The URL can be used to link to this page

Home My WebLink About214-121CAUTION: 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: KRU 2N-337 (PTD 214-121 ) Date:Tuesday, July 8, 2025 8:16:58 AM Attachments:AnnComm Surveillance TIO for 2N-337C.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, July 7, 2025 4:42 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2N-337 (PTD 214-121 ) Well Name: 2N-337 Facility: CPF2 PTD: 214-121 Well Type: Inj AA Number (if applicable): AIO 16.007 AMD Internal Waiver (Yes/No if applicable): Yes Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Well Name: 2N-337 Facility: CPF2 PTD: 200-210 Well Type: Inj AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Chris, CPAI reported 2N-337 for possible IAxOA communication on 4/29/2025. CPAI then completed extensive diagnostics followed by monitoring to confirm well integrity. On analysis of these diagnostics, CPAI concludes the OA has integrity and the source of suspect integrity is thermal and caused by fluctuation in injection rate. CPAI intends for the diagnostics and additional monitoring to be concluded. Please let me know if you have any questions or disagree with this plan. The TIO plot, bleed log, and schematic are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2N-337C 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2N-337 2025-04-16 415 555 140 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,532.0 1/17/2017 2N-337C pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL BOMB HANGER W/DUAL GAUGES 3/15/2017 2N-337C pproven Casing Strings Casing Description PRODUCTION 5 1/2 " OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 28.0 Set Depth (ftKB) 7,029.8 Set Depth (TVD) … 5,054.2 Wt/Len (l… 15.50 Grade L-80 Top Thread Hyd 563 Casing Description LINER 3 1/2" - CEMENTED OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 6,819.4 Set Depth (ftKB) 7,653.0 Set Depth (TVD) … 5,536.6 Wt/Len (l… 9.20 Grade L-80 Top Thread 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,819.4 4,892.8 40.08 SLEEVE SETTING SLEEVE 4.130 6,840.4 4,908.9 40.06 PACKER ZXP PACKER 3.000 6,848.8 4,915.3 40.05 HANGER FLEX LOCK LINER HANGER 2.980 Tubing Strings Tubing Description TUBING WO - 2014 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.8 Set Depth (ft… 6,839.9 Set Depth (TVD) (… 4,908.5 Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.8 25.8 0.00 HANGER FMC HANGER - PORTED DRIFTED TO 2.91" 2.992 483.8 483.4 6.06 NIPPLE CAMCO DS NIPPLE 2.875 6,681.3 4,787.1 39.90 SLEEVE BAKER CMU DS SLIDING SLEEVE DS PROFILE - CLOSED 2.810 6,767.1 4,852.8 40.10 NIPPLE CAMCO D NIPPLE 2.750 6,820.6 4,893.7 40.08 SEAL ASY BAKER BULLET TIE BACK SEAL ASSEMBLY W/ 7' SPACE OUT 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,285.0 7,345.0 5,251.5 5,298.4 4/13/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES 7,345.0 7,390.0 5,298.4 5,333.3 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES, 60 DEG PHASING 7,435.0 7,455.0 5,368.1 5,383.5 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLEINNUM CHARGES, 60 DEG PHASING 7,455.0 7,475.0 5,383.5 5,398.8 4/11/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER, 11.1 GRAM MILLEINNUM DP CHARGES, 60 DEG PHASING 7,475.0 7,490.0 5,398.8 5,410.3 3/24/2015 6.0 IPERF 2.5" 11.1 GRAM MILLENIUM DP CHARGES Frac Summary Start Date 5/7/2007 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 5/7/2007 Top Depth (ftKB) 9,600.0 Btm (ftKB) 9,615.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,355.0 2,490.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 2 5,129.6 3,606.9 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 3 6,168.2 4,395.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 4 6,623.9 4,743.1 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/5/2015 Notes: General & Safety End Date Annotation 4/12/2019 NOTE: WAIVERED WELL - T x IA COMMUNICATION ON GAS ONLY. WATER ONLY INJECTION ALLOWED Comment SSSV: NIPPLE 2N-337C, 4/12/2019 2:28:05 PM Vertical schematic (actual) LINER 3 1/2" - CEMENTED; 6,819.4-7,653.0 IPERF; 7,475.0-7,490.0 IPERF; 7,455.0-7,475.0 IPERF; 7,435.0-7,455.0 IPERF; 7,345.0-7,390.0 IPERF; 7,285.0-7,345.0 3-1/2 Production liner; 6,825.0 ftKB PRODUCTION 5 1/2 "; 28.0- 7,029.8 SEAL ASY; 6,820.6 NIPPLE; 6,767.1 SLEEVE; 6,681.3 GAS LIFT; 6,623.9 GAS LIFT; 6,168.2 Intermediate Casing Cement; 5,200.0 ftKB GAS LIFT; 5,129.6 GAS LIFT; 3,355.0 SURFACE; 29.3-2,858.4 Cement Plug; 2,658.0 ftKB NIPPLE; 516.3 NIPPLE; 483.8 CONDUCTOR; 29.2-108.0 HANGER; 25.8 KUP INJ KB-Grd (ft) 29.25 Rig Release Date 3/14/2007 Annotation Last WO: End Date 2N-337C H2S (ppm) 30 Date 7/1/2008... TD Act Btm (ftKB) 7,547.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032026203 Wellbore Status INJ Max Angle & MD Incl (°) 69.65 MD (ftKB) 2,901.28 WELLNAME WELLBORE2N-337C 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: AOGCC Notification: KRU 2N-337C (PTD 214-121) Suspect IAxOA Date:Tuesday, April 29, 2025 4:24:38 PM Attachments:AnnComm Surveillance TIO for 2N-337C.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Tuesday, April 29, 2025 3:13 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2N-337C (PTD 214-121) Suspect IAxOA Well Name: 2N-337 Facility: CPF2 PTD: 214-121 Well Type: Inj AA Number (if applicable): AIO 16.007 AMD Internal Waiver (Yes/No if applicable): Yes Type of Issue: Suspect Integrity Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): N/A Hi Chris, KRU 2N-337C (PTD 214-121) is a WAG injection well currently on produced water injection. The well has a waiver for TxIA on gas injection with WAG injection allowed. The well is exhibiting signs of possible IA to OA communication. CPAI intends to conduct diagnostics while the well is on water injection and possibly amend the waiver based on the results. The schematic, TIO plot, and bleed log are attached. Please let me know if you have questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2N-337C 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2N-337 2025-04-16 415 555 140 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,532.0 1/17/2017 2N-337C pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL BOMB HANGER W/DUAL GAUGES 3/15/2017 2N-337C pproven Casing Strings Casing Description PRODUCTION 5 1/2 " OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 28.0 Set Depth (ftKB) 7,029.8 Set Depth (TVD) … 5,054.2 Wt/Len (l… 15.50 Grade L-80 Top Thread Hyd 563 Casing Description LINER 3 1/2" - CEMENTED OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 6,819.4 Set Depth (ftKB) 7,653.0 Set Depth (TVD) … 5,536.6 Wt/Len (l… 9.20 Grade L-80 Top Thread 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,819.4 4,892.8 40.08 SLEEVE SETTING SLEEVE 4.130 6,840.4 4,908.9 40.06 PACKER ZXP PACKER 3.000 6,848.8 4,915.3 40.05 HANGER FLEX LOCK LINER HANGER 2.980 Tubing Strings Tubing Description TUBING WO - 2014 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.8 Set Depth (ft… 6,839.9 Set Depth (TVD) (… 4,908.5 Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.8 25.8 0.00 HANGER FMC HANGER - PORTED DRIFTED TO 2.91" 2.992 483.8 483.4 6.06 NIPPLE CAMCO DS NIPPLE 2.875 6,681.3 4,787.1 39.90 SLEEVE BAKER CMU DS SLIDING SLEEVE DS PROFILE - CLOSED 2.810 6,767.1 4,852.8 40.10 NIPPLE CAMCO D NIPPLE 2.750 6,820.6 4,893.7 40.08 SEAL ASY BAKER BULLET TIE BACK SEAL ASSEMBLY W/ 7' SPACE OUT 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,285.0 7,345.0 5,251.5 5,298.4 4/13/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES 7,345.0 7,390.0 5,298.4 5,333.3 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES, 60 DEG PHASING 7,435.0 7,455.0 5,368.1 5,383.5 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLEINNUM CHARGES, 60 DEG PHASING 7,455.0 7,475.0 5,383.5 5,398.8 4/11/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER, 11.1 GRAM MILLEINNUM DP CHARGES, 60 DEG PHASING 7,475.0 7,490.0 5,398.8 5,410.3 3/24/2015 6.0 IPERF 2.5" 11.1 GRAM MILLENIUM DP CHARGES Frac Summary Start Date 5/7/2007 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 5/7/2007 Top Depth (ftKB) 9,600.0 Btm (ftKB) 9,615.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,355.0 2,490.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 2 5,129.6 3,606.9 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 3 6,168.2 4,395.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 4 6,623.9 4,743.1 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/5/2015 Notes: General & Safety End Date Annotation 4/12/2019 NOTE: WAIVERED WELL - T x IA COMMUNICATION ON GAS ONLY. WATER ONLY INJECTION ALLOWED Comment SSSV: NIPPLE 2N-337C, 4/12/2019 2:28:05 PM Vertical schematic (actual) LINER 3 1/2" - CEMENTED; 6,819.4-7,653.0 IPERF; 7,475.0-7,490.0 IPERF; 7,455.0-7,475.0 IPERF; 7,435.0-7,455.0 IPERF; 7,345.0-7,390.0 IPERF; 7,285.0-7,345.0 3-1/2 Production liner; 6,825.0 ftKB PRODUCTION 5 1/2 "; 28.0- 7,029.8 SEAL ASY; 6,820.6 NIPPLE; 6,767.1 SLEEVE; 6,681.3 GAS LIFT; 6,623.9 GAS LIFT; 6,168.2 Intermediate Casing Cement; 5,200.0 ftKB GAS LIFT; 5,129.6 GAS LIFT; 3,355.0 SURFACE; 29.3-2,858.4 Cement Plug; 2,658.0 ftKB NIPPLE; 516.3 NIPPLE; 483.8 CONDUCTOR; 29.2-108.0 HANGER; 25.8 KUP INJ KB-Grd (ft) 29.25 Rig Release Date 3/14/2007 Annotation Last WO: End Date 2N-337C H2S (ppm) 30 Date 7/1/2008... TD Act Btm (ftKB) 7,547.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032026203 Wellbore Status INJ Max Angle & MD Incl (°) 69.65 MD (ftKB) 2,901.28 WELLNAME WELLBORE2N-337C MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-337C KUPARUK RIV U TARN 2N-337C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/14/2024 2N-337C 50-103-20262-03-00 214-121-0 G SPT 4894 2141210 3900 3425 3425 3425 3425 500 500 520 520 REQVAR P Josh Hunt 8/6/2024 2-Year MIT-IA required by AIO 16.007. Required test pressure to pass is the max anticipated injection pressure of 3900 psi 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:KUPARUK RIV U TARN 2N-337C Inspection Date: Tubing OA Packer Depth 930 4190 4000 3975IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240806164010 BBL Pumped:1.6 BBL Returned:1.5 Monday, October 14, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 9 9 9 9 2-Year MIT-IA AIO 16.007 James B. Regg Digitally signed by James B. Regg Date: 2024.10.14 16:19:29 -08'00' 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:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3; Well Integrity Specialist CPF2 Subject:2N-337C, WSW-06, 3Q-21 and 3N-16A 10-426 Forms from 8-17-24 Date:Sunday, August 18, 2024 11:51:50 AM Attachments:image001.png SCLD KRU 2N-337C 08-17-24.xlsx MIT KRU 3N-16A 08-17-24.xlsx MIT KRU 3Q-21 08-17-24.xlsx MIT KRU WSW-06 08-17-24.xlsx Please see the attached 10-426 form for the surface casing leak detect at 2N-337C and the witnessed MITIA’s at WSW-06, 3N-16A and 3Q-21 on 8-17-24. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com 0,75HSRUWLVWKHLQFRUUHFWIRUPIRUGRFXPHQWLQJD VXUIDFHFDVLQJOHDN GHWHFWWHVW-5HJJ .581& 37' surface casing leak detect at 2N-337C Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2141210 Type Inj N Tubing Type Test P Packer TVD 4894 BBL Pump IA Interval O Test psi 1200 BBL Return OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Surface casing leak detect per AIO 16.007. Witnessed waived by Adam Earl. SCLD passed per the 1000' fluid level criteria Notes: 2N-337C Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad Waived Casey / Weimer 08/17/24 Form 10-426 (Revised 01/2017)2024-0817_MIT_KRU_2N-337C_SCLD 9 9 9 9 9 9 2SHUDWRUDFFHSWDQFHFULWHULDIRU 6&/'-5HJJ MEU 2141210 Witnessed waived by Adam Earl. SCLD passed per the 1000' fluid level criteria 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Tuesday, August 30, 2022 11:12 AM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay Cc:Earhart, Will C Subject:Emailing: SCLD KRU 2N-306 8-28-22.xlsx, SCLD KRU 2L-310 08-25-22.xlsx, SCLD KRU 2L-305 08-26-22.xlsx, SCLD KRU 2L-319 08-27-22.xlsx, SCLD KRU 2N-337C 08-29-22.xlsx Attachments:SCLD KRU 2N-306 8-28-22.xlsx; SCLD KRU 2L-310 08-25-22.xlsx; SCLD KRU 2L-305 08-26-22.xlsx; SCLD KRU 2L-319 08-27-22.xlsx; SCLD KRU 2N-337C 08-29-22.xlsx 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. All Attached are the 10 426 forms for the SCLD that are required for each wells associated administrative approval. Due to the fact that the surface casing leak detects are performed with a gas media there are no "bbls pumped" nor "bbls returned". CPAI's surface casing leak detects have two passing criteria; pass according to the MIT OA criteria to 1200 psi or if the OA fluid level depresses below 1000' without maintain MIT criteria. The wells that passed with MIT criteria will have the numbers input into the "Pressures" boxes as a UIC compliance MIT would. If the OA fluid level depressed below 1000' without meeting the MIT criteria the notation of a passing test is placed in the "Notes" portion of the 10 426. Since this is the first submittal of these types of tests if there is additional information in which you believe to be beneficial or you would rather have these test reported in a different manner please feel free to reach out to discuss. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265 6218 Cell phone: (907) 830 9777 Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2141210 Type Inj N Tubing 3050 3050 3050 3050 Type Test P Packer TVD 4894 BBL Pump IA 83 165 165 165 Interval O Test psi 1200 BBL Return OA 1 1350 1340 1335 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad waived Caudle / Galle 08/29/22 Notes:Surface Casing Leak Detect per AIO 16.007 Witness waived by Lou Laubenstein Notes: 2N-337C Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mec han ical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0829_MIT_KRU_2N-337C_OA AIO 16.007 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: Kuparuk Tarn injector 2N-337C (PTD #214-121) 30 day monitor period. Date:Thursday, August 4, 2022 8:44:51 AM Attachments:image001.png AnnComm Surveillance TIO for 2N-337C.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, August 3, 2022 4:04 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: Kuparuk Tarn injector 2N-337C (PTD #214-121) 30 day monitor period. Chris- Kuparuk Tarn injector 2N-337C (PTD #214-121) has completed the 30 day monitor period. The IA has shown stabilization below the DNE of 2400 psi while on gas injection and has now met all of the criteria in which CPAI requires to continue WAG injection with known tubing by inner annulus communication. It is CPAI’s intention to submit an application for continued WAG injection with known tubing by inner annulus communication. While the AA is in process, the well will be left in gas injection service. Attached are the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: SLM 7,532.0 1/17/2017 2N-337C pprovenLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: PULL BOMB HANGER W/DUAL GAUGES 3/15/2017 2N-337C pprovenCasing StringsCasing DescriptionPRODUCTION 5 1/2 "OD (in)5 1/2 ID (in)4.95 Top (ftKB)28.0 Set Depth (ftKB)7,029.8 Set Depth (TVD) …5,054.2 Wt/Len (l…15.50 GradeL-80 Top ThreadHyd 563Casing DescriptionLINER 3 1/2" - CEMENTED OD (in)3 1/2 ID (in)2.99 Top (ftKB)6,819.4 Set Depth (ftKB)7,653.0 Set Depth (TVD) …5,536.6 Wt/Len (l…9.20 GradeL-80 Top Thread511Liner DetailsTop (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in)6,819.4 4,892.8 40.08 SLEEVE SETTING SLEEVE 4.130 6,840.4 4,908.9 40.06 PACKER ZXP PACKER 3.000 6,848.8 4,915.3 40.05 HANGER FLEX LOCK LINER HANGER 2.980 Tubing Strings Tubing Description TUBING WO - 2014 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.8 Set Depth (ft… 6,839.9 Set Depth (TVD) (… 4,908.5 Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.8 25.8 0.00 HANGER FMC HANGER - PORTED DRIFTED TO 2.91" 2.992 483.8 483.4 6.06 NIPPLE CAMCO DS NIPPLE 2.875 6,681.3 4,787.1 39.90 SLEEVE BAKER CMU DS SLIDING SLEEVE DS PROFILE - CLOSED 2.810 6,767.1 4,852.8 40.10 NIPPLE CAMCO D NIPPLE 2.750 6,820.6 4,893.7 40.08 SEAL ASY BAKER BULLET TIE BACK SEAL ASSEMBLY W/ 7' SPACE OUT 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,285.0 7,345.0 5,251.5 5,298.4 4/13/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES 7,345.0 7,390.0 5,298.4 5,333.3 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES, 60 DEG PHASING 7,435.0 7,455.0 5,368.1 5,383.5 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLEINNUM CHARGES, 60 DEG PHASING 7,455.0 7,475.0 5,383.5 5,398.8 4/11/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER, 11.1 GRAM MILLEINNUM DP CHARGES, 60 DEG PHASING 7,475.0 7,490.0 5,398.8 5,410.3 3/24/2015 6.0 IPERF 2.5" 11.1 GRAM MILLENIUM DP CHARGES Frac Summary Start Date 5/7/2007 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 5/7/2007 Top Depth (ftKB) 9,600.0 Btm (ftKB) 9,615.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,355.0 2,490.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 2 5,129.6 3,606.9 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 3 6,168.2 4,395.