,437.86 385,790.62 1.32 1,026.55 MWD+IFR-AK-CAZ-SC(4) 2,603.76 57.09 172.92 2,097.90 2,051.15 -1,207.65 150.79 5,974,362.91 385,799.88 1.89 1,094.95 MWD+IFR-AK-CAZ-SC(4) 2,696.65 57.91 172.38 2,147.81 2,101.06 -1,285.35 160.81 5,974,285.07 385,808.72 1.01 1,165.57 MWD+IFR-AK-CAZ-SC(4) 2,789.63 57.40 172.90 2,197.55 2,150.80 -1,363.26 170.88 5,974,207.03 385,817.59 0.72 1,236.39 MWD+IFR-AK-CAZ-SC(4) 2,882.03 57.90 171.12 2,247.00 2,200.25 -1,440.55 181.73 5,974,129.58 385,827.26 1.71 1,307.13 MWD+IFR-AK-CAZ-SC(4) 2,975.61 57.12 172.49 2,297.27 2,250.52 -1,518.68 192.99 5,974,051.31 385,837.32 1.49 1,378.78 MWD+IFR-AK-CAZ-SC(4) 3,066.87 58.24 172.13 2,346.06 2,299.31 -1,595.10 203.31 5,973,974.74 385,846.48 1.27 1,448.49 MWD+IFR-AK-CAZ-SC(4) 3,121.90 57.88 171.48 2,375.17 2,328.42 -1,641.32 209.96 5,973,928.42 385,852.43 1.20 1,490.88 MWD+1FR-AK-CAZ-SC(4) 3,210.63 58.56 174.40 2,421.91 2,375.16 -1,716.17 219.22 5,973,853.45 385,860.54 2.90 1,558.70 MWD+IFR-AK-CAZ-SC(4) 3,306.67 58.42 174.01 2,472.10 2,425.35 -1,797.63 227.49 5,973,771.88 385,867.57 0.38 1,631.52 MWD+IFR-AK-CAZ-SC(4) 3,401.79 56.60 173.56 2,523.20 2,476.45 -1,877.38 236.17 5,973,692.01 385,875.03 1.95 1,703.14 MWD+IFR-AK-CAZ-SC(4) 3,497.76 56.44 172.96 2,576.14 2,529.39 -1,956.88 245.57 5,973,612.39 385,883.21 0.55 1,774.92 MWD+IFR-AK-CAZ-SC(4) 3,593.56 56.75 173.40 2,628.88 2,582.13 -2,036.28 255.06 5,973,532.85 385,891.50 0.50 1,846.69 MWD+IFR-AK-CAZ-SC(4) 3,688.49 57.63 174.08 2,680.32 2,633.57 -2,115.59 263.76 5,973,453.43 385,898.98 1.11 1,917.94 MWD+IFR-AK-CAZ-SC(4) 3,784.59 57.97 173.64 2,731.53 2,684.78 -2,196.45 272.46 5,973,372.46 385,906.45 0.52 1,990.49 MWD+IFR-AK-CAZ-SC(4) 3,880.30 57.90 174.02 2,782.34 2,735.59 -2,277.08 281.18 5,973,291.70 385,913.93 0.34 2,062.86 MWD+IFR-AK-CAZ-SC(4) 3,975.48 56.20 173.68 2,834.11 2,787.36 -2,356.49 289.73 5,973,212.18 385,921.27 1.81 2,134.12 MWD+IFR-AK-CAZ-SC(4) 3/23/2012 10:44:37AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-48 Project: Western North Slope TVD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Site: CD1 Alpine Pad MD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Well: CD1-48 North Reference: True Wellbore: CD1-48A Survey Calculation Method: Minimum Curvature Design: CD1-48A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E!-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 4,070.36 56.20 173.69 2,886.89 2,840.14 -2,434.86 298.40 5,973,133.70 385,928.75 0.01 2,204.57 MWD+IFR-AK-CAZ-SC(4) 4,165.80 55.49 173.48 2,940.47 2,893.72 -2,513.34 307.23 5,973,055.10 385,936.37 0.77 2,275.19 MWD+IFR-AK-CAZ-SC(4) 4,260.99 55.64 173.27 2,994.30 2,947.55 -2,591.33 316.29 5,972,976.99 385,944.24 0.24 2,345.53 MWD+IFR-AK-CAZ-SC(4) 4,357.15 55.85 174.10 3,048.42 3,001.67 -2,670.32 325.03 5,972,897.88 385,951.78 0.75 2,416.54 MWD+IFR-AK-CAZ-SC(4) 4,453.47 56.51 173.36 3,102.04 3,055.29 -2,749.86 333.77 5,972,818.22 385,959.30 0.94 2,488.01 MWD+IFR-AK-CAZ-SC(4) 4,548.11 56.90 173.29 3,153.99 3,107.24 -2,828.43 342.96 5,972,739.52 385,967.30 0.42 2,558.92 MWD+IFR-AK-CAZ-SC(4) 4,644.93 57.32 173.56 3,206.56 3,159.81 -2,909.20 352.27 5,972,658.63 385,975.37 0.49 2,631.72 MWD+IFR-AK-CAZ-SC(4) 4,741.05 57.38 174.23 3,258.42 3,211.67 -2,989.67 360.88 5,972,578.05 385,982.75 0.59 2,703.90 MWD+IFR-AK-CAZ-SC(4) 4,836.59 55.15 174.23 3,311.48 3,264.73 -3,068.72 368.87 5,972,498.89 385,989.53 2.33 2,774.54 MWD+IFR-AK-CAZ-SC(4) 4,932.12 55.08 174.17 3,366.11 3,319.36 -3,146.68 376.79 5,972,420.83 385,996.26 0.09 2,844.24 MWD+IFR-AK-CAZ-SC(4) 5,028.53 55.12 174.63 3,421.27 3,374.52 -3,225.37 384.50 5,972,342.03 386,002.77 0.39 2,914.44 MWD+IFR-AK-CAZ-SC(4) 5,124.11 55.11 174.54 3,475.94 3,429.19 -3,303.43 391.90 5,972,263.88 386,008.98 0.08 2,983.93 MWD+IFR-AK-CAZ-SC(4) 5,219.83 55.17 175.44 3,530.65 3,483.90 -3,381.67 398.76 5,972,185.55 386,014.65 0.77 3,053.29 MWD+IFR-AK-CAZ-SC(4) 5,315.93 55.08 175.35 3,585.60 3,538.85 -3,460.25 405.09 5,972,106.88 386,019.78 0.12 3,122.64 MWD+IFR-AK-CAZ-SC(4) 5,410.75 55.18 175.36 3,639.81 3,593.06 -3,537.79 411.39 5,972,029.26 386,024.89 0.11 3,191.10 MWD+IFR-AK-CAZ-SC(4) 5,506.39 55.19 175.65 3,694.41 3,647.66 -3,616.07 417.54 5,971,950.91 386,029.85 0.25 3,260.10 MWD+IFR-AK-CAZ-SC(4) 5,602.80 55.01 176.01 3,749.57 3,702.82 -3,694.93 423.29 5,971,871.97 386,034.40 0.36 3,329.37 MWD+IFR-AK-CAZ-SC(4) 5,698.05 54.96 175.71 3,804.23 3,757.48 -3,772.74 428.92 5,971,794.10 386,038.84 0.26 3,397.70 MWD+IFR-AK-CAZ-SC(4) 5,793.82 55.17 175.63 3,859.07 3,812.32 -3,851.03 434.85 5,971,715.73 386,043.57 0.23 3,466.58 MWD+IFR-AK-CAZ-SC(4) 5,889.03 56.26 175.68 3,912.70 3,865.95 -3,929.47 440.81 5,971,637.22 386,048.34 1.15 3,535.61 MWD+IFR-AK-CAZ-SC(4) 5,984.62 56.39 175.70 3,965.70 3,918.95 -4,008.79 446.79 5,971,557.82 386,053.10 0.14 3,605.40 MWD+IFR-AK-CAZ-SC(4) 6,081.03 57.10 175.97 4,018.57 3,971.82 -4,089.20 452.65 5,971,477.34 386,057.73 0.77 3,676.02 MWD+IFR-AK-CAZ-SC(4) 6,175.05 58.78 175.16 4,068.48 4,021.73 -4,168.64 458.81 5,971,397.82 386,062.68 1.93 3,746.00 MWD+IFR-AK-CAZ-SC(4) 6,270.93 59.50 175.41 4,117.66 4,070.91 -4,250.67 465.58 5,971,315.71 386,068.20 0.78 3,818.48 MWD+IFR-AK-CAZ-SC(4) 6,366.61 58.79 172.49 4,166.74 4,119.99 -4,332.33 474.22 5,971,233.93 386,075.60 2.72 3,891.68 MWD+IFR-AK-CAZ-SC(4) 6,462.34 58.07 171.02 4,216.86 4,170.11 -4,413.05 485.92 5,971,153.05 386,086.06 1.51 3,965.74 MWD+IFR-AK-CAZ-SC(4) 6,556.45 57.97 170.71 4,266.70 4,219.95 -4,491.86 498.59 5,971,074.06 386,097.53 0.30 4,038.74 MWD+IFR-AK-CAZ-SC(4) 6,653.80 58.18 170.96 4,318.18 4,271.43 -4,573.43 511.75 5,970,992.30 386,109.44 0.31 4,114.32 MWD+IFR-AK-CAZ-SC(4) 6,749.06 56.96 169.21 4,369.27 4,322.52 -4,652.63 525.58 5,970,912.91 386,122.06 2.01 4,188.28 MWD+IFR-AK-CAZ-SC(4) 6,845.28 57.19 168.44 4,421.57 4,374.82 -4,731.86 541.24 5,970,833.45 386,136.51 0.71 4,263.25 MWD+IFR-AK-CAZ-SC(4) 6,939.74 56.65 169.50 4,473.12 4,426.37 -4,809.55 556.38 5,970,755.55 386,150.46 1.10 4,336.65 MWD+IFR-AK-CAZ-SC(4) 7,033.28 56.05 170.06 4,524.96 4,478.21 -4,886.18 570.20 5,970,678.73 386,163.11 0.81 4,408.45 MWD+IFR-AK-CAZ-SC(4) 7,132.80 56.46 171.45 4,580.24 4,533.49 -4,967.85 583.49 5,970,596.87 386,175.15 1.23 4,484.18 MWD+IFR-AK-CAZ-SC(4) 7,229.51 58.51 172.28 4,632.22 4,585.47 -5,048.58 595.02 5,970,515.98 386,185.45 2.24 4,558.17 MWD+IFR-AK-CAZ-SC(4) 7,324.34 56.97 172.83 4,682.84 4,636.09 -5,128.09 605.42 5,970,436.33 386,194.63 1.70 4,630.51 MWD+IFR-AK-CAZ-SC(4) 7,419.80 56.50 172.53 4,735.20 4,688.45 -5,207.26 615.59 5,970,357.02 386,203.59 0.56 4,702.45 MWD+IFR-AK-CAZ-SC(4) 7,515.63 56.97 173.20 4,787.76 4,741.01 -5,286.76 625.54 5,970,277.38 386,212.33 0.76 4,774.55 MWD+IFR-AK-CAZ-SC(4) 7,611.36 57.70 172.98 4,839.43 4,792.68 -5,366.77 635.23 5,970,197.24 386,220.80 0.79 4,846.92 MWD+IFR-AK-CAZ-SC(4) 7,707.25 58.06 173.57 4,890.42 4,843.67 -5,447.42 644.74 5,970,116.46 386,229.08 0.64 4,919.74 MWD+IFR-AK-CAZ-SC(4) 7,802.95 56.90 173.37 4,941.86 4,895.11 -5,527.59 653.92 5,970,036.17 386,237.03 1.22 4,991.98 MWD+IFR-AK-CAZ-SC(4) 3/23/2012 10:44:37AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-48 Project: Western North Slope TVD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Site: CD1 Alpine Pad MD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Well: CD1-48 North Reference: True Wellbore: CD1-48A Survey Calculation Method: Minimum Curvature Design: CD1-48A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 7,898.84 57.32 172.46 4,993.93 4,947.18 -5,607.49 663.85 5,969,956.13 386,245.74 0.91 5,064.40 MWD+IFR-AK-CAZ-SC(4) 7,994.26 57.09 172.37 5,045.62 4,998.87 -5,687.00 674.44 5,969,876.47 386,255.11 0.25 5,136.85 MWD+IFR-AK-CAZ-SC(4) 8,089.96 57.48 171.73 5,097.34 5,050.59 -5,766.75 685.58 5,969,796.58 386,265.03 0.69 5,209.79 MWD+IFR-AK-CAZ-SC(4) 8,186.05 56.94 172.00 5,149.38 5,102.63 -5,846.71 697.01 5,969,716.45 386,275.24 0.61 5,283.09 MWD+IFR-AK-CAZ-SC(4) 8,281.78 56.05 171.88 5,202.22 5,155.47 -5,925.75 708.20 5,969,637.26 386,285.23 0.94 5,355.46 MWD+IFR-AK-CAZ-SC(4) 8,376.19 56.54 171.70 5,254.61 5,207.86 -6,003.48 719.42 5,969,559.37 386,295.26 0.54 5,426.77 MWD+IFR-AK-CAZ-SC(4) 8,471.71 56.73 173.70 5,307.15 5,260.40 -6,082.61 729.55 5,969,480.11 386,304.18 1.76 5,498.65 MWD+IFR-AK-CAZ-SC(4) 8,566.92 58.06 174.07 5,358.45 5,311.70 -6,162.35 738.09 5,969,400.25 386,311.51 1.43 5,570.18 MWD+IFR-AK-CAZ-SC(4) 8,663.49 57.60 172.76 5,409.87 5,363.12 -6,243.56 747.46 5,969,318.92 386,319.64 1.24 5,643.38 MWD+IFR-AK-CAZ-SC(4) 8,758.84 57.77 171.65 5,460.84 5,414.09 -6,323.39 758.39 5,969,238.93 386,329.35 1.00 5,716.29 MWD+IFR-AK-CAZ-SC(4) I 8,851.87 57.05 171.14 5,510.95 5,464.20 -6,400.89 770.12 5,969,161.27 386,339.89 0.90 5,787.68 MWD+IFR-AK-CAZ-SC(4) 8,947.33 57.53 170.56 5,562.54 5,515.79 -6,480.19 782.89 5,969,081.79 386,351.45 0.72 5,861.14 MWD+IFR-AK-CAZ-SC(4) 9,044.89 57.02 171.38 5,615.28 5,568.53 -6,561.25 795.78 5,969,000.56 386,363.09 0.88 5,936.13 MWD+IFR-AK-CAZ-SC(4) 9,138.64 56.44 172.95 5,666.71 5,619.96 -6,638.89 806.46 5,968,922.76 386,372.60 1.53 6,007.08 MWD+IFR-AK-CAZ-SC(4) 9,236.19 58.07 174.04 5,719.47 5,672.72 -6,720.41 815.75 5,968,841.12 386,380.64 1.92 6,080.50 MWD+IFR-AK-CAZ-SC(4) 9,331.76 57.49 174.54 5,770.43 5,723.68 -6,800.86 823.80 5,968,760.57 386,387.46 0.75 6,152.35 MWD+IFR-AK-CAZ-SC(4) 9,427.52 57.99 174.69 5,821.54 5,774.79 -6,881.48 831.40 5,968,679.85 386,393.82 0.54 6,224.11 MWD+IFR-AK-CAZ-SC(4) 9,524.33 57.03 175.76 5,873.54 5,826.79 -6,962.85 838.20 5,968,598.39 386,399.38 1.36 6,296.05 MWD+IFR-AK-CAZ-SC(4) 9,619.62 57.48 176.37 5,925.09 5,878.34 -7,042.81 843.70 5,968,518.36 386,403.66 0.72 6,366.11 MWD+IFR-AK-CAZ-SC(4) 9,715.63 57.25 174.71 5,976.87 5,930.12 -7,123.41 849.98 5,968,437.68 386,408.72 1.48 6,437.13 MWD+IFR-AK-CAZ-SC(4) 9,810.73 56.22 174.65 6,029.03 5,982.28 -7,202.59 857.35 5,968,358.41 386,414.88 1.08 6,507.55 MWD+IFR-AK-CAZ-SC(4) 9,906.73 56.84 173.39 6,081.97 6,035.22 -7,282.23 865.70 5,968,278.66 386,422.01 1.27 6,578.88 MWD+IFR-AK-CAZ-SC(4) 10,002.55 56.12 172.35 6,134.89 6,088.14 -7,361.49 875.61 5,968,199.26 386,430.71 1.18 6,650.76 MWD+IFR-AK-CAZ-SC(4) 10,098.48 58.45 173.16 6,186.73 6,139.98 -7,441.55 885.78 5,968,119.05 386,439.66 2.53 6,723.44 MWD+IFR-AK-CAZ-SC(4) 10,194.15 58.49 172.21 6,236.76 6,190.01 -7,522.44 896.17 5,968,038.03 386,448.81 0.85 6,796.93 MWD+IFR-AK-CAZ-SC(4) 10,289.10 55.93 171.56 6,288.18 6,241.43 -7,601.45 907.43 5,967,958.86 386,458.86 2.76 6,869.33 MWD+IFR-AK-CAZ-SC(4) 10,385.04 