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Home My WebLink About213-167From:Well Integrity Specialist CPF2 To:Loepp, Victoria T (OGC) Cc:Earhart, Will C; Well Integrity Specialist CPF2 Subject:KRU 2L-322A (PTD #213-167-0) Date:Thursday, September 23, 2021 10:40:35 AM Attachments:image001.png 2L-322A.pdf 2L-322A 90 Day TIO plot.pdf Victoria- KRU 2L-322A (PTD #213-167-0) was reported by operations with an elevated OA pressure. DHD was dispatched and found the OA to be at 1005 psi. DHD attempted a bleed however the OA, continued to recharge. The IA was bleed to investigate IAxOA communication and initial diagnostics suggest that the pressure source is not the IA and more than likely charging from the open shoe. CPAI intends to load the OA with fluid and monitor for fluid fall out and pressure stabilization. Depending on the results of the load, the proper paper work for repair/intervention will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is a 90 TIO plot and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Annular Communication Surveillance 25-Jun-2021Well Name:2L-322 Start Date:25-Jun-2021 23-Sep-2021Days:90 End Date:23-Sep-2021 50 60 70 80 90 100 110 120 130 140 150 0 200 400 600 800 1000 1200 1400 1600 25-Jun-2128-Jun-211-Jul-214-Jul-217-Jul-2110-Jul-2113-Jul-2116-Jul-2119-Jul-2122-Jul-2125-Jul-2128-Jul-2131-Jul-213-Aug-216-Aug-219-Aug-2112-Aug-2115-Aug-2118-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 25-Jun-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD 9,409.0 2/3/2018 2L-322A pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Installed New GLD 12/17/2018 2L-322A zembaej Casing Strings Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 27.5 Set Depth (ftKB) 6,214.7 Set Depth (TVD) … 5,010.1 Wt/Len (l… 29.70 Grade L-80 Top Thread Hydril563 Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 6,033.7 Set Depth (ftKB) 9,486.5 Set Depth (TVD) … 5,245.0 Wt/Len (l… 12.60 Grade P-110 Top Thread Hydril 521 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,033.7 4,921.1 57.69 PACKER BAKER HRD-E ZXP LINER TOP PACKER 4.800 6,055.5 4,932.6 58.33 HANGER BAKER FLEX-LOCK LINER HANGER 4.800 6,065.1 4,937.7 58.60 XO REDUCING XO 17# HYDRIL 563 BOX X 12.6# HYDRIL 521 PIN 3.920 6,774.3 5,190.0 78.09 Swell Packer BAKER SWELL PACKER 3.958 7,115.4 5,224.2 86.23 FRAC PORT FRAC POINT 2.50" Seat #7 (Milled Out 5/24/14) 2.700 7,288.5 5,227.0 90.88 Swell Packer BAKER SWELL PACKER 3.958 7,477.9 5,223.3 91.13 FRAC PORT FRAC POINT 2.375" Seat #6 (Milled Out 5/24/14) 2.700 7,655.6 5,219.9 90.52 Swell Packer BAKER SWELL PACKER 3.958 7,812.1 5,221.0 89.17 FRAC PORT FRAC POINT2.250" SEAT #5 (Milled out 5/24/14) 2.700 7,992.3 5,222.2 89.65 Swell Packer BAKER SWELL PACKER 3.958 8,150.8 5,223.1 89.44 FRAC PORT FRAC POINT 2.125" Seat #4 (Milled out 5/24/14) 2.700 8,298.8 5,225.0 89.42 Swell Packer BAKER SWELL PACKER 3.958 8,455.7 5,225.6 89.83 FRAC PORT FRAC POINT 2.00" Seat #3 (Milled out 5/25/14) 2.700 8,633.1 5,225.1 90.20 Swell Packer BAKER SWELL PACKER 3.958 8,791.3 5,223.6 90.96 FRAC PORT FRAC POINT 1.875" Seat #2 (Milled out 5/25/14) 2.700 8,968.7 5,221.6 89.98 Swell Packer BAKER SWELL PACKER 3.958 9,126.1 5,222.7 89.12 FRAC PORT FRAC POINT1.75" Seat #1 (Milled out 5/25/14) 2.700 9,303.1 5,229.5 85.50 Swell Packer BAKER SWELL PACKER 3.958 9,429.0 5,240.2 85.15 FRAC SLEEVE PRESSURE ACTIVATED FRAC SLEEVE 3.850 9,441.5 5,241.3 85.18 VALVE WELLBORE ISOLATION VALVE 3.850 Tubing Strings Tubing Description TUBING 4.5 x 3.5 @ 59.4 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.2 Set Depth (ft… 6,049.0 Set Depth (TVD) (… 4,929.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.2 25.2 0.00 HANGER FMC TUBING HANGER 3.958 59.4 59.4 0.07 XO Reducing XO 4.5" IBTM box X 3.5" 8rd EUE pin 2.990 530.7 530.4 3.72 NIPPLE CAMCO DS NIPPLE 2.875 5,958.4 4,879.7 55.58 SLEEVE - C BAKER CMU SLIDING SLEEVEW/ DS PROFILE (CLOSED) 2.813 5,981.9 4,892.9 56.24 PACKER BAKER PREMIER PACKER 2.870 6,009.7 4,908.2 57.02 NIPPLE CAMCO D NIPPLE 2.750 6,030.0 4,919.1 57.59 LOCATOR MECHANICAL LOCATOR ABOVE LOCATOR 3.000 6,031.0 4,919.7 57.62 LOCATOR MECHANICAL LOCATOR BELOW LOCATOR w/(4) 3/8" SHEAR SCREWS 3.000 6,048.0 4,928.7 58.11 MULE SHOE MULE SHOE w/WLEG 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,115.4 7,117.7 5,224.2 5,224.4 5/14/2014 PERFP FRAC PORT 7,477.9 7,480.2 5,223.3 5,223.2 5/14/2014 PERP FRAC PORT 7,812.1 7,814.4 5,221.0 5,221.0 5/14/2014 PERP FRAC PORT 8,150.8 8,153.1 5,223.1 5,223.2 5/14/2014 PERP FRAC PORT 8,455.7 8,458.0 5,225.6 5,225.6 5/14/2014 PERP FRAC PORT 8,791.2 8,793.6 5,223.6 5,223.6 5/14/2014 PERP FRAC PORT 9,126.0 9,128.4 5,222.7 5,222.7 5/14/2014 PERP FRAC PORT Frac Summary Start Date 5/14/2014 Proppant Designed (lb) Proppant In Formation (lb) Stg # 2 Start Date 5/14/2014 Top Depth (ftKB) 7,477.9 Btm (ftKB) 7,480.2 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 5/14/2014 Proppant Designed (lb) Proppant In Formation (lb) Stg # 4 Start Date 5/14/2014 Top Depth (ftKB) 8,150.8 Btm (ftKB) 8,153.1 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 5/14/2014 Proppant Designed (lb) Proppant In Formation (lb) Stg # 3 Start Date 5/14/2014 Top Depth (ftKB) 7,812.1 Btm (ftKB) 7,814.4 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 5/14/2014 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 5/14/2014 Top Depth (ftKB) 7,115.4 Btm (ftKB) 7,117.7 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 5/17/2014 Proppant Designed (lb) Proppant In Formation (lb) Stg # 7 Start Date 5/17/2014 Top Depth (ftKB) 8,455.7 Btm (ftKB) 8,458.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 2L-322A, 12/21/2019 10:54:31 AM Vertical schematic (actual) LINER; 6,033.7-9,486.5 FRAC; 9,126.0 PERP; 9,126.0-9,128.4 FRAC; 8,791.2 PERP; 8,791.2-8,793.6 PERP; 8,455.7-8,458.0 FRAC; 8,455.7 PERP; 8,150.8-8,153.1 FRAC; 8,150.8 PERP; 7,812.1-7,814.4 FRAC; 7,812.1 PERP; 7,477.9-7,480.2 FRAC; 7,477.9 PERFP; 7,115.4-7,117.7 FRAC; 7,115.4 INTERMEDIATE; 27.5-6,214.7 MULE SHOE; 6,048.0 LOCATOR; 6,031.0 LOCATOR; 6,030.0 NIPPLE; 6,009.7 PACKER; 5,981.9 SLEEVE - C; 5,958.4 GAS LIFT; 5,867.3 GAS LIFT; 5,188.4 GAS LIFT; 4,230.7 GAS LIFT; 2,934.2 NIPPLE; 530.7 SURFACE; 30.4-2,601.5 CONDUCTOR; 31.2-134.2 HANGER; 25.2 KUP PROD KB-Grd (ft) 40.89 Rig Release Date 5/3/2011 2L-322A ... TD Act Btm (ftKB) 9,486.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032062801 Wellbore Status PROD Max Angle & MD Incl (°) 91.29 MD (ftKB) 7,606.16 WELLNAME WELLBORE2L-322A Annotation Last WO: End Date 3/16/2014 H2S (ppm) 45 Date 12/6/2016 Comment SSSV: NIPPLE Frac Summary Start Date 5/17/2014 Proppant Designed (lb) Proppant In Formation (lb) Stg # 7 Start Date 5/17/2014 Top Depth (ftKB) 9,126.0 Btm (ftKB) 9,128.4 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 5/17/2014 Proppant Designed (lb) Proppant In Formation (lb) Stg # 6 Start Date 5/17/2014 Top Depth (ftKB) 8,791.2 Btm (ftKB) 8,793.6 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,934.2 2,608.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/22/2014 2 4,230.7 3,604.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,646.0 12/20/2019 3 5,188.4 4,341.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/22/2014 4 5,867.3 4,826.6 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.313 0.0 12/20/2019 Notes: General & Safety End Date Annotation NOTE: 2L-322A, 12/21/2019 10:54:33 AM Vertical schematic (actual) LINER; 6,033.7-9,486.5 FRAC; 9,126.0 PERP; 9,126.0-9,128.4 FRAC; 8,791.2 PERP; 8,791.2-8,793.6 PERP; 8,455.7-8,458.0 FRAC; 8,455.7 PERP; 8,150.8-8,153.1 FRAC; 8,150.8 PERP; 7,812.1-7,814.4 FRAC; 7,812.1 PERP; 7,477.9-7,480.2 FRAC; 7,477.9 PERFP; 7,115.4-7,117.7 FRAC; 7,115.4 INTERMEDIATE; 27.5-6,214.7 MULE SHOE; 6,048.0 LOCATOR; 6,031.0 LOCATOR; 6,030.0 NIPPLE; 6,009.7 PACKER; 5,981.9 SLEEVE - C; 5,958.4 GAS LIFT; 5,867.3 GAS LIFT; 5,188.4 GAS LIFT; 4,230.7 GAS LIFT; 2,934.2 NIPPLE; 530.7 SURFACE; 30.4-2,601.5 CONDUCTOR; 31.2-134.2 HANGER; 25.2 KUP PROD 2L-322A ... WELLNAME WELLBORE2L-322A RECEIVED Originated: Schlumberger MAY 31 -AIL PTS - PRINT CENTER Af' G01C 6411 A Street w �i� Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax 2� 23 p Delem to: TRANSMITTAL • • 31 -May -16 MakanaK Bender TRANSMLLW,31May16JW0 Natural Resources Technician II DATA LOGGED Alaska Oil & Gas Conservation Commission , I 120,% 333 W. 7� Ave. Suite 100 Anchorage, AK 99501 K. BENDER r C ' "93-1225 in as ,a;._+ NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTIONWELL • DATA DATE LOGGED COLOR 1G-15 50-029-21024-00 D4AQ-00082 UPARUK RIVER UN WL PMIT-Caliper FINAL FIELD 5 -May -16 1 1 1J-168 50-029-23260-00 DM29-00002 UPARUK RIVER UN Memory PPROF FINAL FIELD 8 -May -16 1 1 1R-29 50-029-22195-00 D4AQ-00085 UPARUK RIVER UN WL LDL-PMIT FINAL FIELD 8 -May -16 1 1 1Y-24AL1 50-029-22371-60 DM29-00006 UPARUK RIVER UN Memory PPROF FINAL FIELD 27 -May -16 1 1 2G-15 50-029-21162-00 DK26-00020 UPARUK RIVER UN WL SCMT FINAL FIELD 12 -May -16 1 1 1 2L -322A 50-103-20628-01 DM29-00005 UPARUK RIVER UN Memory PPROF FINAL FIELD 11 -May -16 1 1 3K-27 50-029-22751-00 D4AQ-00087 UPARUK RIVER UN WL Plug FINAL FIELD 11 -May -16 1 1 Transmittal Receipt A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package X �t�V have been verified to match the media noted above. The specific Print Name Signature Date content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Please return via courier or sign/scan and email a copy to Schlumberger. IaskaPTSPri SC:A14i, • PROACTIVE DIAgNOSTIC SERVICES, INC. s t"jr.j FIN -1, Fir 11RA FA • -2-% 3 - `c 2r,.141)S To: AOGCC� Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 DATA LOGGED %U 2-/2015 M K.BENDER RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 XANW 1) Production Profile 30 -Oct -15 2L -322A BL / CD 2) Signed : �.cv Date Print Name: 50-103-20628-01 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE &MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFIles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit. docx 0 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L Well History File Identifier Organizing (done) ,Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Z"Color Items: ❑ Maps: ZGrayscale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Stacey osep ) Date: /s/ S Project Proofing BY: Stacey Jose Date: C Z ( c)L(l/c( Scanning Preparation x 30 = + = TOTAL PAGES (Count does not include cover sheet) BY: Stacey ose Date:(2/-oL(//y /s/ S Production Scanning Stage 1 BY: Stacey Stage 1 BY: Stacey Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: - YerES _ oseph Date: t2f o(4 / (q If NO in stage 1, page(s) discrepancies were found: YES Joseph Stage 2 Additional Well Reports Digital version appended by: Meredith NO /s/ `' E -S NO Date: /s/ YES NO TOTAL PAGES: Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: Quality Checked /s/ 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. RECEIVEV ConocoPhillips OCT 0 7 2014 Alaska P.O. BOX 100360 �° ANCHORAGE, ALASKA 99510-0360 October 3, 2014 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7t" Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped May 5, 2012, July 27, 2014 & August 17, 2014. The corrosion inhibitor/sealant was pumped August 26 & 27, 2014, September 2, 2014. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, MJ foveland 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) Kuparuk Field Date 10/3/2014 1C_2F_2L & 2T Pads Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1 C-151 50029234970000 2131230 SF na 23" na 3.4 9/2/2014 2E-12 50029212270000 1842110 5'5" 1.00 13" 7/27/2014 3 8/26/2014 2L -322A 50103206280100 2131670 SF na 20" na 3.4 9/2/2014 2L-326 1 50103205970000 2090270 26" na 26" na 3.4 8/27/2014 2T-02 50103200720000 1861410 9'4" 1.00 30" 7/27/2014 2.5 9/2/2014 2T-08 50103200700000 1861090 SF na 22" na 1.7 8/26/2014 2T-09 50103200710000 1861100 6'6" 1.00 25" 5/8/2012 1.7 8/26/2014 2T-10 50103200640000 1860960 SF na 31" na 1.7 8/26/2014 2T-14 50103200610000 1860440 SF na 22" na 1.7 8/27/2014 2T-15 50103200620000 1860450 47" na 28" na 5.1 8/27/2014 2T-17 50103200600000 1860430 25' na 22"na 4.25 9/2/2014 2T-41 50103206750000 2131460 26' 3.00 3" 23":::± 8/17/2014 1.7 8/26/2014 DATA SUBMITTAL COMPLIANCE REPORT 8/12/2014 Permit to Drill 2131670 Well Name/No. KUPARUK RIV U TARN 2L -322A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20628-01-00 MD 9515 TVD 5247 Completion Date 4/23/2014 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No v Samples No Directional Survey Yes DATA INFORMATION \ Types Electric or Other Logs Run: GR / Res, CAST -M, CBL (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log C 24207 Log Header Scans 0 0 2131670 KUPARUK RIV U TARN 2L -322A LOG HEADERS ED C 24207 Digital Data 2850 6000 4/30/2014 Electronic Data Set, Filename: 2L- 322A_CAST_CBL_21 APR14.las ED C 24207 Digital Data 4/30/2014. Electronic File: 2L-322A_ACE _21APR14.dlis ED C 24207 Digital Data 4/30/2014 'Electronic File: 2L-322A_ACE_21APR 14_img.tiff ED C 24207 Digital Data 4/30/2014 r Electronic File: 2L- 322A_CAST_CBL_21 APR14_img.tiff ED C 24220 Digital Data 2531 9515 5/1/2014 . Electronic Data Set, Filename: 2L -322A VISION Service Recorded Mode.las ED C 24220 Digital Data 5/1/2014 8 Electronic File: 2L -322A LWD001 VISION DLIS.dlis ED C 24220 Digital Data 5/1/2014 f Electronic File: 2L -322A LWD001 VISION DLIS.html ED C 24220 Digital Data i 5/1/2014 Electronic File: 2L -322A LWD002 VISION DLIS.dlis ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A LWD002 VISION r DLIS.html ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A LWD003 VISION DLIS.dlis ED C 24220 Digital Data 5/1/2014 ► Electronic File: 2L -322A LWD003 VISION DLIS.html ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service RM DLIS.dlis ED C 24220 Digital Data 5/1/2014 i Electronic File: 2L -322A VISION Service RM DLIS.html AOGCC Page I of 7 Tuesday, August 12, 2014 • • DATA SUBMITTAL COMPLIANCE REPORT 8/12/2014 Permit to Drill 2131670 Well Name/No. KUPARUK RIV U TARN 2L -322A Operator CONOCOPHILLIPS ALASKA INC MD 9515 TVD 5247 Completion Date 4/23/2014 Completion Status 1 -OIL Current Status 1 -OIL API No. 50-103-20628-01-00 UIC No ED C 24220 Digital Data 5/1/2014 r Electronic File: 2L -322A VISION Service 2 MD Recorded Mode Log.PDF ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service 2 MD Recorded Mode Log.tif ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service 2 RT - RM Log.pdf ED C 24220 Digital Data 5/1/2014.. Electronic File: 2L -322A VISION Service 2 RT - RM Log.tif ED C 24220 Digital Data 5/1/2014 , Electronic File: 2L -322A VISION Service 2 TVD Recorded Mode Log.PDF ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service 2 TVD Recorded Mode Log.tif ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service 5 MD Recorded Mode Log.PDF ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service 5 MD ' Recorded Mode Log.tif ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service 5 TVD Recorded Mode Log. PDF I ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A VISION Service 5 TVD J. Recorded Mode Log.tif ED C 24220 Digital Data 5/1/2014 , Electronic File: 2L -322A -Final ASP Surveys.txt ED C 24220 Digital Data 5/1/2014 , Electronic File: 2L -322A Final ASP Survey (NAD27).pdf ED C 24220 Digital Data 5/1/2014 Electronic File: 2L -322A Final ASP Survey (NAD27).xlsx ED C 24220 Digital Data 5/1/2014 , Electronic File: 2L -322A Final ASP Survey (NAD83).xlsx ED C 24220 Digital Data 5/1/2014. Electronic File: 2L -322A [canvas].txt ED C 24220 Digital Data 5/1/2014 ' Electronic File: 2L -322A [macro].txt ED C 24220 Digital Data 5/1/2014 , Electronic File: 2L -322A [petrel].txt ED C 24220 Digital Data 5/1/2014 Electronic File: FinaIMMSSurvey.txt ED C 24220 Digital Data 5/1/2014 -Electronic File: FinalPrintSurveyList.csv j Log C 24220 Log Header Scans 0 0 2131670 KUPARUK RIV U TARN 2L -322A LOG HEADERS ED C 24268 Digital Data 2550 9516 5/14/2014-4 Electronic Data Set, Filename: 2L-322A.las AOGCC Page 2 of 7 Tuesday, August 12, 2014 is • DATA SUBMITTAL COMPLIANCE REPORT 8/12/2014 Permit to Drill 2131670 Well Name/No. KUPARUK RIV U TARN 2L -322A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20628-01-00 MD 9515 TVD 5247 Completion Date 4/23/2014 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 24268 Digital Data 5/14/2014 . Electronic File: Canrig Morning Report 2L - 322A_3 -22-14. pdf ED C 24268 Digital Data 5/14/2014# Electronic File: Canrig Morning Report 2L- 322A_3-23-14.pdf ED C 24268 Digital Data 5/14/2014. Electronic File: Canrig Morning Report 2L - 322A_3 -24-14. pdf ED C 24268 Digital Data 5/14/2014. Electronic File: Canrig Morning Report 2L - 322A_3 -25-14. pdf ED C 24268 Digital Data 5/14/2014. Electronic File: Canrig Morning Report 2L- 322A_3-26-14.pdf ED C 24268 Digital Data 5/14/2014„ Electronic File: Canrig Morning Report 2L - 322A_3 -27-14. pdf ED C 24268 Digital Data 5/14/2014, Electronic File: Canrig Morning Report 2L - 322A_3 -28-14. pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L - 322A_3 -29-14. pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- ` 322A_3-30-14.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- ' 322A_3-31-14.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- = 322A_4-01-14.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- 322A_4-02-14.pdf ED C 24268 Digital Data 5/14/2014, Electronic File: Canrig Morning Report 2L - 322A_4 -03-14. pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- ' 322A_4-04-14.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- 322A_4-05-14.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- 322A_4-06-14.pdf ED C 24268 Digital Data 5/14/2014, Electronic File: Canrig Morning Report 2L - 322A_4 -07-14. pdf ED C 24268 Digital Data 5/14/2014. Electronic File: Canrig Morning Report 2L- 322A_4-08-14.pdf AOGCC Page 3 of 7 Tuesday, August 12, 2014 CJ C] DATA SUBMITTAL COMPLIANCE REPORT 8/12/2014 Permit to Drill 2131670 Well Name/No. KUPARUK RIV U TARN 21--322A Operator CONOCOPHILLIPS ALASKA INC MD 9515 TVD 5247 Completion Date 4/23/2014 Completion Status 1-0IL Current Status 1-0IL API No. 50-103-20628-01-00 UIC No ED C 24268 Digital Data 5/14/2014 _ Electronic File: Canrig Morning Report 2L - 322A_4 -09-14. pdf ED C 24268 Digital Data 5/14/2014, Electronic File: Canrig Morning Report 2L- 322A_4-10-14.pdf ED C 24268 Digital Data 5/14/2014 • Electronic File: Canrig Morning Report 2L - 322A_4 -11-14. pdf ED C 24268 Digital Data 5/14/2014.o Electronic File: Canrig Morning Report 2L- 322A_4-12-14.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L - 322A_4 -13-14. pdf ED C 24268 Digital Data 5/14/2014.* Electronic File: Canrig Morning Report 2L- 322A_4-14-14.pdf ED C 24268 Digital Data 5/14/2014 j, Electronic File: Canrig Morning Report 21-- 322A_4-15-14.pdf ED C 24268 Digital Data 5/14/2014.) Electronic File: Canrig Morning Report 2L- 322A_4-16-14.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L - 322A_4 -17-14. pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- 322A_4-18-14.pdf ED C 24268 Digital Data 5/14/2014. Electronic File: Canrig Morning Report 2L - 322A_4 -19-14. pdf ED C 24268 Digital Data 5/14/2014 Electronic File: Canrig Morning Report 2L- 322A_set.pdf ED C 24268 Digital Data 5/14/2014 r Electronic File: 2L-322A.dbf ED C 24268 Digital Data 5/14/2014,o Electronic File: 2L-322A.mdx ED C 24268 Digital Data 5/14/2014 , Electronic File: 2L-322A_SCL.DBF ED C 24268 Digital Data 5/14/2014 • Electronic File: 2L-322A_SCL.MDX ED C 24268 Digital Data 5/14/2014 • Electronic File: 2L-322A_tvd.dbf ED C 24268 Digital Data 5/14/2014P Electronic File: 2L-322A_tvd.mdx ED C 24268 Digital Data 5/14/2014 Electronic File: 21-322a.hdr ED C 24268 Digital Data 5/14/2014 + Electronic File: 21-322ar.dbf ED C 24268 Digital Data 5/14/2014.* Electronic File: 21-322ar.mdx ED C 24268 Digital Data 5/14/2014 + Electronic File: 2L -322A FINAL REPORT.doc AOGCC Page 4 of 7 Tuesday, August 12, 2014 • DATA SUBMITTAL COMPLIANCE REPORT 8/12/2014 Permit to Drill 2131670 Well Name/No. KUPARUK RIV U TARN 2L -322A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20628-01-00 MD 9515 TVD 5247 Completion Date 4/23/2014 Completion Status 1 -OIL Current Status 1-0I1- UIC No ED C 24268 Digital Data 5/14/2014, Electronic File: 2L -322A FINAL REPORT.pdf ED C 24268 Digital Data 5/14/2014, Electronic File: 2L -322A Isotube Gas Data.xls ED C 24268 Digital Data 5/14/2014 Electronic File: Shipping_Manifest_Isotubes 2L- 322A.doc ED C 24268 Digital Data 5/14/2014. Electronic File: 2L -322A Combo Log MD.pdf ED C 24268 Digital Data 5/14/2014, Electronic File: 2L -322A Combo Log TVD.pdf ED C 24268 Digital Data 5/14/2014• Electronic File: 2L -322A Drilling Dynamics Log MD.pdf ED C 24268 Digital Data 5/14/2014 ..Electronic File: 2L -322A Drilling Dynamics Log TVD.pdf ED C 24268 Digital Data 5/14/2014 , Electronic File: 2L -322A Formation Log MD.pdf ED C 24268 Digital Data 5/14/2014 . Electronic File: 2L -322A Formation Log TVD.pdf ED C 24268 Digital Data 5/14/2014 , Electronic File: 2L -322A Gas Ratio Log MD.pdf ED C 24268 Digital Data 5/14/2014, Electronic File: 2L -322A Gas Ratio Log TVD.pdf ED C 24268 Digital Data 5/14/2014 Electronic File: 2L-322A_Combo_LOG_MD.jpg ED C 24268 Digital Data 5/14/2014 - Electronic File: 2L-322A_Combo_LOG_MD.tif ED C 24268 Digital Data 5/14/2014 -Electronic File: 2L-322A_Combo_LOG_TVD.jpg ED C 24268 Digital Data 5/14/2014 K Electronic File: 2L-322A_Combo_LOG_TVD.tif ED C 24268 Digital Data 5/14/2014 , Electronic File: 2L- 322A_D R I LL I N G_DY NA M I C S_LO G_M D.j pg ED C 24268 Digital Data 5/14/2014 , Electronic File: 2L- 322A_DRI LLI NG_DYNAMICS_LOG_MD.tif ED C 24268 Digital Data 5/14/2014 p Electronic File: 2L- 322A_DRI LLI NG_DYNAM ICS_LOG_TVD.jpg ED C 24268 Digital Data 5/14/2014 Electronic File: 2L- 322A_DRILLING_DYNAMICS_LOG_TVD.tif ED C 24268 Digital Data 5/14/2014 „ Electronic File: 2L- 322A_F O R MAT I O N_LOG_M D.j pg ED C 24268 Digital Data 5/14/2014 , Electronic File: 2L- 322A_FORMATION _LOG_M D.tif ED C 24268 Digital Data 5/14/2014 - Electronic File: 2L- 322A_F ORMATI O N_LOG_TVD.jpg AOGCC Page 5 of 7 Tuesday, August 12, 2014 • DATA SUBMITTAL COMPLIANCE REPORT 8/12/2014 Permit to Drill 2131670 Well Name/No. KUPARUK RIV U TARN 2L -322A Operator CONOCOPHILLIPS ALASKA INC MD 9515 TVD 5247 Completion Date 4/23/2014 Completion Status 1 -OIL Current Status 1 -OIL ED C 24268 Digital Data ED C 24268 Digital Data ED C 24268 Digital Data ED C 24268 Digital Data ED C 24268 Digital Data ED C 24268 Digital Data ED C 24268 Digital Data ED C 24268 Digital Data ED C 24268 Digital Data Log C 24268 Log Header Scans Log 24268 Mud Log Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report v/ Production Test Information Y "D Geologic Markers/Tops Q COMPLIANCE HISTORY API No. 50-103-20628-01-00 UIC No 5/14/2014 Electronic File: 2L- 322A FORMATION LOG TVD.tif 5/14/2014 Electronic File: 2L- 322A_GAS_RAT I O_LOG_M D.j pg 5/14/2014 Electronic File: 2L- 322A GAS RATIO LOG MD.tif 5/14/2014 Electronic File: 2L- 322A_GAS _ RATIO _LOG_TVD.jpg 5/14/2014 Electronic File: 2L- ' 322A_GAS_RATIO_LOG_TVD.tif 5/14/2014 , Electronic File: 2L -322A Engineering Remarks.txt 5/14/2014. Electronic File: 2L -322A Lithologic Remarks.txt 5/14/2014 Electronic File: 2L- 322A_S h owReport_1 _6636ft_9515ft. pdf 5/14/2014. Electronic File: 2L- 322A_ShowReport_1 _6636ft_9515ft.xls 2131670 KUPARUK RIV U TARN 2L -322A LOG v HEADERS 2 Col 2750 9515 5/14/2014 Formation Log MD & TVD LWD Combo Log MD & TVD Gas Ratio Log MD & TVD Drilling Dynamics Log MD & TVD Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data vJ Mud Logs, Image Files, Digital Dat QNA Core Chips Y N3 Mechanical Integrity Test Information YNA Composite Logs, Image, Data Files Core Photographs / N Daily Operations Summary ©Y Cuttings Samples Y �N Laboratory Analyses xzNo AOGCC Page 6 of 7 Tuesday, August 12, 2014 0 DATA SUBMITTAL COMPLIANCE REPORT 8/12/2014 Permit to Drill 2131670 Well Name/No. KUPARUK RIV U TARN 2L -322A Operator CONOCOPHILLIPS ALASKA INC MD 9515 TVD 5247 Completion Date 4/23/2014 Completion Status 1-0I1- Current Status 1-011- Completion -OILCompletion Date: 4/23/2014 Release Date: 12/10/2013 Description Date Comments Comments: API No. 50-103-20628-01-00 UIC No AOGCC Page 7 of 7 Tuesday, August 12, 2014 0 • • e Ferguson, Victoria L (DOA) From: Shultz, Steve (Orbic Engineering, Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Friday, August 01, 2014 9:34 AM To: Ferguson, Victoria L (DOA) Cc: Bearden, J Daniel Subject: RE: KRU 2L-322A(PTD 213-167) 10-407 submission Attachments: 2L -322A Cementing Report (7.625 csg).pdf, 2L -322A Well Diagram.pdf; CPAI_ 2L -322A ACE_21APRl.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Sorry about the delay. I have included the cementing report, the official CPAI well diagram and the CBL. The bond log was run on April 14, 2014. Steve From: Ferguson, Victoria L (DOA)[mailto:victoria.ferguson(a)alaska.gov] Sent: Thursday, July 31, 2014 11:17 AM To: Shultz, Steve (Orbis Engineering, Inc.) Cc: Bearden, J Daniel Subject: [EXTERNAL]RE: KRU 2L-322A(PTD 213-167) 10-407 submission I can't seem to find a response to this email, specifically, when was the CBL run? From: Ferguson, Victoria L (DOA) Sent: Thursday, July 03, 2014 9:29 AM To: steve.shultzCabcontractor.conocophillips.com Cc: Bearden, J Daniel Q. Daniel. Bearden Cdconocophillips.com) Subject: KRU 2L-322A(PTD 213-167) 10-407 submission Steve, From the 10-407 report submission: 1. Please submit the attached cement summary report with the 10-407. More detail than is outlined in the drilling report is needed. It looks like some of the cement has been left out of the cementing record on the face of the 10-407. Please distribute this cement report throughout your organization. This cement summary should be submitted with every 10-407. 2. The wellbore schematic should represent the wellbore after drilling, not proposed. 3. Where in the report is the CBL run? Is the TOC shown in the wellbore schematic the TOC picked from the CBL? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer 1 State of Alaska • Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.fera uson@alaska.00v 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 Ferguson at (907)793-1247 or Victoria.Ferguson@alaska.gov • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT RECEIVED MAY 232014 AND ,L!Q I ;C; 1a. Well Status: Oil Q Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development o 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 24, 2014 213-167 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 March 24, 2014 50-103-20628-01 - 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 209' FNL, 821' FEL, Sec. 22, T10N, R7E, UM April 7, 2014 YA �k 2L -322A Top of Productive Horizon: 8. KB (ft above MSL): 144' RKB - 15. Field/Pool(s): 1952' FSL, 1013' FEL, Sec. 22, T10N, R7E, UM GL (ft above MSL): 115' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 3814' FSL, 891' FEL, Sec. 27, T1 ON, R7E, UM 9485' MD / 5245' TVD Tarn Oil Pool . 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-460829 y- 5927638 Zone -4 9515' MD / 5247' TVD ADL 380052, 380054 11. SSSV Depth (MD + TVD): 17. Land Use Permit: TPI: x-460626 y- 5924520 Zone -4 Total Depth: x-460736 y- 5921102 Zone -4 nipple @ 531' MD / 531' TVD 4600, 4602 18. Directional Survey: Yes I❑ • 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) 1415' MD / 1383' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-drill/Lateral Top Window MD/TVD GR / Res, CAST -M, CBL 2608' MD / 2351' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 164# B-35 43' 146' 43' 146' 24" driven 10.75" 46# L-80 42' 2613' 42' 2358' 13.5" 970 sx AS LiteCRETE, 395 sx LiteCRETE 7.625" 29.7 & 39# L-80 27' 6215' 27' 5010' 9.875" 408 sx Class G 4.5" 12.6# L-80 6034' 9485' 4921' 5245' 6.5" open hole 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" 6049' 5982' MD / 4893' TVD open hole completion from 6034'-9485' MD 4921'-5245' TVD 6034' MD / 4921' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. # } Was hydraulic fracturing used during completion? Yes[] No❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED DA none I IED 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 Q Sidewall Cores Acquired? Yes No ❑✓ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE EMMMS MAY 2 3 2 Form 10-407 Revised 10/2012 CONTINU D O R E E t%J� $� 14 �'� Submit original only 29. GEOLOGIC MARKERS (List all formations and marker untered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes , No If yes, list intervals and formations tested, ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface Permafrost - Bottom 1415' 1383' needed, and submit detailed test information per 20 AAC 25.071. C-37 5152' 4313' Top Bermuda 6698' 5171' N/A Formation at total depth: Bermuda 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4864 Email: Steve. Shu ltz(a)conocophillips.com Printed Name G. L. Allvor�dy Title: Alaska Drilling Manager Signature 6_0� - Phone 265-6120 Date It 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 0 0 Tarn 2L-322 North Rotary Sidetrack Topset Bonsal Horizontal Multi -Stage Frac'd Producer Proposed Wellbore Schematic ConocoFfifflips Gen V A 4-v.--.fe-e, tOP I0if-AiS4-%" 12 601517,1. IOM;WJ' .�lifrenlwell hc-&l 16" Existing Cemented CondUctor.- 16* 62.6# H-40 Tit7m[L 146" NID 3 •,• [awe 05 WOO'& 2,V6, SWVAO 1'.J* C— MUG Existirm Surface Casina: 10-314"45.5#'L-80 BTC 2,614- MD I 2,35-T TVD @ 3T ft 11 Sidetrack KCP off cenwnt plug C 39 degrees In open We @ 2,69Ft'-_: 4 ' 97FUD A Tubina: L-80 EUE8D V\ A 4-1/2" 12.6# L-80 I BTMRtop joint to surface TOG 15 8 gpl U -,4,WA'hlD 15M zijmv Lab": 9-70' Intermediate H4- Intemlediate Casing Upset with Bonzal: T -Wal 29.70 L-80 & 500' TN 1 1OSS 39#'- alf Hydril 563 connections 6,214' MD 16,010' TVD @ 62" Tap tl RAM610A 6 57 5 '41 rvn imm . . . . . . . . . . . . . . . . . . . . . . . . . n t r 2 7%4 �yd 21 wink -T ..... ..... .......... .... AVA' 4RIF ...ri: ............. ......... ......... ... ... .... ...... ............... ...... ............... . ............. .......................... D* MD: ........... ........... ......... " Time Log & Summary ConocoPPhillips s Weliview Web Reporting Report Well Name: 2L-322 Rig Name: NABORS 9ES Job Type: DRILLING SIDETRACK Rig Accept: 3/18/2014 12:00:00 PM Rig Release: 4/24/2014 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth <Phase 'Code Subcode T Comment 3/16/2014 24 hr summary Inspected derrick and secured lines. Laid derrick over. Changed out SRL hanging points and derrick climber assist line. Load out welding shop and mechanics shop. Move pits from sub. Load up camp. Road camp and pits to 2L pad. Spot and set camp. Blown fuse on moving system 1 hr delay. 00:00 03:30 3.50 0 0 MIRU MOVE DMOB P Inspect derrick and secure lines. Pull pins on the "A" legs. Lay derrick over. Set on Derrick stand with 275KIbs Disconnect lines between interconnect. 4 1/16" 10M tree on location with tree adapter. 03:30 06:00 2.50 0 0 MIRU MOVE DMOB P Change out derrick climber assist guide cable. Move SRL's to a lower anchor point in the derrick. Load out mechanics & welding shop. Spot on 2L pad. Load out mud products and misc. to location from 2N-323 06:00 20:00 14.00 0 0 MIRU MOVE MOB P Take down berming around rig. Pull pits away from the rig. Jack up and remove mats from office/camp. Road camp and pits to 2L pad from 2n Pad 20:00 23:00 3.00 0 0 MIRU MOVE MOB P Spot liner for office/camp and spot same. Slide mats under and set down. Remove Jeep from pits and latch truck back up. Roll tires on sub to warm moving system 23:00 00:00 1.00 0 0 MIRU MOVE MOB T Unable to get moving system to work after plugging in hand held. Call out electrician and locate blown fuse. Moving system operational. 3/17/2014 Pull sub off of 2N-323. Move rig from 2N-323 to 2L pad. Hang tree in cellar. Set rig mats and herculite. Spot rig over 2L-322. Lay herculite and spot pit complex. Berm around rig and pits. Inspect and raise derrick. Raise cattle chute and bridle down. 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Move sub off of 2N -323A. Clean up herculite, wood, 4 1/2" x 7" Rams. Remove unused tubing head. Clean up around well site. Time Logs Date From To Dur S. De th E De th Phase "Code Subcode T Comment 03:00 06:00 3.00 0 0 MIRU MOVE MOB P Move rig 3.3miles from 2N -323A to 2L-322 06:00 08:00 2.00 0 0 MIRU MOVE MOB P Set rig mats for herculite over well. Hang tree in cellar, set adapter flange in cellar. Level around the well. 08:00 12:00 4.00 0 0 MIRU MOVE MOB P Notify pad operator and spot rig over 2L-322. Set down and check for level. 12:00 20:30 8.50 0 0 MIRU MOVE MOB P Lay liner, spot pits. Set mats. Berm pits and rig. Close cellar doors. Set stairs. Clean up work areas, engage interconnect. 20:30 00:00 3.50 0 0 MIRU MOVE MOB P PJSM, inspect and raise derrick and pin same. Raise cattle chute. Bridle down. 3/18/2014 Pin Top Drive. Set MI, Schlumberger and Canrig units, continue rigging up service lines and equipment, Change out tugger and man rider cables, rig accepted @ 1200 hrs, R/U hard lines to tiger tank, pull TWC, Displace freeze protect w/ hot sea water, oberve well for flow f/ 30 min. Well static. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Pin Top drive to blocks. Change out Bridle line winch lines in the derrick. Set MI mud shack, Schlumberger MWD unit, Canrig mud logger units. Set up berm for Tiger tank and Spot tank. Begin rig up hard line. 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Rig up and change out tugger lines, change out bridle hanging lines 09:00 10:00 1.00 0 0 MIRU MOVE RURD P Hang bridle lines in derrick 10:00 12:00 2.00 0 0 SLOT MOVE RURD P Change out man rider lines on both off driller side and driller side, fill cracks around cellar. Rig Accepted @ 1200 hrs 12:00 16:00 4.00 0 0 SLOT MOVE RURD P Hook up hardlines to tiger tank, take on brine to pits, pressure test mud lines, test gas alarmsin cellar and mezzanine. 16:00 18:30 2.50 0 0 SLOT MOVE OTHR P R/U lubricator & test t/ 1000 psi pull BPV, secure tree, R/D lubricator. 18:30 20:00 1.50 0 0 SLOT MOVE RURD P R/U cellar hardlines f/ well kill, blow down lines and check connections, test secondary kill line t/ 1500 psi test good 20:00 23:30 3.50 0 0 SLOT MOVE CIRC P Test lines t/ tiger tank t/ 1500 psi good, circulate hot seawater @ 72 spm 210 gpm 420 psi 265 bbls to tiger tank. 23:30 00:00 0.50 0 0 SLOT MOVE OWFF P Observe well for flow f/ 30 min. well static. 3/19/2014 Observe well for flow well static, Nipple down tree, Install blanking plug, Nipple up BOPE stack & riser, hook up service lines & turn buckles, R/U & test BOPE t/ 250/3500 AOGCC inspector Jeff Turkington waived witness, 00:00 00:30 0.50 0 0 SLOT MOVE OWFF P Observe well for flow well static 00:30 01:30 1.00 0 0 SLOT MOVE RURD P Blow Down and R/D hard lines, set BPV as per FMC test in direction of flow 1000 psi f/ 10 min. i'�„ � � Time Logs Wu Date From To Dur S. Depth E.'De th ''Phase Code > Subcode T Comment 01:30 04:00 2.50 0 0 SLOT MOVE NUND P Nipple down tree inspect hanger threads install blanking plug. 04:00 04:30 0.50 0 0 SLOT MOVE RURD P I Make dummy run on test it. 04:30 09:30 5.00 0 0 SLOT MOVE NUND P Nipple up BOP's, Riser and service lines, hook up turn buckle center stack. 09:30 12:30 3.00 0 0 SLOT MOVE RURD P R/U t/ test BOP's fill lines w/ water, grease valves. SHOPS load 4" DP in shed 12:30 15:00 2.50 0 0 SLOT MOVE BOPE P Attempt t/ obtain body test, chart recorder not functioning properly, change out chart recorder. pump up sensors. 15:00 00:00 9.00 0 0 SLOT MOVE BOPE P Test BOPS, body test 2" kill line demco leaked, rebuild valve move on with tests, blanking plug leaking, pull blanking plug clean threads reinstall x 2, test choke valves 1-16, HCR & Man choke and kill, TIW & Dart, upper rams, test w/ 4%" test jt t/ 250 low 3500 high. 3/20/2014 Finish testing BOP's, blow down lines R/D test equipment, R/U GBR casing equipment, M/U & engage landing jt, BOLDS & pull hanger t/ floor, L/D hanger & pull 4.5" 12.6# IBTM tubing f/ 1826't/ surface, R/D casing equipment, R/U t/ test rams w/ 4" & 5" test jt, install double vavles on OA, install high pressure valve in koomey line, attempt shell test leaking, trouble shoot test plug not all the way in profile due t/ lower lock down screws engaged, Mobilize FMC, service rig. 00:00 03:00 3.00 0 0 SLOT MOVE BOPE P Test BOP's , test choke valves 1-16 auto and man IBOP, HCR & Man choke and kill, Upper Lower and blind rams, 2" demco on kill line, inner and outer spool valves, TIW & Dart, t/ 250 low 3500 high, accumulator test, 28 sec 200 psi 148 sect/ full pressure, CPAI Drawdown 55.7 sec electric pump 136 sec air pumps, AOGCC Inspector Jeff Turkington waived witness of test. 03:00 04:00 1.00 0 0 SLOT MOVE RURD P Blow down lines, R/D test equipment. 04:00 05:00 1.00 0 0 SLOT RPCOM RURD P R/U GBR casing equipment to piull 4.5" tubing. 05:00 05:30 0.50 0 0 SLOT RPCOM OTHR P Pull BPV as per FMC 05:30 06:30 1.00 0 0 SLOT RPCOM PULL P P/U landing jt make up crossover, engage hanger, BOLDS, useat hanger w/ 50k weight indicator. 06:30 10:00 3.50 1,826 1,022 SLOT RPCOM PULL P L/D hanger pull out of the hole w/ 4.5" 12.6# IBTM tubing f/ 1826't/ 1022' 10:00 10:30 0.50 1,022 1,022 SLOT RPCOM OTHR P Ice falling from drrick send man up in derick to knock off ice build up. 10:30 15:30 5.00 1,022 0 SLOT RPCOM PULL P Continue L/D 4.5" 12.6# IBTM tubing f/ 1022' t/ surface. 15:30 17:30 2.00 0 0 SLOT RPCOM RURD P R/D gbr casing equipment, clean and clear rig floor, L/D equipment. d9 Time Logs WE Date From To Dur S. De th E. -De' th Phase Code Subcode T Comment 17:30 20:30 3.00 0 0 SLOT RPCOM RURD P R/U t/ test rams w/ 4" & 5" test jts, w/ 4.5" & TIW & Dart, Install companion flange on OA & double valve, Install high pressure line in koomey line. 20:30 23:30 3.00 0 0 SLOT RPCOM BOPE P Attempt shell test on rams w/ 5" test jt, leaking, pull test jt check rubber, rubber good, RIH not dropping all the way into profile, trouble shoot stack, lower lock downs ran in, mobilize FMC 23:30 00:00 0.50 0 0 SLOT RPCOM SVRG P Service rig, top drive and draworks, D3/21/2014 Finish testing BOP's w/ 4" & 5" Test Jts t/ 3500 psi, Install wear ring, R/U & P/U 4" DP f/ shed RIH, POOH and stand back 22 stands in derrick, Iron roughneck hose failed replace, P/U 4" DP f/ shed RIH t/ 2117' run in hole f/ derrick t/ TOC @ 2461', R/U & test mud lines t/ 3500 psi bonnet on 4" demco on #2 mud pump failed, Tighten and retest same failed, replace bonnet seal on 4" demco valve. 00:00 04:00 4.00 0 0 SLOT RPCOM BOPE P Test BOPE w/ 4" & 5" test jt, Upper & lower Rams, Annular t/ 250 low 3500 high. 04:00 05:00 1.00 0 0 SLOT RPCOM RURD P Blow down lines, R/D test equipment, Install wear ring 05:00 05:30 0.50 0 0 SLOT RPCOM RURD P I R/U t/ P/U 4" DP, P/U mule shoe. 05:30 06:00 0.50 0 0 SLOT RPCOM SFTY P PJSM on picking up pipe f/ shed 06:00 10:30 4.50 0 0 SLOT RPCOM TRIP P P/U 4" DP f/ shed 66 jts. 10:30 12:30 2.00 0 0 SLOT RPCOM TRIP P POOH w/ 4" DP racking back in derrick 22 stands. 12:30 13:30 1.00 0 0 SLOT RPCOM OTHR P Clean and clear rig floor R/U t/ RIH f/ shed 13:30 14:00 0.50 0 0 SLOT RPCOM SFTY P BOP Drill Kick while tripping & AAR 14:00 14:30 0.50 0 0 SLOT RPCOM SVRG P I Service rig and top drive. 14:30 17:00 2.50 0 0 SLOT RPCOM RGRP T Repair Iron Roughneck hydraulic hose the failed. 17:00 22:00 5.00 0 2,461 SLOT RPCOM PULD P P/U 4" DP f/ shed RIH 22 stands t/ 2117' RIH f/ derrick and tag TOC @ 2461' PUW-65k SOW -60k 22:00 22:30 0.50 2,459 21459 SLOT RPCOM PRTS P Pressure test mud lines and kelly hose t/ 3500 psi 4" demco bonnet seal leaked. 22:30 23:00 0.50 2,459 2,459 SLOT RPCOM CIRC P Tighten bolts retest same, still leaking. 23:00 00:00 1.00 2,459 2,459 SLOT RPCOM RGRP T Replace bonnet seal on 4" demco on #2 mud pump, blow down top drive. 3/22/2014 Displace well to 9.5 ppg LSND 500 gpm t/ tiger tank, strokes t/ volume didn't match, finish displacement, POOH w/ 4" DP stand back in derrick, R/U and P/U BHA as per DD, P/U 4" DP f/ shed t/ 2372' R/U & perform casing test t/ 3000 psi, blow down and R/D test equipment. 00:00 00:30 0.50 2,459 2,459 SLOT RPCOM SFTY P Pre Job safety meeting on displacing well t/ LSND. 00:30 02:30 2.00 2,459 2,459 SLOT RPCOM CIRC P Displace well t/ 9.5 ppg LSND, pump 25 bbls hi vis spacer, follow w/ 9.5 ppg LSND for calculated strokes 500 gpm 350 psi, take returns t/ tiger tank, shutdown Page 4 of 42 Time Logs WU Date From To Dur = S. De th E. DeiDth Phase Code Subcode T Comment 02:30 04:00 1.50 2,459 21459 SLOT RPCOM CIRC P Volumes pumped didn't match strokes pumped, strap tiger tank and pits, confirm 150 bbls pumped of planned 243, continue to displace remaining 100 bbls taking returns t/ pits 3 bpm 150 psi. 04:00 04:30 0.50 2,459 1,984 SLOT RPCOM TRIP P POOH on elevators f/ 2459't./ 1984' pulling wet running over, well out of ballance. 04:30 05:30 1.00 1,984 1,984 SLOT RPCOM CIRC P Circ and condition mud to even out MW as per mud engineer. 05:30 06:45 1.25 1,984 0 SLOT RPCOM TRIP P POOH on elevators f/ 1984'V surface, L/D mule shoe. 06:45 08:30 1.75 0 0 SLOT RPCOM RURD P Clean and clear floor R/U t/ P/U BHA, bring BHA components t/ rig floor. 08:30 17:00 8.50 0 752 SLOT RPCOM PULD P P/U BHA as per DD, Bit, 675 XP motor, stab, Ecoscope, Telescope, well commander, load sources, flex colars, HWDP, Jars 17:00 20:30 3.50 752 2,372 SLOT RPCOM PULD P P/U 4" Dp f/ shed RI f/ 752' t/ 2372' 20:30 22:00 1.50 2,372 2,372 SLOT RPCOM CIRC P circ and condition mud even out MW, 350 gpm 740 psi 40 RPM 4k tq 22:00 22:30 0.50 2,372 2,372 SLOT RPCOM RURD P RT/U t/ perform casing test. 22:30 00:00 1.50 2,372 2,372 SLOT RPCOM PRTS P Pressure test casing t/ 3000 psi f/ 30 min, Good test. R/D test equipment. 3/23/2014 Wash & Ream 500 gpm 1390 psi 40 RPM 4k tq , drill cement t/ 2518' Drill cement retainer / 2520' observe weight loss, chase in the hole U 2561', Drill cement and retainer t/ 2607', Drill cement t/ 2636', Trough and time drill t/ 2657', side track well t/ 2785', Circ mud f/ LOT, Perform leak off test t/ 14.9 ppg EMW, POOH w/ sidetrack BHA, L/D & Stand Back BHA Break Bit 00:00 01:15 1.25 2,467 2,515 SLOT DRILL DRLG P Reaming / Washing F / 2,467' to 2,515'500 gpm 40 RPM 1390 psi 01:15 06:45 5.50 2,515 2,636 SLOT DRILL DRLG P Drilling cement F/ 2515' to 2518' @500 GPM, WOB 5K, RPM 40, PUW 100K, SOW 75K, ROT 85K. Tagged cement retainer at 2518'. Drilled cement and retainer 2518' to 2520', observe weight fall off take weight again & 2561' drill retainer and cement t/ casing shoe at 2601'. Continue drilling to 2636'. 06:45 08:15 1.50 2,636 2,658 SLOT DRILL DDRL P Drilling, slide F / 2636' to 2658' building angle @ 500 GPM, PUW 100K, SOW 75k, @ 2658' MD, 2389' TVD. #1 Pump 30 SPM, 120 PSI, 45 SPM, 170 PSI. #2 Pump 39 SPM, 110 PSI, 45 SPM, 170 PSI, MW 9.6 PPG. 08:15 09:45 1.50 2,658 2,702 SLOT DRILL DDRL P Time Drill & Trough F / 2658' to 2702' per DD. 300 GPM, PUW 100K, SOW 75K. 09:45 11:00 1.25 2,702 2,714 SLOT DRILL DDRL P Slide drilling F / 2702' to 2714'. 500 GPM, PUW 105K, SOW 75K. 11:00 12:00 1.00 2,714 2,754 SLOT DRILL DDRL P Rotary drilling F / 2714' to 2754'. 500 GPM, RPM 40, WOB 10K, PUW 105K, SOW 75K, ROT 85K. �A Page 5 of 42 Time Logs W 3M Date From To Dur S. De th E'De th Phase Code Subcode T Comment 12:00 13:30 1.50 2,754 2,785 SLOT DRILL DDRL P Rotary drilling F / 2754' to 2786'. 500 GPM, PSI ON 1500, PSI OFF 1274, RPM 40, TQ ON 55K, TQ OFF 43K, PUW 105K, SOW 80K, ROT 90K. #1 Pump @ 2 BPM 120PSI, at 3 BPM 170 PSI. #2 Pump @ 2 BPM 120 PSI, at 3 BPM 170 PSI. MW 9.6 PPG 13:30 14:00 0.50 2,785 2,785 SLOT DRILL LOT P PJSM, R/U test equipment for LOT. 14:00 17:00 3.00 2,785 2,785 INTRM1 DRILL LOT P PJSM, Circulate and condition mud. LOT, 700 PSI, EMW 14.9, MW 9.6 ppg R/D test equipment. 17:00 22:00 5.00 2,785 752 INTRM1 DRILL TRIP P POOH, F / 2785 to 752' 22:00 00:00 2.00 752 0 INTRM1 DRILL PULD P Stand Back & L/D BHA, Unload sources, Break Bit 3/24/2014 P/U BHA #2, shallow test tools, RIH w/ 4" DP t/ 2565' Slip and cut drilling line, service rig, Wash and ream 550 gpm 120 rpm t/ 2785', Drill ahead new formation t/ 3175' footage 390' 00:00 01:00 1.00 0 0 INTRM1 DRILL PULD P I L/D BHA, #1 clear and clean floor, upload MWD. 01:00 04:30 3.50 0 182 INTRM1 DRILL PULD P PJSM, P/U BHA #2, 04:30 06:00 1.50 182 937 INTRM1 DRILL TRIP P TIH W / 5" HWDP, change elevators, continue TIH W/ 4" DP. 06:00 07:45 1.75 937 937 INTRM1 DRILL CIRC P Circulate and condition mud, surface test MWD tool at 937', 200 GPM - 210 PSI, 250 GPM - 290 PSI, 350 GPM - 410 PSI, 400 GPM - 530 PSI, 425 GPM - 490 PSI, 450 GPM - 650 PSI, 500 GPM - 810 PSI. Blow down T/D. 07:45 08:45 1.00 937 2,565 INTRM1 DRILL TRIP P TIH W / 4" DP, 937' to 2,565'. 08:45 11:30 2.75 2,565 2,565 INTRM1 DRILL SLPC P Slip and Cut 61,5' of 1 1/4" drilling line. 11:30 12:00 0.50 2,565 2,565 INTRM1 DRILL SVRG P Service Top Drive, Blocks and Washpipe. 12:00 13:00 1.00 2,565 2,565 INTRM1 DRILL SLPC P Service rig, finish Slip and Cut. 13:00 14:00 1.00 2,565 2,785 INTRM1 DRILL TRIP P PJSM, TIH 2565' to 2785'. 14:00 00:00 10.00 2,785 3,175 INTRM1 DRILL DDRL P Drill New Formation f/ 2785't/ 3175' Footage 390' 600 GPM 1800 psi 120 RPM TQ ON 5.5k OFF 4.5k PUW-105k SOW- 85k ROT- 90k ART- 4.87 AST- 0 ADT - 4.87 3/25/2014 Drilling Ahead w/ 6.75 Periscope f/ 3175't/ 4666' Footage 1491', 600 gpm 2375 psi 140 RPM 7k tq, Maintain mud proerties w/ dilutions and centrifuge, pump HiVis Sweeps every 300' M _� Page 6 of 42 Time Logs Date From To Dur S. De th E.',De th Phase Code Subcode T Comment 00:00 12:00 12.00 3,175 4,000 INTRMI DRILL DDRL P PJSM, Rotary Drilling, 3175' to 4000'. GPM - 600, PSI ON - 21 K, PSI OFF - 21K, RPM - 140, TQ ON - 6.8K, TQ OFF - 5.7K, PUW - 115K, SOW - 90K, ROW - 100K, ART - 8.2 HRS, BIT HRS - 13.07, JAR HRS - 86.77, SPR'S - 8:15 HRS, TVD 3714', MD 3207' #1 Pump @ 2 BPM, 28 STKS = 160 PSI, @ 3 BPM, 42 STKS = 200 PSI #2 Pump @ 2 BPM, 28 STKS = 160 PSI, @ 3 BPM, 42 STKS = 200 PSI 9.6 PPG, Pump Hi Vis Sweeps Every 300', Down Load Link per DD. 12:00 00:00 12.00 4,000 4,666 INTRMI DRILL DDRL P PJSM, Rotary Drilling, 4000' to 4666'. GPM - 500, PSI ON - 2375, PSI OFF - 2350, RPM - 100, TQ ON - 6.7K, TQ OFF - 6K, PUW - 130K, SOW - 100K, ROW - 108K, ART - 7 HRS, BIT HRS - 20.07, JAR HRS - 93.77, SPR'S - 2330HRS, TVD 3940', MD 4666' #1 Pump @ 2 BPM, 28 STKS = 160 PSI, @ 3 BPM, 42 STKS = 210 PSI #2 Pump @ 2 BPM, 28 STKS = 160 PSI, @ 3 BPM, 42 STKS = 210 PSI 9.6 PPG, Pump Hi Vis Sweeps Every 300', Down Link per DD. 3/26/2014 Observe well f/ flow, POOH f/ 4666't/ 2673' no hole issues, RIH f/ 2673't/ 4375' Log t/4395', RIH, Circ Hivis sweep, Drill f/ 4666't/ 5142', pop off tripped rig repair work on pop off, replace demco valve, Drill f/ 5142't/ 5238' 00:00 03:30 3.50 4,666 4,666 INTRMI DRILL TRIP P PJSM, monitor well for 30 minutes, line up on trip tank, short trip out of the hole 4666' to 2673'. 03:30 05:15 1.75 4,666 4,666 INTRMI DRILL TRIP P Monitor the well 15 minutes, TI 2673to 4375', Kelly Up for MWD Log. 05:15 08:00 2.75 4,666 4,666 INTRMI DRILL REAM P Reaming / Washing, Log Well 4375' to 4395' per MWD. Continue Reaming to 4666'. 500 GPM, 40 RPM, 80 ROP, 08:00 12:00 4.00 4,666 4,952 INTRM1 DRILL DDRL P Rotary Drill, 4666' to 4952'. 600 - GPM, PSI ON - 2260, PSI OFF - 2240, RPM - 140, TQ ON - 79K, TQ OFF - 63K, PUW - 135K, SOW - 100K, ROT - 115K. ART - 2.15 HRS, ADT - 2.15 HRS, BIT - 22.22 HRS, JARS - 95.92 HRS. SPR'S 08:15 HRS, MD - 4945', TVD - 4156'. #1 Pump @ 2 BPM, 28 STKS = 170 PSI, @ 3 BPM, 42 STKS = 230 PSI. #2 Pump @ 2 BPM, 28 STKS = 170 PSI, @ 3 BPM, 42 STKS = 230 PSI. __ _. Page 7 of 42 Time Logs WW W Date From To Dur S.'De th E. DeiDth Phase Code Subcode T Comment 12:00 14:15 2.25 4,952 5,142 INTRM1 DRILL DDRL P Rotary Drill, 4952' to 5142'. 600 - GPM, PSI ON - 2550, PSI OFF - 2490, RPM - 120, TO ON - 79K, TO OFF - 63K, PUW - 135K, SOW - 100K, ROT - 115K. ART - 2.15 HRS, ADT - 2.15 HRS, BIT - 22.22 HRS, JARS - 95.92 HRS. SPR'S 08:15 HRS, MD - 4945', TVD - 4156'. #1 Pump @ 2 BPM, 28 STKS = 170 PSI, @ 3 BPM, 42 STKS = 230 PSI. #2 Pump @ 2 BPM, 28 STKS = 170 PSI, @ 3 BPM, 42 STKS = 230 PSI. Pop off failed. 14:15 14:45 0.50 5,142 5,142 INTRM1 DRILL SVRG P Service Rig and Top Drive 14:45 21:30 6.75 5,142 5,142 INTRM1 DRILL RGRP T Down time work on pop off & repladce demco valve. 21:30 00:00 2.50 5,142 5,238 INTRM1 DRILL DDRL P Rotary Drill, 5142' to 5238'. 600 - GPM, PSI ON - 2670, PSI OFF - 2490, RPM - 120, TO ON - 9.5K, TO OFF - 6.5K, PUW - 140K, SOW - 100K, ROT - 115K. ADT - 2.49 HRS, BIT - 24.71 HRS, JARS - 98.41 HRS. SPR'S 2330 HRS, MD - 5237', TVD - 44374'. #1 Pump @ 2 BPM, 28 STKS = 190 PSI, @ 3 BPM, 42 STKS = 250 PSI. #2 Pump @ 2 BPM, 28 STKS = 190 PSI, @ 3 BPM, 42 STKS = 250 PSI. Pop off failed. 3/27/2014 Drill f/ 5238't/ 6224' Circ and condition hole f/ trip out, 500 gpm 130 rpm, Pump Hi Vis sweep, OWFF Well Static, POOH on elevators f/ 6224't/ 3510' tight spots observed @ 5845'5785'4960'20k overpull observed wipe clean. 00:00 12:00 12.00 5,238 5,940 INTRM1 DRILL DDRL P PJSM, Rotary Drilling, 5238' to 5940', Monitor Well for 15 min. GPM - 600, PSI ON - 2760, PSI OFF - 2720, RPM - 130, TO ON - 9.41K, TO OFF - 6.1 K, PUW - 150K, SOW - 105K, ROT - 140K, ART - 6.3 HRS, ADT - 6.33 HRS, BIT HRS - 31.04, JAR HRS - 104.7, SPR'S @ 5940' MD, 4875' TVD. #1 Pump @ 2BBLS, 28 STKS = 190 PSI, @ 3 BBLS, 42 STKS = 240 PSI. #2 Pump @ 2 BBLS, 28 STKS = 190 PSI, @ 3 BBLS, 42 STKS = 250 PSI. MW 10.1 PPG, Downlink per DD. rage 8 of 42 Time Logs Date From To ' Dur S. De th E. De th Phase Code Subcode T Comment 12:00 17:00 5.00 5,940 6,224 INTRMI DRILL DDRL P Rotary Drilling 5940' to 6224'. GPM 540, PSI ON - 2500, PSI OFF - 2400, RPM - 140, TQ ON - 10K, TQ OFF - 9K, PUW - 150K, SOW - 105K, ROT 123K, ART - 2.22 HRS, ADT - 2.22 HRS, Bit - 33.79 HRS, JAR S 107.49 HRS, SPR'S @ 6224' MD, 5015' TVD. #1 Pump @ 2 BBLS, 28 STKS = 160 PSI, @ 3 BBLS, 42 STKS = 220 PSI. #2 Pump @ 2 BBLS, 28 STKS = 170 PSI, @ 3 BBLS, 42 STKS = 220 PSI. MW 9.8 PPG. 17:00 19:00 2.00 6,224 6,224 INTRM1 CASING CIRC P Circ and condition mud pump Hi vis sweep Circ well until hole clean w/ 500 gpm 2000 psi 130 RPM 19:00 19:30 0.50 6,224 6,224 INTRMI CASING OWFF P Observe well f/ flow well static 19:30 00:00 4.50 6,224 3,510 INTRM1 CASING TRIP P POOH f/ 6224't./ 3510' Hole took correct fill Tight spots observed @ 5845', 5785', 4960' Wiped through pulled no overpull observed 3/28/2014 POOH f/ 3510't/ 2600' OWFF, POOH t/ BHA @ 752' OWFF well static, unload sources L/D BHA, pull wear ring, set test plug, change upper rams t/ 7 5/8 solid body, R/U and test upper rams and annular t/ 250/3500 psi, R/D test equipment, R/U t/ run casing, C/O saver sub hanger tesco service loop, M/U tesco casing running tool 00:00 03:30 3.50 3,510 750 INTRM1 CASING TRIP P PJSM, TOH 3510' to Shoe, 2600'. Monitor well for 30 minutes, TOR 5 STDS, pump dry job, continue TOH. 03:30 05:30 2.00 750 152 INTRM1 CASING PULD P PJSM, monitor well for 15 minutes. L/D 5" HWDP and 6 1/4" Jars. 05:30 10:00 4.50 152 152 INTRM1 CASING PULD P PJSM with Schlumberger, L/D BHA and unload Source. Clean and clear the rig floor. 