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 4 6,623.9 4,743.1 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/5/2015 Notes: General & Safety End Date Annotation 4/12/2019 NOTE: WAIVERED WELL - T x IA COMMUNICATION ON GAS ONLY. WATER ONLY INJECTION ALLOWED CommentSSSV: NIPPLE2N-337C, 4/12/2019 2:28:05 PMVertical schematic (actual) LINER 3 1/2" - CEMENTED; 6,819.4-7,653.0 IPERF; 7,475.0-7,490.0 IPERF; 7,455.0-7,475.0 IPERF; 7,435.0-7,455.0 IPERF; 7,345.0-7,390.0 IPERF; 7,285.0-7,345.0 3-1/2 Production liner; 6,825.0 ftKB PRODUCTION 5 1/2 "; 28.0- 7,029.8 SEAL ASY; 6,820.6 NIPPLE; 6,767.1 SLEEVE; 6,681.3 GAS LIFT; 6,623.9 GAS LIFT; 6,168.2 Intermediate Casing Cement; 5,200.0 ftKB GAS LIFT; 5,129.6 GAS LIFT; 3,355.0 SURFACE; 29.3-2,858.4 Cement Plug; 2,658.0 ftKB NIPPLE; 516.3 NIPPLE; 483.8 CONDUCTOR; 29.2-108.0 HANGER; 25.8 KUP INJ KB-Grd (ft)29.25 Rig Release Date3/14/2007AnnotationLast WO:End Date 2N-337CH2S (ppm)30 Date7/1/2008...TDAct Btm (ftKB)7,547.0Well AttributesField NameTARN PARTICIPATING AREA Wellbore API/UWI501032026203 Wellbore StatusINJ Max Angle & MDIncl (°)69.65 MD (ftKB)2,901.28WELLNAME WELLBORE2N-337C 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: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214- 121) 30 day monitor period for diagnostic testing. Date:Wednesday, August 3, 2022 11:10:18 AM Attachments:image001.png AnnComm Surveillance TIO for 2N-306.pdf AnnComm Surveillance TIO for 2L-319.pdf AnnComm Surveillance TIO for 2L-305.pdf AnnComm Surveillance TIO for 2N-337C.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, May 27, 2022 7:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) 30 day monitor period for diagnostic testing. Chris- CPAI has identified four Tarn injectors 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) that were previously waivered for water injection only due to known TxIA while on gas injection. During a recent reservoir evaluation, these 4 wells were identified to have a significant production benefit from the ability to inject MI. CPAI has developed criteria under which it believes a gas injection well may operate safely with TxIA communication. That criterion includes the well having casing rated high enough to support maximum anticipated injection pressure of gas injection should a barrier fail, passing a MITIA to maximum anticipated injection pressure of gas injection, passing a MITOA or SCLD, and passing an IA DDT on water or gas injection and during gas injection service the IA pressure must sustain below the “do not exceed” of 2400 psi. These wells meet the above criteria and CPAI has conducted diagnostic MIT-IAs and SCLDs all with passing results. The remaining criteria yet to be met is the ability to maintain IA pressure under DNE of 2400 psi while on gas injection. Therefore, CPAI intends to place 2L-305, 2L-319, 2N- 306 & 2N-337C into gas injection service for a 30 day monitor period. If the 30 day monitor period displays the ability of the IAs to sustain a pressure below the DNE, CPAI intends to apply for administrative approval for continued WAG injection with known TxIA communication while on gas injection. Attached are the current 90 day TIO plots and wellbore schematics. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: SLM 7,532.0 1/17/2017 2N-337C pprovenLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: PULL BOMB HANGER W/DUAL GAUGES 3/15/2017 2N-337C pprovenCasing StringsCasing DescriptionPRODUCTION 5 1/2 "OD (in)5 1/2 ID (in)4.95 Top (ftKB)28.0 Set Depth (ftKB)7,029.8 Set Depth (TVD) …5,054.2 Wt/Len (l…15.50 GradeL-80 Top ThreadHyd 563Casing DescriptionLINER 3 1/2" - CEMENTED OD (in)3 1/2 ID (in)2.99 Top (ftKB)6,819.4 Set Depth (ftKB)7,653.0 Set Depth (TVD) …5,536.6 Wt/Len (l…9.20 GradeL-80 Top Thread511Liner DetailsTop (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in)6,819.4 4,892.8 40.08 SLEEVE SETTING SLEEVE 4.130 6,840.4 4,908.9 40.06 PACKER ZXP PACKER 3.000 6,848.8 4,915.3 40.05 HANGER FLEX LOCK LINER HANGER 2.980 Tubing Strings Tubing Description TUBING WO - 2014 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 25.8 Set Depth (ft… 6,839.9 Set Depth (TVD) (… 4,908.5 Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.8 25.8 0.00 HANGER FMC HANGER - PORTED DRIFTED TO 2.91" 2.992 483.8 483.4 6.06 NIPPLE CAMCO DS NIPPLE 2.875 6,681.3 4,787.1 39.90 SLEEVE BAKER CMU DS SLIDING SLEEVE DS PROFILE - CLOSED 2.810 6,767.1 4,852.8 40.10 NIPPLE CAMCO D NIPPLE 2.750 6,820.6 4,893.7 40.08 SEAL ASY BAKER BULLET TIE BACK SEAL ASSEMBLY W/ 7' SPACE OUT 2.900 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,285.0 7,345.0 5,251.5 5,298.4 4/13/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES 7,345.0 7,390.0 5,298.4 5,333.3 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLENNIUM CHARGES, 60 DEG PHASING 7,435.0 7,455.0 5,368.1 5,383.5 4/12/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 11.1 GRAM MILLEINNUM CHARGES, 60 DEG PHASING 7,455.0 7,475.0 5,383.5 5,398.8 4/11/2015 6.0 IPERF 2.5" HOLLOW STEEL CARRIER, 11.1 GRAM MILLEINNUM DP CHARGES, 60 DEG PHASING 7,475.0 7,490.0 5,398.8 5,410.3 3/24/2015 6.0 IPERF 2.5" 11.1 GRAM MILLENIUM DP CHARGES Frac Summary Start Date 5/7/2007 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 5/7/2007 Top Depth (ftKB) 9,600.0 Btm (ftKB) 9,615.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,355.0 2,490.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 2 5,129.6 3,606.9 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 3 6,168.2 4,395.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 4 6,623.9 4,743.1 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/5/2015 Notes: General & Safety End Date Annotation 4/12/2019 NOTE: WAIVERED WELL - T x IA COMMUNICATION ON GAS ONLY. WATER ONLY INJECTION ALLOWED CommentSSSV: NIPPLE2N-337C, 4/12/2019 2:28:05 PMVertical schematic (actual) LINER 3 1/2" - CEMENTED; 6,819.4-7,653.0 IPERF; 7,475.0-7,490.0 IPERF; 7,455.0-7,475.0 IPERF; 7,435.0-7,455.0 IPERF; 7,345.0-7,390.0 IPERF; 7,285.0-7,345.0 3-1/2 Production liner; 6,825.0 ftKB PRODUCTION 5 1/2 "; 28.0- 7,029.8 SEAL ASY; 6,820.6 NIPPLE; 6,767.1 SLEEVE; 6,681.3 GAS LIFT; 6,623.9 GAS LIFT; 6,168.2 Intermediate Casing Cement; 5,200.0 ftKB GAS LIFT; 5,129.6 GAS LIFT; 3,355.0 SURFACE; 29.3-2,858.4 Cement Plug; 2,658.0 ftKB NIPPLE; 516.3 NIPPLE; 483.8 CONDUCTOR; 29.2-108.0 HANGER; 25.8 KUP INJ KB-Grd (ft)29.25 Rig Release Date3/14/2007AnnotationLast WO:End Date 2N-337CH2S (ppm)30 Date7/1/2008...TDAct Btm (ftKB)7,547.0Well AttributesField NameTARN PARTICIPATING AREA Wellbore API/UWI501032026203 Wellbore StatusINJ Max Angle & MDIncl (°)69.65 MD (ftKB)2,901.28WELLNAME WELLBORE2N-337C MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-337C KUPARUK RIV U TARN 2N-337C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-337C 50-103-20262-03-00 214-121-0 G SPT 4894 2141210 3900 3390 3390 3390 3390 300 400 400 390 REQVAR P Adam Earl 8/1/2022 MIT-IA tested as per AIO 16.007 to max ant. inj.psi. amended waiver in process test to 4200psi 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:KUPARUK RIV U TARN 2N-337C Inspection Date: Tubing OA Packer Depth 100 4170 3980 3950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803202508 BBL Pumped:2.1 BBL Returned:2 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 AIO 16.007 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:31:40 -08'00' MEMORANDUM Packer Depth Pretest State of Alaska Type Inj W, Alaska Oil and Gas Conservation Commission CO: Jim R�� C��7a��t2ti DATE: Wednesday, August 12, 2020 P.I. Supervisor Test psi 3000 - SUBJECT: Mechanical Integrity Tests 450 BBL Pumped: ConocoPhil lips Alaska, Inc. OA 300 2N -337C FROM: Lou Laubensteln KUPARUK RIV U TARN 2N -337C Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 35 NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N -337C API Well Number 50-103-20262-03-00 Inspector Name: Lou Laubenstein Permit Number: 214-121-0 Inspection Date: 8/3/2020 Insp Num: miti-OL200804123957 Rel Insp Num: Initial 15 Min 30 Min 45 Min 60 Min 1800 1800 1800 3280 3130 3100 325 325 - 325 ' Wednesday, August 12, 2020 Page I of I Packer Depth Pretest Well 2N -337C Type Inj W, TVD 4894 . Tubing. 1800 PTD 21412210 Type Test SPT" Test psi 3000 - IA 450 BBL Pumped: 1.5 BBL Returned: 2 OA 300 Interval REQVAR P/F P Notes: MIT -IA to Maximum anticipated injection pressure per AIO 16.007 Initial 15 Min 30 Min 45 Min 60 Min 1800 1800 1800 3280 3130 3100 325 325 - 325 ' Wednesday, August 12, 2020 Page I of I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, January 31, 2019 10:08 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: 2N -337C (PTD 214-121-0) Suspect IA Pressure Behavior Attachments: 2N -337C 90 -day TIO Plot 1-31-19JPG Chris, Injector 2N -337C (PTD 214-121-0) has shown suspect IA pressurization during MI injection. Operations bled the IA pressure significantly soon after the pressure increase was noted. CPAI intends to obtain initial diagnostics including a MITIA, and observe the well behavior on MI injection during a 30 -day monitor. IfTxIA during MI injection is confirmed, CPAI will WAG to well to water as soon as operationally possible to commence a 30 -day water injection monitor period. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz (covering for Jon Byrne) Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,August 24,2015 Jim Regg _ P.I.Supervisor 1-- el' qi3�15 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-337C FROM: Lou Grimaldi KUPARUK RIV U TARN 2N-337C Petroleum Inspector �r��E® \ 1— t '-' u ' �s Src: Inspector Reviewed By: P.I.Supry Jgg--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-337C API Well Number 50-103-20262-03-00 Inspector Name: Lou Grimaldi Permit Number: 214-121-0 Inspection Date: 8/18/2015 Insp Num: mitLG150818173028 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-337C Type Inj SPT TVD 4894 1 Tubing' 3110 - 3110 , 3110 - 3110 - 938 1900 " 1NITAL � P---� --- 300 ' ---400 - 1825 1810 ' PTD Type Test Test psi IA Interval P/F OA400 - 400 Notes: Fluid verified"to surface". .8 bbl's diesel Pumped,.4 bbl's returned.Very good test,good procedures followed.All required documentations., supplied prior to test. A'"/� //4C&Li\et-it - ( 1---__T-0 -Pre>s CCNec P(61- L & LZet( Scr..Ae 'c Monday,August 24,2015 Page 1 of 1 • • • dwejje oy9 Ir o In 0 0 a N t d) . 1 I 1 I . 1. d l i. .1. 11. .1 . I I 1. 1 . 1. 11 . I .1. A , .1 . ':-..L. , • • • • . 1 N : _ (NI . • • :.. It ' ,,,1 . . . . . co 1 , • • . • . .... .. Lo, Y -i-Li + 4'4 I' 14 1'1 I 'I t' 1 i '+ ! 1 `I 1 1 I i`i p ,� 1'4 C 0a_ 0 0 0 0 00 oLl� 0 i < OC N N LO 0 0 0 1 1Sd 410 • }~--„, KUP INJ 2N-337C ConocoPhillips 8 \I Weil Attributes IMax Angie 8 MD TD Aiaska.lir. f M , N Name Ti,04 ,,,,s.. ' Il k81 r 140(RrolSIn 81109 Qe4Kd /T,u 501032026203 I EARN PART'�CIPATING AREA ILL 19 t.,.I 2,801.28E 7,029.8 +, 11123own} RI. ffMadatton End Data 191.6r4 00 Rip Roteasa Cala 2143370 6'42.14.11913/PM i SSSV:NIPPLE I '!CI 7/1f2006 'Lit:IWO: 29.25 3/1412007 .-.-- - Annotationr„p" � pot r 0r1n Annotationl.ad Med By r In it Last Tag:5LM 17,6050 18272615 Rev Reason:TAG -. I .-n.' l +:•L: Casing SUMgi .:t:.4.P LMsa4l en '6011.1 IDR'; -Tea til Sot Depth l^60) 5s Daplh(117p_.I WIAen I1..Chia :'sp't}. CONDUCTOR Ii 15062 2:17 108.0 1h1. P 1'40 _ WELDED c.11,,nri DewHton '.DIN Ill 1.4 Top 11148) set Depih{1LkB) Sol Depth(P/DI..I WIA.s p Grad. Top Thread ,SURFACE /.,t 6.815 21; 2,858.4 2.311 3 C I P BIC-MOD S:aoo,p DssakIPii60(i+S-.•101•.. Tap In1S8) 'Sot D.pth 11168) Sot Depth(1w}._VAL.11 Cade toplhrend PRODUCTION 512' 5 1,7 4.659 )1:.:1 7.02CS 5.054 2 Is!-..f..1.7 C. Hyd 563 P.PalnoD oiPnnn OD 0.0 10414 Top tfi(a) 'Set Depth 0168) BM Depth(DWI...I('.6L..1f 1,>e. Top Thread LINER 312'- 3172 2.097 6.619.4 _.!3 6.5366 14.0 511 CEMENTED LTMrDetea ltom!nal ID I Tap 89919 TPPITVal0.46i toPin,IL-1 11at0Ps r.,., I'S 6,8194 4,8928 4905 Si it Vi. SETT INC DELVE 4.130' TINNIER,25.13'- ..-k 6,840.4" 4,9089 44106 PACKER 2XP PACKER 3.vol -±' 11 .E'Bb9B�.-.�-4,9153 43o;HAN;:Lf: FLEX LOCK LINER RANGER 2.9;0 1 TabIng Si-rings . ,ii1 f� .WrT,jMn 0 ooI SonL.•l'4 No ID pry Top 1 I s.1 D.pth 111..1600 Lr¢/Ir 11445 4.r.1rut. Gude Yep tennsiion , TUBING WO-20I4 3 3,7 2992 25.+. 6'839'9L -1 905 9 7311--90 EL1E 8M ' Completion Detetle ' NPmlo.110 I Tap MKS) lap 1/1t11(mei Trp It.II'I Thal Des Cath _ phi, I 25R Otc H,ttJ�t'11 FMC HANGER-PoIt)DRIFTEO,'U 0E- --2�t$ 4638 4894 608 NSa7+(E. ZAI.4 OSS NIPPLE2976 ,�,."WRDdLRDR,139133960 I 25.5-6,681.3 A,7B7.1 :T35G E1,6t E DAMP CMU DSSLb ifERffbs PROFILE- -2,310 CLOSED '€R{y;1671 4,862 B 40 10 NIPPLE '0AMCO O NIPPLE 2.750 MIME,4336 ..1 0.0 -Mt./ --'OCR SEAL ASV BAKER BI6 LET 7 t BACK SEAL ASSEIAB�Y N4 T RTr SPACE OUT Perforations&Slots Shoo I Dena Top(TS 531.47V0) (shotsif T04 59161 RIM(nxe) R1P 91 tnKup_ Lana Galt Il Tlc' rn„ 7,285.0 --7,345.0 I '6'I.S 5't n4'4 - '''- '---4(113174115 60 IPER1 25'HOLLOWSTEEL CARRIER SCALLOPED GUNS,11.1 GRAM MILLENNIUM SURFACE-2S3-2X84 4 4. CHARGES • ..__1_ ,-.1_. 7,390 0 5,298.( 5,333.3 :t?o015 TS OLAF 2-5'I40LL0WST1I (MUST,3,3550- I ' CARRIER SCALLOPED DUNS,11.1 GRAM MILLENNIUM CHARGES,60 DEG GAS LIFT,MOSS----- PHASING y I 7,4350 7,455.0 5.388.1 '5,383.5- 4'127015 60 WERE '1.5'HOLLOW S1ELL -- CARRIER SCALLOPED GUNS,11.1 GRAM 646urT.6116R / MILLENNUM _.i I I. CHARGES,60 DEG PHASING GA25'HOLLry5 Stir I gU17,q.� 7 . 7;0,50 7?;C 53.6 1,199.8 411118015 �b1FERF . CARRMLLEIN ,11.1 GRAM ML.LEER,11NUM DP CHARGES,80 DEG PHASING 61 FELE 4.Rt813- - ` 7,4760 7,490.0 5YA 6 5.4103 112412015 CO IPERc 2.6.11.1 GRAM "m- MLLEMUM OP CHARGES NP➢1$61671 .. ' Mandrel Inserts .7 .9 I T.p(vvI0 Type to%h PP+18(. 140 Whit N Tep MM.__ {NKS/ NMca Nwa+ Or,1Pot kir Type. N lS 1Pq qu.DMP Cwt, { 3.355 24905 GAI8 O KBG-2- I GASH!1 DMV A- .00+3 60 T2,2 28./14 tl 5'138.614159296 •• tin8 1,64169 C.ANCO KRG-2- 1 ZilSLLFT TRAY li' (IT 1 Ole 29572014 q..Iiip' 6,168.2 4.3968 CAIdCA KRG2- 114160 LIFT UMY "W 0000 00 1275,2014 - 4 6.623.0 4.7431 CMy(X) TBG-2- I-ASllFT DMT III ` e� 13'd7PJ20t5 I ' End Date AnnMYgn NOTE. P000=11011 4112-,260 '' - 7.0218 , WE111.7,295D7.3R0 , IPSO.7,3450739.0----- . 1PERF;7,43507..4550 4PENF;7455.0.7475a • IPERS.74760-7,4610 1144Eft31'-CEMENTED. .. --. a 66194-7,fb30- 21 41 21 410 25817 WELL LOG TRANSMITTAL DATA LOGGED 6/Zi2ot5 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 6, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 f„; r,.1'\. 1 r RE: Bottom Hole Pressure Survey& Perforating Records: 2N-337C OG 1C Run Date: 3/24, 4/11 &4/14/15 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-337C Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20262-03 Bottom Hole Pressure Survey Log 1 Color Log 50-103-20262-03 SCANNED JON 1 2 2D15 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: •. 2.1 2.5113 2.5-11 3 WELL LOG TRANSMITTAL DATA LOGGED ; K �'A .BEND To: Alaska Oil and Gas Conservation Comm. April 2, 2015 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAY 0 j ?x1.5 .AOG RE: Perforating Record: 2N-337C Run Date: 3/24/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-337C Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20262-03 SCANNED May 2 72015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,la � , /` , ./ /7T7Q Z 1 Loepp, Victoria T (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday,April 24, 2015 1:20 PM To: Loepp,Victoria T(DOA) Cc: CPF2 Prod Engrs Subject: RE:2N-337C (PTD 214-121-0) Follow Up Flag: Follow up Flag Status: Flagged No the well has not been nor will it be pre-produced. Thanks for the info. I always like to double check on these things. Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist NNEDMA v 2015 Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, April 24, 2015 11:28 AM To: NSK Prod Engr Specialist Subject: [EXTERNAL]RE: 2N-337C(PTD 214-121-0) Darrell, Was the well pre-produced? Since the well was approved as an injector, it can be put on injection without a 10-403. Please note that a state witnessed MIT-IA is required after stabilized injection. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria.Loeppa.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: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Friday, April 24, 2015 10:58 AM 1 To: Loepp, Victoria T(DOA) Subject: FW: 2N-337C (PTD 214-121-0) Any decision on this well yet? Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) From: NSK Prod Engr Specialist Sent:Tuesday, April 21, 2015 3:33 PM To: Loepp Victoria (victoria.loepp@alaska.gov) Subject: 2N-337C(PTD 214-121-0) Victoria one more for you: 2N-337C—This well had a 10-403 filed and approved for perforating on 1/26/15.The well class was listed as Service and the well status was listed as WAG after the proposed work. The perforation work was just completed this month and the required 10-404 will be enroute to AOGCC soon. My question is do I need to file any additional sundries to bring this well on Injection? I'm trying to be cautious here and make sure we have all the proper paper work done before bringing the well on. Thanks Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) 2 STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COR SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed. Abandon r Repair w ell r Plug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 214-121-0 3.Address: 6.API Number: Stratigraphic r Service p P. O. Box 100360,Anchorage,Alaska 99510 50-103-20262-03 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 375074 KRU 2N-337C 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CBL Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 7667 feet Plugs(measured) none true vertical 5548 feet Junk(measured) none Effective Depth measured 7624 feet Packer(measured) 6840 true vertical 5513 feet (true vertical) 4909 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2830' 7.625" 2858' 2313 Intermediate 7002' 5.5" 7030' 5054' Production 834' 3.5" 7658' 5540' RECEIVED ns. ti Perforation depth: Measured depth: 7285-7390, 7435-7490 N�Emg APR 2 3 2015 True Vertical Depth: 5252-5333, 5368-5410 S-- AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80,6840 MD,4909 ND Packers&SSSV(type,MD,and ND) PACKER-ZXP PACKER @ 6840 MD and 4909 TVD NIPPLE-CAMCO DS NIPPLE @ 484 MD and 483 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service F Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XX GSTOR r VVINJ r WAG P GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 315-041 Contact Jay Maguire 263-4551 Email Jay.C.Maquireconocophillips.com Printed Name Jay Maguire Title Wells Engineer Signature li,/ Phone:263-4551 Date Y/1.2//S VTL- '/14/l5- RBDMS<V APR 2 8 2015 •I-4 f v,,------ Form 10-404 Revised 10/2012 Submit Original Only KUP INJ 2N-337C ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(SOB) Act Btm(ftKB) c mrcr;A„ll,ps 501032026203 TARN PARTICIPATING AREA INJ 69.65 2,901.28 7,029.8 • --- Comment H2S(ppm) Date - ' Annotation End Date KB-Grd(ft) -Rig Release Date 2N-337C,4/16/20159:2810 AM SSSV:NIPPLE 30 7/1/2008 Last WO: 29.25 3/14/2007 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation -Last Mod By End Date Last Tag:RKB 6,624.0 3/21/2015 Rev Reason:TAG,PERFS hipshkf 4/16/2015 Casing Strings Casing Description OD(in) ID(in) "Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 292 108.0 108.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 29.3 2,858.4 2,311.3 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 51/2" 51/2 4.950 28.0 7,029.8 5,054.2 15.50 L-80 Hyd 563 Casing Description OD(in) ID(in) Top)ftKB) Set Depth(RKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread LINER 31/2"- 31/2 2.992 6,819.4 7,653.0 5,536.6 9.20 L-80 511 CEMENTED Liner Details Nominal ID Top(ftKB) Top)TVD)(ftKB) Top Incl(-) Item Des Corn (In) 6,819.4 4,892.8 40.08 SLEEVE SETTING SLEEVE 4.130 HANGER;25.8-1 l-40-1, 6,840.4 4,908.9 40.06 PACKER ZXP PACKER 3.000 6,848.8 4,915.3 40.05 HANGER FLEX LOCK LINER HANGER 2.980 L._ I Tubing Strings la1FaY�r�r .W1 - ,ay Tubing Description String Ma...ID(in) Top(ftKB) Set Depth)ft„Set Depth(ND)(.5 Wt(IhM9 Grade Top Connection TUBING WO-2014 31/2 2.992 25.8 6,839.9 4,908.5 9.20 L-80 EUE Srd Completion Details _ Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl(') Item Des Com (in) 25.8 25.8 0.00 HANGER FMC HANGER-PORTED DRIFTED TO 2.91" 2.992 483.8 483.4 6.06 NIPPLE CAMCO DS NIPPLE 2.875 -,a,_ *CONDUCTOR_29}-106.0.y , w � 6,681.3 4,787.1 39.90 SLEEVE BAKER CMU DS SLIDING SLEEVE DS PROFILE- 2.810 CLOSED 6,767.1 4,852.8 40.10 NIPPLE CAMCO D NIPPLE 2.705 NIPPLE;163.8 In 6,820.6 4,893.7 40.08 SEAL ASY BAKER BULLET TIE BACK SEAL ASSEMBLY W/7' 2.900 SPACE OUT Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotstt Top(ftKB) Btm(ftKB) )ftKB) (ftKB) Zone Date t) Type Com 7 285.0 7,345.0 5,251.5 5,298.4 4/13/2015 6.0 (PERF 2.5"HOLLOW STEEL ( CARRIER SCALLOPED GUNS,11.1 GRAM MILLENNIUM SURFACE;29.3-25504-s L. CHARGES I- t - 7345 0 7.390 0 5.298.4 5.333.3 4/12/2015 6.0 IPERF 2.5"HOLLOW STEEL GAS LIFT;3,355.0 ` ECARRIER SCALLOPED GUNS,11.1 GRAM MILLENNIUM CHARGES,60 DEG PHASING GAS LIFT;5,129.6 /,1' 0 7,455.0 5.368.1 5,383.5 4/12/2015 6.0 IPERF 2.5"HOLLOW STEEL CARRIER SCALLOPED GUNS,11.1 GRAM GAS LIFT.,6168 z .. MILLEINNUM CHARGES,60 DEG e PHASING 7,455.0 7,475.0 5,383.5 5,398.8 I I I;',I'. 6.0 (PERF 2.5"HOLLOW STEEL GAS LIFT.6.623 9 CARRIER,11.1 GRAM MILLEINNUM DP CHARGES,60 DEG PHASING SLEEVE;6,681.3 .m; 2.5'11.1 GRAM 7,475.0 7,490.0 5,398.8 5,410.3 3/24/2015 6.0 IPERF F MILLENIUM DP CHARGES ) ` Mandrel Inserts NIPPLE;6,767.1 St eti on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 3,355.0 2,490.6 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 9 • SEAL ASY,6,820.6 2 5,129.6 3,606.9 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 9 • 3 6,168.2 4,395.6 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 • • 9 4 6,623.9 4,743.1 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 3/5/2015 9 i Notes:General&Safety 'II'c End Date Annotation :I: .. NOTE. PRODUCTION 5 1/2";28.0- rlS.'. '. 7,029.8 IPERF;7,285.0-7,345.0 (PERF;7,345.0-7,390.0 • (PERF;7,435.07,455.0 ' S IPERF;7,0.55.07,175.0 IPERF;7,475.0-7.490.0 • C • LINER 31/7-CEMENTED; 3 6.819.4-7,653.0- 2N-337C WELL WORK SUMMARY DATE SUMMARY 3/5/2015 DRIFT TBG W/2.65"CENT& 1.75"SAMPLE BAILER(TAG DRILLING MUD @ 6849' SLM); SET CAT SV @ 6767' RKB; PULL SOV&SET DV @ 6624' RKB; MIT TBG TO 3000#, MIT IA TO 2500#, (BOTH PASS); PULL CAT SV @ 6767' RKB; DRIFT TBG W/2.5" DD. BAILER&TAG DRILLING MUD @ 6849' SLM (OBTAINED SAMPLE ). READY FOR CTU (FCO) ((SEE ATTACHMENTS FOR MIT FORM)) 3/7/2015 PERFORMED FILL CLEANOUT FROM DRY TAG AT 6845'CTMD TO HARD TAG AT 7590'CTMD USING A 2.86" UNDERREAMER, PUMPING SLICK DIESEL WITH DIESEL GEL SWEEPS AT 1.4 BPM, MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT, APPEARED TO BE HARD CEMENT FROM 7560'-7590'CTMD, MODERATE CEMENT/SAND CONCENTRATIONS OBSERVED, F/P TBG FROM TD, READY FOR S/L DRIFT, JOB IN PROGRESS. 3/8/2015 RIH WITH RCBL, ENCOUNTER OBSTRUCTION AROUND 6680'AND 6730', ABLE TO GET PAST AFTER A FEW ATTEMPTS. CORRELATE TO SPECTRAL DENSITY LOG DATED 21 DEC 2014. TAG AT 7587'. LOG REPEAT PASS FROM 7587'TO 7325'. LOG MAIN PASS FROM 7587'TO 6250'. GOOD BOND OBSERVED FROM 7587'TO LINER AT 6819'. 3/9/2015 ATTEMPTED TO RIH WITH FIRST PERFORATING GUN. ENCOUNTERED OBSTRUCTION AT 6230'.AFTER POOH, FOUND A PIECE OF METAL IN ONE OF THE GUN SUBS. INSTRUCTED TO RIG DOWN, ALLOW SLICK LINE TO DRIFT. 3/21/2015 TAGGED @ 7533' SLM, EST. 7540' RKB. DRIFTED TBG WITH 2.5" DUMMY GUN TO 7533' SLM WITHOUT ISSUE. READY FOR E/L. 3/24/2015 PERFORATE FROM 7475'TO 7490'WITH 2.5", 11.1 GRAM MILLENIUM DEEP PENETRATING CHARGES. CORRELATED TO HES OPEN HOLE LOG. JOB IN PROGRESS. 4/11/2015 PERFORATED FROM 7455'TO 7475' USING 2.5" HOLLOW STEEL CARRIER 11.1 GRAM MILLENIUM DEEP PENETRATING CHARGES, 6 SPF AND 60 DEGREE PHASING. RIG DOWN IN PLACE. CONTINUE PERFORATING TOMORROW. 4/12/2015 PERFORATED ZONES 7435-7455, 7370-7390, 7370-7345 WITH 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS, 6 SHOTS PER FOOT, 60 DEGREE PHASING, 11.1 GRAM MILLENNIUM CHARGES. 4/13/2015 PERFORATED ZONES 7325-7345, 7305-7325,AND 7285-7305 USING 2.5" HOLLOW STEEL CARRIER SCALLOPED GUNS WITH 11.1 GRAM MILLENNIUM CHARGES 4/14/2015 PERFORMED STATIC BOTTOM HOLE PRESSURE SURVEY AT STATIONS: 7415, 7284, AND 7158. - l�1 Z55tZ WELL LOG TRANSMITTAL DATA LOGGED 3 iBEND2oi M K R To: Alaska Oil and Gas Conservation Comm. March 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 2 4 2015 RE: Radial Cement Bond Log: 2N-337C Run Date: 3/8/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-337C Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20262-03 Radial Cement Bond Log 1 Color Log 50-103-20262-03 SCANNED 1 12©15 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAg-42'0410<-4) zt.24-12-k Q.52-12_,9 ConocoPhillips RECEIVED TRANSMITTAL FEB 182015 CONFIDENTIAL DATA AOGCC FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7t'Ave., suite 100 DATA LOGGED Anchorage AK 99510-0360 Anchorage,Alaska 99501 L Act 1201S M.K.BENDER RE: 2N-337C DATE: 02/17/2015 Transmitted: Kuparuk River Unit, Alaska ll 2N-337C 1 CD and 1 hardcopy report [ Halliburton-Surface data logging and End of well report- mud logging data for 2N-337C; 12/30/2014; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD SCANNED II , FEB 2 5 2015 1Please promptly sign, scan and return electronically to Sandra.D.Lemke(cCOP.com CC: 2N-337C transmittal folder, production well files, eSearch - 4/.) Receip / i O4ate: %iw GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 9072656947 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ai 14- - IA )_ Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: olor Items: ❑ Maps: ‘scale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: (Maria ) Date: ca /v /T /s/ NP Project Proofing! BY: 110110 Date: 40 /s /s/ Scanning Preparation 3 x 30 . 90 + 13 =TOTAL PAGES /O'3 IV /51)1(Count does not incude cover sheet)BY: Martia Date: Production Scanning Stage 1 Page Count from Scanned File: / of 1-t- (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO BY: eft Date:D l4 CV I£ /s/ 01 ID Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o 0 CO N 9 U . v a Na) o >- R\ N N wZZZZZZZZ • U Z e N pvm N .nio c r T }I Q_ m U) U) U) UUU) UU) Cl) -p a) .zaN c T o i= a � � � � � � � ir, U I I I I I I I I n U a. u) 00>` Q0 0 0 0 0 0 0 0 0 o a) a) N J N. r h N- h N- n h N NV NV 'N 'N s Z Z I co co co co W co co co coLL co Q (o ay a7 a) i-, ad C? MLL M M M M LL M M C7 W Z Z Z Z Q N N �,I N Na. Nom. Na N '" Nd N•� Na N '• r N. N. r N. C as W V 1 I I I2 Ig I I2 Ig M co M M co Z2 a) a a a� a � a�I aWI aW aw aWI aWI z z z z z Q 112 o « �� 0 U 0l U 0 0 j kn o o I o M U' o U I fl c� 9 • • Q 0) Q (RJ� 1 vi co N • • ' J E J O N } y 0) a O. co . VI r- >- } } o co U CO O G) a) r CO co OD ' co 0 CO CO d i. I- D O CO O O (0 PPE) N 0 N Co co >f. cl:U 2 d 0 Z z Z Z- N W Z N CO <d v7 CO co co co > > tY N0 J Q' C7) C 0 oo co 00 a0 Q N W > a < Z c�6 fv0 f�0 7 7 ~ E 0 = �' ~ C. �' to Z Z Z Z Co Co 0 0)N m H!G 0 V d o F ry . Ili 0) w'-. > m UI UI d) > co M Coco CO M co. 0 Y l.L fh M•E1 Y O o co — ZZZZ Z Z Z Z a ) O 0 Z Z 7 = 0 0 J 0N U N N 0 rt V ai -6 ui ai -6ai 12 co_1 G) W 0 d u) Z LL LL LL LL LL LL 0 D a, LL LL 0 .... ((� Q — u) cv U U cv o YOB UE v .2N Yocc Cl) \t�j/1 N Lu m Ilo 0 0 0 0 0 N0 2c I o 2 N0 EE >- c) >- I— J N N ) N N N �< N N N Q R W U co Ce Q m= W W W LU LU LU N I W M W W O N I 0) a) O ' 0 LL d in cn cn in cn to d m m aw .0 CL U o 0 0 0 0 0 0 0 0 ENE _6) p W N N N N N N N N N {0 7 0 I co co co co co co in )n an U) Z in a) r r r a) O) 0 it E o Z 4- 4- 1 'O a) co W z m Co a O j > E E Z o `� Cd O) Co Co CoQco V N O co(D O J a C c o E J 0. 7 O. 0 L7 c 2 0 0 a) C o o co o N c r o c0 O C--11 n I E t MV N n U 0 o J M E N Q z O O 0. 'C U I— Z v o E p y O N 10 co11,3 0 C r /2 a) W Cal N Cl) E a' 5 o I— E • � 7 D a) cot C "cm— N CO cc co o N U a) c co Q c c 0 Q` 0. c o COU D r N_ . 0QQen OZ O I N y NQ 0 c C o 2 E 0 cli co z co u) CO CO co co CO CO 'ci-, co CO CO m v o co co co co m m -o CO m i0 v 1� x 0 0 0 0 0 0 aa7 0 0 0 CO c �'\ N LO co CO co co CO CO I CO CO CO I 0 'f ca } IC) N _m _5 .5 .5 .- .5 O) .a O_) a_ O) •la C O D D D D O J O D O J I £ G D N > o 0 0 O 0 co O 00 W 00 W w W O CV F m o o n m o o o m m m cet N N N N W E Co O r N N N N N N N 1* in (N in to in to (N (N N (N )f) N N N N N N N N N N N N Co W 0 0 N E E Z a N m I ai E IN co O ce m 1 V 0 ai c 1 ,0 Z N 0 0 0 0 0 U U 0 0 00 G .N .0 J .N N •�• U C) a o o a a co o 0 o E o E a) cfc a .e w w 0W UW w W ° 0 w w _ 3 i 0 a` 0 0 o O 1 II , O Co" el N O N N 1 O co N N No >- z o 0 o) oco cIIww o V, c, O .4 4Z H Q z 0 C) Z 1 1o os co Ce Q N O O. ` O. a 1 W = 1 I Ce a O C.) W z Z V v Q Z 1 Q A N y 7 J $ tu CL co in lc • a O � E U M N n U 0 J M M Q Zto R N cc cc r I- N 2/�� N W a' N CO a as o I Q = 0 1111 Q c a Z E Q m U 1 Z d • coin O p .. r I m d � I 3 N d o Ce O iir I v « m c R U E 'Q ..- E E O CI.a 2 0 1 ci 71//7771:4' , Alaska Oil and Gas � s� THE STATE ��- ofALASKA Conservation Commission __=_ " t == 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279.1433 ALASFax: 907.276 7542 www.aogcc.alaska.gov Jay Maguire Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 (7Q, t Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-337C Sundry Number: 315-041 Dear Mr. Maguire: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P9C5L4A`24-L__ Cathy P. oerster Chair DATED this day of January, 2015 Encl. STATE OF ALASKA ' 4 Ali ,OIL AND GAS CONSERVATION COMM!, N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate I - . Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r- 2. 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development r 214-121-0 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20262-03 7.If perforating, 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 432C Will planned perforations require spacing exception? Yes r No p KRU 2N-337C . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 375074 . Kuparuk River Field/Tarn Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 7667 , 5548 - 7624' - 5513' - 3046' none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2830' 7.625" 2858' 2313' Intermediate 7002' 5.5" 7030' 5054' E D E ED Production 833' 3.5" 7658' 5540' JAN 2 6 2015 - AO Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): no perforations none 3.5 L-80 6840 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-LINER TOP PACKER s MD=6846 ND=4915 NIPPLE- , MD=484 ND=484 12.Attachments: Description Surrrnary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/6/2015 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG p'' Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jay Maguire @ 263-4551 Email: y.C.Maquire@conocophillips.com Printed Name Jay Maguire Title: Wells Engineer Signature Phone:263-4551 Date I/21,0j Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness . k 5 -09 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: i6 — Li-(, 4 aefiAPPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date. 6 —5 OA( Approved application Is valid tor 12 months trom the date of approval. RBDMS FR - 4 2015 Form 10-403(Revised 10/2012) O fly i/Z}' Submit Form and Attachments in Duplicate j/7 1/2-- ,.� R I G I N A L, 0 ,s ,�,1-.3.4i-/-5" A ' 2N-337C Post-rig Well work: Procedure Summary: 2N-337 was originally drilled in 1998,as a Bermuda Producer. On June 15th, 1998 the well was subsequently plugged back and sidetracked to 2N-337A due to lack of reservoir quality sand found in the original wellbore. In February 2007,the well was sidetracked to 2N-337B to relocate the bottom hole location,and improve Bermuda recovery. The well was shut in September 28`h,2010,due to high water cut. On November 4, 2014,2N-337C was side tracked and converted to a slant MWAG injector to improve Bermuda oil recovery and pattern sweep efficiency. The objective of the proposed 2N-337C is post rig work to perforate the Bermuda zone 7,285'-7,390' MD and Purple zone 7,435' —7,490' MD and prep the well to bring online. Slick Line: 1. Drift and tag to verify that the interval being perforated is free of fill or mud to 7,500'. 2. Dummy drift for perforating gun to planned perforating interval 7,500'. 3. If drift can't be obtained to desired depths, RIH with sample bailer and obtain sample. Plan to perform a coil FCO if heavy mud is encountered or extensive bailing is required. 4. Set SV in 2.75"Camco D-nipple @ 6767'. 5. Pull SOV from GLM @ 6,624'and install dmy valve. 6. MIT-T to 3,000 psi&MIT-IA to 2,000 psi ensure both pass. 7. PULL SV from Camco D-nipple @ 6767' E-Line: 8. RIH and perform a GR/CCL correlation log.With memory CBL in tandem from TD to at least 200'above liner top. 9. RIH and perforate Bermuda zone 7,285'-7,390' MD(4-5 runs). 10. RIH and perforate Purple zone 7,435'—7,490' MD.(2-3 runs). 11. Rig down and move out. Tz 4-337C Stenniswwp04) Rotary Sidetrack Topset Conventional Slant Injector ConocoPhillips Proposed Wellbore Schematic _ SMC Gen V 3-'A"TREE Brunswick 9/26/14 16"" Existing Cemented Conductor: .1 1662.5#H-40 108' MD Di 3%"Camco DS LSND Nipple 2.875" Stage tool @ 1,000 MD - 1,450 ft MD in 7- 9.6 PPG 15/8"casing-be Don't need - aware to not Brine open by accident 3 W x 1"Camco KBG2-9 Existing Surface Casing: 7-5/8"29.7#L-80 BTCM 2,851' MD/2,309'TVD @ 69° 3%"x 1"Camco KBG2-9 Sidetrack KOP off cementlu p g @-68.6 degrees in open hole @-2,900'MD t Campanian::Top 3,443'MD ,t74 NDj' I 4 Tubing: LSND 3%"x1"CamcoKBG2-9 3-%" 9.3#L-80 EUE8RD 47, 9.6-10.0 PPG A IA- Keep up withTOC 15.8 ppg @*/-5,200'MD 6-1/2"x 7-1/2" Dilution � Intermediate Hole 4"DP 3%"x 1"Camco KBG2-9 XXX'MD/XXX' ND Iceberg I op 6,UUU:MU .. 477?rvn� ::. Baker C A Sliding Sleeve '%, CLOSE r /2.812"Cam 'DS' Profile .860'MD 'f ZXP Liner Top Packer XXX'MD 3'A"Ca o'D'Nipple 2.7 'nogo ' �, Flex Lock Liner Hanger X10". 4"ID20'SBE XXX'M r �" ' ► 0► ' Intermediate Casing Topset: 5-1/2" 15.5#L-80 Hydril 563 connections 7,110' MD/5,117'TVD @ 40° Top of Be uda 7,19>r A 5,184'TVD 4-3/4"Production Hole A B2-7/8"DP : LSND I .-.- .-... 10.6-10.8 PPG . Pressure Bermuda Pore P u 6.6-10.4-11.9ono 800—2,800—3,200 psig) Existing Production Casing: ••.•.. - "' 5.5"x3.5"L-8015.5#89.3#LTC-M :: 9,932'MD/5,492'TVD ' Base Bermuda 7,385'MD 5,327'TVD Cemented Production Liner: 3-1/2"9.3#L-80 Hydril 511 7,653' MD/5,531'TVD @ 40° Bettis, Patricia K (DOA) From: Maguire,Jay C <Jay.C.Maguire@conocophillips.com> Sent: Monday, January 26, 2015 3:23 PM To: Bettis, Patricia K(DOA) Subject: RE: Sundry Application: KRU 2N-337C Attachments: 2N-337C_Schematic.pdf Patricia, Here is the updated schematic for KRU 2N-337C. Please let me know if you need anything else from me. Thanks, Jay Maguire Wells Engineer CPAI Drilling&Wells (907)-263-4551 Office From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, January 26, 2015 11:34 AM To: Maguire, Jay C Subject: [EXTERNAL]Sundry Application: KRU 2N-337C Good morning Jay, Please submit a current wellbore schematic for the KRU 2N-337C well. The schematic provided for the sundry application was dated 9/26/14. 