54.64 172.59 6,342.82 6,296.07 -7,679.56 918.30 5,967,880.61 386,468.54 1.61 6,940.76 MWD+IFR-AK-CAZ-SC(4) 10,480.28 56.12 172.41 6,396.93 6,350.18 -7,757.26 928.54 5,967,802.76 386,477.59 1.56 7,011.50 MWD+IFR-AK-CAZ-SC(4) 10,576.07 57.04 171.66 6,449.68 6,402.93 -7,836.44 939.62 5,967,723.43 386,487.46 1.16 7,083.94 MWD+IFR-AK-CAZ-SC(4) 10,672.03 56.75 170.39 6,502.10 6,455.35 -7,915.83 952.15 5,967,643.86 386,498.79 1.15 7,157.36 MWD+IFR-AK-CAZ-SC(4) 10,766.38 55.85 172.63 6,554.45 6,507.70 -7,993.46 963.75 5,967,566.07 386,509.19 2.19 7,228.77 MWD+IFR-AK-CAZ-SC(4) 10,861.71 56.14 174.30 6,607.77 6,561.02 -8,071.97 972.74 5,967,487.44 386,516.99 1.48 7,299.51 MWD+IFR-AK-CAZ-SC(4) 10,957.35 56.87 172.34 6,660.55 6,613.80 -8,151.18 982.02 5,967,408.11 386,525.06 1.87 7,371.00 MWD+IFR-AK-CAZ-SC(4) 11,051.64 57.11 173.34 6,711.92 6,665.17 -8,229.63 991.88 5,967,329.52 386,533.72 0.93 7,442.16 MWD+IFR-AK-CAZ-SC(4) 11,148.50 57.34 172.54 6,764.35 6,717.60 -8,310.45 1,001.89 5,967,248.56 386,542.49 0.73 7,515.40 MWD+IFR-AK-CAZ-SC(4) 11,243.83 57.27 172.62 6,815.85 6,769.10 -8,390.00 1,012.25 5,967,168.87 386,551.64 0.10 7,587.76 MWD+IFR-AK-CAZ-SC(4) 11,339.81 59.57 171.53 6,866.11 6,819.36 -8,470.98 1,023.53 5,967,087.74 386,561.68 2.58 7,661.82 MWD+IFR-AK-CAZ-SC(4) 11,435.57 63.63 170.72 6,911.65 6,864.90 -8,554.19 1,036.54 5,967,004.35 386,573.41 4.30 7,738.68 MWD+IFR-AK-CAZ-SC(4) 11,529.12 67.24 168.68 6,950.53 6,903.78 -8,637.87 1,051.77 5,966,920.44 386,587.37 4.34 7,817.16 MWD+IFR-AK-CAZ-SC(4) 11,581.21 68.38 165.81 6,970.21 6,923.46 -8,684.91 1,062.42 5,966,873.26 386,597.30 5.55 7,862.41 MWD+IFR-AK-CAZ-SC(4) 3/23/2012 10:44:37AM Page 5 COMPASS 2003.16 Build 69 .... .. ..._.. . . . ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-48 Project: Western North Slope TVD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Site: CD1 Alpine Pad MD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Well: CD1-48 North Reference: True Wellbore: CD1-48A Survey Calculation Method: Minimum Curvature Design: CD1-48A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (01100) (ft) Survey Tool Name 11,626.05 70.37 164.40 6,986.01 6,939.26 -8,725.46 1,073.21 5,966,832.55 386,607.47 5.33 7,902.30 MWD+IFR-AK-CAZ-SC(4) 11,671.15 72.30 163.61 7,000.44 6,953.69 -8,766.53 1,084.98 5,966,791.31 386,618.61 4.59 7,943.16 MWD+IFR-AK-CAZ-SC(4) 11,723.54 74.36 162.85 7,015.47 6,968.72 -8,814.58 1,099.46 5,966,743.05 386,632.36 4.17 7,991.34 MWD+IFR-AK-CAZ-SC(4) 11,819.58 76.88 161.70 7,039.32 6,992.57 -8,903.19 1,127.79 5,966,654.03 386,659.33 2.87 8,081.08 MWD+IFR-AK-CAZ-SC(4) 11,915.28 78.89 159.48 7,059.40 7,012.65 -8,991.42 1,158.89 5,966,565.33 386,689.07 3.09 8,172.02 MWD+IFR-AK-CAZ-SC(4) 11,966.53 81.18 157.39 7,068.27 7,021.52 -9,038.36 1,177.44 5,966,518.12 386,706.91 6.01 8,221.49 MWD+IFR-AK-CAZ-SC(4) 12,010.94 83.33 156.73 7,074.26 7,027.51 -9,078.88 1,194.59 5,966,477.35 386,723.44 5.06 8,264.81 MWD+IFR-AK-CAZ-SC(4) 12,057.79 83.33 154.82 7,079.70 7,032.95 -9,121.31 1,213.69 5,966,434.63 386,741.88 4.05 8,310.80 MWD+IFR-AK-CAZ-SC(4) 12,106.38 83.33 153.77 7,085.34 7,038.59 -9,164.80 1,234.62 5,966,390.84 386,762.14 2.15 8,358.67 MWD+IFR-AK-CAZ-SC(4) 12,202.81 84.88 154.29 7,095.25 7,048.50 -9,251.03 1,276.62 5,966,303.98 386,802.82 1.69 8,453.86 MWD+IFR-AK-CAZ-SC(4) 12,298.19 85.50 153.23 7,103.24 7,056.49 -9,336.28 1,318.64 5,966,218.11 386,843.54 1.28 8,548.25 MWD+IFR-AK-CAZ-SC(4) 12,325.00 85.75 152.85 7,105.29 7,058.54 -9,360.11 1,330.76 5,966,194.10 386,855.29 1.69 8,574.83 MWD+IFR-AK-CAZ-SC(5) 12,408.06 86.72 153.18 7,110.74 7,063.99 -9,433.96 1,368.37 5,966,119.69 386,891.76 1.23 8,657.25 MWD+IFR-AK-CAZ-SC(5) 12,501.80 86.53 153.56 7,116.26 7,069.51 -9,517.61 1,410.31 5,966,035.42 386,932.42 0.45 8,750.25 MWD+IFR-AK-CAZ-SC(5) 12,546.01 86.35 155.10 7,119.01 7,072.26 -9,557.38 1,429.42 5,965,995.36 386,950.93 3.50 8,794.01 MWD+IFR-AK-CAZ-SC(5) 12,595.69 87.28 158.29 7,121.77 7,075.02 -9,602.93 1,449.05 5,965,949.52 386,969.85 6.68 8,842.90 MWD+IFR-AK-CAZ-SC(5) 12,641.20 87.46 160.64 7,123.86 7,077.11 -9,645.50 1,464.99 5,965,906.72 386,985.14 5.17 8,887.29 MWD+IFR-AK-CAZ-SC(5) 12,689.00 87.83 162.82 7,125.82 7,079.07 -9,690.85 1,479.96 5,965,861.15 386,999.42 4.62 8,933.48 MWD+IFR-AK-CAZ-SC(5) 12,737.07 88.45 166.37 7,127.38 7,080.63 -9,737.16 1,492.72 5,965,814.65 387,011.47 7.49 8,979.27 MWD+IFR-AK-CAZ-SC(5) 12,784.17 90.43 169.17 7,127.84 7,081.09 -9,783.18 1,502.70 5,965,768.49 387,020.74 7.28 9,023.30 MWD+IFR-AK-CAZ-SC(5) 12,877.95 89.56 172.64 7,127.85 7,081.10 -9,875.77 1,517.52 5,965,675.70 387,034.15 3.81 9,109.02 MWD+IFR-AK-CAZ-SC(5) 12,971.34 92.22 179.45 7,126.40 7,079.65 -9,968.86 1,523.96 5,965,582.52 387,039.17 7.83 9,190.60 MWD+IFR-AK-CAZ-SC(5) 13,013.71 92.53 178.99 7,124.64 7,077.89 -10,011.19 1,524.53 5,965,540.19 387,039.10 1.31 9,226.41 MWD+IFR-AK-CAZ-SC(5) 13,065.02 91.48 178.60 7,122.85 7,076.10 -10,062.46 1,525.61 5,965,488.92 387,039.39 2.18 9,270.00 MWD+IFR-AK-CAZ-SC(5) 13,159.20 89.32 178.25 7,122.19 7,075.44 -10,156.59 1,528.20 5,965,394.77 387,040.55 2.32 9,350.36 MWD+IFR-AK-CAZ-SC(5) 13,252.07 89.01 176.26 7,123.54 7,076.79 -10,249.34 1,532.65 5,965,301.97 387,043.58 2.17 9,430.56 MWD+IFR-AK-CAZ-SC(5) 13,347.00 88.58 172.65 7,125.54 7,078.79 -10,343.79 1,541.82 5,965,207.40 387,051.30 3.83 9,514.77 MWD+IFR-AK-CAZ-SC(5) 13,442.17 88.70 167.02 7,127.80 7,081.05 -10,437.40 1,558.60 5,965,113.55 387,066.66 5.92 9,602.42 MWD+IFR-AK-CAZ-SC(5) 13,488.99 89.25 164.62 7,128.64 7,081.89 -10,482.79 1,570.07 5,965,068.00 387,077.43 5.26 9,646.73 MWD+IFR-AK-CAZ-SC(5) 13,535.36 89.50 162.31 7,129.15 7,082.40 -10,527.23 1,583.26 5,965,023.36 387,089.94 5.01 9,691.19 MWD+IFR-AK-CAZ-SC(5) 13,629.61 88.02 158.66 7,131.19 7,084.44 -10,616.03 1,614.73 5,964,934.10 387,120.05 4.18 9,782.80 MWD+IFR-AK-CAZ-SC(5) 13,723.05 89.69 155.93 7,133.05 7,086.30 -10,702.20 1,650.79 5,964,847.40 387,154.79 3.42 9,874.71 MWD+IFR-AK-CAZ-SC(5) 13,817.42 89.38 153.17 7,133.82 7,087.07 -10,787.40 1,691.34 5,964,761.60 387,194.03 2.94 9,968.25 MWD+IFR-AK-CAZ-SC(5) 13,910.88 90.24 151.56 7,134.13 7,087.38 -10,870.20 1,734.69 5,964,678.16 387,236.11 1.95 10,061.29 MWD+IFR-AK-CAZ-SC(5) 14,004.84 89.50 149.54 7,134.34 7,087.59 -10,952.01 1,780.88 5,964,595.66 387,281.04 2.29 10,155.07 MWD+IFR-AK-CAZ-SC(5) 14,098.50 89.19 146.28 7,135.41 7,088.66 -11,031.35 1,830.63 5,964,515.58 387,329.57 3.50 10,248.69 MWD+IFR-AK-CAZ-SC(5) 14,191.93 88.76 143.04 7,137.08 7,090.33 -11,107.54 1,884.65 5,964,438.58 387,382.42 3.50 10,342.02 MWD+IFR-AK-CAZ-SC(5) 14,286.37 88.95 141.86 7,138.97 7,092.22 -11,182.39 1,942.20 5,964,362.86 387,438.81 1.27 10,436.14 MWD+IFR-AK-CAZ-SC(5) 14,379.38 89.99 141.81 7,139.83 7,093.08 -11,255.52 1,999.67 5,964,288.87 387,495.16 1.12 10,528.77 MWD+IFR-AK-CAZ-SC(5) 14,474.88 91.60 145.46 7,138.51 7,091.76 -11,332.40 2,056.28 5,964,211.15 387,550.58 4.18 10,624.08 MWD+IFR-AK-CAZ-SC(5) 3/23/2012 10:44:37AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-48 Project: Western North Slope TVD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Site: CD1 Alpine Pad MD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Well: CD1-48 North Reference: True Wellbore: CD1-48A Survey Calculation Method: Minimum Curvature Design: CD1-48A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,567.90 92.22 144.47 7,135.41 7,088.66 -11,408.52 2,109.65 5,964,134.23 387,602.78 1.26 10,716.98 MWD+IFR-AK-CAZ-SC(5) 14,661.84 92.22 142.32 7,131.77 7,085.02 -11,483.87 2,165.62 5,964,058.04 387,657.59 2.29 10,810.66 MWD+IFR-AK-CAZ-SC(5) 14,757.27 91.11 139.95 7,128.99 7,082.24 -11,558.13 2,225.47 5,963,982.87 387,716.30 2.74 10,905.54 MWD+IFR-AK-CAZ-SC(5) 14,850.49 90.92 138.57 7,127.34 7,080.59 -11,628.75 2,286.29 5,963,911.34 387,776.03 1.49 10,997.90 MWD+IFR-AK-CAZ-SC(5) 14,943.52 89.07 140.89 7,127.35 7,080.60 -11,699.73 2,346.42 5,963,839.47 387,835.07 3.19 11,090.17 MWD+IFR-AK-CAZ-SC(5) 15,038.50 89.19 144.12 7,128.79 7,082.04 -11,775.07 2,404.22 5,963,763.26 387,891.71 3.40 11,184.83 MWD+IFR-AK-CAZ-SC(5) 15,131.46 91.11 146.48 7,128.55 7,081.80 -11,851.48 2,457.13 5,963,686.05 387,943.44 3.27 11,277.74 MWD+IFR-AK-CAZ-SC(5) 15,224.58 91.66 147.83 7,126.30 7,079.55 -11,929.69 2,507.62 5,963,607.09 387,992.73 1.57 11,370.83 MWD+IFR-AK-CAZ-SC(5) 15,316.98 91.79 148.85 7,123.52 7,076.77 -12,008.30 2,556.10 5,963,527.75 388,040.00 1.11 11,463.16 MWD+IFR-AK-CAZ-SC(5) 15,410.51 90.68 145.06 7,121.50 7,074.75 -12,086.67 2,607.08 5,963,448.62 388,089.77 4.22 11,556.65 MWD+IFR-AK-CAZ-SC(5) 15,504.94 90.00 138.45 7,120.94 7,074.19 -12,160.79 2,665.50 5,963,373.63 388,147.05 7.04 11,650.63 MWD+IFR-AK-CAZ-SC(5) 15,550.64 89.38 135.96 7,121.19 7,074.44 -12,194.32 2,696.54 5,963,339.63 388,177.58 5.61 11,695.66 MWD+IFR-AK-CAZ-SC(5) 15,598.58 89.32 135.86 7,121.73 7,074.98 -12,228.75 2,729.90 5,963,304.70 388,210.40 0.24 11,742.70 MWD+IFR-AK-CAZ-SC(5) 15,693.09 88.88 140.97 7,123.22 7,076.47 -12,299.41 2,792.60 5,963,233.10 388,272.01 5.43 11,836.11 MWD+IFR-AK-CAZ-SC(5) 15,738.02 89.75 144.41 7,123.75 7,077.00 -12,335.14 2,819.83 5,963,196.96 388,298.69 7.90 11,880.91 MWD+IFR-AK-CAZ-SC(5) 15,787.69 89.99 147.16 7,123.87 7,077.12 -12,376.21 2,847.75 5,963,155.48 388,325.98 5.56 11,930.56 MWD+IFR-AK-CAZ-SC(5) 15,839.03 90.00 146.19 7,123.87 7,077.12 -12,419.11 2,875.96 5,963,112.16 388,353.53 1.89 11,981.90 MWD+IFR-AK-CAZ-SC(5) 15,881.00 90.49 144.87 7,123.69 7,076.94 -12,453.71 2,899.71 5,963,077.20 388,376.75 3.35 12,023.85 MWD+IFR-AK-CAZ-SC(5) 15,974.87 90.00 146.36 7,123.29 7,076.54 -12,531.17 2,952.72 5,962,998.94 388,428.57 1.67 12,117.69 MWD+IFR-AK-CAZ-SC(5) 16,069.84 90.43 145.86 7,122.93 7,076.18 -12,610.00 3,005.68 5,962,919.32 388,480.31 0.69 12,212.65 MWD+IFR-AK-CAZ-SC(5) 16,164.97 89.44 145.32 7,123.04 7,076.29 -12,688.49 3,059.44 5,962,840.03 388,532.86 1.19 12,307.75 MWD+IFR-AK-CAZ-SC(5) 16,258.01 90.12 146.53 7,123.40 7,076.65 -12,765.55 3,111.56 5,962,762.19 388,583.80 1.49 12,400.77 MWD+IFR-AK-CAZ-SC(5) 16,352.25 91.04 148.55 7,122.45 7,075.70 -12,845.06 3,162.14 5,962,681.93 388,633.15 2.36 12,494.99 MWD+IFR-AK-CAZ-SC(5) 16,446.71 90.67 146.32 7,121.04 7,074.29 -12,924.65 3,212.97 5,962,601.57 388,682.76 2.39 12,589.43 MWD+IFR-AK-CAZ-SC(5) 16,541.71 89.38 142.28 7,120.99 7,074.24 -13,001.78 3,268.39 5,962,523.61 388,737.00 4.46 12,684.31 MWD+IFR-AK-CAZ-SC(5) 16,635.87 87.59 142.53 7,123.48 7,076.73 -13,076.36 3,325.82 5,962,448.17 388,793.27 1.92 12,778.13 