10:00 12:00 2.00 152 0 INTRM1 CASING PULD P L/D Schlumberger tools and bit. Bring up 7 5/8" elevators and slips to the rig floor. 12:00 13:00 1.00 0 0 INTRM1 CASING PULD P Prepare to run casing, L/D short bails and bring long bails to the rig floor. 13:00 14:30 1.50 0 0 INTRM1 CASING SEQP P Remove wear ring, drain stack, attempt to set test plug. Thaw out frozen OA and set test plug. 14:30 15:00 0.50 0 0 INTRM1 CASING BOPE P PJSM for installing 7 5/8" casing rams in top preventer. 15:00 18:00 3.00 0 0 INTRMI CASING BOPE P Install 7 5/8" casing rams in top preventer. 18:00 19:30 1.50 0 0 INTRM1 CASING BOPE P R/U and Mark and space out for test jt f/ upper rams, fill stack 19:30 20:30 1.00 0 0 INTRM1 CASING BOPE P Test Upper rams and annular t/ 250/3500 psi. R/D test equipment. 20:30 21:00 0.50 0 0 INTRM1 CASING OTHR P Make dummy run of 7 5/8" casing hanger Page 9 of 42 Time Logs Date From To - Dur S. De th E. De th Phase Code Subcode T = Comment 21:00 00:00 3.00 0 0 INTRM1 CASING RURD P R/U t/ run casing, change saver sub t/ 4.5 IF, R/u tesco casing running tool, hang service loop in derrick. 3/29/2014 R/U Casing running equipment, M/U shoe track & float equipment, RIH w/ 39# L-80 Hydril 563 t/ 648' change out grapples, RIH w/ 29.7 # Hydril 563 t/ 2561', CBU stage pumps t/ 6 bpm 180 psi, RIH t/ 4200', CBU stage pumps t/ 6 bpm 280 psi, RIH t/ 4900' take weight packing off, Establish circ wash in the hole 3-6 bpm 330 -480 psi t/ 6183', M/U hanger and landing jt, Land on hanger @ 6214', Circ and cond f/ cement job stage pumps t/ 6 bpm 380 psi, R/D tesco casing running tool, R/U cement head and circ equip. Circ and Cond 6 bpm 580 psi. 00:00 00:30 0.50 0 0 INTRM1 CASING SFTY P I PJSM with TESCO 00:30 01:30 1.00 0 0 INTRM1 CASING PULD P R/U TESCO Casing Running Tool land pipe handling equipment. 01:30 02:30 1.00 0 89 INTRM1 CASING RNCS P M/U shoe track, BAKER LOC shoe, float and 1 - 3 joints of 39# L-80 Hydril 563 casing. Install bow spring cents. on 1 - 3 JTS of casing. 02:30 03:30 1.00 89 648 INTRM1 CASING RNCS P P/U JTS. 4 - 15, 39# L-80 Hydril 563 casing with HYDROFORM Cents. Fill casing every JT, 28 STKS, 2 BBLS. 03:30 04:00 0.50 648 648 INTRM1 CASING RURD P Change 39# grapples to 29.7# grapples on TESCO running tool. 04:00 08:30 4.50 648 2,561 INTRM1 CASING RNCS P Run 29.7# L-80 Hydril 563 casing f/ 691't/ 2093'. Change out JT #50 - 42.91' with new JT - 42,92'. Continue running casing t/ 2561'. M/U TQ 10,300 FT LBS. 08:30 09:00 0.50 2,561 2,561 INTRM1 CASING CIRC P Circulate 1 B/U at 2561', pump 84 STKS, 178 PSI. 09:00 12:00 3.00 2,561 4,161 INTRM1 CASING RNCS P RIH w/ 29.7# Hydril 563 casing f/2561' t/ 4161', circulating every 10 jts 12:00 12:30 0.50 4,161 4,200 INTRM1 CASING RNCS P RIH w/ Hydril 563 29.7# Casing f/ 4161't/ 4200' PUW - 130 SOW - 105 12:30 13:30 1.00 4,200 4,200 INTRM1 CASING CIRC P CBU stage pumps t/ 93 spm 280 psi 13:30 16:30 3.00 4,200 4,900 INTRM1 CASING RNCS P RIH w/ Hydril 563 29.7# Casing f/ 4200't/ 4900', Observe packing off and take weight. 16:30 19:30 3.00 4,900 6,183 INTRM1 CASING RNCS P RIH w/ Hydril 563 29.7# Casing f/ 4900't/ 6183'w/ pumps 45-93 spm 330-480 psi stage pumps up slow, M/U tq 10,300 19:30 20:00 0.50 6,183 6,214 INTRMI CASING RNCS P M/U Hanger and Landing Jt land on casing on hanger @ 6214' 20:00 22:00 2.00 6,214 6,214 INTRM1 CASING CIRC P Circulate and condition f/ cement job stage pumps t/ 6 bpm 580 psi PUW - 205k SOW - 125k Reciprocate pipe 22:00 23:30 1.50 6,214 6,214 INTRM1 CEMEN- RURD P R/D Casing running equipment, install long bails and elevators, R/U cement head and circ equipment.. 23:30 00:00 0.50 6,214 6,214 INTRMI CEMEN-CIRC P Circ and condition mud f/ cement job stage pumps t/ 6 bpm 580 psi PUW- 205k SOW - 125k Page 10 of 42 I Time Logs W 3W Date From To Dur S. Depth E. Deipth Phase Code Subcode T Comment 3/30/2014 24 hr Summary PJSM, Cement as per SLB, Displace cement w/ rig pumps bump plug, check floats good, R/D cement equipment, clear floor, Set 10 3/4"x 7 5/8" Pack off & test, Change top rams, R/U and test BOPE AOGCC Inspector John Crisp Witnessed test. 00:00 00:30 0.50 6,214 6,214 INTRMI CEMEN-SFTY P PJSM with Nabors' crew and Schlumberger cement crew. 00:30 01:00 0.50 6,214 6,214 INTRM1 CEMEN' PRTS P Pressure test cement lines, 250 PSI low and 3500 PSI high. 01:00 03:00 2.00 6,214 6,214 INTRM1 CEMEN-PUCM P Circulate ement/Displace; batchL6 96 BBLS of 15,8 PPG CMT. and 4 BBL§ 11..5 PPG mud. Pump 40PPG_mud_ 5 BPM - 400 PSI. PUW - 215K, SOW - 125K, drop bottom plug and verify. Pump 85 BBLS 15.8 PPG, CMT. at 5 BPM - 250 PSI. Drop top plug and verify. Pump 10 BBLS t of H2O at 5 BPM. Change over to rig pump displacement 168 BBLS at 7 BPM - 310 PSI, 5 BPM - 540 PSI, slow to 2 BPM FCP 900 psi bump plyg�at 910 PSI 3,781 STKS. Hold 1600 PSI for 5 min. and bleed PSI off. Check floats, floats held, UP 03:01. 03:00 05:30 2.50 6,214 0 INTRM1 CEMEN' RURD P R/D cementing equipment and casing tools, clear floor, UD long bails,P/U short bails. 05:30 08:00 2.50 0 INTRM1 CEMEN- WWSP P Set 10 3/4" x 7 5/8" PACK-OFFper FMC, RILDS & test to 5000 PSI for 15 min.. 08:00 12:00 4.00 0 0 INTRM1 CEMEN- FRZP P PJSM with LRS for freeze protect. Test lines to 4000 PSI, perform injectivity test. Pump 88 BBLS sea water, ICP 250 PSI, FCP 500 PSI, pump 104 BBLS diesel 650 PSI, FCP 700 PSI. 12:00 12:30 0.50 0 0 INTRM1 CEMEN SFTY P PJSM for changing rams. 12:30 14:30 2.00 0 0 INTRM1 CEMEN- BOPE P Changing 7 5/8" casing rams with 3 1/2" X 6" VBR'S. 14:30 16:30 2.00 0 0 INTRM1 WHDBO RURD P R/U t/ test BOP's grease choke manifold, fill lines w/ water, flush mud line w/ water, call AOGCC inspector f/ witness. 16:30 00:00 7.50 0 0 INTRM1 WHDBO BOPE P Test GOP's w/ 3.5", 4",4.5" test jts choke valves 1-16, HCR & Man choke and kill, 2" demco, Auto & Man IBOP, TIW & DART, Top Bottom and blind rams, Annular t/ 250/3500 psi, test gas alarms and PVT sensors, AOGCC Inspector John Crisp Witnessed test. 3/31 /2014 Test BOP's w/ 4.5" test jt 250 low 3500 high top bottom rams and annular, R/D test equipment, Thaw kelly hose, remove from derrick, reinstall, P/U & M/U BHA load sources, continue P/U BHA, flex collars jars HWDP, RIH f/ shed w/ 4" DP t/ 1003', slip and cut drilling line 71' Page 11 of 42 I Time Logs W 3W Date From To Dur S. De th E. De th Phase Code Subcode T <Comment 00:00 01:30 1.50 0 0 INTRMI WHDBO BOPE P PJSM, test BOP'S, upper rams, , outer test valve, manual IBOP, inner valve, bottom rams, and annular preventer. Attempt t/ Blow down TD, choke manifold, choke and kill lines. 01:30 02:00 0.50 0 0 INTRM1 WHDBO MPSP P Pull and L/D test plug and test JT. Install wear bushing, 6 7/8" X 10 3/4". 02:00 02:30 0.50 0 0 INTRM1 CEMEN' SVRG P Service top drive, grease blocks and wash pipe. 02:30 12:00 9.50 0 0 INTRM1 CEMEN OTHR T Frozen Kelly hose and standpipe after BOP test. 12:00 13:00 1.00 0 0 INTRMI CEMEN- PULD P Blow down choke manifold and kill line, prepare rig to P/U BHA. 13:00 13:30 0.50 0 0 INTRM1 CEMEN-SVRG P Service rig, grease tongs, Drawworks, and inspect slips and dog collar. 13:30 14:00 0.50 0 0 INTRM1 CEMEN-SFTY P PJSM, P/U 6 1/2" BHA. 14:00 18:00 4.00 0 148 INTRM1 CEMEN- PULD P P/U BHA, make up flex collars and stand back in the derrick. 18:00 19:00 1.00 148 148 INTRM1 CEMEN PULD P PJSM with Schlumberger for loading source. P/U BHA and load Source. 19:00 20:00 1.00 148 526 INTRM1 CEMEN- PULD P M/U BHA flex collars, Jars and HWDP. PUW- 45k SOW - 45k 20:00 22:00 2.00 526 1,003 INTRM1 CEMEN-TRIP P RIH f/ 526'w/ 4" DP f/ shed t./ 1003' 22:00 00:00 2.00 1,003 1,003 INTRM1 CEMEN' SLPC P Slip and cut drill line, 11 wraps 71' Service block and top drive. 04/01/2014 RIH w/ 6-1/2" BHA on 4" DP f/ 1 000't/ 6124'. Shallow pulse test MWD tools. Good. Pressure test 7-5/8" Casing t/ 3000 psi. Good. Control drill 7-5/8" shoe track. Drill 20' new formation. Perform FIT. 16 EMW. 00:00 01:30 1.50 1,003 1,479 INTRMI CEMEN" PULD P I PU 4" DP f/ pipe shed. RIH f/ 1000't/ 1479' MD. 01:30 02:00 0.50 1,479 1,479 INTRM1 CEMEN' DHEQ P Shallow hole test MWD tools, pumping @ 100 gpm & staging to 250 gpm. Tools test good. 02:00 05:00 3.00 1,479 3,853 INTRM1 CEMEN- PULD P PU 4" DP f/ pipe shed. RIH f/ 1479't/ 13853'MD. 05:00 06:30 1.50 3,853 5,950 INTRM1 CEMEN-TRIP P TIH on 4" DP f/ 3853't/ 5950' MD 06:30 07:30 1.00 5,950 5,950 INTRM1 CEMEN' CIRC P Circulate and condition mud. 10.2 ppg in and out. 07:30 11:30 4.00 5,950 5,590 INTRM1 CEMEN- PRTS P Rig up to pressure test 7-5/8" casing @ 5938' MD. Pressure test t/ 3000 psi for 15 min, fail - replace sensator. Retest t/ 3000 psi for 17 min, fail - replace sensator. Retest t/ 3000 psi for 15 min, fail - change test lines. Retest t/ 3000 psi for 30 min. Good test. 11:30 12:00 0.50 5,590 6,119 INTRMI CEMEN- TRIPP TIH & tag cement @ 6119' MD. Page 12 of 42 Time Logs WW 'qW Date From To Dur ' S. De th E. De th Phase Code Subcode T Comment 12:00 21:30 9.50 6,119 6,244 INTRM1 CEMEN- DRLG P drill 7-5/8" shoe track, rat hole, 20' new hole to 6,244' WOB 10k 250gpm 2138 psi 53rpm 7300 ft/lbs torque 21:30 22:30 1.00 6,244 6,244 INTRM1 CEMEN CIRC P Circulate and condition hole to 10ppg MW in and out. 250gpm 30rpm 6,900 ft/lbs torque 22:30 22:45 0.25 6,244 6,244 INTRM1 CEMEN OWFF P Flow check well -Good 22:45 23:30 0.75 6,244 6,244 INTRM1 CEMEN- FIT P Pull up into the shoe at 6,214' Blow down the top drive/kelly hose Purge kill/cement hose lines. Rig up to perform FIT/LOT Close upper pipe rams. 23:30 00:00 0.50 6,244 6,244 INTRM1 CEMEN" FIT P Pump at 5.bbl/min down string and kill line. Pressure up to 1580psi with 10ppg mud. No signs of formation break down. Hold for 10minutes lost 100psi to 1,480psi. Open Hole 6,2440'MD 5,025'TVD EMW 16ppg @1,580psi 4/02/2014 Finished LOT. Swapped hole over to 11.2ppg KLASHIELD. Having trouble keeping mud on screens. Adjust screen sizes. Drill ahead from 6,244' to 6,745'. Flow check. Weight up to 11.4 ppg. Drill from 6,745' to 6,808' 00:00 00:30 0.50 6,244 6,244 INTRM1 CEMEN"LOT P Continue with LOT. Bleed pressure off and recover 1.7bbls back of fluid Pumped 1.75bbls of fluid 00:30 01:00 0.50 6,244 6,244 INTRM1 CEMEN- LOT P Open pipe rams. Blow down choke and kill lines. Break off cement line and blow down same. Monitor well -Good 01:00 02:30 1.50 6,244 6,244 PROD1 DRILL CIRC P PJSM on displacing well over to 11.2ppg Klashield. Pump 30bbls 10ppg hi -vis spacer. Follow with 260bbls of 11.2ppg Offload remainder of 10ppg onto vac trucks. Displace at 250gpm 2380psi 02:30 04:30 2.00 6,244 6,244 PROM DRILL CIRC T Attempt to drill ahead and mud running over the shakers and blinding off at 100gpm. Screen up and clean off shaker screens. Stage pumps up to 250gpm to be able to drill. Take on more fluid to the pits ie f 4� Time Logs W= 1qW Date From To Dur S. De th E. De th'Phase Code Subcode T Comment 04:30 05:00 0.50 6,244 6,256 PROD1 DRILL DRLG P Drill ahead from 6,244' to 6,256' 250gpm 2330psi 50rpm 4500 ft/lbs tq MW 11.2 in/out 05:00 11:30 6.50 6,256 6,256 PROD1 DRILL CIRC T New mud back at surface and blinded off 105's size shaker screens. Clean off screens and change 2 shakers to 84's. Circulate and condition mud as per mud enginner, rotate and reciprocate drill string. Screen back up to 230's and screen out Soltex product that was blinding the screens off. 11:30 20:00 8.50 6,256 6,745 PROD1 DRILL DRLG P Drill ahead f/ 6,256't/ 6,745' MD. Parameters: 250 GPM 120 RPM TQ- 7-9kftlb. PU 130, SO 92, ROT 108,10-20k WOB. 20:00 22:30 2.50 6,745 6,745 PROD1 DRILL OWFF P Observed 1000 gas units at connection. Flow check well - slight ooze. Weight up mud to 11.4 ppg. Flow check well. Good. Take SPR with new mud: Pump 1: 2 bpm-440psi 3bpm-750psi Pump 2: 2 bpm-440psi 3bpm-740psi Max B/U gas 1,920units after initial flow check before 11.4ppg around 22:30 00:00 1.50 6,745 6,808 PROD1 DRILL DRLG P Drill ahead f/ 6,745't/ 6,808' MD. Backream 30' per stand. Parameters: 250 GPM 2,550psi 120 RPM TQ- 7-9kftlb. PU 130, SO 92, ROT 108, 10-15k WOB. 4/03/2014 Drilled ahead from 6,808' to 6,966'. Flow check well. Weight up to 11.6 ppg. Make correlation pass from 6,866' to 6,807'. Make first attempt at Stethoscope data retrieval. Fail. Attempt Stethoscope again. Data inconclusive. Drill f/ 6,966't/ 7,140' MD. Weight up to 11.8 ppg. Attempt Stethoscope again. Unable to get reliable data. Flow check well for 1 hr. Well flowing at — Abbl/hr. Weight up to 11.9ppg. Flow check well. Good. Drill ahead f/ 7,140 t/ 7,257' MD as per new directional plan. 00:00 02:45 2.75 6,808 6,966 PROD1 DRILL DDRL P Drill ahead from 6,608' to 6,966' 250 GPM, 120 RPM, TO 8.2kftlb, PU 125, SO 95, ROT 105. Stop drilling at 6,996' for Stethascope deployment. 02:45 03:00 0.25 6,966 6,966 PROD1 DRILL OWFF P Check well for flow. Slight ooze. 03:00 04:00 1.00 6,966 6,966 PROD1 DRILL CIRC P Circulate bottoms up weight system up to 11.6ppg Gas units at B/U 3,318 units. Time Logs Date From To Dur ` S. De th E.'De th Phase Code Subcode T Comment 04:00 07:30 3.50 6,966 6,966 PROD1 DRILL PLT P Log hole from 6,866' to 6,807'. Identify test zone at 6,810'. Postition bit depth at 6,896.7' Places tool at 6,810.46'. Go through pump cycling process to deploy Stethoscope tool. Retrieve data. Inconclusive. Attempt pressure sample retrieval again. Unable to get accurate sample. 07:30 10:30 3.00 6,966 7,140 PROD1 DRILL DDRL P Directional drill f/ 6,966't/ 7,140' MD. Parameters: 250 GPM, 117 RPM, TQ 8.5kftlb, PU 125, SO 95, ROT 105. 10:30 11:00 0.50 7,140 7,140 PROD1 DRILL OWFF P Flow check well. Slight flow. 11:00 12:00 1.00 7,140 7,140 PROD1 DRILL CIRC P Circulate and weight up mud system to 11.8 ppg. 12:00 14:30 2.50 7,140 7,140 PROD1 DRILL PLT P MAD Pass f/ 7065' t/7050' to find log point. Attempt to obtain pressure test from Stethoscope tool @ 7,051' MD. Unable to get complete test - tool unable to hold seal against formation to obtain complete data. Attempt pressure test again. Inconclusive. 14:30 16:00 1.50 7,140 7,140 PROD1 DRILL OWFF P Observe well for flow for 1 hr to determine if well is underbalanced. Well flowing back slightly. Flow back Irate — Abbl/h r. 16:00 17:00 1.00 7,140 7,140 PROD1 DRILL CIRC P Circulate bottoms up to see gas units gained during flow check. BU strokes: 3040 (212bbl). Started to see gas at surface at 1500stks, 111 bbl early. Max gas units seen: 2600. 17:00 18:30 1.50 7,140 7,140 PROD1 DRILL CIRC P Consult with town to determine plan forward. Weight up mud system to 11.9 ppg. 18:30 19:30 1.00 7,140 7,140 PROD1 DRILL OWFF P Observe well for flow. Static. Obtain SPR with 11.9ppg mud: Pump 1: 530 psi @ 2bpm, 850 psi @ 3 bpm Pump 2: 530 psi @ 2bpm, 850 psi @ 3 bpm. 19:30 00:00 4.50 7,140 7,257 PROD1 DRILL DDRL P Directional drill f/ 7,140't/ 7,257' MD. Control drilling, 50'/hr or less, Max ECD 13.0 ppg EMW seen. Check for flow at each connection. Parameters: 220 GPM, 120 RPM, TQ 6-8kftlb, PU 125, SO 95, ROT 110. 4/04/2014 Drill ahead from 7,257' to 7,667'. Perform Stethoscope test. Drill ahead from 7,667' to 8,006'. Total footage 749' Page 15 ~f Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 7,257 7,476 PROD1 DRILL DDRL P Directionally Drill from 7,257' to 7,476' Footage 219' Control drill at 50ft/hr to maintain ECD WOB:5-10k Rot. 120rpm Tq on 8000ft/lbs Tq off 6,840ft/lbs Pump rate:220gpm Pressure on:2,240psi Pressure off:2,192psi Up wt: 125k Dn wt:95k Rot wt: 102k MW: 11.9ppg Max ECD:13ppg EMW Max Gas:1208units Avg Background Gas:315units 06:00 11:00 5.00 7,476 7,667 PROD1 DRILL DDRL P Directionally Drill from 7,476' to 7,667' Footage 191' Control drill at 50ft/hr to maintain ECD WOB:2-6k Rot. 119rpm Tq on 7,831ft/lbs Tq off 6,840ft/lbs Pump rate:219gpm Pressure on:2,254psi Pressure off:2,239psi Up wt: 125k Dn wt:95k Rot wt: 102k MW: 11.9ppg Max ECD: 12.96 ppg EMW Max Gas:1,394units Avg Background Gas:202units 11:00 12:00 1.00 7,667 7,667 PROD1 DRILL CIRC P Circulate and condition hole for Stethoscope pressure sample. 1 Bottoms Rot. 119rpm Tq 6,840ft/lbs Pump rate:219gpm Pressure 2,254psi Rot wt: 102k MW: 11.9ppg Max ECD-.12.98 ppg EMW Max Gas: 966 units Avg Background Gas: 304units 12:00 14:30 2.50 7,667 7,667 PROD1 DRILL PLT P MAD pass log from 7,667' to 7,563' Position Bit depth at 7,586', probe depth at 7,500'MD 5,223' TVD Conduct Stethoscope test. Readings indicate a formation pressure of 3,270psi. .m Page 16 of 42 Time Logs Date From To Dur S. De th E. De th Phase. Code Subcode T Comment 14:30 18:00 3.50 7,667 7,788 PROD1 DRILL DDRL P Directionally Drill from 7,667' to 7,788' Footage 121' Control drill at 50ft/hr to maintain ECD WOB:2-6k Rot. 119rpm Tq on 7,831ft/lbs Tq off 6,840ft/lbs Pump rate:217gpm Pressure on:2,230psi Pressure off:2,221psi Up wt: 125k Dn wt -.95k Rot wt: 102k MW: 11.9ppg Max ECD:13.01 ppg EMW Max Gas: 960 units Avg Background Gas: 265 units 18:00 00:00 6.00 7,788 8,006 PROD1 DRILL DDRL P Directionally Drill from 7,788' to 8,006' Footage 218' Control drill at 50ft/hr to maintain ECD WOB:2-6k Rot. 119rpm Tq on 8,034ft/lbs Tq off 6,840ft/lbs Pump rate:222gpm Pressure on:2,331psi Pressure off:2,305psi Up wt: 125k Dn wt:95k Rot wt: 102k MW: 11.9ppg Max ECD:13.04 ppg EMW Max Gas: 880 units Avg Background Gas: 580 units 4/05/2014 Drill ahead from 8,006' to 8,181'. Perform Stethoscope test at 8,030'MD, 5223'TVD indicate pressure of 3,259psi . Drill ahead from 8,181' to 8,700'. Total footage 694'. 00:00 06:00 6.00 8,006 8,181 PROD1 DRILL DDRL P Directionally Drill from 8,006' to 8,181' Footage 175' Control drill at 50ft/hr to maintain ECD WOB:2-6k Rot. 121 rpm Tq on 8,044ft/lbs Tq off 6,630ft/lbs Pump rate:219gpm Pressure on:2,331psi Pressure off:2,305psi Up wt:110k Dn wt:90k Rot wt: 101 k MW: 11.9ppg Max ECD: 13.1 ppg EMW Max Gas: 1,267 units Avg Background Gas: 580 units Current formation dip 89.6° : Pogo 47 � Time Logs WO W Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:00 07:00 1.00 8,181 8,181 PROD1 DRILL CIRC P Circulate and condition hole for Stethoscope pressure sample. 1 Bottoms Rot. 124rpm Tq 7,124ft/lbs Pump rate:219gpm up stroke 185gpm down stroke Pressure 2,254psi up 1,670psi down Rot wt: 102k MW: 11.9ppg Max ECD:13 ppg EMW Max Gas: 474 units Avg Background Gas: 304units 07:00 07:30 0.50 8,181 8,181 PROD1 DRILL DLOG P Position Bit depth at 8,116', probe depth at 8,030'MD 5,223' TVD Conduct Stethoscope test. Readings indicate a formation pressure of 3,259psi. 07:30 12:00 4.50 8,181 8,270 PROD1 DRILL DDRL P Directionally Drill from 8,181'to 8,270' Footage 89' Control drill at 50ft/hr to maintain ECD WOB:2-6k Rot. 121 rpm Tq on 7,923ft/lbs Tq off 6,882ft/lbs Pump rate:219gpm Pressure on:2,312psi Pressure off:2,305psi Up wt: 110k Dn wt:90k Rot wt:101 k MW: 11.9ppg Max ECD:13.03 ppg EMW Max Gas: 1,061 units Avg Background Gas: 274 units Current formation dip 89.6° 12:00 18:00 6.00 8,270 8,470 PROD1 DRILL DDRL P Directionally Drill from 8,270' to 8,470' Footage 200' Control drill at 50ft/hr to maintain ECD WOB:2-8k Rot. 121 rpm Tq on 8,133ft/lbs Tq off 7,220ft/lbs Pump rate:220gpm Pressure on:2,367psi Pressure off:2,359psi Up wt:110k Dn wt:90k Rot wt: 101 k MW: 11.9ppg Max ECD: 13.08 ppg EMW Max Gas: 554 units Avg Background Gas: 120 units Current formation dip 89.6° 'f8 of 42 Time Logs WE Date From To Dur S. De th E. De thPhase Code Subcode T <Comment 18:00 00:00 6.00 8,470 8,700 PROD1 DRILL DDRL P Directionally Drill from 8,470' to 8,700' Footage 230' Control drill at 50ft/hr to maintain ECD WOB:2-6k Rot. 121 rpm Tq on 8,044ft/lbs Tq off 7,302ft/lbs Pump rate:221gpm Pressure on:2,345psi Pressure off:2,332psi Up wt:110k Dn wt:90k Rot wt: 101 k MW: 11.9ppg Max ECD: 13.04 ppg EMW Max Gas: 373 units Avg Background Gas: 60 units Current formation dip 89.7° 4/06/2014 Drill ahead from 8,700' to 8,972'. Circulate and condition hole at 8,972' due to high ECD's. Continue drilling from 8,972' to 9,254' and pump 150bbl dilution. 00:00 06:00 6.00 8,700 8,850 PROD1 DRILL DDRL P Directionally Drill from 8,700' to 8,850' Footage 150' Control drill at 50ft/hr to maintain ECD WOB:2-6k Rot. 121 rpm Tq on 8,044ft/lbs Tq off 7,302ft/lbs Pump rate:221gpm Pressure on:2,345psi Pressure off:2,332psi Up wt: 110k Dn wt:90k Rot wt:101 k MW: 11.9ppg Max ECD:13.03 ppg EMW Max Gas: 586 units Avg Background Gas: 128 units Current formation dip 89.7° Page 19 of 42 Time Logs Date From To Dur S. De th E. De th' Phase Code Subcode T Comment 06:00 11:30 5.50 8,850 8,972 PROD1 DRILL DDRL P Directionally Drill from 8,850' to 8,972' Footage 122' Control drill at 50ft/hr to maintain ECD WOB: 4-9k Rot. 122rpm Tq on 8,507ft/lbs Tq off 7,696ft/lbs Pump rate:200gpm Pressure on:2,033psi Pressure off:2,052psi Up wt: 120k Dn wt:80k Rot wt: 100k MW: 11.9ppg Max ECD:13.12 ppg EMW Max Gas: 265 units Avg Background Gas: 50 units Current formation dip 89.7° 11:30 13:00 1.50 8,972 8,972 PROD1 DRILL CIRC P ECD started to rise above 13.2 while reciprocating pipe and down linking. Increase in ECD due to in crease in WOB while drilling down last 30' of last stand, increased cuttings load in hole. Lower flow rate f/ 200 to 190 gpm, resume adding water to active. Circulate 2 BU's. Slowly raise flow rate to 200 and increase flow rate to 210gpm ECD down to 13.1 ppg EMW 13:00 21:00 8.00 8,972 9,155 PROD1 DRILL DDRL P Directionally Drill from 8,972'to 9,155' Footage 183' Control drill at 50ft/hr to maintain ECD WOB: 4-9k Rot. 122rpm Tq on 8,507ft/lbs Tq off 7,696ft/Ibs Pump rate:218gpm Pressure on:2,442psi Pressure off:2,350psi Up wt: 120k Dn wt:80k Rot wt: 100k MW: 11.9ppg Max ECD-. 13.12 ppg EMW Max Gas: 265 units Avg Background Gas: 50 units Current formation dip 89.7° __ ...wM. Page 20 of 42 Time Logs W 30M Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 00:00 3.00 9,155 9,254 PROD1 DRILL DDRL P Directionally Drill from 9,155'to 9,254' Footage 99' Control drill at 50ft/hr to maintain ECD WOB: 4-6k Rot. 122rpm Tq on 8,307ft/lbs Tq off 6,289ft/lbs Pump rate:220gpm Pressure on:2,333psi Pressure off:2,302psi Up wt: 120k Dn wt:80k Rot wt: 100k MW: 11.9ppg Max ECD:12.8 ppg EMW Max Gas: 332 units Avg Background Gas: 57 units Current formation dip 89.7° *Pump 150bbls dillution @21:OOhrs* 4/07/2014 Drill ahead from 9,254' to 9,515' TD of 6 1/2" hole section. Circulate and condtion hole with Hi -vis sweep and 4 bottoms up, weight system up to 12.1 ppg from 11.9ppg. Flow check. Weight system up to 12.2ppg. Flow check. Weight system up to 12.3p g. 00:00 06:00 6.00 9,254 9,400 PROD1 DRILL DDRL P Directionally Drill from 9,254' to 9,400' Footage 146' Control drill at 50ft/hr to maintain ECD WOB: 4-6k Rot. 122rpm Tq on 8,307ft/lbs Tq off 6,289ft/lbs Pump rate:220gpm Pressure on:2,410psi Pressure off:2,380psi Up wt:120k Dn wt:80k Rot wt: 100k MW: 11.9ppg Max ECD:12.99 ppg EMW Max Gas: 960 units Avg Background Gas: 57 units Current formation dip 89.7° __Page 21 of 42 Time Logs Date From To Dur S.'De th E.'De `th Phase Code Subcode T Comment 06:00 10:00 4.00 9,400 9,515 PROD1 DRILL DDRL P Directionally Drill from 9,400' to 9,515' TD Footage 115' Control drill at 50ft/hr to maintain ECD WOB: 4-6k Rot. 122rpm Tq on 8,307ft/Ibs Tq off 6,289ft/lbs Pump rate:220gpm Pressure on:2,410psi Pressure off:2,380psi Up wt: 120k Dn wt:80k Rot wt: 100k MW: 11.9ppg Max ECD: 12.99 ppg EMW Max Gas: 960 units Avg Background Gas: 57 units Current formation dip 89.7° 10:00 16:45 6.75 9,515 9,515 PROD1 CASING CIRC P Pump Hi -vis sweep around. Circulate x4 bottoms up to clean wellbore. Large amount of cuttings coming over shakers when sweep returned. Weight system up to 12.1 ppg from 11.9ppg Rot. 120rpm Tq 5,382ft/lbs Pump rate:220gpm up stroke 200gpm down stroke Pressure 2,486psi up 2,116psi down Rot wt: 100k MW: 12.1 ppg Max ECD: 13.2 ppg EMW Max Gas: 92 units Avg Background Gas: 23 units 16:45 17:45 1.00 9,515 9,515 PROD1 CASING OWFF P Check well for flow. Fluid leve rising in stack at rate of .2bbls/hr 17:45 22:15 4.50 9,515 9,515 PROD1 CASING CIRC P Weight system up to 12.1 ppg from 12.2ppg Pump 200bbl mud dilution Rot. 60rpm Tq 4,691ft/lbs Pump rate: 185 gpm Pressure 1,811 psi Rot wt: 100k MW: 12.2ppg Max ECD:13.2 ppg EMW Max Gas: 827 units Avg Background Gas: 12 units 22:15 22:45 0.50 9,515 9,515 PROD1 CASING OWFF P Check well for flow. Fluid leve rising in stack at rate of .2bbls/hr Page 22 of 42 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 22:45 00:00 1.25 9,515 PROD1 CASING CIRC P Weight system up to 12.2ppg from 12.3ppg Rot. 30rpm Tq 4,691ft/Ibs Pump rate: 185 gpm Pressure 1,811 psi Rot wt: 100k MW: 12.2ppg Max ECD: 13.1 ppg EMW Max Gas: 515 units Avg Background Gas: 8 units 4/08/2014 Continue to weight system up to 12.3. Flow check well. Continue to pump and check for gas at bottoms up. Lost partial circulation. Pump 4 LCM pills and regain full circulation. Stage pumps up monitoring for losses. Conduct well breathing test. Confirm well breathing. Circulate hole watching for gas units. Total losses 291 bbls. 00:00 01:15 1.25 9,515 9,515 PROD1 CASING CIRC P Continue to weight system up to 12.2ppg from 12.3ppg Rot. 30rpm Tq 4,691ft/lbs Pump rate: 185 gpm Pressure 1,811 psi Rot wt: 100k MW: 12.2ppg Max ECD:13.1 ppg EMW Max Gas: 515 units Avg Background Gas: 8 units Pump total 6,977stks 12.3ppg in 12.3ppg out Stage pumps down 150gpm 1,100psi 100gpm 576psi No lossses 01:15 02:00 0.75 9,515 9,515 PROD1 CASING OWFF P Observe well for flow. Flowback 3.5 bbls in 30min. 02:00 03:15 1.25 9,515 9,515 PROD1 CASING CIRC P Circulate and condition hole. Check for B/U gas Rot. 30rpm Tq 4,691ft/Ibs Pump rate: 150 gpm Pressure 1,151psi Rot wt: 100k MW: 12.3ppg Max ECD:Tool will not read at low rate Max Gas: 403 units Avg Background Gas: 8 units Pump total 3,849 stks 12.3ppg in 12.3ppg out Begin taking losses. Initial loss of 10bbls in 10minutes. Time Logs WM Date From To Dur - S. De th E. De th'Phase Code ,- Subcode T 'Comment 03:15 04:00 0.75 9,515 9,515 PROM CASING OWFF T Shut down pump and observe well. Static fluid level. Check all surface lines and equipment.-Good Notify appropriate parties. 04:00 15:30 11.50 9,515 9,515 PROM CASING CIRC T Engage pump at lbbl/min, 207psi. Hole taking 50% losses. Mix#1 LCM pill 35lb/bbl G/seal, Dyna Red, Safe Carb 250 & 40 Pump 44bbls of pill and displace to out of bit. Allow to sit for 20minutes and resume circulation at lbbl/min. Not effective. Pump #2 LCM pill 40bbls. Pump out of bit 1 bbl/min 207psi and pump until 1 for 1 returns same time entire pill out of bit. Shut down and allow to soak. Resume circulation at lbbl/min and begin to observe 50% losses again. Pump #3 LCM pill 44bbls. Pump down to bit at 1 bbl/min 210psi. When pill leaving bit increase rate to 2bbl/min 551 psi. Notice a decrease in losses while circulating from 50% to 40%. Decrease pump rate to lbbl/min 273psi, losses down to 20% then gradually increase to 40%. Pump #4 LCM pill 42bbls. Pump down to bit at 1 bbl/min 294psi. When pill leaving bit increase rate to 2bbl/min 571 psi. Notice a decrease in losses while circulating from 50% to 25%. Slow pump rate to lbbl/min 336psi no losses. Reduce mud weight to 12.1 ppg Total losses 291 bbls 15:30 22:00 6.50 9,515 9,515 PROM CASING CIRC T Circulate and stage pumps up: lbbl/min 332psi 896 stks 2bbl/min 552psi 2,728stls 2.5bbl/min 691 psi 1236stks 3bbl/min 882psi 3993stks 3.5bbl/min 1,134psi 1,776psi 4bbl/min 1,432psi 2,021stks 4.5bbl/min 1,752psi 4,473stks ECD at bit reading 12.88 max 12.86 Low Take SPR #1 Pump 3bbl/min 840psi 2bbl/min 520psi #2 Pump 3bbl/min 864psi 2bbl/min 510psi Time Logs WW Date From To Dur = S. De th E.'De th Phase CodeSubcode T Comment 22:00 23:00 1.00 9,515 9,515 PROD1 CASING OWFF T Conduct Well Breathing test. Total of 36bbls returned in 1 hr period. Time returns to trip tank. Initial return rate of 30bbl per hr. diminish to 15bbls per hour after 14 minutes and maintain during remainder of 38minute test. Total returns to the trip tank 16bbls. Total returns to pit active system 20bbls. 23:00 00:00 1.00 9,515 9,515 PROD1 CASING CIRC T Begin to circulate well at low rate to check for gas. Circulated total of 1,227strokes at end of report time. Rot. 20rpm Tq 4,050ft/lbs Pump rate: 84 gpm Pressure 496 psi Rot wt: 100k MW: 12.05 ppg Max ECD:Not enough flow for tool Max Gas: 86 units Avg Background Gas: 8 units 4/09/2014 Continue to circulate & condition the hole monitoring gas units. Peak units at 923. Conduct well bore breathing test. Reduction in flow back from 17bbl/hr to 3.9 bbl/hr. Circulate & condition hole at 2bpm watching for gas units. Conduct well bore breathing test. 3.1 bbl/hr return rate at end of test. Circulate & Condition hole lost 12bbls . Conduct well breathing test 4.7bbl/hr return rate at end of test. Circulate at 2bpm pump LCM pill. Conduct well breathing test. Diminish down to 1.5bbl/hr. Circulate & Condition hole. 00:00 03:00 3.00 9,515 9,515 PROD1 CASING CIRC T Continue to circulate well at low rate to check for gas. Rot. 20rpm Tq 3,855 ft/lbs Pump rate: 85 gpm Pressure 501 psi Rot wt: 100k MW: 12.05 ppg Max ECD:Not enough flow for tool Max Gas: 924 units Gas units stayed above 500units for 1,932stks 135bbls Avg Background Gas: 89 units Pump total of 6,673stks 466bbls lost 2 bbls during circulation 03:00 04:00 1.00 9,515 9,515 PROD1 CASING OWFF T Conduct well breathing test: Initial flow rate: 17bbls/hr final flow rate after 1 hr: 3.9 bbls/hr Rotate pipe every 5 minutes during test. Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Comment 04:00 07:45 3.75 9,515 9,515 PROD1 CASING CIRC T Circulate well at low rate to check for gas units Rot. 20rpm Tq 3,925 ft/lbs Pump rate: 86 gpm Pressure 505 psi Rot wt: 100k MW: 12 ppg Max ECD:Not enough flow for tool Max Gas: 850 units Avg Background Gas: 230 units Pump total of 5,938 stks 415 bbls lost 0 bbls during circulation 07:45 09:30 1.75 9,515 9,515 PROD1 CASING OWFF T Conduct well breathing test: Initial flow rate: 15bbls/hr final flow rate after 1 hr: 3.1 bbls/hr Rotate pipe every 5 minutes during test. 09:30 11:30 2.00 9,515 9,515 PROD1 CASING CIRC T Circulate well to check for gas units Rot. 16 rpm Tq 3,761 ft/lbs Pump rate: 182 gpm Pressure 1,742 psi Rot wt: 102k MW: 12 ppg Max ECD:12.86 Max Gas: 4,649 units Avg Background Gas: 265 units Pump total of 6,150 stks 429 bbls lost 12 bbls during circulation 11:30 13:00 1.50 9,515 9,515 PROD1 CASING OWFF T Conduct well breathing test: Initial flow rate: 47 bbls/hr final flow rate after 46min: 4.7 bbls/hr Rotate pipe every 5 minutes during test. 13:00 17:45 4.75 9,515 9,515 PROD1 CASING CIRC T Circulate well at low rate to check for gas units and pump LCM pill. Pump LCM pill 40lb/bbl, Safe carb 250/40, G-Seal/Dyna Red Rot. 17 rpm Tq 4,100 ft/lbs Pump rate: 82 gpm Pressure 514 psi Rot wt: 102k MW: 12 ppg Max ECD:Flow to low to turn tool on Max Gas: 1,101 units Avg Background Gas: 82 units Pump total of 7,289 stks 509 bbls lost 22 bbls during circulation 17:45 22:15 4.50 9,515 9,515 PROD1 CASING OWFF T Conduct well breathing test: Initial flow rate: 15 bbls/hr final flow rate after 4 hrs: 1.5bbls/hr Rotate pipe every 5 minutes during test. z + f 4" Time Logs Date From To Dur S. De th E. De th Phase ''Code Subcode T Comment 22:15 00:00 1.75 9,515 9,515 PROD1 CASING CIRC T Circulate well at low rate to check for gas units Rot. 20rpm Tq 3,925 ft/lbs Pump rate: 86 gpm Pressure 533 psi Rot wt: 100k Up wt:122k Dn Wt:87k MW: 12 ppg Max ECD: Not enough flow for tool Max Gas: 1,607 units Avg Background Gas: 128 units Pump total of 2,977 stks 415 bbls at end of report time lost 18 bbls during circulation at end of report time 4/10/2014 Circulate hole and monitor gas units, 1,607 max units observed. Pump out of the hole from 9,509' to 7,850. Circulate hole and monitor gas units 1,091 units observed. Continue to pump out of the hole from 7,850' to 6,140' inside the casing shoe. Establish circulation at low rate to minimize losses. Stage up pumps and rotary to clean the hole. 00:00 03:00 3.00 9,515 9,515 PROD1 CASING CIRC P Circulate 2x's Bottoms up Circulate well at low rate to check for gas units Rot. 20rpm Tq 4,000 ft/lbs Pump rate: 86 gpm Pressure 506 psi Rot wt: 100k MW: 12.05 ppg Max ECD:Not enough flow for tool Max Gas: 1,607 units Avg Background Gas: 128 units Pump total of 7,968 stks 556bbis lost 20 bbls during entire circulation 03:00 08:30 5.50 9,515 7,850 PROD1 CASING TRIP P Pump out of the hole from 9,509' to 7,850 Pump rate: 86 gpm Pressure 514 psi Up wt:122k MW: 12.05 ppg Max ECD:Not enough flow for tool Max Gas: 960 units Avg Background Gas: 128 units Pump total of 5,446 stks 380bbls during pumping out of the hole Gas units starting to rise and peak out at 975units .._,�� _ g3 f'�Cegs 2i o 2 Time Logs Date From To Dur S.'De th E. De th`Phase Code Subcode T 'Comment 00:00 05:00 5.00 6,140 6,140 PROD1 CASING CIRC P Continue to circulate inside the casing shoe. Pump 20bbls of 208 fv Hi -vis sweep brought back formation sand and sand stone pieces 30% increase over shakers. Pump #2 208 fv Hi -vis sweep, brought back formation sand and sand stone pieces 15% increase over shakers Rot. 150rpm Tq 3,939 ft/lbs Pump rate: 85 gpm Pressure 505 psi Rot wt:101 k MW: 12.05 ppg Max ECD -.Not enough flow for tool Max Gas: 61 units Avg Background Gas: 60 units Pump total of 15,778 stks 1101 bbls at end of report time No losses to the formation. 05:00 07:45 2.75 6,140 6,140 PROD1 CASING OWFF T Conduct well breathing test: Initial flow rate: 15 bbls/hr final flow rate after 2 hrs: 4.5bbls/hr 17.5 total bbls returned back Consult with town on plan forward 07:45 11:30 3.75 6,140 4,996 PROD1 CASING TRIP P Pump and rotate out of the hole from 6,140' to 4,996' Lay 500' of 283fv pill from 6,140' to 5,640' Pump Pill at 1bbl/min Pull pipe at 15ft/m i n Pump at rotate parameters Pump rate: 86 gpm Pressure 514 psi RPM -.75 Tq:3,061 ft/lbs Rot wt:98k MW: 12.05 ppg Max ECD:Not enough flow for tool Max Gas: 981 units Avg Background Gas: 49 units Pump total of 5,446 stks 380bbls during pumping out of the hole Gas units starting to rise and peak out at 975units P� Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T ' Comment 11:30 19:30 8.00 4,996 4,996 PROD1 CASING CIRC P Stop tripping and circulate due to high gas units. Stage pumps up from 1 bb/min up to 3bbl/min reduce rate back down to 2bbl/min to reduce losses. Weight up system to 12.2ppg Rot. 77rpm Tq 2,650 ft/lbs Pump rate: 84 gpm Pressure 442 psi Rot wt:95k MW: 12.2 ppg Max ECD. -Not enough flow for tool Max Gas: 1,291 units Avg Background Gas: 40 units Pump total of 15,516 stks 1,083bbls at end of report time Losses to the formation from circulating 25bbls. 19:30 22:45 3.25 4,996 4,996 PROD1 CASING OWFF T Conduct well breathing test: Initial flow rate: 24 bbls/hr final flow rate after 3 hrs-. 3 bbls/hr 24.5 total bbls returned back Consult with town on plan forward 22:45 00:00 1.25 4,996 6,141 PROD1 CASING TRIP T Trip in hole from 4,996' to 6,141' Run in hole at 20ft/min Calclulated displacement 18.66bbls Actual displacement 18.65bbls Fill pipe at 6,141' 4/12/2014 Trip in hole to 7,381'. Establish circulation and condition MW in hole to 12.2ppg. Spot 32bbl 12.2ppg LCM pill out of bit and 125bbl 12.4ppg LCM pill at bit. Pump out of the hole from 7,381' to 5,378'. Establish circulation and bring remainder of system up to 12.4ppg. 00:00 03:00 3.00 6,141 7,381 PROD1 CASING TRIP T Trip in hole from 6,141' to 7,381' Hole slick Run in hole at 20ft/min Calclulated displacement 20.2bbls Actual displacement 20.72bbls up 117 do 84 ,,.� — Paqe 31 C) Time Logs Date From To Dur S. De th E. De thPhase Code Subcode T Comment 03:00 15:30 12.50 7,381 7,381 PROD1 CASING CIRC T Establish circulation start at 1bbl/min Weight mud coming out up to 12.2ppg Lowest weight seen 11.7ppg Slowly reciprocate pipe while pumping with no rotation Pump rate: 42 gpm Pressure 340 psi MW: 12.2 ppg Max ECD:Not enough flow for tool Max Gas: 1412 units Avg Background Gas: 93 units Pump total of 9,375 stks 655bbls 96bbls losses to the formation. Spot 32bbl 12.2ppg LCM pill outside of bit. Spot 125bbl 12.4ppg Hi -Vis LCM pill at bit. 15:30 20:00 4.50 7,381 5,378 PROD1 CASING TRIP P Pump out of the hole from 7,138' to 5,378' Pump 125bbls Hi -Vis 12.4ppg LCM 252fv pill laying it from 7,138' to 5,378' Chase with 12.4ppg mud Pump Pill at 1bbl/min Pull pipe at 20ft/min Pump parameters: Pump rate: 42 gpm Pressure 304psi MW: 12.4 ppg Max ECD:Not enough flow for tool Max Gas: 64 units Avg Background Gas: 21 units Pump total of 1,805 stks 125bbls during pumping out of the hole Lost 39bbls while pumping out of the hole. pages � Time Logs Date From To Dur '= S. De th E. De th Phase - Code Subcode T < Comment 20:00 00:00 4.00 7,381 5,378 PROD1 CASING TRIP P Pump out of the hole from 7,138' to 5,378' Pump 125bbls Hi -Vis 12.4ppg LCM 252fv pill laying it from 7,138' to 5,378' Chase with 12.4ppg mud Pump Pill at lbbl/min Pull pipe at 20ft/m i n Pump parameters: Pump rate: 42 gpm Pressure 304psi MW: 12.4 ppg Max ECD:Not enough flow for tool Max Gas: 64 units Avg Background Gas: 21 units Pump total of 1,805 stks 125bbls during pumping out of the hole Lost 39bbls while pumping out of the hole. 4/13/2014 Continue to weight system up to 12.4ppg. Flow check. Slight mud flow on both Drill pipe and hole. Weight system up to 12.6ppg. Flow check well. Slight flow coming up annulus. Weight up system to 12.7ppg. Flow check. Well taking fluid at .6 bbls/hr. Set Baker Retrievamatic and test. Set test plug and start testing sequence. 00:00 01:00 1.00 5,378 5,378 PROD1 CASING CIRC T Circulate at lbb/min Weight remainder of system up to 12.4ppg Reciprocate pipe 5ft/min pumping with no rotation Pump rate: 37 gpm Pressure 340 psi MW: 12.4 ppg Max ECD:Not enough flow for tool Max Gas:36 units Avg Background Gas: 34 units Pump total of 5,357 stks 374 bbls. 51 bbls losses to the formation. 01:00 01:30 0.50 5,378 5,378 PROD1 CASING OWFF T Check well for flow. Well bore static for 15minutes than began to slightly flow. Break off Top Drive and observe mud coming back up string as well. Consult with town. __. Page 33 of 42 Time Logs Date From To Dur - S. De th E."De th Phase Code Subcode T ', Comment 01:30 06:30 5.00 5,378 5,378 PROD1 CASING CIRC T Circulate at 1bb/min Weight system up to 12.6ppg Reciprocate pipe 5 ft/min while pumping. Attempt 30rpm rotation and immediately incur 35% Loss rate Shut down rotation. As 12.6ppg rising up annulus slow pumps to 3/4 bbl/min to reduce losses. Pump rate: 44 gpm Pressure 333 psi MW: 12.6 ppg Max ECD:Not enough flow for tool Max Gas:21 units Avg Background Gas: 19 units Pump total of 3,422 stks 239 bbls. 23 bbls losses to the formation. 06:30 09:00 2.50 5,378 5,378 PROD1 CASING OWFF T Blow down the Top Drive Check well for flow. Static in the string. Flowing back 1 bbl/hr out annulus. 09:00 15:30 6.50 5,378 5,378 PROD1 CASING CIRC T Circulate at 3/4bb/min Weight system up to 12.7ppg Reciprocate pipe 5 ft/min while pumping. As 12.7ppg rising up annulus slow pumps to 1/2 bbl/min to reduce losses. Pump rate: 30 gpm Pressure 279 psi MW: 12.7 ppg Max ECD:Not enough flow for tool Max Gas: 11 units Avg Background Gas: 11 units Pump total of 3,396 stks 237 bbls. 99 bbls lost to the formation. 15:30 19:15 3.75 5,378 6,141 PROD1 CASING TRIP T Trip in hole from 5,378' to 6,141' Traveling speed:5 ft/min Hole took 55bbls on trip in. 19:15 20:30 1.25 6,141 6,141 PROD1 CASING OWFF T Flow check well. Slight flow coming out drill pipe. Floculated aired up mud. Fluid level dropping in annulus 1.3bbll/hr Flow out drill string stopped and remained static. Fluid level in the annulus dropping at .63bbls/hr Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T ` Comment 20:30 23:00 2.50 6,141 6,192 PROD1 CASING MPSP T Make up Baker Model "EX Retrievamatic and set elements at 44'RKB, Top of Packer at 36'RKB. Bit depth 6,192' Up wt:115k Dn wt:95k Serial # ZAK000253 Size:47D2, 7 5/8", 29.7# 60/40/60 Duro Elements Release from Storm Valve with 11 Turns to the Right and lay down. Pressure test Packer to 500psi for 15minutes.-Good 23:00 23:30 0.50 6,192 6,192 PROD1 WHDBO RURD P Make up Wear ring pulling tool. Drain stack back out Lock Down screws and pull Wear Bushing. Verify gland nut packings are tight. 23:30 00:00 0.50 6,192 6,192 PROD1 WHDBO BOPE P Make up and set test plug. Open IA and fill stack with water. Attempt first pressure test and test plug appears to be leaking. Cycle test pump and test plug seats. 4/14/2014 Continue to test BOPE with 3 1/2", 4", 4 1/2" Test joints to 250/3,500psi. Install wear ring. Blow down lines. Engage storm valve/Retrievamatic verify no pressure. Release packer and flow check. Begin circulating bringing mud weight back up to 12.7ppg. Time Logs W 3W Date From To Dur S. De th E. De th Phase Code ' Subcode T Comment 00:00 10:00 10.00 6,192 61192 PROD1 WHDBO BOPE P Test BOPE, States right to witness waived by Lou Grimaldi. TEST # 1 — BLINDS, Choke Valves - 1,2,3 & 16, Kill Demco 250/3,500psi TEST # 2- Choke Valves- 45,6, 250/3,500psi TEST #3- Choke Valves- 7,8,9, HCR KILL, 250/3,500psi TEST #4- super choke and Bean, Man Kill 250/3,500psi TEST #5 Choke Valves -10 and 11 250/3,500psi **Install test Joint. 3.5" Test Joint TEST #6 -TOP RAMS, Dart Valve, Choke valve 12, 13,and 14 250/3,500psi TEST #7- TIW, Choke valve 15 250/3,500psi TEST #8 -Top Drive IBOP,HCR CHOKE 250/3,500psi TEST #9 -TD TIW, MAN CHOKE 250/3,500psi TEST #10- LOWER PIPE RAMS 250/3,500psi TEST #11 -BAG- 250/2,500psi *** INSTALL 4" TEST JOINT TEST #12- BAG 250/2,500psi TEST #13- TOP PIPE RAMS 250/3,500psi TEST #14- Bottom PIPE RAMS 250/3,500psi ***INSTALL 4.5" TEST JOINT TEST #15- Bottom PIPE RAMS 250/3,500psi TEST #16- BAG 250/2,500psi ***MOVE Test hose to choke man. TEST #17- TOP PIPE RAMS, TIW, Outer Test Spool 250/3,500psi Test #18- Inner Test Spool, 250/3,500psi Accumulator test: Initial: 2,950psi After full function:1,600psi N2 Bottle precharge:1,000psi First 200psi: 35 seconds Full Pressure(3,OOOpsi):162 seconds 6 N2 Bottle average: 2,000psi Air pump recovery time: 173 seconds Electric pump recovery time:65seconds 10:00 12:00 2.00 6,192 6,192 PROD1 WHDBO RURD P Lay down test joint. Blow down choke manifold and kill line. Pull test plug and set 6 7/8" Wear ring. Clean and clear the rig floor. ----- - Time Logs Date From To Dur S. De th E. De th _Phase - Code Subcode T Comment 12:00 16:00 4.00 6,192 6,134 PROD1 CASING MPSP P Make up Retrievamatic pulling tool. Engage equalizing valve and verify no pressure. Release Retrievamatic and monitor the well. Lay down Retrievamatic and pulling tool. Well slightly flowing back at 2bbl/hr. 16:00 00:00 8.00 6,134 6,134 PROD1 CASING CIRC T Circulate at 1bb/min Weight system up to 12.7ppg Reciprocate pipe 5 ft/min while pumping. Slow pumps to 3/4 bbl/min to reduce losses. Pump rate: 44/33 gpm Pressure 206/149 psi MW in: 12.7 ppg MW out: From 12ppg to 12.5ppg Max ECD:Not enough flow for tool Max Gas:5 units Avg Background Gas: 5 units Pump total of 3,422 stks 239 bbls. 74 bbls lost to the formation. 4/15/2014 Circ & Cond MW t/ 12.7ppg, Observe well for flow well flowing but slowing down, BROOH f/ 6134' t/ 4235' Observe well f/ flow well flowing but slowing down, POOH w/ pumps 1 bpm 160 psi f/ 4235't/ 733' 00:00 03:00 3.00 6,134 6,134 PROD1 CASING CIRC T Continue t/ circulate and condition mud 44 gpm 200 psi to obtain even mud weight of 12.7 ppg. 03:00 06:00 3.00 6,134 6,134 PROD1 CASING OWFF T Blow Down top drive, Observe well for flow well flowing but slowing down. 06:00 09:00 3.00 6,134 5,187 PROD1 CASING REAM P BROOH f/ 6134't/ 5187' 10 ft/min 80 rpm 1 bpm 185 psi 09:00 10:00 1.00 5,187 5,187 PROD1 CASING OWFF T Observe well f/ flow well flowing but slowing down. 10:00 12:00 2.00 5,187 4,235 PROD1 CASING REAM P BROOH f/ 5187't/ 4235' 10 ft/min 50 rpm 1 bpm 160 psi. 12:00 00:00 12.00 4,235 733 PROD1 CASING TRIP P POOH w/ pumps f/ 4235't/ 733' 10ft/min 1 bpm 150 psi observe well every 10 stands flowing but slowing down. 4/16/2014 POOH t/ HWDP, Observe well for flow, well flowing initail rate 1.4 bph final rate .91 bph slowing, Stand back & L/D BHA, Unload sources, Trouble shoot skate controls, Finish L/D bha components, R/U & run 4'/z" 12.6# L-80 IBT tubing t/ 1805'. 00:00 01:30 1.50 733 529 PROD1 CASING TRIP P Continue POOH w/ pumps 1 bpm f/ 733't/ 529', Blow down top drive. 01:30 03:30 2.00 529 529 PROD1 CASING OWFF P Observe well for flow, well flowing initail rate 1.4 bph slowed to .91 bph after 2 hrs. Total gain 2.39 bbls after 2 hours of monitoring. Rate slowly decreasing. 03:30 06:00 2.50 529 148 PROD1 CASING PULD P Stand Back & L/D BHA HWDP & Flex collar., PJSM on L/D sources. 06:00 07:00 1.00 148 148 PROD1 CASING RGRP T Trouble shoot pipe skate controls, unable to raise skate to rig floor. Page 37 of 1112 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 10:30 3.50 148 0 PROD1 CASING PULD P L/D remaining BHA, clean and clear rig floor 10:30 12:00 1.50 0 0 COMPZ CASING RURD P R/U t/ run 4'/2' liner w/ GBR. 12:00 14:30 2.50 0 156 COMPZ CASING RNCS P RIH w/ 4'/2" Liner, P/U Float equipment, M/U 3 jts of tubing, Elevators had wrong plate installed, used lift sub t/ run jts. 14:30 15:30 1.00 156 156 COMPZ CASING CIRC P M/U cross over, circ liner & annular volume 1 bpm 50 psi 15:30 00:00 8.50 156 1,805 COMPZ CASING RNCS P RIH w/ 4%2" 12.6# L-80 IBT-m tubing f/ 156't/ 1805' PUW-50k SOW -50k 4/17/2014 Continue RIH w/ 4'/2' 12.6# L-80 IBT Liner f/ 1805't/ 3460', M/U ZXP Liner Hanger, Mix and wait on pal mix to set up, RIH w/ 4%" Liner on 4" DP t/ 5456', Clrc & Cond Mud 11.5ppg MW coming out weight up t/ 12.7 ppg 15 spm 160 psi Loss Rate 11 bph, Cont RIH f/ 5456't/ 6213' Circ & Cond mud 15 spm 190 psi. 00:00 05:00 5.00 1,805 3,460 COMPZ CASING RNCS P I Continue RIH w/ 4'/2' 12.6# L-80 IBT tubing f/ 1805' t/ 3460' 05:00 06:00 1.00 3,460 3,460 COMPZ CASING RNCS P M/U ZXP Liner Hanger, Mix Pal mix and wait to 30 min t/ set up. Simops R/D GBR Casing equipment. PU wt 70k, SO wt 65k. 06:00 12:00 6.00 3,460 4,317 COMPZ CASING RUNL P RIH w/ 4'/2' Liner on 4" DP f/ 3460't/ 4317'5-7 ft/min PUW-73 SOW -65k 12:00 16:30 4.50 4,317 5,456 COMPZ CASING RUNL P RIH w/ 4'/2' Liner on 4" DP f/ 4317't/ 5456' 16:30 19:30 3.00 5,456 5,456 COMPZ CASING CIRC P Circulate and condition mud pumping 15 spm (1 bpm) w/ 190 psi. ICP 150 FCP light mud weight observed , weight up returns to 12.7 ppg. Lost 23 bbls of mud over total circ time. 19:30 22:30 3.00 5,456 6,213 COMPZ CASING RUNL P RIH w/ 4%2' Liner on 4" DP f/ 5456't/ 6213'. PU wt 105k, SO wt 90k. 22:30 00:00 1.50 6,213 6,213 COMPZ CASING CIRC P Circulate and condition mud pumping15 spm (1bpm)177 psi. Note: Lost a total of 13 bbls while circulating a total bottoms up. MW in 12.7 ppg. 4/18/2014 Continue t/ Circ & Cond Mud, RIH w/ 4.5" Liner on 4" DPf/ 6313't/ 9485' space out, Work through numerous tight spots, Circ String volume 15 spm 300 psi minimal returns, total losses f/ day 340 bbls, drop ball pump t/ seat 15 spm 270 psi 2556 stks t/ seat, set hanger & packer as per baker rep, release f/ liner, test liner t/ 2000 psi f/ 30 min, POOH t/ 5858' circ and cond mud even mw t/ 12.4ppg, POOH on elevators t/ 2564' 00:00 03:00 3.00 6,213 6,213 COMPZ CASING CIRC P Circulate and condition mud pumping 15 spm (1bpm) 177 psi. Note: Lost a total of 13 bbls while circulating a total bottoms up. MW in 12.7 ppg. 03:00 07:30 4.50 6,213 7,524 COMPZ CASING RUNL P RIH w/ 4'/2' Liner on 4" DP f/ 6213't/ 7,524', 27 min./std. PU wt 80k, SO wt 74k. Tight Spots Observed @ 6588',6830'-6840', 7127', 7278', 7505' 07:30 09:00 1.50 7,524 7,549 COMPZ CASING CIRC P Kelly up and circulate, working liner through tight spot. Circulate @ 8 to 14 stks/min., 230 psi to 340 psi. (1/2 tot bbl./min.) Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 11:00 2.00 7,549 8,185 COMPZ CASING RUNL P RIH w/4 1/2" Liner on 4" DP f/7,549' to 8,185'. SOW=80k, PUW=125k 11:00 11:45 0.75 8,185 8,185 COMPZ CASING CIRC P Tight spot at 8,185', kelly up and circulate, work liner through tight spot. 11:45 14:00 2.25 8,185 9,485 COMPZ CASING RUNL P RIH f/ 8185't/ 9485' M/U working single and pup. PUW-125k SOW -80k 14:00 15:15 1.25 9,485 9,485 COMPZ CASING CIRC P Circulate and Condition mud pump Liner & Drill String Volume @ 300 psi 15pm, minimal returns observed pushing fluid away. 15:15 18:00 2.75 9,485 9,485 COMPZ CASING PACK P Drop 1.125" Ball circ @ 29 spm 350 psi slow t/ 15 spm 900 stks before calculated bump, Pump 2556 stks t/ ball on seat, pressure up t/ 1200 psi t/ close WIV, pressure up t/ 2700 psi t/ set hanger, slack off 50k set hanger, pressure up t/ 3500 psi t/ release f/ hanger, Slack off set packer 50k. 18:00 18:45 0.75 9,485 9,485 COMPZ CASING PRTS P Test Liner top packer t/ 2000 psi f/ 30 min charted test. R/D 18:45 19:15 0.50 9,485 5,858 COMPZ CASING TRIP P POOH L/D single & pup jt. Stand back one stand t/ 5858' 19:15 20:30 1.25 5,858 5,858 COMPZ CASING CIRC P Circulate and condition mud stage pumps t/ 10 bpm even out MW 12.4ppg 2000 psi, reciprocate pipe. 20.30 00:00 j 3.50 5,858 2,564 i COMPZ CASING TRIP I P POOH f/ 5858't/ 2564' on trip tank 4/19/2014 Continue POOH w/ Liner running tool f/ 2564', L/D BHA, Clear floor, P/U test Packer BHA RIH t/ 6030', Displace drill string t/ 8.6ppg seawater perform negative test, release packer displace well t/ 8.6ppg seawater, Hi -Line Failure @ CPF2 Put rig on rig Power, resume normal operations. 00:00 03:00 3.00 2,564 0 COMPZ RPCOM TRIP P Continue POOH f/ 2564't/ Liner running tool. 03:00 04:30 1.50 0 0 COMPZ RPCOM PULD P L/D Running tool confirm dog sub sheared, Clean & Clear Floor 04:30 12:00 7.50 0 6,030 COMPZ RPCOM TRIP P RIH test packer assy. w/ mule shoe t/ 6030' @ 50' ft/min 12:00 12:30 0.50 6,030 6,030 COMPZ RPCOM OTHR P Space out test packer, R/U t/ displace drill string. 12:30 13:00 0.50 6,030 6,030 COMPZ RPCOM CIRC P I Circ 8.6 ppg sea water 3 bpm 1000 1 psi FCP, Slack off close circ port. 13:00 13:30 0.50 6,030 6,030 COMPZ RPCOM PRTS P Test packer t/ 1000 psi packer leaking, bleed off pressure, unset packer & reset Test packer t/ 1000 psi held pressure on IA. 13:30 14:00 0.50 6,030 6,030 COMPZ RPCOM OWFF P Bleed off psi in 200 psi increments t/ 0 psi f/ 1000 psi, expose to atmosphere. 14:00 18:30 4.50 6,030 6,030 COMPZ RPCOM OWFF P Observe well for flow well dripping 1 gal/3 hr rate. Pressure in IA dropped 50 psi t/ 950 psi. 18:30 19:30 1.00 6,030 6,030 COMPZ RPCOM OTHR P Bleed off psi R/D test equipment, R/U t/ displace well t/ 8.6ppg seawater, Pick up & Unseat packer. Page 39 of 42 Time Logs WW Date From To Dur S. De th E.'De th Phase Code Subcode T Comment 19:30 23:00 3.50 6,030 6,030 COMPZ RPCOM CIRC P Displace well w/ 8.6 ppg seawater @ 4 bpm ICP 1100 psi FCP 250 psi. 23:00 00:00 1.00 6,030 6,030 COMPZ RPCOM OTHR T Service rig, CPF2 Hi -Line Power failure, put rig on generator power. Restore systems. 