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 KUP SVC 2N-337C • Conoco-Phillips ° Well Attributes Max Angle&MD TD Alaska,Inc. / Wellbore APIIUWI Field Name Wellbore Status Incl(') MD(ftKB) Act Blm(ftKB) •rMrriPhlatpG 501032026203 TARN PARTICIPATING AREA SVC 69.65 2,901.28 7,029.8 ••• Comment H2S(ppm) Date Annotation •End Date KB-Grd(ft) Rig Release Date 2N-337C.1/26/201524744 PM SSSV:NIPPLE 30 7/1/2008 Last WO: 29.25 3/14/2007 Vertical schemabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SIDETRACK smsmith 1/22/2015 HANGER 25.8 Casing Strings Casing Description OD(in) ID(in) Top(11613) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread C LINER 5 1/2" 5 1/2 4.950 28.0 7,029.8 5.054.2 15.50 L-80 Hyd 563 Liner Details Nominal ID Top(ftKB) Top(TVD)(NKB) Top Ind(°) Kern Des Com (in) 28.0 28.0 0.00 HANGER FMC HANGER 4.950 Casing Description OD(in) ID(in) –Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER31/2"- 31/2 2.992 6,819.4 7,653.0 5,536.6 9.20 L-80 511 CEMENTED Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Corn (in) 6,819.4 4,892.8 40.08 SLEEVE SETTING SLEEVE 4.130 6,840.4 4,908.9 40.06 PACKER ZXP PACKER ' 3.000 6.848.8 4,915.3 40.05 HANGER I FLEX LOCK LINER HANGER , 2.980 NIPPLE;483.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection r— TUBING WO-2014 3 1/2 2.992 25.8 6,839.9 4,908.5 9.20 L-80 EUE 8rd Completion Details Nominal ID El Top)ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;3,355.0 25.8 25.8 0.00 HANGER FMC HANGER-PORTED DRIFTED 70 2.91" 2.992 483.8 483.4 6.06 NIPPLE CAMCO DS NIPPLE 2.875 6,681.3 4,787.1 39.90 SLEEVE BAKER CMU DS SLIDING SLEEVE DS PROFILE- 2.810 CLOSED 6,767.1 4,852.8 40.10 NIPPLE CAMCO D NIPPLE 2.705 GAS uFT,5.129.0 ❑ 6,820.6 4,893.7 40.08 SEAL ASY BAKER BULLET TIE BACK SEAL ASSEMBLY W/7' 2.900 SPACE OUT Mandrel Inserts st au N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Seri Type Type (in) (psi) Run Date Com GAS LIFT;6,1682 1 3,355.0 2,490.6 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 2 5,129.6 3,606.9 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 9 3 6,168.2 4,395.6 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/25/2014 9 • 4 6.623.9 4.743.1 CAMCO KBG-2- 1 GAS LIFT SOV INT 0.000 0.0 12/25/2014 GAS LIFT;6,623 9 Notes:General&Safety _._ End Date Annotation NOTE SLEEVE;6.681.3 NIPPLE,6,767.1 SEAL ASV;6,820 6 • :.1::::..:.. -::•:.:.,::.• O1::'.. r LINER 51/2":280-79298— I.:,.:::: } -i • 1 LINER 3 1/2"-CEMENTED; 6619.1-7b539 RECEIVED • STATE OF ALASKA JAN 2 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANRoaec la Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb Well Class 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑✓ • WDSPL ❑ Other ❑ No of Completions: Service ❑., ' StratigraphicTest❑ 2 Operator Name. 5.Date Comp,Susp, 12 Permit to Drill Number ConocoPhillips Alaska, Inc orAband •December 26,2014 214-121 / , 3 Address. 6 Date Spudded 13 API Number P.O. Box 100360,Anchorage,AK 99510-0360 • December 7,2014 50-103-20262-03 • 4a Location of Well(Governmental Section) 7.Date TD Reached 14 Well Name and Number Surface: 117'FNL,996'FEL,Sec. 3,T9N, R7E, UM • December 20,2014 KRU 2N-337C • Top of Productive Horizon 8. KB(ft above MSL): 149'RKB - 15 Field/Pool(s) 2516'FNL,614'FWL,Sec. 3,T9N, R7E, UM GL(ft above MSL)• 120.9'AMSL. Kuparuk River Field • Total Depth. 9 Plug Back Depth(MD+TVD) 2662'FNL, 358'FWL,Sec.3,T9N, R7E, UM 7624'MD/5513'TVD • Tarn Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD) 16 Property Designation Surface: x-460597 y- 5911892 Zone-4 • 7667'MD/5548'TVD ' ADL 375074 ' TPI: x-456918 y- 5909514 Zone-4 11.SSSV Depth(MD+ND) 17.Land Use Permit Total Depth: x-456662 y- 5909369 Zone-4 nipple @ 484'MD/484'TVD 4602 18 Directional Survey Yes Q ' No❑ 19.Water Depth,if Offshore 20 Thickness of Permafrost MD/TVD (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1222'MD/1198'TVD 21 Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071) 22 Re-drill/Lateral Top Window MD/TVD caliper, CBL, GR, Dens, Neutron 2635'MD/2223'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT -- - CEMENTING RECORD CASING SIZE WT PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62 6# H-40 28' 108' 28' 108' 24" 103 sx AS 1 7.625" 29.7# L-80 28' _ 2858' 28' _ 2313' 9.875" 274 sx AS III LW,240 sx CI G,60 sx AS I 5.5" 15 5# L-80 28' _ 7030' 28' 5054' 7.5 x 6.75.327 sx Class G 3 5" 9.3# L-80 6825' 7658' 4897' 5540' 4.75" 70 sx Class G 24.Open to production or infection? Yes ❑ No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number) SIZE 1 DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6840' 6846'MD/4915'TVD not perfd 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC L kt" Was hydraulic fracturing used during completion? YesL NoL I - LI + DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED , :hoz . v�� cement retainer @ 9110' 15 bbls Class G Cement plug @ 4500' 83 bbls Class G CIBP @ 3046' kickoff plug 25 bbls 17 0 ppg Class G 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility hook-up i Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 2 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071 NONE Form 10-407 Revised 10/2012 CONTINUED ON REVERSE gDMS JAN 2 2 25rr,it original only • ,29 GEOLOGIC MARKERS(List all formations and mai ncountered) 30 FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1222' 1198' needed,and submit detailed test information per 20 AAC 25.071 T-3.1 7135' 5135' T-3 7185' 5174' Top Bermuda 7204' 5189' Base Bermuda 7395' 5337' N/A Formation at total depth: Bermuda 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final directional survey,cement detail sheets 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact' Scott Brunswick @ 263-4249 Email Scott.A.Brunswick(a�conocophillios.com Printed Name G. Alvord Title. Alaska Drilling Manager Signature Phone 265-6120 Date t(Zf(2..fn`s INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. I Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain) Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 n 2N-337C Stennis Rotary Sidet,__.:Tooset Conventional Slant Injector ConocoPhillips Proposed Wellbore Schematic _ J'FMC Gen V 3-W"TREE Brunswick 1/2/15 16"Existing Cemented Conductor: 16"62.5#H-40 108' MD 3%"Camco DS Nipple 2.875" 483.8'MD tool @ C 1 1,450 ft MD in 7- - 5/8"casing 3''A"x 1"Camco KBG2-9 3355.01' IP Existing Surface Casing: 7-5/8"29.7#L-80 BTCM 2,851' MD/2,309'TVD @ 69° 3 h"x 1"Camco KBG2-9 5129.6'MD Camp pian Tort 3;455'MD (2;5oaa>: Tubing: 31"x 1"Camco KBG2-9 ; 3-Y2"9.3#L-80 EUE8RD 6168.22'MD TOC 15.8 ppg @+/-5,200'MD 6-1/2"x 7-1/2" 3'="x 1"Camco Intermediate Hole KBG2-9 6623.87'MD iceberg,'.o b.s5+c`Nip Baker CMU 2.812"DS Profile 6681.26'MD 1 I 101111 ZXP Liner Top Packer 6845.75'MD Camco 2.75"D Nipple ": Flex Lock Liner Hanger 6854.12'MD (3767.05'MD '. A.�,y 4"ID20'SBE ; � i. `: • Intermediate Casing Topset: 5-,,1/2" 15.5#L-80 Hydril 563 connections "�° 7029.84' MD @ 39° Top of Be'uda 7,20'-„a 5,189'TVD J • A B '7' 4-314" Production Holeys, Base Bermuda 7,359'MD 5,337'TVD Cemented Production Liner: 3-1/2"9.3#L-80 Hydril 511 7,658.34' MD @ 38.61° TD:7,667'MD/5,547'TVD @ 38.61° • Conoco hillips Time Log & Summary Wel/view Web Reporting Report Well Name: 2N-337 Rig Name: NABORS 9ES Job Type: DRILLING SIDETRACK Rig Accept: 11/28/2014 12:00:00 PM Rig Release: 12/27/2014 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/27/2014 24 hr summary Roads& Pads finished prep work on pad-Moved pit complex away f/sub base-Moved sub off of well- Stage well head equipment in cellar area of 2N 337-Move sub over well-Level up sub 00:00 12:00 12.00 MIRU MOVE RURD P Prep rig for move(Roads&Pads still working on location)Change out drag chain wear plate-Prep moving system-Finish working on Diverter system on 2N 336-Clean up hercuite rom around cuttings tank- Remove steam traps from mud pits- Prep pit complex for seperation f/ sub base 12:00 18:00 6.00 MIRU MOVE MOB P Finish prep work on pit complex for move-PJSM w/Peak-Move pit complex away f/sub base-Clean up pad 18:00 21:00 3.00 MIRU MOVE MOB P PJSM-Move sub base off of 2N 319A-Clean up pad-Stage mats on 2N 337C-Place well haed equipment in cellar area @ 2N337C- Hang tree in cellar- 21:00 00:00 3.00 MIRU MOVE MOB P Move sub base onto 2N 337C-Spot rig mats&level sub( Rig over well @ 2300 hrs) 11/28/2014 Continue rig move-Spot pit complex-Set cutting tank-Install berms-Hook up service lines-Take on brine -Install valves on OA&IA-Test mud lines-Pull BPV-RU to displace freeze protect diesel-Held Pre sud meeting-Displace freeze protect diesel w/9.8 ppg brine-Set TWC&test 00:00 06:00 6.00 0 0 MIRU MOVE MOB P PJSM w/Peak&crew on spotting pits-Spread herculite-Spot pit complex&set rig mats-Level complex- 06:00 12:00 6.00 0 MIRU MOVE RURD P -Hook up service lines-Install berm around sub&pits-Prep beam for cutting tank-Install outter valves on OA&IA-Bring rig up on high line power-Spot cutting tank Finish pre spud check list-Prep to take on brine in pits Accpeted rig © 1200 hrs-11/28/14 12:00 14:00 2.00 0 0 MIRU MOVE RURD P Take on brine in pits(9.4 ppg)build volume&wt. up to 9.8 ppg-Test mud lines to 3000 psi 14:00 16:00 2.00 0 0 SLOT WELCTL MPSP P RU&test BPV in direction of flow to 2000 psi-Install FMC lubricator& test to 250&2000 psi-Pull BPV- RD 7 blow down lines Page 1 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:00 1.00 0 0 SLOT WELCTL SFTY P Held Pre-Sud meeting w/rig crew- tool pusher&Co. Rep. 17:00 22:00 5.00 0 0 SLOT WELCTL RURD P RU manifold in cellar&MU lines to tbg&Al for displacement-Clean up cellar area-Blow air through line from cellar to Tiger tank 22:00 22:15 0.25 0 0 SLOT WELCTL SEQP P Fill lines f/wellhaed to Tiger tank w/ brine-Test lines to 2500 psi 22:15 23:00 0.75 0 0 SLOT WELCTL KLWL P Displace well f/freeze protect diesel to 9.8 ppg brine in the tbg&IA from the tbg cut @ 3250'-Pumping @ 5 bbls/min @ 980 psi pumping down IA &taking returns up tbg and out to Tiger tank-Pumped 135 bbls w/9.8 ppg brine back to surface 23:00 23:30 0.50 0 0 SLOT WELCTL OWFF P Blow down lines&monitor well for flow-Well static 23:30 00:00 0.50 0 0 SLOT WHDBO MPSP P Set TWC&test to 2000 psi for 10 mins in direction of flow(Good test) 11/29/2014 ND tree-NU BOP-change btm rams-Test BOPE-Pulled blanking plug&TWO-RU to pull 3 1/2"tbg- Service rig 00:00 01:00 1.00 SLOT WHDBO RURD P Continue to Blow down lines and RD cellar circulation lines after displacement, pump out tree. 01:00 03:30 2.50 SLOT WHDBO NUND P PJSM on ND tree. ND Tree and adapter flange. Remove SBM's and install blanking plug as per FMC. 03:30 06:30 3.00 SLOT WHDBO NUND P PJSM on NU BOPE. inspect bridge cranes and lifting equipment. NU 13-5/8 Class IV BOP stack. MU Kill line and position stack and insert riser. 06:30 09:00 2.50 SLOT WHDBO RURD P PJSM on changing lower pipe rams to 3-1/2 x 6"VBR's. Change rams, clean and clear cellar, Install mouse hole. 09:00 10:00 1.00 SLOT WHDBO SFTY P Held Pre spud with crew on tour and had open discussion on well control. 10:00 13:30 3.50 SLOT WHDBO RURD P RU for Initial BOP test on rig floor and cellar. Inspect all safety lines and connections. MU 4-1/2 HT 40 TIW valve and Dart valve to test joint. Function test bop and purge lines free of air with fresh water. Page 2 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 19:30 6.00 SLOT WHDBO BOPE P Test BOP as follows: Tested Annular, Upper&lower VBR's- Choke manifold valves-Kill&choke line valves-4"Demco on kill line- TD IBOP's-4"HT-40 floor safety& dart valves-All tests were done w/3 1/2"test jt.w/blanking plug installed -Tested blind rams-All tests were 250&3500 psi for 5 mins.- Performed accumulator recovery test -Start pressure 2900 psi-200 psi gain in 34 secs. back to full charge in 2 mins. 25 secs.-N2 bottles average pressure 1983 psi- Witnessing of test waived by Johnnie Hill w/ AOGCC 19:30 20:30 1.00 SLOT WHDBO RURD P RD test equipment&blow down lines 20:30 21:00 0.50 SLOT WHDBO MPSP P PU 3 1/2"test jt/-Pulled blanking plug-LD same-PU T bar&pull TWC 21:00 23:30 2.50 SLOT RPCOM RURD P RU to pull 3 1/2"tbg-bring tongs, slips, elevators to rig floor& RU-PU 1 jt 3 1/2" EUE 8 RD tbg 23:30 00:00 0.50 SLOT RPCOM SVRG P Service rig-grerase TD&D/W 11/30/2014 MU landing jt. into tbg hanger-Back out LDS-Pull tbg hanger to rig floor PU wt 52K-Pulled& LD 3 1/2"tbg -RU&Test hydril&VBR's w/4"&5 1/2"test jts.-RU E line&run gauge ring/Junk Bskt-Change tools RIH &set Baker CIBP @ 3046'-POOH-RD E line-Pull wear bushing-RU to pull pack-off 00:00 08:00 8.00 3,243 0 SLOT RPCOM PULL P Drain stack-MU landing jt into tbg hanger-Back out lock down screws -Un seat&pull hanger to rig floor- PU wt 52 k-Break out landing jt& hanger-Pulled and LD 104 jts. 3 1/2"L-80 9.3#IBT tbg-4 pup jts- DB nipple w/2 pups-hanger-Total lenght of recovery-3218.26'-top of stub @ 3243.43' 08:00 09:00 1.00 0 0 SLOT RPCOM RURD P RD tbg tongs and tbg elevators- Clean up rig floor 09:00 10:30 1.50 0 0 SLOT RPCOM BOPE P RU to test annular&pipe rams w/4" &5 1/2"test jts. 10:30 13:00 2.50 0 0 SLOT RPCOM BOPE P Tested annular and upper&lower VBR's w/4"and 5 1/2"test jts to 250&3500 psifor 5 mins.each test 13:00 13:30 0.50 0 0 SLOT RPCOM BOPE P RD test equipment-drain stack& blow down lines 13:30 15:30 2.00 0 0 SLOT RPCOM RURD P RU&set wear bushing-LD running tool-Clean&clear rig floor 15:30 16:00 0.50 0 0 SLOT PLUG RURD P Install Dutch riser 16:00 17:30 1.50 0 0 SLOT PLUG ELNE P PJSM-RU E line&test Dutch riser & E line pack-off to 500 psi 17:30 19:00 1.50 0 0 SLOT PLUG ELNE P Rand 4.75"gauge ring&junk bskt to 3075'-Ran CCL&GR for later corralation-LD GR&JB Page 3 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:30 2.50 0 0 SLOT PLUG ELNE P PJSM-MU Baker Bridge plug-RIH and coralate to get on depth-Set BP @ 3046'-POOH w/WL& setting tool-LD setting tool 21:30 22:00 0.50 0 0 SLOT PLUG PRTS P Pressure CIBP to 2500 psi for 10 mins. Good test- 22:00 22:30 0.50 0 0 SLOT PLUG RURD P RD E Line&LD Dutch riser 22:30 00:00 1.50 0 SLOT PLUG RURD P PU&pull wear bushing-RU to Pull pack-off 12/01/2014 RU& Pull Pack-off-RU Dutch riser-RU E line&RIH w/WellTech cutter&cut casing©3026'-POOH& RD-MU landing jt to csg hanger-Displace well w/9.8 ppg brine&work casing free-Shut in well Observed 350 psi on DP side&340 psi on Csg-Circ well @ 5 bbls/min Surface to Surface thru choke-Shut in-DP side 390 psi Csg 390 psi(lost 63 bbls)build volume-Confer w/Drilling engineer& Drilling Superintendent 00:00 00:45 0.75 0 0 SLOT PLUG RURD P Back out lock down screws on casing pack-off-Open OA valve-No pressure below packoff-Pull packoff to surface- 00:45 01:00 0.25 0 0 SLOT PLUG OWFF P Monitor well static 01:00 02:30 1.50 0 0 SLOT PLUG ELNE P RU Dutch riser&test to 500 psi (Good Test) 02:30 02:45 0.25 0 0 SLOT PLUG SFTY P PJSM w/Nabors crew-Halliburton& WellTech 02:45 04:30 1.75 0 0 SLOT PLUG ELNE P RU E line&MU WellTech 3 5/8" casing cutter-Surface test tool 04:30 07:00 2.50 0 0 SLOT PLUG ELNE P RIH w/WellTech csg cutter-Tagged CIBP @ 3045'-Pulled up to get on depth-Cut 5 1/2"casing @ 3026'- POOH w/WT csg cutter 07:00 09:30 2.50 0 0 SLOT PLUG ELNE P LD WellTech casing cutter-RD E line-LD Dutch riser 09:30 12:00 2.50 0 0 SLOT PLUG KLWL P PU 5 1/2"landing jt&MU to casing hanger-RU to circ down csg and take returns to Tiger tank-Blow down lines to verify clear-Found ice plug in hardline to tank 12:00 13:30 1.50 0 0 SLOT PLUG KLWL T Shut in well-SIDP 180 psi SICP 190 psi-Clear rig floor of wire line tools(while trawing out line to tank) 13:30 15:00 1.50 0 0 SLOT PLUG KLWL P Displace well to 9.8 ppg brine thruchoke-starting SIDPP 180 psi SICP 190 psi-Establish ICP @ 390 psi-@ 5 bbls/min Pumped 150 bbls -Lost 8 bbls while pumping 15:00 16:00 1.00 0 0 SLOT PLUG KLWL P Worked 5 1/2"casing free- Contiune pumping @ 5 bbls/min @ 390 psi-Shut down-SIDPP 350 SICP 340 16:00 18:00 2.00 0 0 SLOT PLUG KLWL T Monitor well-SIDPP 350 SICP 340 -Circ 10 bbls @ 2-3 bbls/min ery 30 mins to avoid freeze up- Page 4 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 0 0 SLOT PLUG KLWL T Circ-Surface to surface w/Drillers method starting SIDDP 270 psi SICP 270 psi-Pumepd @ 5 bbls /min holding DP to 360 psi-shut down-SIDDP 390 psi SICP 390 psi -Lost 63 bbls while pumping- Observed very litttle gas @ btms up 19:00 00:00 5.00 0 0 SLOT PLUG KLWL T Continue to pump 10 bbls every 30 mins©2-3 bbls/min (building volume in pits) Discussed plan forward w/Drilling Engineer&Drilling Superintendent 12/02/2014 Monitor well&pump every 30 mins to avoid freeze up-Circ w/9.8 ppg attempting to lower Dp&csg pressure -Open choke&bled off 6 bbls-Circ btms up no gas-Bled off 7 bbls in 14 mins Bled off 7 bbls/in 18 mins. pressures coming down-Opened Annular preventer-monitor well-circ btms up-LD landing jt&csg hanger -Blow down TD-Install Xo&TIW valve-circ&wt up to 10.0 ppg-observed well Static foe 11 mins-began oozing down flow line-Wt up to 10.2 ppg_observed well static for 20 mins.then bagan to ooz down flow line 00:00 01:00 1.00 0 0 SLOT PLUG CIRC T Circ 10 bbls brine every 30 mins. to avoid freeze up-SIDP 340 psi SICP 320 01:00 02:00 1.00 0 0 SLOT PLUG CIRC T Opened choke&Pumped (140 bbls)9.8 ppg brine @ 2 bbls/min @ 360 psi on DP&300 psi on csg- Shut&close in choke-SIDPP 350 psi SICP 350 psi-Lost 8.3 bbls during circulation 02:00 04:30 2.50 0 0 SLOT PLUG OWFF T SIDPP 350 