MWD+IFR-AK-CAZ-SC(5) 16,730.57 89.75 144.96 7,125.68 7,078.93 -13,152.70 3,381.80 5,962,371.00 388,848.08 3.43 12,872.64 MWD+IFR-AK-CAZ-SC(5) 16,825.03 89.56 148.15 7,126.25 7,079.50 -13,231.50 3,433.85 5,962,291.42 388,898.92 3.38 12,967.08 MWD+IFR-AK-CAZ-SC(5) 16,917.58 89.99 150.61 7,126.61 7,079.86 -13,311.14 3,480.99 5,962,211.07 388,944.83 2.70 13,059.54 MWD+IFR-AK-CAZ-SC(5) 17,011.48 90.37 152.60 7,126.32 7,079.57 -13,393.74 3,525.64 5,962,127.81 388,988.21 2.16 13,153.13 MWD+IFR-AK-CAZ-SC(5) 17,104.89 91.35 153.97 7,124.92 7,078.17 -13,477.17 3,567.62 5,962,043.76 389,028.92 1.80 13,245.97 MWD+IFR-AK-CAZ-SC(5) 17,198.92 90.86 153.37 7,123.10 7,076.35 -13,561.42 3,609.32 5,961,958.89 389,069.32 0.82 13,339.34 MWD+IFR-AK-CAZ-SC(5) 17,245.95 90.92 152.41 7,122.37 7,075.62 -13,603.28 3,630.75 5,961,916.71 389,090.11 2.04 13,386.12 MWD+IFR-AK-CAZ-SC(5) 17,292.36 90.80 151.61 7,121.68 7,074.93 -13,644.26 3,652.53 5,961,875.41 389,111.26 1.74 13,432.35 MWD+IFR-AK-CAZ-SC(5) 17,386.24 91.17 149.44 7,120.06 7,073.31 -13,725.97 3,698.71 5,961,793.01 389,156.19 2.34 13,526.03 MWD+IFR-AK-CAZ-SC(5) 17,479.41 91.42 147.13 7,117.96 7,071.21 -13,805.20 3,747.67 5,961,713.05 389,203.93 2.49 13,619.15 MWD+IFR-AK-CAZ-SC(5) 17,573.84 90.68 144.73 7,116.23 7,069.48 -13,883.40 3,800.56 5,961,634.05 389,255.62 2.66 13,713.54 MWD+IFR-AK-CAZ-SC(5) 17,667.58 86.85 143.09 7,118.25 7,071.50 -13,959.12 3,855.75 5,961,557.51 389,309.64 4.44 13,807.10 MWD+I F R-AK-CAZ-SC(5) 17,761.47 86.35 142.21 7,123.81 7,077.06 -14,033.63 3,912.61 5,961,482.15 389,365.35 1.08 13,900.55 MWD+IFR-AK-CAZ-SC(5) 17,855.18 83.69 140.21 7,131.95 7,085.20 -14,106.38 3,971.09 5,961,408.52 389,422.71 3.55 13,993.42 MWD+IFR-AK-CAZ-SC(5) 3/23/2012 10:44:37AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-48 Project: Western North Slope TVD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Site: CD1 Alpine Pad MD Reference: D141:19.50+27.25 @ 46.75ft(Doyon 141) Well: CD1-48 North Reference: True Wellbore: CD1-48A Survey Calculation Method: Minimum Curvature Design:" CD1-48A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 17,949.00 83.06 138.96 7,142.77 7,096.02 -14,177.34 4,031.51 5,961,336.66 389,482.03 1.48 14,085.83 MWD+IFR-AK-CAZ-SC(5) 18,043.86 82.75 138.95 7,154.49 7,107.74 -14,248.33 4,093.32 5,961,264.74 389,542.75 0.33 14,179.04 MWD+IFR-AK-CAZ-SC(5) 18,112.00 82.75 138.95 7,163.09 7,116.34 -14,299.31 4,137.71 5,961,213.09 389,586.35 0.00 14,245.97 PROJECTED to TD 3/23/2012 10:44:37AM Page 8 COMPASS 2003.16 Build 69 STATE OF ALASKA AU OIL AND GAS CONSERVATION COM, 3ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Fbrforations r Ibrforate r Other E, Alter Casing r Pull Tubing r Stimulate-Frac 17 Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r .., 212-004 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20592-01 '" Q 0 7. Property Dgsignation(Lease Number): 8.Well Name and Number: ADL 372096,372097,025559 4 CD1-48A 9. Los(List logs andsubmit electronic and printed data per 20AAC25.071): Field/Pool(s):10. none Colville River Field/Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 18112 feet Plugs(measured) None true vertical 7163 feet Junk(measured) None Effective Depth measured 17420 feet Packer(measured) 12089 true vertical 7118 feet (true vertucal 7083 Casing Length Size MD TVD Burst Collapse Conductor 86' 16" 114 114 Surface 3132 9.625" 3160 2440 Intermediate 12375 7" 12403 7111 Liner 5332 4.5" 17420 7119 RECEIVED MAY 072012 Perforation depth: Measured depth: 13080'-17371' True Vertical Depth: 7121'-7121' AOGCC Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 12135 MD, 7088 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER HRD ZXP LINER TOP PACKER @ 12089 MD and 7083 ND SSSV-CAMCO TRMAXX-5E SSSV @ 2427 MD and 2000 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13080'-17371'MD Treatment descriptions including volumes used and final pressure: pumped 896,000#of 16/20 carbolite,final pressure=4000 psi 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 4222 4021 489 -- 330 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ a Service r Stratigraphic r 16.Well Status after work: Oil 17 19 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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: 312-114 Contact T Senden @ 265-1544 Printed Nam T'.Seni n Title Staff Wells Engineer Signature In \ \ Phone:265-1544 Date 5/, 12 6 Form 10-404 Revised 11/2WPM MAY 0 7 2012 *' Submit Original Only CD1-48A Well Work Summary DATE SUMMARY 4/11/12 POLLED B&R @ 11,650' RKL JLLED SOV AND SET SPG @ 11,504' RI—. TEST IA TO 3500 PSI, GOOD. PULLED RHC BODY @ 11,650' RKB. SET FRAC SLEEVE @ 2427' RKB. READY FOR FRAC. ****SPG PROGRAMED FOR 1 SEC SAMPLES STARTING @ 11:57 04-11-12 4/17/12 PUMPED MULTI STAGE ALPINE"C" SAND FRAC. PUMPED A TOTAL OF19.1.Q0.0 LBS OF 16/20 CARBOLITE WITH 870,000 LBS BEHIND PIPE, FRAC PUMPED TO 95% ED SIGN. SCREENED OUT DURING THE 6.5 PPG STAGE WITH 6.5 PPG SLURRY FROM THE FRAC SLEEVE AT 13,080'TO SURFACE LEAVING 26.000#OF PROPANT IN THE TUBING. 4/20/12 PERFORMED A POST FRAC FCO, HEAVY SAND RETURNS FROM SURFACE TO TAG AT 13,078' CTMD, 1:1 RETURNS THROUGH OUT THE JOB, 25 BBLS OF SAND IN THE OT, RUN#2 RIH TO 2418' CTMD AND PULLED THE FRAC SLEEVE, F/P THE TUBING TO 4000' CTMD, JOB IN PROGRESS 4/21/12 RU CTU, MILLED OUT 3 FRAC PORT STATIONS @ 13,077', 14,083' & 14924' CTMD, CONTINUED TO RIH AND CLEANED DOWN TO 15,188' CTMD, F/P TUBING TO 6000'. JOB COMPLETE 4/23/12 ATTEMPT TO DRIFT TBG TO 2.77"TO 11650' RKB. UNABLE TO PASS 1050' SLM DUE TO HYDRATES, RD DOWN SLICKLINE FOR THE NIGHT. RU LRS, PUMP 5 BBLS OF METHANOL CHASED WITH 30 BBLS OF HOT CRUDE, JOB IN PROGRESS. 4/24/12 DRIFT TBG TO 2.77"TO 11658' SLM (UNABLE TO PASS). DRIFT TBG w/2.5" DD BAILER TO 12067' SLM. STOPPED FALLING DUE TO 83 DEG DEV. **NO SAMPLE**. PULLED HES-SPG @ 11503' RKB. REPLACED WITH 1/4" HIGH FLOW ORIFICE. PULLED DV @ 9019' RKB. REPLACED w/3/16" GLV(TRO= 1989). IN PROGRESS. 4/25/12 PULL DV @ 5006' RKB. REPLACED WITH 3/16"GLV(TRO= 1948). PULLED RHC PLUG BODY @ 11650' RKB. SET FRAC SLEEVE (OAL= 57"/MIN ID=2.31") @ 2427' RKB.VERIFIED SSSV ISOLATED WITH FLAPPER CHECKER. READY FOR FLOW BACK. WNS CD1-48A ConocoPhillips • Well Attributes Max Angle&MD TD Alaska,Ins, 0°' 'S. Wellbore API/UWI Field Name Well Status Incl(1 MD(ttKB) Act Btm(ttKB) ealomFl,ier, 501032059201 ALPINE PROD 9253 13,013.71 18,112.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP Last WO: 3/23/2012 8.50 2/15/2009 Well Conag:HORIZONTAL-CD1-48,4/26/2012 12.17:16 PM Schematic-Actual Annotation Depth(ttKB) End Date Annotation Last Mod...End Date Last Tag:SLM 11,703.0 7/22/2011 Rev Reason:GLV C/O ninam 4/26/2012 Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER.23 % CONDUCTOR 16 15.250 28.0 108.0 108.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 27.7 3,159.9 2,395.2 36.00 J-55 BTC _ Casing Description 'String 0... String ID...Top(ttKB) Set Depth(8...Set Depth(ND)...String Wt...String...String Top Thrd ' 9 INTERMEDIATE 7 6.276 27.5 12,403.0 7,110.5 26.00 L-80 BTCM I' Casing Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(ND)...---String Wt...String...String Top Thrd LINER 41/2 3.958 12,088.5 17,4200 7,119.3 12.60 L-80 Hyd 563 Liner Details 1 Top Depth 11 13 (ND) Top Incl Nomi... Top(ftKB) MB) 1`) Item Description Comment ID(in) CONDUCTOR. 12,088.5 7,083.2 83.04 PACKER BAKER HRD ZXP LINER TOP PACKER 4.350 z61oe 12,108.5 7,085.6 83.36 NIPPLE BAKER RS NIPPLE 4.350 12,111.4 7,085.9 83.41 HANGER BAKER FLEX LOCK LINER HANGER 4.350 12,122.0 7,087.1 83.58 SBE BAKER 80-40 20'SEAL BORE EXTENSION 4.000 ® 12,236.9 7,097.8 84.93 NIPPLE HES XN NIPPLE 2.813 SAFETY VLV. _ 2.427 N l 12,497.0 7,116.0 86.55 Swell Packer TAM SWELL PACKER w/5.875"CEMENTRALIZERS 3.958 SLEEVE,2,427 I TI I,I 12,596.4 7,121.6 87.11 Swell Packer TAM SWELL PACKER w/5.875"CEMENTRALIZERS 3.958 13,080.4 7,121.6 89.58 FRAC PORT BALL ACTUATED FRAC SLEEVE w/2.073"SEAT FOR 2.125"BALL 2.125 13,600.9 7,129.9 87.51 Swell Packer TAM SWELL PACKER#3 FREECAP FSC-14 w/5.875 3.958 CEMENTRALIZERS 14,086.0 7,135.2 89.23 FRAC PORT BAKER BALL-ACTUATED FRAC SLEEVE w/2.011"SEAT FOR 2.063" 2.063 BALL SURFACE. 14,610.7 7,133.8 92.22 Swell Packer TAM SWELL PACKER#2,FREECAP-I FSC-14 w/2.875" 3.958 28-3,180 CEMETRALIZERS 14,927.2 7,127.1 89.05 FRAC PORT BAKER BALL-ACTUATED FRAC SLEEVE w/1.948"SEAT FOR 2.00" 2.000 GAS LIFT, . BALL 8 5,00 15,241.6 7,127.1 92.69 Swell Packer TAM SWELL PACKER#1,FREECAP-I FSC-14 w/5.875" 3.958 / CEMENTRALIZERS Tubing Strings Tubing Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING4.5"x3.5" 31/2 2.992 23.3 12,134.6 7,088.4 9.30 L-80 EUE8RD Completion Details Top Depth )TVD) Top Incl Nomi... I Top(ttKB) (ftKB) (") Rem Description Comment ID(in) 1 23.3 23.3 -0.05 HANGER FMC TUBING HANGER 4.500 GAS L UT,9 133.3 133.3 0.46 XO Reducing CROSSOVER 4.5",12.6#,L-80 x 3.5" 2.992 9. 01 ":12,426.8 2,000.1 56.53 SAFETY VLV CAMCO TRMAXX-5E w/2.817'X PROFILE w/1.4"CONTROL LINE 2.812 11,650.4 6,993.8 71.41 NIPPLE HES X NIPPLE 2.813 12,035.6 7,077.1 83.33 GAUGE CAMCO SOLID GAUGE MANDREL 2.867 12,093.0 7,083.7 83.11 LOCATOR BAKER UPPER LOCATOR 2.990 [ 12,123.1 7,087.2 83.