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216-004
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-07 (PTD 216-004) Date:Monday, July 22, 2024 4:00:53 PM Attachments:AnnComm Surveillance TIO for CD5-07.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, July 22, 2024 3:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD5-07 (PTD 216-004) Chris, CRU CD5-07 (PTD 216-004) was reported by operations for high OA. Initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD5-07 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, SBHP, Re-set A1CD5-07 10/7/2023 oberr Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2019.12 36.6 115.0 115.0 78.60 B SURFACE 10 3/4 9.95 36.8 2,291.0 2,190.7 45.50 L-80 H563 INTERMEDIATE 7 5/8 6.88 34.7 10,632.6 7,470.5 29.70 L80 Hyd563 LINER 4 1/2 3.96 10,472.0 21,042.0 7,353.2 12.60 L-80 Hyd 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.7 Set Depth … 10,519.6 Set Depth … 7,461.1 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.7 31.7 0.10 HANGER 11.000 FMC 4-1/2" Tubing Hanger FMC Alp horizont al 3.958 2,173.1 2,095.1 34.73 NIPPLE 4.500 DB-6 Landing Nipple, 4-1/2" X 3.813", L80, HYD563 BxP DB Nipple 3.813 9,956.0 7,312.2 67.38 GAS LIFT 4.500 4-1/2" x 1", Camco KBMG GLM CAMCO KBMG 3.860 10,165.3 7,384.6 71.82 NIPPLE 4.500 DB-6 Landing Nipple, 4-1/2" X 3.75", L80, BTC B x TXP P DB Nipple 3.750 10,478.5 7,456.3 82.62 LOCATOR 4.500 Baker GBH-22 Locator No Go 5.38" OD BakerLocator 3.880 10,503.3 7,459.3 83.45 SEAL ASSY 4.500 Baker Bonded Seal Assembly Baker BSA 3.870 10,517.0 7,460.8 83.76 SEAL ASSY 4.500 Baker Bonded Seal Assembly w/ Mule Shoe BakerBSA 3.870 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,173.12,095.134.73 INJ VALVE 4.5" A1 Injection Valve on 3.812" DB Lock CAMCO A1 HRS- 48 10/7/2023 1.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 9,956.0 7,312.2 67.38 1 GAS LIFT DMY BK 1 0.0 2/22/2023 Ext. pkg. Frued enbur g 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,472.0 7,455.4 82.34 PACKER 6.000 Baker 5 1/2" x 7 5/8" HRD-E ZXP Liner Top Packer w/5.75" ID PBR 11.07' Baker HRD ZXP 5.750 10,491.8 7,457.9 83.17 NIPPLE 5.500 Baker 5 1/2" RS Nipple 5 1/2" Hyd 563 Box x Box, 15.5# L-80 BakerRS PackOff 4.880 10,523.5 7,461.5 83.90 XO Reducing 5.500 Cross over, 5 1/2" H563 x 4-1/2" H563, B x P Baker 3.910 HORIZONTAL, CD5-07, 10/8/2023 1:12:54 PM Vertical schematic (actual) LINER; 10,472.0-21,042.0 Shoe; 21,038.5-21,042.0 INTERMEDIATE; 34.7-10,632.6 Float Shoe; 10,630.0-10,632.6 XO Reducing ; 10,523.5- 10,524.6 SEAL ASSY; 10,517.0 SBE; 10,504.4-10,523.5 SEAL ASSY; 10,503.3 HANGER; 10,494.6-10,504.4 Baffle; 10,498.2-10,499.4 NIPPLE; 10,491.8-10,494.6 PACKER; 10,472.0-10,491.8 LOCATOR; 10,478.5 XO - Threads; 10,476.6 NIPPLE; 10,165.2 XO - Threads; 9,971.1 GAS LIFT; 9,956.0 XO - Threads; 9,946.3 Stage Collar; 5,191.3-5,194.3 SURFACE; 36.8-2,291.0 Float Shoe; 2,288.3-2,291.0 Float Collar; 2,213.0-2,214.2 XO - Threads; 2,174.6 INJ VALVE; 2,173.1 NIPPLE; 2,173.1 XO - Threads; 2,169.9 XO - Threads; 128.1 CONDUCTOR; 36.6-115.0 CASING HANGER; 36.8-36.9 CASING HANGER; 34.7-35.4 HANGER; 31.7 WNS INJ KB-Grd (ft) 36.67 RR Date 3/3/2016 Other Elev… CD5-07 ... TD Act Btm (ftKB) 23,711.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032073400 Wellbore Status INJ Max Angle & MD Incl (°) 92.99 MD (ftKB) 15,238.19 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, October 13, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD5-07 COLVILLE RIV UNIT CD5-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/13/2023 CD5-07 50-103-20734-00-00 216-004-0 W SPT 7460 2160040 1865 2031 2032 2031 2031 283 314 313 312 4YRTST P Austin McLeod 8/19/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD5-07 Inspection Date: Tubing OA Packer Depth 520 2810 2755 2730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230820162403 BBL Pumped:2.9 BBL Returned:2.9 Friday, October 13, 2023 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-07 (PTD# 216-004-0) IA Suspect Date:Thursday, April 20, 2023 11:22:30 AM Attachments:AnnComm Surveillance TIO for CD5-07.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, April 20, 2023 9:52 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, The second 30 day monitor on CD5-07 will end tomorrow 4/21/2023. The annulus pressure trends indicate the valve replacement was successful and the IA pressure has stabilized. A 90-day TIO plot is attached. Given this performance, our intent is to return the well to Normal injector status. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Tuesday, March 21, 2023 9:36 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, The 30 day monitor period will end tomorrow 3/22/2023. The well is showing a slight upward trend that is different from previous trends. CPAI will extend the monitor for another 30days to conduct further diagnostics. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Thursday, February 16, 2023 3:29 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, This well passed initial diagnostics. Historically, this well has had TxIA and was mitigated successfully by replacing the dummy valve with extended packing. CPAI will attempt this same method again and put the well on a 30 day monitor to verify integrity. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Monday, February 6, 2023 1:26 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, CRU CD5-07 (PTD# 216-004-0) was reported by operations with IA Re-pressurization. DHD will conduct the initial diagnostics. Depending on results, well will either be shut in or proper notifications for continued injection will be submitted. Attached in the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com CD5-07 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD5-07 2023-02-01 2064 1335 -729 IA CD5-07 2023-02-03 1875 1245 -630 IA CD5-07 2023-02-18 2035 1500 -535 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD5-07 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swap ou ext pkg DMY, CMIT-IA, re-set A1 CD5-07 2/22/2023 oberr General Notes: Last 3 entries Com Date Last Mod By Well Highlights: Weather caused operations to be shut down for 2+ days. Differential sticking issue because of weather BHA failure in the production section Surface: Spudded 9 ppg, drilled with 10 ppg Intermediate: Drilled with a 9.6 to top of shales, weighted up to a 10.4 at the shales and tripped out with an 10.8 in hole. Production: Began drilling with a 9.0 ppg & then displaced to a 9.6 viscosified brine at TD maconce Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 20 19.12 36.6 115.0 115.0 78.60 B SURFACE 10 3/4 9.95 36.8 2,291.0 2,190.7 45.50 L-80 H563 INTERMEDIATE 7 5/8 6.88 34.7 10,632.6 7,470.5 29.70 L80 Hyd563 LINER 4 1/2 3.96 10,472.0 21,042.0 7,353.2 12.60 L-80 Hyd 563 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.7 Set Depth … 10,519.6 Set Depth … 7,461.1 String Ma… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection TXP ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.7 31.7 0.10 HANGER 11.000 FMC 4-1/2" Tubing Hanger FMC Alp horizont al 3.958 2,173.1 2,095.1 34.73 NIPPLE 4.500 DB-6 Landing Nipple, 4-1/2" X 3.813", L80, HYD563 BxP DB Nipple 3.813 9,956.0 7,312.2 67.38 GAS LIFT 4.500 4-1/2" x 1", Camco KBMG GLM CAMCO KBMG 3.860 10,165.3 7,384.6 71.82 NIPPLE 4.500 DB-6 Landing Nipple, 4-1/2" X 3.75", L80, BTC B x TXP P DB Nipple 3.750 10,478.5 7,456.3 82.62 LOCATOR 4.500 Baker GBH-22 Locator No Go 5.38" OD Baker Locator 3.880 10,503.3 7,459.3 83.45 SEAL ASSY 4.500 Baker Bonded Seal Assembly Baker BSA 3.870 10,517.0 7,460.8 83.76 SEAL ASSY 4.500 Baker Bonded Seal Assembly w/ Mule Shoe Baker BSA 3.870 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,173.1 2,095.1 34.73 INJ VALVE 4.5" A1 Injection Valve on 3.81" DB Lock CAMCO A1 HRS- 44 2/22/2023 1.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 9,956.0 7,312.2 67.38 1 GAS LIFT DMY BK 1 0.0 2/22/2023 Ext. pkg. Frued enbur g 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,472.0 7,455.4 82.34 PACKER 6.000 Baker 5 1/2" x 7 5/8" HRD-E ZXP Liner Top Packer w/5.75" ID PBR 11.07' Baker HRD ZXP 5.750 10,491.8 7,457.9 83.17 NIPPLE 5.500 Baker 5 1/2" RS Nipple 5 1/2" Hyd 563 Box x Box, 15.5# L-80 Baker RS PackOff 4.880 10,523.5 7,461.5 83.90 XO Reducing 5.500 Cross over, 5 1/2" H563 x 4-1/2" H563, B x P Baker 3.910 HORIZONTAL, CD5-07, 2/23/2023 5:30:09 AM Vertical schematic (actual) LINER; 10,472.0-21,042.0 Shoe; 21,038.5-21,042.0 INTERMEDIATE; 34.7-10,632.6 Float Shoe; 10,630.0-10,632.6 XO Reducing ; 10,523.5- 10,524.6 SEAL ASSY; 10,517.0 SBE; 10,504.4-10,523.5 SEAL ASSY; 10,503.3 HANGER; 10,494.6-10,504.4 Baffle; 10,498.2-10,499.4 NIPPLE; 10,491.8-10,494.6 PACKER; 10,472.0-10,491.8 LOCATOR; 10,478.5 XO - Threads; 10,476.6 NIPPLE; 10,165.2 XO - Threads; 9,971.1 GAS LIFT; 9,956.0 XO - Threads; 9,946.3 Stage Collar; 5,191.3-5,194.3 SURFACE; 36.8-2,291.0 Float Shoe; 2,288.3-2,291.0 Float Collar; 2,213.0-2,214.2 XO - Threads; 2,174.6 INJ VALVE; 2,173.1 NIPPLE; 2,173.1 XO - Threads; 2,169.9 XO - Threads; 128.1 CONDUCTOR; 36.6-115.0 CASING HANGER; 36.8-36.9 CASING HANGER; 34.7-35.4 HANGER; 31.7 WNS INJ KB-Grd (ft) 36.67 RR Date 3/3/2016 Other Elev… CD5-07 ... TD Act Btm (ftKB) 23,711.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032073400 Wellbore Status INJ Max Angle & MD Incl (°) 92.99 MD (ftKB) 15,238.19 WELLNAME WELLBORECD5-07 Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-07 (PTD# 216-004-0) IA Suspect Date:Tuesday, March 21, 2023 9:41:11 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Tuesday, March 21, 2023 9:36 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, The 30 day monitor period will end tomorrow 3/22/2023. The well is showing a slight upward trend that is different from previous trends. CPAI will extend the monitor for another 30days to conduct further diagnostics. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Thursday, February 16, 2023 3:29 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, This well passed initial diagnostics. Historically, this well has had TxIA and was mitigated successfully by replacing the dummy valve with extended packing. CPAI will attempt this same method again and put the well on a 30 day monitor to verify integrity. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Monday, February 6, 2023 1:26 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, CRU CD5-07 (PTD# 216-004-0) was reported by operations with IA Re-pressurization. DHD will conduct the initial diagnostics. Depending on results, well will either be shut in or proper notifications for continued injection will be submitted. Attached in the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-07 (PTD# 216-004-0) IA Suspect Date:Thursday, February 16, 2023 3:31:52 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, February 16, 2023 3:29 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, This well passed initial diagnostics. Historically, this well has had TxIA and was mitigated successfully by replacing the dummy valve with extended packing. CPAI will attempt this same method again and put the well on a 30 day monitor to verify integrity. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Monday, February 6, 2023 1:26 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, CRU CD5-07 (PTD# 216-004-0) was reported by operations with IA Re-pressurization. DHD will conduct the initial diagnostics. Depending on results, well will either be shut in or proper notifications for continued injection will be submitted. Attached in the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD5-07 (PTD# 216-004-0) IA Suspect Date:Tuesday, February 7, 2023 9:22:44 AM Attachments:AnnComm Surveillance TIO for CD5-07.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, February 6, 2023 1:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD5-07 (PTD# 216-004-0) IA Suspect Chris, CRU CD5-07 (PTD# 216-004-0) was reported by operations with IA Re-pressurization. DHD will conduct the initial diagnostics. Depending on results, well will either be shut in or proper notifications for continued injection will be submitted. Attached in the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com (.�fiap) ajn;ejadwa1 i15d) aJnssOJd {CId75W Jo ❑d97 aTeN 90 -ZD-£ Z 0 Z �70-z0-Ezoz LE -T O=E ZOZ sz-T o-€ zoz SZ-TO-EZOZ zZ-TO-Ezoz 61-L0-EZOZ 91-T o -E EOZ El -T O -C ZOZ 0 L -T O -E Z O Z L O -T 0-s z OZ bO-TO-£ZOZ L0 -1 0-E z0 z sZ-zT-rzaz sz-zrzzaz � �z-ZL-ZzoZ � oz-zL-ZzoZ LT-ZL-ZzoZ bi-zL-ZzoZ Li-ZT-ZzoZ 80-ZL-zzoz SO-ZL-ZzoZ z0-ZT-ZZaz 6z-LL-ZzoZ 9z-TL-ZzoZ EZ-TL-ZZOZ Oz-TL-ZZOZ Li-TL-ZZOZ tri-TT-ZZOZ LL-TTrZZOZ 00-ZS-ZZOZ MEESE �-■ 1���11�i7■� 111■11■11■11■11111■11■ I■, 111■11■11■11■11■�11■11■ 111■ 11■�11■illl■11.J■, I■, Ifi���li�i■J� . 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Inc. Well Attributes FiLPINE ALPINE Max Angle & MD 50103re APOUWI Mlbume anus ICI(°I 15 KBI 501032073400 INJ 2.99 15,236.19 TO <i Bfm (%KBI V,111 23,]11.0 Comment x3E (ppm) Date MnoYllon Eno pate KIFGM On flip Release Oa[¢ SSSV: NIPPLE Lest WO: 36.67 31312016 XORQONTAL, CpSO], 5ocoW0 9i AM Last Tag VeNwl schematic (actual Annolatton DepM(XKB) End Date Wellbore Lag Mod By ................ Law Tag: Iwo-O7 IlOwn HFNGER: al ) Last Rev Reason Annotation End Date Wellbore I Lat Moo By Rev Reason: Normal Up 91612019 CD5-0] DpanmDll TAICasing Strings casing Dcnomn OD (in) ID (in) Top lfton Set acrs(non So Dul BVD)-. WULen(I grace Top Timaae eaCONDUCTOR wNoucToa, absnp.° 20 19.12 36.6 115.0 1150 78.60 B Casing Description OD pp ID (in) Tap(nKBI Set Deptb(nnal SN Death (Win Vftl (I... Grace Top Thmel xo-Thusm. 1251 SURFACE 103/4 9.95 36.8 2,291.0 2,190.7 45.W 1-40 H563 Casing paotlption OD Nn) ID Nn) Tpp(RKB) SN guests T%KBI SM Depth (Win WIILen Q... Gm,M Top ThrwE xo-Timse. 2ta8.9 NIPPIE; 2,1]11 IIL VALVE, 21]31 W-Tmaaos, 2.174.5 INTERMEDIATE 758 6.88 34.7 10,632.6 7,470.5 29.70 18) Hyd563 Cming Oewrlptlon OD(in, ID(in) Top (%KBI SN OepM(XKBI SO De M1 WD W i.en I Grece Top Tllmn Pt ( I-' ("' LINER 4112 3.96 10,472.0 21,042.0 7,3532 12.80 L-80 Hyd 563 Liner Details Nominal ID Top (IRKS) Top (l I%NB) Tap Incl (% Xem Desi Cam (In) SURFACE; 36.S2 Ana- 10.472.0 7,455A 82.34 PACKER Baker 512' x 7 W HRD-EZ P Liner Top Packer 8015.7lT ID PBR 11.OT 5.750 10,491.8 ],45].9 83.17 NIPPLE Baker 512' RS Nipple 5 W'Hyd 563 Box x Box, 4.880 15.5111--80 10.494.6 7,458.3 83.26 HANGER Baker 512' x] 50Flex-Lock Liner Hanger Hyd 4.800 563, 17p L-80 10.504.4 7,4594 83.48 SBE Seal Bore Extension, W-40, 511T, H553 4.750 xo-Tessom e,..a 10,523.5 7,461.5 83.90 XO Reducing Crours cAnar, 51/7 H50 x 4-1/2-H553, B x P 3.910 GAS LIFT; 9 pal Tubing Strings xo'm^a°a',aw1d Tubing Description Wal TUBING 412 Ma... ID(in) Top MKBI Sal NM (ft.. SN DepI%(WD) I... 801(180X) Grace 3.96 31.7 10,519.6 7,461.1 1 12.60 L-80 Top Connection TXP NPI.; 10,1ab2 Completion Details Top(WD) Top Incl Nominal TIP Mile) (ftKB) E) Item Den Can IDNn) 31.7 31.7 0.10 HANGER FMC4 W-TubingHanger 3.958 xo-nnsa4e10,4me 2,173.1 2.0951 34.73 NIPPLE DB-6 Landing Nipple, 4-1&' X 3.813', 180, HYD563 BxP 3.813 LaGATDR;t:s7ga 101166.3 7,384.6 71.82 NIPPLE DB-6 Landing Nipple,4-12'X 3.75", LW, BTC B x TXP P 3.750 10,4]8.5 7.466.3 82.62 LOCATOR Beker GBH-22 Locator No Go 5.W' GO 3.880 10,503.3 7,459.3 83.45 SEALASSY Baker Sandell Seal Assembly 3.870 10,517.0 7.460.8 83.76 SEALASSY Baker Bonded Seal Assembly eel Mule SM1ce 3.870 SaA ASSY; 10,Was Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) SEALASSY; 10, 517.0 Top Top An Tap Incl (Po(B) (Won El Desi Can Run Date ID gn) ON 2,173.1 2,095.1 34.]31NJ VALVE 4.5 A-I INJ VLV(HSS-1]1/1.2FORIFICE) 9/62019 1.250 ON 3.812" )B-6 LOCK Mandrel Inserts INTERMEDIATE: a4.]-t 0,832.8 M NI H Top MKB) TOP(WD) (Me) Make Model OD (In) 9ery VaM Type "earn PM Type Warn (In) TRO Run (pal) flan DNe Can 1 91956.0 7,312.2 CAMCO KBMG 1 GASLIFT DMV BEK-5 0.000 0.0 922019 Ext. I I pkg. LINER; 10,472. Mn Mz 0 Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, February 9, 2021 9:35 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: RE: CRS CD5-07JPTM 216-004) IA Pressurization: Path Forward Attachments: CD5-07 90 -day TIO 02-09-21.pdf Chris— The Freudenberg high-sealability packing dummy valve was set in CD5-07 and the well underwent a 30 -day monitoring period from January 9, 2021 until February 8, 2021. The annulus pressure trends during this period indicate the valve was successful and the IA pressure showed no anomalous behavior. A 90 -day TIO plot is attached. Given this performance, our intent is to return the well to Normal injector status. Please let us know if you have any questions or disagree with this plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, December 30, 2020 11:03 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: CRU CD5-07 (PTD 216-004) IA Pressurization: Path Forward Chris— Another update on our monitoring of CRU injector CD5-07 (PTD #216-004). In this extended monitoring period, the behavior of the IA pressure shows that the well does have slow TxIA pressurization on water injection. We believe the leak rate is below the resolution of leak detect logging. Our next step is to replace the dummy valve with one that uses Freudenberg high sealability packing. Because we intend to accomplish this wellwork in the next several days, we propose leaving the well on injection to avoid the expense and complication of shutting -in and freeze protecting the well. The well's IA pressure appears that it will remain manageable and under DNE during this time. After the new dummy valve is set we propose diagnosing its performance with another 30 -day monitoring period of injection. Please let us know if you have any questions or disagree with this plan. Thanks, Travis aF From: Smith, Travis T Sent: Wednesday, Dece%rnbec 16, 2020 4:06 PM To: Wallace, Chris D (CED) <chris` w�fla alaska. ov> 1 Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, December 30, 2020 11:03 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: RE: CRU CD5-07 (PTD 216-004) IA Pressurization: Path Forward Chris— Another update on our monitoring of CRU injector CD5-07 (PTD #216-004). In this extended monitoring period, the behavior of the IA pressure shows that the well does have slow TxIA pressurization on water injection. We believe the leak rate is below the resolution of leak detect logging. Our next step is to replace the dummy valve with one that uses Freudenberg high sealability packing. Because we intend to accomplish this wellwork in the next several days, we propose leaving the well on injection to avoid the expense and complication of shutting -in and freeze protecting the well. The well's IA pressure appears that it will remain manageable and under DNE during this time. After the new dummy valve is set we propose diagnosing its performance with another 30 -day monitoring period of injection. Please let us know if you have any questions or disagree with this plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, December 16, 2020 4:06 PM To: Waltace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Senden, R.tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: CRU CD5-D7JJ�TD 216-004) IA Pressurization: Path Forward Chris— An update on our monitoring of CRU injector 615_5�07 (PTD #216-004): the work in Steps 1 and 2 below was completed successfully, and the well was placed on water injection November 16th. Today concludes the stated 30 -day monitoring period. No communication is evident to this point. The well has, -however, been continually ramped up in injection rate during the last 30 days. Therefore I would like to observe the well another 30 days of injection before I classify the well as normal status. Please let us know if you have any questions or disagree with this plan. Thanks, Travis From: Smith -.-Travis T Sent: Monday, November -g;-20-2":40 PM To: Wallace, Chris D (CED) <chris.wallace Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophill ips.com> Sent: Wednesday, December 16, 2020 4:06 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: RE: CRU CD5-07 (PTD 216-004) IA Pressurization: Path Forward Chris— An update on our monitoring of CRU injector CD5-07 (PTD #216-004): the work in Steps 1 and 2 below was completed successfully, and the well was placed on water injection November 16th. Today concludes the stated 30 -day monitoring period. No communication is evident to this point. The well has, however, been continually ramped up in injection rate during the last 30 days. Therefore I would like to observe the well another 30 days of injection before I classify the well as normal status. Please let us know if you have any questions or disagree with this plan. Thanks, Travis From: Smith, Travis T Sent: Monday, November 9, 2020 4:40 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: CRU CD5-07 (PTD 216-004) IA Pressurization: Path Forward Chris— Following the report and shut-in of CRU injector CD5-07 (PTD #216-004), DHD performed standard diagnostic testing on the well. An MITIA passed to 3025 psi, as well as an IA drawdown test. All wellhead seals passed tests with the exception of what we call the upper metal -to -metal seal (this seal, present only in horizontal wellheads, does not provide a flowpath between tubing and IA). The circumstance of TxIA communication on water injection after normal operation during MI injection is unexpected. It is possible that the sudden temperature decrease from MI to seawater injection temporarily allowed a leak path, perhaps at the extended packing dummy valve or in the wellhead. Our proposed path forward is as follows: 1. Pull and replace the extended packing dummy valve. 2. Circulate inhibited seawater and diesel to the IA. 3. Place the well on water injection for a 30 -day monitoring period to determine if TxIA persists. Please let us know if you have any questions or disagree with this plan. Thanks, Travis From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, October 26, 2020 8:22 PM Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, November 9, 2020 4:40 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: CRU CDS-07 (PTD 216-004) IA Pressurization: Path Forward Chris— Following the report and shut-in of CRU injector CD5-07 (PTD #216-004), DHD performed standard diagnostic testing on the well. An MITIA passed to 3025 psi, as well as an IA drawdown test. All wellhead seals passed tests with the exception of what we call the upper metal -to -metal seal (this seal, present only in horizontal wellheads, does not provide a flowpath between tubing and IA). The circumstance of TxIA communication on water injection after normal operation during MI injection is unexpected. It is possible that the sudden temperature decrease from MI to seawater injection temporarily allowed a leak path, perhaps at the extended packing dummy valve or in the wellhead. Our proposed path forward is as follows: 1. Pull and replace the extended packing dummy valve. 2. Circulate inhibited seawater and diesel to the IA. 3. Place the well on water injection for a 30 -day monitoring period to determine if TxIA persists. Please let us know if you have any questions or disagree with this plan. Thanks, Travis _--From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, October 26, 2020 8:22 PM To: Wa 4 e, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPA Wel upt <n1030@conocophillips.com>; Smith, Travis T <Travis.T.Smith@conocophillips.com>; NSK DHD Field Supervisor <NSK DFieldSupervisor@conocophillips.com> Subject: CRU CD5-0 TD 216-004) Report of Suspect IA Pressurization Dear Chris, CRU WAG injector CD5-07 (PTD 216-00*was recently converted from MI to water injection. After the transition from MI to water, the inner annulus experience explained IA pressurization after two bleeds yesterday. Operations has shut in an freeze protected the well. We planto d DHD to Alpine to conduct diagnostics within the next week. The proper paperwork for continued injection or repair wi a submitted when a path forward has been determined. Attached is a wellbore schematic and 90 -day TIO plot. Please let us know if you have any questions or disagree with this p Sincerely, Sara Carly sl& (ff"4# v) / Stepha*l� P%l.C'.1'V Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, October 26, 2020 8:22 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Smith, Travis T; NSK DHD Field Supervisor Subject: CRU CD5-07 (PTD 216-004) Report of Suspect IA Pressurization Attachments: CD5-07 AnnComm Surveillance 90 -Day TIO 10.26.20.pdf; CD5-07.pdf Dear Chris, CRU WAG injector CD5-07 (PTD 216-004) was recently converted from MI to water injection. After the transition from MI to water, the inner annulus experienced unexplained IA pressurization after two bleeds yesterday. Operations has shut in an freeze protected the well. We plan to send DHD to Alpine to conduct diagnostics within the next week. The proper paperwork for continued injection or repair will be submitted when a path forward has been determined. Attached is a wellbore schematic and 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Sincerely, Sara. CarU, & Cif wdkt w) / Stepha.vl� f a4C.IV Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com Wallace. Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, April 21, 2020 6:03 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD5-07 (PTD 216-004) Report of OA Sustained Casing Pressure Attachments: CD5-07 TIO 4.21.20 .pdf, CD5-07.pdf Dear Chris, CRU MI injector CD5-07 (PTD 216-004) was reported to have an OA pressure of 1123 psi on 4/19/20. We believe the recent pressurization is due to recent increased injection temperatures and intend for the well to remain online. Operations bled the OA pressure the same day and it is presently at 400 psi. The 10-3/4" 45.5 Ib/ft. L-80 surface casing has a burst rating of 5210 psi (45% is 2344 psi). A 90 -day TIO trend and wellbore schematic are attached. Please let me know if you have any questions or disagree with the plan forward. Sincerely, SGii''GLCa -Usl i (ft"ki+v) /St-ephANL eiPadv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Wednesday, April 15, 2020 7:09 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; ALP Prod Engr; ALP DS Lead and Simops Coord Subject: RE: CRU CD5-07 (PTD 216-004) End of Monitor Attachments: CD5-07.pdf, CD5-07 TIO 4.15.20 .pdf Good Evening Chris, CRU WAG injector CD5-07 (PTD 216-004) has concluded a monitor for inner annulus pressurization while in gas injection service. After IA pressurization in July 2019, a dummy gas -lift valve was replaced with extended packing in September 2019. The well then underwent an extended monitor period on water -only injection to validate the tubing integrity if administrative approval for continued water -only injection would be needed. The monitor period was completed November 4th, 2019 and confirmed integrity on water -only injection. The well was then planned to be placed on a 30 - day monitor on gas injection after exhibiting integrity on water injection. The well wouldn't take injection and was postponed to be brought online for pressure management purposes until March 16th, 2020. During the gas injection monitor, the inner annulus pressure did not deviate from thermal fluctuations due to higher injection temperatures. As a result, CPAI intends for the well to remain online in gas injection service. Please let me know if you disagree with the plan forward or have further questions. Attached is the TIO plot from the water and gas injection monitor periods and schematic. Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Pcop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Saturday, October 5, 2019 4:51 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com>; ALP DS Lead and Simops Coord <alp1450@conocophillips.com> Subject: RE: CRU CD5-07 (PTD 216-004) Update Hi Chris, CRU WAG injector CD5-07 (PTD 216-004) was reported on July 26th, 2019 for IA re -pressurization after bleeds. Well work to prepare the well for a water monitor period was completed September 6th, 2019, including circulating clean fluid in the IA and installing a new dummy valve with extended packing. A 30 -day monitor on water -only injection starting September 6th, 2019 indicates that the tubing and IA exhibiting integrity. There were disturbances to the IA pressure as a result of injection temperature increase and rate increase that required bleeds during the monitor. CPAI plans to extend the water monitor another 30 -days and then proceed to a 30 -day monitor on gas injection if the well continues to exhibit integrity. Please let me know if you disagree with the plan forward or have any questions. Attached is a 90 -day TIO plot and schematic. Sincerely, Sara�Ca ZA& (}EwAZ+,v) /RaJw,,LKaatk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Friday, August 23, 2019 9:22 AM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: CRU CD5-07 (PTD 216-004) Update Chris, The developed path forward for CD5-07 is to displace MI currently in the tubing with water, pull the existing valve to circulate clean fluids into the IA, set a new dummy valve with better packing in the gas lift mandrel, and then commence a 30 -day monitor period during water injection. CD5-07 will also need its 4 -year state -witnessed MIT, which we will schedule once the well is on stabilized injection. If the well exhibits integrity throughout the water injection monitor period, we will WAG it to MI as soon as operationally possible, for a 30 -day monitor during MI injection. If the well shows suspect behavior during either monitor, CPAI will follow-up with a new plan. CPAI intends to commence the work and monitors in the near future. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Friday, July 26, 2019 9:31 AM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: CRU CD5-07 (PTD 216-004) Report of suspect annular communication Chris, CRU WAG injector CD5-07 (PTD 216-004) IA pressure has been bled two times since 7.24.19 and is exhibiting unexplained IA pressure increase. Operations is mobilizing to shut in and freeze protect the well after which diagnostics will take place and a plan forward will be developed. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, March 17, 2020 2:43 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; ALP Prod Engr; ALP DS Lead and Simops Coord Subject: RE: CRU CD5-07 (PTD 216-004) Update Hi Chris, Since our last communication about CRU WAG injector CD5-07 (PTD 216-004), the well has remained SI due to reservoir pressure management. It was never brought on gas -injection for the 30 -day monitor period. This is an inform that we have started the previously communicated 30 -day monitor period on gas injection. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 Fr Well Integrity Compliance Specialist WNS & CPF3 Sent: rday, October 5, 2019 4:51 PM To: chris.wa a@alaska.gov Cc: CPA Wells Su <n1030@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com>; ALP DS Lead and Simops Coord <alp14 conocophillips.com> Subject: RE: CRU CD5-07 ( 216-004) Update Hi Chris, CRU WAG injector CD5-07 (PTD 216-004) wa eported on July 26th, 2019 for IA re -pressurization after bleeds. Well work to prepare the well for a water monitor period s completed September 6th, 2019, including circulating clean fluid in the IA and installing a new dummy valve with exten d packing. A 30 -day monitor on water -only injection starting September 6t", 2019 indicates that the tubing and IA ex ' iting integrity. There were disturbances to the IA pressure as a result of injection temperature increase and rate increase t t required bleeds during the monitor. CPAI plans to extend the water monitor another 30 -days and then proceed to i 30-d monitor on gas injection if the well continues to exhibit integrity. Please let me know if you disagree with the plan forward or have any quest s. Attached is a 90 -day TIO plot and schematic. Sincerely, $A.1 wCCWUSI&(H"U*v) �1ZacheVKauttk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop com MEMORANDUM TO: Jim Regg I ryPCR P.I. Supervisor Y11 FROM: Austin McLeod Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 2, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD5-07 COLVILLE RIV UNIT CD5-07 Ste: Inspector Reviewed By: P.I. Suprys� NON -CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD5-07 API Well Number 50-103-20734-00-00 Inspector Name: Austin McLeod Permit Number: 216-004-0 Inspection Date: 9/24/2019 Insp Num: mitSAM190924202737 - Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well cDs-o7 ` Type Inj w - TVD 7460 - Tubing 2147 ' 2148 - 2147 , 2148' PTD 2160040 ' Type Test SPT Test psi 1865- ' IA 740 3300 - 3250 3240 BBL Pumped: 4 IBBL Returned: 3.8 OA 240 zs7 290 290 ' Interval 4YRTST P/F P Notes: MIT -IA Wednesday, October 2, 2019 Page 1 of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, October 5, 2019 4:51 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; ALP Prod Engr; ALP DS Lead and Simops Coord Subject: RE: CRU CDS 07 (PTD 216-0041 Update Attachments: CD5-07.pdf; CD5-07 AnnComm Surveillance 90 -Day TIO .pdf Hi Chris, CRU WAG injector CD5-07 (PTD 216-004) was reported on July 26th, 2019 for IA re -pressurization after bleeds. Well work to prepare the well for a water monitor period was completed September 6th, 2019, including circulating clean fluid in the IA and installing a new dummyvalve with extended packing. A 30 -day monitor on water -only injection starting September 6th, 2019 indicates that the tubing and IA exhibiting integrity. There were disturbances to the IA pressure as a result of injection temperature increase and rate increase that required bleeds during the monitor. CPAI plans to extend the water monitor another 30 -days and then proceed to a 30 -day monitor on gas injection if the well continues to exhibit integrity. Please let me know if you disagree with the plan forward or have any questions. Attached is a 90 -day TIO plot and schematic. Sincerely, SarwCarW& (HeA4 /RacheLKautk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhil►ipsAlaska Office: 907-659-7126 1 n2549Cracop.com Cell: 907-331-7514 1 sara.e.carlisle0con com Fro Well Integrity Compliance Specialist WNS & CPF3 Sent: Frifty August 23, 2019 9:22 AM To: chris.walla alaska.go' Cc: CPA Wells Supt 030@conocophillips.com> Subject: CRU CD5-07 (P 16-004) Update Chris, The developed path forward for CD5-07 is to-dis circulate clean fluids into the IA, set a new durm a 30 -day monitor period during water injection. schedule once the well is on stabilized injection. lace MI currently in the tubing with water, pull the existing valve to y e with better packing in the gas lift mandrel, and then commence D5-07 also need its 4 -year state -witnessed MIT, which we will If the well ex%4,sintegrity throughout the water injection monitor period, we will WAG it to MI as soon as operationally possi)le, for a shows suspect behavior during either monitor, CPAI will follow-up with a monitor during MI injection. If the well Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS &CPF3 <n2549@conocophillips.com> Sent: Friday, August 23, 2019 9:22 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD5-07 (PTD 216-004) Update Chris, The developed path forward for CD5-07 is to displace MI currently in the tubing with water, pull the existing valve to circulate clean fluids into the IA, set a new dummy valve with better packing in the gas lift mandrel, and then commence a 30 -day monitor period during water injection. CD5-07 will also need its 4 -year state -witnessed MIT, which we will schedule once the well is on stabilized injection. If the well exhibits integrity throughout the water injection monitor period, we will WAG it to MI as soon as operationally possible, for a 30 -day monitor during MI injection. If the well shows suspect behavior during either monitor, CPAI will follow-up with a new plan. CPAI intends to commence the work and monitors in the near future. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Friday, July 26, 2019 9:31 AM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: CRU CDS-07 (PTD 216-004) Report of suspect annular communication Chris, CRU WAG injector CD5-07 (PTD 216-004) IA pressure has been bled two times since 7.24.19 and is exhibiting unexplained IA pressure increase. Operations is mobilizing to shut in and freeze protect the well after which diagnostics will take place and a plan forward will be developed. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillipS.com> Sent: Friday, July 26, 2019 9:31 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD5-07 (PTD 216-004) Report of suspect annular communication Attachments: CD5-07.pdf, CDS-07 90 day TIO trend 7.26.19.pdf Chris, CRU WAG injector CD5-07 (PTD 216-004) IA pressure has been bled two times since 7.24.19 and is exhibiting unexplained IA pressure increase. Operations is mobilizing to shut in and freeze protect the well after which diagnostics will take place and a plan forward will be developed. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM cWWZ MP$ . . 21 6004 WLL27 85 1 ELOG TRANSMITTAL DATA LQGGED fL f 72011. It• IM K BENDER PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED To: AOGCC Makana Bender JAN 0 6 2017 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 AOGCC (907) 793-1225 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: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 .t` SCANNED2 1) Caliper Report 27-Dec-16 CD5-07 1 Report /CD 50-103-20734-00 2) Signed : Mxtizadza_7/) l5_ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • RECEIVED • 2 1 6 0 0 4 • 27 85 1 J6N o 6 2017 Memory Multi-Finger Caliper ilLN .. AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: CD5-07 Log Date: December 27, 2016 Field: Alpine Log No.: 14809 State: Alaska Run No.: 1 API No. 50-103-20734-00 Pipe Description: 4.5 inch 12.6 lb. L-80 TXP Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 10,418 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of the DB-6 Landing Nipple at 10,165 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 4.5 inch tubing logged appears to be in good to fair condition, with a maximum recorded wall penetration of 30% at an isolated pit in joint 83(3,289 ft). Recorded damage appears as isolated pitting and a line of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS : L:)escriution Percent Via I'enetr i, n Joint ;;1r Isolated Pitting 30 83 3,289 Ft. (MD) Isolated Pitting 23 114 4,511 Ft. (MD) Isolated Pitting 23 109 4,299 Ft. (MD) Isolated Pitting 23 73 2,905 Ft. (MD) Line of Pits 22 107 4,249 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss(> 3%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. T. Leckband C. Waldrop B. Boehme 4 10,1 r-rigineerfs) .rm;alystis) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalvsisCalmemorvlog.com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907)659-2314 • • Correlation of Recorded Damage to Borehole Profile U Pipe 1 4.5 in (7.0'-10,41 7.7') Well: CD5-07 Field: Alpine Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: December 27,2016 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 105 25 1,039 -11 50 __ 1,999 75 2,970 100 3,938 0 iv 125 4,914 J Z g a 150 ( 5,878 6 r k J 175 6,843 200 7,808 225 8,780 250 - 9,751 GLM 1 266 10,401 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=266 • • PDS Report Overview S Body Region Analysis Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 4.5 in. 12.6 ppf L-80 TXP Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 TXP 3.958 in. 7 ft. 10,418 ft. Penetration (%wall) Damage Profile(%wall) 300 Penetration body =II Metal loss body 0 50 100 0.1 250 200 a 150 100 45 a I 50 0 0 to 20 to 40 to over 20% 40% 85% 85% 94 Number of joints analyzed(total=274) 258 16 0 0 ai a Damage Configuration(body) 144 30 ili 11 a 20 a_ 1941 J 10 1 0 244 1 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 1 (12:00) Number of joints damaged(total=54) 27 0 27 0 0 Bottom of Survey=266 0 s PI CIO. PDS Report Joint Tabulation Sheet Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 TXP Tubing 3.958 in. 0.271 in. 7 ft. 10,418 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 7 0 0.01 3 1 3.93 Pup t 0.2 10 0 0.03 10 2 3.94 Pup • 0.3 35 0 0.02 8 1 3.94 Pup • 0.4 54 0 0.04 13 3 3.95 Pup 0.5 78 0 0.03 13 3 3.94 Pup 0.6 98 0 0.02 7 1 3.97 Pup 1 105 0 0.03 12 2 3.92 IN 2 144 0 0.03 12 3 3.95 C 3 183 0 0.02 8 2 3.94 4 222 0 0.02 8 2 3.93 • 5 261 0 0.05 18 2 3.93 Shallow Line of Pits. r 6 300 0 0.02 8 2 3.92 Ell 7 339 0 0.04 15 1 3.94 Shallow Pitting. 8 379 0 0.03 10 1 3.95 9 417 0 0.04 13 2 3.94 10 454 0 0.03 10 2 3.94 11 493 0 0.03 12 1 3.94 in 12 532 0 0.03 12 1 3.94 • 13 571 0 0.05 17 2 3.94 Shallow Line of Pits. ON 14 610 0 0.03 12 1 3.94 W 15 649 0 0.03 10 1 3.94 r 16 688 0 0.03 9 3 3.95 17 727 0 0.05 18 3 3.95 Shallow Line of Pits. 18 766 0 0.04 13 2 3.93 19 805 0 0.03 10 1 3.94 • 20 844 0 0.04 13 3 3.95 C 21 883 0 0.03 10 2 3.95 22 922 0 0.03 10 2 3.95 • 23 961 0 0.04 15 2 3.93 Shallow Line of Pits. 24 1000 0 0.05 17 3 3.94 Shallow Line of Pits. 25 1039 0 0.03 . 9 1 3.92 26 1078 0 0.05 18 2 3.93 Shallow Line of Pits. INIII 27 1117 0 0.04 13 2 3.94 28 1155 0 0.03 9 2 3.95 • 29 1191 0 0.02 8 1 3.95 • 30 1231 0 0.03 12 2 3.93 ■ 31 1269 0 0.04 14 2 3.94 NO 32 1307 0 0.03 9 2 3.95 • 33 1345 0 0.02 8 1 3.94 • 34 1381 0 0.06 22 1 3.94 Line of Pits. INN 35 1420 0 0.05 17 2 3.93 Shallow Line of Pits. :NI 36 1460 0 0.02 7 2 3.95 37 1499 0 0.03 9 2 3.95 • 38 1538 0 0.04 13 2 3.94 IIIII 39 1577 0 0.04 14 2 3.94 W 40 1614 0 0.02 7 3 3.94 41 1652 0 0.02 8 2 3.95 42 1691 0 0.02 9 1 3.94 43 1730 0 0.03 10 2 3.93 • 44 1769 0 0.02 7 1 3.95 i IPenetration Body Metal Loss Body Page 1 • • PDS Report Joint Tabulation Sheet Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 TXP Tubing 3.958 in. 0.271 in. 7 ft. 10,418 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 45 1808 0 0.03 11 1 3.94 ■ 46 1846 0 0.04 13 1 3.92 47 1884 0 0.05 20 2 3.92 Line of Pits. 48 1923 0 0.05 17 2 3.93 Shallow Line of Pits. 49 1961 0 0.03 12 1 3.94 50 1999 0 0.04 13 3 3.93 ■ 51 2038 0 0.03 10 1 3.94 52 2074 0 0.03 10 1 3.93 53 2111 0 0.03 11 1 3.93 53.1 2150 0 0 0 0 3.82 DB-6 LANDING NIPPLE 54 2156 0 0.03 12 2 3.94 ■ 55 2195 0 0.04 13 2 3.94 56 2234 0 0.02 8 1 3.94 57 2273 0 0.03 11 1 3.95 58 2312 0 0.04 13 1 3.93 ■ 59 2351 0 0.03 10 2 3.95 60 2387 0 0.02 8 1 3.95 61 2426 0 0.03 11 1 3.94 62 2466 0 0.04 13 2 3.93 ■ 63 2505 0 0.03 10 2 3.95 64 2544 0 0.05 19 1 3.95 Shallow Pitting. 65 2582 0 0.05 17 1 3.95 Shallow Pitting. 66 2621 0 0.04 15 2 3.90 Shallow Line of Pits. 67 2660 0 0.06 21 2 3.92 Line of Pits. 68 2699 0 0.03 11 1 3.94 69 2738 0 0.04 15 1 3.94 Shallow Line of Pits. 70 2777 0 0.05 19 2 3.93 Shallow Line of Pits. ■ 71 2816 0 0.03 . 11 1 3.95 72 2855 0 0.04 13 1 3.95 73 2892 0 0.06 23 1 3.95 Isolated Pitting. 74 2931 0 0.04 13 2 3.94 75 2970 0 0.03 11 1 3.93 76 3007 0 0.05 18 2 3.94 Shallow Pitting. 77 3046 0 0.05 17 1 3.95 Shallow Pitting. 78 3085 0 0.05 20 1 3.95 Isolated Pitting. 79 3124 0 0.04 16 2 3.95 Shallow Pitting. 80 3161 0 0.05 20 1 3,95 Isolated Pitting. 81 3200 0 0.03 12 1 3.95 82 3238 0 0.04 16 1 3.95 Shallow Pitting. 83 3277 0 0.08 30 1 3.96 Isolated Pitting. 84 3316 0 0.05 18 1 3.93 Shallow Line of Pits. 85 3355 0 0.03 11 2 3.92 86 3393 0 0.05 18 2 3.94 Shallow Pitting. ■ 87 3432 0 0.05 17 1 3.94 Shallow Line of Pits. 88 3470 0 0.04 14 2 3.94 89 3509 0 0.05 20 2 3.93 Isolated Pitting. ■ 90 3548 0 0.04 13 2 3.95 91 3587 0 0.04 13 3 3.94 ■ 92 3626 0 0.03 12 2 3.95 ■ 93 3665 0 0.06 22 2 3.95 Isolated Pitting. Penetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 TXP Tubing 3.958 in. 0.271 in. 7 ft. 10,418 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 94 3704 0 0.03 12 2 3.94 95 3744 0 0.04 14 1 3.95 96 3783 0 0.05 18 1 3.92 Shallow Line of Pits. 97 3821 0 0.05 18 2 3.94 Shallow Pitting. 98 3860 0 0.05 17 3 3.94 Shallow Line of Pits. ■ 99 3899 0 0.04 15 1 3.94 Shallow Pitting. 100 3938 0 0.04 13 1 3.95 101 3977 0 0.05 17 1 3.95 Shallow Pitting. 102 4016 0 0.04 13 2 3.92 103 4055 0 0.06 22 2 3.93 Isolated Pitting. ■ 104 4093 0 0.04 13 1 3.95 • 105 4133 0 0.05 18 2 3.92 Shallow Pitting. • 106 4172 0 0.03 12 2 3.93 107 4211 0 0.06 22 3 3.93 Line of Pits. ■ 108 4250 0 0.03 12 1 3.93 109 4289 0 0.06 23 1 3.94 Isolated Pitting. 110 4328 0 0.05 17 2 3.94 Shallow Pitting. ■ 111 4367 0 0.05 17 2 3.93 Shallow Pitting. ■ 112 4407 0 0.04 15 2 3.94 Shallow Pitting. ■ 113 4445 0 0.05 18 2 3.94 Shallow Line of Pits. ■ 114 4485 0 0.06 23 2 3.94 Isolated Pitting. 115 4524 0 0.03 10 2 3.94 • 116 4563 0 0.03 11 1 3.94 117 4602 0 0.04 13 3 3.94 ■ 118 4641 0 0.05 18 2 3.93 Shallow Line of Pits. 119 4680 0 0.05 17 2 3.94 Shallow Line of Pits. 120 4719 0 0.06 22 1 3.92 Line of Pits. 121 4758 0 0.04 15 2 3.93 Shallow Line of Pits. ■ 122 4797 0 0.03 13 2 3.95 ■ 123 4836 0 0.03 12 1 3.95 124 4875 0 0.04 16 1 3.93 Shallow Line of Pits. 125 4914 0 0.05 17 1 3.95 Shallow Line of Pits. 126 4953 0 0.05 20 1 3.94 Line of Pits. 127 4992 0 0.04 13 2 3.94 128 5030 0 0.03 12 2 3.95 129 5069 0 0.03 10 1 3.95 130 5107 0 0.02 9 2 3.95 131 5146 0 0.02 7 2 3.95 132 5185 0 0.03 12 1 3.95 133 5223 0 0.02 9 2 3.95 134 5260 0 0.01 5 2 3.94 135 5299 0 0.02 7 2 3.95 136 5337 0 0.02 7 2 3.94 • 137 5376 0 0.01 5 1 3.95 138 5415 0 0.02 6 1 3.96 139 5453 0 0.02 6 1 3.95 140 5492 0 0.04 15 3 3.95 Shallow Pitting. 141 5531 0 0.01 5 1 3.94 142 5570 0 0.01 4 1 3.94 143 5606 0 0.02 6 1 3.95 Penetration Body Metal Loss Body Page 3 • • 4Li it_~ PDS Report Joint Tabulation Sheet Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 TXP Tubing 3.958 in. 0.271 in. 7 ft. 10,418 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 144 5645 0 0.02 7 2 3.95 _ • 145 5684 0 0.02 7 1 3.94 146 5722 0 0.02 8 2 3.93 147 5761 0 0.02 7 2 3.94 148 5800 0 0.02 7 2 3.95 149 5839 0 0.01 5 1 3.95 1 150 5878 0 0.01 5 2 3.94 151 5917 0 0.01 5 1 3.95 152 5955 0 0.02 8 1 3.94 • 153 5992 0 0.03 10 2 3.94 • 154 6030 0 0.01 5 1 3.94 i 155 6068 0 0.01 5 1 3.94 i 156 6105 0 0.02 6 1 3.94 II 157 6144 0 0.02 6 1 3.95 II 158 6183 0 0.01 5 1 3.94 1 159 6222 0 0.01 5 1 3.94 1 160 6261 0 0.03 11 2 3.94 • 161 6300 0 0.03 10 2 3.95 • 162 6339 0 0.02 7 1 3.94 163 6378 0 0.05 20 2 3.94 Isolated Pitting. 164 6417 0 0.01 5 2 3.94 i 165 6456 0 0.02 8 2 3.94 • 166 6495 0 0.02 7 2 3.94 11 167 6534 0 0.01 5 1 3.94 1 168 6572 0 0.03 10 1 3.94 • 169 6611 0 0.03 11 2 3.94 170 6650 0 0.03 10 2 3.94 171 6689 0 0.02 6 2 3.94 172 6727 0 0.02 7 2 3.93 173 6766 0 0.02 7 1 3.94 II 174 6804 0 0.02 8 2 3.94 C 175 6843 0 0.02 8 1 3.94 176 6882 0 0.02 7 2 3.94 177 6921 0 0.03 11 2 3.93 • 178 6960 0 0.03 10 2 3.94 • 179 6999 0 0.02 6 1 3.93 i 180 7038 0 0.03 9 3 3.94 C 181 7077 0 0.01 5 1 3.93 182 7116 0 0.02 6 1 3.95 183 7155 0 0.01 5 1 3.94 184 7194 0 0.03 10 1 3.94 • 185 7232 0 0.03 10 2 3.94 • 186 7271 0 0.01 5 1 3.95 1 187 7309 0 0.02 7 1 3.95 i 188 7348 0 0.03 11 1 3.94 IN 189 7387 0 0.02 6 2 3.94 1 190 7424 0 0.02 7 1 3.95 i 191 7463 0 0.02 8 2 3.94 • 192 7502 0 0.02 7 1 3.94 1 193 7541 0 0.02 6 1 3.94 1 Penetration Body Metal Loss Body Page 4 • • tit PDS Report Joint Tabulation Sheet Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 TXP Tubing 3.958 in. 0.271 in. 7 ft. 10,418 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 194 7580 0 0.01 5 1 3.94 195 7619 0 0.02 8 3 3.93 196 7655 0 0.02 7 2 3.92 197 7693 0 0.02 8 2 3.94 198 7732 0 0.01 5 1 3.95 199 7771 0 0.01 5 1 3.94 1 200 7808 0 0.03 11 1 3.94 • 201 7848 0 0.02 7 3 3.95 202 7887 0 0.01 5 1 3.94 203 7926 0 0.02 8 2 3.94 204 7964 0 0.02 6 2 3.94 205 8004 0 0.01 5 1 3.95 206 8042 0 0.02 7 2 3.93 207 8081 0 0.01 5 1 3.94 208 8120 0 0.01 5 2 3.93 209 8159 0 0.02 8 1 3.94 210 8197 0 0.03 11 2 3.94 •r 211 8236 0 0.01 5 1 3.94 212 8275 0 0.02 6 2 3.94 213 8313 0 0.02 7 1 3.93 214 8352 0 0.02 7 2 3.95 215 8391 0 0.02 7 2 3.94 216 8430 0 0.02 6 1 3.93 1 217 8469 0 0.02 8 1 3.93 218 8507 0 0.01 5 1 3.93 1 219 8547 0 0.02 7 2 3.94 1 220 8585 0 0.02 7 1 3.93 U 221 8624 0 0.01 5 1 3.94 222 8663 0 0.01 5 1 3.93 1 223 8702 0 0.02 7 1 3.93 224 8741 0 0.02 6 1 3.92 225 8780 0 0.02 6 2 3.93 226 8819 0 0.02 7 3 3.92 227 8859 0 0.02 8 1 3.92 228 8898 0 0.01 5 1 3.94 229 8937 0 0.02 6 2 3.93 230 8976 0 0.03 10 2 3.93 231 9015 0 0.03 12 2 3.92 232 9054 0 0.01 5 1 3.94 233 9093 0 0.02 7 2 3.93 234 9132 0 0.03 12 1 3.93 111 235 9170 0 0.02 7 3 3.94 236 9209 0 0.01 5 2 3.93 - 237 9247 0 0.04 13 1 3.94 238 9286 0 0.01 5 1 3.93 239 9326 0 0.01 5 1 3.92 240 9363 0 0.01 5 1 3.93 241 9402 0 0.02 6 1 3.93 242 9441 0 0.02 7 2 3.94 243 9480 0 0.02 6 1 3.93 IPenetration Body Metal Loss Body Page 5 • • 41-ii et w - PDS Report Joint Tabulation Sheet Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 TXP Tubing 3.958 in. 0.271 in. 7 ft. 10,418 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 244 9519 0 0.02 7 1 3.93 245 9558 0 0.02 8 1 3.93 246 9597 0 0.02 6 1 3.94 247 9637 0 0.02 7 1 3.94 248 9676 0 0.03 12 2 3.93 249 9715 0 0.02 8 1 3.93 250 9751 0 0.01 5 2 3.93 251 9790 0 0.02 8 1 3.90 252 9829 0 0.02 7 2 3.92 253 9868 0 0.02 7 1 3.90 • 254 9907 0 0.02 6 1 3.91 I 254.1 9947 0 0.03 10 1 3.94 Pup I 254.2 9955 0 0 0 0 3.82 GLM 1 (LATCH ® 12:00) 254.3 9963 0 0.01 5 2 3.91 Pup i 255 9972 0 0.02 7 1 3.92 256 10012 0 0.01 5 1 3.92 257 10051 0 0.02 7 2 3.92 M I 258 10090 0 0.02 6 2 3.92 259 10126 0 0.02 8 1 3.92 259.1 10165 0 0 0 0 3.34 DB-6 LANDING NIPPLE 260 10168 0 0.01 5 2 3.90 261 10207 0 0.02 6 2 3.90 Lt.Deposits. 262 10246 0 0.02 8 2 3.90 Lt.Deposits. • 263 10283 0 0.01 5 1 3.91 264 10322 0 0.02 8 1 3.90 • 265 10361 0 0.04 15 2 3.89 Shallow Pitting. Lt Deposits. ril 266 10401 0 0.01 5 1 3.89 Lt.Deposits. Penetration Body Metal Loss Body Page 6 i PDS Report Cross Sections Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 4.5 in. 12.6 ppf L-80 TXP Analyst: C.Waldrop --1 Cross Section for Joint 83 at depth 3,288.783 ft. Tool speed=46 Nominal ID=3.958 11PMINNattr, Nominal OD=4.5 Remaining wall area=99% Tool deviation=44° 1 Finger= 14 Penetration=0.081 in. Isolated Pitting 0.08 in.=30%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections efif Well: CD5-07 Survey Date: December 27,2016 Field: Alpine Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 4.5 in. 12.6 ppf L-80 TXP Analyst: C.Waldrop Cross Section for Joint 114 at depth 4,510.770 ft. Tool speed=52 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=98% Tool deviation=46° 1 Finger= 14 Penetration=0.063 in. Isolated Pitting 0.06 in.=23%Wall Penetration HIGH SIDE=UP • • WNS INJ CD5-07 ConocoPhillips s L�) Well Attributes 'Max Angle&MD TD Ala•*;I I.I,. 1 Wenboru APIIUWI Field Name Wenbere Elalueci(') D[1B1 Act earn INKS) ,- epn / b(tl1 L12u/.ul n1 Al DINE INJ �n MCan .8/ 38 15.238.19 23./11.0 common! 823(ppm) Dale AnnOta110n End Dae I)(S.Grd(R) I Rig Retia/Dote •-'�~NORrZONTAL-CD5-37 Tre2o to 3 23 34 PM--- 'SSSV. NIPPLE La1K WO: 1136.671 :'1/312016 Verecel scnemebc� od. 1L1at e _ Annotation [New(1188) End Dale Annotation Mod By End Date Lalel Tag: _ _Rev Reason:GLV C/O,SET INJ VALVE pg00e11 718/2016 RAN[.ER 0,7 _.,._....___......_.... .. Caang Strings Casing[...caption OD(in) ID lin) tog(008) 5e1 Depin(hire) Sal rape).(TVD).. wills.).It Grade Top/Mead 4,I ‘ 1 CONDUC TUR 20 19.124 38.6 115.0 115.0 78.60 8 Casing Description 00(In) ID(In) Top(h KS) Eel Depth{dile) 3N Depth(TVD)._. WI/Len{i...Grade Top 711020 SURFACE 103/4 9.950 36.8 2,291.0 2.190.7 45.501-80 11563 Caaing Dose rlpilon "00(In) ID(in) Top(RKB) SM Depth(NRB) SN Depth(TVD)... wllLen(I.. Gads Top Thread CONDUCTOR.3861160 INTERMEDIATE 7 5/8 6.876 34 7 10.632.6 7.470.5 29 70 180 (414563 toeing Daecrlprldn 00(en) ID(In) -Top(088) See Depth(1188) Set 6eprh(fVb)... NR/Len 0..f Grade 'Top'thread 10-Threaa..1251 t LINER 4112 3.968 10.-1720 21,0420 7.353.2 1260 1.80 Hy11563 t Liner Details x0,Threads.2.1099 1 _ r NIPPLE:1,1731 Nominal 1D RIJ VALVE,22.1)]0 1 Top(11KB) Tap ITVD)(11KB) Top Met 01 Ilam Ota Com (In) 10.472.0 7,455.4 82.34 PACKER Baker 5 1/2"x 7 5/8'RHO E ZXP LIner Top Packer 5,750 T117•41.26.x0.Ta.2.1748 y w/5.75'ID PUR t 1.0T 10.491.8 7,457.9 83.17 NIPPLE Baker 5 177 RS Nipple 5 1/2"Hyd 563 80x x Box. 4.880 15.58 L-80 EV RFACE.38 C 2 281.Q (0,494.6 7.458.3 83.26 HANGER Baker 5 1!2"x 7 518'Flex-Lock Liner Hangs..Hyd 4.800 563.170 L.80 10.504,4 7,459,4 83.48 SBE Seal Role Extension,80-40 S fir 41553 4.750 XO-Threads 9 946 3 I 10 523.5 7.451.5 83.90 X0 Reducing C1011/var 61/7"(4553x4 112-1803 RrP 3.910 00-61.16T.9.9500 Tubing Strings XO-ThNde.9.814 i Tubing Dena r 1ptron 510ng Ma OVA) Top(1681 Sel Depth Iti Set Depth(TVD)I WI 111,11) c•raan Top Connection-~ I)11)18(4 4 1/2 :1958 31 7 10.219.5 1.•161 1 11 50 I 80 11(8 NIPPLE 10.143.2 t Completion Details Nominal ID Top 111081 Top)TVD1111KB) TOP Inst(") (1441100.1 Corn tin) I/O.Thrtl4.100706 .31.7 31.7 010 HANGER IMC-I I,T Tubing Ilangur 3.058 LOCATOR.10,471%5 2,1/a 1 2.095.1 34.73 NIPPLE 00.6 Landing Nipple.4-1/2^X.3.813".L80.11Y13663 Lt KP '3.813 kl 10.165.3 7.384.8 71 82 NIPPLE DB-6 Landing Nipple,4.1/2"X 3 75'.L80.BTC 8 x TXP 3.750 P W/RHC plug 4 10.478.5 /,456.3 82 67 LOCATOR .Baker OB-1-22 locator N0 Go 5.38'OD 3.880 SEAL Aa9v.103034 * 10,503.11 7.459.3 83.45 BF AI ASSY Hiker Bonded Seal Assembly 3.870 SEK ABBY-103470 1!1,!,a/r1 L461)8 83'76 SEAL 61.11'1 It.,kei Bonded Seal A33emtaly w7 Mole Shoe - 3.870 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ' Top(TVD) Top Met Tap (NKB) "273915.0 K ) (•1 _ Des Com Run O.11a ID(In) 2.173.0 2.095.0 3477 (NJ VAL VE 3 81"AA•(INJ VI V(HYS 447/1.25"ORIFICE) 743/70)8 (.750 l'tl.RMEDIATE.30/.100320III Mandrel Inserts L Et al ll G NTop(TVD) valve Latah Part SIC. TRO Run III Top(11115) (MOO Make Model OD(ns) Sere Type Type tin) (pall Run Dune Com S I 9.956.0 1.312.2 CAMCO KOMG I CAS LIT/ UMY 'Sews 0.(x10' 0.0 1/3/2015 VI II II II .3 3 II S P, Ik ii Ti a a x • k • W. • is al a 1 a k II t i 1.1 il I S (1909 10 470 0 0)t 342 0 • 2_\m -- oo44 REC .... ..I . D ConocoPhillips NOV 10 2016 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 October 30, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SCANNED MAP Li', f, ?Gly Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU).Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor,engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404,Report of Sundry Operations. The cement was pumped October 29th 2016. The corrosion inhibitor/sealant was pumped on October 30th 2016. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call Aaron Applehans or Roger Winter at 907-659-7506,if you have any questions. Sincerely, Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 10/30/2016 CD5 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal CD5-01 50103207360000 2160220 1.33' .17 bbl .66' 10/29/2016 5.1 gal 10/30/2016 CD5-02 50103207370100 2160680 1' .1 bbl .66' 10/29/2016 5 gal 10/30/2016 CD5-03 50103207180000 2151460 1.08' .1 bbl .66' 10/29/2016 5 gal 10/30/2016 CD5-04 50103207110000 2150720 .875' .07 bbl .66' 10/29/2016 5.1 gal 10/30/2016 CD5-05 50103207120000 2150730 2.25' NA 2.25' 5/29/2016 18 gal 10/30/2016 fir CD5-07 50103207340000 2160040 1.42' .2 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-08 50103207410000 2160510 4.75' .71 bbl 1.83 10/29/2016 CD5-12 50103207420000 2160520 2.58' .47 bbl 0.66 10/29/2016 5 gal 10/30/2016 CD5-315 50103207160000 2151370 1' .1 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-21 50103207380000 2160310 .75' .6bbl 0.66 10/29/2016 3.4 gal 10/30/2016 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,July 21,2016 TO: Jim Regg ,--7 / P.I.Supervisor 1( 7c -((e6— l e� 1 I" SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA INC CD5-07 FROM: Guy Cook COLVILLE RIV UNIT CD5-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ& - NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD5-07API Well Number 50-103-20734-00-00 Inspector Name: Guy Cook Permit Number: 216-004-0 Inspection Date: 7/21/2016 Insp Num: mitGDC160721103858 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD5-07 - iType Inj w- TVD 7455 • Tubing j moo 1005 - 1005 . 1005 PTD 2160040 iType Test SPT Test psi 1864 • IA i242 2200 - 2175 ! 2170 • _- — -- ----- - 1----- 630 � 630 • Interval INITAL PAF P v OA 445 I 630 Notes: Pumped 3 bbls of diesel to get to test pressure. 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J d w o E a as D 011,1 Om O U U 1 C ' N 111 1 ON w } E o c c oQbbo in a. 0 r 0 E 11110 `o z Io c I 11 G ' N N f6 CCI c• h c N E 111111111Q' c, O 1- E WCO ._ V/ 0 c c co I G I at ' O N II 1 I— O C U 'a-, . ' O d O 2 0 d (j `� 1 0 E O / asz d `0 3 co P, N I CO M 1 } C C) O O .- O W ' d N r c c n ;12 = d re D - H - 0 0 . C a) O M o o Q o 0 1 1i c U .. N '� U J - O Q m W U Tx 7 O d c. N V E Q- `) 0 O 2 N 0 O 5 N O O �' 0. 2 0 0 0 0 0 C 0 0 R EIVED • t 1 60 04 APR 19 2015 2710)419 chiumberger A0Gor Transmittal#: 15APR16 SP02 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 1t/t9/2016 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD5-07 T.O.C. Date Dispatched: 15-Apr-16 Job#: 15AKA0031 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement x x 8448' -10900' MD LAS Digital Data N/A Contents on CD x Directional Data N/A Contents on CD As-Built Survey N/A Contents on CD EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/pds x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a�conocophillips.com AlaskaPTSPrintCenter(a�slb.com Attn: Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 _ / „teat Received By: :/G�✓�� uv 111RECEIVED 2 1 60 04 APR 19 2011i 27048 AOGCC Schiumberger Transmittal#: 15APR16-SP01 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery At/( /201C0 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD5-07 Date Dispatched: 15-Apr-16 Job#: 15AKA0031 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2" MD x x Scope Resistivity 2"TVD x x Scope Resistivity 5'MD x x Scope Resistivity 5'TVD x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a,,conocophillips.com AlaskaPTSPrintCenterslb.com Attn: Tom Osterkamp Attn:Stephanie Pacillo /�- 907-263-4795 G>�✓�� V '�/y�``LjPJj Received By: ` • 21 60 04 27048 RECEWED APR 19 2013 AOGCC FINAL NADConversion Western North Slope CD5 Alpine West Pad CD5-07 CD5-07 NAD 27 Definitive Survey Report 09 March, 2016 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-07 Well Position +N/-5 0.00 usft Northing: 5,965,883.11 usft Latitude: 70°18'50.023 N +E/-W 0.00 usft Easting: 349,423.93 usft Longitude: 151°13'13.411 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.30 usft Wellbore CD5-07 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2015 2/11/2016 17.78 80.83 57,469 Design CD5-07 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.67 Vertical Section: Depth From(TVD) , +N/-S +E/-W Direction (usft) (usft) (usft) (0) 36.67 0.00 0.00 332.76 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 67.00 735.00 CD5-07 Svy1 SLB_NSG+SSHOT(CD5-0 GYD-GC-SS Gyrodata gyro single shots 2/5/2016 3:01:0 761.28 2,224.93 CD5-07 Svy2 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 10:41:C 2,325.70 10,576.70 CD5-07 Svy3 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/9/2016 9:05:0 10,667.42 15,422.86 CD5-07 Svy4 SLB_MWD_GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/19/2016 2:12: 15,517.12 23,651.61 CD5-07 Svy5 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2016 2:16: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 36.67 0.00 0.00 36.67 -34.30 0.00 0.00 5,965,883.11 349,423.93 0.00 0.00 UNDEFINED 67.00 0.29 106.91 67.00 -3.97 -0.02 0.07 5,965,883.09 349,424.01 0.96 -0.05 GYD-GC-SS(1) 115.00 0.32 55.24 115.00 44.03 0.02 0.30 5,965,883.13 349,424.24 0.56 -012 "IT an Actual Survey • 20"x 42" _ 167.00 0.54 28.08 167.00 96.03 0.32 0.54 5,965,883.42 349,424.48 0.56 0.04 GYD-GC-SS(1) 267.00 0.45 336.17 266.99 196.02 1.09 0.60 5,965,884.20 349,424.56 0.44 0.70 GYD-GC-SS(1) 367.00 0.70 22.61 366.99 296.02 2.02 0.68 5,965,885.12 349,424.65 0.51 1.48 GYD-GC-SS(1) 459.00 0.68 5.64 458.98 388.01 3.08 0.95 5,965,886.17 349,424.94 0.22 2.31 GYD-GC-SS(1) 578.00 0.86 333.70 577.97 507.00 4.58 0.62 5,965,887.68 349,424.65 0.38 3.79 GYD-GC-SS(1) 643.00 1.37 302.71 642.96 571.99 5.44 -0.25 5,965,888.56 349,423.79 1.19 4.95 GYD-GC-SS(1) 735.00 1.17 306.33 734.94 663.97 6.59 -1.93 5,965,889.74 349,422.14 0.23 6.74 GYD-GC-SS(1) 3/9/2016 9:50:57AM Page 2 COMPASS 5000.1 Build 74 III 0 SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 761.28 0.85 293.88 761.21 690.24 6.83 -2.33 5,965,889.99 349,421.75 1.47 7.14 MWD+IFR-AK-CAZ-SC(2) 856.25 1.23 35.69 856.17 785.20 7.94 -2.38 5,965,891.10 349,421.72 1.72 8.15 MWD+IFR-AK-CAZ-SC(2) 950.56 3.59 51.24 950.40 879.43 10.61 0.52 5,965,893.71 349,424.66 2.57 9.20 MWD+IFR-AK-CAZ-SC(2) 1,044.15 4.37 62.89 1,043.76 972.79 14.07 5.98 5,965,897.06 349,430.19 1.20 9.78 MWD+IFR-AK-CAZ-SC(2) 1,138.30 7.02 65.54 1,137.44 1,066.47 18.09 14.41 5,965,900.91 349,438.70 2.83 9.49 MWD+IFR-AK-CAZ-SC(2) 1,232.49 10.17 68.32 1,230.56 1,159.59 23.55 27.38 5,965,906.11 349,451.78 3.37 8.40 MWD+IFR-AK-CAZ-SC(2) 1,326.95 12.50 69.84 1,323.17 1,252.20 30.15 44.73 5,965,912.36 349,469.25 2.49 6.33 MWD+IFR-AK-CAZ-SC(2) 1,419.97 14.74 68.98 1,413.57 1,342.60 37.87 65.22 5,965,919.66 349,489.90 2.42 3.81 MWD+IFR-AK-CAZ-SC(2) 1,514.24 17.28 67.60 1,504.17 1,433.20 47.51 89.37 5,965,928.81 349,514.23 2.72 1.32 MWD+IFR-AK-CAZ-SC(2) 1,609.01 19.88 66.82 1,594.00 1,523.03 59.21 117.20 5,965,939.96 349,542.29 2.76 -1.01 MWD+IFR-AK-CAZ-SC(2) 1,702.91 22.99 62.96 1,681.40 1,610.43 73.84 148.22 5,965,953.96 349,573.59 3.64 -2.20 MWD+IFR-AK-CAZ-SC(2) 1,797.50 25.46 58.78 1,767.66 1,696.69 92.78 182.06 5,965,972.22 349,607.81 3.18 -0.86 MWD+IFR-AK-CAZ-SC(2) 1,891.98 27.12 59.18 1,852.36 1,781.39 114.34 217.93 5,965,993.05 349,644.09 1.77 1.89 MWD+IFR-AK-CAZ-SC(2) 1,986.37 28.60 61.50 1,935.81 1,864.84 136.14 256.26 5,966,014.08 349,682.85 1.94 3.73 MWD+IFR-AK-CAZ-SC(2) 2,081.14 31.20 62.94 2,017.96 1,946.99 158.14 298.06 5,966,035.23 349,725.09 2.85 4.15 MWD+IFR-AK-CAZ-SC(2) 2,173.72 34.75 62.15 2,095.61 2,024.64 181.38 342.76 5,966,057.57 349,770.24 3.86 4.35 MWD+IFR-AK-CAZ-SC(2) 2,224.93 35.92 61.24 2,137.39 2,066.42 195.43 368.83 5,966,071.09 349,796.59 2.51 4.90 MWD+IFR-AK-CAZ-SC(2) 2,290.63 36.43 59.40 2,190.43 2,119.46 214.63 402.52 5,966,089.61 349,830.65 1.83 6 55 1467-a'11 •ctuai urvey 1) 10-3/4"x 13-1/2" i 2,325.70 36.71 58.43 2,218.59 2,147.62 225.42 420.41 5,966,100.04 349,848.75 1.83 7.95 MWD+IFR-AK-CAZ-SC(3) 2,419.66 38.23 58.70 2,293.16 2,222.19 255.23 469.18 5,966,128.86 349,898.11 1.63 12.13 MWD+IFR-AK-CAZ-SC(3) 2,514.11 41.01 59.29 2,365.91 2,294.94 286.24 520.81 5,966,158.83 349,950.34 2.97 16.07 MWD+IFR-AK-CAZ-SC(3) 2,607.05 43.35 58.39 2,434.78 2,363.81 318.54 574.20 5,966,190.05 350,004.36 2.60 20.34 MWD+IFR-AK-CAZ-SC(3) 2,701.24 45.87 56.51 2,501.83 2,430.86 354.14 629.93 5,966,224.53 350,060.79 3.02 26.48 MWD+IFR-AK-CAZ-SC(3) 2,792.74 47.79 55.15 2,564.43 2,493.46 391.63 685.13 5,966,260.90 350,116.73 2.36 34.54 MWD+IFR-AK-CAZ-SC(3) 2,887.28 48.29 53.48 2,627.64 2,556.67 432.64 742.23 5,966,300.75 350,174.63 1.42 44.86 MWD+IFR-AK-CAZ-SC(3) 2,981.53 48.25 52.43 2,690.38 2,619.41 475.01 798.37 5,966,341.99 350,231.61 0.83 56.83 MWD+IFR-AK-CAZ-SC(3) 3,077.10 48.19 52.03 2,754.06 2,683.09 518.66 854.70 5,966,384.50 350,288.80 0.32 69.85 MWD+IFR-AK-CAZ-SC(3) 3,171.03 47.29 52.48 2,817.22 2,746.25 561.22 909.67 5,966,425.94 350,344.61 1.02 82.52 MWD+IFR-AK-CAZ-SC(3) 3,263.93 47.15 52.71 2,880.32 2,809.35 602.64 963.84 5,966,466.26 350,399.59 0.24 94.55 MWD+IFR-AK-CAZ-SC(3) 3,359.85 47.24 53.50 2,945.50 2,874.53 644.89 1,020.11 5,966,507.37 350,456.70 0.61 106.35 MWD+IFR-AK-CAZ-SC(3) 3,453.34 47.20 53.76 3,009.00 2,938.03 685.58 1,075.37 5,966,546.94 350,512.75 0.21 117.23 MWD+IFR-AK-CAZ-SC(3) 3,547.95 47.19 52.81 3,073.28 3,002.31 727.07 1,131.01 5,966,587.31 350,569.21 0.74 128.65 MWD+IFR-AK-CAZ-SC(3) 3,639.65 47.22 51.78 3,135.58 3,064.61 768.22 1,184.24 5,966,627.38 350,623.26 0.82 140.87 MWD+IFR-AK-CAZ-SC(3) 3,735.76 47.23 51.71 3,200.85 3,129.88 811.91 1,239.64 5,966,669.94 350,679.52 0.05 154.34 MWD+IFR-AK-CAZ-SC(3) 3,829.16 47.24 52.27 3,264.27 3,193.30 854.13 1,293.67 5,966,711.07 350,734.37 0.44 167.15 MWD+IFR-AK-CAZ-SC(3) 3,922.28 47.14 51.79 3,327.55 3,256.58 896.16 1,347.52 5,966,752.01 350,789.05 0.39 179.86 MWD+IFR-AK-CAZ-SC(3) 4,016.70 47.67 51.79 3,391.46 3,320.49 939.15 1,402.14 5,966,793.89 350,844.52 0.56 193.08 MWD+IFR-AK-CAZ-SC(3) 4,112.22 47.69 51.22 3,455.77 3,384.80 983.11 1,457.41 5,966,836.73 350,900.66 0.44 206.86 MWD+IFR-AK-CAZ-SC(3) 4,204.95 47.70 49.92 3,518.19 3,447.22 1,026.67 1,510.38 5,966,879.21 350,954.49 1.04 221.34 MWD+IFR-AK-CAZ-SC(3) 3/9/2016 9:50:57AM Page 3 COMPASS 5000.1 Build 74 el 0 SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,298.49 47.98 49.30 3,580.97 3,510.00 1,071.60 1,563.19 5,966,923.07 351,008.19 0.58 237.11 MWD+IFR-AK-CAZ-SC(3) 4,393.02 48.12 49.12 3,644.16 3,573.19 1,117.53 1,616.42 5,966,967.92 351,062.32 0.20 253.57 MWD+IFR-AK-CAZ-SC(3) 4,487.10 48.14 49.23 3,706.95 3,635.98 1,163.33 1,669.43 5,967,012.65 351,116.24 0.09 270.02 MWD+IFR-AK-CAZ-SC(3) 4,580.41 48.07 49.65 3,769.26 3,698.29 1,208.49 1,722.20 5,967,056.74 351,169.90 0.34 286.02 MWD+IFR-AK-CAZ-SC(3) 4,674.92 48.32 50.96 3,832.27 3,761.30 1,253.49 1,776.41 5,967,100.64 351,224.99 1.07 301.21 MWD+IFR-AK-CAZ-SC(3) 4,769.15 48.33 51.29 3,894.92 3,823.95 1,297.66 1,831.20 5,967,143.70 351,280.66 0.26 315.40 MWD+IFR-AK-CAZ-SC(3) 4,862.39 48.21 51.80 3,956.98 3,886.01 1,340.94 1,885.69 5,967,185.87 351,336.00 0.43 328.92 MWD+IFR-AK-CAZ-SC(3) 4,956.93 48.23 51.95 4,019.97 3,949.00 1,384.46 1,941.15 5,967,228.27 351,392.32 0.12 342.23 MWD+IFR-AK-CAZ-SC(3) 5,050.59 48.24 52.07 4,082.36 4,011.39 1,427.46 1,996.21 5,967,270.15 351,448.22 0.10 355.26 MWD+IFR-AK-CAZ-SC(3) 5,145.01 48.26 52.65 4,145.23 4,074.26 1,470.48 2,051.99 5,967,312.04 351,504.85 0.46 367.97 MWD+IFR-AK-CAZ-SC(3) 5,239.59 48.21 52.72 4,208.23 4,137.26 1,513.24 2,108.10 5,967,353.67 351,561.80 0.08 380.30 MWD+IFR-AK-CAZ-SC(3) 5,334.45 48.18 52.78 4,271.46 4,200.49 1,556.04 2,164.38 5,967,395.33 351,618.92 0.06 392.59 MWD+IFR-AK-CAZ-SC(3) 5,428.66 48.17 53.17 4,334.29 4,263.32 1,598.32 2,220.43 5,967,436.47 351,675.81 0.31 404.52 MWD+IFR-AK-CAZ-SC(3) 5,523.07 48.22 53.08 4,397.22 4,326.25 1,640.55 2,276.73 5,967,477.56 351,732.93 0.09 416.29 MWD+IFR-AK-CAZ-SC(3) 5,617.38 47.69 53.55 4,460.38 4,389.41 1,682.39 2,332.89 5,967,518.26 351,789.92 0.67 427.78 MWD+IFR-AK-CAZ-SC(3) 5,710.49 47.82 53.37 4,522.98 4,452.01 1,723.43 2,388.27 5,967,558.18 351,846.11 0.20 438.91 MWD+IFR-AK-CAZ-SC(3) 5,805.00 47.83 52.64 4,586.43 4,515.46 1,765.57 2,444.21 5,967,599.19 351,902.88 0.57 450.77 MWD+IFR-AK-CAZ-SC(3) 5,900.24 47.74 52.64 4,650.42 4,579.45 1,808.38 2,500.28 5,967,640.86 351,959.79 0.09 463.16 MWD+IFR-AK-CAZ-SC(3) 5,994.00 47.78 52.78 4,713.45 4,642.48 1,850.43 2,555.50 5,967,681.79 352,015.84 0.12 475.27 MWD+IFR-AK-CAZ-SC(3) 6,087.60 47.65 51.51 4,776.43 4,705.46 1,892.92 2,610.17 5,967,723.18 352,071.35 1.01 488.02 MWD+IFR-AK-CAZ-SC(3) 6,181.45 48.14 51.38 4,839.36 4,768.39 1,936.32 2,664.62 5,967,765.47 352,126.65 0.53 501.67 MWD+IFR-AK-CAZ-SC(3) 6,275.65 48.21 50.96 4,902.17 4,831.20 1,980.34 2,719.31 5,967,808.38 352,182.20 0.34 515.77 MWD+IFR-AK-CAZ-SC(3) 6,369.64 48.12 50.19 4,964.87 4,893.90 2,024.81 2,773.40 5,967,851.75 352,237.17 0.62 530.55 MWD+IFR-AK-CAZ-SC(3) 6,462.74 48.13 50.53 5,027.01 4,956.04 2,069.03 2,826.78 5,967,894.89 352,291.43 0.27 545.43 MWD+IFR-AK-CAZ-SC(3) 6,555.83 48.01 50.24 5,089.22 5,018.25 2,113.19 2,880.13 5,967,937.97 352,345.65 0.27 560.26 MWD+IFR-AK-CAZ-SC(3) 6,649.56 48.17 50.07 5,151.82 5,080.85 2,157.88 2,933.69 5,967,981.58 352,400.09 0.22 575.48 MWD+IFR-AK-CAZ-SC(3) 6,743.54 48.13 49.45 5,214.53 5,143.56 2,203.11 2,987.13 5,968,025.71 352,454.42 0.49 591.22 MWD+IFR-AK-CAZ-SC(3) 6,837.55 48.24 49.23 5,277.20 5,206.23 2,248.76 3,040.28 5,968,070.29 352,508.47 0.21 607.48 MWD+IFR-AK-CAZ-SC(3) 6,931.54 48.14 48.98 5,339.86 5,268.89 2,294.62 3,093.23 5,968,115.08 352,562.33 0.22 624.01 MWD+IFR-AK-CAZ-SC(3) 7,025.39 48.05 49.33 5,402.55 5,331.58 2,340.30 3,146.07 5,968,159.69 352,616.07 0.29 640.44 MWD+IFR-AK-CAZ-SC(3) 7,119.36 47.84 49.51 5,465.49 5,394.52 2,385.69 3,199.06 5,968,204.00 352,669.96 0.26 656.53 MWD+IFR-AK-CAZ-SC(3) 7,212.97 48.10 49.37 5,528.17 5,457.20 2,430.91 3,251.89 5,968,248.14 352,723.68 0.30 672.55 MWD+IFR-AK-CAZ-SC(3) 7,306.35 48.12 49.87 5,590.52 5,519.55 2,475.94 3,304.84 5,968,292.10 352,777.52 0.40 688.34 MWD+IFR-AK-CAZ-SC(3) 7,400.38 48.04 51.38 5,653.34 5,582.37 2,520.32 3,358.92 5,968,335.39 352,832.47 1.20 703.05 MWD+IFR-AK-CAZ-SC(3) 7,494.86 48.09 52.34 5,716.48 5,645.51 2,563.73 3,414.20 5,968,377.67 352,888.61 0.76 716.33 MWD+IFR-AK-CAZ-SC(3) 7,588.29 48.18 52.17 5,778.83 5,707.86 2,606.32 3,469.22 5,968,419.15 352,944.47 0.17 729.01 MWD+IFR-AK-CAZ-SC(3) 7,682.26 48.26 52.12 5,841.44 5,770.47 2,649.32 3,524.55 5,968,461.03 353,000.64 0.09 741.91 