psi SICP 350 psi- Monitor pressures on DP&Csg- Pumped 10 bbls brine @ 2 bbls/min every 30 mins.to prevent freeze up 04:30 05:30 1.00 0 0 SLOT PLUG CIRC T Shut in DPP 330 psi SICP 330 psi- Opened choke&circ S to S volume @ 2 bbls/min ICP DP 350 psi ICP Csg 290 psi-FCP DP 350 psi FCP Csg 270 psi-Shut down&close choke-SIDPP 330 psi SICP 330 psi-Lost 1.7 bbls during circulation- 05:30 08:00 2.50 0 0 SLOT PLUG OWFF T Monitor DP&CSG pressures SIDPP 350 psi SICP 350 psi-Pumped 10 bbls brine every 30 mins.to prevent freeze up 08:00 08:30 0.50 0 0 SLOT PLUG OWFF T Bleed off 6.9 bbls thru choke to trip tank-Close choke-SI DPP 70 psi SICP 80 psi-Monitor pressure build up-14 minutes DPP 250 psi CP 250 psi-Open choke&Circ btms up @ 2 bbls/min @ ICP DP 310 psi ICPC 260 psi-FCP DP 310 psi FCP C 260 psi-Shut down&close choke-SIDPP 300 psi SICP 300 psi in 15 min. 08:30 10:30 2.00 0 0 SLOT PLUG OWFF T Monitor DP&CSG pressure DP 300 psi C 300 psi-Pump 10 bbls every 30 mins to prevent freeze up Page 5 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:30 1.00 0 0 SLOT PLUG OWFF T Bleed off 7.2 bbls thru choke to trip tank-DPP 20 psi CP 0 psi-return flow just a small trickle f/6 to 7 bbls took 4 mins-Shut in choke monitor bulid up-DP 60 psi&Csg 60 psi in 14 mins. Open choke&circ btms up @ 2 bbls/min ICP DP 310 psi&240 psi on csg-FCP DP 330 psi FCP C 270 psi -shut down-SIDPP 280 psi SICP 280 psi 11:30 12:00 0.50 0 0 SLOT PLUG OWFF T Monitor DP&Csg pressure DP 280 psi Csg 280 psi 12:00 13:00 1.00 0 0 SLOT PLUG OWFF T Opened choke&bled 7 bbls thru choke to trip tank in 18 mins. 13:00 13:30 0.50 0 0 SLOT PLUG OWFF T Open Annular-Monitor well 13:30 14:30 1.00 0 0 SLOT PLUG CIRC T Circ btms up @ 2 bbls/min @ 90 psi No gas-shut down 14:30 15:00 0.50 0 0 SLOT PLUG RURD T Pull&LD landing jt&csg hanger- Blow down TD-Install XO&TIW valve to 5 1/2"csg 15:00 16:00 1.00 0 0 SLOT PLUG CIRC T Circ @ 2 bbls/min @ 50 psi-wt. up pit#3 to 10.0 ppg 16:00 17:30 1.50 0 0 SLOT PLUG CIRC T Displace 9.8 ppg brine f/well w/10.0 ppg brine© 2 bbls/min @ 55 psi- Shut down&monitor well static for 11 mins.than began to ooz down flow line 17:30 21:00 3.50 0 0 SLOT PLUG OWFF T Monitor well on TT while weighting up pits to 10.2 ppg-gain rate 1 bbl/hr 21:00 23:00 2.00 0 0 SLOT PLUG CIRC T Circ and displace 10.0 ppg brine to 10.2 ppg brine @ 1 bbl/min @ 60 psi -Shut down&blow down TD 23:00 00:00 1.00 0 0 SLOT PLUG OWFF T Monitor well on trip tank-Well static for 20 mins.then began to 000z down flow line 12/03/2014 Wt up to 10.4 ppg in pits-Displace well f/10.2 OOg brine to 10.4 ppg brine-Monitor well 1 hr.Well static- Pull& LD 5 1/2"csg-Test BOPE-RU to run 3 1/2"cmt stinger 00:00 03:30 3.50 0 0 SLOT PLUG OWFF T Monitor well on TT-wt up pits to 10.4 ppg-Gained 1 bbl in 3.5 hrs. 03:30 06:30 3.00 0 0 SLOT PLUG CIRC T Displace well f/10.2 ppg brine to 10.4 ppg @ 1 bbl/min ©66 psi- FCP 49 psi Obtain SPR# 1 1 bbl/min©50 psi 2 bbls/min @ 80 psi #2 1 bbl/min @ 50 psi 2 bbls/min @ 80 psi w/ 10.4 ppg brine 06:30 07:30 1.00 0 0 SLOT PLUG OWFF T Monitor well on TT for 1 hr. -Well static 07:30 15:00 7.50 0 0 SLOT PLUG PULL P Pull&LD 5 1/2" 15.5#L-80 csg- Start PU wt 70 k-SO wt 50 k-hole took proper fill-total lenght recovered from strap in pipe shed (2993.53') 15:00 16:00 1.00 0 0 SLOT PLUG RURD P RU casing equipment-Clean up rig floor 16:00 17:00 1.00 0 0 SLOT WHDBO RURD P RU to test BOPE Page 6 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 23:00 6.00 0 0 SLOT WHDBO BOPE P Tested BOPE-Tested Annular, Upper&lower VBR's , Blind rams, Choke manifold valves, Kill&choke line valves,4"Demco valve on kill line,TD IBOP's, Floor safety&Dart valves to 250 psi low&3500 psi high for 5 mins. -All test done w/4"test jt. -Performed accumulacor recovery test(start pressure 2950 psi- function rams&HCR's -pressure© 1650 psi-Start electric pump 200 psi in 35 secs. back to full charge in 2 mins 46 secs.-N@ bottle average pressure 1916 psi-LD 4"test jt-PU 3 1/2"&5 1/2"test jts&tested Annular&upper&lower VBR's to 250 psi low&3500 psi high- witnessing of test waived by Bob Noble AOGCC 23:00 23:30 0.50 0 0 SLOT WHDBO RURD P RD test equipment-Pull test plug& set wear bushing-Blow down TD 23:30 00:00 0.50 0 0 SLOT PLUG RURD P RU tbg tongs, elevators to run 3 1/2" cmt stinger 12/04/2014 RIH w/3 1/2"tbg (cmt stinger)to 902' PU& RIH w/4"DP to 3016'-Slip&cut drill line&service rig-RIH to 3041' Circ for cmt job-Set KO plug f/3041'to 2658'(calc top)w/25 bbls 17.0 ppg cmt-POOH to 2616'- Close Hydril&hold pressure on cmt-POOH&LD 3 1/2"cmt stinger-MU Dutch riser for wireline 00:00 02:00 2.00 0 902 SLOT PLUG PULD P MU 3 1/2"mule shoe-RIH w/3 1/2" tbg (cmt stringer)picking pipe up f/ shed to 902' 02:00 02:30 0.50 902 902 SLOT PLUG RURD P RD GBR tbg tongs-Change elevators to 4" 02:30 07:00 4.50 902 3,016 SLOT PLUG PULD P RIH w/3 1/2"cmt stinger-Picking up 4" DP f/shed f/902'to 3016'(66 jts&2 DP pups) PU wt 66 k SO wt 57 k 07:00 08:00 1.00 3,016 3,016 SLOT PLUG SLPC P Cut&slip drill 62' 08:00 09:00 1.00 3,016 3,016 SLOT PLUG SVRG P Service DAN, TD, blocks&crown 09:00 11:00 2.00 3,016 3,041 SLOT PLUG PULD P RIH f/3016'-PU 1 jt 4" DP-&tag top of CIBP @ 3043'-PU&change out 10' pup w/5'pup-RIH to 3041' 11:00 13:00 2.00 3,041 3,041 SLOT PLUG CIRC P RU&circ and condition for cmt plug -Stage pump up to 3 bbls/min @ 160 psi-PUwt65k SOwt55k Page 7 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:15 1.25 3,041 3,041 SLOT PLUG CMNT P W/mule shoe @ 3041'set kick off plug-Pumped 5 bbls 12.5 ppg MudPush @ 2.7 bbls/min @ 150 psi -Shut down-Pressure test lines to 3000 psi-Pumped 10 bbls 12.5 ppg MudPush @ 2.8 bbl/min @ 120 psi- Loaded wiper ball string-Pumped 25 bbls Class G cmt w/additives© 17.0 ppg @ 3 bbls/min @ 130 psi- Pumped 5 bbls 12.5 ppg MudPush behind cmt. 3.2 bbl/min © 100 psi- Switched over to rig pumps& displaced cmt to equalize w/16.5 bbls 10.4 ppg brine @ 1.8 bbls/min bbls -CIP @ 1415 hrs.-Blow down lines 14:15 15:00 0.75 3,041 2,578 SLOT PLUG TRIP P POOH f/3041'to 2616'@ 600'/hr. PU wt 65 k 56 k 15:00 16:00 1.00 2,578 2,578 SLOT PLUG CIRC P Circ @ 5 bbls/min @ 249 psi- Observed MudPush @ shakers 16:00 19:30 3.50 2,578 2,578 SLOT PLUG WOC P Closed annular&pressure up to 200 psi and hold pressure on cmt job 19:30 20:00 0.50 2,578 2,578 SLOT PLUG WOC P Bleed off pressure-Open annular- Blow down lines 20:00 21:00 1.00 2,578 902 SLOT PLUG TRIP P POOH w/4" DP f/2616'to 902' -PU wt. 62 k SO wt 56 k 21:00 21:30 0.50 902 902 SLOT PLUG RURD P RU to pull&LD 3 1/2"cmt stinger 21:30 22:30 1.00 902 0 SLOT PLUG PULD P Pull&LD 29 jts 3 1/2"tbg&mule shoe f/902' 22:30 23:30 1.00 0 0 SLOT PLUG RURD P RD tbg tongs and elevators 23:30 00:00 0.50 0 0 SLOT PLUG ELOG P RU Dutch riser for wireline caliper log 12/05/2014 RU E line&ran csg caliper log f/1600'-RD WL-PU&Std back 4" DP f/shed 90 jts-MU mule shoe-RIH picking up remaining 4"DP f/shed-Tagged top of cmt plug @ 2635'-Circ btms up-RU &pressure test 7 5/8"Casing&cmt plug to 2500 psi-Leaked off to 1800 psi in 30 mins. POOH w/DP&mule shoe 00:00 03:15 3.25 0 0 SLOT PLUG ELOG P Finish RU&test Dutch riser to 500 psi-RU E-line 03:15 04:30 1.25 0 0 SLOT PLUG ELOG P RIH w/casing caliper log f/1600'up to surface 04:30 06:30 2.00 0 0 SLOT PLUG ELOG P RD wireline& Dctch riser-Clean up rig floor 06:30 08:30 2.00 0 1,435 SLOT PLUG PULD P PU& RIH w/45 jts-4"DP f/shed to 1435' 08:30 09:00 0.50 1,435 0 SLOT PLUG TRIP P POOH &Std back 4"DP in derrick (15 stds) 09:00 11:00 2.00 0 1,435 SLOT PLUG PULD P PU&RIH w/45 jts.4" DP f/shed to 1435' 11:00 12:00 1.00 1,435 0 SLOT PLUG TRIP P POOH&Std back 4" DP in derrick- (52 stds total in derrick) 12:00 12:30 0.50 0 0 SLOT PLUG SVRG P Service rig-Greased D/VV&TD 12:30 14:00 1.50 0 0 SLOT PLUG OTHR P Clean out mud system-Clean and clear rig floor-RD hoses to Tiger tank Page 8 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:30 2.50 0 1,901 SLOT PLUG PULD P MU 3 1/2"mule shoe-PU&RIH w/ 4" DP f/shed(60 jts)to 1901' -PU wt59k SO wt56k 16:30 17:30 1.00 1,901 2,635 SLOT PLUG TRIP P RIH w/stds f/derrick f/1901'to 2635' (tagged top of cmt) 17:30 18:00 0.50 2,635 2,635 SLOT PLUG CIRC P Circ btms up f/2635'@ 7 bbls/min @ 280 psi 18:00 18:30 0.50 2,635 2,541 SLOT PLUG RURD P Pulled&std back 1 std DP to 2541'- RU to pressure test csg&cmt plug 18:30 19:30 1.00 2,541 2,541 SLOT PLUG PRTS P Pressure test 7 5/8"csg&ctm plug to 2550 psi w/1.6 bbls 10.4 ppg brine-Lost 750 psi in 30 mins. - Bleed off pressure-Flow ck well static(Test failed) 19:30 20:30 1.00 2,541 2,541 SLOT PLUG CIRC P Circulate well @ 3 bbls/min @ 100 psi-RD&blow down lines 20:30 21:30 1.00 2,541 0 SLOT PLUG TRIP P POOH f/2541 w/4" DP&mule shoe -LD mule shoe 21:30 00:00 2.50 0 0 SLOT PLUG SVRG T Clean&service rig-PU BHA XO's& pups to rig floor(while waiting on Baker packer for testing) 12/06/2014 RIH w/Bakerpacker&set @ 2608'-Pressure test 7 5/8"csg above packer to 2500 psi (Good Test) POOH &LD packer-Clean&service rig-MU BHA#1 -RIH to 1578'; Shallow test MWD tools-RIH to 2635' (top of cmt-Clean out cmt f/2635'to 2722' 00:00 03:00 3.00 0 0 SLOT PLUG OTHR T Load pipe shed w/5 1/2"csg- Measure&drift(waiting on Baker Packer( 03:00 05:30 2.50 0 2,612 SLOT PLUG TRIP T MU Baker retrievable packer&RIH on 4" DP to 2616' PU to 2612'&set packer w/element @ 2606'-PU wt 67 k SO wt 55 k 05:30 06:30 1.00 2,612 2,612 SLOT PLUG PRTS T Pressure test 7 5/8"casing from 2606'w/2500 psi for 30 mins. Good Test-Bled off pressure&unseat packer 06:30 09:30 3.00 2,612 0 SLOT PLUG TRIP T POOH w/4" DP&packer f/2612'- LD 1 single of DP&packer 09:30 15:00 5.50 0 0 SLOT PLUG PULD P Load BHA tools back into pipe shed -Clean&service rig(waiting on 3 1/2"elevators)inspect&service 3 1/2"elevators 15:00 18:00 3.00 0 131 SLOT PLUG PULD P PU&MU BHA#1 -Power Drive X6- MU bit-Impulse-VPWD- adnVISION-NM pony DC-NM Stab -Rip tide underreamer-Function test UR 18:00 19:30 1.50 131 627 SLOT PLUG PULD P LD Rip Tide UR-Load RA sources in MWD-Continue MU BHA-Pick UR back up-MU UBHO -1 NM flex DC -NMstab-XO-6jts HWDP-Jars- 8 jts. HWDP to 627' 19:30 20:00 0.50 627 1,578 SLOT PLUG TRIP P RIH w/BHA on 4" DP f/627'to 1578' -PUwt63k SOwt. 58k 20:00 21:00 1.00 1,578 1,578 SLOT PLUG DHEQ P Shallow pulse test tools @ 250 gpm @ 1300 psi w/25 rpm's w/1 k torque-Good Test-Blow down TD Page 9 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 1,578 2,635 SLOT PLUG TRIP P RIH f/1578'to 2635'(tagged top of _ cmt) PU wt 76 k SO wt 62 k 21:30 00:00 2.50 2,635 2,722 SLOT PLUG DRLG P Drilled cmt f/2635'to 2722' MD ADT-2.5 hrs WOB 5 k RPM 55 GPM 240 @ 1300 psi String wt-PU wt 76 k SO wt. 62 k ROT wt. 66 k Torque on/off btm.-4 k/2.3 k Obtained SPR's @ 2130'@ 2620' MD 2280'TVD #2 2 bbls/min @ 190 psi 3 bbls/min @ 350 psi w/10.3+ppg mud wt. 12/07/2014 Drilled cmt f/2722'to 2886' (off of plug)drilled 20'new hole to 2906'-Change well over f/10.4 ppg brine to 9.8 ppg LSND-Performed LOT to 14.3 ppg EMW-Drill 6 3/4"x 7 1/2"hole f/2906'to 3450'-Opened UR @ 2858' 00:00 05:30 5.50 2,722 2,886 SLOT PLUG DRLG P Drilled cmt f/2722'to 2886' MD WOB 5/8 k RPM 60 GPM 240 @ 1300 psi String wt. PU 75 k SO 60 k Torque 4 k SPR' @0100 hrs @2750' w/10.4 ppg brine #1 - 2 bbls/min @ 210 psi 3 bbls/min @ 350 psi #2 - 2 bbls/min @ 190 psi 3 bbls/min @ 360 psi 05:30 06:00 0.50 2,886 2,886 SLOT PLUG SFTY T High H2S alarm sounded-Sercure well&evacuated rig to safe breifing area-All personal accounted for- Driller&floor hand doned Scott air packs and checked rig w/hand held monitors&confirmed 0 H2S- Electrician recalibrated alarms 06:00 07:30 1.50 2,886 2,814 SLOT PLUG DDRL P Drilled 6 3/4"hole f/2886'to 2906' (20'new hole) WOB 5 k RPM 60 GPM 260© 1540 psi String wt PU 75 k SO 60 k ROT 70 k Torque on/off btm-4/3 k ft/lbs Pulled back to 2814' Flow ck-well static TOFF of cement plug @ 2886' Page 10 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:30 1.00 2,814 2,814 SLOT PLUG DISP P Displaced well f/10.4 ppg brine to 9.8 ppg LSND mud @ 6 bbls/min @ 1550 psi w/40 rpms w/2.6 k torque Obtain new SPR's w/9.8 ppg LSND @ 2814' # 1 2 bbls/min @ 240 psi 3 bbls/min ©370 psi #2 2 bbls/min @ 210 psi 3 bbls/min @ 360 psi Monitor well(Static) 08:30 09:30 1.00 2,814 2,814 SLOT PLUG LOT P RU&performed LOT to 14.3 ppg EMW @ 2312'TVD w/540 psi allpied pressure w/9.8 ppg mud 09:30 09:45 0.25 2,814 2,906 INTRM1 DRILL WASH P Wash down f/2814'to 2906 @ 260 gpm @ 1350 psi' 09:45 12:00 2.25 2,906 3,007 INTRM1 DRILL DDRL P Drilled 6 3/4" hole W/RSS f/2906'to 3007' MD 2362'TVD ADT 1.59 hrs ECD 11.7 ppg WOB 5 k RPM 100 GPM 255 @ 1450 psi String wt. PU 73 k SO 60 k ROT 67 k Torque on/off btm.-3.7/3 k @ bit depth 2985'-Opened Underreamer-Pulled up&located 7 5/8"shoe @ 2858' Began UR hole to 7 1/2"f/2858' blade 117'behind bit) Obtained SPR's @ 3007' #1 2 bbls/min @ 230 psi 3 bbls/min @ 370 psi #2 2 bbls/min @ 230 psi 3 bbls/min @ 380 psi 12:00 18:00 6.00 3,007 3,260 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole w/RSS& UR f/3007'to 3260' ADT-3.79 hrs ECD 11.7 ppg Footage 253' WOB 5 k RPM 110 GPM 344 @ 1930 psi String wt. PU 77 k SO 58 k ROT 58 k Torque on/off btm.-3.5/2.8 k SPR's @ 3007'@ 1300 hrs w/9.8 ppg mud #1 2 bbls/min @ 210 psi 3 bbls/min @ 340 psi #2 2 bbls/min @ 210 psi 3 bbls/min @ 340 psi Page 11 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 3,260 3,450 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole w/RSS 7 UR f/3260'to 3450' MD ADT 3.69 hrs ECD 11.7 ppg Footage 1980' WOB 5 k RPM 120 GPM 345 @ 2000 psi Strin wt PU 80 k SO 60 k ROT 66 k Torque on/off btm.-3.3/2.8 k 12/08/2014 Drilled 6 3/4"x 7 1/2"hole f/3450'to 4498' 00:00 00:30 0.50 3,450 3,471 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole w/RSS 7 UR f/3450'to 3471' MD 00:30 02:00 1.50 3,471 3,471 INTRM1 DRILL CIRC T Circ and condition hole while waiting on MWD to trouble shoot surface computers. 02:00 06:00 4.00 3,471 3,613 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole w/RSS& UR f/3471'to 3613' MD ADT 3.35 hrs ECD 11.7 ppg Footage 163' WOB 5 k RPM 120 GPM 345 @ 2100 psi Strin wt PU 83 k SO 61 k ROT 67 k Torque on/off btm.-4.5/4 k 06:00 12:00 6.00 3,613 3,896 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole w/RSS& UR f/3613'to 3896' MD ADT 4.70 hrs ECD 11.75 ppg Footage 283' WOB 5 k RPM 120 GPM 345 @ 2100 psi Strin wt PU 84 k SO 65 k ROT 71 k Torque on/off btm.-4/3.5 k 12:00 00:00 12.00 3,896 4,498 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole w/RSS& UR f/3896'to 4498' MD 3123'TVD ADT-9.02 hrs ECD- 11.7 to 11.5 ppg Footage-602' WOB 4/8 k RPM 120 GPM 345 @ 2200 psi String wt. PU 95 k SO 72 k ROT 77 k Torque on/off btm.-6.5/6 k ft/lbs Obtained SPR's @ 2230 hrs.4434' MD 3071'TVD #1 2 bbls/min @ 220 psi 3 bbls/min @ 360 psi #2 2 bbls/min @ 220 psi 3 bbls/min @ 350 psi 12/09/2014 Drilled 6 3/4"x 7 1/2"hole f/4498' t/5196' Wiper trip f/5196't/3008', circulate BU, RIH to 5196'. Page 12 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 4,498 4,822 INTRM1 DRILL DDRL P Drill 6 3/4"X7 1/2"hole w/RSS&UR f/4498't/4822' MD. ADT 3.99 hrs ECD 11.7 MW 9.6 ppg Footage 324' GPM 345 PSI on 2270 PSI off 2270 RPM 120 TQ on 5,5 k TQ off 5 k PUW 101 k SOW 76 k RTW 83 k SPR 4434' MD 3372'TVD Pump#1 2 BPM 220 psi 3 BPM 360 psi Pump#2 2 BPM 220 psi 3 BPM 350psi. 06:00 12:00 6.00 4,822 5,196 INTRM1 DRILL DDRL P Drill 6 3/4"X7 1/2"hole w/RSS&UR f/4822't/5196' MD. ADT 5.04 hrs ECD 11.7 MW/9.6 ppg Footage 374' GPM 345 PSI on 2400 PSI off 2380 RPM 120 TQ on 7 k TQ off 6.5 k SPR 5006'MD 3504 TVD Pump#1 2 BPM 240 psi 3 BPM 400 psi Pump#2 2 BPM 250 psi 3 BPM 400 psi. 12:00 14:00 2.00 5,196 5,196 INTRM1 DRILL CIRC P Circulate BU at 5196' GPM 250 PSI 1235 MW 9.6 ppg RPM 75 TQ 6 k PUW 110 k SOW 80 k RTW 85 k. Attempt to close UR twice. SPR 5196'MD 3654'TVD Pump#1 2 BPM 280 psi 3 BPM 460 psi Pump#2 2 BPM 270 psi 3 BPM 460 psi. 14:00 19:00 5.00 5,196 3,008 INTRM1 DRILL WPRT P Wiper trip to shoe POOH f/5196' t/3008' PUW 78 k SOW 60 k Cal hole fill 13.8 bbls Actual hole fill 14.8 bbls. 19:00 21:00 2.00 3,008 3,008 INTRM1 DRILL CIRC P Attempt to close UR to pull into casing, 10 k over pull, no go. Circulate BU @ 3008' SPM 83 GPM 242 2 MWD Surveys @ 3008' and 3096'. Monitor well 15 minutes. 21:00 00:00 3.00 3,008 5,196 INTRM1 DRILL WPRT P Run in the hole f/3008't/5196' PUW 112 k SOW 78 k RTW 84 k Cal fill 33.0 bbls Actual fill 28.8 bbls. Drop UR opening tags. Wash to bottom GPM 252 2375 psi RPM 60 TQ 6.5 k 12/10/2014 Drilled 6 3/4"x 7 1/2"hole f/5196' t/6813', pumping HI-Vis sweeps every 300'. 00:00 12:00 12.00 5,196 5,958 INTRM1 DRILL DDRL P Drill 6 3/4"x 7 1/2"hole w/RSS& UR f/5577' t/5958' ADT 8.62 hrs ECD 11.7 MW 9.6 ppg WOB 10 k GPM 345 PSI on 2390 PSI off 2240 RPM 120 TO on 5.3 k TQ off 4,7 k PUW 113 k SOW 88 k RTW 92 k. Pump Hi-Vis Sweep at 5388'. SPR 5673'MD 4019'TVD Pump#1 2 BPM 260 psi 3 BPM 410 psi Pump#2 2 BPM 260 psi 3 BPM 410 psi. Page 13 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 5,958 6,813 INTRM1 DRILL DDRL P Drill 6 3/4"x 7 1/2" hole w/RSS& UR f/5958' t/6813' ADT 8.05 hrs ECD 11.4-11.7 MW 9.6 ppg WOB 5- 10 k GPM 343 PSI on 2450 PSI off 2400 RPM 120 TQ on 7-9 k TQ off 5-6k PUW125k SOW 95k RTW 100 k. SPR 6432'MD 4596'TVD PUMP #1 2 BPM 260 psi 3 BPM 410 psi Pump#2 2 BPM 250 psi 3 BPM 400 psi. Pump sweep every 300 feet, dilute mus as needed. 