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY w/FULL MULE SHOE 2.990 GAS LIFT. _F 1/504 ' In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth sa )TVD) Top Incl Top(ttKB) (ttKB) (") Description Comment _ Run Date ID(in) 2,427 2,000.2 56.53 SLEEVE FRAC SLEEVE SET IN TRDP(OAL=57")-PRE FRAC 4/11/2012 2.265 NIPPLE,11,650 IlOil s Perforations&Slots Shot Top(ND) Btm(ND) Dans Top(ttKB)She(ttKB) (MB) (ttKB) 13,080 13,084 7,121.6 7,121.6 Zone Date OR- Type Comment 3/18/2012 1.0 PERFP Frac Port-Single 4"slot/FRAC Port 14,086 14,089 7,135.2 7,135.3 3/18/2012 1.0 PERFP Frac Port-Single 4"slot/FRAC Port 14,927 14,931 7,127.1 7,127.1 3/18/2012 1.0 PERFP Frac Port-Single 4"slot/FRAC Port GAUGE,12.036 '' 15,534 15,539 7,121.1 7,121.1 3/18/2012 1.0 PERFP Pre-Perfdpup jtw/6 ea 1/2"holes Ell 15,821 15,826 7,123.8 7,123.8 3/18/2012 1.0 PERFP Pre-Per?dpup jtw/6 ea117'holes 16,106 16,111 7,122.0 7,122.1 3/18/2012 1.0 PERFP Pre-Perfdpop jtw/6ea1/2'holes 16,391 16,395 7,121.9 7,121.8 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea 1/7'holes 16,717 16,722 7,125.6 7,125.6 3/18/2012 1.0 PERFP Pre-Perfd pup jt w/6 ea 1/2"holes • 17,044 17,049 7,126.7 7,126.5 3/18/2012 1.0 PERFP Pre-Perld pup jt w/6 e 1/2"holes tittl.,� #'t u 17,366 17,371 7,120.5 7,120.4 3/18/2012 1.0'PERFP Pre-Perfd tw/6 ea 1/2"holes LOCATOR pup 1'_.093 I Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth )TVD) (ND) (ttKB) (ttKB) (ttKB) (ftKB) Type Date Comment 13,080.0 17,371.0 7,121.6 7,121.6 FRAC 4/17/2012 PUMPED 16/20CARBOLITE Mandrel Details Top Depth Top Port SEAL ASSY, _ )TVD) Incl OD Valve Latch Size TRO Run 12,123 r Stn Top(MB) (ftKB) 1") Make Model (in) Sery Type Type (In) (psi) Run Date Com... 1 5,006.4 3,408.6 55.12 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188.1,948.0 4/25/2012 2 9,019.3 5,601.4 57.18'CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,989.0 4/24/2012 3 11,503.8 6,940.5 66.68 CAMCO KBMG 1 GAS LIFT OV BK-5 0.250 0.0 4/24/2012 NTERMEDIATE, 28-12,403 TD(CD2-48), 16,335 LINER, 12,08617,420 HALLIBURTON Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska April 11, 2012 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue,Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD1-48A AK-MW-0009110181 CD1-48A 50-103-20592-01 2" x 5" MD GAMMA RAY/RESISTIVITY Logs: 1 Color Log V- 2" x 5"TVD GAMMA RAY/RESISTIVITY Logs: 1 Color Log �- Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD Rom A1Li3q PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant@halliburton.com Benjamin.Schulze@halliburton.com Date: 1) 4 13- Signed: SEAN PARNELL, GOVERNOR A11e&M L ®111W LBLID333 W.7th AVENUE,SUITE 100 CIDIMIIi IlITEICIIORT CODUUBOf Gev ANCHORAGE.ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Ty Senden Staff Wells Engineer 0 ConocoPhillips Alaska, Inc. f 0 P.O. Box 100360 c . I d` Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD1-48A Sundry Number: 312-114 Dear Mr. Senden: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • fir.. F'i Cathy it'. Foe ster . Chair DATEDthis A s day of March, 2012. Encl. STATE OF ALASKA 00S 3 /Z / 7 Z AL A OIL AND GAS CONSERVATION COMM. .ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stipulate p - Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r , Exploratory r 2120040 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20592-01 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r CD1-48A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372096,372097,025559 Colville River Field/Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 18112 7163 17420' 7118' tt- ._._.____ • Casing Length Size MD TVD ; Burst �ColTt?"--1--- Conductor 86' 16" 114' 114' i R ECEIVF D Surface 3132' 9.625" 3160' 2399' Air Intermediate 12366' 7" 12403' 7119' J MAR 27 ��p2 Production 5332' 4.5" 17420' 7118' I`�'Cil Gas Cons. Commission Ancdturaye Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 15534'-17371' 7121'-7121' 3.5 L-80 12135 Packers and SSSV Type: ;Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER LINER TOP PACKER MD=12088 TVD=7082 PACKER-5 TAM PACKERS MD=12497,12596,13601,14611,15242 TVD=7116,7122,7130,7133,7125 SSSV-CAMCO TRMAXX-5E MD=2427 TVD=2000 12.Attachments: Description Summary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development rI Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/5/2012 Oil r/ Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Senden©265-1544 Printed Nam T Send Title: Staff Wells Engineer Signature Phone:265-1544 Date 3/211414, Commission Use Only Sundry Number: Z.-(( 4 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /6 _jj©L� l I ( APPROVED BY Q Approved by: P COMMISSIONER THE COMMISSION Date: 3 -Z —(Z- 0 ,L Eb-eLiefJM 2A'N2 2012 Submit_/L Submit in Duplicate l t' 3 RIGINAl Overview: CD1-48A was recently re-drilled in the Alpine formation with hybrid completion. 3 Baker Frac- Point ball drop ports are above 7 perforated pups spaced out in the lower part of the wellbore. ✓ fracs will be placed along the lateral. Intermediate String: 2/2/2009: Test lines to 3,000 psi. Bleed off pressure and begin cementing 2nd stage. Pump 20 bbl CW100, 25 bbl Mud Push II and 39 bbl of 15.8 ppg, Class'G'cement. Pump closing plug. Begin displacement with 20 bbl water from cementing unit. Switch over to rig and stage pump rate up to 5 bpm. Bump plug at 2,300 strokes at 230 psi. Pressure up to 1,450 psi and close port collar. Bleed pressure off. 0.5 bbl returns. Rig down cementing equipment. Lay down landing joint. Pull thin wear ring. Conduct 9-5/8"x 7"annular leak off test with 9.8 drilling mud. Formation leaked off at roughly ,/ 650 psi. Flush annulus with 300 bbl fresh water. 2/4/2009: Perform LOT to 12.3 ppg EMW. Called engineer in town to confirm drilling ahead okay. Pre-Frac Procedure: 1. Pull BPV. 2. Pull Shear out valve from bottom mandrel. 3. Replace shear out valve with Side Pocket Gauge. 4. Pressure test IA to 3500 psi (hold 1500 psi on the tubing during test) 5. Pressure test tubing to 3500 psi. 6. Pull ball/rod and RHC plug body from lower nipple. 7. Set frac sleeve across the SSSV profile. Procedure: 1. MIRU sixteen (16)clean insulated frac tanks with a berm surrounding the tanks that holds a single tank volume plus 10%. Load tanks with -470 seawater from the injection system (approximately 7100 bbls are required for the treatment). 2. Rig up Schlumberger equipment and stab Stinger Tree Saver. 3. Pressure test surface lines to 6500 psi 4. Pump the 200 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at-20 BPM with a maximum expected pressure of-5500 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment. 1. 220 bbls YF125ST Pad 2. 100 bbls YF125ST w/2 ppa 16/20 Carbolite 3. 400 bbls YF125ST w/4 ppa 16/20 Carbolite 4. 300 bbls YF125ST w/6 ppa 16/20 Carbolite 5. Drop 24 Bioballs 6. 260 bbls YF125ST Pad 7. 120 bbls YF125ST w/2 ppa 16/20 Carbolite 8. 480 bbls YF125ST w/4 ppa 16/20 Carbolite 9. 340 bbls YF125ST w/6 ppa 16/20 Carbolite 10. Drop 2.0" Frac Ball 11. 460 bbls YF125ST Pad 12. 120 bbls YF125ST w/2 ppa 16/20 Carbolite 13. 440 bbls YF125ST w/4 ppa 16/20 Carbolite 14. 640 bbls YF125ST w/6 ppa 16/20 Carbolite 15. Drop 2.063" Frac 16. Repeat stages 11 —14 . 17. Drop 2.125" Frac Ball 18. 611 bbls YF125ST Pad 19. 140 bbls YF125ST w/2 ppa 16/20 Carbolite 20. 700 bbls YF125ST w/4 ppa 16/20 Carbolite 21. 700 bbls YF125ST w/6 ppa 16/20 Carbolite 22. Flush with linear fluid and freeze protect 4-'6Total Sand: 920,000 lbs. 14-- 6. . Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. 8. FCO if required with slick diesel. Colville River Field CD1-48A WP04 Alpine C Production Well Completion 16"Conductor to 81' Upper Completion .M_ TM 1)Tubing Hanger 2)4-% 12.6#/ft IBT-M Tubing(2 jts), 4-1/2" 12.6# L-80 IBT-M 3) XO 4-% 12.6#IBT-M x 3-'/z"9.3#EUE-8rd-M L-80 O tubing to 108'MD 4)Camco 3.5"TRMAXX-5E SSSV w/2.812"X profile(57°) 2400' 2000' with control line to surface. Cannon Cross-coupling clamps on every joint Frac sleeve to be run off-rig will have a 2.31"ID 5)3-1/2 x 1 Camco KBMG GLM w/DV 55° 4985' 3400' 6)3-'/z x 1 Camco KBMG GLM w/DV 57° 9009' 5600' 9-5/8"40#L-80 BTC 7)3-% X 1"Camco KBMG GLM w/DCK2 65° 11480' 6935' ' Surface Casing Pinned for 2500 psi casing to tbg shear @ 3159'MD/2399 TVD 8)HES 2.813"X-Profile w/RHC plug body 70° 11630' 6992' cemented to surface O GL _j 9)SLB Bottom Hole Pressure Gauge 11967' 7075' Encapsulated I-Wire w/Cannon clamps on every joint. Calculated TOC @ 10)BOT 80-40 GBH locator 83°(18 ft seal travel fully inserted) 12057' 7087' 500'MD above top of Qannik Lower Completion Qannik Interval 11)Baker 5"X 7"HRD ZXP Liner top Packer (°) 12086' 7091' 6098'MD/4032'TVD/57° Baker 5"RS Nipple Hyd 521 box x box O 0! to 6160' MD/4065'TVD/58° Baker 5"x 7"Flex Lock Liner Hanger TSH-521 (°) 12108' 7093' Sub 5"Hyd 521 box x box Baker 80-40 20'x 4"ID Seal Bore Extension Hydril 521 PxP 12119' 7095' HES 7"Cementer (Avg.Seal Bore Length 19 ft) @ 6655'MD XO 5"Hydril 521 Box x 4-1/2"TSH-563 pin 12)4-Y2",12.6#/ft,TSH-563 Tubing 13) HES 2.813"XN with 2.666"NoGo(87°) 12233' 7098' 14)Freecap I FSC-14 5.75"OD Swell Packer -12500'MD w/5.875"OD Cementralizer O GL J 15)Freecap I FSC-14 5.75"OD Swell Packer -12600'MD w/5.875"OD Cementralizer Wellbore Deviation 16)Ball Actuated Sleeve(2.073"Seat for 2.125"Ball) -13080'MD 60° @ 11350'MD 17)Freecap I FSC-14 5.75"OD Swell Packer -13600'MD 65° @ 11480'MD w/5.875"OD Cementralizer 70° @ 11630'MD 18)Ball Actuated Sleeve(2.011"Seat for 2.063"Ball) -14100'MD 71 @ 11650 MD 19)Freecap I FSC-14 5.75"OD Swell Packer -14600'MD 75° @ 11765'MD w/5.875"OD Cementralizer 20)Ball Actuated Sleeve(1.948"Seat for 2.000"Ball) -14900'MD \\ 21)Freecap I FSC-14 5.75"OD Swell Packer -15240'MD w/5.875"OD Cementralizer ', •••• 22) XO 4-'/I,12.6#/ft,TSH-563 x IBT-M 3-1/2" 9.3#L-80 EUE-M 23)4-Y2", 12.6#/ft,IBT-M w/ Pre-Perforated Pups O 24)4-'/2 IBT-M Orange Peel -17400 7120' Calc TUG CuO 9070'MD/6018'TVD \ s 0 . � �o Top Kuparuk C ' \ 'i 6-1/8 Hole TD 11394'MD/ 6893' ' is @ 18112'MD/ TVD/64° O 7119'TVD Top Alpine C E ° :I 6 IED : scifol jj ft - 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 C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-48A ConocoPhillips Alaska, Inc. Permit No: 212-004 Surface Location: 558.8' FNL, 3036' FEL, SEC. 5, Ti1 N, R5E Bottomhole Location: 4525.6' FNL, 4029.2' FEL, SEC. 16, T11N, R5E Dear Mr. Alvord: Enclosed is the approved application for permit to re-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, 0 ,/I Daniel T. Seamount, Jr. F J Chair DATED this -) day of January, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA / VED AL A OIL AND GAS CONSERVATION COMMI )N r ':; A I PERMIT TO DRILLj II 2012 20 AAC 25.005 la.Type of Work: . 1 b.Proposed Well Class: Development-Oil Q . Service- Winj ❑ Single Zone Q. 1 c.Specify if well is pro osed for: Drill ❑ Redrill Q Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ' H 1 ates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 CD1-48A . 3.Address: 6.Proposed Depth: . 12.Field/Pool(s): P.O.Box 100369 Anchorage,AK 99510-0360 MD: 18363 . TVD: 7118 Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 558.8 FNL 3036 FEL Sec 5 T11 N R5E ` ADL 372096,372097,025559 ' Ailpine Oil Pool - Sidetrack point 8.Land Use Permit: 13.Approximate Spud Date: 4638.7 FNL 1736.6 FEL Sec 8 T11 N R5E ADL N/A 1-Feb-12 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4525.6 FNL 4029.2 FEL Sec 16 T11 N R5E 2560 2 miles from Apline PA 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 47.5 feet 15.Distance to Nearest Well Open Surface: x-385,667 • y- 5,975,572 • Zone-4 GL Elevation above MSL: - 19.5 feet to Same Pool: CD1-229PB1, 1,151' 16.Deviated wells: Kickoff depth: 12325 feet - 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3000 Surface: 2283 . 