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215-026
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 22059'feet 12163'feet true vertical 7548' feet None feet Effective Depth measured 22059'feet 11793, 11820', 13666' feet true vertical 7548'feet 6707', 6716', 7454' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 13707' MD 7460' TVD Packers and SSSV (type, measured and true vertical depth) 11793' MD 11820' MD 13666' MD 2113' MD 6707' TVD 6716' TVD 7454' TVD 1989' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Alpine Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 160 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: GBH-22 Seal Assembly SSSV: Camco TRMAXX-5E SSSV Mark Shulman mark.shulman@conocophillips.com (907) 263-3782Senior Well Interventions Engineer 14624-14626' 15511-15514', 16400-16402', 17286-17288', 18172-18175', 19012-19015', 19725-19728', 20442-20444', 21155-21157' 7507-7507', 7521-7521', 7524-7524', 7531-7531', 7533-7533', 7551-7551', 7544-7544', 7549-7549', 7551-7551' Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 499 Gas-Mcf MD 1048 Size 114' 873 1513579 157 267112 347 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-026 50-103-20690-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380077, ADL0384209, ADL0384211, ADL0388902 Collville River Field/ Alpine Oil Pool CRU CD4-93A 20" 13-3/8" 77' measured TVD 7" 7" Plugs Junk measured Length measured true vertical Packer Burst Collapse Intermediate Liner 2 Production 11762' 2033' 8381' Casing 6708' 7472' 4-1/2" 11796' 13820' 22039' 7548' 2772' 114'Conductor Surface Intermediate Liner 1 9-5/8" 12348' 6897'10509' 2809' 2390' TieBack Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:31 pm, Dec 19, 2024 DTTMSTART JOBTYP SUMMARYOPS 8/13/2024 ACQUIRE DATA BRUSH AND FLUSH 11,760' -11,850' SLM. RAN 16' x 3 1/2" PATCH DRIFT TO 11,900' SLM, NO ISSUES. IN PROGRESS 8/14/2024 REPAIR WELL RIG UP ELINE FOR PATCH LOWER PACKER SETTING. SET PARAGON II LOWER PACKER AT 11820'. CCL TO MID ELEMENT = 9.7', CCL STOP DEPTH = 11810.3'. JOB COMPLETE, READY FOR SLICKLINE. 8/15/2024 ACQUIRE DATA SET 3.5" TTS TEST TOOL IN LOWER PACKER @ 11,810' RKB. UNABLE TO GET PASSING CMIT. JOB IN PROGRESS. 8/16/2024 ACQUIRE DATA SET UPPER 3 1/2" PATCH ( OAL= 27' ) @ ' 11,793' RKB. PREFORM MIT- T TO 2500# W/ 3 1/2" TTS TEST TOOL IN TOP OF PATCH @ SAME. UNABLE TO OBTAIN PASSING MIT-T TEST, BUT SHOWS NO TBG X IA COMMUNICATION. PRE PSI T/I/O = 344 / 114 / 0 INT PSI T/I/O = 2614 / 116 / 0 15 MIN PSI T/I/O = 2517 / 117 / 0 30 MIN PSI T/I/O = 2454 / 117 / 0 8/24/2024 ACQUIRE DATA SET 3.5" BAIT SUB CATCHER w/ TTS STINGER ON TOP OF PATCH @ 11,793' RKB. PULL AND REPLACE GLV IN STA #1 @ 5071' RKB ( 3/16" PORT, TRO= 1900 PSI ) PULLED DMY VLV f/ STA # 2 @ 9662' RKB. JOB IN PROGRESS. 8/25/2024 ACQUIRE DATA SET 1" GLV IN STA # 2 @ 9962' RKB ( 3/16" PORT, TRO= 1850 PSI ) PULLED CATCHER @ 11,793' RKB. JOB COMPLETE. 11/29/2024 REPAIR WELL (AC EVAL) RE TIFL PASSED CD4-93A Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CD4-93A smsmith Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install New GLD CD4-93A 8/25/2024 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: smsmith Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 36.6 114.0 114.0 94.00 L-80 Welded SURFACE 13 3/8 12.42 36.8 2,808.8 2,390.2 68.00 L-80 BTCM INTERMEDIATE LINER 1 9 5/8 8.84 1,839.2 12,348.0 6,896.7 40.00 L80 BTCM WINDOW 9 5/8 8.84 11,979.0 12,000.0 6,778.8 TIE BACK 7" 7 6.28 34.1 11,796.3 6,707.8 26.00 L80 BTCM INTERMEDIATE LINER 2 7 6.28 11,787.1 13,820.0 7,472.5 26.00 L-80 Hyd 563 PRODUCTION LINER 4 1/2 3.96 13,658.2 22,039.0 7,547.9 12.60 L-80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.8 Set Depth 13,706.8 Set Depth 7,460.5 String Max No 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.8 31.8 0.00 HANGER 11.000 FMC HANGER 4 1/2" ELASTOMER FMC Alp horizont al 3.958 120.9 120.9 0.02 XO Reducing 4.500 XO, 4.5 IBTM Box x 3.5 EUE Pin 2.992 2,113.1 1,989.1 44.17 SAFTEY VLV 3.500 CAMCO TRMAXX-5E SSSV W/ 2.812" X PROFILE Camco TRMAX X-5E 2.812 5,071.2 3,434.6 62.92 GAS LIFT 3.500 CAMCO KBMG GLM CAMCO KBMG 2.920 9,662.2 5,524.1 58.90 GAS LIFT 3.500 CAMCO KBMG GLM CAMCO KBMG 2.920 11,736.1 6,685.4 67.41 GAS LIFT 3.500 CAMCO KBMG GLM CAMCO KBMG 2.920 13,349.4 7,369.8 69.58 NIPPLE 3.500 X NIPPLE W/ 2.813" PROFILE **Nipple possibly washed out** See WSR 5/30/24 X 2.813 13,613.8 7,444.9 78.46 GAUGE 3.500 CAMCO SOLID GAUGE MANDREL W/ L-WIRE Camco SGM 2.913 13,665.0 7,454.2 80.49 NO GO SUB 5.000 LOCATING SUB 3.18" FROM NOGO BOT 2.992 13,666.1 7,454.4 80.54 SEAL ASSY 3.980 GBH-22 seal assembly 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 11,793.0 6,706.6 68.78 PACKER - PATCH - UPR Lower Patch Packer- Paragon 3-1/2" PIIP (ALPP35027) Paragon PIIP 8/16/2024 1.625 11,796.0 6,707.7 68.85 SPACER PIPE 2-1/16" P-110 Spacer Pipe 8/16/2024 1.590 11,806.0 6,711.3 69.09 LEAK - TUBING LLR = 1.25BPM 7/9/2024 0.000 11,820.0 6,716.3 69.34 PACKER - PATCH - LWR Upper Patch Packer- Paragon 3-1/2" PIIP (ALPP35013) Paragon PIIP 8/14/2024 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,071.2 3,434.6 62.92 1 GAS LIFT GLV BK-5 1 1,900.0 8/24/2024 0.188 9,662.2 5,524.1 58.90 2 GAS LIFT GLV BK-5 1 1,850.0 8/25/2024 0.188 11,736.1 6,685.4 67.41 3 GAS LIFT OV BK 1 0.0 8/10/2024 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 14,624.0 14,626.4 7,507.0 7,507.0 4/7/2015 PERFP FRAC PORT 15,511.3 15,513.8 7,520.7 7,520.7 4/7/2015 PERFP FRAC PORT 16,399.9 16,402.3 7,524.1 7,524.1 4/7/2015 PERFP FRAC PORT 17,285.9 17,288.4 7,531.5 7,531.4 4/7/2015 PERFP FRAC PORT 18,172.4 18,174.9 7,533.4 7,533.3 4/7/2015 PERFP FRAC PORT 19,012.2 19,014.7 7,551.3 7,551.3 4/7/2015 PERFP FRAC PORT 19,725.3 19,727.8 7,544.4 7,544.4 4/7/2015 PERFP FRAC PORT 20,441.9 20,444.3 7,549.0 7,549.0 4/7/2015 PERFP FRAC PORT 21,155.0 21,157.4 7,550.9 7,550.9 4/7/2015 PERFP FRAC PORT Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 20,500.0 21,200.0 1 Hydraulic Fracture 4/18/2015 0.0 0.00 0.00 CD4-93A, 12/12/2024 2:48:28 PM Vertical schematic (actual) PRODUCTION LINER; 13,658.2 -22,039.0 PERFP; 21,155.0-21,157.4 Hydraulic Fracture; 20,500.0 PERFP; 20,441.9-20,444.3 PERFP; 19,725.3-19,727.8 PERFP; 19,012.2-19,014.7 Hydraulic Fracture; 16,500.0 PERFP; 18,172.4-18,174.9 PERFP; 17,285.9-17,288.4 PERFP; 16,399.9-16,402.3 Hydraulic Fracture; 14,600.0 PERFP; 15,511.3-15,513.7 PERFP; 14,624.0-14,626.4 INTERMEDIATE LINER 2; 11,787.1-13,820.0 NIPPLE; 13,349.4 7" Liner Cement; 11,787.0 ftKB INTERMEDIATE LINER 1; 1,839.2-12,348.0 WINDOW; 11,979.0-12,000.0 PACKER - PATCH - LWR; 11,820.0 SPACER PIPE; 11,796.0 LEAK - TUBING; 11,806.0 TIE BACK 7"; 34.1-11,796.3 PACKER - PATCH - UPR; 11,793.0 GAS LIFT; 11,736.1 GAS LIFT; 9,662.2 GAS LIFT; 5,071.2 SURFACE; 36.8-2,808.8 SAFTEY VLV; 2,113.1 CONDUCTOR; 36.6-114.0 HANGER; 31.8 WNS PROD KB-Grd (ft) 36.45 RR Date 11/11/201 4 Other Elev CD4-93A ... TD Act Btm (ftKB) 22,059.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032069001 Wellbore Status PROD Max Angle & MD Incl (°) 91.41 MD (ftKB) 19,392.12 WELLNAME WELLBORECD4-93A Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 16,500.0 20,500.0 1 Hydraulic Fracture 4/19/2015 0.0 0.00 0.00 14,600.0 16,500.0 1 Hydraulic Fracture 4/22/2015 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 11,787.0 13,820.0 6,704.4 7,472.5 7" Liner Cement Cemented liner from shoe @ 13,820' to TOL @ 11,787' 3/24/2015 CD4-93A, 12/12/2024 2:48:32 PM Vertical schematic (actual) PRODUCTION LINER; 13,658.2 -22,039.0 PERFP; 21,155.0-21,157.4 Hydraulic Fracture; 20,500.0 PERFP; 20,441.9-20,444.3 PERFP; 19,725.3-19,727.8 PERFP; 19,012.2-19,014.7 Hydraulic Fracture; 16,500.0 PERFP; 18,172.4-18,174.9 PERFP; 17,285.9-17,288.4 PERFP; 16,399.9-16,402.3 Hydraulic Fracture; 14,600.0 PERFP; 15,511.3-15,513.7 PERFP; 14,624.0-14,626.4 INTERMEDIATE LINER 2; 11,787.1-13,820.0 NIPPLE; 13,349.4 7" Liner Cement; 11,787.0 ftKB INTERMEDIATE LINER 1; 1,839.2-12,348.0 WINDOW; 11,979.0-12,000.0 PACKER - PATCH - LWR; 11,820.0 SPACER PIPE; 11,796.0 LEAK - TUBING; 11,806.0 TIE BACK 7"; 34.1-11,796.3 PACKER - PATCH - UPR; 11,793.0 GAS LIFT; 11,736.1 GAS LIFT; 9,662.2 GAS LIFT; 5,071.2 SURFACE; 36.8-2,808.8 SAFTEY VLV; 2,113.1 CONDUCTOR; 36.6-114.0 HANGER; 31.8 WNS PROD CD4-93A ... WELLNAME WELLBORECD4-93A Originated: Delivered to:22-Aug-24 Alaska Oil & Gas Conservation Commiss 22Aug24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 2P-429 50-103-20378-00-00 201-102 Kuparuk River WL Puncher FINAL FIELD 4-Aug-24 2P-431 50-103-20417-00-00 202-053 Kuparuk River WL Puncher FINAL FIELD 5-Aug-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Puncher FINAL FIELD 6-Aug-24 2P-422A 50-103-2040-01-00 202-067 Kuparuk River WL Puncher FINAL FIELD 7-Aug-24 2W-05 50-029-21208-00-00 184-191 Kuparuk River WL IPROF FINAL FIELD 8-Aug-24 WSW-05 50-029-20838-00-00 182-164 Kuparuk River WL Lee LDL FINAL FIELD 9-Aug-24 CD4-24 50-103-20602-00-00 209-097 Colville River WL Patch FINAL FIELD 13-Aug-24 CD4-93A 50-103-20690-01-00 215-026 Colville River WL Patch FINAL FIELD 14-Aug-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39470 T39471 T39472 T39473 T39474 T39475 T39476 T39477CD4-93A 50-103-20690-01-00 215-026 Colville River WL Patch FINAL FIELD 14-Aug-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.23 08:12:18 -08'00' Originated: Delivered to:22-Jul-24 Alaska Oil & Gas Conservation Commiss 22Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL Perf FINAL FIELD 27-Jun-24 CD2-45 50-103-20395-00-00 201-212 Colville River WL Patch FINAL FIELD 8-Jul-24 CD1-40 50-103-20298-00-00 199-044 Colville River WL LDL FINAL FIELD 10-Jul-24 CD4-24 50-103-20602-00-00 209-097 Colville River WL LDL FINAL FIELD 11-Jul-24 CD4-93A 50-103-20690-01-00 215-026 Colville River WL LDL FINAL FIELD 13-Jul-24 2W-01 50-029-21273-00-00 185-010 Kuparuk River WL LDL FINAL FIELD 16-Jul-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39255 T39256 T39257 T39258 T39259 T39260 CD4-93A 50-103-20690-01-00 215-026 Colville River WL LDL FINAL FIELD 13-Jul-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.22 10:48:54 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-06-19_22173_CRU_CD4-93A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22173 CRU CD4-93A 50-103-20690-01 Caliper Survey w/ Log Data 19-Jun-24 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 215-026 T39061 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.27 08:37:31 -08'00' • 0 0 1-1-- q3 Iry RECEIVED ConocoPhillips APR 0 6 2016 Alaska (� P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 April 4, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SCANNED APR 0 8 2016 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 February 8, 2016. The corrosion inhibitor/sealant was pumped March 26 & 27,2016. The attached spreadsheet presents the well name,top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, _.2,.c.../0, ,.Z//7/7 MJ Loveland 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 14/4/2016 CD2&3 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 CD2-03 50103205120000 2050920 28' 2.2 12.5" 2/8/2016 3.5 3/27/2016 D4-93 50103206900100 2150260 34" 0.2 22" 2/8/2016 11 3/26/2016 CD4-289 50103206970000 2141880 45" NA 45" NA 12 3/27/2016 • • 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. .57. 0 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Colr Items: ❑ Ma : rayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: `Maria Date: 0 /s/ Y A f Project Proofing BY: Maria Date: l C I ab 5 /s/ 114P Scanning Preparation k x 30 = 1 6 0 + J =TOTAL PAGES ! 9cpBY: Date: 4 I ao !�' (Count does not include cover she/s/ Production Scanning Stage 1 Page Count from Scanned File: /9 q (Count does include co r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: AM Date: ! l lao IIs- Is! 04 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES N TOTAL PAGES: Digital version appended by: Meredith Michel Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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V 0 o z - cn ui N a f— a , o GC a aJ J U I O V W 0z C, o o Z < J QY 0- , in s O � E Y J E e, 0 Q v v w 0 V 1 H z o 0 Ca p la ./� a vI > 0 G I Q O- C O % 1 ill Q z E o I Cl IFC) 0a ca z 111. , 1 d • CO 0Mr > I m NF a in d N N N 0' G p O_ I i' �. V O N C C U . N Q 10 U .; O O 0 0 Q a v 0 411 Guhl, Meredith D (DOA) From: Hyden, Duncan P [Duncan.P.Hyden@conocophillips.com] Sent: Tuesday, May 26, 2015 3:09 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: CRU CD4-93A, PTD 215-026, Top of Window Attachments: CD4-93A Nad27 EOW CompassSurveys Surface to TD.pdf Meredith, The correct depth of the top of the window is 11,980'. Please make the necessary changes to the 10-407 form. Attached is the composite definitive survey from surface to TD in NAD27. Please do not hesitate to let me know if I can provide any additional information. Thanks, Duncan Hyden Drilling Engineer I Direct:907-265-6862 I Mobile:907-317-1910 duncan.p.hyden@cop.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Tuesday, May 19, 2015 9:47 AM To: Hyden, Duncan P Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]CRU CD4-93A, PTD 215-026,Top of Window Duncan, In reviewing the recently submitted 10-407 for CRU CD4-93A I noticed that the top of window, listed in box 22,does not match the TOW shown on the schematic,the survey, or as noted in the daily operations summary.The form says 11956' and the schematic, survey,and ops summary state 11980'. Please clarify this 24' discrepancy. Also,the survey provided begins at 11980'. Surveys should be a composite from surface to TD. Please provide a complete survey for this well. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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. 1 • • NADConversion Western North Slope CD4 Nanuq Pad CD4-93A Definitive Survey Report - Nay 27 13 April, 2015 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98©55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD4-93 Well Position +N/-S 0.00 usft Northing: 5,957,557.99 usft Latitude: 70°17'33.301 N +E/-W 0.00 usft Easting: 378,310.58 usft Longitude: 150°59'6.819 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 19.00 usft Wellbore CD4-93A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 3/5/2015 18.42 80.77 57,538 Design CD4-93A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,979.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 150.00 Survey Program Date 5/26/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.00 989.58 CD4-93 Srvy#1 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/5/2014 6:00:0 1,047.13 1,178.36 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/6/2014 1:00:0 1,271.16 1,271.16 CD4-93 Srvy#3 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/25/2014 2:57: 1,330.80 11,979.70 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/25/2014 2:58: 12,032.71 12,500.80 CD4-93A Svy1 INC_ONLY_FILLER(CD4 INC+TREND Inclinometer+known azi trend 4/1/2015 3:52:0 12,537.28 13,771.03 CD4-93A Svy2 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2015 3:55:0 13,866.05 21,998.06 CD4-93A Svy3 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/8/2015 1:39:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 0.00 0.00 0.00 0.00 -55.98 0.00 0.00 5,957,557.99 378,310.58 0.00 0.00 UNDEFINED 114.53 0.02 83.14 114.53 58.55 0.00 0.02 5,957,557.99 378,310.60 0.02 0.01 GYD-GC-SS(1) NOT an Actual Survey 20"x 42" (Interpolated) 127.00 0.02 83.14 127.00 71.02 0.00 0.02 5,957,557.99 378,310.60 0.02 0.01 GYD-GC-SS(1) 152.70 0.01 246.46 152.70 96.72 0.00 0.02 5,957,557.99 378,310.61 0.12 0.01 GYD-GC-SS(1) 246.02 0.08 139.07 246.02 190.04 -0.05 0.06 5,957,557.94 378,310.64 0.09 0.07 GYD-GC-SS(1) 331.02 0.87 341.95 331.02 275.04 0.52 -0.10 5,957,558.51 378,310.49 1.11 -0.50 GYD-GC-SS(1) 425.47 1.38 353.38 425.45 369.47 2.33 -0.45 5,957,560.32 378,310.16 0.59 -2.25 GYD-GC-SS(1) 516.76 3.59 357.35 516.65 460.67 6.28 -0.71 5,957,564.27 378,309.97 2.43 -5.79 GYD-GC-SS(1) 5/26/2015 1:11:01PM Page 2 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98©55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 551.20 4.30 358.01 551.01 495.03 8.65 -0.81 5,957,566.64 378,309.91 2.07 -7.89 GYD-GC-SS(1) 610.40 5.54 356.00 609.99 554.01 13.71 -1.08 5,957,571.71 378,309.72 2.11 -12.42 GYD-GC-SS(1) 705.16 5.49 357.93 704.31 648.33 22.81 -1.57 5,957,580.81 378,309.38 0.20 -20.54 GYD-GC-SS(1) 799.55 5.81 359.68 798.24 742.26 32.10 -1.76 5,957,590.10 378,309.34 0.38 -28.68 GYD-GC-SS(1) 892.99 7.59 355.95 891.04 835.06 42.98 -2.22 5,957,601.00 378,309.06 1.96 -38.33 GYD-GC-SS(1) 989.58 10.27 343.79 986.46 930.48 57.62 -5.07 5,957,615.67 378,306.44 3.38 -52.44 GYD-GC-SS(1) 1,047.13 11.64 340.04 1,042.96 986.98 68.00 -8.49 5,957,626.11 378,303.19 2.68 -63.14 MWD+IFR-AK-CAZ-SC(2) 1,141.28 14.73 333.23 1,134.62 1,078.64 87.62 -17.12 5,957,645.87 378,294.88 3.67 -84.44 MWD+IFR-AK-CAZ-SC(2) 1,178.36 15.71 331.79 1,170.40 1,114.42 96.25 -21.62 5,957,654.57 378,290.52 2.83 -94.17 MWD+IFR-AK-CAZ-SC(2) 1,271.16 19.93 329.82 1,258.73 1,202.75 121.01 -35.52 5,957,679.54 378,277.03 4.59 -122.56 GYD-GC-SS(3) 1,330.80 21.95 327.17 1,314.43 1,258.45 139.17 -46.67 5,957,697.88 378,266.17 3.74 - -143.86 MWD+IFR-AK-CAZ-SC(4) 1,424.48 23.55 322.60 1,400.82 1,344.84 168.75 -67.53 5,957,727.79 378,245.79 2.54 -179.91 MWD+IFR-AK-CAZ-SC(4) 1,519.54 24.36 316.83 1,487.71 1,431.73 198.14 -92.49 5,957,757.58 378,221.32 2.61 -217.84 MWD+IFR-AK-CAZ-SC(4) 1,613.84 25.97 309.27 1,573.08 1,517.10 225.40 -121.79 5,957,785.31 378,192.47 3.81 -256.09 MWD+IFR-AK-CAZ-SC(4) 1,708.56 27.12 304.32 1,657.82 1,601.84 250.70 -155.68 5,957,811.16 378,159.00 2.63 -294.95 MWD+IFR-AK-CAZ-SC(4) 1,753.70 28.49 302.18 1,697.75 1,641.77 262.24 -173.29 5,957,822.97 378,141.57 3.75 -313.75 MWD+IFR-AK-CAZ-SC(4) 1,803.15 31.15 296.50 1,740.65 1,684.67 274.23 -194.72 5,957,835.31 378,120.34 7.84 -334.85 MWD+IFR-AK-CAZ-SC(4) 1,850.81 32.81 291.29 1,781.09 1,725.11 284.42 -217.79 5,957,845.87 378,097.44 6.75 -355.21 MWD+IFR-AK-CAZ-SC(4) 1,896.41 33.59 289.12 1,819.25 1,763.27 293.04 -241.22 5,957,854.87 378,074.15 3.12 -374.39 MWD+IFR-AK-CAZ-SC(4) 1,991.05 36.37 288.03 1,896.78 1,840.80 310.30 -292.65 5,957,872.96 378,023.01 3.01 -415.06 MWD+IFR-AK-CAZ-SC(4) 2,037.15 39.83 285.71 1,933.06 1,877.08 318.54 -319.87 5,957,881.63 377,995.93 8.12 -435.80 MWD+IFR-AK-CAZ-SC(4) 2,085.89 43.41 283.58 1,969.49 1,913.51 326.70 -351.19 5,957,890.30 377,964.76 7.90 -458.52 MWD+IFR-AK-CAZ-SC(4) 2,179.53 46.02 283.48 2,036.02 1,980.04 342.11 -415.24 5,957,906.74 377,900.97 2.79 -503.89 MWD+IFR-AK-CAZ-SC(4) 2,273.85 49.68 283.14 2,099.31 2,043.33 358.20 -483.28 5,957,923.93 377,833.20 3.89 -551.85 MWD+IFR-AK-CAZ-SC(4) 2,368.81 54.38 281.87 2,157.72 2,101.74 374.38 -556.34 5,957,941.29 377,760.42 5.06 -602.39 MWD+IFR-AK-CAZ-SC(4) 2,463.36 56.59 282.39 2,211.29 2,155.31 390.75 -632.51 5,957,958.89 377,684.54 2.38 -654.65 MWD+IFR-AK-CAZ-SC(4) 2,556.43 58.25 281.60 2,261.40 2,205.42 407.04 -709.22 5,957,976.42 377,608.11 1.92 -707.12 MWD+IFR-AK-CAZ-SC(4) 2,651.14 59.67 283.18 2,310.24 2,254.26 424.46 -788.47 5,957,995.12 377,529.15 2.07 -761.83 MWD+IFR-AK-CAZ-SC(4) 2,739.85 59.27 283.44 2,355.31 2,299.33 442.05 -862.82 5,958,013.91 377,455.10 0.52 -814.24 MWD+IFR-AK-CAZ-SC(4) 2,809.30 59.93 282.76 2,390.45 2,334.47 455.63 -921.17 5,958,028.43 377,396.99 1.27 -855.17 MWD+IFR-AK-CAZ-SC(4) NOT an Actual Survey 13-3/8"x 16" (Interpolated) 2,838.37 60.21 282.48 2,404.95 2,348.97 461.13 -945.75 5,958,034.33 377,372.50 1.27 -872.23 MWD+IFR-AK-CAZ-SC(4) 2,936.92 60.71 283.82 2,453.54 2,397.56 480.64 -1,029.24 5,958,055.19 377,289.34 1.29 -930.87 MWD+IFR-AK-CAZ-SC(4) 3,031.24 60.43 284.34 2,499.89 2,443.91 500.63 -1,108.92 5,958,076.45 377,210.00 0.56 -988.01 MWD+IFR-AK-CAZ-SC(4) 3,125.26 61.10 283.78 2,545.81 2,489.83 520.56 -1,188.51 5,958,097.67 377,130.76 0.88 -1,045.07 MWD+IFR-AK-CAZ-SC(4) 3,219.77 61.54 283.07 2,591.16 2,535.18 539.81 -1,269.15 5,958,118.22 377,050.44 0.81 -1,102.06 MWD+IFR-AK-CAZ-SC(4) 3,312.96 62.51 282.64 2,634.88 2,578.90 558.11 -1,349.39 5,958,137.82 376,970.51 1.12 -1,158.04 MWD+IFR-AK-CAZ-SC(4) 3,408.14 62.58 281.69 2,678.76 2,622.78 575.91 -1,431.95 5,958,156.95 376,888.26 0.89 -1,214.73 MWD+IFR-AK-CAZ-SC(4) 3,502.19 62.95 280.70 2,721.80 2,665.82 592.15 -1,513.98 5,958,174.51 376,806.51 1.02 -1,269.81 MWD+IFR-AK-CAZ-SC(4) 3,596.09 62.85 279.22 2,764.58 2,708.60 606.60 -1,596.31 5,958,190.30 376,724.43 1.41 -1,323.49 MWD+IFR-AK-CAZ-SC(4) 5/26/2015 1:11:01PM Page 3 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,690.35 62.95 278.00 2,807.52 2,751.54 619.17 -1,679.28 5,958,204.20 376,641.69 1.16 -1,375.85 MWD+IFR-AK-CAZ-SC(4) 3,782.42 62.91 276.87 2,849.42 2,793.44 629.77 -1,760.57 5,958,216.12 376,560.58 1.09 -1,425.68 MWD+IFR-AK-CAZ-SC(4) 3,880.61 63.21 276.90 2,893.91 2,837.93 640.27 -1,847.47 5,958,228.02 376,473.87 0.31 -1,478.22 MWD+IFR-AK-CAZ-SC(4) 3,974.76 63.27 277.06 2,936.30 2,880.32 650.48 -1,930.92 5,958,239.59 376,390.61 0.16 -1,528.79 MWD+IFR-AK-CAZ-SC(4) 4,069.74 63.20 277.53 2,979.07 2,923.09 661.25 -2,015.03 5,958,251.71 376,306.68 0.45 -1,580.18 MWD+IFR-AK-CAZ-SC(4) 4,163.96 63.10 276.34 3,021.63 2,965.65 671.40 -2,098.48 5,958,263.21 376,223.42 1.13 -1,630.69 MWD+IFR-AK-CAZ-SC(4) 4,258.75 63.18 277.41 3,064.46 3,008.48 681.52 -2,182.43 5,958,274.69 376,139.65 1.01 -1,681.43 MWD+IFR-AK-CAZ-SC(4) 4,353.00 62.68 277.44 3,107.35 3,051.37 692.37 -2,265.65 5,958,286.88 376,056.62 0.53 -1,732.44 MWD+IFR-AK-CAZ-SC(4) 4,446.37 63.03 277.55 3,149.95 3,093.97 703.21 -2,348.03 5,958,299.05 375,974.44 0.39 -1,783.01 MWD+IFR-AK-CAZ-SC(4) 4,539.76 63.18 279.97 3,192.20 3,136.22 715.89 -2,430.34 5,958,313.06 375,892.35 2.32 -1,835.15 MWD+IFR-AK-CAZ-SC(4) 4,633.59 62.95 282.33 3,234.70 3,178.72 732.06 -2,512.40 5,958,330.56 375,810.57 2.26 -1,890.19 MWD+IFR-AK-CAZ-SC(4) 4,729.52 62.80 283.01 3,278.44 3,222.46 750.79 -2,595.70 5,958,350.63 375,727.59 0.65 -1,948.05 MWD+IFR-AK-CAZ-SC(4) 4,823.96 63.06 282.64 3,321.42 3,265.44 769.46 -2,677.70 5,958,370.62 375,645.91 0.44 -2,005.22 MWD+IFR-AK-CAZ-SC(4) 4,917.74 62.49 282.76 3,364.32. 3,308.34 787.79 -2,759.05 5,958,390.27 375,564.88 0.62 -2,061.77 MWD+IFR-AK-CAZ-SC(4) 5,013.12 62.88 282.54 3,408.09 3,352.11 806.35 -2,841.73 5,958,410.16 375,482.51 0.46 -2,119.19 MWD+IFR-AK-CAZ-SC(4) 5,107.22 62.94 280.92 3,450.95 3,394.97 823.38 -2,923.76 5,958,428.52 375,400.78 1.53 -2,174.95 MWD+IFR-AK-CAZ-SC(4) 5,201.32 62.75 279.28 3,493.90 3,437.92 838.06 -3,006.18 5,958,444.53 375,318.61 1.56 -2,228.88 MWD+IFR-AK-CAZ-SC(4) 5,298.02 62.83 277.73 3,538.11 3,482.13 850.78 -3,091.23 5,958,458.62 375,233.78 1.43 -2,282.41 MWD+IFR-AK-CAZ-SC(4) 5,396.35 62.67 276.88 3,583.14 3,527.16 861.90 -3,177.94 5,958,471.14 375,147.27 0.79 -2,335.39 MWD+IFR-AK-CAZ-SC(4) 5,490.47 62.76 277.48 3,626.28 3,570.30 872.35 -3,260.93 5,958,482.93 375,064.47 0.57 -2,385.94 MWD+IFR-AK-CAZ-SC(4) 5,585.40 62.84 277.91 3,669.68 3,613.70 883.66 -3,344.60 5,958,495.59 374,981.00 0.41 -2,437.57 MWD+IFR-AK-CAZ-SC(4) 5,679.85 63.12 278.55 3,712.59 3,656.61 895.70 -3,427.88 5,958,508.98 374,897.94 0.67 -2,489.64 MWD+IFR-AK-CAZ-SC(4) 5,773.73 62.98 279.55 3,755.13 3,699.15 908.86 -3,510.52 5,958,523.48 374,815.53 0.96 -2,542.36 MWD+IFR-AK-CAZ-SC(4) 5,868.56 63.18 279.48 3,798.07 3,742.09 922.84 -3,593.91 5,958,538.80 374,732.38 0.22 -2,596.16 MWD+IFR-AK-CAZ-SC(4) 5,963.15 63.24 279.95 3,840.70 3,784.72 937.09 -3,677.13 5,958,554.40 374,649.40 0.45 -2,650.11 MWD+IFR-AK-CAZ-SC(4) 6,057.06 63.11 280.09 3,883.08 3,827.10 951.67 -3,759.66 5,958,570.31 374,567.13 0.19 -2,704.00 MWD+IFR-AK-CAZ-SC(4) 6,150.40 63.00 281.01 3,925.38 3,869.40 966.91 -3,841.46 5,958,586.86 374,485.59 0.89 -2,758.09 MWD+IFR-AK-CAZ-SC(4) 6,245.06 63.06 281.38 3,968.31 3,912.33 983.28 -3,924.22 5,958,604.58 374,403.12 0.35 -2,813.66 MWD+IFR-AK-CAZ-SC(4) 6,340.63 62.70 281.15 4,011.87 3,955.89 999.90 -4,007.64 5,958,622.54 374,319.98 0.43 -2,869.76 MWD+IFR-AK-CAZ-SC(4) 6,433.49 62.86 282.15 4,054.35 3,998.37 1,016.58 -4,088.52 5,958,640.52 374,239.40 0.97 -2,924.64 MWD+IFR-AK-CAZ-SC(4) 6,528.25 62.87 281.65 4,097.57 4,041.59 1,033.97 -4,171.03 5,958,659.25 374,157.18 0.47 -2,980.96 MWD+IFR-AK-CAZ-SC(4) 6,622.75 62.68 280.94 4,140.80 4,084.82 1,050.42 -4,253.44 5,958,677.03 374,075.06 0.70 -3,036.41 MWD+IFR-AK-CAZ-SC(4) 6,716.46 62.95 280.47 4,183.61 4,127.63 1,065.91 -4,335.34 5,958,693.84 373,993.42 0.53 -3,090.78 MWD+IFR-AK-CAZ-SC(4) 6,811.85 63.08 281.26 4,226.90 4,170.92 1,081.93 -4,418.82 5,958,711.21 373,910.22 0.75 -3,146.39 MWD+IFR-AK-CAZ-SC(4) 6,904.67 63.09 281.85 4,268.92 4,212.94 1,098.51 -4,499.91 5,958,729.10 373,829.41 0.57 -3,201.29 MWD+IFR-AK-CAZ-SC(4) 6,999.31 62.79 281.60 4,311.97 4,255.99 1,115.64 -4,582.43 5,958,747.56 373,747.19 0.39 -3,257.39 MWD+IFR-AK-CAZ-SC(4) 7,094.78 63.24 280.81 4,355.29 4,299.31 1,132.17 -4,665.89 5,958,765.44 373,664.02 0.88 -3,313.43 MWD+IFR-AK-CAZ-SC(4) 7,188.60 63.11 280.90 4,397.63 4,341.65 1,147.93 -4,748.11 5,958,782.53 373,582.07 0.16 -3,368.20 MWD+IFR-AK-CAZ-SC(4) 7,283.55 62.89 281.05 4,440.73 4,384.75 1,164.04 -4,831.16 5,958,799.98 373,499.29 0.27 -3,423.67 MWD+IFR-AK-CAZ-SC(4) 7,378.68 62.84 280.91 4,484.12 4,428.14 1,180.17 -4,914.27 5,958,817.44 373,416.46 0.14 -3,479.19 MWD+IFR-AK-CAZ-SC(4) 5/26/2015 1:11:01PM Page 4 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 7,473.41 63.05 281.26 4,527.21 4,471.23 1,196.39 -4,997.06 5,958,835.00 373,333.95 0.40 -3,534.63 MWD+IFR-AK-CAZ-SC(4) 7,567.34 63.15 280.93 4,569.71 4,513.73 1,212.51 -5,079.26 5,958,852.45 373,252.03 0.33 -3,589.69 MWD+IFR-AK-CAZ-SC(4) 7,660.21 63.18 279.85 4,611.63 4,555.65 1,227.45 -5,160.77 5,958,868.71 373,170.78 1.04 -3,643.39 MWD+IFR-AK-CAZ-SC(4) 7,756.40 63.04 279.21 4,655.14 4,599.16 1,241.65 -5,245.38 5,958,884.28 373,086.42 0.61 -3,697.99 MWD+IFR-AK-CAZ-SC(4) 7,850.34 63.05 279.56 4,697.72 4,641.74 1,255.31 -5,327.99 5,958,899.27 373,004.05 0.33 -3,751.12 MWD+IFR-AK-CAZ-SC(4) 7,945.37 63.08 278.87 4,740.77 4,684.79 1,268.88 -5,411.62 5,958,914.19 372,920.66 0.65 -3,804.69 MWD+IFR-AK-CAZ-SC(4) 8,039.09 62.98 278.28 4,783.27 4,727.29 1,281.33 -5,494.21 5,958,927.97 372,838.29 0.57 -3,856.77 MWD+IFR-AK-CAZ-SC(4) 8,133.53 62.86 279.10 4,826.26 4,770.28 1,294.03 -5,577.33 5,958,942.02 372,755.39 0.78 -3,909.33 MWD+IFR-AK-CAZ-SC(4) 8,227.81 62.95 280.07 4,869.21 4,813.23 1,308.01 -5,660.09 5,958,957.33 372,672.87 0.92 -3,962.82 MWD+IFR-AK-CAZ-SC(4) 8,322.35 63.18 280.61 4,912.03 4,856.05 1,323.14 -5,743.01 5,958,973.80 •372,590.22 0.56 -4,017.37 MWD+IFR-AK-CAZ-SC(4) 8,416.52 63.02 280.18 4,954.64 4,898.66 1,338.29 -5,825.61 5,958,990.29 372,507.88 0.44 -4,071.80 MWD+IFR-AK-CAZ-SC(4) 8,511.31 63.05 279.62 4,997.62 4,941.64 1,352.82 -5,908.84 5,959,006.16 372,424.91 0.53 -4,125.99 MWD+IFR-AK-CAZ-SC(4) 8,605.72 62.91 279.34 5,040.51 4,984.53 1,366.67 -5,991.79 5,959,021.35 372,342.19 0.30 -4,179.47 MWD+IFR-AK-CAZ-SC(4) 8,699.74 62.94 279.23 5,083.30 5,027.32 1,380.18 -6,074.41 5,959,036.19 372,259.81 0.11 -4,232.47 MWD+IFR-AK-CAZ-SC(4) 8,794.11 63.28 279.23 5,125.98 5,070.00 1,393.68 -6,157.49 5,959,051.03 372,176.97 0.36 -4,285.70 MWD+IFR-AK-CAZ-SC(4) 8,886.10 62.99 278.66 5,167.55 5,111.57 1,406.44 -6,238.55 5,959,065.10 372,096.13 0.64 -4,337.28 MWD+IFR-AK-CAZ-SC(4) 8,982.60 63.14 278.96 5,211.27 5,155.29 1,419.61 -6,323.57 5,959,079.65 372,011.35 0.32 -4,391.20 MWD+IFR-AK-CAZ-SC(4) 9,077.52 63.53 278.62 5,253.86 5,197.88 1,432.57 -6,407.40 5,959,093.97 371,927.75 0.52 -4,444.34 MWD+IFR-AK-CAZ-SC(4) 9,171.78 63.93 278.44 5,295.58 5,239.60 1,445.11 -6,490.99 5,959,107.86 371,844.38 0.46 -4,497.00 MWD+IFR-AK-CAZ-SC(4) 9,266.10 63.34 276.93 5,337.47 5,281.49 1,456.42 -6,574.73 5,959,120.51 371,760.83 1.56 -4,548.66 MWD+IFR-AK-CAZ-SC(4) 9,361.05 62.59 274.95 5,380.63 5,324.65 1,465.17 -6,658.84 5,959,130.63 371,676.88 2.02 -4,598.30 MWD+IFR-AK-CAZ-SC(4) 9,455.21 62.75 272.85 5,423.87 5,367.89 1,470.86 -6,742.29 5,959,137.67 371,593.54 1.99 -4,644.95 MWD+IFR-AK-CAZ-SC(4) 9,549.22 61.53 270.81 5,467.80 5,411.82 1,473.52 -6,825.36 5,959,141.67 371,510.54 2.32 -4,688.79 MWD+IFR-AK-CAZ-SC(4) 9,643.37 59.21 266.60 5,514.36 5,458.38 1,471.71 -6,907.14 5,959,141.18 371,428.74 4.60 -4,728.11 MWD+IFR-AK-CAZ-SC(4) 9,736.06 57.68 263.68 5,562.87 5,506.89 1,465.03 -6,985.83 5,959,135.78 371,349.96 3.15 -4,761.67 MWD+IFR-AK-CAZ-SC(4) 9,832.25 55.76 258.96 5,615.68 5,559.70 1,452.94 -7,065.29 5,959,124.98 371,270.32 4.56 -4,790.93 MWD+IFR-AK-CAZ-SC(4) 9,926.42 55.06 255.92 5,669.14 5,613.16 1,436.09 -7,140.94 5,959,109.36 371,194.41 2.76 -4,814.17 MWD+IFR-AK-CAZ-SC(4) 10,021.53 54.74 250.61 5,723.86 5,667.88 1,413.71 -7,215.42 5,959,088.18 371,119.59 4.58 -4,832.02 MWD+IFR-AK-CAZ-SC(4) 10,115.90 53.77 245.59 5,779.01 5,723.03 1,385.17 -7,286.45 5,959,060.81 371,048.11 4.44 -4,842.82 MWD+IFR-AK-CAZ-SC(4) 10,209.83 53.43 240.93 5,834.77 5,778.79 1,351.18 -7,353.94 5,959,027.91 370,980.08 4.01 -4,847.13 MWD+IFR-AK-CAZ-SC(4) 10,304.50 53.51 237.48 5,891.13 5,835.15 1,312.24 -7,419.27 5,958,990.04 370,914.14 2.93 -4,846.07 MWD+IFR-AK-CAZ-SC(4) 10,398.60 54.02 233.83 5,946.77 5,890.79 1,269.43 -7,481.92 5,958,948.25 370,850.81 3.18 -4,840.31 MWD+IFR-AK-CAZ-SC(4) 10,493.00 54.41 230.26 6,001.98 5,946.00 1,222.33 -7,542.28 5,958,902.14 370,789.70 3.10 -4,829.71 MWD+IFR-AK-CAZ-SC(4) 10,587.30 53.94 226.63 6,057.19 6,001.21 1,171.64 -7,599.48 5,958,852.38 370,731.69 3.16 -4,814.41 MWD+IFR-AK-CAZ-SC(4) 10,681.27 53.02 222.13 6,113.13 6,057.15 1,117.70 -7,652.29 5,958,799.31 370,678.02 3.97 -4,794.10 MWD+IFR-AK-CAZ-SC(4) 10,776.13 53.02 217.43 6,170.21 6,114.23 1,059.49 -7,700.75 5,958,741.90 370,628.62 3.96 -4,767.92 MWD+IFR-AK-CAZ-SC(4) 10,870.32 52.79 212.96 6,227.04 6,171.06 998.12 -7,744.04 5,958,681.25 370,584.35 3.79 -4,736.42 MWD+IFR-AK-CAZ-SC(4) 10,964.42 54.20 208.57 6,283.03 6,227.05 933.15 -7,782.69 5,958,616.91 370,544.66 4.04 -4,699.47 MWD+IFR-AK-CAZ-SC(4) 11,057.46 54.60 205.52 6,337.20 6,281.22 865.78 -7,817.08 5,958,550.11 370,509.19 2.70 -4,658.33 MWD+IFR-AK-CAZ-SC(4) 11,151.90 55.31 201.06 6,391.45 6,335.47 794.79 -7,847.62 5,958,479.63 370,477.50 3.94 -4,612.12 MWD+IFR-AK-CAZ-SC(4) 5/26/2015 1:11:01PM Page 5 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,247.80 54.79 196.65 6,446.40 6,390.42 720.43 -7,873.02 5,958,405.70 370,450.90 3.81 -4,560.43 MWD+IFR-AK-CAZ-SC(4) 11,341.95 55.75 192.26 6,500.06 6,444.08 645.53 -7,892.31 5,958,331.13 370,430.41 3.97 -4,505.20 MWD+IFR-AK-CAZ-SC(4) 11,436.66 58.51 188.99 6,551.47 6,495.49 567.37 -7,906.94 5,958,253.22 370,414.52 4.11 -4,444.83 MWD+IFR-AK-CAZ-SC(4) 11,529.96 61.91 186.61 6,597.82 6,541.84 487.16 -7,917.90 5,958,173.21 370,402.26 4.26 -4,380.84 MWD+IFR-AK-CAZ-SC(4) 11,623.63 64.81 184.21 6,639.82 6,583.84 403.82 -7,925.77 5,958,090.02 370,393.04 3.85 -4,312.61 MWD+IFR-AK-CAZ-SC(4) 11,718.92 67.00 179.90 6,678.73 6,622.75 316.92 -7,928.86 5,958,003.18 370,388.55 4.72 -4,238.89 MWD+IFR-AK-CAZ-SC(4) 11,814.46 69.29 175.94 6,714.31 6,658.33 228.34 -7,925.62 5,957,914.57 370,390.36 4.53 -4,160.56 MWD+IFR-AK-CAZ-SC(4) 11,908.45 70.17 173.86 6,746.87 6,690.89 140.53 -7,917.78 5,957,826.64 370,396.77 2.28 -4,080.59 MWD+IFR-AK-CAZ-SC(4) 11,979.70 69.14 175.12 6,771.65 6,715.67 74.03 -7,911.36 5,957,760.06 370,402.12 2.20 -4,019.79 MWD+IFR-AK-CAZ-SC(4) NOT an Actual Survey 9 5/8"x 12-1/4 (Interpolated) 12,032.71 70.04 175.41 6,790.14 6,734.16 24.52 -7,907.26 5,957,710.50 370,405.41 1.78 -3,974.86 INC+TREND(5) 12,127.01 71.47 175.92 6,821.22 6,765.24 -64.25 -7,900.53 5,957,621.63 370,410.70 1.60 -3,894.62 INC+TREND(5) 12,220.97 70.65 176.43 6,851.72 6,795.74 -152.93 -7,894.60 5,957,532.88 370,415.20 1.01 -3,814.86 INC+TREND(5) 12,316.06 68.53 176.96 6,884.88 6,828.90 -241.89 -7,889.46 5,957,443.85 370,418.90 2.29 -3,735.25 INC+TREND(5) 12,407.80 66.45 177.50 6,920.00 6,864.02 -326.54 -7,885.36 5,957,359.16 370,421.62 2.33 -3,659.89 INC+TREND(5) 12,454.77 64.54 177.78 6,939.48 6,883.50 -369.24 -7,883.60 5,957,316.44 370,422.69 4.10 -3,622.03 INC+TREND(5) 12,500.80 62.54 176.87 6,959.99 6,904.01 -410.40 -7,881.68 5,957,275.25 370,423.95 4.69 -3,585.42 INC+TREND(5) 12,537.28 60.84 178.92 6,977.29 6,921.31 -442.49 -7,880.50 5,957,243.15 370,424.61 6.80 -3,557.04 MWD+IFR-AK-CAZ-SC(6) 12,595.73 58.66 182.20 7,006.74 6,950.76 -492.97 -7,880.97 5,957,192.69 370,423.32 6.12 -3,513.56 MWD+IFR-AK-CAZ-SC(6) 12,690.86 55.49 184.50 7,058.44 7,002.46 -572.66 -7,885.61 5,957,113.09 370,417.39 3.90 -3,446.86 MWD+IFR-AK-CAZ-SC(6) 12,785.68 56.11 182.47 7,111.74 7,055.76 -650.94 -7,890.37 5,957,034.91 370,411.36 1.89 -3,381.46 MWD+IFR-AK-CAZ-SC(6) 12,880.05 56.37 179.59 7,164.19 7,108.21 -729.37 -7,891.78 5,956,956.52 370,408.69 2.55 -3,314.24 MWD+IFR-AK-CAZ-SC(6) 12,974.77 59.90 175.86 7,214.20 7,158.22 -809.71 -7,888.54 5,956,876.14 370,410.63 5.01 -3,243.04 MWD+IFR-AK-CAZ-SC(6) 13,069.56 63.52 174.66 7,259.12 7,203.14 -892.88 -7,881.62 5,956,792.88 370,416.19 3.98 -3,167.56 MWD+IFR-AK-CAZ-SC(6) 13,117.89 64.66 173.62 7,280.24 7,224.26 -936.12 -7,877.18 5,956,749.57 370,419.93 3.05 -3,127.89 MWD+IFR-AK-CAZ-SC(6) 13,164.37 65.86 173.39 7,299.69 7,243.71 -978.06 -7,872.41 5,956,707.56 370,424.03 2.62 -3,089.18 MWD+IFR-AK-CAZ-SC(6) 13,258.60 67.81 174.95 7,336.76 7,280.78 -1,064.24 -7,863.62 5,956,621.26 370,431.42 2.57 -3,010.15 MWD+IFR-AK-CAZ-SC(6) 13,352.18 69.63 173.67 7,370.72 7,314.74 -1,151.00 -7,854.97 5,956,534.38 370,438.66 2.33 -2,930.69 MWD+IFR-AK-CAZ-SC(6) 13,446.99 71.92 174.07 7,401.94 7,345.96 -1,240.01 -7,845.41 5,956,445.24 370,446.78 2.45 -2,848.83 MWD+IFR-AK-CAZ-SC(6) 13,541.22 75.38 173.69 7,428.46 7,372.48 -1,329.90 -7,835.77 5,956,355.21 370,454.96 3.69 -2,766.16 MWD+IFR-AK-CAZ-SC(6) 13,634.85 79.35 173.83 7,448.94 7,392.96 -1,420.70 -7,825.84 5,956,264.26 370,463.42 4.24 -2,682.56 MWD+IFR-AK-CAZ-SC(6) 13,727.04 82.85 172.35 7,463.20 7,407.22 -1,511.10 -7,814.88 5,956,173.71 370,472.91 4.11 -2,598.79 MWD+IFR-AK-CAZ-SC(6) 13,771.03 84.33 171.98 7,468.11 7,412.13 -1,554.41 -7,808.92 5,956,130.31 370,478.17 3.47 -2,558.30 MWD+IFR-AK-CAZ-SC(6) 13,820.00 85.46 171.99 7,472.47 7,416.49 -1,602.71 -7,802.12 5,956,081.91 370,484.19 2.30 -2,513.08 MWD+IFR-AK-CAZ-SC(7) NOT an Actual Survey 7"x 8 3/4"by 9-7/8" (Interpolated) 13,866.05 86.52 171.99 7,475.69 7,419.71 -1,648.19 -7,795.72 5,956,036.33 370,489.86 2.30 -2,470.48 MWD+IFR-AK-CAZ-SC(7) 13,960.41 86.59 176.86 7,481.36 7,425.38 -1,741.91 -7,786.57 5,955,942.49 370,497.48 5.15 -2,384.75 MWD+IFR-AK-CAZ-SC(7) 14,055.78 86.95 178.51 7,486.73 7,430.75 -1,837.05 -7,782.72 5,955,847.31 370,499.79 1.77 -2,300.43 MWD+IFR-AK-CAZ-SC(7) 14,150.94 86.26 179.98 7,492.37 7,436.39 -1,932.03 -7,781.47 5,955,752.33 370,499.50 1.70 -2,217.55 MWD+IFR-AK-CAZ-SC(7) 14,246.47 87.64 179.86 7,497.45 7,441.47 -2,027.42 -7,781.34 5,955,656.95 370,498.09 1.45 -2,134.87 MWD+IFR-AK-CAZ-SC(7) 5/26/2015 1:11:01PM Page 6 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,343.21 87.85 178.23 7,501.26 7,445.28 -2,124.07 -7,779.73 5,955,560.30 370,498.14 1.70 -2,050.37 MWD+IFR-AK-CAZ-SC(7) 14,438.13 89.36 179.53 7,503.57 7,447.59 -2,218.94 -7,777.87 5,955,465.42 370,498.46 2.10 -1,967.28 MWD+IFR-AK-CAZ-SC(7) 14,534.69 88.89 178.62 7,505.05 7,449.07 -2,315.47 -7,776.31 5,955,368.88 370,498.45 1.06 -1,882.90 MWD+IFR-AK-CAZ-SC(7) 14,628.19 88.62 176.32 7,507.08 7,451.10 -2,408.85 -7,772.19 5,955,275.46 370,501.07 2.48 -1,799.97 MWD+IFR-AK-CAZ-SC(7) 14,723.45 88.23 175.55 7,509.70 7,453.72 -2,503.84 -7,765.44 5,955,180.38 370,506.28 0.91 -1,714.33 MWD+IFR-AK-CAZ-SC(7) 14,818.96 88.91 174.54 7,512.08 7,456.10 -2,598.96 -7,757.19 5,955,085.15 370,512.98 1.27 -1,627.83 MWD+IFR-AK-CAZ-SC(7) 14,914.38 88.25 171.16 7,514.44 7,458.46 -2,693.59 -7,745.32 5,954,990.34 370,523.32 3.61 -1,539.94 MWD+IFR-AK-CAZ-SC(7) 15,008.37 89.54 168.34 7,516.26 7,460.28 -2,786.05 -7,728.60 5,954,897.63 370,538.54 3.30 -1,451.51 MWD+IFR-AK-CAZ-SC(7) 15,105.76 88.46 163.66 7,517.96 7,461.98 -2,880.51 -7,705.05 5,954,802.81 370,560.56 4.93 -1,357.93 MWD+IFR-AK-CAZ-SC(7) 15,198.68 89.70 160.09 7,519.45 7,463.47 -2,968.79 -7,676.15 5,954,714.08 370,588.02 4.07 -1,267.03 MWD+IFR-AK-CAZ-SC(7) 15,293.72 89.62 158.75 7,520.01 7,464.03 -3,057.76 -7,642.74 5,954,624.59 370,619.98 1.41 -1,173.27 MWD+IFR-AK-CAZ-SC(7) 15,389.43 89.86 158.18 7,520.45 7,464.47 -3,146.79 -7,607.61 5,954,535.01 370,653.66 0.65 -1,078.61 MWD+IFR-AK-CAZ-SC(7) 15,484.85 89.86 154.52 7,520.68 7,464.70 -3,234.18 -7,569.34 5,954,447.02 370,690.51 3.84 -983.79 MWD+IFR-AK-CAZ-SC(7) 15,578.79 90.47 153.41 7,520.41 7,464.43 -3,318.59 -7,528.11 5,954,361.97 370,730.37 1.35 -890.08 MWD+IFR-AK-CAZ-SC(7) 15,674.82 90.13 148.77 7,519.91 7,463.93 -3,402.62 -7,481.70 5,954,277.19 370,775.41 4.84 -794.09 MWD+IFR-AK-CAZ-SC(7) 15,769.88 89.36 147.93 7,520.33 7,464.35 -3,483.54 -7,431.82 5,954,195.48 370,823.96 1.20 -699.07 MWD+IFR-AK-CAZ-SC(7) 15,866.17 89.99 144.53 7,520.88 7,464.90 -3,563.57 -7,378.31 5,954,114.61 370,876.17 3.59 -603.01 MWD+IFR-AK-CAZ-SC(7) 15,963.62 89.92 143.57 7,520.95 7,464.97 -3,642.46 -7,321.10 5,954,034.81 370,932.09 0.99 -506.08 MWD+IFR-AK-CAZ-SC(7) 16,054.87 89.48 145.53 7,521.43 7,465.45 -3,716.79 -7,268.17 5,953,959.64 370,983.80 2.20 -415.25 MWD+IFR-AK-CAZ-SC(7) 16,150.67 89.02 146.07 7,522.69 7,466.71 -3,796.02 -7,214.33 5,953,879.56 371,036.35 0.74 -319.72 MWD+IFR-AK-CAZ-SC(7) 16,246.89 89.68 148.90 7,523.78 7,467.80 -3,877.14 -7,162.62 5,953,797.61 371,086.74 3.02 -223.61 MWD+IFR-AK-CAZ-SC(7) 16,342.77 89.96 148.24 7,524.08 7,468.10 -3,958.95 -7,112.62 5,953,715.01 371,135.40 0.75 -127.76 MWD+IFR-AK-CAZ-SC(7) 16,436.84 90.06 147.65 7,524.06 7,468.08 -4,038.68 -7,062.70 5,953,634.49 371,184.02 0.64 -33.75 MWD+IFR-AK-CAZ-SC(7) 16,531.85 89.72 147.70 7,524.25 7,468.27 -4,118.97 -7,011.89 5,953,553.40 371,233.52 0.36 61.18 MWD+IFR-AK-CAZ-SC(7) 16,628.05 89.41 147.48 7,524.98 7,469.00 -4,200.18 -6,960.34 5,953,471.37 371,283.75 0.40 157.29 MWD+IFR-AK-CAZ-SC(7) 16,722.37 89.27 146.98 7,526.06 7,470.08 -4,279.48 -6,909.29 5,953,391.26 371,333.50 0.55 251.50 MWD+IFR-AK-CAZ-SC(7) 16,817.95 88.66 147.29 7,527.79 7,471.81 -4,359.75 -6,857.43 5,953,310.17 371,384.05 0.72 346.94 MWD+IFR-AK-CAZ-SC(7) 16,912.68 88.76 148.31 7,529.92 7,473.94 -4,439.89 -6,806.96 5,953,229.23 371,433.21 1.08 441.58 MWD+IFR-AK-CAZ-SC(7) 17,008.76 88.96 148.50 7,531.83 7,475.85 -4,521.71 -6,756.63 5,953,146.61 371,482.20 0.29 537.60 MWD+IFR-AK-CAZ-SC(7) 17,104.31 89.79 147.56 7,532.87 7,476.89 -4,602.76 -6,706.05 5,953,064.76 371,531.47 1.31 633.09 MWD+IFR-AK-CAZ-SC(7) 17,199.15 90.61 147.33 7,532.54 7,476.56 -4,682.70 -6,655.01 5,952,984.01 371,581.20 0.90 727.83 MWD+IFR-AK-CAZ-SC(7) 17,295.44 90.82 147.84 7,531.34 7,475.36 -4,763.98 -6,603.40 5,952,901.91 371,631.48 0.57 824.03 MWD+IFR-AK-CAZ-SC(7) 17,389.54 90.90 147.88 7,529.93 7,473.95 -4,843.65 -6,553.35 5,952,821.45 371,680.23 0.10 918.05 MWD+IFR-AK-CAZ-SC(7) 17,485.84 89.25 148.79 7,529.80 7,473.82 -4,925.61 -6,502.80 5,952,738.69 371,729.45 1.96 1,014.31 MWD+IFR-AK-CAZ-SC(7) 17,581.47 89.68 149.09 7,530.70 7,474.72 -5,007.53 -6,453.46 5,952,655.99 371,777.45 0.55 1,109.92 MWD+IFR-AK-CAZ-SC(7) 17,676.06 89.72 149.13 7,531.19 7,475.21 -5,088.70 -6,404.90 5,952,574.05 371,824.68 0.06 1,204.49 MWD+IFR-AK-CAZ-SC(7) 17,770.93 89.68 148.71 7,531.69 7,475.71 -5,169.95 -6,355.92 5,952,492.03 371,872.33 0.44 1,299.34 MWD+IFR-AK-CAZ-SC(7) 17,866.12 90.18 148.99 7,531.81 7,475.83 -5,251.41 -6,306.69 5,952,409.78 371,920.24 0.60 1,394.52 MWD+IFR-AK-CAZ-SC(7) 17,962.68 89.19 149.56 7,532.34 7,476.36 -5,334.42 -6,257.35 5,952,326.00 371,968.22 1.18 1,491.06 MWD+IFR-AK-CAZ-SC(7) 18,058.98 89.51 149.86 7,533.43 7,477.45 -5,417.56 -6,208.78 5,952,242.08 372,015.43 0.46 1,587.36 MWD+IFR-AK-CAZ-SC(7) 5/26/2015 1:11:01PM Page 7 COMPASS 5000.1 Build 65 f Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 18,153.60 90.41 150.22 7,533.49 7,477.51 -5,499.54 -6,161.53 5,952,159.36 372,061.35 1.02 1,681.98 MWD+IFR-AK-CAZ-SC(7) 18,249.43 90.30 150.47 7,532.90 7,476.92 -5,582.82 -6,114.12 5,952,075.33 372,107.40 0.29 1,777.80 MWD+IFR-AK-CAZ-SC(7) 18,344.66 90.23 149.17 7,532.46 7,476.48 -5,665.14 -6,066.25 5,951,992.26 372,153.93 1.37 1,873.03 MWD+IFR-AK-CAZ-SC(7) 18,439.43 90.16 149.23 7,532.14 7,476.16 -5,746.54 -6,017.72 5,951,910.09 