MWD+IFR-AK-CAZ-SC(3) 7,776.48 48.09 52.39 5,904.27 5,833.30 2,692.30 3,580.07 5,968,502.89 353,057.01 0.28 754.71 MWD+IFR-AK-CAZ-SC(3) 7,870.36 47.89 51.87 5,967.10 5,896.13 2,735.12 3,635.13 5,968,544.59 353,112.91 0.46 767.57 MWD+IFR-AK-CAZ-SC(3) 7,963.57 47.99 51.64 6,029.55 5,958.58 2,777.96 3,689.48 5,968,586.33 353,168.11 0.21 780.78 MWD+IFR-AK-CAZ-SC(3) 3/9/2016 9:50:57AM Page 4 COMPASS 5000.1 Build 74 • S SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 8,056.94 47.96 51.51 6,092.05 6,021.08 2,821.07 3,743.82 5,968.628 33 353,223.30 0.11 794.22 MWD+IFR-AK-CAZ-SC(3) 8,149.64 47.46 48.74 6,154.44 6,083.47 2,865.02 3,796.44 5,968,671.22 353,276.78 2.28 809.21 MWD+IFR-AK-CAZ-SC(3) 8,244.36 46.79 43.94 6,218.90 6,147.93 2,912.90 3,846.64 5,968,718.08 353,327.93 3.78 828.80 MWD+IFR-AK-CAZ-SC(3) 8,338.02 45.72 41.71 6,283.67 6,212.70 2,962.51 3,892.64 5,968,766.76 353,374.91 2.06 851.85 MWD+IFR-AK-CAZ-SC(3) 8,431.87 44.27 40.09 6,350.04 6,279.07 3,012.66 3,936.09 5,968,816.01 353,419.35 1.97 876.54 MWD+IFR-AK-CAZ-SC(3) 8,525.54 43.55 36.78 6,417.53 6,346.56 3,063.52 3,976.47 5,968,866.05 353,460.74 2.57 903.28 MWD+IFR-AK-CAZ-SC(3) 8,619.52 44.50 32.56 6,485.12 6,414.15 3,117.22 4,013.59 5,968,919.00 353,498.93 3.28 934.03 MWD+IFR-AK-CAZ-SC(3) 8,715.28 45.40 27.76 6,552.91 6,481.94 3,175.70 4,047.54 5,968,976.77 353,534.04 3.66 970.47 MWD+IFR-AK-CAZ-SC(3) 8,805.96 46.02 22.72 6,616.25 6,545.28 3,234.38 4,075.19 5,969,034.88 353,562.86 4.04 1,009.99 MWD+IFR-AK-CAZ-SC(3) 8,901.74 45.90 17.39 6,682.86 6,611.89 3,299.01 4,098.79 5,969,099.02 353,587.75 4.00 1,056.64 MWD+IFR-AK-CAZ-SC(3) 8,995.49 46.18 12.08 6,747.96 6,676.99 3,364.23 4,115.93 5,969,163.88 353,606.19 4.09 1,106.78 MWD+1FR-AK-CAZ-SC(3) 9,088.29 45.73 7.98 6,812.49 6,741.52 3,429.88 4,127.55 5,969,229.28 353,619.13 3.21 1,159.83 MWD+IFR-AK-CAZ-SC(3) 9,182.28 47.00 3.05 6,877.37 6,806.40 3,497.55 4,134.06 5,969,296.81 353,626.99 4.03 1,217.02 MWD+IFR-AK-CAZ-SC(3) 9,274.68 47.69 358.61 6,939.99 6,869.02 3,565.47 4,135.02 5,969,364.68 353,629.32 3.61 1,276.95 MWD+IFR-AK-CAZ-SC(3) 9,369.88 49.36 352.61 7,003.07 6,932.10 3,636.52 4,129.52 5,969,435.83 353,625.24 5.04 1,342.64 MWD+IFR-AK-CAZ-SC(3) 9,462.86 52.09 348.05 7,061.95 6,990.98 3,707.43 4,117.38 5,969,506.96 353,614.53 4.80 1,411.24 MWD+IFR-AK-CAZ-SC(3) 9,557.13 54.39 346.26 7,118.36 7,047.39 3,781.05 4,100.58 5,969,580.89 353,599.20 2.88 1,484.38 MWD+IFR-AK-CAZ-SC(3) 9,650.90 57.64 344.79 7,170.77 7,099.80 3,856.31 4,081.13 5,969,656.53 353,581.27 3.70 1,560.20 MWD+IFR-AK-CAZ-SC(3) 9,745.03 60.84 343.68 7,218.91 7,147.94 3,934.14 4,059.14 5,969,734.78 353,560.85 3.55 1,639.46 MWD+IFR-AK-CAZ-SC(3) 9,839.71 62.87 344.29 7,263.57 7,192.60 4,014.38 4,036.12 5,969,815.46 353,539.44 2.22 1,721.35 MWD+IFR-AK-CAZ-SC(3) 9,932.23 66.71 343.93 7,302.97 7,232.00 4,094.88 4,013.20 5,969,896.39 353,518.14 4.17 1,803.40 MWD+IFR-AK-CAZ-SC(3) 10,028.08 69.43 343.59 7,338.76 7,267.79 4,180.23 3,988.33 5,969,982.22 353,494.99 2.86 1,890.67 MWD+IFR-AK-CAZ-SC(3) 10,120.11 70.76 341.54 7,370.10 7,299.13 4,262.78 3,962.40 5,970,065.26 353,470.72 2.54 1,975.93 MWD+IFR-AK-CAZ-SC(3) 10,213.13 72.95 338.63 7,399.07 7,328.10 4,345.87 3,932.28 5,970,148.93 353,442.28 3.79 2,063.59 MWD+IFR-AK-CAZ-SC(3) 10,306.10 76.02 337.66 7,423.94 7,352.97 4,429.00 3,898.94 5,970,232.71 353,410.61 3.45 2,152.76 MWD+IFR-AK-CAZ-SC(3) 10,400.15 79.35 335.34 7,444.00 7,373.03 4,513.24 3,862.29 5,970,317.66 353,375.67 4.28 2,244.43 MWD+IFR-AK-CAZ-SC(3) 10,493.06 83.22 332.80 7,458.07 7,387.10 4,595.81 3,822.14 5,970,401.01 353,337.18 4.96 2,336.22 MWD+1FR-AK-CAZ-SC(3) 10,576.70 85.10 332.35 7,466.58 7,395.61 4,669.66 3,783.81 5,970,475.61 353,300.35 2.31 2,419.42 MWD+IFR-AK-CAZ-SC(3) 10,632.59 86.76 332.52 7,470.55 7,399.58 4,719.08 3,758.02 5,970,525.53 353,275.55 2.99 2,475.17 ') 7-5/8"x 9-7/8 by 11" 11161111110 10,667.42 87.80 332.62 7,472.20 7,401.23 4,749.95 3,741.99 5,970,556.72 353,260.14 2.99 2,509.96 MWD+1FR-AK-CAZ-SC(4) 10,762.93 88.81 330.44 7,475.02 7,404.05 4,833.87 3,696.48 5,970,641.53 353,216.33 2.51 2,605.40 MWD+IFR-AK-CAZ-SC(4) 10,858.35 90.75 332.77 7,475.39 7,404.42 4,917.80 3,651.11 5,970,726.35 353,172.66 3.18 2,700.79 MWD+IFR-AK-CAZ-SC(4) 10,953.49 90.88 331.65 7,474.04 7,403.07 5,001.96 3,606.76 5,970,811.37 353,130.00 1.18 2,795.91 MWD+IFR-AK-CAZ-SC(4) 11,048.82 91.30 332.03 7,472.22 7,401.25 5,085.99 3,561.78 5,970,896.28 353,086.72 0.59 2,891.21 MWD+IFR-AK-CAZ-SC(4) 11,144.33 91.23 331.97 7,470.12 7,399.15 5,170.30 3,516.95 5,970,981.46 353,043.59 0.10 2,986.69 MWD+IFR-AK-CAZ-SC(4) 11,240.76 90.04 331.71 7,469.05 7,398.08 5,255.31 3,471.44 5,971,067.36 352,999.81 1.26 3,083.10 MWD+IFR-AK-CAZ-SC(4) 11,334.12 90.65 331.34 7,468.48 7,397.51 5,337.37 3,426.93 5,971,150.30 352,956.95 0.76 3,176.44 MWD+IFR-AK-CAZ-SC(4) 11,429.83 90.70 331.03 7,467.36 7,396.39 5,421.22 3,380.81 5,971,235.05 352,912.52 0.33 3,272.11 MWD+IFR-AK-CAZ-SC(4) 11,524.74 90.98 330.36 7,465.97 7,395.00 5,503.98 3,334.36 5,971,318.71 352,867.74 0.77 3,366.94 MWD+IFR-AK-CAZ-SC(4) 3/9/2016 9:50:57AM Page 5 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,620.21 91.23 329.17 7,464.12 7,393.15 5,586.44 3,286.29 5,971,402.12 352,821.35 1.27 3,462.26 MWD+IFR-AK-CAZ-SC(4) 11,715.87 91.23 329.70 7,462.07 7,391.10 5,668.79 3,237.66 5,971,485.42 352,774.38 0.55 3,557.74 MWD+IFR-AK-CAZ-SC(4) 11,811.46 89.93 330.42 7,461.10 7,390.13 5,751.62 3,189.95 5,971,569.18 352,728.35 1.55 3,653.22 MWD+IFR-AK-CAZ-SC(4) 11,907.45 91.10 329.84 7,460.24 7,389.27 5,834.85 3,142.15 5,971,653.35 352,682.23 1.36 3,749.10 MWD+IFR-AK-CAZ-SC(4) 12,002.98 91.20 331.45 7,458.32 7,387.35 5,918.10 3,095.33 5,971,737.51 352,637.09 1.69 3,844.54 MWD+IFR-AK-CAZ-SC(4) 12,097.82 90.92 331.65 7,456.57 7,385.60 6,001.47 3,050.16 5,971,821.77 352,593.60 0.36 3,939.35 MWD+IFR-AK-CAZ-SC(4) 12,193.67 89.56 330.24 7,456.17 7,385.20 6,085.25 3,003.61 5,971,906.46 352,548.75 2.04 4,035.14 MWD+IFR-AK-CAZ-SC(4) 12,288.67 89.96 331.07 7,456.57 7,385.60 6,168.06 2,957.06 5,971,990.18 352,503.86 0.97 4,130.08 MWD+IFR-AK-CAZ-SC(4) 12,384.01 88.77 331.73 7,457.62 7,386.65 6,251.76 2,911.42 5,972,074.77 352,459.92 1.43 4,225.38 MWD+IFR-AK-CAZ-SC(4) 12,477.98 89.59 333.31 7,458.97 7,388.00 6,335.12 2,868.07 5,972,158.97 352,418.25 1.89 4,319.34 MWD+IFR-AK-CAZ-SC(4) 12,573.97 88.99 333.45 7,460.16 7,389.19 6,420.92 2,825.06 5,972,245.62 352,376.97 0.64 4,415.31 MWD+IFR-AK-CAZ-SC(4) 12,668.39 88.88 333.77 7,461.91 7,390.94 6,505.49 2,783.10 5,972,331.00 352,336.72 0.36 4,509.71 MWD+IFR-AK-CAZ-SC(4) 12,763.66 89.55 332.77 7,463.22 7,392.25 6,590.57 2,740.25 5,972,416.92 352,295.59 1.26 4,604.96 MWD+IFR-AK-CAZ-SC(4) 12,858.92 90.00 334.53 7,463.59 7,392.62 6,675.93 2,697.97 5,972,503.10 352,255.04 1.91 4,700.21 MWD+IFR-AK-CAZ-SC(4) 12,953.60 89.93 333.43 7,463.65 7,392.68 6,761.01 2,656.44 5,972,588.99 352,215.22 1.16 4,794.86 MWD+IFR-AK-CAZ-SC(4) 13,048.70 89.53 333.70 7,464.10 7,393.13 6,846.16 2,614.10 5,972,674.97 352,174.60 0.51 4,889.95 MWD+IFR-AK-CAZ-SC(4) 13,143.82 89.98 333.90 7,464.50 7,393.53 6,931.51 2,572.11 5,972,761.14 352,134.33 0.52 4,985.06 MWD+IFR-AK-CAZ-SC(4) 13,239.99 91.16 334.31 7,463.55 7,392.58 7,018.02 2,530.11 5,972,848.47 352,094.08 1.30 5,081.19 MWD+IFR-AK-CAZ-SC(4) 13,335.06 90.65 334.75 7,462.05 7,391.08 7,103.84 2,489.23 5,972,935.08 352,054.93 0.71 5,176.20 MWD+IFR-AK-CAZ-SC(4) 13,430.19 89.64 334.22 7,461.80 7,390.83 7,189.69 2,448.26 5,973,021.73 352,015.69 1.20 5,271.29 MWD+IFR-AK-CAZ-SC(4) 13,525.32 88.41 333.28 7,463.42 7,392.45 7,274.99 2,406.19 5,973,107.85 351,975.35 1.63 5,366.39 MWD+IFR-AK-CAZ-SC(4) 13,620.69 87.29 333.02 7,467.00 7,396.03 7,360.02 2,363.15 5,973,193.72 351,934.02 1.21 5,461.69 MWD+IFR-AK-CAZ-SC(4) 13,716.78 88.22 331.76 7,470.77 7,399.80 7,445.10 2,318.65 5,973,279.67 351,891.24 1.63 5,557.70 MWD+IFR-AK-CAZ-SC(4) 13,812.73 88.81 331.46 7,473.25 7,402.28 7,529.48 2,273.04 5,973,364.94 351,847.34 0.69 5,653.60 MWD+IFR-AK-CAZ-SC(4) 13,908.38 90.34 332.07 7,473.96 7,402.99 7,613.75 2,227.79 5,973,450.09 351,803.79 1.72 5,749.23 MWD+IFR-AK-CAZ-SC(4) 14,003.87 91.27 331.87 7,472.62 7,401.65 7,698.02 2,182.92 5,973,535.25 351,760.63 1.00 5,844.70 MWD+IFR-AK-CAZ-SC(4) 14,098.71 91.18 330.58 7,470.59 7,399.62 7,781.13 2,137.28 5,973,619.25 351,716.66 1.36 5,939.48 MWD+IFR-AK-CAZ-SC(4) 14,194.87 91.63 330.13 7,468.23 7,397.26 7,864.68 2,089.73 5,973,703.73 351,670.80 0.66 6,035.53 MWD+IFR-AK-CAZ-SC(4) 14,289.29 92.54 331.81 7,464.80 7,393.83 7,947.18 2,043.95 5,973,787.12 351,626.68 2.02 6,129.83 MWD+IFR-AK-CAZ-SC(4) 14,383.91 92.98 330.87 7,460.24 7,389.27 8,030.11 1,998.62 5,973,870.94 351,583.03 1.10 6,224.31 MWD+IFR-AK-CAZ-SC(4) 14,479.48 92.26 330.36 7,455.87 7,384.90 8,113.30 1,951.78 5,973,955.04 351,537.87 0.92 6,319.72 MWD+IFR-AK-CAZ-SC(4) 14,575.23 90.51 330.62 7,453.56 7,382.59 8,196.60 1,904.63 5,974,039.26 351,492.40 1.85 6,415.36 MWD+IFR-AK-CAZ-SC(4) 14,670.15 91.12 331.13 7,452.21 7,381.24 8,279.51 1,858.43 5,974,123.07 351,447.88 0.84 6,510.22 MWD+IFR-AK-CAZ-SC(4) 14,764.80 91.85 331.29 7,449.76 7,378.79 8,362.43 1,812.87 5,974,206.89 351,403.99 0.79 6,604.80 MWD+IFR-AK-CAZ-SC(4) 14,860.61 91.92 331.45 7,446.61 7,375.64 8,446.48 1,766.98 5,974,291.83 351,359.81 0.18 6,700.53 MWD+IFR-AK-CAZ-SC(4) 14,955.73 91.18 332.29 7,444.03 7,373.06 8,530.33 1,722.15 5,974,376.56 351,316.67 1.18 6,795.60 MWD+IFR-AK-CAZ-SC(4) 15,050.78 90.59 333.60 7,442.56 7,371.59 8,614.97 1,678.93 5,974,462.04 351,275.15 1.51 6,890.64 MWD+IFR-AK-CAZ-SC(4) 15,145.48 90.97 332.50 7,441.27 7,370.30 8,699.37 1,636.01 5,974,547.29 351,233.94 1.23 6,985.33 MWD+IFR-AK-CAZ-SC(4) 15,238.20 92.99 334.11 7,438.07 7,367.10 8,782.15 1,594.39 5,974,630.88 351,193.99 2.79 7,077.98 MWD+IFR-AK-CAZ-SC(4) 15,330.57 92.64 333.94 7,433.53 7,362.56 8,865.09 1,553.98 5,974,714.60 351,155.26 0.42 7,170.22 MWD+IFR-AK-CAZ-SC(4) 3/9/2016 9:50:57AM Page 6 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,422.86 91.45 333.93 7,430.24 7,359.27 8,947.94 1,513.45 5,974,798.24 351,116.40 1.29 7,262.43 MWD+IFR-AK-CAZ-SC(4) 15,517.12 92.09 332.13 7,427.33 7,356.36 9,031.91 1,470.73 5,974,883.04 351,075.37 2.03 7,356.64 MWD+IFR-AK-CAZ-SC(5) 15,545.51 91.69 332.35 7,426.39 7,355.42 9,057.02 1,457.51 5,974,908.41 351,062.66 1.61 7,385.01 MWD+IFR-AK-CAZ-SC(5) 15,638.79 90.94 332.72 7,424.25 7,353.28 9,139.76 1,414.50 5,974,991.99 351,021.32 0.90 7,478.26 MWD+IFR-AK-CAZ-SC(5) 15,731.03 90.36 332.58 7,423.21 7,352.24 9,221.68 1,372.13 5,975,074.74 350,980.61 0.65 7,570.50 MWD+IFR-AK-CAZ-SC(5) 15,823.06 90.22 329.82 7,422.74 7,351.77 9,302.32 1,327.80 5,975,156.25 350,937.90 3.00 7,662.48 MWD+IFR-AK-CAZ-SC(5) 15,915.05 89.56 328.71 7,422.92 7,351.95 9,381.39 1,280.78 5,975,236.24 350,892.49 1.40 7,754.30 MWD+IFR-AK-CAZ-SC(5) 16,006.99 89.53 329.57 7,423.65 7,352.68 9,460.31 1,233.63 5,975,316.08 350,846.93 0.94 7,846.05 MWD+IFR-AK-CAZ-SC(5) 16,099.39 90.41 329.28 7,423.70 7,352.73 9,539.86 1,186.63 5,975,396.55 350,801.54 1.00 7,938.30 MWD+IFR-AK-CAZ-SC(5) 16,191.93 90.36 328.13 7,423.07 7,352.10 9,618.93 1,138.56 5,975,476.57 350,755.07 1.24 8,030.60 MWD+IFR-AK-CAZ-SC(5) 16,285.20 90.55 328.37 7,422.33 7,351.36 9,698.24 1,089.48 5,975,556.84 350,707.59 0.33 8,123.58 MWD+IFR-AK-CAZ-SC(5) 16,376.17 90.49 328.44 7,421.51 7,350.54 9,775.73 1,041.82 5,975,635.26 350,661.50 0.10 8,214.28 MWD+IFR-AK-CAZ-SC(5) 16,467.75 91.44 328.74 7,419.97 7,349.00 9,853.87 994.10 5,975,714.34 350,615.36 1.09 8,305.61 MWD+IFR-AK-CAZ-SC(5) 16,559.44 91.54 330.06 7,417.58 7,346.61 9,932.77 947.44 5,975,794.15 350,570.30 1.44 8,397.11 MWD+IFR-AK-CAZ-SC(5) 16,652.29 91.45 328.26 7,415.16 7,344.19 10,012.46 899.86 5,975,874.77 350,524.33 1.94 8,489.74 MWD+IFR-AK-CAZ-SC(5) 16,743.59 91.99 328.57 7,412.42 7,341.45 10,090.20 852.07 5,975,953.45 350,478.10 0.68 8,580.74 MWD+IFR-AK-CAZ-SC(5) 16,833.98 91.97 330.88 7,409.29 7,338.32 10,168.21 806.53 5,976,032.35 350,434.14 2.55 8,670.94 MWD+IFR-AK-CAZ-SC(5) 16,925.13 91.92 331.23 7,406.20 7,335.23 10,247.92 762.44 5,976,112.93 350,391.66 0.39 8,762.00 MWD+IFR-AK-CAZ-SC(5) 17,015.97 91.41 332.60 7,403.56 7,332.59 10,328.03 719.69 5,976,193.87 350,350.53 1.61 8,852.79 MWD+IFR-AK-CAZ-SC(5) 17,108.16 91.57 331.82 7,401.16 7,330.19 10,409.56 676.72 5,976,276.24 350,309.21 0.86 8,944.94 MWD+IFR-AK-CAZ-SC(5) 17,198.53 90.34 330.99 7,399.66 7,328.69 10,488.90 633.48 5,976,356.42 350,267.57 1.64 9,035.27 MWD+IFR-AK-CAZ-SC(5) 17,290.51 90.47 330.92 7,399.01 7,328.04 10,569.31 588.82 5,976,437.70 350,224.54 0.16 9,127.20 MWD+IFR-AK-CAZ-SC(5) 17,382.83 90.50 332.51 7,398.23 7,327.26 10,650.60 545.08 5,976,519.85 350,182.44 1.72 9,219.50 MWD+IFR-AK-CAZ-SC(5) 17,474.50 90.46 334.04 7,397.46 7,326.49 10,732.47 503.86 5,976,602.53 350,142.87 1.67 9,311.16 MWD+IFR-AK-CAZ-SC(5) 17,566.20 90.64 335.36 7,396.58 7,325.61 10,815.37 464.67 5,976,686.19 350,105.36 1.45 9,402.80 MWD+IFR-AK-CAZ-SC(5) 17,657.27 90.53 335.07 7,395.65 7,324.68 10,898.04 426.50 5,976,769.61 350,068.85 0.34 9,493.78 MWD+IFR-AK-CAZ-SC(5) 17,747.01 90.58 334.85 7,394.78 7,323.81 10,979.35 388.52 5,976,851.65 350,032.51 0.25 9,583.45 MWD+IFR-AK-CAZ-SC(5) 17,839.39 90.38 336.19 7,394.01 7,323.04 11,063.42 350.24 5,976,936.46 349,995.93 1.47 9,675.72 MWD+IFR-AK-CAZ-SC(5) 17,934.50 91.45 341.03 7,392.49 7,321.52 11,151.94 315.57 5,977,025.65 349,963.04 5.21 9,770.29 MWD+IFR-AK-CAZ-SC(5) 18,030.22 91.46 340.11 7,390.05 7,319.08 11,242.18 283.73 5,977,116.50 349,933.03 0.96 9,865.09 MWD+IFR-AK-CAZ-SC(5) 18,125.48 91.64 338.05 7,387.48 7,316.51 11,331.12 249.73 5,977,206.11 349,900.82 2.17 9,959.73 MWD+IFR-AK-CAZ-SC(5) 18,220.91 91.08 337.98 7,385.21 7,314.24 11,419.58 214.02 5,977,29526 349,866.89 0.59 10,054.73 MWD+IFR-AK-CAZ-SC(5) 18,316.19 90.75 337.18 7,383.69 7,312.72 11,507.65 177.68 5,977,384.03 349,832.33 0.91 10,149.66 MWD+IFR-AK-CAZ-SC(5) 18,411.54 89.42 337.06 7,383.55 7,312.58 11,595.50 140.61 5,977,472.60 349,797.03 1.40 10,244.73 MWD+IFR-AK-CAZ-SC(5) 18,506.35 89.52 337.16 7,384.43 7,313.46 11,682.84 103.74 5,977,560.65 349,761.92 0.15 10,339.27 MWD+IFR-AK-CAZ-SC(5) 18,602.13 89.02 336.48 7,385.65 7,314.68 11,770.88 66.04 5,977,649.43 349,726.00 0.88 10,434.80 MWD+IFR-AK-CAZ-SC(5) 18,696.64 89.28 334.02 7,387.05 7,316.08 11,856.69 26.48 5,977,736.01 349,688.17 2.62 10,529.20 MWD+IFR-AK-CAZ-SC(5) 18,790.14 89.14 330.16 7,388.34 7,317.37 11,939.29 -17.27 5,977,819.46 349,646.08 4.13 10,622.67 MWD+IFR-AK-CAZ-SC(5) 18,885.26 89.55 328.52 7,389.43 7,318.46 12,021.10 -65.77 5,977,902.23 349,599.23 1.78 10,717.61 MWD+IFR-AK-CAZ-SC(5) 18,981.25 89.15 325.86 7,390.52 7,319.55 12,101.77 -117.78 5,977,983.91 349,548.86 2.80 10,813.13 MWD+IFR-AK-CAZ-SC(5) 3/9/2016 9:50:57AM Page 7 COMPASS 5000.1 Build 74 i r SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67©70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 19,076.68 88.96 326.65 7,392.09 7,321.12 12,181.11 -170.78 5,978,064.29 349,497.46 0.85 10,907.93 MWD+IFR-AK-CAZ-SC(5) 19,171.13 88.96 325.06 7,393.80 7,322.83 12,259.26 -223.79 5,978,143.49 349,446.04 1.68 11,001.68 MWD+IFR-AK-CAZ-SC(5) 19,266.57 89.08 327.18 7,395.44 7,324.47 12,338.48 -276.98 5,978,223.75 349,394.45 2.22 11,096.46 MWD+IFR-AK-CAZ-SC(5) 19,361.81 90.06 326.67 7,396.15 7,325.18 12,418.28 -328.95 5,978,304.58 349,344.09 1.16 11,191.20 MWD+IFR-AK-CAZ-SC(5) 19,457.37 90.98 326.16 7,395.28 7,324.31 12,497.89 -381.81 5,978,385.22 349,292.85 1.10 11,286.17 MWD+IFR-AK-CAZ-SC(5) 19,552.78 92.47 328.97 7,392.41 7,321.44 12,578.37 -432.95 5,978,466.70 349,243.33 3.33 11,381.14 MWD+IFR-AK-CAZ-SC(5) 19,648.29 92.34 331.46 7,388.40 7,317.43 12,661.18 -480.35 5,978,550.44 349,197.61 2.61 11,476.46 MWD+IFR-AK-CAZ-SC(5) 19,743.07 92.42 331.59 7,384.47 7,313.50 12,744.42 -525.50 5,978,634.57 349,154.14 0.16 11,571.14 MWD+IFR-AK-CAZ-SC(5) 19,838.44 92.40 332.55 7,380.46 7,309.49 12,828.61 -570.13 5,978,719.62 349,111.21 1.01 11,666.42 MWD+IFR-AK-CAZ-SC(5) 19,933.96 91.27 332.13 7,377.40 7,306.43 12,913.17 -614.45 5,978,805.05 349,068.60 1.26 11,761.88 MWD+IFR-AK-CAZ-SC(5) 20,029.45 91.51 332.08 7,375.08 7,304.11 12,997.54 -659.11 5,978,890.29 349,025.64 0.26 11,857.34 MWD+IFR-AK-CAZ-SC(5) 20,125.82 90.48 330.74 7,373.41 7,302.44 13,082.14 -705.22 5,978,975.79 348,981.24 1.75 11,953.66 MWD+IFR-AK-CAZ-SC(5) 20,220.30 90.89 330.23 7,372.28 7,301.31 13,164.35 -751.76 5,979,058.92 348,936.36 0.69 12,048.06 MWD+IFR-AK-CAZ-SC(5) 20,316.63 90.80 331.96 7,370.86 7,299.89 13,248.67 -798.32 5,979,144.14 348,891.51 1.80 12,144.34 MWD+IFR-AK-CAZ-SC(5) 20,411.04 90.91 333.99 7,369.45 7,298.48 13,332.76 -841.21 5,979,229.07 348,850.31 2.15 12,238.73 MWD+IFR-AK-CAZ-SC(5) 20,505.80 91.03 334.62 7,367.84 7,296.87 13,418.13 -882.29 5,979,315.25 348,810.96 0.68 12,333.44 MWD+IFR-AK-CAZ-SC(5) 20,601.52 90.79 335.30 7,366.32 7,295.35 13,504.85 -922.80 5,979,402.75 348,772.20 0.75 12,429.08 MWD+IFR-AK-CAZ-SC(5) 20,696.75 91.68 334.00 7,364.27 7,293.30 13,590.88 -963.56 5,979,489.58 348,733.17 1.65 12,524.23 MWD+IFR-AK-CAZ-SC(5) 20,791.85 91.62 333.42 7,361.53 7,290.56 13,676.11 -1,005.66 5,979,575.63 348,692.79 0.61 12,619.28 MWD+IFR-AK-CAZ-SC(5) 20,887.83 92.05 332.20 7,358.46 7,287.49 13,761.44 -1,049.50 5,979,661.81 348,650.68 1.35 12,715.21 MWD+IFR-AK-CAZ-SC(5) 20,982.90 91.86 331.25 7,355.22 7,284.25 13,845.12 -1,094.51 5,979,746.37 348,607.36 1.02 12,810.21 MWD+IFR-AK-CAZ-SC(5) [ 21,042.00 91.99 331.47 7,353.23 7,282.26 13,896.96 -1,122.82 5,979,798.76 348,580.10 0.43 12,869 26 NOT an Actual Sury°:') 4 1/2"x 6-3/4" 21,077.81 92.07 331.60 7,351.96 7,280.99 13,928.42 -1,139.88 5,979,830.55 348,563.68 0.43 12,905.04 MWD+IFR-AK-CAZ-SC(5) 21,173.82 92.43 332.21 7,348.19 7,277.22 14,013.05 -1,185.05 5,979,916.07 348,520.21 0.74 13,000.96 MWD+IFR-AK-CAZ-SC(5) 21,268.72 92.01 331.73 7,344.52 7,273.55 14,096.75 -1,229.62 5,980,000.64 348,477.33 0.67 13,095.78 MWD+IFR-AK-CAZ-SC(5) 21,364.22 91.57 330.77 7,341.53 7,270.56 14,180.44 -1,275.53 5,980,085.23 348,433.11 1.11 13,191.20 MWD+IFR-AK-CAZ-SC(5) 21,459.80 90.30 328.90 7,339.97 7,269.00 14,263.06 -1,323.55 5,980,168.79 348,386.76 2.36 13,286.64 MWD+IFR-AK-CAZ-SC(5) 21,555.29 90.79 326.90 7,339.07 7,268.10 14,343.94 -1,374.29 5,980,250.66 348,337.66 2.16 13,381.77 MWD+IFR-AK-CAZ-SC(5) 21,649.47 90.05 327.84 7,338.38 7,267.41 14,423.25 -1,425.07 5,980,330.97 348,288.49 1.27 13,475.53 MWD+IFR-AK-CAZ-SC(5) 21,744.96 89.57 327.51 7,338.69 7,267.72 14,503.94 -1,476.13 5,980,412.67 348,239.06 0.61 13,570.65 MWD+IFR-AK-CAZ-SC(5) 21,840.13 88.99 326.96 7,339.89 7,268.92 14,583.97 -1,527.63 5,980,493.70 348,189.18 0.84 13,665.37 MWD+IFR-AK-CAZ-SC(5) 21,936.41 88.34 328.04 7,342.13 7,271.16 14,665.14 -1,579.34 5,980,575.89 348,139.10 1.31 13,761.21 MWD+IFR-AK-CAZ-SC(5) 22,030.46 87.50 327.52 7,345.54 7,274.57 14,744.66 -1,629.46 5,980,656.39 348,090.60 1.05 13,854.85 MWD+IFR-AK-CAZ-SC(5) 22,125.64 87.65 329.01 7,349.57 7,278.60 14,825.53 -1,679.47 5,980,738.24 348,042.22 1.57 13,949.65 MWD+IFR-AK-CAZ-SC(5) 22,220.93 88.10 330.67 7,353.11 7,282.14 14,907.86 -1,727.31 5,980,821.51 347,996.04 1.80 14,044.75 MWD+IFR-AK-CAZ-SC(5) 22,315.98 88.67 334.61 7,355.79 7,284.82 14,992.23 -1,770.97 5,980,906.73 347,954.09 4.19 14,139.74 MWD+IFR-AK-CAZ-SC(5) 22,412.47 89.09 335.85 7,357.67 7,286.70 15,079.82 -1,811.39 5,980,995.11 347,915.44 1.36 14,236.12 MWD+IFR-AK-CAZ-SC(5) 22,507.31 89.99 335.67 7,358.43 7,287.46 15,166.30 -1,850.32 .5,981,082.34 347,878.25 0.97 14,330.82 MWD+IFR-AK-CAZ-SC(5) 22,602.20 90.96 337.52 7,357.65 7,286.68 15,253.37 -1,888.01 5,981,170.15 347,842.31 2.20 14,425.49 MWD+IFR-AK-CAZ-SC(5) 3/9/2016 9:50:57AM Page 8 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 22,697.43 90.98 335.77 7,356.03 7,285.06 15,340.78 -1,925.76 5,981,258.29 347,806.33 1.84 14,520.49 MWD+IFR-AK-CAZ-SC(5) 22,792.83 90.83 333.38 7,354.53 7,283.56 15,426.93 -1,966.71 5,981,345.23 347,767.12 2.51 14,615.82 MWD+IFR-AK-CAZ-SC(5) 22,889.07 91.57 333.54 7,352.51 7,281.54 15,513.01 -2,009.70 5,981,432.15 347,725.87 0.79 14,712.03 MWD+IFR-AK-CAZ-SC(5) 22,984.65 91.32 334.30 7,350.10 7,279.13 15,598.83 -2,051.71 5,981,518.79 347,685.59 0.84 14,807.56 MWD+IFR-AK-CAZ-SC(5) 23,078.76 91.56 333.25 7,347.74 7,276.77 15,683.22 -2,093.28 5,981,603.99 347,645.72 1.14 14,901.62 MWD+IFR-AK-CAZ-SC(5) 23,174.20 91.88 330.28 7,344.87 7,273.90 15,767.26 -2,138.41 5,981,688.91 347,602.30 3.13 14,996.99 MWD+IFR-AK-CAZ-SC(5) 23,270.32 91.99 326.32 7,341.62 7,270.65 15,848.98 -2,188.88 5,981,771.62 347,553.48 4.12 15,092.75 MWD+IFR-AK-CAZ-SC(5) 23,365.89 90.95 323.14 7,339.17 7,268.20 15,926.97 -2,244.03 5,981,850.69 347,499.90 3.50 15,187.34 MWD+IFR-AK-CAZ-SC(5) 23,458.57 91.33 323.38 7,337.33 7,266.36 16,001.22 -2,299.46 5,981,926.04 347,445.97 0.48 15,278.73 MWD+IFR-AK-CAZ-SC(5) 23,555.68 90.31 327.01 7,335.94 7,264.97 16,080.94 -2,354.88 5,982,006.84 347,392.17 3.88 15,374.97 MWD+IFR-AK-CAZ-SC(5) 23,651.61 88.69 333.36 7,336.78 7,265.81 16,164.12 -2,402.55 5,982,090.96 347,346.19 6.83 15,470.75 MWD+IFR-AK-CAZ-SC(5) 23,711.00 88.69 333.36 7,338.13 7,267.16 16,217.19 -2,429.17 5,982,144.55 347,320.64 0.00 15,530.12 3/9/2016 9:50:57AM Page 9 COMPASS 5000.1 Build 74 • • CS k -o co b %...o [ m 2 �,� \ f \ q m 2 CO asa_ & $ k 2 6 3 O co E 2 4 . 0E / a) k ? © - fCD IIP:1! crt � 9 \ W T 2 § ƒE & � CD \ ` j ° c m � co / 0 ¢ w f � � IE > •/ El ° k k § $ q "0 0 U 2 2 ▪c E rt 2 cz U U .Q. CD ' ° 2 R E 5 E _ CI » ® U - / 7 CL 0 2 0 k / > O o _2 2 2 / ® / c o 4.1 ƒ t / 3 O .� R rci a) ° ELM E 2 ■ k ai .> dL' 2 6 / a) CC E c_) • • 21 60 04 27048 RECEIVED APR 19 2015 FINAL AOGCC ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad CD5-07 CD5-07 NAD 83 Definitive Survey Report 08 March, 2016 • 0 SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well CD5-07 Well Position +N/-S 0.00 usft Northing: 5,965,629.08 usft Latitude: 70°18'48.812 N +E/-W 0.00 usft Easting: 1,489,457.08 usft Longitude: 151°13'24.724 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.30 usft Wellbore CD5-07 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 2/11/2016 17.78 80.83 57,469 Design CD5-07 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.67 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 36.67 0.00 0.00 332.76 Survey Program Date 3/8/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 67.00 735.00 CD5-07 Svy1 SLB_NSG+SSHOT(CD5-0 GYD-GC-SS Gyrodata gyro single shots 2/5/2016 3:01:4 761.28 2,224.93 CD5-07 Svy2 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 10:41:0 2,325.70 10,576.70 CD5-07 Svy3 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/9/2016 9:05:0, 10,667.42 15,422.86 CD5-07 Svy4 SLB_MWD_GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/19/2016 2:12: 15,517.12 23,651.61 CD5-07 SvyS SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2016 2:16: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.67 0.00 0.00 36.67 -34.30 0.00 0.00 5,965,629.08 1,489.457.08 0.00 0.00 UNDEFINED 67.00 0.29 106.91 67.00 -3.97 -0.02 0.07 5,965,629.06 1,489,457.15 0.96 -0.05 GYD-GC-SS(1) 115.00 0.32 55.24 115.00 44.03 0.02 0.30 5,965,629.09 1,489,457.38 0.56 -0.12 20".x42" �.' !Er!' 167.00 0.54 28.08 167.00 96.03 0.32 0.54 5,965,629.39 1,489,457.62 0.56 0.04 GYD-GC-SS(1) 267.00 0.45 336.17 266.99 196.02 1.09 0.60 5,965,630.16 1,489,457.70 0.44 0.70 GYD-GC-SS(1) 367.00 0.70 22.61 366.99 296.02 2.02 0.68 5,965,631.08 1,489,457.80 0.51 1.48 GYD-GC-SS(1) 459.00 0.68 5.64 458.98 388.01 3.08 0.95 5,965,632.14 1,489,458.09 0.22 2.31 GYD-GC-SS(1) 578.00 0.86 333.70 577.97 507.00 4.58 0.62 5,965,633.65 1,489,457.79 0.38 3.79 GYD-GC-SS(1) 643.00 1.37 302.71 642.96 571.99 5.44 -0.25 5,965,634.52 1,489,456.94 1.19 4.95 GYD-GC-SS(1) 735.00 1.17 306.33 734.94 663.97 6.59 -1.93 5,965,635.71 1,489,455.28 0.23 6.74 GYD-GC-SS(1) 3/8/2016 3:45:17PM Page 2 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 761.28 0.85 293.88 761.21 690.24 6.83 -2.33 5,965,635.95 1,489,454.89 1.47 7.14 MWD+IFR-AK-CAZ-SC(2) 856.25 1.23 35.69 856.17 785.20 7.94 -2.38 5,965,637.07 1,489,454.86 1.72 8.15 MWD+IFR-AK-CAZ-SC(2) 950.56 3.59 51.24 950.40 879.43 10.61 0.52 5,965,639.68 1,489,457.81 2.57 9.20 MWD+IFR-AK-CAZ-SC(2) 1,044.15 4.37 62.89 1,043.76 972.79 14.07 5.98 5,965,643.03 1,489,463.34 1.20 9.78 MWD+IFR-AK-CAZ-SC(2) 1,138.30 7.02 65.54 1,137.44 1,066.47 18.09 14.41 5,965,646.88 1,489,471.85 2.83 9.49 MWD+IFR-AK-CAZ-SC(2) 1,232.49 10.17 68.32 1,230.56 1,159.59 23.55 27.38 5,965,652.07 1,489,484.92 3.37 8.40 MWD+IFR-AK-CAZ-SC(2) 1,326.95 12.50 69.84 1,323.17 1,252.20 30.15 44.73 5,965,658.32 1,489,502.40 2.49 6.33 MWD+IFR-AK-CAZ-SC(2) 1,419.97 14.74 68.98 1,413.57 1,342.60 37.87 65.22 5,965,665.62 1,489,523.05 2.42 3.81 MWD+IFR-AK-CAZ-SC(2) 1,514.24 17.28 67.60 1,504.17 1,433.20 47.51 89.37 5,965,674.78 1,489,547.38 2.72 1.32 MWD+IFR-AK-CAZ-SC(2) 1,609.01 19.88 66.82 1,594.00 1,523.03 59.21 117.20 5,965,685.92 1,489,575.44 2.76 -1.01 MWD+IFR-AK-CAZ-SC(2) 1,702.91 22.99 62.96 1,681.40 1,610.43 73.84 148.22 5,965,699.92 1,489,606.74 3.64 -2.20 MWD+IFR-AK-CAZ-SC(2) 1,797.50 25.46 58.78 1,767.66 1,696.69 92.78 182.06 5,965,718.17 1,489,640.96 3.18 -0.86 MWD+IFR-AK-CAZ-SC(2) 1,891.98 27.12 59.18 1,852.36 1,781.39 114.34 217.93 5,965,739.01 1,489,677.25 1.77 1.89 MWD+IFR-AK-CAZ-SC(2) 1,986.37 28.60 61.50 1,935.81 1,864.84 136.14 256.26 5,965,760.03 1,489,716.01 1.94 3.73 MWD+IFR-AK-CAZ-SC(2) 2,081.14 31.20 62.94 2,017.96 1,946.99 158.14 298.06 5,965,781.18 1,489,758.24 2.85 4.15 MWD+IFR-AK-CAZ-SC(2) 2,173.72 34.75 62.15 2,095.61 2,024.64 181.38 342.76 5,965,803.52 1,489,803.39 3.86 4.35 MWD+IFR-AK-CAZ-SC(2) 2,224.93 35.92 61.24 2,137.39 2,066.42 195.43 368.83 5,965,817.04 1,489,829.74 2.51 4.90 MWD+IFR-AK-CAZ-SC(2) 2,290.63 36.43 59.40 2,190.43 2,119.46 214.63 402.52 5,965,835.56 1,489,863.80 1.83 10-3/4"x 13-1/2" _ 2,325.70 36.71 58.43 2,218.59 2,147.62 225.42 420.41 5,965,845.98 1,489,881.91 1.83 7.95 MWD+IFR-AK-CAZ-SC(3) 2,419.66 38.23 58.70 2,293.16 2,222.19 255.23 469.18 5,965,874.80 1,489,931.26 1.63 12.13 MWD+IFR-AK-CAZ-SC(3) 2,514.11 41.01 59.29 2,365.91 2,294.94 286.24 520.81 5,965,904.77 1,489,983.50 2.97 16.07 MWD+IFR-AK-CAZ-SC(3) 2,607.05 43.35 58.39 2,434.78 2,363.81 318.54 574.20 5,965,935.99 1,490,037.52 2.60 20.34 MWD+IFR-AK-CAZ-SC(3) 2,701.24 45.87 56.51 2,501.83 2,430.86 354.14 629.93 5,965,970.46 1,490,093.96 3.02 26.48 MWD+IFR-AK-CAZ-SC(3) 2,792.74 47.79 55.15 2,564.43 2,493.46 391.63 685.13 5,966,006.83 1,490,149.90 2.36 34.54 MWD+IFR-AK-CAZ-SC(3) 2,887.28 48.29 53.48 2,627.64 2,556.67 432.64 742.23 5,966,046.68 1,490,207.80 1.42 44.86 MWD+IFR-AK-CAZ-SC(3) 2,981.53 48.25 52.43 2,690.38 2,619.41 475.01 798.37 5,966,087.91 1,490,264.78 0.83 56.83 MWD+IFR-AK-CAZ-SC(3) 3,077.10 48.19 52.03 2,754.06 2,683.09 518.66 854.70 5,966,130.42 1,490,321.97 0.32 69.85 MWD+IFR-AK-CAZ-SC(3) 3,171.03 47.29 52.48 2,817.22 2,746.25 561.22 909.67 5,966,171.86 1,490,377.78 1.02 82.52 MWD+IFR-AK-CAZ-SC(3) 3,263.93 47.15 52.71 2,880.32 2,809.35 602,64 963.84 5,966,212.17 1,490,432.76 0.24 94.55 MWD+IFR-AK-CAZ-SC(3) 3,359.85 47.24 53.50 2,945.50 2,874.53 644.89 1,020.11 5,966,253.28 1,490,489.88 0.61 106.35 MWD+IFR-AK-CAZ-SC(3) 3,453.34 47.20 53.76 3,009.00 2,938.03 685.58 1,075.37 5,966,292.85 1,490,545.93 0.21 117.23 MWD+IFR-AK-CAZ-SC(3) 3,547.95 47.19 52.81 3,073.28 3,002.31 727.07 1,131.01 5,966,333.21 1,490,602.39 0.74 128.65 MWD+IFR-AK-CAZ-SC(3) 3,639.65 47.22 51.78 3,135.58 3,064.61 768.22 1,184.24 5,966,373.28 1,490,656.44 0.82 140.87 MWD+IFR-AK-CAZ-SC(3) 3,735.76 47.23 51.71 3,200.85 3,129.88 811.91 1,239.64 5,966,415.84 1,490,712.70 0.05 154.34 MWD+IFR-AK-CAZ-SC(3) 3,829.16 47.24 52.27 3,264.27 3,193.30 854.13 1,293.67 5,966,456.97 1,490,767.56 0.44 167.15 MWD+IFR-AK-CAZ-SC(3) 3,922.28 47.14 51.79 3,327.55 3,256.58 896.16 1,347.52 5,966,497.90 1,490,822.25 0.39 179.86 MWD+IFR-AK-CAZ-SC(3) 4,016.70 47.67 51.79 3,391.46 3,320.49 939.15 1,402.14 5,966,539.78 1,490,877.71 0.56 193.08 MWD+IFR-AK-CAZ-SC(3) 4,112.22 47.69 51.22 3,455.77 3,384.80 983.11 1,457.41 5,966,582.62 1,490,933.86 0.44 206.86 MWD+IFR-AK-CAZ-SC(3) 4,204.95 47.70 49.92 3,518.19 3,447.22 1,026.67 1,510.38 5,966,625.10 1,490,987.69 1.04 221.34 MWD+IFR-AK-CAZ-SC(3) 3/8/2016 3:45:17PM Page 3 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,298.49 47.98 49.30 3,580.97 3,510.00 1,071.60 1,563.19 5,966,668.96 1,491,041.39 0.58 237.11 MWD+IFR-AK-CAZ-SC(3) 4,393.02 48.12 49.12 3,644.16 3,573.19 1,117.53 1,616.42 5,966,713.80 1,491,095.52 0.20 253.57 MWD+IFR-AK-CAZ-SC(3) 4,487.10 48.14 49.23 3,706.95 3,635.98 1,163.33 1,669.43 5,966,758.53 1,491,149.44 0.09 270.02 MWD+IFR-AK-CAZ-SC(3) 4,580.41 48.07 49.65 3,769.26 3,698.29 1,208.49 1,722.20 5,966,802.62 1,491,203.10 0.34 286.02 MWD+IFR-AK-CAZ-SC(3) 4,674.92 48.32 50.96 3,832.27 3,761.30 1,253.49 1,776.41 5,966,846.51 1,491,258.20 1.07 301.21 MWD+IFR-AK-CAZ-SC(3) 4,769.15 48.33 51.29 3,894.92 3,823.95 1,297.66 1,831.20 5,966,889.57 1,491,313.87 0.26 315.40 MWD+IFR-AK-CAZ-SC(3) 4,862.39 48.21 51.80 3,956.98 3,886.01 1,340.94 1,885.69 5,966,931.73 1,491,369.21 0.43 328.92 MWD+IFR-AK-CAZ-SC(3) 4,956.93 48.23 51.95 4,019.97 3,949.00 1,384.46 1,941.15 5,966,974.13 1,491,425.53 0.12 342.23 MWD+IFR-AK-CAZ-SC(3) 5,050.59 48.24 52.07 4,082.36 4,011.39 1,427.46 1,996.21 5,967,016.01 1,491,481.44 0.10 355.26 MWD+IFR-AK-CAZ-SC(3) 5,145.01 48.26 52.65 4,145.23 4,074.26 1,470.48 2,051.99 5,967,057.90 1,491,538.07 0.46 367.97 MWD+IFR-AK-CAZ-SC(3) 5,239.59 48.21 52.72 4,208.23 4,137.26 1,513.24 2,108.10 5,967,099.52 1,491,595.02 0.08 380.30 MWD+IFR-AK-CAZ-SC(3) 5,334.45 48.18 52.78 4,271.46 4,200.49 1,556.04 2,164.38 5,967,141.18 1,491,652.15 0.06 392.59 MWD+IFR-AK-CAZ-SC(3) 5,428.66 48.17 53.17 4,334.29 4,263.32 1,598.32 2,220.43 5,967,182.32 1,491,709.03 0.31 404.52 MWD+IFR-AK-CAZ-SC(3) 5,523.07 48.22 53.08 4,397.22 4,326.25 1,640.55 2,276.73 5,967,223.40 1,491,766.16 0.09 416.29 MWD+IFR-AK-CAZ-SC(3) 5,617.38 47.69 53.55 4,460.38 4,389.41 1,682.39 2,332.89 5,967,264.10 1,491,823.15 0.67 427.78 MWD+IFR-AK-CAZ-SC(3) 5,710.49 47.82 53.37 4,522.98 4,452.01 1,723.43 2,388.27 5,967,304.02 1,491,879.34 0.20 438.91 MWD+IFR-AK-CAZ-SC(3) 5,805.00 47.83 52.64 4,586.43 4,515.46 1,765.57 2,444.21 5,967,345.03 1,491,936.11 0.57 450.77 MWD+IFR-AK-CAZ-SC(3) 5,900.24 47.74 52.64 4,650.42 4,579.45 1,808.38 2,500.28 5,967,386.69 1,491,993.02 0.09 463.16 MWD+IFR-AK-CAZ-SC(3) 5,994.00 47.78 52.78 4,713.45 4,642.48 1,850.43 2,555.50 5,967,427.62 1,492,049.08 0.12 475.27 MWD+IFR-AK-CAZ-SC(3) 6,087.60 47.65 51.51 4,776.43 4,705.46 1,892.92 2,610.17 5,967,469.01 1,492,104.59 1.01 488.02 MWD+IFR-AK-CAZ-SC(3) 6,181.45 48.14 51.38 4,839.36 4,768.39 1,936.32 2,664.62 5,967,511.30 1,492,159.90 0.53 501.67 MWD+IFR-AK-CAZ-SC(3) 6,275.65 48.21 50.96 4,902.17 4,831.20 1,980.34 2,719.31 5,967,554.20 1,492,215.45 0.34 515.77 MWD+IFR-AK-CAZ-SC(3) 6,369.64 48.12 50.19 4,964.87 4,893.90 2,024.81 2,773.40 5,967,597.57 1,492,270.42 0.62 530.55 MWD+IFR-AK-CAZ-SC(3) 6,462.74 48.13 50.53 5,027.01 4,956.04 2,069.03 2,826.78 5,967,640.71 1,492,324.68 0.27 545.43 MWD+IFR-AK-CAZ-SC(3) 6,555.83 48.01 50.24 5,089.22 5,018.25 2,113.19 2,880.13 5,967,683.78 1,492,378.90 0.27 560.26 MWD+IFR-AK-CAZ-SC(3) 6,649.56 48.17 50.07 5,151.82 5,080.85 2,157.88 2,933.69 5,967,727.39 1,492,433.34 0.22 575.48 MWD+IFR-AK-CAZ-SC(3) 6,743.54 48.13 49.45 5,214.53 5,143.56 2,203.11 2,987.13 5,967,771.52 1,492,487.67 0.49 591.22 MWD+IFR-AK-CAZ-SC(3) 6,837.55 48.24 49.23 5,277.20 5,206.23 2,248.76 3,040.28 5,967,816.09 1,492,541.73 0.21 607.48 MWD+IFR-AK-CAZ-SC(3) 6,931.54 48.14 48.98 5,339.86 5,268.89 2,294.62 3,093.23 5,967,860.88 1,492,595.59 0.22 624.01 MWD+IFR-AK-CAZ-SC(3) 7,025.39 48.05 49.33 5,402.55 5,331.58 2,340.30 3,146.07 5,967,905.49 1,492,649.33 0.29 640.44 MWD+IFR-AK-CAZ-SC(3) 7,119.36 47.84 49.51 5,465.49 5,394.52 2,385.69 3,199.06 5,967,949.80 1,492,703.22 0.26 656.53 MWD+IFR-AK-CAZ-SC(3) 7,212.97 48.10 49.37 5,528.17 5,457.20 2,430.91 3,251.89 5,967,993.94 1,492,756.94 0.30 672.55 MWD+IFR-AK-CAZ-SC(3) 7,306.35 48.12 49.87 5,590.52 5,519.55 2,475.94 3,304.84 5,968,037.89 1,492,810.79 0.40 688.34 MWD+IFR-AK-CAZ-SC(3) 7,400.38 48.04 51.38 5,653.34 5,582.37 2,520.32 3,358.92 5,968,081.18 1,492,865.75 1.20 703.05 MWD+IFR-AK-CAZ-SC(3) 7,494.86 48.09 52.34 5,716.48 5,645.51 2,563.73 3,414.20 5,968,123.46 1,492,921.88 0.76 716.33 MWD+IFR-AK-CAZ-SC(3) 7,588.29 48.18 52.17 5,778.83 5,707.86 2,606.32 3,469,22 5,968,164.94 1,492,977.74 0.17 729.01 MWD+IFR-AK-CAZ-SC(3) 7,682.26 48.26 52.12 5,841.44 5,770.47 2,649.32 3,524.55 5,968,206.81 1,493,033.92 0.09 741.91 MWD+IFR-AK-CAZ-SC(3) 7,776.48 48.09 52.39 5,904.27 5,833.30 2,692.30 3,580.07 5,968,248.67 1,493,090.29 0.28 754.71 MWD+IFR-AK-CAZ-SC(3) 7,870.36 47.89 51.87 5,967.10 5,896.13 2,735.12 3,635.13 5,968,290.37 1,493,146.20 0.46 767.57 MWD+IFR-AK-CAZ-SC(3) 7,963.57 47.99 51.64 6,029.55 5,958.58 2,777.96 3,689.48 5,968,332.10 1,493,201.39 0.21 780.78 MWD+IFR-AK-CAZ-SC(3) 3/8/2016 3:45:17PM Page 4 COMPASS 5000.1 Build 74 • • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 8,056.94 47.96 51.51 6,092.05 6,021.08 2,821.07 3,743.82 5,968,374.10 1,493,256.58 0.11 794.22 MWD+IFR-AK-CAZ-SC(3) 8,149.64 47.46 48.74 6,154.44 6,083.47 2,865.02 3,796.44 5,968,416.98 1,493,310.07 2.28 809.21 MWD+IFR-AK-CAZ-SC(3) 8,244.36 46.79 43.94 6,218.90 6,147.93 2,912.90 3,846.64 5,968,463.84 1,493,361.22 3.78 828.80 MWD+IFR-AK-CAZ-SC(3) 8,338.02 45.72 41.71 6,283.67 6,212.70 2,962.51 3,892.64 5,968,512.52 1,493,408.20 2.06 851.85 MWD+IFR-AK-CAZ-SC(3) 8,431.87 44.27 40.09 6,350.04 6,279.07 3,012.66 3,936.09 5,968,561.77 1,493,452.65 1.97 876.54 MWD+IFR-AK-CAZ-SC(3) 8,525.54 43.55 36.78 6,417.53 6,346.56 3,063.52 3,976.47 5,968,611.81 1,493,494.04 2.57 903.28 MWD+IFR-AK-CAZ-SC(3) 8,619.52 44.50 32.56 6,485.12 6,414.15 3,117.22 4,013.59 5,968,664.75 1,493,532.23 3.28 934.03 MWD+IFR-AK-CAZ-SC(3) 8,715.28 45.40 27.76 6,552.91 6,481.94 3,175.70 4,047.54 5,968,722.53 1,493,567.35 3.66 970.47 MWD+IFR-AK-CAZ-SC(3) 8,805.96 46.02 22.72 6,616.25 6,545.28 3,234.38 4,075.19 5,968,780.64 1,493,596.17 4.04 1,009.99 MWD+IFR-AK-CAZ-SC(3) 8,901.74 45.90 17.39 6,682.86 6,611.89. 