4/20/2014 Slip and cut drilling line, TOH w/ retrievamatic packer laying down 95 jts. of DP and packer BHA. Clean pits and surface equipment and TIH with a No Go Assy, and 63 stds of DP, 6,033'. Displace well bore with a salt water sweep and 8.6 ppg sea water until clean. 00:00 02:00 2.00 6,030 6,030 COMPZ RPCOM SLPC P Slip and cut drilling line. Service 1 draw works. 02:00 06:30 4.50 6,030 2,979 COMPZ RPCOM TRIP P TOH, lay down 95 Jts. of 4" DP. 06:30 08:30 2.00 2,979 479 COMPZ RPCOM TRIP P TOH to Packer BHA. 08:30 09:30 1.00 479 0 COMPZ RPCOM PULD P L/D Retrievamatic Packer and BHA. 09:30 12:00 2.50 0 0 COMPZ RPCOM SVRG P Clean pits and surface equipment. 12:00 16:00 4.00 0 0 COMPZ RPCOM SVRG P Clean pits and surface equipment. 16:00 18:30 2.50 0 6,033 COMPZ RPCOM TRIP P TI with a 35.33' No Go Assy., 63 stds. and 1 single to 6,031.53'. PUW 121 K, SOW 90K. 18:30 23:00 4.50 6,033 6,033 COMPZ RPCOM SVRG P Continue cleaning pits and surface equipment Take on sea water to pits 1 and 2. and empty pits 3 and 4. 23:00 00:00 1.00 6,033 6,033 COMPZ RPCOM WASH P Displace well bore with a salt water sweep and 8.6 ppg sea water until clean. Reciprocate and rotate while circulating. PUW 12K, SOW 90K. D4/21/2014 Displace well with 8.6 ppg sea water. L/D 63 stds of 4" DP and 4 stds of 4" HWDP and Jars. R/U Shooting Flange, Wire Line Tools and Equipment. Test Lubricator and Flange to 1000 PSI. Pressure to 1000 PSI and run CBL from 6,031' to 4,300'. 00:00 01:30 1.50 6,032 6,032 COMPZ RPCOM CIRC P Pump HI VIS Sweep and displace well with 8.6 ppg sea water. L/D single jt. of DP and continue displacement at 10 bbls/min. PSI 1305, GPM 420, Total STKS 6025, ROT100 RPM, TQ 4200, RECP pipe, PUW 118K, SOW 90K. Blow Down TD, Monitor well for 10 min. 01:30 08:00 6.50 6,032 0 COMPZ RPCOM PULD P L/D 6031' (188 Jts) 4" DP and 4 stds of 4" HWDP and Jars. 08:00 09:00 1.00 0 0 COMPZ RPCOM PULD P L/D BAKER tools, No Go, XO, PAC PIN, 2 7/8" DP, and PAC MULE SHOE, 09:00 12:00 3.00 0 0 COMPZ RPCOM RURD P Install 13 5/8" SHOOTING FLANGE 12:00 18:00 6.00 0 0 COMPZ RPCOM RURD P N/D Flow Nipple and install 13 5/8" SHOOTING FLANGE. 18:00 20:00 2.00 0 0 COMPZ RPCOM RURD P R/U Wire line tools and equipment, Rizer and Lubricator. 20:00 00:00 4.00 0 0 COMPZ RPCOM ELOG P Test Lubricator and SHOOTIN FLANGE to 1000 PSI. Run CBL at 1000 PSI, 6,031' to 4300'. Page 40 of 4i Time Logs Date From To Dur S..Depth E. Depth Phase 'Code Subcode T Comment 4/22/2014 24 hr Summary Continue CBL logging run POOH, R/D Eline, pull wear ring, R/U & run 3Y2' 9.3# L-80 Tubing t/ 6050' Shear pins w/ 11 k set on NoGo @ 6051', L/D 3 jts, M/U space out pups crossover and 1 jt 4Y2' IBTM and hanger w/ pup, M/U landing jt and crossover 00:00 01:00 1.00 0 0 COMPZ RPCOM ELOG P Continue CBL Logging run, under 1000 psi pressure. 01:00 03:00 2.00 0 0 COMPZ RPCOM RURD P R/D Eline equipment, top sheave, pressure control head. 03:00 07:00 4.00 0 0 COMPZ RPCOM NUND P Nipple down shooting flange, Nipple up picture nipple and air boot Assy. 07:00 07:30 0.50 0 0 COMPZ RPCOM OTHR P R/U and pull wear ring 07:30 09:30 2.00 0 0 COMPZ RPCOM RURD P R/U GBR tubing equipment, R/U t/ run 3.5" upper completion. 09:30 22:15 12.75 0 6,031 COMPZ RPCOM RCST P RIH w/ 3Y2' 9.3# L-80 EUE 8 rnd tubing t/ 346' t/ 6031' 22:15 00:00 1.75 6,031 6,018 COMPZ RPCOM RCST P RIH locate on shear pins, shear pins w/ 11k SOW, NOGO on locator @ 6051.63', P/U L/D 3 jts, M/U space out pups, x -over, 1 jt of 4'/2' IBTM tubing hanger and pup, M/U x -over t/ top drive 4/23/2014 Spot 26 BBLS of corrosion inhibitor. Space out and set TBG hanger, test TBG and IA to 3500 PSI. Bleed TBG and IA to 0 PSI and pressure IA to 2600 PSI and shear SOV. Set TWC and test to 1500 PSI, N/D BOP's. Install Tree and test 300 PSI Low and 5000 PSI High. Pull TWC, R/U to Freeze Protect. 00:00 02:00 2.00 6,018 6,018 COMPZ RPCOM CRIH Spot 26 BBLS of corrosion inhbitor. Circulate 1.5 BPM, 50 PSI, 373 STKS. Chase with 49 BBLS sea water, circulate 1.5 BBLS, 50 PSI, 702 STKS. 02:00 03:00 1.00 6,018 6,018 COMPZ RPCOM HOSO Drain stack, space out and land TBG Hanger. PUW 80K, SOW 69K. Drop Ball and Rod. 03:00 06:00 3.00 6,018 6,018 COMPZ RPCOM THGR Set Packer at 1600 PSI, increase pressure to 3500 PSI and hold for 30 min.. Bleed TBG to 2000 PSI and pressure IA to 3500 PSI and hold for 30 mina. TBG pressure came up to 2500 PSI, good test. Bleed IA and TBG to 0 PSI. Pressure IA to 2600 PSI and shear SOV. 06:00 08:00 2.00 6,018 6,018 COMPZ RPCOM THGR Set TWC and pressure test to 1500 PSI and hold for 15 min., test good. 08:00 12:00 4.00 6,018 6,018 COMPZ RPCOM NUND N/D BOP's, 12:00 16:30 4.50 6,018 6,018 COMPZ RPCOM NUND N/D BOP's, remove seawater from the pits, take on fresh water to flush surface equipment. 16:30 21:30 5.00 6,018 6,018 COMPZ RPCOM WWSP N/U Tree and adapter flange, test to 5000K, hold 10 min., test good. 21:30 22:30 1.00 6,018 6,018 COMPZ RPCOM SEQP Fill Tree with diesel and test 300 PSI low and 5000 PSI high, hold 5 min.. 22:30 00:00 1.50 6,018 6,018 COMPZ RPCOM FCO Pull TWC, R/U to Freeze Protect. 4/24/2014 R/U & Displace well w/ diesel freeze protect @ 2 bpm w LRS, shut down allow tubing & IA communication U -Tube well f/ 1 hr, R/D hard lines, Drain and flush pits and brine tanks, drain mud lines and clean cuttings tank. Rig released @ 1200 hrs. N Wage 41 of 42 I " t4 th E. Depth Phase Code Subcode T ' Comment bate From To Dut 00:00 01:00 1.00 0 0 COMPZ MOVE RURD P R/U t/ displace well w/ freeze protect, steam and blow down hard line t/ tiger tank, R/ U squeeze manifold in cellar. 01:00 04:00 3.00 0 0 COMPZ MOVE FRZP P Freeze protect well w/ diesel @ 2 bpm pumping down IA taking returns up tubing t/ tiger tank, Shut in well put tubing & IA in communication allow t/ U-Tube until static. 04:00 04:30 0.50 0 0 COMPZ MOVE RURD P Set BPV as per FMC 04:30 07:30 3.00 0 0 COMPZ MOVE RURD P Secure wellhead remove secondary annulus valves install flange and gauges. IA psi 0 psi Tubing 0 psi OA 400 psi 07:30 12:00 4.50 0 0 COMPZ MOVE OTHR P Clean and draqin pits, flush and drain brine tanks, drain mud lines clean out cuttings box. Release rig @ 1200 hrs f/ move t/ 2N-322 Page 42 of 42 Schlumberger 2L -322A Final ASP Survey (Def Survey) Report Date: April 25, 2014 - 01:57 PM Survey / DLS Computation: Minimum Curvature / Lubinski Client: ConocoPhillips (Alaska) Inc. -Kup2 Vertical Section Azimuth: 178.000 ° (True North) Field: Kuparuk River Unit2 Vertical Section Origin: 0.000 it, 0.000 ft Structure I Slot: Kuparuk 2L Pad / 2L-322 TVD Reference Datum: RKB Well: 2L-322 (North) TVD Reference Elevation: 143.730 ft above Mean Sea Level Borehole: 2L -322A Seabed / Ground Elevation: 114.800 it above Mean Sea Level UWI I API#: 50-103-20628-01-00 Magnetic Declination: 19.170 ° Survey Name: 2L -322A Final Total Gravity Field Strength: 1001.9628mgn (9.80665 Based) Survey Date: 16 -Apr -14 Gravity Model: GARM Tort I AHD I DDI I ERD Ratio: 175.115 ° / 6591.399 It /.6.321. / 1.256 Total Magnetic Field Strength: 57585.000 nT Coordinate Reference System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Dip Angle: 80.780 ° Location Lat / Long: N 70° 12'47.69533", W 150° 18' 57.25515" Declination Date: March 15, 2014 Location Grid N/E YIX: N 5927637.770 ftUS, E 460829.380 ftUS Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Angle: -0.2973 ° North Reference: True North Grid Scale Factor: 0.99990174 Grid Convergence Used: 0.0000 ° Total Corr Mag NorthaTrue 19.1700 ° Version I Patch: 2.7.1043.0 North: Local Coord Referenced To: Well Head MD Incl Azim True TVDSS TVD VSEC AHD Closure NS. EW DLS Northing Easting Latitude Longitude Comments (ft) (9 M (ft) (ft) (ft) (ft) (fill (ft) (111 (111 001t) MUS) (ftUS) (°) M RTE 0.00 0.00 0.00 -143.73 0.00 0.00 0.00 0.00 0.00 0.00 0,00 5927637.77 460829.38 70.21324870 -150.31590421 Ground Level 28.93 0.00 0.00 -114.80 28.93 0.00 0.00 0.00 0.00 0.00 0.00 5927637.77 460829.38 70.21324870 -150.31590421 88.93 0.14 43.59 -54.80 88.93 -0.05 0.07 0.07 0.05 0.05 0.23 5927637.62 460829.43 70.21324885 -150.31590380 153.93 0.26 31.97 10.20 153.93 -0.23 0.30 0.30 0.24 0.18 0.19 5927638.00 460829.56 70.21324935 -150.31590273 242.93 0.90 144.93 99.20 242.93 0.19 1.02 0.71 -0.17 0.69 1.16 5927637.60 460830.07 70.21324825 -150.31589863 334.93 2.30 165.91 191.16 334.89 2.60 3.56 2.99 -2.55 1.56 1.62 5927635.22 460830.92 70.21324174 -150.31589166 423.93 - 2.99 170.63 280.06 423.79 6.65 7.67 6.98 -6.57 2.37 0.81 5927631.19 460831.71 70.21323075 -150.31588510 518.93 3.59 167.65 374.91 518.64 12.03 13.12 12.40 -11.92 3.41 0.66 5927625.83 460832.73 70.21321614 -150.31587672 613.93 4.64 166.22 469.66. 613.39 18.72 19.93 19.21 -18.58 4.96 1.11 5927619.19 460834.24 70.21319801 -150.31586421 709.93 6.42 166.79 565.21 708.94 27.79 29.18 28.46 -27.55 7.11 1.86 5927610.18 460836.35 70.21317343 -150.31584686 803.93 .8.26 .174.49 658.44 802.17 39.68 41.18 40.40 -39.39 8.96 2.22 5927598.34 460838.14 70.21314108 -150.31583194 898.93 11.33 183.95 752.05 895.78 55.78 57.30 56.22 -55.50 8.97 3.64 5927582.23 460838.06 70.21309708 -150.31583184 993.93 14.41 193.77 844.66 988.39 76.44 78.41 76.50 -76.30 5.52 3.97 5927551.45 460834.50 70.21304026 -150.31585973 1041.16 15.71 192.60 890.27 1034.00 88.29 90.68 88.29 -88.25 2.72 2.83 5927549.52 460831.64 70.21300762 -150.31588226 1135.31 17.39 195.56 960.52 1124.25 114.04 117.49 114.31 -114.24 -3.83 2.00 5927523.56 460824.95 70.21293660 -150.31593512 1231.90 20.89 193.44 1071.76 1215.49 144.41 149.16 145.38 -144.91 -11.71 3.69 5927492.94 460816.92 70.21285282 -150.31599864 1321.54 23.80 196.25 1154.66 1298.39 177.00 183.23 179.00 -177.82 -20.49 3.46 5927460.07 460807.97 70.21276290 -150.31606942 1415.47 25.91 194.57 1239.88 1383.61 214.67 222.70 218.09 -215.89 -30.96 2.37 5927422.07 460797.31 70.21265891 -150.316153 1514.99 29.23 194.49 1328.09 1471.82 258.83 268.76 263.91 -260.47 -42.51 3.34 5927377.55 460785.53 70.21253712 -150.316246 1612.17 32.24 195.82. 1411,61 1555.34 306.27 318.41 313.35 -308.39 -55.51 3.18 .5927329.70 460772.27 70.21240619 -150.316351 1708.06 35.34 194.17 1491.30 1635.03 357.27 371.74 366.51 -359.90 -69.28 3.37 5927278.27 460758.24 70.21226547 -150.31646285 1801.31... 35.56 194.98 1567.26 1710.99 409.10 425.82 420.50 -412.24 -82.89 0.56 5927226.00 460744.36 70.21212247 -150.31657260 1895.57 36.34 197.62 1643.57 1787.30 461.63 481.15 475.64 -485.34 -98.43 1.84 5927172.99 460728.55 70.21197740 -150.31669790 1992.92 36.52 197.81 1721.90 1865.63 516.05 538.96 533.19 -520.41 -116.02 0.22 5927118.02 460710.67 70.21182696 -150.31683974 2087.35 37.29 .196.42 1.797.41 1941.14 569.62 595.68 589.73 -574.60 -132.70 1.20 5927063.92 460693.71 70.21167891 -150.31697423 2175.97 37.26 196.84 1867.93 2011.66 620.48 649.33 643.30 -626.03 -148.06 0.29 5927012.58 460678.09 70.21153841 -150.31709808 2274.79 37.60 196.50 1946.40 2090.13 677.38 709.40 703.27 -683.57 -165.29 0.40 5926955.14 460660.56 70.21138122 -150.31723699 2366.67 38.15- 196.60 2018.85 2162.58 730.80 765.74 759.55 -737.58 -181.34 0.60 5926901.21 460644.23 70.21.123366 -150:31736640 2462.51 38.70 196.53 2094.01 2237.74 787.33 825.37 819.11 -794.73 -198.34. 0.58 5926844.16 460626.94 70.21107752 -150.31750346 2560.37 39.02 197.16 2170.20 2313.93 845.43 886.76 880.43 -853.49 -216.13 0.52 5926785.50 480608.84 70.21091700 -150.31764690 Tie -In Survey 2608.13 39.05 197.33 2207.30 2351.03 873.83 916.84 910.47 -882.22 -225.05 0.23 5926756.82 460599.78 70.21083852 -150.31771879 2690.97 37.04 193.94 2272.55 2416.28 922.45 967.89 961.49 -931.36 -238.84 3.50 5926707.76 460585.74 70.21070427 -150.31782995 2787.17'. 36.86. 188.34.. 2349.45 2493.18 978.71 1025.68 1019.18 -988.04 -250.01 3.50 5926651.14 460574.28 70.21054941 -150.31791998 2882.29 39.27 187.82 2424.33 2568.06 1036.45 1084.33 1077.51 -1046,10 -258.24 2.56 5926593.13 460565.74 70.21039079 -150.31798637 2977.06 41.36 188.17 2496.59 2640.32 1096.83 1145.64 1138.51 -1106.82 -266.77 2.22 5926532.46 460556.90 70.21022492 -150.31805514 Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2L Pad\2L-322 (North)\2L-322A\2L-322A Final 5/2/2014 7:17 AM Page 1 of 3 MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) VI 1°1 (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) MUS) MUS) 3075.62 41.37 191.51 2570.57 2714.30 1160.56 '1210.76 1203.50 -1170.97 -277.90 2.24 5926468.37 460545.44 70.21004985 -150.31814484 3170.85 40.40 192.30 2642.57 2786.30 1221.07 1273.09 1265.81 -1231.96 -290.75 1.15 5926407.45 460532.27 70.20988302 -150.31824846 3266.37 39.84 188.55 2715.62 2859.35 1281.15 1334.63 1327.27 -1292,47 -301.90 2.60 5926347.01 460520.81 70.20971771 -150.31833830 3360.82 39.91 185.89 2788.11 2931.84 1340.91 1395.18 1387.50 -1352.54 -309.51 1.81 5926286.99 460512.89 70.20955362 -150.31839962 3457.85 39.69 183.98 2862.66 3006.39 1402.56 1457.28 1449.03 -1414.41 -314.85 1.28 5926225.15 460507.23 70.20938459 -150.31844269 3552.91 39.03 180.71 2936.17 3079.90 1462.65 1517.56 1508.38 -1474.63 -317.33 2.29 5926164.96 460504.44 70.20922008 -150.31846265 3648.45 38.04 175.89 3010.92 3154.65 1522.13 1577.06 1566.18 -1534.08 -315.49 3.43 5926105.51 460505.97 70.20905767 -150.31844780 3743.50 38.97 173.02 3085.30 3229.03 1581.17 1636.23 1622.77 -1592.95 -309.66 2.00 5926046.61 460511.50 70.20889682 -150.31840075. 3837.66 39.50 173.14 3158.24 3301.97 1640.51 1695.78 1679.54 -1652.07 -302.48 0.57 5925987.45 460518.36 70.20873530 -150.31834288 3932.49 39.64 173.78 3231.34 3375.07 1700.73 1756.19 1737.42 -1712.09 -295.60 0.45 5925927.41 460524.93 70.20857134 -150.31828739 4027.29 39.69 175.33 3304.31 3448.04 1761.13 1816.70 1795.87 -1772.32 -289.86 1.04 5925867.15 460530.36 70.20840679 -150.31824109 4121.54 39.70 175.31 3376.83 3520.56 1821.26 1876.90 1854.34 -1832.32 -284.95 0.02 5925807.14 460534.96 70.20824288 -150.31820147 4219.49 39.62 176.34 3452.24 3595.97 1883.73 1939.41 1915.30 -1894,67 -280.40 0.68 5925744.77 460539.19 70.20807255 -150.31816476 4314.39 39.72 177.50 3525.29 3669.02 1944.29 1999.99 1974.70 -1955.16 -277.14 0.79 5925684.27 460542.13 70.20790730 -150.31813851 4409.32 39.55 176.70 3598.40 3742.13 2004.84 2060.54 2034.18 -2015.63 -274.08 0.57 5925623.79 460544.87 70.20774208 -150.31811360 4504.95 39.67 178.28 3672.07 3815.80 2065.80 2121.51 2094.20 -2076.54 -271.41 1.06 5925562.87 460547.23 70.20757568 -150.31809226 4598.11 39.69 178.70 3743.77 3887.50 2125.28 2180.99 2152.98 -2136.00 -269.84 0.29 5925503.41 460548.49 70.20741324 -150.31807961 4695.19 39.82 178.00 3818.41 3962.14 2187.36 2243.08 2214.34 -2198.06 -268.06 0.48 5925441.35 460549.95 70.20724370 -150.318065 4789.56 39.49 175.94 3891.06 4034.79 2247.57 2303.30 2273.67 -2258.19 -264.88 1.44 5925381.21 460552.82 70.20707942 -150.318039 4884.94 39.74 174.18 3964.54 4108.27 2308.30 2364.11 2333.27 -2318.78 -259.64 1.21 5925320.60 460557.74 70.20691391 -150.3179972 4980.74 39.93 175.01 4038.11 4181.84 2369.56 2425.48 2393.37 -2379.87 -253.86 0.59 5925259.49 460563.21 70.20674700 -150.31795067 5076.01 39.93 175.09 4111.16 4254.89 2430.63 2486.63 2453.42 -2440.79 -248.58 0.05 5925198.55 460568.16 70.20658057 -150.31790812 5171.32 39.98 175.34 4184.22 4327.95 2491.76 2547.83 2513.60 -2501.78 -243.48 0.18 5925137.53 460572.95 70.20641394 -150.31786695 5266.11 40.08 175.46- 4256.80 4400.53 2552.67 2608.80 2573.64 -2562.56 -238.59 0.13 5925076.74 460577.53 70.20624791 -150.31782752 5362.02 39.89 175.96 4330.29 4474.02 2614.25 2670.43 2634.42 -2624.01 -233.98 0.39 5925015.27 460581.82 70.20608002 -150.31779033 5457.69 40.39 175.88 4403.43 4547.18 2675.88 2732.11 2695.33 -2685.53 -229.59 0.53 5924953.74 460585.89 70.20591195 -150.31775494 5548.73 43.16 174.62 4471.32 4615.05 2736.46 2792.75 2755.13 -2745.96 -224.55 3.18 5924893.28 460590.61 70.20574685 -150.31771430 5646.17 46.29 174.49 4540.54 4684.27 2804.89 2861.31 2622.65 -2814.22 -218.04 3.21 5924825.01 460596.77 70.20556039 -150.31768183 5742.47 49.66 174.40 4605.00 4748.73 2876.28 2932.84 2893.12 -2885.41 -211.11 3.50 5924753.79 460603.32 70.20536591 -150.31760599 5838.81 52.37 173.87 4665.60 4809.33 2950.99 3007.72 2966.88 -2959.89 -203.46 2.85 5924679.27 460610.59 70.20516241 -150.31754424 5934.13 54.90 173.80 4722.12 4865.85 3027.54 3084.47 3042.47 -3036.20 -195.21 2.65 5924602.93 460618.44 70.20495395 -150.31747778 6028.00 57.53 174.81 4774.31 4918.04 3105.38 3162.48 3119.46 -3113.82 -187.48 2.94 5924525.27 460625.77 70.20474188 -150.31741545 6124.66 60.33 176.14 4824.19 4967.92 3188.09 3245.26 3201.47 -3196.35 -180.97 3.13 5924442.72 460631.85 70.20451643 -150.31736290 6156.18 61.35 177.15 4839.55 4983.28 3215.60 3272.78 3228.81 -3223.83. -179.36 4.28 5924415.24 460633.32 70.20444136 -150.31734992 7-518in Csv 6214.65 64.19 177.20 4866.30 5010.03 3267.58 3324.77 3280.52 -3275.75 -176.79 4.86 5924363.31 460635.61 70.20429951 -150.31732925 6246.37 65.73 177.22 4879.73 5023.46 3296.32 3353.51 3309.10 -3304.45 -175.39 4.86 5924334.60 460636.86 70.20422110 -150.31731796 6317.95 69.57 177.44 4906.94 5050.67 3362.50 3419.70 3374.97 -3370.57 -172.31 5.37 5924268.48 460639.60 70.20404046 -150.31729311 6364.21 69.61 178.08 4923.07 5066.80 3405.86 3463.05 3418.15 -3413.89 -170.62 1.30 5924225.15 460641.07 70.20392211 -150.31727944 6459.35 70.33 178.26 4955.66 5099.39 3495.24 3552.44 3507.25 -3503.23 -167.76 0.78 5924135.81 460643.46 70.20367804 -150.31725642 6555.30 71.83 178.86 4986.77 5130.50 3586.00 3643.20 3597.77 -3593.97 -165.48 1.67 5924045.07 460645.27 70.20343016 -150.31723804 6650.84 73.44 177.73 5015.29 5159.02 3677.18 3734.38 3688.70 -3685.11 -162.77 2.03 5923953.93 460647.51 70.20318117 -150.3172161 8743.85 76.37 176.37 5039.51 5183.24 3766.96 3824.17 3778.09 -3774.78 -158.14 3.45 5923864.24 460651.68 70.20293619 -150.317178 6840.44 - 81.83.174.86 5057.77 5201.50 3861.68 3918.99 3872.25 -3869.31 -150.88 5.86 5923769.69 460658.45 70.20267794 -150.317120 6937.02 86.02 173.32 5067.98 5211.71 3957.47 4015:00 3967.31 -3964.81 -140.99 4.62 5923674.14 460667.84 70.20241703 -150.31704054 7031.68 85.85 174.42 5074.70 5218.43 4051.65 4109.42 4060.80 -4058.69 -130.90 1.17 5923580.22 460677.44 70.20216056 -150.31695926 7127.71 - - 86.29 - 177.91 - 5081.28 5225.01 4147.39 4205.23 4156.13 -4154.26 -124.50 - 3.65 5923484.63 - 460683.35 70.20189945 -150.31690762 7222.49 90.39 179.24 5084.02 5227.75 4242.10 4299.95 4250.71 -4248.95 -122.14 4.55 5923389.94 460685.21 70.20164077 -150.31688863 7317.28 91.10 179.59 5082.79 5226.52 4336.85 4394.73 4345.42 -4343.73 -121.18 0.84 5923295.16 460685.68 70,20138184 -150.31688082 7413.86 91.20 180.08 5080.85 5224.58 4433.36 4491.29 4441.93 -4440.29 -120.90 0.52 5923198.61 460685.46 7020111805 -150.31687857 7508.17 91.10. 181.32 5078.96 5222.69 4527.55 4585.58 4536.21 -4534.57 -122.05 1.32 5923104.35 460683.82 70.20086047 -150.31688784 7606.16 91.29 182.72 5076.92 5220.65 4625.27 4683.55 4634.18 -4632.48 -125.50. 1.44 x.5923006.47 460679.86 70.20059300 -150.31691565 - 7697.27 89.87 184.14 5075.99 5219.72 4715.97 4774.65 4725.23 -4723.41 -130.95 2.20 5922915.57 460673.94 70.20034456 -150.31695957 7793.06 89.02 183.40 5076.92 5220.65 4811.26 4870.44 4820.94 -4818.99 -137.25 1.18 5922820.04 460667.14 70.20008345 -150.31701031 7887.00 89.76 179.61 5077.92 5221.65 4905.01 4964.37 4914.86 -4912.87 -139.72 4.11 5922726.18 460664.19 70.19982696 -150.31703017 - 7980.53 89.63 - 177.45 5078,42 5222.15 4998.52 5057.90 5008.25 -5006.37 -137.32 2.31 5922632.69 460668.11 70.19957155 -150.31701082 8078.22 89.80 175.73 5078.91 5222.64 5096.18 5155.59 5105.57 -5103.88 -131.51 1.77 5922535.15 460671.41 70.19930515 -150.31696399 8174.55 89.32 174.78 5079.65 5223.38 5192.39 5251.92 5201.34 -5199.87 -123.54 1.10 5922439.13 460678.88 70.19904289 -150.31689976 8269.66 89.21 . 173.42 5080.87 5224.60 5287.27 5347.02 5295.69 -5294.47 -1.13.77 1.43 5922344.49 460688.16 70.19878446 -150.31682098 8364.56 89.88 176.16 5081.62 5225.35 5382.01 5441.91 5389.99 -5388.97 -105.15 2.97 5922249.96 460696.29 70.19852630 -150.31675153 Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2L Pad\2L-322 (North)\2L-322A\2L-322A Final 5/2/2014 7:17 AM Page 2 of 3 Legal Description: Surface: 5071.0 FSL 821.4 FEL S22 TION R7E UM BHL: 3814 FSL 891 FEL 27 T10N R7EUM Northing (Y) Easting (X) 5927637.770 460829.380 5921102.180 460735.860 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. 21 Yes ❑ No I have checked to the best of my ability that the following data is correct: MD Incl Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) (1 1°1 (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ftus) (flus) (°1 (I 8460.69 89.83 174.21 5081.86 5225.59 5478.02 5538.04 5485.61 -5484.75 -97.08 2.03 5922154.15 460703.86 70.19826462 -150.31668651 8555.48 90.35 173.87 5081.71 5225.44 5572.59 5632.83 5579.71 -5579.03 -87.24 0.66 5922059.83 460713.21 70.19800706 -150.31660719 8651.73 90.16 176.18 5081.29 5225.02 5668.70 5729.08 5675.46 -5674.91 -78.89 2.41 5921963.92 460721.06 70.19774512 -150.31653992 8747.15 90.76 176.47 5080.52 5224.25 5764.07 5824.50 5770.59 -5770.13 -72.78 0.70 5921868.68 460726.68 70.19748496 -150.31649064 8841.45 91.18 176.65 5078.92 5222.65 5858.33 5918.78 5864.63 -5864.24 -67.12 0.48 5921774.54 460731.85 70.19722786 -150.31644504 8937.06 90.10 177.47 5077.86 5221.59 5953.92 6014.39 5960.05 -5959.72 -62.22 1.42 5921679.05 460736.26 70.19696703 -150.31640553 9032.21 89.73 178.94 5076.00 5221.73 6049.07 6109.54 6055.11 -6054.82 -59.23 1.59 5921583.94 460738.74 70.19670722 -150.31638151 9127.56 89.11 180.36 5078.96 5222.69 6144.37 6204.88 6150.44 -6150.16 -58.65 1.62 5921488.61 460738.83 70.19644675 -150.31637681 9222.95 88.11 180.49 5081.28 5225.01 6239.64 6300.24 6245.80 -6245.52 -59.36 1.06 5921393.27 460737.63 70.19618624 -150.31638250 9317.99 85.02 181.03 5086.97 5230.70 6334.39 6395.10 6340.66 -6340.37 -60.62 3.30 5921298.44 460735.88 70.19592711 -150.31639263 9415.31 85.13 180.04 5095.33 5239.06 6431.26 6492.06 6437.62 -6437.32 -61.52 1.02 5921201.50 460734.47 70.19566224 -150.31639992 9455.78 85.20 178.61 5098.74 5242.47 6471.57 6532.39 6477.93 -6477.65 -61.05 3.53 5921161.18 460734.74 70.19555208 -150.31639609 4-112in Liner 9485.00 85.20 178.61 5101.18 5244.91 6500.69 6561.50 6507.04 -6506.76 -60.34 0.00 5921132.07 460735.29 70.19547255 -150.31639039 Projection to bit 9515.00 85.20 178.61 5103.69 5247.42 6530.58 6591.40 6536.91 -6536.64 -59.62 0.00 5921102.18 460735.86 70.19539091 -150.31638455 Survey Type: Def Survey 10 Survey Error Model: ISCWSA Rev 0 "' 3-D 95.000% Confidence 2.7955 sigma Survey Program: Description Part MD From MD To EOU Freq Hole Size Casing Diameter SurveyTool Type yp Borehole / Survey y (ft) (ft) (ft) (in) (in) 1 0.000 698.932 Act Stns 30.000 30.000 CB -GYRO -SS 2L-322PB1 / 2L-322PB1 Definitive 1 898.932 2608.125 Act Stns 30.000 30.000 MWD+IFR-AK-CAZ-SC 2L-322PB1/2L-322PB1 Definitive 1 2608.125 6214.650 Act Stns 9.875 7.625 MWD+IFR-AK-CAZ-SC 2L -322A / 2L -322A Final 1 6214.650 9455.780 Act Stns 6.500 4.500 MWD+IFR-AK-CAZ-SC 2L -322A / 2L -322A Final 1 9455.780 9515.000 Act Stns 6.500 4.500 BLIND 2L -322A / 2L -322A Final Legal Description: Surface: 5071.0 FSL 821.4 FEL S22 TION R7E UM BHL: 3814 FSL 891 FEL 27 T10N R7EUM Northing (Y) Easting (X) 5927637.770 460829.380 5921102.180 460735.860 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. 21 Yes ❑ No I have checked to the best of my ability that the following data is correct: 0 Surface Coordinates Declination & Convergence ❑+ GRS Survey Corrections 121 Survey Tool Codes SLB DE: Client Representative: Date: • Drilling Office 2.7.1043.0 Kuparuk River Unit2\Kuparuk 2L Pad\2L-322 (North)\2L-322A\2L-322A Final 5/2/2014 7:17 AM Page 3 of 3 �LL"32'ZA- 3 —� Cement Detail Report 2L-322 String: Intermediate Casing Cement Job: DRILLING SIDETRACK, 3/16/2014 00:00 Cement Details Description Cementing Start Date ICementing End Date Wellbore Name Intermediate Casing Cement 3/30/2014 01:00 3/30/2014 03:01 2L-322 Comment Circulate 1 Cement 1 Displace; batchup 96 BBLS of 15,8 PPG CMT. and 40 BBLS 11..5 PPG mud. Pump 40 BBLS 11.5 PPG mud @ 5 BPM - 400 PSI. PUW - 215K, SOW - 125K, drop bottom plug and verify. Pump 85 BBLS 15.8 PPG CMT. at 5 BPM - 250 PSI. Drop top plug and verify. Pump 10 BBLS of H20at 5 BPM. Change over to rig pump displacement 168 BBLS at 7 BPM -310 PSI, 5 BPM - 540PSI, slow to 2 BPM FCP 900 psi , bump plug at 910 PSI 3,781 STKS. Hold 1600 PSI for 5 min. and bleed PSI off. Check floats, floats held, CIP 03:01. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Intermediate Casing 4,722.0 6,224.0 Yes 0.0 Yes Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 5 900.0 1,600.0 Yes 20.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Circulate / Cement / Displace; batchup 96 BBLS of 15,8 PPG CMT. and 40 BBLS 11-5 PPG mud. Pump 40 BBLS 11.5 PPG mud @ 5 BPM - 400 PSI. PUW - 215K, SOW - 125K, drop bottom plug and verify. Pump 85 BBLS 15.8 PPG CMT. at 5 BPM - 250 PSI. Drop top plug and verify. Pump 10 BBLS of H2O at 5 BPM. Change over to rig pump displacement 168 BBLS at 7 BPM - 310 PSI, 5 BPM - 540 PSI, slow to 2 BPM FCP 900 psi , bump plug at 910 PSI 3,781 STKS. Hold 1600 PSI for 5 min. and bleed PSI off. Check floats, floats held, CIP 03:01. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl} Intermediate Cement 1 4,722.0 6,224.0 408 G 85.0 Yield (ft'lsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) 1.17 5.26 15.80 57.7 6.36 Additives Additive Type Concentration Cone Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Cone Unit label Dispersant D065 0.5 %BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.1 %BWOC Additive Type concentration Cone Unit label Gas Block D970 2.0 gal/sx Additive Type Concentration Cone Unit label Acelerator (Calcium Chloride) S002 0.14 gal/sx Page 1/1 Report Printed: 7/10/2014 ,jV-OCUP PROD 0 2L -322A COnocoPhiIIips AlH51ka.lm;,ft�lccrtrrnentl Well Attributes Max Angle & MD JTD WellOoreAPWVII FICIaNamc WNlbotOSlatus SU1 032062801 TARN PARTICIPATING AREA PROD norl 1301ftKe) Act im(fIK ) 9129 7,606.16 9.486.0 SSSV: NPPIE 2S (ppm) Datc nnolation nd Date Last WO: VI62014 KGr INJ Rig 4089 Release Date 51312011 2La22A, 6e5 0141017w AIA .'r- sc main: 1--r Annotation ) Depth IRK Last Tag: nd Date Annotallon Last rtod By End Rev Reas.T GLV C10 hipshkf Date 615201-0 FINGER: 252 i SURFACE; 304-2,601.5 CONDUCTOR; 312-134.2 NIPPLE; 530.7 GAS LIFT; 2,9312 GAS LIFT. 4.2;07 GAS OFT: 5198.2- GAS LIFT. 5,867.3 SLEEVE• C; 6.952-4 PACKER; 5,9519-_ NIPPLE; 6,0091 LOCATOR; 6.030,0 LOCATOR; 6,0310 MULE SHOE: 6.480 INTERVEDWE 2756,2147 PERFP:7.115.47.117.7 FRAC; 7.115.4 PERP, 7,477.9-7,480 2 FRAC: 2477.9 PERP.7,8121'781/4 FRAC; 7,6721 PERP,8.150.f1-8.1537 FRAC.8.150.6Lf PERP,9455.781580 FRAC:6d557L� FRAC; 6.791.27.8121 PERP; 6791.2-87936 , PERP, 9,1260.9,1281-s FRAC: 9.1260 `� LINER, 6.0337.9.486.5 Casing Strings Casing DcswiP6on OD(in loin Top 11 8) Set pt h lnKe) get Depl ( D)... WOLen (L.. rade op mead CONDUCTOR 16 15,250 31.2 134.2 134.2 62.50 H-40 Welded Casing Dcsarplion OD (in) ID (in) op lnl(6) el Depth (fIK ) Set Depth (V 1.., ULen (1... rade op Thea INTERMEDIATE 75/8 6.875 27.5 6214.7 5.010.1 29.70 L-80 Hydri1563 Casing 005"IPNen 00(In) 1 (in) op{ftK) Set epih lflK ) Set Depth(o)... W9Len (I... r rep Ieead LINER 4 12 3.958 6,033.7 9.486.5 5,245.0 12.60 P110 Hydril 521 Liner Details Nominal ID Top(IMB) Top(TVD)(11K8) Toplmll') Item Des Cam lin) 6,033.7 4,921.1 57.69 PACKER BAKER I IRD-E ZXP LINER TOP PACKER 4800 6,055.5 4,932.6 58.33 HANGER BAKER FLEX -LOCK LINER HANGER 4.8 0 6,065.1 4,937.7 58.60 XO REDUCING XO 17# HYDRIL 563 BOX X 12.6# HYORIL 5 1 PIN 3,920 ,74.3 5,1 78.09IWIIPacker BAKER SWELL PACKER 3.958 7,115.4 5,224.2 86.23 FRAC PORT FRAC POINT 2.50' Seat #7 2.400 7,288.5 5,227.0 90-88 Swell Packer BAKER SWELL PACKER 3.958 7,477.9 5,223.3 91.13 FRAC PORT FRAC POINT 2.375' Seat #5 2275 7,655.6 5,219.9 90.52 Swell Packer BAKER SWELL PACKER 7,812.1 5,221.0 89.17 FRAC PORT FRAC POINT2 250' SEAT #5 2.150 7,02-3 5.222.'1 8 . 5 Tntil Packer BAKER SWELL PACKER 3.9 8.150.8 5, .44 FRA P RT FRAC POINT 2AW Seat#4 8.298.8 5,225.0 89.42 Swell Packer BAKER SWELL PACKER 3.958 8 477 572F-6 .6 89,83 FRAC PORT FRAC POINT 2,00- Seat 03 1.900 8,677.1 5.225.1 90.20 Swell Packer BAKER SWELL PACKER 3.95E 8,7911 5.223.6 90.96 FRAC PORT FRAC POINT 1.875' Seat #2 1.775 8,968.7 5,221.6 89.98 Swell Packer BAKER SWELL PACKER 3.958 9.126.1 5.M-7 89.12 FRAC-POR T FRAC POINT1.75- Seat #1 .65 %303.1 5,229.5 85.50 Svrell Packer BAKER SWELL P 1958 9,429.0 5,240-2 85.15 FRAC SLEEVE PRESSURE ACTIVATED FRAC SLEEVE 3.850 9,4415 5,241.3 85.18 VALVE WELLBORE ISOLATION VALVE 3.850 Tubing Strings Tubing Des<sip[ion TUBING 4.5 x 3.5 @ 59.4 String r. a... 3 12 ID In) 2.990 op ( ) 25.2 Set Depth R. 6,049.0 Set epi ( ) 1 A,929 2 wt p f) 9.30 Gr L-80 op onnaetlon EUE Completion Details Nominal ID Top (nKB) Top (TVD) ntK8) Top Incl (-) It.. Des Com {in) 25.2 25.2 0.00 HANGER FMC TUBING HANGER 3.958 59.4 5'9.4 a wring X04.5- I M boxX 3. ' rd ELIE pin 2.990 5307 1 ' CAMCONIPPLE 2.812 5,958.4 4,879,7 55.58 SLEEVE - C BAKER CMU SLIDING SLEEVEW/ DS PROFILE (CLOSED) 2.813 5,981.9 4,892.9 56.24 PACKER BAKER PREMIER PACKER 2.870 6,WO.7 4,008.2 57.02 NIPPLE CAMCO D NIPPLE .75 6,030.0 4,919-1 57.59 LOCATOR MECHANICAL LOCATOR ABOVE 1-6ZATUP 3-37 6.031.0 4,919.7 57.62 LOCATOR MECHANICAL LOCATOR BELOW LOCATOR vd(4) SHEAR SCREWS 0 6,0 8. -----492T-7 58.11 MULE H E MULE H WNVLEr, 3.OW Perforations & Slots SAot Dens Tap (TVD) Bt. (TVD) (shots# rep MKB) at. (10(a) (11148) (BKEI) lone Date 0 Type Co. 7.115.4 7,117.7 -5-,2F4-2 5,224.4 5174/2014 PERFP FRAC PORT 7, 7.40-2 5,223.3 5,223.2 5/1412014 PERP TR -AC PORT 7,812.1 7,814.4 5,221.0 5,221.0 5/14/2014 PERP FRACPORT 8,150.8 B, 153.1 5,223.1 5,223.2 5114!2014 PERP FRAC PORT 8,455.7 8,458.0 5,225.6 5,225.6 511412014 PERP JFRACPORT 8.791.2 8.793.61 5,223.61 5223.61 5114/2014 I PERP I FRAC PORT 9,126.0 9,128.4 5,2ZZ.7 1 5,M-1 I 5114/ZU14 I PERP FRAC PORT Stimulations & Treatments Min Top Alas at. Depth Depth Top(TVD) I Blm (iVD) (OKS) BIKE) (Itmal (ITKB) Type Dale Com 7,814.4 5.22 LO 5,221.0 FRAC 511412014 FRAC v150-11,360 1120 proppant ,1 .1 .1 5,223.2 F C 5!14/2014 FRAC .1504.360 16120 proppant 7,115. 7,117.7 ---5.947--T2-24-4 FRA 511 12014 FfIA vd5 4, lB/Z proppanl 7,477.9 7,480.2 5,223.3 5.223.2 FRAC 5/141 14 FRAC./504,36016/20 proppant ,1 ,1 22. FRAC 511712014 FRAC vd501,062#1620 proppanl 8,455.7 8,45& 5,225. 5, FRA 5117 4 FR wf 1 plGppanl 8,791.2 8,793.6 5,223.6 5,223.6 FRAC 5/1721114 FRACw1501,062#16 p(oppant Mandrel Inserts st 2-B Top(TVD) Valve Latch Port Sf. TRORun N Top (rlKB) IIIKBI Make Model OD lin) Sery Type TYPO (in) (psi) Run Date Com 2,934.2 2,608.0 CAMCO MMG 1 112 GAS LIFT OMY RK 0000 0.O 41 14 ,67A -MCO- MM 1112 OULIFT DMV RK 0.000 0-0 4222014 3 5,188.4 4,341.1 CAMCO MMG 11/2 GA LIFT MY RK 0 0. 4222 14 4 5,11F753 4, ,6 -CA-M-ff Mw 1 112 GAS LIFT OV RK 0. 1 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair well Plug Perforations Perforate Other " Alter Casing j" Pull TubingStimulate - Frac JV— Waiver j Time Extension Change Approved Program r—Operat. Shutdown J-'"' Stimulate - Other Re-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory Stratigraphic J " Service 213-167-0 3. Address: 6. API Number: 50-103-20628-01 P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380052, 380054 2L -322A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 9515 feet Plugs (measured) none true vertical 5247 feet Junk (measured) none Effective Depth measured 9485 feet Packer (measured) 5982, 6034 true vertical 5245 feet (true vertical) 4893, 4921 Casing Length Size MD TVD Burst Collapse CONDUCTOR 103 16 146 146 SURFACE 2571 10.75 2613 2358 INTERMEDIATE 6170 7.625 6215 5010 PROD. LINER 3453 4.5 9485 5245 RECEIVED Perforation depth: Measured depth: open hole 6775-9485 JUN`' 13 2014 True Vertical Depth: 5190'-5245 V 2VV Tubing (size, grade, MD, and TVD) 3.5, L-80, 6049 MD, 4929 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 5982 MD and 4893 TVD PACKER - BAKER HRD-E ZXP LINER TOP PACKER @ 6034 MD and 4921 TVD NIPPLE - CAMCO DS NIPPLE @ 531 MD and 530 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 6775'-9485' Treatment descriptions including volumes used and final pressure: 1005560# Of 16/20 proppant 13. ntative Daily Average Production or Injecl 0 Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation new well Subsequent to operation 3807 2555 717 -- 939 14. Attachments 15. Well Class after work: Exploratory J`— Development Service r Stratigraphic Copies of Logs and Surveys run 16. Well Status after work: Oil J✓ Gas r WDSPL Daily Report of Well Operations XX GSTOR r WIND r WAG GINJ SUSP SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-262 Contact Adam Klem C@_ 263-4529 Email Adam. Klem(cr�conocophiIlips. com Printed Name Am Klem Title Completions Engineer Signature Phone: 263-4529 Date i VHF 611,7114 Form 10-404 Revised 10/2012 A*#— 4r` lflly Submit Original Only 2L -322A FRAC SUMMARY • DATE SUMMARY 5/4/2014 SET BAITED PULLING TOOL ON BALL n' ROD @ 5941' SLM; PULLED SOV & SET DV @ 5867' RKB. IN PROGRESS. 5/5/2014 MITT TO 4000 PSI (PASS) MITx IA TO 3500 PSI (PASS) PULLED CATCHER W/ BALL N' ROD; PULL RHC PLUG BODY @ 6010' RKB. (UNABLE TO PUMP INTO WELL DUE TO WELLBORE ISO VALVE) DRIFTED TBG WITH 2.65" BLR ASSEMBLY DOWN TO 6315' SLM BEFORE STALLING OUT. JOB COMPLETE. 5/14/2014 Performed first 4 of 8 stages of fracture treatment with 27# linear/x-linked gel placing 504,360 lbs of 16/20 proppant. Well freeze protected, will reload frac tanks and sand to return for final stages of frac. 5/17/2014 Performed final 4 stages of fracture treatment with 30# linear/x-linked gel placing 501,200 lbs of 16/20 proppant as per design. Well freeze protected. 5/23/2014 WAITED 8 HRS TO GET ASRC TO FINISH RIGGING UP AND GETTING FLUIDS ON LOCATION, MIRU CTU #5, RU & TEST BHA, TOO LATE TO START THE JOB, JOB IN PROGRESS. 5/24/2014 RIH TO MILL OUT FRAC SLEEVES/BALLS, MILLED THROUGH 4 OUT OF 7 SLEEVES, (AVERAGED 10 MINUTES PER FRAC SLEEVE), HEAVY FRAC SAND IN RETURNS WHILE MAINTAINING 1:1, ASRC UNABLE TO PROVIDE SUPPORT TO FINISH THE MILLING IN 1 DAY, SWEEP THE HOLE WITH GEL AND CHASE IT OUT @ 70%, RETURN IN AM WITH NEW PLAN OF FLUIDS IN UPRITES, JOB IN PROGRESS. 5/25/2014 RIH TO MILL OUT FRAC SLEEVES/BALLS, MILLED THROUGH THE LAST 3 SLEEVES, (AVERAGED 13 MINUTES PER FRAC SLEEVE), LIGHT FRAC SAND IN RETURNS WHILE MAINTAINING 1:1, RIH TO ISO VALVE @ 9425' CTMD (9437 RKB), SWEEP THE HOLE WITH 50 BBLS GEL AND CHASE IT OUT @ 50%, READY TO SECURE WELL AND PERFORM TREE SWAP, JOB COMPLETE. 5/26/2014 GAUGED TBG TO 2.77" TO D NIPPLE @ 6010' RKB. SET 2.75" CA -2 PLUG & CATCHER @ SAME. MIT TBG, PASSED. MIT IA, PASSED. PULLED DV @ 5867' RKB. READY FOR BPV. 5/29/2014 (SEC) T POT PASSED, T PPPOT PASSED, T (ABOVE BPV) DDT IN PROGRESS, T (BELOW BPV) X IA DDT IN PROGRESS. 5/30/2014 BPV INTEGRITY TEST(FAILED) 5/30/2014 RIGGED UP TO TREE CAP, PUMPED 290 BBLS DOWN TBG UP IA TAKING RETURNS TO F/L IN WELL 321. COMPLETE CIRC OUT, PERFORMED MIT COMBO T x IA, PASS'D, DID DRAW DOWN TEST, 30 MINUTES, PASS'D. RDMO JOB COMPLETE. 5/31/2014 (SEC) T X IA DDT PASSED, T (ABOVE BPV) DDT PASSED, THA AND TREE SWAP. NOTE: REMOVED 10K FRAC TREE AND INSTALLED 5K PRODUCTION TREE. 6/1/2014 TREE SHELL TEST(PASSED), T -POT (PASSED) T-PPPOT (PASSED) 6/2/2014 ASSIST VLV CREW IN PULLING BPV; SET OV @ 5867' RKB (OBTAIN GOOD TBG TEST); PULL CATCHER & CA -2 PLUG @ 6010' RKB; DRIFT TBG (STOPPED DUE TO DEVIATION) & MEASURE BHP @ 6034' RKB: 2992 PSI. READY FOR FLOWBACK. KUP PROD • 2L -322A LOWCOM111Ip5 T Well Attributes Nlax Angle & MD ITO N iSkB, Inc. •• Wellbore API/UW Field Name 501032062801 TARN PARTICIPATING AREA Wellbore Status PROD ncl (') MO (ftKB) Act Btm (RKB) 91.29 7,606.16 9,486.0 Comment SSSV: NIPPLE 112S (ppm) I Date Annotation Entl Date Last W0: 3/16/2014 KB-Grd (ft) Rig 40.89 Release Date 5/3/2011 2L -322A, 6/3/20146.48.23 AM ertica sc magic acwa Annotation Depth (ftKB) End Date Last Tag: Annotation Rev Reason: SIDETRACK, GLV C/O, PULL PLUG, ADD PERFS Last Motl By haggea End Date 5/28/2014 "-- HANGER; 252- -- SU RFACE; 30.4-2,601.5 CONDUCTOR; 31.2-134.2 NIPPLE; 530.7 GAS LIFT; 2.934.2 GAS LIFT; 4,230.7 GAS LIFT; 5,188.4 GAS LFT; 5,867.3 SLEEVE - C; 5,958.4 PACKER, 59819- NIPPLE; 6,009.7 LOCATOR; 6.030.0 LOCATOR; 6.031.0 MULE SHOE, 8,048.0 INTERMEDIATE; 27.5-6,2147 PERFP; FRAC;115 -7,1177 7.115.4 FRAC; PERP; 7.477.9-74 2 80. FRAC; 7,,47 .9 PERP; 7.812.1-7,814.4 FRAC; 7,812.1 PERP; 8,150.8-8,153.1 FRAC, 8,150.8 FRAC, PERP; 8,AC,8,8,4555.7 7 45 FRAC; 8,791.2 PERP; 8,791.28,7936 PERP; 9,126.0-9,128.4 FRAC; 9,126.0 LINER; 6,0337-9,486.5 as ng ngs Casing Description00 (in) ID (in) Top (ftKB Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR 16 15.250 31.2 134.2 134.2 62.50 H-40 Welded Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (L.. Grade Top Thread INTERMEDIATE 7518 6.875 27.5 6,214.7 5,010.11 29.70 L-80 Hydril563 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WI (I... Grade Top Thread LINER 41/2 3.958 6,033.7 9,486.5 5,245.0 12.60 P-110 Hydril 521 Liner Details Nominal ID Top (ftKB) Top (TVD)(ftKB) Top Incl I') Item Des Com (in) 6,033.7 4,921.1 57.69 PACKER BAKER HRD-E ZXP LINER TOP PACKER 4.800 6,055.5 4,932.6 58.33 HANGER BAKER FLEX -LOCK LINER HANGER 4.800 6,065.1 4,937.7 58.60 XO REDUCING XO 17# HYDRIL 563 BOX X 12.6# HYDRIL 521 PIN 3.920 6,774.3 5,190.0 78.09 Swell Packer BAKER SWELL PACKER 3.958 7,115.4 5,224.2 86.23 FRAC PORT FRAC POINT 2.50" Seat #7 2.400 7,288.5 5,227.0 90.88 Swell Packer BAKER SWELL PACKER 1958 7,477.9 5,223.3 91.13 FRAC PORT FRAC POINT 2.375' Seat #6 2.275 7,655.6 5,219.9 90.52 Swell Packer BAKER SWELL PACKER 3.958 7,812.1 5,221.0 89.17 FRAC PORT FRAC POINT2.250" SEAT #5 2.150 7,992.3 5,222.2 89.65 Swell Packer BAKER SWELL PACKER 3.958 8,150.8 5,223.1 89.44 FRAC PORT FRAC POINT 2.125' Seat #4 2.025 8,298.8 5,225.0 89.42 Swell Packer BAKER SWELL PACKER 3.958 8,455.7 5,225.6 89.83 FRAC PORT FRAC POINT 2.00" Seat #3 1.900 8,633.1 5,225.1 90.20 Swell Packer BAKER SWELL PACKER 1958 8,791.3 5,223.6 90.96 FRAC PORT FRAC POINT 1.875' Seat #2 1.775 8,968.7 5,221.6 89.98 Swell Packer BAKER SWELL PACKER 3.958 9,126.1 5,222.7 89.12 FRAC PORT FRAC POINT1.75" Seat #1 1.650 9,303.1 5,229.5 85.50 Swell Packer BAKER SWELL PACKER 3.958 9,429.0 5,240.2 85.15 FRAC SLEEVE PRESSURE ACTIVATED FRAC SLEEVE 3.850 9,441.5 5,241.3 85.18 VALVE WELLBORE ISOLATION VALVE 3.850 Tubing Strings Tubing Description TUBING 4.5x3.5@ 59.4 String Ma... 31/2 ID (in) 2.990 Top (ftKB) 25.2 Set Depth (R.. 6,049.0 Set Depth (TVD) (... 4,929.2 Wt (Ib#t) 9.30 Grade L-80 Top Connection EUE Completion Details :. Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (') Item Des Com (in) 25.2 25.2 0.00 HANGER FMC TUBING HANGER 3.958 59.4 59.4 0.07 XO Reducing XO 4.5' IBTM box X 3.5' 8rd EUE pin 2.990 530.7 530.4 3.72 NIPPLE CAMCO DS NIPPLE 2.812 5,958.4 4,879.7 55.58 SLEEVE - C BAKER CMU SLIDING SLEEVEW/DS PROFILE 2.813 (CLOSED) 5,981.9 4,892.9 56.24 PACKER BAKER PREMIER PACKER 2.870 6,009.7 4,908.2 57.02 NIPPLE CAMCO D NIPPLE 2.750 6,030.0 4,919.1 57.59 LOCATOR MECHANICAL LOCATOR ABOVE LOCATOR 3.000 6,031.0 4,919.7 57.62 LOCATOR MECHANICAL LOCATOR BELOW LOCATOR w/(4) 3/8" 3.000 SHEAR SCREWS 6,048.0 4,928.7 58.11 MULE SHOE MULE SHOE w/WLEG 3.000 :Perforations & Slots Shot Den Top (TVD) St. (TVD) (shotsR Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,115.4 7,117.7 5,224.2 5,224.4 5/14/2014 PERFP FRAC PORT 7,477.9 7,480.2 5,223.3 5,223.2 5/14/2014 PERP FRAC PORT 78121 7,814,4 5,221.0 5,221.0 5/14/2014 PERP FRAC PORT 8,150.8 8,153.1 5,223.1 5,223.2 5/14/2014 PERP FRAC PORT 8,455.7 8,458.0 5,225.6 j 5,225.6 j 5/14/2014 PERP FRAC PORT 8,791.2 8,793.6 5,223.6 5,223.6 5/14/2014 PERP FRAC PORT 9,126.0 9,128.4 5,222.7 5,222.7 5/14/2014 PERP I FRAC PORT Stimulations & Treatments Min Top Max St. Depth Depth Top (TVD) Btm (TVD) (ftKB) (R(B) (ftKB) (ftKB) Type Date Com 7.812.1 7.814.4 5,221.0 5,221.0 FRAC 5/14/2014 FRAC w/504,360 16/20 proppant 8,150.8 8,153.1 5,223.1 5,223.2 FRAC 5/14/2014 FRAC w/504,36016/20 proppant 7,115.4 7,117.7 5,224.2 5,224.4 FRAC 5/14/2014 FRAC w/504,36016/20 proppant 7,477.9 7,480.2 5,223.3 5,223.2 FRAC 5/14/2014 FRAC w/504,360 16/20 proppant 9,126.0 9,128.4 5,222.7 5,222.7 FRAC 5/17/2014 FRAC w/501,062# 1620 proppant 8,455.7 8,458.0 5,225.6 5,225.6 FRAC 5/1712014 FRAC w/501,062# 1620 proppant 8,781.2 8,793.6 5,223.6 5,223.6 FRAC 5/17/2014 FRAC w/501,062# 1620 proppant Mandrel Inserts St ati on Top (TVD) Valve Latch Port Size TRO Run N Top (ftKB) (ftKB) Make Model OL!!!) Sam Type Type (in) (psi) Run Date Com 2,934.2 2,608.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/22/2014 2 4,230.7 3,604.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/22/2014 3 5,188.4 4,341.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/22/2014 4 5,867.3 4,826.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/4/2014 0• Corocd hilli s 2 EC IVE MAY 14 2014 TRANSMITTAL A®GCC CONFIDENT/AL DA TA FROM: Sandra D. Lemke, AT03-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7' Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2L -322A DATE: 05/14/2014 Kuparuk River Unit, Alaska 1 hardcopy report with digital data on CD DATALOGGED 5/%-412014 M K BENDER Canrig Final well report mud logging data; 4/7/2014; table of contents, mud logging equipment; general well details, data, pressure/formation strength, drilling data, show reports, daily reports and formation logs; color log Formation log MD/TVD Gas ratio MD/TVD Drilling dynamics MD/TVD CD contains daily reports, DML data, final well report, LAS files, Log PDF files, remarks, TIFF files, show report Please promptly sign, scan and return electronically to 5andra.D.Lemke(&Q0 cam CC: 2L -322A transmittal folder, production well files, eSearch % Receipt: � �� Date: s/ l y k v _ GIS -Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907 265,6947 L --A • FINAL WELL REPORT MUDLOGGING DATA 2L -322A Provided by: C)kWIG DRILLING TECHNOLOGY LTD. Approved by: Liard Little Compiled by: Distribution: 5/5/14 T. D. Date 213-167-tq -�y2(o1161 RECEIVE MAY 14 2014 AOGCC Britten Adams Daniel Hillegeist 04/07/2014 • • r � U Cvnacllips X.9". irc. 2L -322A TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................ 1.1 Equipment Summary ..................................... 1.2 Crew........................................................... 2 WELL DETAILS .................................................. 2.1 Well Summary .............................................. 2.2 Hole Data .................................................... 2.3 Daily Activity Summary ................................. 3 GEOLOGICAL DATA .......................................... 3.1 Lithostratigraphy.......................................... 3.2 Mudlog Summary ......................................... 3.2.1 Campanian Sand ................................... 3.2.2 C-50 ..................................................... 3.2.3 C-40 ..................................................... 3.2.4 C-37 ..................................................... 3.2.5 Iceberg ................................................. 3.2.6 T-7 ....................................................... 3.2.7 T-4.1 .................................................... 3.2.8 T-3.1 .................................................... 3.2.9 Bermuda ............................................... 3.2.10 T-2 ....................................................... 3.3 Isotube Summary ......................................... 3.4 Sampling Program / Sample Dispatch........... 4 PRESSURE / FORMATION STRENGTH DATA..... 4.1 Pore Pressure Evaluation ............................. 4.2 Pore Pressure Plot ...................................... 4.3 Quantitative Methods ................................... 5 DRILLING DATA ................................................ 5.1 Survey Data ................................................ 5.2 Bit Record .................................................. 5.3 Mud Record ................................................ 6 SHOW REPORTS .............................................. 7 DAILY REPORTS .............................................. Enclosures: 2"/100' Formation Log (MD/TVD) 2'7100' Drilling Dynamics Log (MD/TVD) 2"/100' LWD / Lithology Log (MD/TVD) 2'7100' Gas Ratio Log (MD/TVD) Final Data CD .2 .2 .2 .3 .3 .3 .4 .7 .7 .8 .8 10 12 12 13 14 15 16 16 21 24 27 28 28 29 30 31 31 34 35 37 39 1 • • nwocoPhillips 2L -322A 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Years QGM Agitator (Mounted in possum belly) Technician Days Ditch gas Flame ionization total gas & 0 — 1 chromatography. Travis Smith 5 Effective Circulating Density From Schlumberger 6214' MD to TD 0 — ECD 15 Howard Lamp 7 From Schlumberger & Encoder from 0 — Hook Load / Weight on bit (Canrig Drilling Technology LTD. Derived from Strokes/Minute and Pump 0 — Mud Flow In Output Mud Flow Out Nabors 9ES 0 — Mudlogging Unit Computer HP Compaq Pentium 4 0 — System X2, DML & Ri watch Mudlogging Unit DAC box In -unit data collection/distribution center 0 — Canrig Drilling Technology LTD pit 0 — Pit Volumes, Pit Gain/Loss sensors. Pump Pressure Nabors 9ES 0 — Pump stroke counters Nabors 9ES Stroke counter #1 & #2 0 — Rate of Penetration Nabors 9ES 2.5 hrs. — RPM Nabors 9ES 0 — Torque Nabors 9ES 0 — 1.2 Crew Unit Type : Steel Arctic Unit Number ML059 Mudloggers Years' Days -2 Sample Catchers Years DaysRZ Technician Days Britten Adams 3 29 Ben Calo 1 3 Travis Smith 5 Daniel Hillegeist 3 31 Dean Kekaulua 6 15 Howard Lamp 7 '' Years experience as Mudlogger .Z Days at wellsite between spud and total depth of well 4 .r- ConocoPhilllps .»jlsk3.Er�r, 2L -322A • 2 WELL DETAILS is • 2.1 Well Summary Well: 2L -322A API Index #: 50-103-20628-01-00 Field: Kuparuk River Field Surface Co -Ordinates: 209' FNL, 821' FEL, Sec 22,T10N,R7E,UM Borough: North Slope Primary Target Depth: 6636' State: Alaska TD Depth: 9515' Rig Name / Type: Nabors 9ES, Arctic Triple Suspension Date: — Primary Target: Base Bermuda License: — Spud Date: 3/21/2014 Ground Elevation: Pad 120.9' MSL Completion Date: 4/19/2014 RT Elevation: RKB 148.9' MSL Completion Status: Run 4.5" Tubing to TD. Secondary Target: Depth: None Classification: Production TD Date: 4/7/2014 TD Formation: Bermuda Days Testing: None Days Drilling: 18 Surface 14.9 2.2 Hole Data CAMG Maximum Depth Mud Shoe Depth FIT / MD MD TVD Hole TD Weight Dev. o Casing/ Coring LOT Section (ft)ft) FDSS Formation (ppg) (inc) Liner (ft) SS (Pp9) (ft) 10.75" 2613' -- C. Sand 9.5 39.05 none -- Surface Surface 14.9 9.75" 6214' -4867' T-4.1 10 60.33 none 7 5/8" 2655' -2244' 14.7 6.50" 1 9515' 1 -5003' 1 Bermuda 1 11.9 1 85.20 1 none 4.5" 2655' -2244' 16.0 CAMG • • • GonocoPhillips Ak96kj., ani— 2L -322A 2.3 Daily Activity Summary 3/21/2014 Test BOPs, install and remove wear bushing, then lay down test joints. Pick up 66 joints of 4" drill pipe. Pull out of hole. Perform well control drill. Pick up drill pipe. Trip in hole to 2461' and tag cement lightly. Test standpipe manifold. Rig up and test mud lines to 3500 PSI. Line leaked. Circulate and condition. Tighten 4" bonnet on pump #2. Retest and bonnet still leaking. Continue to troubleshoot and test mud lines. 3/22/2014 Pressure test mud lines and top drive to 3500 PSI, good test. Displace well with 9.5 PPG LSND mud. Check volumes on pits and tiger tank and volume did not match. Continue to pump 100 BBLS to complete displacement. Monitor well, it was static. Trip out of hole to surface. Pick up BHA to drill out retainer. Run in hole, then circulate and condition. Test casing to 3000 PSI, good test. Rig down test equipment and blow down lines. 3/23/2014 Drill cement from 2516' and tag retainer at 2518'. Drill retainer and cement to 2607'. Continue to 2636' slide drilling. Slide from 2636' to 2714', building curve. Rotary drill from 2714' to 2785'. Perform LOT at 700 PSI, EMW=16. Trip out of hole and lay down BHA. 3/24/2014 Lay down BHA. Pick up BHA. Trip in hole. Surface test MWD tool at 937'. Trip in hole to 2565'. Cut and slip drilling line. Service top drive. Trip in hole to 2785'. Begin to drill ahead from 2785' to 3175'. 3/25/2014 Drill ahead from 3175' 4666'. Prepare for short trip. 3/26/2014 Short trip from 4666' to 2673'. Drill from 4666' to 5142'. Pump pop off valve damaged. Rebuild pop off valve, rebuild 4" demco on mud line. Drill ahead from 5142' to 5236'. 3/27/2014 Drill ahead from 5237' to 6224'. TD for casing. Circulate and condition. Back ream out two stands. Pull out of hole on elevators, hole conditions look good. Trip out of hole using elevators. Tight hole at 5845', 5785' and 4960'. Pulled over 20K over, worked pipe back down and pulled clean. 3/28/2014 Pull out of hole and lay down BHA. Prepare to run casing. Test BOPs. Rig up to run casing. Make dummy run with hanger. Service top drive. Rig up for running Tesco tool. 3/29/2014 Pick up Tesco running tool. Rig up/down to run casing. Run casing to 6214.65'. Circulate and condition. Prep rig floor for cement job. Rig down casing job. Rig up for cement job. 3/30/2014 Pressure test cement lines. Prepare 96 bbls of 15.8 PPG cement. Perform cement job, pump 85 bbls cement. Rig down casing/cement job. Change rams from 7 5/8 to 3 '/ x 6. Pick up test tools. Test BOPs. 3/31/2014 Test BOPs. Service top drive. Down time due to top drive. Bring down frozen kelly hose to rig floor to thaw and steam whip frozen standpipe. Pick up BHA and service top drive. Pick up drill pipe. Cut 11 wraps of drilling line. Prepare to run in hole with 4" drill pipe. CAMG 4 Conocophlllips A0WJr-,-. 2L -322A 4/11/20114 Trip in hole from 1000', tag cement at 6119'. Drill out of cement from 6119' to 6244'. Circulate one bottoms up for FIT test. Short trip, stand one stand back and flow check well for 15 minutes. Rig up and perform FIT test with 10 ppg mud. 4/2/2014 Perform FIT test. Change hole to 11.2 Klashield mud. Drill from 6244' to 6746'. Saw maximum gas of 1920 units at 6745'. Weight up to 11.4 ppg mud. Drill ahead from 6746' to 6808'. 4/3/2014 Drill from 6808 to 6966'. Observed 3218 units downtime gas at 6966'. Weight up to 11.6 ppg mud. Drill from 6966' to 7140'. Weight up to 11.8 ppg mud due to high gas. Make MADD pass from 7065' to 7050'. Take two samples. Monitor well then weight up to 11.9 ppg mud due to high gas. Monitor well. Drill from 7140' to 7253'. 4/4/2014 Drill from 7253' to 7667' and circulate bottoms up. Make MADD pass from 7667' to 7603'. Drill from 7667' to 8005'. 