372,201.13 0.10 1,967.79 MWD+IFR-AK-CAZ-SC(7) 18,535.19 89.99 148.92 7,532.01 7,476.03 -5,828.69 -5,968.51 5,951,827.16 372,249.00 0.37 2,063.54 MWD+IFR-AK-CAZ-SC(7) 18,630.73 86.83 149.23 7,534.66 7,478.68 -5,910.60 -5,919.43 5,951,744.47 372,296.74 3.32 2,159.01 MWD+IFR-AK-CAZ-SC(7) 18,726.31 87.32 149.33 7,539.54 7,483.56 -5,992.66 -5,870.67 5,951,661.64 372,344.17 0.52 2,254.46 MWD+IFR-AK-CAZ-SC(7) 18,821.72 86.91 148.81 7,544.34 7,488.36 -6,074.40 -5,821.69 5,951,579.12 372,391.81 0.69 2,349.74 MWD+IFR-AK-CAZ-SC(7) 18,916.30 87.22 149.18 7,549.19 7,493.21 -6,155.36 -5,773.04 5,951,497.39 372,439.14 0.51 2,444.18 MWD+IFR-AK-CAZ-SC(7) 19,011.82 90.19 147.23 7,551.34 7,495.36 -6,236.51 -5,722.73 5,951,415.44 372,488.13 3.72 2,539.61 MWD+IFR-AK-CAZ-SC(7) 19,106.28 90.58 147.32 7,550.71 7,494.73 -6,315.98 -5,671.67 5,951,335.17 372,537.89 0.42 2,633.96 MWD+IFR-AK-CAZ-SC(7) 19,201.54 90.40 147.26 7,549.89 7,493.91 -6,396.13 -5,620.19 5,951,254.20 372,588.06 0.20 2,729.11 MWD+IFR-AK-CAZ-SC(7) 19,296.97 90.32 146.58 7,549.29 7,493.31 -6,476.09 -5,568.11 5,951,173.42 372,638.84 0.72 2,824.40 MWD+IFR-AK-CAZ-SC(7) 19,392.12 91.41 146.63 7,547.86 7,491.88 -6,555.52 -5,515.74 5,951,093.16 372,689.91 1.15 2,919.37 MWD+IFR-AK-CAZ-SC(7) 19,487.81 90.92 147.39 7,545.91 7,489.93 -6,635.76 -5,463.65 5,951,012.09 372,740.69 0.94 3,014.91 MWD+IFR-AK-CAZ-SC(7) 19,582.65 90.08 148.78 7,545.09 7,489.11 -6,716.26 -5,413.51 5,950,930.79 372,789.51 1.71 3,109.69 MWD+IFR-AK-CAZ-SC(7) 19,678.31 90.40 149.79 7,544.68 7,488.70 -6,798.50 -5,364.66 5,950,847.78 372,837.03 1.11 3,205.34 MWD+IFR-AK-CAZ-SC(7) 19,773.01 90.30 150.65 7,544.11 7,488.13 -6,880.69 -5,317.62 5,950,764.85 372,882.72 0.91 3,300.04 MWD+IFR-AK-CAZ-SC(7) 19,868.31 89.62 150.68 7,544.17 7,488.19 -6,963.77 -5,270.93 5,950,681.03 372,928.06 0.71 3,395.33 MWD+IFR-AK-CAZ-SC(7) 19,963.91 88.98 151./3 7,545.34 7,489.36 -7,047.30 -5,224.45 5,950,596.76 372,973.18 0.82 3,490.91 MWD+IFR-AK-CAZ-SC(7) 20,059.55 89.44 150.84 7,546.66 7,490.68 -7,130.93 -5,178.07 5,950,512.40 373,018.20 0.57 3,586.53 MWD+IFR-AK-CAZ-SC(7) 20,153.95 89.51 152.03 7,547.52 7,491.54 -7,213.83 -5,132.93 5,950,428.79 373,061.98 1.26 3,680.89 MWD+IFR-AK-CAZ-SC(7) 20,249.52 89.55 152.78 7,548.31 7,492.33 -7,298.52 -5,088.66 5,950,343.39 373,104.87 0.79 3,776.38 MWD+IFR-AK-CAZ-SC(7) 20,344.91 89.57 153.73 7,549.04 7,493.06 -7,383.71 -5,045.74 5,950,257.54 373,146.41 1.00 3,871.61 MWD+IFR-AK-CAZ-SC(7) 20,440.03 90.47 153.89 7,549.01 7,493.03 -7,469.06 -5,003.76 5,950,171.52 373,187.00 0.96 3,966.52 MWD+IFR-AK-CAZ-SC(7) 20,536.49 90.85 153.87 7,547.90 7,491.92 -7,555.66 -4,961.29 5,950,084.25 373,228.05 0.39 4,062.75 MWD+IFR-AK-CAZ-SC(7) 20,630.94 90.82 152.93 7,546.52 7,490.54 -7,640.11 -4,919.01 5,949,999.14 373,268.96 1.00 4,157.02 MWD+IFR-AK-CAZ-SC(7) 20,728.33 90.22 151.71 7,545.64 7,489.66 -7,726.34 -4,873.77 5,949,912.19 373,312.79 1.40 4,254.33 MWD+IFR-AK-CAZ-SC(7) 20,822.52 87.97 149.96 7,547.12 7,491.14 -7,808.57 -4,827.88 5,949,829.23 373,357.34 3.03 4,348.48 MWD+IFR-AK-CAZ-SC(7) 20,917.56 88.22 149.56 7,550.28 7,494.30 -7,890.64 -4,780.04 5,949,746.41 373,403.84 0.50 4,443.47 MWD+IFR-AK-CAZ-SC(7) 21,012.84 90.18 148.13 7,551.61 7,495.63 -7,972.16 -4,730.76 5,949,664.11 373,451.80 2.55 4,538.72 MWD+IFR-AK-CAZ-SC(7) 21,108.45 90.37 147.67 7,551.15 7,495.17 -8,053.15 -4,679.95 5,949,582.31 373,501.28 0.52 4,634.26 MWD+IFR-AK-CAZ-SC(7) 21,203.73 89.99 147.11 7,550.86 7,494.88 -8,133.41 -4,628.60 5,949,501.24 373,551.32 0.71 4,729.44 MWD+IFR-AK-CAZ-SC(7) 21,298.66 89.96 146.85 7,550.90 7,494.92 -8,213.01 -4,576.87 5,949,420.82 373,601.75 0.28 4,824.24 MWD+IFR-AK-CAZ-SC(7) 21,394.34 89.89 147.58 7,551.02 7,495.04 -8,293.45 -4,525.06 5,949,339.56 373,652.24 0.77 4,919.80 MWD+IFR-AK-CAZ-SC(7) 21,489.93 89.65 147.94 7,551.41 7,495.43 -8,374.30 -4,474.07 5,949,257.90 373,701.92 0.45 5,015.32 MWD+IFR-AK-CAZ-SC(7) 21,584.88 89.99 147.94 7,551.70 7,495.72 -8,454.77 -4,423.67 5,949,176.64 373,751.00 0.36 5,110.21 MWD+IFR-AK-CAZ-SC(7) 21,680.20 90.78 147.69 7,551.06 7,495.08 -8,535.44 -4,372.90 5,949,095.16 373,800.46 0.87 5,205.46 MWD+IFR-AK-CAZ-SC(7) 21,774.93 90.68 147.98 7,549.86 7,493.88 -8,615.62 -4,322.47 5,949,014.18 373,849.58 0.32 5,300.11 MWD+IFR-AK-CAZ-SC(7) 21,869.73 90.58 146.92 7,548.81 7,492.83 -8,695.52 -4,271.47 5,948,933.47 373,899.27 1.12 5,394.81 MWD+IFR-AK-CAZ-SC(7) 5/26/2015 1:11:01PM Page 8 COMPASS 5000.1 Build 65 a , Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 21,965.70 90.27 147.23 7,548.10 7,492.12 -8,776.08 -4,219.31 5,948,852.09 373,950.12 0.46 5,490.65 MWD+IFR-AK-CAZ-SC(7) 21,998.06 90.13 148.48 7,547.99 7,492.01 -8,803.48 -4,202.09 5,948,824.41 373,966.89 3.89 5,522.99 MWD+IFR-AK-CAZ-SC(7) 22,039.00 90.13 148.48 7,547.90 7,491.92 -8,838.37 -4,180.69 5,948,789.18 373,987.72 0.00 5,563.91 PROJECTED to TD NOT an Actual Survey 4-1/2"x 6-1/8" _(Interpolated) 22,059.00 90.13 148.48 7,547.85 7,491.87 -8,855.42 -4,170.23 5,948,771.96 373,997.90 0.00 5,583.91 PROJECTED to TD NOT an Actual Survey (Interpolated) 5/26/2015 1:11:01PM Page 9 COMPASS 5000.1 Build 65 STATE OF ALASKA AIIIIKA OIL AND GAS CONSERVATION COIrSSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate Pull Tubing r Operations Shutdow n Performed: Suspend r Perforate fl Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: I- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r 215-026-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service " 50-103-20690-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384209,380077,388902,384211 CRU CD4-93A 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 22059 feet Plugs(measured) none true vertical 7548 feet Junk(measured) none Effective Depth measured 22059 feet Packer(measured) 1839, 11787, 13658 true vertical 7548 feet (true vertical) 1771,6705, 7453 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 114 114 SURFACE 2772 13.375 2809 2389 INTERMEDIATE ' 10509 9.625 12348 6904' INTERMEDIATE : 2033 7 13820 7472' PRODUCTION 8381 4.5 22039' 7548 R �w EC E IN/ D Perforation depth: Measured depth: liner w/frac ports from 14624'-21157' MAY 132015 True Vertical Depth: 7507'-7551' A 00CC Tubing(size,grade,MD,and TVD) 3.5, L-80, 13707 MD, 7461 TVD Packers&SSSV(type,MD,and TVD) PACKER-HRD-E ZXP LINER TOP PACKER @ 1839 MD/1771 TVD PACKER-BAKER HRD-E ZXP LINER TOP PACKER @ 11787 MD/6705 TVD PACKER-BAKER HRD ZXP PACKER @ 13658 MD/7453 TVD SSSV-CAMCO TRMAXX-5E SSSV @ 2113 MD/1989 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 14600'-21200' Treatment descriptions including volumes used and final pressure: 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 new well Subsequent to operation no test yet 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: � Daily Report of Well Operations FY Exploratory f Development Service r Stratigraphic I Copies of Logs and Surveys Run r' 16.Well Status after work: Oil Pr Gas r WDSPL Printed and Eectronic Fracture Stimulation Data fl GSTOR r WINJ r WAG r GINJ r SUSP J SPLUG 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: 315-170 Contact Robert Blakney(,265-6417 Email Robert.G.Blakney(c�conocophillips.com Printed Name Ro ert Blakney Title Sr. Completions Engineer Signature -hone:265-6417 Date 5 /13 `(5 Form 10-404 Revised 5/2015 Submit Original Only WNS PROD 1111 CD4-93A ConocoPhillips 08, Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Bim(ftKB) frolot Pr+igps 501032069001 ALPINE PROD 91.41 19,392.12 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD4-93A,5113/2015 126.14 PM SSSV:NIPPLE Last WO: 36.45 11/11/2014 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --._"-... Last Tag' Rev Reason:Frac,Milled Frac Port IDs,GLV hipshkf 5/12/2015 HANGER,3111 "C CIO,Set Frac Sly 1 il -- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Se-Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .. ., CONDUCTOR 20 19.124 36.6 114.0 114.0 94.00 L-80 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I��+\SURFACE 133/8 12.415 36.8 2,808.8 2,3902_, 68.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;36.6-114.0 - n INTERMEDIATE LINER 9 5/8 8.835 1,839.2 12,348.0 6,896.7 40.00 L80 BTCM 1 XO Reducing;121.0 Liner Details Nominal ID -T . Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 1,839.2 1,771.3 32.40 PACKER HRD-E ZXP LINER TOP PACKER 9.510 1,862.5 1,790.9 33.01 HANGER BAKER FLEX LOCK III LINER HANGER 9.550 SAFTEY VLV;2,113.1 1,872.1 1,798.9 33.17 XO Reducing Liner cross over sub-10.75'1)563x95/8"BTC 8.820 (Casing) © Ii J Casing Description OD(in) ID(in) "Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WNLen(I...Grade Top Thread TIE BACK 7" 7 6.276 34.1 11,796.3 6,707.8 26.00 L80 BTCM SURFACE;36.8-2,808.8/ Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread at INTERMEDIATE LINER 7 6.276 11,787.1 13,820.0 7,472.5 26.00 L-80 Hyd 563 GAS LIFT;5,071.2 j 2 Liner Details Nominal ID GAS LIFT;9,662.2 Top(MB) Top(TVD((ftKB) Top Incl(°) Item Des Corn (in) ID la 11,787.1 6,704.5 68.63 PACKER BAKER HRD-E ZXP LINER TOP PACKER 6.200 ME 11,814.0 6,714.1 69.28 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 6.200 GAS LIFT;11,738.1 I ill 11,816.8 6,715.1 69.31 HANGER BAKER FLEX-LOCK LINER HANGER 6.220 OR 11,826.7 6,718.6 69.40 Casing 7",26#,L-80,H563 casing 6.276 TIE BACK 7-;34.1-11796.3 Intermediate 13,400.6 7,387.1 70.80 Casing 7",29#,TN-110,H563 casing 6.184 Intermediate WINDOW;11,979.0-12,000.0 Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Tap Thread PRODUCTION LINER 4 1/2 3.958 13,658.2 22,039.0 7,547.9 12.60 L-80 ATM Liner Details ;.. Nominal ID y, Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com I (in) INTERMEDIATE LINER 1; ,'L 13,658.2 7,453.1 80.24 PACKER BAKER HRD ZXP LINER TOP PACKER 4.340 1,839.2-12,348.0 NIPPLE;13,349.4 ® 13,678.0 7,456.3 80.99 NIPPLE BAKER RS PACKOFF NIPPLE 4.250 ,: 11 t 13,680.9 7,456.7 81.10 HANGER BAKER FLEX LOCK LINER HANGER 4.400 GAUGE;13,613.6 - - 13,690.0 7,458.1 81.44 SBE BAKER SEAL BORE EXTENSION W/COUPLING 4.000 i 14,508.9 7,504.6 89.02 SLEEVE CAMCO SLIDING SLEEVE 2.813 14,624.0 7,507.0 88.63 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 2.700 2.058 BAFFLE/2.099 BALL(Milled to 2.70) NO GO SUB;13,665.0 I`' MP 15,511.3 7,520.7 90.03 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 2.700 • }f• 1.993 BAFFLE/2.033 BALL(Milled to 2.70) SEAL ASSY;13,866.1 ,i I �.' 16,399.9 7,524.1 90.02 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 2.700 x ' 1.929 BAFFLE/1.968 BALL(Milled to 2.70) 17,285.9 7,531.5 90.80 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 2.700 INTERMEDIATE LINER 2; t' �`c 1.866 BAFFLE/1.904 BALL(Milled to 2.70) 11,787.1-13,820.0 18,172.4 7,533.4 90.39 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 2.700 1.805 BAFFLE/1.841 BALL,(Milled to 2.70) 19,012.2 7,551.3 90.19 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.745 Citt 1.745 BAFFLE/1.780 BALL II19,725.3 7,544.4 90.35 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.685 1.685 BAFFLE/1.720 BALL 20,441.9 7,549.0 90.48 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.625 PERFP;14,624.0-14,626.4 1 1.625 BAFFLE/1.660 BALL 21,155.0 7,550.9 90.18 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.565 1.565 BAFFLE/1.600 BALL PERFP;15,511.3-15,513.7 21,910.8 7,548.4 90.45 FRAC PORT BAKER P FRAC SLEEVE,3460 PSI 3.830 Hydrautc Fracture;14,600.0 21,920.7 7,548.4 90.42 FRAC PORT BAKER P FRAC SLEEVE,3530 PSI 3.860 PERFP;16,399.9-16,402.3 1 22,025.5 7,547.9 90.13 WIV BAKER WIV,1088 PSI 0.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection PERFP;17,285.9-17,266.4 TUBING-2015-3 31/2 2.992 31.8 13,706.8 7,460.5 9.30 L-80 EUE 1/2"x41/2"@120.9 Completion Details PERFP;18,172.4-18,174.9 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) Hydraulic Fracture;16,500.0 31.8 31.8 0.00 HANGER FMC HANGER 4 1/2"ELASTOMER 3.958 PERFP;19,012.2-19,014.7 120.9 120.9 0.02 XO Reducing XO,4.5 IBTM Box x 3.5 EUE Pin 2.992 2,113.1 1,989.1 44.17 SAFTEY VLV CAMCO TRMAXX-5E SSSV W/2.812"X PROFILE 2.812 PERFP;19,725.3-18,727.8 13,349.4 7,369.8 69.58 NIPPLE X NIPPLE W/2.813"PROFILE 2.813 13,613.8 7,444.9 78.46 GAUGE CAMCO SOLID GAUGE MANDREL W/L-WIRE 2.913 13,665.0 7,454.2 80.49 NO GO SUB LOCATING SUB 3.18"FROM NOGO 2.992 PERFP;20,441.9-20,444.3 13,666.1 7,454.4 80.54 SEAL ASSY GBH-22 seal assembly 2.990 Hydraulic Fracture;20,500.0 Perforations&Slots PERFP;21,155.0-21,157.4 Shot I Den Top(TVD) Bier(TVD) (shotslf Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date 4/7/2015 4/7/2015 4/7/2015 t) Type PERFP FRAC PORT Com PERFP FRAC PORT PERFP FRAC PORT 14,624.0 14,626.4 7,507.0 7,507.0 15,511.3 15,513.8 7,520.7 7,520.7 16,399.9 16,402.3 7,524.1 7,524.1 17,285.9 17,288.4 7,531.5 7,531.4 ,4)7/2015 PERFP FRAC PORT PRODUCTION LINER;13,658.2 -22,039.0 WNS PROD • CD4-93A ConocoPhillips Alaska,Inc. C'rnocnpr hus CD4-93A,5/13/2015 1:28:18 PM Verncal schematic(actual) ..................................................._.......................... HANGER;31.8- [;f)'J•28 n n Perforations&Slots ■ Shot ,. ...,. .. Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) 81m(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 18,172.4 18,174.9 7,533.4 7,533.3 4/7/2015 PERFP FRAC PORT 19, 12.2 19, 14.7 7,551.3 7,551.3 4/7/2015 PERFP FRAC PORT CONDUCTOR; Reducing,121.0 ., , , 19,725.3 19,727.8 7,544.4 7,544.4 4/7/2015 PERFP FRAC PORT 20,441.9 20,444.3 7,549.0 7,549.0 4/7/2015 PERFP FRAC PORT 21,155.0 21,157.4 7,550.9 7,550.9 4/7/2015 PERFP FRAC PORT Stimulations&Treatments SAFTEY VLV;2,113.1 1'_. Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com I I 20,500.0 21,200.0 7,548.4 7,550.8 Hydraulic 4/18/2015 Pumped 1st Stage.70,7128 of 16/20 proppant Fracture SURFACE;36.8-2,808.8 16,500.0 20,500.0 7,524.1 7,548.4 Hydraulic 4/19/2015 Pumped Stages 2-6,386,5898 0116/20 proppant Fracture GAS LIFT;5,071.2 Z 14,600.0 16,500.0 7,506.4 7,524.1 Hydraulic 4/22/2015 Pumped Stages 7-9,385,629#of 16/20 proppant Fracture 1111 Mandrel Inserts GAS LIFT;9,662.2 st all I MR on Top(ND) Valve Latch Port Size TRO Run GAS LIFT;11,736.1 N Top(ftKB) OMB) Make Model 00 (in) Sery Type Type (in) (psi) Run Date Com 1� 5,071.2 3,434.6 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 2,115.0 5/6/2015 2 9,662.2 5,524.1 CAMCO KBMG 1 GAS OFT GLV BK-5 0.188 2,061.0 5/6/2015 TIE BACK r;34.1-11,796.3 '. 3 11,736.1 6,685.4 CAMCO KBMG 1 GAS LIFT OV BK 0.250 5/5/2015 DCK-2 } v� Notes:General&Safety WINDOW;11,979.0-12,000.0 End Date Annotation NOTE li INTERMEDIATE LINER 1; '1 1,839.2-12,348.0 NIPPLE;13,349.4 .. GAUGE;13,813.8 NO GO SUB;13,665.0 SEAL ASSY;13,666.1 I1 .r, INTERMEDIATE LINER 2; 11,787.787.1-13,820.0 NZI PERFP;14,624.0-14,626.4 PERFP;15,511.3-15,513.7 .NI Hydraulic Fracture;14,600.0 PERFP;16,399.9-16,402.3 111 PERFP;17,285.9-17,288. PERFP;18,772.4-18,174.8 Hydraulic Fracture;18,500.0 PERFP;19,012.2-19,014.7 PERFP;19,725.3-19,727.8 PERFP;20,441.9-20,444.3 Hydraulic Fracture;20,500.0 PERFP;21,155.0-21,157.4 PRODUCTION LINER;13,858.2 -22,038.0 CD4-93A WELL WORK SUMMAR. DATE SUMMARY 4/14/2015 GAUGE TBG TO 2.78" TO 13500' SLM. **NO PROBLEMS**. ATTEMPT TO SET 2.81" PXX PLUG BODY © 13349' RKB. **POOR ACTION DUE TO DEVIATION & HEAVY FLUIDS/GRIT IN LOCK MANDREL**. IN PROGRESS. 4/15/2015 SET 3" SLIP STOP CATCHER @ 11819' SLM. PULL SOV @ 11736' RKB. REPLACE WITH DV. PULL CATCHER © 11821' SLM. SET 2.81" FRAC SLEEVE (2.28" DRIFT/2.85" NO-GO/OAL= 80") @ 2113' RKB. UNABLE TO WORK 3.89" OR 3.86" G.RING PAST 1' RKB (TBG HANGER). **READY FOR LRS TO MITT& MIT-IA**. IN PROGRESS. 4/15/2015 MIT-T TO 4000PSI WITH IA AT OPSI MIT-IA TO 3500PS1 WITH TBG AT 1500PS1 JOB COMPLETE 4/16/2015 BROACH TBG FROM 3.874"TO 3.886"TO 5' SLM. CLEAR TO XO @ 84' SLM. IN PROGRESS. 4/17/2015 BROACH TBG TO 3.896"THRU TIGHTAREA BETWEEN 1' - 3' SLM. READY FOR FRAC. 4/18/2015 Pumped injection test, Data frac and first frac stage at 20 BPM, Dropped 2 -- 1.60 frac balls without any pressure signature of sleeve shifting, shutdown to find balls or problem with launcher, well is freeze protected with 20 diesel. 70,712#of 16/20 proppant to formation. 4/19/2015 Pumped stages 2 thru 6 of fracture treatment at 20 BPM, placed 386,589#of 16/20 carbolite, Reloading SA/1/and Sand for stages 7 thru 10. Well is freeze protected with 20 bbls diesel. 4/22/2015 Performed stages 7-9 of fracture treatmentas per design. Screened out on 7 ppa of last stage (stage 10) of treatment(385,629#of 16/20 proppant to formation) Unable to squeeze freeze protect into well, tree left wrapped and heated. Fluid issues may have contributed to screenout. Began demob to vacate from Alpine. Note: See attached treatment reports 4/28/2015 MOBILZE CREWS TO ALPINE, PERFORM WEEKLY BOP TEST, PUMP 1.25" BALL TO DRIFT NEW STRING OF CT, JOB IN PROGRESS. 4/29/2015 PERFORM FILL CLEANOUT FROM SURFACE TO 12000" CTMD USING SLICK SEAWATER WITH SAFELUBE AND DUO-VIS SWEEPS AT 1.5 BPM, MAINTAINING 1:1 RETURNS THROUGHOUT CLEANOUT, MODERATE SAND CONCENTRATIONS OBSERVED, CONTINUE TO FCO DOWN TO 14624' , JOB IN PROGRESS. 4/29/2015 PERFORMED FCO USING SEAWATER AND DUO-VIS GEL SWEEPS TO 15,400' LOST RETURNS AFTER FRAC SLEEVE AT 14,624' WAS EXPOSED. NO BALL WAS ON SEAT IN FRAC SLEEVE AT 14,624' CONTINUED TO CLEAN TO NEXT FRAC SLEEVE FOR CORRELATION CHECKING WEIGHTS EVERY 100'. AT 15,400' CTMD STARTED PULLING HEAVY. WORKED COIL UPHOLE TO 13,059' CTMD. MADE C/O WITH RELIEF. JOB IN PROGRESS. 4/29/2015 WORK ON GETTING CT MOVING, AFTER 5 HOURS OF SURGING THE WELL TO SLOWLY INCH PIPE UP HOLE WE ESTABLISHED COMMUNICATION FROM CT TO THE TANKS, CT WEIGHT GOES BACK TO NORMAL AT 11000' CTMD, PUMP A 10 BBL SWEEP OF DUO-VIS TO SWEEP THE HOLE BEFORE PULLING OUT, JOB IN PROGRESS 4/30/2015 POOH, PERFORM CHAIN INSPECTION, CHANGE PACKOFFS, RIH WITH FISHING BHA TO PULL FRAC SLEEVE, JOB IN PROGRESS. 4/30/2015 PULLED FRAC SLEEVE FROM 2113' MD. MILLED FRAC PORT AT 14,624' MD. JOB IN PROGRESS. 4/30/2015 MILLED THROUGH FRAC SLEEVE#2 AT 15511' RKB AND FRAC SLEEVE#3 AT 16400' RKB, BACK REAM 3 TIMES ACROSS EACH AND DRY DRIFT, GETTING BACK HEAVY FRAC SAND WHILE MAINTAINING 1:1 RETURNS, PULL WIPER TRIP TO TBG TAIL AT 13700' IN BETWEEN EACH SLEEVE TO CLEAN UP THE HOLE, JOB IN PROGRESS 5/1/2015 CLEANING THE HOLE, PERFORMING SHORT TRIP FROM 16495' CTMD TO THE TBG TAIL AT 13700', GETTING HEAVY OVERPULLS IF WE TRY TO PULL FASTER THAN 20 FPM, JOB IN PROGRESS. 5/1/2015 POOH WITH COIL FROM STUCK POINT AT 15,100' STUCK AGAIN FROM 14,925'TO 14,905', 10,429' TO 10,327'AND AGAIN AT 6535'. METAL SHAVINGS IN RETURNS. APPEARED TO LOSE RETURNS FROM COIL TO CROSS FLOW WHILE TAKING RETURNS FROM ONE OF THE TWO EXPOSED FRACTURE ZONES. WELL FREEZE PROTECTED. JOB IN PROGRESS. 5/1/2015 TAG UP, BREAK DOWN MILLING BHA, CHANGE PACK OFFS, PERFORM CHAIN INSPECTION, RU FCO BHA AND N2 PUMP, RIH FOR A NITROFIED FILL CLEAN OUT, JOB IN PROGRESS. 5/2/2015 PERFORM NITROFIED FILL CLEANOUT FROM SURFACE TO 17286' CTMD USING SEAWATER/SAFELUBE AND DUO-VIS SWEEPS AT 1.5 BPM/500 SCFM WHILE MAINTAINING 1:1 RETURNS, MODERATE SAND CONCENTRATIONS OBSERVED, JOB IN PROGRESS. 512/2015 PULLED OOH TO SURFACE FROM 16K' CHANGED OUT PACKOFMU BHA 2 RIH TO 14,810' STARTED PULLING 10 ER. PULLED UP HOLE CONDITIONINWO SEAWATER WHILE WAITING ON N2 DUE TO ACCESS 0 RESUPPLY ROAD. JOB IN PROGRESS. 5/2/2015 WAIT 5 HOURS ON N2 TRANSPORT, LOAD SLB PUMP TRUCK, SLB PUMPERS P/T HARDLINE, JOB IN PROGRESS 5/2/2015 5/3/2015 RIH TO MILL OUT FRAC SLEEVE#4 AT 17286' RKB,PERFORM WIPER TRIP TO THE TBG TAIL AT 13500' CTMD, MILLED OUT 5TH FRAC SLEEVE AT 18172' RKB MAKING 3 REAMING PASSES THROUGH EACH, JOB IN PROGRESS. 5/3/2015 CLEANED OUT WELL FROM 18,488' CTMD USING SEAWATER AND DUO-VIS. APPEARED TO BECOME DIFFERENTIALLY STUCK AT 14,700'ACCORDING TO SLB FREE POINT CALCULATION. WORKED COIL FREE FROM DEPTH OF 17,025' CTMD TO SURFACE. FREEZE PROTECTED WELL WITH DIESEL TO 2000'TVD. READY FOR SLICK LINE. 5/4/2015 DRIFT TBG TO XN NIP © 13349' RKB w/ FULL BORE BRUSH, 2.78" G-RING. ATTEMPT TO SET PX PLUG @ SAME WAS UNSUCCESSFULL. APPEARS THAT AFTER SETTING THE PLUG BODY, POSSIBLY PUSHED TRASH INTO PLUG BODY WHEN RUNNING IN TO SET THE PRONG. IN PROGRESS 5/5/2015 PULLED PX PLUG BODY @ 13349' RKB. SET SLIP STOP CATCHER @ 11883' SLM. PULLED DGLV @ 11736' RKB, REPLACED w/ 1" OV(1/4" PORT). PULLED DGLV @ 9662' RKB. IN PROGRESS 5/6/2015 SET 1" GLV(3/16" PORT, TRO= 2061) @ 9662' RKB. PULLED DGLV @ 5071' RKB, REPLACED w/ 1" GLV(3/16" PORT, TRO= 2115). PULLED SLIP STOP CATCHER @ 11883' SLM. SET FRAC SLEEVE @ 2113' RKB. READY FOR FLOW BACK -. • • • Client: ConocoPhillips Alaska Inc. Schlumberger Well: CD4-93A Basin/Field: Colville Delta/Alpine State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Post-Job Well Completed: 4/22/2015 Date Prepared: 4/29/2015 2:25 PM Report ID: RPT-36577 Fluid Name&Vole Additive Additive Description ji Concentration Volume B882 Guar Polymer Slurry 6.1 Gal/1000 Gal 2,789.0 Gal F103 Surfactant 1.1 Gal/1000 Gal 485.0 Gal 1218 Breaker r 0.1 Lb/1000 Gal 33.0 Lb H J475 Breaker 1 9 Lb/1000 Gal 4,098.0 Lb YF127FIexD:WF127 454,826 Gal J511 Stabilizing Agent 3.3 Lb/1000 Gal 1,487.0 Lb J604 Crosslinker 2.5 Gal/1000 Gal 1,125.0 Gal L065 Scale Inhibitor i 2 Gal/1000 Gal 914.0 Gal M002 Additive 2.5 Lb/1000 Gal 1,155.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 135.0 Lb S522-1620 Propping Agent varied concentrations 874,898.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* 80.31494 % 66402-68-4 Ceramic materials and wares,chemicals 18.69511 % 64742-47-8 Distillates(petroleum),hydrotreated light 0.27318 % 9000-30-0 Guar gum 0.24627 % 107-21-1 Ethylene Glycol 0.13384 % 7727-54-0 Diammonium peroxodisulphate 0.07212 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate 0.03653 % 50-70-4 Sorbitol 0.03177 % 1310-73-2 Sodium hydroxide(impurity) 0.02488 % ................._._...___. 111-76-2 2-butoxyethanol 0.01557 % 67-63-0 Propan-2-ol 0.01557 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer 0.01548 % 11138-66-2 Gum,xanthan 0.01354 % 1330-43-4 Sodium tetraborate 0.00867 % 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) 0.00778 % 68131-39-5 C12-15 alcohol ethyoxylated 0.00778 % 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) 0.00778 % 7647-14-5 Sodium chloride 0.00738 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite 0.00711 % 7631-86-9 Silicon Dioxide 0.00438 % _ 10043-52-4 Calcium Chloride 0.00373 % 108-32-7 4-methyl-1,3-dioxolan-2-one 0.00219 % 91053-39-3 Diatomaceous earth,calcined 0.00144 % 14807-96-6 Magnesium silicate hydrate(talc) 0.00047 % 111-46-6 2,2"-oxydiethanol(impurity) 0.00039 % 10377-60-3 Magnesium nitrate 0.00029 % 68153-30-0 Amine treated smectite clay 0.00027 % 9002-84-0 poly(tetrafluoroethylene) 0.00020 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one 0.00015 % 7786-30-3 Magnesium chloride 0.00014 % 7447-40-7 Potassium chloride(impurity) 0.00012 % 2682-20-4 2-methyl-2h-isothiazol-3-one 0.00005 % 14808-60-7 Crystalline silica(impurity) 0.00003 % 14464-46-1 Cristobalite 0.00003 % Total 100 *Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 18 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 RECEIVED • STATE OF ALASKA • MAY 1 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND Mr la.Well Status: Oil ❑ ' Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0% Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. , orAband.: April 11,2015 215-026/ - 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 March 15,2015 50-103-20690-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2846'FNL,4896'FEL,Sec. 19,T11N, R5E, UM April 4,2015 CRU CD4-93A - Top of Productive Horizon: 8. KB(ft above MSL): 56'RKB 15.Field/Pool(s): 983'FSL,2479'FEL,Sec.23,T11N, R4E, UM GL(ft above MSL): 19'AMSL Colville River Field Total Depth: 1145'FNL, 1175'FWL,Sec.36,T11N, R4E, UM 9.Plug Back Depth(MD+TVD): 22059'MD/7548'TVD Alpine Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-378311 y- 5957558 Zone-4 22059'MD/7548'TVD ADL 384209,380077,384211,388902' TPI: x-370465 y- 5956241 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-373998 y- 5948772 Zone-4 SSSV @ 2113'MD/1989'TVD Tobin 932351,932036,932076 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) 1592'MD/1555'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.ly-drill/Lateral Top Window MD/TVD GR/Res,caliper 119'MD/6763'TVD MG S'?L•fs 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 154# X-65 37' 114' 37' 114' 42" 10 cu yds 13.375" 68# L-80 37' 2809' 37' 2389' 16" 319 sx Class G 9.625" 40# L-80 1839' 12348' 1770' 6904' 12.25" 643 sx Class G 7" 26#/29# L-80/T110 11787' 13820' 6704' 7472' 9.875" 699 sx Class G 7" 26# L-80 34' 11780' 34' 6702' $Z5" 147 4.5" 12.6# L-80 13658' 13706' 7453' 7460' 6 ,i 7,5- liner with frac sleeves 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 13706' 13658'MD/7453'TVD liner with frac sleeves from 13658'-13706'MD 7453'-7460'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes Li No❑ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED "FEt7 cement plug @ 12135' 39 bbls 15.8 Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) / waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 07 Buis / Irr g/`C/,, r _C4 � N REVERSERBDM�C� MAY 2 1�15ubmit original only G For? Pit 9/ .h/ �(y/ , 29. GEOLOGIC MARKERS(List all formations and marncountered): 30. • FORMATION TESTS NAME MD TVD Well tested? 0 Yes Q 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 1592' 1555' needed,and submit detailed test information per 20 AAC 25.071. HRZ 11956' 6763' Kalubik 12671' 7047' Lower Kalubik 12724' 7076' Miluveach 12879' 7163' Alpine A 14148' 7492' N/A Formation at total depth: Alpine A 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Duncan Hyden @ 265-6862 Email: Duncan.P.Hyden(a�conocophillips.com Printed Name G. L.Alvord 46at____ Title: Alaska Drilling Manager j Signature L — 1- 4,,,ti\ ,, Phone 265-6120 Date 5.I , J 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 10/2012 . 1 WNS PROD • CD4-93A ConocoPhillips `_' .Wwb Well Attributes Max Angle&MD TD hirljtiii,lit; Wellbore APIIUWI Field Name Wellbore Status tel("I MD(ftKB) Act Btm(ftKB) ro�WsBtp,`. 501032069001 ALPINE PROD 1 91.41 19,392.12 "-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD4.93A,5/11/20152:33:46 PM - SSSV:NIPPLE Last WO: 36.45 11/11/2014 Venicalschemabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SIDETRACK smsmith 5/4/2015 HANGER;31.8-- 4:A .,'.,1......._......._Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread '' CONDUCTOR 20 19.124 36.6 114.0 114.0 94.00 L-80 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Tap Thread SURFACE 133/8 12.415 36.8 2,808.8 2,390.2 68.00 L-80 BTCM Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;36.6-114.0 ..- INTERMEDIATE LINER 95/8 8.835 1,839.2 12,348.0 6,896.7 40.00 L80 BTCM XO Reducing;121.0 V 1 _ Liner Details '1, Nominal ID Top(ftKB) Top(ND)(ftKB) Top Mel(°) Item Des Com (in) - 1,8392 1,771.3 32.40 PACKER HRD-E ZXP LINER TOP PACKER 9.510 SAFTEV VLV;2,113.1 '` 1,862.5 1,790.9 33.01 HANGER BAKER FLEX LOCK III LINER HANGER 9.550 D 1 1,872.1 1,798.9 33.17 XO Reducing Liner cross over sub-10.75'H563 x 9 5/8"BTC 8.820 (Casing) SURFACE;36.a-2,808.8 ' Casing Description OD(in) ID(in) •Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' ti TIE BACK 7" 7 6.276 34.1 11,796.3 6,707.8 26.00 L80 BTCM GAS LIFT;5,071.2 8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE LINER 7 6.276 11,787.1 13,820.0 7,472.5 26.00 L-80 Hyd 563 ! 2 GAS LIFT;9,662.2 f Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) GAS LIFT;11,736.1 E. 11,787.1 6,704.5 68.63 PACKER BAKER HRD-E ZXP LINER TOP PACKER 6.200 hi11,814.0 6,714.1 69.28 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 6.200 TIE BACK 7';34.7-11,798.3 11,816.8 6,715.1 69.31 HANGER BAKER FLEX-LOCK LINER HANGER 6.220 #: ibi 11,826.7 6,718.6 69.40 Casing 7",26#,L-80,H563 casing 6.276 Intermediate WINDOW;11,979.0-12,000.0 13,400.6 7,387.1 70.80 Casing 7",29#,TN-110,H563 casing ' 6.184 �I,.: Intermediate RECEIVED ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth 2,26) Set Depth(ND)...Wt/Len(0 Grade Top Thread PRODUCTION LINER 41/2 3.958 12,140.2 1(ftKB)0 6,867.3 12.60 L-80 IBTM TopT Liner Details • Nominal ID MAY 2015 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com BAKER HRDE LINER SETTING (in) 12,140.2 6,825.4 71.36 SLEEVE SLEEVE 5.250 .l 12,155.9 6,830.5 7122 NIPPLE BAKER"RS"PACKOFF SEAL NIPPLE 4.410 Aw ^ /IIS 12,172.6 6,835.9 71.07 PACKER BAKER SHEAR RELEASE PREMER PACKER 3.870 (v�,(` _ (`/_ (90,000 lbs) PRODUCTION LINER;12,140.2 _I 12,242.0 6,858.8 70.18 NIPPLE XN PROFILE LANDING NIPPLE,3.725'no go 3.725 -12,267.0 12,263.1 6,866.0 69.71 PATCH NOV OVERSHOT CASING PATCH(5.75"OD) 4.500 INTERMEDIATE LINER i;__ (Swallows 3.18') 1,839.2-12,348.0 NIPPLE;13,349.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread . PRODUCTION LINER 41/2 3.958 13,658.2 22,039.0 7,547.9 12.60 L-80 IBTM GAUGE;13,613.8 = Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) I , 13,658.2 7,453.1 80.24 ECP BAKER HRD ZXP LINER TOP PACKER 4.340 NO GO SUB;13,665.0 r 13,678.0 7,456.3 80.99'NIPPLE BAKER RS PACKOFF NIPPLE 4.250 ri ik.j E 13,680.9 7,456.7 81.10 HANGER BAKER FLEX LOCK LINER HANGER 4.400 SEAL ASSY;13,666.1 "6I� 13,690.0 7,458.1 81.44 SBE BAKER SEAL BORE EXTENSION W/COUPLING 4.000 14,508.9 7,504.6 89.02 SLEEVE CAMCO SLIDING SLEEVE 2.813 INTERMEDIATE LINER 2; 14,624.0 7,507.0 88.63 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 2.058 11,787.1-13,820.0 2.058 BAFFLE/2.099 BALL 'fo:::1 15,511.3 7,520.7 90.03 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.993 CID 1.993 BAFFLE/2.033 BALL C1:3 16,399.9 7,524.1 90.02 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.929 1.929 BAFFLE/1.968 BALL . 17,285.9 7,531.5 90.80 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.866 PERFP;14,624.0-14,626.4 t NII111 1.866 BAFFLE/1.904 BALL 18,172.4 7,533.4 90.39 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.805 1.805 BAFFLE/1.841 BALL PERFP;15,511.3-15,513.7 int 19 012.2 7,551.3 90.19 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.745 1.745 BAFFLE/1.780 BALL PERFP;16,399.9-16,402.3 Hill 19,725.3 7,544.4 90.35 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.685 . 1.685 BAFFLE/1.720 BALL 20,441.9 7,549.0 90.48 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.625 PERFP;17,285.9-17,288.4 1III r 1.625 BAFFLE/1.660 BALL . 21,155.0 7,550.9 90.18 FRAC PORT HALLIBURTON RAPIDSTAGE FRAC SLEEVE W/ 1.565 BAFFLE/1.600 BALL 1.565 PERFP;18,172.4-18,174.9 1 NI • • 21,910.8 7,548.4 90.45 FRAC PORT BAKER P FRAC SLEEVE,3460 PSI 3.830 21,920.7 7,548.4 90.42 FRAC PORT BAKER P FRAC SLEEVE,3530 PSI 3.860 PERFP;19,012.2-19,014.7 1■6 22,025.5 7,547.9 90.13 WIV BAKER WIV,1088 PSI 0.000 PERFP;19,725.3-19,727.8 • Tubing Strings . Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-2015-3 31/2 2.992 31.8 13,706.8 7,460.5 9.30 L-80 EUE PERFP;20,441.9-20,444.3 1 ii,III 1/2"x 4 1/2"@ 120.9 Completion Details Nominal ID PERFP;27,155.0-21,157.4 'IIS Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.8 31.8 0.00 HANGER FMC HANGER 4 1/2"ELASTOMER 3.958 120.9 120.9 0.02 XO Reducing XO,4.5 IBTM Box x 3.5 EUE Pin 2.992 ' 2,113.1 1,989.1 44.17 SAFTEY VLV CAMCO TRMAXX-5E SSSV W/2.812"X PROFILE 2.812 13,349.4 7,369.8 69.58 NIPPLE X NIPPLE W/2.813"PROFILE 2.813 13,613.8 7,444.9 78.46 GAUGE CAMCO SOLID GAUGE MANDREL W/L-WIRE 2.913 PRODUCTION LINER;13, -22,039.0658.2 1 .1 L 11-, _ WNS PROD RECEIVE. CD4-93A ConocoPhillips .w Alaska.Inc. nnocnPrvals'-'9' MAY 12 2015 CD4-93A,5/11/2015 2:33:45 PMr Vertical schematic(actual) HANGER;31.8 9 Vp94;7' ___ Completion Details Nominal ID '' '' "'' ' ' " '" Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 13,665:0 7,454.2 80.49 NO GO SUB LOCATING SUB 3.18"FROM NOGG 2.952 13,666.17,454.4 80.54 SEAL ASSY GBH-22 seal assembly 2990 CONDUCTOR;36.6-114.0—• Perforations&Slots XO Reducing 121.0 Shot Dens ."'1,r Top(ND) Btm(TVD) (shotslf Top(ftKB) Bim(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 14,624.0 14,626.4 7,507.0 7,507.0 4/7/2015 PERFP FRAC PORT ISAFTEY VLV;2.113.1 15,511.3 15,513.8 7,520.7 7,520.7 4/7/2015 PERFP FRAC e RT 16,399.9 16,402.3 7,524.1 7,524.1 4/7/2015 PERFP FRAC PORT 17,285.9 17,288.4 7,531.5 7,531.4 1 _e' SURFACE;36.6-2,808,8—` + 18,172.4 18,174.9 7,533.4 7,533.3 4/7/2015 PERFP FRAC PORT GAS LIFT;5,071.2 19,012.2 19,014.7 7,551.3 7,551.3 4/7/2015 PERFP FRAC PORT I♦ 19,725.3- 19,727.8 7,544.4 7,544.4- 4/7/2015 PERFP FRAC PORT GAS LIFT;9,662.2 � 20,441.9 20,444.3 7,549.0 7,549.0 4/7/2015 PERFP FRAC PORT 21,155.0 21,157.4 7,550.9 7,550.9 4/7/2015 PERFP FRAC PORT GAS LIFT;11,738.1 1g Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run TIE BACK 7';34.7-11,798.3 N Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com ,� 1 5,071.2 3,434.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/10/2015 WINDOW;11,979.0-12,0050 2 9,662.2 5,524.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/10/2015 3 11,736.1 6,685.4 CAMCO KBMG 1 GAS LIFT SOV BEK-5 0.000 2,500.0 4/10/2015 DCK-2 I: Notes:General&Safety I ' End Date Annotation NOTE: • • • • • • I. 'I PRODUCTION LINER;12,140.2 -12,267.0 INTERMEDIATE LINER 1;_ 1,839.2-12,348.0 NIPPLE;13,349. • GAUGE;13,613.8 : ® r., NO GO SUB;13,665.0 SEAL ASSY;13,666.1 LI e/ 1 . INTERMEDIATE LINER 2; , ' 11,787.1-13,820.0 1=1 PERFP;14,624.0-14,626.4 PERFP;15,511.3-15,513.7 PERFP;16,399.9-16,402.3 PERFP;17,285.9-17,288.4 PERFP;18,172.4-18,174.9 PERFP;19,012.2-19,014.7 PERFP;79,725.3-19,727.8 il PERFP;20,441.9-20,444.3 PERFP;21,155.0-21,157A PRODUCTION LINER;13,858.2 -22,039.0 CD4-93A PRE-RIG WELL SUMMARY DATE SUMMARY • • 12/17/2014 PUMP 45 BBL OF 180* CRUDE DOWN TBG FORA FREEZE PROTECT JOB COMPLETE 1/19/2015 PULLED 4.5"WRDP-2 (S/N: HAS-251) @ -2' SLM (TBG HANGER AREA) . PACKING DAMAGED & LARGE BALL OF METAL SHAVINGS IN FLAPPER AREA. GAUGE TBG TO 3.75" TO 6000' SLM. NO PROBLEMS ENCOUNTERED. READY FOR E-LINE. 1/20/2015 STANDBY FOR WEATHER AND SLICKLINE TO DIAGNOSE METAL SHAVINGS FOUND IN WELL ON PREVIOUS JOB, 1/20/2015 RAN 3.61" MAGNET TO 12081' RKB. UNABLE TO PASS. BAILED FINE METAL SHAVINGS FROM 12081'- 12086' RKB WITH 2.5" DD BAILER. DRIFTED TO 12269' SLM WITH SAME. 1/21/2015 CLEAN OUT METAL SHAVINGS @ 12,051' RKB w/3" BLR & 3.61 MAGNET DN TO TOP OF LINER @ 12,269' RKB. MINIMAL METAL RECOVERED. READY FOR ELINE 1/22/2015 ATTEMPT TO VIDEO OBSTRUCTION AT 12268'W/ EV VIDEO CAMERA. PUMP APRROX 2750 GAL OF NITROGEN (APPROX 275000 SCF). WELLHEAD PRESSURE INCREASED TO 3500 PSI. ONLY ABLE TO DISPLACE FLUID TO 11580'. ANOTHER LOAD OF NITROGEN TO BE BROUGHT OUT IN THE MORNING TO COMPLETE JOB. JOB IN 1/23/2015 ENCOUNTER DEBRIS @ -12,150' RKB, WHILE WORKING PAST LOST DOWNVIEW PICTURE DUE TO LENS GETTING COVERED. PERFORM SIDEWALL VIDEO LOG OF 4.5" LINER TOP AND OBSTRUCTION AREA. APPEARS THAT THE LINER HAS BEEN MILLED THROUGH THE SIDE WALLS OF LINER AND CAUSED FOLDING AND COLLAPSING OF 2/14/2015 MOB TO ALPINE, SPOT UNIT 2/14/2015 PULL OV© 12076' RKB. SET DV @ SAME. READY FOR LRS & COIL. 2/14/2015 FLUID PACK TUBING, THEN PERFORM STEP INJECTIVITY TEST AT 1 BPM/1.5 BPM/2 BPM. MIT-IA TO 2000 PSI AFTER INJECTIVITY TEST 2/15/2015 TEST BOP, MU TOOLS 2/16/2015 RU CT, TAG NIPPLE @ 12,242', FLAG PIPE @ 12'210', RIH W/WEATHERFORD CEMENT RETAINER, SET @ 12,210 CTMD, PUMP 39 BBL 15.8PPG CEMENT THROUGH RETAINER, LAY IN 1 BBL ON TOP, DRESS CEMENT TOP TO 12,135' CTMD, CIRC OUT REMAINING CEMENT W/SEA WATER, FP TO 2000', JOB COMPLETE, READY FOR ELINE/SLICKLINE 2/19/2015 MITxT TO 2000 PSI (PASS) READY FOR E-LINE JOB IN PROGRESS 2/19/2015 TAG TOP OF CEMENT w/ 1.75" S.BAILER @ 12137' SLM. **RECOVERED SMALL AMOUNT OF CEMENT**. READY FOR E-LINE. 2/19/2015 MOBILIZE FROM KUPARUK TO ALPINE. STAGE EQUIPMENT WHILE STANDING BY FOR COIL AND FRAC EQUIPMENT TO BE RELOCATED. 2/20/2015 CORRELATED TO TUBING TALLY AND CUT TUBING WITH 3.625"JET CUTTER AT 12120'. OBSERVED TUBING PRESSURE DROP FROM 2200 PSI TO 0 PSI AFTER FIRING JET CUT. DISCOVERED THAT KNUCKLE JOINT SHEARED DURING JET CUT LEAVING 9.3' OF TOOLS IN THE WELLBORE. 2/22/2015 PUMPED 337 BBLS OF SW DOWN TBG PUMPED 67 BBLS OF DIESEL DOWN TBG U-TUBE TBG & IA CMIT-TxIATO 2000 PSI ***PASS*** JOB COMPLETE • • ConacoPhillips Time Log & Summary Weliview Web Reporting Report Well Name: CD4-93 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 3/7/2015 12:00:00 AM Rig Release: 4/12/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/03/2015 24 hr Summary Prep rig and camp for move across ice road. Wait on weather. (Phase 3) 00:00 12:00 12.00 0 0 MIRU MOVE WAIT T Wait on weather to move onto ice road. Continue to perform maintenance work on Mud Pump#2. Disconnect service line in pits. Rebuild BOP test pump manifold. Work on TD service loop control cables(new encapsulation). Prep Pit/Motor complexes for move(tie bars and steering rods). Inspect/perform maintenance on moving system for prep to move rig. Function test portable air compressor, secure bulk barite lines. Work on Mud pump pulsation dampeners. Laid Herculite for camp on CD4. Note: Spill Drill at 0527 hrs, CRT: 58 sec 12:00 18:00 6.00 0 0 MIRU MOVE WAIT T Work on work orders for rig electrical and mechanical maintenance. Run new MPD instrument cable to driller's console. Take mouse hole measurements for 90'mouse hole installation. 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Continue to work on work orders for rig electrical and mechanical maintenance. Continue sling and wire rope inventory. Install signage. Clean under pipe shed. PU and install split rotary bushings-27.5" bowl OD and 26-7/8"bushing ID. 03/04/2015 Continue to wait on weather and perform rig maintenance.Wind dissipated. Prep camp and move to CD4-93A. Pull ball mill, pits and motor complex away from rig. move pipe shed. Move rig off of CD3-130 well and prep to move. 00:00 08:30 8.50 MIRU MOVE WAIT T Continue to wait on weather while decreasing from Phase 3 to Phase 2. Continue maintenance work on Mud pump#2. Service pipe skate. Page 1 of 351 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 12:00 3.50 MIRU MOVE RURD T Prep Rig for move. Freeze protect equipment. Start and warm up rig genset#2, start camp generator and take Rig and camp off of highline power. Finish mounting Safe-kick control box at driller's console. Review Move checklist. Electrician disconnected Rig from pit complexes. Note: Rig and camp on generators at 1100 Hrs 3/4/15 12:00 18:00 6.00 MIRU MOVE RURD T Continue to prep rig for move, review Rig Move checklist. PJSM. Prep pits and Motors for move. Disconnect Ball mill from rig and blow down water and steam. 18:00 00:00 6.00 MIRU MOVE MOB T Review Rig Move checklist. Move rig camp to CD4-93A and set up. Disconnect service lines from rig sub to Pits. Disconnect pipe shed heater and move. Move pipe shed away from rig sub. Move Pits and Motor complexes away from sub. Skid rig floor back and pin. 33/05/2015 Finish moving camp and Ball mill onto CD4 pad and spot. Ice bridge on icce road had cracks and damage. Call for technical inspection and clearance of bridge condition. Perform remedial ice repairs, cover with matting boards and proceed with moving rig. Move rig to CD2 pad and wait on Security, as instructed, before proceeding with impassable loads. 00:00 03:30 3.50 0 0 :MIRU MOVE MOB T Continue to move rig camp and Ball mill to CD4-93A. Spot and set up. 03:30 07:00 3.50 0 0 MIRU MOVE MOB T Move matting boards from CD3 to CD4. Move shop and electrician's shack to CD4 and spot. 07:00 10:00 3.00 0 0 MIRU MOVE MOB T Inspect cracks and holes in the CD3 ice bridge. Perform remedial ice repair. Spot rig mats over the previously damaged area. Comence to move, Pits and Motor complexes, pipe shed and Rig sub, down the ice road. 10:00 21:00 11.00 0 0 MIRU MOVE MOB T Continue to move, Pits and Motor complexes, pipe shed and Rig sub over CD3 ice bridge and down the ice road to CD2 pad.. 21:00 00:00 3.00 0 0 MIRU MOVE WAIT T Rig sub wait at the junction of CD3 ice road and CD2 gravel access road, as requested by Alpine Security, 03/06/2015 Continue moving rig to CD4 pad. Spot rig over CD4-93 well. RU and accept rig. 00:00 08:30 8.50 0 0 MIRU MOVE MOB T Continue to move Rig and pipe shed from CD3 to CD4 pad. 08:30 10:00 1.50 0 0 MIRU MOVE MOB T Spot Rig next to CD4-93 well and level. Spot pipe shed next to rig. Lower rig floor suppot feet and rear cellar wind walls. Page 2 of 35 Time Logs • •, Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:45 0.75 0 0 MIRU MOVE MOB T Remove safety lock pins for rig floor. PJSM. Cantilever rig floor into position, over CD4-93 well. 10:45 12:00 1.25 0 0 MIRU MOVE MOB T PJSM. Spot Mud pit complex next to rig and spot motors. 