3,299.01 4,098.79 5,968,844.77 1,493,621.06 4.00 1,056.64 MWD+IFR-AK-CAZ-SC(3) 8,995.49 46.18 12.08 6,747.96 6,676.99 3,364.23 4,115.93 5,968,909.63 1,493,639.51 4.09 1,106.78 MWD+IFR-AK-CAZ-SC(3) 9,088.29 45.73 7.98 6,812.49 6,741.52 3,429.88 4,127.55 5,968,975.03 1,493,652.45 3.21 1,159.83 MWD+IFR-AK-CAZ-SC(3) 9,182.28 47.00 3.05 6,877.37 6,806.40 3,497.55 4,134.06 5,969,042.56 1,493,660.31 4.03 1,217.02 MWD+IFR-AK-CAZ-SC(3) 9,274.68 47.69 358.61 6,939.99 6,869.02 3,565.47 4,135.02 5,969,110.43 1,493,662.64 3.61 1,276.95 MWD+IFR-AK-CAZ-SC(3) 9,369.88 49.36 352.61 7,003.07 6,932.10 3,636.52 4,129.52 5,969,181.58 1,493,658.57 5.04 1,342.64 MWD+IFR-AK-CAZ-SC(3) 9,462.86 52.09 348.05 7,061.95 6,990.98 3,707.43 4,117.38 5,969,252.70 1,493,647.86 4.80 1,411.24 MWD+IFR-AK-CAZ-SC(3) 9,557.13 54.39 346.26 7,118.36 7,047.39 3,781.05 4,100.58 5,969,326.64 1,493,632.54 2.88 1,484.38 MWD+IFR-AK-CAZ-SC(3) 9,650.90 57.64 344.79 7,170.77 7,099.80 3,856.31 4,081.13 5,969,402.28 1,493,614.61 3.70 1,560.20 MWD+IFR-AK-CAZ-SC(3) 9,745.03 60.84 343.68 7,218.91 7,147.94 3,934.14 4,059.14 5,969,480.53 1,493,594.19 3.55 1,639.46 MWD+IFR-AK-CAZ-SC(3) 9,839.71 62.87 344.29 7,263.57 7,192.60 4,014.38 4,036.12 5,969,561.21 1,493,572.79 2.22 1,721.35 MWD+IFR-AK-CAZ-SC(3) 9,932.23 66.71 343.93 7,302.97 7,232.00 4,094.88 4,013.20 5,969,642.14 1,493,551.49 4.17 1,803.40 MWD+IFR-AK-CAZ-SC(3) 10,028.08 69.43 343.59 7,338.76 7,267.79 4,180.23 3,988.33 5,969,727.98 1,493,528.35 2.86 1,890.67 MWD+IFR-AK-CAZ-SC(3) 10,120.11 70.76 341.54 7,370.10 7,299.13 4,262.78 3,962.40 5,969,811.02 1,493,504.09 2.54 1,975.93 MWD+IFR-AK-CAZ-SC(3) 10,213.13 72.95 338.63 7,399.07 7,328.10 4,345.87 3,932.28 5,969,894.69 1,493,475.65 3.79 2,063.59 MWD+IFR-AK-CAZ-SC(3) 10,306.10 76.02 337.66 7,423.94 7,352.97 4,429.00 3,898.94 5,969,978.47 1,493,443.98 3.45 2,152.76 MWD+IFR-AK-CAZ-SC(3) 10,400.15 79.35 335.34 7,444.00 7,373.03 4,513.24 3,862.29 5,970,063.43 1,493,409.04 4.28 2,244.43 MWD+IFR-AK-CAZ-SC(3) 10,493.06 83.22 332.80 7,458.07 7,387.10 4,595.81 3,822.14 5,970,146.77 1,493,370.56 4.96 2,336.22 MWD+IFR-AK-CAZ-SC(3) 10,576.70 85.10 332.35 7,466.58 7,395.61 4,669.66 3,783.81 5,970,221.38 1,493,333.73 2.31 2,419.42 MWD+IFR-AK-CAZ-SC(3) 10,632.59 86.76 332.52 7,470.55 7,399.58 4,719.08 3,758.02 5,970,271.30 1,493,308.93 2.99 2,475 17 ) 7-8/8"x 9-7/8 by 11" 10,667.42 87.80 332.62 7,472.20 7,401.23 4,749.95 3,741.99 5,970,302.49 1,493,293.53 2.99 2,509.96 MWD+IFR-AK-CAZ-SC(4) 10,762.93 88.81 330.44 7,475.02 7,404.05 4,833.87 3,696.48 5,970,387.30 1,493,249.72 2.51 2,605.40 MWD+IFR-AK-CAZ-SC(4) 10,858.35 90.75 332.77 7,475.39 7,404.42 4,917.80 3,651.11 5,970,472.12 1,493,206.05 3.18 2,700.79 MWD+IFR-AK-CAZ-SC(4) 10,953.49 90.88 331.65 7,474.04 7,403.07 5,001.96 3,606.76 5,970,557.14 1,493,163.40 1.18 2,795.91 MWD+IFR-AK-CAZ-SC(4) 11,048.82 91.30 332.03 7,472.22 7,401.25 5,085.99 3,561.78 5,970,642.06 1,493,120.12 0.59 2,891.21 MWD+IFR-AK-CAZ-SC(4) 11,144.33 91.23 331.97 7,470.12 7,399.15 5,170.30 3,516.95 5,970,727.24 1,493,077.00 0.10 2,986.69 MWD+IFR-AK-CAZ-SC(4) 11,240.76 90.04 331.71 7,469.05 7,398.08 5,255.31 3,471.44 5,970,813.14 1,493,033.22 1.26 3,083.10 MWD+IFR-AK-CAZ-SC(4) 11,334.12 90.65 331.34 7,468.48 7,397.51 5,337.37 3,426.93 5,970,896.08 1,492,990.37 0.76 3,176.44 MWD+IFR-AK-CAZ-SC(4) 11,429.83 90.70 331.03 7,467.36 7,396.39 5,421.22 3,380.81 5,970,980.84 1,492,945.94 0.33 3,272.11 MWD+IFR-AK-CAZ-SC(4) 11,524.74 90.98 330.36 7,465.97 7,395.00 5,503.98 3,334.36 5,971,064.50 1,492,901.17 0.77 3,366.94 MWD+IFR-AK-CAZ-SC(4) 3/8/2016 3:45:17PM Page 5 COMPASS 5000.1 Build 74 III/ • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67©70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,620.21 91.23 329.17 7,464.12 7,393.15 5,586.44 3,286.29 5.971,147.91 1,492,854.78 1.27 3,462.26 MWD+IFR-AK-CAZ-SC(4) 11,715.87 91.23 329.70 7,462.07 7,391.10 5,668.79 3,237.66 5,971,231.22 1,492,807.81 0.55 3,557.74 MWD+IFR-AK-CAZ-SC(4) 11,811.46 89.93 330.42 7,461.10 7,390.13 5,751.62 3,189.95 5,971,314.98 1,492,761.79 1.55 3,653.22 MWD+IFR-AK-CAZ-SC(4) 11,907.45 91.10 329.84 7,460.24 7,389.27 5,834.85 3,142.15 5,971,399.15 1,492,715.67 1.36 3,749.10 MWD+1FR-AK-CAZ-SC(4) 12,002.98 91.20 331.45 7,458.32 7,387.35 5,918.10 3,095.33 5,971,483.31 1,492,670.54 1.69 3,844.54 MWD+IFR-AK-CAZ-SC(4) 12,097.82 90.92 331.65 7,456.57 7,385.60 6,001.47 3,050.16 5,971,567.57 1,492,627.05 0.36 3,939.35 MWD+1FR-AK-CAZ-SC(4) 12,193.67 89.56 330.24 7,456.17 7,385.20 6,085.25 3,003.61 5,971,652.27 1,492,582.20 2.04 4,035.14 MWD+IFR-AK-CAZ-SC(4) 12,288.67 89.96 331.07 7,456.57 7,385.60 6,168.06 2,957.06 5,971,735.99 1,492,537.32 0.97 4,130.08 MWD+IFR-AK-CAZ-SC(4) 12,384.01 88.77 331.73 7,457.62 7,386.65 6,251.76 2,911.42 5,971,820.58 1,492,493.39 1.43 4,225.38 MWD+IFR-AK-CAZ-SC(4) 12,477.98 89.59 333.31 7,458.97 7,388.00 6,335.12 2,868.07 5,971,904.79 1,492,451.72 1.89 4,319.34 MWD+1FR-AK-CAZ-SC(4) 12,573.97 88.99 333.45 7,460.16 7,389.19 6,420.92 2,825.06 5,971,991.43 1,492,410,45 0.64 4,415.31 MWD+1FR-AK-CAZ-SC(4) 12,668.39 88.88 333.77 7,461.91 7,390.94 6,505.49 2,783.10 5,972,076.82 1,492,370.20 0.36 4,509.71 MWD+IFR-AK-CAZ-SC(4) 12,763.66 89.55 332.77 7,463.22 7,392.25 6,590.57 2,740.25 5,972,162.74 1,492,329.08 1.26 4,604.96 MWD+IFR-AK-CAZ-SC(4) 12,858.92 90.00 334.53 7,463.59 7,392.62 6,675.93 2,697.97 5,972,248.92 1,492,288.52 1.91 4,700.21 MWD+1FR-AK-CAZ-SC(4) 12,953.60 89.93 333.43 7,463.65 7,392.68 6,761.01 2,656.44 5,972,334.82 1,492,248.71 1.16 4,794.86 MWD+IFR-AK-CAZ-SC(4) 13,048.70 89.53 333.70 7,464,10 7,393.13 6,846.16 2,614.10 5,972,420.80 1,492,208.10 0.51 4,889.95 MWD+1FR-AK-CAZ-SC(4) 13,143.82 89.98 333.90 7,464.50 7,393.53 6,931.51 2,572.11 5,972,506.97 1,492,167.83 0.52 4,985.06 MWD+IFR-AK-CAZ-SC(4) 13,239.99 91.16 334.31 7,463.55 7,392.58 7,018.02 2,530.11 5,972,594.29 1,492,127.59 1.30 5,081.19 MWD+IFR-AK-CAZ-SC(4) 13,335.06 90.65 334.75 7,462.05 7,391.08 7,103.84 2,489.23 5,972,680.91 1,492,088.44 0.71 5,176.20 MWD+IFR-AK-CAZ-SC(4) 13,430.19 89.64 334.22 7,461.80 7,390.83 7,189.69 2,448.26 5,972,767.56 1,492,049.20 1.20 5,271.29 MWD+1FR-AK-CAZ-SC(4) 13,525.32 88.41 333.28 7,463.42 7,392.45 7,274.99 2,406.19 5,972,853.69 1,492,008.86 1.63 5,366.39 MWD+IFR-AK-CAZ-SC(4) 13,620.69 87.29 333.02 7,467.00 7,396.03 7,360.02 2,363.15 5,972,939.56 1,491,967.54 1.21 5,461.69 MWD+IFR-AK-CAZ-SC(4) 13,716.78 88.22 331.76 7,470.77 7,399.80 7,445.10 2,318.65 5,973,025.51 1,491,924.77 1.63 5,557.70 MWD+IFR-AK-CAZ-SC(4) 13,812.73 88.81 331.46 7,473.25 7,402.28 7,529.48 2,273.04 5,973,110.78 1,491,880.87 0.69 5,653.60 MWD+IFR-AK-CAZ-SC(4) 13,908.38 90.34 332.07 7,473.96 7,402.99 7,613.75 2,227.79 5,973,195.93 1,491,837.33 1.72 5,749.23 MWD+IFR-AK-CAZ-SC(4) 14,003.87 91.27 331.87 7,472.62 7,401.65 7,698.02 2,182.92 5,973,281.09 1,491,794.17 1.00 5,844.70 MWD+1FR-AK-CAZ-SC(4) 14,098.71 91.18 330.58 7,470.59 7,399.62 7,781.13 2,137.28 5,973,365.09 1,491,750.21 1.36 5,939.48 MWD+IFR-AK-CAZ-SC(4) 14,194.87 91.63 330.13 7,468.23 7,397.26 7,864.68 2,089.73 5,973,449.58 1,491,704.35 0.66 6,035.53 MWD+1FR-AK-CAZ-SC(4) 14,289.29 92.54 331.81 7,464.80 7,393.83 7,947.18 2,043.95 5,973,532.97 1,491,660.24 2.02 6,129.83 MWD+IFR-AK-CAZ-SC(4) 14,383.91 92.98 330.87 7,460.24 7,389.27 8,030.11 1,998.62 5,973,616.79 1,491,616.59 1.10 6,224.31. MWD+IFR-AK-CAZ-SC(4) 14,479.48 92.26 330.36 7,455.87 7,384.90 8,113.30 1,951.78 5,973,700.90 1,491,571.43 0.92 6,319.72 MWD+1FR-AK-CAZ-SC(4) 14,575.23 90.51 330.62 7,453.56 7,382.59 8,196.60 1,904.63 5,973,785.12 1,491,525.97 1.85 6,415.36 MWD+1FR-AK-CAZ-SC(4) 14,670.15 91.12 331.13 7,452.21 7,381.24 8,279.51 1,858.43 5,973,868.94 1,491,481.45 0.84 6,510.22 MWD+IFR-AK-CAZ-SC(4) 14,764.80 91.85 331.29 7,449.76 7,378.79 8,362.43 1,812.87 5,973,952.75 1,491,437.57 0.79 6,604.80 MWD+IFR-AK-CAZ-SC(4) 14,860.61 91.92 331.45 7,446.61 7,375.64 8,446.48 1,766.98 5,974,037.70 1,491,393.39 0.18 6,700.53 MWD+IFR-AK-CAZ-SC(4) 14,955.73 91.18 332.29 7,444.03 7,373.06 8,530.33 1,722.15 5,974,122.43 1,491,350.25 1.18 6,795.60 MWD+IFR-AK-CAZ-SC(4) 15,050.78 90.59 333.60 7,442.56 7,371.59 8,614.97 1,678.93 5,974,207.91 1,491,308.74 1.51 6,890.64 MWD+IFR-AK-CAZ-SC(4) 15,145.48 90.97 332.50 7,441.27 7,370.30 8,699.37 1,636.01 5,974,293.16 1,491,267.54 1.23 6,985.33 MWD+IFR-AK-CAZ-SC(4) 15,238.20 92.99 334.11 7,438.07 7,367.10 8,782.15 1,594.39 5,974,376.75 1,491,227.59 2.79 7,077.98 MWD+IFR-AK-CAZ-SC(4) 15,330.57 92.64 333.94 7,433.53 7,362.56 8,865.09 1,553.98 5,974,460.48 1,491,188.86 0.42 7,170.22 MWD+IFR-AK-CAZ-SC(4) 3/8/2016 3:45.17PM Page 6 COMPASS 5000.1 Build 74 • i SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope ND Reference: CD5-07:34.3+36.67©70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,422.86 91.45 333.93 7,430.24 7,359.27 8,947.94 1,513.45 5,974,544.12 1,491,150.01 1.29 7,262.43 MWD+IFR-AK-CAZ-SC(4) 15,517.12 92.09 332.13 7,427.33 7,356.36 9,031.91 1,470.73 5,974,628.92 1,491,108.98 2.03 7,356.64 MWD+IFR-AK-CAZ-SC(5) 15,545.51 91.69 332.35 7,426.39 7,355.42 9,057.02 1,457.51 5,974,654.29 1,491,096.27 1.61. 7,385.01 MWD+IFR-AK-CAZ-SC(5) 15,638.79 90.94 332.72 7,424.25 7,353.28 9,139.76 1,414.50 5,974,737.88 1,491,054.94 0.90 7,478.26 MWD+IFR-AK-CAZ-SC(5) 15,731.03 90.36 332.58 7,423.21 7,352.24 9,221.68 1,372.13 5,974,820.63 1,491,014.22 0.65 7,570.50 MWD+IFR-AK-CAZ-SC(5) 15,823.06 90.22 329.82 7,422.74 7,351.77 9,302.32 1,327.80 5,974,902.14 1,490,971.53 3.00 7,662.48 MWD+IFR-AK-CAZ-SC(5) 15,915.05 89.56 328.71 7,422.92 7,351.95 9,381.39 1,280.78 5,974,982.13 1,490,926.12 1.40 7,754.30 MWD+IFR-AK-CAZ-SC(5) 16,006.99 89.53 329.57 7,423.65 7,352.68 9,460.31 1,233.63 5,975,061.97 1,490,880.56 0.94 7,846.05 MWD+IFR-AK-CAZ-SC(5) 16,099.39 90.41 329.28 7,423.70 7,352.73 9,539.86 1,186.63 5,975,142.45 1,490,835.17 1.00 7,938.30 MWD+IFR-AK-CAZ-SC(5) 16,191.93 90.36 328.13 7,423.07 7,352.10 9,618.93 1,138.56 5,975,222.47 1,490,788.71 1.24 8,030.60 MWD+IFR-AK-CAZ-SC(5) 16,285.20 90.55 328.37 7,422.33 7,351.36 9,698.24 1,089.48 5,975,302.74 1,490,741.24 0.33 8,123.58 MWD+IFR-AK-CAZ-SC(5) 16,376.17 90.49 328.44 7,421.51 7,350.54 9,775.73 1,041.82 5,975,381.16 1,490,695.15 0.10 8,214.28 MWD+IFR-AK-CAZ-SC(5) 16,467.75 91.44 328.74 7,419.97 7,349.00 9,853.87 994.10 5,975,460.25 1,490,649.01 1.09 8,305.61 MWD+IFR-AK-CAZ-SC(5) 16,559.44 91.54 330.06 7,417.58 7,346.61 9,932.77 947.44 5,975,540.05 1,490,603.96 1.44 8,397.11 MWD+IFR-AK-CAZ-SC(5) 16,652.29 91.45 328.26 7,415.16 7,344.19 10,012.46 899.86 5,975,620.68 1,490,557.99 1.94 8,489.74 MWD+IFR-AK-CAZ-SC(5) 16,743.59 91.99 328.57 7,412.42 7,341.45 10,090.20 852.07 5,975,699.36 1,490,511.77 0.68 8,580.74 MWD+IFR-AK-CAZ-SC(5) 16,833.98 91.97 330.88 7,409.29 7,338.32 10,168.21 806.53 5,975,778.26 1,490,467.81 2.55 8,670.94 MWD+IFR-AK-CAZ-SC(5) 16,925.13 91.92 331.23 7,406.20 7,335.23 10,247.92 762.44 5,975,858.85 1,490,425.34 0.39 8,762.00 MWD+IFR-AK-CAZ-SC(5) 17,015.97 91.41 332.60 7,403.56 7,332.59 10,328.03 719.69 5,975,939.79 1,490,384.21 1.61 8,852.79 MWD+IFR-AK-CAZ-SC(5) 17,108.16 91.57 331.82 7,401.16 7,330.19 10,409.56 676.72 5,976,022.16 1,490,342.90 0.86 8,944.94 MWD+IFR-AK-CAZ-SC(5) 17,198.53 90.34 330.99 7,399.66 7,328.69 10,488.90 633.48 5,976,102.34 1,490,301.26 1.64 9,035.27 MWD+IFR-AK-CAZ-SC(5) 17,290.51 90.47 330.92 7,399.01 7,328.04 10,569.31 588.82 5,976,183.63 1,490,258.23 0.16 9,127.20 MWD+IFR-AK-CAZ-SC(5) 17,382.83 90.50 332.51 7,398.23 7,327.26 10,650.60 545.08 5,976,265.78 1,490,216.13 1.72 9,219.50 MWD+IFR-AK-CAZ-SC(5) 17,474.50 90.46 334.04 7,397.46 7,326.49 10,732.47 503.86 5,976,348.45 1,490,176.57 1.67 9,311.16 MWD+IFR-AK-CAZ-SC(5) 17,566.20 90.64 335.36 7,396.58 7,325.61 10,815.37 464.67 5,976,432.12 1,490,139.06 1.45 9,402.80 MWD+IFR-AK-CAZ-SC(5) 17,657.27 90.53 335.07 7,395.65 7,324.68 10,898.04 426.50 5,976,515.54 1,490,102.56 0.34 9,493.78 MWD+IFR-AK-CAZ-SC(5) 17,747.01 90.58 334.85 7,394.78 7,323.81 10,979.35 388.52 5,976,597.58 1,490,066.22 0.25 9,583.45 MWD+IFR-AK-CAZ-SC(5) 17,839.39 90.38 336.19 7,394.01 7,323.04 11,063.42 350.24 5,976,682.40 1,490,029.64 1.47 9,675.72 MWD+IFR-AK-CAZ-SC(5) 17,934.50 91.45 341.03 7,392.49 7,321.52 11,151.94 315.57 5,976,771.59 1,489,996.76 5.21 9,770.29 MWD+IFR-AK-CAZ-SC(5) 18,030.22 91.46 340.11 7,390.05 7,319.08 11,242.18 283.73 5,976,862.45 1,489,966.75 0.96 9,865.09 MWD+IFR-AK-CAZ-SC(5) 18,125.48 91.64 338.05 7,387.48 7,316.51 11,331.12 249.73 5,976,952.05 1,489,934.55 2.17 9,959.73 MWD+IFR-AK-CAZ-SC(5) 18,220.91 91.08 337.98 7,385.21 7,314.24 11,419.58 214.02 5,977,041.21 1,489,900.62 0.59 10,054.73 MWD+IFR-AK-CAZ-SC(5) 18,316.19 90.75 337.18 7,383.69 7,312.72 11,507.65 177.68 5,977,129.98 1,489,866.07 0.91 10,149.66 MWD+IFR-AK-CAZ-SC(5) 18,411.54 89.42 337.06 7,383.55 7,312.58 11,595.50 140.61 5,977,218.55 1,489,830.77 1.40 10,244.73 MWD+IFR-AK-CAZ-SC(5) 18,506.35 89.52 337.16 7,384.43 7,313.46 11,682.84 103.74 5,977,306.60 1,489,795.67 0.15 10,339.27 MWD+IFR-AK-CAZ-SC(5) 18,602.13 89.02 336.48 7,385.65 7,314.68 11,770.88 66.04 5,977,395.38 1,489,759.75 0.88 10,434.80 MWD+IFR-AK-CAZ-SC(5) 18,696.64 89.28 334.02 7,387.05 7,316.08 11,856.69 26.48 5,977,481.96 1,489,721.92 2.62 10,529.20 MWD+IFR-AK-CAZ-SC(5) 18,790.14 89.14 330.16 7,388.34 7,317.37 11,939.29 -17.27 5,977,565.42 1,489,679.84 4.13 10,622.67 MWD+IFR-AK-CAZ-SC(5) 18,885.26 89.55 328.52 7,389.43 7,318.46 12,021.10 -65.77 5,977,648.19 1,489,633.00 1.78 10,717.61 MWD+IFR-AK-CAZ-SC(5) 18,981.25 89.15 325.86 7,390.52 7,319.55 12,101.77 -117.78 5,977,729.87 1,489,582.63 2.80 10,813.13 MWD+IFR-AK-CAZ-SC(5) 3/8/2016 3:45:17PM Page 7 COMPASS 5000.1 Build 74 III 40 SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 19,076.68 88.96 326.65 7,392.09 7,321.12 12,181.11 -170.78 5,977,810.26 1,489,531.24 0.85 10,907.93 MWD+IFR-AK-CAZ-SC(5) 19,171.13 88.96 325.06 7,393.80 7,322.83 12,259.26 -223.79 5,977,889.45 1,489,479.82 1.68 11,001.68 MWD+IFR-AK-CAZ-SC(5) 19,266.57 89.08 327.18 7,395.44 7,324.47 12,338.48 -276.98 5,977,969.72 1,489,428.24 2.22 11,096.46 MWD+IFR-AK-CAZ-SC(5) 19,361.81 90.06 326.67 7,396.15 7,325.18 12,418.28 -328.95 5,978,050.55 1,489,377.88 1.16 11,191.20 MWD+IFR-AK-CAZ-SC(5) 19,457.37 90.98 326.16 7,395.28 7,324.31 12,497.89 -381.81 5,978,131.19 1,489,326.64 1.10 11,286.17 MWD+IFR-AK-CAZ-SC(5) 19,552.78 92.47 328.97 7,392.41 7,321.44 12,578.37 -432.95 5,978,212.68 1,489,277.13 3.33 11,381.14 MWD+IFR-AK-CAZ-SC(5) 19,648.29 92.34 331.46 7,388.40 7,317.43 12,661.18 -480.35 5,978,296.42 1,489,231.41 2.61 11,476.46 MWD+IFR-AK-CAZ-SC(5) 19,743.07 92.42 331.59 7,384.47 7,313.50 12,744.42 -525.50 5,978,380.55 1,489,187.94 0.16 11,571.14 MWD+IFR-AK-CAZ-SC(5) 19,838.44 92.40 332.55 7,380.46 7,309.49 12,828.61 -570.13 5,978,465.61 1,489,145.02 1.01 11,666.42 MWD+IFR-AK-CAZ-SC(5) 19,933.96 91.27 332.13 7,377.40 7,306.43 12,913.17 -614.45 5,978,551.03 1,489,102.41 1.26 11,761.88 MWD+IFR-AK-CAZ-SC(5) 20,029.45 91.51 332.08 7,375.08 7,304.11 12,997.54 -659.11 5,978,636.28 1,489,059.46 0.26 11,857.34 MWD+IFR-AK-CAZ-SC(5) 20,125.82 90.48 330.74 7,373.41 7,302.44 13,082.14 -705.22 5,978,721.78 1,489,015.06 1.75 11,953.66 MWD+IFR-AK-CAZ-SC(5) 20,220.30 90.89 330.23 7,372.28 7,301.31 13,164.35 -751.76 5,978,804.91 1,488,970.18 0.69 12,048.06 MWD+IFR-AK-CAZ-SC(5) 20,316.63 90.80 331.96 7,370.86 7,299.89 13,248.67 -798.32 5,978,890.14 1,488,925.34 1.80 12,144.34 MWD+IFR-AK-CAZ-SC(5) 20,411.04 90.91 333.99 7,369.45 7,298.48 13,332.76 -841.21 5,978,975.07 1,488,884.15 2.15 12,238.73 MWD+IFR-AK-CAZ-SC(5) 20,505.80 91.03 334.62 7,367.84 7,296.87 13,418.13 -882.29 5,979,061.24 1,488,844.80 0.68 12,333.44 MWD+IFR-AK-CAZ-SC(5) 20,601.52 90.79 335.30 7,366.32 7,295.35 13,504.85 -922.80 5,979,148.75 1,488,806.04 0.75 12,429.08 MWD+1FR-AK-CAZ-SC(5) 20,696.75 91.68 334.00 7,364.27 7,293.30 13,590.88 -963.56 5,979,235.58 1,488,767.02 1.65 12,524.23 MWD+IFR-AK-CAZ-SC(5) 20,791.85 91.62 333.42 7,361.53 7,290.56 13,676.11 -1,005.66 5,979,321.63 1,488,726.64 0.61 12,619.28 MWD+IFR-AK-CAZ-SC(5) 20,887.83 92.05 332.20 7,358.46 7,287.49 13,761.44 -1,049.50 5,979,407.82 1,488,684.54 1.35 12,715.21 MWD+IFR-AK-CAZ-SC(5) L20,982.90 91.86 331.25 7,355.22 7,284.25 13,845.12 -1,094.51 5,979,492.38 1,488,641.22 1.02 12,810.21 MWD+IFR-AK-CAZ-SC(5) 21,042.00 91.99 331.47 7.353.23 7.282.26 13.896.96 -1,122.82 5,979,544.77 1,488,613.96 0.43 12,869.26 ) 4 1/2"x 6-3/4" 21,077.81 92.07 331.60 7,351.96 7,280.99 13,928.42 -1,139.88 5,979,576.56 1,488,597.54 0.43 12,905.04 MWD+1FR-AK-CAZ-SC(5) 21,173.82 92.43 332.21 7,348.19 7,277.22 14,013.05 -1,185.05 5,979,662.08 1,488,554.08 0.74 13,000.96 MWD+IFR-AK-CAZ-SC(5) 21,268.72 92.01 331.73 7,344.52 7,273.55 14,096.75 -1,229.62 5,979,746.66 1,488,511.21 0.67 13,095.78 MWD+IFR-AK-CAZ-SC(5) 21,364.22 91.57 330.77 7,341.53 7,270.56 14,180.44 -1,275.53 5,979,831.24 1,488,466.99 1.11 13,191.20 MWD+IFR-AK-CAZ-SC(5) 21,459.80 90.30 328.90 7,339.97 7,269.00 14,263.06 -1,323.55 5,979,914.81 1,488,420.65 2.36 13,286.64 MWD+IFR-AK-CAZ-SC(5) 21,555.29 90.79 326.90 7,339.07 7,268.10 14,343.94 -1,374.29 5,979,996.69 1,488,371.55 2.16 13,381.77 MWD+IFR-AK-CAZ-SC(5) 21,649.47 90.05 327.84 7,338.38 7,267.41 14,423.25 -1,425.07 5,980,077.00 1,488,322.38 1.27 13,475.53 MWD+IFR-AK-CAZ-SC(5) 21,744.96 89.57 327.51 7,338.69 7,267.72 14,503.94 -1,476.13 5,980,158.69 1,488,272.95 0.61 13,570.65 MWD+IFR-AK-CAZ-SC(5) 21,840.13 88.99 326.96 7,339.89 7,268.92 14,583.97 -1,527.63 5,980,239.73 1,488,223.08 0.84 13,665.37 MWD+IFR-AK-CAZ-SC(5) 21,936.41 88.34 328.04 7,342.13 7,271.16 14,665.14 -1,579.34 5,980,321.92 1,488,173.01 1.31 13,761.21 MWD+IFR-AK-CAZ-SC(5) 22,030.46 87.50 327.52 7,345.54 7,274.57 14,744.66 -1,629.46 5,980,402.42 1,488,124.51 1.05 13,854.85 MWD+IFR-AK-CAZ-SC(5) 22,125.64 87.65 329.01 7,349.57 7,278.60 14,825.53 -1,679.47 5,980,484.28 1,488,076.13 1.57 13,949.65 MWD+IFR-AK-CAZ-SC(5) 22,220.93 88.10 330.67 7,353.11 7,282.14 14,907.86 -1,727.31 5,980,567.55 1,488,029.96 1.80 14,044.75 MWD+IFR-AK-CAZ-SC(5) 22,315.98 88.67 334.61 7,355.79 7,284.82 14,992.23 -1,770.97 5,980,652.77 1,487,988.01 4.19 14,139.74 MWD+IFR-AK-CAZ-SC(5) 22,412.47 89.09 335.85 7,357.67 7,286.70 15,079.82 -1,811.39 5,980,741.15 1,487,949.36 1.36 14,236.12 MWD+IFR-AK-CAZ-SC(5) 22,507.31 89.99 335.67 7,358.43 7,287.46 15,166.30 -1,850.32 5,980,828.39 1,487,912.18 0.97 14,330.82 MWD+IFR-AK-CAZ-SC(5) 22,602.20 90.96 337.52 7,357.65 7,286.68 15,253.37 -1,888.01 5,980,916.20 1,487,876.25 2.20 14,425.49 MWD+IFR-AK-CAZ-SC(5) 3/8/2016 3:45:17PM Page 8 COMPASS 5000.1 Build 74 III S • SLB Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 22,697.43 90.98 335.77 7,356.03 7,285.06 15,340.78 -1,925.76 5,981,004.34 1,487,840.27 1.84 14,520.49 MWD+IFR-AK-CAZ-SC(5) 22,792.83 90.83 333.38 7,354.53 7,283.56 15,426.93 -1,966.71 5,981,091.29 1,487,801.06 2.51 14,615.82 MWD+IFR-AK-CAZ-SC(5) 22,889.07 91.57 333.54 7,352.51 7,281.54 15,513.01 -2,009.70 5,981,178.21 1,487,759.81 0.79 14,712.03 MWD+IFR-AK-CAZ-SC(5) 22,984.65 91.32 334.30 7,350.10 7,279.13 15,598.83 -2,051.71 5,981,264.85 1,487,719.54 0.84 14,807.56 MWD+IFR-AK-CAZ-SC(5) 23,078.76 91.56 333.25 7,347.74 7,276.77 15,683.22 -2,093.28 5,981,350.05 1,487,679.68 1.14 14,901.62 MWD+IFR-AK-CAZ-SC(5) 23,174.20 91.88 330.28 7,344.87 7,273.90 15,767.26 -2,138.41 5,981,434.97 1,487,636.26 3.13 14,996.99 MWD+IFR-AK-CAZ-SC(5) 23,270.32 91.99 326.32 7,341.62 7,270.65 15,848.98 -2,188.88 5,981,517.68 1,487,587.44 4.12 15,092.75 MWD+IFR-AK-CAZ-SC(5) 23,365.89 90.95 323.14 7,339.17 7,268.20 15,926.97 -2,244.03 5,981,596.76 1,487,533.87 3.50 15,187.34 MWD+IFR-AK-CAZ-SC(5) 23,458.57 91.33 323.38 7,337.33 7,266.36 16,001.22 -2,299.46 5,981,672.11 1,487,479.95 0.48 15,278.73 MWD+IFR-AK-CAZ-SC(5) 23,555.68 90.31 327.01 7,335.94 7,264.97 16,080.94 -2,354.88 5,981,752.92 1,487,426.15 3.88 15,374.97 MWD+IFR-AK-CAZ-SC(5) 23,651.61 88.69 333.36 7,336.78 7,265.81 16,164.12 -2,402.55 5,981,837.04 1,487,380.17 6.83 15,470.75 MWD+IFR-AK-CAZ-SC(5) 23,711.00 88.69 333.36 7,338.13 7,267.16 16,217.19 -2,429.17 5,981,890.63 1,487,354.62 0.00 15,530.12 3/8/2016 3:45:17PM Page 9 COMPASS 5000.1 Build 74 • m 4.; a I cz co a 73 o 0 i c m o 0o,o .- ,D O •►> >. O m a Rs = ors4 CO O ni a.) a) (13 co Cri ;0 O) • 0 2 0 V = O o 0 o o a a) or a a j w = o q o cp ti o ° o '� stn .} w v g o .a a) 03 U L o M CD :1 Cu C . c ° Cl) ca C z E L °: a) u) a.c Z c _ 0 a) C o o 2 0 N o:J U E 7:, ❑ O c ami �j o N h ca o ` to o c U C 4 41t5o6VU Q 4- o c a) o E w o >. — d3 U .O L Eo- ��^ Q S ( o cn . 4� c a) Y z aa)) CC D s co 'u. w } til cn o 0 cn .° o a� a LILiEl EI w a r_ as di .17-d o E. m N U) 92 0 Q a) CC c a) U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 2OAAC 25.105 20PAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE' WDSPL❑ No. of Completions: Service ❑✓ . Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/3/2016 216-004 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 2/5/2016 50-103-20734-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 328' FNL, 2555' FEL, Sec 18,T11N, R4E, UM 2/27/2015 CRU CD5-07 Top of Productive Interval: 9. Ref Elevations: KB: 70.6' 17. Field/Pool(s): 890' FNL, 4059' FEL, Sec 8,T11N, R4E, UM GL: 34.3' BF: Colville River Unit/Alpine Pool - Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 5231' FNL, 60' FEL, Sec 25,T12N, R3E, UM 21042' MD/7353'TVD ASRC-NPR1,ASRC-NPR2,ASRC-NPR4 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 349424 y- 5965883 Zone- 4 23711' MD/7338'TVD 932126, 932128, 932669 TPI: x- 353275 y- 5970525 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 347321 y- 5982144 Zone- 4 N/A 1340' MD/ 1336'TVD 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log, spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary Gyro, GR/Res, MWD/LWD, SonicScope TOC- RECEIVED APR 0 7 2016 23. CASING, LINER AND CEMENTING RECORD AOGGC WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 78.6 B 37' 115' 37' 115' 42" 113 sx Class'B' 10 3/4" 45.5 L-80 37' 2291' 37' 2191' 13 1/2" 1058 sx 11.0 ppg DeepCRETE; 274 sx 15.8 ppg Class'G' 7 5/8" 29.7 L-80 35' 10633' 35' 7471' 9 7/8"x 11" 399 sx 15.8 ppg Class'G'; 310 sx 15.8 ppg Class'G' 4 1/2" 12.6 L-80 10472' 21042' 7455' 7353' 6 3/4" Uncemented Liner 24. Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4 1/2" 10520' 10472' MD/7455'TVD See Attachment, page 3 COMPLETION 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE, 3/S/ to Was hydraulic fracturing used during completion? Yes❑ No 0 VERIFIEDPer 20 AAC 25.283(i)(2)attach electronic and printed information LI.. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A 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 -0 • Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate � Form 10-407 Revised 11/2015L g/2 6/`b CONTINUED ON PAGE 2 7A I 14IS. Submit ORIGINIAL onyx_ d (l�64 RBDMS II-L- APR 1 1 2016 28.CORE DATA Conventional ): Yes ❑ No E Sidewall Coreikes ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. None 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1340' 1336' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. C30 2460' 2324' K3 4593' 3777' K2 4942' 4009' K2 Basal 5045' 4078' None Albian 97 5534' 4405' Albian 96 7399' 5652' HRZ 9512' 7092' Kalubik(Base HRZ) 9642' 7166' Kuparuk C 9883' 7283' Alpine C 10245' 7408' UJU 10256' 7411' Alpine A 10545' 7464' Top of Productive Interval 10633' 7471' Formation at total depth: Alpine A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.G. Samuel @ 265-6309 k4 C L Email: John.G.Samuel@cop.com Printed Name: G. L.Alvord Title: Alaska Drilling Manager Signature: C.-. Oak Phone: 265-6120 Date: 4-(1 +Zai b f INSTRUCTIONS CRU CD5-07 General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including,but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to: core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • CRU CD5-07 ConocoPhillips Alaska, Inc Well Completion or Recompletion Report and Log Form 10-407 Open to Production or Injection - Box #24 Attachment - Page 3 of 3 4-1/2", L-80, 12.6#, Hyd 563 Pre-perforated Pup Jts MD TVD Perforated Pup Joint 10690' - 10700' 7473' -7473' Perforated Pup Joint 11020' - 11030' 7473' -7473' Perforated Pup Joint 11351' - 11360' 7468' -7468' Perforated Pup Joint 11687' - 11697' 7463' -7463' Perforated Pup Joint 12023' - 12033' 7458' -7458' Perforated Pup Joint 12362' - 12372' 7458' -7457' Perforated Pup Joint 12696' - 12705' 7462' -7463' Perforated Pup Joint 13029' - 13039' 7464' -7464' Perforated Pup Joint 13362' - 13372' 7462'-7462' Perforated Pup Joint 13694' - 13704' 7470'-7470' Perforated Pup Joint 14027' - 14037' 7472'-7472' Perforated Pup Joint 14359' - 14369' 7462' -7461' Perforated Pup Joint 14692' - 14701' 7452' -7452' Perforated Pup Joint 15023' - 15033' 7443' -7443' Perforated Pup Joint 15353' - 15363' 7433' -7432' Perforated Pup Joint 15683' - 15693' 7424' -7424' Perforated Pup Joint 16012' - 16022' 7424' -7424' Perforated Pup Joint 16345' - 16355' 7422' -7422' Perforated Pup Joint 16677' - 16687' 7415' -7414' Perforated Pup Joint 17008' - 17018' 7404' -7404' Perforated Pup Joint 17346' - 17357' 7399' -7399' Perforated Pup Joint 17679' - 17689' 7396'-7396' Perforated Pup Joint 18010' - 18020' 7391' -7390' Perforated Pup Joint 18343' - 18352' 7384' -7383' Perforated Pup Joint 18674' - 18684' 7387' -7387' Perforated Pup Joint 19006' - 19016' 7391' -7391' Perforated Pup Joint 19339' - 19348' 7396' -7396' Perforated Pup Joint 19675' - 19685' 7387' -7387' Perforated Pup Joint 20019' - 20029' 7375' -7375' Perforated Pup Joint 20367' - 20377' 7370' -7370' Perforated Pup Joint 20704' -20713 7364' -7364' • 1111 WNS SVC CD5-07 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status nal(") MD(ftKB) Act Btm(ftKB) cvncriPtynpc 501032073400 ALPINE SVC 92.99 15,238.19 23,711.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD5-07,3/16/20162:39:35 PM SSSV:NIPPLE Last WO: 36.67 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ....................................................................................................................Last Tag: Rev Reason:NEW WELL Ishak( 3/16/2016 HANGER;31.7 g __................... Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread , . ), .I,,1 .:iii 4 CONDUCTOR 20 19.124 36.6 115.0 115.0 78.60 B Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 36.8 2,291.0 2,190.7 45.50 L-80 H563 n Casing Description -OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;36.6-115.0 INTERMEDIATE 7 5/8 6.875 34.7 10,632.6 7,470.5 29.70 L80 Hyd563 Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread XO-Threads:128.1 LINER 4 1/2 3.958 10,472.0 21,042.0 7,353.2 12.60 L-80 Hyd 563 Liner Details XO-Threads;2.169.9 Nominal ID NIPPLE.2.173.1 Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) X0-Threads;2,174.6 _ 10,472.0 7,455.4 82.34'PACKER Baker 51/2"x 7 5/8"HRD-E ZXP Liner Top Packer 5.750 w15.75"ID PBR 11.07' 10,491.8 7,457.9 83.17 NIPPLE Baker 5 1/2"RS Nipple 5 1/2"Hyd 563 Box x Box, 4.880 SURFACE;36.8-2,291.0- 15.56 L-80 10,494.6 7,458.3 83.26'HANGER Baker 5 1/2"x 7 5/8"Flex-Lock Liner Hanger Hyd 4.800 563,176 L-80 xo-Threads;9.946.3 10,504.4 7,459.4 83.48 SBE Seal Bore Extension,8040,51/2",H563 4.750 GAS LIFT;9,956.0 10,523.5 7,461.5 83.90-X0 Reducing Cross over,5 1/2"H563 x 4-1/2"H563,B x P 3.910 XO-Threads:9,971.1 Tubing Strings Tubing Description String Ma...ID(in) Top(ft66) Set Depth(ft..Set Depth(7913)(...Wt(Ib/ft) Grade Top Connection NIPPLE;10.1652 ,. TUBING 41/2 3.958 31.7 10,519.6 7,461.1 12.60 L-80 TXP Completion Details XO-Threads;10,476.6 k� Nominal lD LOCATOR;10.478.5 Top(ftKB) Top(TVD)(ftKB) Top Incl(") item Des Com (In) 31.7 31.7 0.10'HANGER 'FMC 4-1/2"Tubing Hanger 3.958- 2,173.1' 2,095.1 34.73 NIPPLE DB-6 Landing Nipple,4-1/2"X 3.813",L80,HYD563 BxP 3.813 10,165.3 7,384.6 71.82 NIPPLE DB-6 Landing Nipple,4-1/2"X 3.75",L80,BTC B x TXP 3.750 P w/RHC plug SEAL Asst;10s03.3 10,478.5 7,456.3 82.62 LOCATOR Baker GBH-22 Locator No Go 5.38"OD 3.880 SEAL ASSY;10,517.0 = 10,503.3 7,459.3 83.45 SEAL ASSY Baker Bonded Seal Assembly 3.870 10,517.0 7,460.8 83.76-SEAL ASSY Baker Bonded Seal Assembly w/Mule Shoe 3.870 Mandrel Inserts St all on Top(TVD) Valve Latch Port Size TRO Run INTERMEDIATE;34.7-10,832.6 N, Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type _ On) (psi) Run Date Com 1 9,956.0 7,312.2 CAMCO KBMG 1 GAS LIFT SOV BEK-5 0.000' 0.0 3/2/2016 U 14 d If 0 0 U S S U S U S • tl • U • S S • ll U S • t! • S I t! • f! • LINER;10,472.0-21,042.0 Operations Summary (with Timelog Depths) - �W�6et s CD5-07 ConocoPhiilips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/4/2016 2/4/2016 1.00 MIRU MOVE MOB P Move ball mill away from rig. RD 04:00 05:00 service lines. 2/4/2016 2/4/2016 0.50 MIRU MOVE MOB P Move pits/motors away from sub 05:00 05:30 2/4/2016 2/4/2016 1.25 MIRU MOVE MOB P Raise cellar windwalls,raise feet.Jack 05:30 06:45 floor into moving position 2/4/2016 2/4/2016 0.25 MIRU MOVE MOB P Jack sub up,remove shims 06:45 07:00 2/4/2016 2/4/2016 0.50 MIRU MOVE MOB P Move sub off CD5-10 07:00 07:30 2/4/2016 2/4/2016 0.50 MIRU MOVE MOB P Set sub down and turn tires to crab 07:30 08:00 position 2/4/2016 2/4/2016 0.50 MIRU MOVE MOB P Crab sub down well row from CD5-10 08:00 08:30 to CD5-07 2/4/2016 2/4/2016 1.00 MIRU MOVE MOB P Set sub down,turn tires SIMOPS-Set 08:30 09:30 annular on conductor 2/4/2016 2/4/2016 0.50 MIRU MOVE MOB P Spot sub over CD5-07 09:30 10:00 2/4/2016 2/4/2016 0.50 MIRU MOVE MOB P Lower feet and rear windwalls 10:00 10:30 2/4/2016 2/4/2016 1.00 MIRU MOVE MOB P Skid floor into drilling position SIMOPS 10:30 11:30 -Pull pits/motors towards sub 2/4/2016 2/4/2016 0.50 MIRU MOVE MOB P Spot pits/Mtrs and pipe shed 11:30 12:00 2/4/2016 2/4/2016 4.00 MIRU MOVE RURD P Shim Pits and Motors,trim Herculite 0.0 0.0 12:00 16:00 around rig,hook up hoses and lines at inter-connect,hook up flow line in Pits, install hand rails and lower all stairways,attach pipe shed rails, function skate,test run conveyor and dump valve,tie drain lines to cellar and hook up cellar pump. Gyro rep perform North referance siting. Review and finalize Rig Acceptance check list. Note:rig back on high line power at 15:15 hrs 2/4/16 Rig accepted: 16:00 hours,2/4/16 2/4/2016 2/4/2016 6.00 MIRU MOVE RURD P Function Rotary,drawworks,TD and 0.0 0.0 16:00 22:00 function test MPs. Test flow meter, MU bolts on bottom of annular. NU Riser,flowline,clamp on riser and chain down riser to stack. (Simops- Function Rotary,drawworks,TD and function test MPs.Test flow meter)NU Hole fill and bleeder lines. Measure RKB elevation,calibrate TD height. Install valves on conductor outlets. Take on mud to pits. Hook up flare lines and install mouse hole. Hook up Koomey accumulater hydraulic lines to surface annular. PU lift subs to rig floor,install elevators. 2/4/2016 2/5/2016 2.00 MIRU MOVE PULD P Change out Iron roughneck torque 0.0 0.0 22:00 00:00 adjust SIMOPS-Finish RU Gyro equip,install elevators, PU 6 stds of 5" HWDP and stand back. Page 1/20 Report Printed: 3/7/2016 .:, Drilling !perations Summary (with Timelog Depths) :{ &Wel s CD5-07 conocoPhilttp*s Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/5/2016 2/5/2016 0.75 MIRU MOVE SEQP P Function Annular preventer. 0.0 0.0 00:00 00:45 2/5/2016 2/5/2016 0.75 MIRU MOVE SEQP P Prime mud pumps and fill stack and 0.0 0.0 00:45 01:30 hole with 9.0 ppg Drillplex mud and check for leaks-good. 2/5/2016 2/5/2016 0.75 MIRU MOVE SFTY P Hold Pre-spud meeting and PU BHA 0.0 0.0 01:30 02:15 PJSM. 2/5/2016 2/5/2016 1.75 MIRU MOVE BHAH P MU BHA#1 to 92'. Orient Motor/ 0.0 92.0 02:15 04:00 MWD. 2/5/2016 2/5/2016 0.25 MIRU MOVE SEQP P Fill lines with water,pressure test to 92.0 92.0 04:00 04:15 3,500 psi and check for leaks-good. Shallow pulse test MWD. 2/5/2016 2/5/2016 0.25 MIRU MOVE DRLG P Wash and ream with 450 gpm,520 92.0 115.0 04:15 04:30 psi,50 rpm and tag bottom at 115'. 2/5/2016 2/5/2016 1.25 SURFAC DRILL DDRL P Spud well and drill to 275'md,ADT: 115.0 275.0 04:30 05:45 1.0 hrs,TVD:275'.PU=SO=75K lb. 2/5/2016 2/5/2016 0.25 SURFAC DRILL TRIP P Blow down TD and LD 5"HWDP 275.0 85.0 05:45 06:00 single. POOH to 85'. 2/5/2016 2/5/2016 1.00 SURFAC DRILL BHAH P Continue to MU BHA with NMDCs, 85.0 199.0 06:00 07:00 Jars and STAB to 199'. 2/5/2016 2/5/2016 0.25 SURFAC DRILL BHAH P Wash to TD at 275'with 450 gpm,590 199.0 275.0 07:00 07:15 psi,50 rpm,2.5K TQ.. 2/5/2016 2/5/2016 4.75 SURFAC DRILL DDRL P Drill 13-1/2"hole with motor from 275' 275.0 568.0 07:15 12:00 to 568'. ADT=4.26 hrs, AST=0.9 hrs,ART=3.36 hrs. TVD=563'. PU= 107K,SO=92K, ROT= 100K lb. TQ on/off=3.2K/1.5K ft-lb 2/5/2016 2/5/2016 2.00 SURFAC DRILL DDRL P Drill 13-1/2"hole with motor from 568' 568.0 747.0 12:00 14:00 to 747'. ADT= 1.54 hrs, ART=0.87 hrs,AST=0.67 hrs. TVD=747'. PU= 107K,SO= 105K, ROT= 120K lb. TQ on/off=3.5K/1.5K ft-Ib, 2/5/2016 2/5/2016 1.00 SURFAC DRILL 'SRVY P Run Gyro for survey check shots. 747.0 747.0 14:00 15:00 Confer with town about pulling BHA to check tools. 2/5/2016 2/5/2016 0.25 SURFAC DRILL OWFF T Flow chk-static. 747.0 747.0 15:00 15:15 2/5/2016 2/5/2016 0.25 SURFAC DRILL TRIP T POOH from 747'to 563'.Consult with 747.0 563.0 15:15 15:30 town 2/5/2016 2/5/2016 0.25 SURFAC DRILL TRIP T RIH from 563'to 747'. PU= 110K,SO= 563.0 747.0 15:30 15:45 107K. 2/5/2016 2/5/2016 0.75 SURFAC DRILL DDRL P Drill from 747'to 795'trying to build 747.0 795.0 15:45 16:30 hole angle with inadequate response. 2/5/2016 2/5/2016 1.25 SURFAC DRILL CIRC T Circ at 1.5 bpm, 140 psi while consult 795.0 795.0 16:30 17:45 with town on plan forward. 2/5/2016 2/5/2016 0.75 SURFAC DRILL DDRL P Drill from 795'to 840'trying to build 795.0 840.0 17:45 18:30 hole angle. ADT:2.73 hr,ART:0.4 hr, AST:0.79 hr. 2/5/2016 2/5/2016 0.75 SURFAC DRILL OWFF T Flow chk-static. Blow down TD. 840.0 840.0 18:30 19:15 2/5/2016 2/5/2016 0.75 SURFAC DRILL CIRC T Circ at 100 gpm,240 psi while consult 840.0 840.0 19:15 20:00 with town on plan forward. 2/5/2016 2/5/2016 2.50 SURFAC DRILL TRIP T POOH from 840'to 91' 840.0 91.0 20:00 22:30 Page 2/20 Report Printed: 3/7/2016 Operations Summary (with Timelog!epths) ''' • &Wens CD5-07 C:onocoPhillips ii Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/5/2016 2/6/2016 1.50 SURFAC DRILL BHAH T LD BHA#1 and change out BHA 91.0 0.0 22:30 00:00 components and bit. Total Tour: ADT:6.99 hr,ART:4.63 hr,AST:2.36 hr. 2/6/2016 2/6/2016 1.25 SURFAC DRILL BHAH T Change motor housing bend from 0.0 92.0 00:00 01:15 1.50°to 1.83°.Orient and scribe MWD/Motor/UBHO and verify. 2/6/2016 2/6/2016 1.00 SURFAC DRILL BHAH T Continue to MU BHA with NMDCs, 92.0 199.0 01:15 02:15 Jars and STAB to 199'. 2/6/2016 2/6/2016 0.75 SURFAC DRILL TRIP T RIH from 199'to 750'with 5"HWDP 199.0 750.0 02:15 03:00 from derrick 2/6/2016 2/6/2016 0.25 SURFAC DRILL WASH T Wash to TD at 840'with 450 gpm,820 750.0 840.0 03:00 03:15 psi. 2/6/2016 2/6/2016 2.50 SURFAC DRILL DDRL P Drill 13-1/2"hole from 840' to 1,027'. 