4/5/2014 Drill from 8005' to 8181'. Circulate bottoms up. Perform pressure logs. Drill from 8181' to 8700'. 4/6/2014 Drill ahead from 8700' to 8970'. Circulate and condition mud due to high ECDs. Drill from 8970' to 9254'. 4/7/2014 Drill ahead from 9254' to 9516' TD. Pump high viscosity sweep then weight up mud to 12.1 ppg. Monitor well for one hour. Weight up mud to 12.2 ppg and perform a 200 bbl dilution. Circulate bottoms up then monitor well. Weight up mud to 12.3 ppg. 4/8/2014 Weight up to 12.3 ppg mud. Lost returns. Circulate mud at 1 bpm. Pump 45 bbl, 35 ppb LCM pills. Lower mud weight to 12.1 ppg. Stage pumps up to 180 gps at'/ bbl stages to get ECD readings. Monitor well, conduct well bore breathing test. Circulate bottom up at 2 bpm. 4/9/2014 Circulate mud at 2 bpm, observed maximum of 4626 units gas. Monitor the well for breathing and observed 9 bbls flow back. Circulate at 2 bpm and pump LCM pill. Circulate and condition. 22 bbls loss during circulation. Monitor well for 225 minutes, recorded max flow back of 10.8 bbls/hr and final flow back rate 0.3 bbls/hr. Circulate and condition and observed 1607 units of gas maximum and 18 bbls mud lost. 4/10/2014 Circulate mud at 2 bpm and pump out of hole to 7667'. Circulate bottoms up 2.5 times. Pump out of hole to 6141' shoe. Circulate at 2 bpm and observe pit gain. Shut down and monitor well for breathing. 15 bbls flowed back in 22 minutes. Circulate and condition. 4/11/2014 Circulate at 2 bpm and then pump two 20 bbl high viscosity sweeps. Monitor well for breathing. Pump 500' of high viscosity pill out while back reaming out of hole to 5001'. Weight up to 12.2 ppg mud. Monitor well for breathing. Trip into hole to spot pill. 4/12/2014 Trip in hole to 7381'. Circulate and condition mud at 1 bpm. Weight up to 12.2 ppg mud. Pump high viscosity LCM pill while pulling out of hole from 7381' to 5377'. Circulate and condition at 1 bpm, weight up mud to 12.4 ppg. 0 CAMG _.- GxxxoPhillips AWWIrc 2L-322A 4/13/2014 Weight up mud to 12.4 ppg. Circulate and condition, monitor well for 0.5 hrs and confirm positive flow. Circulate and condition, weight up mud to 12.6 ppg. Monitor well and observe positive flow. Circulate and condition, weight up mud to 12.7 ppg. Trip in hole from 5377' to 6192', test BOPs. 4/14/2014 Test BOPs. Pull storm packer and monitor well, no high gas observed. Circulate and condition mud at % bpm to maintain mud at 12.7 ppg. 4/15/2014 Circulate and condition mud, pumping % bpm. Monitor well, and then begin to back ream out of hole from 6214' to 5187'. Circulate and condition, and then monitor well. Back ream out of hole from 5187' to 733'. Continue to back ream out of hole. 4/16/2014 Back ream out of hole to 558'. Monitor well and then lay down BHA. Service rig, then continue to lay down BHA. Rig up and run in hole with 4'/" liner. 4/17/2014 Continued picking up 4 %' liner. Picked up liner hanger and ran in hole on 4" drill pipe to 5,452'. Continued running liner in hole on drill pipe to 6,203. 4/18/2014 Continued to circulate bottoms up at 1 bpm. Continued to run liner in hole to 9,485' and set hanger and released. Set liner top packer and test. CorwxoPNIl1F35 2L-322A 0 3 GEOLOGICAL DATA • 0 3.1 Lithostratigraphv LWD tops refer to provisional picks by the mudlogger. FORMATION PROGNOSED LWD PICK MD (ft) TVD (ft) MD (ft) TVD (ft) Campanian Sand 2805' 2502' 2808' 2513' C-50 4280' 3643' 4333' 3684' C-40 4830' 4068' 4828' 4065' C-37 5154' 4319' 5153' 4315' Iceberg -- -- 5222' 4368' T-7 5695' 4723' 5689' 4714' T-4.1 6095' 4958' 6150' 4982' T-3.1 6502' 5123' 6488' 5109' Top Bermuda 6623' 7093' 6636' 5155' T-2 7500' 5216' 7160' 5226' CorwxoPhillips Alaska, 1ri :. 2L -322A 3.2 Mudlop Summary 3.2.1 Campanian Sand 2RnR' to 4333' MD (-2369' to -3540' TVDSS) Drill Rate (ft/hr) Total Gas (units) MaximumMinimum Average Maximum Minimum Average 214.4 0.4 109.2 109 0 26.5 From 2808'-3500' MD, Campanian Sand is dominated by claystone/clay with thin layers of siltstone 10%-20% and sands/sandstone 10%-20%. Background gas is 18-30units. Sandstone/sands increased as depth increase from 3500'-4333' MD. Sands/sandstone max at 40%-50%, siltstone 10%-20%, and background remain at 20- 30 units. Claystone (2850-2900) = medium gray to medium dark gray with olive gray undertones; no induration; malleable to flexible tenacity; massive to nodular cuttings habit; smooth to clayey texture; greasy to waxy luster; cohesive to pliable clay properties; clotted to pasty consistency; massive to thick bedding; no oil indicators. Claystone (2900-2950) = olive gray to medium dark gray; no induration; malleable to flexible tenacity; massive to wedgelike cuttings habit; smooth and clayey to gritty; greasy to waxy luster; cohesive to pliable clay properties; clumpy to mushy consistency; massive to thick bedding; trace very fine grain sand; no oil indicators. Claystone (2950-3000) = medium gray to medium dark gray with olive gray undertones; no induration; malleable to flexible tenacity; massive to wedgelike cuttings habit; clayey to gritty texture; waxy to dull luster; cohesive to pliable clay properties; curdy to pasty consistency; massive bedding; very fine grain sand; no oil indicators. Claystone (3000-3050) = medium light gray to medium gray with light olive gray undertones; no induration; malleable to elastic tenacity; massive cuttings habit; clayey to silty texture; waxy to frosted luster; adhesive to pliable clay properties; clumpy to curdy consistency; massive bedding; siltstone; sand; trace tuff; no oil indicators. Claystone (3050-3100) = medium light gray to medium gray; no induration; malleable to flexible tenacity; massive to wedgelike cuttings habit; clayey to silty texture; greasy to waxy luster; adhesive to plastic clay properties; lumpy to clotted consistency; massive bedding; no oil indicators. Claystone (3100-3150) = olive gray to medium dark gray; no induration; malleable to flexible tenacity; massive to nodular cuttings habit; clayey to silty texture; greasy to waxy luster; cohesive to plastic clay properties; lumpy to clotted consistency; massive bedding; trace siltstone; trace fine to medium grain sand; no oil indicators. Claystone (3150-3200) = olive gray to medium dark gray with light gray undertones; malleable tenacity; massive to wedgelike cuttings habit; clayey to gritty texture; greasy to waxy luster; adhesive to pliable clay properties; clumpy to clotted consistency; massive bedding; siltstone; trace fine grain sand; no oil indicators. Claystone (3200-3250) = medium gray to medium dark gray; no induration; malleable tenacity; massive to tabular cuttings habit; clayey to silty texture; greasy to waxy luster; adhesive to plastic clay properties; clumpy to clotted consistency; massive bedding; sandstone; trace siltstone; no oil indicators. Claystone (3250-3300) = olive gray to medium dark gray with brownish gray undertones; no induration; malleable to flexible tenacity; massive to wedgelike cuttings habit; silty to gritty texture; waxy to dull luster; cohesive to pliable clay properties; lumpy to clotted consistency; massive bedding; sandstone; trace siltstone; no oil indicators. CCorvcoPhiillips 2L -322A Claystone (3300-3350) = olive gray to medium dark gray; no induration; malleable to sectile tenacity; massive to tabular cuttings habit; clayey to gritty texture; waxy to earthy luster; adhesive to pliable clay properties; lumpy to clotted consistency; massive bedding; 20% sandstone; trace siltstone; no oil indicators. Sandstone (3350-3400) = olive gray to medium dark gray with light olive gray undertones; very fine to fine grain size; moderate sphericity; subrounded to rounded; moderate to well sorted; moderately consolidated; clay matrix; matrix supported; moderate textural maturity; moderate compositional maturity; 40% claystone; no oil indicators. Claystone (3400-3450) = olive gray to medium dark gray; no induration; malleable to flexible tenacity; massive to wedgelike cuttings habit; clayey to gritty texture; waxy to dull luster; cohesive to pliable clay properties; lumpy to pasty consistency; massive bedding; 10% sandstone; siltstone; no oil indicators. Siltstone (3455-3495) = olive gray to slight brownish gray with light olive gray hue and dark gray hues color; crumbly to slight crunchy tenacity; earthy fracture; wedgelike to blocky cutting habits; dull to earthy when dry luster; silty to gritty with slight clayey texture; thin bedding structure; no oil indictors. Sandstone (3525 3595) = medium dark gray to light olive gray with olive gray hue, dark gray hues, translucent clear to white hues, and black lithic colors; quartz dominant with traces of black lithics interbedded in framework; upper very fine to lower fine grain size; well to moderate sorting; subrounded to subangular angularity; moderate sphericity; consolidated sandstone with easily friable to friable hardness; cemented grain support; platy to wedgelike cutting habits; gritty to matte texture; thin bedding structure; no oil indictors. Claystone (3605-3655) = olive gray to light olive gray with olive black hues colors; lumpy to mushy consistency; cohesive to expansive clay properties; pulverulent to malleable tenacity; irregular fracture; nodular to rounded balls cutting habits; dull to earthy when dry luster; clayey to smooth with occasional silty texture; massive to 40 thick bedding structure; no HCL reaction; no oil indictors. Sandstone (3665-3720) = dark gray to olive black with brownish gray hues; black lithic, and translucent clear to slight white hues colors, quartz dominant framework; very fine to fine grain size; well to moderate sorting sub angular to subrounded angularity; moderate to high sphericity; consolidate with easily friable hardness; cement grain support; carbonaceous plant matter interbedded; bright yellowish tuff fluorescence; no cut color; no oil odor; no oil indictors; no HCL reaction. Claystone (3735-3790) = olive gray to olive black with brownish black hues colors; adhesive clay properties; lumpy clotted consistency; malleable to pulverulent tenacity; irregular fracture; massive to nodular cutting habits; dull to earthy when dry and waxy when wet luster; smooth to clayey with occasional silty grains texture; massive to thick bedding structure; no HCL reaction; no oil indictors. Sandstone (3800-3870) = medium gray to medium dark gray with olive gray hue, brownish gray hues, and occasional yellowish gray sandstone with clear to translucent white/smokey colors; quartz dominant framework; very fine to fine grain size; well to fair sorting subrounded to subangular angularity; moderate sphericity; consolidate with friable to firm friable hardness; dolomite to calcite cement grain support; sparkling gemlike luster when wet; contorted bedding structure; moderate to weak HCL reaction; no oil indictors. Siltstone (3880-3915) = brownish black to dark gray colors; brittle to crumbly tenacity; earthy to mottled fracture; tabular to wedgelike cutting habits; dull to earthy when dry luster; silty to matte texture; thin to soft sediment deformation bedding structure; no no HCL reaction; no oil indictors. Claystone (3925-3980) = brownish gray brownish black with dark gray hues colors; cohesive clay properties; clotted to mushy and clumpy consistency; malleable to pulverulent tenacity; irregular fracture; nodular to massive cutting habits; dull to earthy when dry and waxy when wet luster; clayey to smooth with occasional silty grains texture; thick to massive bedding structure; no reaction HCL; no oil indictors in bulk sample. • CorbocoP fillips A13iska.Of— 2L -322A Sandstone (3990-4045) = dark gray to grayish black with brownish gray hues, clear to translucent smokey hues, and black grains color; consolidated with easily friable to friable hardness; quartz framework; very fine to fine grain size; well to fair sorting; sub rounded to subangular angularity; low to moderate sphericity; cement grain support; thin to contorted bedding structure; no HCL reaction; no oil indictors in sample. Claystone (4055-4095) = cohesive to expansive clay properties; lumpy to clotted and mushy consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to nodular cutting habits; dull to earthy when dry luster; clayey to silty texture; massive to thick bedding structure; no HCL reaction; no oil indictors. Siltstone (4105-4145) = olive black to dark gray with brownish black hues colors; friable to easily friable hardness; crumbly to crunchy tenacity; earthy to drusy fracture; tabular to wedgelike cutting habits; frosted when wet and dull to earthy luster; matte to sucrosic texture; thin bedding structure no reaction HCL; no oil indictors. Sandstone (4155-4210) = light olive gray to medium gray with olive gray hues; traces of black lithics, clear to translucent smokey white, yellowish gray hues colors; very fine to fine grain size; quartz dominant framework; well to fair sorting; angular to subangular angularity; low to moderate sphericity; consolidated with easily friable to friable hardness; cement grain support; thick bedding structure; no HCL reaction; no oil indictors. Claystone (4220-4270) = olive gray to light olive gray with traces of olive black hue colors; expansive to cohesive clay properties; lumpy to clumpy consistency; malleable to pulverulent tenacity; irregular fracture; massive to nodular cutting habits; dull to earthy when dry; clayey to smooth with occasional silty grains texture; massive to thick bedding structure; no HCL reaction; no oil indictors. Claystone (4280-4320) = olive gray to light olive gray with dark gray hues; no to very poor induration; malleable to pulverulent; massive to wedgelike cuttings habit; clayey to gritty texture; waxy to dull luster; cohesive to pliable clay properties; clumpy to clotted consistency; massive to thick bedding structure; no oil indicators. Claystone (4330-4370) = olive gray to brownish black; no induration; malleable to flexible tenacity; massive to wedgelike cuttings habit; smooth to gritty texture; greasy to waxy luster; cohesive to expansive clay properties; clumpy and clotted consistency; massive to thick bedding structure; no oil indicators. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 2824 109 20054.947 204.748 79.836 2853 71 11854.986 146.060 93.840 3.2.2 C-50 dQ'A4' +n AR77' Mn (-3540' to -3920' T/nSSI Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 193.2 13.4 106.7 77 5 36.7 CAMG 10 Conocophllips �a�ska. sr•{:. 2L -322A Sands/sandstone disappears at 4400' MD and tuff enters at 4500' MD. Claystone is dominant at 80% and 10% siltstone until 4550' MD. Siltstone increase from 10%-40% and thin tuff layer is remove from the lithology. Around 4700'MD, sands/sandstone reenters the lithology and gas increase 20 units with siltstone becoming the dominant sediment. Claystone (4380-4420) = olive gray to medium dark gray with brownish black hues; no induration; pulverulent to malleable tenacity; massive to tabular cuttings habit; clayey to gritty texture; waxy to dull luster; cohesive to pliable clay properties; lumpy to mushy consistency; massive to thick bedding structure; no oil indicators. Claystone (4430-4470) = olive gray to brownish black; no induration; malleable to flexible and pulverulent when dry; massive to nodular cuttings habit; clayey and smooth to gritty texture; waxy to dull luster; cohesive to plastic clay properties; lumpy to clumpy consistency; siltstone; trace tuff; no oil indicators. Claystone (4480-4525) = medium gray to medium dark gray with medium light gray hues; no induration; malleable to pulverulent tenacity; massive to nodular cuttings habit; smooth to gritty texture; waxy to dull luster; pliable to expansive clay properties; clumpy to clotted consistency; massive to thick bedding structure; siltstone; trace tuff; no oil indicators. Claystone (4535-4575) = olive gray to brownish black with dark gray hues; no induration; malleable to flexible tenacity; massive to nodular and tabular cuttings habit; silty to gritty texture; waxy to dull luster; cohesive to pliable clay properties; lumpy to clumpy consistency; massive to thick bedding structure; siltstone; no oil indicators. Claystone (4585-4625) = medium gray to medium dark gray with brownish black hues; very poor induration; crumbly to malleable tenacity; massive to nodular cuttings habit; clayey to gritty texture; waxy to dull luster; cohesive to pliable clay properties; lumpy to clotted consistency; siltstone; no oil indicators. Claystone (4635-4675) = medium gray to medium dark gray with olive gray hues; no induration; pulverulent to malleable tenacity; massive to nodular cuttings habit; clayey to gritty texture; waxy to dull luster; cohesive to pliable clay properties; clumpy to clotted consistency; massive bedding structure; no HCL reaction; no oil indictors. Siltstone (4700-4760) = brownish black to dark gray with olive black hues colors; crumbly tenacity; easily friable to friable hardness; earthy to drusy fracture; elongated to bladed edges cutting habits; waxy to earthy luster; matte to sucrosic texture; thick bedding structure; no HCL reaction no oil indictors. Claystone (4770-4820) = grayish black to slight olive black colors; adhesive to colloidal clay properties; clotted to pasty consistency; malleable tenacity; irregular fracture; nodular to curved cutting habits; dull to earthy when dry and waxy when wet luster; clayey to smooth with silty grain interbedded texture; soft sediment deformation bedding structure; no HCL reaction; one orange to slight yellowish color in visual fluorescence; no oil odor; no cut color; no other oil indictors. aonka Depth TG C1 C2 C3 C41 C4N C51 C5N 4474 52.932 11177.538 250.280 4662 51.273 11171.471 391.448 4796 73.566 16491.117 334.422 127.734 0 11 c. • L r ConocoPhillips fLyska. 41('. 2L -322A 3.2.3 C-40 4828' to 5152' MD -3921' to -4170' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 453.8 38.6 137.4 90 2 48.9 C-40 is dominated with siltstone 70%-80%. Sands/sandstone is 10%-20% and claystone has 20% sediment in the formation. Gas average around 40-50 units and propane enter the gas column in this formation. Thin tuff layer is interbedded throughout this entire formation. Siltstone (4840-4885) = grayish black to medium dark gray with slight dark greenish gray hues color; easily friable to friable hardness; brittle to crumbly tenacity; earthy to slight hackly fracture; elongated to platy and flaky cutting habits; dull to earthy when dry luster; matte to sucrosic texture; thick to large bedding structure; no HCL reaction; no oil indictors. Siltstone (4895-4955) = grayish black dark gray with traces of dark greenish gray siltstone interbedded hues colors; brittle to crumbly with occasional slight crunchy tenacity; slightly hackly to earthy fracture; elongated to platy and wedgelike cutting habits; dull to earthy when dry and frosted when wet luster; matte to sucrosic texture; laminae and massive bedding structure; weak HCL reaction due to carbonaceous interbedded within; no oil indictors. Tuff (4965-5015) = smokey to yellowish light gray with dark gray hues color; sift to easily friable; crumbly to pulverulent tenacity; earthy to irregular fracture; nodular to elongated bladed cutting habits; waxy luster; smooth texture; very thin to soft sediment deformation bedding structure; moderate HCL reaction; orange to yellowish fluorescence colors; no oil indictors. Siltstone (5025-5065) = brownish black to grayish black with olive black hues colors; brittle to crumbly tenacity; slight hackly to earthy fracture; flaky to elongated cutting habits; dull to earthy when dry and frosted when wet luster; matte to sucrosic texture; thick massive bedding structure; no HCL reaction; no oil indictors. Claystone (5075-5120) = brownish black to dark gray colors; cohesive to expansive clay properties; clotted to mushy consistency; malleable tenacity; irregular fracture; nodular to rounded cutting habits; dull to waxy luster; smooth to clayey with gritty trace minerals texture; soft sediment deformation bedding structure; very weak HCL reaction; no oil indictors. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4827 77.298 16480.931 403.022 153.966 4951 73.929 14168.692 448.977 179.415 5047 90.467 17504.012 739.026 456.569 3.2.4 C-37 to 5221' MD (-4171' to -4224' Drill Rate (ft/hr) I Total Gas (units) Maximum Minimum Average I Maximum I Minimum I Average CANtIG 12 CQnacoPhillips Xisk , irt- 2L -322A 0 1 181.4 1.1 117.1 47 23 38.2 C-37 is a thin formation with 80% siltstone and 20%-25% claystone. Background gas ranges from 30-40 units. Siltstone (5130-5180) = brownish black to grayish black with olive black hues; friable to firm friable; moderate to well induration; brittle to crunchy tenacity; flaky to scaly cuttings habit; gritty to sucrosic texture; dull luster when dry and resinous when wet luster; massive to thick bedding structure; claystone; trace tuff; trace yellow fluorescence; very weak HCL reaction; no oil indicators. Siltstone (5190-5225) = medium dark gray to dark gray with brownish black hues; friable to firm friable; moderate to well induration; brittle to crunchy tenacity; flaky to scaly cuttings habit; silty to sucrosic luster; massive to thick bedding structure; claystone; weak HCL reaction; no oil indicators. Peaks Depth TG I C1 I C2 I C3 I C41 I C4N C51 C5N 5202 42.667 1 9024.102 1 394.426 1 232.229 1 15.697 201.1 0.3 115.7 113 3.2.5 Iceberg 5222' t� 5689' MD (-4224' to -4569' TVDSS) In Iceberg formation, butane has it first appears in the well. From 5222'-5500' MD, siltstone and claystone are the dominant sediments. Around 5525' MD traces of tuff is deposit and sandstone enters the formation. Sandstone becomes dominant at the end of the formation with 80% sediment. Background gas throughout this formation is 40-60 units. Siltstone (5255-5295) = medium gray to medium dark gray with brownish black hues; friable to moderate hard; moderate to well induration; brittle to pulverulent; scaly to tabular cuttings habit; silty to sucrosic texture; earthy when dry to frosted when wet luster; massive to thick bedding structure; no oil indicators. Claystone (5305-5350) = medium dark gray to dark gray with brownish black hues; no induration; malleable to flexible tenacity; massive to tabular cuttings habit; smooth to gritty texture; dull to earthy when dry and greasy to waxy when wet luster; cohesive to pliable clay properties; clumpy to clotted consistency; massive to thick bedding structure; no oil indicators. Siltstone (5380-5425) = medium gray to medium dark gray with brownish gray hues; friable to moderate hard; moderate to well induration; dense to crunchy tenacity; platy to scaly cuttings habit; silty to gritty texture; earthy when dry to resinous when wet luster; massive to thick bedding structure; claystone; trace tuff; trace yellow sample fluorescence; no oil indicators. Claystone (5435-5485) = medium light gray to medium dark gray with brownish gray hues; no induration; malleable to flexible tenacity; massive to tabular cuttings habit; smooth to silty texture; earthy to dull when dry and greasy when wet luster; cohesive to expansive clay properties; curdy to mushy consistency; massive to thick bedding structure; siltstone; trace tuff; trace pyrite; no oil indicators. Claystone (5495-5540) = medium light gray to medium gray with brownish gray hues; no induration; malleable tenacity; massive to nodular cuttings habit; smooth to gritty texture; dull when dry and greasy when wet luster; pliable to expansive clay properties; clotted to mushy consistency; siltstone; trace tuff; trace yellow sample fluorescence; no oil indicators. CANW 13 Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum MinimumAverage 201.1 0.3 115.7 113 22 �60 In Iceberg formation, butane has it first appears in the well. From 5222'-5500' MD, siltstone and claystone are the dominant sediments. Around 5525' MD traces of tuff is deposit and sandstone enters the formation. Sandstone becomes dominant at the end of the formation with 80% sediment. Background gas throughout this formation is 40-60 units. Siltstone (5255-5295) = medium gray to medium dark gray with brownish black hues; friable to moderate hard; moderate to well induration; brittle to pulverulent; scaly to tabular cuttings habit; silty to sucrosic texture; earthy when dry to frosted when wet luster; massive to thick bedding structure; no oil indicators. Claystone (5305-5350) = medium dark gray to dark gray with brownish black hues; no induration; malleable to flexible tenacity; massive to tabular cuttings habit; smooth to gritty texture; dull to earthy when dry and greasy to waxy when wet luster; cohesive to pliable clay properties; clumpy to clotted consistency; massive to thick bedding structure; no oil indicators. Siltstone (5380-5425) = medium gray to medium dark gray with brownish gray hues; friable to moderate hard; moderate to well induration; dense to crunchy tenacity; platy to scaly cuttings habit; silty to gritty texture; earthy when dry to resinous when wet luster; massive to thick bedding structure; claystone; trace tuff; trace yellow sample fluorescence; no oil indicators. Claystone (5435-5485) = medium light gray to medium dark gray with brownish gray hues; no induration; malleable to flexible tenacity; massive to tabular cuttings habit; smooth to silty texture; earthy to dull when dry and greasy when wet luster; cohesive to expansive clay properties; curdy to mushy consistency; massive to thick bedding structure; siltstone; trace tuff; trace pyrite; no oil indicators. Claystone (5495-5540) = medium light gray to medium gray with brownish gray hues; no induration; malleable tenacity; massive to nodular cuttings habit; smooth to gritty texture; dull when dry and greasy when wet luster; pliable to expansive clay properties; clotted to mushy consistency; siltstone; trace tuff; trace yellow sample fluorescence; no oil indicators. CANW 13 Conoc flips nLyBka irn- 2L-322A Claystone (5550-5595) = medium light gray to medium gray with brownish gray hues; no induration; malleable to flexible tenacity; massive to nodular cuttings habit; smooth to silty texture; dull to earthy when dry and greasy when wet luster; cohesive to expansive clay properties; lumpy to mushy consistency; massive bedding structure; siltstone; no oil indicators. Sandstone (5605-5670) = medium dark gray to medium gray with yellowish gray hues, black lithics minerals, clear to translucent minerals, and light olive gray hues colors; quartz dominant with black carbonaceous minerals and tuff framework; upper very fine to upper fine grain size; moderate to well sorting; subangular to subrounded angularity; low to moderate sphericity; consolidate with firm friable hardness; moderate to strong HCL reaction; lenticular bedding structure; no oil indictors in bulk sample. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5264 71.388 14307.980 524.821 347.155 75.279 113.435 5380 107.627 18322.804 1156.580 526.823 110.888 208.469 38.261 84.794 5491 74.551 10316.955 573.318 343.510 48.713 123.335 41.463 67.103 3.2.6 T-7 5RR9' to si sn' MD (-4570' to -4838' TVDSS) T-7 formation begins with a thin layer of carbonaceous shale. Sandstone is dominant until 5850' MD. Gas peaked 182 units at 5800' MD with an increase in sands to 80%. From 5850'-6000' MD, siltstone is the dominant sediment with 70%-80%. From 6000'-6150' MD, siltstone and sands/sandstone become even in sediment deposits with trace to 10% claystone. Siltstone (5680-5720) = dark gray to olive black with olive gray hues colors; crumbly to brittle tenacity; friable hardness; earthy to slight hackly fracture; platy to wedgelike cutting habits; dull to earthy when dry luster; matte to sucrosic surface texture; thick to thin bedding structure; no HCL reaction; no oil indictors. Sand/sandstone (5730-5800) = light gray to very light gray dominant with pinkish grays hues; light pinkish gray hues; clear to translucent smokey hues colors; quartz dominant framework; lower medium to very fine grain size; poor to very poor sorting; subangular to angular angularity; low to moderate sphericity; unconsolidated 50% to 10% sandstone consolidation; thick and rip up bedding structure; no oil odor; no free oil; no cut color; yellowish visual fluorescence; light milky fluorescence cut with slow changing of color; moderate HCL reaction in bulky sample. Carbonaceous shale (5810-5845) = grayish black to black with slight olive black hues color; dense to crunchy tenacity; blocky to hackly fracture; bladed to tabular cutting habits; frosted to earthy luster; abrasive texture; very thin bedding structure; no HCL reaction; no oil indictors. Siltstone (5855-5900) = dark gray to medium dark gray with olive gray hues colors; crumbly to brittle tenacity; earthy fracture; elongated to flaky and platy cutting habits; dull to earthy when dry and frosted when wet luster; matte to slight sucrosic texture; thick to massive bedding structure; no HCL reaction; no oil indictors in sample. Sandstone (5910-5970) = light olive gray to olive gray with translucent smokey white to clear mineral, black minerals, and light green grayish minerals hues colors; quartz dominant framework; fine grain size; well to fair sorting; subrounded to subangular angularity; low to moderate sphericity; consolidated with firm friable to moderate hard hardness; cement grain support; thin to lenticular bedding structure; moderate HCL reaction; no 9 14 �GJ Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 203.5 0.3 118.3 182 1 62.9 T-7 formation begins with a thin layer of carbonaceous shale. Sandstone is dominant until 5850' MD. Gas peaked 182 units at 5800' MD with an increase in sands to 80%. From 5850'-6000' MD, siltstone is the dominant sediment with 70%-80%. From 6000'-6150' MD, siltstone and sands/sandstone become even in sediment deposits with trace to 10% claystone. Siltstone (5680-5720) = dark gray to olive black with olive gray hues colors; crumbly to brittle tenacity; friable hardness; earthy to slight hackly fracture; platy to wedgelike cutting habits; dull to earthy when dry luster; matte to sucrosic surface texture; thick to thin bedding structure; no HCL reaction; no oil indictors. Sand/sandstone (5730-5800) = light gray to very light gray dominant with pinkish grays hues; light pinkish gray hues; clear to translucent smokey hues colors; quartz dominant framework; lower medium to very fine grain size; poor to very poor sorting; subangular to angular angularity; low to moderate sphericity; unconsolidated 50% to 10% sandstone consolidation; thick and rip up bedding structure; no oil odor; no free oil; no cut color; yellowish visual fluorescence; light milky fluorescence cut with slow changing of color; moderate HCL reaction in bulky sample. Carbonaceous shale (5810-5845) = grayish black to black with slight olive black hues color; dense to crunchy tenacity; blocky to hackly fracture; bladed to tabular cutting habits; frosted to earthy luster; abrasive texture; very thin bedding structure; no HCL reaction; no oil indictors. Siltstone (5855-5900) = dark gray to medium dark gray with olive gray hues colors; crumbly to brittle tenacity; earthy fracture; elongated to flaky and platy cutting habits; dull to earthy when dry and frosted when wet luster; matte to slight sucrosic texture; thick to massive bedding structure; no HCL reaction; no oil indictors in sample. Sandstone (5910-5970) = light olive gray to olive gray with translucent smokey white to clear mineral, black minerals, and light green grayish minerals hues colors; quartz dominant framework; fine grain size; well to fair sorting; subrounded to subangular angularity; low to moderate sphericity; consolidated with firm friable to moderate hard hardness; cement grain support; thin to lenticular bedding structure; moderate HCL reaction; no 9 14 �GJ 0 C+ortocPhillips 2L -322A oil indictors. Siltstone (5980-6025) = grayish black to brownish black with dark olive hues colors; easily friable to friable hardness; brittle and crumbly tenacity; earthy to drusy fracture; platy to wedgelike cutting habits; dull to earthy when dry and frosted when wet luster; matte to slight sucrosic texture; thick bedding structure; no HCL reaction; no oil indictors. Sand (6035-6085) = translucent to clear with light olive gray hues, moderate yellow green hues and black lithic colors; unconsolidated sand; quartz dominant framework; upper medium to upper fine grain size; poor to very poor sorting; angular to subangular angularity; low to moderate sphericity; trace pyrite; lenticular bedding structure; low reaction HCL; no oil indictor in bulk sample. Siltstone (6095-6140) = olive black to dark gray colors; crunchy to slight stiff tenacity; hackly to earthy and drusy fracture; wedgelike to bladed edges with occasional platy cutting habits; dull to earthy when dry and frosted when wet luster; matte to sucrosic texture; thick to massive bedding structure; no HCL reaction; no oil indictors. Peaks Depth TG C1 C2 C3 C41 CM C61 C5N 5794 158.174 5303.566 1389.300 1493.352 430.803 756.479 395.438 41.533 6117 130.438 25254.596 1664.581 1159.831 198.930 444.143 128.095 132.937 3.2.7 T-4.1 6150' to R4RR' MD (-4Rw to -496.5' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 269.1 0.1 78.7 212 10 100.7 At the start of T-4.1, there is a peak of gas that correlates with 70%-80% sands/sandstone increase. Siltstone is the dominant sediment with 20%-10% claystone and trace tuffs. Sandstone (6150-6200) = clear to white with translucent smokey white, light olive gray, yellowish gray and light gray hue colors; consolidated 40% and rip up 60% with sands; quartz dominant; medium to fine grain size; fair to well sorting; subangular to angular angularity; low sphericity; moderate HCL reaction; traces of carbonaceous minerals interbedded; trace pyrite; no oil indictors. Siltstone (6245-6315) = brownish black to brownish gray with olive black hue and grayish black hues colors; soft to easily friable; crumbly to brittle tenacity; earthy fracture; wedgelike to blocky cutting habits; dull to waxy luster; matte to silty surface texture; thick to soft sediment deformation bedding structure; very weak HCL in sample; bright yellowish green visual fluorescence in bulk sample; no cut color; milky white cut fluorescence color with white streamers; oil odor; soltex contamination in mud properties; no other oil indictors. Claystone (6325-6385) = olive gray to medium dark gray with light olive gray hues colors; colloidal to pliable clay properties; clumpy to gelatinous consistency; malleable sectile tenacity; irregular fracture; tabular to wedgelike cutting habits; dull to earthy and slight waxy luster; clayey to smooth texture; thin bedding structure; in bulk sample few yellowish green in visual fluorescence; slow slight milk white cut fluorescence color; no cut color; no oil odor; weak to moderate HCL reaction. Siltstone (6395-6450) = olive gray to dark gray with brownish black and olive black hues colors; easily friable to friable hardness; brittle to crumbly tenacity; earthy to slight hackly fracture; tabular to wedgelike cutting habits; dull to earthy when dry luster; matte to silty texture; massive bedding structure; no oil odor; no free oil; no cut color; no visual fluorescence color; slow and very light milky color fluorescence cut with no streamers. is CAISM 15 0 ConocoPhillips ra3ska. r - 2L -322A Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6182 125.720 20715.953 1796.436 1248.511 250.191 542.207 155.560 151.797 6270 170.616 27513.246 1875.162 1095.005 53.139 290.060 97.457 95.134 6435 157.189 26003.234 1651.690 870.657 105.125 287.073 58.063 99.281 3.2.8 T-3.1 6488' to 6636' MD (-4965' to -5011' TVDSS) T 3.1 begins with a thin layer of carbonaceous shale. Siltstone is dominant with 60% deposited. Sandstone/sands and claystone each has 20% sediment in formation. Background is slightly high then T-4.1 with 114 units' average. Sandstone (6515-6570) = light olive gray to olive gray with clear to translucent hues and traces of black lithics interbedded colors; quartz dominant framework; very fine to fine grain size; well to fair sorting; rounded to subangular angularity; high to moderate sphericity; consolidate to easily friable; cement grain support; thin bedding structure; no HCL reaction; no oil odor; no free oil; no cut color; no fluorescence color; no oil indictors. Siltstone (6580 6630) = olive gray to brownish gray with olive black hues; firm friable to moderate hard; moderate to well induration; dense to crunchy tenacity; bladed to wedgelike cuttings habit; matte to gritty texture; dull to earthy texture when dry; massive to thick bedding structure; no HCL reaction; no oil odor; no free oil; no cut color; no fluorescence color; no oil indicators. Peaks Depth Drill Rate (ft/hr) Total Gas (units) C1 C2 Maximum Minimum Average Maximum Minimum Average 6535 143.554 167.6 0.3 113.4 172 2 114.8 73.435 60.689 T 3.1 begins with a thin layer of carbonaceous shale. Siltstone is dominant with 60% deposited. Sandstone/sands and claystone each has 20% sediment in formation. Background is slightly high then T-4.1 with 114 units' average. Sandstone (6515-6570) = light olive gray to olive gray with clear to translucent hues and traces of black lithics interbedded colors; quartz dominant framework; very fine to fine grain size; well to fair sorting; rounded to subangular angularity; high to moderate sphericity; consolidate to easily friable; cement grain support; thin bedding structure; no HCL reaction; no oil odor; no free oil; no cut color; no fluorescence color; no oil indictors. Siltstone (6580 6630) = olive gray to brownish gray with olive black hues; firm friable to moderate hard; moderate to well induration; dense to crunchy tenacity; bladed to wedgelike cuttings habit; matte to gritty texture; dull to earthy texture when dry; massive to thick bedding structure; no HCL reaction; no oil odor; no free oil; no cut color; no fluorescence color; no oil indicators. Peaks Depth TG C1 C2 C3 C41 UN C51 C5N 6535 143.554 21940.532 1724.849 927.128 139.648 374.040 73.435 60.689 6574 172.120 25766.537 2056.133 1125.946 161.273 417.600 107.386 92.315 6636 134.585 25245.941 2539.732 1381.974 296.784 710.110 178.558 204.051 3.2.9 Bermuda 6636' to 7160' Mr) (-5(111' to -5082' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 191.9 0.4 92 2569 74 859.3 The Bermuda is the primary formation. This formation was drilled through horizontal around 5200' TVD. As we enter horizontal "Heel" drilling, background gas increased to 325-400 units. Methane and heavies gas are abundant in the area. Sands/sandstone is the dominant sediment until 8550' MD. Hydrocarbon odor was notice at the shaker area and in sample. Most samples had high fluorescence characteristics. Sandstone (6640-6685) = light olive gray to dark gray with olive gray hues; very fine to fine grain size; moderate sphericity; subrounded to rounded; moderate to well sorted; friable to well consolidated; grain supported; thin bedding structure; very weak HCL reaction; no oil odor; no free oil; no cut color; trace yellow fluorescence; no oil indicators. 16 GAMG CortocoPhillips Alaska. W',;. 2L -322A Sandstone (6695-6750) = light olive gray to medium gray with medium dark gray hues; very fine to fine grain size; moderate to high sphericity; subrounded to rounded; moderate to well sorting; moderately to well consolidated; grain supported; quartz dominant; carbonaceous laminations interbedded; trace oil odor; no stain; 30% yellow fluorescence; light milky white cut fluorescence; no cut color; no residue; no residue fluorescence. Sandstone (6760-6810) = light gray to medium dark gray with brownish gray hues; very fine to fine grain size; moderate to high sphericity; rounded to well rounded; well sorted; friable to very poorly consolidated; grain matrix; quartz dominant; very light oil odor; 50% patchy dull yellow fluorescence; faint white cut fluorescence; no cut color; no residue; faint yellow residue fluorescence. Sandstone (6820-6870) = light olive gray to medium dark gray with brownish gray hues; very fine to fine grain size; moderate to high sphericity; well rounded; well sorted; easily friable to moderately consolidation; grain matrix; quartz dominant; very light oil odor; 40% patchy dull yellow fluorescence, streaming dull light milky yellow; no cut color; no visible residue; faint yellow residue fluorescence. Sandstone (6880-6930) = light olive gray to brownish gray with medium dark gray hues; very fine to fine grain size; high sphericity; rounded to well rounded; moderate sorting; friable to moderate consolidation; grain supported; quartz dominant; very slight odor; 50% patchy dull yellow fluorescence; blooming dull blue white cut fluorescence; no cut color; no visible residue; faint yellow residue fluorescence. Sandstone (6940-7010) = light olive gray to olive gray with brownish gray hues; fine to medium grain size; high sphericity; rounded to well rounded; poor to moderate sorting; friable to poor consolidation; soft to easily friable hardness; cement grain support; massive to thick lenticular bedding structure; very weak HCL reaction; oil odor; no free oil; bright greenish yellow fluorescence color; no visual cut color; milky white cut fluorescence with fast color change; yellowish white residue fluorescence with bright intensity; no other oil indictors. Sandstone (7020-7095) = light olive gray to olive gray with trace of olive black hues and grayish black hues color; quartz dominant; poorly consolidate; upper fine to lower fine grain size; fair to moderate sorting; subrounded to rounded angularity; moderate sphericity; friable to firm friable hardness; cement grain support; massive to thick bedding structure; oil odor in sample and near shakers; no free oil; 90% greenish yellow visual fluorescence; milky white fluorescence cut color with bright white streamers; bright yellowish white residue fluorescence; no visual residue color; very low HCL reaction. Sandstone (7105-7180) = olive gray to light olive gray with clear to translucent quartz minerals and olive black hues color; quartz dominant framework; lower fine to lower medium grain size; moderate to slight well sorting; sub round to subangular angularity; moderate sphericity; friable to firm friable hardness; cement grain supported; massive to thick bedding structure; oil odor in sample; no free oil; 6o% patchy dull greenish yellow fluorescence; blooming bright milky white fluorescence cut color; no visual residue; dull white residue fluorescence; very low HCL reaction. Sandstone (7190-7255) = olive gray to medium dark gray with brownish black hues; very fine to fine grain size; moderate to high sphericity; rounded to well rounded; moderate to well sorting; friable to moderately consolidated; cement grain supported; massive to thick bedding structure; quartz dominant framework; none to faint oil odor; 30% patchy dull greenish yellow fluorescence; blooming faint milky white cut fluorescence; no visible cut; no visible residue; none to faint white residue fluorescence; low HCL reaction. Sandstone (7265-7330) = olive gray to dark gray with brownish black hues; very fine to upper fine grain size; moderate to high sphericity; rounded to well rounded; moderate sorting; friable to poorly consolidation; cement grain supported; massive to thick bedding structure; quartz dominant framework; very faint oil odor; 40% patchy dull yellow fluorescence; blooming dull milky white cut fluorescence; no visible cut; no visible residue; dull milky yellow residue fluorescence; very low HCL reaction. Sandstone (7340-7405) = light olive gray to medium dark gray with dark gray hues; fine to lower medium grain size; moderate to high sphericity; rounded to well rounded; moderate to well sorted; poorly to moderately consolidated; grain supported; quartz dominant framework; no oil odor; 30% patchy dull greenish yellow 01 17 ConocoPhillips i%}yuk8.loc 2L -322A 0 fluorescence; slow blooming faint milky white cut fluorescence; no visible cut; no visible cut; no visible residue; none to faint white residue fluorescence; no HCL reaction. Sandstone (7415-7470) = light olive gray to medium gray with brownish gray hues; fine to lower medium grain size; moderate to high sphericity; rounded; moderate to well sorted; friable to poorly consolidated; grain supported; quartz dominant framework; 30% patchy dull greenish yellow fluorescence; slow blooming faint milky white cut fluorescence; no visible cut; no visible cut; no visible residue; weak HCL reaction. Siltstone (7480-7540) = olive black to brownish black with olive gray hues; stiff to slight dense tenacity; earthy to earthy fracture; wedgelike to blocky cutting habits; dull to earthy when dry and frosted when wet luster; matte to sucrosic texture; thin to lenticular bedding structure; slight oil odor; no free oil; no cut color; 90% fluorescence yellowish green color; faster cut reaction in fluorescent; milky fluorescence cut; no visual residue; no other indictors. Sandstone (7550-7625) = olive gray to light olive gray with clear to translucent minerals, and black hues color; quartz dominant framework; upper fine to lower fine grain size; well to moderate sorting; subrounded to subangular angularity; moderate sphericity; poor consolidation with easily friable to friable hardness; cement grain support; massive bedding structure; oil odor in sample; 98% green yellowish fluorescence; no free oil; bright white fluorescence cut color with streamers; no visual residue; yellowish white residue fluorescence with dull intensity; very weak HCL reaction. Sandstone (7635-7705) = olive gray to light olive gray with black to brownish black hues and clear to translucent smokey minerals colors; quartz dominant framework; well to moderate sorting; subrounded to subangular angularity; upper fine to lower fine grain size; poor consolidation with friable to easily friable; cement overgrowths; massive to thick bedding structure; very weak oil odor; no free oil; no visual cut color; slow pale milky fluorescence cut color; 80% greenish yellow visual fluorescence color; very weak HCL reaction. Siltstone (7715-7770) = olive black to brownish brown with grayish hues colors; crumbly to brittle tenacity; earthy to drusy fracture; wedgelike to slight blocky cutting habits; dull to earthy when dry luster; matte to silty texture; laminae to thin bedding structure; weak oil odor; no free oil; no visual cut color; fast and milky white fluorescence cut with no streamers; 60% greenish yellow visual fluorescence color; very weak HCL reaction. Sandstone (7780-7840) = light olive gray to medium gray with brownish gray hues; moderate to high sphericity; subangular to subrounded; moderate to well sorted; friable to moderately consolidated; cement grain supported; quartz dominant; thin bedding structure; weak oil odor; no visible stain; 40% dull greenish yellow fluorescence; slow crush faint milky white cut fluorescence; no visible cut; no visible residue; faint white residue fluorescence; very weak HCL reaction. Sandstone (7850-7915) = light olive gray to medium dark gray with brownish gray hues; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; friable to moderately consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; weak to moderate oil odor; faint visible oil stain; 70% patchy bright fluorescence; no visible cut; no visible residue; dull to bright milky yellow residue fluorescence; weak to moderate HCL reaction. Sandstone (7925-8000) = yellowish gray to light olive gray with medium light gray hues; lower fine to lower medium grain size; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; friable to moderately consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; weak to moderate oil odor; no visible stain; 70% patchy bright greenish yellow fluorescence; blooming bright milky white cut fluorescence; no visible cut; no visible residue; faint yellow white residue fluorescence; weak to moderate HCL reaction. Sandstone (8030-8105) = yellowish gray to light olive gray with medium light gray hues; lower fine to upper fine grain size; low to moderate sphericity; subangular to rounded; poor to moderate sorting; friable to very poorly consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; moderate to strong oil odor; 10% patchy visible stain; 80% even bright greenish yellow ConocoPhillips 2L -322A fluorescence; immediate bright white cut fluorescence; no visible cut; no visible residue; light milky yellow residue fluorescence; weak to moderate HCL reaction. Sandstone (8115-8190) = yellowish gray to light olive gray with medium gray hues; lower fine to lower medium grain size; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; friable to poorly consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; moderate oil odor; 10% patchy visible stain; 80% patchy bright greenish yellow fluorescence; immediate dull milky fluorescence cut with white streamers; fainted yellowish fluorescence; weak HCL reaction; no other oil indictors. Siltstone (8200-8260) = brownish black to brown gray with olive black hues colors; stiff to crumbly tenacity; drusy to mottled fracture; wedgelike to bladed edges cutting habits; dull to earthy when dry luster; matte to silty texture; lenticular to thin bedding structure; very weak oil odor; no free oil; 85% yellowish green visual fluorescence; no visual cut color; dull milky fluorescence cut color; faint milky residue fluorescence color; weak HCL reaction; no other oil indictors. Sandstone (8270-8340) = olive gray to light olive gray with clear to translucent minerals colors and black hues colors; quartz dominant framework; very fine to fine grain size; well to moderate sorting; rounded to subrounded angularity; high to moderate sphericity; poorly consolidate with friable to easily friable hardness; cement overgrowth with matrix grain support; no free oil; slight oil odor; no visual cut; 40% greenish yellowish visual fluorescence; faint milky fluorescence cut; weak faint yellowish residue fluorescence cut; no other oil indictors. Sandstone (8350-8425) = olive gray to light olive gray with clear to translucent smokey mineral, black hues, and medium dark gray hues colors; quartz dominant framework; upper fine to lower fine grain size; well sorting; subrounded to rounded angularity; moderate sphericity; poor consolidation with easily friable to friable hardness; cement matrix grain support; oil odor in bulk sample; no free oil; not visual cut color; 90% yellowish green visual fluorescence; dull milky fluorescence cut with fast color change; faint pale yellowish residue 40 fluorescence; no other oil indictors; weak HCL reaction. Siltstone (8435-8495) = olive gray to light olive gray with dark gray hues; easily friable to friable hardness; poor to moderate induration; crunchy to pulverulent; wedgelike to bladed cuttings habit; silty to gritty texture; dull to earthy luster when dry; thin to lenticular bedding structure; very weak oil odor; 20% patchy dull yellow fluorescence; faint blooming milky white cut fluorescence; no visible cut; faint white residue fluorescence; weak HCL reaction. Siltstone (8505-8560) = medium gray to medium dark gray with olive gray hues; soft to easily friable; very poor to poor induration; crumbly to pulverulent tenacity; wedgelike to bladed cuttings habit; silty to gritty texture; dull to earthy luster when dry; thin to lenticular bedding structure; no oil odor; 5% patchy dull yellow fluorescence; no cut fluorescence; no other oil indicators; weak HCL reaction. Siltstone (8570-8635) = medium gray to medium dark gray with olive gray hues; soft to moderately hard; poor to moderate induration; dense to pulverulent tenacity; wedgelike to bladed cuttings habit; silty to gritty texture; dull to earthy when dry luster; thin bedding structure; carbonaceous laminations interbedded; no oil odor; trace dull yellow fluorescence; very faint blooming milky yellow cut fluorescence; no visible cut; no visible residue; faint white residue fluorescence; weak HCL reaction. Siltstone (8665-8720) = medium gray to medium dark gray with olive gray hues; poor to well induration; pulverulent to dense tenacity; wedgelike to bladed cuttings habit; silty to granular texture; dull to earthy when dry luster; thin bedding structure; no oil odor; 10% dull yellow fluorescence; no cut fluorescence; no visible cut; no visible residue; faint yellow white residue fluorescence; weak to moderate HCL reaction. Siltstone (8730-8780) = medium light gray to medium dark gray with olive gray hues; friable to firm friable hardness; poor to moderate induration; dense to crunchy tenacity; wedgelike to curved cuttings habit; silty to gritty texture; dull to frosted when dry luster; thin bedding structure; 5% dull patchy yellow fluorescence; no cut 0 19 �G CortocoPhillIps .N IJk.