12/11/2014 TD well at 7039'MD 5062'TVD. Gas spike at BU, 9800 units. Weight up mud to 9.8 ppg, monitor well for 5 minutes, still flowing, Continue circulating, gas spike at BU 2700 units. Continue circulating,weight mud up to 10.5 ppg. Short trip, pump 10 stands out of the hole to 6149'. 00:00 03:30 3.50 6,813 7,039 INTRM1 DRILL DDRL P Drill 6 3/4"x 7 1/2"hole w/RSS& RU f/6813' t/7039'TD. TVD 5062' ADT 2.48 hrs ECD 11.4 MW 9.6 WOB 8 k GPM 345 PSI on 2560 PSI off 2500 RPM 120 TQ on 8 k TQ off 6.6k PUW125k SOW98k RTW 105 k. Well flow at BU, gas spike 9800 units. 03:30 07:30 4.00 7,039 7,039 INTRM1 CASING KLWL T Circulate and weight mud to 9.8 ppg. Recipricate while circulating RPM 60 GPM 345 2500 psi PUW 107 k SOW 103 k Monitor well for 5 minutes,well still flowing,weight mud up to 10 ppg. Gas spike at BU 2700 units. 07:30 12:00 4.50 7,039 7,004 INTRM1 CASING KLWL T Continue to build mud weight to 10.0 ppg. Flow check well for 15 minutes, well still flowing, stand 1 stand of drill pipe back. Drop RFID, continue circulating and build mud weight to 10.3 ppg, UR did not close. Continue circulating GPM 90 PSI 370 RPM 60 PUW 109 k SOW 107 k. SPR©7039' MD 5062'TVD Pump #1 @ 2 BPM 280 psi @ 3 BPM 450 psi. Pump#2 @ 2 BPM 280 psi @ 3 BPM 410 psi. 12:00 12:30 0.50 7,004 7,004 INTRM1 CASING KLWL T Circulate until 10.3 ppg mud in/out. SPR @ 7000' MD 5034'TVD Pump #1 @ 2 BPM/30 stks 330 psi @ 3 BPM/45 stks 510 psi. Pump#2© 2 BPM/30 stks 320 psi @ 3 BPM/ 45 stks 510 psi. 12:30 13:00 0.50 7,004 7,004 INTRM1 CASING OWFF T Monitor well for 30 minutes,well still flowing, .5 bbls gain in 30 minutes. Page 14 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 19:00 6.00 7,004 7,004 INTRMI CASING KLWL T Continue circulating building mud weight to 10.5 ppg. GPM 90 PSI 400 RPM 60 PUW 125 k SOW 98 k RTW 107 k. At BU gas spike of 457 units. SPR©7000' MD 5034' TVD Pump#1 ©2 BPM/30 stks 330 psi @ 3 BPM/45 stks 530 psi. Pump#2 @ 2 BPM/30 stks 330 psi @ 3 BPM 520 psi. 19:00 21:00 2.00 7,004 7,004 INTRM1 CASING KLWL T Continue to circulate 10.5 ppg mud until balanced. Mud weight in 10.5 ppg, mud weight out 10.6 ppg, mud U tubing up DP. 21:00 00:00 3.00 7,004 6,244 INTRMI CASING WPRT T Short trip/Pump 10 stands out of the hole f/7004 t/6149' GPM 90 SPM 30 RPM 60 TQ 6-7 k PUW 125 k SOW 98 k RTW 106 k. 12/12/2014 Short trip, pump 10 stands out f/7004't/6149'. Run back to bottom and circulate BU. Observe well flow for 65 minutes, well still flowing, circulate and condition mud. Pump out of the f/7004't/3578'. 00:00 00:30 0.50 6,244 6,149 INTRM1 CASING WPRT T Short trip/Pump 10 stands out of the hole f/6244't/6149'. GPM 41 SPM 16 RPM 60 TQ 6-7 k PUW 125 k SOW 98 k RTW 106 k. 00:30 02:00 1.50 6,149 7,004 INTRMI CASING WPRT T Run back in the hole f/6149 t/7004' Cal. Disp. 5.8 bbls Actual Disp. 3.2 bbls. No problems running back into the hole. 02:00 05:00 3.00 7,004 7,004 INTRMI CASING CIRC T Circulate and condition mud after short trip. Circulate BU BPM 2 SPM 29 PSI 450 RPM Units of gas 119 at BU. 05:00 06:00 1.00 7,004 7,004 INTRM1 CASING OWFF T Observe well for flow 65 minutes, 5.6 bbls total gain. 06:00 10:00 4.00 7,004 6,500 INTRM1 CASING CIRC T Circulate and condition mud MW 10.5 ppg SPM 14 GPM 41 PSI 295 TQ 7,2 k Recipricate f/7004't/ 6910'. Units of gas at BU 457. Observe well flow for 15 minutes, 1.3 bbl gain. 10:00 00:00 14.00 6,500 3,578 INTRM1 CASING TRIP P Pump out of the hole f/6500't/3578' BPM 1 SPM 14 GPM 40 PSI 285 PUW 75 k SOW 60 k. CAL hole fill 12 bbls Actual hole fill 7 bbls. 12/13/2014 Pump out of the hole to the Shoe. Circulate B/U and attempt to monitor well,well out of balance, Ciirculate and condition mud and monitor the well for 1 hr. POOH t/2342'circulate and condition mud. POOH to the HWDP at 627'and monitor well for 1 hr. L/D the HWDP and BHA. R/U and run 5 1/2"casing Shoe track. 00:00 02:30 2.50 3,578 2,810 INTRMI CASING TRIP P Pump out of the hole f/3578' t/2810' BPM 1 SPM 14 GPM 40 PSI 285 PUW75k SOW58k. Page 15 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 06:30 4.00 2,810 2,810 INTRM1 CASING CIRC T B/O TD to blow down,well out of balance and flow up DP. M/U TD and circulate 3 B/U to balance well. Mud wt 10.7 ppg in and 10.7 ppg out. B/O TD and observed well flow for 15 min., still flowing up the DP due to barite sag. M/U TD and circulate 2 B/U to balance well. 06:30 07:30 1.00 2,810 2,810 INTRM1 CASING OWFF T Monitor well flow for 1 hr strapping TT every 5 minutes. .3 bbl gain first 30 mins and .1 bbl gain last 30 minutes. Total gain over 1 hr.4 bbls. 07:30 09:00 1.50 2,810 2,342 INTRM1 CASING TRIP P POOH f/2810' t/2342' PUW 72 k SOW 60 k Cal Disp 2.71 bbls Actual Disp.4 bbls. 09:00 10:30 1.50 2,342 2,342 INTRM1 CASING OWFF T Circulate and condition mud, mud wt 10.7 ppg in/out. Monitor the well for flow 1 hr .1 bbl gain. 10:30 13:30 3.00 2,342 627 INTRM1 CASING TRIP P POOH f/2342' t/627' PUW 48 k SOW 48 k Cal fill 6 bbls Actula fill 4.5 bbls. 13:30 14:30 1.00 627 627 INTRM1 CASING OWFF P Monitor well for 1 hr, 0 bbl gain. Conduct pre-job safety meeting LID BHA. Well flow looks good, continue POOH. 14:30 21:00 6.50 627 0 INTRM1 CASING PULD P L/D HWDP and 6 3/4"x 7 1/2"BHA. Clean and clear floor of all tools, prepare to run 5 1/2"casing. 21:00 22:00 1.00 0 0 INTRM1 CASING RURD P Pull ware bushing,and perform dummy run with 5 1/2"hanger. 22:00 22:30 0.50 0 0 INTRM1 CASING RURD P P/U Volant running tool and air slips. 22:30 00:00 1.50 0 253 INTRM1 CASING PULD P P/U 5 1/2"casing Shoe track and run 3 joints of 5 1/2" 15.50# L-80 Hydril 563 casing. 12/14/2014 Run 5 1/2"casing f/253' t/2850'. Circulate and condition mud staging pumps f/1 BPM t/4 BPM. Run casing f/2850' t/4956' Circulate and condition mud staging pumps f/1 BPM t/4 BPM Continue running 5 1/2"casing. 00:00 09:30 9.50 253 2,850 INTRM1 CASINGPUTB P Run 5 1/2"casing f/253' t/2850' fill every JT and top off every 10. PUW 60 k SOW 50 k Mud wt 10.5 ppg. 09:30 10:30 1.00 2,850 2,850 INTRM1 CASING CIRC P Circulate and condition mud, pump 1 BPM staging up to 4 BPM. GPM 44 PSI 237 SPM 15 PUW 60 k SOW 50k Mud wt 10.5 ppg. 10:30 19:30 9.00 2,850 4,956 INTRM1 CASING PUTB P Run 5 1/2"casing f/2850' t/4956' fill every JT and toping off every 10. PUW89k SOW63k Mud wt10.5 Calc displ 9,3 bbls Actual 3.4 bbls. Page 16 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 00:00 4.50 4,956 5,168 INTRM1 CASING CIRC P Circulate and condition mud, staging pumps t/4 BPM, monitoring well for losses while pumping. A lot of sticky oily sand coming over the shakers. Stage pump to 4 BPM lost 1 BPM for a total loss of 8 bbls. Backed pump off to 3 BPM and losses went to 0. Continued running casing in the hole and gained back the 8 bbls lost. 12/15/2014 Run 5 1/2"casing to 7029', circulate and condition mud. R/U and cement casing, shoe 7029', FC 6943'. Set 7 5/8"x 5 1/2"pack-off, Freeze protect 7 5/8"x 5 1/2"annulus w/36 bbls of Isotherm to 2183'. 00:00 01:00 1.00 5,168 5,168 INTRM1 CASING CIRC P Circulate and codition mud, staging pumps to 4 BPM SPM 68 PSI 684 PUW 80 k SOW 60 k. 01:00 07:00 6.00 5,168 6,954 INTRM1 CASING PUTB P Run 5 1/2"casing f/5168' t/6954' PUW 116 k SOW 73 k Calc Disp 11.1 bbls Actual Disp-4,7 bbls. 07:00 08:30 1.50 6,954 7,029 INTRM1 CASING WASH P Wash f/6954' t/6996' M/U 5 1/2" Hanger and wash to 7029'TD GPM 36 PSI 317 SPM 12 PUW 116 k SOW 73 k. 08:30 13:30 5.00 7,029 7,029 INTRM1 CEMEN-CIRCP Circulate and codition mud for cement job. Install cement head and lines, continue circulating. GPM 47 PSI 312 SPM 17 BPM 1 MUD wt 10.5 ppg PUW 117 k SOW 75 k. 13:30 15:00 1.50 7,029 7,029 INTRM1 CEMEN-CMNT P Pump cement job 5 bbls CW100 PT cement lines pump 25 bbls CW100 30 bbls MP-2 11.0 ppg Drop bottom plug pump 68 bbls cement 15.8 ppg Drop top plug Flush lines w/ 10 bbls H2O Swap to rig pumps Displace 41 SPM 615 PSI Bump at 2657 stks @ 14:57 hrs Hold 1200 PSI for 15 minutes Check floats All good Loss of 34 bbls mud for cement job. Shoe @ 7029' FC @ 6943'. 15:00 17:00 2.00 7,029 7,029 INTRM1 CEMEN-RURD P R/D SLB and all cementing tools. Clear floor and prep for setting Pack-off. 17:00 18:30 1.50 7,029 7,029 INTRM1 CEMEN:WWSP P Set 5 1/2"x 7 5/8" Pack-off as per FMC rep. Test to 5000 psi for 10 minutes, good test. 18:30 19:30 1.00 7,029 7,029 INTRM1 CEMEN-RURD P L/D Pack-off running tools. 19:30 20:30 1.00 7,029 7,029 INTRM1 CEMEN-SVRG P Service rig 20:30 21:30 1.00 7,029 7,029 INTRM1 CEMEN-PULD P L/D 4"DP, racked in the derrick, in secondary mouse hole. 21:30 00:00 2.50 7,029 7,029 INTRM1 CEMEN FRZP P Freeze protect 7 5/8"x 5 1/2" annulus with 36 bbls of Isotherm to 2183'. 12/16/2014 L/D 71 stands of DP out of the derrcik. Wash BOP stack and change top and bottom rams to 2 7/8"x 5" VBR's. Test BOPE and alarms,test witnessed by Matt Herrera AOGCC Rep. Page 17 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 10:00 10.00 0 0 INTRM1 CEMEN-PULD P L/D 71 stands of 4" DP using Mouse Hole. 10:00 12:00 2.00 0 0 INTRM1 WHDBO RURD P Pull ware bushiing,flush stack and install test plug. 12:00 17:00 5.00 0 0 INTRM1 WHDBO OTHR P Install top and bottoms rams 2 7/8" x 5"VBR's. Prep Cellar and floor for BOPE test. 17:00 00:00 7.00 0 0 INTRMI WHDBO BOPE P BOPE test witnessed by Matt Herrera AOGCC Rep. Test H2S/LEL alarms. Test BOPE and Choke Manifold to 250 low/3500 psi high. Super Choke tested to 250 low/ 1000 psi high. 12/17/2014 Complete BOPE testing,test 5.5"casing to 3000 psi for 30 minutes. P/U 4 3/4" BHA#2/2 7/8" DP and run in the hole to 1500'. Shallow hole test MWD tools,test good. Service rig and continue to P/U 2 7/8" DP. 00:00 01:00 1.00 0 0 INTRM1 WHDBO BOPE P Continue BOPE test Perform AOGGC Koomey test and CPAI Draw Down test. CPAI Draw Down/ shut off air and electic pumps/close valve to Koomey bottles/close Rams and 1 HCR/start air pumps/ 0 psi-2500 psi=3 min 52 secs Close Rams and 1 HCR/start electric pump/0 psi-3000 psi= 1 min 2 secs. 01:00 05:00 4.00 0 0 INTRM1 WHDBO RURD P R/D test equipment, prep to P/U 2 7/8"DP. 05:00 06:00 1.00 0 0 INTRM1 CEMEN-PRTS P Pressure test 5 1/2"casing to 3000 psi for 30 minutes 06:00 10:00 4.00 0 0 INTRM1 CEMEN RURD P Move the 2 7/8"DP from the pipe shed to P/U the 4 3/4" BHA#2. 10:00 15:00 5.00 0 182 INTRMI CEMEN PULD P P/U 4 3/4"BHA#2 f/64' t/182' 15:00 22:30 7.50 182 1,500 INTRM1 CEMEN PULD P P/U 2 7/8" DP f/182' t/1500' 22:30 23:30 1.00 1,500 1,500 INTRM1 CEMEN'DHEQ P Test MWD tools @ 1500' GPM 130 SPM 39 PSI 1000 PUW 45 k SOW 45 k. 23:30 00:00 0.50 1,500 1,500 INTRM1 CEMEN SVRG P Service rig/install breather cap covers/brake fluid/wash pipe. 12/18/2014 P/U 2 7/8"DP/TIH/tag cement 6824'. Ream/wash cement to FC 6938'. Drill FC and cement to 7011'. 00:00 00:30 0.50 1,500 1,500 INTRM1 CEMEN-SEQP P Pressure test 2 7/8"TIW valve t/250 psi low/3500 psi high. 00:30 12:00 11.50 1,500 6,824 INTRM1 CEMEN-PULD P P/U 2 7/8"DP/TIH f/1500' t/6824' PUW 90 k SOW 65 k Calc. Disp. 54.8 bbls Actual Disp. 57.2 bbls. 12:00 14:00 2.00 6,824 6,917 INTRMI CEMEN-COCF P Ream/Wash cement f/6824 U 6917' GPM 110 SPM 38 PSI 1815 PUW95k SOW65k WOB2-5k. 14:00 16:30 2.50 6,917 6,917 INTRM1 CEMEN-RGRP T Service TD, grabber dies for 2 7/8" DP are worn. Unable to hold back-up. Change out grabber dies. 16:30 17:30 1.00 6,917 6,917 INTRMI CEMEN-CIRCP Circulate B/U 6917' GPM 114 SPM 39 PSI 1850 PUW 95 k SOW 65 k. Adjust cuttings box chute to allwo cuttings to move away from the bottom of tank. Page 18 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 19:30 2.00 6,917 6,938 INTRM1 CEMEN-COCF P Ream/wash cemnt f/6917' t/6938' GPM 115-120 SPM 39-43 PSI 1950 RPM 30 TQ 4-5 k PUW 98 k SOW 65 k RTW 75 k 19:30 00:00 4.50 6,938 7,011 INTRM1 CEMEN-DRLG P Tag float collar 6938' /control drill f/ 6938' t/7011' WOB2-4k GPM 130 SPM 44 PSI on 1850 PSI off 1750 RPM 30 TQ on 4-5 k TQ off 4-4.5 k PUW 100 k SOW 65 k Mud wt 10.5 ppg. 12/19/2014 Circulate and condition mud, bring mud wt up to 10.5 ppg. Drill out the shoe track and 20'of new hole. Circulate B/U and pull back to shoe and perform FIT/1480 psi/16.0 ppg EMW. Drill f/7059' t/7400' 00:00 02:00 2.00 I 7,011 7,011 INTRM1 CEMEN CIRC P Circulate and condition mud/bring mud wt up to 10.5 ppg all the way around. GPM 120 SPM 41 PSI 1844 PUW76k SOW73k. 02:00 05:00 3.00 7,011 7,059 INTRM1 CEMEN-DRLG P Drill out shoe track and 20'of new hole f/7011' t/7059'. GPM 140 SPM 46 PSI on 1957 PSI off 1933 TQon4k TQoff4k WOB5-10k RTW 75 k. 05:00 06:00 1.00 7,059 7,059 INTRM1 CEMEN-CIRC P Circulate and condition mud/pump B/U GPM 144 SPM 46 PSI 1945 PUW 105 k SOW 65 k RTW 73 k. 06:00 07:00 1.00 7,059 7,007 INTRM1 CEMEN PULD P L/D 3 Jts of DP/ f/7059' t/7007' 07:00 08:00 1.00 7,007 7,007 INTRM1 CEMEN FIT P Perform FIT/1480 psi EMW 16.0/ Good Test 08:00 10:30 2.50 7,007 7,059 PROD1 DRILL DISP P Displace well with new mud/10.5 ppg LSND GPM 130 PSI 2060 SPM 53 PUW 11 k SOW 60 k. P/U 3 Jts of DP t/7059'. 10:30 12:00 1.50 7,059 7,106 PROD1 DRILL DDRL P Drill f/7059' t/7106' WOB 3-6 k GPM 140 PSI on 2850 PSI off 2650 RPM 50-80 TQon4-4.5k TQ off 3.5-4.3k PUW110k SOW62k RTW 74 k ADT 1.17 hrs. SPR's taken at 12:00 hrs MD 7098' TVD 5112' MW 10.5 ppg. Pump#1 @ 2 bpm 660 psi #2 @ 3 bpm 1210 psi. Pump#2 @ 2 bpm 580 psi #2 @ 3 bpm 1120 psi Page 19 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 7,106 7,396 PROD1 DRILL DDRLI P Drill f/7106' t/7396' WOB 3-6 k GPM 140 PSI on 2850 PSI off 2650 RPM 50-80 TQ on 4-4.5 k TQ off 3.5-4.3k PUW 114k SOW62k RTW 77 k ADT 8 hrs.AST 2.5,Total Bit hrs=9.64 hrs, Total Jar hrs= 9.64 hrs, Slide as needed. SPR's taken at 12:00 hrs MD 7098' TVD 5112' MW 10.5 ppg. Pump#1 @ 2 bpm 660 psi #2 @ 3 bpm 1210 psi. Pump#2 @ 2 bpm 580 psi #2 @ 3 bpm 1120 psi 12/20/2014 Weight up mud system to 10.7 ppg, TD well at 7667'. Circulate and condition mud 2 B/U, observe well for flow 15 minutes, no flow. POOH to shoe 7029', circulate and condition mud, observe well for flow 15 minutes, no flow. POOH laying down 2 7/8' DP. 00:00 03:00 3.00 7,396 7,396 PROD1 DRILL CIRC P Weight circulating system up from 10.5 ppg to 10.7 ppg while rotating and reciprocatingfrom 7,330-ft to 7,394-ft at(57 spm) 140 gpm @ 2,675 psi, rotating @ 50 rpm w/3.81 free torque. UP wt- 112k and DN wt -62k and ROT wt-75k 03:00 11:30 8.50 7,396 7,667 PROD1 DRILL DDRL P Drill f/7396' t/7667' WOB 3-6 k GPM 140 PSI on 2850 PSI off 2650 RPM 50-80 TQ on4-4.5k TQ off 3.5-4.3k PUW 114k SOW62k RTW 77 k ADT 8 hrs.AST 2.5, Total Bit hrs=9.64 hrs,Total Jar hrs= 9.64 hrs, Slide as needed. SPR's taken at 12:00 hrs MD 7098' TVD 5112' MW 10.5 ppg. Pump#1 @ 2 bpm 660 psi #2 @ 3 bpm 1210 psi. Pump#2 @ 2 bpm 580 psi #2 @ 3 bpm 1120 psi 11:30 13:00 1.50 7,667 7,667 PROD1 CASING CIRC P Circulate and condition mud, pump B/U GPM 140 SPM 56 PSI 2775 RPM 55 TQON4k PUW117k SOW 63k RTW76k Mud wt in/out 19.8 ppg. SPR's taken at 13:00 hrs 7637'MD 5524'TVD Pump#1 @ 1 BPM 650 psi @ 2 BPM 1320 psi Pump#2 @ 1 BPM 650 psi @ 2 BPM 1280 psi 13:00 13:30 0.50 7,667 7,667 PROD1 CASING OWFF P Observe well for flow 15 munites/not flow, looks good. Prep shed for 2 7/8"DP while observing flow. 13:30 16:30 3.00 7,667 7,011 PROD1 CASING PULD P POOH laying down 2 7/8"DP f/ 7667' t/7011' PUW 103 k SOW 63 k Calc fill 3.3 bbls Actual fill 3.7 bbls. Page 20 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:30 2.00 7,011 7,011 IPROD1 iCASING CIRC P Circulate and condition mud at the shoe 7029' GPM 125 SPM 53 PSI 2300 PUW 103 k SOW 63 k. At B/U/58 Units of gas. Obsrve well for flow 15 minutes/not flow, looks good. 18:30 00:00 5.50 7,011 4,650 PROD1 CASING PULD P POOH laying down 2 7/8"DP f/ 7011' t/4650' PUW 75 k SOW 50 k Calc fill 9 bbls Actual fill 10.4 bbls. 12/21/2014 Lay down 2 7/18" DP and 4 3/4" BHA, R/U the Dutch riser and Haliburton wireline, Run in the hole with logging tools, could not go past 3012'. POOH and P/U WellTech Tractor. 00:00 07:00 7.00 4,650 182 PROD1 CASING PULD P Lay down 2 7/8"DP f/4650 t/182' PUW 75 k SOW 50 k Calc disp 32 bbls Actual disp 29.3 bbls 07:00 12:00 5.00 182 0 PROD1 CASING PULD P Lay down 4 3/4"BHA#2 and all SLB running tools. 12:00 14:00 2.00 0 0 PROD1 EVALFN ELOG P R/D GBR tools, clear the floor and intall the Dutch riser. 14:00 14:30 0.50 0 0 PROD1 EVALFN SFTY P Pre-job safety meeting/R/U wireline tools. 14:30 18:00 3.50 0 0 PROD1 EVALFN ELOG P R/U wireline to perform logging run/ GR/RES/NEUT/DENS Allow tools to warm up/function test tools. 18:00 22:00 4.00 0 0 PROD1 EVALFN ELOG T RIH with Haliburton wireline to perform open hole log/ GR/RES/NEUT/DENS. Could not get tools to go past 3012'. 22:00 00:00 2.00 0 0 PROD1 EVALFN FLOG T R/U WeIlTech Tractor with Haliburton logging tools. 12/22/2014 Run Haliburton E line/WeIlTech Tractor for open hole logs /GR/RES/NEUT/DENS. Load PH6 work string into pipe shed. Rig up and run 3 1/2" Production liner on PH6 work string. 00:00 04:30 4.50 0 0 PROD1 EVALFN ELOG P Run in the hole with Haliburton E line and WeIlTech Tractor for open hole logs/GR/RES/NEUT/Dens. 04:30 10:00 5.50 0 0 PROD1 EVALFN ELOG P R/D wireline, Dutch riser and all Haliburton/ WeIlTech tools. Continue loading the PH6 work string into the pipe shed. Prep rig to run 3 1/2"liner. 10:00 12:00 2.00 0 0 COMPZ CASING SVRG P Service rig/TP/Crown/Drawworks /Housekeeping 12:00 14:30 2.50 0 0 COMPZ CASING RURD P Finish rigging up for 3 1/2"Hydril 511 Production Liner run. 14:30 15:00 0.50 0 0 COMPZ CASING SFTY P Pre-job safety meeting/Running 3/1/2"Liner. 15:00 21:00 6.00 0 0 COMPZ CASING PUTB P Run 3 1/2"Shoe Track/Production liner w/FLEXLOCK HANGER/ZXP PACKER/Length 842', fill every 15 joints. 