12:00 14:00 2.00 0 0 MIRU MOVE MOB T PJSM. Spot Ball mill into position and finish spotting and connecting Pipe shed. (Clear snow near well row for the Tiger tank). 14:00 16:00 2.00 0 0 MIRU MOVE RURD T PJSM. Connect service lines at interconnect. Warm high-line power cable and junction box/Pits and Rig sub interconnect with Tioga heater per electrician. Take on water at 1400 hrs. 16:00 20:00 4.00 0 0 MIRU MOVE RURD T PJSM. Continue to work on rigging up and work on pre-spud chk list. Electrician hooked up VFD control cable to sub, install IA/Outer OA valves on wellhead, insulate under the rig floor, hook up Gas Buster and flare line and bring on brine to pits, at 2000 hrs. 20:00 00:00 4.00 0 0 MIRU MOVE RURD T PJSM. Continue to work on pre-spud chk list. Prep Mud pumps and connect line to IA valve. Note: Tbg =0 psi, IA=0 psi, OA= 300 psi at 2000 hrs Note: Rig went on high-line power at 20:30 hrs. X3/07/2015 Accept rig at 00:00 hours, RU lubricator and pull BPV. Pressure test casing to 2,000 psi. RU lines to tree and displace diesel to brine. Flow-chk. Install BPV and test tbg/BPV to 1,500 psi. ND tree, NU BOPE, install upper pipe rams. NU MPD RCD and flowlines. Test BOPE. 00:00 02:00 2.00 0 0 MIRU MOVE RURD T PJSM. Continue to work on pre-spud chk list. Note: RIG ACCEPTED on daywork at 00:00 hrs 02:00 02:30 0.50 0 0 MIRU MOVE SFTY T Pre-Spud safety meeting with crew and service hands. Note:Tbg=0 psi, IA=0 psi, OA= 300 psi at 0200 hrs 02:30 03:45 1.25 MIRU WELCTL MPSP T RD Tree cap. PU FMC lubricator, RU gauges and pressure test to 1,000 psi. Pull BPV. Blow down line to Tiger tank and cement line in cellar to ensure there are no ice plugs. Test flowline to Tiger tank with 120 psi air pressure and search for leaks -ok. 03:45 05:00 1.25 MIRU WELCTL RURD T PJSM. RU 1502 circ equip to tree for displacement of freeze protect diesel. Prime mud pumps. Page 3 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:30 0.50 MIRU WELCTL SFTY T PJSM for pressure testing and displacement. 05:30 06:30 1.00 MIRU WELCTL PRTS T Pressure test lines to 2,500 psi-ok. Bleed off pressure and line up to pump down tbg to verify circulation w/1.5 bbl-good. Blow down line to Tiger tank. Line up to pump down IA to test 7"csg/cement plug and hanger to 2,000 psi and hold for 15 min-good. Bleed off press. 06:30 09:00 2.50 MIRU WELCTL KLWL T Line up and pump down tubing with 35 bbl of Deep Clean followed by 449 bbl of 8.6 ppg seawater.Take returns to the Tiger tank. Shut down and blow down lines. 09:00 09:30 0.50 MIRU WELCTL OWFF T Flow chk for 30 min-good. (Prep BOP adapter spool for SafeKick RCD head. 09:30 10:15 0.75 MIRU WHDBO MPSP T RD circulating equipment. Set BPV. 10:15 11:00 0.75 MIRU WHDBO MPSP T RU and test BPV in direction of flow to 1,500 psi for 15 min. Bleed off pressure, blow down lines and RD test equipment. 11:00 12:00 1.00 MIRU WHDBO NUND T PJSM. B/D lines. N/D tree. 12:00 15:00 3.00 MIRU WHDBO NUND T PJSM. Continue to ND tree, install blanking plug and spacer spool. Re-position MPD equipment in cellar for NU 15:00 20:00 5.00 MIRU WHDBO NUND T PJSM. Remove bolts on BOP adapter flange and NU BOPs. 20:00 00:00 4.00 MIRU WHDBO MPDA T PJSM. MU MPD RCD bearing housing and actuator valve. Note: OA=0 psi @ 2300 hrs 03/08/2015 Finish RU of MPD equip and flowline. RU and test BOPE. RD test equip. Pull blanking plug and BPV. Flow chk, Pull tbg hanger to rig floor. CBU. Pull 4-1/2"tbg and control line and LD. (pulled 10 of 310 jts) 00:00 05:30 5.50 0 0 MIRU WHDBO MPDA T PJSM. Continue to RU MPD Flow Box, Flowline,Tripping nipple, Katch Kan, hole fill and mud bucket lines. Note:Daylight Savings time-0200- 0300 hrs 05:30 07:00 1.50 0 0 MIRU WHDBO OTHR T PJSM. Change out from 3.5 x 6"to 4.5 x 7"VBRs, in upper pipe rams. 07:00 08:15 1.25 0 0 MIRU WHDBO MPDA T Continue to RU MPD-turn buckles, Airboot(on Tripping nipple x Flow box), Katch Kan. Install mouse hole, PU 5"test joint. 08:15 10:45 2.50 0 0 MIRU WHDBO RURD T PJSM. RU BOP test equip. Fill stack and lines with water and check for leaks. Change out valve on test pump hose. Page 4 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 12:00 1.25 0 0 MIRU WHDBO BOPE T Test BOPE:With 5"testjt, test Annular to 250/2500 psi&chart for 5 min-passed. Test upper 4.5 x 7" VBRs to 250/3,500 psi and hold for 5 minutes each. Choke manifold valves#1, 9, 11, 12, 13, 14, auto/ manual IBOPs,4" Demco Kill, HCR choke/kill, man choke/kill, needle valve, to 250/3500 psi for 5 min- passed. Test witnessed by AOGCC Matt Herrera. 12:00 15:15 3.25 0 0 MIRU WHDBO BOPE T Continue to test BOPE with 5"test jt,test dart valve, FOSV, upper/lower 3-1/2"x 6"VBR's, blind rams to 250/3500 psi for 5 min-passed) Draw down test on man/super choke to 1100 psi.Accumulator test-initial 3050 psi/1500 psi after function, 28 sec to first 200 psi& 176 sec to full system pressure.4 bottles @ 1975 psi. Gas alarms tested. Test witnessed by AOGCC Matt Herrera. 15:15 17:00 1.75 0 0 MIRU WHDBO BOPE T Test BOPE:With 4.5"testjt,test Annular to 250/2500 psi&chart for 5 min-passed. Test upper 4.5 x 7" VBRs and lower 3-1/2"x 6"VBRs to 250/3,500 psi and hold for 5 minutes each. Test witnessed by AOGCC Matt Herrera. 17:00 18:45 1.75 0 0 MIRU WHDBO BOPE T Test BOPE:With 7"testjt,test Annular to 250/2500 psi and chart for 5 min-passed. Test upper 4.5 x 7"VBRs to 250/3,500 psi and hold for 5 minutes each-failed. Draw down test on man/super choke to 1100 psi. Test witnessed by AOGCC Matt Herrera. 18:45 19:30 0.75 MIRU WHDBO RURD T Pull BPV. MU testjt and pull blanking plug. 19:30 21:30 2.00 0 0 SLOT RPCOM RURD T RU casing equipment and control line spool. LD old air slips, install head pin Landing Jt B. 21:30 22:15 0.75 12,120 12,120 SLOT RPCOM PULL T Pull tubing hanger to rig floor. (165K to pull hanger free). CBU with 3-6 bbl/min, 170-680 psi. SPR#1; 20=70 psi, 30= 170 psi SPR#2; 20=60 psi, 30= 170 psi 22:15 22:30 0.25 12,120 12,120 SLOT RPCOM OWFF T Flow check. PJSM for pulling 4-1/2" tubing completion. 22:30 23:15 0.75 12,120 12,085 SLOT RPCOM PULL T PJSM. Pull and LD tbg hanger and pup, blow down lines. 23:15 00:00 0.75 12,085 11,675 SLOT RPCOM TRIP T PJSM. POOH with 4-1/2", 12.6 lb/ft, L-80, IBTM tubing with 0.25" stainless control line with stainless bands from 12,085'to 11,675'md. (10 of 310 total jts) PU= 155K Page5of35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/09/2015 24 hr Summary Continue to pull 4-1/2"tbg assembly and LD. Pull 7"packoff. PU/MU 7"spear assembly and engage casing. Pull until seals are out and observe OA pressure increase. CBU and displace out diesel freeze protect. Flow check and RU csg equip. LD csg spear and pull and LD 7"csg to 11,197'. 00:00 02:15 2.25 11,675 9,915 SLOT RPCOM PULL T Continue to POOH with 4-1/2", 12.6 lb/ft, L-80, IBTM tubing with 0.25" stainless control line with stainless bands from 11,675'to 9,915'md. 02:15 02:30 0.25 9,915 9,915 SLOT RPCOM PULL T LD SSSV and RD control line spooling equip. Cap off control line. Note: All 60 SS bands were recovered. 02:30 03:15 0.75 9,915 9,316 SLOT RPCOM PULL T Continue to POOH with 4-1/2", tubing and LD from 9,915'to 9,316' md. 03:15 03:30 0.25 9,316 9,316 SLOT RPCOM RURD T LD control line spooling equip from rig floor. 03:30 12:00 8.50 9,316 27 SLOT RPCOM PULL T Continue to POOH with 4-1/2", tubing and LD from 9,316'and to seal assembly. Cut joint(#1 in tally) was cut half way around its circumference at 7.47' from the pin end. Calc/Actual fill=45.83/54.5 bbl 12:00 12:30 0.50 27 0 SLOT RPCOM PULL T PJSM. LD seal assembly and clear rig floor. Flow chk-static. 12:30 13:30 1.00 0 0 SLOT PLUG BOPE T PU and set 7"test joint. Test upper 4-1/2"x 7"VBRs to 250/3500 psi and chart for 5 min-passed. Pull and LD test jt. 13:30 14:30 1.00 0 0 SLOT PLUG PULL T Make up Pack-off pulling tool. Verify 0 psi on OA. BOLDS and pull 7" Pack off. 14:30 15:45 1.25 0 0 SLOT PLUG PULL T PJSM on unlanding casing and circulating. Pick up Spear assembly and make up to Top Drive. Engage csg with Spear, close annular, fill pipe to monitor OA pressure. Pull seals free with 285K Ib,with weight breaking over to 275K lb while stripping seals through the annular preventer. Well"U"tubed with a pressure increase on OA side-seals out. 15:45 18:45 3.00 12,110 12,110 SLOT PLUG CIRC T Circulate sea water down 7"csg displacing out diesel freeze protect and corrosion inhibited seawater, taking returns out to the Tiger tank. Circulate 500 bbls at 4-6 bbl/min, 180-630 psi until returns clean. Blow down lines to Tiger tank and TD. 18:45 21:00 2.25 12,110 12,079 SLOT PLUG CIRC T Pull hanger to rig floor.Attempt to release casing spear but well still U-tubing. CBU at 8 BPM, 360 psi while PU/RU 7"casing equip. 21:00 21:15 0.25 12,079 12,079 SLOT PLUG OWFF T Flo-chk-static. PJSM on laying down 7"casing. Page6of35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 22:00 0.75 12,079 12,079 SLOT PLUG BHAH T Release spear from 7"csg and LD spear assembly. 22:00 22:30 0.50 12,079 12,079 SLOT PLUG RURD T PJSM. LD 7"hanger and blow down TD. Change to 7"csg elevators. 22:30 00:00 1.50 12,079 11,197 SLOT PLUG PULL T POOH with 7", L-80, 26 lb/ft, BTC-M casing from 12,079'to 11,197' (19 of 281 jts). PU=284K 03/10/2015 Continue to pull 7"csg and LD. PU/MU 9-5/8"scraper assembly and RIH picking up 5" DP. 00:00 12:00 12.00 11,197 1,652 SLOT PLUG PULL T POOH with 7", L-80,26 Ib/ft, BTC-M casing from 11,197'to 1,652' (242 of 281 jts). PU=SO=90K. Note: Had a flare or bulge in the 7" csg,evenly around the casing and 4.2'from the pin end of Jt#129 in the tally or at 5,539.8'md. OD of flared are is 7.36" 12:00 15:00 3.00 1,652 0 SLOT PLUG PULL T POOH with 7"casing from 1,652'to 0' LD tie-back seal assembly to pipe shed. Calc/Actual Fill= 112.0/ 113.5 bbl 15:00 15:30 0.50 0 0 SLOT PLUG RURD T PJSM. RU and set long wear ring. 15:30 17:15 1.75 0 0 SLOT PLUG BHAH T PJSM. Clear rig floor. LD Csg equip, PU scraper BHA. 17:15 20:30 3.25 0 0 SLOT PLUG PULD T PJSM. PU 72 jts of 5"DP and RIH to 2,225'. POOH and rack back. 20:30 22:15 1.75 0 0 SLOT PLUG TRIP T PJSM. PU 72 jts of 5" DP and RIH to 2,225'. POOH and rack back. 22:15 00:00 1.75 10 0 SLOT PLUG BHAH T PJSM. Clear rig floor. MU 9-5/8" scraper BHA to 59'.. 03/11/2015 Finish PU/MU 9-5/8"scraper and RIH picking up remaining 5" DP. Tag up on 7"csg liner top, CBU with sweep, Cut and slip DL. POOH with 9-5/8"scraper to 6,654'. 00:00 01:45 1.75 59 568 SLOT PLUG BHAH T Continue to MU 9-5/8"scraper BHA to 538'. PU=SO=90K 01:45 12:00 10.25 568 8,822 SLOT PLUG TRIP T RIH with 9-5/8"csg scraper BHA to 8,822'md. (Note: only saw a 1K bobble on the Wt indicator when entering the 9-5/8"liner top at 1,839'). SPRs at 8,085', 10:50 hrs MP#2 30=50 psi,40=90 psi 12:00 16:15 4.25 8,822 12,028 SLOT PLUG TRIP T Continue to RIH with 9-5/8"csg scraper BHA from 8,822'to 12,028' md. 16:15 17:00 0.75 12,028 12,104 SLOT PLUG WASH T PJSM. Screw in with TD and wash down with 5 BPM, 190 psi from 12,028'to 12,104'and and tag 7"liner top 17:00 18:00 1.00 12,104 12,098 SLOT PLUG CIRC T PJSM. Pump 34 bbl Hi-Vis sweep at 17.8 BPM (748 gal/min), 2,080 psi and CBU 18:00 18:15 0.25 12,098 12,098 SLOT PLUG OWFF T PJSM. Flo-chk for 15 min-static. 18:15 19:00 0.75 12,098 11,551 SLOT PLUG TRIP T PJSM. POOH from 12,080 to 11,551' (5 stds) Page 7 of 35 Time Logs ill 411 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:00 2.00 11,551 11,551 SLOT PLUG SLPC T PJSM. Cut&Cut 67'of drill line and service TD. 21:00 00:00 3.00 11,551 6,654 SLOT PLUG TRIP T PJSM. Continue POOH with 9-5/8" csg scraper from 11,551 to 6,654'(57 stds) PU= 195K, SO= 125K lb 03/12/2015 Continue to POOH with scraper and lay down same. Clean and clear rig floor. Make up and RIH with 9 5/8" CIBP Set CIBP at 12,007'md, un-sting from CIBP and press test CIBP to 2,500 psi. CBU, flo-chk-static. POOH and rack back 5"DP to 2,050'md. 00:00 03:00 3.00 6,654 629 SLOT PLUG TRIP T Continue to POOH racking back 5" drill pipe monitoring displacement on the trip tank. Up/DN wt 90K at 629' 03:00 03:15 0.25 629 629 SLOT PLUG OWFF T Check well for flow.-Good Function test Annular,4 1/2"x 7" TPR, 3 1/2"x 6" BPR's. (SIMOPS PJSM on laying down BHA) 03:15 03:45 0.50 629 79 SLOT PLUG TRIP T Continue to trip out with 1 stand of 5" DP and 5 stands of 5" HWDP. Calculate fill 100bbIs Actual fill 99bbls 03:45 04:30 0.75 79 0 SLOT PLUG BHAH T Lay down scraper BHA 04:30 06:00 1.50 0 0 SLOT PLUG BHAH T Clean and clear the rig floor. Send out scraper and bit. Pick up CIBP tools. 06:00 06:30 0.50 0 0 SLOT PLUG BHAH T MU 9-5/8"CIBP 06:30 15:30 9.00 0 11,931 SLOT PLUG TRIP T RIH with 9-5/8"CIBP to 11,931'md. Calc/Actual= 103/105 bbl. PU= 185K, SO= 130K Ib, at 7,219'. 15:30 16:00 0.50 11,931 12,007 SLOT PLUG MPSP T PJSM. MU to TD. Continue to RIH from 11,931'to 12,007'. Set CIBP at 12,007'md. Top of CIBP at 12,005'. 16:00 16:30 0.50 12,007 11,928 SLOT PLUG PRTS T PJSM. POOH from 12,007'to 11,928'. Rack back one stand of DP. Pressure test CIBP to 2,500 psi and record for 15 min.-good. 16:30 18:45 2.25 11,928 11,928 SLOT PLUG CIRC T Circulate surface to surface with 650 gpm, 1,400-1,500 psi. Blow down TD and mudline. 18:45 19:00 0.25 11,928 11,928 SLOT PLUG OWFF T PJSM. Flow chk for 15 min. -static. 19:00 00:00 5.00 11,928 2,050 SLOT PLUG TRIP T PJSM. Blow down TD and mud line. POOH from 11,928'to 2,050'. PU= 115K, SO= 100K lb. 03/13/2015 Finish POOH with CIBP running tool, LD. Pull WB and set test plug. RU test equip.Test MPD bearing housing and BOPE. RD test equip, PU/MU whipstock assembly and MWD. RIH and shallow test, continue to RIH at 4,447'. Notice:witnessing of BOPE test waived by Bob Noble of AOGCC 00:00 01:00 1.00 2,050 627 SLOT PLUG TRIP T Continue to POOH from 2050'to 627'. Flo-chk-static. Page 8 of 35 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:45 0.75 627 0 SLOT PLUG TRIP T POOH from 627'and rack back HWDP. LD CIBP running tool. Calc/ Actual= 104.22/101.5 bbl 01:45 02:45 1.00 0 0 SLOT WHDBO RURD T Drain stack, pull wear ring and install test plug. Close Blind rams, clean rig floor. 02:45 04:45 2.00 0 0 SLOT WHDBO MPDA T PJSM. RU SafeKick(SK) 1502 x 2-1/16"flange"T". Fill lines to RCD head/spool. Pull and LD trip nipple and install SafeKick 2K psi,test plug in RCD and clamp in place. RU SafeKick return lines in rig cellar. 04:45 06:00 1.25 0 0 SLOT WHDBO MPDA T PJSM. Fill lines and test RCD/ Spool/actuator valve to 250/1,000 psi and hold for 5/10 min each and record-good. Blow down lines. 06:00 06:45 0.75 0 0 SLOT WHDBO MPDA T PJSM. Un-clamp and pull SK test plug. Re-install trip nipple and air boot. RU hole fill line. 06:45 07:45 1.00 0 0 SLOT WHDBO RURD T PJSM. Install 5"test joint. RU BOP test equip. Fill stack and lines with water and check for leaks. 07:45 12:00 4.25 0 0 SLOT WHDBO BOPE T Test BOPE:With 5"testjt, test Annular to 250/2500 psi&chart for 5 min-passed. Test upper 4.5 x 7" VBRs to 250/3,500 psi and hold for 5 minutes each. Choke manifold valves#1 - 14, needle valve on#1, 4" Demco valve on Kill line, Dart valve, TD manual IBOP, FOSV, HCR Kill/Choke, manual Choke/Kill to 250/3500 psi for 5 min each. Test lower 3.5 x 6"VBRs to 250/3,500 psi and hold for 5 minutes each- good. Drain stack, swap out from 5" to 7"test jts,fill with water and purge air. 12:00 14:00 2.00 0 0 SLOT WHDBO BOPE T Test BOPE with 7"testjt. Test Annular to 250/2,500 psi,test upper/lower VBR's, blind rams to 250/3500 psi for 5 min-passed)- good. Test witnessing waived by AOGCC Bob Noble. 14:00 14:30 0.50 0 0 SLOT WHDBO BOPE T PJSM. Koomey Accumulator test- system initial-3,000 psi/1,550 psi after function, 30 sec to first 200 psi & 160 sec to full system pressure.4 bottles average- 1925 psi. SIMOPS -pull test jt. 14:30 15:15 0.75 0 0 SLOT WHDBO RURD T Pull test plug, set wear ring and blow down lines. 15:15 20:00 4.75 0 714 SLOT WHPST BHAH T PJSM. MU whipstock and orient to MWD. PU HWDP and string magnets to 714' md. 20:00 20:30 0.50 714 1,559 SLOT WHPST TRIP T RIH with whipstock from 714'to 1,559' Page 9 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:15 0.75 1,559 1,559 SLOT WHPST DHEQ T MU TD and pulse test MWD with 450 gpm, 540 psi-good. Blow down TD and mud line. 21:15 00:00 2.75 1,559 4,477 SLOT WHPST TRIP T Continue to RIH with whipstock from 1,559'to 4,477',filling pipe every 3,000'. Only 1-2K lb bobble was seen as whipstock and mills entered 9-5/8"liner. 03/14/2015 Finish RIH to 11,900' md, survey and orient. Set whipstock and shear off. Displace well to 10.4 ppg LSND, finger print new MPD system and train crews. Trouble shoot MPD software glitch. Pull RCD element and mill window in 9-5/8"csg. 00:00 08:45 8.75 4,477 11,826 SLOT WHPST TRIP T Continue to RIH with whipstock from 4,477'to 11,826', filling pipe every 3,000'and then blowing down. 08:45 09:15 0.50 11,826 11,826 SLOT WHPST CIRC T Break circulation and bring rate up to 496gpm 1220psi. Circulate until getting good signal from the MWD. Up Wt: 290k Dn Wt:155k 09:15 11:00 1.75 11,826 11,826 SLOT WHPST WPST T Orientate whip stock and tag CIBP at 12,005'. Orientate and work pipe to 49R. Set 10k down to shear anchor screws(3-1/2"Brass) Pick up to 310k and confirm anchor set. Slack off and shear 1" Brass connecting bolt at 25k down. Circulating at 496gpm 1220psi Up Wt:290k Dn Wt:155k Blow down Top Drive and Mud Line 11:00 11:15 0.25 11,826 11,826 SLOT WHPST SFTY T PJSM on installing Rotating Head with crew. 11:15 13:30 2.25 11,826 11,826 SLOT WHPST MPDA T Blow down Trip Tank fill up line and pull fitting from riser. Drain stack. Connect straps to picking eyes on riser. Pull Flow Riser Stabbed rotating head bearing 2-3k to stab pipe through element. Adjusted flow box to be more centered in the rotary table. Seated bearing in the RCD head, closed and locked clamp. 13:30 14:00 0.50 11,826 11,826 SLOT WHPST SFTY T PJSM on displacing the well to 10.4ppg LSND Discuss Target ZERO and roles and responsibilities. Designate Motor Man as the Spill Champ. Page 10 of 35 Time Logs • ` Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:45 2.75 11,826 11,826 SLOT WHPST DISP T Break circulation and pump 40bbls Hi-Vis spacer. Displace 8.6ppg seawater with 10.4ppg LSND. Pump at 340gpm and inject sea water returns as circulating. Take returns back to the pits when getting 10.2ppg back. 16:45 18:45 2.00 11,826 11,826 SLOT WHPST MPDA T Perform finger printing and training with SideKick MPD system for rig crew. 18:45 20:45 2.00 11,826 11,826 SLOT WHPST MPDA T Trouble shoot MPD control software. Not responding to ramp up commands. 20:45 23:00 2.25 11,730 11,730 SLOT WHPST MPDA T PJSM. Blow down TD and MPD equipment and manifold. Pull RCD element and stand back. Install Trip Riser. Work air boot around riser into place and energize. 23:00 00:00 1.00 11,730 11,981 SLOT WHPST MILL T PJSM. Tag top of window at 11,980'• md. Stage rotary up from 40-80 rpm. Mill window in 9-5/8"csg from 11,980'to 11,981'with 11 bbl/min and 1,440 psi. With pumps off above the window: PU=269K, SO= 162K lb. SPRs at 11,975', 23:00 hrs MP#1 20=290 psi, 30=360 psi MP#2 20=290 psi, 30=350 psi 03/15/2015 Finish milling window and 20'of new formation. CBU and perform FIT to 13.5 ppg EMW. CBU,flo-chk-static. Install RCD head, and strip OOH to 11,600'. 00:00 07:00 7.00 11,981 12,000 SLOT WHPST MILL T Continue to mill window in 9-5/8"csg from 11,981'to 12,000'with 500 gpm and 1,580 psi, 80-100 rpm, 18-20 TQ Sweep hole at 11,987'. 07:00 12:00 5.00 12,000 12,008 SLOT WHPST DDRL T Drill/Mill new formation from 12,000' to 12,008'with 500 gpm, 1,720 psi, 110 rpm, 15-17K TQ. Sweep hole at 11,995', 12,007'. PU=225K, SO= 170K, ROT= 195K(with 1 bpm), 12:00 16:15 4.25 12,008 12,020 SLOT WHPST DDRL T Drill/Mill new formation from 12,008' to 12,020'with 500 gpm, 1,700-1,650 psi, 110-120 rpm, 14-17K TQ. 16:15 16:45 0.50 12,020 12,020 SLOT WHPST REAM T Ream thru window 3X with string mills from 12,020- 11,975'and with 500 gpm, 1,650 psi, 110 rpm,20K TQ. Drift thru window w/o pumps- good. 16:45 18:30 1.75 12,020 12,020 SLOT WHPST CIRC T PJSM. CBU and pump Super sweep at 500 gpm, 1,650 psi, 110 rpm, 22K TQ. 18:30 19:00 0.50 12,020 11,954 SLOT WHPST TRIP T Pull mill assembly back inside window and rack back one stand. Blow down TD and flo-chk for 5 min- static. Page 11 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:00 1.00 11,954 11,954 SLOT WHPST FIT T Flush Kill line, RU test equip and head pin. Close top rams and perform FIT to 13.5 ppg EMW,with 10.4 ppg MW, plus 1,093 psi surface pressure applied-good. Blow down lines, RD test equip, re-open rams. 20:00 20:45 0.75 11,954 11,954 SLOT WHPST CIRC T PJSM. CBU at 11,954'and with 650 gpm, 2,360 psi. Blow down TD. 20:45 21:15 0.50 11,954 11,954 SLOT WHPST OWFF T Flow check for 30 min-static. 21:15 22:15 1.00 11,954 11,954 SLOT WHPST MPDA T Pull Trip Nipple(riser)and install RCD element at 11,954'md. 22:15 23:00 0.75 11,954 11,954 SLOT WHPST MPDA T Test software patch for MPD software and train drillers,with 650 gpm,2,380 psi-good. Blow down TD. 23:00 23:30 0.50 11,954 11,600 SLOT WHPST TRIP T PJSM. Strip OOH from 11,954'to 11,600'md, pumping 170 gpm and holding 330 psi back pressure with MPD. 23:30 00:00 0.50 11,954 11,600 SLOT WHPST TRIP T PJSM. Strip OOH from 11,954'to 11,600'md, pumping 170 gpm and holding 330 psi back pressure with MPD. 03/16/2015 Continue to strip OOH with milling BHA. LD mills and running tool. Wash stack. PU/MU drilling RSS assembly.Strip in hole, shallow test MWD. Continue to RIH. 00:00 00:45 0.75 11,600 11,043 SLOT WHPST TRIP T Continue to POOH holding back pressure with MPD from 11,600'to 11,043'md. 00:45 01:15 0.50 11,043 11,043 SLOT WHPST CIRC T Chk hole fill-good. Pump 38 bbl, 13.5 ppg slug. 01:15 06:15 5.00 11,043 4,921 SLOT WHPST TRIP T Continue to POOH holding back pressure with MPD from 11,043'to 4,921'md. 06:15 06:45 0.50 4,921 4,921 SLOT WHPST RGRP T Replace hydraulic hose on Iron Roughneck. 06:45 10:15 3.50 4,921 873 SLOT WHPST TRIP T Continue to POOH holding back pressure with MPD from 4,921'to 873'md. PU=SO=95K 10:15 12:00 1.75 873 873 SLOT WHPST MPDA T PJSM. Pull MPD element. RU to install Trip Nipple 12:00 12:45 0.75 873 873 SLOT WHPST MPDA T PJSM. Continue to install Trip Nipple-Riser. 12:45 13:15 0.50 873 650 SLOT WHPST TRIP T POOH from 873'to 650'. 13:15 14:15 1.00 650 595 SLOT WHPST BHAH T Clean metal cuttings from Extreme magnets from 650'to 595'md. 14:15 16:15 2.00 595 0 SLOT WHPST BHAH T POOH from 595'and handle window milling BHA. Clear and clean rig floor. Calc/Actual= 105/122 bbl. 16:15 17:00 0.75 0 0 SLOT WHPST BHAH T LD Milling BHA tools from rig floor Starter Mill in 8 1/2"out 1/8"under gauge Lower Mill in 8 3/8"out 1/4"under gauge Upper Mill in gauge 8 3/4" Page 12 of 35 Time Logs 4110 1111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:00 2.00 0 0 SLOT WHPST WWWH T PJSM. MU stack washer and wash stack with 4 bpm,400 psi. Blow down TD and LD stack washer. 19:00 21:30 2.50 0 138 SLOT WHPST BHAH T PU/MU 8-3/4"x 9-7/8"RSS assembly with reamer. 21:30 22:45 1.25 138 1,535 SLOT WHPST TRIP T PJSM. RIH from 138 to 1,535'. 22:45 23:30 0.75 1,535 1,535 SLOT WHPST DHEQ T PJSM. MU to TD and shallow pulse test MWD-Good. Test Rhino reamer with 500/550 gpm, 990/1,190 psi-good. 23:30 00:00 0.50 1,535 1,634 SLOT WHPST TRIP T Blow down TD, continue to RIH from 1,535'to 1,674'md. 03/17/2015 Cont.to RIH f/1,674'to 11,896'. Slip&cut drill line. Trouble shoot electrical on top drive. Install RCD element. Function test MPD equipment. 00:00 13:00 13.00 1,634 11,896 SLOT WHPST TRIP T Continue to trip in the hole from F/1,674'T/11,896' Filling pipe every 2,000' Trip as per trip schedule to keep surge at a 10.9 ppg EMW max MD Ft/Hr 0-1,000' 5,000 1,000'-3,000' 5,000 3,000'-5,000' 5,000 5,000'-7,000' 3,000 7,000'-9,000' 1,800 9,000'-11,000' 1,200 11,000-11,896' 1,000 13:00 14:30 1.50 11,896 11,896 SLOT WHPST SLPC T Slip&cut drill line 14:30 16:00 1.50 11,896 11,896 SLOT WHPST SVRG T Service rig&top drive 16:00 21:30 5.50 11,896 11,896 SLOT WHPST RGRP T Trouble shoot electrical issue with top drive. Loose connection on service loop connecting to top drive. SIMOPS-Circ B/U w/450 gpm @ 1650 psi 21:30 23:45 2.25 11,896 11,896 SLOT WHPST MPDA T Remove trip riser&install MPD RCD element. 23:45 00:00 0.25 11,896 11,979 SLOT WHPST MPDA T Function test MPD equipment& ramp up/ramp down to simulate connections f/11,896'to 11,979' 03/18/2015 Drill 8-3/4"hole to 12,170'. P/U to 12,155'&open reamer(9-7/8"hole© 12,062'). Cont to drill ahead to f/12,170'to 12,970' 00:00 00:30 0.50 11,979 12,005 SLOT WHPST TRIP T RIH through window slick f/11,979'to 12,005' 00:30 00:45 0.25 12,005 12,020 INTRM2 DRILL REAM T Wash& Ream Dn f/12,005'to 12,020'w/550gpm 2350psi, 30rpm, 12k tq. 00:45 04:30 3.75 12,020 12,170 INTRM2 DRILL DDRL T Drill ahead f/12,020'to 12,170'at reduced parameters w/550 gpm @ 2235 psi,40 rpm @ 15.5 k trq,ADT 3.14 Page 13 of 35 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:30 05:00 0.50 12,170 12,170 INTRM2 DRILL UREM T P/U to 12,155'&function 9 7/8" reamer to open position w/545 gpm @ 2448 psi&w/30rpm @ 17.2 k trq (9/7/8"hole @ 12,062') Closed under reamer:545 gpm 2460 psi 2773 trpm/Open under reamer: 545 gpm 2310 psi 2500 trpm. Under ream 8'of hole f/12,155'to 12,163'bit depth. Set 5 k WOB on under gouge hole to confirm reamer blades are open and functioning. Cont.to ream to 12,170' 05:00 12:00 7.00 12,170 12,467 INTRM2 DRILL DDRL T Drill ahead 8-3/4"X 9-7/8"hole f/12,170'to 12,467'MD 6,944'TVD. ADT 5.02 hrs ECD 11.74 ppg. 650 gpm, 2910 psi, 80 rpm, 20-22 kft lbs drilling trq. 12:00 00:00 12.00 12,467 12,970 INTRM2 DRILL DDRL T Drill ahead 8-3/4"X 9-7/8"hole f/12,467'to 12,970' MD 7,213'TVD. ADT 8.46 hrs ECD 11.74 ppg. 700 gpm, 3380 psi, 120 rpm, 21 -23 kft lbs drilling trq. 03/19/2015 Drill ahead to 13,437'. RCD bearing leaking mud. Circ clean&wt up to 10.5 ppg. Pump out of hole to 11,900'. Circ B/U&PJSM for C/O bearing. 00:00 12:00 12.00 12,970 13,383 INTRM2 DRILL DDRL T Drill ahead 8-3/4"X 9-7/8"hole f/12,970'to 13,383' MD 7,383'TVD. ADT 9.6 hrs ECD 11.75 ppg. 700 gpm, 3330 psi, 120 rpm, 21 -23 kft lbs drilling trq. 12:00 14:00 2.00 13,383 13,437 INTRM2 DRILL DDRL T Drill ahead 8-3/4"X 9-7/8"hole f/13,383'to 13,437' MD 7,400'TVD. ADT 1.44 hrs ECD 11.75 ppg. 700 gpm, 3400 psi, 120 rpm, 23 kft lbs drilling trq. (Safe Kick MPD bearing leaking mud) 14:00 14:30 0.50 13,437 13,437 INTRM2 DRILL CIRC T Cycle reamer to closed position with continuous flow. Reamer closed on 3rd attempt with rotation w/700 gpm @ 3700 psi Reamer open 700 gpm @ 3500 trpm /Reamer closed 700 gpm @ 3750 rpm 14:30 16:15 1.75 13,437 13,437 INTRM2 DRILL CIRC T Circ&weight up f/10.3 ppg to 10.5 ppg w/700 gpm 3700 psi 16:15 23:15 7.00 13,437 11,900 INTRM2 DRILL PMPO T Pump OOH f/13,437'to 11,900' w/700 gpm While holding 150 psi back pressure while pumping&510- 480 psi while on slips. (Pumped w/200 gpm @ 880 psi&holding 280 psi back pressure while pulling bit across window) Page 14 of 35 Time Logs i • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 11,900 11,900 INTRM2 DRILL CIRC T Circ B/U w/700 gpm @ 3500 psi,40 rpm @ 13 k trq. PU wt 245 k, SO wt 148 k, ROT wt 164 k 03/20/2015 Cont. to circ B/U&PJSM for C/O MPD bearing. C/O bearing. Pump in hole w/500 gpm f/11,900'to 13,437'. Open reamer&resume drilling ahead f/13,437'to TD of 13,825'. Close reamer. 00:00 00:30 0.50 11,900 11,900 INTRM2 DRILL CIRC T Cont. to circ B/U w/700 gpm @ 3500 psi,with no rotation due to bearing leaking. (SIMOPS-PJSM on C/O bearing) 00:30 03:30 3.00 11,900 11,900 INTRM2 DRILL MPDA T C/O Safe Kick MPD bearing while maintaining 450-500 psi annulus pressure. (Trap 500 psi on MPD bearing. Line up cement line to annulus. Shut annular preventer& maintain 475-500 psi with HCR kill line. Bleed off psi to MPD bearing. Replace MPD bearing as per procedure. Line back up to MPD bearing&. pressure up void to 500 psi. Open annular preventer& equalize pressure. Function test new MPD bearing with ramp up/ramp down procedure. Good test.) 03:30 11:15 7.75 11,900 13,437 INTRM2 DRILL TRIP T RIH f/11,900'to 13,327'@ 1000 ft/hr with 500 gpm @ 2120 psi as per MPD trip schedule. holding 160 psi back pressure while pumping&480 psi back pressure while in slips. Take weight at 13,327'ream through with 45rpms no problems. Continue to wash and ream down to 13,437'. Opened reamer at 13,405'with continuous flow indexing 646gpm 3160psi 3320 TRPM 60rpm Top Drive-Closed Cycle pumps to 272gpm 1,100psi Back up to 658gpm 2,960psi 3046 TRPM 60rpm Top Drive-Reamer OPEN 11:15 20:30 9.25 13,437 13,781 INTRM2 DRILL DDRL T Drill ahead 8-3/4"X 9-7/8"hole f/13,437'to 13,781' MD 7,469'TVD. ADT 6.79 hrs, ECD 11.81 ppg, 700 gpm, 3450 psi, 90 rpm, 23 kft lbs drilling trq. Increased Mud Weight from 10.5ppg to 10.7ppg 20:30 21:30 1.00 13,781 13,781 INTRM2 DRILL RGRP T Lost 300 psi. Seal/gasket on mud pump#2 leaking. Circ on mud pump #1 w/375 gpm @ 1620 psi&C/O seal gasket on mud pump#2 Page 15 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 13,781 13,825 INTRM2 DRILL DDRL T Drill ahead 8-3/4"X 9-7/8"hole f/13,781'to TD of 13,825' MD 7,472' TVD.ADT.78 hrs, ECD 11.88 ppg, 700 gpm, 3470 psi, 90 rpm, 23 kft lbs drilling trq., 17 kft lbs off bottom trq, PU wt 275 k, SO wt 145 k, ROT wt 200 k(Cycle reamer closed) Reamer open 700 gpm @ 3470 trpm /Reamer closed 700 gpm @ 3710 rpm 03/21/2015 Circ clean for 3.5 B/U.Wt up f/10.7 ppg to 11.6 ppg as per schedule. F/C. Strip OOH as per MPD schedule to 11,896'. F/C. Pump 14 ppg slug. Drop 2.77"drift. Strip OOH as per MPD schedule f/11,896'to 6,621' 00:00 03:30 3.50 13,825 13,825 INTRM2 CASING CIRC T Circ hole clean for 3.5 B/U w/700 gpm 3700 psi 03:30 14:30 11.00 13,825 13,825 INTRM2 CASING CIRC T Wt up f/10.7 ppg to 11.6 ppg as per wt up schedule. Wt up in .3 ppg increments. Initial circulating rate 700 gpm ©3700 psi, 100 rpm @ 21 k ftlbs trq. &Final circulating rate of 100 gpm @ 440 psi, 50 rpm @ 16 k ftlbs trq. 14:30 15:00 0.50 13,825 13,825 INTRM2 CASING OWFF T F/C(static) B/D top drive 15:00 18:15 3.25 13,825 11,896 INTRM2 CASING TRIP T Strip OOH as per MPD shedule f/13,825'to 11,896'. Holding 150 psi while pulling&50 psi in slips. (Tight spot @ 13,045'w/45k max overpull. Worked thru once&tight spot was free. Saw 7- 10 k drag while pulling BHA thru window) 18:15 18:45 0.50 11,896 11,896 INTRM2 CASING OWFF T F/C(static) 18:45 19:30 0.75 11,896 11,896 INTRM2 CASING CIRC T Pump 38 bbl of 14 ppg slug. B/D top drive. Drop 2.77"OD hollow drift. 19:30 00:00 4.50 11,896 6,621 INTRM2 CASING TRIP T Strip OOH as per MPD shedule f/11,896'to 6,621'. Holding 200-150 psi while pulling&50 psi in slips. 03/22/2015 Cont.to POOH to 690'. Remove RCD element. POOH& L/D BHA. C/O saver sub. R/U to run 7"liner. RIH 7" liner to 2,037'. M/U liner hanger/packer assy. Mix&pour pal mix. Cont.to RIH whiner with DP stands in derrick f/2,037'to 5,604'. 00:00 05:15 5.25 6,621 690 INTRM2 CASING TRIP T Strip OOH as per MPD shedule f/6,621'to 690'. Holding 150- 100 psi while pulling&50 psi in slips. 05:15 07:00 1.75 690 690 INTRM2 CASING MPDA T F/C&PJSM. Pull MPD element& install trip riser. 07:00 08:00 1.00 690 138 INTRM2 CASING TRIP T POOH on elevators on TT f/690'to 138'. (Racked back HWDP& swapped out jars for 30.29'jt HWDP) 08:00 10:15 2.25 138 0 INTRM2 CASING BHAH T L/D BHA as per SLB. Calc fill 118 bbls/Act fill 27 bbls 10:15 11:00 0.75 0 0 INTRM2 CASING BHAH T Clear&clean floor of BHA tools 11:00 11:15 0.25 0 0 INTRM2 CASING WAIT T Code 8 down time charged to rig for not having tools&equipment ready for next operation of C/O saver sub on top drive. Page 16 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:45 1.50 0 0 INTRM2 CASING RGRP T PJSM. C/O saver sub on top drive 12:45 13:15 0.50 0 0 INTRM2 CASING RURD T R/U power tongs tools&equipment to run 7"liner. 13:15 17:45 4.50 0 2,037 INTRM2 CASING PUTB T PJSM. RIH while picking up 7"liner as per detail to 2,037' (Baker EZ ream shoe, 1 jt 29#7"TN-110, 1 jt 29#7"TN-110 w/float insert 2'from pin, 1 jt 29#7"TN-110, 1 jt 29#7" TN-110 w/landing collar insert 2'from pin,6 jts 29#7"TN-110, 39 jts 26# L-80) 17:45 19:15 1.50 2,037 2,037 INTRM2 CASING OTHR T M/U liner hanger/packer assy&mix &pour pal mix(Liner T&D data; PU wt 108 k&SO wt 107 k) 19:15 00:00 4.75 2,037 5,604 INTRM2 CASING RUNL T RIH w/liner on drill pipe with stands out of derrick f/2,037'to 5,604'. Fill pipe every 10 stands w/fill up hose. (DP tally incudes 5 stands of HWDP @ 459') 03/23/2015 RIH with liner to top of window. Collect T&D data. Cont.to RIH with liner to set depth of 13,820'. M/U Bkaer cement head. Circ&cond mud for cement job&cut mud wt to 11.0 ppg. 00:00 22:00 22.00 5,604 13,820 'INTRM2 CASING RUNL T RIH w/liner on drill pipe with stands out of derrick f/5,604'to 13,820'. Fill pipe every 10 stands w/fill up hose. PU wt 295 k&SO wt 145k(P/U cement head&tag bottom @ 13,825') T&D at the top of window; PU wt 245 k, SO wt 158 k, ROT wt 198 k, 10 rpm @ 13.9 k ft/lbs trq, 20 rpm @ 14.5 k ft/lbs trq 22:00 00:00 2.00 13,820 13,820 INTRM2 CEMEN-CIRC T Circ&cond mud for cement job as per MPD schedule. Cut mud wt from 11.6 ppg to 11.0 ppg&reduce YP <20. Initially circ w/125 gpm @ 730 psi. Reciprocate pipe 10'stroke every 10 minutes. PU wt 295 k&SO wt 145 k 03/24/2015 Cont.to circ&cond. mud. Cement liner. Set liner hanger, set packer&release from liner. Circ out cement from top of liner lap. Displace to sea water. POOH laying down 5"DP(Tested casing to 3500 psi @ 21:00 hrs) 00:00 05:15 5.25 13,820 13,820 INTRM2 CEMEN-CIRC T Cont. Circ&cond mud for cement job as per MPD schedule. Cut mud wt from 11.6 ppg to 11.0 ppg& reduce YP<20. Initially circ w/125 gpm @ 730 psi. &final circ w/350 gpm @ 1100 psi. Circulated total of 21,000 stks. Reciprocate pipe 10' stroke every 10 minutes. PU wt 305 k&SO wt 145 k. SIMOPS-PJSM on cement job. Page 17 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 07:45 2.50 13,820 13,820 1NTRM2 CEMEN-CMNT T Cement Liner; Dowell pump 1.1 bbls H2O&psi test lines to 5000 psi (good),44.3 bbls 12 ppg mud push, 142.3 bbls Class G cement(699 sxs @ 1.16 ft3/sx yield), drop dart, 10.2 bbls H20. Rig displace with 254.8 bbls 11.0 ppg LSND, bump plug with 2494 stks, CIP @ 7:05 hrs. Initial circ rate of 6 bpm @ 200 psi&final circ rate 3 bpm @ 770 psi. Pressure up to 1260 psi&hold for 5 min. (100%returns&reciprocated pipe with 10'stroke) 07:45 08:00 0.25 13,820 11,787 INTRM2 CEMEN-PACK T Set liner hanger&packer; Pull string in tension with 320 k&pressure up f/1260 psi to 3900 psi, psi dropped to 1800 psi&hook load decreased f/320 k to 200 k, slack off to 100 k, appear to set hanger. Bleed off psi& check floats(good). Pick up on string to release from liner with 310 k &still have liner, hanger not set. Reposition liner at set depth. Pull string in tension with 310 k& pressure up to 2500 psi, psi dropped to 1650 psi&hook load decreased f/310 k to 230 k, slack off to 100 k, appear to set hanger. Pick up on string to release from liner with 310 k &still have liner, hanger not set. Reposition liner at set depth. Pull string in tension with 280 k& pressure up to 2500 psi, psi dropped to 1150 psi&hook load decreased f/280 k to 230 k, slack off to 70 k, set hanger. Pick up on string to neutral wt of 200 k&apply 4 wraps to the left,work down trq.Apply 2 more wraps for 6 total,work trq down while slacking off&seen 10 k sheer on running tool&release from liner. Release trq&pick 6'to expose dog subs. Rotate w/10 rpm @ 13 k trq& set packer with sheer indication @ 50 k wob&set total of 70 k on hook load. Repeat to confirm packer set. Release trq, pick up 23'to high circ point w/1 bpm @ 430 psi. (Liner hanger&packer set-Shoe 13,820' &TOL 11,787') 08:00 10:45 2.75 11,787 11,787 INTRM2 CEMEN CIRC T Circ&cond&circ out residual cement from top of liner w/460 gpm 1600 psi. 3 bbls cement back to surface. Circulate 1 surface to surface volume. F/C&u tubing. Cont.to circ w/700 gpm @ 2900 psi, even mud wt in/out 11.0 ppg Page 18 of 35 Time Logs III Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:30 0.75 11,787 11,787 INTRM2 CEMEN-RURD T L/D cement head 11:30 12:30 1.00 11,787 11,787 INTRM2 CEMEN PRTS T R/U&pressure liner top to 1080 psi &chart for 10 min(good) 12:30 16:00 3.50 11,787 11,787 INTRM2 CEMEN DISP T PJSM-Displace 11.0 ppg LSND to sea water. Pump 31 bbls space& chase with 1140 bbls sea water w/330 gpm @ 140-600 psi. 16:00 16:30 0.50 11,787 11,787 INTRM2 CEMEN OWFF T F/C(static. B/D top drive 16:30 21:00 4.50 11,787 8,023 INTRM2 CEMEN-PULD T POOH f/11,787'to 8,023'while laying down 5"DP 21:00 22:15 1.25 8,023 8,023 INTRM2 CEMEN-PRTS T R/U&pressure test casing to 3500 psi&chart for 30 min(good) 13.4 bbls pumped 22:15 00:00 1.75 8,023 6,478 INTRM2 CEMEN-PULD T POOH f/8,023'to 6,478'while laying down 5" DP 03/25/2015 Cont.to POOH& L/D DP. L/D liner running tools. RIH w/remaining DP in derrick. Slip&cut drill line. POOH & L/D DP. C/O saver sub&C/O upper rams. Test B.O.P.'s. Dummy run with master bushings. R/U to RIH w/clean out BHA. 00:00 06:15 6.25 6,478 0 INTRM2 CEMEN-PULD T POOH f/6,478'to surface while laying down 5" DP. F/C©460' HWDP (static) Calc Hole Fill 103 bbls/Act Hole Fill 103 bbls 06:15 07:00 0.75 0 0 INTRM2 CEMEN-BHAH T L/D Baker running tool 07:00 08:15 1.25 0 2,230 INTRM2 CEMEN-TRIPT RIH w/24 stands 5"DP from derrick 08:15 10:30 2.25 2,230 2,230 INTRM2 CEMEN SLPC T PJSM-Slip&cut 60'drill line, Service blocks&top drive 10:30 13:00 2.50 2,230 0 INTRM2 CEMEN-PULD T POOH f/2,230'to surface while laying down 5" DP 13:00 15:30 2.50 0 0 INTRM2 CEMEN-RURD T Clean&clear floor. C/O saver sub on top drive to XT 39. SIMOPS-C/O upper rams to 3-1/2"X 6"VBR's 15:30 17:30 2.00 0 0 INTRM2 WHDBO RURD T PJSM. P/U test jt&pull wear ring. R/U to test BOPE. M/U 4"safety valves to test. Set upper test plug. 17:30 22:00 4.50 0 0 INTRM2 WHDBO BOPE T Test BOPE w/4"test jt. (Annular to 250/2500 psi, Man choke valves#1 - 14,4"needle&4" Demco, HCR choke&kill, Man choke&kill, Man &auto IBOP, Upper&lower 3-1/2"x 6"VBR's, &blind rams to 250/3500 psi&chart for 5 min)Draw down on choke. Koomey test; 27 sec first 200 psi& 165 sec's to full system psi,4 bottles©2000 psi.Witness waived by AOGCC-Louis Grimaldi 22:00 22:45 0.75 0 0 INTRM2 WHDBO RURD T R/D testing equip&set 12-3/8" ID wear ring. 22:45 00:00 1.25 0 0 INTRM2 CEMEN RURD T Dummy run with new split master bushings. Install master bushings with split bowl inserts for tripping. R/U to RIH Page 19 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/26/2015 24 hr Summary M/U Baker clean out BHA. Trip in hole to 11,808'. Clean out SBE&polish off TOL. Pump sweep&circ clean. F/C. POOH&L/D BHA. Prep to C/O rams 00:00 00:30 0.50 0 0 INTRM2 CEMEN-RURD T Prep floor for tripping. C/O elevators. P/U air slips 00:30 01:30 1.00 0 26 INTRM2 CEMEN-BHAH T P/U Baker polish mill assembly& XO. 01:30 16:00 14.50 26 11,732 INTRM2 CEMEN-PULD T RIH while picking up 4"DP from pipe shed to 11,732'(racked back 4 stands in derrick) 16:00 16:45 0.75 11,732 11,809 INTRM2 CEMEN REAM T W&R f/11,732'to 11,809'w/185 gpm @ 360 psi,40 rpm©5.5-6.5 k trq(no go out on top of liner with top dress mill)Polish up SBE 4 times with 5 k WOB max. 16:45 18:00 1.25 11,809 11,809 INTRM2 CEMENT CIRC T Pump 31 bbl high vis sweep&circ clean w/560 gpm @ 2640 psi 18:00 18:30 0.50 11,809 11,809 INTRM2 CEMENT OWFF T F/C(static)B/D top drive 18:30 23:00 4.50 11,809 0 INTRM2 CEMENT TRIP T POOH on elevators on TT f/11,809 to surface. Calc Hole Fill 71.8 bbls/Act Hole Fill 69.5 bbls 23:00 23:30 0.50 0 0 INTRM2 CEMEN-BHAH T L/D polish mill BHA. Clean&clear floor 23:30 00:00 0.50 0 0 INTRM2 CEMEN"BOPE T Prep to C/O upper rams to 7". Pull wear ring&set upper test plug. 03/27/2015 C/O upper rams to 7"&test. R/U to run 7"tie back. Dummy run with 7"hanger. RIH with 7"tie back assembly,tag up on no-go, add 2.05'space out pup. Close Hydril, line up to displace. PJSM and displace 7" x 9-5/8"annulus with corrosion inhibited SW and diesel. 