�n-. 2L -322A afluorescence; no visual cut; no residue; faint yellow residue fluorescence; weak HCL reaction Sandstone (8790-8850) = light olive gray to medium gray with brownish gray hues; very fine to upper fine grain size; moderate to high sphericity; subrounded to rounded; moderate to well sorting; friable to poorly consolidated; cement grain supported; very faint oil odor; no visible stain; 20% patchy dull yellow fluorescence; no cut fluorescence with one yellowish white streamer; very faint yellow white residue fluorescence; no visual residue; no other oil indictors; weak HCL reaction. Siltstone (8860-8925) = olive black to brownish black with dark gray hues colors; crumbly to crunchy tenacity; earthy to drusy fracture; wedgelike to tabular/blocky cutting habits; dull to earthy when dry and frosted when wet luster; matte to sucrosic texture; lenticular to thin bedding structure; no free oil; no oil odor; no visual residue; no visual cut color; 5% yellowish green visual fluorescence; no cut fluorescence color; no residue cut fluorescence color; weak HCL reaction in bulk sample. Sandstone (8935-9005) = olive gray to light olive gray with black hues, clear to translucent smokey colors; quartz dominant; very fine to fine grain size; well to moderate sorting; rounded to subrounded angularity; high to moderate sphericity; poorly consolidated with easily friable to friable hardness; quartz to dolomite cement grain support; massive to thick bedding structure; no free oil; no oil odor; no visual cut color; no fluorescence colors; no fluorescence cut color; no residue color; no residue fluorescence cut; very weak HCL reaction. Siltstone (9015-9080) = olive black to brownish black with grayish black hues, and olive gray hues colors; crumbly to slight crunchy tenacity; earthy to slight hackly fracture; wedgelike to tabular blocky cutting habits; dull to earthy when dry and frosted when wet luster; silty to gritty texture; lenticular to thin bedding structure; no free oil; no oil odor; no fluorescence; no cut fluorescence; no visible cut; no visible residue; no residue fluorescence; very weak HCL reaction. Siltstone (9090-9145) = olive black to brownish black with grayish black hues; friable to firm friable; moderate . induration; crunchy to pulverulent tenacity; wedgelike to tabular cuttings habit; silty to gritty texture; dull to earthy luster; thin to lenticular bedding structure; no free oil; no oil odor; no fluorescence; no cut fluorescence; no visible cut; no visible residue; no residue fluorescence; very weak HCL reaction. Siltstone (9155-9215) = olive gray to dark gray with brownish black hues; friable to firm friable; moderate to well induration; crumbly to crunchy tenacity; tabular to wedgelike cuttings habit; silty to gritty texture; dull to earthy when dry to frosted when wet luster; thin to lenticular bedding structure; no oil odor; no visible stain; no fluorescence; no cut fluorescence; no visible cut; no visible residue; no residue fluorescence; very weak HCL reaction. Siltstone (9250-9315) = olive gray to medium dark gray with brownish black hues; friable to moderately hard; moderate to well induration; dense to crunchy tenacity; wedgelike to tabular cuttings habit; clayey to gritty texture; dull to earthy when dry and waxy when wet luster; thin to lenticular bedding structure; no oil odor; no visible stain; trace dull yellow orange fluorescence; no cut fluorescence; no visible cut; no visible residue; faint white residue fluorescence; very weak HCL reaction. Siltstone (9325-9385) = olive gray to medium dark gray with brownish gray hues; friable to firm friable hardness; poor to moderate induration; brittle to crunchy tenacity; wedgelike to tabular cuttings habit; silty to gritty texture; dull to earthy when dry and waxy when wet luster; thin to lenticular bedding structure; no oil odor; no visible stain; trace yellow fluorescence; no cut fluorescence; no visible cut; no visual residue; no residue fluorescence cut color; weak HCL reaction. Siltstone (9395-9455) = brownish black to olive black with grayish black hues and brownish gray hues colors; friable to firm friable hardness; crumbly to crunchy tenacity; hackly to earthy fracture; wedgelike to bladed edges cutting habits; dull to earthy when dry luster; matte to sucrosic texture; thick bedding structure; no free oil; no oil odor; no visual residue; no cut color; no visual fluorescence color; no cut fluorescence color; no residue cut colors; weak to moderate HCL reaction. 0 20 CorwxoPhilii X35 AOSka3. tor - 2L -322A PPakc Depth TG C1 C2 C3 C41 C4N C51 C5N 6826 1050.741 207002.188 13858.943 6081.566 1004.454 2634.171 541.072 751.905 6904 1344.354 352572.579 22910.720 8806.718 1153.264 3045.931 628.931 775.593 6950 1741.141 286980.829 23505.159 10915.070 1549.205 3953.316 893.655 1155.161 6971 2560.894 627132.181 77298.775 42178.814 5886.564 15772.881 3570.987 4273.750 7054 2569.620 417293.521 47593.434 26573.167 3395.672 9726.355 2159.781 2687.493 7109 1336.654 228008.612 23989.908 14043.021 2035.540 5863.330 1466.112 1794.335 3.2.10 T-2 7160' to 9515' MD -5082' to -5003' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 149.3 0.2 41.5 1382 0 270 At the beginning of T-2 formation, the sample show decreased and gas units had a slight decrease. From 8500'-9515' MD, hydrocarbon shows are not appearing in sand/sandstone. In the rest of the formation, siltstone and sandstone are layered and interbedded between each other. Gas background ends around 27-37 units. Sandstone (7190-7255) = olive gray to medium dark gray with brownish black hues; very fine to fine grain size; moderate to high sphericity; rounded to well rounded; moderate to well sorting; friable to moderately consolidated; cement grain supported; massive to thick bedding structure; quartz dominant framework; none to faint oil odor; 30% patchy dull greenish yellow fluorescence; blooming faint milky white cut fluorescence; no visible cut; no visible residue; none to faint white residue fluorescence; low HCL reaction. Sandstone (7265-7330) = olive gray to dark gray with brownish black hues; very fine to upper fine grain size; moderate to high sphericity; rounded to well rounded; moderate sorting; friable to poorly consolidation; cement grain supported; massive to thick bedding structure; quartz dominant framework; very faint oil odor; 40% patchy dull yellow fluorescence; blooming dull milky white cut fluorescence; no visible cut; no visible residue; dull milky yellow residue fluorescence; very low HCL reaction. Sandstone (7340-7405) = light olive gray to medium dark gray with dark gray hues; fine to lower medium grain size; moderate to high sphericity; rounded to well rounded; moderate to well sorted; poorly to moderately consolidated; grain supported; quartz dominant framework; no oil odor; 30% patchy dull greenish yellow fluorescence; slow blooming faint milky white cut fluorescence; no visible cut; no visible cut; no visible residue; none to faint white residue fluorescence; no HCL reaction. Sandstone (7415-7470) = light olive gray to medium gray with brownish gray hues; fine to lower medium grain size; moderate to high sphericity; rounded; moderate to well sorted; friable to poorly consolidated; grain supported; quartz dominant framework; 30% patchy dull greenish yellow fluorescence; slow blooming faint milky white cut fluorescence; no visible cut; no visible cut; no visible residue; weak HCL reaction. Siltstone (7480-7540) = olive black to brownish black with olive gray hues; stiff to slight dense tenacity; earthy to earthy fracture; wedgelike to blocky cutting habits; dull to earthy when dry and frosted when wet luster; matte to sucrosic texture; thin to lenticular bedding structure; slight oil odor; no free oil; no cut color; 90% fluorescence yellowish green color; faster cut reaction in fluorescent; milky fluorescence cut; no visual residue; no other indictors. Sandstone (7550-7625) = olive gray to light olive gray with clear to translucent minerals, and black hues color; • 21 CAWG ConocoPhillips A -ivka,;M- 2L-322A quartz dominant framework; upper fine to lower fine grain size; well to moderate sorting; subrounded to subangular angularity; moderate sphericity; poor consolidation with easily friable to friable hardness; cement grain support; massive bedding structure; oil odor in sample; 98% green yellowish fluorescence; no free oil; bright white fluorescence cut color with streamers; no visual residue; yellowish white residue fluorescence with dull intensity; very weak HCL reaction. Sandstone (7635-7705) = olive gray to light olive gray with black to brownish black hues and clear to translucent smokey minerals colors; quartz dominant framework; well to moderate sorting; subrounded to subangular angularity; upper fine to lower fine grain size; poor consolidation with friable to easily friable; cement overgrowths; massive to thick bedding structure; very weak oil odor; no free oil; no visual cut color; slow pale milky fluorescence cut color; 80% greenish yellow visual fluorescence color; very weak HCL reaction. Siltstone (7715-7770) = olive black to brownish brown with grayish hues colors; crumbly to brittle tenacity; earthy to drusy fracture; wedgelike to slight blocky cutting habits; dull to earthy when dry luster; matte to silty texture; laminae to thin bedding structure; weak oil odor; no free oil; no visual cut color; fast and milky white fluorescence cut with no streamers; 60% greenish yellow visual fluorescence color; very weak HCL reaction. Sandstone (7780-7840) = light olive gray to medium gray with brownish gray hues; moderate to high sphericity; subangular to subrounded; moderate to well sorted; friable to moderately consolidated; cement grain supported; quartz dominant; thin bedding structure; weak oil odor; no visible stain; 40% dull greenish yellow fluorescence; slow crush faint milky white cut fluorescence; no visible cut; no visible residue; faint white residue fluorescence; very weak HCL reaction. Sandstone (7850-7915) = light olive gray to medium dark gray with brownish gray hues; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; friable to moderately consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; weak to moderate oil odor; faint visible oil stain; 70% patchy bright fluorescence; no visible cut; no visible residue; dull to • bright milky yellow residue fluorescence; weak to moderate HCL reaction. Sandstone (7925-8000) = yellowish gray to light olive gray with medium light gray hues; lower fine to lower medium grain size; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; friable to moderately consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; weak to moderate oil odor; no visible stain; 70% patchy bright greenish yellow fluorescence; blooming bright milky white cut fluorescence; no visible cut; no visible residue; faint yellow white residue fluorescence; weak to moderate HCL reaction. Sandstone (8030-8105) = yellowish gray to light olive gray with medium light gray hues; lower fine to upper fine grain size; low to moderate sphericity; subangular to rounded; poor to moderate sorting; friable to very poorly consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; moderate to strong oil odor; 10% patchy visible stain; 80% even bright greenish yellow fluorescence; immediate bright white cut fluorescence; no visible cut; no visible residue; light milky yellow residue fluorescence; weak to moderate HCL reaction. Sandstone (8115-8190) = yellowish gray to light olive gray with medium gray hues; lower fine to lower medium grain size; low to moderate sphericity; subangular to subrounded; poor to moderate sorting; friable to poorly consolidated; cement grain supported; quartz dominant; thin bedding structure; carbonaceous laminations interbedded; moderate oil odor; 10% patchy visible stain; 80% patchy bright greenish yellow fluorescence; immediate dull milky fluorescence cut with white streamers; fainted yellowish fluorescence; weak HCL reaction; no other oil indictors. Siltstone (8200-8260) = brownish black to brown gray with olive black hues colors; stiff to crumbly tenacity; drusy to mottled fracture; wedgelike to bladed edges cutting habits; dull to earthy when dry luster; matte to silty texture; lenticular to thin bedding structure; very weak oil odor; no free oil; 85% yellowish green visual fluorescence; no visual cut color; dull milky fluorescence cut color; faint milky residue fluorescence color; weak HCL reaction; no other oil indictors. 0 - - 22 ConocoPhi Ili ps Alaska, Or. 2L -322A • Sandstone (8270-8340) = olive gray to light olive gray with clear to translucent minerals colors and black hues colors; quartz dominant framework; very fine to fine grain size; well to moderate sorting; rounded to subrounded angularity; high to moderate sphericity; poorly consolidate with friable to easily friable hardness; cement overgrowth with matrix grain support; no free oil; slight oil odor; no visual cut; 40% greenish yellowish visual fluorescence; faint milky fluorescence cut; weak faint yellowish residue fluorescence cut; no other oil indictors. Sandstone (8350-8425) = olive gray to light olive gray with clear to translucent smokey mineral, black hues, and medium dark gray hues colors; quartz dominant framework; upper fine to lower fine grain size; well sorting; subrounded to rounded angularity; moderate sphericity; poor consolidation with easily friable to friable hardness; cement matrix grain support; oil odor in bulk sample; no free oil; not visual cut color; 90% yellowish green visual fluorescence; dull milky fluorescence cut with fast color change; faint pale yellowish residue fluorescence; no other oil indictors; weak HCL reaction. Siltstone (8435-8495) = olive gray to light olive gray with dark gray hues; easily friable to friable hardness; poor to moderate induration; crunchy to pulverulent; wedgelike to bladed cuttings habit; silty to gritty texture; dull to earthy luster when dry; thin to lenticular bedding structure; very weak oil odor; 20% patchy dull yellow fluorescence; faint blooming milky white cut fluorescence; no visible cut; faint white residue fluorescence; weak HCL reaction. Siltstone (8505-8560) = medium gray to medium dark gray with olive gray hues; soft to easily friable; very poor to poor induration; crumbly to pulverulent tenacity; wedgelike to bladed cuttings habit; silty to gritty texture; dull to earthy luster when dry; thin to lenticular bedding structure; no oil odor; 5% patchy dull yellow fluorescence; no cut fluorescence; no other oil indicators; weak HCL reaction. Siltstone (8570-8635) = medium gray to medium dark gray with olive gray hues; soft to moderately hard; poor • to moderate induration; dense to pulverulent tenacity; wedgelike to bladed cuttings habit; silty to gritty texture; dull to earthy when dry luster; thin bedding structure; carbonaceous laminations interbedded; no oil odor; trace dull yellow fluorescence; very faint blooming milky yellow cut fluorescence; no visible cut; no visible residue; faint white residue fluorescence; weak HCL reaction. Siltstone (8665-8720) = medium gray to medium dark gray with olive gray hues; poor to well induration; pulverulent to dense tenacity; wedgelike to bladed cuttings habit; silty to granular texture; dull to earthy when dry luster; thin bedding structure; no oil odor; 10% dull yellow fluorescence; no cut fluorescence; no visible cut; no visible residue; faint yellow white residue fluorescence; weak to moderate HCL reaction. Siltstone (8730-8780) = medium light gray to medium dark gray with olive gray hues; friable to firm friable hardness; poor to moderate induration; dense to crunchy tenacity; wedgelike to curved cuttings habit; silty to gritty texture; dull to frosted when dry luster; thin bedding structure; 5% dull patchy yellow fluorescence; no cut fluorescence; no visual cut; no residue; faint yellow residue fluorescence; weak HCL reaction. Sandstone (8790-8850) = light olive gray to medium gray with brownish gray hues; very fine to upper fine grain size; moderate to high sphericity; subrounded to rounded; moderate to well sorting; friable to poorly consolidated; cement grain supported; very faint oil odor; no visible stain; 20% patchy dull yellow fluorescence; no cut fluorescence with one yellowish white streamer; very faint yellow white residue fluorescence; no visual residue; no other oil indictors; weak HCL reaction. Siltstone (8860-8925) = olive black to brownish black with dark gray hues colors; crumbly to crunchy tenacity; earthy to drusy fracture; wedgelike to tabular/blocky cutting habits; dull to earthy when dry and frosted when wet luster; matte to sucrosic texture; lenticular to thin bedding structure; no free oil; no oil odor; no visual residue; no visual cut color; 5% yellowish green visual fluorescence; no cut fluorescence color; no residue cut fluorescence color; weak HCL reaction in bulk sample. Sandstone (8935-9005) = olive gray to light olive gray with black hues, clear to translucent smokey colors; • 23 rJyukg, for 2L -322A quartz dominant; very fine to fine grain size; well to moderate sorting; rounded to subrounded angularity; high to moderate sphericity; poorly consolidated with easily friable to friable hardness; quartz to dolomite cement grain support; massive to thick bedding structure; no free oil; no oil odor; no visual cut color; no fluorescence colors; no fluorescence cut color; no residue color; no residue fluorescence cut; very weak HCL reaction. Siltstone (9015-9080) = olive black to brownish black with grayish black hues, and olive gray hues colors; crumbly to slight crunchy tenacity; earthy to slight hackly fracture; wedgelike to tabular blocky cutting habits; dull to earthy when dry and frosted when wet luster; silty to gritty texture; lenticular to thin bedding structure; no free oil; no oil odor; no fluorescence; no cut fluorescence; no visible cut; no visible residue; no residue fluorescence; very weak HCL reaction. Siltstone (9090-9145) = olive black to brownish black with grayish black hues; friable to firm friable; moderate induration; crunchy to pulverulent tenacity; wedgelike to tabular cuttings habit; silty to gritty texture; dull to earthy luster; thin to lenticular bedding structure; no free oil; no oil odor; no fluorescence; no cut fluorescence; no visible cut; no visible residue; no residue fluorescence; very weak HCL reaction. Siltstone (9155-9215) = olive gray to dark gray with brownish black hues; friable to firm friable; moderate to well induration; crumbly to crunchy tenacity; tabular to wedgelike cuttings habit; silty to gritty texture; dull to earthy when dry to frosted when wet luster; thin to lenticular bedding structure; no oil odor; no visible stain; no fluorescence; no cut fluorescence; no visible cut; no visible residue; no residue fluorescence; very weak HCL reaction. Siltstone (9250-9315) = olive gray to medium dark gray with brownish black hues; friable to moderately hard; moderate to well induration; dense to crunchy tenacity; wedgelike to tabular cuttings habit; clayey to gritty texture; dull to earthy when dry and waxy when wet luster; thin to lenticular bedding structure; no oil odor; no visible stain; trace dull yellow orange fluorescence; no cut fluorescence; no visible cut; no visible residue; faint white residue fluorescence; very weak HCL reaction. to Siltstone (9325-9385) = olive gray to medium dark gray with brownish gray hues; friable to firm friable hardness; poor to moderate induration; brittle to crunchy tenacity; wedgelike to tabular cuttings habit; silty to gritty texture; dull to earthy when dry and waxy when wet luster; thin to lenticular bedding structure; no oil odor; no visible stain; trace yellow fluorescence; no cut fluorescence; no visible cut; no visual residue; no residue fluorescence cut color; weak HCL reaction. Siltstone (9395-9455) = brownish black to olive black with grayish black hues and brownish gray hues colors; friable to firm friable hardness; crumbly to crunchy tenacity; hackly to earthy fracture; wedgelike to bladed edges cutting habits; dull to earthy when dry luster; matte to sucrosic texture; thick bedding structure; no free oil; no oil odor; no visual residue; no cut color; no visual fluorescence color; no cut fluorescence color; no residue cut colors; weak to moderate HCL reaction • Donlre Depth TGC1 Methane Ethane Propane ppm ppm ppm C2 C3 C41 C4N C51 C5N 7496 1382.338 250255.998 24982.741 13146.533 1654.825 4898.124 1215.642 1624.820 8027 1031.749 164531.128 19653.373 11758.293 1579.645 4664.479 1095.539 1494.640 8134 1229.886 195482.718 23779.461 14828.734 2475.695 6973.537 2139.709 2598.739 8821 117.034 18097.015 1111.356 684.968 148.696 343.738 162.996 162.208 3.3 Isotube Summary Isotube Depth Gas units Methane Ethane Propane ppm ppm ppm Iso Normal Butane Butane ppm ppm Iso Pentane ppm Normal Pentane ppm Box Sample MD TVD ft ft 1 1 2809 2511 100 18240 176 68 1 2 3332 2911 33 5542 76 1 3 73555 3083 I 20 3883 CilG L4 • • • CD lips AAW. 11}41. 2L -322A 1 4 4000 3428 22 4202 90 Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 2 1 5 4500 3813 5 928 14535 2163 5667 1374 1630 2 1 6 5000 4198 68 13731 420 190 5650 1414 1732 2 1 7 5502 4581 76 13785 681 469 61 164 59 88 1 8 5783 4775 157 5086 1364 1467 424 743 785 75 1 9 6000 4903 60 10957 649 715 119 237 66 118 1 10 6126 4969 130 23917 1622 1086 208 435 114 96 1 11 6201 5004 176 27279 2443 1866 345 812 214 215 1 12 6412 5084 206 35125 2006 1032 120 335 74 90 1 13 6500 5113 142 21601 1675 903 159 410 51 42 1 14 6712 5176 960 181094 14995 6812 1370 3018 582 613 1 15 6750 5185 95 9885 1117 991 267 689 172 246 1 16 6780 5191 308 50966 3523 1787 293 761 170 237 1 17 6810 5197 511 96343 6234 2647 476 1138 228 306 1 18 6840 5202 359 61888 4269 1925 297 838 176 250 1 19 6875 5206 662 127293 8981 3848 544 1410 298 335 1 20 6900 5209 1150 258799 16452 5990 752 1969 387 437 1 21 6930 5212 339 55364 4153 2104 327 884 212 324 1 22 6960 5214 1324 270833 23111 10306 1397 3438 747 845 1 23 6990 5216 1835 360824 31881 14959 2037 5678 1329 1567 1 24 7020 5219 1254 224190 25682 14360 2014 5540 1217 1462 1 25 7050 1 5221 2363 379642 44361 24917 3117 9044 1983 2485 Isotube Box Sample Depth MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 2 1 7080 5223 1545 281171 27242 14535 2163 5667 1374 1630 2 2 7110 5225 1306 218004 23004 13506 1956 5650 1414 1732 2 3 7139 5225 638 78061 8744 6016 1124 3125 907 1108 2 4 7170 5226 344 24827 3596 3845 926 2931 931 1168 2 5 7200 5227 259 20204 2133 2108 536 1 1902 685 897 2 6 7230 5228 521 72018 6794 4386 904 2614 839 1101 2 7 7260 5227 325 39426 2973 2274 576 1873 640 954 2 8 7290 5227 521 48394 4088 2899 625 2040 745 1010 2 9 7320 5226 387 54104 4458 2842 582 1868 655 901 2 10 7350 5226 215 20498 1811 1568 405 1298 520 693 2 11 7380 5225 641 95904 9652 5399 889 2684 779 1086 2 12 7410 5225 266 33540 2487 1611 369 1264 469 728 2 13 7441 5224 190 17663 1645 1331 309 1126 442 634 2 14 7460 5224 1126 212215 19939 10159 1409 4064 1059 1323 2 15 7500 5223 1150 205446 20647 10902 1359 4032 996 1340 2 16 7530 5222 492 79150 6337 3475 520 1671 520 745 2 17 7560 5222 511 75002 7311 4416 678 2075 633 1 870 2 18 7590 5221 628 95112 9617 5417 789 2342 644 882 2 19 7620 5220 780 128656 13847 7586 1038 3058 866 1106 Isotube Box Sample Depth MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane PPM Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 2 20 7650 5220 908 148711 1 16840 9458 1290 1 3738 1 1003 1277 2 21 7684 5220 230 28389 2427 1672 279 1018 356 526 2 22 7710 5220 253 29808 3241 2399 412 1357 453 624 2 23 7740 5220 403 59881 5816 1 3277 495 1573 445 665 `E7 • • ,., CDnocoPhilflps 2L -322A 2 1 24 7770 1 5220 641 99002 11002 1 5941 828 2347 1 662 827 2 1 25 7797 1 5221 362 48937 5298 1 3216 566 1619 1 533 694 Isotube Box Sample Depth MD ft TVD ft Gas units Methane ppm Ethane PPM Propane PPM Iso Butane PPM Normal Butane PPM Iso Pentane ppm Normal Pentane ppm 3 1 7830 5221 348 51862 5213 2963 473 1523 456 656 3 2 7860 5221 474 73550 7460 4352 545 1894 563 742 3 3 7890 5221 479 70316 7322 4282 662 1870 567 744 3 4 7920 5221 542 83046 8641 4803 682 2064 557 797 3 5 7950 5222 217 24975 3061 2355 378 1332 386 575 3 6 7980 5222 692 114982 12088 6826 705 2412 586 1052 3 7 8020 5222 960 155831 18774 11181 1460 4348 1007 1404 3 8 8040 5222 864 135972 15985 9646 1365 3968 955 1254 3 9 8070 5222 825 126974 14652 9109 1210 3823 912 1365 3 10 8100 5222 380 46386 5865 4388 824 2441 822 1040 3 11 8130 5223 1134 188986 22661 12856 1992 5428 1533 1804 3 12 8160 5223 257 19870 2752 3010 660 2042 761 984 3 13 8190 5223 411 67664 5485 3218 628 1756 652 855 3 14 8220 5224 395 63226 5646 3430 701 1897 950 830 3 15 8250 5224 197 25561 2005 1471 272 934 368 470 3 16 8280 5224 307 46113 4067 2561 439 1284 459 582 3 17 8310 5225 122 11758 1059 919 228 718 254 426 3 18 8340 5225 272 42304 3068 1828 313 410 579 0 3 19 8374 5225 389 68581 4973 2679 471 1184 414 491 3 20 8400 5225 518 93886 7346 3950 617 1566 523 866 3 21 8430 5225 151 19748 1818 1400 296 778 348 454 3 22 8460 5225 156 19690 1706 1302 238 746 293 408 3 23 8490 5225 117 12924 1012 870 180 584 247 346 3 24 8520 5225 1 91 9349 796 713 179 1 499 245 319 3 25 8550 5225 1 67 6458 457 467 149 369 197 188 Isotube Box Sample Depth MD TVD ft ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm iso Pentane ppm Normal Pentane ppm 4 1 8580 5225 74 7422 524 416 135 371 158 225 4 2 8610 5225 68 6567 446 480 72 405 163 200 4 3 8640 5225 68 8100 448 376 96 298 197 196 4 4 8670 5225 60 7120 450 347 65 250 155 213 4 5 8707 5224 126 17748 1392 806 132 428 226 228 4 6 8730 5224 55 6795 443 319 0 185 180 154 4 7 8760 5224 58 7044 512 374 55 198 119 214 4 8 8790 5223 45 4829 313 270 69 121 102 161 4 9 8820 5223 119 18230 1118 681 144 333 154 155 4 10 8850 5222 53 5622 373 324 110 264 163 154 Isotube Box Sample Depth MD TVD ft ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane PPM Iso Pentane ppm Normal Pentane ppm 4 11 8880 5222 51 5668 1 389 1 310 1 0 143 123 87 4 12 8910 5222 32 2607 175 229 65 143 127 153 4 13 8940 1 5221 31 2543 228 263 16 141 118 140 26 CAMG Conoc fillips 1+130.1, IY:1 . 2L -322A 4 14 8970 5221 24 1372 139 214 0 111 96 113 4 15 9000 5221 22 1566 122 194 0 131 51 97 4 16 9030 5221 16 2340 202 126 91 96 0 0 4 17 9060 5222 35 3554 315 309 0 143 61 107 4 18 9092 5222 28 3026 238 216 0 172 100 115 4 19 9120 5222 31 2908 217 297 49 116 1 91 178 4 20 9153 5223 33 3173 287 305 60 134 60 41 4 21 9180 5223 31 3293 284 224 93 200 51 51 4 22 9210 5224 51 7406 542 402 146 273 142 74 4 23 9240 5226 56 7913 739 551 112 247 144 116 4 24 9270 5227 50 7778 512 331 50 155 92 165 4 25 9300 5229 48 7950 489 360 0 136 61 84 • • Isotube Box Sample Depth MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 5 1 9330 5231 57 7043 810 639 106 288 110 115 5 2 9360 5234 38 4746 356 380 62 129 50 108 5 3 9390 5236 42 5817 471 427 59 215 69 71 5 4 9420 5239 53 7176 664 570 89 234 117 132 5 5 9450 5242 1 38 5131 410 383 60 156 82 123 5 6 9480 5244 1 34 4961 346 459 49 194 99 68 5 7 9510 5247 1 39 6234 451 279 61 179 3.4 Samplina Proaram / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to Alaska Archives Washed, screened & dried 50'1300 West 56`" A Reference Samples* 2750'— 6270' Anchorage, AK 99502 Set owner: CPAI Attn: Dan Przywojski/Mike McCracken ConocoPhillips Alaska Inc. Alaska Archives Washed, screened & dried10'-30' 1300 West 56`" B Reference Samples* 6270' — 9515' Anchorage, AK 99502 Set owner: CPAI Attn: Dan Przywojski/Mike McCracken ConocoPhillips Alaska Inc. Isotech Laboratories C ISOTUBES* 500' 2800'— 6270' 1308 Parkland Court Champaign, IL 61821 (217) 398-3490 Isotech Laboratories D ISOTUBES* 30' 6270'— 9515' 1308 Parkland Court Champaign, IL 61821 217 398-3490 Sample frequency was locally altered according to drill rate constraints and zones of Interest. -,j PZA i .• CorkiWillips +uasKa., Of- 2L-322A f.2L-322A 4 PRESSURE / FORMATION STRENGTH DATA 4.1 Pore Pressure Evaluation NOTE: Clyst = Claystone/Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sst = Sandstone, Ash = Ash Fall Tuff, CSltst = Carbonaceous Siltstone Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of this well; Background Gas (BG) Corrected Dexponent (DXC) Wireline Density (WREN) Pressure Tests (RFT) Connection Gas (CG) Trip Gas (TG) Mud Weight (MW) Hole Conditions (HC) Resistivity (RES) Sonic (SON) 28 Primary Secondary Interval Tops Pore Pressure (MW) Trend MD TVDSS Min Max Trend Formation Interval Lithology Lithology Indicators (%) (%) (ft) (ft) (ppg) (ppg) Campanian CI st 70% Sd/Sst 20% 2808' -2369' 9.0 9.6 Up BG,DXC C-50 Sltst/CI st 70% Sst/Sd 10% 4333' -3540' 9.1 9.4 Sli Up BG,DXC C-40 Sltst 70%-80% CI st 20% 4828' -3921' 9.3 9.7 Sli Up BG,DXC C-37 Sltst 75% CI st 20% 5153' -4171' 9.7 9.8 Sli Up BG,DXC,CG Iceberg CI st 50% Sltst 30% 5222' -4224' 9.7 10 Sli Up BG,DXC,CG T-7 Sltst 40% Sd/Sst 35% 5689' -4570' 9.7 9.9 Sli Up BG,DXC,CG TG, BG, T-4.1 Sltst 70% Sd/Sst 15% 6150' -4838' 9.7 9.9 Sli Up DXC, CG, HC BG, CG,RFT, T-3.1 Sltst 65% Sd/Sst 20% 6488' -4965' 9.3 11.4 Up DXC,CG,MW HC, RFT,BG, Berumda Sd/Sst 80% Sltst 30% 6636' -5011' 11.3 14.4 Up DXC, CG, M W BG, RFT, RES, T-2 Sltst 60% Sd/Sst 40% 7160' -5082' 11.9 14.4 Up HC,TG,DXC MW NOTE: Clyst = Claystone/Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sst = Sandstone, Ash = Ash Fall Tuff, CSltst = Carbonaceous Siltstone Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of this well; Background Gas (BG) Corrected Dexponent (DXC) Wireline Density (WREN) Pressure Tests (RFT) Connection Gas (CG) Trip Gas (TG) Mud Weight (MW) Hole Conditions (HC) Resistivity (RES) Sonic (SON) 28 • 4.2 Pore Pressure Plot 9 2700 -k 3700 4700 5700 C L 0 9 A O 6700 7700 • ConocoPhillips 2L -322A Pore Pressure Gradient Pore Pressue (ppg) 10 11 12 13 14 CAMG 29 0 4.3 Quantitative Methods a CkmocoPhillips r z,a';ki, rr. 2L -322A The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD, and then modified using the indicators described above, DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD — (0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. 30 CAMG Conoc llips 2L -322A 0 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. o () Azim. o () True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (.1100ft) 28.93 0 0 28.93 0 0 0 0 88.93 0.14 43.59 88.93 0.05 0.05 -0.05 0.23 153.93 0.26 31.97 153.93 0.24 0.18 -0.23 0.19 242.93 0.9 144.93 242.93 -0.17 0.69 0.19 1.16 334.93 2.3 165.91 334.89 -2.55 1.56 2.6 1.62 423.93 2.99 170.63 423.79 -6.57 2.37 6.65 0.81 518.93 3.59 167.65 518.64 -11.92 3.41 12.03 0.66 613.93 4.64 166.22 613.39 -18.56 4.96 18.72 1.11 709.93 6.42 166.79 708.94 -27.55 7.11 27.79 1.86 803.93 8.26 174.49 802.17 -39.39 8.96 39.68 2.22 898.93 11.33 183.95 895.78 -55.5 8.97 55.78 3.64 993.93 14.41 193.77 988.39 -76.3 5.52 76.44 3.97 1041.16 15.71 192.6 1034 -88.25 2.72 88.29 2.83 1135.31 17.39 195.56 1124.25 -114.24 -3.83 114.04 2 1231.9 20.89 193.44 1215.48 -144.91 -11.71 144.41 3.69 1321.54 23.8 196.25 1298.39 -177.82 -20.49 177 3.46 1415.47 25.91 194.57 1383.61 -215.88 -30.96 214.67 2.37 1514.99 29.23 194.49 1471.82 -260.47 -42.51 258.82 3.34 1612.17 32.24 195.82 1555.34 -308.39 -55.51 306.27 3.18 1708.06 35.34 194.17 1635.02 -359.9 -69.28 357.26 3.37 1801.31 35.56 194.98 1710.99 -412.24 -82.89 409.1 0.56 1895.57 36.34 197.62 1787.3 -465.34 -98.43 461.62 1.84 1992.92 36.52 197.81 1865.62 -520.41 -116.02 516.05 0.22 2087.35 37.29 196.42 1941.13 -574.6 -132.7 569.62 1.2 2175.97 37.26 196.84 2011.65 -626.03 -148.06 620.48 0.29 2274.79 37.6 196.5 2090.13 -683.57 -165.29 677.38 0.4 2366.57 38.15 196.6 2162.57 -737.58 -181.34 730.8 0.6 2462.51 38.7 196.53 2237.73 -794.73 -198.34 787.33 0.58 2560.37 39.02 197.16 2313.94 -853.5 -216.13 845.43 0.52 2608.13 39.05 197.33 2351.03 -882.22 -225.05 873.83 0.23 2690.97 37.04 193.94 2416.28 -931.36 -238.84 922.46 3.5 2787.17 36.86 188.34 2493.18 -988.04 -250.01 978.72 3.5 2882.29 39.27 187.82 2568.06 -1046.1 -258.24 1036.45 2.56 2977.06 41.36 188.17 2640.32 -1106.82 -266.77 1096.83 2.22 3075.62 41.37 191.51 2714.3 -1170.98 -277.9 1160.56 2.24 3170.85 40.4 192.3 2786.29 -1231.97 -290.76 1221.07 1.15 3266.37 39.84 188.55 2859.35 -1292.48 -301.9 1281.15 2.6 3360.82 39.91 185.89 2931.84 -1352.54 -309.51 1340.91 1.81 3457.85 1 39.69 183.98 3006.39 -1414.41 -314.85 1402.56 1.28 31 CANRIG Is • • CvnocoPhillips 2L -322A 3552.91 39.03 180.71 3079.89 -1474.63 -317.33 1462.65 2.29 Measured Depth (ft) Incl. o Azim. o True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (°/100ft) 3648.45 38.04 175.69 3154.65 -1534.08 -315.49 1522.13 3.43 3743.5 38.97 173.02 3229.03 -1592.95 -309.66 1581.18 2 3837.66 39.5 173.14 3301.96 -1652.07 -302.48 1640.51 0.57 3932.49 39.64 173.78 3375.06 -1712.09 -295.6 1700.73 0.45 4027.29 39.69 175.33 3448.04 -1772.32 -289.86 1761.13 1.04 4121.54 39.7 175.31 3520.56 -1832.32 -284.95 1821.26 0.02 4219.49 39.62 176.34 3595.97 -1894.67 -280.4 1883.73 0.68 4314.39 39.72 177.5 3669.02 -1955.16 -277.14 1944.3 0.79 4409.32 39.55 176.7 3742.13 -2015.64 -274.08 2004.84 0.57 4504.95 39.67 178.28 3815.8 -2076.54 -271.41 2065.8 1.06 4598.11 39.69 178.7 3887.5 -2136 -269.84 2125.29 0.29 4695.19 39.82 178 3962.14 -2198.06 -268.06 2187.37 0.48 4789.56 39.49 175.94 4034.79 -2258.19 -264.88 2247.57 1.44 4884.94 39.74 174.18 4108.27 -2318.78 -259.64 2308.3 1.21 4980.74 39.93 175.01 4181.84 -2379.87 -253.86 2369.56 0.59 5076.01 39.93 175.09 4254.89 -2440.79 -248.58 2430.63 0.05 5171.32 39.98 175.34 4327.95 -2501.79 -243.48 2491.76 0.18 5266.11 40.08 175.46 4400.53 -2562.56 -238.59 2552.67 0.13 5362.02 1 39.89 175.96 4474.02 -2624.01 -233.98 2614.25 0.39 5457.69 40.39 175.88 4547.16 -2685.53 -229.59 2675.88 0.53 5548.73 43.16 174.62 4615.05 -2745.97 -224.55 2736.46 3.18 5646.17 46.29 174.49 4684.27 -2814.22 -218.04 2804.89 3.21 5742.47 49.66 174.4 4748.73 -2885.41 -211.12 2876.28 3.5 5838.81 52.37 173.87 4809.33 -2959.89 -203.46 2950.99 2.85 5934.13 54.9 173.8 4865.85 -3036.2 -195.21 3027.54 2.65 6028 57.53 174.81 4918.04 -3113.83 -187.48 3105.39 2.94 6124.66 60.33 176.14 4967.92 -3196.35 -180.97 3188.09 3.13 6156.18 61.35 177.15 4983.28 -3223.83 -179.36 3215.6 4.28 6246.37 65.73 177.22 5023.46 -3304.45 -175.39 3296.32 4.86 6317.95 69.57 177.44 5050.67 -3370.57 -172.31 3362.5 5.37 6364.21 69.61 178.08 5066.8 -3413.89 -170.62 3405.86 1.3 6459.35 70.33 178.26 5099.39 -3503.23 -167.76 3495.24 0.78 6555.3 71.83 178.86 5130.5 -3593.97 -165.48 3586 1.67 6650.84 73.44 177.73 5159.02 -3685.11 -162.77 3677.18 2.03 6743.85 76.37 176.37 5183.24 -3774.78 -158.14 3766.96 3.45 6840.44 81.83 174.86 5201.49 -3869.31 -150.88 3861.68 5.86 6937.02 86.02 173.32 5211.71 -3964.81 -140.99 3957.47 4.62 7031.68 85.85 174.42 5218.42 -4058.69 -130.91 4051.65 1.17 7127.71 86.29 177.91 5225.01 -4154.26 -124.5 4147.39 3.65 7222.49 90.39 179.24 5227.75 -4248.95 -122.14 4242.1 4.55 7317.28 91.1 179.59 5226.52 -4343.73 -121.18 4336.85 0.84 7413.86 91.2 180.08 5224.58 -4440.29 -120.9 4433.37 0.52 CAN21G 32 • • ConocoPh l li ps 2L -322A 7508.17 91.1 181.32 5222.69 -4534.57 -122.05 4527.55 1.32 7606.16 91.29 182.72 5220.65 -4632.48 -125.5 4625.27 1.44 Measured Depth (ft) Incl. (0) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (.1100ft) 7697.27 89.87 184.14 5219.72 -4723.41 -130.95 4715.97 2.2 7793.06 89.02 183.4 5220.65 -4818.99 -137.25 4811.27 1.18 7887 89.76 179.61 5221.65 -4912.88 -139.72 4905.01 4.11 7980.53 89.63 177.45 5222.15 -5006.37 -137.32 4998.53 2.31 8078.22 89.8 175.73 5222.64 -5103.88 -131.51 5096.18 1.77 8174.55 89.32 174.78 5223.38 -5199.88 -123.54 5192.4 1.1 8269.66 89.21 173.42 5224.6 -5294.47 -113.77 5287.28 1.43 8364.56 89.88 176.16 5225.35 -5388.97 -105.15 5382.01 2.97 8460.69 89.83 174.21 5225.59 -5484.75 -97.08 5478.02 2.03 8555.48 90.35 173.87 5225.44 -5579.03 -87.24 5572.59 0.66 8651.73 90.16 176.18 5225.02 -5674.91 -78.89 5668.7 2.41 8747.15 90.76 176.47 5224.25 -5770.13 -72.78 5764.08 0.7 8841.45 91.18 176.65 5222.65 -5864.25 -67.12 5858.33 0.48 8937.06 90.1 177.47 5221.59 -5959.72 -62.22 5953.92 1.42 9032.21 89.73 178.94 5221.73 -6054.82 -59.24 6049.07 1.59 9127.56 89.11 180.36 5222.69 -6150.16 -58.65 6144.37 1.62 9222.95 88.11 180.49 5225.01 -6245.52 -59.36 6239.65 1.06 9317.99 85.02 181.03 5230.7 -6340.37 -60.62 6334.39 3.3 9415.31 85.13 180.04 5239.05 -6437.33 -61.52 6431.26 1.02 9455.78 85.2 178.61 5242.47 -6477.65 -61.05 6471.57 3.53 9515 85.20 1 178.61 1 5247.57 *Projected To Total Depth CANRIG 33 C+OI'UDtc -III 5 2L -322A 5.2 Bit Record 34 ('.ANRIG Depth In Total Bit Avg. Avg. Avg. Avg. Bit Size Make Type / S# Jets / TFA MD/ Footage Hrs ROP WOB RPM PP Wear BHA (ft/hr) (Klbs) (psi) 1 10%11 Smith VR+ 16x3, 14 254' 2785' 6.5 -- -- -- -- None 1 2 9 7/8" Hycalog PDC/ 12x3/ 2785' 3439' 40.9 113.3 9.5 123.7 2234 1 -1 -WT -A- X 2 SKH5416D 0.74 -1 -NO -TD 3 6.5" NOV PDC/ 11X5/ 6224' 3292' 74.02 55.1 8.1 116.3 2363 1 -1 -WT -A- X -1 -PN -TD 3 A192849 0.46 34 ('.ANRIG ConoC[ lli j]5 X50,. fr^C. 2L -322A 5.3 Mud Record Contractor: MI SWACO Mud Type: LSND Date Depth MW (ppg) Temp VIS (s/qt) PV YP Gels FL (cc) FC Sols ( /o) O/W Ratio Sd ( /o) pH Cl (ml/I) Ca (ml/1) 3/16/14 - - - - - - - - - - - - - - - 3/17/14 - - - - - - - - - - - - - - - 3/18/14 - - - - - - - - - - - - - - - 3/19/14 2470' 9.5 86 62 8 17 12/14/15 7.2 1/- 5 1/95 - 9.6 500 100 3/20/14 2470' 9.5 68 58 9 15 11/13/14 7.4 1/- 5 1/95 - 9.6 600 100 3/21/14 2470' 9.5 66 48 8 19 12/14/15 7.4 1/- 5 1/95 - 9.7 500 100 3/22/14 2470' 9.5 52 52 8 17 13/14/15 7.2 1/- 5 1/95 - 10.0 1000 100 3/23/14 2785' 9.6 72 44 8 19 12/14/16 5.6 1/- 5.5 2/93 - 9.7 1000 200 3/24/14 2800' 9.6 80 44 9 24 13/15/16 5.2 1/- 5.5 2/93 - 9.9 1400 - 3/25/14 4572' 9.5 104 47 10 23 12/19/24 4.8 1/- 7 2/91 - 10.0 1200 - 3/26/14 5142' 10.0 92 50 10 24 11/16/24 4.9 1/- 10 2/88 Tr 9.9 1000 40 3/27/14 6224' 9.9 98 41 8 18 8/9/11 4.9 1/- 9 3/88 Tr 9.6 600 80 3/28/14 6224' 10.0 80 41 8 18 8/9/11 4.7 1/- 9 3/88 Tr 9.5 600 40 3/29/14 6224' 10.3 78 44 10 18 8/9/11 7.9 1/- 10 4/86 Tr 9.4 600 40 3/30/14 6224' 10.2 70 45 10 18 9/11/13 7.6 1/- 10 4/86 Tr 9.5 600 40 3/31/14 6224' 11.2 66 68 16 20 7/10/13 3.2 1/- 15 2/84 - 9.8 135600 80 4/1/14 6241 10.1 78 65 11 18 11/13/15 6.6 1/- 10 3/87 Tr 10.9 600 1800 4/2/14 6745' 11.5 92 44 13 23 5/7/11 3.1 1/- 15 3/82 - 9.8 130000 80 4/3/14 7181' 11.9 98 45 14 25 7/10/11 3.2 1/- 18 2/80 Tr 9.9 124000 80 4/4/14 7901' 11.9 105 45 16 26 5/6/7 3.7 1/- 18 3/79 Tr 9.6 121000 80 4/5/14 8607' 11.9 102 45 18 21 5/6/7 3.9 1/- 18 3/79 0.25 9.7 135000 80 4/6/14 9190' 11.9 94 45 17 20 5/6/7 4.5 1/- 18 3/79 0.25 9.8 124000 80 4/7/14 9515' 12.2 90 47 19 24 4/6/8 3.8 1/- 20 4/76 0.25 9.6 131000 80 4/8/14 9515' 12.1 84 44 15 22 4/5/6 4.2 1/- 19 4/77 0.25 9.6 129000 80 4/9/14 9515' 12.1 80 44 16 21 4/5/6 4.2 1/- 18 2/80 0.25 9.3 110000 80 4/10/14 9515' 12.1 72 47 17 24 5/6/8 4.2 1/- 18 2/80 0.25 9.5 111000 80 4/11/14 9515' 12.2 81 50 17 25 5/7/8 4.5 1/- 19 3/78 0.25 9.5 106000 80 4/12/14 9515' 12.4 70 1 54 1 18 26 8/9/11 4.7 1/- 20 3/77 0.25 9.4 105000 80 4/13/14 9515' 12.7 78 56 19 30 9/10/11 4.5 1/- 20 3/77 0.25 9.5 112000 80 4/14/14 9515' 12.7 70 53 15 33 7/9/11 4.5 1 1/- 21 3/76 0.25 9.4 127000 80 W COAillllps +sem. trx:. 2L -322A Abbreviations MW = Mud Weight WL = Water or Filtrate Loss Ca = Hardness Calcium YP = Yield Point Gels = Gel Strength Sd = Sand content Cl = Chlorides VIS = Funnel Viscosity PV = Plastic Viscosity Sols = Solids ECD = Effective Circulating Density FC = Filter Cake O/W = Oil to Water ratio W Date Depth MW (ppg) Temp VIS (s/qt) PV YP Gels FL (cc) FC Sols ( /o) O/W Ratio Sd ( /o) pH Cl (ml/1) Ca (ml/1) 4/15/14 9515' 12.7 86 46 19 30 7/9/10 3.9 1/- 21 3/76 0.25 9.2 125000 80 4/16/14 9515' 12.7 89 45 16 28 7/10/11 4 1/- 21 3/76 0.25 9.3 125000 80 4/17/14 9515' 12.7 75 53 17 28 7/8/9 4.5 1/- 21 3/76 0.25 9.2 120000 80 Abbreviations MW = Mud Weight WL = Water or Filtrate Loss Ca = Hardness Calcium YP = Yield Point Gels = Gel Strength Sd = Sand content Cl = Chlorides VIS = Funnel Viscosity PV = Plastic Viscosity Sols = Solids ECD = Effective Circulating Density FC = Filter Cake O/W = Oil to Water ratio W * 6 SHOW REPORTS • • ConocoPhillips 2L -322A Hydrocarbon Show Report # 'I Operator: Repsd ME: 2L327AAPI Nrndier: 50-103-20828-01-00 Field Tan U Pool D#_ 415T�1i14 mw FloWsOM Tine_ &2r lira8r Stat End Abdo e83e %D 8M MD Uraisd S of htredm 5155 T%o 5225 TVD Aveirages PiMer Plot. � Before Diuring Ager htmd� ROP upjh 130.0 60.7 41.3 181A 1MO6 17:7 7.1 7.3 22-0 RPM 113.8 118.4 118.e 125A am llud 11.20 11.60 11.90 11.6D _ ,m w Cts 30,000 30.000 30= MOM Total Gas 108 110 81 278 Cl IDJM TIx= 122M 44,481 C2 383 1,25:3 587 3.125 C3 82 3612 195 981 , , a Cd 9 217 121 C5 1 794 55 236 LdtKAow Sardsionefsands = alive gFay m W o%e gray with clear tD tragi sn>o" nwmak black hues, and median dark gray hues cokws; quartz dmw— t framework; upper fare to knver fare grain siP; somV; subrounded to rounded angutartr, nnderate sphericity; Poor oonsdidabon vvdh easdy t iabe t© fudge hardness. oernert matrix grain s44ort; as odor in bolt sarnpie- Odor £tmwate Fkmxesoenm cut 9Uli TjMre tit Distri Em tr>nuaaie waftab cakwFiwe Cokw iib GRA Residual Arnorrtp>louba Caiort Nw Q Star Fire Res"w FIS, 1►nme "MeION Cut !4e 1.6 Free Oil in Mud ; mne Commends Show Rating: 0.0 Poo; QA Fair, C3.0 Good. <4.0 F Fent This waNval aw cw*d drilled. Britten Adams 37 • ConocoPhillips AOSka, 4N% 2L -322A ConocoPhillips CAI'�M 2L -322A Ratio Plot #1 April 5, 2014 Depths 6636' to 9515' 10000 1000 100 10 10 Ej i 1 2 3 4 C1/C2 C1/C3 C1/C4 C1/C5 0 38 ConocoPhillips AJISK-31 Wlr 2L-322A • 7 DAILY REPORTS • • C.AMG 39 0 • CANRIG ConocoPhillips Alaska, Inc. Report for: Granville Rizek Josh Riley Date: 3/21/14 Time: 23:59 milli.... D—M— 2L -322A Daily Geologic Report Current Depth (MD): 2461' Current Depth (TVD): 2461' 24 hr Footage (MD): 0 Current Pressure Test Mud Lines Operations: ROP: ^ Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: A. .-J M........+:.... /1 0 A 7!Y -'_W -j1'5 FV: 48 PV: 8 YP: 1 16 FL: 7.4 Gels: 1 12/14/15 Sol: 5 H: 9.7 CI 500 Ca++: 100 7771 MW Change: Depth: From: Mud Loss event: Depth: Volume: nr n n+n To: Reason: Ditch Gas: Current: 0 1 Max: 0 1 Depth (MD/TVD): C3 Avg BG: 0 1 1246172461' Trip Gas I 1nm e. .... ,.., Tools Run Depth Interval MD/TVD Hi Low Av Comments GR Resi Res2 Res23 Neutron Sonic !_ . C. r+n rs.� ,P -W CANRIG Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None rs.� ,P -W CANRIG Lithologies: Current: Last 24 hrs: Test BOPs, install and remove wear bushing, then lay down test joints. Pick up 66 joints of 4" drill pipe. Pull out of hole. Perform well control drill. Pick up drill pipe. Operational Summary: Trip in hole to 2461' and tagged cement lightly. Test standpipe manifold. Rig up and test mud lines to 3500 PSI. Line leaked. Circulate and condition. Tighten 4" bonnet on pump #2. Retest and bonnet still leaking. Continue to troubleshoot and test mud lines. Failures: None L_J • CAN121G r� L J CAI\iRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Josh Riley Date: 3/22/14 Time: 23:59 Current Depth (MD): 2461' Current Finish casing pressure Current Depth (TVD): 2461' Operations: test and rig down test equipment. 24 hr Footage (MD): 0 nrillinn Pnromo+ore ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: MW: 9.5 FV: 52 PV: 18 1 =.1 FL: 7.2 Gels: 1 13/14/15 Sol: 5 H: 1 10.0 1 Cr1000 Ca++ 100 MW Change: Depth: From: Mud Loss event: Depth: Volume: rzne nnta To: Reason: Ditch Gas: Current: 0 Max: 2 Depth (MD/TVD): 2461'/2461' Avg BG : 0 C4N C51 C5N Trip Gas I AAM C -11 Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Res2 Res23 Neutron Sonic No._ Dept MD/TVD TG C1 C2 C3 C41 C4N C51 C5N CANRIG Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None No._ Dept MD/TVD TG C1 C2 C3 C41 C4N C51 C5N CANRIG Lithologies: Current: Last 24 hrs: Pressure test mud lines and top drive to 3500 PSI, good test. Displace well with 9.5 PPG LSND mud. Check volumes on pits and tiger tank and volume did not Operational Summary: match. Continue to pump 100 BBLS to complete displacement. Monitor well, it was static. Trip out of hole to surface. Pick up BHA to drill out retainer. Run in hole, then circulate and condition. Test casing to 3000 PSI, good test. Rig down test equipment and blow down lines. Failures: None • • • CANING r..:.ConocoPhillips Alaska, Inc. ,,,.,,, 2L -322A Daily Geologic Report Report for: Granville Rizek Josh Riley Date: 3/23/14 Time: 23:59 Current Depth (MD): 2785' Current Laying down BHA Current Depth (TVD): 2496' Operations: 24 hr Footage (MD): 303' flrillinry D�r�moforc ROP: Current: 0 Max: 1380 Torque: Current: 0 Max: 18634 WOB: Current 0 Max: 37 RPM: Current: 0 Max: 2513 PP: Current: 0 Max: 1493 Lag: Strokes: 2622 Time: 18 min Surf -Surf: Strokes: 2968 Time: 20 min ECD: Current: C3 Max: C4N Mud Pro erties @ 2785' MW: 9.6 1 FV: 44 1 PV: 8 YP: 19 Gels: 12/14/16 1 Sol: 5.5 1 pH: 9.7 Cl-: 1000 Ca++ 200 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 278 Depth (MD/TVD): 2461' Avg BG: 40 1 \Alli Q......n r.. Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Res 1 Res2 Res23 Neutron Sonic n___ e,,.,....i.. No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2643' 274 48984.57 552.46 342.86 95.94 245.01 86.08 174.16 CANNG Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None n___ e,,.,....i.. No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2643' 274 48984.57 552.46 342.86 95.94 245.01 86.08 174.16 CANNG Lithologies: Current: Last 24 hrs: Drill cement from 2516' and tag retainer at 2518'. Drill retainer and cement to Operational Summary: 2607'. Continue to 2636' slide drilling. Slide from 2636' to 2714', building curve. Rotary drill from 2714' to 2785'. Perform LOT at 700 PSI, EMW=16. Trip out of hole and lay down BHA. Failures: None • • r: CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Josh Riley Date: 3/24/14 Time: 23:59 Current Depth (MD): 3175' Current Drill ahead Current Depth (TVD): 2794' Operations: 24 hr Footage (MD): 390' nrillir Dnrnmo+orc ROP: Current: 148.5 Max: 214.4 Torque: Current: 5424.7 Max: 7323 WOB: Current 2.24 Max: 19 RPM: Current: 119.9 Max: 123 PP: Current: 1787.3 Max: 1817 Lag: Strokes: 3557 Time: 18.1 Surf -Surf: Strokes: 3807 Time: 19.3 ECD: Current: C3 Max: C4N RA -4 Dr---, +;o rl 0Q1)0'/9CZ07' M MW: 9.6 FV: 44 PV: 19 YP: 1 24 1 FL: 5.2 Gels: 1 13/15/16 1 Sol: 5.5 H: 9.9 CI 1400 1 Ce ' - MW Change: Depth: From: Mud Loss event: Depth: Volume: r-'- n n+n To: Reason: Ditch Gas: Current: 31.8 Max: 109 Depth (MD/TVD): 2824' AvgBG: 21 C51 C5N Trip Gas I %Aln C.v.m Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Rest Rest Res23 Neutron Sonic rpt 1T No. v� Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas 2 3251 13 1980.34 103.79 3 3293 33 Connection Gases 106.30 C1 C2 C3 C41 C4N C51 C5N None rpt 1T No. v� Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 3237 10 1391.71 2 3251 13 1980.34 103.79 3 3293 33 5821.56 106.30 4 3332 1 33 1 5541.64 75.75 Lithologies: Current: Last 24 hrs: Lay down BHA. Pick up BHA. Trip in hole. Surface test MWD tool at 937'. Trip in Operational Summary: hole to 2565'. Cut and slip drilling line. Service top drive. Trip in hole to 2785'. Begin to drill ahead from 2785' to 3175'. Failures: None • • CANRIG w • CAIVRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: L. Martin Josh Riley Date: 3/25/14 Time: 23:59 Current Depth (MD): 4666' Current Depth (TVD): 3940' 24 hr Footage (MD): 1491 nrillinn Pornmctcre Current Prepare for short trip. Operations: ROP: Current: 0 Max: 199.5 Torque: Current: 5424.7 Max: 19095 WOB: Current 2.24 Max: 20 RPM: Current: 119.9 Max: 141 PP: Current: 24 Max: 2381 Lag: Strokes: 5247 Time: 25 Surf -Surf: Strokes: 5611 Time: 27 ECD: Current: 0 Max: 10.44 MW: V9.5 V FV: 47 PV: 10 YP: 23 FL: 14.8 Gels: 1 12/19/24 Sol: 7 H: 10.0 CI 1200 Ca++: 3 MW Change: Depth: From: Mud Loss event: Depth: Volume: nno nntn To: Reason: Ditch Gas: Current: 0 Max: 62 Depth (MD/TVD): 4454' Avg BG: 24.3 Trip Gas 2 4560 22 4750.08 Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Res2 Res23 Neutron Sonic �__ n_._.._1_,. No. vu Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas 2 4560 22 4750.08 218.47 - - - 3 4586 40 Connection Gases 190.85 - - - - C1 C2 C3 C41 C4N C51 C5N None �__ n_._.._1_,. No. vu Depth (M /TVD TG C1 C2 C3 C41 C4N C51 C5N 1 4500 5 928 - - - 2 4560 22 4750.08 218.47 - - - 3 4586 40 8668.29 190.85 - - - - 4 1 4615 134 7522.69 149.28 - - D Lithologies: Current: 80% Claystone, 20% Siltstone Last 24 hrs: 90% Claystone, 5% Sandstone, 5% Siltstone isOperational Summary: Failures: None • 0 Drill ahead from 3175' 4666'. Prepare for short trip. • • CANRIG ConocoPhilli s Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Josh Riley Date: 3/26/14 Time: 23:59 Current Depth (MD): 5236' Current Drill ahead Current Depth (TVD): 4399' Operations: 24 hr Footage (MD): 570' nrillinn D�romo+orc ROP: ^ Current: 123.2 Max: 453.8 Torque: Current: 7903.3 Max: 10218 WOB: Current 7.1 Max: 20 RPM: Current: 126 Max: 143 PP: Current: 2477.5 Max: 2715 Lag: Strokes: 6004 Time: 29 Surf -Surf: Strokes: 6414 Time: 31 ECD: Current: 10.68 Max: 10.77 R A..A M..........