21:00 21:30 0.50 0 0 COMPZ CASING CIRC P Circulate and condition mud/SPM 87/BPM 5/PSI 710, circulate B/U. Page 21 of 24 v • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 0 0 COMPZ CASING RUNL P Run 3 1/2"liner on PH6 work string f/842' t/1783'/PUW 50 k/SOW 47 k/fill every 15 stands. (When circulating keep ECD's below 13.1 and do not exceed 1800 psi.) 12/23/2014 Run 3 1/2"Liner to the 5 1/2"shoe. Circulate and condition mud. Run 3 1/2"Liner to TD 7667'. Circulate and condition mud, pump 2 B/U at Liner shoe depth 7658'. 00:00 16:00 16.00 1,783 7,005 COMPZ CASING RUNL P Run in the hole with 3 1/2"Liner on PH6 work string. f/1783' t/6222'. PUW 98 k SOW 52 k Calc fill 28.7 bbks Actual fill 29.6 bbls/fill every 15 stands. 16:00 18:00 2.00 7,005 7,005 COMPZ CASING CIRC P Circulate and condition mud at the 5 1/2"casing shoe 7,029'. GPM 81 SPM 35 ICP 1200 FCP 830 PUW 117 k SOW 61 k 1080 units of gas at B/U, circulae 10.8 ppg mud S/S. 18:00 21:30 3.50 7,005 7,667 COMPZ CASING RUNL P Run in the hole with 3 1/2"Liner on PH6 work string f/7005' U 7667'TD. 21:30 22:30 1.00 7,667 7,667 COMPZ CEMEN-RURD P R/U cement lines and Baker Cement head. 22:30 00:00 1.50 7,667 7,658 COMPZ CEMEN-CIRCP Circulate 2 B/U, stage pumps up to 2 BPM. PUW 125 k SOW 62 k 1 BPM 815 psi 1.5 BPM 990 psi 2 BPM 880 psi ECD's 11.2. Recipricate 10'-20'/7638'-7658' 12/24/2014 Cement the 3 1/2"Production Liner and displace the well with completion fluids. Lay down the PH6 work string and Baker running tools. 00:00 03:00 3.00 7,658 7,658 COMPZ CEMEN-CMNT P Cement 3 1/2" Production Liner/ Shoe 7658' /Top of Lap 6816'. PUW 125 k SOW 62 k. Pump 5 bbls of water/pressure test cement linges to 4000 psi/Pump 10 bbls CW100/Pump 12 bbls MudPush II/ Pump 15.5 bbls cement/Pump.5 bbls water/Drop dart/Pump 10 bbls water/Swap to rig for displacement/displace at 3 BPM/ slow pumps at last 10 bbls/stop reciprocating Liner/Space out 213' above the intermediate casing/ Bump plug at 791 strokes 1200 psi/ pressure to 1700 psi for 5 minutes/ Set liner per BOT 4000 psi. /Bleed pressure to 0 and check floats for flow back, float good. 03:00 08.30 5.50 7,658 7,658 COMPZ WELLPF DISP P Diplace to completion fluid/35 bbls high vis spacer/250 bbls 9.7 ppg brine/35 bbls high vis spacer/180 bbls 8.5 ppg seawater/5 BPM PSI 1859 GPM 211 SPM 87. 08:30 09:00 0.50 7,658 7,658 COMPZ WELLPF OWFF P Observe well for flow/No flow 09:00 10:00 1.00 7,658 7,658 COMPZ WELLPF SVRG P Service rig/TD/Crown/Drawworks. Page 22 of 24 r • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 17:00 7.00 6,724 3,000 COMPZ WELLPF PULD P Lay down PH6 work string f/6724' t/ 6285' PUW 70 k SOW 55 k. Calc fill 15.4 bbls Actual fill 16 bbls. 17:00 19:00 2.00 3,000 3,000 COMPZ WELLPF SLPC P Slip and cut 110'of drilling line. 19:00 00:00 5.00 3,000 0 COMPZ WELLPF PULD P lay down PH6 work string and Baker running tools f/3000' t/0'. 12/25/2014 Prepare to run 3.5"Completion string. Run 5.5"tubing to 6798'. Circulate seawater Surface to Surface. Teat casing to 3000 psi for 30 minutes. Space out 7"above fully located position/6840'. 00:00 03:00 3.00 0 0 COMPZ WELLPF RURD P Wash and clean the top of the 5.5" hanger. Pull ware bushing and prepare to run 3.5"tubing completion string. 03:00 18:30 15.50 0 6,798 COMPZ RPCOM PUTB P P/U 3.5"completion string to 6798'. PUW 95 k SOW 56 k Calc Disp 11 bbls Actual Disp 11.2 bbls. 18:30 20:00 1.50 6,798 6,798 COMPZ RPCOM CIRC P Circulate and condition with seawater Surface to Surface/2.5 BPM PSI 450 STKS 45. 20:00 21:00 1.00 6,798 6,798 COMPZ RPCOM PRTS P Pressure test 5.5"casing to 3000 psi /30 minutes/ Test good. 21:00 22:00 1.00 6,798 6,798 COMPZ RPCOM RURD P R/U equipment for Space Out 22:00 00:00 2.00 6,798 6,840 COMPZ RPCOM HOSO P Tag at 6847'/set down 15 k to confirm/PUW 95 k SOW 55 k. L/D joints 217, 216, and 215. Space Out w/2 pups 10.15', and 4.19'/joint 215 below the tubing hanger /land at 6839.89'. 7'above fully located position. 12/26/2014 Spot CI/seawater pill from setting sleeve to SOV. Land hanger,test tubing, casing and shear out. Change rams in BOP's, N/D BOPE and N/U tree. 00:00 00:30 0.50 6,840 6,840 COMPZ RPCOM THGR P P/U landing joint and M/U 3.5" tubing hanger 00:30 02:30 2.00 6,840 6,940 COMPZ RPCOM CRIH P Circulate and spot CI/seawater pill f/setting sleeve t/SOV. BPM 1.5 PSI 95/shut down and let fluids equalize. 02:30 03:30 1.00 6,940 6,940 COMPZ RPCOM THGR P Land hanger and run in LD's. 03:30 08:00 4.50 6,940 6,940 COMPZ RPCOM PRTS P Pressure test tubing to 3000 psi for 30 minutes/good. Pressure test IA to 2500 psi for 30 minutes/good. Bleed pressure off and Shear Out (SOV). L/D landing joint and install Two way check. 08:00 12:30 4.50 6,940 6,940 COMPZ RPCOM RURD P Clean and clear rig floor of all tools. Clean sumps, pits, rotary table and L/D mouse hole 12:30 17:00 4.50 6,940 6,940 COMPZ RPCOM BOPE P Change rams in BOP's to 3.5"x 6" VBR's. 17:00 19:30 2.50 6,940 6,940 COMPZ WHDBO NUND P N/D BOPE and clean-up well head for adapter flange. 19:30 00:00 4.50 6,940 6,940 COMPZ WHDBO NUND P Pad operator verified correct orientation of tree. N/U tree and test to 5000 psi/test good. Page 23 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/27/2014 24 hr Summary Freeze protect well, secure well head&cellar, finish cleaning pits, prep floor V move, Move rig V 2N-336 00:00 02:00 2.00 6,940 0 COMPZ WHDBO FRZP P R/U and Freeze Protect well w/LRS R/D Hard Lines 02:00 04:00 2.00 0 0 DEMOB MOVE RURD P Secure Well Install gauges clean cellar 04:00 12:00 8.00 0 0 DEMOB MOVE RURD P Finish Cleaning Pits, prep V move rig, remove hard lines V tiger tank, take down secondary containment. Prep floor V move rig released @ 1200 hrs Move rig V 2N-336 Page 24 of 24 NADConversion Kuparuk River Unit Kuparuk 2N Pad 2N-337C Definitive Survey Report N A D 2 7] 07 January, 2015 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project: Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellbore: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Project Kuparuk River Unit,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 2N-337 Well Position +N/-S 0.00 usft Northing: 5,911,892.60 usft Latitude: 70°10'12.816 N +E/-W 0.00 usft Easting: 460,596.52 usft Longitude: 150°19'1.635 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.90 usft Wellbore 2N-337C Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2014 11/25/2014 18.83 80.75 57,548 Design 2N-337C Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 2,824.36 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°l 28.07 0.00 0.00 242.00 Survey Program Date 1/7/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 251.07 2,824.36 2N-337(2N-337) MWD MWD-Standard 4/4/2001 12:00:C 2,901.28 2,970.71 2N-337C Srvy#1-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 2:2; 3,062.04 3,062.04 2N-337C Srvy#2-Inc+Trend(2N-337C) INC+TREND Inclinometer+known azi trend 12/12/2014 4:1 3,159.40 7,002.69 2N-337C Srvy#3-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 4:27 7,086.06 7,086.06 2N-337C Srvy#4-Inc+Trend(2N-337C) INC+TREND Inclinometer+known azi trend 12/12/2014 9:32 7,121.53 7,617.42 2N-337C Srvy#5-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 9:3! Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 28.07 0.00 0.00 28.07 -120.90 0.00 0.00 5,911,892.60 460,596.52 0.00 000 UNDEFINED 251.07 0.67 142.46 251.06 102.09 -1.03 0.79 5,911,891.56 460,597.31 0.30 -0.22 MWD(1) 341.81 1.88 183.94 341.78 192.81 -2.94 1.02 5,911,889.66 460,597.52 1.60 0.48 MWD(1) 432.50 4.16 198.23 432.34 283.37 -7.55 -0.12 5,911,885.05 460,596.37 2.63 3.65 MWD(1) 521.09 7.44 200.71 520.47 371.50 -15.97 -3,15 5,911,876.65 460,593.29 3.71 10.28 MWD(1) 608.00 10.40 208.49 606.32 457.35 -28.13 -8.88 5,911,864.52 460,587.49 3.67 21.05 MWD(1) 699.69 14.01 205.01 695.92 546.95 -45.47 -17.53 5,911,847.23 460,578.76 4.02 36.82 MWD(1) 790.35 16.01 197.19 783.49 634.52 -67.36 -25.86 5,911,825.38 460,570.31 3.14 54.46 MWD(1) 880.62 15.80 199.98 870.31 721.34 -90.80 -33.74 5,911,801.98 460,562.31 0.88 72.42 MWD(1) 971.65 15.43 200.52 957.98 809.01 -113.79 -42.22 5,911,779.04 460,553.71 0.44 90.70 MWD(1) 1/7/2015 1:00:01PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellbore: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,062.27 16.20 198.91 1,045.17 896.20 -137.04 -50.54 5,911,755.84 460,545.27 0.98 108.96 MWD(1) 1,153.94 16.29 200.42 1,133.18 984.21 -161.19 -59.17 5,911,731.74 460,536.51 0.47 127.92 MWD(1) 1,245.36 19.29 203.95 1,220.22 1,071.25 -187.01 -69.78 5,911,705.98 460,525.78 3.49 149.41 MWD(1) 1,338.99 21.32 212.44 1,308.05 1,159.08 -215.52 -85.19 5,911,677.55 460,510.22 3.82 176.40 MWD(1) 1,434.74 22.74 218.59 1,396.82 1,247.85 -244.68 -106.08 5,911,648.50 460,489.18 2.83 208.53 MWD(1) 1,529.84 25.33 225.21 1,483.68 1,334.71 -273.39 -131.99 5,911,619.93 460,463.12 3.93 244.89 MWD(1) 1,623.40 29.03 229.10 1,566.90 1,417.93 -302.36 -163.36 5,911,591.12 460,431.60 4.39 286.19 MWD(1) 1,718.10 32.88 228.72 1,648.10 1,499.13 -334.38 -200.06 5,911,559.30 460,394.74 4.07 333.62 MWD(1) 1,813.70 35.91 229.19 1,726.97 1,578.00 -369.83 -240.79 5,911,524.07 460,353.83 3.18 386.23 MWD(1) 1,909.20 39.76 229.54 1,802.38 1,653.41 -407.96 -285.24 5,911,486.17 460,309.19 4.04 443.38 MWD(1) 2,004.27 42.92 230.64 1,873.75 1,724.78 -448.23 -333.42 5,911,446.15 460,260.81 3.41 504.82 MWD(1) 2,096.57 46.32 231.94 1,939.44 1,790.47 -488.75 -384.01 5,911,405.90 460,210.01 3.81 568.51 MWD(1) 2,192.04 50.23 235.27 2,002.98 1,854.01 -530.96 -441.38 5,911,364.00 460,152.43 4.85 638.98 MWD(1) 2,286.81 54.04 235.82 2,061.14 1,912.17 -573.27 -503.06 5,911,322.01 460,090.53 4.05 713.31 MWD(1) 2,379.83 57.86 237.48 2,113.22 1,964.25 -615.61 -567.44 5,911,280.01 460,025.94 4.36 790.03 MWD(1) 2,475.68 61.89 238.43 2,161.31 2,012.34 -659.58 -637.70 5,911,236.42 459,955.46 4.29 872.71 MWD(1) 2,569.38 65.42 239.52 2,202.89 2,053.92 -702.84 -709.65 5,911,193.54 459,883.29 3.91 956.55 MWD(1) 2,662.68 67.66 239.74 2,240.03 2,091.06 -746.10 -783.49 5,911,150.66 459,809.23 2.41 1,042.06 MWD(1) 2,757.85 69.03 240.81 2,275.15 2,126.18 -789.96 -860.30 5,911,107.21 459,732.20 1.78 1,130.47 MWD(1) 2,824.43 68.76 241.33 2,299.12 2,150.15 -820.00 -914.67 5,911,077.45 459,677.69 0.83 1,192.57 MWD(1) 2,858.00 69.13 238.98 2,311.19 2,162.22 -835.59 -941.84 5,911,062.00 459,650.44 6.62 1,223.88 MWD+IFR-AK-CAZ-SC(2) 74/8"x 9-7/8" 2,901.28 69.65 235.97 2,326.43 2,177.46 -857.37 -975.99 5,911,040.40 459,616.18 6.62 1,264.26 MWD+IFR-AK-CAZ-SC(2) 2,970.71 69.26 233.13 2,350.80 2,201.83 -895.07 -1,028.94 5,911,002.98 459,563.03 3.87 1,328.72 MWD+IFR-AK-CAZSC(2) 3,062.04 69.50 234.40 2,382.96 2,233.99 -945.60 -1,097.89 5,910,952.82 459,493.83 1.33 1,413.31 INC+TREND(3) 3,159.40 68.94 232.94 2,417.50 2,268.53 -999.52 -1,171.22 5,910,899.29 459,420.23 1.52 1,503.37 MWD+IFR-AK-CAZ-SC(4) 3,253.21 67.81 236.86 2,452.09 2,303.12 -1,049.66 -1,242.54 5,910,849.52 459,348.65 4.07 1,589.89 MWD+IFR-AK-CAZ-SC(4) 3,349.78 67.69 234.87 2,488.66 2,339.69 -1,099.81 -1,316.52 5,910,799.76 459,274.42 1.91 1,678.75 MWD+IFR-AK-CAZ-SC(4) 3,445.53 67.70 234.57 2,525.00 2,376.03 -1,150.98 -1,388.84 5,910,748.98 459,201.85 0.29 1,766.62 MWD+IFR-AK-CAZ-SC(4) 3,543.39 68.38 237.86 2,561.60 2,412.63 -1,201.43 -1,464.26 5,910,698.92 459,126.17 3.19 1,856.90 MWD+IFR-AK-CAZ-SC(4) 3,636.92 64.84 239.48 2,598.73 2,449.76 -1,246.08 -1,537.56 5,910,654.67 459,052.64 4.11 1,942.58 MWD+IFR-AK-CAZ-SC(4) 3,729.74 61.01 241.52 2,640.97 2,492.00 -1,286.78 -1,609.46 5,910,614.34 458,980.54 4.57 2,025.18 MWD+IFR-AK-CAZ-SC(4) 3,827.93 59.07 241.56 2,690.00 2,541.03 -1,327.32 -1,684.25 5,910,574.19 458,905.55 1.98 2,110.24 MWD+IFR-AK-CAZ-SC(4) 3,923.89 56.71 242.77 2,741.01 2,592.04 -1,365.28 -1,756.11 5,910,536.62 458,833.50 2.68 2,191.52 MWD+IFR-AK-CAZSC(4) 4,019.20 54.43 243.01 2,794.89 2,645.92 -1,401.10 -1,826.08 5,910,501.16 458,763.35 2.40 2,270.12 MWD+IFR-AK-CAZ-SC(4) 4,114.30 51.28 244.11 2,852.31 2,703.34 -1,434.87 -1,893.94 5,910,467.76 458,695.32 3.44 2,345.88 MWD+IFR-AK-CAZ-SC(4) 4,208.94 47.79 243.19 2,913.72 2,764.75 -1,466.80 -1,958.46 5,910,436.16 458,630.64 3.76 2,417.84 MWD+IFR-AK-CAZ-SC(4) 4,303.02 45.17 240.59 2,978.51 2,829.54 -1,498.91 -2,018.63 5,910,404.37 458,570.31 3.43 2,486.04 MW3+IFR-AK-CAZ-SC(4) 4,397.47 41.98 239.50 3,046.93 2,897.96 -1,531.40 -2,075.04 5,910,372.18 458,513.74 3.47 2,551.10 MWD+IFR-AK-CAZ-SC(4) 4,492.93 39.06 240.88 3,119.49 2,970.52 -1,562.24 -2,128.84 5,910,341.61 458,459.79 3.20 2,613.08 MWD+IFR-AK-CAZ-SC(4) 1/7/2015 1:00:01PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellborn: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD 1VDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 4,587.04 39.76 241.70 3,192.20 3,043.23 -1,590.94 -2,181.24 5,910,313.19 458,407.24 0.93 2,672.82 MWD+IFR-AK-CAZ-SC(4) 4,683.05 39.90 242.17 3,265.93 3,116.96 -1,619.87 -2,235.50 5,910,284.55 458,352.83 0.35 2,734.32 MWD+IFR-AK-CAZ-SC(4) 4,777.88 40.23 241.46 3,338.50 3,189.53 -1,648.70 -2,289.30 5,910,256.00 458,298.89 0.59 2,795.35 MWD+IFR-AK-CAZ-SC(4) 4,873.88 40.24 241.86 3,411.79 3,262.82 -1,678.14 -2,343.88 5,910,226.85 458,244.17 0.27 2,857.36 MWD+IFR-AK-CAZ-SC(4) 4,967.03 40.31 241.85 3,482.86 3,333.89 -1,706.54 -2,396.98 5,910,198.73 458,190.93 0.08 2,917.58 MWD+IFR-AK-CAZ-SC(4) 5,062.66 40.27 242.63 3,555.80 3,406.83 -1,735.35 -2,451.70 5,910,170.21 458,136.06 0.53 2,979.42 M1MD+IFR-AK-CAZ-SC(4) 5,159.81 40.37 241.39 3,629.88 3,480.91 -1,764.85 -2,507.20 5,910,141.00 458,080.41 0.83 3,042.28 MWD+IFR-AK-CAZ-SC(4) 5,255.05 40.61 241.23 3,702.31 3,553.34 -1,794.54 -2,561.45 5,910,111.60 458,026.01 0.27 3,104.11 MWD+IFR-AK-CAZ-SC(4) 5,350.59 40.58 239.88 3,774.86 3,625.89 -1,825.10 -2,615.59 5,910,081.33 457,971.72 0.92 3,166.26 MWD+IFR-AK-CAZSC(4) 5,445.60 40.46 238.20 3,847.08 3,698.11 -1,856.85 -2,668.52 5,910,049.85 457,918.63 1.16 3,227.90 MWD+IFR-AK-CAZ-SC(4) 5,540.74 40.61 239.04 3,919.39 3,770.42 -1,889.04 -2,721.31 5,910,017.93 457,865.68 0.60 3,289.62 MWD+IFR-AK-CAZ-SC(4) 5,636.18 40.69 240.76 3,991.80 3,842.83 -1,920.22 -2,775.09 5,909,987.04 457,811.74 1.18 3,351.75 MW1J+IFR-AK-CAZ-SC(4) 5,730.60 40.57 242.18 4,063.46 3,914.49 -1,949.59 -2,829.11 5,909,957.96 457,757.58 0.99 3,413.23 MWD+IFR-AK-CAZ-SC(4) 5,825.66 40.63 242.08 4,135.64 3,986.67 -1,978.51 -2,883.79 5,909,929.33 457,702.75 0.09 3,475.09 MWD+IFR-AK-CAZSC(4) 5,921.02 40.67 241.95 4,207.99 4,059.02 -2,007.65 -2,938.65 5,909,900.47 457,647.75 0.10 3,537.21 MWD+IFR-AK-CAZSC(4) 6,015.74 40.65 242.71 4,279.84 4,130.87 -2,036.31 -2,993.31 5,909,872.10 457,592.95 0.52 3,598.93 MVVD+IFR-AK-CAZ-SC(4) 6,113.41 40.54 242.14 4,354.01 4,205.04 -2,065.73 -3,049.64 5,909,842.97 457,536.46 0.40 3,662.48 MW1J+IFR-AK-CAZ-SC(4) 6,211.84 40.66 241.05 4,428.74 4,279.77 -2,096.20 -3,105.98 5,909,812.80 457,479.97 0.73 3,726.53 MWD+IFR-AK-CAZSC(4) 6,306.42 40.70 240.59 4,500.47 4,351.50 -2,126.26 -3,159.81 5,909,783.03 457,425.99 0.32 3,788.17 MWD+IFR-AK-CAZ-SC(4) 6,395.21 40.06 241.35 4,568.11 4,419.14 -2,154.18 -3,210.10 5,909,755.37 457,375.56 0.91 3,845.68 MWD+IFR-AK-CAZSC(4) 6,490.35 40.16 240.69 4,640.87 4,491.90 -2,183.88 -3,263.72 5,909,725.96 457,321.79 0.46 3,906.96 MWD+IFR-AK-CAZ-SC(4) 6,586.45 40.02 240.87 4,714.39 4,565.42 -2,214.09 -3,317.74 5,909,696.03 457,267.63 0.19 3,968.84 MWD+IFR-AK-CAZ-SC(4) 6,681.62 39.90 240.55 4,787.34 4,638.37 -2,243.99 -3,371.04 5,909,666.41 457,214.17 0.25 4,029.95 M1MD+IFR-AK-CAZSC(4) 6,776.36 40.12 241.69 4,859.90 4,710.93 -2,273.41 -3,424.38 5,909,637.28 457,160.69 0.81 4,090.85 MWD+IFR-AK-CAZSC(4) 6,872.45 40.03 242.35 4,933.43 4,784.46 -2,302.43 -3,479.01 5,909,608.54 457,105.91 0.45 4,152.71 MWD+IFR-AK-CAZSC(4) 6,967.93 39.68 242.60 5,006.73 4,857.76 -2,330.71 -3,533.27 5,909,580.55 457,051.51 0.40 4,213.89 MWD+IFR-AK-CAZ-SC(4) 7,002.69 40.01 242.27 5,033.42 4,884.45 -2,341.01 -3,553.01 5,909,570.35 457,031.72 1.13 4,236.16 MWD+IFR-AK-CAZ-SC(4) 7,029.00 39.80 243.22 5,053.60 4,904.63 -2,348.74 -3,568.02 5,909,562.70 457,016.67 2.46 4,253.04 INC+TRENO(5) 5 1/2"x 6-3/4" 7,086.06 39.36 245.32 5,097.58 4,948.61 -2,364.52 -3,600.76 5,909,547.09 456,983.85 2.46 4,289.36 INC+TREND(5) 7,121.53 39.79 242.78 5,124.92 4,975.95 -2,374.41 -3,621.08 5,909,537.30 456,963.49 4.72 4,311.94 MWD+IFR-AK-CAZ-SC(6) 7,202.65 39.31 241.85 5,187.47 5,038.50 -2,398.41 -3,666.82 5,909,513.55 456,917.63 0.94 4,363.59 MWD+IFR-AK-CAZ-SC(6) 7,274.61 38.71 241.56 5,243.39 5,094.42 -2,419.88 -3,706.70 5,909,492.29 456,877.64 0.87 4,408.89 MWD+IFR-AK-CAZ-SC(6) 7,308.10 38.52 242.15 5,269.56 5,120.59 -2,429.74 -3,725.13 5,909,482.53 456,859.16 1.24 4,429.79 MWD+IFR-AK-CAZ-SC(6) 7,401.78 39.32 239.13 5,342.45 5,193.48 -2,458.60 -3,776.40 5,909,453.94 456,807.74 2.20 4,488.61 MWD+IFR-AK-CAZ-SC(6) 7,498.06 40.15 239.41 5,416.49 5,267.52 -2,490.05 -3,829.31 5,909,422.77 456,754.68 0.88 4,550.08 MWD+IFR-AK-CAZ-SC(6) 7,590.52 38.94 240.17 5,487.78 5,338.81 -2,519.67 -3,880.17 5,909,393.41 456,703.66 1.41 4,608.90 MWD+IFR-AK-CAZSC(6) 7,617.42 38.61 239.24 5,508.76 5,359.79 -2,528.17 -3,894.72 5,909,384.99 456,689.07 2.49 4,625.74 MW3+IFR-AK-CAZ-SC(6) 7,658.00 38.61 239.24 5,540.47 5,391.50 -2,541.12 -3,916.48 5,909,372.16 456,667.25 0.00 4,651.03 PROJECTED to TD 3112"x4-314" 1/7/2015 1:00:01 PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project: Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellbore: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,667.00 38.61 239.24 5,547.50 5,398.53 -2,543.99 -3,921.31 5,909,369.31 456,662.41 0.00 4,656.64 PROJECTED to TD 1/7/2015 1:00:01PM Page 5 COMPASS 5000.1 Build 65 Cement Detail Report 2N-337 Conoca.Phil1ps String: Cement Plug Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 12/4/2014 00:00 12/4/2014 00:00 2N-337B Comment W/mule shoe @ 3041'set kick off plug-Pumped 5 bbls 12.5 ppg MudPush @ 2.7 bbls/min @ 150 psi-Shut down-Pressure test lines to 3000 psi-Pumped 10 bbls 12.5 ppg MudPush @ 2.8 bbl/min @ 120 psi-Loaded wiper ball string-Pumped 25 bbls Class G cmt w/additives @ 17.0 ppg @ 3 bbls/min @ 130 psi- Pumped 5 bbls 12.5 ppg MudPush behind cmt. 3.2 bbl/min @ 100 psi-Switched over to rig pumps&displaced cmt to equalize w/16.5 bbls 10.4 ppg brine @ 1.8 bbls/min bbls -CIP @ 1415 hrs.