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole ' Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6.125 N/A- NIA- NIA- N/A N/A 32- 32-- 18,363 7,118 Open hole /SLpTTE/' 4.iher q•S" it.G Molt. 7x41 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 16,388 7,128 16,388 7,128 Casing Length Size Cement Volume MD TVD Conductor/Structural 76.0' 16.0" Pre-Installed 114.0' 114.0' Surface 3,123' 9.625" 395bbls Lead/39bbls Tail 3,160' 2,440' Intermediate 12,366' 7.0" 39bbls for each stages respectively, 12,403.0' 7,111' Open hole 3,985' 6.125" N/A 16,388' 7,128' Perforation Depth MD(ft): None Perforation Depth TVD(ft): None 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 5-Jan-12 22. I hereby certify that the foregoing is true and correct. Contact Weifeng Dai @ 907-263-4324 Printed Name C.Alvord Title Alaska Drilling Manager Signature �+/-(/� (,`�j Phone L -(o(2_,v7 Date ill 12_0(d..12_0(d.....l ✓✓✓ """/A/ Commission Use Only Permit to DrillAPI Number: ..--7 ,--z--..,:(7: - / Permit Approv�I See cover letter for other Number: 27v C �_. 50-/� -7 %`;7,,z-6` Date: I\`�`\� requirements. Conditions of approval: If box is checked,wellmaynot`be used to explore for,test,or produce coalbed meths e,gas hydrates,or gas contained in shale Other: T 3SOO s z- 4SC� (GS( Samples req'd: YeE1 N� Mud log req'd: Ye❑ P[t� I H2S measures: Yeilj NcEr Directional svy req'd: Ye[ NG //7 5// ....4eAPPROVED BY THE COMMISSION DATE: `�� ,COMMISSIONER Form 10-401(Revised 7/2009) This permit is valid for 24 h €:\ Iltikclattof 1pproval(20 AAC 25.005(g)) Submit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 INV Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 January 5th, 2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 RIFeVFD I Anchorage, Alaska 99501 JAN 1 0 2012 Alaska Liu as ipr�n�. iorrxnission Application lication for Permit to Re-Enter and Re-Drill CD1-48/ CD1-48A alask Dear Commissioner: ConocoPhillips Alaska Inc. hereby applies for a permit to re-enter and sidetrack the CD1-48 producer well from the CD1 drilling pad. This well, originally drilled in February 2009, has been unable to flow crude due to suspected formation collapse since August 2011. The expected spud date for this well is around February 1st, 2012 conducting operations with Doyon Rig 141. Prior to Doyon 141 rig move to CD1-48, pre-rig work includes pump kill weight brine, cut inner mandrel of premier production packer, set pump open plug, conduct MIT for tubing and production casing integrity. When Doyon 141 rig move onto CD1-48 well, the proposed plan is to de-complete the well and set bridge plug at +1- 12,368' and test, then set whipstock in 7" casing at +1- 12,325'and mill out window. Re-drill a new 6.125" horizontal lateral section as replacement well for the original one in the same Alpine sandstone. This new CD1-48A well is planned to parallel the original wellbore roughly 200 ft to the west, reaching a planned TD of 18,363 ft MD. Please find attached the information required by 20 AAC 25.005 (a) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Weifeng Dai at 263- 4324 or Chip Alvord at 265-6120. Sincerely, Weifeng Dai wgl` Z✓ DOA Drilling Engineer Apl m for Permit to Drill,Well CD1-48A Saved:6-Jan-12 CD1-48A Application for Permit to Drill Document 0 ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (9) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3))4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25005 (c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 5 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 5 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 5 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 6 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 (Requirements of 20 AAC 25.005 (c)(14)) 7 CD1-48A APD Page 1 of 7 OR I G I A L Printed:6-Jan-12 Apr m for Permit to Drill,Well CD1-48A Saved:6-Jan-12 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Proposed Well Schematic 7 CD1-48A APD Page 2 of 7 OR ! I N A L Printed:6-Jan-12 Api in for Permit to Drill,Well CD1-48A Saved:6-Jan-12 1. Well Name (Requirements of 20 AAC 25.005(() The well for which this application is submitted will be designated as CD1-48A. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 558.8 FNL 3036 FEL Sec 5 T11N R5E • NAD 1927 RKB Elevation 47.5'AMSL Northings: 5,975,319.91 Eastings: 1,525,700.32 — Pad Elevation 19.5'AMSL . Location at Sidetrack Point 4638.7 FNL 1736.6 FEL Sec 8 T11N R5E Nad 1927 Measured Depth, RKB: 12,325' Northings: 5,965,942.01 Eastings: 1,526,887.26 Total Vertical Depth,RKB: 7,106' Total Vertical Depth, SS: 7,058' Location at Total Depth 4525.6 FNL 4029.2 FEL Sec 16 T11N R5E Nad 1927 Measured Depth,RKB: 18,363' Northings: 5,960,731.67 Eastings: 1,529,812.15 Total Vertical Depth,RKB: 7,118' ' Total Vertical Depth, SS: 7,071' CD1-48A APD Page 3 of 7 d`e p d A I Printed:6-Jan-12 Api )n for Permit to Drill,Well CD1-48A Saved:6-Jan-12 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005©(3)) Please reference BOP schematics on file for Doyon 141. - 4. Drilling Hazards Information (Requirements of 20AAC25.005cob The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Csg Setting Fracture Pore Casing Depth Gradient pressure ASP Size MD/TVD(ft) (lbs./ (psi) Drilling (in) gal) (psi) 16 114/ 114 10.9 52 53 9 5/8 3,160/2,440 14.5 1073 1,596 7 12,403/7,111 13 2,996 2,283 6-1/8 N/A 13 2,996 • 2,283 Open Hole • • NOTE:The Doyon 141 5000 psi BOP equipment is adequate.Test BOP to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052)—0.1]D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP—(0.1 x D) Where; FPP=Formation Pore Pressure at the next casing point ASP CALCULATIONS (C) Drilling below surface casing(9 5/8") ASP= [(FG x 0.052)—0.1]D ' =[(14.5 x 0.052)—0.1]x 2,440= 1,596 psi <� OR J ASP=FPP—(0.1 x D) =2,996—(0.1 x 7,111')=2,285 psi (C) Drilling below intermediate casing(7") ASP=FPP—(0.1 x D)=2,996—(0.1 x 7,129' =2,283 psi ' CD 1-48A APD Page 4 of 7 0 n (11\ 1 ir\ Printed:6-Jan-12 Apr Dn for Permit to Drill,Well CD1-48A Saved:6-Jan-12 (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. ©data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2—Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20 AAC 25.005©(5)) Mill out 7"casing and continue drill 20' open hole,circulate hole clean and ensure mud weight in and out equal, then conduct FIT to 12.5ppg equivalent mud weight. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005©(6)) The proposed plan is to open hole complete the well,no casing and cement job planned. 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Doyon 141. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Mineral Oil Base Mud systems having the following properties: Hole Section OBM 12,325'—18,363' Density(ppb 8.8—9.2 Plastic Viscosity 15—22 Yield Point(cP) 8— 12 HTHP Fluid Loss(ml/30min) <5 OWR 80:20 Electrical Stability(my) +1-400 Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of20AAC 25.005(c)(9)) • N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. CD 1-48A APD Page 5 of 7 Printed:6-Jan-12 $ $ $ 1 L s � Apr )n for Permit to Drill,Well CD1-48A Saved:6-Jan-12 12. Evidence of Bonding (Requirements of20AAC25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska,Inc. is on file with the Commission. . 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic. Rig Work Plan 1. MIRU Doyon 141 onto CD1-48. • 2. Pull BPV, circulate diesel out and displace well to 9.0 ppg KWF. Verify IA and tubing pressure are zero. 3. Install BPV and test to 1,000 psi in direction of flow. 4. Nipple down tree. Nipple up BOPE and test to 3,500 psi.. Clearance issues with the blanking plug prevent the lower rams from being tested at this point. CPAI requests approval for testing the lower rams after the tubing is pulled from the well. 5. Pressure up to open the pump open plug, unset packer and circulate BU. 6. Pull 3-1/2"tubing and packer. 7. RIH clean out assembly with casing scraper to 7"casing shoe at+/- 12,403' MD. 8. POOH with assembly and pick up bridge plug. ConocoPhillips would like to request a waiver to AAC25.112 Well plugging requirements. �� 9. RIH to set bridge plug at+/- 12, 368' MD mid joint. 10. Test 7"casing and retainer to 3,500 psi for 30 mins. Record on chart. 11. Run and set top of whipstock at+/- 12,325', mill out window exit 7"casing. / 12. Drill 6-1/8" horizontal section to well TD of 18,363' MD/7,118'TVD. 13. Circulate hole clean and pull out of hole. 14. Run 4-1/2", 12.6 ppf, L-80 TSH and IBT-M perforated liner to TD, set liner and liner top packer. .T/is 15. Run upper completion string, displace well to kill weight brine. Stab seal assembles in seal bore as well 13 setting tubing hanger in well head housing. 16. Drop the Ball & Rod assembly, pressure test tubing and annulus to 3,500 psi respectively. 17. Pressure test hanger seals to 5000 psi, Install 2 way check and test from direction of flow to 3,000 psi. Nipple down BOP. 18. Install tubing head adapter assembly and tree. Pressure test adapter assembly and tree to 5000 psi. 19. Remove 2 way check valve. 20. Freeze protection in tubing&IA. 21. Install BPV and test in direction of flow to 1,000 psi, secure well. CD 1-48A APD Page 6 of 7 r Printed:6-Jan-12 tit AR Dn for Permit to Drill,Well CD1-48A Saved:6-Jan-12 22. Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) A majority of the fluid needs will be supported by the M-I SWACO mud plant in Deadhorse. The Alpine • mixing plant will be utilized if a well control issue or lost circulation situation occurs. The M-I SWACO Alpine Injection Skid at CD1-19A will be used for all liquid drilling wastes (Class I & II - approved). The Kuparuk Class II injection well can also be utilized if needed (1R-18). 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic A CD1-48A APD ' I Page 7 of 7 p t Printed:6-Jan-12 Api m for Permit to Drill,Well CD1-48A Saved:6-Jan-12 Attachment 1—Directional Plan ORIGINAL I ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad CD1-48 Plan: CD1-48A 60R toolface kick-off. Lower doglegs than wp03, Plan: CD1-48Awp04 but a little more directional work. Stay about 200' to the west of the existing lateral. Extended TD about a 1000' south of that for wp02. Standard Proposal Report permit Pacic 05 January, 2012 lof 01 HALLIBURTON • • Sperry Drilling Services ORIGINAL Northing (5000 ft/in) 1 1 1 1 1 1 1 1 1 1 I mliiiiliiiiIiiiiIiiiil 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 N O - - N i'_■ _ _ co _ 7 - C - - — _ ON _ Q O —.