+i.... /l nOnn'I')rn7' Y MW: 10.0 T FV: 50 PV: 1 10 YP: 1 24 FL: 4.9 Gels: 1 11/16/24 1 Sol: 10 H: 9.9 CI 1000 Ca` - 40 MW Change: Depth: From: Mud Loss event: Depth: Volume: nr n n+n To: Reason: Ditch Gas: Current: 0 Max: 90 Depth (MD/TVD): 5047' Avg BG: 45.4 20.08 108.47 Rest 4666'- 5236' rir.�rautr.!r_.tirr� Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 4666'- 5236' 248.06 20.08 108.47 Rest 4666'- 5236' 4.58 1 3.38 Res2 4666'- 5236' 365.38 2.43 6.14 Res23 C2 C3 C41 C4N Neutron C5N None 415.60 1 241.08 - - - Sonic l_., C.. n+n rsr_W.M.M.. T r -_w No. vM Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas 420.20 190.48 - - - 2 5050 23 3741.92 187.08 117.70 - - - - Connection Gases 5156 C1 C2 C3 C41 C4N C51 C5N None 415.60 1 241.08 - - - rsr_W.M.M.. T r -_w No. vM Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 5000 68 13731.40 420.20 190.48 - - - 2 5050 23 3741.92 187.08 117.70 - - - - 3 5156 36 7195.99 328.55 201.28 52.65 65.17 - - 4 5217 1 9626.08 415.60 1 241.08 - - - Lithologies: Current: 90% Siltstone, 10% claystone Last 24 hrs: 80% Siltstone, 10% Sandstone, 10% Claystone Short trip from 4666' to 2673'. Drill from 4666' to 5142'. Pump pop off valve Operational Summary: damaged. Rebuild pop off valve, rebuild 4" demco on mud line. Drill ahead from 5142' to 5236'. Failures: None • CANING �,��,,.�r.,a,.,,,.,�. • • CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Josh Riley Date: 3/27/14 Time: 23:59 Current Depth (MD): 6224' Current Trip out of hole Current Depth (TVD): 5132' Operations: 24 hr Footage (MD): 988' nrillinn Pnrnmatnre ROP: Current: 0 Max: 203.5 Torque: Current: 3.5 Max: 1 11624 WOB: Current 0 Max: 22 RPM: Current: 0 Max: 141 PP: Current: 25.7 Max: 3387 Lag: Strokes: 7015 Time: 46 Surf -Surf: Strokes: 7488 Time: 46 ECD: Current: 0 Max: 10.89 Mud Pro erties @ 2800'/2507' Current: MW: 9.9 FV: 41 PV: 8 Y P : F18 20.08 Gels: 8/9/11 Sol: 9 H: 9.6 Cl_:600 Ca++ 80 MW Change: Depth: Mud Loss event: Depth: rrne nnt!n From: To: Reason: Volume: Ditch Gas: Current: I 0 Max: 1 185 1 Depth (MD/TVD): 5786' Avg BG: 65.8 290.9 20.08 107.56 Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 5236'/4399'- 6224'/5132' 290.9 20.08 107.56 Rest 5236'/4399'- 622475132' 466.26 0.17 4.97 Res2 5236'/4399'- 622475132' 2223.61 0.07 6.78 Res23 C2 C3 C41 C4N Neutron C5N None 114.3 96.2 Sonic 6192' 185 29184.1 2640.9 vN Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas 1 6083' 64 12532.5 736.2 602.7 60.8 192.9 Connection Gases 125.1 C1 C2 C3 C41 C4N C51 C5N None 114.3 96.2 3 6192' 185 29184.1 2640.9 1845.6 vN Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 6083' 64 12532.5 736.2 602.7 60.8 192.9 78.4 125.1 VNo. 2 6126' 132 23917.3 1622.2 1085.9 208.2 435.0 114.3 96.2 3 6192' 185 29184.1 2640.9 1845.6 372.0 810.4 235.3 233.1 4 6224' 92 1 14009.2 1230.51 1100.8 175.3 1 473.5 104.0 108.0 Lithologies: Current: 40% Sand, 30% Sandstone, 20% Siltstone, 10% Claystone Last 24 hrs: 60% Siltstone, 25% Claystone, 15% Sand/Sandstone Drill ahead from 5237' to 6224'. TD for casing. Circulate and condition. Back ream Operational Summary: out two stands. Pull out of hole on elevators, hole conditions look good. Trip out of hole using elevators. Tight hole at 5845', 5785' and 4960'. Pulled over 20K over, worked pipe back down and pulled clean. Failures: None f�J 40 CANRIG 0 L` CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Josh Riley Date: 3/28/14 Time: 23:59 Current Depth (MD): 6224' Current Depth (TVD): 5132' 24 hr Footage (MD): 0 Current Rig up to run casing Operations: ROP: ^Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Y MW: v10.0 FV: 41 PV: 8 YP: 18 FL: 14.7 Gels: 8/9/11 1 Sol: 9 H: 9.5 CI 600 Ca++ 40 MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth MD/TVD Ava BG: I 1AM a .., ,,1.,, To: Reason: Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Res2 Res23 Neutron Sonic No. vu Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD CANRIG ❑xe.i.nrr 1'n u..,i..... Lm. Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None No. vu Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD CANRIG ❑xe.i.nrr 1'n u..,i..... Lm. Lithologies: Current: Last 24 hrs: • Pull out of hole and lay down BHA. Test BOPs. Rig up to run casing. Make Operational Summary: dummy run with hanger. Service top drive. Rig up for running Tesco tool. Failures: None L_J • CANIG • • CANRIG ConocoPhillips Alaska, Inc. Report for: Lee Martin Josh Riley Date: 3/29/14 Time: 23:59 2L -322A Daily Geologic Report Current Depth (MD): 6224' Current Depth (TVD): 5132' 24 hr Footage (MD): 0 Current Rig up for cement job Operations: ROP: ^ Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: nA...r o.......+:-- /% G7I)A'/moi i G' ----- - C1 C2 C3 C41 C4N C51 C5N Trip Gas MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De Avg BG To: Reason: Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Res2 Res23 Neutron Sonic No. vN Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD CANRIG Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None No. vN Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD CANRIG Lithologies: Current: Last 24 hrs Pick up Tesco running tool. Rig up/down to run casing. Run casing to 6214.65'. Operational Summary: Circulate and condition. Prep rig floor for cement job. Rig down casing job. Rig up for cement job. Failures: None • • CMRIG • • CAN�t.G ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Josh Riley Date: 3/30/14 Time: 23:59 Current Depth (MD): 6224' Current Test BOPs Current Depth (TVD): 5132' Operations: 24 hr Footage (MD): 0 o....,..,.,+. ROP: Current Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: AA...4 o........-+;.... /l a1313 A'/CZi i r.' 4 MW: v10.2 ` FV: 45 PV: 10 YP: 18 FL: 7.6 Gels: 9/11/13 Sol: 10 H: 9.5 CI 600 Ca++ 40 MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Ava BG: To: Reason: Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Res 1 Res2 Res23 Neutron Sonic No. vu Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None No. vu Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD Lithologies: Current: Last 24 hrs: Pressure test cement lines. Prepare 96 bbls of 15.8 PPG cement. Perform cement Operational Summary: job, pump 85 bbls cement. Rig down casing/cement job. Change rams from 7 5/8 to 3 1/2 x 6. Pick up test tools. Test BOPs. Failures: None • • CMR,IG • • CANRIG ConocoPhillips Alaska, Inc. Report for: Lee Martin Josh Riley Date: 3/31/14 Time: 23:59 2L -322A Daily Geologic Report Current Depth (MD): 6224' Current Depth (TVD): 5132' 24 hr Footage (MD): 0 Current Prepare to run in hole Operations: with 4" drill pipe ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties @ 622475115' Depth MD/TVD MW: 11.2 1 FV: 68 C41 PV: 16 YP: 1 20 FL: 13.2 Gels: 7/10/13 1 Sol: 15 p H: 9.8 CF 1 135600 1 Ca- L80 Connection Gases C1 C2 C3 C41 C4N C51 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG: Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Rest Res2 Res23 Neutron Sonic No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD CANRIG Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD CANRIG Lithologies: Current: Last 24 hrs: Test BOPs. Service top drive. Down time due to top drive. Bring down frozen kelly Operational Summary: hose to rig floor to thaw and steam whip frozen standpipe. Pick up BHA and service top drive. Pick up drill pipe. Cut 11 wraps of drilling line. Prepare to run in hole with 4" drill pipe. Failures: None r� • s • El CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Rick Bjorhus Date: 4/1/14 Time: 23:59 Current Depth (MD): 6244' Current FIT Test Current Depth (TVD): 5147' Operations: 24 hr Footage (MD): 20' ROP: ~Current 0 Max: 145.3 Torque: Current: 0 Max: 9107 WOB: Current 0 Max: 15 RPM: Current: 0 Max: 129 PP: Current: 12.5 Max: 2462 La Strokes: 2689 Time: 32 Surf -Surf: Strokes: 3130 Time: 34 ECD: Current: C3 Max: C4N . A. .J n____..a _ /% n- nn A'IC4 i CI MW: 10.1 FV: 1 65 1 PV: 11 YP: 1 18 FL: 6.6 Gels: 1 11/13/15 Sol: 10 H: 10.9 CI 600 Ca": 1800 MW Change: Depth: From: Mud Loss event: Depth: Volume: To: Reason: Ditch Gas: Current: 0 Max: 26 Depth (MD/TVD): 6239' Avg BG: 17 C5N Trip Gas Tools Run Depth Interval MD[TVD Hi Low Avg Comments GR Resi Res2 Res23 Neutron Sonic No. vu Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 6241' 19 2466.19 174.74 253.91 48.69 143.88 CMR,IG Depth(MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N None No. vu Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 6241' 19 2466.19 174.74 253.91 48.69 143.88 CMR,IG Lithologies: Current: Last 24 hrs: Trip in hole from 1000', tag cement at 6119'. Drill out of cement from 6119' to Operational Summary: 6244'. Circulate one bottoms up for FIT test. Short trip, stand one stand back and flow check well for 15 minutes. Rig up and perform FIT test with 10 ppg mud. Failures: None • • CMRIG • 0 F' CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Rick Bjorhus Date: 4/2/14 Time: 23:59 Current Depth (MD): 6795' Current Drill ahead Current Depth (TVD): 5196' Operations: 24 hr Footage (MD): 551' nrillinn Pnrnmctcre ROP: Current: 20.4 Max: 269.1 Torque: Current: 9186.06 Max: 1 10114 WOB: Current 16.03 Max: 25 RPM: Current: 119.7 Max: 125 PP: Current: 2658.1 Max: 2768 La Strokes: 2897 Time: 33 Surf -Surf: Strokes: 3330 Time: 36 ECD: Current: 12.46 Max: 12.55 M MW: 11 5 FV: 44 PV: 13 YP: 23 FL: 3.1 Gels: 1 5/7/11 Sol: 1 15 H: 9.8 Cl_� 130000 Ca--- 80 MW Change: Depth: From: Mud Loss event: Depth: Volume: (_'no rhtn To: Reason: Ditch Gas: Current: 318 Max: 1920 Depth (MD/TVD): 6745' Avg BG: 17 136.3 Rest 6244'- 6795' 6.81 1.79 I 1AM c . n, r., Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 6244'- 6795' 163.9 131.4 136.3 Rest 6244'- 6795' 6.81 1.79 4.2 Res2 6244'- 6795' 9.01 1.7 4.2 Res23 6840' 359 61888.22 4268.84 Neutron 296.84 Connection Gases 6712' 181093.73 Sonic 6811.90 1369.57 3017.82 582.15 Nov vM Depth C1 C2 C3 C41 C4N C51 C5N C5N MD/TVD 6810' 511 96343.26 6233.56 2647.00 475.89 1138.41 Trip Gas 306.15 2 6840' 359 61888.22 4268.84 1924.63 296.84 Connection Gases 6712' 181093.73 14995.15 6811.90 1369.57 3017.82 582.15 612.67 None 1410.08 297.55 335.30 Nov vM Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 6810' 511 96343.26 6233.56 2647.00 475.89 1138.41 227.69 306.15 2 6840' 359 61888.22 4268.84 1924.63 296.84 838.46 176.16 250.45 3 6875' 662 127293.47 8981.11 3848.09 543.95 1410.08 297.55 335.30 CANRIG 4 1 6900 1 1150 1258799.45 1 16451.90 1 5989.61 1 751.80 1 1969.05 1 387.02 1 436.61 Lithologies: Current: 70% Sandstone, 20% Siltstone, 10% Claystone Last 24 hrs: 60% Siltstone, 30% Sandstone, 10% Claystone Perform FIT test. Change hole to 11.2 Klashield mud. Drill from 6244' to 6746'. Operational Summary: Saw maximum gas of 1920 units at 6745'. Weight up to 11.4 ppg mud. Drill ahead from 6746' to 6808'. Failures: None • 0 CANRIG • • r� CAIVR.G ConocoPhillips Alaska, Inc. Report for: Lee Martin Rick Bjorhus Date: 4/3/14 Time: 23:59 2L -322A Daily Geologic Report Current Depth (MD): 7222' Current Depth (TVD): 5233' 24 hr Footage (MD): Current Drill ahead Operations: ROP: Current: 36.5 Max: 191.9 Torque: Current: 8152.2 Max: 10119 WOB: Current 13.1 Max: 21 RPM: Current: 117.6 Max: 123 PP: Current: 2247.9 Max: 2817 La Strokes: 3069 Time: 39 Surf -Surf: Strokes: 3584 Time: 46 ECD: Current: 13.02 Max: 13.09 RA.,A 0r-- .r+i..n /1 ROOA'/Ci 1 W Y MW: vii 9 FV: 45 PV: 14 YP: 1 25 FL: T -Ca++ 13.2 Gels: 1 7/10/11 Sol: 1 18 1 pH: 9.9 CI 124000 7.8 80 MW Change: Mud Loss event: rrno no+m Depth: 7050' From: 11.6 To: 11.9 Reason: High Gas Depth: Volume: Ditch Gas: Current: 289 Max: 2569 Depth (MD/TVD): 7054' Avg BG: 17 Avg Comments GR Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 6795'- 7222' 156.17 95.39 130.01 Resi 6795'- 7222' 10.9 5.9 7.8 Res2 6795'- 7222' 14.16 5.01 7.49 Res23 7200' 259 20203.884 2133.3205 Neutron 535.8387 Connection Gases 3218u@6966' 397802.38 Sonic 29814.94 4216.03 11152.83 2484.29 No. Depth C1 C2 C3 C41 C4N C51 C5N C5N MD/TVD 7170' 344 24826.665 3595.7801 3845.1549 926.1344 2931.1695 Trip Gas 1167.5855 2 7200' 259 20203.884 2133.3205 2108.311 535.8387 Connection Gases 3218u@6966' 397802.38 53116.13 29814.94 4216.03 11152.83 2484.29 2906.35 None 2614.448 838.733 1101.235 No. vM Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 7170' 344 24826.665 3595.7801 3845.1549 926.1344 2931.1695 931.0152 1167.5855 2 7200' 259 20203.884 2133.3205 2108.311 535.8387 1902.1688 684.57 896.9494 3 7230 521 72017.61 6793.785 4386.486 903.6224 2614.448 838.733 1101.235 CANRIG 4 1 7260 1 325 1 39425.56 1 2973.214 1 2273.767 1576.4127 1 1872.979 1 639.7226 1 953.768 Lithologies: Current: 70% Sandstone, 30% Siltstone Last 24 hrs: 70% Sandstone, 30% Siltstone Drill from 6808 to 6966'. Observed 3218 units downtime gas at 6966'. Weight up to Operational Summary: 11.6 ppg mud. Drill from 6966' to 7140'. Weight up to 11.8 ppg mud due to high gas. Make MADD pass from 7065' to 7050'. Take two samples. Monitor well then weight up to 11.9 ppg mud due to high gas. Monitor well. Drill from 7140' to 7253'. Failures: None • is • • CANRIG ConocoPhillips Alaska, Inc. ,,.,, ..�.r,.,,.,..I ,,, 2L -322A Daily Geologic Report Report for: Lee Martin Rick Bjorhus Date: 4/4/14 Time: 23:59 Current Depth (MD): 7970' Current Drill ahead Current Depth (TVD): 5222' Operations: 24 hr Footage (MD): 748' ROP: ^ Current: 46.5 Max: 137.7 Torque: Current: 8297.49 Max: 19182 WOB: Current 4.64 Max: 14 RPM: Current: 117.6 Max: 121 PP: Current: 2341.25 Max: 2411 Lag: Strokes: 3334 Time: 43 Surf -Surf: Strokes: 3900 Time: 51 ECD: Current: 12.98 Max: 13.14 K A. .-J n_.....,...a:,.,. /l Cnn A'/Ci-4C' MW: 11.97 FV: 45 PV: 16 YP: 26 FL: 3.7 Gels: 5/6/7 1 Sol: 18 H: 9.6 Cl -,121000 13.53 Ca++: 80 MW Change: Depth: From: Mud Loss event: Depth: Volume: r -,n, n'+� To: Reason: Ditch Gas: Current: 860 Max: 1382 Depth (MD/TVD): GR Avg BG: 446 104.79 135.89 Resi 7222'- 7970' Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 7222'- 7970' 162.89 104.79 135.89 Resi 7222'- 7970' 13.53 5.49 7.34 Res2 7222'- 7970' 13.53 4.79 7.21 Res23 7890 479 70315.526 7321.5175 Neutron 661.749 Connection Gases 7948' 27999.066 Sonic 2559.707 408.693 1431.225 412.649 v No Depth C1 C2 C3 C41 C4N C51 C5N C5N MD/TVD 7860 474 73549.642 7460.2558 4351.514 545.0005 1893.8945 Trip Gas 742.0065 2 7890 479 70315.526 7321.5175 4282.4517 661.749 Connection Gases 7948' 27999.066 3391.381 2559.707 408.693 1431.225 412.649 614.318 None 2063.9773 557.3586 796.7692 v No vM Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 7860 474 73549.642 7460.2558 4351.514 545.0005 1893.8945 563.3957 742.0065 2 7890 479 70315.526 7321.5175 4282.4517 661.749 1869.5313 567.0612 743.5017 3 7920 542 83046.093 8640.8483 4802.6232 682.1668 2063.9773 557.3586 796.7692 CMRIG �.�r.............1',,. 4 7950 217 1 24974.606 13061.4621 1 2354.5843 1 378.2544 1 1332.1617 1 385.731 1 574.9149 Lithologies: Current: 90% Sandstone, 10% Siltstone Last 24 hrs: 80% Sandstone, 20% Siltstone Operational Summary: Drill from 7253' to 7667' and circulate bottoms up. Make MADD pass from 7667' to 7603'. Drill from 7667' to 8005'. Failures: None • • CANRIG 1� • x CAN21G ,,mConocoPhilli s Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Rick Bjorhus Date: 4/5/14 Time: 23:59 Current Depth (MD): Current Depth (TVD) 24 hr Footage (MD): r)AIIi- Duero +nrc 8656' Current Drill ahead 5225' Operations: ROP: ^Current: 33.7 Max: 1 122.3 Torque: Current: 8748.5 Max: 1 10386 WOB: Current 7.68 Max: 14 RPM: Current: 121 Max: 123 PP: Current: 2078 Max: 2454 Lag: Strokes: 3583 Time: 48 Surf -Surf: Strokes: 4197 Time: 56 ECD: Current: 13.04 Max: 13.15 ee..,a n.,...,..:,.,. /1 Grfn A'ICi i C' 4 MW: V11 9 FV: 45 PV: 18 YP: 21 FL: 3.9 Gels: 5/6/7 Sol: 18 H: 9.7 CI -1 135000 Ca" 80 MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 56 Max: 1263 De Avg BG : 358.4 1 1nm c. ,, ,,.,.,, To: Reason: 8118 Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 7970'-8656' 280.61 79.34 131.88 Resi 7970'-8656' 10.14 4.42 6.59 Res2 7970'-8656' 16.21 4.00 7.27 Res23 8610' 68 6566.6055 446.0699 Neutron 71.7244 Connection Gases 376u@8618' 7136.609 Sonic 466.089 79.295 388.492 176.134 Nov Depth C1 C2 C3 C41 C4N C51 C5N C5N MD/TVD 8580' 74 7422.2241 524.2199 415.5495 135.0722 371.424 Trip Gas 225.4055 2 8610' 68 6566.6055 446.0699 479.9097 71.7244 Connection Gases 376u@8618' 7136.609 458.691 466.089 79.295 388.492 176.134 203.54 None 298.3344 197.0699 195.8748 4 8670' 60 7120.24111 449.5823 1 Nov vu'Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 1 8580' 74 7422.2241 524.2199 415.5495 135.0722 371.424 157.8284 225.4055 2 8610' 68 6566.6055 446.0699 479.9097 71.7244 404.9808 163.4344 199.9866 3 8640' 68 8100.1607 447.8261 375.5815 96.3305 298.3344 197.0699 195.8748 4 8670' 60 7120.24111 449.5823 1 346.781 1 65.4419 1 249.6079 154.8099 212.6961 Lithologies: Current: 80% Siltstone, 20% Sandstone Last 24 hrs: 70% Sandstone, 30% Siltstone • Operational Summary: Drill from 8005' to 8181'. Circulate bottoms up. Perform pressure logs. Drill from 8181 ' to 8700'. Failures: None 0 0 CANRIG n • Is CANf��G ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Rick Biorhus Date: 4/6/14 Time: 23:59 Current Depth (MD): 9210' Current Drill ahead Current Depth (TVD): 5222' Operations: 24 hr Footage (MD): 554 r)AIIi- D--t.rc ROP: ^Current: 24.99 Max: 149.3 Torque: Current: 8927 Max: 10507 WOB: Current 5.23 Max: 15 RPM: Current: 119 Max: 123 PP: Current: 2316 Max: 2508 Lag: Strokes: 3787 Time: 50 Surf -Surf: Strokes: 4441 Time: 58 ECD: Current: 12.94 Max: 13.22 RA...a n.,..._..:_., n n4nAl -`:W.711.9 Current: FV: 45 PV: 17 YP: 1 20 1 FL: 14.5 Gels: 1 5/6/7 Sol: 18 H: 9.8 CI 124000 Ca++ 80 MW Change: Depth: From: Mud Loss event: Depth: Volume: r'_- n �+n To: Reason: Ditch Gas: Current: 50 Max: 136 Depth (MD/TVD): 8711 Avg BG: 47.4 159.52 115.96 136.40 I \Alli Q --- Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 8656'-9210' 159.52 115.96 136.40 Resi 8656'-9210' 5.69 4.42 4.99 Res2 8656'-9210' 7.87 4.18 4.91 Res23 9153 33 3173.1095 287.1355 Neutron 60.2066 Connection 305u@9190' 49459.63 Sonic 2972.913 442.3876 1194.257 365.679 NJ No. Depth C1 C2 C3 C41 C4N C51 C5N C5N MD/TVD 9120 31 2908.493 216.8883 297.1149 48.9506 116.2998 Trip Gas 178.1189 2 9153 33 3173.1095 287.1355 305.0497 60.2066 Connection 305u@9190' 49459.63 5162.293 2972.913 442.3876 1194.257 365.679 498.2845 Gases 199.5025 50.8846 1 51.2115 4 9210 51 7406.2098 541.7818 None 1 146.0664 1 272.5921 141.8731 1 74.0137 NJ No. vN Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N 1 9120 31 2908.493 216.8883 297.1149 48.9506 116.2998 90.9885 178.1189 2 9153 33 3173.1095 287.1355 305.0497 60.2066 133.7678 59.7247 40.9318 3 9180 31 3292.8351 284.0622 224.2321 92.6658 199.5025 50.8846 1 51.2115 4 9210 51 7406.2098 541.7818 1 402.3248 1 146.0664 1 272.5921 141.8731 1 74.0137 CANRIG Lithologies: Current: 80% Siltstone, 20% Sandstone Last 24 hrs: 60% Siltstone, 40% Sandstone Operational Summary: Drill ahead from 8700' to 8970'. Circulate and condition mud due to high ECDs. Drill from 8970' to 9254'. Failures: None • 0 F-1 LJ 0 CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Lee Martin Rick Bjorhus Date: 4/7/14 Time: 23:59 Current Depth (MD): 9516' Current Depth (TVD): 5247' 24 hr Footage (MD): 306 nrillinn Pnrnmc4cre Current Weight up mud to 12.3 Operations: ppg ROP: Current: 0 Max: 312.5 Torque: Current: 4135 Max: 9495 WOB: Current 0 Max: 11 RPM: Current: 30.7 Max: 125 PP: Current: 1751 Max: 2487 La Strokes: 3884 Time: 62 Surf -Surf: Strokes: 4556 Time: 73 ECD: Current: 13.11 Max: 13.22 Mud Pro erties @ 9515' MW: 12.2 FV: 47 PV: 19 YP: 24 FL: 3.8 Gels: 4/6/8 Sol: 20 H: 9.6 Cl -:131000 Ca++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: r,nL- nn+n Ditch Gas: I Current: 12 Max: 69 Depth (MD/TVD): 9325' Avg BG: 144 9210'-9516' 159.52 I \A/n Q. imm1- Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR 9210'-9516' 159.52 133.78 145.54 Resi 9210'-9516' 4.92 4.42 4.65 Rest 9210'-9516' 5.24 4.18 4.61 Res23 9450 38 5131.424 410.068 Neutron 59.683 Connection 339u@9475' 5231.271 Sonic 468.083 52.221 195.85499.843 345.968 No. Depth C1 C2 C3 C41 C4N C517 C5N C5 MD/TVD 9420 53 7175.91 663.836 569.544 89.001 234.438 Trip Gas 132.328 2 9450 38 5131.424 410.068 382.635 59.683 Connection 339u@9475' 5231.271 372.927 468.083 52.221 195.85499.843 345.968 80.749 Gases 193.986 98.751 68.22 4 9510 39 6234.119 1 451.338 None 61.254 178.817 - - No. v� Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5 1 9420 53 7175.91 663.836 569.544 89.001 234.438 116.862 132.328 2 9450 38 5131.424 410.068 382.635 59.683 155.603 81.502 123.356 3 9480 34 4961.368 345.968 459.044 48.689 193.986 98.751 68.22 4 9510 39 6234.119 1 451.338 1 279.482 61.254 178.817 - - Lithologies: Current: 70% Siltstone, 30% Sandstone Last 24 hrs: 70% Siltstone, 30% Sandstone Drill ahead from 9254' to 9516' TD. Pump high viscosity sweep then weight up Operational Summary: mud to 12.1 ppg. Monitor well for one hour. Weight up mud to 12.2 ppg and perform a 200 bbl dilution. Circulate bottoms up then monitor well. Weight up mud to 12.3 ppg. Failures: None r"1 r 0 • • CANRIG ConocoPhilli s Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Rick Bjorhus Date: 4/8/14 Time: 23:59 Current Depth (MD): 9516' Current Circulate and condition Current Depth (TVD): 5247' Operations: mud 24 hr Footage (MD): 0 nrillinn Dnrmmntnrc ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3884 Time: 2:12 Surf -Surf: Strokes: 4556 Time: 2:35 ECD: Current: 12.87 Max: 13.11 KA -4 D --H— /nl Qr;1 r".' MW: 12.1 FV: 44 PV: 15 YP: 22 FL: 4.2 Gels: 4/5/6 Sol: 19 H: 9.6 Cl-; 129000 Ca--- 80 MW Change: Depth: From: Mud Loss event: Depth: Volume: r_no nn+o To: Reason: Ditch Gas: Current: 51 Max: 403 Depth (MD/TVD): 9515' Avg BG: 17 C5N Trip Gas I Wn CGimmary Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Rest Res23 Neutron Sonic r— G„on+� No. M Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None No. M Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Lithologies: Current: Last 24 hrs: Weight up to 12.3 ppg mud. Lost returns. Circulate mud at 1 bpm. Pump 45 bbl, 35 Operational Summary: ppb LCM pills. Lower mud weight to 12.1 ppg. Stage pumps up to 180 gps at 1/2 bbl stages to get ECD readings. Monitor well, conduct well bore breathing test. Circulate bottom up at 2 bpm. Failures: None • r1 LJ • CANf��G ConocoPhilli s Alaska, Inc. Report for: Granville Rizek Rick Bjorhus Date: 4/9/14 Time: 23:59 2L -322A Daily Geologic Report Current Depth (MD): 9516' Current Depth (TVD): 5247' 24 hr Footage (MD): 0 Current Circulate and condition Operations: mud ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: 3884 Time: 2:12 Surf -Surf: Strokes: 4556 Time: 2:35 ECD: Current: 12.81 Max: 12.87 Mud Pro erties @ 9515' MW: 12.1 1 FV: 44 PV: 16 YP: 1 21 FL:4.2 Gels: 4/5/6 Sol: 18 H: 9.3 CI 111000 Ca++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: rrna nn+a Ditch Gas: Current: 1294 Max: 4626 Depth (MD/TVD): 9515' Avg BG: 130 C4N C51 C5N Trip Gas I Xnrn c...,.,,- 11 Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Rest Res23 Neutron Sonic n rz n+n No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CANRIG I �xiu i�e:'I.....-....... L�n.. Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CANRIG I �xiu i�e:'I.....-....... L�n.. Lithologies: Current: Last 24 hrs: Circulate mud at 2 bpm, observed maximum of 4626 units gas. Monitor the well for breathing and observed 9 bbls flow back. Circulate at 2 bpm and pump LCM pill. Operational Summary: Circulate and condition. 22 bbls loss during circulation. Monitor well for 225 minutes, recorded max flow back of 10.8 bbls/hr and final flow back rate 0.3 bbls/hr. Circulate and condition and observed 1607 units of gas maximum and 18 bbls mud lost. Failures: None • r� CMR.IG 0 • • CAIVR�G ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Rick Bjorhus Date: 4/10/14 Time: 23:59 Current Depth (MD): 9516' Current Depth (TVD): 5247' 24 hr Footage (MD): 0 nrillinn Pornmc+cre Current Circulate and condition Operations: ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: KA -4 Prn nr+ioe inl aR1 r,' MW: 12.1 FV: 47 PV: 17 YP: 24 FL: 4.2 Gels: 5/6/8 Sol: 18 H: 9.5 CI-� 111000 1 Ca'+' 80 MW Change: Depth: Mud Loss event: Depth: 9515' r_ne no+o From: To: Reason: Volume: 74 bbls Ditch Gas: Current: 42 Max: 1293 Depth (MD/TVD): 9515' AvgBG: 33 C41 C4N C51 I %Ain Q...,,.,,�r„ Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Res 1 Res2 Res23 Neutron Sonic rye r. nn+e No. _ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None No. _ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Lithologies: Current: Last 24 hrs: Circulate mud at 2 bpm and pump out of hole to 7667'. Circulate bottoms up 2.5 Operational Summary: times. Pump out of hole to 6141' shoe. Circulate at 2 bpm and observe pit gain. Shut down and monitor well for breathing. 15 bbls flowed back in 22 minutes. Circulate and condition. Failures: None • • CANING D> %,-,,TIMI',,,,,,\ Ute. a • CANFt�G ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Rick Bjorhus Date: 4/11/14 Time: 23:59 Current Depth (MD): 9516' Current Trip into hole to spot pill Current Depth (TVD): 5247' Operations: 24 hr Footage (MD): 0 r)rillinn Pnrnmc+cre ROP: ^ Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: KA -4 D+i fm OC,1 C.' M MW: 12.2 FV: 50 PV YP: 1 25 FL: 14.5 Gels: 5/7/8 1 Sol: 19 H: 9.5 CI 106000 Ca++ 80 MW Change: Depth: From: Mud Loss event: Depth: Volume: (_ n e rh+o To: Reason: Ditch Gas: Current: 0 Max: 1291 Depth (MD/TVD): 9516' Avg BG: 50 C5N Trip Gas Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Res2 Res23 Neutron Sonic l�.. C. ..a.. Nov vu Depth TG C1 C2 C3 MD/TVD Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None Nov vu Depth TG C1 C2 C3 MD/TVD C41 C4N C51 C5N 1 2 3 4 CANRIG Lithologies: Current: Last 24 hrs: Circulate at 2 bpm and then pump two 20 bbl high viscosity sweeps. Monitor well Operational Summary: for breathing. Pump 500' of high viscosity pill out while back reaming out of hole to 5001'. Weight up to 12.2 ppg mud. Monitor well for breathing. Trip into hole to spot pill. Failures: None • • • CANRI — ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Rick Bjorhus Date: 4/12/14 Time: 23:59 Current Depth (MD): 9516' Current Depth (TVD): 5247' 24 hr Footage (MD): 0 nrillinn Pnrmmn+nrc Current Weight up mud to 12.4 Operations: ppg ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties @ 9515' 35 MW: 12.4 FV: 54 PV: 18 YP: 26FL: 4.7 Gels: 8/9/11 Sol: 20 H: 9.4 Cr:105000 Ca"'80 MW Change: Depth: 9515' From: 9.2 To: 9.4 Reason: Return flow Mud Loss event: Depth: Volume: rrno nn+n Ditch Gas: Current: 35 Max: 1412 Depth (MD/TVD): 9516' Avg BG: 35 C4N C51 C5N Trip Gas Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Res 1 Rest Res23 Neutron Sonic No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Lithologies: Current: Last 24 hrs: Trip in hole to 7381'. Circulate and condition mud at 1 bpm. Weight up to 12.2 ppg Operational Summary: mud. Pump high viscosity LCM pill while pulling out of hole from 7381' to 5377'. Circulate and condition at 1 bpm, weight up mud to 12.4 ppg. Failures: None L' • CANRIG • • CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Rick Bjorhus Date: 4/13/14 Time: 23:59 Current Depth (MD): 9516' Current Testing BOPs Current Depth (TVD): 5247' Operations: 24 hr Footage (MD): 0 nrillinn Pnrnmctcre ROP: ^Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: AA..A D..,.....+;.... !l aC1 r.' M MW: V12.7 FV: 56 PV: 19 YP: 30 FL: 14.5 Gels: 9/10/11 Sol: 20 H: 9.5 CI 112000 Ca++ 80 MW Change: Depth: 9515' Mud Loss event: Depth: Gas Data Ditch Gas: Current: 0 Max:35 Avg BG : 11 I %AIM 0............ r.. From: 12.4 To: 12.7 Reason: positive flow Volume: MD/TVD): 1 9516' Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Rest Res23 Neutron Sonic r` C.. n+n Nov vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CMRIG Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None Nov vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CMRIG 0 • 0 Lithologies: Current: Last 24 hrs: IDWeight up mud to 12.4 ppg. Circulate and condition, monitor well for 0.5 hrs and Operational Summary: confirm positive flow. Circulate and condition, weight up mud to 12.6 ppg. Monitor well and observe positive flow. Circulate and condition, weight up mud to 12.7 ppg. Trip in hole from 5377' to 6192', test BOPs. Failures: None 0 • CANING • CAfVR�G ConocoPhillips Alaska, Inc. ,>.,, ,.,:r..,,,,,,,.:. 2L -322A Daily Geologic Report Report for: Granville Rizek Rick Bjorhus Date: 4/14/14 Time: 23:59 Current Depth (MD): 9516' Current Depth (TVD): 5247' 24 hr Footage (MD): 0 nrillinn Parnmatarc Current Circulate and condition Operations: mud to maintain 12.7 ppg ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties @ 9515' MW: 12.7 1 FV: 53 PV: 15 YP: 33 FL: 4.5 Gels: 7/9/11 1 Sol: 21 H: 9.4 Cl -:127000 Ca++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 9516' Volume: 93 bbls frac nota Ditch Gas: Current: 5 Max: 7 Depth (MD/TVD): 9516' Avg BG: 5 C51 C5N Trip Gas Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Res2 Res23 Neutron Sonic !_oc Fvnntc r_.,, Q-1— No. ^ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None r_.,, Q-1— No. ^ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Lithologies: Current: Last 24 hrs: Operational Summary: Test BOPs. Pull storm packer and monitor well, no high gas observed. Circulate and condition mud at/4 bpm to maintain mud at 12.7 ppg. Failures: None • • CANRIG • • CAN�G ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Rick Bjorhus Date: 4/15/14 Time: 23:59 Current Depth (MD): 9516' Current Depth (TVD): 5247' 24 hr Footage (MD): 0 Ilrillinn Pnrromc#orc Current Back ream out of hole Operations: ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: La Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: "'W-1)2.7 Depth MD/TVD FV: 46 PV: 19 YP: 1 30 FL: 13.9 Gels: 1 7/9/10 Sol: 21 H: 19.2 1 Cl --125000 1 Ca++: 80 MW Change: Depth: Mud Loss event: Depth: 9516' Gas Data Ditch Gas: Current: 2 Max: 7 Avg BG: 2 From: Volume: 32 bbls T To: Reason: 9516' Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Rest Res2 Res23 Neutron Sonic No. vM Depth TG C1 MD/TVD Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None No. vM Depth TG C1 MD/TVD C2 C3 C41 C4N C51 C5N 1 2 3 4 CANIRIG Lithologies: Current: Is Last 24 hrs: Operational Summary: Failures: None r� U Circulate and condition mud, pumping 3/4 bpm. Monitor well, then begin to back ream out of hole from 6214' to 5187'. Circulate and condition then monitor well. Back ream out of hole from 5187' to 733'. Continue to back ream out of hole. 1] 0 s CANR�G ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Josh Riley Date: 4/16/14 Time: 23:59 Current Depth (MD): Current Depth (TVD) 24 hr Footage (MD): nrill;n Dornmo+ore 9516' Current Run in hole with liner 5247' Operations: 0 - __ - ROP: ____ -_ Current: ------T- Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: RA -4 Drnnor+i— rl OG1 G' MW Change: Depth: From: Mud Loss event: Depth: 9516' Volume: 9 bbls Gas Data Ditch Gas: Current: 1 Max: 2 Depth (MDT AvaAva BG: 1 rmr■iu,rr__r..zr� To: Reason: 9516' Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Rest Res2 Res23 Neutron Sonic 12.7 FV: 45 PV: 16 YP: 128 FL: 4 Gels: 1 7/10/11 Sol: 21 H: 9.3 CI 125000 Ca", 80 MW Change: Depth: From: Mud Loss event: Depth: 9516' Volume: 9 bbls Gas Data Ditch Gas: Current: 1 Max: 2 Depth (MDT AvaAva BG: 1 rmr■iu,rr__r..zr� To: Reason: 9516' Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Rest Res2 Res23 Neutron Sonic No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Depth MD/TVD C1 C2 C3 C41 C4N C517 C5N Trip Gas Connection Gases None No. vM Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 Lithologies: Current: Last 24 hrs: Back ream out of hole to 558'. Monitor well and then lay down BHA. Service rig, Operational Summary: then continue to lay down BHA. Rig up and run in hole with 4'/2" liner. Failures: None • 0 CANRIG • Is • CANRIG ConocoPhilli s Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Josh Riley Date: 4/17/14 Time: 23:59 Current Depth (MD): 9516' Current Circulating bottoms up Current Depth (TVD): 5247' Operations: 24 hr Footage (MD): 0 nrillinn Pnrnmatare ROP: ~Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: hili irl Dr—r+i— rl Qr.1 R' MW: 12.7 _ FV: 1 53 1PV: 17 1 YP: 28 FL: 14.5 Gels: 7/8/9 Sol: 121 1 pH: 19.2 1 Cl-: 120000 1 Ca++: 80 MW Change: Depth: From: Mud Loss event: Depth: 9516' Volume: 9 bbls (;ac nates To: Reason: Ditch Gas: Current: 1 Max: 2 Depth (MD/TVD): 9516' Avg BG: 1 C51 C5N Trip Gas I Min Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Resi Rest Res23 Neutron Sonic f'-- !=-"—+� No ^ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CANRIG Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None No ^ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CANRIG Lithologies: Current: 0 Last 24 hrs: Operational Summary: Continued picking up 4 1/2' liner. Picked up liner hanger and ran in hole on 4" drill pipe to 5,452'. Continued running liner in hole on drill pipe to 6,203 Failures: None • 0 0 • CANRIG ConocoPhillips Alaska, Inc. 2L -322A Daily Geologic Report Report for: Granville Rizek Josh Riley Date: 4/18/14 Time: 23:59 Current Depth (MD): 9516' Current Pulling out of hole Current Depth (TVD): 5247' Operations: 24 hr Footage (MD): 0 nrillinrr Pnrnmctorc ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: KAi A Prnnortioe nn QR1 ri' MW Change: Mud Loss event: Gas Data Ditch Gas: C AvgBG : 1 I Wn Q --- Depth: Depth: 9516' 1 1 Max: 1 2 From: To: Reason: Volume: 9 bbls 9516' Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Rest Rest Res23 Neutron Sonic Depth MD/TVD FV: 60 PV: 23 YP: 30 FL: 4.3 Gels: 1 7/9/11 Sol: 20 H: 9.4 Cl-- 125000 Ca++: 80 MW Change: Mud Loss event: Gas Data Ditch Gas: C AvgBG : 1 I Wn Q --- Depth: Depth: 9516' 1 1 Max: 1 2 From: To: Reason: Volume: 9 bbls 9516' Tools Run Depth Interval MD/TVD Hi Low Avg Comments GR Rest Rest Res23 Neutron Sonic (_nes Q- 1 -No. ^ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CANRIG Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases None (_nes Q- 1 -No. ^ Depth TG C1 C2 C3 C41 C4N C51 C5N MD/TVD 1 2 3 4 CANRIG Lithologies: Current: Last 24 hrs: Operational Summary: Continued to circulate bottoms up at 1 bpm. Continued to run liner in hole til 9,485' and set hanger and released. Set liner top packer and test. Failures: None • CMR,IG 2�3-��I t Z.y Z Lo RECEIVE® MAY 01 2014 AOGC( Sdiumberger 2L -322A Final ASP Survey (Def survey) Repan Daft: April 25. 2014.01:57 PM Smvey I DLS Computation: Minimum Cmvalure I Lubin ld Crennt. ConocoPliegs (Alaska) Inc -KUP2 vertkal Section AaimuM: 178000' (i NOM) Field: KupwA River Uril2 Vertical Section Origin: 0.000 6 0000 0 Structure I Slot Kuparuk 2L Pad 12L322 rence TVD RefeDatum: RKB We": 2L-32204nxm) TVD Reference Elevation: 143.730 ft b -Mean Sea Level Borehole: 2L322A Seabed I Ground Elevation: 114.800 R aooae Mean Sea Level UN I AFM: 50-103-20628-01-00 Magnetic Declination: 19.170' Survey Name: 2L322A Final Total Greedy Field Strength: 101.9528n gn (9.80685 Based) Survey Date: 16AW-14 Gravity Mosel: GARM Ton l AND I DDl I ERD Ratio: 175.115' 16591.399 K 16.32111.256 Tctal Magnetic Freta Strength: 57585.00 nT Coordinate Reference System: MAD27 Alaska Sale Plane, Zone 04, US Feet Magnetic Dip Angle: 0.780' Location Let I Long: N 70' 12 47.69533-, W 150' 18' 5725515' Declination Date: Marta 15, 2014 Location Grid ME YDL N 5927697.770 ftU$, E 460829.380 RUS Magnetic Declination Model: BGGM 2013 CRS Grid Convergence Any. -02973 • nd, Reference: Tae NOM Grid Scale Factor. 0.999910174 Gra Convergence Used: D,000' Version I Patch: 2.7.1043.0 Toud Con Mag Nonh�True North: 19.170' Local Coord Referenced To: Well !lead MD mel Aam True TVDS$ TVD VSEC AND Closure NS EW OlS NorNelg Easting Latduca Longitude Cnoweents 60 M 19 Ml 011 Ml Rel Ml IRI tR) .= Nti151 IflU51 1'1 1'1 RTE0.0 0.0 0.0 -143.73 0.0 0.0 0.0 0.0 0.0 0.0 0.0 5927837.77 460829.36 7021324870 -15031590421 Ground Level 28.93 0.0 0.0 -114.90 28.93 00 0.0 0.00 0.00 0.0 0.0 5927837.77 480829.38 7021324870 -15031590421 88.93 0.14 43.59 -54.80 88.93 -0.05 0.07 0.07 006 005 023 5927637.82 460829.43 7021324885 -150.31580380 163.93 026 31.97 1020 153.93 -0.23 0.30 030 024 018 0,19 5927638.0 460829,56 701132405 -150.31590273 242.93 0.90 144.93 9920 241.93 0.19 1,02 0.71 -0,17 069 1.16 5927637,0 4083007 7021324625 -150,31589863 334.93 2.30 165.81 191.16 334.89 2.60 3.56 299 -255 1.56 1,62 5927635.2 480830,92 7021324174 -150.31589188 423.93 2.99 170.63% 280.06 423.79 6.65 7.67 6.98 -6.57 2.37 0.81 5927631.19 4083171 7021323075 -150.31588510 6M18,93 3.69 167. 374,91 518.64 1203. 13.12 12.40 -11,82 3.41 066 5927825.63 460832.73 7011321614 -150.31587672 613.93 4.84 18622 468.66 613.39 18.72 19.93 1921 -1666 4.96 1.11 59M 9.18 480834.24 7021319801 -150.31585421 709,93 6.42 168.79 5&521 708.94 ZTM 29,18 28.46 -27.55 7.11 1.86 5927610.18 4603835 7021317343 -15021584656 803,93 8.26 174.49 666.44 802,17 39.88 41.18 40.40 39.39 am 2.22 5927598.34 460838,14 7021814108 -160.31583186 898.93 11.33 183.95 762.05 05.78 55.78 57.30 56.71 -65.50 8.87 3.64 6927582.23 460836.08 7021309706 -15031583184 98393 14.41 19377 8" se 988.39 76.44 78,41 76.50 -76.30 5.52 397 592758145 40834.507021369028-150.31585973G -150.31585973 1041.78 15.71 192.0 890.27 1034.0 88.29 WAS $029 -8825272 293 597/548.52 480891.64 702130762 -15031585226 1135.31 1739 195.55 90.52 112425 114,04 117.49 11431 -11424 3.83 2.0 592752356 480824.95 7021293660 -150.31593512 1231.0 20.89 193,44 1071.76 1215.49 144 1 149.16 14538 -W.91 -11.71 3.69 5927492.94 480616.92 70.21285282 -150.31599864 1321.54 23.80 196.25 1154.86 1298.39 177.00 18323 179.0 47792 -20.49 3.46 5927460.07 46007.97 7021278290 -150.31806942 1415.47 25,91 194.57 1239.86 1383.61 214.67 222.70 218.09 -215.99 -30.96237 5927422.07 46079731 70.21285091 -150.31815382 '514.99 2923 194.09 1328.0 1471.82 258.83 268.76 263.91 -280A7 -42.51 3,34 592737755 40786.63 7021253712 -150.31524698 1612.17 32.24 195.82 1411.61 1555.34 306.27 31861 31335 -3039 -5551 3.18 5927329.70 46077227 702124019 -150.31595188 170.0 35.34 194.17 1491.30 1635.0 35727 371.74 35651 3£9.90 X28 3.37 5927278.27 40758.24 7021228547 -15031648285 1801.31 35.56 194,98 1567.28 1710.99 409.10 425.82 42050 -41214 -8250 0.58 59272260 40744.38 7021212247 -150.31657280 78%.57 38.34 197.62 1643.57 1787.30 461.63 481.15 47554 -465.34 -08.43 1.84 5927172.99 40728,55 70.21197740 -t 5031609790 1992.92 3652 197.81 1721,90 1865.63 516.05 538.96 53319 -520.41 -118.02 022 5927118.02 460710.67 70.21182698 -150.31883974 2097.35 37.29 196.42 1797.41 1941.14 SWA2 595.66 569.73 57490 -13270 1.20 5927063.92 460893.71 70,21167891 -150.31597423 2175.97 3726 196.84 1667.93 2011.66 6211.48 649.33 643.30 4126.03 -148.06 029 5927012.58 160676.09 70.21163841 -160.31709808 2274.79 37.0 196.0 1846.40 2090.13 677.% 70.40 70327 683.57 -16528 000 5925055.14 16086050 70.21138122 -10.31723899 2358.57 38.15 196.60 2018.85 2162.58 730.80 765.74 75955 -737.56 -181.34 0.0 59260121 4604423 7021123366 -150.31730640 2462.51 38.70 196.53 2094.01 2237.74 787.33 825. $19.11 -794.73 -19834 0.58 5928814.18 460626.94 70.21107752 -150.31750346 2560.37 39,02 197.16 2170.20 2313.93 845.43 88676 037 8,43 -853.48 -278.13 0.52 5926785.50 46060894 702109170 -150,3176460 Tie-in Survey 2868.13 $9.05 197.33 2207.30 2351.0 87383 916.84 910A7 -682.72 -715.05 023 6925756.82 460599.78 7021093852 -150.31771879 2690.97 37.04 193.61 2272.55 2418.28 922.45 967.50 get A9 -981.36 -238.84 3.50 5928707,78 460585.74 7021OTD427 -160.31782995 2787.17 36.86 188.34 2349AS 2493.18 976.71 1025,68 1019.18 4888.04 -250.01 3.50 5926651,14 40574.28 7021054941 -150.31791998 2862.29 3927 187.82 2424.33 2568.06 1035.45 108433 107751 -1048.10 -258.24 2,56 S9% 593.13 0 4565.74 7011039079 -150.31798537 2977.06 41.36 188.17 2496.59 2640.32 1096.93 1145.64 1138.51 -110882 -288,77 2.22 5928532.48 40558.90 7021022492 -150.31805514 Drilling Office 2.7-7043.0 Kuparuk River Unit2ftparuk 2L Padl2L-322 (NMh)12L322AM-322A Final 425/2014 204 PM Page 1 of 3 comments M0 116 A -hue SS hD1ftl TVD VSEC AFm Wave ift) /'1 fM 167 181 MS Ew IXS 14or81i n9 EaaBnp 1a769We 1-oe9auee !/tl Ml MI Ifti f'/10071 ! 1 1.1 M 3075.62 3170.85 41.37 40.40 191.51 19290 2670,57 2642,57 2714.30 2786.30 1160.56 1210.76 1203.50 -1170.97 -27.90 2.24 5926468.37 460545.44 70,21004965 45091814484 3266,37 39.84 188.55 2715,62 2859.35 1221.07 1281.15 1273.09 1265.81 •1231.95 -290.75 1.15 5926407.45 460532.27 70.20988302-750A10249se 3360.82 39.91 185.68 2788.11 2931.84 1340.91 1331.63 1395.18 132727 1387.50 -1292.47 -301.90 2.60 59%347.01 460520.81 702097171 -15091686830 3457,85 39.68 183.98 2862.65 300699 140256 145728 -135264 -30951 1,81 5926286.99 460512.89 7020945362 .150.37838%2 1449.03 -1414A7 -314.85 1.28 5926225.15 46050723 7020938459 -150.31844289 3552.91 3648AS 39.03 38.04 160.71 175.69 2938.17 3010.92 3079.90 3154.65 1462.85 151756 1508.38 •1474.63 -317.33 229 5928164.96 480504.44 70.20822008 -150.37848265 3743.50 38.97 77302 3085.30 3229,93 1522.73 1581.77 157.06 1636.7! 1586.78 •1634,68 -315.49 3.43 5928105.51 460505.97 70.20905757 •750.31944750 393].68 39.50 173.14 3758.24 330'1.97 7840.37 1596,78 1822.7 167954 -9492.95 399,68 200 5928016.87 460499.50 7020888882 -150.31849075 3932.49 39,64 173.78 3231.34 3375.07 1700.73 1756.19 1737.42 -7652,07 -902.48 0.57 5925987.45 460518.36 7D.26873550 .150,31834288 -1712.09 -296.60 0.45 5925927.41 460524.93 70.20857134 -150.31828739 4027.29 4129.54 39.69 3970 175,33 175.37 3301.31 3378.93 3448.04 3520.58 1761.13 /816.70 179587 -1771.32 -289.86 1.04 5925867.15 460550.38 70.20840679 -150.31824109 4219.49 3962 17654 315224 3595.97 1821.28 1a83.73 18]6.90 1939.41 1864.34 •1832,32 -28495 0.02 5926807.14 46063/96 7020824288 -75091820947 4314.39 39.12 17,50 352529 3869,02 191429 1999.99 1915,30 1974.70 •1861,67 -280.40 0.68 5925714.7 460539.79 7920907755 -750.31818176 4409.32 39.55 176.70 3598.40 374213 2004.84 2060.54 -1965.16 -277.14 0.79 5925684.27 460542.13 7020790730 -150.31813851 209478 -2015.63 -274.08 0.57 5925623.79 480544.87 7020774208 -15031811380 4504.95 4598.11 39.67 39.69 17828 178.70 3672.07 3743.n 3815.80 3897.50 208850 212151 1094.20 -2076.51 -271A1 1.06 5925562.87 46054723 7020757568 -150.31808718 4895.19 39.82 175.94 381891 3962,74 212526 2187.36 2180.9!! 216298 -2136.00 -250.64 0.29 5925503.41 460518.49 7020741324 -19091807867 4750.56 39.19 775.84 950108 103{.79 2247.57 2243,08 2300.30 2214.34 717387 .2196.06 -268.08 0.48 5925441.35 460549.95 7020724370 -150.310=18 4884.94 39.74 174.18 3964,54 410827 230930 2384,11 -7258.19 -264.89 1.16 5925389.27 460552.82 7020707842 -150.973 233327 -2316.78 -25914 1.21 5925320.50 460557.74 7020501391 -15031789728 498074 `+076.01 39.93 39.83 175.01 775.09 4038.11 4111.16 1161.&1 4254.50 2369.66 2425.46 2393.37 -2379.87 -253.86 0.59 5925259A9 460583.21 7020674700 •1509779+067 5171.32 39,96 175.34 4184.22 4327.95 2430,63 2197.78 248619 2453.42 -2440,79 -248.56 0.05 5925198.55 460588.16 7020856047 -750.37790812 5266.17 40.08 175.48 4256.80 1400.53 2552.67 2517.89 2868.50 2513.80 .2501.78 .243.48 0.18 5925137,53 460572.95 7020641394 -150.31788895 5362.02 99.89 175.96 1330.29 4471.02 281425 2670.43 2571.60 2830,12 -2562.58 -238.59 0.13 5925078.74 46057.63 70.21162479'1 -150.31782752 -262101 43398 0.39 5925015.27 460581.82 7020608002 -15097779033 545189 5548.73 40.39 43.16 175.88 174,62 4403.43 1071.32 1517.18 4615,05 2875.88 2712.11 269533 _2885,53 -229,68 0,53 5924953.74 460585.89 70.20591195 -150-31775494 5846.17 4629 17/.49 4540.54 486027 2736,48 2804.89 2792.75 2755.13 -2746,96 -224.55 3.18 5924993.28 460590,81 70.20574885 -150,31771450 5742 47 49.88 174,40 4605.00 4748.73 287628 2861.31 291284 282265 2503,12 -2614.22 -278.04 321 5924825.01 460596.7 7020558039 -150.31766183 5838.81 52.37 173.87 4665.60 4SM-33 2950,99 3007,72 2966,88 -28MA7 411.11 3,50 5924753.79 460803.32 7020536591 -15091780599 _295989 _20346 2,85 592467927 460670.59 7020516241 -150.31754324 5934.19 6028,00 54.90 57.53 173.50 174.87 4722.12 174.31 4505.65 4918.04 3027,54 306497 304247 •3031120 -19521 2.85 5924802.93 160818.16 7020495395 -150.3974778 Bt24.a8 80.33 176.14 4824.18 4967.92 3705.% 3188.09 316248 3119.46 -3113.82 AS7A6 294 592452527 180825.7 7020074188 -150.37747545 8958.16 61.35 97.48 4339.55 4983.28 3215.60 324528 3279.78 1201.47 3228,81 3198.35 -180.97 3.93 5924442,72 480631,85 7020051843 -150.31738290 74240 C49 8214.64 64.19 7720 4868.30 5070.03 176758 3324,7 9280.52 .3223,83 -979.36 4.28 592449524 48083332 7020/44136 •150.37734992 327675 •17679 4.86 5924383.31 460635.61 70.2042995/ -150.31732925 6246.37 6317,95 65.73 89.57 17722 17.44 4879.73 4905.94 5023.48 503017 3296,32 335351 3309.10 3304.45 -175.50 4.86 5924334.60 460636.88 70.21622110 -150.31731795 636421 69.61 178.08 49276.28 308880 3351.50 3405.86 3179.70 3374.97 3370.57 -172.31 5.37 5924288,48 460639.60 7020400046 -150.31728911 8059.35 70.39 1.68 49553.07 •91.39 319524 346395 3562,44 3478.15 341399 -5.95 9.90 492422 460891.07 70.20391211 -15091722944 655590 71.83 178.86 4986,7 5130.50 3636.00 364320 350725 3597.7 -350323 -1170.82 87.76 0.78 5924135.81 460643.46 7020367804 -150.31725W -3593.97 -165.48 1.67 5824045.07 46064527 7020343018 4509172380/ 6650.84 66M.44743.85 73.44 76,37 17.73 176.37 501529 5050,51 5159.02 518324 367.18 3786.98 3734.38 368870 1585.11 -162.7 2.03 5923953.93 460647.51 7020118117 -150.31721612 87.83 174,88 5067.77 52.11.50 3861.68 3824.17 5018.99 377909 •3774,78 -759.14 9.45 592386424 480657.68 7020293619 -150.31777880 OW -02 6937'02 86,02 173.32 5067.98 5211.71 SMA7 4015.00 387225 5087.31 3869.31 -15016 5.86 6923769.69 480058.45 7020267794 -150.31712027 7031.63 85.85 174,42 5074.70 5218.43 405115 4109.42 4080.80 3964,31 -140.99 4.62 6923671,14 450687.84 7020241703 -150.31704054 7127.71 7222.49 86.29 90.39 177,91 17924 SM1.28 5081.02 571601 5727.75 4147.50 420523 4156.13 -4058.69 4154.26 -13090 -124.50 1.17 3.85 $923580.21 5923484.63 46067.44 460583,35 7020218056 -150.31695926 7020189845 7317.26 91.10 179.59 506279 5228,52 4242.70 4335.85 4299.95 439,473 4260.71 -4248.95 -121.14 4.55 5923389.94 480685.21 -750.31696782 7020164077 -150.31686883 7506.77 75M 91.20 180.08 5060.85 6224.68 4433.36 448129 1315.42 4"193 434373 -121.18 0.84 5923295.16 480685.68 7020138184 -15091840082 17 97.10 181-32 5078.96 6221.89 452155 458556 453621 444029 4534.57 420.90 0.52 5923198.61 480885,46 7020111605 -150.31697857 7606.16 769727 9129 59.87 182.72 184,11 5078.92 5075.99 5220.85 5218.72 4625.27 486355 4834.18 4832.48 -771.05 -125.50 1.32 1.44 5923104,35 5923006.47 460651.82 180879.86 7020086047 -15031688784 7020058300 -150.31681565 7793.08 89.02 189.40 5078.92 5220.65 4715.97 487126 474.65 4870,44 4725.23 4723.41 -130.95 2.20 5922975.57 460673,94 7020034456 _75097896857 7887,00 89.76 179.81 5077.92 5211.85 4905.01 496427 4820.94 4914.86 -4818.99 -13725 9.78 5922820.04 480867.14 7020006345 -750.4 1 7117 0 3 7 7980,53 89.63 17.45 507442 5222.15 4968.52 5057.90 25 4912.87 -139.72 4.11 5822726.18 460664,19 70,199826% -150.31703017 •500037 •137.32 2,31 5972632.69 460366.11 70,19957155 -150.31701062 8074,72 8174.55 89.80 8992 175.73 774.78 5078,97 6079.65 522284 522398 50%,18 5192.39 5155.50 5105.57 3103.88 •131.51 in 5922535.14 460677.41 7479830515 •150.31696399 8289.68 8927 973'42 5080'87 5221.60 526727 5757.92 534792 5201.34 5295.89 -5199.87 -123.54 1.10 5922439.13 460678.38 70,79804289 -150.31649978 8384.58 89.88 176.16 5081.62 5225.35 5382.01 5141.91 5389.99 -5294.47 -113.7 1.43 5922344,49 460668.18 70.19678446 -750.31882098 3388.97 -105.15 2.97 5971249.96 48069829 70.19852830 .150 Drilling Office 2,7,1043,0 Kuparuk River Unit2WUparuk 2L Pad12L-322 (NoAh)%2L322Al2L-322A Final 4125/2014 2:04 PM Page 2 of 3 0 0 Comma MD m7 Ind M Aabn True 11 TVD55 TVD VSEL AHD Cl- NS EW DLS MorlAmg Eaalirp "1"1" L4rgilude 8460.0 89.83 17421 Ml 5081.88 ml 5225.59 MI 5478.02 RII 5538.04 fltl 648581 IRI 5484.75 MI -97.08 Pn= 2.03 1RUSI 5922154.15 1:2. 480703.86 f1 1'1 70.19828462 -150.31688651 8555.48 90.35 173.67 5081. 71 22544 5. 5572.59 5632.83 5579.71 -6579.03 -8724 0.68 5922059.83 48071321 70.19800706 -150.31080719 8651,73 90.16 176.18 5081.29 5225.02 5888.70 5729,08 %75.48 -5874.91 -78.89 2.41 5921963.92 40721.0 70,19774512 -150.31653892 8747.15 90.76 176.47 6080.52 5224.25 $764 07 5824.50 5770.59 -5770.13 -72.78 0.70 5921886.68 40726.68 70.19748498 -150.31649064 8841.45 91.18 176.65 6078.92 5222.65 5858.33 591678 5864.63 5884.24 $7.12 0.48 5921774.54 460731.86 70.19722786 -150.31844504 8937.06 90.10 177.47 5077.88 5221.59 5953.92 6014.39 5960,05 -5959.72 52.22 1.42 6921679.05 46073628 70.19696703 -150.31640563 903221 89.73 178.94 5078.00 5221.73 6049.07 6109.54 W55.11 5054.82 -59.23 1.59 5921583.94 480738.74 70.19670722 -150.31638151 9127.56 89.11 10.36 5078.98 5222.69 6144.37 6204.88 8150.44 -8150,18 -58.65 1.62 5921488.61 460738.63 70.19644875 -15031637681 9222.86 88.11 10.49 508128 522501 6239.64 8300.24 6245.80 .4245,62 -59.36 t -W 5921393.27 460737.63 70.18818624 -150-31638250 9317.99 85.02 181. 03 5.97 086 5230.70 6334 .39 6395.10 6.86 310 534037 -80.62 3.30 5821298.44 460735.88 70.19592711 -160.31639289 9415,31 85.13 180.04 5085.33 5239.06 643126 6492.08 6437.62 -8437.32 -81.52 1,02 5921201.50 460734.47 7D.1956=4 -150.31839992 9455.78 8520 MAI 5098.74 5242.47 6471.57 6532.39 6477.93 -8477.65 41.05 3.53 592118118 460734.74 70.19565208 -150.31839609 4-12m 17 r 948500 8520 178.61 5101.18 5244.91 8500.69 6561.506507-04 -6W6.75 -80.34 0.00 5921132.07 460735.29 70.19547255 -150.316.98039 Projeclion M be 9515.00 8520 178.61 5103.89 5247.42 6530.58 8591.40 6538.91 4536.84 -59.62 D.00 6921102.18 480735.86 70,19539091 -150.31638455 Swvey Type: Def Suvey Survey Error Mode: ISCWSA Rev 0--- 3D 95.00%C40fWence 2.7955 sigma Survey Program: D-ripll>n P� MD From MD To PB IR) Legal Description: 1 0.000 898.932 1 898.932 2608.125 12808.125 6214.850 1 6214.850 9455.780 1 9455.788 9515.00 Sedaoe: 5071.0 FSL 821A FEL S22 T10N R7E UM 3814 FSL 891 FEL 27 T10N R7EUM Drilling Office 2.7.1043.0 EOU Frey Nola Sire Casirrp D-iama0v Sufwy ToolType Borehole I Su IM PN (in) fV°y Ad Bmm 30.000 30.000 CB -GYRO -SS 2L-322P81/2L-322PB7 Defrltive AU SSU 30.000 30000 MWDNFR-AK-M-SC 2L.322P81/21,-322PB1 Defiftwe Ad Sms 9.875 7.625 MWDHFR-AK-CAZSC 2L-322A/2LJ22A Fhal Ad Sms 8.500 4.500 MWDNFR-AK MSC 2L -322A 12 -322A Feel Ad Stns 8.500 4.500 BUND 2L322A/2L-322AF I X92 M*nh� 99 480829 0 5921102.180 480735.80 Final Definitive Survey Verified and Signed -off AN H/gef6 and/or well poeidon objeceve9 Rave been aNrieved. 