00:00 01:45 1.75 0 0 INTRM2 CEMEN BOPE T C/O upper rams to 7"solid body. SIMOPS-R/U to run casing 01:45 03:15 1.50 0 0 INTRM2 CEMEN BOPE T Test annular&upper 7"rams 250/3500 psi&chart for 5 min (good). RD test equip. 03:15 04:00 0.75 0 0 INTRM2 CEMEN RURD T Dummy run with 7" hanger. SIMOPS -prep shed&rig floor to run 7"tie back 04:00 18:15 14.25 0 11,755 INTRM2 CEMENT PUTB T PJSM-RIH w/7"tie back assembly to 11,755"(Baker seal assembly& 7",26 lb/ft, L-80, BTCM casing.Avg MU= 11,100 ft-lb. 1 per jt, 8-3/8" Rigid Centralizer on jts 1 &2). PU= 290K, SO= 157K. 18:15 19:30 1.25 11,755 11,806 INTRM2 CEMEN HOSO T MU swedge and cement hose to joint #282 and wash down at 2 BPM, 50 psi from 11757- 11,799'md. PU joint#283 and tag up on No-Go. 19:30 20:00 0.50 11,806 11,806 INTRM2 CEMEN PRTS T RU and test seals to 1,050 psi for 10 min-good. Page 20 of 35 411 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:45 1.75 11,806 11,786 INTRM2 CEMEN-HOSO T LD Jts#283 and#282. Pull Jt#283 and add 2.05'pup. PU/MU Landing Jt and Hanger with swedge and cement hose. RIH, locating hanger below Hydril. Close Hydril and reverse circ at 2 bpm, 60 psi and confirm not stabbed into seals. 21:45 00:00 2.25 11,786 11,786 INTRM2 CEMEN CRIH T Reverse circ: 30 bbl of Hi-Vis spacer with 3%lubes, 256 bbl of corrosion inhibited seawater. Test lines to 2,000 psi to pump freeze protect diesel. 03/28/2015 Finish displacing 7"x 9-5/8"annulus, land 7"csg, install pack-off and test. Set WB. PU and stand back remaining 4" DP(15.7 lb/ft). Change rams and test BOPE. 00:00 00:45 0.75 11,786 11,786 INTRM2 CEMEN CRIH T Continue to reverse circ: a total of 256 bbl of corrosion inhibited seawater. 00:45 02:30 1.75 11,786 11,786 INTRM2 CEMEN FRZP 'T PJSM. Test lines to 2,000 psi-good. Pump 213 bbl of diesel freeze protect at 2.2 bpm, ICP= 160 psi, FCP=380 psi. 02:30 02:45 0.25 11,786 11,801 INTRM2 CEMEN-HOSO T Strip thru Hydril and land csg at 11,801'md. (4.87'from being fully located). 02:45 03:30 0.75 11,801 11,801 INTRM2 CEMEN-RURD T Flush and blow down lines to cellar tote. RD circ equipment. Open Hydril and drain stack. Back out and lay down 7"landing Jt 03:30 04:15 0.75 11,801 11,801 INTRM2 CEMEN-WWSP T Set 13-3/8"x 7"packoff 04:15 04:45 0.50 11,801 11,801 INTRM2 CEMEN-WWSP T Test packoff to 5,000 psi and test failed at 4,200 psi.Attempt to test multiple times. Pull and inspect packoff. 04:45 05:45 1.00 11,801 11,801 INTRM2 CEMEN-WWSP T PU 4"test joint and"J" into packoff. Set 4K of TD weight on packoff. Made several attempts to test seals- fail. 05:45 06:15 0.50 11,801 11,801 INTRM2 CEMEN-WWSP T Pull packoff to rig floor and inspect. Change out damaged upper inner/outer packoff seals. 06:15 06:45 0.50 11,801 11,801 INTRM2 CEMEN-WWSP T Re-set packoff and set down with 10K of TD weight. RILDS. 06:45 07:00 0.25 11,801 11,801 INTRM2 CEMEN WWSP T Test packoff void and seals to 5,000 psi for 15 min-good. 07:00 08:30 1.50 11,801 11,801 INTRM2 CEMEN PRTS T Pump down OA and pressure test tie-back seals, 7"x 9-5/8"x 13-3/8" annulus to 2,500 psi for 30 min- good. Bled of pressure, blow down lines and RD test equip. 08:30 13:15 4.75 11,801 11,801 INTRM2 CEMEN PULD T PU and rack back 36 stds of 4", 15.7 lb/ft,XT-39 DP while monitoring well on Trip tank. Gain= Loss=0. Change out UPRs from 7"solid body rams to 3.5"x 6.0"VBRs. Page 21 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 14:45 1.50 11,801 11,801 INTRM2 CEMEN-RURD T MU floor valves for BOP test. Clear and clean rig floor. PJSM. SIMOPs- change out upper ram door seal. 14:45 16:15 1.50 11,801 11,801 INTRM2 WHDBO RURD T PU 4-1/2"test jt and set test plug. RU test equip. Fill stack, chk manifold and lines with water. 16:15 00:00 7.75 11,801 11,801 INTRM2 WHDBO BOPE T BOPE Test: Test w/4.5", 4"and 3.5" test joints, Test Annular to 250/2,500 psi for 5 min,Test UPRs and LPR 3.5"x 6"VBRs to 250/3,500 psi. Tested choke valves#1 -14, auto& man IBOP, HCR choke&kill,4" Demco,4"FOSV,dart&needle valves, HCR choke&kill to 250/3500 psi for 5 min. -good. Perform draw down test on manual and Super chokes to 1,100 psi. Koomey test; IP=3,050 psi,After close= 1,500 psi,200 psi recovery 32 sec, full recovery 183 sec, N2-4 bottle average= 1,950 psi. Conoco test with air pump-7:20 min, electric pump-69 secs. Function tested BOPE from the remote pane-good. 03/29/2015 Continue to RIH while PU 4"DP. RIH, cut and slip drill line, continue RIH, tag up on landing collar. Test csg to 3,500 psi for 30 min-good. Drill cement shoe track to 13,696. 00:00 01:15 1.25 11,801 11,801 INTRM2 WHDBO BOPE T Pull test plug. RU and flush Poor Boy gas buster thru the Super choke,with 1-3 bpm,20-300 psi. Open Blind rams. Note:witnessing of BOP test waived by Matt Herrera of the AOGCC. 01:15 01:30 0.25 11,801 11,801 INTRM2 WHDBO RURD T Blow down choke/kill lines. 01:30 02:00 0.50 11,801 0 INTRM2 WHDBO RURD T Set WB. 02:00 04:30 2.50 0 282 INTRM2 CEMEN-BHAH T PU/MU 6-1/8" RSS BHA to 282'. PU =SO=75K lb. 04:30 06:00 1.50 282 1,698 INTRM2 CEMEN-PULD T PU 4", 14 lb/ft,XT-39 DP from pipe shed to 1,698'. 06:00 06:30 0.50 1,698 1,698 INTRM2 CEMEN-DHEQ T Pulse test MWD with 250 gpm, 1,120 psi, 30 rpm, 1K TQ-good. 06:30 07:30 1.00 1,698 2,643 INTRM2 CEMEN-PULDT Continue to PU 4", 14 lb/ft,XT-39 DP from pipe shed to 2,643'md. 07:30 11:30 4.00 2,643 9,637 INTRM2 CEMEN-TRIPT Continue to RIH with 4", 14 Ib/ft, XT-39 DP from derrick to 9,637'md, filling pipe every 20 stds. Test Gas alarms-good. 11:30 12:00 0.50 9,637 10,304 INTRM2 CEMEN-PULD T Continue to PU 4", 14 lb/ft,XT-39 DP from pipe shed to 10,304'md. 12:00 15:00 3.00 10,304 12,561 INTRM2 CEMEN"PULD T Continue to PU 4", 14 lb/ft,XT-39 DP from pipe shed to 12,561'md, filling pipe every 20 stds. 15:00 16:00 1.00 12,561 12,561 INTRM2 CEMEN-SLPC T PJSM. Slip and cut 60'of drill line. 16:00 16:30 0.50 12,561 12,561 INTRM2 CEMEN-SVRG T Service TD and drawworks. Page 22 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:00 0.50 12,561 12,561 INTRM2 CEMEN-SEQP T Calibrate the Block height to the MWD. 17:00 18:00 1.00 12,561 13,554 INTRM2 CEMEN-TRIPT Continue to RIH with 4", 14 lb/ft, XT-39 DP from derrick to 13,554'md. 18:00 19:00 1.00 13,554 13,640 INTRM2 CEMEN-COCF T Wash and ream from 13,554'to 13,692' with 2 bpm, 840-1,100 psi, 30 rpm, 5.5-9.0 ft-lb TQ.Tag up on landing collar at 13,692'. Stand back one std for csg test. PU=210K, SO= 140K, ROT= 165K, TQ=5.5K. 19:00 19:30 0.50 13,640 13,640 INTRM2 CEMEN-RURD T Blow down TD and RU for casing test. 19:30 20:30 1.00 13,640 13,640 INTRM2 CEMEN-PRTS T Pressure test 7"casing to 3,500 psi for 30 min-good. RD test equip and blow down Kill line. 20:30 21:15 0.75 13,640 13,640 INTRM2 CEMEN-RURD T Bring new split bushing to rig floor. Remove old and install new split bushings in rotary table. 21:15 00:00 2.75 13,640 13,696 INTRM2 CEMEN-DRLG T Drill out landing collar with 200-240 gpm, 1,250- 1,790 psi, 30-60 rpm, 11K TQ. Stalling out TD with 2-3K WOB. Increase lubes to 2%and drill cement to 13,696'and while continuing to work pipe and stalling out TD with 11.3-11.4 ft-lb TQ. 33/30/2015 Continue to drill 7"csg shoe track. Displace well to Flo-Pro 9.0 ppg drilling mud. RU and perform FIT to 12.7 ppg EMW. Install MPD element.Wash and ream to TD, survey and drill ahead to 13,950'. 00:00 00:45 0.75 13,640 13,696 INTRM2 CEMEN-DRLG T Continue to drill out 7"shoe track from 13,696'to 13,700'with 220 gpm, 1,840 psi, 40 rpm, 11K TQ. Stalling out TD with 2-3K WOB. 00:45 03:30 2.75 13,640 13,696 INTRM2 CEMEN CIRC T Circ and increase lubes from 2%to 3%. MW increased to 9.0 ppg after circ and mixing the old mudthat was in the wellbore. Re-check free rotating torque- 11K. Increase torque limiter setting to 14K. 03:30 12:30 9.00 13,696 13,825 INTRM2 CEMEN DRLG T Continue to drill out 7"shoe track from 13,700 to 13,825'with 240- 120 gpm, 2,290-870 psi, 50-120 rpm, 5-30K WOB, 8.5- 12.5K TQ. 12:30 14:15 1.75 13,825 13,830 INTRM2 CEMEN DISP T PJSM. Pump 39 bbl H-Vis spacer and displace well with 498 bbl of 9.0 ppg Flo-Pro drilling mud while wash and reaming to btm of rat hole to 13,830' md. 14:15 15:00 0.75 13,830 13,830 INTRM2 CEMEN OWFF T Flow chk for 30 min-static. Clean out under shale shakers. 15:00 15:45 0.75 13,830 13,850 INTRM2 CEMEN DDRL T Drill 20'of new hole from 13,830-50' 15:45 16:45 1.00 13,830 13,850 INTRM2 CEMEN CIRC T CBU with 240 gpm, 2,200 psi, 60 rpm and 6K TQ. 16:45 17:00 0.25 13,850 13,850 INTRM2 CEMEN OWFF T Flow-chk for 15 min-static 17:00 17:15 0.25 13,850 13,786 INTRM2 CEMEN MPDA T Pull back inside csg to 13,786'. Break single and set in mouse hole. Blow down TD. Page 23 of 35 Time Logs • . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:15 1.00 13,786 13,786 INTRM2 CEMEN-FIT T RU test equip and perform FIT to 12.7 ppg EMW with 1,450 psi surface pressure and 9.0 ppg mud. 18:15 18:45 0.50 13,786 13,786 INTRM2 DRILL RURD T Blow down lines and RD test equip. 18:45 20:15 1.50 13,786 13,786 PROD1 DRILL MPDA T PJSM. Remove Trip Nipple and install MPD element. 20:15 21:15 1.00 13,786 13,850 PROD1 DRILL REAM T Wash and ream to bottom at 13,850' and with 240 gpm,2,100 psi, 100 rpm, 5.5K TQ. Check survey. 21:15 00:00 2.75 13,850 13,950 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/13,850'to 13,950'MD, 7,480' TVD, ADT-2.5 hrs. ECD- 10.35 ppg Footage- 100',. WOB 12K, RPM 120 GPM 250 @ 2,230 psi. PU= 197K, SO= 134K, ROT= 160K, TQ on/off=8.0/5.5K ft-lbs(2% MI-776), SPRs- 13,800'md, 15:00 hrs MP#1: 15-530 psi, 25-760 psi MP#2: 15-540 psi, 25-760 psi Note: OA=540 psi @ 22:20 hrs 03/31/2015 Drill ahead 6-1/8"lateral hole section. CBU to condition mud. Drill ahead to 15,325'md. 00:00 03:15 3.25 13,950 14,138 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/13,950'to 14,138' MD. ECD- 10.50 ppg Footage- 188', WOB 13K, RPM 120 GPM 250 @ 2,380 psi.TQ on/off=7.6/5.5K ft-lbs(2% MI-776), 03:15 04:45 1.50 14,138 14,138 PROD1 DRILL CIRC T CBU 2X with gas peaking at+1,000 units and mud cut from 9.0 to 8.3 ppg. Circ holding 100 psi back pressure and running the mud de-gasser. 04:45 12:00 7.25 14,138 14,688 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/14,138'to 14,688'MD, 7,507' TVD, ADT-8.16 hrs. ECD- 10.93 ppg Footage-550', WOB 11K, RPM 140 GPM 250 @ 2,350 psi. PU= 195K, SO= 130K, ROT= 160K, TQ on/off=6.7/4.5K ft-lbs (2%MI-776), SPRs-14,593' md, 10:40 hrs MP#1: 15-650 psi, 25-840 psi MP#2: 15-650 psi, 25-840 psi Note: OA=0 psi @ 12:00 hrs Page 24 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 14,688 15,325 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/14,688'to 15,325'MD,7,519' TVD, ADT-10.22 hrs. ECD- 10.81 ppg Footage-637', WOB 8K, RPM 140 GPM 255 @ 2,350 psi. PU= 192K, S0= 131K, ROT= 159K, TQ on/off=6.0/4.0K ft-lbs (2%MI-776), SPRs- 15,260'md,22:40 hrs MP#1: 15-660 psi, 25-820 psi MP#2: 15-660 psi, 25-800 psi Note: OA=20 psi @ 19:00 hrs 34/01/2015 Drill ahead 6-1/8"lateral hole section to 18,023'. 00:00 12:00 12.00 15,325 16,234 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/ 15,325'to 16,234' MD, 7,523' TVD, ADT-9.17 hrs. ECD- 11.19 ppg Footage-909', WOB 11.5K, RPM 140 GPM 245 @ 2,680 psi. PU= 195K, SO= 125K, ROT= 155K, TQ on/off=7.5/5.5K ft-lbs (2%MI-776), SPRs- 16,211'md, 10:30 hrs MP#1: 15-810 psi, 25-1060 psi MP#2: 15-800 psi, 25-1030 psi Note: OA= 100 psi @ 07:15 hrs 12:00 00:00 12.00 16,234 17,420 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/16,234'to 17,420'MD, 7529' TVD, ADT-9.26 hrs. ECD- 11.46 ppg Footage- 1,186', WOB 12.5K, RPM 140 GPM 245 @ 2,840 psi. PU=203K, S0= 118K, ROT= 154K, TQ on/off=9.5/6.5K ft-lbs (2%MI-776), SPRs- 16,974'md, 19:30 hrs MP#1: 15-820 psi, 25-1030 psi MP#2: 15-820 psi, 25-1020 psi Note: OA=300 psi©20:45 hrs 34/02/2015 Drill ahead 6-1/8"lateral hole section to 20,200'. Page 25 of 35 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 17,420 18,588 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/17,420'to 18,588'MD, 7,532' TVD, ADT-9.25 hrs. ECD- 11.36 ppg Footage- 1,168', WOB 7.5K, RPM 145 GPM 245 @ 2,770 psi. PU=207K, SO= 116K, ROT= 153K, TQ on/off= 12.0/7.8K ft-lbs (2%MI-776), SPRs-18,023'md, 05:45 hrs MP#1: 15-890 psi, 25-1140 psi MP#2: 15-880 psi, 25-1130 psi Note: OA=350 psi©06:30 hrs 12:00 00:00 12.00 18,588 19,643 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/18,588'to 19,643'MD, 7,545' TVD, ADT-8.89 hrs. ECD- 11.69 ppg Footage- 1,055', WOB 15K, RPM 140 GPM 250 @ 3,150 psi. PU=206K, SO= 110K, ROT= 152K, TQ on/off= 14.0/9.5K ft-lbs (2%MI-776), SPRs- 19,167'md, 18:30 hrs MP#1: 15-990 psi, 25-1230 psi MP#2: 15-980 psi, 25-1210 psi Note: OA=400 psi @ 20:00 hrs 04/03/2015 Drill ahead 6-1/8"lateral hole section to 21,813'. 00:00 12:00 12.00 19,643 20,775 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/19,643'to 20,775'MD,7,544' TVD, ADT-9.35 hrs. ECD- 11.87 ppg Footage- 1,132', WOB 9K, RPM 140 GPM 250 @ 3,170 psi. PU=210K, SO= 105K, ROT= 157K, TQ on/off= 14.5/10.0K ft-lbs (2%MI-776), SPRs-20,120'md, 05:00 hrs MP#1: 15-1000 psi, 25-1260 psi MP#2: 15-970 psi, 25-1210 psi Note: OA=400 psi @ 20:00 hrs Page 26 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 20,775 21,813 PROD1 DRILL DDRL I T Drill 6-1/8"hole w/SWS Power Drive RSS f/20,775'to 21,813' MD,7,594' TVD, ADT-9.14 hrs. ECD-11.45 ppg Footage- 1,038', WOB K, RPM 140 GPM 250 @ 2,750 psi. PU=225K, SO= 103K, ROT= 151K, TQ on/off= 15.5/10.1K ft-lbs (2%MI-776), SPRs-21,359'md, 19:150 hrs MP#1: 15-1060 psi, 25-1260 psi MP#2: 15-1070 psi, 25-1300 psi Note: OA=300 psi @ 12:00 hrs 04/04/2015 Drill ahead to 6-1/8" lateral hole section TD. CBU 6X. displace hole to 10.5 lb/gal NaCI/NaBr fluid. Strip OOH to 21,445'. 00:00 03:15 3.25 21,813 22,059 PROD1 DRILL DDRL T Drill 6-1/8"hole w/SWS Power Drive RSS f/21,813'to 22,059'MD, 7,547' TVD, ADT-2.52 hrs. ECD- 11.73 ppg Footage-246', WOB 12K, RPM 140 GPM 250 @ 3,030 psi. PU=220K, SO= 100K, ROT= 157K, TQ on/off= 15.5/11.0K ft-lbs ,(2%MI-776), Note: OA=350 psi @ 07:15 hrs 03:15 06:15 3.00 22,059 22,059 PROD1 CASING CIRC T C&C mud 2X bottoms up,with 250 gpm, 3,180 psi, 140 rpm, 13-14K TQ. Blow down TD. 06:15 06:30 0.25 22,059 22,059 PROD1 CASING OWFF T Close MPD choke and rotate at 10 rpm, 10.5-11.0 ft-lb. Monitor pressure buildup and stabilize at 569 psi. 06:30 19:30 13.00 22,059 22,059 PROD1 CASING CIRC T C&C mud with 250 gpm,3,440- 3,270 psi, 140 rpm, 13.5-12.5K TQ. Blow down TD. 19:30 19:45 0.25 22,059 22,059 PROD1 CASING SFTY T PJSM for displacing well to 10.5 ppg fluid. 19:45 22:15 2.50 22,059 22,059 PROD1 CASING DISP T Displace well to 10.5 ppg NaCI/ NaBr fluid at 250 to 120 gpm, ECD- 11.93 to 11.57 ppg, 140-60 rpm, 12.3-8.3 ft-lb TO. SPRs-21,359'md, 19:150 hrs MP#1: 10-400 psi MP#2: 10-390 psi Note: Had 10.5 ppg fluid circulated to surface at the calculated guage hole volume. Page 27 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 22,059 22,059 PROD1 CASING OWFF T Rotate at 10 rpm and close MPD choke. Pressure built from 20 psi to 59 psi in 10 min. Open choke to allow exhale to zero psi for 10 min, with a 0.5 bbl gain. Close choke and build from 6 psi to 32 psi in 10 min. and stabilizing. 22:45 23:15 0.50 22,059 22,026 PROD1 CASING PULD T LD single joint(used while circulating to keep TD below windwalls). Blow down TD. 23:15 00:00 0.75 22,026 21,455 PROD1 CASING TRIP T Strip OOH from 22,026'to 21,455' and per schedule,while pumping at 2 bpm, holding 350 psi when stripping and 30-50 psi when set in slips. No overpull. 04/05/2015 Continue to strip OOH to the 7"csg shoe, flow check for 30 min, continue to strip OOH to 8,217'. 00:00 08:45 8.75 21,455 13,755 PROD1 CASING TRIP T Strip OOH from 21,455'to 13,735' and per schedule,while pumping at 2 bpm, holding 350 psi when stripping and 30-50 psi when set in slips. Calc/Actual=53.6/87 bbl. PU= 190K, SO= 135K(10.5 ppg brine). OA=0 psi at 11:00 hrs 08:45 12:00 3.25 13,755 13,755 PROD1 CASING OWFF T Flow chk-Shut down mud pump, close MPD choke. Pressure built to 57 psi in 27 min. Bled 0.25 bbl to trip tank. Close MPD choke again and pressure built to 55 psi in 34 min. Open choke and bleed off pressure, flowing back to a tote in the cellar. Initial calculated flow back rate FBR =2.5 bbl/hr, final FBR= 1.8 bbl/hr. 12:00 14:30 2.50 13,755 13,755 PROD1 CASING OWFF T Continue to flow back to a tote in the cellar. Initial calculated flow back rate FBR= 1.59 bbl/hr, final FBR= 1.41 bbl/hr. 14:30 16:00 1.50 13,755 13,755 PROD1 CASING OWFF T Blow down cement line to cellar. Shut in MPD choke and monitor pressure build up to 47 psi. Confer with town and decide to weight up from 10.5 to 10.7 ppg. 16:00 18:45 2.75 13,755 13,755 PROD1 CASING CIRC T Circulate and increase brine weight to 10.7 ppg, adding NaBr. Circ at 200 gpm, 1,710 psi, 20 rpm, 2.5-3.0 ft-lb TQ. 18:45 19:30 0.75 13,755 13,755 PROD1 CASING OWFF T IIClose MPD choke, blow down TD land monitor pressure build up. No pressure-well static. Page.28 of 35 Time Logs Date From To Dur S. Uepth E. Depth Phase Code Subcode T Comment 19:30 20:15 0.75 13,755 13,755 PROD1 CASING CIRC T PU= 178K, SO= 150K, ROT= 165K, torque at 20 rpm =3K ft-lb. Pump 26 bbl, 12.5 ppg dry job. Blow down TD. SPRs- 13,755'md, 19:45 hrs MP#1: 10-250 psi, 20-470 psi MP#2: 10-260 psi, 20-490 psi 20:15 00:00 3.75 13,755 8,217 PROD1 CASING TRIP T Strip OOH from 13,735'to 8,217'and per schedule,while pumping at 2 bpm, holding 270-300 psi when stripping and 30 psi when set in slips. PU= 135K 04/06/2015 Continue to strip OOH to 1,000'. Remove MPD element, Flow check, POOH and LD BHA. RU casing equip, PU/MU 4-1/2"liner assembly and Frac sleeves, RIH to 13,800', CBU, check parameters, flow chk and PU 4" HWDP. 00:00 04:45 4.75 8,217 1,036 PROD1 CASING TRIP T Strip OOH from 8,217'to 1,036'and per schedule,while pumping at 2 bpm, holding 270-280 psi when stripping and 30 psi when set in slips. 04:45 05:00 0.25 1,036 1,036 PROD1 CASING OWFF T Flow chk-static. PJSM for pulling MPD element 05:00 06:15 1.25 1,036 1,036 PROD1 CASING MPDA T Blow down MPD chokes and cement line to cellar. Pull MPD element, set and install Trip nipple. 06:15 07:15 1.00 1,036 282 PROD1 CASING TRIP T POOH from 1,036'to 282', monitoring well on Trip tank. 07:15 08:45 1.50 282 0 PROD1 CASING BHAH T PJSM. LD 6-1/8"RSS drilling BHA. Total trip-Calc/Actual Fill= 137/ 213 bbl. 08:45 10:00 1.25 0 0 PROD1 CASING BHAH T Clear and clean rig floor. LD BHA tools from floor. 10:00 11:00 1.00 0 0 COMPZ CASING RURD T PJSM. RU casing tools for4-1/2" liner. 11:00 12:00 1.00 0 108 COMPZ CASING PUTB T PJSM for running 4-1/2"liner. PU 5.75" EZ Ream float shoe and 4.5" Wellbore Isolation Valve. 12:00 13:30 1.50 108 524 COMPZ CASING PUTB T RIH with 4-1/2", 12.6 lb/ft, L-80, IBTM, R3, SCC with torque rings installed. MU to 5,700 ft-lb with Jet-Lube, Run-N-Seal thread dope. Note: special clearance collars- 4.92"OD. 13:30 15:00 1.50 524 0 COMPZ CASING PULL T PJSM. POOH and MU WIV to proper torque. 15:00 00:00 9.00 0 7,630 COMPZ CASING PUTB T Continue to RIH with 4-1/2", 12.6 lb/ft, L-80, IBTM, R3, SCC to 7,630' md. 34/07/2015 Run 4-1/2", 12.6 lb/ft, L-80, IBTM production liner to TD. Drop WIV ball and pressure test liner to 2,500 psi for 30 min-good. Set liner hanger, release, set liner top packer, test, Displace well to seawater. 00:00 00:45 0.75 7,630 8,325 COMPZ CASING PUTB T Continue to RIH with 4-1/2", 12.6 lb/ft, L-80, IBTM, R3, SCC from 7,630' to 8,325'md. Page 29 of 35 Time Logs . •` Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 01:45 1.00 8,325 8,481 COMPZ CASING OTHR T Make up 5"Seal Bore Extension, 5" x 7"liner hanger and 5"x 7" Liner Top packer to 8,481' . Mix and fill with quick set PAL mix. MU 4-1/2" IBTM x 3-1/2" IF, Liner x DP XO. PU= 119, SO= 100K. 01:45 02:45 1.00 8,481 8,481 COMPZ CASING CIRC T Circ 1X liner volume with 3 bpm, 320 psi. RD csg equip, install DP elevators. 02:45 08:00 5.25 8,481 13,777 COMPZ CASING RUNL T Continue to run liner on 4"DP from 8,481'to 13,777', filling pipe every 20 stds. Calc=65.4/ Actual=52.5 bbl 08:00 10:45 2.75 13,777 13,777 COMPZ CASING CIRC T RU headpin on DP and circ with 3-1 bpm 510- 150 psi. SIMOPs: PJSM, PU 17 stds of 4", 28.9 lb/ft HWDP via the mouse hole and rack back. No losses while circulating. 10:45 11:00 0.25 13,777 13,777 COMPZ CASING CIRC T Obtain parameters-PU= 175K, SO= 130K, ROT= 152K. Free rotating torque=3.6K ft-lb at 10 rpm,4.0K at 20 rpm.. 11:00 11:30 0.50 13,777 14,310 COMPZ CASING RUNL T Continue to run liner on 4"DP from 13,777'to 14,310', 11:30 20:30 9.00 14,310 22,039 COMPZ CASING RUNL P Continue to run liner on 4" DP from 14,310'to 22,059', filling pipe every 20 stds. Tag bottom, set down 10K to verify. PU=240K, S0= 125K. Locate liner on depth at 22,039'and 20:30 00:00 3.50 22,039 22,039 COMPZ CASING CIRC P Circ and cond mud until even 10.7 ppg in/out, at 1 -4.5 bbl/min and 350- 1,400 psi stand pipe pressure. 04/08/2015 Displace well to seawater, flow chk, cut and slip drill line and POOH laying down 4" DP. 00:00 00:30 0.50 22,039 22,039 COMPZ CASING CIRC P Continue to circ and cond mud until even in/out, at 4.5 bbl/min and 1,380 psi stand pipe pressure. 00:30 02:00 1.50 22,039 22,039 COMPZ CASING CIRC P Blow down TD,drop 1.25"WIV closing ball down DP. RU head pin and pump with 4.5-2.0 bbl/min, 1,280-760 psi. Ball on seat after 245 bbl pumped, increase pressure and close WIV. Hold 2,500 psi on liner and WIV. 02:00 03:15 1.25 22,039 22,039 COMPZ CASING PRTS P Test WIV and liner to 2,500 psi and record data. Bleed off pressure and RD test equip. Page 30 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:45 0.50 22,039 22,039 COMPZ CASING PACK T MU to Top Drive and slackoff to 70K verifying liner hanger set. Pressure up to 2,900 psi(P-sleeve pressure limit). Bleed off pressure and PU to 245K-not released from hanger. Proceed to attempt to release by applying left hand turns to drill string. Work 3 LH turns into string. Release torque and slackoff to 90K and PU to 145K, multiple times.Apply 5 LH turns of torque to drill string followed by releasing torque and working drill string-not released. 03:45 05:00 1.25 22,039 13,648 COMPZ CASING PACK P Blow down TD due to time. Repeat the process by applying 7, 9, 11, 13, 14 left hand turns to drill string with TQ limiter set at 3.7K ft-lb and working torque into drill string with 150K up and slacking off to 70K. PU to the on bottom weight of liner (240K)verifying not released from hanger until 14 LH wraps applied. PU to 200K verifying free from liner hanger. Rotate at 20 rpm, 5.5K torque and slack off to 115K setting liner top packer at 13,658'md. . PU above liner and close 3.5"x 6"pipe rams. 05:00 05:45 0.75 13,648 13,648 COMPZ CASING PRTS P Test liner top packer and 7"csg annulus to 2,500 psi for 30 min- good. 05:45 06:00 0.25 13,648 13,624 COMPZ WELLPF TRIP P POOH to 13,624'and un-sting running tool from RS seal nipple. PU=200K, SO= 165K. 06:00 06:15 0.25 13,624 13,624 COMPZ WELLPF SFTY P PJSM for displacement. 06:15 08:15 2.00 13,624 13,624 COMPZ WELLPF DISP P Displace well from 10.7 ppg NaCI/ NaBr brine to 8.6 ppg seawater at 8-6 bpm, 3,040- 1,210 psi. Obtain SPRs and blow down TD. SPRs-13,624'md, 08:00 hrs MP#1: 20-160 psi, 30-330 psi MP#2: 20-160 psi, 30-330 psi Note: OA=0 psi @ 11:00 hrs 08:15 08:45 0.50 13,624 13,624 COMPZ WELLPF OWFF P Flow chk for 30 min-static. PJSM for slip and cut drill line. 08:45 09:30 0.75 13,624 13,624 COMPZ WELLPF SLPC P Slip and cut 60'of drill line. Gain= Loss=0. 09:30 10:00 0.50 13,624 13,624 COMPZ WELLPF SVRG P Service rig. Gain=Loss=O. 10:00 23:00 13.00 13,624 0 COMPZ WELLPF PULD P POOH and LD 14"HWDP and 14" DP. 23:00 23:30 0.50 0 0 COMPZ WELLPF BHAH P Inspect liner running tool-ok. LD RT to pipe shed. Clear and clean the rig floor. Page 31 of 35 Time Logs 11, Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 667 COMPZ WELLPF TRIP P RIH with 4" DP from the derrick to 667'. 34/09/2015 RIH with stood back 4"DP and POOH laying down the same. RU test equip and test BOPs with 3-1/2"test joint. RD test equip, RU tubing running tools. RIH with 3-1/2"tubing assembly+ I-wire to 1,954'. 00:00 03:30 3.50 667 9,817 COMPZ WELLPF TRIP P Continue to RIH with 4"DP from the derrick from 667'to 9,817'(102 stds). PU= 160K, SO= 135K. 03:30 11:00 7.50 9,817 0 COMPZ WELLPF PULD P POOH laying down 4"DP to pipe shed. 11:00 11:15 0.25 0 0 COMPZ WHDBO RURD P Clear and clean rig floor. RU test equip and PU 3-1/2" test joint. Drain stack. 11:15 11:30 0.25 0 0 COMPZ WHDBO RURD P Pull wear ring 11:30 12:30 1.00 0 0 COMPZ WHDBO RURD P Set 3-1/2"test joint and test plug. RU pressure recorders. Fill stack and choke manifold with water. 12:30 16:30 4.00 0 0 COMPZ WHDBO BOPE P PJSM. Test BOPE w/3-1/2"test jt. Test Annular to 250/2500 psi. Test Upper&lower 3-1/2"x 6"VBR's, & Blind rams to 250/3500 psi&chart for 5 min. Test HCR choke&kill, Man choke&kill, Man&auto IBOP to 250/3,500 psi. Choke manifold valves#1, #12-14, 4"needle and 4" Demco Kill line to 250/3,500 psi. Test needle valve, Choke manifold valves 5,8,10, Dart valve,valves# 4,6,7, 3,4,6.-all good. Accumulator test: initial pressure- 3,000 psi, after closing= 1,500 psi. Build back up by 200 psi,to 1,700 psi in 26 sec and 169 seconds to build back to full system pressure. 4 bottles at 1,950 average pressure. Witnessing of test waived by AOGCC-Jeff Jones 16:30 17:00 0.50 0 0 COMPZ WHDBO RURD P Pull test plug, blow down Choke/Kill lines and clean under rig floor. 17:00 19:00 2.00 0 0 COMPZ RPCOM RURD P PJSM. RU tubing equipment, I-wire, Control line spools, sheaves in derrick. 19:00 00:00 5.00 0 0 COMPZ RPCOM PUTB P PJSM. Run 3-1/2", 9.3 lb/ft, L-80 EUE with I-wire and Cannon clamps to 1,954'. MU to 2,600 Ib,with Run-N-Seal thread compound. 04/10/2015 Continue to run 3-1/2"tubing completion. Tag up, space out, PU and spot corrosion inhibited brines,stab back in and set tubing hanger. 00:00 14:30 14.50 1,954 11,585 COMPZ RPCOM PUTB P PJSM. Run 3-1/2", 9.3 Ib/ft, L-80 EUE with I-wire and Cannon clamps from 1,954' to 11,585'. MU to 2,600 Ib,with Run-N-Seal thread compound. Check I-wire continuity every 1,000'. Page 32 of 35 4110 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 15:15 0.75 1,954 11,585 COMPZ RPCOM PUTB P Connect 0.25"stainless control line to SSSV and pressure test connections and line to 6,000 psi for 10 min-good. 15:15 16:15 1.00 11,585 13,653 COMPZ RPCOM PUTB P PJSM. Run 3-1/2", 9.3 Ib/ft, L-80 EUE with I-wire and Cannon clamps from 11,585 to 13,653'. PU= 137K, SO= 105K. Cannon clamps: (431)3-1/2" Full clamps, (9)3-1/2" 1/2 clamps, (2)3-1/2"Safety Valve Stand-off clamps, (1)4-1/2"x3-1/2"XO clamp, (2)3-1/2"Safety Valve Stand-off clamps, (1)4-1/2"x3-1/2"XO clamp, 16:15 18:45 2.50 13,653 13,710 COMPZ RPCOM HOSO T MU head pin and line to tubing string.Wash down pumping at 2 bpm and 140 psi to confirm seal entry. Shut down pumps and RIH to 13,710'and slack off with 10-15K lb. Work several times but unable to run past 13,710'. 18:45 19:15 0.50 13,691 13,710 COMPZ RPCOM HOSO T PU out of SBE to 13,691'. Pump with 4 bpm 530-570 psi and attempt to cleanup liner top while conferring with town. RIH but unable to move past 13,710'. 19:15 19:45 0.50 13,710 13,690 COMPZ RPCOM HOSO T PU out of SBE to 13,690'. Pump with 4-6 bpm 510- 1,080 psi and attempt to cleanup liner top. 19:45 20:00 0.25 13,690 13,713 COMPZ RPCOM HOSO P RIH to 13,713'w/o problem. Pressure test seals and tbg to 1,000 psi-ok. 20:00 20:15 0.25 13,713 13,716 COMPZ RPCOM HOSO P Shut down pumps, PU to 13,690'. RIH to 13,716'and tag up on No-Go at 13,716'. 20:15 20:45 0.50 13,716 13,551 COMPZ RPCOM HOSO P POOH and lay down 3-1/2"tbg for space out. 20:45 21:00 0.25 13,551 13,551 COMPZ RPCOM SFTY P Flow chk for 15 min-ok. Blow down lines and select space out joint. 21:00 21:45 0.75 13,551 13,681 COMPZ RPCOM HOSO P MU 3-1/2" EUE and 4-1/2"IBTM space out joints. 21:45 22:30 0.75 13,681 13,681 COMPZ RPCOM THGR P MU Tbg hanger and terminate I-wire and 0.25"SS control lines. Press test swage-lock connections to 5,000 psi for 5 min each-ok. PJSM on pumping corrosion inhib brine and RU test equip. 22:30 23:30 1.00 13,681 13,681 COMPZ RPCOM CRIH P Pump 66 bbl of corrosion inhib brine directly from truck at 3 bpm. Chase with 120 bbl of 8.6 ppg seawater from the pits at 6 bpm and 1,070 psi. SIMOP-RD I-wire and control line spooling equip and sheaves. LD tbg running equip. Page 33 of 35 Time Logs , Date From To Dur S. Depth E. Depth Phase Code Subcode -T Comment 23:30 00:00 0.50 13,681 13,713 COMPZ RPCOM THGR P MU landing Jt B and RIH and land tbg,spaced out 3.18'from fully located. RILDS. 34/11/2015 Land 3-1/2"tubing completion. Pressure test tubing and seals to 2,500 psi for 30 min-ok. Press test IA to 2,500 psi for 30 min-ok. Pressure up IA and shear out SOV. Set TWC and test. ND BOPs/NU tree and test. Freeze protect well. 00:00 02:30 2.50 13,713 13,713 COMPZ RPCOM PRTS P IPJSM. Pressure test tubing to 3,500 psi/30 minutes-good. Bleed tbg pressure to 1,500 psi and shut-in. Pressure test Annulus and liner top pkr to 2,500 psi/30 min-good. Bleed down Annulus pressure to 0 psi. Bleed down tbg pressure to 0 psi. Pressure up the annulus to 2,500 psi w/o shearing. Bled down pressure to zero. Re-pressure annulus and shear out DCK-2 SOV at 2,580 psi. 02:30 03:30 1.00 13,713 0 COMPZ WHDBO MPSP P PJSM. LD landing jt. RU and set TWC.Test TWC to 1,500 psi/10 min in the direction of flow-good. 03:30 07:30 4.00 0 0 COMPZ WHDBO MPDA P PJSM. Blow down lines and LD LJ-B. RD MPD flow box, Ketch-Kan and MPD valves on stack. 07:30 11:00 3.50 0 0 COMPZ WHDBO NUND P ND BOP stack. 11:00 13:00 2.00 0 0 COMPZ WHDBO NUND P PJSM.Terminate control line and NU Tree 13:00 13:45 0.75 0 0 COMPZ WHDBO PRTS P RU test equip and test Tbg Hanger adapter void and elastomer seal to 5,000 psi for 10 min-good. 13:45 16:00 2.25 0 0 COMPZ WHDBO PRTS P RU test equip and test Tree to 250/ 5,000 psi for 10 min each while monitoring IA pressure-good. RD test equip. 16:00 16:30 0.50 0 0 COMPZ WHDBO MPSP P RU pressure lubricator and pull TWC. 16:30 17:15 0.75 0 0 COMPZ WHDBO FRZP P RU squeeze manifold and hard lines to tree and annulus for freeze protecting. 17:15 18:30 1.25 0 0 COMPZ WHDBO FRZP P Fill surface lines and pressure test to 3,000 psi-good. Bleed off pressure and line up to pump down IA. Pump 65 bbl of(LEPD) diesel freeze protect from truck using the cement unit when the truck gauge read empty. Pumped remaining 25 bbl of diesel from the Ball Mill(ULSD). Pumped freeze protect at 2.7-2.3 bbl/min, 240 psi ICP, 1,180 psi FCP. Had good returns thru-out. 18:30 19:30 1.00 0 0 COMPZ WHDBO FRZP P Allow diesel to U-tube for 30 min. Blow down and flush surface lines with water. RD Sqz manifold, hoses and hard line to tree. 19:30 20:30 1.00 0 0 COMPZ WHDBO MPSP P !RU lubricator to tree,test and set BPV. Page 34 of 35 Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:00 1.50 0 0 COMPZ WHDBO MPSP P PJSM. RU and test BPV in the direction of flow to 2,500 psi/10 min -good. Bleed off pressure, blow down lines and RD squeeze manifold and test equip. 22:00 00:00 2.00 0 0 DEMOB MOVE RURD P Secure well. Remove double annulus valves from wellhead, RU flanges/gauges. Clear and clean rig floor. NOTE: RIG RELEASED at 24:00 hrs,4/11/2015 Page 35 of 35 NADConversion Western North Slope CD4 Nanuq Pad CD4-93A r jf) (A 1 CC Definitive Survey Report 3r IN7�li aF��shNi i�aS �dU�I �r " �'� t r � 13 April, 2015 0 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor i Well CD4-93 Well Position +N/-S 0.00 usft Northing: 5,957,557.99 usft Latitude: 70°17'33.301 N +EI-W 0.00 usft Easting: 378,310.58 usft Longitude: 150°59'6.819 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 19.00 usft Wellbore CD4-93A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 3/5/2015 18.42 80.77 57,538 Design CD4-93A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,979.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 150.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.00 989.58 CD4-93 Srvy#1 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/5/2014 6:00:0 1,047.13 1,178.36 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/6/2014 1:00:0 1,271.16 1,271.16 CD4-93 Srvy#3 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/25/2014 2:57: 1,330.80 11,979.70 CD4-93Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZ SCC 9/25/2014 2:58: 12,032.71 12,500.80 CD4-93A Svy1 INC_ONLY_FILLER(CD4 INC+TREND Inclinometer+known azi trend 4/1/2015 3:52:0 12,537.28 13,771.03 CD4-93A Svy2 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2015 3:55:0 13,866.05 21,998.06 CD4-93A Svy3 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/8/2015 1:39:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11197970 69 14 175 12 6,771 65 6,715.67 74 03 7,911 36 5957,760.06 370 402.11 2.20 -4,019.80 i" n :yta, V[VeV,) 9-5/8"x 12-1/4" - 12,032.71 70.04 175 41 6,790.14 6,734 16 24 52 -7,907.26 5,957,710 49 370,405.41 1 78 -3,974.87 INC+TREND(5) 12,127.01 71.47 175.92 6,821.22 6,765.24 -64.25 -7,900.54 5,957,621.63 370,410.70 1.60 -3,894.62 INC+TREND(5) 12,220.97 70.65 176.43 6,851.72 6,795.74 -152.93 -7,894.61 5,957,532.88 370,415.19 1.01 -3,814.87 INC+TREND(5) 12,316.06 68.53 176.96 6,884.88 6,828.90 -241.89 -7,889.47 5,957,443.85 370,418.89 2.29 -3,735.25 INC+TREND(5) 12,407.80 66.45 177.50 6,920.00 6,864.02 -326.54 -7,885.37 5,957,359.16 370,421.62 2.33 -3,659.89 INC+TREND(5) 12,454.77 64.54 177.78 6,939.48 6,883.50 -369.24 -7,883.61 5,957,316.44 370,422.69 4.10 -3,622.03 INC+TREND(5) 12,500.80 62.54 176.87 6,959.99 6,904.01 -410.40 -7,881.69 5,957,275.25 370,423.94 4.69 -3,585.43 INC+TREND(5) 4/13/2015 1:34:56PM Page 2 COMPASS 5000.1 Build 65 . Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey �' Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,537.28 60.84 178.92 6,977.29 6,921.31 -442.49 -7,880.50 5,957,243.15 370,424.60 6.80 -3,557.04 MVD+IFR-AK-CAZ-SC(6) 12,595.73 58.66 182.20 7,006.74 6,950.76 -492.97 -7,880.98 5,957,192.69 370,423.31 6.12 -3,513.57 MVD+IFR-AK-CAZ-SC(6) 12,690.86 55.49 184.50 7,058.44 7,002.46 -572.66 -7,885.62 5,957,113.09 370,417.38 3.90 -3,446.87 MWD+IFR-AK-CAZ-SC(6) 12,785.68 56.11 182.47 7,111.74 7,055.76 -650.94 -7,890.38 5,957,034.91 370,411.36 1.89 -3,381.46 MWD+IFR-AK-CAZ-SC(6) 12,880.05 56.37 179.59 7,164.19 7,108.21 -729.37 -7,891.78 5,956,956.52 370,408.68 2.55 -3,314.24 MWD+IFR-AK-CAZ-SC(6) 12,974.77 59.90 175.86 7,214.20 7,158.22 -809.71 -7,888.54 5,956,876.14 370,410.62 5.01 -3,243.04 MWD+IFR-AK-CAZ-SC(6) 13,069.56 63.52 174.66 7,259.12 7,203.14 -892.88 -7,881.63 5,956,792.88 370,416.18 3.98 -3,167.56 MWD+IFR-AK-CAZ-SC(6) 13,117.89 64.66 173.62 7,280.24 7,224.26 -936.12 -7,877.19 5,956,749.57 370,419.92 3.05 -3,127.89 MVVD+IFR-AK-CAZ-SC(6) 13,164.37 65.86 173.39 7,299.69 7,243.71 -978.06 -7,872.42 5,956,707.56 370,424.02 2.62 -3,089.18 MVVD+IFR-AK-CAZ-SC(6) 13,258.60 67.81 174.95 7,336.76 7,280.78 -1,064.24 -7,863.63 5,956,621.26 370,431.41 2.57 -3,010.15 MWD+IFR-AK-CAZ-SC(6) 13,352.18 69.63 173.67 7,370.72 7,314.74 -1,151.00 -7,854.97 5,956,534.38 370,438.66 2.33 -2,930.69 MWD+IFR-AK-CAZ-SC(6) 13,446.99 71.92 174.07 7,401.94 7,345.96 -1,240.01 -7,845.42 5,956,445.23 370,446.77 2.45 -2,848.83 MVVD+IFR-AK-CAZ-SC(6) 13,541.22 75.38 173.69 7,428.46 7,372.48 -1,329.90 -7,835.78 5,956,355.21 370,454.96 3.69 -2,766.16 MVVD+IFR-AK-CAZ-SC(6) 13,634.85 79.35 173.83 7,448.94 7,392.96 -1,420.70 -7,825.85 5,956,264.26 370,463.41 4.24 -2,682.56 MWD+IFR-AK-CAZ-SC(6) 13,727.04 82.85 172.35 7,463.20 7,407.22 -1,511.10 -7,814.89 5,956,173.70 370,472.91 4.11 -2,598.79 MWD+IFR-AK-CAZ-SC(6) 13,771.03 84.33 171.98 7,468.11 7,412.13 -1,554.41 -7,808.93 5,956,130 31 370,478.16 3.47 -2,558.31 MWD+IFR AK-CAZ-SC(6) 13,820.00 85.46 171.99 7,472.47 7,416.49 -1,602.71 -7,802.13 5,956,081.91 370454.18 2.30 -2513.08 �, 4/pt) 13,866.05 86.52 171.99 7,475.69 7,419.71 -1,648.19 -7,795.72 5,956,036.33 370,489.85 2.30 -2,470.48 MWD+IFR-AK-CAZ-SC(7) 13,960.41 86.59 176.86 7,481.36 7,425.38 -1,741.91 -7,786.57 5,955,942.49 370,497.48 5.15 -2,384.75 MWD+IFR-AK-CAZ-SC(7) 14,055.78 86.95 178.51 7,486.73 7,430.75 -1,837.05 -7,782.73 5,955,847.31 370,499.78 1.77 -2,300.43 MWD+IFR-AK-CAZ-SC(7) 14,150.94 86.26 179.98 7,492.37 7,436.39 -1,932.03 -7,781.48 5,955,752.33 370,499.50 1.70 -2,217.55 MVVD+IFR-AK-CAZ-SC(7) 14,246.47 87.64 179.86 7,497.45 7,441.47 -2,027.42 -7,781.34 5,955,656.95 370,498.09 1.45 -2,134.87 MVD+IFR-AK-CAZ-SC(7) 14,343.21 87.85 178.23 7,501.26 7,445.28 -2,124.07 -7,779.73 5,955,560.30 370,498.13 1.70 -2,050.37 MWD+IFR-AK-CAZ-SC(7) 14,438.13 89.36 179.53 7,503.57 7,447.59 -2,218.94 -7,777.88 5,955,465.42 370,498.45 2.10 -1,967.28 MWD+IFR-AK-CAZ-SC(7) 14,534.69 88.89 178.62 7,505.05 7,449.07 -2,315.47 -7,776.32 5,955,368.88 370,498.45 1.06 -1,882.90 MVD+IFR-AK-CAZ-SC(7) 14,628.19 88.62 176.32 7,507.08 7,451.10 -2,408.85 -7,772.19 5,955,275.45 370,501.06 2.48 -1,799.97 MVD+IFR-AK-CAZ-SC(7) 14,723.45 88.23 175.55 7,509.70 7,453.72 -2,503.84 -7,765.44 5,955,180.38 370,506.27 0.91 -1,714.33 MVD+IFR-AK-CAZ-SC(7) 14,818.96 88.91 174.54 7,512.08 7,456.10 -2,598.96 -7,757.20 5,955,085.15 370,512.98 1.27 -1,627.83 MVD+IFR-AK-CAZ-SC(7) 14,914.38 88.25 171.16 7,514.44 7,458.46 -2,693.59 -7,745.33 5,954,990.34 370,523.31 3.61 -1,539.94 MVD+IFR-AK-CAZ-SC(7) 15,008.37 89.54 168.34 7,516.26 7,460.28 -2,786.06 -7,728.61 5,954,897.63 370,538.53 3.30 -1,451.51 MWD+IFR-AK-CAZ-SC(7) 15,105.76 88.46 163.66 7,517.96 7,461.98 -2,880.51 -7,705.06 5,954,802.81 370,560.55 4.93 -1,357.93 MW1D+IFR-AK-CAZ-SC(7) 15,198.68 89.70 160.09 7,519.45 7,463.47 -2,968.79 -7,676.16 5,954,714.08 370,588.01 4.07 -1,267.03 MWD+IFR-AK-CAZ-SC(7) 15,293.72 89.62 158.75 7,520.01 7,464.03 -3,057.76 -7,642.75 5,954,624.59 370,619.97 1.41 -1,173.27 MVVD+IFR-AK-CAZ-SC(7) 15,389.43 89.86 158.18 7,520.45 7,464.47 -3,146.79 -7,607.62 5,954,535.01 370,653.65 0.65 -1,078.61 MWD+IFR-AK-CAZ-SC(7) 15,484.85 89.86 154.52 7,520.68 7,464.70 -3,234.18 -7,569.35 5,954,447.02 370,690.50 3.84 -983.79 MWD+IFR-AK-CAZ-SC(7) 15,578.79 90.47 153.41 7,520.41 7,464.43 -3,318.59 -7,528.12 5,954,361.97 370,730.36 1.35 -890.08 MWD+IFR-AK-CAZ-SC(7) 15,674.82 90.13 148.77 7,519.91 7,463.93 -3,402.63 -7,481.71 5,954,277.19 370,775.40 4.84 -794.09 MWD+IFR-AK-CAZ-SC(7) 15,769.88 89.36 147.93 7,520.33 7,464.35 -3,483.55 -7,431.83 5,954,195.48 370,823.96 1.20 -699.07 MWD+IFR-AK-CAZ-SC(7) 15,866.17 89.99 14453 7,520.88 7,464.90 -3,563.58 -7,378.31 5,954,114.61 370,876.17 3.59 -603.01 MWD+IFR-AK-CAZ-SC(7) 4/13/2015 1:34:56PM Page 3 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope ND Reference: �i���10 CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: �'')'�' CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 , North Reference: - True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey 0IIIIPh F11 s m a 41111 Map Map Vertical 14'ii01i111:111ii1y MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,963.62 89.92 143.57 7,520.95 7,464.97 -3,642.46 -7,321.10 5,954,034.81 370,932.09 0.99 -506.09 MWD+IFR-AK-CAZ SC(7) 16,054.87 89.48 145.53 7,521.43 7,465.45 -3,716.79 -7,268.18 5,953,959.64 370,983.79 2.20 -415.25 MWD+IFR-AK-CAZ-SC(7) 16,150.67 89.02 146.07 7,522.69 7,466.71 -3,796.02 -7,214.34 5,953,879.56 371,036.34 0.74 -319.72 MWD+IFR-AK-CAZ-SC(7) 16,246.89 89.68 148.90 7,523.78 7,467.80 -3,877.14 -7,162.63 5,953,797.61 371,086.73 3.02 -223.61 MWD+IFR-AK-CAZ-SC(7) 16,342.77 89.96 148.24 7,524.08 7,468.10 -3,958.95 -7,112.63 5,953,715.01 371,135.39 0.75 -127.76 MWD+IFR-AK-CAZ-SC(7) 16,436.84 90.06 147.65 7,524.06 7,468.08 -4,038.68 -7,062.70 5,953,634.49 371,184.02 0.64 -33.75 MWD+IFR-AK-CAZ-SC(7) 16,531.85 89.72 147.70 7,524.25 7,468.27 -4,118.97 -7,011.90 5,953,553.40 371,233.51 0.36 61.18 MWD+IFR-AK-CAZ-SC(7) 16,628.05 89.41 147.48 7,524.98 7,469.00 -4,200.18 -6,960.34 5,953,471.37 371,283.74 0.40 157.29 MWD+IFR-AK-CAZ-SC(7) 16,722.37 89.27 146.98 7,526.06 7,470.08 -4,279.48 -6,909.29 5,953,391.26 371,333.50 0.55 251.50 MWD+IFR-AK-CAZ-SC(7) 16,817.95 88.66 147.29 7,527.79 7,471.81 -4,359.75 -6,857.43 5,953,310.17 371,384.05 0.72 346.94 MWD+IFR-AK-CAZ-SC(7) 16,912.68 88.76 148.31 7,529.92 7,473.94 -4,439.89 -6,806.97 5,953,229.23 371,433.20 1.08 441.57 MWD+IFR-AK-CAZ-SC(7) 17,008.76 88.96 148.50 7,531.83 7,475.85 -4,521.71 -6,756.64 5,953,146.61 371,482.20 0.29 537.60 MWD+IFR-AK-CAZ-SC(7) 