- d O - F m 0 -- U _ a O 3 • el - U v - m ❑ Q_ N N- - 'Cr CO — - co - 0 d - ilk ❑ _ ❑ U - CO p — U — o ❑•,- 1:0‘- p v U7 a) illU -o p — U { NO _ -0 N 9,Ail 0 10 0 C A- _ V - ir U I /. , � 77.0V U _ OMil O �` . `Uan - U ❑ C - N N �� ./ pii;€l) ; (sj 44 'le ,,,"19(7).07..„... 01215 rh n U ❑ \.... ,''! U_ - N a) - - 0 • ❑ ❑ • nrn 0 N - LO Tco iii1', ge rU 8141". "''.• U iii. 1-* n - ■c. 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Ln - -p !pO OO 0p 0 p °sempNop o 0 ! x - u,NpcaOO O <- v O O O OO O _ � CO O W o 00 O ,O O NM U C1� _ O N M 03 N x 4114. x h. pp 0 O O CL O) N Q O CO -O VI in I QO 0 o N- , 0 0o O o o O O O o O O O Lo O In O in O N In N- O N (u!/14. 5Q.. /f-)1 I , cp o -o 1CD1-48Awp04 (6 m x N 1 8363 4 o 18000 — IN NM N- / 17000 Co O 1000 0 0 1-5-000 V/ 14000 —o 00006 ; S 0 0 00026 i r o o N 000 09 -0 0 << 0 0 0000 M .— co it, 000x 6 i 0 0 o U 0 0008 0 0 CO QO 6 Ol 45 Tr O0c O O o00 . 0. Q. s 000 . n o Q _o 000800 N Tr p 000e O N 0 ,.3 x -o V co 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N co co (u!/TI 00061 pal ripA anal ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD1-48 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Site: CD1 Alpine Pad North Reference: True Well: CD1-48 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-48A Design: CD1-48Awp04 Project Western North Slope 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 CD1 Alpine Pad Site Position: Northing: 761.93ft Latitude: 53°45'41.229 N' From: Map Easting: -1,140,637.87ft Longitude: 157°35'23.034 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -6.11° Well CD1-48 Well Position +NI-S 0.00 ft Northing: 5,975,572.62ft Latitude: 70°20'31.604 N +E/-W 0.00 ft Easting: 385,667.53 ft Longitude: 150°55'40.432 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore Plan:CD1-48A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 12/19/2011 15.87 79.77 57,334 Design CD1-48Awp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,325.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 147.00 [Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (0) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 12,325.00 85.75 152.85 7,105.98 7,058.48 -9,359.44 1,330.42 0.00 0.00 0.00 0.00 12,337.60 86.72 154.52 7,106.81 7,059.31 -9,370.71 1,335.99 15.24 7.63 13.22 60.00 12,374.60 86.72 154.52 7,108.93 7,061.43 -9,404.05 1,351.89 0.00 0.00 0.00 0.00 12,474.60 87.50 157.42 7,113.98 7,066.48 -9,495.26 1,392.55 3.00 0.78 2.90 75.00 12,669.60 87.71 163.27 7,122.14 7,074.64 -9,678.66 1,458.06 3.00 0.11 3.00 88.00 13,063.01 90.13 170.00 7,129.55 7,082.05 -10,061.10 1,548.91 1.82 0.61 1.71 70.33 13,213.01 90.13 170.00 7,129.21 7,081.71 -10,208.82 1,574.96 0.00 0.00 0.00 0.00 14,213.01 90.12 145.00 7,127.01 7,079.51 -11,125.39 1,954.62 2.50 0.00 -2.50 -90.00 18,363.00 90.12 145.00 7,118.48 7,070.98 -14,524.85 4,334.95 0.00 0.00 0.00 0.00 1/5/2012 3:41:54PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD1-48 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Site: CD1 Alpine Pad North Reference: True Well: CD1-48 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-48A Design: CD1-48Awp04 Planned Survey 1 i Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-$ +E/-W Northing Easting DLS Vert Section I (ft) (°) C°) (ft) ft (ft) (ft) (ft) (ft) 7,058.48 12,325.00 85.75 152.85 7,105.98 7,058.48 -9,359.44 1,330.42 5,966,194.78 386,854.96 1.74 8,574.09 TOW:DLS 15.24 TFO 60.00 12,337.60 ' 86.72 154.52 7,106.81 7,059.31 -9,370.71 1,335.99 5,966,183.42 386,860.36 15.24 8,586.57 BOW:37 hold at 12337.60 MD-7"x 8-3/4" 12,374.60 86.72 154.52 7,108.93 7,061.43 -9,404.05 1,351.89 5,966,149.84 386,875.74 0.00 8,623.19 Start DLS 3.00 TFO 75.00 12,400.00 86.91 155.26 7,110.34 7,062.84 -9,427.02 1,362.65 5,966,126.72 386,886.15 3.00 8,648.31 12,474.60 87.50 157.42 7,113.98 7,066.48 -9,495.26 1,392.55 5,966,058.04 386,915.01 3.00 8,721.83 Start DLS 3.00 TFO 88.00 12,500.00 87.52 158.18 7,115.08 7,067.58 -9,518.75 1,402.14 5,966,034.40 386,924.24 3.00 8,746.76 12,600.00 87.63 161.18 7,119.31 7,071.81 -9,612.44 1,436.83 5,965,940.21 386,957.49 3.00 8,844.22 12,669.60 87.71 163.27 7,122.14 7,074.64 -9,678.66 1,458.06 5,965,873.68 386,977.70 3.00 8,911.32 Start DLS 1.82 TFO 70.33 12,700.00 87.90 163.79 7,123.30 7,075.80 -9,707.79 1,466.67 5,965,844.42 386,985.87 1.82 8,940.44 12,800.00 88.51 165.50 7,126.43 7,078.93 -9,804.17 1,493.13 5,965,747.66 387,010.86 1.82 9,035.69 12,900.00 89.13 167.21 7,128.49 7,080.99 -9,901.32 1,516.72 5,965,650.16 387,032.95 1.82 9,130.01 13,000.00 89.74 168.92 7,129.48 7,081.98 -9,999.15 1,537.39 5,965,552.04 387,052.13 1.82 9,223.32 13,063.01 90.13 170.00 7,129.55 7,082.05 -10,061.10 1,548.91 5,965,489.92 387,062.71 1.82 9,281.55 Start 150.00 hold at 13063.01 MD 13,100.00 90.13 170.00 7,129.47 7,081.97 -10,097.53 1,555.34 5,965,453.41 387,068.58 0.00 9,315.59 13,200.00 90.13 170.00 7,129.24 7,081.74 -10,196.01 1,572.70 5,965,354.68 387,084.44 0.00 9,407.64 13,213.01 90.13 170.00 7,129.21 7,081.71 -10,208.82 1,574.96 5,965,341.84 387,086.50 0.00 9,419.62 Start DLS 2.50 TFO-90.00 13,300.00 90.13 167.83 7,129.01 7,081.51 -10,294.18 1,591.69 5,965,256.24 387,101.92 2.50 9,500.32 13,400.00 90.13 165.33 7,128.79 7,081.29 -10,391.44 1,614.90 5,965,158.65 387,123.65 2.50 9,594.53 13,500.00 90.13 162.83 7,128.56 7,081.06 -10,487.59 1,642.34 5,965,062.09 387,149.61 2.50 9,690.12 13,600.00 90.13 160.33 7,128.34 7,080.84 -10,582.46 1,673.94 5,964,966.76 387,179.76 2.50 9,786.89 13,700.00 90.13 157.83 7,128.11 7,080.61 -10,675.86 1,709.65 5,964,872.84 387,214.04 2.50 9,884.67 13,800.00 90.13 155.33 7,127.89 7,080.39 -10,767.61 1,749.40 5,964,780.50 387,252.39 2.50 9,983.27 13,900.00 90.12 152.83 7,127.67 7,080.17 -10,857.54 1,793.12 5,964,689.92 387,294.72 2.50 10,082.50 14,000.00 90.12 150.33 7,127.46 7,079.96 -10,945.47 1,840.72 5,964,601.28 387,340.97 2.50 10,182.17 14,100.00 90.12 147.83 7,127.25 7,079.75 -11,031.25 1,892.10 5,964,514.73 387,391.03 2.50 10,282.10 14,200.00 90.12 145.33 7,127.04 7,079.54 -11,114.71 1,947.18 5,964,430.46 387,444.83 2.50 10,382.09 14,213.01 90.12 145.00 7,127.01 7,079.51 -11,125.39 1,954.62 5,964,419.67 387,452.10 2.50 10,395.09 Start 4149.99 hold at 14213.01 MD 14,300.00 90.12 145.00 7,126.83 7,079.33 -11,196.64 2,004.51 5,964,347.66 387,500.90 0.00 10,482.03 14,400.00 90.12 145.00 7,126.63 7,079.13 -11,278.56 2,061.87 5,964,264.89 387,556.99 0.00 10,581.97 14,500.00 90.12 145.00 7,126.42 7,078.92 -11,360.47 2,119.22 5,964,182.12 387,613.09 0.00 10,681.91 14,600.00 90.12 145.00 7,126.22 7,078.72 -11,442.39 2,176.58 5,964,099.34 387,669.19 0.00 10,781.85 14,700.00 90.12 145.00 7,126.01 7,078.51 -11,524.30 2,233.94 5,964,016.57 387,725.28 0.00 10,881.78 14,800.00 90.12 145.00 7,125.80 7,078.30 -11,606.22 2,291.30 5,963,933.80 387,781.38 0.00 10,981.72 14,900.00 90.12 145.00 7,125.60 7,078.10 -11,688.13 2,348.66 5,963,851.02 387,837.48 0.00 11,081.66 15,000.00 90.12 145.00 7,125.39 7,077.89 -11,770.05 2,406.01 5,963,768.25 387,893.58 0.00 11,181.60 15,100.00 90.12 145.00 7,125.19 7,077.69 -11,851.96 2,463.37 5,963,685.48 387,949.67 0.00 11,281.54 15,200.00 90.12 145.00 7,124.98 7,077.48 -11,933.88 2,520.73 5,963,602.70 388,005.77 0.00 11,381.48 1/5/2012 3:41:54PM Page 3 COMPASS 2003.16 Build 69 L.. ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD1-48 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Site: CD1 Alpine Pad North Reference: True Well: CD1-48 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-48A Design: CD1-48Awp04 Planned Survey I Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 7,077.28 15,300.00 90.12 145.00 7,124.78 7,077.28 -12,015.79 2,578.09 5,963,519.93 388,061.87 0.00 11,481.42 15,400.00 90.12 145.00 7,124.57 7,077.07 -12,097.71 2,635.44 5,963,437.16 388,117.96 0.00 11,581.36 15,500.00 90.12 145.00 7,124.37 7,076.87 -12,179.62 2,692.80 5,963,354.39 388,174.06 0.00 11,681.29 15,600.00 90.12 145.00 7,124.16 7,076.66 -12,261.54 2,750.16 5,963,271.61 388,230.16 0.00 11,781.23 15,700.00 90.12 145.00 7,123.95 7,076.45 -12,343.45 2,807.52 5,963,188.84 388,286.25 0.00 11,881.17 15,800.00 90.12 145.00 7,123.75 7,076.25 -12,425.37 2,864.87 5,963,106.07 388,342.35 0.00 11,981.11 15,900.00 90.12 145.00 7,123.54 7,076.04 -12,507.28 2,922.23 5,963,023.29 388,398.45 0.00 12,081.05 16,000.00 90.12 145.00 7,123.34 7,075.84 -12,589.20 2,979.59 5,962,940.52 388,454.54 0.00 12,180.99 16,100.00 90.12 145.00 7,123.13 7,075.63 -12,671.11 3,036.95 5,962,857.75 388,510.64 0.00 12,280.93 16,200.00 90.12 145.00 7,122.93 7,075.43 -12,753.03 3,094.30 5,962,774.97 388,566.74 0.00 12,380.87 16,300.00 90.12 145.00 7,122.72 7,075.22 -12,834.94 3,151.66 5,962,692.20 388,622.83 0.00 12,480.81 ' 16,400.00 90.12 145.00 7,122.51 7,075.01 -12,916.86 3,209.02 5,962,609.43 388,678.93 0.00 12,580.74 16,500.00 90.12 145.00 7,122.31 7,074.81 -12,998.77 3,266.38 5,962,526.65 388,735.03 0.00 12,680.68 16,600.00 90.12 145.00 7,122.10 7,074.60 -13,080.69 3,323.73 5,962,443.88 388,791.13 0.00 12,780.62 16,700.00 90.12 145.00 7,121.90 7,074.40 -13,162.60 3,381.09 5,962,361.11 388,847.22 0.00 12,880.56 16,800.00 90.12 145.00 7,121.69 7,074.19 -13,244.52 3,438.45 5,962,278.33 388,903.32 0.00 12,980.50 16,900.00 90.12 145.00 7,121.49 7,073.99 -13,326.43 3,495.81 5,962,195.56 388,959.42 0.00 13,080.44 17,000.00 90.12 145.00 7,121.28 7,073.78 -13,408.35 3,553.16 5,962,112.79 389,015.51 0.00 13,180.38 , 17,100.00 90.12 145.00 7,121.08 7,073.58 -13,490.26 3,610.52 5,962,030.01 389,071.61 0.00 13,280.32 17,200.00 90.12 145.00 7,120.87 7,073.37 -13,572.18 3,667.88 5,961,947.24 389,127.71 0.00 13,380.26 17,300.00 90.12 145.00 7,120.66 7,073.16 -13,654.09 3,725.24 5,961,864.47 389,183.80 0.00 13,480.19 17,400.00 90.12 145.00 7,120.46 7,072.96 -13,736.01 3,782.60 5,961,781.70 389,239.90 0.00 13,580.13 17,500.00 90.12 145.00 7,120.25 7,072.75 -13,817.92 3,839.95 5,961,698.92 389,296.00 0.00 13,680.07 i 17,600.00 90.12 145.00 7,120.05 7,072.55 -13,899.84 3,897.31 5,961,616.15 389,352.09 0.00 13,780.01 17,700.00 90.12 145.00 7,119.84 7,072.34 -13,981.75 3,954.67 5,961,533.38 389,408.19 0.00 13,879.95 17,800.00 90.12 145.00 7,119.64 7,072.14 -14,063.67 4,012.03 5,961,450.60 389,464.29 0.00 13,979.89 17,900.00 90.12 145.00 7,119.43 7,071.93 -14,145.58 4,069.38 5,961,367.83 389,520.38 0.00 14,079.83 18,000.00 90.12 145.00 7,119.22 7,071.72 -14,227.50 4,126.74 5,961,285.06 389,576.48 0.00 14,179.77 