21 Yu 0 No I have checked t4 d» beet of nWabTWOM the fogowblg dffi is conecb O+ Surface C-IcAra des OO Ded-on a Carvergence O GRS Survey C- ion El Survey Tod SLB DE A b i Milli- 2 e w,-, Merl Reprememauve: Dale: Kuparuk River UnlMKuparuk 2L Pad12L-322 (Norlh)12L-3220k12L-322A Final 4/25/2014 2:04 PM Page 3 of 3 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • 2`� - \(40-1• 2-A2-0-7 DATA LOGGED t / � /2014 M K BENDER April 23, 2014 RECEIVED RE: CAST/CBL, ACE: 2L -322A APR 3 0 2014 Run Date: 4/21/2014 APPCC technical data listed below is being submitted herewith. Please address any probleg concerns to the attention of Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 2L -322A Data in LAS or DLIS format, Digital Log Image files 1 CD Rom 50-103-20628-01 ACE Log 1 Color Log 50-103-20628-01 CAST/CBL Field print 1 Color Log 50-103-20628-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date:'eo L 11 \ ASigned: M '�:) "-�f V GOVERNOR SEAN PARNELL Adam Klem �! Staff V Qf'Vlllt,lV 11C11J in ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2L -322A Sundry Number: 314-262 Dear Mr. Klem: Al"asit'a Oil and ""las 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. toerster Chair TW DATED this day of April, 2014. Encl. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS qn nnr. 9j; 9Rn 4/24114 1. Type of Request: Abandon Rug for Redrill Perforate New Pool Repair w ell Change Approved Program Suspend Rug Perforations Perforate Pull Tubing Time Extension Operational Shutdown Re-enter Susp. Well Frac{vrC Stimulate r%7 Alter casing Other: , 9 4 i 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory � Stratigraphic Development t Service zk-a - 3 - 1� - - � 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20628-01 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 No I, 2L -322A, 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380052, 380054 Kuparuk River Field / Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9515 ' 5220 , 9485'N 5220' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 103 16 146' 146' SURFACE 2571 10.75 2613' 2358' INTERMEDIATE 6170' 7.625" 6214.7' 4882 PROD. LINER 3453 4H' 9485' 5220' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5 L-80 6028 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER MD=5979 TVD=4790 no SSSV 12. Attachments: Description Summary of Proposal W 13. Well Class after proposed work: Detailed Operations Program f- BOP Sketch F Exploratory I— Stratigraphic Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/28/2014 Oil f;. , WINJ f" Gas WDSPL Suspended ('! GINJ WAG F Abandoned 16. Verbal Approval: Date: Commission Representative: GSTOR I— SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Adam Klem @ 263-4529 Email: Adam.Klem.cop.com Printed Name Adam Klem Title: Staff Completions Engineer Signature Phone: 263-4529 Date 7% Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test r- Mechanical IntegrityTest r— Location Clearance Other: RBDMS AY Spacing Exception Required? Yes ❑ No Subsequent Form Required: /o — ,ID 4 n APPROVED BY C Approved by: COMMISSIONER THE COMMISSION Date: �NNivvcu a n auv�o ..u..... �... �� .......�......... ......__ rr�---_ Form 10-403 (Revised 10/2012) I ' _ INA[ Submit Form and Attachments in Duplicate i 2L -322A Sundry Application 2L -322A had its top hole completed in March of 2014 as horizontal producer in the Bermuda formation. The well will be completed with 3.5" tubing and a 4.5" liner with one pressure actuated sliding sleeve, 7 ball actuated sliding sleeves and swellable packers between each sleeve. We will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the production to be 1000 bpd in 2014 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Bermuda 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 1,700' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 25 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. 10,500bbls 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. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 476 bbl breakdown stage (linear gel) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 25 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. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following schedule @ 25bpm with a maximum expected treating pressure of 4763 psi. Stage 1 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 1 Stage 2 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa RUN • • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 2 Stage 3 • 476 bbls Schlumberger fluid Pad Y 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 3 Stage 4 • 476 bbls Schlumberger fluid Pad 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 4 Stage 5 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 5 Stage 6 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa Drop ball 6 Stage 7 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 7 Stage 8 AK 11 • 0 476 bbls Schlumberger fluid Pad 0 238 bbls Schlumberger fluid w/ 2 ppa 0 298 bbls Schlumberger fluid w/ 4 ppa 0 71 bbls Schlumberger fluid w/ 5 ppa 0 79 bbls Schlumberger fluid w/ 6 ppa 0 60 bbls Schlumberger fluid w/ 8 ppa 0 Flush with 63 bbls of linear fluid and freeze protect 0 Total Sand: Approx. 1,000,000 lbs of sand type CarboLite 16/20 11. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 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). 14. 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 appropriate disposal well until they are clean enough for production.) Cement Evaluation of 2L -332A. No offset wells within'/4 mile of 2L -322A 2L -322A: 7 5/8" Casing cement job was pumped on 3/30/2014 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 11.5 ppg mud. The plug was bumped to 910 psi, floats held. Full returns were observed during the job. AK Tarn 21--322 North Rotary Sidetrack Tonset Bonsai Horizontal Multi -Stage Frac'd Producer ConocoPhillips Current Wellbore Schematic Gen V Tem oraryFMC 1 OK tree w/ DSA 4-1%" tree, top joint is 4-1%" 12.6# IBTM, crossed over to match current wellhead 16" Existina Cemented Conductor: 16" 62.6# H-40 Klem 4/23/14 146' MD 3'G" Camco DS Nipple 2.875" 500'MD 3'"cam°M Existing Surface Casing: A L10-3/4" 45.5# L-80 BTC 2,613' MD / 2,358' TVD @ 39° 3 %" Camco MMG Sidetrack KOP off cement plug @ 39 degrees in open hole @ 2,750' MD Campanian Top 2,808' MD (2,513'TVoj'i' Tubu 3 '/" Camco MMG 3-'//2" 9.33# L-80 EU E8RD AD tt.o PPG 4-1/2" 12.6# L-80 IBTM top joint to surface zep up with TOC 15.8 ppg @ 4620' 9-�I$" Intermediate Hole 'iution 3'/," Camco MMG Baker CMU Sliding Sleeve CLOSED wl 2.812" Cmco 'DSProtik 10' above production packer Iceberg!TOp 5,222' MD {4,369' TVD) 3.5" x 7-50, Baker Premier Packer -5,979' MD Base Bermuda 7,078' MD 5,246' TVD Production Liner na_ 90°: 4-1/2" 12.6# IBTM 6032' MDto 9,485' MD 11 Stimulation Surface Rig -Up Pop -01 Tank �z> mea J is • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. Pop -OB Tank Pump Truck 2L -322A Bermuda Multi -stage U 0 Frac Design Om Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Conc. (Ib/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Pad 20 YF125ST 476 25 0.00 2.0 PPA 20 YF125ST 238 25 CarboLite 16/20 1.00 4.0 PPA 20 YF125ST 298 25 CarboLite 16/20 2.00 5.0 PPA 20 YF125ST 71 25 CarboLite 16/20 3.00 6.0 PPA 20 YF125ST 79 25 CarboLite 16/20 4.00 8.0 PPA 20 YF125ST 60 25 CarboLite 16/20 6.00 Flush 20 WF125 91 25 0.00 • TF125ST 9776 bbis WF125 728 • •' 0 40 Model Results Initial Fracture Top TVD - 5228 ft Initial Fracture Bottom TVD - 5258 ft Propped Fracture Half -Length - 290.5 ft EOJ Hyd Height at Well - 132.6 ft Average Propped Width - .212 in Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. 0 • . ........ .... .... ----------------- ......... =MIA 1\ ; 8:35, April 11 2014 0 0 LO N tm C 0 z 2L-326 - 2N-315 2LI 329 Easting (2500 ft/in) 1 1 i 1 1 1 1 i 1 1 1 1 i 1 I I I I I I I I i Kuparuk 2L Pad I I �1 I 2L-329A- 2L-309PE 2L-322- _/ _ R=1500' -t,,�L-315 21- 323 2L -322A 2L-325 2L - 2N -305 2N -305A Kuparuk 2N Pad Easting (2500 ft/in) 2L-319 2L-310 2L2L-3-` 2L-311 2L-307 21--3071-2-01 - - - - - 2L-3071-2 ---------2L-320PB2 2L-313 2L-320PB1 2L -317A 2L-320 2L-321 21--309 2L-317 0 s tQ N C) 0 0 • ..................... .... -........................................................................................................ Fddhere--------------------------------------------------------------------------------------------------------------------- -------- Service Ticket No : 901286714 PGM Version. Logs Processed. CASTiCBL Date Logged 04-21-2014 Type Fluid In Hole: SEA WATER DIRECTIONAL INFORMATION Maximum Deviation @ KOP @ Remarks: 1. LOG CORRELATED TO SLB MWD LOG DATED 23 MAR 2014, TIED INTO GAMMA SIGNATURE 2, FREE PIPE INTERVAL WHICH BEING USED FOR INTERPRETATION IS AT 2940-2970 FT.. WITH OZ WATER OF 02 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAYBE GIVEN BY HALLIBURTON PERSONNEL OR WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM ANY USER OF SUCH DATAINTERPRETATIONS. CONVERSIONS. OR RECOMMENDATIONS AGREES THAT HALUBURTON IS NOT RESPONSIBLE EXCEPT VMERE DUE TO GROSS NEGLIGENCE OR WLLFUL MISCONDUCT FOR ANY LOSS DAMAGES OR EXPENSES RESULTING FROM THE USETHEREOF HALLIBURTON �"' KUP PROD 2L -322A O m O 20 C r r K .. na v o o' Z 0 OD r -u D o 0 � w0 -G r0 N v, s2 - nom. E C, Q adv �w0 � CD A� r Z N ZO o N m r 0 0 C D O00 O Z' A Or r ci 'u-0 r �o rn CAI D n U) U) D N ril �Cl > cern# z z z o 03 z -c � r m =1 _ m C D M O `. r Z c� p N --1 A A D O O O ..................... .... -........................................................................................................ Fddhere--------------------------------------------------------------------------------------------------------------------- -------- Service Ticket No : 901286714 PGM Version. Logs Processed. CASTiCBL Date Logged 04-21-2014 Type Fluid In Hole: SEA WATER DIRECTIONAL INFORMATION Maximum Deviation @ KOP @ Remarks: 1. LOG CORRELATED TO SLB MWD LOG DATED 23 MAR 2014, TIED INTO GAMMA SIGNATURE 2, FREE PIPE INTERVAL WHICH BEING USED FOR INTERPRETATION IS AT 2940-2970 FT.. WITH OZ WATER OF 02 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAYBE GIVEN BY HALLIBURTON PERSONNEL OR WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM ANY USER OF SUCH DATAINTERPRETATIONS. CONVERSIONS. OR RECOMMENDATIONS AGREES THAT HALUBURTON IS NOT RESPONSIBLE EXCEPT VMERE DUE TO GROSS NEGLIGENCE OR WLLFUL MISCONDUCT FOR ANY LOSS DAMAGES OR EXPENSES RESULTING FROM THE USETHEREOF HALLIBURTON �"' KUP PROD 2L -322A ConocoPhillir �r;A r•; F. ?S ` We11 A s M 6 MD TD i a=r_ra-[-. -- ..an Hams iwwocnaTa-ue— r•ai 1 --c.N' - C Fn 'i3fREi r -- 5' 29 7.94--G Gam!Nnl - ^I7 i;CMl PY.! - -- INK�/.gM1 CIW is KB•Gra l*13 --�-� rh RINa6l Cl4 AnMgtsm ne[h(RGO) CcQD a ! '... CndD (Lnna'elkm ..'• asing Sittings 4iNG �_wn,: r�l:nG Wr .. c.. -.:•s WQ.q 77i'S olnl iW IrtKC7 EPo[• IRKOi i7YD1_. Y16t 0®It [0.1" 55;5 : 5 - i-5;. T@p111Wm Hf rC6,i ,mr.t rcr 4 1St2 I 1 4P 3 ..x..;a. r ry , ►... 63 4L .. M.2. Cp Liner Detaft 7 1w MIO 1 169 ' OIT ON 1. M11051�7174ffy1rd%3tw. X 3 r' - _ ._ 11GX. ' e,OSa6 a,43t5 -+-_-;.- 3atr�Imc�cNc3lta--X75.8`41YStldiu35.r�g S 1t217a H7d-6Ni3�x pry 3^t.c5 j�.:�.� 4.5?5.5 � 56 .�=-- ": xos-�,�A 1.1,��3�„a s^,a.e4 My�253A �•�: `,;='_ e �.TT7o `.'253 .c{t1s 1 @S[4l3WROpacker 1T' [G7T5? 355,a- 7.1'[3.3 5=8 d523}` -=n: FwcPwx2-WScat #7 2.4:0 5.2157 wB7 `:.- 7.3879 ;;4T6 4 5,:23 fl 91.13 =� Frac Flom 2.37V Uat e5 - - M-34 :t'!E Ikkaswl1lpwket - �> 1.8'56 3.72:. 5 Q9 t8 °� - Frac Pcra 2.23Y Sail t3 - _..-, 17.SIC) 1.WE.5 5.rc1.9 59.65• -v: t: r:: cc• awetSFs^_ka 2 S53 2 . FwPc;42.12S54x 64 18.1407 4.257 3 5.7i1.o" SSil =r . =.. . aae6r3Wwpackir 13- } =� x.454.: - :.Z2�.2 69.0 wRA-- FwePca42.M'Se3i !3 (8.470? • SX 63 E,' S 7.'3J J 502915441 P: T.kaSwPOpxkEx "C- S.M..S 5,7233 93.95 == f.Palt1.S75�'Seat 12 Ism 'J3 �. -. a -' • -' 6.5BT 2 S.221 26'i 9S &4ef swr41 packer U, G8.9J0) 3m 5,5245 5,:?33 5913'==4 y",; : :- F= Pam 111Y Susi ti (5.135! 5.2v" S .2:5 P::� _ Balv3WMmitcT A' t l .55$ 5,ar�s 3.?355 "Is "!U_ P, t is i i r 4 Aci m 4v. * d 7 _.- S440) 5,210.6 &5.171 Stang 54e a Wcr=l& 130=" Vtwc _ .. Q w i L.J I i E 4 i HiP'l I-.ff-fu` »—rmm r1 Tf' if(iwii In 0 I TI 4 r, HIM 11111RID.1111K w 11 L PO-OFOM i ■� aamson irr■r 21 Q� r- 171 Iff j Ill 'a i i G N AL t 4 W�3ir�iat — =— 9 dhtl -2 mp�__ - =Is I=i N• ChkLLIF3uv-l—u .7 ill Ii r� im 0 0 w a am, ■■■Mi St i�ssCC� ■�� I } 3 7 k 4� �3 24 ■■■■EI Illi ■■■■N I 'I If�l�fi, -am.mmi-- i -SG WMSGT LC1 DZAVG 0 CCL 1 FCB) 0 -50 50 0 50 1�1 6.1 vo Its 0 OVAL 1 1 :6o0 i FCEMBI0 10 ECC 1 10 GR 150 LO �HllH I CLOT l 11 10 ZAVG 0 ray s HALLIBURTON Plot File: 11-LOCAL-1ACE_21--322MSurvey Infolfrs fastacelACE_DSP Data: ACE_2L-322A1001 cast-cbllmainl' Plot Time: 22 -Apr -14 03:47:08 Plot Range: 2850 ft to 6000 ft HALLIBURTON Plot Time: 22 -Apr -14 03:47:08 Plot Range: 2850 ft to 6000 ft Data: ACE -2L -322A\001 cast-cbllmainl' Plot File: 'Irs fastaceACESEGCURVES_DSP 0 CA110 0 CBM 0 CCt10 0 CD110 0 CE110 0 CF110 0 CGt10 0 CH110 0 C1110 1OZAVG 0 0 GR 150 CA2 I CB21r Ir CC21r In CDZ0Ir CE21r 10 CF210ID CGZ10 10 CH210I0 C1210I CA3 0 CB310 10 CC310 10 CD310 10 CE310 0 CF310 0 CG310 0 CH310 0 C131 0 CA410 0 CB410 0 CC410 0 CD410 0 CE410 0 CF410 1 0 CG410 0 CH410 0 C1410 Zp 1 DZAVG 0 1 Zp40 I X11 LC 6 15 OHI O �0 CA610 O CBBIO_ IO CC�10DBI OIO CE610 0 CFS10 0 CG810 0 Ct1610 0 CI610 I k dip i —_. "` ,.. ■■rid■■■f ' ■il,.:■■fir: ■r- M 11 prim ft -A A 1p =�� iip�iii -fir amm"m Eg /Jmmm.- E 3 I■■r:■■MS :■■■�-q■■!rl■■F;ter,■■FLsI •.-A■■■F1■■EZ3011,5001 A-- r:,■■!"+G■■!"! J■■l" SI'!■■L•• ...7009:..5■■■i: i■■�.1■■■■'., ■■i5:7■■G:•�■■E,: 0000[ i 4■■■ia!■■i= i■■Et ■■■E_ rA■■■r- l■■k-710006.■■■■■I '>i■■!'=■■■L"I■■■vi■■■l 1■■■■:i■■■■_AMEN r:i■■■br i'J■■■!p ■■■r A■■■n■■■■[r- OIL bA : Unions ■■/'!■■N■■ - ■■I-ze 1■■■ - 111990,911 ■N'F'4'!!F;.N■ L EME61mom- AMMENIF,i ■■ria■■■r° ;■■■rte■■■ca■■■1, N IIwIwl�Jrrr I Il■ri■■■aJ■ In■r.■■r.�■ 111■:'.s�■■■ Illi■1►7■■ I ai.I ZP 1:2001 LO 6.1501 LO �IvCA610 ■■■.1■NOR i7■■■i ■■W..'■■Wa■■■c ■fir-�■■■� �9■■t 0 CB610 0 CC610 0 CD VENOMS -loop""; =Q■■= -■■i'1■■ ■■■ti■■■■7■■ 0 GR 150 • 0 CA410 0 CB410 0 CC410 0 0 0 CE410 0 CF410 o CG410 o CH410 0 C1410 ape I OZAVG 0 0 CA310 0 CB310 0 CC310 0 CD310 0 CE310 0 CF310 0 CG310 0 CH310 0 C1310 0 CA21010 CB21010 CC21010 CD21010 CE21010 CF21010 CG21010 CH21010 02101 0 CA11010 CB11010 CC11010 CD11010 CE11010 CF11010 CG11010 CH11010 C1110 HALLIBURTON Plot Time: 22-Apr4403:47:11 Plot Range: 2860 ft to 6000 R Data: ACE_2L322A1001 cast-cbAmainl" Plot File: IVrs fastaceACE SEG CURVE3_0SP COMPANY CONOCOPHILLIPS ALASKA, INC. WELL 2L -322A FIELD TARN OIL POOL COUNTY N.SLOPE STATE ALASKA ADVANCED CEMENT EVALUATION �A HALLISUR I N ; z� D • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, April 23, 2014 4:26 PM To: 'Adam.Klem@conocophillips.com' Subject: KRU 2L -322A: Sundry Application (PTD 213-167) Good afternoon Adam, The sundry application is for stimulating the Bermuda Formation. From the wellbore schematic, the production liner is from 6,032' to 9,485' MD. In Box 11 of Form 10-403, the total depth, both MD and TVD, and the effective depths do not correspond to the wellbore schematic provided. Please submit the correct KRU 2L -322A depth information for Box 11. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov. r� U Bettis, Patricia K (DOA) n 1� From: Klem, Adam [Adam.Klem@conocophillips.com] Sent: Wednesday, April 23, 2014 4:04 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2L -322A: Sundry Application (PTD 213-167) Attachments: 2L-322 wo Bonzai current.pdf Here is a current WBD. Let me know if you need anything else. Adam Klem From: Bettis, Patricia K (DOA)[ma iIto: patricia.bettiscahalaska.gov] Sent: Wednesday, April 23, 2014 3:14 PM To: Klem, Adam Subject: [EXTERNAL]FW: KRU 2L -322A: Sundry Application (PTD 213-167) Adam, Please submit a current wellbore schematic for the KRU 2L -322A well. This may be sent to me via e-mail. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov_. 0 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, April 23, 2014 3:14 PM To: 'Adam. Klem@conocophillips.com' Subject: FW: KRU 2L -322A: Sundry Application (PTD 213-167) Adam, Please submit a current wellbore schematic for the KRU 2L -322A well. This may be sent to me via e-mail. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov. STATE OF ALASKA RECEIVED ALAOKA OIL AND GAS CONSERVATION COMMISSION 23 2014 APPLICATION FOR SUNDRY APPRPVALS 20 AAC 25.280 _&."4 11t4114 1. Type of Request: Abandon Plug for Redrill Perforate New Pool Repai w ell j" Change Approved Program Suspend r Rug Perforations Perforate Pull Tubing j"m Time Extension r Operational Shutdown r Re-enter Susp. Well Stimulate rv— , Alter casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory Development Stratigraphic j® Service }g q 03- /0 3. Address: 6 API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20628-01 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 r 2L -322A 9. Property Designation (Lease Number): __]10., Field/Pool(s): ADL 380052, 380054. Kuparuk River Field /Tarn Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7473 5319 2481' 2256' ` 81', 4630', 5500', 6500' Casing Length Size MD D, Burst Collapse CONDUCTOR 103 16 146' 146' SURFACE 2571 10.75 2613' 2358 INTERMEDIATE 6170' 7.625" 6212' V8Z Perforation Depth MD (ft): Perforation Depth TVD (ft): T bing Size: Tubing Grade: Tubing MD (ft): none none 3.5 L-80 6028 Packers and SSSV Type: Packers and{$SSV MID ( ) and TVD (ft) PACKER - BAKER PREMIER PACKER D=59 TVD+4790 no SSSV 12. Attachments: DescriptionSurrmary of ProposalW Clas r ro osed work: Detailed Operations Program BOP Sketc r7'orat _ Stratigraphic Development , Service 14. Estimated Date for Commencing Operations: 1 . Well Stas fter proposed work: 4/28/2014 Oil Gas VVDSPL F Suspended _ 16. Verbal Approval: Date: WINJ GINJ WAG F Abandoned Commission Representative: GSTOR SPLUG 17. 1 hereby certify that the foregoing is true and correct to the -'best of my knowledge. Contact: Adam Klem @ 263-4529 Email: Adam.Klem.cop.com Printed Name dam Klem Title: Staff Completions Engineer Signature Phone: 263-4529 Date Commission Use Only ySundry Number: n Conditions of approval: Notify Commission $o that a representative may witness Plug Integrity BOP Test 'Mechanical Integrity Test Location Clearance Other: Spacing Exception Required?' Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Approved aRl llcatlnes jallatiLmontnS Trom the date or approval. Form 10-403 (Revised 10/2012) k Submit Form and Attachments in Duplicate 0 • 2L -322A Sundry Application 2L -322A had its top hole completed in March of 2014 as horizontal producer in the Bermuda formation. The well will be completed with 3.5" tubing and a 4.5" liner with one pressure actuated sliding sleeve, 7 ball actuated sliding sleeves and swellable packers between each sleeve. We will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the production to be 1000 bpd in 2014 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Bermuda 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 1,700' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 25 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. 10,500bbls 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. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 476 bbl breakdown stage (linear gel) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 25 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. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following schedule @ 25bpm with a maximum expected treating pressure of 4763 psi. Stage 1 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 1 Stage 2 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa AK 0 • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa Drop ball 2 Stage 3 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 3 Stage 4 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 4 Stage 5 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 5 Stage 6 • 476 bbls Schlumberger fluid Pad • 238bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa Drop ball 6 Stage 7 • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Drop ball 7 Stage 8 m • • 476 bbls Schlumberger fluid Pad • 238 bbls Schlumberger fluid w/ 2 ppa • 298 bbls Schlumberger fluid w/ 4 ppa • 71 bbls Schlumberger fluid w/ 5 ppa • 79 bbls Schlumberger fluid w/ 6 ppa • 60 bbls Schlumberger fluid w/ 8 ppa • Flush with 63 bbls of linear fluid and freeze protect • Total Sand: Approx. 1,000,000 lbs of sand type CarboLite 16/20 11. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 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). 14. 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 appropriate disposal well until they are clean enough for production.) Cement Evaluation of 2L -332A. No offset wells within '/4 mile of 2L -322A 2L -322A: 7 5/8" Casing cement job was pumped on 3/30/2014 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 11.5 ppg mud. The plug was bumped to 910 psi, floats held. Full returns were observed during the job. /:" Stimulation Surface Rig -Up d C L4 U Minimum pressure rating on all surface treating lines 10,000 psi Main treating line PRV is set to 95% of max treating pressure IA parallel PRV set to 3500 psi Frac pump trip pressure setting are staggered and set below main treating line PRV Tree saver used on all fracs rated for 15,000 psi. POOR Tank Pump Trude 2L -322A Bermuda Multi -stage Frac Model E E Frac Design 1 stage Job Description Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Conc. (Ib/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Pad 20 YF125ST 476 25 0.00 2.0 PPA 20 YF125ST 238 25 CarboLite 16/20 1.00 4.0 PPA 20 YF125ST 298 25 CarboLite 16/20 2.00 5.0 PPA 20 YF125ST 71 25 CarboLite 16/20 3.00 6.0 PPA 20 YF125ST 79 25 CarboLite 16/20 4.00 8.0 PPA 20 YF125ST 60 25 CarboLite 16/20 6.00 Flush 20 WF125 91 25 0.00 Totals (8 stages) YF125ST - 9776 bbls WF125 - 728 bbls CarboLite 16/20 - 1,000,000 Ibs • Model Results Initial Fracture Top TVD - 5228 ft Initial Fracture Bottom TVD - 5258 ft Propped Fracture Half -Length - 290.5 ft EOJ Hyd Height at Well - 132.6 ft Average Propped Width - .212 in Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. 0 18:35, April 11 2014 c 2L-326 - 2N-315 - 2L-329 Easting (2500 Win) IIIIIIIIIIIIIIIIIIIIIII Kuparuk 2L Pad 2L-329A- 2L-32N�' 2L -309P[ 2L-322 _/ _ R=1500' 2L -,�L-315 \1 323 2L -322A 2L-325 2L - 2N -305 2N -305A Kuparuk 2N Pad Easting (2500 ft/in) 2L-319 2L-310 2L2L-3� 2L-311 2L-307 2L-3u'L 2-01 _ - - 2L-307L2 ---------2L-320PB2 2L-313 2 L-320 P B 1 2L -317A 2L-320 2L-321 2L-309 2L-317 0 3 0 N CD 0 0 • 0 Ferguson, Victoria L (DOA) From: Nabors 9ES Co man <Nabors9ESComan@conocophillips.com> Sent: Sunday, April 13, 2014 3:14 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Shultz, Steve (Orbis Engineering, Inc.); Rauchenstein, Rock D; Alvord, Chip; Bearden, J Daniel; Ferguson, Victoria L (DOA) Subject: RE: Nabors 9es BOP test due 4/14/2014 Well 21--322A Follow Up Flag: Follow up Flag Status: Flagged All, We are circulating and weighting up f/ 12.6 ppg to 12.7 ppg at this time (bit depth 5377'). We will circulate while running in the hole closer to the shoe @ 6214'. Set a storm packer after monitoring hole. Then we will perform our BOPE test this evening. ctraVL,VLLI,e gliorhus/Paul, swith Nabors 9ES 907-659-7718 Office 907-659-7614 Rig From: Regg, James B (DOA) [mailto:jim.regg alaska.gov] Sent: Saturday, April 12, 2014 11:44 AM To: Nabors 9ES Co man; DOA AOGCC Prudhoe Bay Cc: Shultz, Steve (Orbis Engineering, Inc.); Rauchenstein, Rock D; Alvord, Chip; Bearden, J Daniel; DOA AOGCC Prudhoe Bay; Ferguson, Victoria L (DOA) Subject: [EXTERNAL]RE: Nabors 9es BOP test due 4/14/2014 Well 2L -322A Deferring the BOPE test until after running the liner would only be approved if you cannot safely hang off to test. Suggest you give us an update of the well's status tomorrow. Sent from Samsung Mobile Original message From: Nabors 9ES Co man <Nabors9ESComankconocophillips.com> Date: 04/12/2014 2:33 PM (GMT -06:00) To: "Regg, James B (DOA)" <<iim.reRgkalaska.gov>,DOA AOGCC Prudhoe Bay <doa. aogcc.prudhoe.baykalaska..ov> Cc: "Shultz, Steve (Orbic Engineering, Inc.)" <Steve.Shultzgcontractor.conocophillips.com>,"Rauchenstein, Rock D" <Rock.D.Rauchensteinkconocophillips.com>,"Alvord, Chip" <Chip.Alvordgconocophillip i.com>,"Bearden, J Daniel" <J.Daniel.Beardenkconocophillips.com> Subject: Nabors 9es BOP test due 4/14/2014 Well 2L -322A Jim, Ms. The last BOP test performed on Nab*9es ended at 0130hrs 3/31/2014 after se0g 7-5/8" intermediate casing at 6214'. The next test is due Monday 4/14/2014. 6-1/2" hole was drilled to TD of 9516' at which point plans are to pull out of the hole to run a 4-1/2" liner. We are experiencing lost returns when pumping and the well will flow back when pumping is stopped. While monitoring the well without pumping the return rate decreases but stabilizes after a couple of hours. We are able to resume pumping with partial losses and small volumes of gas in the returns. The current mud weight is 12.2 ppg and we are currently increasing the mud weight to 12.4 ppg to increase our trip margin. We are also spotting LCM pills in order to control the losses. At this time we are not sure we will be able to pull out of the hole to perform a BOP test before Monday the 14`h. If necessary and conditions are appropriate it may be necessary to hang the drill string off on a Storm Packer in order to test the BOP. We would also like to consider the possibility of testing BOPE after running the liner. crav,,VLLLe Rizek / R.%c%gjorhus / Paul-Svu.ith Nabors 9 ES Company Men 907-659-7718 Office 907-659-7614 Rig TIDE STATE 'T A 7<7 GOVERNOR SEAN PARNELL Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L -322A Sundry Number: 314-226 Dear Mr. Alvord: a • € m,-ka, Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this L day of April, 2014. Encl. CJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25280 RECEIVED APR 0 9 2014 AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program Q Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc Exploratory ❑ Development Q - Stratigraphic ❑ Service ❑ 213-167 ' 3. Address: 6. API Number: P.O. Box 100360 Anchorage, AK 995510-0360 50-103-20628-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 2L -322A Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380052,'380054' 1 Kuparuk River Field Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MID (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9515' 5247' 9515 1 5247' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 16" 146" 146" Surface 2571' 10-3/4" 2613' 2358' 5210 2480 Intermediate 6186' 7-5/8" 6214' 5011 9180 8810 Production Liner 3451' 4-1/2" 9515' 5247' 11590 9200 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size:Tubing Grade: Tubing MD (ft): N/A N/A 3-1/2" L-80 6028' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premium Packer 602874918' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 71 Service ❑ 14. Estimated Date for 4/8/2014 15. Well Status after proposed work: Commencing Operations: Oil ❑✓ Gas ❑ WDSPL ❑ Suspended ❑ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: 9 �9 Commission Representative: 0eiv i'd, c� ,'-5a-y, GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct the best of my knowledge. Contact Steve Shultz Email Steve Shultz(C�contractor. con OCOphIIIIpS.COrII Printed Name Chip Alvord 265-6120 Title Drilling Manager Signature Phone Date 1 (`1 /Z. 14- 4COMMISSION 44 COMMISSIONUSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3A14-- 22Zc Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / (� U L �—�� vr�Y� OI RBDMS MAY 10 2014 f Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required:�L APPROVED BY 1,2 Approved by: COMMISSIONER THE COMMISSION Date: . / Submit Form and Form 10-403 (Revised 10/2012) Appro dplication is vaalid for 12 months from tthh/e dattee o`f aapproval. Attachments in Duplicate V117 d 10 i A-�I A I N A I �1. \ � CIN �',W { � "X) ` • Post Office Box 100360 Anchorage, Alaska 99510-0360 Chip Alvord Phone (907) 265-6120 Email: Chip.Alvord(&conocophillias.com April 8, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED APR 0 9 2014 ANOGIC10, Conoc6Phillips' Re: Application for Sundry Approval to Change Approved Program for 2L -322A (PTD 213-167) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Sundry Approval to Change the Approved drilling program for 2L -322A (PTD 213-167). As outlined in our meeting dated April 8th, 2014, ConocoPhillips believes we have met the intent of the AOGCC regulations 20 ACC 25.030(d)(5) regarding cement height of at least 500' above the upper -most hydrocarbon bearing zone in the Tarn Pool (Iceberg formation). Upon top -setting the Bermuda with our 7-5/8" casing string, 96 bbls (461 sx) of Class G cement was successfully pumped to achieve a cement height of 1,570' MD (1,200' TVD) above the shoe which covers at least 500' above the Iceberg. ConocoPhillips believes this cement coverage satisfies the AOGCC's intent of zonal isolation, and therefore, the Bonzai cement procedure is not needed. 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 10-403 APPLICATION FOR Sundry Approval to Change Approved Program 2. A Un -cemented horizontal liner proposal 3. Proposed Completion Diagram Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Steve Shultz at 263-4297. Sincerely, A e. _ �-vord CPAI Drilling Manager 'On 21--322 North (wp12) Rotary Sidetrack Tonset Bonsai Horizontal Multi -Stage Frac'd Producer ConocoPhillips Proposed Wellbore Schematic WMC Gen V Tem orary FMC 10K it _ w/ DSA 4-%" tree, top joint is 4-%" 12.6# IBTM, crossed over to match current well head 16" Existing Cemented Conductor: 16" 62.6# H-40 Bearden 4/08/14 146' M D LSND 9.5 — 10.0 PPG Keep up with Dilution Iceberg Top 3 %" Camco DS Nipple 2.875" 500'MD 3%"Carrico IVIMG Existing Surface Casing; 10-3/4" 45.5# L-80 BTC 2,613' MD / 2,358' TVD @ 39- L 9° LOT: 14.9 PPG @ 2,786' MD on March 23, 2014 3'/:" Camco MMG Sidetrack KOP off cement plug @ 39 degrees in open hole @ 2,750' MD fracture Gradient 12.5noa Tubin : 3''/:"Camco MMG 3'/2" 9.3# L-80 EUE8RD X \X 4-1/2" 12.6# L-80 IBTM top joint to surface TOC 15.8 ppg @ +/-4,653' MD +500' above Iceberg) 9-7/8" Intermediate Hole 31/" Carrico MMG (A,BWTVD) of Bermuda 6,636' MD 5,155' TVD Baker CMU Sliding Sleeve CLOSED .12.812" Camco'DS' Profile 10' above production packer fracture :radient. 3i5nna !: 3.5" x 7-5/8", Baker Premier Packer -5,950' MD 3 %" Camco D Nipple 2.75" nogo 7-5/8" x 3-%" Baker Flex Lock Liner hanger ZXP liner top packer w/RS Ni ple 6,08 ' MD, Intermecl�tate asing Topset 7-5/8" 29.7# L-80 & 500' TN110SS 39# - all Hydril 563 connections Y8oP4 G11P245 FIT: 4,(1' TVD @ D ✓ 64 Production Liner an 90D: / 4-1/2" 12.6# IBTM Perforated Pup 7,100' MD to 9,515' MD 5,215' TVD to 5,220' TVD Tarn Un -cemented Horizontal Liner Proposal New Tarn well designs call for top -setting the Bermuda to maintain well control when drilling high reservoir pressure. Initial well planning we may have inadvertently misinterpreted the AOGCC rules concerning cement isolation for horizontal wells (all planned as producers). ■ We were under the impression that we had to place continuous cement up to 500' above the hydrocarbon bearing zones ■ From further review, it appears that 500' of cement must be placed above the upper most sand in the Pool. ■ The Tarn pool consists of the C-30, Bermuda, Cairne, Iceberg. We are top -setting just above the Bermuda then placing —1,500' to 2,000' of cement! p gJ p g to place cement 500' above the top of the Iceberg. Therefore, we believe we are achieving the AOGCC's intent of isolation already, and performing the additional Bonzai cement job is not required. 110 a. I Aerte I ICairne 0 Al 5W feet of cement above the iceberg 7 5/8" Intermediate Casing cemented Cement shoe at 6,224MD 4 1/2" Liner(uncemented) r 16.0 p[DR MWE FiT Addressing Any Meltwater Concerns Tarn has been injecting/producing slightly longer than Meltwater, and we have observed no signs of the containment issues that Meltwater has. i ✓ No 4D seismic signature above Bermuda that indicate pressure or saturation changes. ✓ No wells with sustained elevated OA pressure. ✓ OA gas samples at Tarn show 99% methane, no MI signature. In addition, Tarn cements 500' above the top of the pool (500' above Iceberg). Meltwater also cements 500' above the top of the pool, but the Meltwater pool only consists of the Bermuda. Therefore, Meltwater only has -500' of cement above the Bermuda, where Tarn typically has 1500'- 2,000' of cement above the Bermuda. • Ferguson, Victoria L (DOA) 0 From: Ferguson, Victoria L (DOA) Sent: Wednesday, April 09, 2014 3:56 PM To: 'Steve.Shultz@contractor.conocophillips.com' Subject: RE: KRU Tarn Oil Pool 2L-322A(PTD 213-167, Sundry 314-226) Verbal approval is granted to proceed with this Sundry. A CBL is required. The approved sundry will be available tomorrow. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferouson(c)alaska.aov From: Ferguson, Victoria L (DOA) Sent: Wednesday, April 09, 2014 1:05 PM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Subject: KRU Tarn Oil Pool 2L-322A(PTD 213-167, Sundry 314-226) We are reviewing the sundry. Just to let you know, we will be requiring a CBL - From: Shultz, Steve (Orbis Engineering, Inc.) fmaiIto: Steve. Shultz@contractor.conocophiIlips.com] Sent: Tuesday, April 08, 2014 11:15 AM To: Ferguson, Victoria L (DOA) Subject: RE: Tarn Well Completions Sorry Victoria, I pulled that out of the Pool Rules. I should have stated it as a log. Steve From: Ferguson, Victoria L (DOA)[mailto:victoria.ferguson@alaska.gov] Sent: Tuesday, April 08, 2014 10:39 AM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]RE: Tarn Well Completions Also, the file labeled Tarn Pool Rules is a log - From: Ferguson, Victoria L (DOA) Sent: Tuesday, April 08, 2014 10:16 AM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Subject: RE: Tarn Well Completions We cannot view either of the visio drawings - 1 From: Shultz, Steve (Orbis Engineering, Inc.) [ma ilto: Steve. Shultz@contractor.conocophillips.com] Sent: Monday, April 07, 2014 3:16 PM To: Ferguson, Victoria L (DOA); Schwartz, Guy L (DOA) Subject: Tarn Well Completions Victoria and Guy, We have finished drilling on 2L -322A North and now are ready to proceed with the completion. This well called for a Bonzai completion which would ensure we had cement from the top of the Bermuda Sand to the shoe of the 7 5/8" intermediate casing. Due to the Bermuda being highly pressured we are now top setting the majority of our wells to have better control while drilling the Bermuda. During the initial planning of the completion we may have inadvertently misinterpreted the AOGCC rules concerning cement isolation. We were under the impression we had to be 500 feet above any hydrocarbon bearing zone with cement isolation, but upon further review it appears that 500 feet above the upper most sand in the pool is what is required. The Tarn pool consisting of the C-30, the Bermuda, the Cairne and the Iceberg has to have cement 500' above the Iceberg (upper most sand). On 2L -322A this has been accomplished when we cemented from just above the Bermuda (6,224'MD) to 500 feet over the Iceberg (4,654'MD) for a total cement column of 1,570 feet MD/ 1,200 feet TVD. For all of our topsets in the Tarn we plan to continue cementing the full length from the top of the Bermuda to 500 feet over the Iceberg. The dilemma we have now is the complicated Bonzai completion that we planned on using to complete these wells. Originally we contemplated running a drilling liner for isolation just above the Bermuda, but in order to do that we would have had to increase all of our casing sizes which would have required increased hole sizes making the wells uneconomical. The complicated Bonzai completion was then implemented since BP had down these in the past. Originally, we were going to run our frac sleeves, swell packers, an external casing packer, a stage tool and liner hanger in on drill pipe (see attached). Once on bottom we would set and release from the liner hanger, then shift our inner string inside the liner and position a cup tool so as to be able to inflate our external casing packer. Once that was accomplished we would reposition our cups and open a cementing diverter tool. Cement would then be pumped placing cement from the top of the ECP to out liner hanger inside the 7 5/8" casing. The diverter tool would then be closed by pulling the inner string. The inner string would then be pressure up and a burst disc ruptured to allow us to circulate out any excess cement. Finally the inner string would be pulled out of the hole with the drill pipe. As can be ascertained from this long and complicated process, there is a high element of risk of failure if any one of these operations prove ineffective. Now that we are more aware of our obligations for cement isolation which we have already accomplished for 2L -322A, we would like to request permission to simplify our completion for this well and future Tarn wells and run the frac sleeves and swell packers along with a conventional liner hanger as before, but would forego the cementing operation with the inner string, the external casing packer and diverter tool. Would it be possible for myself and some co-workers to come over tomorrow and discuss the situation. Thanks, Steve Shultz ConocoPhillips Drilling Engineer • 0 PTD 213-14-7 Ferguson, Victoria L (DOA) From: Shultz, Steve (Orbis Engineering, Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Monday, April 07, 2014 3:16 PM To: Ferguson, Victoria L (DOA); Schwartz, Guy L (DOA) Subject: Tarn Well Completions Attachments: Bermuda Pool.xlsx; 2L-322 North Proposed Schematic.vsd; 2L-322 wo Bonzai.vsd; Tarn Pool Rules.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria and Guy, We have finished drilling on 2L -322A North and now are ready to proceed with the completion. This well called for a Bonzai completion which would ensure we had cement from the top of the Bermuda Sand to the shoe of the 7 5/8" intermediate casing. Due to the Bermuda being highly pressured we are now top setting the majority of our wells to have better control while drilling the Bermuda. During the initial planning of the completion we may have inadvertently misinterpreted the AOGCC rules concerning cement isolation. We were under the impression we had to be 500 feet above any hydrocarbon bearing zone with cement isolation, but upon further review it appears that 500 feet above the upper most sand in the pool is what is required. The Tarn pool consisting of the C-30, the Bermuda, the Cairne and the Iceberg has to have cement_500' above the Icebergjupper most sand). On 2L -322A this has been accomplished when we cemented from just above the Bermuda (6,224'MD) to 500 feet over the Iceberg (4,654'MD) for a total cement column of 1,570 feet MD/ 1,200 feet TVD. For all of our topsets in the Tarn we plan to continue cementing the full length from the top of the Bermuda to 500 feet over the Iceberg. The dilemma we have now is the complicated Bonzai completion that we planned on using to complete these wells. Originally we contemplated running a drilling liner for isolation just above the Bermuda, but in order to do that we would have had to increase all of our casing sizes which would have required increased hole sizes making the wells uneconomical. The complicated Bonzai completion was then implemented since BP had down these in the past. Originally, we were going to run our frac sleeves, swell packers, an external casing packer, a stage tool and liner hanger in on drill pipe (see attached). Once on bottom we would set and release from the liner hanger, then shift our inner string inside the liner and position a cup tool so as to be able to inflate our external casing packer. Once that was accomplished we would reposition our cups and open a cementing diverter tool. Cement would then be pumped placing cement from the top of the ECP to out liner hanger inside the 7 5/8" casing. The diverter tool would then be closed by pulling the inner string. The inner string would then be pressure up and a burst disc ruptured to allow us to circulate out any excess cement. Finally the inner string would be pulled out of the hole with the drill pipe. As can be ascertained from this long and complicated process, there is a high element of risk of failure if any one of these operations prove ineffective. Now that we are more aware of our obligations for cement isolation which we have already accomplished for 2L -322A, we would like to request permission to simplify our completion for this well and future Tarn wells and run the frac sleeves and swell packers along with a conventional liner hanger as before, but would forego the cementing operation with the inner string, the external casing packer and diverter tool. Would it be possible for myself and some co-workers to come over tomorrow and discuss the situation. Thanks, Steve Shultz ConocoPhillips Drilling Engineer 0 Ferguson, Victoria L (DOA) • From: Shultz, Steve (Orbis Engineering, Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Tuesday, April 01, 2014 9:20 AM To: Ferguson, Victoria L (DOA) Subject: Bonsai Completions Follow Up Flag: Follow up Flag Status: Flagged Victoria, We are about to complete our first Bonsai Completion in the Tarn field. I just wanted to reaffirm our plan with the state. In the past, since it is a state requirement to have 500 feet of cement isolation over any hydrocarbon producing zone, BP was involved with top setting casing above producing formations and came up with the Bonsai completion. This involves the cementing of the upper portion of the liner without cementing the lower portion of the liner. This works well with slotted liners or liners involving sleeves for frac operations and passes muster for the states requirement of cement isolating from the top of the zone to a minimum of 500 feet over the zone. The liner may only have several hundred feet of length above the zone of interest but once it is cement in place the cement would be continuous from the top of the zone to the liner lap and then isolation would continue up with the cement outside the intermediate casing to a minimum of 500 feet over the zone. I had a conversation with Guy about a year ago to see if the state still required a Bonsai Completion when we top set just several hundred feet above Bermuda to ensure we had cement isolation as per state guide lines. He told me yes, especially since we planned on fracing the Bermuda. I just wanted to make sure that this is still the case. Steve Shultz Drilling Engineer ConocoPhillips 263-4297 2L-314 Tarawa (wp08 Grace Roots Toaset Pilo ole Bonsai Horizontal Mufti -Stage Frac'd Producer ConocoPhillips Proposed Wellbore Schematic Fresh Water Spud Mud Permafrost 9.6 PPG 3'h" Camco D Nipple 2.875" 500'MD Fresh Water Spud Mud 9.8-10 PPG 3''A" Camco MMG 3 Ya" Camco LSND 9.6 —10.0 PPG 3 v," Camco Keep up with Dilution 3 X" Camco 3 h" Camco D Nipple 2.75" nogo y111)�V C^, Top of Bermuda 9,244' MD 5,328' TVD Rnnani I it `.:: 3!tiCkerllAloMr �bRlEii+t 1artt�at 1,35dPit�li . CAMERON 4-1W" tree, top joint is 4-1/2" 12.6# IBTM, crossed over (for frac equipment) Bearden 1/20/2014 New Existing- onductor: 16" 62.6# H-40 Surface Casing: 10-3/4" 45.5# L-80 Hydril 563 2,619' MD / 2,236' TVD @ 62- 13-112" Surface Hole 9-7/8" Intermediate Hole Tubina: 3'/2" 9.3# L-80 EUE8RD 4-1/2" 12.6# L-80 IBTM top joint to surface Estimated top of cement @ +/- 6,800' MD (500' above Iceberg) Production Liner &V 58.5-: 4-1/2" 12.6# IBTM 8,791' MD / 5,175' TVD TO 11,602' MD / 5,413' TVD V e ( C2 t� t10 0 1910010 501032014500 -Cr:}- ARCO KRU 3610-7/1 1464 FNL 714 FWL TW P: 10 N - Ra rage: 7 E - Sec _ 36 -4SCQ -Sccc Tarn (Di Pa©t -577 -5577 -S}77 c a V-1 f "Vi S Tarn Un -cemented Liner Proposal New Tarn well designs call for top -setting the Bermuda to maintain well control when drilling high reservoir pressure. Initial welllannin we may have inadvertently misinterpreted the AOGCC rules p g concerning cement isolation. ■ We were under the impression that we had to place continuous cement up to 500' above the hydrocarbon bearing zones ■ From further review, it appears that 500' of cement must be placed above the upper most sand in the Pool. ■ The Tarn pool consists of the C-30, Bermuda, Cairne, Iceberg. We are top -setting just above the Bermuda, then placing —1,500' to 2,000' of cement to place cement 500' above the top of the Iceberg. Therefore, we believe we are achieving the AOGCC's intent of isolation already, and performing the additional Bonzai cement job is not required. 5-00 feet of cement above the Iceberg e7/8^Intermediate Hole Aerte \\7 N, 7 5/8" Intermediate Casing cernented -Cai Cement shoe at 6,224MD 16Oppgrvl��IEFIT 4 112" Liner (uncemented) Addressing Any Meltwater Concerns Tarn has been injecting/producing slightly longer than Meltwater, and we have observed no signs of the containment issues that Meltwater has. 0 ✓ No 4D seismic signature above Bermuda that indicate pressure or saturation changes. ✓ No wells with sustained elevated OA pressure. ✓ OA gas samples at Tarn show 99% methane, no MI signature. In addition, Tarn cements 500' above the top of the pool (500' above Iceberg). Meltwater also cements 500' above the top of the pool, but the Meltwater pool only consists of the Bermuda. Therefore, Meltwater only has —500' of cement above the Bermuda, where Tarn typically has 1500'— 2,000' of cement above the Bermuda. an6l ©Q� Tata kw"r goA-WS are C(6 PMJOWS. Ferguson, Victoria L (DOA) From: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Tuesday, April 08, 2014 2:27 PM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA); Wallace, Chris D (DOA) Cc: Blakney, Robert G; Shultz, Steve (Orbis Engineering, Inc.); Lewis, Adam M (Alaska); Umlauf, Kelly K Subject: Well Schematic (2N -323A 1st program well) Attachments: 2N -323A Ripple final Schematic 3_10.pdf Thank you for meeting with us this afternoon. As requested, please find attached the schematic of our first 2014 program well, 2N -323A rotary sidetracked slant. Our 10-407 Completions Report for this well is due to arrive at the AOGCC prior to April 16`h. The well was successfully fracture stimulated on March 24`h with 324'000lbs of 16/20 mesh proppant. The well was placed on production on Aprl 15`, and is currently producing 3,000 bbl/fluid per day at —50% water cut, and is still cleaning up. I have contacted Mr. Robbie Blakney, our Tarn completions engineer, regarding frac modeling (pre/post job) data for this well. He is also gathering frac modeling analysis performed for our multi -stage horizontal jobs. Within the hour, we will report back to you to schedule a meeting to discuss this topic. Regards, Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell 6'G :rine not ceded fc NO part, _SND 9.6 PPG Keep up with Dilution TN -323A Ripple (As Built) Rotary Sidet k Topset Conventional Slant Producer Final Wellbore Schematic 3 %" Cameo DS Nipple 2.875" 500'MD 0 ConocoPhilli s p -€ -IC Gen V 41/V tree, top joint is 4-%" 12.6# IBTM, crossed over to match current well head Bearden 3/14/14 16" Existing Cemented Conductor: 16" 62.6# H-40 108' MD 3'/:" x 1" Cameo MMG 4277' MD Existing 9-5/8" Weatherford Gemoco Stage Collar @ 1,800' (be aware when tripping in & out) FIT 13.7 ppg EMW @ 3,470' MD / 2,300' TVD 2/19/2014 Existing Surface Casing: 9-5/8" 40# L-80 BTC 3,460' MD / 2,299' TVD @ 62D 3 K" x 1"Cameo MMG ' %:.. Tubing: 7131' MD 3-1/2" 9.3# L-80 EUE8RD 4-1/2' 12.6# L-80 IBTM top joint to surface Estimated top of cement @ 8,000' Mo (+500' above Iceberg) 8_1/2" Intermediate Hol/ 3''/z" x 1" Cameo 8986' MD 3 %" x 1" Cameo MMG 9840' MD Baker CMU Sliding Sleeve CLOSED w/ 2.812" Camco'DS' Profile 9873' MD 3 %" Camco'D' Nipple 2.75" nogo 9924' MD Cemented Production Liner: 3-1/2" 9.3# L-80 Hydril 563 10,663' MD / 5,256' TVD @ 42° Well TVD LOT/FIT 2L-309 4944 16 2L-327 5114 15.6 2N-327 5155 16 2N-310 5152 14.8 2L-330 5237 16 2N -305A 5213 17.5 2N -318A 4917 17.0 • 0 P7 -1D 2-13 — / (, 7 - Ferguson, Victoria L (DOA) From: Regg, James B (DOA) Sent: Tuesday, March 25, 2014 8:33 AM To: Bordelon, Toby Cc: Ferguson, Victoria L (DOA) Subject: RE: 9 -ES BOPE Test 3-20-14 Follow Up Flag: Follow up Flag Status: Flagged You were approved to do work under a sundry that included no BOPE testing so receipt of BOPE test report without any explanation was confusing. I will revise. Sent from Samsung Mobile -------- Original message -------- From: "Bordelon, Toby" <Toby.Bordelongnabors.com> Date: 03/25/2014 6:30 AM (GMT -09:00) To: "Regg, James B (DOA)" <jim.regggalaska.gov> Subject: RE: 9 -ES BOPE Test 3-20-14 Jim, I was informed prior to drilling out cement, the retainer,and exiting the casing & performing the LOT we were onpermit to drill # 2101740 and well name 2L-322 after above is performed we would go to this PTD 2131670 and 2L -322A. Is that correct if not i can change the form and resubmit. At the time we performed this test we had not done any drilling or any of the above. Please advise and thank you. Toby Bordelon Nabors Alaska Drilling Rig 9 -ES From: Regg, James B (DOA) <iim.re>;@alaska.>;ov> Sent: Monday, March 24, 201410:41 AM To: Bordelon, Toby Subject: RE: 9 -ES BOPE Test 3-20-14 Is this supposed to be KRU 2L -322A (PTD 2131670)? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 0 0 From: Bordelon, Toby[mailto:Toby.Bordelon@nabors.com] Sent: Friday, March 21, 2014 3:18 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: n9escm@conocophillps.com; Johnston, David Subject: 9 -ES BOPE Test 3-20-14 ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. THE STATE o 1A LASKA J-.V GOVERNOR SEAN PARNELL G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: Kuparuk River Field, Tarn Oil Pool, 2L -322A ConocoPhillips Alaska, Inc. Permit No: 213-167 Surface Location: 209' FNL, 821' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 1494' FNL, 879' FEL, SEC. 27, T1ON, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re -drill the above referenced development well. 