840.0 1,027.0 03:15 05:45 ADT= 1.4 hrs 2/6/2016 2/6/2016 2.25 SURFAC DRILL REAM T Work thru Slide area to reduce hole 840.0 1,027.0 05:45 08:00 tortuosity with 60 rpm, 1.5K TQ,550 gpm, 1,080 psi. 2/6/2016 2/6/2016 4.00 SURFAC DRILL DDRL P Drill 13-1/2"hole with motor from 1,027.0 1,465.0 08:00 12:00 1,027' to 1,465'. ADT=3.83 hrs, AST=1.85 hrs,ART= 1.98 hrs. TVD= 1,460'. PU=120K,SO= 118K, ROT= 115K lb. TQ on/off=2.5K/4.5K ft-lb 2/6/2016 2/6/2016 9.25 SURFAC DRILL DDRL P Drill 13-1/2"hole from 1,465' to 1,465.0 2,301.0 12:00 21:15 2,301'. ADT=6.22 hrs, AST= 1.95 hrs,ART=4.27 hrs. TVD=2002'. PU= 120K,SO= 118K, ROT= 115K lb. TQ on/off=4.5K/2.5K ft-lb Pump not plug sweeps on last two stands drilled down with 100%excess cuttings returned. 2/6/2016 2/6/2016 2.00 SURFAC CASING CIRC P Circulate and survey hole, Pump 4X 2,301.0 1,964.0 21:15 23:15 bottoms up standing one stand back every bottoms up. Pump 1X nut plug sweep with first CBU. 2/6/2016 2/6/2016 0.25 SURFAC CASING OWFF P Flow chk for 15 minutes-okay 1,964.0 1,964.0 23:15 23:30 2/6/2016 2/7/2016 0.50 SURFAC CASING TRIP P POOH from 1,964'to 1,781' 1,964.0 1,781.0 23:30 00:00 2/7/2016 2/7/2016 1.00 SURFAC CASING TRIP P POOH from 1,781'to HWDP at 747'. 1,781.0 747.0 00:00 01:00 Flo-chk-static. 2/7/2016 2/7/2016 0.75 SURFAC CASING TRIP P POOH from 732'to BHA at 199'. 747.0 199.0 01:00 01:45 2/7/2016 2/7/2016 1.75 SURFAC CASING BHAH P PJSM.LD Drilling Jars and BHA#2 199.0 0.0 01:45 03:30 from 199. Calc/Actual Fill:30/39 bbl 2/7/2016 2/7/2016 1.00 SURFAC CASING BHAH P Clean and clear floor. LD BHA 0.0 0.0 03:30 04:30 STABs,PU Volant CRT,bail extensions. Blow down mudline and clean MP and suction and discharge screens/chambers.SIMOPs-Flow chk for 30 min-static. 2/7/2016 2/7/2016 1.25 SURFAC CASING RURD P RU 4'bail extensions and 10-3/4" 0.0 0.0 04:30 05:45 elevators.RU casing tools. MU floor valve on XO. Monitor hole-good. Page 3/20 Report Printed: 3/7/2016 • Operations Summary (with Timelog Depths) &Wells CD5-07 Ccx asci iti pis Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/7/2016 2/7/2016 5.50 SURFAC CASING PUTB P PJSM.Run 10-3/4"composite float 0.0 2,291.0 05:45 11:15 shoe,2 jts 10-3/4"BTCM casing, HES float collar, 1 jts 10 3/4"BTC casing, XO-BTCM x H563(PxB). Baker-Lok first 3 connections.Check floats- okay. Continue running 10-3/4",45.5 lb/ft, L-80, H563, R3 casing to 2,291'(53 total jts including shoe track). Calc/Actual fill=36/24 bbl). Avg MU torque=7,700 ft-lb for BTCM when made up to the mark using Run&Seal thread dope, 16,200 ft-lb torque for H563 connections with Seal Guard ECF thread dope.SO= 130K lb. Cents=(Centek-10-3/4" bow springs,51 total): 1 -10'from shoe on stop collar, 1 -30'from pin on jt#2 on stop, 1 -20'from pin on jt#3, 1 -free floating on joints#4-51 2/7/2016 2/7/2016 0.50 SURFAC CASING HOSO P MU casing hanger and landing joint. 2,291.0 2,291.0 11:15 11:45 Land casing on hanger at 2,291'md. 2/7/2016 2/7/2016 2.50 SURFAC CEMENT CIRC P Circ&cond mud for cement job Stage 2,291.0 2,291.0 11:45 14:15 flow rate from 1 -8 bpm, 150-450 psi, reciprocate pipe 10'. 2/7/2016 2/7/2016 0.25 SURFAC CEMENT RURD P BD Top drive and RU cement lines 2,291.0 2,291.0 14:15 14:30 and valve to cement swivel. 2/7/2016 2/7/2016 2.75 SURFAC CEMENT CMNT P PJSM. Surface cement job: Dowell 2,291.0 2,291.0 14:30 17:15 pump 2.0 bbls H2O and test lines to 2,500 psi-good,Dowell pump 75 bbls 10.5 ppg Mud Push II, Drop bottom plug,Dowell pump 365 bbls of 11.0 ppg scavenger slurry plus Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 6.0 bpm,250 psi. Dowell pump 57.8 bbls, 15.8 ppg,"G", 1.17 ft3/sx Tail cement at 7.0-7.5 bpm/500-800 psi. Drop top plug. Dowell pump 20 bbls H2O. 2/7/2016 2/7/2016 0.75 SURFAC CEMENT CMNT P Rig displace with 193.3 bbls of 10.0 2,291.0 2,291.0 17:15 18:00 ppg DrillPlex spud mud with YP=18. Initial 6 bpm at 250 psi,decreasing to 3.1 bpm at 500 psi. Increase to 1,000 psi and hold for 5 min.Check floats- good.Full returns throughout and 230 bbls of contaminated and good cement back to surface.Reciprocated pipe with 10'stroke until 335 bbl of Lead cement pumped.Stopped reciprocating due to excess drag and hole appearing to get sticky.CIP at 15:45 hrs,02/07/16. 2/7/2016 2/7/2016 1.25 SURFAC CEMENT RURD P Blow down cement line and RD Volant 0.0 0.0 18:00 19:15 CRT. Flush surface riser and Annular with black water. Function annular, close and monitor annulus pressure. Check pressure every 15 min for one hour and every 30 min there after. Pressure=0 psi when SI and at 24:00 hrs. Note:Annulus SI at 18:00 hrs Page 4/20 Report Printed: 3/7/2016 Dry • Operations Summary (with Timelog!epths) &Wells CD5-07 Conocol hillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/7/2016 2/8/2016 4.75 SURFAC CEMENT WOC P WOC for 12 hrs. SIMOPs:PJSM. PU 0.0 0.0 19:15 00:00 5"DP, perform required inspection on TD. 2/8/2016 2/8/2016 6.00 SURFAC CEMENT WOC P Continue to WOC. SIMOPs:Replace 0.0 0.0 00:00 06:00 part of the hydraulic line under the rig floor,finish required inspection and service work on the TD. PU and rack back 5"DS-50 DP(20 stds)in the derrick.PU and rack back Intermediate BHA#3 to 92'.Continue to work on both mud pumps(valves and seats). Monitor pressure on the annulus:5 psi at 06:00 hrs. Fluid holding static at flowline level. 2/8/2016 2/8/2016 1.00 SURFAC CEMENT WOC P Bleed off pressure under annular- 0.0 0.0 06:00 07:00 slight trickle.Shut-in and monitor pressure. Built back to 2 psi.Crack open and had a slight trickle. Shut back in and consult with town. SIMOPs: MU Dart/TIW valve for BOP test,prep tools and equipment for nipple down/nipple up. 2/8/2016 2/8/2016 4.00 SURFAC CEMENT WOO P Continue to WOC.PU bit#3 and 2X 0.0 0.0 07:00 11:00 MPD elements. PU 4"IF and 4"XT- 39 test connectors.Continue to PU and RB 21 stds of 5"DP(4ltotal stds of DS-50). Continue to monitor pressure on annular,increasing from 2 -28 psi. Stab MPD element on 5"DS- 50 DP and rack back. 2/8/2016 2/8/2016 0.50 SURFAC CEMENT WOO P Bleed off pressure(28 psi)under 0.0 0.0 11:00 11:30 annular and monitor flowrate (appeared to be mud). Flow at 32 sec to fill a quart cup to 97 sec to fill a quart cup.SIMOPs:continue to PU/MU 3 stds of 5"NC-50 DP and rack back.Open annular preventer. 2/8/2016 2/8/2016 0.50 SURFAC CEMENT NUND P Drain riser and annular. Attempt to 0.0 0.0 11:30 12:00 back out 10-3/4"Landing jt with 6K on EZ-Torque wrench-no good. 2/8/2016 2/8/2016 0.50 SURFAC CEMENT NUND P Back out 10-3/4"Landing jt with EZ- 0.0 0.0 12:00 12:30 Torque wrench-good. Back out pup jt on 10-3/4"landing jt. 2/8/2016 2/8/2016 2.75 SURFAC CEMENT NUND P ND Riser,annular,surface adaptor. 0.0 0.0 12:30 15:15 2/8/2016 2/8/2016 5.75 SURFAC WHDBOP NUND P NU wellhead and BOP stack.Test 0.0 0.0 15:15 21:00 wellhead seals to 1,000 psi-good. SIMOPs:change out Blind ram seals and NU MPDE. Check on trickle from annulus-9.0 ppg water cut mud with 2,400 ppm chlorides. 2/8/2016 2/8/2016 1.00 SURFAC WHDBOP RURD P MU test joint and install lower test 0.0 0.0 21:00 22:00 plug. Fill stack with water and RU test equipment. Page 5/20 Report Printed: 3/7/2016 operations Summary (with Timelog!epths) &Wells CD5-07 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(5KB) 2/8/2016 2/9/2016 2.00 SURFAC WHDBOP BOPE P BOPE Test:Test with 5"test joint, 0.0 0.0 22:00 00:00 Test Annular to 250/2,500 psi for 5 min, Test auto/manual IBOP, HCR Choke and Kill,Test choke valves #1,5,8,9,10,11,12,13 and#14.Test 4" Demco,choke and needle valve above#1 and Dart valve to 250/3,500 psi for 5 min. Test witnessing waived by Chuck Scheve of the AOGCC. 2/9/2016 2/9/2016 2.50 SURFAC WHDBOP BOPE P BOPE Test:Test with 5"test joint,Test 0.0 0.0 00:00 02:30 choke manifold valves#2,3,4,6,7, FOSV, HCR Choke and Kill, 5" manual IBOP, 3 1/2"X 6"upper VBR's,to 250/3500 psi for 5 min.- good. Koomey test; IP=3,150 psi, manifold press after close=1,450 psi, 200 psi recovery 37 sec,full recovery 216 sec, N2-4 bottle average=2,000 psi.Test Super/manual chokes to 1,100 psi. Test gas alarms-good. Test witnessing waived by Chuck Scheve of the AOGCC. 2/9/2016 2/9/2016 2.50 SURFAC WHDBOP MPDA P Pull Trip nipple. Install MPD test plug 0.0 0.0 02:30 05:00 in rotating head.Test MPD equipment to 200/1200 psi and chart.Blow down MPDE,pull test plug and RU Trip nipple. Pull lower test plug and search for leak.(Service 2"Lo-Torc valve on RCD.(LT1). PJSM.Stab RCD bearing on stand of 5"DP and rack back in derrick. Install MPD trip nipple. Blow down Choke manifold and MPD lines. 2/9/2016 2/9/2016 0.50 SURFAC WHDBOP MPDA P MU test jt and pull test plug. 0.0 0.0 05:00 05:30 2/9/2016 2/9/2016 0.50 SURFAC WHDBOP OTHR P Install bails and elevators Install 10"ID 0.0 0.0 05:30 06:00 wear ring.Clean&clear floor. 2/9/2016 2/9/2016 0.25 SURFAC WHDBOP RURD P Flush Poor-boy gas buster with 3 bpm, 0.0 0.0 06:00 06:15 90 psi. Blow down Choke/Kill lines. 2/9/2016 2/9/2016 1.00 SURFAC CEMENT BHAH P Finish MU BHA#3 with bit to 150'. 0.0 150.0 06:15 07:15 2/9/2016 2/9/2016 0.75 SURFAC CEMENT TRIP P RIH with 5"HWDP and Jars from 150' 150.0 702.0 07:15 08:00 to 702' 2/9/2016 2/9/2016 0.25 SURFAC CEMENT PULD P Continue RIH and PU 5"DP from 702.0 2,015.0 08:00 08:15 shed from 702'to 2,015'. 2/9/2016 2/9/2016 0.50 SURFAC CEMENT DHEQ P Shallow pulse test MWD with 450 gpm 2,015.0 2,015.0 08:15 08:45 and 1,030 psi. 2/9/2016 2/9/2016 0.50 SURFAC CEMENT SLPC P Slip and Cut 68'of drill line while CBU. 2,015.0 2,015.0 08:45 09:15 2/9/2016 2/9/2016 0.50 SURFAC CEMENT SVRG P Lubricate the rig,service TD and 2,015.0 2,015.0 09:15 09:45 drawworks. Blow down TD.Continue to CBU. 2/9/2016 2/9/2016 1.50 SURFAC CEMENT PRTS P RU testing equip. Fill lines and test 2,015.0 2,015.0 09:45 11:15 casing to 3,500 psi and chart for 30 min(good). RD testing equip and BD lines Page 6/20 Report Printed: 3/7/2016 • • Drilling Operations Summary (with Timelog Depths) ,{ &Wens IV CD5-07 Chiklips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/9/2016 2/9/2016 0.50 SURFAC CEMENT COCF P Wash and Ream from 2,015'to TOC 2,015.0 2,195.0 11:15 11:45 (cement stringers)at 2,195',w/450 gpm, 1,030 psi,40 rpm. 2/9/2016 2/9/2016 2.00 SURFAC CEMENT DRLG P Drill out FC and cement shoe track 2,195.0 2,301.0 11:45 13:45 from 2,165'to 2,288', FS from 2,288'- 2,291'and rat hole from 2,291'-2,301' with 450-650 gpm, 1,600-2,100 psi, 40 rpm and 4K TQ. 2/9/2016 2/9/2016 0.25 SURFAC CEMENT DDRL P Drill ahead 20'of new formation from 2,301.0 2,321.0 13:45 14:00 2,301'to 2,321'. Begin displacement to 9.6 ppg LSND while drilling with 650 gpm,40 rpm,4K TQ. 2/9/2016 2/9/2016 0.75 SURFAC CEMENT DISP P Finish displacement of 10 ppg 2,301.0 2,321.0 14:00 14:45 DrillPlex mud to 9.6 ppg LSND at 650 gpm,50 rpm,2,020 to 1,560 psi. 2/9/2016 2/9/2016 0.25 SURFAC CEMENT TRIP P POOH from 2,321'to inside csg at 2,321.0 2,283.0 14:45 15:00 2,283', Blow down TD. RU test equip and flo-chk-static. 2/9/2016 2/9/2016 0.75 SURFAC CEMENT FIT P RU test equip and perform FIT to 18.0 2,283.0 2,283.0 15:00 15:45 ppg EMW with 9.6 ppg LSND and 960 psi surface pressure. Blow down hose, lines and RD test equip. 2/9/2016 2/9/2016 1.50 INTRM1 DRILL DDRL P Drill ahead from 2,321'to 2,410'with 2,283.0 2,410.0 15:45 17:15 700 gpm, 1,800 psi,60 rpm,5.5K TQ. 2/9/2016 2/9/2016 0.50 INTRM1 DRILL CIRC P Shut down pump and break 2,410.0 2,410.0 17:15 17:45 connection. Drop activation ball and pump down with 650 gpm. Slowed pumps to 125 gpm and 120 psi. Ball went on seat and sheared cutters open at 1,230 psi. Increased pump rate to 800 gpm and saw PU and "pull test"against the 10-3/4"csg shoe with 10K lb confirming 11"cutters open. 2/9/2016 2/9/2016 4.00 INTRM1 DRILL DDRL P Drill ahead from 2,410'to 3,023'and 2,410.0 3,023.0 17:45 21:45 2/9/2016 2/9/2016 0.50 INTRM1 DRILL SVRG T Circ at 1 bpm,40 psi, 15 rpm. Clean 2,410.0 3,023.0 21:45 22:15 out and adjust cutting drag chain. 2/9/2016 2/10/2016 1.75 INTRM1 DRILL DDRL P Drill ahead from 3,023'to 3,330'and/ 3,023.0 3,330.0 22:15 00:00 2,924'tvd, ADT:5.34 hrs, ECD 10.81 ppg,800 gpm,2,000 psi,PU= 135K, S0=125K, ROT= 125K Ib, 180 rpm, 6.5/2.8K TQ,9K lb WOB SPRs-2,300'md, 16:00 hrs MP#1: 30-90, 40-130 MP#2: 30-90, 40-130 2/10/2016 2/10/2016 12.00 INTRM1 DRILL DDRL P Drill ahead from 3,330'to 4,985'and/ 3,330.0 4,985.0 00:00 12:00 4,038'tvd, ADT:8.15 hrs, ECD 11.43 ppg,800 gpm,2,550 psi, PU=162K, S0= 135K, ROT= 145K Ib, 180 rpm, 12.5/6.5K TQ,23K lb WOB SPRs-2,300'md, 16:00 hrs MP#1: 30-130, 40-160 MP#2: 30-130, 40-170 2/10/2016 2/10/2016 7.25 INTRM1 DRILL DDRL P Drill ahead from 4,985'to 6,067'and/ 4,985.0 6,067.0 12:00 19:15 4,762'tvd, ADT:4.84 hrs Page 7/20 Report Printed: 3/7/2016 • • Drilling Operations Summary (with Timelog Depths) .-t &welns CD5-07 ConocoPhitlps Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/10/2016 2/10/2016 0.50 INTRM1 DRILL RGRP T Repair Drag chain in mud pits.Center 6,067.0 6,067.0 19:15 19:45 sprocket and tighten with impact wrench. Function test-ok SIMOPs: circulate well at 1 bpm, 100 psi,30 rpm,9K TQ 2/10/2016 2/11/2016 4.25 INTRM1 DRILL DDRL P Drill ahead from 6,067'to 6,808'and/ 6,067.0 6,808.0 19:45 00:00 5,256'tvd, ADT:7.88 hrs, ECD 11.17 ppg,800 gpm,2,510 psi, PU= 190K, SO= 150K,ROT=174K Ib, 180 rpm, 17.2/7K TQ, WOB=33K lb SPRs-5,865'md, 17:50 hrs MP#1: 30-170, 40-220 MP#2: 30-180, 40-220 2/11/2016 2/11/2016 12.00 INTRM1 DRILL DDRL P Drill ahead from 6,808'to 8,684'and/ 6,808.0 8,684.0 00:00 12:00 6,529'tvd, ADT:7.88 hrs,ECD 11.16 ppg,800 gpm,2,580 psi,PU=233K, SO=176K,ROT= 199K Ib, 180 rpm, 20/12.5K TQ, WOB=33K lb SPRs-8,590'md, 11:20 hrs MP#1: 30-210, 40-260 MP#2: 30-210, 40-260 2/11/2016 2/11/2016 0.50 INTRM1 DRILL BKRM P Backream from 8,684'to 8,590'with 8,684.0 8,684.0 12:00 12:30 800 gpm,2,520 psi, 180 rpm, 11.5K TQ. 2/11/2016 2/11/2016 0.50 INTRM1 DRILL MPDA P Pull Trip nipple and install MPD 8,684.0 8,684.0 12:30 13:00 bearing. 2/11/2016 2/11/2016 0.50 INTRM1 DRILL MPDA P Circulate at 6 bpm,430 psi and break 8,684.0 8,684.0 13:00 13:30 in RCD bearing with 5-=100 rpm, 10.3 -12.2K TQ,for 2 minutes. 2/11/2016 2/12/2016 10.50 INTRM1 DRILL DDRL P Drill ahead from 8,684'to 9,620'and/ 8,684.0 9,620.0 13:30 00:00 7,153'tvd, ADT:7.61 hrs,ECD 11.8 ppg,800 gpm,2,580 psi, PU=240K, SO= 176K, ROT=200K Ib, 180 rpm, 23.3/11.5K TQ, WOB=33K lb SPRs-8,590'md, 11:20 hrs MP#1: 30-210, 40-260 MP#2: 30-210, 40-260 2/12/2016 2/12/2016 12.00 INTRM1 DRILL DDRL P Drill ahead from 9,260'to 10,370'and/ 9,620.0 10,370.0 00:00 12:00 7,437'tvd, ADT:8.52 hrs,ECD 11.46 ppg,800 gpm,2,990 psi,PU=270K, SO=165K, ROT=205K Ib, 180 rpm, 25/15K TO, WOB=27K lb SPRs-10,370'md, 11:50 hrs MP#1: 30-500, 40-540 MP#2: 30-500, 40-540 2/12/2016 2/12/2016 2.50 INTRM1 DRILL DDRL P Drill ahead from 10,370'to 10,642' 10,370.0 10,642.0 12:00 14:30 and/7,470'tvd, ADT:1.76 hrs, ECD 11.48 ppg,800 gpm,3,050 psi, PU= 272K,SO=167K, ROT=205K Ib, 180 rpm,25/18K TQ, WOB=27K lb Page 8/20 Report Printed: 3/7/2016 Operations Summary (with Timelog Depths) &&W' • W+ mm CD5-07 ConocoPhiilips a3.;eks Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/12/2016 2/12/2016 0.50 INTRM1 CASING CIRC P Pump up final survey. Backream at 60 10,642.0 10,642.0 14:30 15:00 rpm,800 gpm,3,060 psi and 14.5K TQ from 10,642 to 10,619'. 2/12/2016 2/12/2016 0.50 INTRM1 CASING CIRC P Drop ball and shear close under- 10,642.0 10,642.0 15:00 15:30 reamer with 2,200 psi. 2/12/2016 2/12/2016 6.75 INTRM1 CASING CIRC P Circ hole clean for 5 B/U with 775-600 10,642.0 10,642.0 15:30 22:15 gpm,2890-1920 psi, 160-100 rpm, 17-14 TQ while reciprocating the pipe 80'strokes and holding 74-100 psi backpressure. 20:00 hrs start weighting up from 10.4 ppg to 10.6 pp9. 2/12/2016 2/13/2016 1.75 INTRM1 CASING CIRC T Continue to circulate and Wait on 10,642.0 10,642.0 22:15 00:00 Weather-Phase 2/3. Continue to increase MW to 10.7 ppg. Circ hole clean with 600 gpm,2,450 psi, 100 rpm, 15K TQ while reciprocating the pipe 80'strokes and holding 31 psi back pressure. 2/13/2016 2/13/2016 12.00 INTRM1 CASING CIRC T Continue to Wait on Weather-Phase 10,642.0 10,642.0 00:00 12:00 2/3. Continue to increase MW to 10.8 ppg. Circ hole clean with 600 gpm, 2,450 psi, 100 rpm, 15K TQ while reciprocating the pipe 80'strokes and holding 31 psi back pressure. 2/13/2016 2/14/2016 12.00 INTRM1 CASING CIRC T Continue to Wait on Weather-Phase 10,642.0 10,642.0 12:00 00:00 2/3. Circ hole clean with 600 gpm, 2,450 psi, 100 rpm, 15K TQ while reciprocating the pipe 80'strokes and holding 31 psi back pressure. 2/14/2016 2/15/2016 24.00 INTRM1 CASING CIRC T Continue to Wait on Weather-Phase 10,642.0 10,642.0 00:00 00:00 2/3. Circ hole clean with 600 gpm, 2,600 psi,80 rpm, 14K TQ while reciprocating the pipe 80'strokes and holding 33 psi back pressure. PU=272K,SO= 167K, ROT=205K lb. 2/15/2016 2/15/2016 11.00 INTRM1 CASING CIRC T Continue to Wait on Weather-Phase 10,642.0 10,642.0 00:00 11:00 2/3. Circ hole clean with 600 gpm, 2,450 psi, 100 rpm, 15K TQ while reciprocating the pipe 80'strokes, ECD 11.5-11.6,31 psi line restriction from MPD equipment. 2/15/2016 2/15/2016 3.00 INTRM1 CASING CIRC P Increase mud weight from a 10.8ppg 10,642.0 10,642.0 11:00 14:00 to 11.1 ppg with pre-sheared spike fluid. 2/15/2016 2/15/2016 0.25 INTRM1 CASING OWFF P Flow check well,rot 10rpm 10,642.0 10,642.0 14:00 14:15 Well ooze then stop. 2/15/2016 2/15/2016 0.50 INTRM1 CASING SMPD P Rack back first stand and attempt to 10,642.0 10,557.0 14:15 14:45 pull on elevators from 10,557'. Pull 50k over at 10,519'and slacking off to block weight at 10,532'. Attempt to work pipe past tight spot. Page 9/20 Report Printed: 3/7/2016 0 • Operations Summary (with Timelog Depths) .-; &W,+ CD5-07 ConocoPhitrps Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/15/2016 2/15/2016 2.00 INTRM1 CASING BKRM T Rack back first stand and attempt to 10,557.0 10,525.0 14:45 16:45 pull on elevators from 10,557'.Pull 50k over at 10,519'work pipe trying to pass start to take weight at 10,532'. Set slips and kelly up at 10,525'with pipe free. Establish circulation @ 230gpm 635psi and pick up to rotating weight of 230k. Attempt to establish rotation and torque out at 30kft/Ibs. Release torque and work pipe trying to establish a free area. Pull up to 325k and set 100k trying to work free spot. Consult with town and work pipe in the downward position firing jars with torque trapped in the pipe.Set 50k down on Jars and fire.Reduce pump rate and work pipe to no success. Torque pipe up to 29kft/lbs and slacked off and pipe jumped with rotation then stuck again. Consult with town and work pipe up, pull up to 375k and pipe moved up hole.Continue to work pipe until small area of free pipe observed at 10,525'. Pick up to 280k and rotate pipe at 50rpm's pipe broke over at 27kft/lbs and free tq at 16kft/lbs 2/15/2016 2/15/2016 2.25 INTRM1 CASING BKRM T BROOH slowly from 10,525'with 430 10,525.0 10,461.0 16:45 19:00 gpm, 1,380 psi,56 rpm and 16K TQ. 2/15/2016 2/15/2016 0.75 INTRM1 CASING REAM T Ream back trough tight spots from 10,461.0 10,558.0 19:00 19:45 10,461'to 10,558'with 430 gpm, 1,380 psi and 16K TQ. 2/15/2016 2/15/2016 1.75 INTRM1 CASING SMPD P Line up and strip-OOH holding MPD 10,558.0 9,150.0 19:45 21:30 back pressure as scheduled from 10,558'to 9,150'. 2/15/2016 2/15/2016 0.50 INTRM1 CASING OWFF P Shut down pump,close Orbit valve 9,150.0 9,150.0 21:30 22:00 and flow check well in the cellar for 5 minutes-static. 2/15/2016 2/16/2016 2.00 INTRM1 CASING SMPD P Line up and strip-OOH holding MPD 9,150.0 6,808.0 22:00 00:00 back pressure as scheduled from 9,150"to 6,808'. 2/16/2016 2/16/2016 3.25 INTRM1 CASING SMPD P Strip OOH as per MPD schedule 6,808.0 2,297.0 00:00 03:15 f/6,808'to 2,297' 2/16/2016 2/16/2016 0.50 INTRM1 CASING OWFF P F/C(static) 2,297.0 2,297.0 03:15 03:45 2/16/2016 2/16/2016 1.25 INTRM1 CASING CIRC P Pump 29 bbl nut plug sweep&circ 2,297.0 2,297.0 03:45 05:00 casing clean w/550-450 gpm @ 980- 380 psi,60 rpm @ 2 k trq. 2/16/2016 2/16/2016 1.00 INTRM1 CASING SMPD P Strip OOH as per MPD schedule 2,297.0 702.0 05:00 06:00 f/2,297'to 702' 2/16/2016 2/16/2016 1.25 INTRM1 CASING MPDA P Remove MPD bearing&install trip 702.0 702.0 06:00 07:15 nipple. 2/16/2016 2/16/2016 0.75 INTRM1 CASING TRIP P POOH f/702'to 150 on elevators on 702.0 150.0 07:15 08:00 TT 2/16/2016 2/16/2016 1.75 INTRM1 CASING BHAH P L/D BHA#3 as per SLB 150.0 0.0 08:00 09:45 2/16/2016 2/16/2016 0.50 INTRM1 CASING BHAH P Clean&clear floor of BHA tools& 0.0 0.0 09:45 10:15 equipment Page 10/20 Report Printed: 3/7/2016 Drilling, Operations Summary (with Timelog Depths) =; W CD5-07 ConocoPhiiiaps Aixcka Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/16/2016 2/16/2016 0.50 INTRM1 CASING WWWH P M/U stack washer&flush stack 0.0 0.0 10:15 10:45 2/16/2016 2/16/2016 1.25 INTRM1 CASING RURD P Drain BOPE stack.P/U bail 0.0 0.0 10:45 12:00 extensions. P/U Volant tool to rig floor. Pull wear ring as per FMC. Un-able to pull with tugger. Pull with top drive. 2/16/2016 2/16/2016 2.00 INTRM1 CASING BOPE P C/O upper rams to 7 5/8".With 7 5/8" 0.0 0.0 12:00 14:00 test joint,test annular to 250/2500 psi &upper rams 250/3500 psi&chart for 5 min. 2/16/2016 2/16/2016 1.25 INTRM1 CASING RURD P Set 10.125"thin wall wear ring. R/U to 0.0 0.0 14:00 15:15 run casing. M/U Volant tool&R/U elevators&slips. 2/16/2016 2/17/2016 8.75 INTRM1 CASING PUTB P RIH 7 5/8"29.7#L-80 Hyd 563 casing 0.0 3,663.0 15:15 00:00 to 3,663'(Check floats-good) 2/17/2016 2/17/2016 14.25 INTRM1 CASING PUTB P RIH 7 5/8"29.7#L-80 Hyd 563 casing 3,663.0 10,593.0 00:00 14:15 f/3,663'to 10,593' 2/17/2016 2/17/2016 0.25 INTRM1 CASING HOSO P M/U hanger&land on depth @ 10,593.0 10,633.0 14:15 14:30 10,632.59. P/U wt 285 k,SO wt 175 k. 2/17/2016 2/17/2016 0.50 INTRM1 CEMENT RURD P C/O wash cups on Volant tool. B/D. 10,633.0 10,663.0 14:30 15:00 B/D top drive&R/U cement lines. 2/17/2016 2/17/2016 4.50 INTRM1 CEMENT CIRC P Circ&cond mud for cement job. 10,663.0 10,663.0 15:00 19:30 Stage pumps f/1 to 7.5 bpm,240-690 psi.Reciprocate pipe 10'. Mud wt 10.8 ppg in/out w/20 yield point. 2/17/2016 2/17/2016 3.00 INTRM1 CEMENT CMNT P PJSM.Cement 1st stage as per 10,663.0 10,663.0 19:30 22:30 Dowell.Dowell pressure test lines to 4000 psi(good).Dowell pump 40.1 bbls 12.5 ppg Mud Push,Drop ByPass plug,82.5 bbls 15.8 ppg 1.16 yld Qannik blend cement, Drop landing plug, 10.1 bbls H2O& displace with 489 bbls(486 bbls calculated+3 bbls 1/2 shoe track volume) 10.8 ppg LSND. Did not bump plug. Initial 6 bpm @ 150-450 psi, Final 3 bpm @ 360 psi. Reciprocate pipe w/full returns.Check floats(good)CIP 22:30 hrs 2/17/2016 2/17/2016 1.25 INTRM1 CEMENT RURD P Blow down cement lines&R/D same. 0.0 0.0 22:30 23:45 R/D Volant.Clean&clear floor. Prep to L/D 5"DP.SIMOPS-W.O.C. 2/17/2016 2/18/2016 0.25 INTRM1 CEMENT PULD P L/D 2 stands 5"DP via 90'mouse 0.0 0.0 23:45 00:00 hole.SIMOPS-W.O.C. 2/18/2016 2/18/2016 0.50 INTRM1 CEMENT PULD P L/D 2 stands 5"DP via 90'mouse 0.0 0.0 00:00 00:30 hole. 2/18/2016 2/18/2016 0.75 INTRM1 CEMENT RURD P L/D Volant tool&casing tools& 0.0 0.0 00:30 01:15 equipment via beaver slide.Strip off 5" MPD bearing from DP&bring 4" bearing to rig floor. 2/18/2016 2/18/2016 7.75 INTRM1 CEMENT PULD P L/D 49 stands 5"DP via 90'mouse 0.0 0.0 01:15 09:00 hole. Move 6 stands to DS. L/D 12 stands 5"DP via 90'mouse hole. L/D HWDP&jars. 2/18/2016 2/18/2016 0.75 INTRM1 CEMENT RURD P R/U cement head&cement lines 0.0 0.0 09:00 09:45 Page 11/20 Report Printed: 3/7/2016 operations Summary (with Timelog 6epths) Wells CD5-07 ConocoPhitlips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/18/2016 2/18/2016 2.50 INTRM1 CEMENT CIRC P Pressure test lines to 3800 psi.Open 5,191.0 5,191.0 09:45 12:15 stage collar w/3100 psi.Circ&cond mud for cement job.Stage pumps to 7 bpm @ 320 psi. 10.8 ppg in/out 2/18/2016 2/18/2016 2.00 INTRM1 CEMENT CMNT P Cement 2nd stage.Dowell pressure 5,191.0 5,191.0 12:15 14:15 test lines to 4000 psi(good). Dowell pump 46 bbls 12.5 ppg Mud Push,64 bbls 15.8 ppg 1.16 yld Qannik blend cement,Drop closing plug, 10 bbls H2O&displace with 244 bbls 10.8 ppg LSND.Initial 5.6 bpm&Final 3 bpm @ 582 psi.w/full returns. Bump closing plug&pressure to 2190 psi& shift stage collar closed. Hold for 5 min.CIP 14:00 hrs 2/18/2016 2/18/2016 0.50 INTRM1 CEMENT RURD P R/D cement head&cement lines. 0.0 0.0 14:15 14:45 Clean&clear floor 2/18/2016 2/18/2016 1.50 INTRM1 CEMENT WWSP P L/D landing jt.Set pack off&test to 0.0 0.0 14:45 16:15 5000 psi for 10 min(good). 2/18/2016 2/18/2016 0.75 INTRM1 CEMENT WWWH P R/U stack washer&flush stack. R/D& 0.0 0.0 16:15 17:00 B/D top drive. 2/18/2016 2/18/2016 4.00 INTRM1 CEMENT PULD P L/D 40 stands 5"DP via 90'mouse 0.0 0.0 17:00 21:00 hole. Move 6 stands to ODS for next well.SIMOPS-C/O upper pipe rams to 3 1/2"X 6"VBR's 2/18/2016 2/18/2016 2.00 INTRM1 CEMENT RURD P C/O saver sub to 4"XT 39. 0.0 0.0 21:00 23:00 2/18/2016 2/18/2016 0.75 INTRM1 WHDBOP RURD P R/U testing equipment. Fill stack& 0.0 0.0 23:00 23:45 lines with H2O. 2/18/2016 2/19/2016 0.25 INTRM1 WHDBOP BOPE P Test BOPE w/4"Test jt.Annular 0.0 0.0 23:45 00:00 250/2500 chart for 5 min(good) 2/19/2016 2/19/2016 6.00 INTRM1 WHDBOP BOPE P BOPE Test:Test with 4"&4 1/2"test 0.0 0.0 00:00 06:00 joints,Test Annular to 250/2,500 psi for 5 min,Test choke valves#1 -14 and needle valve to 250/3,500 psi for 5 min. HCR Choke and Kill,4"Demco, 5"FOSV,dart&needle valves,auto& manual IBOP, HCR choke&kill,3 1/2" X 6"upper&lower VBR's,&blind rams to 250/3500 psi for 5 min. Koomey test; IP=3,150 psi,manifold press after close= 1,300 psi,200 psi recovery 33 sec,full recovery 232 sec, N2-4 bottle average=2350 psi. Tested gas alarms.Draw down on man&super choke to 1,200 psi. - Test witnessed waived by Brian Bixby of the AOGCC.(Tighten Oteco clamp on choke line leaking) 2/19/2016 2/19/2016 1.00 INTRM1 WHDBOP RURD P R/D testing equipment. B/D choke& 0.0 0.0 06:00 07:00 kill lines. Pull test plug&install 7.0625"ID wear ring. Install split bushings. 2/19/2016 2/19/2016 2.25 INTRM1 CEMENT BHAH P M/U BHA#4 as per SLB 0.0 411.0 07:00 09:15 2/19/2016 2/19/2016 2.00 INTRM1 CEMENT PULD P Single in hole w/4"DP f/411'to 2,301' 411.0 2,301.0 09:15 11:15 2/19/2016 2/19/2016 0.50 INTRM1 CEMENT DHEQ P Shallow hole test MWD&directional 2,301.0 2,301.0 11:15 11:45 tools w/250 gpm @ 1700 psi,30 rpm @ 2 k trq Page 12/20 Report Printed: 3/7/2016 • Operations Summary (with Timelog Depths) „:4 IrMirlThill &Wells CD5-07 LonoscOPhiilips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/19/2016 2/19/2016 3.00 INTRM1 CEMENT PULD P Single in hole w/4"DP f12,301'to 2,301.0 5,042.0 11:45 14:45 5,042' 2/19/2016 2/19/2016 1.25 INTRM1 CEMENT PRTS P R/U testing equipment&test casing to 5,042.0 5,042.0 14:45 16:00 1000 psi for 10 min(good).R/D&B/D testing equipment. 2/19/2016 2/19/2016 0.75 INTRM1 CEMENT COCF P W&R f/5,042'to stage collar @ 5,191' 5,042.0 5,191.0 16:00 16:45 w/215 gpm @ 1450 psi,50 rpm @ 4.5 k trq. 2/19/2016 2/19/2016 1.50 INTRM1 CEMENT DRLG P Drill stage collar f/5,191'to 5,193' 5,191.0 5,193.0 16:45 18:15 w/215-230 gpm @ 1400-1580 psi, 30-60 rpm @ 4.7-5 k trq.Work through stage collar&confirm clear. 2/19/2016 2/19/2016 1.75 INTRM1 CEMENT REAM P W&R f/5,193 to 5,421'w/215 gpm @ 5,193.0 5,421.0 18:15 20:00 1460 psi,60 rpm @ 4.5 k trq. 2/19/2016 2/19/2016 0.75 INTRM1 CEMENT PULD P Single in hole w/4"DP(/5,421'to 5,421.0 5,932.0 20:00 20:45 5,932'(started losing down weight) 2/19/2016 2/19/2016 1.00 INTRM1 CEMENT REAM P W&R f15,932'to 6,083'w/215 gpm @ 5,932.0 6,083.0 20:45 21:45 1450-1520 psi,60-70 rpm @ 4.5- 5.5 k trq. 2/19/2016 2/20/2016 2.25 INTRM1 CEMENT PULD P Single in hole w/4"DP f/6,083'to 6,083.0 7,789.0 21:45 00:00 7,789'.PU wt 173 k,SO wt 118 k 2/20/2016 2/20/2016 1.00 INTRM1 CEMENT PULD P Single in hole w/4"DP f/7,789'to 7,789.0 8,546.0 00:00 01:00 8,546'.SO wt 122 k 2/20/2016 2/20/2016 0.25 INTRM1 CEMENT CIRC P Fill pipe&break cir. PJSM on slip& 8,546.0 8,546.0 01:00 01:15 cut drill line. 2/20/2016 2/20/2016 0.75 INTRM1 CEMENT SLPC P Slip&cut 68'drill line.SIMOPS-Circ 8,546.0 8,546.0 01:15 02:00 w/2.5 bpm @ 660 psi 2/20/2016 2/20/2016 0.50 INTRM1 CEMENT SVRG P Service rig&top drive 8,546.0 8,546.0 02:00 02:30 2/20/2016 2/20/2016 1.00 INTRM1 CEMENT DHEQ T Downlink to MWD tools&actvate 8,546.0 8,546.0 02:30 03:30 sonic tool w/250 gpm @ 2140 psi. (Mud aired up and had trouble getting MWD detection) 2/20/2016 2/20/2016 0.25 INTRM1 CEMENT SLPC P Calibrate block height from slip&cut. 8,546.0 8,546.0 03:30 03:45 2/20/2016 2/20/2016 3.75 INTRM1 CEMENT DLOG P Sonic log 900 ft/hr for cement integrity 8,546.0 10,093.0 03:45 07:30 while single in hole w/4"DP f/8,546'to 10,093' 2/20/2016 2/20/2016 1.00 INTRM1 CEMENT COCF P W&R f/10,093'to 10,251'w/230 gpm 10,093.0 10,251.0 07:30 08:30 @ 2070 psi,30 rpm @ 10 k trq 2/20/2016 2/20/2016 2.50 INTRM1 CEMENT PRTS P R/U testing equipment.Test casing to 10,251.0 10,251.0 08:30 11:00 3500 psi&chart for 30 min.(Had some trouble with air heaters causing pressure to fluctuate.Shut off heaters). (Good test). R/D testing equipment. 2/20/2016 2/20/2016 1.50 INTRM1 CEMENT COCF P W&R f/10,251'to 10,447'.Tag T.O.C. 10,251.0 10,447.0 11:00 12:30 w/230 gpm @ 2140 psi,50 rpm @ 11 k trq 2/20/2016 2/20/2016 3.75 INTRM1 CEMENT DRLG P Drill cement,shoe track&rat hole 10,447.0 10,642.0 12:30 16:15 f/10,447'to 10,642'w/230-250 gpm @ 2140-2440 psi,40-50 rpm@ 11 - 13.5 k trq.(Tag B/C, F/C as per tally) 2/20/2016 2/20/2016 0.50 INTRM1 CEMENT DDRL P Drill 20'new formation f/10,642'to 10,642.0 10,662.0 16:15 16:45 10,662'MD/7,472'TVD,ADT 0.4 hrsd.260 gpm @ 2700 psi,50 rpm @ 11.5 k trq Page 13/20 Report Printed: 3/7/2016 Operations Summary (with Timelog Depths) ., Drilriwots CD5-07 t:onocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/20/2016 2/20/2016 1.25 INTRM1 CEMENT CIRC P Circ clean for FIT w/260 gpm @ 2700 10,662.0 10,538.0 16:45 18:00 psi,50 rpm @ 13.5 k trq. Back ream BHA inside casing f/10,662'to 10,538' 2/20/2016 2/20/2016 0.25 INTRM1 CEMENT OWFF P F/C(static)B/D top drive 10,538.0 10,538.0 18:00 18:15 2/20/2016 2/20/2016 1.00 INTRM1 CEMENT FIT P R/U testing equipment.FIT to 12.8 10,538.0 10,538.0 18:15 19:15 ppg w/820 psi 1.3 bbls.R/D testing equipment. 2/20/2016 2/20/2016 1.25 PROD1 DRILL MPDA P Remove trip nipple.Rack back spare 10,538.0 10,538.0 19:15 20:30 MPD bearing. Install MPD bearing. 2/20/2016 2/20/2016 0.75 PROD1 DRILL REAM P Break in new bearing.W&R f/10,538' 10,538.0 10,662.0 20:30 21:15 to 10,662' w/260 gpm©2650 psi,50 rpm @ 11 k trq&100 rpm @ 12.5 k trq 2/20/2016 2/21/2016 2.75 PROD1 DRILL DDRL P Drill ahead f/10,662'to 10,785'MD/ 10,662.0 10,785.0 21:15 00:00 7,476'TVD,ADT 1.59 hrs,9.75 ppg ECD,275 gpm, 1920 psi, PU wt 203 k, SO wt 147 k,ROT wt 163 k, 150 rpm, Trq 10.3/5.8 k,WOB 15/18 k (Pump 32 bbl spacer&displace to 9.0 ppg FloPro on the fly) 2/21/2016 2/21/2016 12.00 PROD1 DRILL DDRL P Drill ahead f/10,785'to 12,527'MD/ 10,785.0 12,527.0 00:00 12:00 7,460'TVD,ADT 9.31 hrs, 10.14 ppg ECD,275 gpm,2350 psi, PU wt 195 k, SO wt 137 k,ROT wt 162 k, 150 rpm, Trq 10.3/5.8 k,WOB 8/4.5 k 2/21/2016 2/22/2016 12.00 PROD1 DRILL DDRL P Drill ahead f/12,527'to 13,873'MD/ 12,527.0 13,873.0 12:00 00:00 7,474'TVD,ADT 9.6 hrs, 10.15 ppg ECD,275 gpm,2410 psi,PU wt 192 k, SO wt 134 k, ROT wt 162 k, 150 rpm, Trq 7/5 k,WOB 14/19 k 2/22/2016 2/22/2016 12.00 PROD1 'DRILL DDRL P Drill ahead f/13,873'to 15,262'MD/ 13,873.0 15,522.0 00:00 12:00 7,438'TVD,ADT 9.1 hrs, 10.51 ppg ECD,295 gpm,2830 psi, PU wt 195 k, SO wt 128 k,ROT wt 162 k, 150 rpm, Trq 8.5/5.5k,WOB 10k 2/22/2016 2/22/2016 4.00'PROD1 DRILL DDRL P Drill ahead f/15,262'to 15,522'MD/ 13,873.0 15,522.0 12:00 16:00 7,427'TVD,ADT 3.62 hrs, 10.25 ppg ECD,300 gpm,2860 psi, PU wt 198 k, SO wt 130 k,ROT wt 165 k, 160 rpm, Trq 8/5.5 k,WOB 8/11 k. (Not able to maintain directional control efficiently, decision made to POOH&CIO BHA) 2/22/2016 2/22/2016 7.25 PROD1 DRILL CIRC T Circ hole clean for 5+B/U w/275-230 15,522.0 15,484.0 16:00 23:15 gpm @ 2540-1900 psi, 150 rpm @ 6.5 k trq. Rack back 1 stand to 15,484' 2/22/2016 2/23/2016 0.75 PROD1 DRILL DISP T Pump 31 bbl space&displace to 9.5 15,484.0 15,484.0 23:15 00:00 ppg viscosified brine w/275 gpm @ 2420-2020 psi, 150 rpm©6.5 k trq. 2/23/2016 2/23/2016 1.25 PROD1 DRILL DISP T Cont.to displace to 9.5 ppg viscosified 15,484.0 15,484.0 00:00 01:15 brine w/275 gpm @ 2020 psi, 150 rpm @ 6 k trq.Obtain SPR's 2/23/2016 2/23/2016 0.25 PROD1 DRILL OWFF T F/C(static)-SIMOPS B/D top drive& 15,484.0 15,484.0 01:15 01:30 line up MPD for stripping out of hole. 2/23/2016 2/23/2016 4.75 PROD1 DRILL SMPD T Strip OOH f115,484'to 10,538'as per 15,484.0 10,538.0 01:30 06:15 MPD trip schedule. Page 14/20 Report Printed: 3/7/2016 0 ng Operations Summary (with Timelog Depths) `;, &W U CD5-07 ConocoPhillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/23/2016 2/23/2016 0.25 PROD1 DRILL OWFF T F/C(static) 10,538.0 10,538.0 06:15 06:30 2/23/2016 2/23/2016 7.50 PROD1 DRILL SMPD T Strip OOH f/10,538'to 411'as per 10,538.0 411.0 06:30 14:00 MPD trip schedule. 2/23/2016 2/23/2016 0.50 PROD1 DRILL OWFF T F/C(static)Function rams&B/D MPD 411.0 411.0 14:00 14:30 lines 2/23/2016 2/23/2016 0.50 PROD1 DRILL MPDA T Remove MPD bearing&install trip 411.0 411.0 14:30 15:00 nipple. 2/23/2016 2/23/2016 2.25 PROD1 DRILL BHAH T PJSM.Rack back HWDP&jars.L/D 411.0 0.0 15:00 17:15 BHA as per SLB. Hole Fill Cal/Act=87.8/120.5 bbls 2/23/2016 2/23/2016 0.25 PROD1 DRILL MPDA T Strip RCD bearing from drill pipe 0.0 0.0 17:15 17:30 2/23/2016 2/23/2016 1.25 PROD1 DRILL BHAH T Clean&clear floor of BHA tools& 0.0 0.0 17:30 18:45 equip. 2/23/2016 2/23/2016 1.75 PROD1 DRILL BHAH T M/U BHA#5 as per SLB 0.0 350.0 18:45 20:30 2/23/2016 2/23/2016 0.50 PROD1 DRILL TRIP T RIH f/350'to 1,766' 350.0 1,766.0 20:30 21:00 2/23/2016 2/23/2016 1.00 PROD1 DRILL DHEQ T Attempt to shallow hole test.Having 1,766.0 1,766.0 21:00 22:00 trouble getting signal from tools. Mud aired up.Shallow hole test good,but not able to down link 2/23/2016 2/24/2016 2.00 PROD1 DRILL TRIP T RIH f/1,766'to 5,274'Fill pipe every 1,766.0 5,274.0 22:00 00:00 20 stands 2/24/2016 2/24/2016 3.50 PROD1 DRILL TRIP T RIH f/5,274'to 10,477'.Fill pipe every 5,274.0 10,477.0 00:00 03:30 20 stands 2/24/2016 2/24/2016 0.25 PROD1 DRILL CIRC T Break circ w/100 gpm @ 270 psi. 10,477.0 10,477.0 03:30 03:45 PJSM on slip&cut. 2/24/2016 2/24/2016 0.50 PROD1 DRILL SLPC T Slip&cut 36'drill line. 10,477.0 10,477.0 03:45 04:15 2/24/2016 2/24/2016 0.50 PROD1 DRILL SVRG T Service rig,top drive&blocks 10,477.0 10,477.0 04:15 04:45 2/24/2016 2/24/2016 0.25 PROD1 DRILL SLPC T Calibrate block height. 10,477.0 10,477.0 04:45 05:00 2/24/2016 2/24/2016 0.75 PROD1 DRILL MPDA T Remove trip nipple&install MPD 10,477.0 10,477.0 05:00 05:45 bearing. 