18,100.00 90.12 145.00 7,119.02 7,071.52 -14,309.41 4,184.10 5,961,202.28 389,632.58 0.00 14,279.71 18,200.00 90.12 145.00 7,118.81 7,071.31 -14,391.33 4,241.46 5,961,119.51 389,688.68 0.00 14,379.64 18,300.00 90.12 145.00 7,118.61 7,071.11 -14,473.24 4,298.81 5,961,036.74 389,744.77 0.00 14,479.58 18,363.00 90.12 145.00 7,118.48 7,070.98 -14,524.85 4,334.95 5,960,984.59 389,780.11 0.00 14,542.54 3,160.00 2,395.70 9-5/8"x 12-1/4" 9-5/8 12-1/4 12,337.60 7,106.81 7"x 8-3/4" 7 8-3/4 18,363.00 7,118.48 4-1/2"x 6-1/8" 4-1/2 6-1/8 1/5/2012 3:41.54PM Pagei4 ItiAi COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD1-48 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Project: Western North Slope MD Reference: Plan: 19.5+28 @ 47.50ft(Doyon 141) Site: CD1 Alpine Pad North Reference: True Well: CD1-48 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-48A Design: CD1-48Awp04 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 12,325.00 7,105.98 -9,359.44 1,330.42 TOW: DLS 15.24 TFO 60.00 12,337.60 7,106.81 -9,370.71 1,335.99 BOW:37 hold at 12337.60 MD 12,374.60 7,108.93 -9,404.05 1,351.89 Start DLS 3.00 TFO 75.00 12,474.60 7,113.98 -9,495.26 1,392.55 Start DLS 3.00 TFO 88.00 1 12,669.60 7,122.14 -9,678.66 1,458.06 Start DLS 1.82 TFO 70.33 13,063.01 7,129.55 -10,061.10 1,548.91 Start 150.00 hold at 13063.01 MD 13,213.01 7,129.21 -10,208.82 1,574.96 Start DLS 2.50 TFO-90.00 14,213.01 7,127.01 -11,125.39 1,954.62 Start 4149.99 hold at 14213.01 MD 18,363.00 7,118.48 -14,524.85 4,334.95 TD at 18363.00 1/5/2012 3.41:54PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL Zti m 0L ti a m 3 Jmo 0 J > aL la I a v/ a> Z £ is al N C o :ca Fa U O N • n N a)N N d O O N in _� O cu 3 co w oo �� aii O co N x ca o C L Ce V Z 2 O Ng M r 0 Z U M O p V ' y Q O N CTS00 M C T 3.L 7• C L �� co Nr.d W _ N ' a (in — - • ooc > o 0 "' 2u- 0 • c L O 1 o = C W_ ■ O Q V♦ O N O. /�� el R a •_ m M d r C LJ U tX 0 Li j kai V/ £ CO CIM o ■ N .1"-- 77, n� LT- 0aCOQ oQ d Orn Z 0_ L co O N t U co N O O m m 0 T"' Lrj Z 2.d c i6 a " N W • O N O '' ++ T. 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W CO d M Ln N • I I U c G I I `'' O pp o o U of0 N C N N J O 0 I-- - 0 gi . 0 E m c74 Ti d 111 a• OD pry ; .- C ' a Q 0 U Q O yvag �i� N_ a, 0 F a agN osaa o 1— p vava x3HB- esv o 0 In sg:ass H .0 04 raMi � x P 1 I I` L N spec 1.511g iv 0 Q 0 `c' Northing (3000 ft/in) I I I I I i i i I I 1 i i i I I I I i I i i i I leI I I i i i i I i i i I I i I I I I i 1 1 1 I I I I I i i i i I i I I I I I I I I I ii N - N - r - ; - tO _ IC - M — Ili — — LC) _ N O v C - 0 o - C O m Q co co _ O N a co C— Z Q1 co U N d U ? - U — C N _ CO - � O N O o - R W _ � U 0 M � 0 Cr) = W a N OD — — Q� .. 0 • U tro p - I 7` M V Q 1 O co — vi r O . N F 8 II CD co U) U O o _ a v Yya — e - o r‘(1) 110 a_ mc = CV OD o aEa - — I 0.....1)U — ch 0" - O - O C _ U V I IIIiiiiIiiI II II I I iI III I Ii I IIiiiiIii (u!/j1 000E) 6u!43JoN ORIGINAL HALLIBURTON ConocoPhillips CD 1 -48Awp04 Alaska Sperry Drilling ANTI-COLLISION SETTINGS 15:23,January 042012 Interpolation Method: MD, interval:25.00 Depth Range From: 12325.00 To 18363.00 Results Limited By: Centre Distance:2033.50 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 50.00 1190.00 CD1-48 Gyro(CD1-48) GYD-GC-SS 1216.05 1307.86 CD1-48 MWD(CD1-48) MWD+IFR-AK-CAZ-SC 1370.00 1463.00 CD1-48 Gyro(CD1-48) GYD-GC-SS 1540.69 12325.00 CD1-48 MWD(CD1-48) MWD+IFR-AK-CAZ-SC 12325.00 18363.00 CD1-48Awp04(Plan: CD1-48A) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2395.70 3160.00 9-5/8" x 12-1/4" 9-5/8 7106.81 12337.60 7" x 8-3/4" 7 7118.48 18363.00 4-1/2"x 6-1/8" 4-1/2 /1/ [40 - / ///J U 0 70 m C - CO U - a do- 1 12350 13000 13650 14300 14950 15600 16250 16900 Measured Depth LEGEND - CD1-229(aka ND1),CD1-229,CD1-229 V1 --X- C01-31,CD1-31 IIFR,CD7-31 IIFR V1 $- CD740,CD140,CD140 V1 -X- CD1-229(aka ND1),CD1-229PB1,CD1-229P943'4- CD1-32,CD132,CD1-32 V1 -9- CD741,CD1-41,CD1-41 V1 - CD1-229(aka NO1),Plan:CD1-29,C01-29wpG - CD1-32,CD132PB1,CD7-32PB1 V3 -9- CD141,CD7-41PB1,C0741PB7 V1 - CD1-25,C01-25,CD1-25 V1 -9- CD1-33,CD133,CD1-33 V1 -A- CD142,00742,C0142 117 - CD1-26,CD1-26,CD1-26 V1 -i- CD134,CD134,CD1-34 V1 -X- CD1-43,CD1-43,CD1-43 V7 - CD1-26,CD1-28PB1,CD1-26PB1 V1 -9- CD1-35,CD135,CD1-35 V1 -0- 00144,C0144,CD144 V1 CD1-27,CD1-27,CD1.27 V1 -9- CD1-36,CD1-36,CD1-36 VI C0144,CD1-44P87,CD144PB1 V1 - CD1-28,CD7-28,CD1-28 V1 CD1-36,CD136P8/,CD736PB1 VI -A- CD745,CD145,CD145 V1 - CD1-28,CD1-28PB1,CD1-28PB1 V1 -8- CD1.37,CD137,CD137 V5 - CD145,CD1-45PB1,CD145PB1 VI - 001-30,CD130,CD130 V1 -X- CD1-38,CD138,CD138 V1 - CD746,CD746,CD746 V4 CD1-30,CD130PB7,CD130P81 V1 -A- CD138,CD138PB1,C01-38PB1 VI -- CD1-48,CD1-48,CD1-48 VO -� CD131,CD131,CD131 V6 -A- 001-39,CD139,CD1-39 V1 -e- Plan:CD1-50,Plan:CD1-50,CD7-50wp02 VO CD131,CD1-31 CAZ,CD131 CAZ V7 -X- CD1-39,CD139P81,CD139PB1 V1J� -e- CD1-48A%p04 6 v ati 1 » O i O O B LO CJ Ie. 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X7' 444 Y T 44444 d e wgli8u98BB88uuVuuuuu8uu8u8888888888885 i J , r4““4“m ,1q4?3???5?3??4'v4;44444401 5 8888888888688888888883888688888888888le8 Oo �JlJ QL 4j QI- 1W 1W 111 �JlJ 1I{/lW �J1J 0 QI- mi8410 O O X M M 0 N ' C U ✓ C_ 3 8 mw g o 0 ro o to N N AIM `m a co or,.., - o f) aI 8 0. 1 � 8 1„ U I r o 8 0 8 0 8 2 N ; c CD > O ..., Q' g E § gl/ op ____O O u_,_ O 1 M o O ft3 . iii .l _ O c aur Q %4j 0p O U 0 ' gag ih N 01 Ce l ' d eLi g�g�Q�Q€ X8$8 0 C 0 63 d3 8aN N N 5 0 4444 "-` Q • 388888 m9 o m ip 81888 p'FF H M� a.s$ oRIGINPAL N LB CR� r REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 3 4/5/00 AJR MRT Per A00001 ACS 7 4/10/04 AG GD CA Per K04033ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC 5, T 11 N, R 5 E, UMIAT MERIDIAN Well 'Y' 'X' Lat. (N) Lonq. (W) Sec FNLLineFWL Gnd Pad CD1-1 5,975,904.92 385,999.99 70' 20' 34.922" 150' 55' 30.868" 222' 2,572' 13.0' 19.5' CD1-2 5,975,897.89 385,992.91 70' 20' 34.852" 150' 55' 31.071" 229' 2,565' 13.0' 19.5' CD1-3 5,975,890.99 385,985.82 70' 20' 34.783" 150' 55' 31.275" 236' 2,558' 13.1' 19.5' CD1-4 5,975,883.83 385,978.79 70' 20' 34.711" 150' 55' 31.478" 243' 2,551' 13.2' 19.5' CD1-5 5,975,876.67 385,971.58 70' 20' 34.640" 150' 55' 31.685" 251' 2,544' 13.3' 19.5' CD1-6 5,975,869.89 385,964.83 70' 20' 34.572" 150' 55' 31.879" 258' 2,538' 13.4' 19.5' CD1-7 5,975,862.73 385,957.33 70' 20' 34.501" 150' 55' 32.095" 265' 2,530' 13.3' 19.5' CD1-8 5,975,855.21 385,950.60 70' 20' 34.426" 150' 55' 32.288" 272' 2,523' 13.2' 19.5' CD1-9 5,975,848.42 385,943.41 70' 20' 34.358" 150' 55' 32.495" 279' 2,517' 13.1' 19.5' CD1-10 5,975,841.34 385,936.18 70' 20' 34.287" 150' 55' 32.703" 286' 2,510' 13.0' 19.5' CD1-11 5,975,834.23 385,929.27 70' 20' 34.216" 150' 55' 32.902" 294' 2,502' 12.9' 19.5' CD1-12 5,975,827.15 385,922.42 70' 20' 34.145" 150' 55' 33.099" 301' 2,496' 12.8' 19.5' CD1-13 5,975,820.00 385,915.06 70' 20' 34.074" 150' 55' 33.311" 308' 2,489' 12.7' 19.5' CD1-14 5,975,812.97 385,908.00 70' 20' 34.004" 150' 55' 33.514" 315' 2,482' 12.6' 19.5' CD1-15 5,975,805.80 385,901.08 70' 20' 33.932" 150' 55' 33.713" 323' 2,474' 12.5' 19.5' CD1-16 5,975,798.86 385,894.08 70' 20' 33.863" 150' 55' 33.914" 330' 2,468' 12.4' 19.5' CD1-17 5,975,791.81 385,886.84 70' 20' 33.793" 150' 55' 34.123" 337' 2,461' 12.3' 19.5' CD1-18 5,975,784.91 385,879.88 70' 20' 33.724" 150' 55' 34.323" 344' 2,454' 12.2' 19.5' CD1-19 5,975,777.92 385,872.81 70' 20' 33.654" 150' 55' 34.526" 351' 2,447' 12.1' 19.5' CD1-20 5,975,770.66 385,865.67 70' 20' 33.581" 150' 55' 34.732" 358' 2,440' 12.0' 19.5' CD1-21 5,975,763.76 385,858.49 70' 20' 33.512" 150' 55' 34.938" 365' 2,433' 11.9' 19.5' *CD1-22 5,975,756.46 385,851.10 70' 20' 33.440" 150' 55' 34.151" 373' 2,426' 11.9' 19.5' CD1-23 5,975,749.31 385,844.44 70' 20' 33.368" 150' 55' 35.342" 380' 2,419' 12.0' 19.5' CD1-24 5,975,742.40 385,837.30 70' 20' 33.299" 150' 55' 35.548" 387' 2.412' 12.2' 19.5' CD1-25 5,975,735.34 385,830.26 70' 20' 33.229" 150' 55' 35.750" 394' 2,405' 12.4' 19.5' CD1-26 5,975,728.10 385,823.14 70' 20' 33.156" 150' 55' 35.955" 401' 2,398' 12.6' 19.5' CD1-27 5,975,721.21 385,816.08 70' 20' 33.088" 150' 55' 36.158" 408' 2,391' 12.8' 19.5' CD1-28 5,975,714.15 385,809.10 70' 20' 33.017" 150' 55' 36.359" 416' 2,384' 13.0' 19.5' CD1-29 5,975,707.14 385,802.20 70' 20' 32.947" 150' 55' 36.558" 422' 2,377' 13.2' 19.5' CD1-30 5,975,700.17 385,794.75 70' 20' 32.877" 150' 55' 36.772" 430' 2,370' 13.4' 19.5' CD1-31 5,975,692.73 385,787.40 70' 20' 32.803" 150' 55' 36.984" 437' 2,362' 13.3' 19.5' CD1-32 5,975,685.92 385,780.68 70' 20' 32.735" 150' 55' 37.177" 444' 2.356' 13.2' 19.5' CD1-33 5,975,678.67 385,773.79 70' 20' 32.663" 150' 55' 37.375" 452' 2,349' 13.1' 19.5' CD1-34 5,975,671.88 385,766.54 70' 20' 32.595" 150' 55' 37.584" 459' 2,342' 12.9' 19.5' CD1-35 5,975,664.72 385,759.63 70' 20' 32.524" 150' 55' 37.782" 466' 2,335' 12.9' 19.5' CD1-36 5,975,657.49 385,752.52 70' 20' 32.451" 150' 55' 37.987" 473' 2,328' 12.8' 19.5' CD1-37 5,975,650.51 385,745.40 70' 20' 32.381" 150' 55' 38.191" 480' 2,321' 12.7' 19.5' CD1-38 5,975,643.79 385,738.44 70' 20' 32.315" 150' 55' 38.391" 487' 2,314' 12.6' 19.5' CD1-39 5,975,636.34 385,731.37 70' 20' 32.240" 150' 55' 38.595" 495' 2,307' 12.5' 19.5' CD1-40 5,975,629.19 385,724.32 70' 20' 32.168" 150' 55' 38.797" 502' 2,300' 12.4' 19.5' CD1-41 5,975,622.37 385,717.40 70' 20' 32.101" 150' 55' 38.997" 509' 2,293' 12.3' 19.5' CD1-42 5,975,615.01 385,710.21 70' 20' 32.027" 150' 55' 39.204" 516' 2,286' 12.2' 19.5' CD1-43 5,975,607.63 385,702.97 70' 20' 31.954" 150' 55' 39.412" 523' 2,279' 12.1' 19.5' CD1-44 5,975,600.75 385,696.00 70' 20' 31.885" 150' 55' 39.613" 531' 2,272' 12.1' 19.5' CD1-45 5,975,593.74 385,689.04 70' 20' 31.815" 150' 55' 39.813" 538' 2,265' 12.0' 19.5' CD1-46 5,975,586.84 385,681.76 70' 20' 31.746" 150' 55' 40.022" 545' 2,258' 12.2' 19.5' CD1-47 5,975,579.96 385,674.74 70' 20' 31.677" 150' 55' 40.224" 552' 2,251' 12.1' 19.5' CD1-48 5,975,572.62 385,667.53 70' 20' 31.604" 150' 55' 40.432" 559' 2,244' 12.0' 19.5' CD1-49 5,9/5,565.51 365,660.62 /0' 20' 31.533" 150' 55' 40.630' 555" 2,237' 12.0 19.5' * CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98. ALPINE MODULE:CD10 UNIT: CD ConocoPhillips ALPINE PROJECT CD1 WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK663D1 3/5/99 CE-CD10-663D1 2 OF 3 7 ORIGINAL Ar ion for Permit to Drill,Well CD1-48A Saved:6-Jan-12 Attachment 2— Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment:Detailed Risk Information for further discussion of these risks) 6-1/8"Hole Event Risk Level Mitigation Strategy Lost circulation Low , Reduced pump rates,reduced trip speeds,real time equivalent circulating density(ECD)monitoring, mud rheology,lost circulation material Hole swabbing on trips Moderate' Reduced trip speeds,mud properties,proper hole filling,pumping out of hole,real time equivalent circulating density(ECD)monitoring,weighted sweeps. Abnormal Reservoir low . Well control drills,increased mud weight.No Pressure mapped faults occur in the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices,mud scavengers Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the attachments. CD1-48A wp04 fails major risk analysis with the parent wellbore CD1-48A wp04,new lateral will separate from original lateral wellbore once kick off.A tolerable collision worksheet and evaluation has been performed on the wellbore.Besides the old lateral,the closest well to the proposed CD1-48A well path is CD1- 229PB1,the closest ellipse separation is 618.52' at 12,696'MD. Ingeneral,no significant clearance issue exist with sidetrack well plan. g Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted, although this is highly unlikely,the rig will be prepared to weight up if required. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Ap, ion for Permit to Drill,Well CD1-48A Saved:6-Jan-12 Attachment 3— Proposed Well Schematic Colville River Field CD1-48A WP04 Alpine C Production Well Completion 16"Conductor to 81' Upper Completion M9 11[2 1)Tubing Hanger ,' ::::::, 2)4-W 12.6#/ft IBT-M Tubing(2 jts), O 4-112" 12.6#L-80 IBT-M 3)XO 4-'/:"12.6#IBT-M x 3-'/:"9.3#EUE-Brd-M L-80 s -..1„..',..„...1: tubing to 108'MD 4)Camco 3.5"TRMAXX-5E SSSV w/2.812"X profile(57) 2418' 2000' with control line to surface. Cannon Cross-coupling damps on every joint Frac sleeve to be run off-rig will have a 2.31"ID Ilii Q 5)3-h"x 1"Camco KBMG GLM w/DV 55° 4985 3400' iiiii 6)3-h"x 1"Camco KBMG GLM IN/DV 57° 9009 5600' :•:: ...... 9-5/8"40#L-80 BTC 7)3-h"X 1"Camco KBMG GLM w/DCK2 65° 11480' 6935' Surface Casing Pinned for 2500 psi casing to tbg shear g 3159'MD/2399 TVD 8)HES 2.813"X-Profile w/RHC plug body 70° 11630' 6992' cemented to surface O oL 9)SLB Bottom Hole Pressure Gauge 11967' 7075' Encapsulated I-Wire w/Cannon damps on every joint. Calculated TOC @ 10)BOT 80-40 GBH locator 83° 12057' 7087' 500'MD above top of Qannik Lower Comoletlon Qannik Interval 11)Baker 5"X 7"HRD ZXP Uner top Packer(°) 12086 7091' 6098'MD/4032'TVD/57° Baker 5"RS Nipple TSH-563 BxB 0 01 to 6160'MD/4065'TVD/58° Baker 5"x 7"Flex Lock Liner Hanger TSH-563(°) 12108' 7093' r.: XO 5"Hydril 563 Box x 5"TSH-563 Box Baker 80-40 20'x 4"ID Seal Bore Extension Hydril 563 PxP 12119' 7095' HES 7"Cementer XO 5"Hydril 563 Box x 4-1/2"TSH-563 pin 6655'MD 12)4-W,12.6#/ft,TSH-563 Tubing 13) HES 2.813"XN with 2.75"NoGo(81.7°) 12161' 7099' 14)Freecap I FSC-14 575"ODSwell Packer w/5.875"OD Cementralizer -12350'MD 15)Freecap I FSC-14 575"ODSwell Packer w/5.875"OD Cementralizer -12400'MD 16)Ball Actuated Sleeve(tentative:2.073"Seat for 2.125"Ball) O or_',..1 17)Freecap I FSC-14 575"ODSwell Packer w/5.875"OD Cementralizer 18)Ball Actuated Sleeve(tentative: 2.011"Seat for 2.063"Ball) Wellbore Deviation 19)Freecap I FSC-14 5.75"ODSwell Packer w/5.875"OD Cementralizer 60° @ 11350'MD 20)XO 4-h",12.6#/ft,TSH-563 x IBT-M 65° @ 11480'MD 21)4-W,12.6#/ft,IBT-M w/Pm-Perforated Pups 70° @ 11630'MD 22)4-W IBT-M Orange Peel 18353' 7118' 71@11650'MD 75° @ 11765'MD Q 3-1/2" 9.3#L-80 EUE-M TOC O 9 Top Kuperuk C 6-1/8"Hole TD 2000' 18363'MD/ 1;1-- 11463'MD/ 6928 TVD/64° 87118'3'D Top Alpine C 1E) ZNIII ■ •.. W .. .. .... .. .. .. •::G7 12398'MD/ 7119' D!86 4- '12.6#L-80 TSH-563 x Planned window in 7" / 4-'/:"12.66 L-80 IBT-M Liner 12308'MD/7112'TVD(85.5°) (81 18353'MD/ 118'TVD CD1-48 Originial Wellbore 7"26#L-80 BTC-M Casing 12403'MD/7119'TVD(86°).,. , (ran on 1/29/2009) Bridge Plug f RIG1NAL OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST(1./WELL NAME L C/' _� PTD# 2( /Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /V/le POOL: . t` _, Off Check Box for 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 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:9/09/2011 -0a 0 i- -0 m � '0 3l 11 0m o 0 o 0) -o m 0 �• N r 3 CD -, N -0 3. 0 3om cn.co o 0 N 0 f° 0 0 o A 73 o D1 1.1). 0 = O c 7 0 j CD O CD j CD CD Zi •• N N N W W W W W W W W W W N N.) N N..) N..) N N..) Na N N O CO V 0) 01 A W N ' -, ° n CO 0) V 0) 01 A W N -, O Co 0D V 6) 01 A W N -, 0 (O CO 0) 01 A W N -> 0 V 0 16 m 0 (./) 0) 0 -0 m 0 CO CO 0 �, D �, D 0 0 0 0 0) 0 -0 D * 0 -0 -0 O O = co * * C r '0 z ,3 n 0 0 CD CD CD CD CD7' O O 7 n a p) 0. CD c 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 04 09:26:17 2012 Reel Header Service name LISTPE Date 12/04/04 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 12/04/04 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Alpine MWD/MAD LOGS WELL NAME: CD1-48A API NUMBER: 501032059201 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 04-APR-12 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: -XX-0009110181 -XX-0009110181 LOGGING ENGINEER: JOE LYMAN PAUL ORTH OPERATOR WITNESS: LARRY HILL LARRY HILL �i Ck SURFACE LOCATION t SECTION: 5 TOWNSHIP: 11N RANGE: 5E FNL: 559 FSL: FEL: 3036 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 46.75 GROUND LEVEL: 19.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6. 125 7.000 12325.0 2ND STRING 3RD STRING PRODUCTION STRING • REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . ONLY INVERT/ REVERT SECTIONS (IF ANY) GREATER THAN 30' TVD ARE PRESENTED. 3. THIS SIDETRACK EXITED CD1-48 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 12, 325'MD/7105'TVD. THE WINDOW WAS MILLED AND ABOUT 40' OF RAT HOLE WERE DRILLED DURING MWD RUN 1. ONLY ROP DATA ARE PRESENTED FOR THIS RUN. 4 . MWD RUN 2 COMPRISED DIRECTIONAL, NATURAL GAMMA RAY (PCG) WITH SCINTILLATION DETECTORS, AZIMUTHAL DEEP RESISTIVITY (ADR) , DRILL STRING DYNAMICS SENSOR (DDSr) , PRESSURE WHILE DRILLING (PWD) , AND GEO-PILOT ROTARY STEERABLE BHA (GP) . 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIRE- MENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUNS 1,2 REPRESENT WELL CD1-48A WITH API#: 50-103-20592-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 18, 112'MD/7163'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION PGGR PCG GAMMA RAY AH1P/ARH16P AVG 16 INCH 2M PHASE RESISTIVITY AH2P/ARH32P AVG 32 INCH 2M PHASE RESISTIVITY AM3P/ARM48P AVG 48 INCH 500K PHASE RESISTIVITY ADXT ADR FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1. 1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/04 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12303.5 18037.0 AH2P 12310.0 18067.0 FET 12310.5 18067.0 AM3P 12310.5 18067.0 AH1P 12311.5 18067.0 ROP 12328.5 18112.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 12328.5 12378.0 MWD 2 12378.0 18112.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD HR 4 1 68 4 2 AH1P MWD OHMM 4 1 68 8 3 AH2P MWD OHMM 4 1 68 12 4 AM3P MWD OHMM 4 1 68 16 5 GR MWD API 4 1 68 20 6 ROP MWD FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12303.5 18112 15207.8 11618 12303.5 18112 FET MWD HR 0.35 100.69 1.86989 11514 12310.5 18067 AH1P MWD OHMM 0.05 2397. 97 8. 94978 11512 12311.5 18067 AH2P MWD OHMM 0.02 5000 11.7018 11515 12310 18067 AM3P MWD OHMM 0.02 1081.35 9.19746 11514 12310.5 18067 GR MWD API 45.76 114.41 80.7603 11468 12303.5 18037 ROP MWD FPH 0.11 210. 99 101.211 11568 12328.5 18112 First Reading For Entire File 12303.5 Last Reading For Entire File 18112 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/04 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/04 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROPA 12328.5 12378.0 $ LOG HEADER DATA DATE LOGGED: 08-MAR-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 12378.0 TOP LOG INTERVAL (FT) : 12325.0 BOTTOM LOG INTERVAL (FT) : 12378.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 85.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6. 125 DRILLER'S CASING DEPTH (FT) : 12325.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.70 MUD VISCOSITY (S) : 60.0 MUD PH: MUD CHLORIDES (PPM) : 90000 FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: 151.5 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12328.5 12378 12353.3 100 12328.5 12378 ROP MWD010 FPH 0.11 37.29 8.9606 100 12328.5 12378 First Reading For Entire File 12328.5 Last Reading For Entire File 12378 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/04 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/04 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PGGR 12303.5 18037.0 AH2P 12310.0 18067.0 ADXT 12310.5 18067.0 AM3P 12310.5 18067.0 AH1P 12311.5 18067.0 ROPA 12378.5 18112.0 LOG HEADER DATA DATE LOGGED: 15-MAR-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 18112.0 TOP LOG INTERVAL (FT) : 12378.0 BOTTOM LOG INTERVAL (FT) : 18112.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 82.8 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 11680934 ADR Azimuthal Deep Resis BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.125 DRILLER'S CASING DEPTH (FT) : 12325.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.80 MUD VISCOSITY (S) : 45.0 MUD PH: 10.0 MUD CHLORIDES (PPM) : 95000 FLUID LOSS (C3) : 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.000 78.0 MUD AT MAX CIRCULATING TERMPERATURE: .490 165.2 MUD FILTRATE AT MT: 1.000 78.0 MUD CAKE AT MT: . 900 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel J • DEPT FT 4 1 68 0 1 FET MWD020 HR 4 1 68 4 2 AH1P MWD020 OHMM 4 1 68 8 3 AH2P MWD020 OHMM 4 1 68 12 4 AM3P MWD020 OHMM 4 1 68 16 5 GR MWD020 API 4 1 68 20 6 ROP MWD020 FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12303.5 18112 15207.8 11618 12303.5 18112 FET MWD020 HR 0.35 100. 69 1.86989 11514 12310.5 18067 AH1P MWD020 OHMM 0.05 2397. 97 8.94978 11512 12311.5 18067 AH2P MWD020 OHMM 0.02 5000 11.7018 11515 12310 18067 AM3P MWD020 OHMM 0.02 1081.35 9.19746 11514 12310.5 18067 GR MWD020 API 45.76 114 .41 80.7603 11468 12303.5 18037 ROP MWD020 FPH 8.34 210. 99 102.015 11468 12378.5 18112 First Reading For Entire File 12303.5 Last Reading For Entire File 18112 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/04/04 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 12/04/04 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 12/04/04 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File