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. 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this /0- day of December, 2013. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED NoV 0 4 2013 1 a. Type of Work: 1 b. Proposed Well Class: Development - Oil Service - Wini ❑ Single Zone D. 1c. 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: 1,/l Blanket Single Well 11. Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59-52-180, 2L-322A� 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 9542' < TVD: 5220' • Kuparuk River Field - 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 209' FNL, 821' FEL, Sec. 22, T1 ON, R7E, UM • ADL 380052, 380054 • Tarn Oil Pool r Top of Productive Horizon: 8. Land Use Permit: 13, Approximate Spud Date: 1778' FSL, 1023' FEL, Sec. 22, T10N, R7E, UM 4600, 4602 2/1/2014 Total Depth: 9. Acres in Property: 14. Distance to 1494' FNL, 879' FEL, Sec. 27, T10N, R7E, UM . 51a-0I1I5I Nearest Property: 1.25 mile to CRU 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 143 feet 15. Distance to Nearest Well Open Surface: x- 460829 y- 5927638 Zone- 4- GL Elevation above MSL: 115 feet to Same Pool: 2N-305, 1830' 16. Deviated wells: Kickoff depth: X2700 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: . 90° deg Downhole: 3000 psig , Surface: 2684 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight I Grade Coupling Length MD TVD MD TVD including stage data) 9.875" 7.625" 29.7 & 39# -80, TN -11 Hydril 563 6222' 28' 28' 6250' 5037' 422 sx GasBLOK Class G 6.5" 4.5" 12.6# L-80 MBT 3454' 6100' 4966' 9554' 5231' 96 sx Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 7473 5319 2481, 4630, 5500, 6500 2481 2256 none Casing Length Size Cement Volume MD TVD Conductor/Structural 103' 16" driven 146' 146' Surface 2571' 10.75" 970 sx AS LiteCRETE & 2613' 2358' 395 sx LiteCRETE Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): none nolle 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ✓ Time v. Depth Ploti7l Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4864 Email Steve. SInultz(a)contractor. cop. com Printed Name G. L. Alvord Title Alaska Drilling Manager SignaturePhone: 265-6120 Date 841 (Zn t 14 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 13 16 - 50- l 3 - a0(o ',tg- (�, — C)O Date: I t' for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed m9thane, gas hydrates, or gas contained in shales: ✓ Mud log Yes❑ No [jj/ Other: Samples req'd: Yes 0 No req'd: Directional svy req'd: Yes( No H2S measures: Yes No Yes Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: ❑ No APP,.ROVEDBYTHE Date: 12-10 Approved by: ' COMMISSIONER COMMISSION Form 10-401 (Revised 10/2012) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g))/'s!�2_ / A& /&-/ it Post Office Box 100360 Anchorage, Alaska 99510-0360 Chip Alvord Phone (907) 265-6120 Email: Chip.Alvord(a,conocophillips.com October 14, 2013 M o ' O ! � r .. NOV 0 4 2013 AOGCC Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Re -Enter and Re -Drill 2L -322A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a permit to re-enter and sidetrack the 2L -322A producer well from the Tarn 2L drilling pad. This well, originally drilled in June 2011, had difficulties with higher than expected pore pressure and as a result was forced to temporarily abandon the well. The intended spud date for this well is February Is`, 2014 using Nabors 9ES. / On the original well a series of abandonment cement plugs were pumped in place to isolate the Bermuda Sand , (see attached). A retainer was set inside of the 10 %" surface casing lust above the shoe and cement was bullheaded in place with enough volume to cover the Campanian Sand just below the surface casing shoe. A 4'/" kill string was run into the well and the well freeze protected with diesel after which a dry hole tree was installed at surface securing the well. P7-0 a/G —/T -f When the Nabors 9ES rig moves onto 2L -322A, the proposed plan (under Sundry #313-552 approved 10/28/13) is to change over to drilling mud and pull out with the 4'/2" kill string. A 9 7/8" bit will be picked up and run in to drill out the retainer and shoe of the 10'/" surface casing. The well is then to be sidetracked just below the surface shoe and drilled to +/- 150 feet MD above the Bermuda Sand./An intermediate 7 5/8" casing will then be run and cemented in place top setting the Bermuda Formation. A 6'/z" bit will then be run, to drill the horizontal lateral portion of the well. Finally, a 4'/2" production liner, equipped with swell packers and frac sleeves will be run into the open hole for the lower completion and a 3 1/2" tubing assembly with be run for the upper completion. 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 drilling fluids program summary. 4. Abandonment Diagram and Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling / collision avoidance information as required by 20 ACC 25.05(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 Steve Shultz at 263-4864. Sincerely, A 4 - Chip Alvord CPAI Drilling Manager • Aion for Permit to Drill, Well 2L-322A Saved: 1-Nov-13 Permit It — Tarn Well 2L-322A (North) �•, �k Application for Permit to Drill Document axWell M o xi m i x 6 Well VQIu e Table of Contents 1. Well Name.................................................................................................................................3 Requirements of 20 AAC 25.005()9........................................................................................................................ 3 2. Location Summary...................................................................................................................3 Requirements of 20 AAC 25.005(c) (2)................................................................................................................... 3 Requirements of 20 AAC 25.050(b)........................................................................................................................ 3 3. Blowout Prevention Equipment Information........................................................................4 Requirements of 20 AAC 25.005(c) (3)................................................................................................................... 4 4. Drilling Hazards Information.................................................................................................4 Requirements o 20 AAC 25.005 (c)(4) 4 5. Procedure for Conducting Formation Integrity Tests .........................................................5 Requirements of 20 AAC 25.005 (c)(5) 5 6. Casing and Cementing Program............................................................................................5 Requirements of 20 AAC 25.005(c)(6)................................................................................................................... 5 7. Diverter System Information..................................................................................................5 Requirements o 20 AAC 25.005 c 7 5 8. Drilling Fluid Program............................................................................................................6 Requirements o 20 AAC 25.005 c 8 6 9. Abnormally Pressured Formation Information....................................................................6 Requirements o 20 AAC 25.005 (c)(9) 6 10. Seismic Analysis.......................................................................................................................6 Requirements of 20 AAC 25.005 (c)(10)................................................................................................................ 6 11. Seabed Condition Analysis......................................................................................................6 Requirements of 20 AAC 25.005 (c)(11)................................................................................................................ 6 12. Evidence of Bonding................................................................................................................6 Requirements of 20 AAC 25.005 (c)(12)................................................................................................................ 6 13. Proposed Drilling Program.....................................................................................................7 Requirements of 20 AAC 25.005 (c)(13)................................................................................................................ 7 2L -322A APD Page 1 of 13 Printed: 1 -Nov -13 • A ion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.......................................8 Requirements of 20 AAC 25.005 (c)(14)................................................................................................................ 8 15. Attachments..............................................................................................................................8 AttachmentI Drilling Hazards.............................................................................................................................. 8 Attachment 2 Temporary Abandoment................................................................................................................... 8 Attachment3 Well Schematic................................................................................................................................. 8 Attachment 4 Planned Mud Weight Curve............................................................................................................. 8 Attachment 5 Cement Summary.............................................................................................................................. 8 Attachment 6 Directional Plan............................................................................................................................... 8 2L -322A APD Page 2 of 13 Printed. 1 -Nov -13 0 R I Ation for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L 322A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; This well is a redrill of the original 2L -322A which experienced problems in 2011 while drilling into the Bermuda Formation. Due to high gas content and bouts of lost circulation, it was deemed prudent to temporarily abandon the well. The well has several plugs in open hole and a final plug which was squeezed away from the existing 10 3/4" surface casing shoe. This permit requests permission to redrill the well from the existing 10 3/4" surface casing. Location at Surface 209' FNL, 821' FEL, Sec 22, T10N, R7E, UM NAD 1927 Northings: 5, 927, 637.8 Eastings: 460, 829.4 RKB Elevation 154.8' AMSL Pad Elevation 114.8' AMSL Location of 10 3/4" Casing Shoe 1091' FNL, 1046 FEL. Sec 22, TION, RM, UM NAD 1927 Northings : 5,926,756 6 Eastings: 460, 601.6 Measured Depth, RKB: 2,613' Total Vertical Depth, RKB: 2,360' Total Vertical Depth, SS. 2.205' Location of 7 5/8" Casing Shoe (Top Set the Bermuda) 1777.9' FSL, 1022.5 FEL. Sec 22, TION, RM, UM NAD 1927 Northings: 5, 924, 345.6 Eastings: 460, 616.2 Measured Depth, RKB: 6,250' Total Vertical Depth, RKB: 5,037' Total Vertical Depth, SS. 4,882' Location at Heal of Horizontal Interval Bermuda) 952.2' FSL, 984.5' FEL, Sec 22, TION, R713, UM Nad 1927 Northings: 5,923,519.9 Eastings: 460,651.2 Measured Depth, RKB: 7,105' Total Vertical Depth, RKB: 5,227' Total Vertical Depth, SS. 5,072' Location at Toe of Horizontal Interval 1,494' FNL, 879' FEL, Sec 27, TION, RM, UM Nad 1927 Northings: 5, 921, 072.9 Eastings: 460, 748.1 Measured Depth, RKB: 9,554' Total Vertical Depth, RKB: 5,23 1' Total Vertical Depth, SS. 5,077' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must �I , 0 !r1j{ b � I� 2L -322A APD Page 3 of 13 Printed: 1 -Nov -13 • Aion for Permit to Drill, Well 2L -322A tA Saved: 1 -Nov -13 (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient, The bottom hole pressures from the 2L-322A's offset wells are: Well Type SBHP MW Distance Direction Shut in Time 2L-309 Producer 1,228 psi 4.6 ppg 2,689' E/NE 148 hrs 2L-325 Producer 1,418 psi 5.1 ppg 3,386' E 920 hrs 2L-327 Producer 1,159 psi 4.0 ppg 3,724' E/NE 69 his 2L -329A Injector 3,291 psi 11.4 ppg 4,286' N 32760 hrs Given the above range of pressures for the nearest wells, 2L -322A is expected to have a BHP pressure of +/-3000 psi at the reservoir depth of 5,226' TVD. This was observed while drilling the original well. Equivalent Mud Weight @ TD = 3,000 / (5,226*..052) =w11.00pppg = 0.574 psi/ft_y The maximum potential surface pressure (MPSP) while drilling 2L-322 is calculated using the observed mud weights used to drill the original well in 2011. The Bermuda formation was drilled from top to bottom with 10.0 ppg water base mud. The gas content increased as drilling progressed but there no indication of the well flowing. To bring the gas content down the mud weight was raised incrementally to 11.2 ppg. Due to formations above the Bermuda (Campanian and Iceberg) being open, lost circulation occurred along with the breathing phenomenon while raising the mud weight. The mud weight continued to be increased incrementally to 11.8 ppg with losses becoming significantly more and breathing more pronounced. It was then deemed that the mud losses and the breathing complicated the gas issue with open formations above, and it was our decision to temporarily abandon the well. Therefore, we would like to re -drill with 11.2 ppg water base mud from our top set of the 7 5/8" casing (Campanian and Iceberg behind pipe) and keep our ECD's low as possible for drilling this hole section. In the event we would have to weight up to 11.8 ppg the MPSP would be as follows. MPSP = (5,226 ft TVD)*(.052)*(11.8) - (5,226 ft TVD *.I (gas gradient)) Stix = 2,684 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. Any gas seen on the original well is residual gas from MI injection from other wells and 2L -322A APD Page 4 of 13 Printed: 1 -Nov -13 • A ion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensityfor differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.03069,- Drill 5.030(%);Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission.Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified to the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of arry slotted liner, pre perforated liner, or screen to be installed; Casin and Cementing Program Hole TOP Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) in Ib/ft Grade Conn. (ft) ft ft Cement Program Driven 16 24 164.8 B-35 Welded 120' Surf 120'/ 120' Casing cemented to surface with 319 bbls of 11.0 ppg lead Cement followed 10-3/4 13-1/2 45.5 L-80 BTC 2,573' Surf 2,613'/ 2,358' by 114 bbls of 12.0 ppg tail cement had 83 bbls of cement returns to surface TOC @ 4,019' MD / 3441' 7-5/8 97/8- 29.7 & L-80 & HydrilTheoretical 6,222' Surf 6,250'/ 5,037' TVD. Cemented w/ 39.0 TN -110 563 422 sx GasBLOK Class "G" 15.8 ppg 4 1/2" 6 1/2" ppb L-80 MBT 3,454' 6,100%4,966' 9,554%5,231' Cementing liner with 96 sx of Class "G" 15.8 ppg to liner top "See attached" 6. Diverter System Information Requirements of 20 AAC 25.005(c) (7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Nabors 9ES. / 2L -322A APD Page 5 of 13 Printed: 1 -Nov -13 C A ion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Intermediate WBM 2,613'— 6,250 ' Density (ppg) 9.4-10.0 Yield Point (cP) 20-28 pH 9.5-10.5 Plastic Viscosity (lb/100 st) 16-20 API Filtrate (cc) 4-6 Solids (%) 6-7 Production WBM 6,250'— 9,553" Density (ppg) 11.2 Yield Point (CP) 18-28 HTHP Fluid Loss (m1130min) < 5 Plastic Viscosity 16-20 pH 9.5-10.5 Diagram of Nabors 9ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.03369; N/A - Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) fora well drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A - Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding)have been met; Evidence of bonding for Conoco Phillips Alaska, Inc. is on file with the Commission. 2L -322A APD Page 6 of 13 R I N ,1�� I Printed: 1 -Nov -13 0 Aion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. Rig Operations Summary 1. MIRU Nabors 9ES onto 2L -322A. Notify AOGCC Field inspector 24 hours prior to BOPE test. 2. Circulate diesel freeze protect out of the 10 %" surface casing through the 4 %" kill string, with drilling mud 3. Set BPV and ND tree and NU up 13-5/8" 5M BOPE and test to 250/3500 psi. 4. Pull & lay down 4-1/2" tubing kill string (1826' MD). 5. MU 6 %" BHA with a 9 7/8" bit and directional assembly 6. Run in hole to retainer at 2,531' MD, pressure test 10 %" casing to 3500 psi for 30 minutes 7. Drill out retainer and continue cleanout to the 10 %" casing shoe at 2,613'MD, drill an additional 20' and perform LOT 8. Continued drilling and attempt to sidetrack well, do not go below 2,850'MD if unable to sidetrack a. If successful in sidetracking, POOH and PU directional BHA with a PCD bit and go to step 14. b. If unsuccessful proceed with cement plug for sidetrack and go to step 9. 9. POOH and and LD directional tools and PU 450 feet of 3 %" stinger with the 5" drill pipe 10. RIH with stinger to 2850' and circulate 11. RU cementers and spot a 17.0 ppg Class "G" cement plug from 2,850' to inside shoe of the 10 %" casing 12. POOH with drill pipe and stinger, lay down same P. 13. P/U 9 7/8" bit and directional drilling BHA and RIH. Tag TOC, drillout and side track well � 14. Continue drilling to 6,238' MD 5,025 TVD for the 7 5/8" intermediate casing point` 15. Run 7 5/8" 29.7# & 39#, L-80 & TN -110, Buttress and Hydril 563 casing to TD and land on mandrel in wellhead. 16. Pump cement job placing cement top 500'+ above Iceberg formation. 17. PU and RIH with a 6 %" bit and 4 %" directional assembly and weight up to 11.2 ppg. 18. Control drill the 6 %" hole section to +/-9,542' MD / 5,220' TVD. 19. Run 4-1/2", 9.3#, L-80, IBTM Bonzai completion with 6 swell packers and 6 frac sleeves. Liner top placed at +/- 6,088' MD 4955' TVD allowing for 150' of overlap in the 7 5/8" casing. (See diagram) 20. Once liner is on bottom circulate and condition mud and prepare for the Bonzai cementing operation 21. Pressure up on drill pipe and set Flex -Lok liner hanger, slack off 30K to ensure liner hanger has set 22. Continue to pressure up to release the liner running tool, pick up on drill pipe to confirm running tool is free. 23. Place fillup tool on depth and inflate the ECP (external casing packer) positioned below the top of the Bermuda Sand. 24. Open the cementing stage tool just above the ECP with additional pressure 25. Pump liner cement job with 15.8 ppg Class "G" slurry and 40% excess in open hole which will bring the top of cement above the liner top 0 I I b", !t L 2L -322A APD Page 7 of 13 Printed: 1 -Nov -13 4 Aion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 26. Without bleeding off pressure, pick up on drill string and close stage tool, reverse out excess cement 27. Set down on drill string to set liner top packer and test 28. POOH with liner running tool 29. Run 3-1/2" tubing upper completion (see diagram). Circulate around with brine and set production packer 30. Secure well, RDMO. 31. 2L -322A will be fracture stimulated after RDMO. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II '/ disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility/for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 14. Attachments Attachment 1 Drilling Hazards Summary Attachment 2 Temporary Abandonment Attachment 3 Well Schematic Attachment 4 Planned Mud Weight Curve Attachment 5 Cement Summary Attachment 6 Directional Plan 2L -322A APD Page 8 of 13 Printed: 1 -Nov -13 0 A ion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 Attachment 1 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) Risk Description Mitigation Stuck 7" Casing Cutting & Pulling 7" casing Utilize 2 -cut method Lost Circulation Lost circulation possible Reduced pump rates, trip Zones speeds, real time PWD monitoring, mud rheology, LCM addition Shallow Gas Watch for gas when Drill the intervals with caution approaching the Campanian and prepare to weight up. and Iceberg Sands Make frequent flow checks to verify static prior to POOH. Barite Sag Settling or stratification of Close attention to mud barite in a drilling fluid properties and drilling resulting in a density gradient operations to minimize sag. Swab/Surge Multiple BHA & tripping runs Reduced tripping speeds, mud properties, proper hole filling practices, pumping out of hole, real time ECD, weighted sweeps Abnormal Reservoir Drilling into an injection The 7 5/8" intermediate casing Pressure conduit is being top set just above the Bermuda Sand for well control and 11.2 ppg water base mud is to be used on this re -drill 2L -322A APD Page 9 of 13 Printed: 1 -Nov -13 0 R, 1 G@hd_ 0 Temporary Abandoment y. KUP ConocoPhillips weft Attributes Ala ka,In, 175'01-03-2=00 venhre APvuwt Tiele Name 551032062800 TARN PARTI„IPATANG AREA SSSV: NONE amm•.. c•a�em v.;v, aMsaer. a.er Ap91 ion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 2L-322 I _ IK40.I Weldl m Mar ��16g Comment w onl tpKER Hagerfi up 3.98[ l7w) MKeI —"'P0- akin DMe_ commael Blov, down Tap drive liner Make up Hand pin arM 2.580.4 Squeeze Cement 51V2011 with Rati inel cement lines. RU Schlumberger. Pick up out of relainer. Circulate at 5 BPM -260 PSI, Observed 900 units of gas. Sling into retehrer. Establish Injection rate at 3 BPM -650 PSI. Tum over to Schlumbeygef. Pump 5 BBLS of 12.5 PPG Mud Push. Pressure test tines to 3000 PSI. Pump 45 BBLS of cement, and 4 BBLS of H2O. Willi Rig Displace Will 36 BBLS m 11.6 PPG mud. Pull stinger and pump to leave 5 BBLS of cement above reattrap. POOH 10 2315' MD. Ckculale bolt"' up s16 BPM -230 PSI, observing no -mem returns. Mix d pump 15 BBLS dry job. CAP r�D 1690 HAS __— l,725.1 $ emrrd r9 1 011 With dO - Pun. 50 hl PHI, add 20 BnLS of W 11.9 mod. Tum over w Schlumberger 6 continue with15 BBLS of 12.5 Mud Push It Test lines to 3000 PSI. Goad test. Pump 95 BBLS of 15.8 PPG cement, and 4 BBLS of H2O. Drop Dill pipe wiper bag. With N. displace cement with 70 BBLS, Observed 47 BBLS pumped before catching coment. Observed i wr 1 returns during job. Max Gas observed . 3800 units. CIP at 20:45 FIRS. POOH slow from, 5630' -4250MD, ob.-Ang no D— on annulus from well, agowing cemenl to fab out of DP unto annulus Haying atafic. UP WT -165K, SO i WT - 140K. 5,046.2 Fhsl Plug 4282011 WMrig - Pump 5086E LCM pill, and 20 BBLS of 11.9 mud. Turn over w Schlumberger d continue vAth 15 BBLS of 12.5 Mud Push It. Test lines w 35W PSI. Good test Pump 89 BBLS of 16 PPG cement, end 2 BBLS ai H20. Drop Drill Pipe caper hall. With d9, displace cement vilh 75 BBLS, keepurg 1400 6 01 cement in OP. Wserved d7 88LS Vt+^ped before -thing cement. Ouse ,dld only 33 BBLS of reto. s during job. Mm Gas observed - 1250 units. CAP at 22:15 HRS. C 92011 Line up, and batch or .Pump 15 L of 12.5 PPG Place Mud Push II. Test lines to 3500 PSI. Continue pump 66.71 BBLS of 15.9 PPG GasBlok ceme^I chase -Ah 2 BBLS h20. Continue displace with 11.9 PPG MW for 115 BBLS, cementing drill eking in place at 7473' MD. Obsorved only 37 BBL returns dud -job. Max gas - 985 units. Shut Omer. CIP @T 0130 HRS. RD Lines. Sub Valve. n R I G I ,,1Y !,(i I--- 2L -322A APD Page 10 of 13 Printed.' 1 -Nov -13 Tarn 21--322 North (wp11) Rotary Sidetrack Tooset Bonsai Horizontal Multi -Stage Frac'd Producer Proposed Wellbore Schematic Ap ion for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 ConocoPhillips Gen V Tem ora FMC 1 OK tree / DSA 4-1W' tree, top 100' is 4-1/V 12.6# IBTM, crossed over to match current wellhead 16" Existina Cemented Conductor: 16" 62.6# H-40 Bearden 10/13/13 146' MD 3 s" Cameo Da Nipple 2.876" 600'MD 3 v," Camc, MM Existing Surface Casina: 10-3/4" 45.5# L-80 BTC 2,613' MD / 2,358' TVD 9 39° 3'/." Cameo MMS Sidetrack KOP off Cement plug @ 39 degrees in open hole @ 2,700' MD S:YYD':� �: Fsactiire Cirac�ieitt: T3oiia: t-: 3'/a"Cameo MMO Tubing' 3-1/2" 9.3# L-80 EUE8RD L.SNO 5.8 — 10.0 PPG Keep up with TOC 15.8 ppg @+/-4,505' MD 9-7/8" Intermediate Hole Dilution (500'aboveIceberg) 3 Y" Camoo MMG ::ICeli2ig;To{i5:166';ICI{f?(a,3ai•;Y�q .•.,.,. .....•.,...•.•.•. . �factUr Ci'a •t��1z••• •:: Baker CMU Sliding Sleeve CLOSED w/ 2.813' 3.5"x75/8', Baker Premier PackerXXXXMD Cameo X Profile 10' above production packer 7-5/8" x 3=f.' Baker Flex Lock Liner hanger ZXP liner top packer 3'." Cameo D Nipple 2.76" nog, w/ RS Nipple, %XXX' MD Intermediate Casing Tooset with Sonzai: 29.7# L-80 & 500' TN110SS 39# - all Hydril 563 connections 6,250' MD / 5,03T TVD @ 64D To of Bermuda 6583 MD 5 155 ND :•:4i3''S`bei ParolSers:•:•:•:•:•:':':•:':':':':':':':':' :g 'e'a ' I PratwgtioiTkrole: iji.i.:.:.[.[.[.[ [.... :' ::[:[[:[:i:i:, o 0 0 0 0 .. :paYzolie:F�C;R fi�cka[; ;;;;;;;;;;;;;;;;;;;;; :; . . . . . . . . . . . . . . . .... s 4 e..... . Base Bermuda 7,090' MD 5,258•TVD Production Liner (a) 90-: 4-1/2" 12.6# IBTM Perforated Pup 6,100' MD to 9,554' MD 4,966' TVD to 5,232' TVD 2L -322A APD Page 11 of 13 Printed: 1 -Nov -13 0 R11 I C "'ll 11'�' 12 11 W e i 10 9 h t p p 8 9 8 2600 0 Mud Curve for 2L -322A Apion for Permit to Drill, Well 2L -322A 0 Saved: 1 -Nov -13 3600 4600 5600 6600 7600 8600 9600 Depth MD -322A Cementing Program: J, RI 1 Cj 11 -1�11 ,I 2L -322A APD Page 12 of 13 Printed: 1 -Nov -13 0 2L -322A Cementing Program: Surface Kick Off Plug AID on for Permit to Drill, Well 2L -322A Saved: 1 -Nov -13 Cement from 2850' MD to 2500' MD with Class G + Additives @ 17 PPG Slurry: (2850'-2500') X 0.532 ft3/ft X 1.5 (50% excess) = 280 ft3 Total Volume = 280 ft3 => 239 sx @ 1.17 ft3/sk System: 239 Class "G" @ 17.0 PPG yielding 1.15 ft3/sk, Class G +.2% BWOC D046 (Antifoamer) +.2% BWOC D167 (Fluid Loss) + 1 % BWOC D065 (Dispersant) 7-5/8" Intermediate Casing run to 6,238' MD / 5,025' TVD Cement with 15.8 ppg Class "G" from 7 5/8" shoe @ 6,238'MD, Top of Iceberg Formation at 5,154'MD which will require cement to at least 4,654'MD, with gauge hole and calculated excess theoretical TOC would be at 4,019' MD . Using 40% excess annular volume. Lead: (6,238ft- 4654ft) X 0.215 ft3/ft X 1.4 (40% excess) = 477 ft3 annular vol. 477 ft3+ 17 ft3 (shoe track)=494 ft3 Total Volume = 494 ft3 => 422 Sk @ 1.17 ft3/sk System: 422 Sx Class "G", +.40 gal/sk of cement D047 (Antifoam) +.40% BWOC D065 Dispersant, 2.0 gal/sk of cement D600G GASBLOK,+ .010 gal/sk of cement D177 Retarder 4 %" X 6 %" Bonzai Cement Operation: Cement with 15.8ppg Class "G" from the diverter tool (6,582'MD) in the 4 '/2" liner to the 4 '/2" liner top (6,088'MD). With 40% excess TOC should be at 5,918'MD prior to reversing out Lead: (6,582'-6,088') X 0.138 ft3/ft X 1.4 (40% excess) = 95.4 ft3 annular vol. 95.4 ft3 +16.8 16.8 ft3 (under displacement)=112.2 ft3 Total Volume = 112.2 ft3 => 96 Sk @ 1.17 ft3/sk System: 96 sx Class "G", +.40 gal/sk of cement D047 (Antifoam) +.40% BWOC D065 Dispersant +2.0 gal./sk of cement D600G (GASBLOK) + .01 gal.sk of cement D177 (Retarder) 2L -322A APD Page 13 of 13 Printed: 1 -Nov -13 I1 k-. ., ^ ., 2L-322Awpl2 6.161 Plan Summary ` SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 88.00 993.00 21--322 Gyro (R100) (2L-322) CB -GYRO -SS 1040.23 2559.43 21--322 MWD (R100) (2L-322) MWD+IFR-AK-CAZ-SC 2601.31 2688.00 21--322 MWD (R200) (2L-322) MWD+IFR-AK-CAZ-SC 2688.00 6237.75 2L-322Awp12 (Plan: 2L -322A) MWD+IFR-AK-CAZ-SC 6237.75 9542.18 2L-322Aw 12 Plan: 2L -322A MWD+IFR-AK-CAZ-SC I CASING DETAILS TVD MD Name Size 2345.53 2601.31 10-3/4" x 13-1/2" 10-3/4 5024.80 6237.75 7-5/8" X 9-7/8" 7-5/8 5219.80 9542.18 4-1/2" x 6-1/2" 4-1/2 0 0° CSG_Topset TOP -BERM 10-3/4" x 13-1/2" 5 C-80 T-4.1 T-3.1 TOP_BERM_SEIS 5 ZYj0�000 '' �� `. �� ` o 90 d CAMP SST T-7_ ,' - �, N 000 7-5/8"X9-7/8" 9 C i� C-37 / Ice erg cC1400 ' 0, i 4-1/2" x 6-1/2" M C-40 500 C 50 L7-5' 7-5/8"X J711 o n 0 0 0 2500 5000 7500 10000 0 900 1800 2700 3600 4500 5400 6300 10-3/4" x 13-1/2" Horizontal Departure Measured Depth C300----- o 2 330 30 2W'.... = z woo al CL . ... 300 .-' .. '•' a000 azuo so azoo - zmo - N- xoa N Z 150 87 270 888 90 C) .2 ,.. C 240 .- •,.,, .,,, ... 120 - �ao - 0 210. .... __• '. .150 wo 7 e000 3000 3500 4000 4500 5000 5500 6000 6500 7000 001 180 - SECTION DETAILS Sec MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLeg TFace VSec Target 24 1 2688.00 39.12 197.84 2412.82 2270.02 -930.78 -240.44 5926457.57 1600617.84 0.00 0.00 921.83 25628 6Z 2 2738.00 40.48 196.86 2451.24 2308.44 -961.33 -249.98 5926427.07 1600608.14 3.00 -25.00 952.02 3 3380.84 39.29 176.83 2946.56 2803.76 -1365.95 -299.46 5926022.76 1600556.54 2.00-102.96 1354.67 4 5406.49 39.29 176.83 4514.31 4371.51 -2646.73 -228.62 5924741.76 1600620.67 0.00 0.00 2637.14 5 7093.01 89.88 177.43 5214.80 5072.00 -4119.27 -156.56 5923269.00 1600685.00 3.00 0.77 4111.30 21--322 EB 22Aug13 Heel 6 9542.18 89.88 177.43 5219.80 5077.00 -6565.97 -46.74 5920822.00 1600782.00 0.00 0.00 6560.34 21--322 EB 22Aug13 Toe CAMP -SST 3642.8 C-50 4072.8 C-40 4318.8 C-37 / Iceberg 4717.8 T-7 -T 49 1 Rename the well to 2L -322A. Change RKB from Doyon 15 to Nabors 50 9ES. Change intermediate casinq depth. rTopset Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2012 Magnetic Model Date: 17 -Oct -13 T Depth Reference: Plan: 114.8+28 @ 142.80ft (Nabors 9ES) System SS Reference: Mean Sea Level Y ( ) Magnetic Declination: a True To convert a Magnetic Direction to a True Direction, Add 19.44° East North / Y: 5927386.99 Ground Level /Mud Line: 114.80 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference East / X: 1600863.13 Rig: Nabors 9ES k-. ., ^ ., S I Chlumbepuep s ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad 2L-322 (North) Plan: 2L -322A Plan: 2L-322Awp12 Plan Summary 17 October, 2013 onocoPhilli ► Schlumberger Schlumberger Plan Summary CotIOCOPhilfip5 ConocoPhilkps (Alaska) Inc. -Kup2 ie IllaWence: Well 2L-322 (North) F, 'Kuparuk River Unit �, �. Plan. 114.8+28 @ 142.80ft (Nabors 9ES) Kuparuk2LPad Plan: 114.8+28@ 142.80ft (Nabors 9ES) A p 2L322 (North) #��b True x "I Plan: 2L -322A � r. Minimum Curvature 2L-322Awp12 ? EDM v16 Prod ` Kuparuk River Unit, North 31ope 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 �a Kuparuk 2L Pad Site Position: Northing: 5,927,444.35 ft Latitude: 70° 12'47.137 N From: Map Easting: 1,601,111.65 ft Longitude: 1500 19' 1.199 W Position Uncertainty: 0.00ft Slot Radius: 0.1 Grid Convergence: -0.30 ° Well 2L322 (North) +.. Well Position +N/ -S 0.00ft Northing: 5,927,386.99 It Latitude: 70° 12'46.560 N +E/ -W 0.00ft Easting: 1,60Q863.13ft Longitude: 150'19'8.406W Position Uncertainty 0.00ft Wellhead Elevation: ft Ground Level: 114.80ft 10/17/2013 3:45:OOPM Page 2 COMPASS 2003.16 Build 69 LO N 01 C 0 0 z 0 Kuparuk 2L Pad ?9 2L-322 2L-326 2L-322Awp12 Easting (2500 Win) 2N-316 2N-315 2N-308 rws su5t Tam 3A 2N-307 -318 2N-313 2N-311 2 3 A 2N -311A `2NN 321 2N-32 \ C 2Al 1) 0 14PB1 (wp06a) 2L-306PB1 \V 2L-308PB1 (wp02) 2L-319 V 2L-308wp03 [ L-310 Z O 2L-311 2L-304 E m N cnO 1 2L-320 B2 2L- 7 - 320 B1 L -311A (wpOt) 2L-301 2L-302 (wp 1) L-323 2L -317A 325 \ 2L-320 2L-302 (wp01) \\\` 2L-321 2L-330 -247309 2N-301(wp03) 2N-322 (wp06) 2L-32PB1(wp03) 3 2 2N-301PB1 (WP03) 2N-322PB1 (wp06) 2L-328 (wp03) f [ 2N-304PB1 - 2N-312 (wp02) Easting (2500 ft/in) 0 V r- I !", ! , 1 ! 't U" L z It, � A 2L-322Awpl2 Plan View - o 7000 2000 3000 10-3/4" x 13-1/2" -1500- 4000 0 5000 LO ,3000 6000 Y ___- 7-5/8" X 9-7/8" 0 z 7000 04500 Ln 22 2L 3 8000 -6000 9000 2L 322Awp12--------- X42---- 4-1/2" x 6-1/2" -7500 -6000 -4500 -3000 -1500 0 1500 3000 4500 6000 West( -)/East(+) (1500 Win) 0 9 2L-322Awp12 Section View 0 850 1p00 1700 °°° c `L 10-3/4" x 13-1/2" a 2550 0 U 3400 N 4250 7-5/8" X 9-7/8" N M 4-1/2" x 6-1/2" O N O 0o O CO 0) 0)CD 0 5100 0 850 1700 2550 3400 N 4250 M 5100 5950 6800 J Vertical Section at 178.00° (850 ft/in) N mumbepgop Schlumberger ;, , Plan Summary COriOCOPINIlipS , Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk2LPad �14t2 Well: 2L-322 (North) iftf8 Wellbore: Plan: 2L -322A Design: 2L-322Awp12 Survey Tool Program Date 10/17/2013 From To R; (ft) (ft) Survey (Wellbore) Tool Name Description 88.00 993.00 2L-322 Gyro (R100) (2L-322) CB -GYRO -SS Camera based gyro single shot 1,040.23 2,559.43 21--322 MWD (R100) (2L-322) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,601.31 2,688.00 2L-322 MWD (R200) (2L-322) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,688.00 6,237.75 2L-322Awp12 (Plan: 2L -322A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,237.75 9,542.18 2L-322Awp12 (Plan: 2L -322A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey ,ems �'Lat. MD Inc Azi TVD TVDSS DLeg TFace Northing Easting Error Vert. Error " (ft) (1) (°) (ft).. (ft) (°/100ft) (°) (ft) (ft) (ft) (ft) 2,688.00 39.12 197.84 2,412.82 2,270.02 0.39 78.74 5,926,457.57 1,600,617.84 5.19 1.69 PP, DLS 3.00 TFO -25.00 2,700.00 39.44 197.60 2,422.11 2,279.31 3.00 -25.00 5,926,450.35 1,600,615.49 5.21 1.69 2,734.80 40.39 196.92 i 2,448.80 2,306.00 3.00 -24.81 5,926,429.06 1,60Q608.75 5.21 1.69 C-80.. 2,738.00 40.48 196.86 2,451.24 2,308.44 3.00 -24.30 5,926,427.07 1,600,608.14 5.26 1.69 Start DLS 2.00 TFO -102.96 2,800.00 40.22 194.99 2,498.49 2,355.69 2.00 -102.96 5,926,388.54 1,600,596.92 5.35 1.69 2,805.65 40.20 194.82 2,502.80 2,360.00 2.00 -101.53 5,926,385.02 1,600,595.97 5.35 1.69 i CAMP SST 2,900.00 39.86 191.93 2,575.06 2,432.26 2.00 -101.40 5926,326,08 1,600,581.62 5.49 1.71 3,000.00 39.58 188.83 2,651.98 2,509.18 2.00 -99.19 5,926,263.31 1,600,569.78 5.65 1.73 3,100.00 39.38 185.70 2,729.17 2,586.37 2.00 -96.81 5,926,200.30 1,600,561.41 5.81 1.75 3,200.00 39.27 182.55 2,806.53 2,663.73 2.00 -94.39 5,926,137.14 1,600,556.52 5.98 1.78 3,300.00 39.25 179.39 2,883.97 2,741.17 2.00 -91.95 5,926,073.89 1,600,555.12 6.15 1.81 3,380.84 39.29 176.83 2,946.56 2,803.76 2.00 -89.51 5,926,022.76 1,600,556.54 6.29 1.84 2025.65 hold at 3380.84 MD _Start 3,400.00 39.29 176.83 2,961.39 2,818.59 0.00 0.00 5,926,010.64 1,600,557.15 6.33 1.85 3,500.00 39.29 176.83 3,038.78 2,895.98 0.00 0.00 5,925,947.40 1,600,560.31 6.51 1.89 3,600.00 39.29 176.83 3,116.18 2,973.38 0.00 0.00 5,925,884.16 1,600,563.48 6.72 1.93 10/17/2013 3:45:00PM Page 3 COMPASS 2003.16 Build 69 E TFace Schlumberger;.N Inc Schlumbep9ep Plan Summary � c�llips Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2L-322 (North) Project: Kuparuk River Unit TVD Reference: Plan: 114.8+28 @ 142.80ft (Nabors 9ES) Site: Kuparuk 2L Pad MD Reference: Plan: 114.8+28 @ 142.80ft (Nabors 9ES) Well: 2L-322 (North) North Reference:. True Wellbore: Plan: 2L -322A Survey Calculation Method: Minimum Curvature Design: 2L-322Awp12 Database: EDM v16 Prod Planned Survey 3,270.97 3,128.17 TFace MD Inc Azi TVD TVDSS DLeg (ft) (ft) (°) (°) (ft) (ft) (°MOOft) 1.98 3,700.00 39.29 176.83 3,193.57 3,050.77 0.00 5,925,694.45 3,800.00 39.29 176.83 3,270.97 3,128.17 0.00 7.68 3,900.00 39.29 176.83 3,348.36 3,205.56 0.00 0.00 4,000.00 39.29 176.83 3,425.76 3,282.96 0.00 1,600,585.02 4,100.00 39.29 176.83 3,503.15 3,360.35 0.00 2.32 4,200.00 39.29 176.83 3,580.55 3,437.75 0.00 5,925,315.01 4,280.43 39.29 176.83 3,642.80 3,500.00 0.00 9.46 C-50 0.00 5,925,188.53 1,600,598.30 9.78 2.60 0.00 4,300.00 39.29 176.83 3,657.94 3,515.14 0.00 1,600,602.61 4,400.00 39.29 176.83 3,735.34 3,592.54 0.00 2.74 4,500.00 39.29 176.83 3,812.73 3,669.93 0.00 5,924,935.58 4,600.00 39.29 176.83 3,890.13 3,747.33 0.00 11.12 4,700.00 39.29 176.83 3,967.52 3,824.72 0.00 0.00 4,800.00 39.29 176.83 4,044.92 3,902.12 0.00 1,600,620.46 4,836.02 39.29 176.83 4,072.80 3,930.00 0.00 3.14 C-40 4,900.00 39.29 176.83 4,122.32 3,979.52 0.00 5,000.00 39.29 176.83 4,199.71 4,056.91 0.00 5,100.00 39.29 176.83 4,277.11 4,134.31 0.00 5,153.87 39.29 176.83 4,318.80 4,176.00 0.00 C-37 t Iceberg 5,200.00 39.29 176.83 4,354.50 4,211.70 0.00 5,300.00 39.29 176.83 4,431.90 4,289.10 0.00 5,400.00 39.29 176.83 4,509.29 4,366.49 0.00 5,406.49 39.29 176.83 4,514.31 4,371.51 0.00 Start DLS 3.00 TFO 0,77 5,500.00 42.10 176.89 4,585.21 4,442.41 3.00 TFace Northing Easting Lat. Error Vert. Error (°) (ft) (ft) (ft) (ft) 0.00 5,925,820.92 1,600,566.65 6.94 1.98 0.00 5,925,757.68 1,600,569.81 7.17 2.03 0.00 5,925,694.45 1,600,572.98 7.42 2.08 0.00 5,925,631.21 1,600,576.14 7.68 2.14 0.00 5,925,567.97 1,600,579.31 7.96 2.20 0.00 5,925,504.73 1,600,582.47 8.24 2.26 0.00 5,925,453.86 1,600,585.02 8.24 2.26 0.00 5,925,441.49 1,600,585.64 8.53 2.32 0.00 5,925,378.25 1,600,588.81 8.84 2.39 0.00 5,925,315.01 1,600,591.97 9.15 2.46 0.00 5,925,251.77 1,600,595.14 9.46 2.53 0.00 5,925,188.53 1,600,598.30 9.78 2.60 0.00 5,925,125.29 1,600,601.47 10.11 2.67 0.00 5,925,102.51 1,600,602.61 10.11 2.67 0.00 5,925,062.06 1,600,604.64 10.44 2.74 0.00 5,924,998.82 1,600,607.80 10.78 2.82 0.00 5,924,935.58 1,600,610.97 11.12 2.89 0.00 5,924,901.51 1,600,612.67 11.12 2.89 0.00 5,924,872.34 1,600,614.13 11.47 2.97 0.00 5,924,809.10 1,600,617.30 11.82 3.05 0.00 5,924,745.86 1,600,620.46 12.17 3.13 0.00 5,924,741.76 1,600,620.67 12.19 3.14 0.77 5,924,680.87 1,600,623.69 12.53 3.21 10/17/2013 3:45:OOPM Page 4 COMPASS 2003.16 Build 69 Schlumberger � schlumbopgop Plan Summary �. �ad�lfips ConocoPhillips(Alaska) Inc. Kup2. �e kAi$N2t 321ttitfilj KUparuk River Unit, '� Fiat . ' ' ;<' . Kuparuk 2L Pad . e F9rt1�1.iti(ttbQtS w4t, 2L-322 (North) N4isNbdl Plan: 2L -322A tJaain 2L-322Awp12 ' EOMs/i#iFhi e MD Inc c6 Ift) t`1; t°1 fftl eon7��i , .) 5,600.00 45.09 176.94 4,657.62 4,514.82 3.00 0.73 5,924,612.01 1,600,627.03 12.92 3.29 5,687.28 47.71 176.99 4,717.80 4,575.00 3.00 0.69 5,924,548.89 1,600,630.05 12.92 3.29 T-7 5,700.00 48.09 176.99 4,726.33 4,583.53 3.00 0.66 5,924,539.46 1,600,630.49 13.32 3.38 5,800.00 51.09 177.04 4,791.14 4,648.34 3.00 0.66 5,924,463.41 1,600,634.06 13.75 3.47 5,900.00 54.09 177.08 4,851.88 4,709.08 3.00 0.63 5,924,384.08 1,600,637.72 14.19 3.57 6,000.00 57.09 177.11 4,908.38 4,765.58 3.00 0.60 5,924,301.68 1,600,641.47 14.65 3.68 6,090.65 59.81 177.15 4,955.80 4,813.00 3.00 0.58 5,924,224.52 1,600,644.93 14.65 3.68 T-4,1 6,100.00 60.09 177.15 4,960.48 4,817.68 3.00 0.56 5,924,216.43 1,600,645.29 15.12 3.80 6,200.00 63.09 177.18 5,008.05 4,865.25 3.00 0.56 5,924,128.58 1,600,649.18 15.60 3.92 6,237.75 64.23 177.19 5,02.E0 4,882.00 3.00 0.55 5,924,094.78 1,600,650.66 15.60 3.92 CSt3. upset - 7-5/8" X 9-718" 6,300.00 66.09 177.21 5,050.95 4,908.15 3.00 0.54 5,924,038.35 1,600,653.12 15.95 3.90 6,400.00 69.09 177.24 5,089.06 4,946.26 3.00 0.53 5,923,946.01 1,600,657.10 16.18 3.90 6,436.62 70.19 177.25 5,101.80 4,959.00 3.00 0.52 5,923,911.71 1,600,658.57 16.18 3.90 T-3.1 6,500.00 72.09 177.27 5,122.28 4,979.48 3.00 0.52 5,923,851.79 1,600,661.12 16.42 3.91 6,570.80 74.22 177.29 5,142.80 5,000.00 3.00 0.51 5,923,784.10 1,600,663.98 16.42 3.91 TOP -BERM 6,600.00 75.09 177.30 5,150.53 5,007.73 3.00 0.51 5,923,755.97 1,600,665.16 16.69 3.93 6,695.61 77.96 177.33 5,172.80 5,030.00 3.00 0.51 5,923,663.09 1,600,669.03 16.69 3.93 TOP SEIS -BERM 6,700.00 78.09 177.33 5,173.71 5,030.91 3.00 0.50 5,923,658.80 1,600,669.20 16.97 3.95 6,800.00 81.09 177.35 5,191.77 5,048.97 3.00 0.50 5,923,560.55 1,600,673.25 17.27 3.99 6,900.00 84.09 177.38 5,204.66 5,061.86 3.00 0.49 5,923,461.49 1,600,677.29 17.58 4.03 7,000.00 87.09 177.41 5,212.35 5,069.55 3.00 0.49 5,923,361.89 1,600,681.30 17.91 4.08 COMPASS 2003.16 Build 69 10/17/2013 3:45:OOPM Page 5 9,100.00 9,200.00 89.88 177.43 5,219.10 5,076.30 0.00 0.00 Schlumberger 1,600,768.45 27.30 6.49 9,300.00 Schlambepp 177.43 5,219.311 5,076.51 0.00 0.00 5,921,063.96 1,600,772.41 Summary 9,400.00 Conoa;�hilfips C Company: onocoPhillips (Alaska) Inc. -Kup2 . ..... -o Local Coordinate Reference: Well 2L-322 (North) 5,920,964.05 1,600,776.37 Project: Kuparuk River Unit 9,500.00 89.88 TVD Reference: 5,219.71 Plan: Il 4.8+28 @ 142.80ft (Nabors 9ES) P� 0.00 Site: Kuparuk 2L Pad 5,920,864.14 1,600,780.33 28.78 6.92 MD Reference: Plan: 4.8+28 @ 142.80ft (Nabors 9ES) l Well: 2L-322 (North) North Reference: True Page 6 Wellbore: Plan: 2L -322A COMPASS 2003.16 Build 69 Survey Calculation Method; Minimum Curvature Design: 2L-322Awp12 Database: EDM v16 Prod Planned Survey MID Inc Azi TVD TVDSS DLeg TFace Northing Easting IN (1) V) (ft) (ft) (-/1 00ft) (ft) (ft) 7,093.01 89.88 177.43 5,214.80 5,072.00 3.00 0.49 5,923,269.00 1,600,685.00 18.23 4.14 Start 2449.17 hold at 7093.01 MD - 2L-322 EB 22Aug13 Heel 7,100.00 89.88 177.43 5,214.81 5,072.01 0.00 0.00 5,923,262.02 1,600,685.28 18.25 4.14 7,200.00 89.88 177.43 5,215.02 5,072.22 0.00 0.00 5,923,162.11 1,600,689.24 18.61 4.21 7,300.00 89.88 177.43 5,215.22 5,072.42 0.00 0.00 5,923,062.19 1,600,693.20 18.97 4.28 7,400.00 89.88 177.43 5,215.43 5,072.63 0.00 0.00 5,922,962.28 1,600,697.16 19.34 4.35 7,500.00 89.88 177.43 5,215.63 5,072.83 0.00 0.00 5,922,862.37 1,600,701.12 19.73 4.44 7,600.00 89.88 177.43 5,215.84 5,073.04 0.00 0.00 5,922,762.46 1,600,705.08 20.12 4.53 7,700.00 89.88 177.43 5,216.04 5,073.24 0.00 0.00 5,922,662.55 1,600,709.04 20.52 4.62 7,800.00 89.88 177.43 5,216.24 5,073.44 0.00 0.00 5,922,562.64 1,600,713.00 20.93 4.72 7,900.00 89.88 177.43 5,216.45 5,073.65 0.00 0.00 5,922,462.72 1,600,716.96 21.35 4.83 8,000.00 89.88 177.43 5,216.65 5.073.85 0.00 0.00 5,922,362.81 1,600,720.92 21.77 4.93 8,100.00 89.88 177.43 5,216.86 5,074.06 0.00 0.00 5,922,262.90 1,600,724.88 22.20 5.05 8,200.00 89.88 177.43 5,217.06 5,074.26 0.00 0.00 5,922,162.99 1,600,728.84 22.64 5.16 8,300.00 89.88 177.43 5,217.26 5,074.46 0.00 0.00 5,922,063.08 1,600,732.80 23.08 5.28 8,400.00 89.88 177.43 5,217.47 5,074.67 0.00 0.00 5,921,963.17 1,600,736.76 23.53 5.41 8,500.00 89.88 177.43 5,217.67 5.074.87 0.00 0.00 5,921,863.26 1,600,740.72 23.99 5.53 8,600.00 89.88 177.43 5,217.88 5,075.08 0.00 0.00 5,9211,763.34 1,600,744.68 24.45 5.66 8,700.00 89.88 177.43 5,218.08 5,075.28 0.00 0.00 5,921,663.43 1,600,748.65 24.91 5.79 8,800.00 89.88 177.43 5,218.28 5,075.48 0.00 0.00 5,921,563.52 1,600,752.61 25.38 5.93 8,900.00 89.88 177.43 5,218.49 5,075.69 0.00 0.00 5,921,463.61 1,600,756.57 25.86 6.06 9,000.00 89.88 177.43 5,218.69 5,075.89 0.00 0.00 5,921,363.70 1,600,760.53 26.33 6.20 89 88 177 43 5 21890 507610 000 000 5 921 263 79 1 600 764 49 26.82 6.34 9,100.00 9,200.00 89.88 177.43 5,219.10 5,076.30 0.00 0.00 5,921,163.88 1,600,768.45 27.30 6.49 9,300.00 89.88 177.43 5,219.311 5,076.51 0.00 0.00 5,921,063.96 1,600,772.41 27.79 6.63 9,400.00 89.88 177.43 5,219.51 5,076.71 0.00 0.00 5,920,964.05 1,600,776.37 28.28 6.78 9,500.00 89.88 177.43 5,219.71 5,076.91 0.00 0.00 5,920,864.14 1,600,780.33 28.78 6.92 1011712013 3:45:00PM Page 6 COMPASS 2003.16 Build 69 Targets Schlumberger Target Name scmumbopg8p hit/miss target Dip Angle Dip Dir. Plan Summary +N/ -S . COI1000pit1llip5 Com ConocoPhillips (Alaska) Inc. -Kup2 Easting LOcal Coordinate Reference: Well 2L-322 (North) Proje&° Kuparuk River Unit (ft) TVD Reference: Plan: 114.8+28 @ 142.80ft (Nabors 9ES) Site: Kuparuk 2L Pad 5,214.80 MD Reference:" Plan: 114.8+28 @ 142.80ft (Nabors 9ES) Well: 21--322 (North) 1,600,685.00 70'12'6.046N 150'19'12.948W North Reference: True 10-3/4 Wellbore: Plan 2L -322A Survey Calculation Method+ Minimum Curvature 7-5/8 Design: 2L-322Awp12 Databasg ��a EDM v16 Prod 21-322 EB 22Aug131 0.00 0.00 Planned Survey -6,565.97 -46.74 5,920,822.00 1,600,782.00 70° 11' 41.981 N 150° 19'9.761 W MD Inc Azi TVD TVDSS DLeg TFace Northing Easting Lat. Error Vert. Error (ft) (°) (°) (ft) (ft) (°I100ft) (°) (ft) (ft) (ft) ;(ft) 9,542.18 89.88 177.43 5,219.80 5,077.00 0.00 0.00 5,920,822.00 1,600,782.00 28.99 6.99 TD at 9542.18 - 2L322 EB 22Aug13 Toe Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2L-322 EB 22Aug131 0.00 0.00 5,214.80 -4,119.27 -156.56 5,923,269.00 1,600,685.00 70'12'6.046N 150'19'12.948W - plan hits target center 2,345.53 10-3/4" x 13-1/2" 10-3/4 13-1/2 6,237.75 Point 7-5/8 9-7/8 9,542.18 5,219.80 4-1/2" x 6-1/2" 21-322 EB 22Aug131 0.00 0.00 5,219.80 -6,565.97 -46.74 5,920,822.00 1,600,782.00 70° 11' 41.981 N 150° 19'9.761 W - plan hits target center - Point 10/17/2013 3:45:00PM Page 7 COMPASS 2003.16 Build 69 a Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft ) Name 2,601.31 2,345.53 10-3/4" x 13-1/2" 10-3/4 13-1/2 6,237.75 5,024.80 7-5/8" X 9-7/8" 7-5/8 9-7/8 9,542.18 5,219.80 4-1/2" x 6-1/2" 4-1/2 6-1/2 10/17/2013 3:45:00PM Page 7 COMPASS 2003.16 Build 69 a ScMumbepler Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site:Kuparuk 2L Pad Well: 2L-322 (North) Wellbore: Plan: 2L -322A Design: 2L-322Awp12 Formations Measured Vertical Depth Depth' (ft) (ft):. Name 2,805.65 2,502.80 CAMP SST 6,436.62 5,101.80 T-3.1 -240.44 5,153.87 4,318.80 C-37 / Iceberg 5,687.28 4,717.80 T-7 2,738.00 2,451.24 -961.33 6,090.65 4,955.80 T-4.1 Start DLS 2.00 TFO -102.96 4,836.02 4,072.80 C-40 6,570.80 5,142.80 TOP_BERM -299.46 2,734.80 2,448.80 C-80 6,695.61 5,172.80 TOP_BERM_SEIS 4,280.43 3,642.80 CSO -228.62 6,237.75 5,024.80 CSG_Topset 0 10/17/2013 3:45:OOPM Page 8 COMPASS 2003.16 Build 69 2,688.00 2,412.82 -930.78 -240.44 KOP: DLS 3.00 TFO -25.00 2,738.00 2,451.24 -961.33 -249.98 Start DLS 2.00 TFO -102.96 3,380.84 2,946.56 -1,365.95 -299.46 Start 2025.65 hold at 3380.84 MD 5,406.49 4,514.31 -2,646.73 -228.62 Start DLS 3.00 TFO 0.77 7,093.01 5,214.80 -4,119.27 -156.56 Start 2449.17 hold at 7093.01 MD 9,542.18 5,219.80 -6,565.97 -46.74 TD at 9542.18 Checked By: Approved By: Date: 10/17/2013 3:45:OOPM Page 8 COMPASS 2003.16 Build 69 0 0 Ferguson, Victoria L (DOA) From: Shultz, Steve (Orbis Engineering, Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Tuesday, December 10, 2013 10:31 AM To: Ferguson, Victoria L (DOA) Subject: RE: 2L-322A(PTD 213-167) Victoria, It should be in the body of the "Directional Planning Summary", about 18 pages back. If it isn't let me know and I'll get it right over to you. Since we will be drilling out of the surface casing shoe for the sidetrack the only close approach issue is the original well bore 2L-322PB which we will be diverging from and this should be a non -issue. Let me know if you can't find it. Thanks, Steve From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Tuesday, December 10, 2013 9:12 AM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]2L-322A(PTD 213-167) Steve, Was a proximity or anti -collision analysis complete? What were the results? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferguson@-alaska.gov Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering, Inc.) [Steve.Shultz@contractor.conocophillips.com] Sent: Tuesday, November 05, 2013 12:11 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2L -322A: Permit to Drill Application Patricia, We will be running all the logs on LWD and they will include: 9 7/8' hole- GR/Resistivity/Density/Neutron and PWD 6 %z" Hole- GR/Resitivity/Density/Neutron, Stethoscope, Periscope and PWD Steve From: Bettis, Patricia K (DOA) [ma iIto: patricia.bettis0alaska.gov] Sent: Tuesday, November 05, 2013 10:57 AM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]KRU 2L -322A: Permit to Drill Application Good morning Steve, What logs does ConocoPhillips plan to acquire in the intermediate and the production holes? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov. 0 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: KALL QL -- 4h PTD: C13) V � ✓ Development _ Service _Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: KLQc p K 21'VLJ— POOL: Kl .� Pi V6s- '164M CJI Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50---- 0--(If function the be (Iflast two digits Production should continue to reported as a of original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- - - from records, data and logs acquired for well (name onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception 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 also required for this well: Well Logging 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 5/2013 1tVL PERMIT ECKI:IST ',Field & Pool KUPARUK RIVER, TARN OIL - 490165 PTD#:2131670 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV U TARN 2L -322A Program DEV Well bore seg J DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0380052, Surf Loc & Top Prod Interv; ADL0380054, TD 3 Unique well name and number Yes KRU 2L -322A 4 Well located in a defined pool Yes KUPARUK RIVER, TARN OIL - 490165, governed by CO 430A 5 Well located proper distance from drilling unit boundary Yes CO 430A, Pool shall not be opened in any well closer than 300' to an external boundary where ownership changes 6 Well located proper distance from other wells Yes Conforms to CO 430A, Rule 3 -which specifies 10 -acre spacing 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 300' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes PKB 11/5/2013 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided NA Conductor set in 2L-322 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 2L-322 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons_ No Productive interval will be completed with swell packers and frac sleeves 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a_ re -drill, has a 10-403 for abandonment been approved Yes PTD 210-174, Sundry 313-552 26 Adequate wellbore separation _proposed Yes Proximity analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA i28 Drilling fluid program schematic equip list adequate Yes Max form pressure is 3000 psi(5226' TVD)11.0 ppg EMW; will drill w/ 9.4-11.2 ppg EMW Appr Date _& VLF 12/10/2013 29 BOPEs, do they meet_ regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2685 psi; BOP test pressure is 3500 psi 31 Choke manifold complies w/API_ RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 133 Is presence of H2S gas_ probable _ Yes H2S measures required_ 34 Mechanical condition of wells within AOR verified (For service well only) - NA 135 Permit can be issued w/o hydrogen sulfide measures No H2S is present in reservoir. H2S measures required. Geology 36 Data- presented on potential overpressure zones Yes Expected reservoir is 1.1.0 ppg EMW; will be drilled using 9.4-11.2 ppg mud. 37 Seismic analysis of shallow gas_zones_ - NA_ Potential for shallow gas within Campanian and Iceberg ss; 75/8 "_casing will be set approx_150' MD above - - Appr Date condition survey (if off_ -shore) - - - _N_A_ Bermuda ss. Mitigation measures discussed -in Drilling -Hazards Summary PKB 11/5/2013 :38 X39 _Seabed Contact name/phone for weekly progress reports_ [exploratory only] _ NA -Onshore development well._ - - - - - - - - - - Geologic Engineering ubl' Commissioner: Date: Commissioner: Date C m s Date 0 E