17,104.31 89.79 147.56 7,532.87 7,476.89 -4,602.76 -6,706.05 5,953,064.76 371,531.46 1.31 633.08 MWD+IFR-AK-CAZ-SC(7) 17,199.15 90.61 147.33 7,532.54 7,476.56 -4,682.70 -6,655.02 5,952,984.01 371,581.19 0.90 727.83 MWD+IFR-AK-CAZ-SC(7) 17,295.44 90.82 147.84 7,531.34 7,475.36 -4,763.98 -6,603.41 5,952,901.91 371,631.47 0.57 824.03 MWD+IFR-AK-CAZ-SC(7) 17,389.54 90.90 147.88 7,529.93 7,473.95 -4,843.65 -6,553.35 5,952,821.45 371,680.23 0.10 918.05 MWD+IFR-AK-CAZ-SC(7) 17,485.84 89.25 148.79 7,529.80 7,473.82 -4,925.61 -6,502.80 5,952,738.69 371,729.44 1.96 1,014.30 MWD+IFR-AK-CAZ-SC(7) 17,581.47 89.68 149.09 7,530.70 7,474.72 -5,007.53 -6,453.47 5,952,655.99 371,777.44 0.55 1,109.91 MWD+IFR-AK-CAZ-SC(7) 17,676.06 89.72 149.13 7,531.19 7,475.21 -5,088.70 -6,404.91 5,952,574.05 371,824.68 0.06 1,204.49 MWD+IFR-AK-CAZ-SC(7) 17,770.93 89.68 148.71 7,531.69 7,475.71 -5,169.95 -6,355.93 5,952,492.03 371,872.33 0.44 1,299.34 MWD+IFR-AK-CAZ-SC(7) 17,866.12 90.18 148.99 7,531.81 7,475.83 -5,251.41 -6,306.69 5,952,409.78 371,920.24 0.60 1,394.51 MWD+IFR-AK-CAZ-SC(7) 17,962.68 89.19 149.56 7,532.34 7,476.36 -5,334.42 -6,257.36 5,952,326.00 371,968.22 1.18 1,491.06 MWD+IFR-AK-CAZ-SC(7) 18,058.98 89.51 149.86 7,533.43 7,477.45 -5,417.57 -6,208.79 5,952,242.08 372,015.43 0.46 1,587.35 MWD+IFR-AK-CAZ-SC(7) 18,153.60 90.41 150.22 7,533.49 7,477.51 -5,499.54 -6,161.54 5,952,159.36 372,061.34 1.02 1,681.97 MWD+IFR-AK-CAZ-SC(7) 18,249.43 90.30 150.47 7,532.90 7,476.92 -5,582.82 -6,114.12 5,952,075.33 372,107.40 0.29 1,777.80 MWD+IFR-AK-CAZ-SC(7) 18,344.66 90.23 149.17 7,532.46 7,476.48 -5,665.14 -6,066.25 5,951,992.26 372,153.93 1.37 1,873.03 MWD+IFR-AK-CAZ-SC(7) 18,439.43 90.16 149.23 7,532.14 7,476.16 -5,746.54 -6,017.73 5,951,910.09 372,201.13 0.10 1,967.79 MWD+IFR-AK-CAZ-SC(7) 18,535.19 89.99 148.92 7,532.01 7,476.03 -5,828.69 -5,968.51 5,951,827.16 372,249.00 0.37 2,063.53 MWD+IFR-AK-CAZ-SC(7) 18,630.73 86.83 149.23 7,534.66 7,478.68 -5,910.60 -5,919.44 5,951,744.47 372,296.74 3.32 2,159.01 MWD+IFR-AK-CAZ-SC(7) 18,726.31 87.32 149.33 7,539.54 7,483.56 -5,992.66 -5,870.68 5,951,661.63 372,344.16 0.52 2,254.46 MWD+IFR-AK-CAZ-SC(7) 18,821.72 86.91 148.81 7,544.34 7,488.36 -6,074.40 -5,821.70 5,951,579.12 372,391.80 0.69 2,349.74 MWD+IFR-AK-CAZ-SC(7) 18,916.30 87.22 149.18 7,549.19 7,493.21 -6,155.36 -5,773.04 5,951,497.39 372,439.14 0.51 2,444.18 MWD+IFR-AK-CAZ-SC(7) 19,011.82 90.19 147.23 7,551.34 7,495.36 -6,236.51 -5,722.74 5,951,415.44 372,488.12 3.72 2,539.61 MWD+IFR-AK-CAZ-SC(7) 19,106.28 90.58 147.32 7,550.71 7,494.73 -6,315.98 -5,671.67 5,951,335.17 372,537.89 0.42 2,633.96 MWD+IFR-AK-CAZ-SC(7) 19,201.54 90.40 147.26 7,549.89 7,493.91 -6,396.13 -5,620.20 5,951,254.20 372,588.06 0.20 2,729.11 MWD+IFR-AK-CAZ-SC(7) 19,296.97 90.32 146.58 7,549.29 7,493.31 -6,476.09 -5,568.11 5,951,173.42 372,638.84 0.72 2,824.40 MWD+IFR-AK-CAZ-SC(7) 19,392.12 91.41 146.63 7,547.86 7,491.88 -6,555.52 -5,515.75 5,951,093.15 372,689.90 1.15 2,919.37 MWD+IFR-AK-CAZ-SC(7) 19,487.81 90.92 147.39 7,545.91 7,489.93 -6,635.76 -5,463.66 5,951,012.08 372,740.68 0.94 3,014.91 MWD+IFR-AK-CAZ-SC(7) 19,582.65 90.08 148.78 7,545.09 7,489.11 -6,716.26 -5,413.52 5,950,930.79 372,789.50 1.71 3,109.69 MWD+IFR-AK-CAZ-SC(7) 19,678.31 90.40 149.79 7,544.68 7,488.70 -6,798.50 -5,364.66 5,950,847.78 372,837.02 1.11 3,205.34 MWD+IFR-AK-CAZ-SC(7) 4/13/2015 1:34:56PM Page 4 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True i Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name ,- 19,773 01 90.30 150.65 7,544 11 7,488 13 -6,880.69 -5,317.63 5,950,764 35 372,882.72 0.91 3,300.04 MWD+IFR-AK-CAZ-SC(7) 19,868.31 89.62 150.68 7,544.17 7,488.19 -6,963.77 -5,270.94 5,950,681.03 372,928.05 0.71 3,395.33 MWD+IFR-AK-CAZ-SC(7) 19,963.91 88.98 151.13 7,545.34 7,489.36 -7,047.30 -5,224.46 5,950,596.76 372,973.17 0.82 3,490.91 MWD+IFR-AK-CAZ-SC(7) 20,059.55 89.44 150.84 7,546.66 7,490.68 -7,130.93 -5,178.07 5,950,512.40 373,018.19 0.57 3,586.53 MWD+IFR-AK-CAZ-SC(7) 20,153.95 89.51 152.03 7,547.52 7,491.54 -7,213.83 -5,132.94 5,950,428.79 373,061.97 1.26 3,680.89 MWD+IFR-AK-CAZ-SC(7) 20,249.52 89.55 152.78 7,548.31 7,492.33 -7,298.53 -5,088.67 5,950,343.39 373,104.86 0.79 3,776.37 MWD+IFR-AK-CAZ-SC(7) 20,344.91 89.57 153.73 7,549.04 7,493.06 -7,383.71 -5,045.74 5,950,257.53 373,146.40 1.00 3,871.61 MWD+IFR-AK-CAZ-SC(7) 20,440.03 90.47 153.89 7,549.01 7,493.03 -7,469.06 -5,003.76 5,950,171.52 373,186.99 0.96 3,966.51 MWD+IFR-AK-CAZ-SC(7) 20,536.49 90.85 153.87 7,547.90 7,491.92 -7,555.66 -4,961.30 5,950,084.25 373,228.04 0.39 4,062.75 MWD+IFR-AK-CAZ-SC(7) 20,630.94 90.82 152.93 7,546.52 7,490.54 -7,640.11 -4,919.01 5,949,999.14 373,268.95 1.00 4,157.02 MWD+IFR-AK-CAZ-SC(7) 20,728.33 90.22 151.71 7,545.64 7,489.66 -7,726.35 -4,873.78 5,949,912.19 373,312.78 1.40 4,254.32 MWD+IFR-AK-CAZ-SC(7) 20,822.52 87.97 149.96 7,547.12 7,491.14 -7,808.58 -4,827.89 5,949,829.23 373,357.33 3.03 4,348.48 MWD+IFR-AK-CAZ-SC(7) 20,917.56 88.22 149.56 7,550.28 7,494.30 -7,890.64 -4,780.05 5,949,746.41 373,403.83 0.50 4,443.47 MWD+IFR-AK-CAZ-SC(7) 21,012.84 90.18 148.13 7,551.61 7,495.63 -7,972.16 -4,730.76 5,949,664.11 373,451.79 2.55 4,538.71 MWD+IFR-AK-CAZ-SC(7) 21,108.45 90.37 147.67 7,551.15 7,495.17 -8,053.15 -4,679.96 5,949,582.31 373,501.27 0.52 4,634.26 MWD+IFR-AK-CAZ-SC(7) 21,203.73 89.99 147.11 7,550.86 7,494.88 -8,133.41 -4,628.61 5,949,501.24 373,551 31 0.71 4,729.44 MWD+IFR-AK-CAZ-SC(7) 21,298.66 89.96 146.85 7,550.90 7,494.92 -8,213.01 -4,576.88 5,949,420.82 373,601.74 0.28 4,824.24 MWD+IFR-AK-CAZ-SC(7) 21,394.34 89.89 147.58 7,551.02 7,495.04 -8,293.45 -4,525.07 5,949,339.56 373,652.24 0.77 4,919.80 MWD+IFR-AK-CAZ-SC(7) 21,489.93 89.65 147.94 7,551.41 7,495.43 -8,374.30 -4,474.08 5,949,257.90 373,701.91 0.45 5,015.32 MWD+IFR-AK-CAZ-SC(7) 21,584.88 89.99 147.94 7,551.70 7,495.72 -8,454.77 -4,423.68 5,949,176.63 373,751.00 0.36 5,110.21 MWD+IFR-AK-CAZ-SC(7) 21,680.20 90.78 147.69 7,551.06 7,495.08 -8,535.44 -4,372.90 5,949,095.16 373,800.45 0.87 5,205.45 MWD+IFR-AK-CAZ-SC(7) 21,774.93 90.68 147.98 7,549.86 7,493.88 -8,615.62 -4,322.48 5,949,014.18 373,849.57 0.32 5,300.11 MWD+IFR-AK-CAZ-SC(7) 21,869.73 90.58 146.92 7,548.81 7,492.83 -8,695.52 -4,271.48 5,948,933.47 373,899.27 1.12 5,394.81 MWD+IFR-AK-CAZ-SC(7) 21,965.70 90.27 147.23 7,548.10 7,492.12 -8,776.08 -4,219.31 5,948,852.09 373,950.11 0.46 5,490.65 MWD+IFR-AK-CAZ-SC(7) 21,998.06 90.13 148.48 7,547.99 7,492.01 -8,803.48 -4,202.10 5,948,824.41 373,966.88 3.89 5,522.99 MWD+IFR-AK-CAZ-SC(7) 22,039 00 90 13 148 48 7,547 90 7,491.92 -8,838.38 4,180.69 5,948,789.18 373,987.72 0 00 5,563.91 .()T an j ;.....",' 4-112"x 6 1/8" 22,059 00 90 13 148 48 7,547 85 7,491.87 -8,855.42 -4,170.24 5,948,771 96 373,997.90 0 00 5,583.90 PROJECTED to TD y fin' ey i 4/13/2015 1.34.56PM Page 5 COMPASS 5000.1 Build 65 • • i 0 o 2 $ 2 a) 2 @ 2 t c o c Ct \ c, » / C o \ [ 2= 42 __ z \ - $ 2 \ k HUN•Z 17r3 8E • 0 _ _ _ _ .. $ . \ o / \ \j 14 0 co % _: @ ® 0 $ j 111:7 73 q \ 0 2 m . = k k / d 0 0 0 —S--- --a3 ®CI 7:1 t k 0 0 / 0 0 2 ® % a @ 'E "4 / . Li) m _• $ c J \ % ± \ ; / ƒ 0 O 3 m / E 1 E1 El a k / > 0 al 2 a m % 7 m \ 0 a) CC / 0 • 11110 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday, September 15, 2015 10:00 AM To: Duncan.P.Hyden@conocophillips.com Subject: CD4-93A 215-026 10-407 Cement Summaries Duncan, Please provide cement summaries for this 10-407. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa.alaska.gov 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 Victorialoem@alaska.gov 1 i • Cement Detail Report CD4-93 +Con©coPhillips String: CEMENT PLUG Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name CEMENT PLUG 2/16/2015 00:00 2/16/2015 00:00 CD4-93 Comment PUMP 38Bbls of Cement 15.8 ppg below retainer,spot 1 bbl of cement on top of retainer Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return'' Vol Cement... Top Plug? Btm Plug? CEMENT PLUG 12,163.0 14,317.0 Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(It) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/15/2015 • • • • : Cement Detail Report 024 ells CD4-93 ConocoPhillips String: 7"Liner Cement Job: DRILLING SIDETRACK, 3/3/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 7"Liner Cement 3/24/2015 05:15 3/24/2015 07:45 CD4-93A Comment 44.3 bbls 12.0 ppg mud push, 142.3 bbls 15.8 cement.3 bbls cement to surface when circ clean on top of liner.Full returns. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? 7"Liner Cement Cement Liner 11,787.0 13,820.0 Yes Yes No 0 Pump snit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 770.0 1,260.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 1/8 Comment Cemented liner from shoe @ 13,820'to TOL @ 11,787' Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement Intermediate Class G, 11,787.0 13,820.0 699 G 142.3 15.8 ppg,Qaanik Blend Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 0.00 15.80 7.50 1,000.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/15/2015 0 i 11 5026 Z5 69 2 Scbluiiiberger Transmittal#: 14APR15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery M. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD4-93A Date Dispatched: 14-Apr-15 Job#: 15AKA0086 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2"MD x x Scope Resistivity 2"TVD RECEIVED x x Scope Resistivity 5"MD x x Scope Resistivity 5"ND APR 14 2015 x x C LAS Digital Data i0GV N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey:PDF x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter(a�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 j �Q� v 6...e...eatReceived By: � 215026. • 15692 RECEIVED FINAL APR 14 2015 AOGGC NADConversion Western North Slope CD4 Nanuq Pad CD4-93A Definitive Survey Report ;.k, NAD 13 April, 2015 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD4-93 Well Position +N/-S 0.00 usft Northing: 5,957,557.99 usft Latitude: 70°17'33.301 N +E/-W 0.00 usft Easting: 378,310.58 usft Longitude: 150°59'6.819 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 19.00 usft Wellbore CD4-93A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 3/5/2015 18.42 80.77 57,538 Design CD4-93A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,979.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 150.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.00 989.58 CD4-93 Srvy#1 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/5/2014 6:00:0 1,047.13 1,178.36 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/6/2014 1:00:0 1,271.16 1,271.16 CD4-93 Srvy#3 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/25/2014 2:57: 1,330.80 11,979.70 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/25/2014 2:58: 12,032.71 12,500.80 CD4-93A Svy1 INC_ONLY_FILLER(CD4 INC+TREND Inclinometer+known azi trend 4/1/2015 3:52:0 12,537.28 13,771.03 CD4-93A Svy2 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2015 3:55:0 13,866.05 21,998.06 CD4-93A Svy3 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/8/2015 1:39:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,979.70 69.14 175.12 6,771.65 6,715.67 74.03 -7,911.36 5,957,760.06 370,402.11 2.20 -4,019.804 -,,-`., °w- I) 9-5/8"x 12-1/4" �� 12,032.71 70.04 175.41 6,790.14 6,734.16 24.52 -7,907.26 5,957,710.49 370,405.41 1.78 -3,974.87 INC+TREND(5) 12,127.01 71.47 175.92 6,821.22 6,765.24 -64.25 -7,900.54 5,957,621.63 370,410.70 1.60 -3,894.62 INC+TREND(5) 12,220.97 70.65 176.43 6,851.72 6,795.74 -152.93 -7,894.61 5,957,532.88 370,415.19 1.01 -3,814.87 INC+TREND(5) 12,316.06 68.53 176.96 6,884.88 6,828.90 -241.89 -7,889.47 5,957,443.85 370,418.89 2.29 -3,735.25 INC+TREND(5) 12,407.80 66.45 177.50 6,920.00 6,864.02 -326.54 -7,885.37 5,957,359.16 370,421.62 2.33 -3,659.89 INC+TREND(5) 12,454.77 64.54 177.78 6,939.48 6,883.50 -369.24 -7,883.61 5,957,316.44 370,422.69 4.10 -3,622.03 INC+TREND(5) 12,500.80 62.54 176.87 6,959.99 6,904.01 -410.40 -7,881.69 5,957,275.25 370,423.94 4.69 -3,585.43 INC+TREND(5) 4/13/2015 1:34:56PM Page 2 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98©55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,537.28 60.84 178.92 6,977.29 6,921.31 -442.49 -7,880.50 5,957,243.15 370,424.60 6.80 -3,557.04 MWD+IFR-AK-CAZ-SC(6) 12,595.73 58.66 182.20 7,006.74 6,950.76 -492.97 -7,880.98 5,957,192.69 370,423.31 6.12 -3,513.57 MWD+IFR-AK-CAZ-SC(6) 12,690.86 55.49 184.50 7,058.44 7,002.46 -572.66 -7,885.62 5,957,113.09 370,417.38 3.90 -3,446.87 MWD+1FR-AK-CAZ-SC(6) 12,785.68 56.11 182.47 7,111.74 7,055.76 -650.94 -7,890.38 5,957,034.91 370,411.36 1.89 -3,381.46 MWD+IFR-AK-CAZ-SC(6) 12,880.05 56.37 179.59 7,164.19 7,108.21 -729.37 -7,891.78 5,956,956.52 370,408.68 2.55 -3,314.24 MWD+1FR-AK-CAZ-SC(6) 12,974.77 59.90 175.86 7,214.20 7,158.22 -809.71 -7,888.54 5,956,876.14 370,410.62 5.01 -3,243.04 MWD+IFR-AK-CAZ-SC(6) 13,069.56 63.52 174.66 7,259.12 7,203.14 -892.88 -7,881.63 5,956,792.88 370,416.18 3.98 -3,167.56 MWD+IFR-AK-CAZ-SC(6) 13,117.89 64.66 173.62 7,280.24 7,224.26 -936.12 -7,877.19 5,956,749.57 370,419.92 3.05 -3,127.89 MWD+IFR-AK-CAZ-SC(6) 13,164.37 65.86 173.39 7,299.69 7,243.71 -978.06 -7,872.42 5,956,707.56 370,424.02 2.62 -3,089.18 MWD+IFR-AK-CAZ-SC(6) 13,258.60 67.81 174.95 7,336.76 7,280.78 -1,064.24 -7,863.63 6,956,621.26 370,431.41 2.57 -3,010.15 MWD+1FR-AK-CAZ-SC(6) 13,352.18 69.63 173.67 7,370.72 7,314.74 -1,151.00 -7,854.97 5,956,534.38 370,438.66 2.33 -2,930.69 MWD+1FR-AK-CAZ-SC(6) 13,446.99 71.92 174.07 7,401.94 7,345.96 -1,240.01 -7,845.42 5,956,445.23 370,446.77 2.45 -2,848.83 MWD+1FR-AK-CAZ-SC(6) 13,541.22 75.38 173.69 7,428.46 7,372.48 -1,329.90 -7,835.78 5,956,355.21 370,454.96 3.69 -2,766.16 MWD+1FR-AK-CAZ-SC(6) 13,634.85 79.35 173.83 7,448.94 7,392.96 -1,420.70 -7,825.85 5,956,264.26 370,463.41 4.24 -2,682.56 MWD+IFR-AK-CAZ-SC(6) 13,727.04 82.85 172.35 7,463.20 7,407.22 -1,511.10 -7,814.89 5,956,173.70 370,472.91 4.11 -2,598.79 MWD+IFR-AK-CAZ-SC(6) 13,771.03 84.33 171.98 7,468.11 7,412.13 -1,554.41 -7,808.93 5,956,130.31 370,478.16 3.47 -2,558.31 MWD+IFR-AK-CAZ-SC(6) 13,820.00 85.46 171.99 7,472.47 7,416.49 -1,602.71 -7,802.13 5,956,081.91 370,484.18 2.30 -2,513.08 SNOT an Actual Survey) 7"x 8-3/4"by 9-7/8" s 13,866.05 86.52 171.99 7,475.69 7,419.71 -1,648.19 -7,795.72 5,956,036.33 370,489.85 2.30 -2,470.48 MWD+IFR-AK-CAZ-SC(7) 13,960.41 86.59 176.86 7,481.36 7,425.38 -1,741.91 -7,786.57 5,955,942.49 370,497.48 5.15 -2,384.75 MWD+1FR-AK-CAZ-SC(7) 14,055.78 86.95 178.51 7,486.73 7,430.75 -1,837.05 -7,782.73 5,955,847.31 370,499.78 1.77 -2,300.43 MWD+IFR-AK-CAZ-SC(7) 14,150.94 86.26 179.98 7,492.37 7,436.39 -1,932.03 -7,781.48 5,955,752.33 370,499.50 1.70 -2,217.55 MWD+IFR-AK-CAZ-SC(7) 14,246.47 87.64 179.86 7,497.45 7,441.47 -2,027.42 -7,781.34 5,955,656.95 370,498.09 1.45 -2,134.87 MWD+IFR-AK-CAZ-SC(7) 14,343.21 87.85 178.23 7,501.26 7,445.28 -2,124.07 -7,779.73 5,955,560.30 370,498.13 1.70 -2,050.37 MWD+1FR-AK-CAZ-SC(7) 14,438.13 89.36 179.53 7,503.57 7,447.59 -2,218.94 -7,777.88 5,955,465.42 370,498.45 2.10 -1,967.28 MWD+IFR-AK-CAZ-SC(7) 14,534.69 88.89 178.62 7,505.05 7,449.07 -2,315.47 -7,776.32 5,955,368.88 370,498.45 1.06 -1,882.90 MWD+1FR-AK-CAZ-SC(7) 14,628.19 88.62 176.32 7,507.08 7,451.10 -2,408.85 -7,772.19 5,955,275.45 370,501.06 2.48 -1,799.97 MWD+IFR-AK-CAZ-SC(7) 14,723.45 88.23 175.55 7,509.70 7,453.72 -2,503.84 -7,765.44 5,955,180.38 370,506.27 0.91 -1,714.33 MWD+1FR-AK-CAZ-SC(7) 14,818.96 88.91 174.54 7,512.08 7,456.10 -2,598.96 -7,757.20 5,955,085.15 370,512.98 1.27 -1,627.83 MWD+IFR-AK-CAZ-SC(7) 14,914.38 88.25 171.16 7,514.44 7,458.46 -2,693.59 -7,745.33 5,954,990.34 370,523.31 3.61 -1,539.94 MWD+IFR-AK-CAZ-SC(7) 15,008.37 89.54 168.34 7,516.26 7,460.28 -2,786.06 -7,728.61 5,954,897.63 370,538.53 3.30 -1,451.51 MWD+IFR-AK-CAZ-SC(7) 15,105.76 88.46 163.66 7,517.96 7,461.98 -2,880.51 -7,705.06 5,954,802.81 370,560.55 4.93 -1,357.93 MWD+1FR-AK-CAZ-SC(7) 15,198.68 89.70 160.09 7,519.45 7,463.47 -2,968.79 -7,676.16 5,954,714.08 370,588.01 4.07 -1,267.03 MWD+1FR-AK-CAZ-SC(7) 15,293.72 89.62 158.75 7,520.01 7,464.03 -3,057.76 -7,642.75 5,954,624.59 370,619.97 1.41 -1,173.27 MWD+IFR-AK-CAZ-SC(7) 15,389.43 89.86 158.18 7,520.45 7,464.47 -3,146.79 -7,607.62 5,954,535.01 370,653.65 0.65 -1,078.61 MWD+IFR-AK-CAZ-SC(7) 15,484.85 89.86 154.52 7,520.68 7,464.70 -3,234.18 -7,569.35 5,954,447.02 370,690.50 3.84 -983.79 MWD+1FR-AK-CAZ-SC(7) 15,578.79 90.47 153.41 7,520.41 7,464.43 -3,318.59 -7,528.12 5,954,361.97 370,730.36 1.35 -890.08 MWD+1FR-AK-CAZ-SC(7) 15,674.82 90.13 148.77 7,519.91 7,463.93 -3,402.63 -7,481.71 5,954,277.19 370,775.40 4.84 -794.09 MWD+1FR-AK-CAZ-SC(7) 15,769.88 89.36 147.93 7,520.33 7,464.35 -3,483.55 -7,431.83 5,954,195.48 370,823.96 1.20 -699.07 MWD+IFR-AK-CAZ-SC(7) 15,866.17 89.99 144.53 7,520.88 7,464.90 -3,563.58 -7,378.31 5,954,114.61 370,876.17 3.59 -603.01 MWD+IFR-AK-CAZ-SC(7) 4/13/2015 1:34:56PM Page 3 COMPASS 5000.1 Build 65 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,963.62 89.92 143.57 7,520.95 7,464.97 -3,642.46 -7,321.10 5,954,034.81 370,932.09 0.99 -506.09 MWD+IFR-AK-CAZ-SC(7) 16,054.87 89.48 145.53 7,521.43 7,465.45 -3,716.79 -7,268.18 5,953,959.64 370,983.79 2.20 -415.25 MWD+IFR-AK-CAZ-SC(7) 16,150.67 89.02 146.07 7,522.69 7,466.71 -3,796.02 -7,214.34 5,953,879.56 371,036.34 0.74 -319.72 MWD+IFR-AK-CAZ-SC(7) 16,246.89 89.68 148.90 7,523.78 7,467.80 -3,877.14 -7,162.63 5,953,797.61 371,086.73 3.02 -223.61 MWD+IFR-AK-CAZ-SC(7) 16,342.77 89.96 148.24 7,524.08 7,468.10 -3,958.95 -7,112.63 5,953,715.01 371,135.39 0.75 -127.76 MWD+IFR-AK-CAZ-SC(7) 16,436.84 90.06 147.65 7,524.06 7,468.08 -4,038.68 -7,062.70 5,953,634.49 371,184.02 0.64 -33.75 MWD+IFR-AK-CAZ-SC(7) 16,531.85 89.72 147.70 7,524.25 7,468.27 -4,118.97 -7,011.90 5,953,553.40 371,233.51 0.36 61.18 MWD+IFR-AK-CAZ-SC(7) 16,628.05 89.41 147.48 7,524.98 7,469.00 -4,200.18 -6,960.34 5,953,471.37 371,283.74 0.40 157.29 MWD+IFR-AK-CAZ-SC(7) 16,722.37 89.27 146.98 7,526.06 7,470.08 -4,279.48 -6,909.29 5,953,391.26 371,333.50 0.55 251.50 MWD+IFR-AK-CAZ-SC(7) 16,817.95 88.66 147.29 7,527.79 7,471.81 -4,359.75 -6,857.43 5,953,310.17 371,384.05 0.72 346.94 MWD+IFR-AK-CAZ-SC(7) 16,912.68 88.76 148.31 7,529.92 7,473.94 -4,439.89 -6,806.97 5,953,229.23 371,433.20 1.08 441.57 MWD+IFR-AK-CAZ-SC(7) 17,008.76 88.96 148.50 7,531.83 7,475.85 -4,521.71 -6,756.64 5,953,146.61 371,482.20 0.29 537.60 MWD+IFR-AK-CAZ-SC(7) 17,104.31 89.79 147.56 7,532.87 7,476.89 -4,602.76 -6,706.05 5,953,064.76 371,531.46 1.31 633.08 MWD+IFR-AK-CAZ-SC(7) 17,199.15 90.61 147.33 7,532.54 7,476.56 -4,682.70 -6,655.02 5,952,984.01 371,581.19 0.90 727.83 MWD+IFR-AK-CAZ-SC(7) 17,295.44 90.82 147.84 7,531.34 7,475.36 -4,763.98 -6,603.41 5,952,901.91 371,631.47 0.57 824.03 MWD+IFR-AK-CAZ-SC(7) 17,389.54 90.90 147.88 7,529.93 7,473.95 -4,843.65 -6,553.35 5,952,821.45 371,680.23 0.10 918.05 MWD+IFR-AK-CAZ-SC(7) 17,485.84 89.25 148.79 7,529.80 7,473.82 -4,925.61 -6,502.80 5,952,738.69 371,729.44 1.96 1,014.30 MWD+IFR-AK-CAZ-SC(7) 17,581.47 89.68 149.09 7,530.70 7,474.72 -5,007.53 -6,453.47 5,952,655.99 371,777.44 0.55 1,109.91 MWD+IFR-AK-CAZ-SC(7) 17,676.06 89.72 149.13 7,531.19 7,475.21 -5,088.70 -6,404.91 5,952,574.05 371,824.68 0.06 1,204.49 MWD+IFR-AK-CAZ-SC(7) 17,770.93 89.68 148.71 7,531.69 7,475.71 -5,169.95 -6,355.93 5,952,492.03 371,872.33 0.44 1,299.34 MWD+IFR-AK-CAZ-SC(7) 17,866.12 90.18 148.99 7,531.81 7,475.83 -5,251.41 -6,306.69 5,952,409.78 371,920.24 0.60 1,394.51 MWD+1FR-AK-CAZ-SC(7) 17,962.68 89.19 149.56 7,532.34 7,476.36 -5,334.42 -6,257.36 5,952,326.00 371,968.22 1.18 1,491.06 MWD+1FR-AK-CAZ-SC(7) 18,058.98 89.51 149.86 7,533.43 7,477.45 -5,417.57 -6,208.79 5,952,242.08 372,015.43 0.46 1,587.35 MWD+1FR-AK-CAZ-SC(7) 18,153.60 90.41 150.22 7,533.49 7,477.51 -5,499.54 -6,161.54 5,952,159.36 372,061.34 1.02 1,681.97 MWD+IFR-AK-CAZ-SC(7) 18,249.43 90.30 150.47 7,532.90 7,476.92 -5,582.82 -6,114.12 5,952,075.33 372,107.40 0.29 1,777.80 MWD+IFR-AK-CAZ-SC(7) 18,344.66 90.23 149.17 7,532.46 7,476.48 -5,665.14 -6,066.25 5,951,992.26 372,153.93 1.37 1,873.03 MWD+IFR-AK-CAZ-SC(7) 18,439.43 90.16 149.23 7,532.14 7,476.16 -5,746.54 -6,017.73 5,951,910.09 372,201.13 0.10 1,967.79 MWD+IFR-AK-CAZ-SC(7) 18,535.19 89.99 148.92 7,532.01 7,476.03 -5,828.69 -5,968.51 5,951,827.16 372,249.00 0.37 2,063.53 MWD+IFR-AK-CAZ-SC(7) 18,630.73 86.83 149.23 7,534.66 7,478.68 -5,910.60 -5,919.44 5,951,744.47 372,296.74 3.32 2,159.01 MWD+IFR-AK-CAZ-SC(7) 18,726.31 87.32 149.33 7,539.54 7,483.56 -5,992.66 -5,870.68 5,951,661.63 372,344.16 0.52 2,254.46 MWD+IFR-AK-CAZ-SC(7) 18,821.72 86.91 148.81 7,544.34 7,488.36 -6,074.40 -5,821.70 5,951,579.12 372,391.80 0.69 2,349.74 MWD+IFR-AK-CAZ-SC(7) 18,916.30 87.22 149.18 7,549.19 7,493.21 -6,155.36 -5,773.04 5,951,497.39 372,439.14 0.51 2,444.18 MWD+IFR-AK-CAZ-SC(7) 19,011.82 90.19 147.23 7,551.34 7,495.36 -6,236.51 -5,722.74 5,951,415.44 372,488.12 3.72 2,539.61 MWD+IFR-AK-CAZ-SC(7) 19,106.28 90.58 147.32 7,550.71 7,494.73 -6,315.98 -5,671.67 5,951,335.17 372,537.89 0.42 2,633.96 MWD+IFR-AK-CAZ-SC(7) 19,201.54 90.40 147.26 7,549.89 7,493.91 -6,396.13 -5,620.20 5,951,254.20 372,588.06 0.20 2,729.11 MWD+IFR-AK-CAZ-SC(7) 19,296.97 90.32 146.58 7,549.29 7,493.31 -6,476.09 -5,568.11 5,951,173.42 372,638.84 0.72 2,824.40 MWD+IFR-AK-CAZ-SC(7) 19,392.12 91.41 146.63 7,547.86 7,491.88 -6,555.52 -5,515.75 5,951,093.15 372,689.90 1.15 2,919.37 MWD+IFR-AK-CAZ-SC(7) 19,487.81 90.92 147.39 7,545.91 7,489.93 -6,635.76 -5,463.66 5,951,012.08 372,740.68 0.94 3,014.91 MWD+IFR-AK-CAZ-SC(7) 19,582.65 90.08 148.78 7,545.09 7,489.11 -6,716.26 -5,413.52 5,950,930.79 372,789.50 1.71 3,109.69 MWD+IFR-AK-CAZ-SC(7) 19,678.31 90.40 149.79 7,544.68 7,488.70 -6,798.50 -5,364.66 5,950,847.78 372,837.02 1.11 3,205.34 MWD+IFR-AK-CAZ-SC(7) 4/13/2015 1:34:56PM Page 4 COMPASS 5000.1 Build 65 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 19,773.01 90.30 150.65 7,544.11 7,488.13 -6,880.69 -5,317.63 5,950,764.85 372,882.72 0.91 3,300.04 MWD+IFR-AK-CAZ-SC(7) 19,868.31 89.62 150.68 7,544.17 7,488.19 -6,963.77 -5,270.94 5,950,681.03 372,928.05 0.71 3,395.33 MWD+IFR-AK-CAZ-SC(7) 19,963.91 88.98 151.13 7,545.34 7,489.36 -7,047.30 -5,224.46 5,950,596.76 372,973.17 0.82 3,490.91 MWD+IFR-AK-CAZ-SC(7) 20,059.55 89.44 150.84 7,546.66 7,490.68 -7,130.93 -5,178.07 5,950,512.40 373,018.19 0.57 3,586.53 MWD+IFR-AK-CAZ-SC(7) 20,153.95 89.51 152.03 7,547.52 7,491.54 -7,213.83 -5,132.94 5,950,428.79 373,061.97 1.26 3,680.89 MWD+IFR-AK-CAZ-SC(7) 20,249.52 89.55 152.78 7,548.31 7,492.33 -7,298.53 -5,088.67 5,950,343.39 373,104.86 0.79 3,776.37 MWD+IFR-AK-CAZ-SC(7) 20,344.91 89.57 153.73 7,549.04 7,493.06 -7,383.71 -5,045.74 5,950,257.53 373,146.40 1.00 3,871.61 MWD+IFR-AK-CAZ-SC(7) 20,440.03 90.47 153.89 7,549.01 7,493.03 -7,469.06 -5,003.76 5,950,171.52 373,186.99 0.96 3,966.51 MWD+IFR-AK-CAZ-SC(7) 20,536.49 90.85 153.87 7,547.90 7,491.92 -7,555.66 -4,961.30 5,950,084.25 373,228.04 0.39 4,062.75 MWD+IFR-AK-CAZ-SC(7) 20,630.94 90.82 152.93 7,546.52 7,490.54 -7,640.11 -4,919.01 5,949,999.14 373,268.95 1.00 4,157.02 MWD+IFR-AK-CAZ-SC(7) 20,728.33 90.22 151.71 7,545.64 7,489.66 -7,726.35 -4,873.78 5,949,912.19 373,312.78 1.40 4,254.32 MWD+IFR-AK-CAZ-SC(7) 20,822.52 87.97 149.96 7,547.12 7,491.14 -7,808.58 -4,827.89 5,949,829.23 373,357.33 3.03 4,348.48 MWD+IFR-AK-CAZ-SC(7) 20,917.56 88.22 149.56 7,550.28 7,494.30 -7,890.64 -4,780.05 5,949,746.41 373,403.83 0.50 4,443.47 MWD+IFR-AK-CAZ-SC(7) 21,012.84 90.18 148.13 7,551.61 7,495.63 -7,972.16 -4,730.76 5,949,664.11 373,451.79 2.55 4,538.71 MWD+IFR-AK-CAZ-SC(7) 21,108.45 90.37 147.67 7,551.15 7,495.17 -8,053.15 -4,679.96 5,949,582.31 373,501.27 0.52 4,634.26 MWD+IFR-AK-CAZ-SC(7) 21,203.73 89.99 147.11 7,550.86 7,494.88 -8,133.41 -4,628.61 5,949,501.24 373,551.31 0.71 4,729.44 MWD+IFR-AK-CAZ-SC(7) 21,298.66 89.96 146.85 7,550.90 7,494.92 -8,213.01 -4,576.88 5,949,420.82 373,601.74 0.28 4,824.24 MWD+IFR-AK-CAZ-SC(7) 21,394.34 89.89 147.58 7,551.02 7,495.04 -8,293.45 -4,525.07 5,949,339.56 373,652.24 0.77 4,919.80 MWD+IFR-AK-CAZ-SC(7) 21,489.93 89.65 147.94 7,551.41 7,495.43 -8,374.30 -4,474.08 5,949,257.90 373,701.91 0.45 5,015.32 MWD+IFR-AK-CAZ-SC(7) 21,584.88 89.99 147.94 7,551.70 7,495.72 -8,454.77 -4,423.68 5,949,176.63 373,751.00 0.36 5,110.21 MWD+IFR-AK-CAZ-SC(7) 21,680.20 90.78 147.69 7,551.06 7,495.08 -8,535.44 -4,372.90 5,949,095.16 373,800.45 0.87 5,205.45 MWD+IFR-AK-CAZ-SC(7) 21,774.93 90.68 147.98 7,549.86 7,493.88 -8,615.62 -4,322.48 5,949,014.18 373,849.57 0.32 5,300.11 MWD+IFR-AK-CAZ-SC(7) 21,869.73 90.58 146.92 7,548.81 7,492.83 -8,695.52 -4,271.48 5,948,933.47 373,899.27 1.12 5,394.81 MWD+IFR-AK-CAZ-SC(7) 21,965.70 90.27 147.23 7,548.10 7,492.12 -8,776.08 -4,219.31 5,948,852.09 373,950.11 0.46 5,490.65 MWD+IFR-AK-CAZ-SC(7) 21,998.06 90.13 148.48 7,547.99 7,492.01 -8,803.48 -4,202.10 5,948,824.41 373,966.88 3.89 5,522.99 MWD+IFR-AK-CAZ-SC(7) 22,039.00 90.13 148.48 7,547.90 7,491.92 -8,838.38 -4,180.69 5,948,789.18 373,987.72 0.00 5,563.91 ," Actual S 4-1/2"x 6-1/8" 22,059.00 90.13 148.48 7,547.85 7,491.87 -8,855.42 4,170.24 5,948,771.96 373,997.90 0.00 5,583.90 PROJECTED to TO NOT an' , urvey 4/13/2015 1:34:56PM Page 5 COMPASS 5000.1 Build 65 • • 0 0 a. 0 0 a 2 a > 1:2) 2 % 2 bill c o I ia) /11) 9 » Cu - �m - k)\ ]§ %\ :' § § /k o � 8 \ _ - k , j _ .. .0 § \ /tC ■ E Ik 0e Cw > wo Ill O $ } o g .� _J cE 13= k / 2 ic e . k U o p k 0 § 2 / 0 2 § % CO 41 £ t = k Ce = � 0 / 3 % / t 7fp D m k > a t t & CO a) 0 g CC a) 6 X15026 . r 25692 RECEIVED APR 14 2015 FINAL AOGCC ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD4 Nanuq Pad CD4-93A Definitive Survey Report NAD 83 13 April, 2015 0 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98©55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98©55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD4-93 Well Position +N/-S 0.00 usft Northing: 5,957,305.15 usft Latitude: 70°17'32.114 N +E/-W 0.00 usft Easting: 1,518,344.09 usft Longitude: 150°59'18.087 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 19.00 usft Wellbore CD4-93A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 3/5/2015 18.42 80.77 57,538 Design CD4-93A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,979.70 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 36.98 0.00 0.00 150.00 Survey Program Date 4/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.00 989.58 CD4-93 Srvy#1 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/5/2014 6:00:2 1,047.13 1,178.36 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 9/6/2014 1:00:1 1,271.16 1,271.16 CD4-93 Srvy#3 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 9/25/2014 2:57: 1,330.80 11,979.70 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/25/2014 2:58: 12,032.71 12,500.80 CD4-93A Svy1 INC_ONLY_FILLER(CD4 INC+TREND Inclinometer+known azi trend 4/1/2015 3:52:4 12,537.28 13,771.03 CD4-93A Svy2 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2015 3:55:5 13,866.05 21,998.06 CD4-93A Svy3 MWD+GMAG(CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/8/2015 1:39:3 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,979.70 69.14 175.12 6,771.65 6,715.67 74.03 -7,911.36 5,957,507.63 1,510,435.63 2.20 -4,019.80 : •) 9-5/8"x 12-1/4" � 12,032.71 70.04 175.41 6,790.14 6,734.16 24.52 -7,907.26 5,957,458.06 1,510,438.92 1.78 -3,974.87 INC+TREND(5) 12,127.01 71.47 175.92 6,821.22 6,765.24 -64.25 -7,900.54 5,957,369.20 1,510,444.21 1.60 -3,894.62 INC+TREND(5) 12,220.97 70.65 176.43 6,851.72 6,795.74 -152.93 -7,894.61 5,957,280.45 1,510,448.70 1.01 -3,814.87 INC+TREND(5) 12,316.06 68.53 176.96 6,884.88 6,828.90 -241.89 -7,889.47 5,957,191.42 1,510,452.39 2.29 -3,735.25 INC+TREND(5) 12,407.80 66.45 177.50 6,920.00 6,864.02 -326.54 -7,885.37 5,957,106.72 1,510,455.12 2.33 -3,659.89 INC+TREND(5) 12,454.77 64.54 177.78 6,939.48 6,883.50 -369.24 -7,883.61 5,957,064.00 1,510,456.18 4.10 -3,622.03 INC+TREND(5) 12,500.80 62.54 176.87 6,959.99 6,904.01 -410.40 -7,881.69 5,957,022.82 1,510,457.43 4.69 -3,585.43 INC+TREND(5) 4/13/2015 10:40:23AM Page 2 COMPASS 5000.1 Build 65 . • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98©55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 12,537.28 60.84 178.92 6,977.29 6,921 31 -442.49 -7,880.50 5,956,990.72 1,510,458.10 6.80 -3,557.04 MWD+IFR-AK-CAZ-SC(6) 12,595.73 58.66 182.20 7,006.74 6,950.76 -492.97 -7,880.98 5,956,940.26 1,510,456.80 6.12 -3,513.57 MWD+IFR-AK-CAZ-SC(6) 12,690.86 55.49 184.50 7,058.44 7,002.46 -572.66 -7,885.62 5,956,860.66 1,510,450.87 3.90 -3,446.87 MWD+IFR-AK-CAZ-SC(6) 12,785.68 56.11 182.47 7,111.74 7,055.76 -650.94 -7,890.38 5,956,782.48 1,510,444.84 1.89 -3,381.46 MWD+IFR-AK-CAZ-SC(6) 12,880.05 56.37 179.59 7,164.19 7,108.21 -729.37 -7,891.78 5,956,704.09 1,510,442.16 2.55 -3,314.24 MWD+IFR-AK-CAZ-SC(6) 12,974.77 59.90 175.86 7,214.20 7,158.22 -809.71 -7,888.54 5,956,623.71 1,510,444.10 5.01 -3,243.04 MWD+IFR-AK-CAZ-SC(6) 13,069.56 63.52 174.66 7,259.12 7,203.14 -892.88 -7,881.63 5,956,540.45 1,510,449.65 3.98 -3,167.56 MWD+IFR-AK-CAZ-SC(6) 13,117.89 64.66 173.62 7,280.24 7,224.26 -936.12 -7,877.19 5,956,497.14 1,510,453.39 3.05 -3,127.89 MWD+IFR-AK-CAZ-SC(6) 13,164.37 65.86 173.39 7,299.69 7,243.71 -978.06 -7,872.42 5,956,455.13 1,510,457.48 2.62 -3,089.18 MWD+IFR-AK-CAZ-SC(6) 13,258.60 67.81 174.95 7,336.76 7,280.78 -1,064.24 -7,863.63 5,956,368.83. 1,510,464.87 2.57 -3,010.15 MWD+IFR-AK-CAZ-SC(6) 13,352.18 69.63 173.67 7,370.72 7,314.74 -1,151.00 -7,854.97 5,956,281.94 1,510,472.11 2.33 -2,930.69 MWD+IFR-AK-CAZ-SC(6) 13,446.99 71.92 174.07 7,401.94 7,345.96 -1,240.01 -7,845.42 5,956,192.80 1,510,480.22 2.45 -2,848.83 MWD+IFR-AK-CAZ-SC(6) 13,541.22 75.38 173.69 7,428.46 7,372.48 -1,329.90 -7,835.78 5,956,102.78 1,510,488.40 3.69 -2,766.16 MWD+IFR-AK-CAZ-SC(6) 13,634.85 79.35 173.83 7,448.94 7,392.96 -1,420.70 -7,825.85 5,956,011.83 1,510,496.85 4.24 -2,682.56 MWD+IFR-AK-CAZ-SC(6) 13,727.04 82.85 172.35 7,463.20 7,407.22 -1,511.10 -7,814.89 5,955,921.27 1,510,506.34 4.11 -2,598.79 MWD+IFR-AK-CAZ-SC(6) 13,771.03 84.33 171.98 7,468.11 7,412.13 -1.554.41 -7,808.93 5.955,877 88 1,510,511.60 3.47 -2,558.31 MWD+IFR-AK-CAZ-SC(6) 13,820.00 85.46 171.99 7,472.47 7,416.49 -1,602.71 -7,802.13 5,955,829.48 1,510,517.62 2.30 -2,513.08 i•'.,all Ada" urvey 7"x 8-3/4"by 9-7/8" 13,866.05 86.52 171.99 7,475.69 7,419.71 -1,648.19 -7,795.72 5,955,783.90 1,510,523.28 2.30 -2,470.48 MWD+IFR-AK-CAZ-SC(7) 13,960.41 86.59 176.86 7,481.36 7,425.38 -1,741.91 -7,786.57 5,955,690.05 1,510,530.90 5.15 -2,384.75 MWD+IFR-AK-CAZ-SC(7) 14,055.78 86.95 178.51 7,486.73 7,430.75 -1,837.05 -7,782.73 5,955,594.87 1,510,533.20 1.77 -2,300.43 MWD+IFR-AK-CAZ-SC(7) 14,150.94 86.26 179.98 7,492.37 7,436.39 -1,932.03 -7,781.48 5,955,499.89 1,510,532.91 1.70 -2,217.55 MWD+IFR-AK-CAZ-SC(7) 14,246.47 87.64 179.86 7,497.45 7,441.47 -2,027.42 -7,781.34 5,955,404.52 1,510,531.50 1.45 -2,134.87 MWD+IFR-AK-CAZ-SC(7) 14,343.21 87.85 178.23 7,501.26 7,445.28 -2,124.07 -7,779.73 5,955,307.86 1,510,531.54 1.70 -2,050.37 MWD+IFR-AK-CAZ-SC(7) 14,438.13 89.36 179.53 7,503.57 7,447.59 -2,218.94 -7,777.88 5,955,212.99 1,510,531.85 2.10 -1,967.28 MWD+IFR-AK-CAZ-SC(7) 14,534.69 88.89 178.62 7,505.05 7,449.07 -2,315.47 -7,776.32 5,955,116.45 1,510,531.84 1.06 -1,882.90 MWD+IFR-AK-CAZ-SC(7) 14,628.19 88.62 176.32 7,507.08 7,451.10 -2,408.85 -7,772.19 5,955,023.02 1,510,534.45 2.48 -1,799.97 MWD+IFR-AK-CAZ-SC(7) 14,723.45 88.23 175.55 7,509.70 7,453.72 -2,503.84 -7,765.44 5,954,927.95 1,510,539.66 0.91 -1,714.33 MWD+IFR-AK-CAZ-SC(7) 14,818.96 88.91 174.54 7,512.08 7,456.10 -2,598.96 -7,757.20 5,954,832.71 1,510,546.36 1.27 -1,627.83 MWD+IFR-AK-CAZ-SC(7) 14,914.38 88.25 171.16 7,514.44 7,458.46 -2,693.59 -7,745.33 5,954,737.90 1,510,556.69 3.61 -1,539.94 MWD+IFR-AK-CAZ-SC(7) 15,008.37 89.54 168.34 7,516.26 7,460.28 -2,786.06 -7,728.61 5,954,645.19 1,510,571.91 3.30 -1,451.51 MWD+IFR-AK-CAZ-SC(7) 15,105.76 88.46 163.66 7,517.96 7,461.98 -2,880.51 -7,705.06 5,954,550.37 1,510,593.92 4.93 -1,357.93 MWD+IFR-AK-CAZ-SC(7) 15,198.68 89.70 160.09 7,519.45 7,463.47 -2,968.79 -7,676.16 5,954,461.64 1,510,621.37 4.07 -1,267.03 MWD+IFR-AK-CAZ-SC(7) 15,293.72 89.62 158.75 7,520.01 7,464.03 -3,057.76 -7,642.75 5,954,372.15 1,510,653.33 1.41 -1,173.27 MWD+IFR-AK-CAZ-SC(7) 15,389.43 89.86 158.18 7,520.45 7,464.47 -3,146.79 -7,607.62 5,954,282.57 1,510,687.01 0.65 -1,078.61 MWD+IFR-AK-CAZ-SC(7) 15,484.85 89.86 154.52 7,520.68 7,464.70 -3,234.18 -7,569.35 5,954,194.58 1,510,723.85 3.84 -983.79 MWD+IFR-AK-CAZ-SC(7) 15,578.79 90.47 153.41 7,520.41 7,464.43 -3,318.59 -7,528.12 5,954,109.52 1,510,763.70 1.35 -890.08 MWD+IFR-AK-CAZ-SC(7) 15,674.82 90.13 148.77 7,519.91 7,463.93 -3,402.63 -7,481.71 5,954,024.74 1,510,808.74 4.84 -794.09 MWD+IFR-AK-CAZ-SC(7) 15,769.88 89.36 147.93 7,520.33 7,464.35 -3,483.55 -7,431.83 5,953,943.03 1,510,857.29 1.20 -699.07 MWD+IFR-AK-CAZ-SC(7) 15,866.17 89.99 144.53 7,520.88 7,464.90 -3,563.58 -7,378.31 5,953,862.15 1,510,909.50 3.59 -603.01 MWD+IFR-AK-CAZ-SC(7) 4/13/2015 10:40:23AM Page 3 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 15,963.62 89.92 143.57 7,520.95 7,464.97 -3,642.46 -7,321.10 5,953,782.35 1,510,965.41 0.99 -506.09 MWD+IFR-AK-CAZ-SC(7) 16,054.87 89.48 145.53 7,521.43 7,465.45 -3,716.79 -7,268.18 5,953,707.18 1,511,017.12 2.20 -415.25 MWD+IFR-AK-CAZ-SC(7) 16,150.67 89.02 146.07 7,522.69 7,466.71 -3,796.02 -7,214.34 5,953,627.09 1,511,069.66 0.74 -319.72 MWD+IFR-AK-CAZ-SC(7) 16,246.89 89.68 148.90 7,523.78 7,467.80 -3,877.14 -7,162.63 5,953,545.15 1,511,120.04 3.02 -223.61 MWD+IFR-AK-CAZ-SC(7) 16,342.77 89.96 148.24 7,524.08 7,468.10 -3,958.95 -7,112.63 5,953,462.54 1,511,168.70 0.75 -127.76 MWD+IFR-AK-CAZ-SC(7) 16,436.84 90.06 147.65 7,524.06 7,468.08 -4,038.68 -7,062.70 5,953,382.02 1,511,217.32 0.64 -33.75 MWD+IFR-AK-CAZ-SC(7) 16,531.85 89.72 147.70 7,524.25 7,468.27 -4,118.97 -7,011.90 5,953,300.93 1,511,266.81 0.36 61.18 MWD+IFR-AK-CAZ-SC(7) 16,628.05 89.41 147.48 7,524.98 7,469.00 -4,200.18 -6,960.34 5,953,218.89 1,511,317.04 0.40 157.29 MWD+IFR-AK-CAZ-SC(7) 16,722.37 89.27 146.98 7,526.06 7,470.08 -4,279.48 -6,909.29 5,953,138.78 1,511,366.79 0.55 251.50 MWD+IFR-AK-CAZ-SC(7) 16,817.95 88.66 147.29 7,527.79 7,471.81 -4,359.75 -6,857.43 5,953,057.69 1,511,417.34 0.72 346.94 MWD+IFR-AK-CAZ-SC(7) 16,912.68 88.76 148.31 7,529.92 7,473.94 -4,439.89 -6,806.97 5,952,976.74 1,511,466.49 1.08 441.57 MWD+IFR-AK-CAZ-SC(7) 17,008.76 88.96 148.50 7,531.83 7,475.85 -4,521.71 -6,756.64 5,952,894.12 1,511,515.48 0.29 537.60 MWD+IFR-AK-CAZ-SC(7) 17,104.31 89.79 147.56 7,532.87 7,476.89 -4,602.76 -6,706.05 5,952,812.27 1,511,564.74 1.31 633.08 MWD+IFR-AK-CAZ-SC(7) 17,199.15 90.61 147.33 7,532.54 7,476.56 -4,682.70 -6,655.02 5,952,731.52 1,511,614.46 0.90 727.83 MWD+IFR-AK-CAZ-SC(7) 17,295.44 90.82 147.84 7,531.34 7,475.36 -4,763.98 -6,603.41 5,952,649.42 1,511,664.74 0.57 824.03 MWD+IFR-AK-CAZ-SC(7) 17,389.54 90.90 147.88 7,529.93 7,473.95 -4,843.65 -6,553.35 5,952,568.95 1,511,713.49 0.10 918.05 MWD+IFR-AK-CAZ-SC(7) 17,485.84 89.25 148.79 7,529.80 7,473.82 -4,925.61 -6,502.80 5,952,486.19 1,511,762.70 1.96 1,014.30 MWD+IFR-AK-CAZ-SC(7) 17,581.47 89.68 149.09 7,530.70 7,474.72 -5,007.53 -6,453.47 5,952,403.49 1,511,810.70 0.55 1,109.91 MWD+IFR-AK-CAZ-SC(7) 17,676.06 89.72 149.13 7,531.19 7,475.21 -5,088.70 -6,404.91 5,952,321.55 1,511,857.93 0.06 1,204.49 MWD+IFR-AK-CAZ-SC(7) 17,770.93 89.68 148.71 7,531.69 7,475.71 -5,169.95 -6,355.93 5,952,239.52 1,511,905.57 0.44 1,299.34 MWD+IFR-AK-CAZ-SC(7) 17,866.12 90.18 148.99 7,531.81 7,475.83 -5,251.41 -6,306.69 5,952,157.27 1,511,953.48 0.60 1,394.51 MWD+IFR-AK-CAZ-SC(7) 17,962.68 89.19 149.56 7,532.34 7,476.36 -5,334.42 -6,257.36 5,952,073.49 1,512,001.46 1.18 1,491.06 MWD+IFR-AK-CAZ-SC(7) 18,058.98 89.51 149.86 7,533.43 7,477.45 -5,417.57 -6,208.79 5,951,989.57 1,512,048.66 0.46 1,587.35 MWD+IFR-AK-CAZ-SC(7) 18,153.60 90.41 150.22 7,533.49 7,477.51 -5,499.54 -6,161.54 5,951,906.84 1,512,094.57 1.02 1,681.97 MWD+IFR-AK-CAZ-SC(7) 18,249.43 90.30 150.47 7,532.90 7,476.92 -5,582.82 -6,114.12 5,951,822.81 1,512,140.63 0.29 1,777.80 MWD+IFR-AK-CAZ-SC(7) 18,344.66 90.23 149.17 7,532.46 7,476.48 -5,665.14 -6,066.25 5,951,739.74 1,512,187.15 1.37 1,873.03 MWD+IFR-AK-CAZ-SC(7) 18,439.43 90.16 149.23 7,532.14 7,476.16 -5,746.54 -6,017.73 5,951,657.56 1,512,234.34 0.10 1,967.79 MWD+IFR-AK-CAZ-SC(7) 18,535.19 89.99 148.92 7,532.01 7,476.03 -5,828.69 -5,968.51 5,951,574.63 1,512,282.21 0.37 2,063.53 MWD+IFR-AK-CAZ-SC(7) 18,630.73 86.83 149.23 7,534.66 7,478.68 -5,910.60 -5,919.44 5,951,491.94 1,512,329.95 3.32 2,159.01 MWD+IFR-AK-CAZ-SC(7) 18,726.31 87.32 149.33 7,539.54 7,483.56 -5,992.66 -5,870.68 5,951,409.10 1,512,377.37 0.52 2,254.46 MWD+IFR-AK-CAZ-SC(7) 18,821.72 86.91 148.81 7,544.34 7,488.36 -6,074.40 -5,821.70 5,951,326.59 1,512,425.01 0.69 2,349.74 MWD+IFR-AK-CAZ-SC(7) 18,916.30 87.22 149.18 7,549.19 7,493.21 -6,155.36 -5,773.04 5,951,244.86 1,512,472.34 0.51 2,444.18 MWD+IFR-AK-CAZ-SC(7) 19,011.82 90.19 147.23 7,551.34 7,495.36 -6,236.51 -5,722.74 5,951,162.90 1,512,521.31 3.72 2,539.61 MWD+IFR-AK-CAZ-SC(7) 19,106.28 90.58 147.32 7,550.71 7,494.73 -6,315.98 -5,671.67 5,951,082.63 1,512,571.08 0.42 2,633.96 MWD+IFR-AK-CAZ-SC(7) 19,201.54 90.40 147.26 7,549.89 7,493.91 -6,396.13 -5,620.20 5,951,001.66 1,512,621.24 0.20 2,729.11 MWD+IFR-AK-CAZ-SC(7) 19,296.97 90.32 146.58 7,549.29 7,493.31 -6,476.09 -5,568.11 5,950,920.87 1,512,672.02 0.72 2,824.40 MWD+IFR-AK-CAZ-SC(7) 19,392.12 91.41 146.63 7,547.86 7,491.88 -6,555.52 -5,515.75 5,950,840.61 1,512,723.08 1.15 2,919.37 MWD+IFR-AK-CAZ-SC(7) 19,487.81 90.92 147.39 7,545.91 7,489.93 -6,635.76 -5,463.66 5,950,759.53 1,512,773.86 0.94 3,014.91 MWD+IFR-AK-CAZ-SC(7) 19,582.65 90.08 148.78 7,545.09 7,489.11 -6,716.26 -5,413.52 5,950,678.24 1,512,822.67 1.71 3,109.69 MWD+IFR-AK-CAZ-SC(7) 19,678.31 90.40 149.79 7,544.68 7,488.70 -6,798.50 -5,364.66 5,950,595.23 1,512,870.19 1.11 3,205.34 MWD+IFR-AK-CAZ-SC(7) 4/13/2015 10:40:23AM Page 4 COMPASS 5000.1 Build 65 • • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93A:19+36.98 @ 55.98usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 19,773.01 90.30 150.65 7,544.11 7,488.13 -6,880.69 -5,317.63 5,950,512.29 1,512,915.87 0.91 3,300.04 MWD+IFR-AK-CAZ-SC(7) 19,868.31 89.62 150.68 7,544.17 7,488.19 -6,963.77 -5,270.94 5,950,428.47 1,512,961.20 0.71 3,395.33 MWD+IFR-AK-CAZ-SC(7) 19,963.91 88.98 151.13 7,545.34 7,489.36 -7,047.30 -5,224.46 5,950,344.20 1,513,006.32 0.82 3,490.91 MWD+IFR-AK-CAZ-SC(7) 20,059.55 89.44 150.84 7,546.66 7,490.68 -7,130.93 -5,178.07 5,950,259.84 1,513,051.34 0.57 3,586.53 MWD+IFR-AK-CAZ-SC(7) 20,153.95 89.51 152.03 7,547.52 7,491.54 -7,213.83 -5,132.94 5,950,176.22 1,513,095.12 1.26 3,680.89 MWD+IFR-AK-CAZ-SC(7) 20,249.52 89.55 152.78 7,548.31 7,492.33 -7,298.53 -5,088.67 5,950,090.82 1,513,138.00 0.79 3,776.37 MWD+1FR-AK-CAZ-SC(7) 20,344.91 89.57 153.73 7,549.04 7,493.06 -7,383.71 -5,045.74 5,950,004.96 1,513,179.53 1.00 3,871.61 MWD+IFR-AK-CAZ-SC(7) 20,440.03 90.47 153.89 7,549.01 7,493.03 -7,469.06 -5,003.76 5,949,918.95 1,513,220.12 0.96 3,966.51 MWD+IFR-AK-CAZ-SC(7) 20,536.49 90.85 153.87 7,547.90 7,491.92 -7,555.66 -4,961.30 5,949,831.67 1,513,261.17 0.39 4,062.75 MWD+IFR-AK-CAZ-SC(7) 20,630.94 90.82 152.93 7,546.52 7,490.54 -7,640.11 -4,919.01 5,949,746.56 1,513,302.07 1.00 4,157.02 MWD+IFR-AK-CAZ-SC(7) 20,728.33 90.22 151.71 7,545.64 7,489.66 -7,726.35 -4,873.78 5,949,659.61 1,513,345.90 1.40 4,254.32 MWD+IFR-AK-CAZ-SC(7) 20,822.52 87.97 149.96 7,547.12 7,491.14 -7,808.58 -4,827.89 5,949,576.65 1,513,390.45 3.03 4,348.48 MWD+IFR-AK-CAZ-SC(7) 20,917.56 88.22 149.56 7,550.28 7,494.30 -7,890.64 -4,780.05 5,949,493.83 1,513,436.94 0.50 4,443.47 MWD+IFR-AK-CAZ-SC(7) 21,012.84 90.18 148.13 7,551.61 7,495.63 -7,972.16 -4,730.76 5,949,411.52 1,513,484.89 2.55 4,538.71 MWD+IFR-AK-CAZ-SC(7) 21,108.45 90.37 147.67 7,551.15 7,495.17 -8,053.15 -4,679.96 5,949,329.72 1,513,534.37 0.52 4,634.26 MWD+IFR-AK-CAZ-SC(7) 21,203.73 89.99 147.11 7,550.86 7,494.88 -8,133.41 -4,628.61 5,949,248.65 . 