2/24/2016 2/24/2016 4.50 PROD1 DRILL TRIP T RIH f/10,477'to 15,423'. Fill pipe 10,477.0 15,423.0 05:45 10:15 every 20 stands 2/24/2016 2/24/2016 1.25 PROD1 DRILL REAM T W&R f/15,423'to 15,522'w/260 gpm 15,423.0 15,522.0 10:15 11:30 @ 1840 psi. 100 rpm @ 6.5 k trq. 2/24/2016 2/25/2016 12.50 PROD1 DRILL DDRL P Drill ahead f/15,522'to 16,986'MD/ 15,522.0 16,986.0 11:30 00:00 7,404'TVD,ADT 8.79 hrs, 10.41 ppg ECD,270 gpm,2700 psi,PU wt 219 k, SO wt 139 k, ROT wt 180 k, 140 rpm, Trq 10.5/7.5 k,WOB 15/18 k. (Displace to 9.0 ppg Flo Pro on the fly) 2/25/2016 2/25/2016 12.00 PROD1 DRILL DDRL P Drill ahead f/16,986'to 18,775'MD/ 16,986.0 18,775.0 00:00 12:00 7,388'TVD,ADT 8.46 hrs, 10.53 ppg ECD,270 gpm,3040 psi,PU wt 235 k, SO wt 125 k, ROT wt 185 k, 140 rpm, Trq 12.6/8.5 k,WOB 15 k. 2/25/2016 2/26/2016 12.00 PROD1 DRILL DDRL P Drill ahead f/18,775'to 20,310'MD/ 18,775.0 20,310.0 12:00 00:00 7,370'TVD,ADT 8.68 hrs, 10.65 ppg ECD,275 gpm,3150 psi, PU wt 240 k, SO wt N/A k,ROT wt 184 k, 140 rpm, Trq 14/10.5 k,WOB 16/19 k. Page 15/20 Report Printed: 3/7/2016 • 0 Drilling Operations Summary (with Timelog Depths) .`.:i &Wets CD5-07 CcmiaccoPtiillips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/26/2016 2/26/2016 0.25 PROD1 'DRILL DDRL P Drill ahead f/20,310'to 20,376'MD/ 20,310.0 20,376.0 00:00 00:15 7,369'TVD ADT.36 hrs(swivel packing on top drive leaking) 2/26/2016 2/26/2016 0.50 PROD1 DRILL BKRM T BROOH f/20,376'to 20,281'w/270 20,376.0 20,281.0 00:15 00:45 gpm @ 2970 psi, 140 rpm @ 10 k trq. 2/26/2016 2/26/2016 0.25 PROD1 DRILL CIRC T Reciprocate pipe&circ w/270 gpm @ 20,281.0 20,281.0 00:45 01:00 2970 psi, 140 rpm© 10 k trq. PJSM on C/O swivel packing.Stage tools& equipment. 2/26/2016 2/26/2016 0.50 PROD1 DRILL RGRP T 0/0 swivel packing on top drive 20,281.0 20,281.0 01:00 01:30 2/26/2016 2/26/2016 0.50 PROD1 DRILL REAM T W&R in hole f/20,281'to 20,376' 20,281.0 20,376.0 01:30 02:00 w/270 gpm @ 2930 psi, 140 rpm @ 10.5 k trq 2/26/2016 2/26/2016 10.00 PROD1 DRILL DDRL P Drill ahead f/20,376'to 21,710'MD/ 20,376.0 21,710.0 02:00 12:00 7,336'TVD,ADT 6.96 hrs, 10.81 ppg ECD,275 gpm,3400 psi,PU wt 242 k, • SO wt N/A k, ROT wt 185 k, 140 rpm, Trq 15.7/10.5 k,WOB 16/17 k. 2/26/2016 2/27/2016 12.00 PROD1 DRILL DDRL P Drill ahead f/21,710'to 23,140'MD/ 21,710.0 23,140.0 12:00 00:00 7,345'TVD,ADT 8.0 hrs, 10.93 ppg ECD,275 gpm,3580 psi, PU wt 253 k, SO wt N/A k, ROT wt 178 k, 140 rpm, Trq 17/11 k,WOB 16/19 k. 2/27/2016 2/27/2016 5.00 PROD1 DRILL DDRL P Drill ahead f/23,140'to TD of 23,711' 23,140.0 23,711.0 00:00 05:00 MD/7,337'TVD,ADT 3.94 hrs, 10.87 ppg ECD,300 gpm,3940 psi,PU wt 255 k,SO wt N/A k,ROT wt 182 k, 140 rpm,Trq 17/12.5 k,WOB 22 k. (TD cut short due to not being able to maintain directional control) 2/27/2016 2/27/2016 2.75 PROD1 CASING CIRC P Circ clean w/275 gpm @ 3540 psi, 23,711.0 23,711.0 05:00 07:45 140 rpm @ 12.5 k trq 2/27/2016 2/27/2016 0.25 PROD1 CASING OWFF P F/C(static) 23,711.0 23,711.0 07:45 08:00 2/27/2016 2/27/2016 6.25 PROD1 CASING CIRC P Circ clean w/275 gpm @ 3500 psi, 23,711.0 23,711.0 08:00 14:15 140-120 rpm @ 12-11 k trq(5+B/U total) 2/27/2016 2/27/2016 3.00 PROD1 CASING DISP P Pump 36 bbl spacer&displace to 9.3 23,711.0 23,711.0 14:15 17:15 ppg viscosified brine w/275 gpm @ 3460-2660 psi, 100 rpm @ 11 -10 k trq 2/27/2016 2/27/2016 0.50 PROD1 CASING OWFF P F/C(static) 23,711.0 23,711.0 17:15 17:45 2/27/2016 2/28/2016 6.25 PROD1 CASING SMPD P StripOOH as per MPD schedule 23,711.0 17,777.0 17:45 00:00 (/23,711'to 17,777' 2/28/2016 2/28/2016 6.00 PROD1 CASING SMPD P StripOOH as per MPD schedule 17,777.0 10,572.0 00:00 06:00 (/17,777'to 10,572' 2/28/2016 2/28/2016 1.50 PROD1 CASING CIRC P Pump sweep&circ casing clean 10,572.0 10,572.0 06:00 07:30 w/275 gpm @ 1600 psi,30-80 rpm @ 4.5-3.5 k trq 2/28/2016 2/28/2016 0.25 PROD1 CASING OWFF P F/C(static) 10,572.0 10,572.0 07:30 07:45 2/28/2016 2/28/2016 0.25 PROD1 CASING CIRC P Pump 35 bbls 10.8 ppg dry job w/4 10,572.0 10,572.0 07:45 08:00 bpm @ 660 psi. B/D top drive&line up on MPD 2/28/2016 2/28/2016 9.75 PROD1 CASING SMPD P StripOOH as per MPD f/10,572'to 10,572.0 350.0 08:00 17:45 350' Page 16/20 Report Printed: 3/7/2016 fperations Summary (with Timelog Depths) ;_:eDrilling CD5-07 ConocoPhiHlips Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/28/2016 2/28/2016 0.50 PROD1 CASING OWFF P F/C(static)SIMOPS-B/D MPD lines 350.0 350.0 17:45 18:15 &PJSM on remove RCD bearing. 2/28/2016 2/28/2016 0.75 PROD1 CASING MPDA P Remove RCD bearing&install trip 350.0 350.0 18:15 19:00 nipple. 2/28/2016 2/28/2016 2.25 PROD1 CASING BHAH P Rack back 1 std HWDP.L/D jar stand 350.0 0.0 19:00 21:15 &BHA as per SLB 2/28/2016 2/28/2016 0.75 PROD1 CASING BHAH P Clean&clear floor of BHA tools& 0.0 0.0 21:15 22:00 equipment. 2/28/2016 2/28/2016 0.50 PROD1 CASING SVRG P Service rig&top drive. 0.0 0.0 22:00 22:30 2/28/2016 2/28/2016 0.75 COMPZN CASING RURD P R/U to run liner. R/U power tongs,4 0.0 0.0 22:30 23:15 1/2"slips&elevators. 2/28/2016 2/29/2016 0.75 COMPZN CASING PUTB P RIH 4 1/2" 12.6#L-80 Hyd 563 liner to 0.0 419.0 23:15 00:00 419' 2/29/2016 2/29/2016 8.00 COMPZN CASING PUTB P RIH 4 1/2" 12.6#L-80 Hyd 563 liner to 419.0 10,513.0 00:00 08:00 f/419'to 10,513' 2/29/2016 2/29/2016 1.25 COMPZN CASING OTHR P C/O elevators. M/U seal bore 10,513.0 10,570.0 08:00 09:15 extension&liner hanger packer assembly f/10,513'to 10,570'. Mix& pour pal mix. 2/29/2016 2/29/2016 0.50 COMPZN CASING CIRC P RIH with 1 stand of 4"DP f/10,570' 10,570.0 10,611.0 09:15 09:45 to10,611'. Break circ w/1.5-3 bpm @ 50-130 psi.Obtain T&D parameters. PU wt 162 k,SO wt 135 k,Rot wt 147 k, 10/20 rpm @ 4.4 k trq. 2/29/2016 2/29/2016 9.25 COMPZN CASING RUNL P RIH w/liner on 4"DP f/10,611'to set 10,611.0 21,042.0 09:45 19:00 depth of 21,042'. 2/29/2016 2/29/2016 1.00 COMPZN CASING HOSO P P/U 1 single joint for space out. P/U& 21,042.0 10,472.0 19:00 20:00 5/0 confirm set depth.Liner shoe 21,042'/TOL 10,472'. PU wt 250,SO wt 155 k. Drop ball 19:10 hrs&pump down w/3 bpm @ 500 psi.Seat ball& pressure up to 3550 psi&set liner hanger.5/0 to 80 k&confirm set. P/U &dog out.S/0 to 80 k&set packer. Rotate @15 rpm @4.4ktrq& confirm set. L/D single jt. 2/29/2016 2/29/2016 0.75 COMPZN CASING PRTS P R/U testing equipment&test liner top 10,472.0 10,472.0 20:00 20:45 packer to 2000 psi&chart for 10 min (good). R/D testing equipment. 2/29/2016 2/29/2016 0.25 COMPZN WELLPR TRIP P POOH&rack back 1 stand drill pipe to 10,472.0 10,441.0 20:45 21:00 put bottom of running tools @ 10,441' 2/29/2016 2/29/2016 2.50 COMPZN WELLPR DISP P Pump 35 bbls spacer&displace to 9.3 10,441.0 10,441.0 21:00 23:30 ppg non-viscosified brine w/7 bpm @ 1250 psi. Reciprocate pipe, Pump efficiency wrong,and lost suction to pumps.Shut down. F/C.(static). Trouble shoot pumps.Continue with displacement w/5 bpm @ 1040 psi. Lost+/-13 bbls during displacement 2/29/2016 2/29/2016 0.25 COMPZN WELLPR OWFF P F/C(static) 10,441.0 10,441.0 23:30 23:45 2/29/2016 3/1/2016 0.25 COMPZN WELLPR SLPC P PJSM.Slip&cut drill line 10,441.0 10,441.0 23:45 00:00 3/1/2016 3/1/2016 1.00 COMPZN WELLPR SLPC P PJSM.Slip&cut 68'of drill line. 10,441.0 10,441.0 00:00 01:00 Monitor well on trip tank-1.5 bbls/hr static losses Page 17/20 Report Printed: 3/7/2016 Mining Operations Summary (with Timelog Depths) a Welts CD5-07 Conocotxhitlaps Alaskz Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/1/2016 3/1/2016 0.75 COMPZN WELLPR CIRC P Obtain SPR's.Pump 35 bbls 10.8 ppg 10,441.0 10,441.0 01:00 01:45 dry job. B/D top drive. PU wt 215 k, SO wt185k SPRs-10,441'md,01:00 hrs MP#1: 20-150,30-380 3/1/2016 3/1/2016 4.50 COMPZN WELLPR PULD P POOH while L/D 4"DP f/10,441'to 10,441.0 7,299.0 01:45 06:15 7,299' 3/1/2016 3/1/2016 0.75 COMPZN WELLPR TRIP P POOH standing back 4"DP in derrick 7,299.0 5,964.0 06:15 07:00 from 7,299'to 5,964'(14 stds for next well). 3/1/2016 3/1/2016 5.50 COMPZN WELLPR PULD P POOH while LD 4"DP from 5,964', 5,964.0 0.0 07:00 12:30 laying down pipe in shed. LD liner running tool. Calc/Actual fill=78.4/ 103.0 bbl 3/1/2016 3/1/2016 3.25 COMPZN WELLPR PULD P LD 4'DP from derrick via the mouse 0.0 0.0 12:30 15:45 hole(29 stds to be sent in for annual inspection). 3/1/2016 3/1/2016 0.50 COMPZN RPCOMP RURD P Pull wear ring and set 9"ID, 0.0 0.0 15:45 16:15 retrievable completion wear ring. 3/1/2016 3/1/2016 0.50 COMPZN RPCOMP RURD P Clear and clean rig floor. 0.0 0.0 16:15 16:45 3/1/2016 3/1/2016 3.50 COMPZN RPCOMP RURD P PU tools and equipment to run 4-1/2" 0.0 0.0 16:45 20:15 tubing completion RU double-stacked power tongs and Torque-Turn monitoring equipment.Change out collars on two DB nipples, Baler-Lok threads, MU and set aside.(Monitor well on Trip tank. Losses=5-6 bbl of 9.3 ppg brine). 3/1/2016 3/2/2016 3.75 COMPZN RPCOMP PUTB P PJSM. Run 4-1/2", 12.6 Ib/ft,L-80, 0.0 572.0 20:15 00:00 TXP, R3 tubing to 572'md, made up to 7,000 ft-lb with Run&Seal Arctic thread dope. Monitor and record TXP make-up with Torque-Turn equip. 3/2/2016 3/2/2016 8.00 COMPZN RPCOMP PUTB P Continue to run 4-1/2", 12.6 lb/ft, L-80, 572.0 5,472.0 00:00 08:00 TXP, R3 tubing from 572'-5,472'md, made up to 7,000 ft-lb with Run&Seal Arctic thread dope.Monitor and record TXP make-up with Torque-Turn equip, Tenaris reps on site. PU= 112K,SO= 105K lb 3/2/2016 3/2/2016 0.75 COMPZN RPCOMP RURD P RD double stack power tongs and 5,472.0 5,472.0 08:00 08:45 torque turn equip.PU/RU single power tongs and torque turn equip for monitoring MU on first run of 4-1/2" TXP connection. 3/2/2016 3/2/2016 3.25 COMPZN RPCOMP PUTB P Continue to run 4-1/2" tubing from 5,472.0 7,919.0 08:45 12:00 5,472'-7,919'md,made up to 7,000 ft -lb with Run&Seal Arctic thread dope. Monitor and record TXP make- up with Torque-Turn equip and Tenaris reps(203 total jts run). PU= 137K,S0= 120K lb. Page 18/20 Report Printed: 3/7/2016 • Operations Summary (with Timelog Depths) &Wells • CD5-07 Conoccehillips F.f.e ky Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/2/2016 3/2/2016 4.00 COMPZN RPCOMP PUTB P Continue to run 4-1/2" tubing from 7,919.0 10,390.0 12:00 16:00 7,919'-10,390'md,made up to 7,000 ft-lb with Run&Seal Arctic thread dope.Monitor and record TXP make- up with Torque-Turn equi and Tenaris reps. Calc/Actual Displ=37.44 bbl/ 7.5 bbl. 3/2/2016 3/2/2016 1.00 COMPZN RPCOMP HOSO P MU 4-1/2"TXP x H563 XO and RIH 10,390.0 10,525.0 16:00 17:00 from 10,390'to 10,481'. Rig up circulating equipment.Wash down with 1 BPM,60 psi.Observe pressure increase to 120 psi at 10,499'. Bleed off pressure and continue to RIH and No-Go at 10,525'and slack off with 10K lb and confirm. PU= 162K, SO= 127K lb. 3/2/2016 3/2/2016 0.25 COMPZN RPCOMP PRTS P Pressure test IA to 200 psi for 10 10,525.0 10,525.0 17:00 17:15 minutes. 3/2/2016 3/2/2016 1.50 COMPZN RPCOMP HOSO P RD circulating equipment and POOH 10,525.0 10,392.0 17:15 18:45 from 10,525'to 10,392'laying down 4 jts of 4-1/2"tubing used for space out. MU 5.75'space out pup plus 1 joint of tbg. MU ACME wear ring puller to landing joint B. Pull wear ring. LD same 3/2/2016 3/2/2016 1.25 COMPZN RPCOMP HOSO P MU 1 jt of 4-1/2", H563 and Tbg Hngr. 10,392.0 10,494.0 18:45 20:00 Align hanger, MU Landing Jt A with head pin and circulating lines. RIH to 10,494'. 3/2/2016 3/2/2016 1.25 COMPZN RPCOMP CRIH P Pump 21 bbls of Corrosion Inhibited 10,494.0 10,494.0 20:00 21:15 brine at 2.8 bbl/min, 180 psi, followed by 151 bbl 9.3 ppg brine and pump at 3 bpm, 190 psi. 3/2/2016 3/2/2016 0.75 COMPZN RPCOMP THGR P RIH to 10,519'and land 4-1/2"tubing 10,494.0 10,519.0 21:15 22:00 on hanger. (No-Go 2.9'from fully located). RLDS. 3/2/2016 3/2/2016 1.25 COMPZN RPCOMP THGR P Test hanger seals to 250 psi low for 5 10,494.0 10,519.0 22:00 23:15 min,5,000 psi high for 10 min-ok. 3/2/2016 3/3/2016 0.75 COMPZN RPCOMP RURD P Drop Ball and Rod and let fall. RU 10,519.0 10,519.0 23:15 00:00 head pin,flow tee and hoses. 3/3/2016 3/3/2016 2.50 COMPZN RPCOMP PRTS P Attempt to pressure test tubing(4x) to 10,519.0 10,519.0 00:00 02:30 3,500 psi for 30 min-Not holding pressure, (no flow observed from the IA). Monitor well-static. Consult with town. 3/3/2016 3/3/2016 0.75 COMPZN RPEQPT PRTS P Line up to test IA-liner top packer, 10,519.0 10,519.0 02:30 03:15 seal assembly,7-5/8"csg and 4-1/2" tubing to 2,000 psi for 30 minutes- good.(Flow-check well with tubing open at surface for 30 min-static). Pump and shear out at 2,610 psi. 3/3/2016 3/3/2016 0.25 COMPZN RPCOMP RURD P Blow down lines and RD circulating 0.0 0.0 03:15 03:30 equip. 3/3/2016 3/3/2016 0.50 COMPZN WHDBOP PRTS P Set TWC and re-install landing Jt"B". 0.0 0.0 03:30 04:00 3/3/2016 3/3/2016 0.50 COMPZN WHDBOP PRTS P Pump down IA and test TWC and 0.0 0.0 04:00 04:30 Hanger seals in direction of flow to 2,500 psi for 15 min and record- good. Bleed off pressure. LD LJ"B", RD circulating equip.,blow down lines to cellar. Page 19/20 Report Printed: 3/7/2016 Drilling Operations Summary (with Timelog Depths) IQ W� CD5-07 Conoccehillips P413,1,5 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/3/2016 3/3/2016 0.75 COMPZN WHDBOP WWWH P MU stack washer and flush stack with 0.0 0.0 04:30 05:15 10 bpm and 50 psi. LD same. Blow down TD and surface lines. 3/3/2016 3/3/2016 1.75 COMPZN WHDBOP MPDA P PJSM. Remove 90'mouse hole,Trip 0.0 0.0 05:15 07:00 nipple and Orbit valve. RD MPD RCD, flow lines, 3/3/2016 3/3/2016 1.25 COMPZN WHDBOP NUND P Drain stack,break Ram door bolts. 0.0 0.0 07:00 08:15 ND BOPE,break UPR and Blind ram doors for BWM. SIMOPs-Change out Saver sub from 4"XT-39 to 5"DS50. 3/3/2016 3/3/2016 0.75 COMPZN WHDBOP NUND P NU tree and adapter,continue to c/o 0.0 0.0 08:15 09:00 Saver-sub, clean and clear rig floor. PU FMC lubricator to rig floor. 3/3/2016 3/3/2016 0.50 COMPZN WHDBOP PRTS P Test void to 5,000 psi for 15 min.- 0.0 0.0 09:00 09:30 good. Test tree to 250/5000 psi for 10 min and record-(good). RD test equip. 3/3/2016 3/3/2016 0.50 COMPZN WHDBOP MPSP P Continue to RD test equipment. Pull 0.0 0.0 09:30 10:00 TWC.SIMOPs-RD mud lines and flare line. 3/3/2016 3/3/2016 0.25 COMPZN WHDBOP FRZP P PJSM. RU squeeze manifold and lines 0.0 10:00 10:15 for freeze protect. 3/3/2016 3/3/2016 1.50 COMPZN WHDBOP CRIH P PJSM.Test lines to 3,000 psi. Pump 0.0 0.0 10:15 11:45 203.3 bbl of corrosion inhibited 9.3 ppg brine at 4.5-2.0 bpm,3,050-780 psi. 3/3/2016 3/3/2016 2.25 COMPZN WHDBOP FRZP P Ball Mill pump 85 bbl diesel freeze 0.0 0.0 11:45 14:00 protect.down IA at 2.2 bpm,2,500 psi. Let u-tube across squeeze manifold. 3/3/2016 3/3/2016 2.50 COMPZN WHDBOP MPSP P RU lubricator and test. Install BPV and 0.0 0.0 14:00 16:30 attempt to test to 2,500 psi for 15 min in direction of flow with pressure bleed off. Pull,inspect clean and reset and test to 2,500 psi for 15 min-good. Bleed off psi to 0 psi and shut in well on IA. Flush lines with H2O and blow down. RD circ lines and equip. Secure well. 3/3/2016 3/3/2016 3.50 DEMOB MOVE RURD P Blow down water and steam to rig 0.0 0.0 16:30 20:00 sub. Warm up Cold start generator. Take rig off of high-line power at 1930 hrs,03/03/2016. Release rig from CD5-07 Daywork at 2000 hrs,03/03/2016. Page 20/20 Report Printed: 3/7/2016 • NADConversion Western North Slope CD5 Alpine West Pad CD5-07 CD5-07 Definitive Survey Report 09 March, 2016 • SLB • Definitive Survey Report Company; NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-07 Well Position +N/-S 0.00 usft Northing: 5,965,883.11 usft Latitude: 70°18'50.023 N +El-W 0.00 usft Easting: 349,423.93 usft Longitude: 151°13'13.411 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.30 usft Wellbore CD5-07 Magnetics Model Name Sample Date Declination . Dip Field Strength (°) (°) (nT) BGGM2015 2/11/2016 17.78 80.83 57,469 Design CD5-07 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.67 Vertical Section: Depth From(TVD) 411-S +EI-W Direction (usft) (usft) (usft) (°) 36.67 0.00 0.00 332.76 Survey Program Date From To (usft) (usft) Survey',(Wellbore) Tool Name Description Survey Date 67.00 735.00 CD5-07 Svy1 SLB_NSG+SSHOT(CD5-0 GYD-GC-SS Gyrodata gyro single shots 2/5/2016 3:01:0 761.28 2,224.93 CD5-07 Svy2 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2016 10:41:0 2,325.70 10,576.70 CD5-07 Svy3 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/9/2016 9:05:0 10,667.42 15,422.86 CD5-07 Svy4 SLB_MWD_GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/19/2016 2:12: 15,517.12 23,651.61 CD5-07 SvyS SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2016 2:16: Survey Map' Map Vertical MD Inc Azi TVD TVDSS 411-5 +El-W' Northing Easting DLS Section'' (usft) (°) (°) (usft) (ulsiTj._.'' (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.67 0.00 0.00 36.67 -34.30 0.00 0.00 5,965,883.11 349,423.93 0.00 0.00 UNDEFINED 67.00 0.29 106.91 67.00 -3.97 -0.02 0.07 5,965,883.09 349,424.01 0.96 -0.05 GYD-GC-SS(1) 115.00 0.32 55.24 115.00 44.03 0.02 0.30 5,965,883.13 349,424.24 0.56 -0.12 GYD-GC-SS(1) 20"x42" 167.00 0.54 28.08 167.00 96.03 0.32 0.54 5,965,883.42 349,424.48 0.56 0.04 GYD-GC-SS(1) 267.00 0.45 336.17 266.99 196.02 1.09 0.60 5,965,884.20 349,424.56 0.44 0.70 GYD-GC-SS(1) 367.00 0.70 22.61 366.99 296.02 2.02 0.68 5,965,885.12 349,424.65 0.51 1.48 GYD-GC-SS(1) 459.00 0.68 5.64 458.98 388.01 3.08 0.95 5,965,886.17 349,424.94 0.22 2.31 GYD-GC-SS(1) 578.00 0.86 333.70 577.97 507.00 4.58 0.62 5,965,887.68 349,424.65 0.38 3.79 GYD-GC-SS(1) 643.00 1.37 302.71 642.96 571.99 5.44 -0.25 5,965,888.56 349,423.79 1.19 4.95 GYD-GC-SS(1) 735.00 1.17 306.33 734.94 663.97 6.59 -1.93 5,965,889.74 349,422.14 0.23 6.74 GYD-GC-SS(1) 3/9/2016 9:50:57AM Page 2 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference' Well CD5-07 Project Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well:_ CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey E -€ Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) „_(°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 761.28 0.85 293.88 761.21 690.24 6.83 -2.33 5,965,889.99 349,421.75 1.47 7.14 MWD+IFR-AK-CAZ-SC(2) 856.25 1.23 35.69 856.17 785.20 7.94 -2.38 5,965,891.10 349,421.72 1.72 8.15 MVVD+IFR-AK-CAZ-SC(2) 950.56 3.59 51.24 950.40 879.43 10.61 0.52 5,965,893.71 349,424.66 2.57 9.20 MWD+IFR-AK-CAZ-SC(2) 1,044.15 4.37 62.89 1,043.76 972.79 14.07 5.98 5,965,897.06 349,430.19 1.20 9.78 MWD+IFR-AK-CAZ-SC(2) 1,138.30 7.02 65.54 1,137.44 1,066.47 18.09 14.41 5,965,900.91 349,438.70 2.83 9.49 MWD+IFR-AK-CAZ-SC(2) 1,232.49 10.17 68.32 1,230.56 1,159.59 23.55 27.38 5,965,906.11 349,451.78 3.37 8.40 MWD+IFR-AK-CAZ-SC(2) 1,326.95 12.50 69.84 1,323.17 1,252.20 30.15 44.73 5,965,912.36 349,469.25 2.49 6.33 MWD+IFR-AK-CAZ-SC(2) 1,419.97 14.74 68.98 1,413.57 1,342.60 37.87 65.22 5,965,919.66 349,489.90 2.42 3.81 MWD+IFR-AK-CAZ-SC(2) 1,514.24 17.28 67.60 1,504.17 1,433.20 47.51 89.37 5,965,928.81 349,514.23 2.72 1.32 MWD+IFR-AK-CAZ-SC(2) 1,609.01 19.88 66.82 1,594.00 1,523.03 59.21 117.20 5,965,939.96 349,542.29 2.76 -1.01 MWD+IFR-AK-CAZ-SC(2) 1,702.91 22.99 62.96 1,681.40 1,610.43 73.84 148.22 5,965,953.96 349,573.59 3.64 -2.20 MWD+IFR-AK-CAZ-SC(2) 1,797.50 25.46 58.78 1,767.66 1,696.69 92.78 182.06 5,965,972.22 349,607.81 3.18 -0.86 MWD+IFR-AK-CAZ-SC(2) 1,891.98 27.12 59.18 1,852.36 1,781.39 114.34 217.93 5,965,993.05 349,644.09 1.77 1.89 MWD+IFR-AK-CAZ-SC(2) 1,986.37 28.60 61.50 1,935.81 1,864.84 136.14 256.26 5,966,014.08 349,682.85 1.94 3.73 MWD+IFR-AK-CAZ-SC(2) 2,081.14 31.20 62.94 2,017.96 1,946.99 158.14 298.06 5,966,035.23 349,725.09 2.85 4.15 MVVD+IFR-AK-CAZ-SC(2) 2,173.72 34.75 62.15 2,095.61 2,024.64 181.38 342.76 5,966,057.57 349,770.24 3.86 4.35 MWD+IFR-AK-CAZ-SC(2) 2,224.93 35.92 61.24 2,137.39 2,066.42 195.43 368.83 5,966,071.09 349,796.59 2.51 4.90 MVVD+IFR-AK-CAZ-SC(2) 2,290.63 36.43 59.40 2,190.43 2,119.46 214.63 402.52 5,966,089.61 349,830.65 1.83 6.55 MWD+IFR-AK-CAZ-SC(3) 10-3/4"x 13-1/2" 2,325.70 36.71 58.43 2,218.59 2,147.62 225.42 420.41 5,966,100.04 349,848.75 1.83 7.95 MWD+IFR-AK-CAZ-SC(3) 2,419.66 38.23 58.70 2,293.16 2,222.19 255.23 469.18 5,966,128.86 349,898.11 1.63 12.13 MWD+IFR-AK-CAZ-SC(3) 2,514.11 41.01 59.29 2,365.91 2,294.94 286.24 520.81 5,966,158.83 349,950.34 2.97 16.07 MWD+IFR-AK-CAZ-SC(3) 2,607.05 43.35 58.39 2,434.78 2,363.81 318.54 574.20 5,966,190.05 350,004.36 2.60 20.34 MWD+IFR-AK-CAZ-SC(3) 2,701.24 45.87 56.51 2,501.83 2,430.86 354.14 629.93 5,966,224.53 350,060.79 3.02 26.48 MWD+IFR-AK-CAZ-SC(3) 2,792.74 47.79 55.15 2,564.43 2,493.46 391.63 685.13 5,966,260.90 350,116.73 2.36 34.54 MWD+IFR-AK-CAZ-SC(3) 2,887.28 48.29 53.48 2,627.64 2,556.67 432.64 742.23 5,966,300.75 350,174.63 1.42 44.86 MVVD+IFR-AK-CAZ-SC(3) 2,981.53 48.25 52.43 2,690.38 2,619.41 475.01 798.37 5,966,341.99 350,231.61 0.83 56.83 MWD+IFR-AK-CAZ-SC(3) 3,077.10 48.19 52.03 2,754.06 2,683.09 518.66 854.70 5,966,384.50 350,288.80 0.32 69.85 MWD+IFR-AK-CAZ-SC(3) 3,171.03 47.29 52.48 2,817.22 2,746.25 561.22 909.67 5,966,425.94 350,344.61 1.02 82.52 MWD+IFR-AK-CAZ-SC(3) 3,263.93 47.15 52.71 2,880.32 2,809.35 602.64 963.84 5,966,466.26 350,399.59 0.24 94.55 MWD+IFR-AK-CAZ-SC(3) 3,359.85 47.24 53.50 2,945.50 2,874.53 644.89 1,020.11 5,966,507.37 350,456.70 0.61 106.35 MWD+IFR-AK-CAZ-SC(3) 3,453.34 47.20 53.76 3,009.00 2,938.03 685.58 1,075.37 5,966,546.94 350,512.75 0.21 117.23 MWD+IFR-AK-CAZ-SC(3) 3,547.95 47.19 52.81 3,073.28 3,002.31 727.07 1,131.01 5,966,587.31 350,569.21 0.74 128.65 MWD+IFR-AK-CAZ-SC(3) 3,639.65 47.22 51.78 3,135.58 3,064.61 768.22 1,184.24 5,966,627.38 350,623.26 0.82 140.87 MWD+IFR-AK-CAZ-SC(3) 3,735.76 47.23 51.71 3,200.85 3,129.88 811.91 1,239.64 5,966,669.94 350,679.52 0.05 154.34 MWD+IFR-AK-CAZ-SC(3) 3,829.16 47.24 52.27 3,264.27 3,193.30 854.13 1,293.67 5,966,711.07 350,734.37 0.44 167.15 MVVD+IFR-AK-CAZ-SC(3) 3,922.28 47.14 51.79 3,327.55 3,256.58 896.16 1,347.52 5,966,752.01 350,789.05 0.39 179.86 MWD+IFR-AK-CAZ-SC(3) 4,016.70 47.67 51.79 3,391.46 3,320.49 939.15 1,402.14 5,966,793.89 350,844.52 0.56 193.08 MWD+IFR-AK-CAZ-SC(3) 4,112.22 47.69 51.22 3,455.77 3,384.80 983.11 1,457.41 5,966,836.73 350,900.66 0.44 206.86 MWD+IFR-AK-CAZ-SC(3) 4,204.95 47.70 49.92 3,518.19 3,447.22 1,026.67 1,510.38 5,966,879.21 350,954.49 1.04 221.34 MWD+IFR-AK-CAZ-SC(3) 31912016 9:50:57AM Page 3 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 4,298.49 47.98 49.30 3,580.97 3,510.00 1,071.60 1,563.19 5,966,923.07 351.008.19 0.58 237.11 MWD+IFR-AK-CAZ-SC(3) 4,393.02 48.12 49.12 3,644.16 3,573.19 1,117.53 1,616.42 5,966,967.92 351,062.32 0.20 253.57 MWD+IFR-AK-CAZ-SC(3) 4,487.10 48.14 49.23 3,706.95 3,635.98 1,163.33 1,669.43 5,967,012.65 351,116.24 0.09 270.02 MWD+IFR-AK-CAZ-SC(3) 4,580.41 48.07 49.65 3,769.26 3,698.29 1,208.49 1,722.20 5,967,056.74 351,169.90 0.34 286.02 MWD+IFR-AK-CAZ-SC(3) 4,674.92 48.32 50.96 3,832.27 3,761.30 1,253.49 1,776.41 5,967,100.64 351,224.99 1.07 301.21 MWD+IFR-AK-CAZ-SC(3) 4,769.15 48.33 51.29 3,894.92 3,823.95 1,297.66 1,831.20 5,967,143.70 351,280.66 0.26 315.40 MWD+IFR-AK-CAZ-SC(3) 4,862.39 48.21 51.80 3,956.98 3,886.01 1,340.94 1,885.69 5,967,185.87 351,336.00 0.43 328.92 MWD+IFR-AK-CAZ-SC(3) 4,956.93 48.23 51.95 4,019.97 3,949.00 1,384.46 1,941.15 5,967,228.27 351,392.32 0.12 342.23 MVD+IFR-AK-CAZ-SC(3) 5,050.59 48.24 52.07 4,082.36 4,011.39 1,427.46 1,996.21 5,967,270.15 351,448.22 0.10 355.26 MWD+IFR-AK-CAZ-SC(3) 5,145.01 48.26 52.65 4,145.23 4,074.26 1,470.48 2,051.99 5,967,312.04 351,504.85 0.46 367.97 MVD+IFR-AK-CAZ-SC(3) 5,239.59 48.21 52.72 4,208.23 4,137.26 1,513.24 2,108.10 5,967,353.67 351,561.80 0.08 380.30 MWD+IFR-AK-CAZ-SC(3) 5,334.45 48.18 52.78 4,271.46 4,200.49 1,556.04 2,164.38 5,967,395.33 351,618.92 0.06 392.59 MWD+IFR-AK-CAZ-SC(3) 5,428.66 48.17 53.17 4,334.29 4,263.32 1,598.32 2,220.43 5,967,436.47 351,675.81 0.31 404.52 MWD+IFR-AK-CAZ-SC(3) 5,523.07 48.22 53.08 4,397.22 4,326.25 1,640.55 2,276.73 5,967,477.56 351,732.93 0.09 416.29 MWD+IFR-AK-CAZ-SC(3) 5,617.38 47.69 53.55 4,460.38 4,389.41 1,682.39 2,332.89 5,967,518.26 351,789.92 0.67 427.78 MWD+IFR-AK-CAZ-SC(3) 5,710.49 47.82 53.37 4,522.98 4,452.01 1,723.43 2,388.27 5,967,558.18 351,846.11 0.20 438.91 MWD+IFR-AK-CAZ-SC(3) 5,805.00 47.83 52.64 4,586.43 4,515.46 1,765.57 2,444.21 5,967,599.19 351,902.88 0.57 450.77 MWD+IFR-AK-CAZ-SC(3) 5,900.24 47.74 52.64 4,650.42 4,579.45 1,808.38 2,500.28 5,967,640.86 351,959.79 0.09 463.16 MWD+IFR-AK-CAZ-SC(3) 5,994.00 47.78 52.78 4,713.45 4,642.48 1,850.43 2,555.50 5,967,681.79 352,015.84 0.12 475.27 MWD+IFR-AK-CAZ-SC(3) 6,087.60 47.65 51.51 4,776.43 4,705.46 1,892.92 2,610.17 5,967,723.18 352,071.35 1.01 488.02 MWD+IFR-AK-CAZ-SC(3) 6,181.45 48.14 51.38 4,839.36 4,768.39 1,936.32 2,664.62 5,967,765.47 352,126.65 0.53 501.67 MWD+IFR-AK-CAZ-SC(3) 6,275.65 48.21 50.96 4,902.17 4,831.20 1,980.34 2,719.31 5,967,808.38 352,182.20 0.34 515.77 MWD+IFR-AK-CAZ-SC(3) 6,369.64 48.12 50.19 4,964.87 4,893.90 2,024.81 2,773.40 5,967,851.75 352,237.17 0.62 530.55 MWD+IFR-AK-CAZ-SC(3) 6,462.74 48.13 50.53 5,027.01 4,956.04 2,069.03 2,826.78 5,967,894.89 352,291.43 0.27 545.43 MWD+IFR-AK-CAZ-SC(3) 6,555.83 48.01 50.24 5,089.22 5,018.25 2,113.19 2,880.13 5,967,937.97 352,345.65 0.27 560.26 MWD+IFR-AK-CAZ-SC(3) 6,649.56 48.17 50.07 5,151.82 5,080.85 2,157.88 2,933.69 5,967,981.58 352,400.09 0.22 575.48 MWD+IFR-AK-CAZ-SC(3) 6,743.54 48.13 49.45 5,214.53 5,143.56 2,203.11 2,987.13 5,968,025.71 352,454.42 0.49 591.22 MWD+IFR-AK-CAZ-SC(3) 6,837.55 48.24 49.23 5,277.20 5,206.23 2,248.76 3,040.28 5,968,070.29 352,508.47 0.21 607.48 MWD+IFR-AK-CAZ-SC(3) 6,931.54 48.14 48.98 5,339.86 5,268.89 2,294.62 3,093.23 5,968,115.08 352,562.33 0.22 624.01 MWD+IFR-AK-CAZ-SC(3) 7,025.39 48.05 49.33 5,402.55 5,331.58 2,340.30 3,146.07 5,968,159.69 352,616.07 0.29 640.44 MWD+IFR-AK-CAZ-SC(3) 7,119.36 47.84 49.51 5,465.49 5,394.52 2,385.69 3,199.06 5,968,204.00 352,669.96 0.26 656.53 MWD+IFR-AK-CAZ-SC(3) 7,212.97 48.10 49.37 5,528.17 5,457.20 2,430.91 3,251.89 5,968,248.14 352,723.68 0.30 672.55 MWD+IFR-AK-CAZ-SC(3) 7,306.35 48.12 49.87 5,590.52 5,519.55 2,475.94 3,304.84 5,968,292.10 352,777.52 0.40 688.34 MWD+IFR-AK-CAZ-SC(3) 7,400.38 48.04 51.38 5,653.34 5,582.37 2,520.32 3,358.92 5,968,335.39 352,832.47 1.20 703.05 MWD+IFR-AK-CAZ-SC(3) 7,494.86 48.09 52.34 5,716.48 5,645.51 2,563.73 3,414.20 5,968,377.67 352,888.61 0.76 716.33 MWD+IFR-AK-CAZ-SC(3) 7,588.29 48.18 52.17 5,778.83 5,707.86 2,606.32 3,469.22 5,968,419.15 352,944.47 0.17 729.01 MWD+IFR-AK-CAZ-SC(3) 7,682.26 48.26 52.12 5,841.44 5,770.47 2,649.32 3,524.55 5,968,461.03 353,000.64 0.09 741.91 MWD+IFR-AK-CAZ-SC(3) 7,776.48 48.09 52.39 5,904.27 5,833.30 2,692.30 3,580.07 5,968,502.89 353,057.01 0.28 754.71 MWD+IFR-AK-CAZ-SC(3) 7,870.36 47.89 51.87 5,967.10 5,896.13 2,735.12 3,635.13 5,968,544.59 353,112.91 0.46 767.57 MWD+IFR-AK-CAZ-SC(3) 7,963.57 47.99 51.64 6,029.55 5,958.58 2,777.96 3,689.48 5,968,586.33 353,168.11 0.21 780.78 MWD+IFR-AK-CAZ-SC(3) 3/9/2016 9:50:57AM Page 4 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) O (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,056.94 47.96 51.51 6,092.05 6,021.08 2,821 07 3,743.82 5,968,628.33 353,223.30 0.11 794.22 MWD+IFR-AK-CAZ-SC(3) 8,149.64 47.46 48.74 6,154.44 6,083.47 2,865.02 3,796.44 5,968,671.22 353,276.78 2.28 809.21 MWD+IFR-AK-CAZ-SC(3) 8,244.36 46.79 43.94 6,218.90 6,147.93 2,912.90 3,846.64 5,968,718.08 353,327.93 3.78 828.80 MWD+IFR-AK-CAZ-SC(3) 8,338.02 45.72 41.71 6,283.67 6,212.70 2,962.51 3,892.64 5,968,766.76 353,374.91 2.06 851.85 MVVD+IFR-AK-CAZ-SC(3) 8,431.87 44.27 40.09 6,350.04 6,279.07 3,012.66 3,936.09 5,968,816.01 353,419.35 1.97 876.54 MWD+IFR-AK-CAZ-SC(3) 8,525.54 43.55 36.78 6,417.53 6,346.56 3,063.52 3,976.47 5,968,866.05 353,460.74 2.57 903.28 MWD+IFR-AK-CAZ-SC(3) 8,619.52 44.50 32.56 6,485.12 6,414.15 3,117.22 4,013.59 5,968,919.00 353,498.93 3.28 934.03 MWD+IFR-AK-CAZ-SC(3) 8,715.28 45.40 27.76 6,552.91 6,481.94 3,175.70 4,047.54 5,968,976.77 353,534.04 3.66 970.47 MWD+IFR-AK-CAZ-SC(3) 8,805.96 46.02 22.72 6,616.25 6,545.28 3,234.38 4,075.19 5,969,034.88 353,562.86 4.04 1,009.99 MWD+IFR-AK-CAZ-SC(3) 8,901.74 45.90 17.39 6,682.86 6,611.89 3,299.01 4,098.79 5,969,099.02 353,587.75 4.00 1,056.64 MWD+IFR-AK-CAZ-SC(3) 8,995.49 46.18 12.08 6,747.96 6,676.99 3,364.23 4,115.93 5,969,163.88 353,606.19 4.09 1,106.78 MWD+IFR-AK-CAZ-SC(3) 9,088.29 45.73 7.98 6,812.49 6,741.52 3,429.88 4,127.55 5,969,229.28 353,619.13 3.21 1,159.83 MWD+IFR-AK-CAZ-SC(3) 9,182.28 47.00 3.05 6,877.37 6,806.40 3,497.55 4,134.06 5,969,296.81 353,626.99 4.03 1,217.02 MWD+IFR-AK-CAZ-SC(3) 9,274.68 47.69 358.61 6,939.99 6,869.02 3,565.47 4,135.02 5,969,364.68 353,629.32 3.61 1,276.95 MWD+IFR-AK-CAZ-SC(3) 9,369.88 49.36 352.61 7,003.07 6,932.10 3,636.52 4,129.52 5,969,435.83 353,625.24 5.04 1,342.64 MWD+IFR-AK-CAZ-SC(3) 9,462.86 52.09 348.05 7,061.95 6,990.98 3,707.43 4,117.38 5,969,506.96 353,614.53 4.80 1,411.24 MWD+IFR-AK-CAZ-SC(3) 9,557.13 54.39 346.26 7,118.36 7,047.39 3,781.05 4,100.58 5,969,580.89 353,599.20 2.88 1,484.38 MWD+IFR-AK-CAZ-SC(3) 9,650.90 57.64 344.79 7,170.77 7,099.80 3,856.31 4,081.13 5,969,656.53 353,581.27 3.70 1,560.20 MWD+IFR-AK-CAZ-SC(3) 9,745.03 60.84 343.68 7,218.91 7,147.94 3,934.14 4,059.14 5,969,734.78 353,560.85 3.55 1,639.46 MWD+IFR-AK-CAZ-SC(3) 9,839.71 62.87 344.29 7,263.57 7,192.60 4,014.38 4,036.12 5,969,815.46 353,539.44 2.22 1,721.35 MWD+IFR-AK-CAZ-SC(3) 9,932.23 66.71 343.93 7,302.97 7,232.00 4,094.88 4,013.20 5,969,896.39 353,518.14 4.17 1,803.40 MWD+IFR-AK-CAZ-SC(3) 10,028.08 69.43 343.59 7,338.76 7,267.79 4,180.23 3,988.33 5,969,982.22 353,494.99 2.86 1,890.67 MWD+IFR-AK-CAZ-SC(3) 10,120.11 70.76 341.54 7,370.10 7,299.13 4,262.78 3,962.40 5,970,065.26 353,470.72 2.54 1,975.93 MWD+IFR-AK-CAZ-SC(3) 10,213.13 72.95 338.63 7,399.07 7,328.10 4,345.87 3,932.28 5,970,148.93 353,442.28 3.79 2,063.59 MWD+IFR-AK-CAZ-SC(3) 10,306.10 76.02 337.66 7,423.94 7,352.97 4,429.00 3,898.94 5,970,232.71 353,410.61 3.45 2,152.76 MWD+IFR-AK-CAZ-SC(3) 10,400.15 79.35 335.34 7,444.00 7,373.03 4,513.24 3,862.29 5,970,317.66 353,375.67 4.28 2,244.43 MWD+IFR-AK-CAZ-SC(3) 10,493.06 83.22 332.80 7,458.07 7,387.10 4,595.81 3,822.14 5,970,401.01 353,337.18 4.96 2,336.22 MWD+IFR-AK-CAZ-SC(3) 10,576.70 85.10 332.35 7,466.58 7,395.61 4,669.66 3,783.81 5,970,475.61 353,300.35 2.31 2,419.42 MWD+IFR-AK-CAZ-SC(3) 10,632.59 86.76 332.52 7,470.55 7,399.58 4,719.08 3,758.02 5,970,525.53 353,275.55 2.99 2,475.17 MWD+IFR-AK-CAZ-SC(4) 7e X9-718b911" 10,667.42 87.80 332.62 7,472.20 7,401 23 4,749.95 3,741.99 5,970,556.72 353,260.14 2.99 2,509.96 MVVD+IFR-AK-CAZ-SC(4) 10,762.93 88.81 330.44 7,475.02 7,404.05 4,833.87 3,696.48 5,970,641.53 353,216.33 2.51 2,605.40 MWD+IFR-AK-CAZ-SC(4) 10,858.35 90.75 332.77 7,475.39 7,404.42 4,917.80 3,651.11 5,970,726.35 353,172.66 3.18 2,700.79 MWD+IFR-AK-CAZ-SC(4) 10,953.49 90.88 331.65 7,474.04 7,403.07 5,001.96 3,606.76 5,970,811.37 353,130.00 1.18 2,795.91 MWD+IFR-AK-CAZ-SC(4) 11,048.82 91.30 332.03 7,472.22 7,401.25 5,085.99 3,561.78 5,970,896.28 353,086.72 0.59 2,891.21 M1.ND+IFR-AK-CAZ-SC(4) 11,144.33 91.23 331.97 7,470.12 7,399.15 5,170.30 3,516.95 5,970,981.46 353,043.59 0.10 2,986.69 MWD+IFR-AK-CAZ-SC(4) 11,240.76 90.04 331.71 7,469.05 7,398.08 5,255.31 3,471.44 5,971,067.36 352,999.81 1.26 3,083.10 MWD+IFR-AK-CAZ-SC(4) 11,334.12 90.65 331.34 7,468.48 7,397.51 5,337.37 3,426.93 5,971,150.30 352,956.95 0.76 3,176.44 MWD+IFR-AK-CAZ-SC(4) 11,429.83 90.70 331.03 7,467.36 7,396.39 5,421.22 3,380.81 5,971,235.05 352,912.52 0.33 3,272.11 MWD+IFR-AK-CAZ-SC(4) 11,524.74 90.98 330.36 7,465.97 7,395.00 5,503.98 3,334.36 5,971,318.71 352,867.74 0.77 3,366 94 MWD+IFR-AK-CAZ-SC(4) 3/9/2016 9:50:57AM Page 5 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 11,620.21 91.23 329.17 7,464.12 7,393.15 5,586.44 3,286.29 5,971,402 12 352,821.35 1.27 3,462.26 MWD+IFR-AK-CAZ-SC(4) 11,715.87 91.23 329.70 7,462.07 7,391.10 5,668.79 3,237.66 5,971,485.42 352,774.38 0.55 3,557.74 MWD+IFR-AK-CAZ-SC(4) 11,811 46 89.93 330.42 7,461.10 7,390.13 5,751.62 3,189.95 5,971,569.18 352,728.35 1.55 3,653.22 MWD+IFR-AK-CAZ-SC(4) 11,907.45 91.10 329.84 7,460.24 7,389.27 5,834.85 3,142.15 5,971,653.35 352,682.23 1.36 3,749.10 MWD+IFR-AK-CAZ-SC(4) 12,002.98 91.20 331.45 7,458.32 7,387.35 5,918.10 3,095.33 5,971,737.51 352,637.09 1.69 3,844.54 MWD+IFR-AK-CAZ-SC(4) 12,097.82 90.92 331.65 7,456.57 7,385.60 6,001.47 3,050.16 5,971,821.77 352,593.60 0.36 3,939.35 MVVD+IFR-AK-CAZ-SC(4) 12,193.67 89.56 330.24 7,456.17 7,385.20 6,085.25 3,003.61 5,971,906.46 352,548.75 2.04 4,035.14 MWD+IFR-AK-CAZ-SC(4) 12,288.67 89.96 331.07 7,456.57 7,385.60 6,168.06 2,957.06 5,971,990.18 352,503.86 0.97 4,130.08 MVVD+IFR-AK-CAZ-SC(4) 12,384.01 88.77 331.73 7,457.62 7,386.65 6,251.76 2,911.42 5,972,074.77 352,459.92 1.43 4,225.38 MWD+IFR-AK-CAZ-SC(4) 12,477.98 89.59 333.31 7,458.97 7,388.00 6,335.12 2,868.07 5,972,158.97 352,418.25 1.89 4,319.34 MWD+IFR-AK-CAZ-SC(4) 12,573.97 88.99 333.45 7,460.16 7,389.19 6,420.92 2,825.06 5,972,245.62 352,376.97 0.64 4,415.31 MWD+IFR-AK-CAZ-SC(4) 12,668.39 88.88 333.77 7,461 91 7,390.94 6,505.49 2,783.10 5,972,331.00 352,336.72 0.36 4,509.71 MWD+IFR-AK-CAZ-SC(4) 12,763.66 89.55 332.77 7,463.22 7,392.25 6,590.57 2,740.25 5,972,416.92 352,295.59 1.26 4,604.96 MWD+IFR-AK-CAZ-SC(4) 12,858.92 90.00 334.53 7,463.59 7,392.62 6,675.93 2,697.97 5,972,503.10 352,255.04 1.91 4,700.21 MWD+IFR-AK-CAZ-SC(4) 12,953.60 89.93 333.43 7,463.65 7,392.68 6,761.01 2,656.44 5,972,588.99 352,215.22 1.16 4,794.86 MWD+IFR-AK-CAZ-SC(4) 13,048.70 89.53 333.70 7,464.10 7,393 13 6,846.16 2,614.10 5,972,674.97 352,174.60 0.51 4,889.95 MWD+IFR-AK-CAZ-SC(4) 13,143.82 89.98 333.90 7,464.50 7,393.53 6,931.51 2,572.11 5,972,761.14 352,134.33 0.52 4,985.06 MVVD+IFR-AK-CAZ-SC(4) 13,239.99 91.16 334.31 7,463.55 7,392.58 7,018.02 2,530.11 5,972,848.47 352,094.08 1.30 5,081 19 MWD+IFR-AK-CAZ-SC(4) 13,335.06 90.65 334.75 7,462.05 7,391.08 7,103.84 2,489.23 5,972,935.08 352,054.93 0.71 5,176.20 MWD+IFR-AK-CAZ-SC(4) 13,430.19 89.64 334.22 7,461.80 7,390.83 7,189.69 2,448.26 5,973,021.73 352,015.69 1.20 5,271.29 MWD+IFR-AK-CAZ-SC(4) 13,525.32 88.41 333.28 7,463.42 7,392.45 7,274.99 2,406.19 5,973,107.85 351,975.35 1.63 5,366.39 M1.ND+IFR-AK-CAZ-SC(4) 13,620.69 87.29 333.02 7,467.00 7,396.03 7,360.02 2,363.15 5,973,193.72 351,934.02 1.21 5,461.69 M1M3+IFR-AK-CAZ-SC(4) 13,716.78 88.22 331.76 7,470.77 7,399.80 7,445.10 2,318.65 5,973,279.67 351,891.24 1.63 5,557.70 MWD+IFR-AKCAZ-SC(4) 13,812.73 88.81 331.46 7,473.25 7,402.28 7,529.48 2,273.04 5,973,364.94 351,847.34 0.69 5,653.60 MVVD+IFR-AK-CAZ-SC(4) 13,908.38 90.34 332.07 7,473.96 7,402.99 7,613.75 2,227.79 5,973,450.09 351,803.79 1.72 5,749.23 MVVD+IFR-AK-CAZ-SC(4) 14,003.87 91.27 331.87 7,472.62 7,401.65 7,698.02 2,182.92 5,973,535.25 351,760.63 1.00 5,844.70 MWD+IFR-AK-CAZ-SC(4) 14,098.71 91.18 