1,513,584.41 0.71 4,729.44 MWD+IFR-AK-CAZ-SC(7) 21,298.66 89.96 146.85 7,550.90 7,494.92 -8,213.01 -4,576.88 5,949,168.23 1,513,634.83 0.28 4,824.24 MWD+IFR-AK-CAZ-SC(7) 21,394.34 89.89 147.58 7,551.02 7,495.04 -8,293.45 -4,525.07 5,949,086.96 1,513,685.32 0.77 4,919.80 MWD+IFR-AK-CAZ-SC(7) 21,489.93 89.65 147.94 7,551.41 7,495.43 -8,374.30 -4,474.08 5,949,005.30 1,513,734.99 0.45 5,015.32 MWD+IFR-AK-CAZ-SC(7) 21,584.88 89.99 147.94 7,551.70 7,495.72 -8,454.77 -4,423.68 5,948,924.03 1,513,784.08 0.36 5,110.21 MWD+IFR-AK-CAZ-SC(7) 21,680.20 90.78 147.69 7,551.06 7,495.08 -8,535.44 -4,372.90 5,948,842.55 1,513,833.53 0.87 5,205.45 MWD+IFR-AK-CAZ-SC(7) 21,774.93 90.68 147.98 7,549.86 7,493.88 -8,615.62 -4,322.48 5,948,761.57 1,513,882.64 0.32 5,300.11 MWD+IFR-AK-CAZ-SC(7) 21,869.73 90.58 146.92 7,548.81 7,492.83 -8,695.52 -4,271.48 5,948,680.86 1,513,932.33 1.12 5,394.81 MWD+IFR-AK-CAZ-SC(7) 21,965.70 90.27 147.23 7,548.10 7,492.12 -8,776.08 -4,219.31 5,948,599.47 1,513,983.18 0.46 5,490.65 MWD+IFR-AK-CAZ-SC(7) 21,998.06 90.13 148.48 7,547.99 7,492.01 -8,803.48 -4,202.10 5,948,571.80 1,513,999.94 3.89 5,522.99 MWD+1FR-AK-CAZ-SC(7) 22,039.00 90.13 148.48 7,547.90 7,491.92 -8,838.38 -4,180.69 5,948,536.56 1,514,020.78 0.00 5,563.91 NOT an Actual Survey 4-1/2"x 6-1/8" 22,059.00 90.13 148.48 7,547.85 7,491.87 -8,855.42 -4,170.24 5,948,519.35 1,514,030.95 0.00 5,583.90 PROJECTED to TD NO an-.r'ia Nrvey 4/13/2015 10:40:23AM Page 5 COMPASS 5000.1 Build 65 • • 4.; 0 a 0 o I "W c = o o m N M > •C C rn^ M (Ism$t N • (Q m C O y _.+ i e />1 0 :I- 7,C O N Y 4! o _ a) y ON N r 12 ru 10 W0 -0 40 C ¢-I 0 (/) 0 0 0) C = Z E 6O N0 4., us > V +70 a) C v) h ❑ *+ N O S- a) t f+ 0 US 0 0 O O -k---r_, _ 'Q � ot3V Uc0 r--- p d 3 U o o N To 0 v U c N CO _ d , Y m a) LL w � dU) O (lU) L) ❑ ❑ ❑ ❑ w N M Q _ ai > W as 0 • C m � ra (/) El2 0 0 CC C a) :,-7 ti of TSF • • �w\� 1�j, s, THE STATE Alaska Oil and Gas °fALASIK:A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o ;•t Tw Main: 907.279.1433 ALAS r- Fax: 907.276.7542 www.aogcc.alaska.gov Robert Blakney ( � Sr. Completions Engineer 1 `�'' ) ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD4-93A Sundry Number: 315-170 Dear Mr. Blakney: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this 0 day of April, 2015 Encl. STATE OF ALASKA RECEIVED All OIL AND GAS CONSERVATION COMM�N APPLICATION FOR SUNDRY APPROVALS MAR 2 5 2015 20 AAC 25.280 1--c3 `,s 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change AAO r Suspend r Rug Perforations r Ferforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate pr. Alter casing r Other:Frac Treatment 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 1. 215-026 ' 3.Address: Stratigraphic6.API Number: r Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20690-01 , 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No J I CRU CD4-93A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 384209,380077,388902,384211 + 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): 13825 7472 12007' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 114' 114' SURFACE 2772 13.375" 2819' 2395' INTERMEDIATE 1 10509 9.625" 12348' 6904' INTERMEDIATE 2 2033 7 13820' 7472' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none na na na Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal pr. 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory r Stratigraphic r Development ' Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/8/2015 Oil p. • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265-6417 Email: Robert.G.Blakney@conocophillips.com Printed Name Robert BI-, ne Title: Sr. Completions Engineer Signature Phone:265-6417 Date 3 (z_...5(( 5 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 5 -17 Cj Plug Integrity r BOP Test/,r Mechanical Integrity Test /�r LocationClearancer Other: 19054 /4•/N''' Ors (t/UI Mo( Iv „'vQ. RLC Foci �'" - ' , //���-- . _(U! t sae s vac 4'01,43i vc.)w.4a.cf-oc v5.c,r plus o rrv4 o/2 20 AAG 25. 2.8 3. Spacing Exception Required? Yes 0 No b Subsequent Form Required: /a — t-Q/- � APPROVED BY d Approved by: /cLswl(/T" COMMISSIONER THE COMMISSION Date: T -3 —45— Approved application Is valid for 12 n1�ths tr_oi he date of approval."046...3_/� Form 10-403(Revised 10/2012) ORIGINAL ISI Submit Form and Attachments in Duplicate V L 3/31/is ON 3/2,6//J RBDMScAPR - 6 2015 • • CD4 — 93A Alpine A Producer - Planned Schematic iiiii i.. 20"944 H-40 Welded Upper Completion: Depth (MD) A ` I. Conductor to 114'lililill 3.5" L-80 EUE tubing --0-13,650' 110111 lijl 1)3-i/2"TRMAXX-5E SSSV --2500' 2.812"X Profile(5.176"OD) 2)SLB BHP Gauge, Encapsulated I-Wire --13,600 w/cannon clamps on every joint 3)X nipple 2.812" ID 13,620 13-3/8"684 L-80 BTC 4)WLEG 13,650 Surface Casing 2808'MD/2390'TVD 60° Lower Completion: cemented to surface 5)ZXP Liner Top Packer& Flexlock Liner Hanger — 13,650' • 6)4 W, 12.6#/ft, L-80 IBT-M Liner —13,650-21,500 w/ball actuated frac ports every—750' • • 7)toe circulating sub(1.25"ball seat) —21,560 Calculated TOC ©3388' MD &P-sleeves(-3500 psi shear) Top of Qannik @ 6492' MD/4080'TVD iilli I Iiii 3-1/2" 9.34 L-80 EUE in I iii i 7"x 9 5/8" Liner Top Packer 11800'MD/6708'TVD @ 69° • \0111 Sidetrack point • 12000' MD/6778' TVD @ 69° Iiii 7"26#L-80 Tenaris Blue Liner P sleeves and 400'7"29#TH110SS Tenaris Blue Tail :!!!! : ; Iiili!,:::.: •,...._,,, iiiii.;"'llilliiiiiiiiiliiiirliiilillii . to 13820'MD/7473'TVD 87° Toe circ sub ",f.1 d , : 4-Y2" 12.64 L-80 Liner 6 1/8"Hole TD 13650'MD/7455'TVD @ 81° 21562'MD/7555'TVD A iiiiiitfilliiiiili ;iiiiiiii :115111111.1111Nlis'illigill • CD4-93a Hydraulic Fracturing Smithy Application Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners an operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). ! • TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) VERIFICATION OF FACTS AND Commission in the Matter of the ) AFFIDAVIT OF DORA I.SORIA. Request of Conoco Alaska, Inc.for ) Hydraulic fracturing for CPAI ) CD94-93A under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Dora I.Soria,being first duly sworn, upon oath,deposes and states as follows: 1. My name is Dora Soria. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI"). 3. I am acquainted with the facts associated with the drilling of CD4-93A Well ("Well"). 4. I have reviewed the Application for Sundry Approvals for the proposal that the Well be stimulated by hydraulic fracturing as defined in 20 MC 25.283(m). To the best of my knowledge and belief all facts therein are true and accurate. 5. Pursuant to 20 MC 25.283 (1), CPAI, the well operator, prepared a Notice of Operations that is in compliance with the Provision of 20 MC 25.283. A copy of this notice is attached hereto ("Notice Letter") and includes a plat attached as Exhibit 1 in compliance with 20 MC 25.283(2). 7. On March 19, 2015, pursuant to 20 AAC 25.283 (1), CPAI sent a copy of the Notice Letter by certified mail to the last known address of all owners, landowners, surface owners, and operators of within a one-half mile radius of the current proposed trajectory stating that upon request CPAI will make a complete copy of the application available and providing CPAI's contact information. These names and addresses are set forth on Exhibit 2 attached to CPAI's Request the Application for Sundry Approvals under 20 AAC 25.283 dated January 20, 2015. Subscribed and sworn to this 19th day of March,2015. Dora I. Soria • • STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT This instrument was acknowledged before me this 19th day of March,2015,by Dora I. Soria. • •---- -- Notary Public, State of Alaska STATE OF ALASKA 4 NOTARY PUBLIC My Commission Expires: / (4 3 LA S F 7,JOIN oZ a i to REBECCA SWENSEN . I My Commission Expires Aug.27,2016 • P.0.Box 100360 r o Anchorage,AK 99510-0360 ®noPhi l'w Phone: 907-263-6297 March 19,2015 VIA HAND DELIVERY OR CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283 (1)for CD4-96A Well ADLs 372097,380075,380077,384209,384211,388902, CPAI Nos.931996,932034,932035,932076,932080,932351 Colville River Unit,Alaska CPAI Contract No.203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. as Operator and on behalf of the Colville River Unit working interest owners ("CPAP'), hereby notifies you that it is submitting an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.055 ("Application") for the CD4-96A Well ("Well"). This notice of operations is being provided pursuant to subsection of 20 AAC 25.283 effective March 19,2015. The Well is located on leases ADLs 380077,384209, 388902 as depicted on Exhibit 1. The surface,target and bottomhole location are as follows: Location FNL FEL Township Range Section Meridian Surface 2848.63 4896.503 11N 5E 19 Umiat Target 4778.95 2451.315 11N 4E 24 Urniat Bottomhole 737.8153 4333.3 UN 4E 36 Umiat Exhibit 1 shows the Well location and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section, as ellipses ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. Please contact me at the address or phone number shown below if you have any questions or require any additional information. Sincerely, • G Gr-..!. 44/!-con Dora I. Soria Staff Landman 700 G Street Anchorage,AK 99510 Phone: (907)265 6297 Attachments: Exhibits 1 &2 • • Exhibit 1 ADL380075 ADL372097 47, ADL380077 DL38 208 AD. 84211 ' r L384209 ADL38'209 a 0 0 / Legend 'v �89Q� PROPOSED WELL TRAJECTORY PROPOSED OPEN SECTION ADL388905 0 PROPOSED FRAC PORT 1f2 MILE RADIUS ASRF_NPR2 I JCPA OW'NEDLEASE REFERENCES: Wall Data:ConoePhltpsAtaskaWeis DatabaseATDB ConoeoPhillips Surface Fac,'hes:Notch Slope 6K Savoy 7125112 Pubtshe l 320113 Alaska Statenido 0,18 Gas Leases 1/1212015 Alaska,Inc Water Y.La11 Data.DNR-Groundeater Duabn No Potablo Water 11113.15 aro in the Castle River UntL tJ CD4 93A Plat Analysis >No Potable Wear Agu.'ers are in the CoY'JIc River Una LEASES 3/16/201 S OS o �c.1 ta)Antsd LS5 1,120f5 • Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator& Owner: ConocoPhillips Alaska,Inc. (Hand helivered) 700 G Street(Zip 99501) P. O.Box 100360 Anchorage,AK 99510 Attention: Patrick J.Wolfe, Manager North Slope Development Owners(Non-Operators): Anadarko E&P Onshore LLC 1099 18th Street, Suite 1800 Denver,CO 80202 Attention: Mike Nixson,Director Land-Alaska Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave. Suite 800 Anchorage,AK 99501 Attention: Paul Decker, Acting Director Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,Alaska 99503-5963 Attention: Teresa 1mm,Resource Development Manager Surface Owners: Mr.Isaac Nukapigak, President Kuukpik Corporation P.O.Box 89187 Nuigsut,AK 99789 State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave. Suite 800 Anchorage,AK 99501 Attention: Paul Decker,Acting Director • • 0 CD4-93a Hydraulic Fracturing Sundry Application Section 2 — Plat 20 AAC 25.283 (a)(2) \ '6,-- \ \ % .-.1 6.........______AIL4'9';,,C04.43 4a1 I. Ci4O) Vet \ '''IM11111.1.11 C04-3NP131 C01-304 _____V----A 4 LI / 1;---------_____? '' "114 0.,..,081cc4.2%-. co+lsent co,o______ -- 3, ........c.CUll"20044,3,‘Z#92.4 CO C04_302 0 co4.51 \ 04-3131,81V V r.co4-A ccosasne2:-.J1,04-24/‘ IA: 1.co,30,4 1 cokes ct,'"55' i ,,,, coos3.B.--4,10 %e 404.1iFill C04-N1 • "C04.11rat---;i39;fe ..-8 ‘., CV.4-2W1333, 1 1 t • 11111111.1111.11111.1111111.11.i 0,4,7111‘PB1 cpt.IVY‘i 211SP02 ,.., .......• • _________00003 CEA' . gC134.12 ' • ---- \\ • \\ : 76rep, * • • npt _ • cPs cif \ • .0. A \ • ,4,-, 6rc,,,, • ,..., , co\1, • • &Vt. i". • ,t- Ci. • -lifv• Pal--cowl,-17 a\ I... • ,..? te .,... ilk Legend • —WELLS IN 112 MILE RADIUS OF OPEN SECTION •••"...... -WELLS IN 112 MILE RADIUS OF TRAJECTORY .... -PROPOSED WELL TRAJECTORY •••.0.•"""" . ...PROPOSED OPEN SECTION '... : :National Petroleum Reserve-Alaska(NPR-A)Boundary • 93AopenBuff ./, • ED 1/2 MILE RADIUS .• . • rine River Unit • • Maw Operated Units REFERENCES. NOV. W91 Data:ConotoPhillas Alaska Wets Database&TDB Surface Faciaties North Slope 6I(Sutvey 7/25112 Publahni 3/20/13 ConocoPhillips Alaska Stalesside CU&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data.CINR-Ground ratter DMs'on N .No Potable Water We are in the CoWle River Unit CD4-93A Plat Analysis a No Potable Water Aquifers are h the CoNtra Rivet Unit A WELLS 3/1612015 I es a iRef .3111),,,ICS41.11.1S i • Wells within .5 mile radius WELL_NAME API PERMIT_NUM BUS_AREA JD BUB_ID FLUID TYPE STATUS WELL_TYPE CD2-36 501032044700 203-014 ALP WNS MWAG ACTIVE INJ CD2-37 501032043400 202-211 ALP WNS OIL ACTIVE PROD CD2-60 501032051100 205-068 ALP WNS MWAG PA INJ CD2-60A 501032051101 209-115 ALP WNS MWAG ACTIVE INJ CD2-77 501032062900 210-179-0 ALP WNS OIL ACTIVE PROD CD4-03 501032064100 211-113-0 ALP WNS MWAG ACTIVE INJ CD4-05 501032055800 207-155 ALP WNS OIL ACTIVE PROD CD4-07 501032055300 207-118 ALP WNS OIL ACTIVE PROD CD4-12 501032041401 210-091 ALP WNS MWAG ACTIVE INJ CD4-12PB1 501032041470 210-091 ALP WNS PA EXPEND CD4-16 501032053500 206-131 ALP WNS OIL ACTIVE PROD CD4-17 501032053400 206-118 ALP WNS MWAG ACTIVE INJ CD4-208 501032051700 205-162-0 NANUQ WNS MWAG PA INJ CD4-208A 501032051701 211-060-0 ALP WNS OIL ACTIVE PROD CD4-208APB1 501032051771 211-060-0 ALP WNS PA EXPEND CD4-208PB1 501032051770 205-162-0 NANUQ WNS PA EXPEND CD4-209 501032053200 206-065 NANUQ WNS MWAG ACTIVE INJ CD4-210 501032053300 206-077 NANUQ WNS OIL PA PROD CD4-210A 501032053301 211-072-0 ALP WNS OIL ACTIVE PROD CD4-210APB1 501032053370 211-072-0 ALP WNS PA EXPEND CD4-211 501032053800 206-153 NANUQ WNS OIL ACTIVE PROD CD4-213 501032054000 206-173 NANUQ WNS PA IN) CD4-213A 501032054001 212-003-0 ALP WNS PA IN) CD4-213B 501032054002 212-005-0 ALP WNS MWAG ACTIVE INJ CD4-213BPB1 501032054070 212-005-0 ALP WNS PA EXPEND CD4-213BPB2 501032054071 212-005-0 ALP WNS PA EXPEND CD4-214 501032053700 206-145 NANUQ WNS MWAG ACTIVE INJ CD4-215 501032053900 206-157 NANUQ WNS OIL ACTIVE PROD CD4-23 501032062100 210-067-0 ALP WNS OIL ACTIVE PROD CD4-23PB1 501032062170 210-067-0 ALP WNS PA EXPEND CD4-23PB2 501032062171 210-067-0 ALP WNS PA EXPEND CD4-24 501032060200 209-097-0 ALP WNS MWAG ACTIVE INJ CD4-24PB1 501032060270 209-097-0 ALP WNS PA EXPEND CD4-24PB2 501032060271 209-097-0 ALP WNS PA EXPEN D CD4-25 501032060800 209-150 ALP WNS OIL ACTIVE PROD CD4-25L1 501032060860 210-121-0 ALP WNS OIL ACTIVE PROD CD4-25P01 501032060870 209-150 ALP WNS PA EXPEND CD4-26 501032060000 209-049 ALP WNS MWAG ACTIVE INJ CD4-27 501032064400 211-146 ALP WNS MWAG ACTIVE IN) CD4-27PB1 501032064470 211-146 ALP WNS PA EXPEND CD4-27PB2 501032064471 211-146 ALP WNS PA EXPEND CD4-27PB3 501032064472 211-146 ALP WNS PA EXPEND CD4-289 501032069700 214-188-0 NANUQ WNS OIL ACTIVE PROD CD4-290 501032067400 213-130-0 NANUQ WNS OIL ACTIVE PROD CD4-291 501032067200 213-110-0 NANUQ WNS MWAG ACTIVE INJ CD4-291PB1 501032067270 213-110-0 NANUQ WNS PA EXPEND CD4-292 501032066900 213-035-0 NANUQ WNS OIL ACTIVE PROD CD4-298 501032062300 210-130-0 NANUQ WNS OIL ACTIVE PROD CD4-298PB1 501032062370 210-130-0 NANUQ WNS PA EXPEND CD4-301 501032055700 207-150 NANKUP WNS PA PROD CD4-301A 501032055701 207-174 NANKUP WNS PA PROD CD4-301B 501032055702 207-180 NANKUP WNS OIL ACTIVE PROD CD4-302 501032054500 207-056 NANKUP WNS MWAG ACTIVE INJ C04-304 501032055500 207-132 NANKUP WNS OIL ACTIVE PROD CD4-304P81 501032055570 207-132 NANKUP WNS PA EXPEND CD4-306 501032055000 207-094 NANKUP WNS MWAG ACTIVE INJ • • ___ WELL_NAME API PERMIT NUM BUS AREA BUB FLUID STATUS WELL CD4-318 501032051900 205-196 NANKUP WNS OIL PA PROD CD4-318A 501032051901 206-113 NANKUP WNS OIL ACTIVE PROD CD4-318PB1 501032051970 205-196 NANKUP WNS PA EXPEND CD4-319 501032051600 205-148 NANKUP WNS MWAG ACTIVE INJ CD4-320 501032053100 206-055 NANKUP WNS OIL ACTIVE PROD CD4-320PB1 501032053170 206-055 NANKUP WNS PA EXPEND CD4-321 501032053600 206-142 NANKUP WNS MWAG ACTIVE INJ CD4-322 501032055100 207-101 NANKUP WNS MWAG ACTIVE INJ CD4-93 501032069000 214-081-0 ALP WNS PA PROD CD4-96 501032067300 213-129-0 ALP WNS OIL PA PROD CD4-96A 501032067301 214-056-0 ALP WNS OIL ACTIVE PROD CD4-96APB1 501032067370 214-056-0 ALP WNS PA EXPEND NANUK1 501032023800 196-057 NAK NAK PA EXPLOR NANUQ 3 501032036500 201-026 NANUQ WNS PA EXPLOR NANUQ 5 501032041400 202-042 ALP WNS PA EXPLOR Well data sourced from ConocoPhillips Alaska Wells Database ATDB No Potable water wells are in the Colville Rive Unit-Source DNR groundwater Division CD4-93a Hydraulic Fracturing Sundry Application SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." • CD4-93a Hydraulic Fracturing Sundry Application SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore • trajectory and fracturing interval. A water well sampling plan is not applicable. • • CD4-93a Hydraulic Fracturing Sundry Application SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • CD4-93a Hydraulic Fracturing Sundry Application SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: CD4-93A: 13 & 3/8" casing cement pump report on 9/08/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement. Full returns were seen throughout the job and the pipe was reciprocated. The plug bumped @ 1,000 psi and the floats were checked and they held. 9 & 5/8" casing cement pump report on 9/20/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with water. The plug bumped and the floats were checked and they held. 7" casing cement pump report on 3/24/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 11.0 ppg mud. Rotated the liner and full returns were seen throughout the job. The plug bumped @ 1,260 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • • CD4-93a Hydraulic Fracturing Sundry Application SECTION 7— PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 9/12/2014 the 13 & 3/8" casing was pressure tested to 3500 psi for 30 mins. On 9/21/2014 the 9 & 5/8" casing was pressure tested to 3500 psi for 30 mins. On 3/24/2014, the 7" casing was pressure tested to 3500 psi for 30 mins. The 3.5" tubing will be pressure tested to 3,500 psi prior to frac'ing. The 7" casing will be pressure tested to 3,500 psi prior to frac'ing. • . 1 CD4-93a Hydraulic Fracturing Sundry Application SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collaspe 13 & 3/8" 68 L-80 5,020 psi _ 2,260 psi 9 & 5/8" 40 L-80 5,750 psi 3,090 psi 7" 26 L-80 7,240 psi 5,410 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi • • CD4— 93A Alpine A Producer - Planned Schematic :: 20"94#H-40 Welded Upper Completion: Ail ?:„.• Depth (MD) Conductor to 114' 3.5” L-80 EUE tubing -0-13,650' 1) 3-1/2''TRMAXX-5E SSSV 2500' 2.812"X Profile(5.176"OD) 2)SLB BHP Gauge,Encapsulated I-Wire 13,600 ihhii ----._e w/cannon clamps on every joint iiiiiiilln 3)X nipple 2.812" ID 13,620 13-3/8"68#L-80 BTC 4)WLEG 13,650 0 Mi Surface Casing Lower Completion: 2808'MD/2390'TVD@ 60° cemented to surface 5)ZXP Liner Top Packer& Flexlock Liner Hanger - 13,650' 6)4%", 12.6#/ft, L-80 IBT-M Liner -13,650-21,500 w/ball actuated frac ports every-750' 7)toe circulating sub(1.25"ball seat) 21,560 IIIII Calculated TOC @ 3388' MD &P-sleeves(--3500 psi shear) Top of Qannik @ 6492'MD/4080'TVD iii 3-1/2" 9.311 L-80 EUE iihi 7"x 9 5/8"Liner Top Packer 11800'MD/6708'TVD @ 69° Sidetrack point ! . 12000' MD/6778'TVD @ 69° .1....!..i....1.,.!...si....!' ':i11•1:1111::\\\.• '::''. :'4'1114'.. 7"26#L-80 Tenaris Blue Liner P sleeves and 400'7"29#TH110SS Tenaris Blue Tail . , >` to 13820'MD 17473'TVD @ 87° Toe circ sub 0 0 0 0 0 0 0 0 0 ---10D � ` 4'/2" 12.6#L-80 Liner �� 6 118" Hole TD iiiiiiiii 0 13650'MD/7455'TVD @ 81° --21562'MD/7555'TVD '' 0 o. i;•kill>; ;: _is _ _ • • CD4-93a Hydraulic Fracturing Sundry Application Stimulation Surface Rig-Up a L U_ Eked/Taltlo \ Tale Tacit • t' t' V Z 1,11 i1 1;1 11 8 • Minimum pressure rating on all surface 11:1 t� treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3500 psi 11001011 • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 H psi. er " .> t��►Y I d G Afrui dwnd U Pop Ofl Tank E Pop-ON Tank Z-v r Pump Truck Fin l Frac Pump 43 P►d- Frac Pump Frac Pump --� - FracPunp Frac Pump --r-193-1W+ Frac Pump Stimulation Tree Saver 0 • CD4-93a Hydraulic Fracturing Sunday Application OPEN POSITION CLOSED POSITION (I?IOR 10 WANI)THINDL It I ON) TiO f ANORLI.'TINS, LRIL Di /cfMC oNNEIRON r ti,„ r r rr ar _ . DREMOfECOPERATEDi wn wk.*. MASIER VALVE ............. rrr :(4..., it) MANUAL OPERATED /MASTER vuvE *!!!0.1.4.11,.. mimeo 'or 1)%low Nfri w .. Stin3?r Stinger .._..... MANDREL l_..._.. I . rji 1 • 1-2 VENT ®(.w--VALVE \\ OPEN 'e r� lilt IN - i1 Ilk.i 01 FLOW TEE AND } S?? r i VENT VAI WELLHEAD� 't );i7'. ; r VALVES _ }- //�:/�// OPEN "I. 7'Li GDj4�:iUr, ' �( t , , WELLHEAD r VALVES T CLOSED ., I Lt_7. i .}.- , • e it, ia1 0, \! -- \ OUADPACNOff ,� ( �j 4. ASSEMBLY IN PLACE IN TUBING a I \t.#p� } $ kms/ TUBING !, 1\\` r, r♦ • The universal tool is rated for 15,000 psi and has 84"of stroke. • Tool ID 2.25"down 4 V2 tubing and 1.75"down 3 %2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75"mandrel 36 bpm • 410 CD4-93a Hydraulic Fracturing Sundry Application SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 25' TVD thick at the heel of the lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 14,164' MD/7,438'TVDSS. The estimated fracture gradient for the Alpine A is 12.5 ppg. The overlying confining zone consists of over 600' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 11,956' MD/6708' TVDSS. CD4-93a Hydraulic Fracturing Sundry Application SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: CD4 - 24: 7" casing cement pump report on 12/15/2009 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.2 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1,300 psi and the floats were checked and they held. CD4 - 318: 7" casing cement pump report on 8/30/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.2 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1,100 psi and the floats were checked and they held. CD4 - 27: 7" casing cement pump report on 1/05/2012 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 11.3 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1,300 psi and the floats were checked and they held. CD4— 16: 7" Casing cement job was pumped on 6/21/2007 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.86 LSND mud. The plug was bumped @ 1,100 psi and floats held. Full returns were seen throughout the job. CD4— 322: 7" casing cement pump report on 8/12/2007 (1st stage) shows job was pumped to completion with returns up the annulus, indicating competent cementing operations. Bumped plug and checked floats. Tested casing to 3500 psi for 30 min. Pump report 8/13/2007 for 2nd stage pumped as designed. CD4 — 5: 7" casing cement pump report on 11/27/2007 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, bumped the plug on schedule with 2470 psi and checked floats and no pipe movement. CD4-17: 7" casing cement pump report on 9/24/2006 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, bumped the plug on schedule with 1200 psi, and floats held. CD4-321: 7" casing cement pump report on 10/21/2006 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, humped the plug on schedule with 1500 psi, and floats held. CD4-213h: 7" casing cement pump report on 11/24/2014 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, bumped the plug on schedule with 1500 psi, and floats held. CD4-26: 7-5/8" casing cement pump report on 5/16/2009 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, bumped the plug on schedule with 1270 psi, and floats held. • CD4-93a Hydraulic Fracturing Sundry Application CD4-23: 7-5/8" casing cement pump report on 7/24/2010 shows that the job was pumped as designed, indicating competent cementing operations. Bumped the plug on schedule with 1500 psi and the floats held. CD4-96a: 7-5/8" casing cement pump report on 6/23/2014 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, pipe was rotated and reciprocated, bumped the plug on schedule with 1220 psi, and floats held. CD4-25: 7-5/8" casing cement pump report on 10/12/2010 shows that the job was pumped as designed, indicating competent cementing operations. Bumped the plug on schedule with 1100 psi and floats held. CD4-210a: 7" casing cement pump report on 7/19/2011 shows that the job was pumped as designed, indicating competent cementing operations. Bumped the plug on schedule with 1480 psi and floats held. CD4-215: 7" casing cement pump report on 12/14/2006 shows that the job was pumped as designed, indicating competent cementing operations. The job was pumped with full returns throughout, bumped the plug on schedule with 1300 psi, and floats held. Summary All wells are cemented in accordance with 20 AAC 25.030. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • • CD4-93a Hydraulic Fracturing Sundry Application SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that there arewo fau_s or fractures that transect the Alpine A formation and may enter the confining zone within one half mile radius of the wellbore trajectory for CD4-93A. The larger fault is noted on the map, estimated (from CD4-93) to occur at approximately 18,710' MD. In addition to this fault, there may be an additional sub-seismic fault in the reservoir, inferred while drilling CD4-93, estimated to intersect the CD4-93A wellbore at approximately 20,960' MD. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • • CD4-93a Hydraulic Fracturing Sundry Application o 9.4) • • • • • • • • Seismically mopped • fault• , 18,710'MD • • • • • • 20,960'MD •• • • • • • Subselsmk fault Inferred from drilling data NPRA '•,3s•1".•., • • Legend ', --POSSIBLE FAULTS WITHIN 112 MILE of OPEN SECTION • �''• --PROPOSED WELL TRAJECTORY PROPOSED OPEN SECTION • ::::National Petroleum Reserve•Alaska(NPR•A) Boundary 93AopenBulf •••,,,s s..••s' ,,- QCPAI Operated Units REFERENCES' `yrs Vka Data.ConocoPnmt ps Alaska Vt4'tts Database ATOB Cono coPh•I I i ps SurlacoFaots NoahSlore 6KSurvey7/25'12PsVehed310'13 Alaska Stato,do WE Gas Leases I712l2015 Naska,6tc. Met kW!!Data:ONR-Groundwater Ovison >No Potoblo MC(%Wls aro in tho CO/We Riser Unit CD4-93A Plat Analysis Ho Potabto Water Agv3ers aro in tho Cohnfo Ryer Unit FAULTS 3/16/2015 1 os o r't3 <A3!CS T.7CS1113:713 * Map view depiction of seismically mapped faults and sub-seismic inferred faults (orientation unknown) from drilling data faults located within '/ mile radius of the reservoir well section (highlighted in red) in which the hydraulic fracture is planned • • CD4-93a Hydraulic Fracturing Sundry Application SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD4 -93a will be completed in April 2014 as horizontal producer in the Alpine A formation. The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After each stage we will drop a ball (progressively getting larger), these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Schlumberger Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 24 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 10,750 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 720 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7200 psi. 9 300 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite ® 100 bbls YF127ST w/2 ppa 16/20 Carbolite ® 100 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 100 bbls YF127ST w/4 ppa 16/20 Carbolite ® 100 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 80 bbls YF127ST w/ 6 ppa 16/20 Carbolite ® Drop ball 1 ® 300 bbls YF127ST Pad © 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite ® 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite © 100 bbls YF127ST w/ 3 ppa 16/20 Carbolite • • CD4-93a Hydraulic Fracturing Sundry Application • 100 bbls YF127ST w/4 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 80 bbls YF127ST w/6 ppa 16/20 Carbolite • Drop ball 2 • 300 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/2 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 100 bbls YF127ST w/4 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 80 bbls YF127ST w/6 ppa 16/20 Carbolite • Drop ball 3 • 300 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/2 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 100 bbls YF127ST w/4 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 80 bbls YF127ST w/ 6 ppa 16/20 Carbolite • Drop ball 4 • 290 bbls YF127ST Pad • 90 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF127ST w/6 ppa 16/20 Carbolite • Drop ball 5 • 290 bbls YF127ST Pad • 90 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 6 ppa 16/20 Carbolite • Drop ball 6 o 290 bbls YF127ST Pad o 90 bbls YF127ST w/ 1 ppa 16/20 Carbolite O 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite o 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite © 140 bbls YF127ST w/6 ppa 16/20 Carbolite o Drop ball 7 • CD4-93a Hydraulic Fracturing Sundry Application • 340 bbls YF127ST Pad • 90 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF127ST w/6 ppa 16/20 Carbolite • 145 bbls YF127ST w/ 7 ppa 16/20 Carbolite • Drop ball 8 • 340 bbls YF127ST Pad • 90 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/2 ppa 16/20 Carbolite • 110 bbls YF127ST w/3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF127ST w/6 ppa 16/20 Carbolite • 145 bbls YF127ST w/ 7 ppa 16/20 Carbolite • Drop ball 9 • 400 bbls YF127ST Pad • 90 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF127ST w/6 ppa 16/20 Carbolite • 145 bbls YF127ST w/ 7 ppa 16/20 Carbolite • 150 bbls YF127ST w/ 7 ppa 16/20 Carbolite • Flush with 160 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx: 960,000 lbs 16/20 Carbolite 12. RDMO SLB Equipment, Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 0 • Client: ConocoPhillips Alaska Inc. Schlumberger Well: CD4-93a Basin/Field: Colville-Prudhoe Basin/ Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 3/24/2015 12:59 PM Report ID: RPT-35777 Fluid Name&Volume Additive Additive Description Concentration Volume 8882 Guar Polymer Slurry 6.2 Gal/1000 Gal 2,720.0 Gal D047 AntiFoam_Agent 0.1 Gal/1000 Gal _ 25.0 Gal F103 Surfactant 1 Gal/1000 Gal 435.0 Gal 1218 Breaker 0,1 Lb/1000 Gal 25.0 Lb YF127ST,WF127 438,900 Gal 1475 Breaker 8.5 Lb/1000 Gal 3,750.0 Lb 1532 Crosslinker 4.7 Gal/1000 Gal 2,060.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 870.0 Gal M002 Additive 1 Lb/1000 Gal 420.0 Lb M275 Bactericide 0.6 Lb/1000 Gal 250.0 Lb S522-1620 Propping Agent varied concentrations 960,000.0 Lb The total volume leted in the tables above represents the summation of water and additives.Water Is suppled byctent CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplled by Client)' _78% 66402-68-4 Ceramic materials and wares,chemicals -21 % 64742-47-8 Distillates(petroleum),hydrotreated light <1% 9000-30-0 Guar gum <1 % 56-81-5 1,2,3-Propanetriol <1 % 7727-54-0 Diammonium peroxidisulphate <0.1% 1303-96.4 ( Sodium tetraborate decahydrate <0.1 % 107-21-1 G Ethylene glycol <0.1 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1 % 111-76-2 2-butoxyethanol <0.1% 67-63-0 Propan-2-ol <0.1 % 1310-73-2 Sodium hydroxide(impurity) <0.01% 7647-14-5 Sodium chloride(impurity) <0.01 % 34398.01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01% 34398-01-1(7E0) Linear C11 alcohol ethoxylate(leo) <0.01 % 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite <0.01% 25322-69-4 Polypropylene glycol <0.01% 7631-86-9 Silicon Dioxide <0.01% 10043-52-4 Calcium Chloride <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01% 10377-60-3 Magnesium nitrate <0.001 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 111-46-6 2,2"-oxydiethanol(Impurity) <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazoioi-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 68153-30-0 Amine treated smectite clay <0.001 % 9002-84-0 - poly(tetrafluoroethylene) <0.001 % 7447-40-7 I Potassium chloride(impurity) <0.001% 2682-20-4 2 methyl-2h-isothiazol-3-one <0.0001% 14808-60-7 Crystalline silica(impurity) <0.0001% 14464-46-1 Cristobalite <0.0001 % Total 100% •Mir water is supplied by she client.Schlumberger has performed no analysis of the seater and cannot provide a breakdown of components that may hove been added to the water be third-parties. 1 CAZIW R)Schlumberger 2015.Used by ConecoPhilips Aloske Inc.by permission. Page:1/1 i • ATTACHVENTI:PUMP SCHEDULE 403.27 2702 V.411.1. 6140 Sary PAY 22P. R)44.vTr. 0010 R_ or41J 171 WO Name C04-S34 I:n.cter-Gr St.,FFV 8520 A..t"f Pros. SSS] =,Fri T,:M 17127ST A:M.V1 Used 18G3CHECLT, STEP STAGE COVVE`JTS FLUID ER VP C. ORrYIOLWE DAT(VOLWJE FFEPPART CLUH MULE Enea.. P A TAPE PATE UTE STAGE CVM STAGE 0451 STAGE CAM STs 09055 CW &[Iter a6Fbl IE,14 1661) IEE.) (GEL) (GAL) ILES) ILES) ISEL4 18EL) 1/749+1) 1 1-ec14.11.,1 WF127 20 235 235 9852 6652 235 235 8.0 But 4,3.0,r3s000 peeve. 00 5 P. TF12751 20 200 250 485 10100 23352 250 255 8.0 3 E 4lin.r4 107127 20 240 235 719 6652 30204 235 719 5.0 Hard t...;...tor pm.. FLED RAI? CF WITTLCLWE ORTOLOLSJME PROPPAIT CLEAR SOLI.5 (,+cap._ STEP ST GE MIMES COMMENTS TAPE PATE RATE STAGE CIM STAGE CIA! STAGE CLII 525 0.005.5 CW &Herr PPA IUP81) I6J^11 (SAL) (OOL) (GEL) (GAL) 1151) 065) (EEL) )BOL( (075a) PAO TF12757 20 100 300 1019 12E00 42504 0 0 0 3(1 1019 5.0 1 FLAT TF12797 20 1.2 100 1119 4200 4700.4 4322 4,022 11W ea,. 96 1115 8,0 2 FLAT 4F12751 20 144 100 1219 4200 51204 7717 11,732 taleo-30.... 92 1207 5.0 3 FLAT YF127ST 20 I7 7 100 1019 4200 55404 11124 33.033 tam e..eaa ea 1235 0.0 4 FIAT Y7127ST 20 170 100 1419 420) 50604 14274 37,1366 ,1442 CvSrta 85 1380 10.0 5 FIAT TFIPST 20 161 100 1519 4200 63804 17156 54.332 ft.Car 44 62 1462 10.0 1 6 FIAT TF12751 20 158 50 (593 3300 67164 15931 70263 Ilan<a5c4e. 63 1525 10.0 Ball 1.51" DIaLEdE TF12701 20 200 15 1614 630 67794 0 70263 15 1540 8,0 I PAO YF12781 20 200 300 1914 12E00 41394 0 70,263 300 1840 8.0 1 1 MT YF127ST 20 142 100 2014 4203 64594 4022 74.285 14.31earbLea 96 1936 0.0 1 2 FLAT '77121ST 20 184 100 2114 4200 23794 7717 52,002 tarn Car.. 92 2028 8.0 1 3 FLAT 4F12751 20 17T 100 2214 4200 92514 11124 93,126 ma,000.4.a 68 2116 8.0 I 4 FIAT 5612701 20 170 IC.) 2314 4200 97194 14274 107,400 tsso 24.<4a. 65 M01 10.0 1 5 FIAT TF12757 20 , 164 100 2414 4300 101394 17196 124,596 1450 Ca-.a.. 82 2233 100 1 6 FIAT YF12707 20 106 80 2434 3360 104754 15531 140,526 1423ca .,• 63 2346 100 1 Ball 4.635" DISPLACE TF12751 20 :00 10 2504 420 505174 0 140526 10 2354 5.0 20 PAO 7712751 20 100 300 2804 12000 117774 0 140,526 300 2656 5.0 1I 1 FLAT 56(07ST 20 192 100 2904 4200 121474 4022 144,549 tam 0400w 93 2752 0.0 22 2 RUT TF12751 20 104 100 3004 4200 126174 7717 162266 142-20>4.44, 92 2844 8.0 23 3 FIAT 5612757 20 177 100 3104 4200 130374 11124 163,383 tlmc03,04. 83 2932 8.0 24 4 FLAT TF13751 20 170 100 3204 4203 134574 14274 177,663 0.m04.5444 85 3017 10.0 25 5 FUT TF12757 20 154 100 3304 4200 138774 17150 194,859 11.361.0..9. 82 3099 10.0 25 6 FLAT TF12701 20 156 80 3384 3360 142134 15931 210,79) 11045.540. 63 3162 10.0 27 8.111,76" DISPLACE 4F12757 20 200 10 3334 420 142514 0 210,790 10 3172 8.0 25 PAD YF12750 20 200 307 3694 12600 155154 0 210,790 300 3472 8.0 12 1 HAT TF12701 20 192 100 3794 4203 159354 4322 214,012 Icor 0v'e404 56 3562 8.0 30 2 FLAT 5F12751 20 1a4 100 3694 4207 163514 7717 222,529 1601CO S,Ll4 92 36.6) 80 31 3 FLAT TF12731 20 177 100 3994 4200 167704 11124 233,602 Ism Cr.. 65 3749 5.0 33 4 FLAT TF12731 20 170 100 4094 320) 171954 14274 247,926 14110.,1.41. 85 2633 10.0 33 5 FUT 571275T 20 164 100 4194 4200 176154 17196 265,)22 UT)c.d... 82 3215 100 34 6 FIAT 51(2751 20 153 to 4274 3360 176514 15931 231,053 5523030,44. 63 3976 10.0 55 Ball 1.813' aSFLACE 47127ST 20 200 10 4284 420 179934 0 241,053 10 35404 8.0 36 PAD SF12751 20 200 250 4574 (21E0 192114 0 281,053 230 4278 5.0 37 1 FUT TF12757 20 197 10 4664 3767 155634 3620 224,673 0.240.,SA44 56 4304 8.0 31 2 FLAT '(712751 20 184 100 4764 420) 200094 7717 292,350 15230.44n4. 92 4456 5.0 52 3 FIAT TF11751 20 17 7 110 4874 4Q0 204714 12236 2.33,626 125024.>4. 97 4553 8.0 ..) 4 FIAT 4F12757 20 170 120 4994 5050 209754 17129 321,754 1(0524,544.11 102 4555 10.0 41 5 FLAT YF12757 20 154 130 5124 5460 215214 22355 344,109 1471 Ca•3.AaTOO _ 4762 10.0 42 6 FLAT 5712757 20 (58 ' 140 5284 5850 221094 27879 371,959 Isla ea:.. 111 4372 100 43 Ball 1.255° PURACE TF12781 20 200 10 5274 420 221514 0 371,000 10 4582 5.0 44 PAD 0152721 20 :.10 290 5564 12164 233094 0 371,538 293 5172 0.0 45 1 FLAT 01121S7 20 15 2 90 5554 _ 375') 237474 3620 375507 103310,2A, 86 5258 8.0 4s 2 FLAT SF1275T 20 184 100 5754 4203 241674 7717 383,375 1601511144.54 52 5350 0.0 47 3 FLAT TF12757 20 I 7 7 1(0 5884 4620 246244 12236 395,560 3E.730.0.4.9. 97 5447 5.0 41 4 FLAT TF12751 20 170 120 5434 5040 251334 17129 412,633 1102005444 102 5543 10.0 43 5 FLAT YF12257 20 154 130 6114 541) 259794 22355 435044 UT Ea .I4. 106 5616 10.0 60 6 FLAT 4712757 20 153 ' 140 6254 5630 262674 77879 462,923 IATA C.rx9. 111 5736 100 51 Ball 1.94.3" du-ACE YF12751 24 20 10 6284 420 253094 0 462923 10 5776 80 55 PAD TF12757 20 ;00 243 6554 121E3 275274 0 923 250 6016 8.0 53 1 FLAT YF1273T_20 102 90 6644 3760 279054 3620 4E6,542 11.71074x11. 86 6103 8.0 34 2 FIAT 5112741 20 134 10) 8744 4200 283254 7717 474:1+3 1450 Carew 92 6245 8.0 65 3 FLAT _ 5112751 20 17 7 110 6834 4510 247874 11234 406,405 11^4 artnaa 97 6342 410 54 4 FIAT YF12750 20 170 120 6974 5040 232314 17129 503,624 1533415A44 102 6444 10.0 17 S FLAT 7112731 20 154 130 7104 545) 253374 22355 525,979 1401 0.0304s. 103 6510 100 55 6 FIAT TF12751 20 158 14) 7744 5887 304251 27879 553,658 (.710.44.'4. 111 0501 100 58 SAO 2' DISPLACE TF12751 20 200 10 7254 420 304974 0 553,658 10 6371 00 60 PAO TF12751 20 200 340 7594 14250 316553 0 553,658 340 7011 8.0 61 1 FLAT YF12751 20 192 90 7644 3763 322734 3020 557,477 15716+.e4.24 50 7101 8.0 22 2 FLAT SF12750 20 164 100 7784 42017 326934 7717 565155 1431 C,K3.9. 100 7201 5.0 63 3 FLAT TF12737 20 177 110 7594 .0520 331554 12236 577,433 1.00...44. 110 7311 0.0 14 4 FLAT YF12751 20 170 120 8014 5040 336594 17127 5.4.009 0.340i9044,6 120 7431 10.0 65 5 FLAT 7F127ST 20 164 130 8144 5460 342051 72355 616,914 1713 Ca..t.t. 130 7561 10.0 84 6 FLAT TF12757 20 155 143 8284 5883 347534 27679 641,793 1113 Cr.. 140 7701 100 II 7 FLAT TF12757 20 103 145 6421 6090 354024 32549 877,342 15200014/ 143 7846 10.0 _.. 14 Ball 2.053- 4054145E 5F1275T 20 200 10 5439 420 354444 0 677,342 10 7656 5.0 59 PAD 71121ST 20 200 340 8779 14283 352724 0 677,342 340 8156 5.0 70 1 FUT YF1275T 20 1.62 90 8569 376+) 372504 3620 680,951 lin u,TLe. E6 6252 8.0 11 2 FLAT TF17757 20 154 000 8969 4200 376704 7717 5+13,610 1000 Cale 62 8374 6.0 72 3 FAT 1F12757 20 17 7 110 9079 4620 331324 12235 710914 1x2103.514. 97 8471 5.0 73 4 FLAT YF127ST 20 170 120 9199 5540 356354 17129 718,043 1)000.0044. 102 6573 10.0 74 5 RUT Y712751 20 034 130 9329 5460 331824 22355 74)353 I030Ea,1.44. (CO 1679 100 75 6 FLAT 267121ST 20 156 140 9469 1320 377704 27879 785277 1311 ear.. III 8750 10.0 76 7 FLAT 267121ST 20 153 145 9.514 6090 493794 32549 802,028 1122645444 III 8971 10.0 77 0 8.1)2.10' DSPLACE SF12701 20 10 10 9624 420 004214 0 200.826 10 6911 8.0 76 i PAO TF12751 20 200 410 10024 16533 421014 0 600,826 4)0 9311 6.0 79 1 1 FLAT TF1275720102 90 10114 3700 424794 3020 80,445 315024,1:6.. 66 9337 8.0 60 1 2 FLAT TF12751 20 154 100 10214 4200 426014 7717 612,163 1wa4,.).1. 92 61518.0 51 1 3 FLAT TF12751 20 177 110 15324 4520 413614 12234 824,358 10240.n*4: 97 9166 - 0.0 62 1 4 FLAT TF12757 20 170 120 80404 5040 435654 17129 841,527 1333 c4.0.4.44 102 56-68 10.0 63 1 S FLAT TF12757 20 14 1300 10574 5450 444114 22355 653,807 1031.141. 106 9794 400 64 1 6 FIAT YF12781 20 158 100 10714 5660 443364 27379 831,761 3531 Cr.. 111 9435 10.0 6i 1 7 FLAT YF12781 20 153 145 15859 6090 456034 32519 934,310 la a)<sa4. III 1(116 10.0 (5 1 5 FIAT TF12751 20 , 118 . 145 11004 6050 462174 35593 4.40233 1.33..04 107 10173 10.0 e7 1 FLUSH TF12751 20 200 70 11074 2937 455111 70 10193 100 63 1 - FLUSH Y07127 20 200 70 11144 2937 458049 70 10262 10.0 _ e3 1 FLUSH Free/ 4(70) 20 220 19 11163 604 455852 19 10282 TOTALS 11163 960293 10282 50 aM own;SP&S.A... 2621E2815I FLUSH P,FORVATISN yaLLAsomeitaBeesA110R DsaTRAC• 71011115 STY TO TDP FORT. 340O•l PAC/FRAC.-11, 0P,2yTA1iG•415FQCM4Tgf( (3,9 IS FLUD ERT. 165 E3C.sillµl n'0v41 11,5. 1.109 IGS. 5341985 Fats Al) 20!4 .M&EPiL5AFO 3j.Q FLUSSD• 1 04 57130 FRC.sill ry TOTAL400• 10262/85 FLUSH VOL.159 FF CO011 LOSS. 81(21 •PEAS FRCS 0330)44 13712685 •.,1C4rCW',5 VD TO 11.)TAI. 14713 .3703 HUD.3)730 AN,TFr.11 Pes. GENERAL 148730 .D B.SLEEVE• 7155 EST.4355578.70.'17+1 N'41Hi-v000010. TASH5RE0VPID P.PE5166(-s4.El 170 FAST 51101£. 21533 -ANL. 2181 e.4528404t3•Aµr3354 PAD%URT(PATIO 3:0241 31% star E 03. 572.2]I% 272e7 531 TOTALSFOA1I S13009 V133 N% V 5;44 23% VFPERTUESO 6.2E. 10400 01337 Se's0 Paary. 6)744 31% S.A9 23% 1.1D31E MS AG 52E. 401A Water gilt 151144513% 4011 1., 13 23 (C'ALT IL)SG62E. 114 5 Fta4'.•Aels::.=2120 32.5.44 17 i1 605 S`a2e Puts 810 014)),,1 LENGTH V__�1E T69 Prs.S,Ir3 U1Ha.TW4 133 001e Ili., R Seat 54,LERO111L0.LTR T53. TE•prGn•(140 P14Fp111 543453 11 57351 24)11 3111(041 PHIS. CAS SO 72E. 4.6.302 •015261,1 61.11 57 U. 513212 33112 22006444 1.441 4176 1,744 lb Stn.3 11311 2341174 4555 PAIpT... 63.1145 B..Tma Stage4 11413 1111 L. 1111 513,316 11741 115 I LW 1.110 1175 3,744 11 5132.6 17231 1141611. 1113 1.05 114 sal &4237 40111 1121584 1.675 F121 ASS 9.1 $14241 11166 150411,1 (535 .3615 2,651 54! 51A249 14551 1103 L. 2.620 $4582 TED 10 524/4 13 14152 1160585 2341 ' 5152 3,711 p1 7:_`13 • cD Q CD 2 .Q V 2 < U— Co Na)M 0) a) co 4 11) CD U 5 • • , . I ci. (3 Q O O o o O O O O O O OG a. O O O O o O O O o O a_ 0 !Z O ,-- N CO V' (0 (0 N . CO O U) U) Q) U) C) U) U) U) L J J J :...i _D- ...i •=1- ._) N I co 0 0 0 0 0 0 0 0 'O N N N N N N N N C CO CO CO CO CO CO CO CO CO Q Q) CL F. CO kJ U 73 c Op) O O O O O o O O O O p N N N N N N N N N N vJ — w Q U S] 4a (U (n } 0)lit SD .SQ O CO v a) in ® O E ^ o 0 0 0 0 0 0 in o © }? to o �r <r v o O O O jv co N- - o 0) O LC) d7 Ca C) H I- I- 1- H H H H H r` coco E co co r co N co r co N Z N N N N N N N N N LL C a } >- >- >- >- i >- >- } ii 1 1 I Q. v .0 E@ E o 0 0 CD 0 0 0 0 0 o (1.) a. .fl N N N N N N N N N N -1--,a — 0 Cl) (l aQi coo n o 0 0 0 0 0CL 0 0 aS: r ,• h.. U Z r N CO V' to CD N- co (NN v— ` V • • W co oo ` •= •„,- "4---,- a) m o u� 'd: °° � > a .4_, C) 0 ) Ln (0 CC, � . >, _ ma) .= E -1- 'V > -u) Q -I " (n c O Q) v) 4 (CS c O U O •_Q. O Q. -= Et 1:1) C •- a) n :+ , _U (l) (n -0 -Q 8 7, (I3 0 a) > E 4- -C-D. ;48 O = ++ U -0 to O O O ca a) c . a) O F- mu_ *., a) . , pro _O � 4) a) a -c a L. L. . rs, .. �" 4•#• .0 L O •i•+ to a) O ✓ Vvs caLLZd o (LS E L • I Z� LL LL � =7ii 7,5 0. cL' a) w Q' cf, O to ++ :�+71. ° ® > E oC 'o � o �sa- - - 0. w < .- SCDa) aD c CO (n -0 a) •— z0 -0 ® ao (0 (na) oo N � E 2 � E E i • 4110 CD4-93a Hydraulic Fracturing Sundry Application SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) OFT�l \�\\11/7 4 , THE STATE Alaska Oil and Gas jt3 ofA LA..S KA Conservation Commission 1- -tAt_= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 04t, ALAS Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD4-93A ConocoPhillips Alaska, Inc. Permit No: 215-026 Surface Location: 2846 FNL, 4896' FEL, Sec. 19, T11N, R5E, UM Bottomhole Location: 737' FNL, 4333 FEL, Sec. 36, T11N, UM 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this /9 day of February, 2015. Da:,w t"' his i i u.'' en,W STATE OF ALASKA AL OIL AND GAS CONSERVATION COMMON FEB 0 5 2015 PERMIT TO DRILL 20 AAC 25.005 Arf% la.Type of Work: lb.Proposed Well Class: Development-Oil LI, Service- Winj U Single Zone ❑., • lc.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill 0' Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket E. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc.. Bond No. 59-52-180 • CRU CD4-93A - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360,Anchorage,AK 99510-0360 MD: 21562 ' TVD 7555 Colville River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Alpine Oil Pool . Surface: 2846.34 FNL;4896.44 FEL;Sec19;T11 N;R5E;UM • ADL 384209,380077,388902,384211 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4441.33 FNL,2508.71 FEL;Sec23;T11 N,R4E;UM Tobin No.932076,932036,932351 • 2/20/2015 Total Depth: 9.Acres in Property: 6941.24 . 14.Distance to Nearest Property: 737.82 FNL;4333.30 FEL;Sec36;T11N;R4E;UM 1.8 miles from ADL 390672 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 55.1 feet 15.Distance to Nearest Well Open Surface:x- 378,310.58 y- 5,957,557.99 Zone-4 - GL Elevation above MSL: . 18.8 feet to Same Pool: 25'(CD4-93) 16.Deviated wells: Kickoff depth: - 12000 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 90 degrees Downhole: 3,324 Surface: 2,5699 18.Casing Program: Specifications To1i`- Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length ' MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 77 37 37 114 114 cement in place 16" 13.375" 68# L-80 BTC-M 2772 37 37 2809 2390 1412 sx 11.2#,329 sx 15.8#cment in p 12.25" 9.625" 40# L-80 BTC-M 10509 1839 1771 12348 6904 1056 sx 12.2#,219 sx 15.8#cement in 8.75"x 9.875' 7.0" 26# L-80 BTC-M 13773 37 37 13810 7473 622 sx 15.8# 6.125" 4.5" 12.6# L-80 IBT-M 21525 37 37 21562 7555 Liner with frac sleeves 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): 21464 7559 Casing Length Size Cement Volume MD TVD Conductor/Structural 77 20 12 yds 114 114 Surface 2772 13.875 486.5 bbls lead,71.6 bbls tail 2819 2395 Intermediate 10509 9.625 458.8 bbls lead,50 bbls tail 12349 6904 Production 13879 7 133 bbls 13,955.00 7472 Liner 14280 4.5 n/a 21464 7559 Perforation Depth MD(ft): 14,030-14,050 Perforation Depth TVD(ft): 7,488-7,491 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 MC 25.050 requirements I] 21. Verbal Approval: Commission Representative: Date 2/5/2015 22. I hereby certify that the foregoing is true and correct. Contact Duncan Hyden 265-6862 Email Duncan.P.HydenAcop.com Printed Name G.L.Alvord Title Alaska Drilling Manager Signature f - . t--lam'& Phone 265-6120 Date 2/5/2015 Commission Use Only Permit to Drill V API Number: Permit Approval See cover letter for other Number: ) 0 �(, 50- )0. - aQ(o9O -0( -0:3 Date: r^� ,� � � �.A requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed meths p,gas hydrates,or gas contained in shales: g Other: B 0 p tr S f to 5U 0 r 5 1 Samples req'd: Yes No Y..I Mud log req'd:Yes❑ No Z /z}n r v/ cl r p )---C t7- N i--lr fr 5 f i b Z,3--- ()p5)H2S measures: Yes Nor❑�r Directional svy req'd:Yes No,❑ Spacing exception req'd: Yes III Nol!I Inclination-only svy req'd:Yes NoL`J/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:2 -/-,_--/5 Submit Form and Form 10-401(Revised 10/2012) This permit is valid fpr 4 pag "''�ff o thf date of a proval 20,E-C 25.005(g)) Attachments in Duplicate ConocoPhillips Alaska,Inc. � 4; t 0 S P.O.Box 100360 Anchorage,AK 99510-0360 FEB 0 5 Z015 ConocoPhillips Tel: 907-276-1215 AGOC February 5th,2015 O Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Re: Application for Permit to Drill CD4-93A Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore production well from the CD4 drilling pad with rig Doyon 19. The intended spud date for this well is 2/20/15. CD4-93A is planned to be a horizontal Alpine A sand producer.The original wellbore,CD4-93,was successfully drilled to a total depth of 21,562' The 4.5"completion liner became stuck while running in the hole at a depth of 14,317' and no further progress was made.The decision was made to complete the well to allow rigless interventions and potential production. Production was not achieved and it is now planned to returnCD4-93after the CD3 drilling season. The plan is to re-enter the well and sidetrack off of a whipstock out of the 9%"intermediate#1 casing at 12,000' MD/6,779' TVD.The second intermediate will be drilled with a 8 3/4"x 9'/a"drilling assembly down to the Alpine A sand.Managed Pressure Drilling technology will be utilized to assist with providing stability through the HRZ,Kalubik,and Miluveach formations. The section will be lined with a 7"cemented liner and tied-back to surface on a subsequent run. The production interval will be comprised of a 6%"horizontal hole that will be geo-steered in the Alpine A sand at 90° inclination.Managed Pressure Drilling will be used in this hole section to prevent wellbore breathing during connections.Once the drilling assembly is pulled from the hole,the the well will be completed as a producer with a 4.5"liner with sliding frac sleeves.A 3.5"tubing upper completion will then be run. It is the intention of ConocoPhillips to frac CD4-93A at a later date. Please find attached the information required by 20 ACC 25.005 (a) and(c) 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 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035(d)(2) 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b) 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 Duncan Hyden at 265-6862 (Duncan.P.Hyden(a,conocophillips.com)or Chip Alvord at 265-6120. Sincerely, cc: CD4-93A Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson ATO 1720 Chip Alvord ATO 1570 Duncan Hyden Jack Walker ATO 1740 Drilling Engineer Lanston Chin Kuukpik Corp IJINAL • Appli for Permit to Drill,Well CD4-93A Saved:5-Feb-15 CD4-93A Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(1) 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005 (c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005(c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005 (c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005 (c)(11) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) CD4-93A APD Page 1 of 15 ORIGINAL Printed:5-Feb-15 • Appn for Permit to Drill,Well CD4-93A Saved: 5-Feb-15 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005(c)(14) 15. Attachments 8 Attachment 1 Directional Plan 10 Attachment 2 Drilling Hazards Summary 11 Attachment 3 Well Schematic 13 Attachment 4 Cement Summary 14 CD4-93A APD Page 2of15 ORIGINAL Printed:5-Feb-15 • Applill for Permit to Drill,Well CD4-93A Saved:5-Feb-15 1. Well Name (Requirements of 20 AAC 25.005(fl) The well for which this application is submitted will be designated as CD4-93. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for: Location at Surface 2846.34 FNL;4896.44 FEL; Sec19;T11N;R5E;UM ' NAD 1927 RKB Elevation 55.1'AMSL Northings 5,957,557.99 Eastings: 378,310.58 Pad Elevation 18.8'AMSL Location at Top of Productive Interval 4441.33 FNL,2508.71 FEL; Sec23;T11N,R4E;UM (Heel) NAD 1927 Measured Depth, RKB: 13,810.35' Northings: 5,956,096.71 Eastings: 370,432.56 Total Vertical Depth, RKB: 7,473.00' Total Vertical Depth, SS: 7,417.55' Location at Total Depth 737.82 FNL;4333.30 FEL; Sec36;T11N;R4E;UM (Toe) NAD 1927 Measured Depth, RKB: 21,562.41' Northings: 5,949,182.95 Eastings: 373,776.16 Total Vertical Depth, RKB: 7,555.44' Total Vertical Depth, SS: 7,500.00' 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 of 20 AAC 25.005(c)(3)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035(h)(2)is granted. At CD4,there has not been a significant indication of shallow gas or gas hydrates above the C30 where casing will be set. 01? c/ c 1 Please reference BOP schematics on file for Doyon 19. CD4-93A APD Page 3 of 15 0 . 1GINAL Printed:5-Feb-15 AppSon for Permit to Drill,Well CD4-93A Saved:5-Feb-15 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Csg Setting Depth Fracture Pore pressure ASP Drilling Size(in) MD/TVD(ft) Gradient(ppg) (psi) (psi) 9.625 12000/6778 16.4 2982 2541 7 13810/7473 12.5 3288 2569 4.5 21562/7555 12.5 3324 N/A 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 FPP=0.4525 x TVD 1. ASP CALCULATIONS a. Drilling below intermediate liner(9-5/8") ASP=[(FG x 0.052)—0.1] D =[(16.4 x 0.052)—0.1]x 6778=5103 psi OR ASP=FPP—(0.1 x D) =3288—(0.1 x 7473)=2541 psi f b. Drilling below intermediate casing(7") ASP=[(FG x 0.052)—0.1] D = [(12.5 x 0.052)—0.1] x 7473 =4110 psi OR ASP=FPP—(0.1 x D) =3324—(0.1 x 7555)=2569 psi I (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary CD4-93A APD Page 4 of 15 ORIGINAL Printed:5-Feb-15 . App ,n for Permit to Drill,Well CD4-93A Saved:5-Feb-15 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cement in Place Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) fn) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement in Place 20 42 65 H-40 Welded 77 Surf 114/114 Cemented 3/25/14 Cemented on 9/8/14 to Surface with 13 3/8 16 68 L-80 BTC-M 2,772 Surf 2,809/2,390 486.5 bbls ASLite Lead 11 ppg, 71.6 bbls Class G Tail Slurry 15.6 ppg Cemented on 9/20/14 with 458.8 bbls 9 5/8 12 1/4 40 L-80 BTC-M 10,509 1,839/1,771 12,348/6,904 Class G Lead at 12.2 ppg w/TOC at 5488' MD(Qannik Isolation)followed by 50 bbls Class G Tail at 15.8 ppg Casing and Cementing Program Csg/Tbg Hole weight Length Top MD/TVD Btm MD/TVD OD(in) Sizel (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program Tie- 7 26 L-80 BTC-M 11,763 Surf 11,800/6,708 Uncemented tie-back back 7 8 3/4 26 L-80 Tenaris 2 010 11 800/6,708 13,810/7,473 622 sx Class G 15.8 ppg to liner top at -- x 9 7/8 Blue 11,800 MD EUE- 3 1/2 n/a 9.3 L-80 13,613 Surf 13,650/7,457 n/a 8RD-M 4 1/2 6 1/8 12.6 L-80 IBT-M 7,912' 13,650/7,457 21,562/7,555 Open hole liner w/frac sleeves 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Intermediate#2 Production Hole 8 3/4"x 9'/e" 6 1/g" 7"Casing Density 10.7 ppg 9.0 ppg PV As Low as Possible 7— 12 YP 20—25 10— 15 Funnel Viscosity Initial Gels 12—15 6—9 10 minute gels 20—25 8— 12 API Filtrate <5 cc/30 min HPHT Fluid Loss at 165 <8 cc/30 min <10 cc/30 min PH 9.5- 10.0 9.0-9.5 %by wt CaC12 n/a n/a Oil/Water Ratio n/a n/a CD4-93A APD Page 5 of 15 Printed:5-Feb-15 ORIGINAL Apon for Permit to Drill,Well CD4-93A Saved: 5-Feb-15 Intermediate#2: The lower intermediate section will be drilled with a lightly treated fresh water polymer mud(LSND). The drilling fluid will utilize RESINEX and Soltex for shale stability. Good filter cake quality,hole cleaning, and low drill solids will be very important in maintaining wellbore stability and minimizing torque and drag. Production Hole: The horizontal production interval will be drilled with M-I SWACO's FloPro WBM drill-in fluid. Sized calcium carbonate will be used as a bridging agent for proper filter cake building and fluid loss control.Micronized barite will be on location if higher than expected reservoir pressures are encountered. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD4-93A APD Page 6 of 15 O I G I N A L Printed:5-Feb-15 Apn for Permit to Drill,Well CD4-93A Saved: 5-Feb-15 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 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. 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: Completion Schematic. 1. MIRU Doyon 19 on CD4-93A 2. Pull BPV and VR plugs. Record tubing,IA and OA pressures. 3. Circulate out freeze protect to kill weight brine and monitor well for pressure. 4. Set BPV and test through IA to 1,500 psi for 10 minutes. Record test. Set blanking plug. 5. Nipple down tree 6. Nipple up BOPE&test to 250/3500 psi with 4 '/2"test joint. 7. Remove blanking plug and BPV. 8. Pull 4 '/2"upper completion and lay down same. 9. Change out upper VBRs to 7"solid body rams. Test same to 250/3500 psi 10. Pull 7"casing from tie-back at 12,100' MD and lay down same. 11. Change out upper VBRs to 3 '/2"x 6". Test same to 250/3500 psi with 5"test joint. 12. RIH and set CIBP at 12,100' MD 13. RIH, set whipstock at 12,000' MD and mill window. 14. Pick up motor BHA and run in hole to kick-off from window. 15. Drill 20' of new formation and perform FIT to 18.0 ppg EMW. 16. Once sidetrack is confirmed,pull out of hole for a 8 3/4"rotary steerable assembly with a 9'/g"hole opener. 17. Trip in hole to TD with rotary steerable assembly. 18. Displace to 10.7 ppg LSND WBM. 19. Install rotating head element. Hold 11.8 ppg EMW at the window by holding backpressure during connections. 20. Drill hole to intermediate casing point into the Alpine B sand maintaining 11.8 ppg EMW with MPD system (LWD Program: GR/RES/PWD). / 21. At TD,circulate until hole is clean. 22. Weight up to 11.8 ppg and pull out of hole on elevators. CD4-93A APD Page 7 of 15 Printed:5-Feb-15 ORIGINAL • AppliV for Permit to Drill,Well CD4-93A Saved:5-Feb-15 23. Change upper VBRs to 7"solid body rams. Test same to 250/3500 psi. 24. Run in hole with 7"liner on 5"drill pipe. 25. Run in hole to TD. 26. Circulate and reduce mud weight to 10.8 ppg. 27. Cement 7"liner while reciprocating and rotating if possible. 28. Land drill pipe dart in liner wiper plug and pressure up to set hanger and to release liner running tool. 29. Set 7"x 9%"packer. 30. Circulate out any excess cement. 31. Pull out of hole with liner running tool and lay down same. 32. Run 7"tie-back. 33. Displace backside of 7"to corrosion inhibited brine and diesel freeze protect.Test tie-back seals. 34. Change upper rams to 3 'h"x 6"VBR's. Test BOPE to 250/3500 psi with 4"&4 '/2"test joints. 35. Pick up RIH with 6 '/8"drilling assembly. (LWD Program: GR/PWD/AZI.RES.).'Test casing to 3500 psi. 36. Drill out and perform FIT to 12.5 ppg EMW. Minimum acceptable leak-off for drilling ahead is 11.8 ppg✓ EMW. 37. Install RCD element to hold back pressure during connections to minimize wellbore breathing. 38. Drill 6'/8"horizontal section to TD. 39. Circulate the hole clean,weight up for trip margin and pull out of hole. 40. Run lower completion of 4 '/2"liner with frac sleeves, liner top hanger/packer and swell packers for zonal isolation. 41. Run upper completion of 3 '/2",9.3#,L-80 EUE tubing with SSSV, 3 GLM,BHP gauge,Premier Packer,XN profile and wireline entry guide. 42. Space out and land hanger. 43. Install 2 way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 44. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 45. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 46. Drop ball and rod. Shear circulation valve in GLM. 47. Circulate tubing to diesel and install freeze protection in the annulus. 48. Set BPV and secure well. Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Incidental fluids developed from drilling operations on well ll CD4-93A will be injected into a permitted annulus on the CD4 pad,or the Class 1 disposal well on CDI pad. CD4-93A will not be a viable candidate for annular injection due to the four string casing design. 15. Attachments Attachment 1 Drilling Hazards Summary Attachment 2 Completion Schematic Attachment 3 Cement Summary& Calculations Attachment 4 Directional Plan CD4-93A APD Page 8 of 15 ORIGINAL Printed:5-Feb-15 AppIli for Permit to Drill,Well CD4-93A Saved:5-Feb-15 Attachment 1 —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) 8'/"x 9%8"INTRM2 Section-7"Liner w/Tieback Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material. Borehole Instability Moderate Use MPD equipment to provide a constant BHP while drilling and tripping pipe Reduced trip speeds,mud properties,proper hole filling,pumping Hole swabbing on trips Moderate out of hole,real time equivalent circulating density(ECD) monitoring,weighted sweeps. Abnormal Reservoir Pressure Low Well control drills,increased mud weight.No mapped faults occur across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers Monitor survey magnetics for interference that may indicate close approach,including continuous azimuth measurement from the RSS tool. Steer away from offset well if magnetic interference indicates proximity.Real-time tracking of traveling cylinder by rig site and town personnel to ensure we are not excessively encroaching on the Collision Risk w/CD4-16 Low offset well. Stop drilling immediately if a projection(180' from the bit)will cross the minor risk tolerance line(no-go circles). Monitor drilling parameters such as ROP,standpipe pressure rotary torque, returns at surface and volumes,etc.In order to recognize any indications of a possible collision. Shut-in CD4-16 while drilling the intermediate#2 section. 6'/s"Hole/Horizontal Production Hole Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Moderate circulating density(ECD)monitoring,mud rheology,lost circulation material Wellbore breathing Moderate Use MPD equipment to maintain constant BHP to prevent wellbore from breathing fluid back into wellbore Hole swabbing on trips Moderate Reduced trip speeds,mud properties,proper hole filling,pumping out of hole,ECD monitoring,weighted sweeps. BOPE drills,Keep mud weight above 8.8 ppg.Check for flow Abnormal Reservoir Pressure Medium during connections and if needed,increase mud weight.Well control drills,increased mud weight. Hydrogen Sulfide gas Low H2S drills,detection systems, alarms,standard well control practices, mud scavengers CD4-93A is in the Alpine A while CD4-23 is in the Alpine C.The two reservoirs are separated by—80' TVD of the Alpine B and have not found to be in communication.The Schlumberger Periscope Collision w/CD4-23 Low deep resistivity tool and geologist at the rig site monitoring cuttings are additional mitigations in place to confirm wellbore position. With a production tree on CD4-23 and a BOP stack on CD4-93A well control equipment is in place to handle this extremely remote possibility and prevent any release to the environment. CD4-93A APD Page 9 of 15 Printed:5-Feb-15 ORIGINAL Apillion for Permit to Drill,Well CD4-93A Saved:5-Feb-15 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the following attachments. Center Ellipse Clearance Summary Based on Offset Offset Well Name—Wellbore—Design Depth(ft) MD(ft) Separation Separation Factor Minimum (ft) (ft) (Minor Risked) CD4-16-CD4-16-CD4-16 12,605.99 10,625.00 212.34 211.63 301.56 Center Distance CD4-23-CD4-23-CD4-23 21,553.61 15,825.00 269.47 269.03 607.31 Clearance Factor CD4-23-CD4-23PB2-CD4-23PB2 18,136.16 12,400.00 418.85 418.12 573.64 Center Distance CD4-93-CD4-93-CD4-93 12,000.00 12,000.00 0.00 -0.81 0.000 Center Distance CD4-93-CD4-93-CD4-93 12,049.96 12,050.00 1.53 -2.83 0.351 Center Factor Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,the rig will be prepared to weight up if required. Lower Shale Stability: HRZ/Kalubik/Miluveach in the intermediate#2 hole section will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4- string casing design to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. CD4-93A APD Page 10 of 15 ORIG I n /( L Printed:5-Feb-15 0 Appli for Permit to Drill,Well CD4-93A Saved: 5-Feb-15 Attachment 2—Well Schematic CD4—93A Alpine A Producer Wp05 Proposed Schematic updated 2/4/2015 by D.Hyden I' Upper Completion: Length I 20"94#H-40 Welded '/z"126#/ft IBT-M Tubi. A 1! is Conductor to 114' 1)4 ng(2 jts) l; XO to 3-W EUE tubing I 2)3-W TRMAXX-5E SSSV 1.5' 1,, 2.812"X Profile(5.176"OD) • 3)3-''A"x 1"Camco KBMG GLM (xx°)w/DV 7' I 4)3-'/z'x 1"Camco KBMG GLM(xx°)w/DV 7' 5)3-%"x 1"Camco KBMG GLM(xx°)w/DCK2 7' r pinned for 2500 psi casing to tbg shear I •,- 13-3/8"68#L-80 BTC 6)SLB BHPauge,Encapsulated I-Wire Ili. Surface Casing Gauge, on clamps on every joint 1.5' 2808'MD/2390'TVD @ 60° 8)X nipple 2.812"ID 1.5' cemented to surface 9)WLEG 1.5' Lower Completion: 10)ZXP Liner Top Packer& Flexlock Liner Hanger 37' XO 5"Hydril 521 Box 4'/z'IBTM pin Calculated TOC©3388'MD 12)4 W, 12.6#/ft,L-80 IBT-M Liner w/ball actuated frac ports every-750' Top of Qannik @ 6492'MD/4080'TVD 13)toe circulating sub(1.25"ball seat)&P-sleeves(-3500 psi shear) 3-1/2" 9.3#L-80 EUE • • • • • • 7"x 9 5/8"Liner Top Packer 11800'MD/6708'TVD @ 69° i Sidetrack point k2000'MD/6778'TVD @ 69° 7"26#L-80 Tenaris Blue Liner P Sleeves and 400'7"29#TH110SS Tenaris Blue Tail • e ,to 13810'MD/7473'Tr x2_87° Toe circ sub III O_ 0 0 0 0 0 0 0 0 0 0 0 ,r 4'/3"12.6#L-80 Liner 6 1/8"Hole TD ¢ 'i. 9 5/8"40#L-80 BTC-M Liner to 13650'MD/7455'TVD @ 81° 21562'MD/7555'TVD .iiiiiii: to 12348'MD/6904'TVD @ 68° ni:iiiiiii.i i'ii: ii €::::::1110111€€>.€<`€ CD4-93A APD Page 11 of 15 Printed:5-Feb-15 JRIGINAL • Applen for Permit to Drill,Well CD4-93A Saved:5-Feb-15 Attachment 3—Cement Summary CD4-93A WP05 Proposed Casing Schematic In Place ' 20"H-40 Welded Conductor 114' In Place 13 4 18"68#L-80 BTC ,.2.809.'.MD/.2,a9a'.TVD.fi°aa3`.azi. In Place 9-5/8"40#L-80 BTC-M Liner 12,348'MD/6,904'ND 68°/175°azi ih 13,702'MD/7,409'TVD 7"26#L-80 Tenn Blue Liner 13,810'MD/7,473'TVD 87°/170°azi .� 14,096'MD/7,488'TVD Alpine A , 21,562'MD/7,555'TVD 6-1/8"Open Hole CD4-93A APD Page 12 of 15 ORIGINAL Printed:5-Feb-15 • ApplOn for Permit to Drill,Well CD4-93A Saved:5-Feb-15 CD4-93 Cementing Program: 7"Intermediate liner run to 13810' MD/7473' TVD Top of slurry is designed to be at liner top at 11806'MD.Assume 40% excess annular volume. Tail Slurry: (12000'-11800')x 0.1585 ft3/ft x 1.00(no excess)=32 ft3 liner lap vol. (13810'-12000')x 0.2646 ft3/ft x 1.4(40%excess)=671 ft3 annular vol. 80' x 0.2148 ft3/ft x 1.00(no excess)= 18 ft3 shoe track vol. Total volume=32+671+ 18=721 ft3=>622 Sk @ 1.16 ft3/sk System: 622 Sx Class G+0.4%D167,0.3%D65,0.03 gps B177, 0.2%D46 @ 15.8 ppg yielding 1.16 ft3/sk CD4-93A APD Page 13 of 15 Printed:5-Feb-15 ORIGINAL Appli.for Permit to Drill,Well CD4-93A Saved:5-Feb-15 Attachment 4— Directional Plan CD4-93A APD Page 14 of 15 ORIGINAL Printed:5-Feb-15 ritCD4-93/. vpO5 Permit Pack Plan Summary Base Pennafrost \ eB `5 C 20 nu 7"x 8-3/4"by 9-7/8" -5 > C-30 p IlL......." Imikik, s) 0) jri n1/ / chi �,�g� Qanni +eac - _ �� 17 0 1 1 1 1 1 1 1 I I 1 I I I I I I1 I 0 �_' 0 5000 10000 15000 20000 120"x421 13-3/8x16'j 4-1/2"x6-1/8Measured De.th120"x 42" Geodetic Datum: North American Datum 1983 Depth Reference: CD4-93:19+36.45 @ 55.45usft(Doyon 19)13-3/8"x 161 Rig: Doyon 19 '44 7 x83/4"by9 7/8" 41/2x6 1/8" 00 0 0 0 oa 0r rn o ro o m 0 ` c0 Ea co 0 N N N _ I I I I I 1 I 1 1 I 1 I 1 t 1 1 I I I I I I I �I I 0 12000 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 0 12000 - 12190 Horizontal Departure 330 l'‘''''''' "` 30 12190 - 12370 71/ - � / 12370 - 12560 r--- _ -- • 12560 12740 .2 '� �/� �- rt°4"4 ,�d'R 12740 - 12930 i0 60 l�'--- "._.. _____ ___. _..__.. 300 /l 11 h4. 1* � sig i 60 12930 - 13110 aai �, 4, �. 'lei0-14.'=r l 13110 - 13300 0 - , �/ f �i yy y A 13300 - 13650 E' - 11 i11 �����y\V 13650 14000 �I j11_ 1 i''i I` t` .�' (1 I ,,i \\ - a 14000 - 14350 o _-_-___ 270 1 F j.. /;!(11(11 a "SV!i f �\nt,r,,ii 90 14.350 - 14700 30 I }1� ` ,� , �f '•'41. 14700 - 15050 1 1+ ISI I - .\ t I 1'15 k 11.1 0 - ` I V �It "it,tt'',1 C,',4 1\�� 15050 - 15400 U _ \ � f (111'1 If11,��1\\\lI,120 � I 15400 - 15750 �l (1111 t, 15750 - 16100 oId11 nI I I I I I \ I I I , 16100 - 16780 12000 13500 15000 16500 18000 19500 21000 240 16780 - 17470 SURVEY PROGRAM r M1ds •f�"�r 17470 - 18150 Surface Location \!! d Oki . , 'fll�,� 18150 - 18830 e th From Depth To Survey/Plan Tool 1V�\ Oki- ltl0.0 ECM p 126.47 989.05 CD4-93 Srvy#1 GYD-GC-SS(CD4-93) GYD-GC-SS Pad Elevation: 19.00 210 `,� , /��-{068 v 150 18830 - 19520 1046.60 1177.83 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SMDBIFf38a,K-CAZ-SC t., 19520 20200 1270.63 1270.63 CD4-93 Srvy#3 GYD-GC-SS(CD4-93) GYD-GC-SS CASING DETAILS 180 20200 20880 1330.27 12000.00 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-865t(D67F824,K-CAZ-SC 20880 - 21562 12000.00 12450.00 CD4-93Awp05(Plan:CD4-93A) INC+TREND TVD MD Name TM 12450.00 13810.35 CD4-93Awp05(Plan:CD4-93A) MWD 7473.00 13810.35 7"x 8-3/4"by 9-7/8" Magnetic Model: BGGM2014 13810.35 15310.35 CD4-93Awp05(Plan:CD4-93A) MWD 7555.45 21562.41 4-1/2"x 6-1/8" Magnetic Model Date: 05-Mar-15 - 13810.35 21562.41 CD4-93Awp05(Plan:CD4-93A) MWD+IFR-AK-CAZ-SC Magnetic Declination: 18.42° To convert a Magnetic Direction to a True Direction,Add 18.42°East SECTION DETAILS 1555.4 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 12000.00 68.83 175.49 6778.59 54.65 -7909.77 0.00 0.00-4002.22 KOP:13.56°/100'DLS,45°TF,for 16.5' Base Permafrost 2 12016.50 70.42 177.17 6784.33 39.22 -7908.78 13.56 45.00-3988.36 Hold for 20' 3 12036.50 70.42 177.17 6791.04 20.40 -7907.85 0.00 0.00-3971.59 Start 3°/100'DLS,45°TF,for 50' 4 12086.50 71.48 178.29 6807.36 -26.83 -7905.99 3.00 45.00-3929.76 Start 2°/100'DLS,100°TF,for 50' -2415.4 5 12136.50 71.31 179.33 6823.31 -74.20 -7905.01 2.00 100.00-3888.24 Adjust TF to 150°,for 50' C-30 6 12186.50 70.45 179.86 6839.69 -121.44 -7904.67 2.00 150.00-3847.17 Start 3.5°/100'DLS,172.53°TF,for 421.4' -2755.4 7 12607.90 55.84 182.16 7029.58 -496.28 -7910.79 3.50 172.53-3525.60 Hold for 259.45' 8 12867.35 55.84 182.16 7175.27 -710.80 -7918.86 0.00 0.00-3343.86 Start 3.5°/100'DLS,-21.77°TF,for 943.01' 9 13810.35 87.00 170.49 7473.00 -1589.49 -7853.90 3.50 -21.77-2550.41 Hold for 428.96' C-20 10 14239.31 87.00 170.49 7495.45 -2011.96 -7783.09 0.00 0.00-2149.13 CD4-93ST 1.Heel 101714 DK Start 3.5°/100'DLS,65.02°TF,for 128.82' 11 14368.13 88.91 174.57 7500.05 -2139.58 -7766.36 3.50 65.02-2030.25 Hold for 261.1T 12 14629.30 88.91 174.57 7505.02 -2399.53 -7741.66 0.00 0.00-1792.78 Start 3.5°/100'DLS,-87.38°TF,for 416.8' 13 15046.10 89.60 160.00 7510.45 -2804.98 -7650.19 3.50 -87.38-1395.91 CD4-93ST 2.T2 101714 DK Start 2°/100'DLS,-90.03°TF,for 518.31' -3817.4 14 15564.42 89.60 149.63 7514.04 -3273.38 -7429.94 2.00 -90.03 -880.15 Hold for 5998' 4y 77K22-,34 Marker 15 21562.41 89.60 149.63 7555.45 -8448.38 -4397.85 0.00 0.00 5117.59 CD4-93ST 3.Toe 101714 DK TD:21562.41'MD,7555.45'ND -q�73,g Marker(Qanni Basal K-2 ■'"t-,.,> 5702.4 - Fai - I • -Collision Minor Risked -(f16Albian 97 Ettan 96(Nanuq) Nanuq Base ... -6755.5 HRZ =7j f•y.ne B ch Alpine A I.By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as s c in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted Brijby: Approved by: 0RIGINAehlfesiePotnis Nate Beck Duncan Hyden t ro ❑ 00 cxo q Northing (4500 usft/in) -1 I I l 1 1 I 0 1111111111 I I I I 1 1 1 1 1 1 1 1 1 I I I I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 U ❑ ❑ -- 1 J N - N O N — m p _ a ' 3U co ❑2 riT- N tD❑•a UN L CCS--) NO7 ❑ sU i. CO OQ U U ¢ OU N dU Nd co coo W Q cz NV OnN0 - — . • O 0 0 i-; ,,,,,••••": r / — /❑ m N ❑ O OM ❑Uccoo N -- U / ❑ O !'/ U ❑ /p� v � — - • o00/ — ► ` �' . (; - - •� UX N �0 N ❑ • ❑ N Q ❑ U r O O U Q o LO 0O — + UV N N U N ��� ` ❑ N d -0 uI N U V C ❑ - N U ❑ 3 ^^(� • M �` 0. II. cr .1 i, 0 a f` ❑ U !'ii op N 00 Q 0 O cq N d U ❑co. Z - • ,. QO C1 nrnr Cn V AWrt ape: cc? a 11,1111, 1\,....„. 8 lair, es/ ❑ . o o ,1 �1� .�a !�� +i 8 o, I ./ / v \l* !,? t. v NI 0 -a, In F la U _ W -.1r,-/--.01111.1.111P .. 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U , o 1 \ N U \ 11 0 i l I l l 12000 13500 15000 16500 18000 19500 21000 Measured Depth Displayed interval could be less than entire range: 12000.00 To 21562.41 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations, interval: 25.00 Depth Range From: 12000.00 To 21562.41 Results Limited By: Centre Distance: 2352.60 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 126.47 989.05 CD4-93 Srvy#1 GYD-GC-SS (CD4-93) GYD-GC-SS 1046.60 1177.83 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC(CD4-93)1WD+IFR-AK-CAZ-SC 1270.63 1270.63 CD4-93 Srvy#3 GYD-GC-SS (CD4-93) GYD-GC-SS 1330.27 12000.00 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC(CD4-93)1WD+IFR-AK-CAZ-SC 12000.00 12450.00 CD4-93Awp05 (Plan: CD4-93A) INC+TREND 12450.00 13810.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 15310.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 21562.41 CD4-93Awp05 (Plan: CD4-93A) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 7473.00 13810.35 7"x 8-3/4" by 9-7/8" 7 7555.45 21562.41 4-1/2"x 6-1/8" 4-1/2 -e-- CD2-60,CD2-60A,CD2-60A VO --X- CD4-24,CD4-24,CD4-24 VO - CD4-304,CD4-304,CD4-304 V6 ▪ CD4-03,CD4-03,CD4-03 VO -e- CD4-24,C04-24P81,CD4-24PB1 VO CD4-304,CD4-304PB1,CD4-304PB1 V16 - CD4-05,CD4-05,CD4-05 VO -.3- CD4-24,CD4-24PB2,CD4-24PB2 VO - CD4-306,CD4-306,CD4-306 V1 --X-- CD4-07,CD4-07,CD4-07 VI -X-- CD4-25,CD4-25,CD4-25 VO -40- CD4-318,CD4-318,CD4-318 V6 - C04-16,CD4-16,CD4-16 V2 -.3- CD4-25,CD4-25L1,CD4-25L1 VO --- CD4-316,CD4-318A,CD4-318A V5 - CD4-17,CD4-17,CD4-17 V13 -A- CD4-25,CD4-25PB1,CD4-25PB1 VO -A- CD4-318,CD4-318PB1,CD4-318PB1 V3 -9- CD4-208,CD4-208,CD4-208 V7 --1-- CD4-26,CD4-26,CD4-26 VO -0- CD4-319,CD4-319,CD4-319 V5 ▪ CD4-208,CD4-208A,CD4-208A V0 -0- CD4-27,CD4-27,CD4-27 VO --1-- CD4-320,CD4-320,CD4-320 V7 - CD4-208,CD4-208APB1,CD4-208APB1 VO -1- CD4-27,CD4-27PB1,CD4-27PB1 VO -9- CD4-320,CD4.320PB1,CD4-320PB1 V4 CD4-208,CD4-208PB1,CD4-208PB1 V6 -X- CD4-27,CD4-27PB2,CD4-27PB2 VO -0- CD4-321,CD4-321,CD4-321 V16 - CD4-209,CD4-209,CD4-209 V4 -A- CD4-27,CD4-27PB3,CD4-27PB3 VO -A- CD4-322,CD4-322,C04-322 V8 ▪ CD4-210,CD4-210,CD4-210 V3 -9- CD4-289,CD4-289,CD4-289 VO -A-- CD4-93,CD4-93,CD4-93 VO -9- CD4-210,C04-210A,CD4-210A VO -e- CD4-289,CD4-289,CD4-289wp05 VO -A- CD4-96,CD4-96,CD4-96 VO - - CD4-210,CD4-210APB1,CD4-210APB1 VO - CD4-290,CD4-290,CD4-290 VO -0- CD4-96,CD4-96A,CD4-96A VO -X- CD4-211,CD4-211,CD4-211 V2 -A- CD4-291,CD4-291,CD4-291 VO -e- CD4-96,CD4-96APB1,CD4-96AP81 VO 0 CD4-213,CD4-2138,CD4-2138 VO --X- CD4-291,CD4-291PB1,CD4-291P91 VO -e- Plan:CD4-286,Plan:CD4-266,CD4-286 wp03 VO *- CD4-213,CD4-213B,CD4-2136wp20.1 VO 2 C 292222, 04 92n(U -9- Plan:CD4-287,Plan:CD4-287,CD4-287wp02 VO T CD4-213,CD4-213BP81,CD4-213BPB1 VO tn2 , D4-24,4 9 @.... -A- Plan:CD4-288,Plan:CD4-288,CD4-288wp03 VO rne_ola rnn_l1raoao rn._o�¢aoao wn n ��nnJJ o n wn _G- oi..,rnn_jos Dim.,.rnn_ooa rnn_oon...m wn ! ConocoPhilli s CD4-93Awp05 Schlumberger Alaska . 1 .., . _ m Minor Risked 0 U • 300 - ---,I --..,______T 0 `o ca. - U CD1 y 150 U o _ \ a) U _ 12000 13500 15000 16500 18000 19500 21000 Measured Depth Displayed interval could be less than entire range: 12000.00 To 21562.41 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval: 25.00 Depth Range From: 12000.00 To 21562.41 Results Limited By: Centre Distance: 2352.60 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 126.47 989.05 CD4-93 Srvy#1 GYD-GC-SS (CD4-93) GYD-GC-SS 1046.60 1177.83 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC (CD4-93)IWD+IFR-AK-CAZ-SC 1270.63 1270.63 CD4-93 Srvy#3 GYD-GC-SS (CD4-93) GYD-GC-SS 1330.27 12000.00 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC (CD4-93)IWD+IFR-AK-CAZ-SC 12000.00 12450.00 CD4-93Awp05 (Plan: CD4-93A) INC+TREND 12450.00 13810.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 15310.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 21562.41 CD4-93Awp05 (Plan: CD4-93A) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 7473.00 13810.35 7"x 8-3/4" by 9-7/8" 7 7555.45 21562.41 4-1/2"x 6-1/8" 4-1/2 CD2-60,CD2-60A,CD2-60A VO CD4-24,CD4-24,CD4-24 VO -A- CD4-304,CD4-304,CD4-304 V6 ▪ CD4-03,CD4-03,CD4-03 VO -X- CD4-24,CD4-24PB1,CD4-24PB1 VO -I- CD4-304,CD4-304PB1,CD4-304P81 V16 -X- CD4-05,CD4-05,CD4-05 VO -A- CD4-24,CD4-24PB2,CD4-24PB2 VO El CD4-306,CD4-306,CD4-306 VI CD4-07,CD4-07,CD4-07 VI -I- CD4-25,CD4-25,CD4-25 VO -A- CD4-318,CD4-318,CD4-318 V6 -X- CD4-16,CD4-16,CD4-16 V2 -A- CD4-25,CD4-25L1,CD4-25L1 VO -4- CD4-318,CD4-318A,CD4-318A V5 - CD4-17,CD4-17,CD4-17 V13 -9- CD4-25,CD4-25PBI,CD4-25PB1 VO -B- CD4-318,CD4-31SPB1,CD4-318PB1 V3 -0- CD4-208,CD4-208,CD4-208 V7 -e- CD4-26,CD4-26,CD4-26 VO A CD4-319,CD4-319,CD4-319 V5 -9- CD4-208,CD4-208A,CD4-208A VO -A- CD4-27,CD4-27,CD4-27 VO -e- CD4-320,CD4-320,CD4-320 V7 -X- CD4-208,CD4-208APBI,CD4-208APB1 VO -e- CD4-27,CD4-27PB1,CD4-27PB1 VO -0- CD4-320,CD4-320PB1,CD4-320PB1 V4 -e- CD4-208,CD4-208PB1,CD4-208P81 V6 -i- CD4-27,CD4-27PB2,CD4-27PB2 VO A CD4 321,CD4-321,CD4-321 V16 -A- CD4-209,CD4-209,CD4-209 V4 $ CD4-27,CD4-27PB3,CD4-27PB3 VO -R- CD4-322,CD4-322,CD4-322 V8 $- CD4-210,CD4-210,CD4-210 V3 -0- CD4-289,CD4-289,CD4-289 VO -A- CD4-93,CD4-93,CD4-93 VO -A- CD4-210,CD4-210A,CD4-210A VO -X- CD4-289,CD4-289,CD4-289wp05 VO -A- CD4-96.CD4-96,CD4-96 VO -1- CD4-210,CD4-210APB1,CD4-210APB1 VO -4-- CD4-290,CD4-290,CD4-290 VO 0, CD4-96,CD4-96A,CD4-96A VO - CD4-211,CD4-211,CD4-211 V2 CD4-291,CD4-291,CD4-291 VO 0 CD4-96,CD4-96APB1,CD4-96APB1 VO -X- CD4-213,CD4-213B,CD4-213B VO - CD4-291,CD4-291PB1,CD4-29IPB1 VO -s- Plan:CD4-286,Plan:CD4-286,CD4-286 wp03 VO ▪ CD4-213,CD4-213B,CD4-213Bwp20.1 VO -X- CD4-292,CD4-292,CD4-292 VO -B- Plan:CD4-287,Plan:CD4-287,CD4-287wp02 VO -a- CD4-213,CD4-213BPB1,CD4-213BPB1 VO T* CD4-298,CD4-298,CD4-298 VO -{R- Plan:CD4-288,Plan:CD4-288,CD4-288wp03 VO �- rnn_91,1 rnn 7+9non9 rnn?i noon,vn rii: n[n f I_97 ii' r� n_1can,Mn -A- ni.,.,.rnn_non Dl...-rnn_900 rnn.,oc..,.,n,Mn 1110 conoc hli s CD4-93Awp05 mSchlumberger Alaska 60 / a 0 t I CD 30 - U V 0 Iv CDU --- 0 1 i r i I I I 1111 1 r- `i r T I i 1 1 r I i 12000 12150 12300 12450 12600 12750 12900 13050 Measured Depth Displayed interval could be less than entire range: 12000.00 To 21562.41 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval: 25.00 Depth Range From: 12000.00 To 21562.41 Results Limited By: Centre Distance: 2352.60 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 126.47 989.05 CD4-93 Srvy#1 GYD-GC-SS (CD4-93) GYD-GC-SS 1046.60 1177.83 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC (CD4-93)IWD+IFR-AK-CAZ-SC 1270.63 1270.63 CD4-93 Srvy#3 GYD-GC-SS (CD4-93) GYD-GC-SS 1330.27 12000.00 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC (CD4-93)IWD+IFR-AK-CAZ-SC 12000.00 12450.00 CD4-93Awp05 (Plan: CD4-93A) INC+TREND 12450.00 13810.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 15310.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 21562.41 CD4-93Awp05 (Plan: CD4-93A) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 7473.00 13810.35 7"x 8-3/4" by 9-7/8" 7 7555.45 21562.41 4-1/2"x 6-1/8" 4-1/2 -0- CD2-60,CD2-60A,CD2-60A VO -X- CD4-24,CD4-24,CD4-24 VO -a CD4-304,CD4-304,CD4-304 V6 CD4-03,CD4-03,CD4-03 VO -e- CD4-24,CD4-24PB1,CD4-24PB1 VO -I- CD4-304,CD4-304PB1,CD4-304PB1 V16 - CD4-05,CD4-05,CD4-05 VO -0- CD4-24,CD4-24PB2,CD4-24PB2 VO -A- CD4-306,CD4-306,CD4-306 VI X CD4-07,CD4-07,CD4-07 VI -X- CD4-25,CD4-25,CD4-25 VO -0- CD4-318,CD4-318,CD4-318 V6 - CD4-16,CD4-16,CD4-16 V2 -0- CD9-25,CD4-25L1,CD4-25L1 VO -X- CD4-318,CD4-318A,CD4-318A V5 - CD4-17,CD4-17,CD4-17 V13 -A- CD4-25,CD4-25PB1,CD4-25PB1 VO -A- CD4-318,CD4-318PB1,CD4-318PBI V3 -8- CD4-208,CD4-208,CD4-208 V7 -I-- CD4-26,CD4-26,CD4-26 VO -0.- CD4-319,CD4-319,CD4-319 V5 CD4-208,CD4-208A,CD4-208A VO --0- CD4-27,CD4-27,CD4-27 VO -I- CD4-320,CD4-320,CD4-320 V7 -e- CD4-208,CD4-208APB1,CD4-208APB1 VO --I- CD4-27,CD4-27PB1,CD4-27PB1 VO -EF CD4-320,CD4-320PB1,CD4-320PB1 V4 CD4-208,CD4-208PB1,CD4-208PB1 V6 -X- CD4-27,CD4-27PB2,CD4-27PB2 VO -0- CD4-321,CD4-321,CD4-321 V16 - CD4-209,CD4-209,CD4-209 V4 -A- CD4-27,CD4-27PB3,CD4-27PB3 VO CD4-322,CD4-322,CD4-322 V8 -h- CD4-210,CD4-210,CD4-210 V3 $ CD4-289,CD4-289,CD4-289 VO -A- CD4-93,CD4-93,CD4-93 VO - CD4-210,CD4-210A,CD4-210A VO -e- CD4-289,CD4-289,CD4-289wp05 VO -A- CD4-96,CD4-96,CD4-96 VO -X- CD4-210,CD4-210APB1,CD4-210APB1 VO -I- CD4-290,CD4-290,CD4-290 VO -0- CD4-96,CD4-96A,CD4-96A VO �- CD4-211,CD4-211,CD4-211 V2 � CD4-291,CD4-291,CD4-291 VO -e- CD4-96,CD4-96APB1,CD4-96APB1 VO - CD4-213,CD4-2138,CD4-213B VO - - CD4-291,CD4-291PB1,CD4-29IPBI VO � Plan:CD4-286,Plan:CD4-286,CD4-286 wp03 VO -0-* CD4-213,CD4-213B,CD4-213Bwp20.1 VO 't44924. 2 C 29yyytt VO �- Plan:CD4-287,Plan:CD4-287,CD4-287wp02 VO T CD4-213,CD4-213BPBI,CD4-213BPB1 VOci...,b4„9„czo_fl�-2y86 0 - Plan:CD4-288,Plan:CD4-288,CD4-288wp03 VO - rnn_.,a rnn,1'MAR,rnn_91 nuoov vn r n_TTo¢9Y���,..Jgn. rj,..x_o vn t.,.,rnn_oos of-rnn_va, rnn?an..,..na Ira oPhilli s , Conoc • p C D 4-9 3 Awp 0 5 Schlumberger Alaska U 60 - 111 0. t F. y 30 U ° - Minor Risked U 0 12000 12150 12300 12450 12600 12750 12900 13050 Measured Depth Displayed interval could be less than entire range: 12000.00 To 21562.41 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval: 25.00 Depth Range From: 12000.00 To 21562.41 Results Limited By: Centre Distance: 2352.60 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 126.47 989.05 CD4-93 Srvy#1 GYD-GC-SS (CD4-93) GYD-GC-SS 1046.60 1177.83 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC (CD4-93)1WD+IFR-AK-CAZ-SC 1270.63 1270.63 CD4-93 Srvy#3 GYD-GC-SS (CD4-93) GYD-GC-SS 1330.27 12000.00 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC (CD4-93)IWD+IFR-AK-CAZ-SC 12000.00 12450.00 CD4-93Awp05 (Plan: CD4-93A) INC+TREND 12450.00 13810.