330.58 7,470.59 7,399.62 7,781.13 2,137.28 5,973,619.25 351,716.66 1.36 5,939.48 MWD+IFR-AK-CAZ-SC(4) 14,194.87 91.63 330.13 7,468.23 7,397.26 7,864.68 2,089.73 5,973,703.73 351,670.80 0.66 6,035.53 MVVD+IFR-AK-CAZ-SC(4) 14,289.29 92.54 331.81 7,464.80 7,393.83 7,947.18 2,043.95 5,973,787.12 351,626.68 2.02 6,129.83 MWD+IFR-AK-CAZ-SC(4) 14,383.91 92.98 330.87 7,460.24 7,389.27 8,030.11 1,998.62 5,973,870.94 351,583.03 1.10 6,224.31 MWD+IFR-AK-CAZ-SC(4) 14,479.48 92.26 330.36 7,455.87 7,384.90 8,113.30 1,951.78 5,973,955.04 351,537.87 0.92 6,319.72 MVVD+IFR-AK-CAZ-SC(4) 14,575.23 90.51 330.62 7,453.56 7,382.59 8,196.60 1,904.63 5,974,039.26 351,492.40 1.85 6,415.36 MWD+IFR-AK-CAZ-SC(4) 14,670.15 91.12 331.13 7,452.21 7,381.24 8,279.51 1,858.43 5,974,123.07 351,447.88 0.84 6,510.22 MWD+IFR-AK-CAZ-SC(4) 14,764.80 91.85 331.29 7,449.76 7,378.79 8,362.43 1,812.87 5,974,206.89 351,403.99 0.79 6,604.80 MWD+IFR-AK-CAZ-SC(4) 14,860.61 91.92 331.45 7,446.61 7,375.64 8,446.48 1,766.98 5,974,291.83 351,359.81 0.18 6,700.53 MWD+IFR-AK-CAZ-SC(4) 14,955.73 91.18 332.29 7,444.03 7,373.06 8,530.33 1,722.15 5,974,376.56 351,316.67 1.18 6,795.60 MVVD+IFR-AK-CAZ-SC(4) 15,050.78 90.59 333.60 7,442.56 7,371.59 8,614.97 1,678.93 5,974,462.04 351,275.15 1.51 6,890.64 MWD+IFR-AK-CAZ-SC(4) 15,145.48 90.97 332.50 7,441.27 7,370.30 8,699.37 1,636.01 5,974,547.29 351,233.94 1.23 6,985.33 MWD+IFR-AK-CAZ-SC(4) 15,238.20 92.99 334.11 7,438.07 7,367.10 8,782.15 1,594.39 5,974,630.88 351,193.99 2.79 7,077.98 MWD+IFR-AK-CAZ-SC(4) 15,330.57 92.64 333.94 7,433.53 7,362.56 8,865.09 1,553.98 5,974,714.60 351,155.26 0.42 7,170.22 MWD+IFR-AK-CAZ-SC(4) 3/9/2016 9:50:57AM Page 6 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S - +El-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 1542286 91.45 333.93 7,430.24 7,359.27 8,947.94 1,513 45 5,974,798.24 351,116.40 1.29 7,262.43 MWD+IFR-AK-CAZ-SC(4) 15,517.12 92.09 332.13 7,427.33 7,356.36 9,031.91 1,470.73 5,974,883.04 351,075.37 2.03 7,356.64 MWD+IFR-AK-CAZ-SC(5) 15,545.51 91.69 332.35 7,426.39 7,355.42 9,057.02 1,457.51 5,974,908.41 351,062.66 1.61 7,385.01 MWD+IFR-AK-CAZ-SC(5) 15,638.79 90.94 332.72 7,424.25 7,353.28 9,139.76 1,414.50 5,974,991.99 351,021.32 0.90 7,478.26 MWD+IFR-AK-CAZ-SC(5) 15,731.03 90.36 332.58 7,423.21 7,352.24 9,221.68 1,372.13 5,975,074.74 350,980.61 0.65 7,570.50 MWD+IFR-AK-CAZ-SC(5) 15,823.06 90.22 329.82 7,422.74 7,351.77 9,302.32 1,327.80 5,975,156.25 350,937.90 3.00 7,662.48 MWD+IFR-AK-CAZ-SC(5) 15,915.05 89.56 328.71 7,422.92 7,351.95 9,381.39 1,280.78 5,975,236.24 350,892.49 1.40 7,754.30 MWD+IFR-AK-CAZ-SC(5) 16,006.99 89.53 329.57 7,423.65 7,352.68 9,460.31 1,233.63 5,975,316.08 350,846.93 0.94 7,846.05 MWD+IFR-AK-CAZ-SC(5) 16,099.39 90.41 329.28 7,423.70 7,352.73 9,539.86 1,186.63 5,975,396.55 350,801.54 1.00 7,938.30 MVVD+IFR-AK-CAZ-SC(5) 16,191.93 90.36 328.13 7,423.07 7,352.10 9,618.93 1,138.56 5,975,476.57 350,755.07 1.24 8,030.60 MWD+IFR-AK-CAZ-SC(5) 16,285.20 90.55 328.37 7,422.33 7,351.36 9,698.24 1,089.48 5,975,556.84 350,707.59 0.33 8,123.58 MVVD+IFR-AK-CAZ-SC(5) 16,376.17 90.49 328.44 7,421.51 7,350.54 9,775.73 1,041.82 5,975,635.26 350,661.50 0.10 8,214.28 MWD+IFR-AK-CAZ-SC(5) 16,467.75 91.44 328.74 7,419.97 7,349.00 9,853.87 994.10 5,975,714.34 350,615.36 1.09 8,305.61 MW13+IFR-AK-CAZ-SC(5) 16,559.44 91.54 330.06 7,417.58 7,346.61 9,932.77 947.44 5,975,794.15 350,570.30 1.44 8,397.11 MWD+IFR-AK-CAZ-SC(5) 16,652.29 91.45 328.26 7,415.16 7,344.19 10,012.46 899.86 5,975,874.77 350,524.33 1.94 8,489.74 MWD+IFR-AK-CAZ-SC(5) 16,743.59 91.99 328.57 7,412.42 7,341.45 10,090.20 852.07 5,975,953.45 350,478.10 0.68 8,580.74 MWD+IFR-AK-CAZ-SC(5) 16,833.98 91.97 330.88 7,409.29 7,338.32 10,168.21 806.53 5,976,032.35 350,434.14 2.55 8,670.94 MWD+IFR-AK-CAZ-SC(5) 16,925.13 91.92 331.23 7,406.20 7,335.23 10,247.92 762.44 5,976,112.93 350,391.66 0.39 8,762.00 MWD+IFR-AK-CAZ-SC(5) 17,015.97 91.41 332.60 7,403.56 7,332.59 10,328.03 719.69 5,976,193.87 350,350.53 1.61 8,852.79 MWD+IFR-AK-CAZ-SC(5) 17,108.16 91.57 331.82 7,401.16 7,330.19 10,409.56 676.72 5,976,276.24 350,309.21 0.86 8,944.94 MWD+IFR-AK-CAZ-SC(5) 17,198.53 90.34 330.99 7,399.66 7,328.69 10,488.90 633.48 5,976,356.42 350,267.57 1.64 9,035.27 MVVD+IFR-AK-CAZ-SC(5) 17,290.51 90.47 330.92 7,399.01 7,328.04 10,569.31 588.82 5,976,437.70 350,224.54 0.16 9,127.20 MWD+IFR-AK-CAZ-SC(5) 17,382.83 90.50 332.51 7,398.23 7,327.26 10,650.60 545.08 5,976,519.85 350,182.44 1.72 9,219.50 MWD+IFR-AK-CAZ-SC(5) 17,474.50 90.46 334.04 7,397.46 7,326.49 10,732.47 503.86 5,976,602.53 350,142.87 1.67 9,311.16 MWD+IFR-AK-CAZ-SC(5) 17,566.20 90.64 335.36 7,396.58 7,325.61 10,815.37 464.67 5,976,686.19 350,105.36 1.45 9,402.80 MVVD+IFR-AK-CAZ-SC(5) 17,657.27 90.53 335.07 7,395.65 7,324.68 10,898.04 426.50 5,976,769.61 350,068.85 0.34 9,493.78 MWD+IFR-AK-CAZ-SC(5) 17,747.01 90.58 334.85 7,394.78 7,323.81 10,979.35 388.52 5,976,851.65 350,032.51 0.25 9,583.45 MWD+IFR-AK-CAZ-SC(5) 17,839.39 90.38 336.19 7,394.01 7,323.04 11,063.42 350.24 5,976,936.46 349,995.93 1.47 9,675.72 MWD+IFR-AK-CAZ-SC(5) 17,934.50 91.45 341.03 7,392.49 7,321.52 11,151.94 315.57 5,977,025.65 349,963.04 5.21 9,770.29 MWD+IFR-AK-CAZ-SC(5) 18,030.22 91.46 340.11 7,390.05 7,319.08 11,242.18 283.73 5,977,116.50 349,933.03 0.96 9,865.09 MWD+IFR-AK-CAZ-SC(5) 18,125.48 91.64 338.05 7,387.48 7,316.51 11,331.12 249.73 5,977,206.11 349,900.82 2.17 9,959.73 MWD+IFR-AK-CAZ-SC(5) 18,220.91 91.08 337.98 7,385.21 7,314.24 11,419.58 214.02 5,977,295.26 349,866.89 0.59 10,054.73 MWD+IFR-AK-CAZ-SC(5) 18,316.19 90.75 337.18 7,383.69 7,312.72 11,507.65 177.68 5,977,384.03 349,832.33 0.91 10,149.66 MWD+IFR-AK-CAZ-SC(5) 18,411.54 89.42 337.06 7,383.55 7,312.58 11,595.50 140.61 5,977,472.60 349,797.03 1.40 10,244.73 MWD+IFR-AK-CAZ-SC(5) 18,506.35 89.52 337.16 7,384.43 7,313.46 11,682.84 103.74 5,977,560.65 349,761.92 0.15 10,339.27 MWD+IFR-AK-CAZ-SC(5) 18,602.13 89.02 336.48 7,385.65 7,314.68 11,770.88 66.04 5,977,649.43 349,726.00 0.88 10,434.80 MWD+IFR-AK-CAZ-SC(5) 18,696.64 89.28 334.02 7,387.05 7,316.08 11,856.69 26.48 5,977,736.01 349,688.17 2.62 10,529.20 MWD+IFR-AK-CAZ-SC(5) 18,790.14 89.14 330.16 7,388.34 7,317.37 11,939.29 -17.27 5,977,819.46 349,646.08 4.13 10,622.67 MWD+IFR-AK-CAZ-SC(5) 18,885.26 89.55 328.52 7,389.43 7,318.46 12,021.10 -65.77 5,977,902.23 349,599.23 1.78 10,717.61 MWD+IFR-AK-CAZ-SC(5) 18,981.25 89.15 325.86 7,390.52 7,319.55 12,101.77 -117.78 5,977,983.91 349,548.86 2.80 10,813.13 MVVD+IFR-AK-CAZ-SC(5) 3/9/2016 9:50:57AM Page 7 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 19,076.68 88.96 326.65 7,392.09 7,321.12 12,181.11 -170.78 5,978,064.29 349,497.46 0.85 10,907.93 MWD+IFR-AK-CAZ-SC(5) 19,171.13 88.96 325.06 7,393.80 7,322.83 12,259.26 -223.79 5,978,143.49 349,446.04 1.68 11,001.68 MWD+IFR-AK-CAZ-SC(5) 19,266.57 89.08 327.18 7,395.44 7,324.47 12,338.48 -276.98 5,978,223.75 349,394.45 2.22 11,096.46 MWD+IFR-AK-CAZ-SC(5) 19,361.81 90.06 326.67 7,396.15 7,325.18 12,418.28 -328.95 5,978,304.58 349,344.09 1.16 11,191.20 MWD+IFR-AK-CAZ-SC(5) 19,457.37 90.98 326.16 7,395.28 7,324.31 12,497.89 -381.81 5,978,385.22 349,292.85 1.10 11,286.17 M1MD+IFR-AK-CAZ-SC(5) 19,552.78 92.47 328.97 7,392.41 7,321.44 12,578.37 -432.95 5,978,466.70 349,243.33 3.33 11,381.14 MVVD+IFR-AK-CAZ-SC(5) 19,648.29 92.34 331.46 7,388.40 7,317.43 12,661.18 -480.35 5,978,550.44 349,197.61 2.61 11,476.46 MWD+IFR-AK-CAZ-SC(5) 19,743.07 92.42 331.59 7,384.47 7,313.50 12,744.42 -525.50 5,978,634.57 349,154.14 0.16 11,571.14 MWD+IFR-AK-CAZ-SC(5) 19,838.44 92.40 332.55 7,380.46 7,309.49 12,828.61 -570.13 5,978,719.62 349,111.21 1.01 11,666.42 MWD+IFR-AK-CAZ-SC(5) 19,933.96 91.27 332.13 7,377.40 7,306.43 12,913.17 -614.45 5,978,805.05 349,068.60 1.26 11,761.88 MWD+IFR-AK-CAZ-SC(5) 20,029.45 91.51 332.08 7,375.08 7,304.11 12,997.54 -659.11 5,978,890.29 349,025.64 0.26 11,857.34 MWD+IFR-AK-CAZ-SC(5) 20,125.82 90.48 330.74 7,373.41 7,302.44 13,082.14 -705.22 5,978,975.79 348,981.24 1.75 11,953.66 MWD+IFR-AK-CAZ-SC(5) 20,220.30 90.89 330.23 7,372.28 7,301.31 13,164.35 -751.76 ' 5,979,058.92 348,936.36 0.69 12,048.06 MWD+IFR-AK-CAZ-SC(5) 20,316.63 90.80 331.96 7,370.86 7,299.89 13,248.67 -798.32 5,979,144.14 348,891.51 1.80 12,144.34 MWD+IFR-AK-CAZ-SC(5) 20,411.04 90.91 333.99 7,369.45 7,298.48 13,332.76 -841.21 5,979,229.07 348,850.31 2.15 12,238.73 MWD+IFR-AK-CAZ-SC(5) 20,505.80 91.03 334.62 7,367.84 7,296.87 13,418.13 -882.29 5,979,315.25 348,810.96 0.68 12,333.44 MWD+IFR-AK-CAZ-SC(5) 20,601.52 90.79 335.30 7,366.32 7,295.35 13,504.85 -922.80 5,979,402.75 348,772.20 0.75 12,429.08 MWD+IFR-AK-CAZ-SC(5) 20,696.75 91.68 334.00 7,364.27 7,293.30 13,590.88 -963.56 5,979,489.58 348,733.17 1.65 12,524.23 MWD+IFR-AK-CAZ-SC(5) 20,791.85 91.62 333.42 7,361.53 7,290.56 13,676.11 -1,005.66 5,979,575.63 348,692.79 0.61 12,619.28 MWD+IFR-AK-CAZ-SC(5) 20,887.83 92.05 332.20 7,358.46 7,287.49 13,761.44 -1,049.50 5,979,661.81 348,650.68 1.35 12,715.21 MWD+IFR-AK-CAZ-SC(5) 20,982.90 91.86 331.25 7,355.22 7,284.25 13,845.12 -1,094.51 5,979,746.37 348,607.36 1.02 12,810.21 MWD+IFR-AK-CAZ-SC(5) 21,042.00 91.99 331.47 7,353.23 7,282.26 13,896.96 -1,122.82 5,979,798.76 348,580.10 0.43 12,869.26 MWD+IFR-AK-CAZ-SC(5) 4 itr x 6414" 21,077.81 92.07 331.60 7,351.96 7,280.99 13,928.42 -1,139.88 5,979,830.55 348,563.68 0.43 12,905.04 MWD+IFR-AK-CAZ-SC(5) 21,173.82 92.43 332.21 7,348.19 7,277.22 14,013.05 -1,185.05 5,979,916.07 348,520.21 0.74 13,000.96 MVVD+IFR-AK-CAZ-SC(5) 21,268.72 92.01 331.73 7,344.52 7,273.55 14,096.75 -1,229.62 5,980,000.64 348,477.33 0.67 13,095.78 MWD+IFR-AK-CAZ-SC(5) 21,364.22 91.57 330.77 7,341.53 7,270.56 14,180.44 -1,275.53 5,980,085.23 348,433.11 1.11 13,191.20 MWD+IFR-AK-CAZ-SC(5) 21,459.80 90.30 328.90 7,339.97 7,269.00 14,263.06 -1,323.55 5,980,168.79 348,386.76 2.36 13,286.64 MWD+IFR-AK-CAZ-SC(5) 21,555.29 90.79 326.90 7,339.07 7,268.10 14,343.94 -1,374.29 5,980,250.66 348,337.66 2.16 13,381.77 MWD+IFR-AK-CAZ-SC(5) 21,649.47 90.05 327.84 7,338.38 7,267.41 14,423.25 -1,425.07 5,980,330.97 348,288.49 1.27 13,475.53 MWD+IFR-AK-CAZ-SC(5) 21,744.96 89.57 327.51 7,338.69 7,267.72 14,503.94 -1,476.13 5,980,412.67 348,239.06 0.61 13,570.65 MWD+IFR-AK-CAZ-SC(5) 21,840.13 88.99 326.96 7,339.89 7,268.92 14,583.97 -1,527.63 5,980,493.70 348,189.18 0.84 13,665.37 MWD+IFR-AK-CAZ-SC(5) 21,936.41 88.34 328.04 7,342.13 7,271.16 14,665.14 -1,579.34 5,980,575.89 348,139.10 1.31 13,761.21 MWD+IFR-AK-CAZ-SC(5) 22,030.46 87.50 327.52 7,345.54 7,274.57 14,744.66 -1,629.46 5,980,656.39 348,090.60 1.05 13,854.85 MWD+IFR-AK-CAZ-SC(5) 22,125.64 87.65 329.01 7,349.57 7,278.60 14,825.53 -1,679.47 5,980,738.24 348,042.22 1.57 13,949.65 MWD+IFR-AK-CAZ-SC(5) 22,220.93 88.10 330.67 7,353.11 7,282.14 14,907.86 -1,727.31 5,980,821.51 347,996.04 1.80 14,044.75 MWD+IFR-AK-CAZ-SC(5) 22,315.98 88.67 334.61 7,355.79 7,284.82 14,992.23 -1,770.97 5,980,906.73 347,954.09 4.19 14,139.74 MWD+IFR-AK-CAZ-SC(5) 22,412.47 89.09 335.85 7,357.67 7,286.70 15,079.82 -1,811.39 5,980,995.11 347,915.44 1.36 14,236.12 MWD+IFR-AK-CAZ-SC(5) 22,507.31 89.99 335.67 7,358.43 7,287.46 15,166.30 -1,850.32 5,981,082.34 347,878.25 0.97 14,330.82 M1M3+IFR-AK-CAZ-SC(5) 22,602.20 90.96 337.52 7,357.65 7,286.68 15,253.37 -1,888.01 5,981,170.15 347,842.31 2.20 14,425.49 MWD+IFR-AK-CAZ-SC(5) 3/9/2016 9:50:57AM Page 8 COMPASS 5000.1 Build 74 • SLB • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-07 Project: Western North Slope TVD Reference: CD5-07:34.3+36.67 @ 70.97usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-07:34.3+36.67©70.97usft(Doyon 19) Well: CD5-07 North Reference: True Wellbore: CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07 Database: EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 22,697.43 90 98 335.77 7,356.03 7,285.06 15,340 78 -1,925.76 5,981,258.29 347,806 33 1.84 14,520.49 MWD+IFR-AK-CAZ-SC(5) 22,792.83 90.83 333.38 7,354.53 7,283.56 15,426.93 -1,966.71 5,981,345.23 347,767.12 2.51 14,615.82 MWD+IFR-AK-CAZ-SC(5) 22,889.07 91.57 333.54 7,352.51 7,281.54 15,513.01 -2,009.70 5,981,432.15 347,725.87 0.79 14,712.03 MWD+IFR-AK-CAZ-SC(5) 22,984.65 91.32 334.30 7,350.10 7,279.13 15,598.83 -2,051.71 5,981,518.79 347,685.59 0.84 14,807.56 MVVD+IFR-AK-CAZ-SC(5) 23,078.76 91.56 333.25 7,347.74 7,276.77 15,683.22 -2,093.28 5,981,603.99 347,645.72 1.14 14,901.62 MWD+IFR-AK-CAZ-SC(5) 23,174.20 91.88 330.28 7,344.87 7,273.90 15,767.26 -2,138.41 5,981,688.91 347,602.30 3.13 14,996.99 MWD+IFR-AK-CAZ-SC(5) 23,270.32 91.99 326.32 7,341.62 7,270.65 15,848.98 -2,188.88 5,981,771.62 347,553.48 4.12 15,092.75 MWD+IFR-AK-CAZ-SC(5) 23,365.89 90.95 323.14 7,339.17 7,268.20 15,926.97 -2,244.03 5,981,850.69 347,499.90 3.50 15,187.34 MWD+IFR-AK-CAZ-SC(5) 23,458.57 91.33 323.38 7,337.33 7,266.36 16,001.22 -2,299.46 5,981,926.04 347,445.97 0.48 15,278.73 MWD+IFR-AK-CAZ-SC(5) 23,555.68 90.31 327.01 7,335.94 7,264.97 16,080.94 -2,354.88 5,982,006.84 347,392.17 3.88 15,374.97 MWD+IFR-AK-CAZ-SC(5) 23,651.61 88.69 333.36 7,336.78 7,265.81 16,164.12 -2,402.55 5,982,090.96 347,346.19 6.83 15,470.75 MWD+IFR-AKCAZ-SC(5) 23,711.00 88.69 333.36 7,338.13 7,267.16 16,217.19 -2,429.17 5,982,144.55 347,320.64 0.00 15,530.12 PROJECTED to TD 3/9/2016 9:50:57AM Page 9 COMPASS 5000.1 Build 74 • S Final Definitive Survey Verified and Sinned-off All targets and/or well position objectives have been achieved. Yes [ 1 No I have checked to the best of my ability that the following data is correct: C l Surface Coordinates U Declination & Convergence GRS Survey Corrections Digitally signed by Brij C Survey Tool Codes Hall-Potnis Date:2016.03.08 SLB DE: 15:52:33-09'00' Digitally signed by Client Representative: john.g.samuell@c 'D°Nngsanioell@xo"`°'h'llips.`°m onocophillips.comm"-'°""gsam°e"'`°"°`°P"""ps.`° Date: Date 2016.03.09 0797:35-09'00' • Cement Detail Report 0 • al CD5-07 Conoccontithps Al..k.* String: Conductor Cement Job: DRILLING ORIGINAL, 2/4/2016 04:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 3/20/2015 20:00 3/20/2015 22:00 CD5-07 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement 36.7 115.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg (bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Concrete-Class"B" 0.0 115.0 113 B 20.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.20 4.00 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/6/2016 • • Cement Detail Report CD5-07 Conoc€Phillips htrke String: Surface Cement Job: DRILLING ORIGINAL, 2/4/2016 04:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Cement 2/7/2016 15:37 2/7/2016 17:45 CD5-07 Comment PJSM. Surface cement job: Dowell pump 2.0 bbls H2O and test lines to 2,500 psi-good, Dowell pump 75 bbls 10.5 ppg Mud Push II, Drop bottom plug, Dowell pump 365 bbls of 11.0 ppg scavenger slurry plus Lead DeepCRETE cement plus additives, 1.91 ft3/sk yield at 6.0 bpm,250 psi. Dowell pump 57.8 bbls, 15.8 ppg,"G", 1.17 ft3/sx Tail cement at 7.0-7.5 bpm/500-800 psi. Drop top plug.Dowell pump 20 bbls H2O. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface 36.7 1,791.0 Yes 230.0 Yes No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg (bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 6 6 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 9 7/8 Comment Lead=11.0 ppg DeepCrete Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.7 1,791.0 1,058 G 360.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 11.00 5.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,791.0 2,291.0 274 G 57.0 Yield(ft3/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.10 15.80 3.50 500.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface 1,791.0 2,291.0 Yes No Yes Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 440.0 500.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Tail=15.8 ppg"G" Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 3/30/2016 • Cement Detail Report OS CD5-07 ConocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 2/4/2016 04:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/17/2016 20:00 2/18/2016 14:00 CD5-07 Comment Cement 1st stage as per Dowell.Dowell pressure test lines to 4000 psi(good).Dowell pump 40.1 bbls 12.5 ppg Mud Push, Drop ByPass plug,82.5 bbls 15.8 ppg 1.16 yld Qannik blend cement, Drop landing plug, 10.1 bbls H2O&displace with 489 bbls(486 bbls calculated+3 bbls 1/2 shoe track volume) 10.8 ppg LSND. Did not bump plug. Initial 6 bpm @ 150-450 psi,Final 3 bpm @ 360 psi. Reciprocate pipe w/full returns.Check floats(good). Cement 2nd stage. Dowell pressure test lines to 4000 psi(good). Dowell pump 46 bbls 12.5 ppg Mud Push,64 bbls 15.8 ppg 1.16 yld Qannik blend cement, Drop closing plug, 10 bbls H2O&displace with 244 bbls 10.8 ppg LSND.Initial 5.6 bpm&Final 3 bpm @ 582 psi.w/full returns. Bump closing plug&pressure to 2190 psi&shift stage collar closed.Hold for 5 min.CIP 14:00 hrs Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing Isolate Shoe 9,745.0 10,632.6 Yes Yes Yes Cement Q Pump[nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 360.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 3/4 Comment PJSM.Cement 1st stage as per Dowell.Dowell pressure test lines to 4000 psi(good). Dowell pump 40.1 bbls 12.5 ppg Mud Push, Drop ByPass plug,82.5 bbls 15.8 ppg 1.16 yld Qannik blend cement,Drop landing plug, 10.1 bbls H2O&displace with 489 bbls(486 bbls calculated+3 bbls 1/2 shoe track volume) 10.8 ppg LSND.Did not bump plug. Initial 6 bpm @ 150-450 psi, Final 3 bpm @ 360 psi.Reciprocate pipe w/full returns.Check floats(good) Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 9,745.0 10,632.6 399 G 82.5 Yield(f/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 5.00 500.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 4,441.0 5,191.0 Yes Yes No Cement Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 5 582.0 2,190.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 3/4 Comment Dowell pressure test lines to 4000 psi(good).Dowell pump 46 bbls 12.5 ppg Mud Push,64 bbls 15.8 ppg 1.16 yld Qannik blend cement,Drop closing plug, 10 bbls H2O&displace with 244 bbls 10.8 ppg LSND.Initial 5.6 bpm&Final 3 bpm @ 582 psi.w/full returns. Bump closing plug&pressure to 2190 psi&shift stage collar closed.Hold for 5 min.CIP 14:00 hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,441.0 5,191.0 310 G 64.0 Yield(ft'/sack) Mix H2O Ratio(gauss... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 4.25 500.0 Additives Additive Type Concentration Conc Unit label Page 111 Report Printed: 3/30/2016 • • prO 2.14 -001- Loepp, l6 —Ob¢Loepp, Victoria T (DOA) From: Samuell, John G <John.G.Samuell@conocophillips.com> Sent: Friday, February 26, 2016 8:40 AM To: Loepp, Victoria T(DOA) Subject: RE: CRU CD5-07 Intermediate Casing TOC: PTD 216-004 Follow Up Flag: Follow up Flag Status: Flagged 12.8 ppg EMW J.G. Samuell Drilling Engineer I ConocoPhillips Alaska I Direct:(907)265-6309 I Mobile:(832)465-8148 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, February 26,2016 8:36 AM To:Samuell,John G < ohn.G.Samuell@conocophillips.com> Subject: [EXTERNAL]RE: CRU CD5-07 Intermediate Casing TOC: PTD 216-004 J.G., Thanx for the information. What was the FIT? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a,alaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Samuell, John G [mailto:John.G.Samuell@conocophillips.com] Sent: Thursday, February 25, 2016 4:57 PM To: Loepp, Victoria T(DOA) Subject: CRU CD5-07 Intermediate Casing TOC: PTD 216-004 Victoria, Attached is the TOC log for the 7-5/8" intermediate casing.The shoe is set at 10,632' MD/7,470'TVD in the Alpine A reservoir.TOC is interpreted to be at 9,726' MD/7,209'TVD. J.G. Samuell Drilling Engineer i ConocoPhillips Alaska I Direct: (907)265-6309 I Mobile: (832)465-8148 1 DI— I— m o ICC/) 1 (" ° ' DmmO P-- c v m C I r- z --i {- 0 '=* a _ r- z CD 0 4:13 . .CT CD CI)- . CO 7. a . . Z■ IA n 0 00101 0 .-- � (f) ET 0 00 oo C 000 .E vmof o 1 O 0N co W r y 13 o =" co 0 CID N C7 o C I Z0 M D o 0 M �' o - __ o o co 0 * = = -a 0 m5 aN 0 eiri (1) 0 CD = c mn n Ci=1 r+ CD "'"J FOLD HERE The well name, location and borehole reference data were furnished by the customer All interpretations are opinions based on inferences from electrical or other measurements and we cannot,and do not guarantee the accuracy or correctness of any interpretation,and we will not,except in the case gross or willful negligence on our part,be liable or responsible for any loss, costs,damages oe expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers,agents or employees. These interpretations are also subject to Clause 4 of our General Terms and Conditions as set out in our Price Schedule. Waveform 1 - MH Waveform 1 - MH 300 ( us ) 3000 0 (us) 300C CASING_WINDOW_STOP Casing Amp(No-fil Casing Window Stop 300 ( us ) 3000 -20 ( ) 100 0 (us) 300C MD Casing Window StarS/T Projection - M Casing Amp(Filter Casing Window Star 1 : 240 I I ft 300 ( us ) 3000 40 (us/ft) 240 -20 ( ) 100 0 (us) 300C 8450 E i itA i fil I I I, I _Ai I\ */ a p. I i i i. I i / iIII.' �'I II .. .,,,,,,,, , . i 1 ` ' , i ll�t �I ', , I. I II ����fl,nt i i ii, f i' 4.. / • •,#11 11, I 1 8500 . . - II MY* i. ., , I j. i' ' I 1 I i . . . t '. I IMNVW 4 . , 1, . 1 1,1 ,0ill 1 , I !/ . it ... 8550 I It ,, I( : ' 1 -- '------- .----.-----,----\iv : 1 0AA" 1 .1. , I ' 1 1 ' I II 11 t ' I 1 II 1 1 I 1 ,,.., ,.... 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I I'l.Ill MD Casing Window Star S/T Projection- M Casing Amp(Filter Casing Window Star 1 ' 240 300 3000 -20 100 0 300C f1' (us) 40 ( us/ftl 240 ( ) fus) CASING_WINDOW_STOP 1p Casing Am -fil Casing Window Stop 300 ( us ) 3000 -20 ( ) 100 0 (us) 300C Waveform 1 - MH Waveform 1 - MH 300 (us) 3000 0 (us) 300C Company: ConocoPhillips Alaska, Inc. Well: CD5-07 Field: Colville River Unit Borough: North Slope Schlumberger State: Alaska ,, of T� ! • ,,w\��\��j�'4, THE STATE Alaska Oil and Gas m �� of �,,0; iJich IjsKA. Conservation Commission `•t . _,- 333 West Seventh Avenue k ; tZ--, , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 IiiiMain: 907.279.1433 Off 4LAS14-Q. Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-07 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-004 Surface Location: 328' FNL, 2555' FEL, SEC. 18, T11N, R4E, UM Bottomhole Location: 4781' FNL, 261' FEL, SEC. 25, T12N, R3E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 8., fs;(-444----- Cathy P. 'oerster �� Chair DATED this ��T day of January, 2016. STATE OF ALASKA RECEIVED AKA OIL AND GAS CONSERVATION COMM. ION ,JAN 0 5 2016 PERMIT TO DRILL 20 AAC 25.005 dAic la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ • Service-Disp LIlc.Spe i i pr'posed for: Drill •0 Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone ❑, Coalbed Gas ❑ Gas Hydrates ❑ Redril ❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: '5. Bond: Blanket ❑. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. - Bond No. 59-52-180 • CRU CD5-07 ' 3.Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 24209 , TVD: , 7347 Colville River Unit. 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Alpine Pool Surface: 328'FNL,2555' FEL,Sec. 18,T11N, R4E, UM , ASRC-NPR1,ASRC-NPR2,ASRC-NPR4 Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 952'FNL,4024'FEL,Sec.8,T11N,R4E, UM 932126,932128,932669 2/1/2016 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 4781'FNL,261'FEL,Sec.25,T12N, R3E, UM 27,783, 12,615, 15,912 2374.15'from AA092347 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL(ft): • 70.6 15. Distance to Nearest Well Open Surface: x-349424 y- 5965883 Zone-4 • GL Elevation above MSL(ft): . 34.3 to Same Pool: 2,750'to CD5-09 16. Deviated wells: Kickoff depth: , 450 feet 17. Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 90.5 degrees Downhole: 3374 Surface: 2590 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94 H-40 Welded 80 36 36 116 116 10 yds. 13-1/2" 10-3/4" 45.5 L-80 H-563/BTC 2210 36 36 2246 2160 973 sx 11.0 ppg,271 sx 15.8 ppg G 9-7/8 x 11" 7-5/8" 29.7 L-80 H-563/BTC 10552 36 36 10588 7456 412 sx 15.8 ppg G;432 sx 15.8 ppg G 6-3/4" -4-1/2" 12.6 L-80 HYD563 13771 10438 6912 24209 7347 N/A-Pre-perfed pups 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑ Time v. Depth Plot ❑ , Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 1/5/2016 22. I hereby certify that the foregoing is true and the procedure approved herein will not J.G.Samue11265-6309 be deviated from without prior written approval. Contact John.G.Samuell(a�cop.com Email Printed Name Chip Alvord Title Drilling Manager Signature /2.c ,41Stln Pr- C'A/t/oJhone 265-6120 Date 12/30/2015 Commission Use Only Permit to Drill API Number Permit Approval See cover letter for other Number: 0/1(0'' 001 50- /o 3- 0.o?3 xi-00-co Date: '-(W-I 4 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: r ' Other: /�jO p f'$f to '50O P -.) ,_/__� Samples req'd: Yes No Mud log req'd:Yes No �J /` rC Vevl tr✓ rc- t� Z sv�O's ❑ Cr L� ,fi h I-Iv l Q p HyS measures: Y�e,� �( No Directional svy req'd:Yes No �f f bvrtincSS ec1 ./14,1T A rC-c� &J� ❑ Inclination-onlysvyreq'd:Yes No ❑ S acing exception req'd: Yes No q' at-tee-,Sf-a ii/13e d Iii)C'G f/ ori , ❑ Ri -Post initial injection MIT req'd:Yes CI D l vei i , va,'v d U d-e l-- zO A,q-G 25. 035111)(2i E. ❑ APPROVED BY Approved by: /°? jYf9A ..,4.� - COMMISSIONER THE COMMISSION Date: /-/1-/, &Ref43 1 A ' o60 SubmitForm and Form 10-401(Revised 11/2015) a 0 OnthS from t e date�ap�oval(20 AAC 25.005(g)) Attachments inn Duplicate • • ConocoPhillips Alaska,Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 January 5,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill CRU CD5-07 Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore injection well from the CD5 drilling pad with rig Doyon 19. The intended spud date for this well is 2/1/16. CRU CD5-07 is planned to be an Alpine A injection well.The 13-1/2"surface hole will TD above the C-30 sand and then 10- 3/4"casing will be set. The intermediate section will be drilled with a 9-7/8"x 11"underreamer BHA and Managed Pressure Drilling technology.This hole will be subsequently cased with a 7-5/8"casing string to surface and cemented to 500' above the uppermost hydrocarbon bearing interval.The suface by intermediate casing annulus will then be evaluated for future annular disposal by performing a leak-off test. The 6-3/4"production section will then be horizontally drilled and completed as injector in the Alpine A reservoir.The well will be completed with a 4-1/2"liner with pre-perfed pups across the productive zone and tied back to surface with a 4-1/2" upper completion. Please find attached the information required by 20 AAC 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 AAC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035 (d)(2) 6. Directional drilling/collision avoidance information as required by 20 AAC 25.050(b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 AAC 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 J.G. Samuell at 265-6309 (John.G.Samuell(a,cop.com)or Chip Alvord at 265-6120. Sincerely, cc: CD5-07 Well File/Ann Haggerty-Sherrod ATO 1530 Rob Stinson ATO 1720 Chip Alvord ATO 1570 J.G. Samuell Jason McLennan ATO 1790 Drilling Engineer Lanston Chin Kuukpik Corp 111 Applici•for Permit to Drill,Well CRU CD5-07 Saved:5-Jan-16 CD5-07 Application for Permit to Drill Document 2 i�tX 7 9� S„i` 3h ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.0050 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005(c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005 (c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(11) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) CD5-07 APD Page 1 of 15 Printed:5-Jan-16 • Applica•or Permit to Drill,Well CRU CD5-07 Saved:5-Jan-16 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005 (c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005 (c)(14) 15. Attachments 10 Attachment 1 Cement Summary 11 Attachment 2 Drilling Hazards Summary 11 Attachment 3 Completion Schematic 15 Attachment 4 Directional Plan 16 CD5-07 APD Page 2 of 15 Printed:5-Jan-16 • ApplicaSor Permit to Drill,Well CRU CD5-07 Saved: 5-Jan-16 1. Well Name (Requirements of 20 AAC 25.005(I) The well for which this application is submitted will be designated as CRU CD5-07. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 328'FNL,2555' FEL, Sec. 18,Ti 1N,R4E,UM • NAD 1927 RKB Elevation 70.6'AMSL• Northings: 5,965,883 Eastings: 349,424 Pad Elevation 34.3'AMSL Top of Productive Horizon(Heel) 952'FNL,4024'FEL, Sec.8,T11N,R4E,UM NAD 1927 Measured Depth, RKB: 10,588' Northings: 5,970,462 Total Vertical Depth, RKB: 7,456' Eastings:353,309 Total Vertical Depth, SS: 7,385' Total Depth (Toe) 4781'FNL,261'FEL, Sec.25,T12N,R3E,UM NAD 1927 Measured Depth, RKB: 24,209' Northings: 5,982,598 Total Vertical Depth, RKB: 7,347' Eastings: 347,128 Total Vertical Depth, SS: 7,276' Requirements of 20 AAC 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 19. CD5-07 APD Page 3of15 Printed:5-Jan-16 • Applica•or Permit to Drill,Well CRU CD5-07 Saved: 5-Jan-16 4. Drilling Hazards Information (Requirements of 20AAC25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Size Csg Setting Depth Fracture Pore pressure ASP Drilling (in) MD/TVD(ft) Gradient(ppg) (psi) (psi) 20 116/ 116 10.9 52 54 10.75 2,246/2,160 14.5 977 1,412 7.625 10,588/7,456 12.5 3,374 2,590 N/A 24,209/7,347 12.5 3,325 n/a PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP=[(FG x 0.052)-0.1]*D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP-(0.1 x D) Where: FPP=Formation Pore Pressure at the next casing point FPP=0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20"conductor ASP= [(FG x 0.052)-0.1] D =[(10.9 x 0.052)-0.1]x 116=54 psi OR ASP=FPP-(0.1 x D) =977-(0.1 x 2160')=761 psi 2. Drilling below 10-3/4"surface casing ASP=[(FG x 0.052)-0.1]D = [(14.5 x 0.052)-0.1]x 2160' = 1412 psi OR ASP=FPP-(0.1 x D) =3374-(0.1 x 7456')=2628 psi 3. Drilling below 7-5/8"intermediate casing ASP= [(FG x 0.052)-0.1] D =[(12.5 x 0.052)-0.1]x 7456=4101 psi OR ASP=FPP-(0.1 xD) =3325-(0.1 x 7347')=2590 psi (B)data on potential gas zones; CD5-07 APD Page 4 of 15 Printed:5-Jan-16 • Applicator Permit to Drill,Well CRU CD5-07 Saved: 5-Jan-16 The well bore is not expected to penetrate any gas zones. (C)data concerning potential causes of hole problems such as abnormally geo pressuredstrata,lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) Siz1� (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 42 94 H-40 Welded 80 30/30 116/116 Previously Installed HYD Cement to Surface with 10-3/4 13.5 45.5 L-80 563 X 2,210 36/36 2,246/2,160 973 sx DeepCrete Lead 11.0 ppg, BTCM 271 sx Class G Tail Slurry 15.8 ppg HYD 7-5/8 9.875 29.7 L-80 63 X 9,593 36/36 10,588/7,456 Stage 1: 412 sx Class G at 15.8 ppg x11 BTCM Stage 2: 432 sx Class G at 15.8 ppg 4-1/2 6.75 12.6 L-80 563D 13,771 10,438/7,412 24,209/7,347 N/A—Pre-perfed liner 4-1/2 N/A 12.6 L-80 EUE 10,402 36/36 10,438/7,412 N/A-production tubing 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2)is granted. At CDS,eight penetrations have been completed and there has not been a significant indication of shallow gas or gas hydrates `1 1 above the C30 where casing will be set. CD5-07 APD Page 5 of 15 Printed:5-Jan-16 • Applic2•ior Permit to Drill,Well CRU CD5-07 Saved: 5-Jan-16 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.75 Casing Size in. 10.75 7.625 4.5 Density PPG 8.8— 10.0 9.6— 11.1 9.0 PV cP 30-80 10 10 YP Ib./100 ft2 100-200 20 -28 10 - 15 Funnel Viscosity s/qt. 300 50 - 60 40 - 50 Initial Gels Ib./100 ft2 50 10 6 10 Minute Gels lb./100 ft2 6.0 15 8 API Fluid Loss cc/30 min. N.C.—15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0— 12.0 10.0 pH 11.0 9.5- 10.0 9.0-9.5 Surface Hole: A mixed-metal oxide fresh water drilling fluid(Drilplex)will be used for the surface interval. Keep flow line viscosity at±200 sec/qt while drilling and running casing.Reduce viscosity prior to cementing.Maintain mud weight<l0.0 ppg by use of solids control system and dilutions where necessary. Intermediate#1: Fresh water polymer mud system.Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation,particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material.Good filter cake quality, hole cleaning and maintenance of low drill solids(by diluting as required)will all be important in maintaining wellbore stability.The mud will be weighted up to 11.1 before pulling out of the hole. Note: Managed Pressure Drilling(MPD)will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill-in fluid(FloPro)weighted to 9.0 ppg with calcium carbonate and KC1. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-07 APD Page 6 of 15 Printed:5-Jan-16 • Applica.r Permit to Drill,Well CRU CD5-07 Saved: 5-Jan-16 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A- Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto CD5-07. 2. Rig up and test riser,dewater cellar as needed. 3. Drill 13.5"hole to the surface casing point as per the directional plan(LWD Program: GR)./ 4. Run and cement 10-3/4"surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low/3500 psi high. K 7. Pick up and run in hole with 9-7/8"x 11"drilling BHA to drill the intermediate hole section. 8. Pressure test casing to 3500 psi. 9. Drill out 20' of new hole and perform LOT.Maximum LOT to 18.0 ppg.Minimum LOT required to drill ahead is 12.5 ppg EMW. 10. Drill 9-7/8"x 11"hole to section TD using Managed Pressure Drilling to maintain constant bottom hole pressure on connections(LWD Program: GR/Res). 11. Change out upper pipe rams to 7-5/8"solid bodies and test same. 12. Run 7-5/8"casing and cement to 500' above hydrocarbon bearing zones. 13. Change upper pipe rams to 3-1/2"x 6"VBRs. 14. Test BOPE to 250 psi low/3,500 psi high. 15. Pick up and run in hole with 6-3/4"drilling BHA.Verify top of cement with sonic tool in recorded mode. 16. Pressure test casing to 3,500 psi. 17. Drill out shoe track and 20 feet of new formation.Perform LOT to a maximum of 18 ppg.Minimum required leak-off value is 11.0 ppg EMW. 18. Drill 6-3/4"hole to section TD(LWD Program: GR/Azimuthal Res./Sonic for TOC evaluation). 19. Pull out of hole with drilling BHA. 20. RIH with 4.5"liner completion(pre-perfed)on 4"drill pipe. 21. Set liner hanger and release from liner. Set liner top packer. CD5-07 APD Page 7 of 15 Printed:5-Jan-16 • Applic.or Permit to Drill,Well CRU CD5-07 Saved:5-Jan-16 22. Displace well to kill weight brine. 23. Run 4.5" upper completion. 24. Space out and land tubing hanger. 25. Install 2-way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 26. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi.Remove 2-way check. 27. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 28. Shear circulation valve in GLM. 29. Circulate tubing to diesel and install freeze protection in the annulus. 30. Set BPV and secure well. RDMO. CD5-07 APD Page 8 of 15 Printed:5-Jan-16 • Applicator Permit to Drill,Well CRU CD5-07 Saved: 5-Jan-16 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Incidental fluids developed from drilling operations on well CD5-07 will be injected into the surface casing x production casing annulus of CD5-09 and/or CD5-11 wells upon approval. Well CD1-01A will be used as a backup disposal well for excess fluid volumes. 1 The CD5-07 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include only the Alpine sand based on pre-drill interpretations.There will be 500' of cement fill placed above the top of the Alpine reservoir. Once CD5-07 has been drilled and completed,consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations,per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above,any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation(C-40). These 450-500'thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes.Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection,the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure =(12.0 ppg)*(0.052)*(Surf. Shoe TVD)+ 1,500 psi =(12.0 ppg)*(0.052)*(2,160')+ 1,500 psi =2966 psi Pore Pressure = 1,049 psi Therefore Differential=2966—1049= 1916 psi. The internal casing pressure is conservative,since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85%collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85%of Burst 85% of (PO Type Collapse Burst 10-3/4" 45.5 L-80 3 HYD563/BTCM 2470 psi 2100 psi 5210 psi 4429 psi 7-5/8" 29.7 L-80 3 HYD563/BTCM 4790 psi 4071 psi 6890 psi 5856 psi CD5-07 APD Page 9 of 15 Printed:5-Jan-16 . Applicat.r Permit to Drill,Well CRU CD5-07 Saved:5-Jan-16 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan CD5-07 APD Page 10 of 15 Printed:5-Jan-16 • Applic.or Permit to Drill,Well CRU CD5-07 Saved. 5-Jan-16 Attachment 1 —Cement Summary CD5-07 Cementing Program: CD5-07_wp10 Schematic J 20"94#H-40 We Conductor to eld115'd 10-314"45.5#L-80 HYD563/BTCM A 2,246'MD/2,159'TVD @ 34°inc. Top of Cement 3,986'MD K2(Qannik) 4,486'MD HES Cementer O o 0 5,451'MD 9-7/8"x 11"Hole Top of Cement 9,639'MD 7-518"29.7 L-80 HYD563 X BTCM Casing Alpine A Arc ` 10,588'MD/7,456'TVD @ 87° 6.3/4" Hole 4-1/2"Pre-Perfed Pup Liner 12.6 ppf L80 HYD563 24,209'MD/7,347 @ 90.5° CD5-07 APD Page 11 of 15 Printed:5-Jan-16 • Applicipor Permit to Drill,Well CRU CD5-07 Saved:5-Jan-16 10.75" Surface Casing run to 2,246' MD/2,160' TVD Cement from 2246' MD to 1746'(500' of tail)with Class G+Adds. @ 15.8 PPG, and from 1746'to surface with 11.0 ppg DeepCrete. Assume 250%excess annular volume in permafrost and 50%excess below the permafrost (1324' MD),zero excess in 20"conductor. Lead slurry from 1,901'MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (116'—36') X 1.3645 ft3/ft X 1.0 (0%excess) = 109 ft3 Permafrost to Conductor (1,324'— 115') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,538 ft3 Top of Tail to Permafrost (1,746'— 1,324')X 0.3637 ft3/ft X 1.5 (50% excess) = 230 ft3 Total Volume = 109 + 1,538 + 230 = 1,877 ft3=> 973 sx of 11.0 ppg DeepCrete @ 1.93 ft3/sk Tail slurry from 2,246'MD to 1,746' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,246'—1,746')X 0.3637 ft3/ft X 1.50 (50%excess) = 273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0 (0%excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 271 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8%S002 accelerator @ 1.17 ft3/sk 7.625"Intermediate Casing run to 10,588' MD/7,456' TVD Top of slurry is designed to be at 9,639' MD,which is 500' above the UJU.Assume 40%excess annular volume. Tail slurry from 10,588'MD to 9,639'MD with 15.8 ppg Class G + additives Shoe to Top of Cement (10,588'—9,639')X 0.3428 ft3/ft X 1.40 (40%excess) = 456 ft3 Shoe Joint (80')X 0.2578 ft3/ft X 1.0 (0%excess) = 21 ft3 Total Volume = 456 + 21 = 477 ft3 => 412 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk Qannik Second Stage from 5,451' MD to 3,986'MD with 15.8 ppg Class G + additives 1,040'MD Across Qannik (5,026'—4,411')X 0.3428 ft3/ft X 1.40 (40% excess) = 500 ft3 Total Volume = 500 ft3 => 432 sx of 15.8 ppg Class G +0.2% D046 antifoamer,0.3% D065 dispersant and 0.8%S002 accelerator @ 1.16 ft3/sk CD5-07 APD Page 12 of 15 Printed:5-Jan-16 • Applicor Permit to Drill,Well CRU CD5-07 Saved:5-Jan-16 Attachment 2— Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole/10-3/4"Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots,traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight,decreased Gas Hydrates Low mud viscosity, increased circulating times,controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters,Increase mud weight,use weighted sweeps. Lost Circulation Low Reduced pump rates,mud rheology,lost circulation material,use of low density cement slurries 9-7/8"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills, increased mud weight.No mapped faults occur across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers 6-3/4"/4-1/2" Liner Production Interval Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills,increased mud weight. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers CD5-07 APD Page 13 of 15 Printed:5-Jan-16 • Applicor Permit to Drill,Well CRU CD5-07 Saved:5-Jan-16 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden.LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik and instability in the production interval will require higher mud weights and managed pressure drilling in order to stabilize the formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. CD5-07 APD Page 14 of 15 Printed:5-Jan-16 • Applicior Permit to Drill,Well CRU CD5-07 Saved: 5-Jan-16 Attachment 3—Completion Schematic CD5-07—Alpine A Injector Proposed Schematic updated 1/5/2016 by J.Samuel) 20"94#H-40 Welded Upper Completion: Length Conductor to 110' 1)4-W 12.6#/ft EUE Tubing 2)DB 3.813" 3)3-W x 1"Camco KBMG GLM(xx )w/DCK2 T pinned for 2500 psi casing to tbg shear 4)X nipple 3.785"ID 1.5' 5)WLEG 1.5' Lower Completion: 10-3I4"45.5#L-80 4) ZXP liner top packer& Hyd 563/BTC Flex lock Liner Hanger 37' Surface Casing XO 5"Hydril 521 Box X 4-%"HYD563 pin 2,246'MD/2,160'TVD 5)4%", 12.6#/ft,L-80 HYD563 Liner w/pre-perfed pup every 300' ZXP liner top packer &hanger Top Reservoir at+/- Alpine A Sand 7437'TVD ' 0 0 0 0 0 0 0 o O 0 0 0 Mirage plug , 6 314"Hole TD 4-1/2" 12.6#L-80 24,209'MD 17,347'TVD 7 518"29.7 L-80 HYD563 Liner HYD563 x BTCM Intermediate Casing 10,588'MD 1 7,456'TVD CD5-07 APD Page 15 of 15 Printed:5-Jan-16 • DD• CD5-O7wplO. 1 7 . 060 Plan Summary LCU UJU Kalublk i I AIpA r >5 HRZ,� I 1 . -5 1 1 Base Permafrost v 1 '\ / m - / C30 1 I i - ' J K2 A11357 7-518"x 9-7/8"by 11" K3 \ i AIb96 , 0 - I ti i 1 i 'i I i i i i I 1 i i I I I I i f 0 t 0110-3/4"x 13-12215500 11000 16500 22000 Measured Depth 'llf`���� o `� 0° 0 110-3/4"x 13-12'1 Depth Reference: Plan:34.3+36.3 C�70.60usft(Doyon 19) /���` ;�;,®® 1',,e6s- Rig: Doyon 19 p. M 0 ' P6� „ I7-5/8"x 9-718"by 11" , if 0040, ..v... ,{:, 1412"x 6-3/4" z+l( 1' >' >/ �/ e5i>/ >/ N/ N/ IN' N/ ei I I I i i t I'd di tr `z/`6 0'I g ' d Id I gI I O O O O O O O O O cos-oftog51°nII 36 450 0 2500 5000 �150� 1 000 9255'0 15/800 9759b 2 0 0 450 640 Horizontal Departure a� �, },n 1COie�++I 640 - 840 330 rr1•y� ^'ef�t3s e 30 �% ��,[TP ■e"�i'���jN cosai'+moB 840 - 1030 t'-- --- ..--. ■i CM yS,, k%�� 1030 - 1220 i .� ��tn i c 'v'- CDS10WpC9.1 ■ 1'igjyr E'����i /�. - 1220 - 1420 ti O In CD5-09.p11 ... _ ;a�r =,Z ?a, aAR�R f i1. s "60 1420 - 1s10 aal g0 _ C -0wvP 4� .°44 >,-,P.,< ' - IcosmWwe 1610 - 1800 _E '0,D5-05 __ ... 300 �.,„.h..%.,- 3C,4,917/Irkt-t ; '17. 1500 - 2740 N \CD5-04 10 ... /j , ,F �'4C . . 2780 3680 e 680 - 4610 8 30 to:, asla - 5550 O -.. 270 ,4�t---.'. 2..8 aaceFK ,a . A ""` 060.:,-,: 5550 - 6490 ,-- III �■ '° it, 6490 - 7420 C. -. -. 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N. 0 l0 0 u) 0 O i- N r N r 0 u) u) 0 0 N a= u) u) u) u) N u) u) N- N V CO u) a- u) .- u) N V V V V V CO V CO u) CO o N r r a) 0 7 2 V CO W N 7 V O CO CO N- N- I,- CO N- CO 0 CO u) 0 u) 0 N- u) CO N C N N N N u) u) CO I- r ,- CO CO .- a- 0) .- 0) (D CO N- N- N. N. C0 u) u) I- u) N O M M (fl O) M I` O N u) N u) N u) N N M O O co 7 (O N N (O co co Co .- N N N N M N N N O O M N V Cr cr V O O M CO CO a` y a- r s- .- T- a- m 7.. W N U) CO 4- O O N O (d 0 0 N 000 (00 (0 <00 I` O I` 0 (00 O N •O r N.n N-r N-r N CO N 0 0 N- CO M .- 0 0) (0 CO CO r u) CO V O V N a- N CO Cr 0 V 0) V O 7 (A O W V u) O Q) O O o) o) V [Y V d' V O O O O CO cu 7 L0) N CA N CO I- 0) 0 0 7r-- N- 0 V0) V0) O) I- N N- N I- 0 u) N 0 m N a y 7 co V u) N V u) I. N V CO u) s- V a- V .- V V V V V CO V CO N Q CO o 7 e- ppa) 0 N V 2 C O0) 00) 00) 00) O (O CO co N- V V O N V CO - CO 00) O O N tN 0 N W CO CO OD N. 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X Q N 7 m V) 00000 000000 00 i CI- i i i O 0 CO O 10 M Z Q) cocococoV, V co co co co C C C C C 0 0. 0 N ry M co co co 7 co u) u) u) 0) 0) 0) 0) CO CO CO M CO CO CO CO CO CO m m m m m N U p r N - O O O O O O O O O o O O o a a- O L 0 0 0 2 0 0 0 0 0 0 /C 0 c io d V) (n (n (n (n V) (n (n v) V) v) (n ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ _ _ NI NI CO •(I, 2 rn O N CO C 00000 000000 000000000000 00000 3 N O N N 'Q 00000 000000 00 i i i i i i i i N V) V) V) C crs y 0 E H CO CO CO CO V V u) (0 u) (r) 0 0 0 0 O 0 m N C0 N Q M CO CO CO V u) u) u) u) Cr) 0) 0) CO ,O` C rn 2 G 0 0 0 0 0 0 0 0 0 0 0 0 0 CO CO M CO 0) M M M CO o) U U U U U v M T U co 0 a) E u) u) u) u) (n u) u) u) u) (n u) co co V) co co co co' co' co' u) co' co' C C C C C c) t-t 00000 000000 000000 000000 co co al co co C C tem 0 p2 MCC 4, 65 U U U U U U U U U U U U U U U 00 U U U U U U U U a a a o_ o_ < 00 • 9 z o ci) ccc g 0 O O E 0 O 0 C Y Y Y Y . Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y N N (/) (/1 N N N N N N N N N N N N N N N N N N .‘e) 02 C) 2 0_' 0_ 0_ 2 a' •R 2 lY a' lY lY a' a' 0_ 2 Q' a R R 88888 888888 000000 000000 888 a m a o m m 7a- m m m o a m m m m m m m m m m m m m m m 01 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 Cl.,cn N N N N N N N N N N N N N N N N N N N N N N N N N N l0 N l6 N (0 l6 (a N N (0 l6 t0 (0 l6 l6 l0 N (0 (0 l6 N N (0 Ca CO (0 a a a a a a a a a a a a a a a a O a a a a a a a a a s 0. c O O C..) •0 0 C H E 8 8 m a, 8 m `0 0 `0 a, `0 0 0 0 `0 w `0 0 0 0 0` m O 0 `O 0 o con ti t"i o 0 0 or, 0 0 0 0 0 0 0 0 o 0 0000 o -6 () tit U m E LL LL co co LL N Li_ N LCL N LCL O LCL a ll CO LL w0 LL U) LcmcL U) Li LL IL C 0) N N N N N a) .N 0) .N a) N a) N a) 0 a) N 0) N 0) .N 0) N 0) 0) E 0 0 ❑ ❑ 0 0 0 0 o a o ❑ 0 a o a o ❑ 0 ❑ o ❑ 0 p 0 0 E c c c c c c c c c c c c C c E 22222 222222 222222 222222 2222 7 co co C C CO C co E co C co C co C N C C6 C CO C CO C CO C (0 co C/) .) 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N l- O CO N O CO d Li O C C C CO Ln O M O Ln O) N N N O) O C Lf) C) n Ln O C) 1) O .0 CO O N O M N C N O N N Le (A CA N O) M N C) C T,_- O N O C) (0 a y LO Ln co M Ca- C Ln N N C C N M C C LO Ln C C CO COC Ln C a) 01O cD r r ,- r r r r r r C(N Q 0 V E O CO CO O O) O O N )- N N N N CO CO N N O CO CO N C N C C) Ln C Ln O 00 C N Ln N CO N N CO CO N N C N N- W 0 O O O O O O C) 6 O M M O O'0' N6 O O LD 6N N O O (`6 CC T N E 0)C E .1- 0000 N N N N N N 220, N O O N N M M N N O O N W Cb •C E N r r r r r r c O 'E N r ` 0 a 3 0) co O O 0 C CO O O CO O O CA C N O LC) Ln O O O LO O O r-- 0 0 I- a) '0 N O CO CO O N N O 0) N N N- a- a- N N O N N N CO CO N O CO 1 N9 Q. 2 L r6 C C C (O La CJ M (a viOi N N: Lri O) O C Ln W r Ln O O) Lo A O N CO CO N C N O N N N 61 C) N O) CO N CA C N- N O C) U) C Q = N a (N Ln co co M C ,- C Ln N N C C N M C C Ln u) C C CO, CO C Ln C 0 m V w (00 -S m 2 ix o 2 I L Ln I's o0 d 9 z c •E Q p '4) :4 a . c , UN c o a c a z u) .0 O co - 3 3 N N N N N N Q W O ❑ ❑ 0] Lb m lb m in C 0) U y 5 a) Ln Ln (t p n n co co ";0_ o 0 0 0 0 0 0 ` CO y a) a a s a Q 3 Q ? 3 3 3 3 3 3 0 0 a. a (a E 3 - - 3 3 3 3 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ L = ' N u- co O O) O) N N Q) CT Ln Ln N N (O O N r W CO a 0. 7 U a (y U z o n Q 'Y.'? § m ao o_ o_ oa n § a s 3 3 2 IF ° a 2 � 2 ❑ o o o o a ¢ o 0 0 0 ? ? o 3 ? a o o a a s- ,- U }i C y • = U s- v- U U (•,- ,•,- 0 CD 5 j j co co N N N- I,- N N co CO N N ❑ ❑ CT Lo o N ?� = m , co Ln N N rn rn Ln Q Q § § m m § § m m § m m 00 a >, d o00 rnm55 E E ¢ a ❑ ❑ ¢ Q ❑ ❑ Qa ❑ ❑ C. 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T,2 `i _ c, L CCOOUOOOO > 0 N c . c O 4. O O O O n O 6 W N C = 2 .NE NC) C) O O v v n W W 8 .2 d 74" O (Si N 0 02 NC v L N N d ai ro .0o 13 a csi Q d c .cm CL) m m ° N up'$ av 3 NC NN . m cv O y C N ._ 6 0O ca O ` ) •D- p pp C mc 7O NN U ON N E V N �p 0 18 a m N w Q W 0 6 6 0 0 12:56, January 64 2(16 Ladder View CD5-07w„10.1 1'� The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. F. . ... .-:: 1 a a a Wit. $ 3 q I , 300 c 1I m ail lif a i• In l N N 150 m, 1 ( Ufr [ 0 lip; SII 2 t 0 III I;' i L11471 „ r . 0 Equivelant Magnetic Distance I i i I I I I I I i I I I I I I I I I I I I u 3500 7000 10500 140001 17500 21000 24500 Displayed interval could be less than entire well:Measured Depth 36.30 To 24208.60 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 36.30 500.00 CD5-07wp10.1 (Plan: CD5-07) INC+TREND 2159.60 2245.84 10-3/4” x 13-1/2" 36.30 500.00 CD5-07wp10.1 (Plan: CD5-07) GYD-GC-SS 7455.58 10588.00 7-5/8"x 9-7/8" by 11" 500.00 1500.00 CD5-07wp10.1 (Plan: CD5-07) MWD 7347.03 24208.60 4-1/2"x 6-3/4" 500.00 2245.84 CD5-07wp10.1 (Plan: CD5-07) MWD+IFR-AK-CAZ-SC 2245.84 3745.84 CD5-07wp10.1 (Plan: CD5-07) MWD 2245.84 10588.00 CD5-07wp10.1 (Plan: CD5-07) MWD+IFR-AK-CAZ-SC 10588.00 12088.00 CD5-07wp10.1 (Plan: CD5-07) MWD 1f15RR(1(1 247(18 An (.f '-(17wn1f1 1 (Plan. Cm-(17) MWfl+IFR-AK-CA7-SC' A d 00n 0 0 0 t]W U V U I§ - 1_ m i i u) ' 1 ' P- '' ',..I I/ i \ 30 - `. _ :.. .,) ' ... ......_.. ........ -- --- \ / . — o ......... ..._... C U : 0I ' ] I i 1 I I 1 I I I I I 1 1 I I I I l I I I I 1 I I I I 1 I I I t 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth Equivelant Magnetic Distance • Sb 4b0 CD5-07wp10.1 MD Inc Azi TVD D1eg TFace Tar 640 36.30 0.00 0.00 36.30 .00 0.00 36.30 To 24208.60 450.00 0.00 0.00 43560:0:i:031 50.00 0.00 0.00 640 840 600.04 2.25 155.00 600.00 1.50 155.00 901.64 9.15 115.79 900.00 2.50 -50.00 840 1030 12:57,January 04 2016 1330.15 14.05 65.84 1320.60 2.50 -90.00 1030 1220 1433.24 14.05 65.84 1420.60 0.00 0.00 CASING DETAILS 2812.45 48.00 52.00 2586.40 2.50 -18.30 1220 1420 8138.17 48.00 52.00 6150.00 0.00 0.00 TVD MD Name 8180.63 44 :00(61 .00 50.00 6178.42 3.50 -90.67 1420 1610 2159.60 2245.84 10-3/4" x 13-1/2" 9322.99 4 .06 355.25 6974.95 3.50 -109.02 7455.58 10588.A(fi/8" x 9-7/8" by 11" 9325.17 48.06 355.25 6976.40 0.00 0.00 1610 1800 7347.03 24208.60 4-1/2' x 6-314" 10588.35 87.00 331.86 7455.60 3.50 -34.65 CD5-07 01.Heel 120715 JD 10608.35 87.00 331.86 7456.65 0.00 0.00 1800 2740 10724.24 90.48 331.86 7459.20 3.00 -0.05 SURVEY PROGBAX 24208.60 90.48 331.86 7347.03 0.00 0.00 CD5-07 02.Toe 110515 JD 27404 3680 eptM1 Fro. Depth To SurveylPlan Tao, 3680 461 0 38.30 500.BB C05-07.ple.1 (518n:CD5-8]) INC.TBEND 38.3' SBB.00 L05-0]ep10.1 (Plan:CD5-07) CM-GL-SS 50'.00 1588.80 COS-B7wp1B.1 (Plan:LOS-8]) X1.0 500.00 2245.84 C05-07,18.1 (Plan: ....7) pW.IFR-AN-LA2-sc 45565100 5550 2245.84 3745.84 C05-07,10.1 (Plan:105.07) ml• 2245.84 10588.8' COS-9]x410.1 (Plan:GS-07) ....IFR-AN-G2-SC 10588.88 12888.80 C05-97x410.1 (Plan:....7) xl,. 6490 10588.00 24208.80 C05-87.10 1 (Plan:GS-']) RW.IFR-AK-G2-SC 6490 7420 7420 - 8360 CD5-02wp09 8360 9300 CD5-03wp11 9300 11160 0/360 11160 13030 CD5-03 -----.i:_ ,1111\�u h. li%:5,, 13030 14890 a �iiiltN �. CD5-01wp08 -30/33 • ) y1 r ,, 0 14890 16760 / '•.= 4< ' ....'es.'i,iA1 V i°.�®'at 1 16760 - 18620 1 11 j 1 t;01'1,', F m•s �,�114i1+'i�.+�,1 p•+a 4 i%a°' . 11118463678026930000 8620 20480 CD5-09 `�� -� P r% a;t�f`4 ;.r.a.,ea�� 4+�` ► r�',�ai �! z iv !/i�' \ r♦ vw►+ 20480 22350 126 j:'� ���.t.•,.,07:;: • :'�����/ �>�,��d/i►�•ra\I ��►!�T;r ::DWPOI • CD5-12wp07 ® �/► e, 'lai • ; .1 " ri 'i� .'.� t e��>yd°a ,+���, � Ir , ♦ -�►� Bis ��1►Git�l! \atilq-�csY�a�� " .Q ,Ti A( 1LE .Ll •/Wt�)�y�a\�a p .7me ,FRA, 71 ,G r< Ir ♦s' O .. � /�♦ t � (w4Ka��1 3 � 1♦ .. i.::si� `r/i ►►•�v1►�A\ A, ,IN3ah ig,�1 a t,1e-o, 4- vs, a ro • s .% 4',‘V, \� (ice iti, 'vs :bYyH� -7. I i'� \►.'►a '' e F 6-' 7 f T 04, \ yI' Cir. _• ..SK�b�F.d.��4aLv �'�• i � � a r � 8 ,�7}r � • 1 .��1\ , • 4811.,©4111tvat a �xeRc tt ".., °ra, s . 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'C 1 Ln d- Cr M M 0 c0 r ' d' M N M d- in 1/4_0 N. 00 ON 7- Cr) d- '0 00 0 N 1- ,- c- c- N N 0 aN0 Y pN Q Q Q Z y,,V K Lc_ Ldf Eopo 0 0 a c mc c m c _... a a an anon ' 3 3 3 3 3 3 3 z o 0 0 0 0 0 0 0 vi V V U V V V u V '-4'48.1= 8,2 ' � ao0 m v ' O am O O ` O o p O 0 0° rt. � � q m rn (3\M 0 0 o0 '7...q :7-., "d_.v o 0 k, U p O r rl \ N ,2`3pN O 0 00 rn N .o 0 NO N ON N O ia L. 0 'RI 0 0 0 a1 d- d- 0 0 0 Ln 1/4.0 1/4.0 r%.4 immi < O O O N. 00 CO O o O N N 00 00 00 CO M 00 0 Ln l-n Ln Ln N N 0 Ln Ln , r- x- r- as 1 0 Ln '0 '.0 in Ln Ln Ln Ln rn M M M LA 0 M M rrl r'r1 M M cs; 0 • 0 0 d- d- in d- Ln 01 -in in dO V 0 - rr1 0 0 '0 `-: N d- r; 'C 01 7 M M N 'C :3'0 O O O M N C O N c0 c0 d- 00 0 M Ln O 0 rc 1 rn CO c70m 00 N m CO 0 N 0 a, m Ln .O 0 d- r- N 00 0- 0 0 0 0 • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-07 Plan: CD5-07 Plan: CD5-07wp10.1 Error Ellipse Survey Report 04 January, 2016 0 i SLB Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-07 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.6ousft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.6ousft(Doyon 19) Well: Plan:CD5-07 North Reference: True Wellbore: Plan:CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07wp10.1 Output errors are at 1.00 sigma Database: EDM Production Project Western North Slope,North Slope Alaska,United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site CD5 Alpine West Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Well Plan:CD5-07 Well Position +N/-S 0.00 usft +E/-W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 34.30 usft Wellbore Plan:CD5-07 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 2/11/2016 17.78 80.83 57,469 Design CD5-07wp10.1 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) I 36.30 0.00 0.00 332.00 Survey Tool Program Date 1/4/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 36.30 500.00 CD5-07wp10.1 (Plan.CD5-07) INC+TREND Inclinometer+known azi trend 36.30 500.00 CD5-07wp10.1 (Plan:CD5-07) GYD-GC-SS Gyrodata gyro single shots 500.00 1,500.00 CD5-07wp10.1 (Plan:CD5-07) MWD MWD-Standard 500.00 2,245.84 CD5-07wp10.1 (Plan:CD5-07) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,245.84 3,745.84 CD5-07wp10.1 (Plan:CD5-07) MWD MWD-Standard 2,245.84 10,588.00 CD5-07wp10.1 (Plan:CD5-07) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,588.00 12,088.00 CD5-07wp10.1 (Plan:CD5-07) MWD MWD-Standard 10,588.00 24,208.60 CD5-07wp10.1 (Plan:CD5-07) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (soft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 450.00 0.00 0.00 450.00 4.16 0.00 4.16 0.00 1.15 0.02 0.02 4.16 4.16 0.00 INC+TREND(1,1) 600.04 2.25 155.00 600.00 0.61 0.00 0.61 0.00 1.15 0.04 0.04 0.61 0.61 45.00 MWD(2,2) 901.64 9.15 115.79 900.00 0.73 -0.01 0.85 0.02 1.15 0.10 0.10 0.85 0.75 130.06 MWD(2,2) 1/4/2016 3:13:02PM Page 2 COMPASS 5000.1 Build 74 • • SLB Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-07 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-07 North Reference: True Wellbore: Plan:CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07wp10.1 Output errors are at 1.00 sigma Database: EDM Production 1 Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Send-major Semi-minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 1,330.15 14.05 65.84 1,320.60 1.30 -0.07 1.63 0.10 1.16 0.21 0.24 1.78 1.14 97.08 MWD(2,2) 1,433.24 14.05 65.84 1,420.60 1.40 -0.07 1.97 0.12 1.17 0.25 0.28 2.10 1.25 90.77 MWD(2,2) 2,245.84 33.93 54.58 2,159.60 1.99 -0.19 3.18 0.08 1.19 0.60 0.84 3.25 2.09 68.80 MWD(3,3) 2,440.47 38.76 53.52 2,316.32 2.01 -0.25 4.40 0.34 1.22 0.69 0.81 4.44 2.21 61.75 MWD(3,3) 2,812.45 48.00 52.00 2,586.40 2.30 -0.36 7.33 0.85 1.45 0.82 1.24 7.36 2.48 56.83 MWD(3,3) 4,584.83 48.00 52.00 3,772.35 4.05 -0.35 11.65 0.04 2.92 1.72 2.20 11.66 3.39 55.19 MWD+IFR-AK-CAZ-SC(4,3) 4,911.65 48.00 52.00 3,991.04 4.62 -0.35 13.44 0.04 3.36 1.97 2.58 13.46 3.72 54.88 MWD+IFR-AK-CAZ-SC(4,3) 5,519.35 48.00 5200 4,397.67 5.50 -0.35 16.15 0.04 4.04 2.38 3.19 16.17 4.25 54.57 MWD+IFR-AK-CAZ-SC(4,3) 7,336.59 48.00 52.00 5,613.64 8.22 -0.35 24.36 0.04 6.11 3.89 5.44 24.38 5.96 54.11 MWD+IFR-AK-CAZ-SC(4,3) 8,138.17 48.00 52.00 6,150.00 9.36 -0.35 27.74 0.04 6.97 4.62 6.52 27.76 6.69 54.02 MWD+IFR-AK-CAZ-SC(4,3) 8,180.63 48.00 50.00 6,178.42 9.52 -0.35 27.84 020 7.01 4.66 6.59 27.91 6.73 54.01 MWD+IFR-AK-CAZ-SC(4,3) 9,231.33 47.08 359.39 6,913.09 19.20 -1.91 17.44 4.45 8.16 5.98 8.35 29.29 8.09 52.98 MWD+IFR-AK-CAZ-SC(4,3) 9,322.99 48.06 355.25 6,974.95 19.29 -1.99 17.10 4.51 8.18 6.01 8.38 29.31 8.13 52.96 MWD+IFR-AK-CAZ-SC(4,3) 9,325.17 48.06 355.25 6,976.40 1929 -1.99 17.10 4.51 8.19 6.01 8.38 29.31 8.13 52.95 MWD+IFR-AK-CAZ-SC(4,3) 9,583.54 55.68 349.04 7,135.92 17.90 -3.26 15.36 4.93 8.50 6.30 8.75 29.59 8.71 52.09 MWD+IFR-AK-CAZ-SC(4,3) 9,817.72 62.81 344.33 7,255.65 15.53 -4.51 14.20 5.28 8.89 6.53 9.08 29.84 9.55 51.01 MWD+IFR-AK-CAZ-SC(4,3) 10,139.16 72.81 338.76 7,376.98 12.85 -5.56 13.73 5.58 9.33 6.68 9.33 30.06 10.58 49.66 MWD+IFR-AK-CAZ-SC(4,3) 10,406.61 81.24 334.58 7,436.99 10.67 -6.39 13.80 5.85 9.79 6.75 9.51 30.27 11.70 47.98 MWD+IFR-AK-CAZ-SC(4,3) 10,588.00 86.99 331.87 7,455.58 10.21 -6.58 13.98 5.74 9.83 6.76 9.44 30.57 11.94 46.90 MWD(4,4) 10,588.35 87.00 331.86 7,455.60 10.21 -6.58 13.98 5.74 9.83 6.76 9.44 30.57 11.94 46.90 MWD(4,4) 10,608.35 87.00 331.86 7,456.65 10.21 -6.58 14.12 5.66 9.83 6.76 9.40 30.61 12.01 46.57 MWD(4,4) 10,724.24 90.48 331.86 7,459.20 9.81 -6.79 15.06 5.18 9.85 6.76 9.16 30.86 12.50 44.55 MWD(4,4) 24,208.60 90.48 331.86 7,347.03 26.37 -6.79 84.63 5.92 26.39 6.65 18.69 85.62 27.22 161.04 MWD+IFR-AK-CAZ-SC(5,4) Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude CD5-07 02.Toe 110515, 0.00 0.00 7,347.03 16,666.32 -2,632.02 5,982,343.71 1,487,160.86 70°21'32.725 N 151°14'41.682 W -plan hits target center -Circle(radius 100.00) CD5-07 01.Heel 120715 0.00 0.00 7,455.60 4,656.81 3,792.01 5,970,208.37 1,493,341.67 70°19'34.604 N 151°11'34.029 W -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 2,245.84 2,159.60 10-3/4"x 13-1/2" 10-3/4 13-1/2 10,588.00 7,455.58 7-5/8"x 9-7/8"by 11" 7-5/8 11 24,208.60 7,347.03 4-1/2"x 6-3/4" 4-1/2 6-3/4 1/4/2016 3:13:02PM Page 3 COMPASS 5000.1 Build 74 • • SLB Error Ellipse Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-07 Project: Western North Slope TVD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.3+36.3 @ 70.60usft(Doyon 19) Well: Plan:CD5-07 North Reference: True Wellbore: Plan:CD5-07 Survey Calculation Method: Minimum Curvature Design: CD5-07wp10.1 Output errors are at 1.00 sigma Database: EDM Production Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,330.15 1,320.60 Base Permafrost 0.00 2,440.47 2,316.32 C30 0.00 4,584.83 3,772.35 K3 0.00 4,911.65 3,991.04 K2 0.00 5,519.35 4,397.67 Alb97 0.00 7,336.59 5,613.64 Alb96 0.00 9,231.33 6,913.09 HRZ 0.00 9,583.54 7,135.92 Kalubik 0.00 9,817.72 7,255.65 LCU 0.00 10,139.16 7,376.98 UJU 0.00 10,406.59 7,436.99 AIpA 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 450.00 450.00 0.00 0.00 KOP:Start 1.5°/100'DLS,155°TF,for 150.04' 600.04 600.00 -2.67 1.25 Start 2.5°/100'DLS,-50°TF,for 301.6' 901.64 900.00 -18.49 25.37 Adjust TF to-90°,for 428.51' 1,330.15 1,320.60 -12.00 103.75 Hold for 103.09' 1,433.24 1,420.60 -1.76 126.59 Start 2.5°/100'DLS,-18.3°TF,for 1379.21' 2,812.45 2,586.40 394.32 700.64 Hold for 5325.72' 8,138.17 6,150.00 2,830.97 3,819.41 Start 3.5°/100'DLS,-90.67°TF,for 42.46' 8,180.63 6,178.42 2,850.83 3,843.94 Adjust TF to-109.02°,for 1142.36' 9,322.99 6,974.95 3,576.78 4,146.27 Hold for 2.18' 9,325.17 6,976.40 3,578.40 4,146.14 Start 3.5°/100'DLS,-34.65°TF,for 1263.19' 10,588.35 7,455.60 4,656.81 3,792.01 Hold for 20' 10,608.35 7,456.65 4,674.42 3,782.59 Start 3°/100'DLS,-0.05°TF,for 115.89' 10,724.24 7,459.20 4,776.57 3,727.96 Hold for 13484.36' 24,208.60 7,347.03 16,666.32 -2,632.02 TD:24208.6'MD,7347.03'TVD Checked By: Approved By: Date: 1/4/2016 3:13:02PM Page 4 COMPASS 5000.1 Build 74 Pool Report • • WELLBORE TARGET DETAILS(MAP CO-ORDINATES) 10:30,January 14 2016 C D 5-0?w p 10.1 Name TVD Shape CD5S07 01.Heel 120715 JD 7 .60 Circle(Radius:100.00) 00507 02.Toe 110515 JD 7347347 09 Circle(Radius:100.00) C05.07 01.Hee1 110615 JD 7476.74 Ciide(Radius:100.00) Quarter Mile View CD5-07 01.Meel 120515 JD 7466.74 Circle(Radius,100.00) CD5-0701.HeM 120715 JD Circle 7455.60 Circle(Radius.1320.00) 005A7 02.Toe 110516 JD Circle 7347.09 Circle(Radius:1320.00) A`J 6 1 • 17500 Ga5A3 14000— cn 0 o i 40500 'F GOSAA L t O Z -77000— Nuigs tl 1 ,/ 7000— 0 co 3500— • II)<, w t4011' 0 GOy A6 I I I I -10500 -7000 -3500 0 3500 7000 10500 14000 17500 West(-1/East(+1 (3500 usft/inl • • WELLBORE TARGET DETAILS(MAP CO-ORDINATES) 19:26,January 142016 CD5-07111/1310.1 Name ND Shape CDS-07 01.Heel 1JD 1455 60 Circle(Radius: 00 00) T CD5-07 02. 1105150515 JD 7347.03 Circle(Radius'.100.00) Quarter Mile View CD5-07 01 Flee!110515 JD 74]6.74 Circle(Radius 10000) C05-07 01 Heel 120515 JD 7468.74 Circle(Radius'.100 00) CD507 01.Neel 120715 JO Circle 7455.60 Circle(Radius:1320 00) CD5-07 02.T 110515 JO Circle 7347 03 Circle(Radius:1320 00) Ci''' O Y 6<.. 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Legal Description(NAD27 only) Starting Coordinates: Legal Description X1489457.08Township: 1011 N Range: 1004 E Y: [5965629.08 Meridian: 1u v.1 S ection:118 FNL 1327.52992 FEL , 12554.7963 Transform I Quit 1 Help 1 CD5-07wp10.1 Intermediate Casing I CPA: 1 —� ' '-'s.,- From: _ From: To: Datum: [NAD Region: alaska Datum: 1NAD27 „I Region: alaska C" Latitude/Longitude [Decimal Degrees C Latitude/Longitude !Decimal Degrees C UTM Zone: i' South C UTM Zone: ;True- l.._ South t+ State Plane Zone: 4 Units: us4t C State Plane Zone: ;True t i Llnits: lius- _.'.,1 ft C Legal Description(NAD27 only) a: Legal Description(NAD27 only) Starting Coordinates: — Legal Description I X: 1493341.83 LTownship: 1011 N w Range: 1004 E .F Y: 15970208.06 Meridian: ju J Section:18 J FN L J 1952.24562 j FE L _17. 14024.1743 Transform Quit j Help I • CD5-°7wP1°.1 TD " ,4,:[,"1 ql: ' X. Efi r-P,A: Coo-dinate Converter From: To: Datum: INAD83 z7::al Region: Ialaska ji Datum: [NAD27 ',A. Region: raiaska 2:i C Latitude/Longitude [Decimal Degrees '...d C Latitude/Longitude 'Decimal Degrees : C UTM Zone: I - E South C UTM Zone: True l South .--'.,. Units: 1:1;76 a State Plane Zone: 4 —,1 Units: LT;i1 .., C State Plane Zone: True .:1 C Legal Description INAD27 only) (iLegal Description(NAD27 only) Starting Coordinates: X: 1-T487160.85 Y: 5982343.71 _ .........„ „ .. _ „.„ [ Legal Description Township: 1012F-...1.1 Range: F003 rE--A. Meridian: ILL ] Section:125 IFNL 1 k781.2747 1261.46389 I 1261.46389 .._ Transform ----1 Q uit I Help • • Tollerable Collision Risk Worksheet As - built EgamE41111111311101=21 DESCRIPTION 100111111201311111011111kailEZM DESCRIPTION 1 f/ /15 CZ DB C.A. UPDATED PER K150003ACS 1itil • a ALPINE SATELLITE DEVELOPMENT 11 / �r LOCATION OF 1 THIS SURVEY ibitsw.,,,,derll *'' `�,�.CD4 TO ALPINEI MI ( 1 � ` � CD5 ACCESS ROAD r�•..� x II emmt.,..6,;3,-.1w rte ' . N '3:s= r. ..Y J,AL` nIttwomiamwelgrieg ' IIJI, . q lPRuIJ , t Immo ;..I� + •R1 L TE 1 ! ilk VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SECTION 7, T. 11 N., R. 4 E., U.M. SECTION 16. T. 11 N., R. 4 E., U.M. CD-5 PA ��s�' PAD OU\" R OooN , x aV .`r` W , � ° T a!' �o � 3xX4X� OO.�ee : • - s •r A U amu,, ix � rw�� •ee _ -. s i % s •=e ;00 • 11 .x % �� : le. 111f PLANT N ANC 0 15'46 52" -p LP 4a _ rO -Y\ KUUKPIK �- 41M. IFIL rn Alpine Survey Office ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. ##/##/15I DRAWING NO: PART: I REV: 14-12-09-1C CE—CD50— # 1 OF 3 1 REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 11#/##/15 CZ DB C.A. UPDATED PER K150003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC. 18, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST. WELL 'Y' 'X' LAT.(N) LONG.(W) FNL FWL GND PAD CD5-x01 5,965,661.64 1,489,572.44 70' 8' 49.155" 151' 13' 21.378" 293' 2489' 27.6 34.1 CD5-x02 5,965,656.28 1,489,553.29 70' 8' 49.099" 151' 13' 21.934" 299' 2470' 28.1 34.1 CD5-x03 5,965,650.92 1,489,534.00 70' 8' 49.042" 151' 13' 22.493" 305' 2451' 28.4 34.1 CD5-x04 5,965,645.24 1,489,514.77 70' 8' 48.982" 151' 13' 23.051" 311' 2432' 26.6 34.2 CD5-x05 5,965,639.80 1,489,495.46 70' 8' 48.925" 151° 13' 23.611" 316' 2412' 28.1 34.3 CD5-x06 5,965,634.56 1,489,476.20 70' 8' 48.870" 151' 13' 24.170" 322' 2393' 27.7 34.3 I CD5-x07, 5,965,629.08 1,489,457.08 70' 8' 48.812" , 151' 13' 24.724" 328' 2374' 27.9 34.3 I CD5-x08 5,965,623.88 1,489,437.69 70' 8' 48.757" 151' 13' 25.287" 334' 2355' 28.1 34.3 CD5-x09 5,965,618.27 1,489,418.53 70' 8' 48.698" 151' 13' 25.842" 340' 2336' 27.3 34.2 CD5-x10 5,965,613.12 1,489,399.13 70' 8' 48.644" 15V 13' 26.405" 345' 2317' 28.1 34.1 CD5-x11 5,965,607.66 1,489,379.86 70' 8' 48.586" 151' 13' 26.964" 351' 2297' 27.9 34.1 CD5-x12 5,965,602.23 1,489,360.56 70' 8' 48.529" 151' 13' 27.524" 357' 2278' 28.0 34.1 CD5-x13 5,965,596.59 1,489,341.43 70' 8' 48.470" 151' 13' 28.079" 363' 2259' 26.1 34.2 CD5-x14 5,965,591.36 1,489,322.33 70° 8' 48.414" 151' 13' 28.633" 368' 2240' 27.6 34.2 CD5-x15 5,965,586.10 1,489,303.11 70' 8' 48.359" 151' 13' 29.190" 373' 2221' 26.8 34.2 NAD 83 NOTES: KUUKPIK 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. I.ICMF2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) ,,,,,,,DINEe 7D-17'9 Alpine Survey Office ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 14-12-09-1C ##/##/15 CE-CD50-### 1 OF 3 1 REV DATE BY CK APP DESCRIPTION REV DATE BY h APP DESCRIPTION 1 ##/##/15 CZ DB C.A. UPDATED PER K150003ACS NOTES: 1 . ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD-4 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, JUNE 2013. 4. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD5-X12, CD5-X13, CD5-X14, CD5-X15, 4/10/15, FB 2015-12 PGS 4-7, 9; CD5-X01 THRU CD5-X11, 4/17/15, FB 2015-10 PGS 49-52; SURVEYOR'S CERTIFICATE , I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED OF ALq ♦♦ TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS � •,..••••"" ••..,.•'Sir 9 ♦ AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT `;. . ♦♦♦ SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST a i • �� ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE • 1 49th * V CORRECT. • / DATE: REGISTRATION NO. LS-5077 Donald G. Bruce o- ♦crf No. LS-5077 1,i_44'47 • Fe KUUKPIK .• LCM FL.. eta esa,dka•anawpp,wYawon(ITTrseo Alpine Ofilce (9077 070-4739 Alpine Survey Office y* ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 14-12-09-1C ##/##/15 CE—CD50—### 1 OF 3 1 • • Loepp, Victoria T (DOA) From: Samuell, John G <John.G.Samuell@conocophillips.com> Sent: Thursday, January 14, 2016 10:46 AM To: Loepp, Victoria T(DOA) Subject: RE: CRU CD5-07(PTD 216-004) 1/4 mile AOR Attachments: CD5-07wp10.1 PlanSummary- PermitPack.pdf Victoria, 1/4 mile radius circles on Page 41 and 42 of the attached. J.G. Samuell Drilling Engineer I ConocoPhillips Alaska I Direct:(907)265-6309 I Mobile:(832)465-8148 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Wednesday, January 13, 2016 9:38 AM To: Samuell, John G Subject: [EXTERNAL]CRU CD5-07(PTD 216-004) 1/4 mile AOR J.G., Please show a% mile radius circle around the injection interval on the wellbore plots. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepoc 7alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • Bettis, Patricia K (DOA) From: Samuell,John G <John.G.Samuell@conocophillips.com> Sent: Thursday, January 07, 2016 5:17 PM To: Bettis, Patricia K (DOA) Subject: RE: CRU CD5-07: Permit to Drill Application (PTD 216-004) Patricia, We plan on flowing the well back for 1—3 days to clean off the filter cake from the wellbore. Once that is complete we will dummy off the gas lift valve and put the well on injection. J.G. Samuell Drilling Engineer I ConocoPhillips Alaska Dirert(90I)265 63091 Mobile (832)465 8148 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, January 07, 2016 1:41 PM To: Samuell, John G Subject: [EXTERNAL]CRU CD5-07: Permit to Drill Application (PTD 216-004) Good afternoon John, Does ConocoPhillips plan to pre-produce CD5-07 and if so, for what duration. 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.bettistalaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, January 07, 2016 1:41 PM To: John.G.Samuell@conocophillips.com Subject: CRU CD5-07: Permit to Drill Application (PTD 216-004) Good afternoon John, Does ConocoPhillips plan to pre-produce CD5-07 and if so, for what duration. 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. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: (L. CE— o7- PTD: R1(0 - ooki Development X Service Exploratory _Stratigraphic Test Non-Conventional FIELD: ('V1)l4. 1VEti POOL: C I Jc)/.L ►�1 — JAIf I),6_ Or/ 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- - - - (If last two digits Production should continue to be reported as a function of the 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 on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a 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, v composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 • 11J LI 0 0) a a) to a) b . N' pa) a 0 13 C (O : or c, c 0 a r d' m 4 W -' C. a)' d O' O oc co co c ao a o. Z o -o a�' a .� ` O v` M diU o' C N m' .0 0 C11" >, LL' U, o c' 3. aa'i o, a a�. d a�' 0 5' �, •E aa)), E, a d o u�i , , '3; Z. 2 c, y = c' N' ril a v. Lu 0) m, c. o 4 0' c ' �' a) o ' ,c) E, co v. U 1 o ; 9 N 0' 3' >O' 0, „ co M V• a 2 F- ' ' H' ' 0'' 0 E' c v' 0_ ' E' .4., 0) o' 4 0 . 1 D', N, J _, @, m' m c. o o li' ' w ' o' a) c AlIJJ-i d, O' c a �, 3 0 a) y' aa) M' m' Z. 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