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 15310.35 CD4-93Awp05 (Plan: CD4-93A) MWD 13810.35 21562.41 CD4-93Awp05 (Plan: CD4-93A) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 7473.00 13810.35 7"x 8-3/4" by 9-7/8" 7 7555.45 21562.41 4-1/2"x 6-1/8" 4-1/2 -A- CD2-60,CD2-60A,CD2-60A VO CD4-24,CD4-24,CD4-24 VO -A- CD4-304,CD4-304,CD4-304 V6 -A- CD4-03,CD4-03,CD4-03 VO -- CD4-24,CD4-24PB1,CD4-24PB1 VO CD4-304,CD4-304PBI,CD4-304PBI VI6 X CD4-05,CD4-05,CD4-05 VO -A- CD4-24,CD4-24PB2,CD4-24PB2 VO -8- CD4-306,CD4-306,CD4-306 VI CD4-07,CD4-07,CD4-07 VI CD4-25,CD4-25,CD4-25 VO -A- CD4-318,CD4-318,CD4-318 V6 - - CD4-16,CD4-16,CD4-16 V2 -A- CD4-25,CD4-25L1,CD4-25L1 VO CD4-318,CD4-318A,CD4-318A V5 -0- CD4-17,CD4-17,CD4-17 V13 -9-- CD4-25,CD4-25PB1,CD4-25PB1 VO $- CD4-318,CD4-318PB1,CD4-318PB1 V3 CD4-208,CD4-208,CD4-208 V7 -e-- CD4-26,CD4-26,CD4-26 VO -A- CD4-319.CD4-319.CD4-319 V5 $- CD4-208,CD4-208A,CD4-208A VO -A- CD9-27,CD4-27,CD4-27 VO $ CD4-320,CD4-320,CD4-320 V7 - CD4-208,CD4-208APB1,CD4-208APB1 VO -8- CD9-27,CD4-27PB1,CD4-27PB1 VO -0- CD4-320,CD4-320PB1,CD4-320PB1 V9 - CD4-208,CD4-208PB1,CD4-208PBI V6 CD4-27,CD4-27PB2,CD4-27PB2 VO -- CD4-321,CD4-321,CD4-321 V16 -A- CD4-209,CD4-209,CD4-209 V4 $ CD4-27,CD4-27PB3,CD4-27PB3 VO $ CD4-322,CD4-322,CD4-322 V8 - CD4-210,CD4-210,CD4-210 V3 CD4-289,CD4-289,CD4-289 VO -A- CD4-93,CD4-93,CD4-93 VO ▪ CD4-210,CD4-210A,CD4-210A VO -X- CD4-289,CD4-289,CD4-289wp05 VO CD4-96,CD4-96,CD4-96 VO - CD4-210,CD4-210APB1,CD4-210APBl VO - CD4-290,CD4-290,CD4-290 VO -- CD4-96,CD4-96A,CD4-96A VO - - CD4-211,CD4-211,CD4-211 V2 -A- CD4-291,CD4-291,CD4-291 VO -e- CD4-96.CD4-96APB1,CD4-96APB1 VO X CD4-213,CD4-213B,CD4-213B VO CD 291,C11_D4444--�LD4-291PB1,CD4-291PB1V0 -e- Plan:CD4-286,Plan:CD4-286,CD4-286 wp03 VO CD4-213,CD4-213B,CD4-213Bwp20.1 VO � 2, ORM,42,C2U2 v\ /+�.r -9- Plan:CD4-287,Plan:CD4-287,CD4-287wp02 VO �- CD4-213.CD4-213BPB 1,CD4-213BPB1 VO 4-98, 4-2 ,C 44- Plan:CD4-288,Plan:CD4-288,CD4-288wp03 VO rnn_via rnn?ivnnu>rnn_vinnouv vn rrn eau rn r n_oc �_ ni,..rnn_voc oi..«.rnn_voa rnn ooc..,..m yr, MU IDC AD IVU +1W-3 *el-W meg trace vJec! target V 16VVV 12000.00 68.83 175.49 6778.59 54.65 -7909.77 0.00 0.00 -4002.22 CD4-93.40005 w 12016.5 42 177.17777 6784.33, 39.22 -7908.78 13.56 45.00 6 12000 12190 12000.00 To 21562.41 12086.5 .48 178.29 6807.36 -26.83 -7905.99 3.00 45.00 6 12190 12370 12136.50 71,31 179.33 6823.31 -74.20 -7905.01 2.00 100.00 3 8.24 12186.50 70.45 179.86 6839.69 -121.44 -7904.67 2.00 150.00 -3847.17 12607.90 55.84 182.16 7029.58 -496.28 -7910.79 3.50 172.53 -3525.60 12370 12560 12867.35 55.84 182.16 7175.27 -710.80 -7918.86 0.00 0.00 -3343.86 13:28.February 02 2015 13810.35 87.00 170.49 7473.00 -1589.49 -7853.90 3.50 -21.77 -2550.41 12560 12740 14239.31 87.00 170.49 7495.45 -2011.96 -7783.09 0.00 0.00 -2149.13 CD4-93ST 1.Heel 101714 DK 14368.13 88.91 174.57 7500.05 -2139.58 -7766.36 3.50 65.02 -2030.25 12740 12930 SURVEY PROGRAM 14629.30 88.91 174.57 7505.02 -2399.53 -7741.66 0.00 0.00 -1792.78 0000 From Depth To Survey/PlanToo! 15046.10 89.60 160.00 7510.45 -2804.98 -7650.19 3.50 -87.38 -1395.91 CD4-93ST 2.T2 101714 DK 126.47 989.05 C64-936rry#1 GY0-( SS86131-6211-SS 15564.42 89.60 149.63 7514.04 -3273.38 -7429.94 2.00 -90.03 -880.15 12930 13110 1046.60 1177.83 CD4-93 Soy PI MWOHFR-AMI AIMPS(@14'i91-$C 1270.63 1270.63 CD4-93 Soy 83 GYD-GCSSl6133-9M-S6 21562.41 89.60 149.63 7555.45 -8448.38 -4397.85 0.00 0,00 5117.59 CD4-93ST 3.Toe 101714 DK 1330.37 13009.00 CD4-93 Soy.MWDrIFR-AN00.W(6104581-SC 13110""" 13300 12000.00 13450.00 C134-93Awp05(Plan:CD4-93A31C0TREND 12450.00 13810.35 CD493Awp05(Plan:CD4.93.611WD 13810.35 15310.35 CD4934.wp05(Plan:CD4- WD 13300 13650 13810.35 21562.41 C13493Awp05(Plan:CD4-OS931yYYDHFR-AK-C/S-SC CASING DETAILS 13650 14000 TVD MD Name Size 14000 14000 14350 7473.00 238104'x 8-3/4"by 9-7/8" 7 _ -- .- 4-1/2"x 6-1/8" 4-1/2 • _ 7555.45 .3 --: 14350 14700 14700 _- 15050 15050 15400 0/360 15400 15750 -41 15750 16100 _--.®- z� . 16100 16780 30/330 y , �` ��' ,,�tet' iii j� 30 16780 17470 .� 7----=------,----4-- `'.� � ,2F=, 6 y 17470 18150 ti j -\�`4''''SS ^M5,',Z hFuZ`i a K At, \ 1"; 18150 18830 aws '`+ „ � 18830 19520 �r y am® .4 �--y - 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WDDR-AK-CAZSC CASING DETAILS 13650 14000 TVD MD Name Size 14000 14350 7473.00 13810.34"x 8-3/4"by 9-7/8" 7 7555.45 21562.41 4-1/2"x 6-1/8" 4-1/2 14350 14700 14700 15050 .:_ 15050 15400 MinorRisked 15400 15750 0/360 15750 16100 16100 16780 -30/330 210 16100 16780 / 30 16780 17470 l"/! 195 �i/, 17470 _ 18150 180 ����1 '' 18150 18830 165 �, , //��''''� ', 18830 19520 _ 150 \ fj/I����,'�'�''',/hi** ,, 19520 20200 tt, �i,'' `,' ,� �� I 20200 20880 60/300 121 'i'�rl '�� ,j , , 7 60 20880 21562 /4/ _�.tit, i X14, X# j 7/ , � Ali 11 1 x, 411 ..- viii ! 1 1 , */ IIE 111 ,„,, ii,/,/ // , //////////, , //, , . ._ , , ,, . ff, , :i: ,\ -90/270 � � �-90 � \'\i '0 , II ( ., , ,, \\\4 � � 01 \X$\ \\ %1111111 10 Ii,,,‘,,, Sti o�� -120/240 120 150 165 ..,:z_ 41" N. , ______ 180 \ 195 -150/210 210 •00000150 y -180/ 180 -1- $ r c 29070305 VO aaa>OI.c09.304P81 VII -6 C04.03.CD9-5160.CD9a8A VO � r -Pr � c $ c 9c .C09.96/081 CD9.90.81 vo -Pr _ c . •n,vo $ vo -A- $ c 9 PVR -X- • c c I vo --r $ PUR . 227049E vo -1- c -E c - -$ c09 -E c $ cC09-318P81v3 $ P,.rt . .aea.p3 vo c -o- C >3..5O4.r v9 $ C 4- r $ $ Mart .m5.9a0 VO $ 00,.1,.coma,.CD417v 3 9 c 9 CIA�26.C94•26PcOplIPT egvo�,4�y CDC - 81.CO4 r vo 9 c - -$ Plan e75 :CD4-0.7.C04-117,10vo -9- a o0 rat coa2o9 v7 a Pt0 vo 27 w p 09 vo -9- e ,Cl -B- COIL• meoa-70SP�, -B- c 004.10 9f c 9 7r c0(,272eyo ^-i c a°1� -@- CD9-321 C09.321.C09•321 VI6 �E c Goa OOPoPta VO 9 c 9 7e 04-1,74o 1,,"1 -B- cw-ozz.C09.322.C09.322 vs 9 Goa me.CD4-208P131.eo,2 a 6 9 C04.2.3.COL.23POI.e09.03P81 vo $ c00 r7.ew27 m.e VO c 00 v3 -$ C04.83.C0<03.c09.03 w MU 113c AZI 1 VU 4-1W-A *rJ-VV Uleg trace vnect target U • UUU 12000.00 68.83 175.49 6778.59 54.65 -7909.77 0.00 0.00 -4002.22 CD4-93Awp05 ;Zosao ,;;;,; 6;9,:04 39.22 20.40 -7909.85 10.0 40.00 - 12000 12190 19000.00 To 21562.41 12086.50 178.29 6807.36 -74.83 -7905.99 3.00 45.00 -3 12190 12370 12136.50 71.31 179.33 6823.31 -74.20 -7905.01 2.00 100.00 -388 .24 12186.50 70.45 179.86 6839.69 -121.44 -7904.67 2.00 150.00 -3847.17 12607.90 55.84 182.16 7029.58 -496.28 -7910.79 3.50 172.53 -3525.60 12370 12560 12867.35 55.84 182.16 7175.27 -710.80 -7918.86 0.00 0.00 -3343.86 16:19.February 04 2015 13810.35 87.00 170.49 7473.00 -1589.49 -7853.90 3.50 -21.77 -2550.41 12560 12740 14239.31 87.00 170.49 7495.45 -2011.96 -7783.09 0.00 0.00 -2149.13 CD4-93ST 1.Heel 101714 DK 14368.13 88.91 174.57 7500.05 -2139.58 -7766.36 3.50 65.02 -2030.25 12740 12930 SURVEY PROGRAM 14629.30 88.91 174.57 7505.02 -2399.53 -7741.66 0.00 0.00 -1792.78 epth Ecom Depth To Survey/Plan Tod 15046.10 89.60 160.00 7510.45 -2804.98 -7650.19 3.50 -87.38 -1395.91 CD4-93ST 2.T2 101714 DK 115.47 989.05 C0.93Srvy41 CYO-CC-SS(C7.11420-SS 15564.42 89.60 149.63 7514.04 -3273.38 -7429.94 2.00 -90.03 -880.15 12930 13110 1040.83 1270.83 CD4-93 srvy43 MWD4GYD.0 nnseam/7-SS 21562.41 89.60 149.63 7555.45 -8448.38 -4397.85 0.00 0.00 5117.59 CD4-93ST 3.Toe 101714 DK 0330.93 1177.83 CD4-935rvy42 4YUCCSS 0059SA 1330.17 12000.00 CD4.93Srvy44 MWD.DR-A964REND SC 13110 _.__._....... 13300 11000.00 11450.00 CD4093Awp05 Mem CD4-93WWC,TRE[m 11450.00 13810.35 C0-93Awp05(Plow CD4-93*WD 13910.35 15310.35 C0.93Awp0Dan:cD4-93.0[000 13300 13650 11810.35 11501.41 CD4-93Awp0S Men:C0.93�WD.DR-AK-CAZSC CASING DETAILS 13650 14000 TVD MD Name Size 14000 14350 7473.00 13810.30"x 8-3/4"by 9-7/8" 7 7555.45 21562.41 4-1/2"x 6-1/8" 4-1/2 14350 14700 14700 - 15050 15050 15400 0/360 15400 15750 15750 16100 16100 16780 -30/330 - -- _ 210 30 16780 17470 19517470 _ 18150 180 NN 18150 18830 165 \�` 18830 - 19520 150a 19520 20200 20200 20880 -60/300120 '� `, 60 20880 21562 r, •4 10 i ------1 1 _ -,,,1,_1.1111111 4i,iiiii 'T"', ,, 1 /it ( ,z �uup „ 4�. 4 5111111*,‘,'-\ , � II ��Il % 3 1I iil \,,, .\, ,K\N„,4111..., -90 1 270 90 \\ ,, 61 /'''' ,,, ! 1 \ \\ ftill -, / , ,z \ \ * 777', ------___-_\--- 79501 --: ::::,„, / \z,' / /\,.- 10 120/240 135 % ; // / y/ 120 _1 150_ --- / ���- __ 1165��� z. /� -150/210 -- 210---�/� 150 :� � 225 -180/ 180 co -- 690at.CMa10Y3 �- M.209„P05V0 -•.1- ao4.Co44o4P91.CM4mPe1v19 e -A- c $ CD4-210.004.2130,0042/0090 �E c9. . - -E- c $ cam.CMan.CM4m VI 9 c M-00POI..C04-96A Vo -3' Ca 3- 09 el CO -A, Co -o- CD 094,!.CMa10 V0 9 Port CD4-286...to co -93- CIN-OS -- CM-On..m4;n.cocz t C,3D P -1- -3f- 1 VO $ 700 .a3W002 V. -r- CM c94. -fr -x- W200Caza VO Pe $ 3V3 $ Mart 00..003 Cl CD4 1a ca°;n -o- ccP2D 1 V0 $ I..9.a z 0 + .t9.c94a00>0 4, a-31a:CD4a19Caa:VS -A- rt -20°. .. a..00t V0 $- c .c9.1>CM,>VII 9 C04-3.CD4.2;338P111.CD4.[ -9- coca. P ,� e�Va C04. C ee01.C134.20.1:111 w 9 094.320.C.04.320.00039 000 v> -6' n n a>5 .09407,094 w vo $ c0-ma 000.x0.cwaa v7 9 CMsO3.CMaueC.2.coo-tixP..Vo $ coo4. c =-+>e 5q6 _ LU 401 VO 9 c . .co4.3t0ret.cw 320 v4 $ c94.93A,059� $ C 004045.004.215.094043 V4 9 CM-a> CD�1�Di D4.30IA V0 $ C CD4-321.CM421 v1 �E C - $ CDst3.004.23.00.23 59 -1-- CD.a. DN4, 11 .0040018 Vo $ C114.322 CwaII.094022 ve 9 CD4 A.C04 209P.4.CD4.t00P0l Vt 9 CM03.C94.i9Ym.CM.x3PN!00 $ C04-27.C04.x>Pe3.CD4x>Fm V0 2 402 V5 $ C04.93.Co4-93.CM.93 VO • • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD4 Nanuq Pad CD4-93 Plan: CD4-93A Plan: CD4-93Awp05 Error Ellipse Survey Report 04 February, 2015 Multiply by 2.58 ORIGINAL • Schlumberger4111 Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93: 19+36.45 @ 55.45usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93: 19+36.45 @ 55.45usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: Plan:CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93Awp05 Output errors are at 1.00 sigma Multiply by 2.58 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site CD4 Nanuq Pad Site Position: Northing: Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.93 ° Well CD4-93 Well Position +N/-S 0.00 usft Northing: usft Latitude: +E/-W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 19.00 usft Wellbore Plan:CD4-93A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) I BGGM2014 3/5/2015 18.42 80.77 57,538 Design CD4-93Awp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,000.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 36.45 0.00 0.00 150.00 Survey Tool Program Date 2/4/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 126.47 989.05 CD4-93 Srvy#1 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 1,046.60 1,177.83 CD4-93 Srvy#2 MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 1,270.63 1,270.63 CD4-93 Srvy#3 GYD-GC-SS(CD4-93) GYD-GC-SS Gyrodata gyro single shots 1,330.27 12,000.00 CD4-93 Srvy#4 MWD+IFR-AK-CAZ-SC( MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC 12,000.00 12,450.00 CD4-93Awp05(Plan:CD4-93A) INC+TREND Inclinometer+known azi trend 12,450.00 13,810.35 CD4-93Awp05(Plan:CD4-93A) MWD MWD-Standard 13,810.35 15,310.35 CD4-93Awp05(Plan:CD4-93A) MWD MWD-Standard 13,810.35 21,562.41 CD4-93Awp05(Plan:CD4-93A) MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) 0) 01 (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) l) 12,000.00 66.83 175.49 6,778.59 20.04 -4.99 12.92 7.56 14.76 5.59 9.42 45.99 11.19 93.80 MWD+IFR-AK-CAZ-SC(1,4) 12,016.50 70.42 177.17 6,784.33 19.38 -4.98 12.69 7.54 14.73 5.59 9.43 46.14 11.66 93.62 INC+TREND(1,5) 12,036.50 70.42 177.17 6,791.04 19.39 -4.98 16.17 7.54 14.74 5.60 9.43 46.16 15.33 93.96 INC+TREND(1,5) 12,086.50 71.48 178.29 6,807.36 19.00 -4.98 31.43 7.52 14.80 5.63 9.46 46.32 30.90 97.87 INC+TREND(1,5) 2/4/2015 4:05:35PM Page 2 COMPASS 5000.1 Build 65 ORIGINAL iSchlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93:19+36.45 @ 55.45usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93:19+36.45 @ 55.45usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: Plan:CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93Awp05 Output errors are at 1.00 sigma aL,Multiply by 2.58 Database: OAKEDMP2 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (1 (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 12,136.50 71.31 179.33 6,823.31 19.18 -4.93 49.08 7.50 14.87 5.65 9.48 50.10 44.92 152.26 INC+TREND(1,5) 12,186.50 70.45 179.86 6,839.69 19.70 -4.86 67.21 7.48 14.97 5.67 9.50 67.38 45.84 174.28 INC+TREND(1,5) 12,607.90 55.84 182.16 7,029.58 28.28 -3.63 160.97 7.59 15.82 6.00 9.96 161.13 46.12 179.43 MWD(1,6) 12,653.97 55.84 182.16 7,055.45 28.28 -3.63 160.99 7.70 15.83 6.09 10.14 161.15 46.14 179.48 MWD(1,6) 12,760.82 55.84 182.16 7,115.45 28.29 -3.63 161.01 7.81 15.85 6.20 10.32 161.16 46.17 179.54 MWD(1,6) 12,855.20 55.84 182.16 7,168.45 28.30 -3.63 161.03 7.88 15.86 6.27 10.45 161.18 46.19 179.58 MWD(1,6) 12,867.35 55.84 182.16 7,175.27 28.30 -3.63 161.03 7.88 15.86 6.27 10.45 161.18 46.19 179.58 MWD(1,6) 12,876.60 56.14 182.01 7,180.45 27.63 -3.77 161.10 7.94 15.86 6.31 10.51 161,19 46.20 179.60 MWD(1,6) 13,338.45 71.32 175.78 7,384.45 19.63 -5.66 161.00 9.07 16.04 6.67 11.55 161.54 46.14 179.92 MWD(1,6) 13,810.35 87.00 170.49 7,473.00 16.31 -6.64 159.98 10.26 16.33 6.77 12.51 162.10 45.86 0.18 MWD(1,7) 14,143.78 87.00 170.49 7,490.45 16.37 -6.64 160.35 11.30 16.39 6.79 13.47 162.59 45.45 0.40 MWD(1,7) 14,239.31 87.00 170.49 7,495.45 16.39 -6.64 160.40 11.41 16.41 6.79 13.57 162.65 45.41 0.42 MWD(1,7) 14,368.13 88.91 174.57 7,500.05 16.40 -6.73 162.05 11.50 16.46 6.80 13.88 162.86 45.31 0.49 MWD(1,7) 14,629.30 88.91 174.57 7,505.02 16.55 -6.73 162.51 12.11 16.60 6.80 14.46 163.35 45.15 0.64 MWD(1,7) 15,046.10 89.60 160.00 7,510.45 16.92 -6.80 154.35 14.01 16.95 6.81 15.62 16424 44.61 0.80 MWD(1,7) 15,564.42 89.60 149.63 7,514.04 16.60 -6.81 141.75 10.92 16.63 6.81 12.87 162.80 45.13 0.43 MWD+IFR-AK-CAZ-SC(2,7) 21,562.41 89.60 149.63 7,555.45 21.42 -6.81 147.56 10.92 21.44 6.86 14.41 168.34 43.55 179.52 MWD+IFR-AK-CAZ-SC(2,7) 13,810.35 7,473.00 7"x 8-3/4"by 9-7/8" 7 9-7/8 21,562.41 7,555.45 4-1/2"x 6-1/8" 4-1/2 6-1/8 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,594.32 1,555.45 Base Permafrost 2,860.07 2,415.45 C-30 3,576.71 2,755.45 C-20 5,912.18 3,817.45 K-3 Marker 6,476.00 4,073.45 K-2 Marker(Qannik) 6,694.77 4,173.45 Basal K-2 9,984.79 5,702.45 Albian 97 10,718.72 6,135.45 Albian 96(Nanuq) 10,768.57 6,165.45 Nanuq Base 11,934.52 6,755.45 HRZ 12,653.97 7,055.45 HRZ Base 12,760.82 7,115.45 K-1 Marker 12,855.20 7,168.45 Kuparuk C 12,876.60 7,180.45 Miluveach 13,338.45 7,384.45 Alpine B 14,143.78 7,490.45 Alpine A 2/4/2015 4:05:35PM Page 3 COMPASS 5000.1 Build 65 ORIGINAL • Schlumberger • Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD4-93 Project: Western North Slope TVD Reference: CD4-93: 19+36.45 @ 55.45usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-93: 19+36.45 @ 55.45usft(Doyon 19) Well: CD4-93 North Reference: True Wellbore: Plan:CD4-93A Survey Calculation Method: Minimum Curvature Design: CD4-93Awp05 Output errors are at 1.00 sigma Database: OAKEDMP2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 12,000.00 6,778.59 54.65 -7,909.77 KOP: 13.56°/100'DLS,45°TF,for 16.5' 12,016.50 6,784.33 39.22 -7,908.78 Hold for 20' 12,036.50 6,791.04 20.40 -7,907.85 Start 3°/100'DLS,45°TF,for 50' 12,086.50 6,807.36 -26.83 -7,905.99 Start 2°/100'DLS,100°TF,for 50' 12,136.50 6,823.31 -74.20 -7,905.01 Adjust TF to 150°,for 50' 12,186.50 6,839.69 -121.44 -7,904.67 Start 3.5°/100'DLS, 172.53°TF,for 421.4' 12,607.90 7,029.58 -496.28 -7,910.79 Hold for 259.45' 12,867.35 7,175.27 -710.80 -7,918.86 Start 3.5°/100'DLS,-21.77°TF,for 943.01' 13,810.35 7,473.00 -1,589.49 -7,853.90 Hold for 428.96' 14,239.31 7,495.45 -2,011.96 -7,783.09 Start 3.5°/100'DLS,65.02°TF,for 128.82' 14,368.13 7,500.05 -2,139.58 -7,766.36 Hold for 261.17' 14,629.30 7,505.02 -2,399.53 -7,741.66 Start 3.5°/100'DLS,-87.38°TF,for 416.8' 15,046.10 7,510.45 -2,804.98 -7,650.19 Start 2°/100'DLS,-90.03°TF,for 518.31' 15,564.42 7,514.04 -3,273.38 -7,429.94 Hold for 5998' 21,562.41 7,555.45 -8,448.38 -4,397.85 TD:21562.41'MD,7555.45'TVD Checked By: Approved By: Date: 2/4/2015 4:05:35PM oR (GINALPeCOMPASS 5000.1 Build 65 ! • Pool a or Permit Pack C - oc ea, et et ei 0 c4 • ?0£1433 J •� 0 �0 J O d O 0 ) A. 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Latitude/Longitude 'Decimal Degrees .1 :- Latitude/Longitude 'Decimal Degrees wi C UTM Zone: 1- r South — UTM Zone: irTrue I— South (,i` State Plane Zone: 14---ii Units: lus.11 ,I 4 State Plane Zone 14 - i ..,' Units: r- Legal Description(NAD27 only) ' Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates X: ii4409 X: 1 378310.580637971 Y: 15957305.15 Y r 5957557.98642965 Transform I Quit I Help i . CD4-93Awp05 Sidetrack / Kick-off Point rt. CPA!Coordinate Converter (: — i i4-14 INOWIR) From To: -, Datum: INAD83 '. Region: I alaska .. Datum: NAD27 2..1 — * Region: ialaska 21 C Latitude/Longitude i Decimal Degrees ...ni r Latitude/Longitude 'Decimal Degrees C UTM Zone: i— South C UTM Zone: Till----;---- r South 1 4.` State Plane Zone ;4 ,.. Units: 'us-ft .,I :i' State Plane Zone: ii7...1 Units: 1;;.76-7".i, I r Legal Description(NAD27 only) 4" Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: X: 11510436.91 X , 370403.470612412 Y: 15957488.2-.7, Y: E5957741.4165719 I Trani= ! Quit I Help ORIGINAL CD4-93Awp05 Intermediate Casing I . . CPA i Coordinate Converter From- To: Datum- 1NAD83Ow: lalaska Datum. 1NAD27 Region: lalaska C Latitude/Longitude 'Decimal Degrees C Latitude/Longitude 'Decimal Degrees I UTM Zone: r South C UTM Zone: Trur7 r South State Plane Zime: 11 Units: An.ft State Plane Zone: 11---7 Units: ITITir:1 Legal Description(NAD27 only) Legal Description INAD27 only) Starting Coordinates: Ending Coordinates: X: 11510466.07 X: 1 370432 55981418 Y: 15955843.54 Y I 5956096.70953006 1 Transform Quit Help CD4-93Awp05 TD CPA!Coordinate Converter 1--= HO' From: To: Datum: 1NAD 83 j Region: Jalaska Datum- 1NAD27 Region: Jalaska C Latitude/Longitude 'Decimal Degrees (" Latitude/Longitude 'Decimal Degrees UTM Zone: r South C UTM :one: Tr51eF South IT* State Plane Zone. Units: us.ft I State Plane Zone: 14---;]. Units. fuTii-7.1 r ' Legal Description(NAD 27 only) • Legal Description lNAD27 only) Starting Coordinates: Ending Coordinates: X. 11513810.00 X 373776.163125798 Y: 15948930.00 Y 5949182.95227557 Transform I Quit I Help bl . U .1`( I I • 1 CD4-93Awp05 Surface Location —1 C3 CPA!Coo-dinate Converter 1 From- To: 1 i Datum: .NAD 83 •1 Region. lalaska •i Datum: 11:11-/- .1 Region Ialaska ,..j r Latil ude/Lorigitude [Decimal Degrees zi C Latitude/Longitude 1Decimal Dearees _L1. (- UTM Zone: i 7 South 4— UTM Zone: Ilrue I- South 4 State Plane Zone: q, Units: ur;:iiE. C State Plane Zone: Ii-----E, Units: FT:us- ., a Legal Description(NAD27 only) Starting Coordinates: Legal Description X 11518344.09 Township- 1-1011 IN -.11-- Range: 1005 1E •- Y' 15957305.15 Meridian: 1.-6---:, Section:113 ffii:"."E 12848.4830 FF E-L I.1 1 4 8 9 6.4 1 6 9 _ i Transform Qtit i Help 4....___ —......I 1 CD4-93Awp05 Sidetrack / Kick-off Point ,--I CI CPA!Coordinate Converter 1 From To: Datum. WAD83 •I Region: Ialaska .1 Datum NAD27 w, Region: (alaska - •11 i C Latitude/Longitude !Decimal Degrees . 1. Latitude/Longitude !Decimal Degrees C UTM -7 , ,...one: 1 7 South r UTM ,---- ,--- Zone. IT rup , South ni State Plane Zone. r4--, Units: 11,10 2:1 ' Slate Plane Zone 4 • Units C ,i4i,-, .i.i1 Legal Description(NAD27 only) . 1 1 Starting Coordinates Legal Description 1 X 11510436.91 Township: 1011 IN....11. Range! 1004 rE17 Y' 15957488.23 Meridian: lij-7,„A. Section:123 ITNI , j 12797.2257 'FE17.7., 12564.4399 i 1 i ;..... „..........1 a T tanstotm Quit I Help 1/4 / ORIGINAL 0 0 1 CD4-93Awp05 Intermediate Casing I ,-I I IZ5 ___CPA!Coordinate Converter 1 From. To: i :, Datum: 'NAD83 •! i Region: r---alaska •; Datum: 1NAD27 2.i Region" ialaska 1 C Latitude/Longitude ;Decimal Degrees .1 - Latitude/Longitude 'Decimal Degrees • (111" UTM Zone: r---- E South '- UTM Zone. ii rue E South _ . . State Plane Zone: 174--E, Units: 1;51- J (1- State Plane Zone. "4 ,' Units: ...:„ 4" Legal Description INAD27 only) Starting Coordnater Legal Description ------------- ------- X 11510466.07 Township: I-011 11-. Range: Y* 1595584a 54 Meridian: ilj-!!!...] Section:I23 1FN -L ,_____71 !41441.3325 ITEEE 12.50a7136 Transform i Quit I Help \ , , I CD4-93Awp05 TD l ,-_ a CPA!Coordinate Converter , From- To: Datum: NAD83 ,i Region: ialaska .1 ! NAD 27 • Region* laska I a •, Datum, C Latitude/Longitude fDecimal Degrees !!!!....1 Latitude/Longitude !Decimal Degrees • 1 ' r UTM Zone i 1- South r` LIT M -Zone [ rue r South (i State Plane Zone !4 ,1 Units: lus•ft •_ " Slate Plane Zone: 4 :3 Units: 117..ft _., ..-- "•' Legal Description(NAD27 only) Starting Coordinates. Legal Description I X 11 513810.00 Township- Range: 1011 f N .I '00-4 - E . I Y' 15948930,00 ! Meridian, 1u ,H Section. 3-6— FNL •: '73781531 'FELT 1•1 [4333.2992 :, 1'tanstorm i Quit i Help I • Tollerable Collision Risk Worksheet ciRic) INA _ i • ConocoPhi I I i psConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska A Tolerable Collision Generic name of scenario: CD4-93wp05 Alpine A producer collision with CD4-23 Alpine C porducer while drilling Risk Worksheet Description: (Be specific.Include all factors which affect either the cost of collision or the cost of reducing the risk) based on Rev.1-29 Jul 99 To hit the geologic target,a well path that does not pass major risk was developed.The planned well path CD4-93Awp05 violates major risk rules between the depths of 21,553'MD. Use this sheet to describe a well interference scenario where QRA With the confidence we have in the Schlumberger Periscope deep resistivity tool to keep us in zone, may be applicable.Check first that the scenario really is different mud loggers and geologist at the rig site monitoring cuttings,and known geology,we view the from those described on existing worksheets, potential for a collision as extremely low.With a production tree on CD4-23 and a BOP stack on CD4-93A well control equipment is in place to handle this extremely remote possibility and prevent Prepared by: Duncan Hyden any release to the environment.Mitigation measures in place to reduce the risk of collision with CD4 23 include: Monitor survey magnetics for interference that may indicate close approach,including continuous Authorized by: Rob Stinson azimuth measurement from the RSS tool Do the consequences Are the ©No of collision include a tt Yes consequences risk to personnel or the of collision " environment? predictable'? Maj List all the consequences of Yes ' collision and the necessary remedial action: Cost of Collision: In the remote event there is a collision,mud from CD4-93A would enter the production interval.The biggest risk of this event is damage to the reservoir on $13,000,000 CD4-23.Redrill CD4-23-Slot Recovery&sidetrack production section The remediation of the CD4-93A wellbore would be to isolate the CD4-23 wellbore with cement then open hole sidetrack costing 7 days rig time. $2,345,000 How could the probability of collision or the severity of Estimate the total cost of C= $15,345,000 the consequences be reduced?How might this impact collision the drilling operation? Cost: Is there a practical way to substantially reduce Estimate the NPV of the 0 Yes either the probability of a No planned well collision or the severity of the consequences? V= $20,500,000 • Accepting a finite risk of collision will reduce the NPV of the planned well.What reduction,as a fraction of the total NPV,are you prepared to tolerate?(Guideline=0.05) F= 0.05 Estimate the total cost of substantially reducing the V= $0 • risk V F/C = 0.066797002 Given the uncertainty in the above estimates,by how If V F hen close approach tolerances need not be se+ many times must the savings made from not reducing c If V F the risk outweigh he risk itself?(Guideline=20) F Tolerable Collision Risk=1 in C/V F M = 20 F= 1 /M = 0.05 Tolerable Collision Risk = 1 in 15 Minor Risk 1/20 RI G 1 N A L applied • • ConocoPhi l l i psConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska A Tolerable Collision Generic name of scenario: CD4-93wp05 Alpine A producer collision with CD4-23PB2 Alpine C porducer while drilling RiskWorksheet Description: (Be specific.Include all factors which affect either the cost of collision or the cost of reducing the risk) based on Rev.1-29 Jul 99 To hit the geologic target,a well path that does not pass major risk was developed.The planned well path CD4-93Awp05 violates major risk rules at depths of 18,136'MD&18,536'MD. Use this sheet to describe a well interference scenario where QRA With the confidence we have in the Schlumberger Periscope deep resistivity tool to keep us in zone may be applicable.Check first that the scenario really is different and geologist at the rig site monitoring cuttings,and known geology,we view the potential for a from those described on existing worksheets. collision as extremely low.With a production tree on CD4-23PB2 and a BOP stack on CD4-93A well control equipment is in place to handle this extremely remote possibility and prevent any release to Prepared by: Duncan Hyden the environment.Mitigation measures in place to reduce the risk of collision with CD4-23PB2 include: Monitor survey magnetics for interference that may indicate close approach,including continuous Authorized by: Rob Stinson azimuth measurement from the RSS tool Do the consequences Are the PCI No of collision include a O Yes consequences O No risk to personnel or the of collision TO environment? predictable? Major risk List all the consequences of ()Yes - collision and the necessary remedial action: Cost of collision: The remediation of the CD4-93A wellbore would be to isolate the CD4-23PB2 wellbore with cement then open hole sidetrack costing 7 days rig time. $2,450,000 How could the probability of collision or the severity of Estimate the total cost of C= $2,450,000 the consequences be reduced?How might this impact collision the drilling operation? Cost: Is there a practical way to substantially reduce Estimate the NPV of the O Yes either the probability of ®No planned well collision or the severity of the consequences? V= $20,500,000 • Accepting a finite risk of collision will reduce the NPV of the planned well.What reduction,as a fraction of the total NPV,are you prepared to tolerate?(Guideline=0.05) y F= 0.05 Estimate the total cost of substantially reducing the V= $0 ' risk V F/C= 0.418367347 Given the uncertainty in the above estimates,by how hen close approach tolerances need not be set many times must the savings made from not reducing the risk outweigh he risk itself?(Guideline=20) Tolerable Collision Risk=1 in C/V F M = 20 F= 1 /M = 0.05 Tolerable Collision Risk = 1 in 2 Minor Risk 1/10 ORIGINAL. applied 1110 I ConocoPhillipsConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska Tolerable Collision Generic name of scenario: CD4-93wp05 Alpine A producer collision with CD4-93 parent wellbore while drilling Risk Worksheet Description: (Be specific.Include all factors which affect either the cost of collision or the cost of reducing the risk) based on Rev.1-29 Jul 99 To hit the geologic target,a well path that does not pass major risk was developed.The planned well path CD4-93wp05 violates major risk rules at depths of 12,000'MD&12,448'MD. Use this sheet to describe a well interference scenario where QRA This situation is driven primarily by the intended sidetrack depth from the parentbore of CD4-93A. may be applicable.Check first that the scenario really is different When drilling off of the whipstock with magnetic interference from the existing casing string,only from those described on existing worksheetsinclination will be reliable until surveys clean up. Utilizng inclination-only surveys will provide ample data to interpret the relative position of CD4-93A to that of the parent wellbore. Prepared by: Duncan Hyden With a BOP stack on CD4-93A well control equipment is in place to handle this extremely remote possibility and prevent any release to the environment.Mitigation measures in place to reduce the Authorized by: Rob Stinson risk of collision with the parent wellbore include: Do the consequences Are the *No of collision include a ©Yes consequences 0 No Top risk to personnel or the of collision environment? predictable? Major risk List all the consequences of pYes collision and the necessary remedial action: Cost of Collision: The remediation of the CD4-93A wellbore would be to cement then open hole sidetrack costing 4 days rig time. $1,400,000 4 How could the probability of collision or the severity of Estimate the total cost of C= $1,400,000 the consequences be reduced?How might this impact collision the drilling operation? Cost: Is there a practical way to substantially reduce Estimate the NPV of the Q Yes either the probability of O No planned well collision or the severity of the consequences? V= $20,500,000 Accepting a finite risk of collision will reduce the NPV of the planned well.What reduction,as a fraction of the total NPV,are you prepared to tolerate?(Guideline=0.05) F= 0.05 Estimate the total cost of substantially reducing the V= $0 • risk V F/C= 0.732142857 Given the uncertainty in the above estimates,by how If v F hen close approach tolerances need not be set many times must the savings made from not reducing If V the risk outweigh he risk itself?(Guideline=20) Tolerable Collision Risk=1 in C/V F M = 20 F = 1 /M = 0.05 Tolerable Collision Risk = 1 in 1 Minor Risk 1/10 C ! 1 applied • • ConocoPh i I l i psConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska Tolerable Collision Generic name of scenario: 406 CD4-93wp05 Alpine A producer collision with CD4-16 Alpine A producer while drilling. RiskWorksheet Description: (Be specific.Include all factors which affect either the cost of collision or the cost of reducing the risk) based on Rev.1-29 Jul 99 To hit the geologic target,a well path that does not pass major risk was developed.The planned well path CD4-93wp05 violates major risk rules at a dpeth of 12,606'MD. Use this sheet to describe a well interference scenario where QRA This situation is driven primarily by the intended sidetrack depth from the parentbore of CD4-93A. may be applicable.Check first that the scenario really is different When drilling off of the whipstock with magnetic interference from the existing casing string,only from those described on existing worksheets. inclination will be reliable until surveys clean up. Given that CD4-93A crosses above CD4-16, utilizng inclination-only surveys will provide ample data to interpret the relative position of CD4-93A Prepared by: Duncan Hyden to that of CD4-16. With a production tree on CD4-16 and a BOP stack on CD4-93A well control equipment is in place Authorized by: Rob Stinson to handle this extremely remote possibility and prevent any release to the environment.Mitigation Do the consequences include nces Arseq the No of collision include a �Yes consequences Q N0 risk to personnel or the of collision OP environment? predictable? Major risk � 3 List all the consequences ofQ Yes collision and the necessary remedial action: Cost of Collision: In the remote event there is a collision,loss of primary barrier-7"intermediate casing and 3-1/2"-would be experienced. The remediation of the CD4-93A wellbore would be to isolate the CD4-16 wellbore with cement then open hole sidetrack costing 10 days rig time. Redrill CD4-16-Slot Recovery&redrill intermediate and production section. $3,500,000 $13,000,000 How could the probability of collision or the severity of Estimate the total cost of C= $16,500,000 the consequences be reduced?How might this impact collision the drilling operation? Cost: Is there a practical way to substantially reduce Estimate the NPV of the Q Yes either the probability of ®No planned well collision or the severity of the consequences? V= $20,500,000 • Accepting a finite risk of collision will reduce the NPV of the planned well.What reduction,as a fraction of the total NPV,are you prepared to tolerate?(Guideline=0.05) 1 F= 0.05 Estimate the total cost of substantially reducing the V= $0 • risk V F/C= 0.062121212 IfGiven the uncertainty in the above estimates,by how V F then close approach tolerances need not be se, many times must the savings made from not reducing If V F the risk outweigh he risk itself?(Guideline=20) cen Tolerable Collision Risk=1 in C/V F M = 20 F= 1 /M = 0.05 Tolerable Collision Risk = 1 in 16 Minor Risk 1/20 t3RLG1NAL applied • • As- built ORIGINAL • REV DATE I EY CK ApP DESCRIPTION REV DA.7 BY CK I APP DESCRIPTION 12 3/31/11 !A;; I D3 C.A. UPDATED PER K140002 ACS 11 4/1/13 CZ DB C.A. UPDATED PER K133O03AC5 4 ecc � �, '.``css �Ao \ • \*14. , ill „:-.3., P lo .:.,.,_..L __, , .,,,,,,, ,„.. .„,,,Iiik4 , e.t. ..1- &'''''' : awmf----4-0-41,60. . LOCATION OF �� r�" 1ple!), ►�- -: THIS SURVEY \..91` \\c,.., h , f \„..r. '' t \ ' -..k.... i , ,. ilb f:. E SATELLITE DEVELO ENT % \. \ : 1 f r VICINITY MAP NOT TO SCALE , C OI,O RS�Y oc p 1,C,--'4.'45') CD—A —A VSSCA+ 5 PAD , ��Pat --.- ‘,....:,,,Vis*.il t'A-1:;)-1 gg..?Via..F N j " -BtBC + fef`f'• ` SynIII!�1firS�KP �C740' �� � r I ,,xi+fr TIKEh • / �� -, P'111 I PLANT1 Cb-4 To ALPSNEr N PIPg1-1%6 ASPC r).\N 13'27.50 -- -"`'- __.,01 , L,, , 1 d � 7_________---------------",i. 14 LEGEND: KUUKP1K ^ . 0 P 0POSED CONDUCTOR toF 0 • EXISTING CONDUCTOR * I.CMFLL. N N 4 EXISTING WELLHEAD -- � 6. ABANDONED IVELL .4(pirhe Survey Office 'P•"' ALPINE MODULE C04a UNIT: CD ConocoPhi I li ias ALPINE PROJECT CD-4 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO- PART: 'REV- 05-D3-03-1B-1 10/11/05 CE—CDLO-121 l 1 OF 3 , 12 • IL__ REV PAYE BY C‹ bk-SCR'PllON 1..2E D.V_ E, _L_TY qtt APP DESCRi ren ON 9 3/31/14 , AG DR O.P.. UPDATED PER K140003ACS, 8 4/02/13 CZ DB C.A. JPDATED PER k130003A1CS CONDUCTORS CD4-X97 THRU CD4-X28 ARE LOCATED IN PROTRACTED SEC. 24, T 11 N, R 4 E, U.M. CONDUCTOR CD4-X96 IS LOCATED IN PROTRACTED SEC. 19, T 11 N, R 5 E, U.M. SEC.LINE 0/S EXIST_ WELL. t vl 'X' LAT.(N) LONG.(W) FSL FEL OND PAD C04-Y86 5.957,337.85 1,518,460,27 70' 17' 32.458 150' 59' 14.133" 2456' 4769" ' 12.4 187§ 004-287 5,957.333:22 1.518,450.76 70' 17 .41 150' 59 14.699 2. -1 4 80 12.4 19.1 004-X58 5 957 328.53 1 518.441.29 70' 17 32.3601' 150' 59' 15.265" 2456' 4-._799 12.4 15,9 CD4-189 5,957,323.89 1, 14,421,75 70" '7' 32.311" , 150' 59 15.832 2461' 4519- 12,4 19 004-190 ,5.957,319.25 1 518402.44 70' '7' . --T---62-1' 150' 59' 16.393" 2446 4-838' 12,4 19.0 004-191 5.957,314.54 1,518,38257 70" '7' 52,213" 150' 59' 16.9616 2441' 4857T 12.4 18.9 CD4-1-0 5,957,31g 03 1,518,363 49 70 1T N,165" 150' 59' 17.524" 2436' 4877' 12.4 1-771001-X93 5,957,305.15 1, 18... 44..09 70' j 7' 32114' i .3" 59' 16.087' 2431' 4896' 12.4 190 1004-i96W11-57,291.25 1,518.286,,,48 70' 7 31_968". 150' 5977'7411‘11024r 19.4 18.9 CD4-X97 5.957.286.78 1,518266.76 70' 7 31.921. 150' 59' 20_331 2412 12 12.4 19.5 C04-X98 b,957,282.,22 1,518,247.43 /0' T 31.873' 150' 59' 20_893" 2407` 31' 12.4 19,1 1-00- 99 5,957.277,95 1.515.227.75 70' 7' 31.828" 150* 51" 21.464" 2402" 51' 12.4 19.0 024-3018 5957,273,28 1,519,20824 70' 7' 31.779" 150' 59' 22.030" 2.397 70' 124 19.0 C4-3O2 5,957,26833 1,515,15E64 70' 7. 31.728,7-- 150' 59:22.599 2392' 90' 12.4 19.6 CD4-303 p.n7.263.9g 1,518,189.26 70' 7 31_681 150' 59 23052 2337' 109' , 124 19.6 C04-304'5,957,259,25 1,518,149. 57 70' 1 31.532" 150' 59 23.7251' 2382' 128' 124 19.5 C04-05 :5,95 .254.43 1,518,130.28 ., 70'-7' 31.581" 150' 59. 24.293 2377 148 124 19.5 004-306 5,957,249,75 1518.111287 7er 7' 31_532" 150' 59 24.857" 2372 167 124 19_6 004-07 5_957,245 29 1.518,091,49 70' 7' 31_485" 150" 59' 25.419" 2357' 186 124 9,7 C04-205 5„957240.13 1.515,071 80 70* 7' 31.431" 150' 59' 25.991" 236.? 206. 124 9.8 004-209 5,957.235.77 1,51E1.052_15 70" 7'_3 ..L_13:5" 150" 55 26561 D 2357' 226 124 9.7 CD4-210 5,957,230.92 1,51803298 70" 7 31734- . 150' 59' 27.118" 2362' 245 12.4 9.6 CD4-211 :5 957 226.94 1 515 013.7.5 70' 7' 31_292" 150' 59 27.875" 2348' 264 1 4 20.0 CD4-212 5,957.222.25 1,517,994.40 70' 7' 31.243" 150' 59' 28.238" 2343 283 12.4 9.6 CD4-213 5,957,217,19 1,517,974.60 70' r 31.190" 150* 59 28.g-12" 2337' 303 12.4 9.9 CD4-214 5.957,212,45 1,517,955,51 70' T 31.140" 150- 59' 29.367" 2332 322 124 9.8 C04-215 IfilL1MP:141: • 1 71fir1041144111 70 7 3--.094 150' 59 29.937 23 34' 12.4 9.8 •'-15 5 957.203.17 1,..,1. '1...3 70' 7 3'.043 150* 59 30,495 2322 -461 1 4 • ... . 004-17 5.957 196.80 1 517,897.14 70' 7 30.997' 150' 59' 31.051 2316 380 12.4 9.5 iiimmmo 6,957,193.71 1,517,877.3: ' 7 30.94-4' 150` 59 31.6 4 2 12 400 1 .4 •.6_, 004- 19 5 957,189.54 1,517,557_90 70- 7 30.930 150" 59 32200 230a, 419 124 9.7 004-320 5 957 185.03 1 517 83E65 70' 7 30.852' 150" 59' 32759" 2303 435' 124 9.7 C04-321 5,957.180.2 1.517.819.26 70' 7 30.802 150" 59 33.322 2298 458 17,.4 9.0 0D4-322 5 957 175.24 1,517.799.90 70' 7' .30.749" 150' 59 33.884" 2292' 477' 12.4 9.0 GOA-X23 6 957 170.76 1 517 80,38 70' '7 30.702 e 59 34.450 2288 496 1 4 19.0 DIABEE3'zI q 1... .5 1,. •0.8 ME 17 30.655 150' 59 35.01: 2 ;3 51c 12.4 004-X25 595715i3'. 1,517,741.31 70' 17 30.603 150' 59 .35_554 2278"- 535' 12.4 19.0 CD4-X26 5 957.157.11 1 10 721.97 70. 17W 150° 59 36.146 2273 55. 1 .4 19.5 004-227 5 957 151_94 1 1 ,o . 6 70' 171 30_ 05" 150- 59' 36.709 2268 574 12.4 19.6 CD4-X27 ,957,150 77 1,517,597.37 01 1 30.4-92 150' 59 36.850 66 579 124 16.4 C04-X28,,, , ... , 4-. • 1, li.• -..>• I' I. , ** • ,„ .4. 1 . .1 .4 1 ' : . NAD 83 ti.,,k. KUUKPIK NOTES: 1. COORDINATES SHOFIN HEREON ARE ALASKA STATE, PLANE, ZONE 4, NAD 83. ' ILCNIF" 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B,P.M.S.L.) "'"ailF" Z40470"""I'Amisur,,0707;7 IIIPP-' I ALFINE M°DILE:CE140 UNIT; CO ConocoPhillips , ALPINE PROJEC- CD-4 WELL CONDLCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAVIIN0 NCI PART; REV: 05-03-03-18-2 10/11/05 CE-0040-121 2 OF 3 9 ORIGIN 1\ 1 .iEV DATE BY CSC APP •DESCBiP11G 1 REV DATE BY APP ,'ESCRIPTIO 4 9 3/31/14 AG DB C.A. UPDATED PER K140003ACS 8 4/02/09 CZ DB C.A. UDDATED PER K130003ACS NOTES: 1 . ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD-4 GRAVEL PAD. 3. BASIS O= COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, OCTOBER 2005 4. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD4-208, CD4-209, CD4-210 CD4-318A, CD4-319, 10/11/05, E 2005 -26 PGS. 30-31; CD4-05, CD4-306, CD4-07, 04/13/06, FB 2003-10, PCS 26, CD4-320, 04/14/06, PG 29; CD4-302, CD4--303. CD4-304, 004-16, CD4-17, 04/18/06, PG 47; CD4-211, CD4-213, CD4-214, CD4-215, 04-26-06, RB 2006-' 0, PGS 65-66; CD4-301B, CD4-321, 5/13/06, FB 2006-13, PC. 27; CD4-322, C04-X23, CDL--X24 CD4-X25, 03130/07, FB 2007-08, PGS. 4-5; CD4-X26, 5/3/07, FB 2007-09, PG. 42; CD4-X98 & CD4-X99, 4/2/09, FB 2009-05, PG. 41; CD4-X27 & CD4-X28, 4/9/09, F32009---05, PG. 55; CD4-X96 & CD4-X97, 4/29/12, FB2012-04, PG. 58; CD4-287, CD4-189, CD4-190, CD4-191 , CD4-292, 4/1/€3, FB. 2013-09, PG. 55. FB2013-26, PG. 43; CD4-X86, CD4-X88, CD4-X93, 3/30/14 5. CD4-212 IS EXISTING WELL NANUQ #5. REFERENCE DRAWING CE-APOO-162. CD4-227 IS EXISTING WELL NANUQ #3 (ABANDONED). REFERENCE DRAWING CEA-M1 XX-60D380. SURVEYOR'S CERTIFICATE +•y�1►•Rti��R i HEREBY CERTIFY THAT I AU PROPERLY REGISTERED AND L CENSED •+ ,4 OF A(4 • TO PRACTICE ,._AND SURVEYING IN THE STATE CF ALASKA, THAT THIS • �� •. �fi ` AS-BUILT REPRESENTS A SURVEY !.AADS By ME OR UNDER 4lY DIRECT • c.', "'•:9 �• SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST ar ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND CTH=R DETAILS ARE *z 49th �\ * 16,0 CORRECT. 0 DATE; REGISTRATION ND. il L5-13020 Alan J. Gri#f;r, ' o v't b es; • errib KUUKPIK v.11..11r.f r,e EMl.Ya Mdap,lYrs rsm Alpine Survey Office A_P!NE 'TIC:ULE:CD40 1.3417: CD ConocoPhillips ALPINE CROJECT CD-4 VaiELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE ND. DRAWING NO: PART: RE's: 05-03-03-1B-3 10/11/25 CE-CD4 -121 3 OF 3 9 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: U., Chi - 93/1- PTD: 02)5--0 Development _Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: �!Utiii KiVEkT POOL: C /L/d/f 'Jk-ir) A`1A✓1E• €1 ') Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 I • 00 ToN CA O C 0 Q O: ._ 15 o', Cc , ;c m' 0 � a t EYaQ cn N co.co C co. w 0. E O , o co v: 3 �: o, os a' o, E: 0: . 3 3: v: 0 2 o v, ' ': .C: 3, c —: a): o: a 'o coOM (°) C, 8: '3: O L N. co •C _ N 'cu 0 -, 3' y, L. Q. ami a co , �, 3, w° u r flu aa Eo; N. i 4 0, c :) p: co U O 0 0. y: R i7 3. 0. � 2. 1-1-1 C: H 0 �, `: a): E N: ' .O: a ' •'' p: a �' p: Z, H. 0 CO' C: a) a . 0' O: (D) a E. �O' 0 0 n • �: �: p. v. E ai co as O: a' co a t U 0 o a m: �, y, U. a: - M. 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