-Blow down lines Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug Kick-off plug 2,658.0 3,041.0 No No No Q Pump Init(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) 3 2 3 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) Plug Back Cement 2,658.0 3,041.0 141 G 25.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.00 3.90 17.00 Additives Additive Type Concentration Conc Unit label D186 Accelerator gal/sx Additive Type Concentration Conc Unit label DO 46 Atifoam %BWOC Additive Type Concentration Conc Unit label DO65 Dispersant %BWOC Additive Type Concentration Conc Unit label D167 Fluid loss %BWOC Page 1/1 Report Printed: 1/21/2015 Cement Detail Report 0 2N-337 ConoccPhi'lips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 12/15/2014 13:30 12/15/2014 15:00 2N-337C Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement casing minimum 5,200.0 7,039.0 No No No Cement of 500'above C-37 Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 30 631.0 994.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump cement job 5 bbls CW100 PT cement lines pump 25 bbls CW100 30 bbls MP-2 11.0 ppg Drop bottom plug pump 68 bbls cement 15.8 ppg Drop top plug Flush lines w/10 bbls H2O Swap to rig pumps Displace 41 SPM 615 PSI Bump at 2657 stks @ 14:57 hrs Hold 1200 PSI for 15 minutes Check floats All good Loss of 34 bbls mud for cement job. Shoe @ 7029' FC @ 6943'. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 25.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 30.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Cement 5,200.0 7,039.0 327 G 68.0 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/21/2015 '' Cement Detail Report Oa 1N il 2N-337 Corlocc liilpps Atxka String: 3-1/2 Production liner Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 3-1/2 Production liner 12/24/2014 00:15 12/24/2014 02:30 2N-337C Comment Cement 3 1/2"Production Liner/Shoe 7658' /Top of Lap 6816'. PUW 125 k SOW 62 k. Pump 5 bbls of water/pressure test cement linges to 4000 psi/ Pump 10 bbls CW100/Pump 12 bbls MudPush II/Pump 15.5 bbls cement/Pump.5 bbls water/Drop dart/Pump 10 bbls water/Swap to rig for displacement/displace at 3 BPM/slow pumps at last 10 bbls/stop reciprocating Liner/Space out 213'above the intermediate casing/Bump plug at 791 strokes 1200 psi/pressure to 1700 psi for 5 minutes/Set liner per BOT 4000 psi. /Bleed pressure to 0 and check floats for flow back,float good. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? 3-1/2 Production liner Cement liner in place 6,825.0 7,658.0 No 3.0 No Yes 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) 2 1 2 1,008.0 1,400.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement 3 1/2"Production Liner/Shoe 7658' /Top of Lap 6816'. PUW 125 k SOW 62 k. Pump 5 bbls of water/pressure test cement linges to 4000 psi/ Pump 10 bbls CW100/Pump 12 bbls MudPush II/Pump 15.5 bbls cement/Pump.5 bbls water/Drop dart/Pump 10 bbls water/Swap to rig for displacement/displace at 3 BPM/slow pumps at last 10 bbls/stop reciprocating Liner/Space out 213'above the intermediate casing/Bump plug at 791 strokes 1200 psi/pressure to 1700 psi for 5 minutes/Set liner per BOT 4000 psi. /Bleed pressure to 0 and check floats for flow back,float good. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Production Cement 6,825.0 7,667.0 70 G 1.6:6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.25 15.80 Additives Additive Type Concentration Conc Unit label / k ,tib d5,9 ', '2j'f- 5' (, - JJ r IQ Page 1/1 Report Printed: 1/21/2015 21 4121 WELL LOG TRANSMITTAL 25 2 68 To: Alaska Oil and Gas Conservation Comm. January 13, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED CG��D DATA LOGGED RE: Triple Combo - Open Hole: 2N-337C wl.K/%V201 BEND R JAN 1 5 2015 Run Date: 12/21/2014 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-337C Triple Combo Data in LAS format and Digital Log Image files 1 CD Rom 50-103-20262-03 Triple Combo Log 1 Color Log 50-103-20262-03 Borehole Volume Plot 1 Color Log 50-103-20262-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A1'It NTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ✓a �, 6.e„..eat 21 41 21 25260 SchlumbergerDrilling & Measurements Transmittal #: 13JAN15-NG01 DATA LOGGED MWD/LWD LogProduct Delivery ►5/2oig K.BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2N-337C Date Dispatched: 13-Jan-15 Job#: 14AKA0132 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISON* Resistivit!2" MD x x VISON* Resistivifi 2"TVD x x VISON* Resistivifi 5" MD ' ` x x VISON* Resistivifi 5"TVD JAN 1 3 2015 x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: PDF x Survey: txt,xls,pdf x Please sign and email a copy to: Please sign and email/fax a copy to: catherine.Roso(a�Conocophilips.com AlaskaPTSPrintCenter a,slb.corn_ Cathaerine Roso Attn: Nathan Green Fax: 907-273-4760 Received By: AAit„i „ ,/,, 21 4121 25260 NADConversion RECEIVED Kuparuk River Unit JAN 13 2015 Kuparuk 2N Pad AOGCC 2N-337C GC Definitive Survey Report EN A D 2 7 07 January, 2015 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project: Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellbore: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Project Kuparuk River Unit,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 2N-337 Well Position +N/-S 0.00 usft Northing: 5,911,892.60 usft Latitude: 70°10'12.816 N +E/-W 0.00 usft Easting: 460,596.52 usft Longitude: 150°19'1.635 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.90 usft Wellbore 2N-337C Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 11/25/2014 18.83 80.75 57,548 Design 2N-337C Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,824.36 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (') 28.07 0.00 0.00 242.00 Survey Program Date 1/7/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 251.07 2,824.36 2N-337(2N-337) MWD MWD-Standard 4/4/2001 12:00:C 2,901.28 2,970.71 2N-337C Srvy#1-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 2:2f 3,062.04 3,062.04 2N-337C Srvy#2-Inc+Trend(2N-337C) INC+TREND Inclinometer+known azi trend 12/12/2014 4:17 3,159.40 7,002.69 2N-337C Srvy#3-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 4:27 7,086.06 7,086.06 2N-337C Srvy#4-Inc+Trend(2N-337C) INC+TREND Inclinometer+known azi trend 12/12/2014 9:32 7,121.53 7,617.42 2N-337C Srvy#5-MWD+IFR-AK-CAZ-S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 9:3E 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 28.07 0.00 0.00 28.07 -120.90 0.00 0.00 5,911,892.60 460,596.52 0.00 0.00 UNDEFINED 251.07 0.67 142.46 251.06 102.09 -1.03 0.79 5,911,891.56 460,597.31 0.30 -0.22 MWD(1) 341.81 1.88 183.94 341.78 192.81 -2.94 1.02 5,911,889.66 460,597.52 1.60 0.48 MWD(1) 432.50 4.16 198.23 432.34 283.37 -7.55 -0.12 5,911,885.05 460,596.37 2.63 3.65 MWD(1) 521.09 7.44 200.71 520.47 371.50 -15.97 -3.15 5,911,876.65 460,593.29 3.71 10.28 MWD(1) 608.00 10.40 208.49 606.32 457.35 -28.13 -8.88 5,911,864.52 460,587.49 3.67 21.05 MWD(1) 699.69 14.01 205.01 695.92 546.95 -45.47 -17.53 5,911,847.23 460,578.76 4.02 36.82 MWD(1) 790.35 16.01 197.19 783.49 634.52 -67.36 -25.86 5,911,825.38 460,570.31 3.14 54.46 MWD(1) 880.62 15.80 199.98 870.31 721.34 -90.80 -33.74 5,911,801.98 460,562.31 0.88 72.42 MWD(1) 971.65 15.43 200.52 957.98 809.01 -113.79 -42.22 5,911,779.04 460,553.71 0.44 90.70 MWD(1) 1/7/2015 1:00:01PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project: Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellbore: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (o/100') (ft) Survey Tool Name 1,062.27 16.20 198.91 1,045.17 896.20 -137.04 -50.54 5,911,755.84 460,545.27 0.98 108.96 MWD(1) 1,153.94 16.29 200.42 1,133.18 984.21 -161.19 -59.17 5,911,731.74 460,536.51 0.47 127.92 MWD(1) 1,245.36 19.29 203.95 1,220.22 1,071.25 -187.01 -69.78 5,911,705.98 460,525.78 3.49 149.41 MWD(1) 1,338.99 21.32 212.44 1,308.05 1,159.08 -215.52 -85.19 5,911.677.55 460,510.22 3.82 176.40 MWD(1) 1,434.74 22.74 218.59 1,396.82 1,247.85 -244.68 -106.08 5,911.648.50 460,489.18 2.83 208.53 MWD(1) 1,529.84 25.33 225.21 1,483.68 1,334.71 -273.39 -131.99 5,911,619.93 460,463.12 3.93 244.89 MWD(1) 1,623.40 29.03 229.10 1,566.90 1,417.93 -302.36 -163.36 5,911,591.12 460,431.60 4.39 286.19 MWD(1) 1,718.10 32.88 228.72 1,648.10 1,499.13 -334.38 -200.06 5,911,559.30 460,394.74 4.07 333.62 MWD(1) 1,813.70 35.91 229.19 1,726.97 1,578.00 -369.83 -240.79 5,911,524.07 460,353.83 3.18 386.23 MWD(1) 1,909.20 39.76 229.54 1,802.38 1,653.41 -407.96 -285.24 5,911,486.17 460,309.19 4.04 443.38 MWD(1) 2,004.27 42.92 230.64 1,873.75 1,724.78 -448.23 -333.42 5,911,446.15 460,260.81 3.41 504.82 MWD(1) 2,096.57 46.32 231.94 1,939.44 1,790.47 -488.75 -384.01 5,911.405.90 460,210.01 3.81 568.51 MWD(1) 2,192.04 50.23 235.27 2,002.98 1,854.01 -530.96 -441.38 5,911,364.00 460,152.43 4.85 638.98 MWD(1) 2,286.81 54.04 235.82 2,061.14 1,912.17 -573.27 -503.06 5,911,322.01 460,090.53 4.05 713.31 MWD(1) 2,379.83 57.86 237.48 2,113.22 1,964.25 -615.61 -567.44 5,911,280.01 460,025.94 4.36 790.03 MWD(1) 2,475.68 61.89 238.43 2,161.31 2,012.34 -659.58 -637.70 5,911,236.42 459,955.46 4.29 872.71 MWD(1) 2,569.38 65.42 239.52 2,202.89 2,053.92 -702.84 -709.65 5,911,193.54 459,883.29 3.91 956.55 MWD(1) 2,662.68 67.66 239.74 2,240.03 2,091.06 -746.10 -783.49 5,911,150.66 459,809.23 2.41 1,042.06 MWD(1) 2,757.85 69.03 240.81 2,275.15 2,126.18 -789.96 -860.30 5,911,107.21 459,732.20 1.78 1,130.47 MWD(1) 2,824.43 68.76 241.33 2,299.12 2,150.15 -820.00 -914.67 5,911,077.45 459,677.69 0.83 1,192.57 MWD(1) 2,858.00 69.13 238.98 2,311.19 2,162.22 -835.59 -941.84 5,911,062.00 459,650.44 6.62 1,223.88 MWD+IFR-AK-CAZ-SC(2) 7-5/8"x 9-7/8" 2,901.28 69.65 235.97 2,326.43 2,177.46 -857.37 -975.99 5,911,040.40 459,616.18 6.62 1,264.26 MWD+IFR-AK-CAZ-SC(2) 2,970.71 69.26 233.13 2,350.80 2,201.83 -895.07 -1,028.94 5,911,002.98 459,563.03 3.87 1,328.72 MWD+IFR-AK-CAZ-SC(2) 3,062.04 69.50 234.40 2,382.96 2,233.99 -945.60 -1,097.89 5,910,952.82 459,493.83 1.33 1,413.31 INC+TREND(3) 3,159.40 68.94 232.94 2,417.50 2,268.53 -999.52 -1,171.22 5,910,899.29 459,420.23 1.52 1,503.37 MWD+IFR-AK-CAZ-SC(4) 3,253.21 67.81 236.86 2,452.09 2,303.12 -1,049.66 -1,242.54 5,910,849.52 459,348.65 4.07 1,589.89 MWD+IFR-AK-CAZ-SC(4) 3,349.78 67.69 234.87 2,488.66 2,339.69 -1,099.81 -1,316.52 5,910,799.76 459,274.42 1.91 1,678.75 MWD+IFR-AK-CAZ-SC(4) 3,445.53 67.70 234.57 2,525.00 2,376.03 -1,150.98 -1,388.84 5,910,748.98 459,201.85 0.29 1,766.62 MWD+IFR-AK-CAZ-SC(4) 3,543.39 68.38 237.86 2,561.60 2,412.63 -1,201.43 -1,464.26 5,910,698.92 459,126.17 3.19 1,856.90 MWD+IFR-AK-CAZ-SC(4) 3,636.92 64.84 239.48 2,598.73 2,449.76 -1,246.08 -1,537.56 5,910,654.67 459,052.64 4.11 1,942.58 MWD+IFR-AK-CAZ-SC(4) 3,729.74 61.01 241.52 2,640.97 2,492.00 -1,286.78 -1,609.46 5,910,614.34 458,980.54 4.57 2,025.18 MWD+IFR-AK-CAZ-SC(4) 3,827.93 59.07 241.56 2,690.00 2,541.03 -1,327.32 -1,684.25 5,910,574.19 458,905.55 1.98 2,110.24 MWD+IFR-AK-CAZ-SC(4) 3,923.89 56.71 242.77 2,741.01 2,592.04 -1,365.28 -1,756.11 5,910,536.62 458,833.50 2.68 2,191.52 MWD+IFR-AK-CAZ-SC(4) 4,019.20 54.43 243.01 2,794.89 2,645.92 -1,401.10 -1,826.08 5,910,501.16 458,763.35 2.40 2,270.12 M1MD+IFR-AK-CAZ-SC(4) 4,114.30 51.28 244.11 2,852.31 2,703.34 -1,434.87 -1,893.94 5,910,467.76 458,695.32 3.44 2,345.88 MWD+IFR-AK-CAZ-SC(4) 4,208.94 47.79 243.19 2,913.72 2,764.75 -1,466.80 -1,958.46 5,910,436.16 458,630.64 3.76 2,417.84 M1MD+IFR-AK-CAZ-SC(4) 4,303.02 45.17 240.59 2,978.51 2,829.54 -1,498.91 -2,018.63 5,910,404.37 458,570.31 3.43 2,486.04 MWD+IFR-AK-CAZ-SC(4) 4,397.47 41.98 239.50 3,046.93 2,897.96 -1,531.40 -2,075.04 5,910,372.18 458,513.74 3.47 2,551.10 MWD+IFR-AK-CAZ-SC(4) 4,492.93 39.06 240.88 3,119.49 2,970.52 -1,562.24 -2,128.84 5,910,341.61 458,459.79 3.20 2,613.08 MWD+IFR-AK-CAZ-SC(4) 1/7/2015 1:00:01PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project: Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellbore: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +EI-W Northing Easting DLS Section (usft) (") (") (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 4,587.04 39.76 241.70 3,192.20 3,043.23 -1,590.94 -2,181.24 5,910,313.19 458,407.24 0.93 2,672.82 MWD+IFR-AK-CAZ-SC(4) 4,683.05 39.90 242.17 3,265.93 3,116.96 -1,619.87 -2,235.50 5,910,284.55 458,352.83 0.35 2,734.32 MW3+IFR-AK-CAZ-SC(4) 4,777.88 40.23 241.46 3,338.50 3,189.53 -1,648.70 -2,289.30 5,910,256.00 458,298.89 0.59 2,795.35 MWD+IFR-AK-CAZ-SC(4) 4,873.88 40.24 241.86 3,411.79 3,262.82 -1,678.14 -2,343.88 5,910,226.85 458,244.17 0.27 2,857.36 MWD+IFR-AK-CAZ-SC(4) 4,967.03 40.31 241.85 3,482.86 3,333.89 -1,706.54 -2,396.98 5,910,198.73 458,190.93 0.08 2,917.58 MWD+IFR-AK-CAZ-SC(4) 5,062.66 40.27 242.63 3,555.80 3,406.83 -1,735.35 -2,451.70 5,910,170.21 458,136.06 0.53 2,979.42 MWD+IFR-AK-CAZ-SC(4) 5,159.81 40.37 241.39 3,629.88 3,480.91 -1,764.85 -2,507.20 5,910,141.00 458,080.41 0.83 3,042.28 MWD+IFR-AK-CAZ-SC(4) 5,255.05 40.61 241.23 3,702.31 3,553.34 -1,794.54 -2,561.45 5,910,111.60 458,026.01 0.27 3,104.11 MWD+IFR-AK-CAZ-SC(4) 5,350.59 40.58 239.88 3,774.86 3,625.89 -1,825.10 -2,615.59 5,910,081.33 457,971.72 0.92 3,166.26 MWD+IFR-AK-CAZ-SC(4) 5,445.60 40.46 238.20 3,847.08 3,698.11 -1,856.85 -2,668.52 5,910,049.85 457,918.63 1.16 3,227.90 MWD+IFR-AK-CAZ-SC(4) 5,540.74 40.61 239.04 3,919.39 3,770.42 -1,889.04 -2,721.31 5,910,017.93 457,865.68 0.60 3,289.62 MWD+IFR-AK-CAZ-SC(4) 5,636.18 40.69 240.76 3,991.80 3,842.83 -1,920.22 -2,775.09 5,909,987.04 457,811.74 1.18 3,351.75 MWD+IFR-AK-CAZ-SC(4) 5,730.60 40.57 242.18 4,063.46 3,914.49 -1,949.59 -2,829.11 5,909,957.96 457,757.58 0.99 3,413.23 MWD+IFR-AK-CAZ-SC(4) 5,825.66 40.63 242.08 4,135.64 3,986.67 -1,978.51 -2,883.79 5,909,929.33 457,702.75 0.09 3,475.09 MWD+IFR-AK-CAZ-SC(4) 5,921.02 40.67 241.95 4,207.99 4,059.02 -2,007.65 -2,938.65 5.909,900.47 457,647.75 0.10 3,537.21 MWD+IFR-AK-CAZ-SC(4) 6,015.74 40.65 242.71 4,279.84 4,130.87 -2,036.31 -2,993.31 5,909,872.10 457,592.95 0.52 3,598.93 MWD+IFR-AK-CAZ-SC(4) 6,113.41 40.54 242.14 4,354.01 4,205.04 -2,065.73 -3,049.64 5,909,842.97 457,536.46 0.40 3,662.48 MWD+IFR-AK-CAZ-SC(4) 6,211.84 40.66 241.05 4,428.74 4,279.77 -2,096.20 -3,105.98 5,909,812.80 457,479.97 0.73 3,726.53 MWD+IFR-AK-CAZ-SC(4) 6,306.42 40.70 240.59 4,500.47 4,351.50 -2,126.26 -3,159.81 5,909,783.03 457,425.99 0.32 3,788.17 MWD+IFR-AK-CAZ-SC(4) 6,395.21 40.06 241.35 4,568.11 4,419.14 -2,154.18 -3,210.10 5,909,755.37 457,375.56 0.91 3,845.68 MWD+IFR-AK-CAZ-SC(4) 6,490.35 40.16 240.69 4,640.87 4,491.90 -2,183.88 -3,263.72 5,909,725.96 457,321.79 0.46 3,906.96 MWD+IFR-AK-CAZ-SC(4) 6,586.45 40.02 240.87 4,714.39 4,565.42 -2,214.09 -3,317.74 5,909,696.03 457,267.63 0.19 3,968.84 MWD+IFR-AK-CAZ-SC(4) 6,681.62 39.90 240.55 4,787.34 4,638.37 -2,243.99 -3,371.04 5,909,666.41 457,214.17 0.25 4,029.95 MWD+IFR-AK-CAZ-SC(4) 6,776.36 40.12 241.69 4,859.90 4,710.93 -2,273.41 -3,424.38 5,909,637.28 457,160.69 0.81 4,090.85 MWD+IFR-AK-CAZ-SC(4) 6,872.45 40.03 242.35 4,933.43 4,784.46 -2,302.43 -3,479.01 5,909,608.54 457,105.91 0.45 4,152.71 MWD+IFR-AK-CAZ-SC(4) 6,967.93 39.68 242.60 5,006.73 4,857.76 -2,330.71 -3,533.27 5,909,580.55 457,051.51 0.40 4,213.89 MWD+IFR-AK-CAZ-SC(4) 7,002.69 40.01 242.27 5,033.42 4,884.45 -2,341.01 -3,553.01 5,909,570.35 457,031.72 1.13 4,236.16 MWD+IFR-AK-CAZ-SC(4) 7,029.00 39.80 243.22 5,053.60 4,904.63 -2,348.74 -3,568.02 5,909,562.70 457,016.67 2.46 4,253.04 INC+TREND(5) 5 1/2"x 6-3/4" 7,086.06 39.36 245.32 5,097.58 4,948.61 -2,364.52 -3,600.76 5,909,547.09 456,983.85 2.46 4,289.36 INC+TREND(5) 7,121.53 39.79 242.78 5,124.92 4,975.95 -2,374.41 -3,621.08 5,909,537.30 456,963.49 4.72 4,311.94 MWD+IFR-AK-CAZ-SC(6) 7,202.65 39.31 241.85 5,187.47 5,038.50 -2,398.41 -3,666.82 5,909,513.55 456,917.63 0.94 4,363.59 MWD+IFR-AK-CAZ-SC(6) 7,274.61 38.71 241.56 5,243.39 5,094.42 -2,419.88 -3,706.70 5,909,492.29 456,877.64 0.87 4,408.89 MWD+IFR-AK-CAZ-SC(6) 7,308.10 38.52 242.15 5,269.56 5,120.59 -2,429.74 -3,725.13 5,909,482.53 456,859.16 1.24 4,429.79 MWD+IFR-AK-CAZ-SC(6) 7,401.78 39.32 239.13 5,342.45 5,193.48 -2,458.60 -3,776.40 5,909,453.94 456,807.74 2.20 4,488.61 MVVD+IFR-AK-CAZ-SC(6) 7,498.06 40.15 239.41 5,416.49 5,267.52 -2,490.05 -3,829.31 5,909,422.77 456,754.68 0.88 4,550.08 MWD+IFR-AK-CAZ-SC(6) 7,590.52 38.94 240.17 5,487.78 5,338.81 -2,519.67 -3,880.17 5,909,393.41 456,703.66 1.41 4,608.90 MWD+IFR-AK-CAZ-SC(6) 7,617.42 38.61 239.24 5,508.76 5,359.79 -2,528.17 -3,894.72 5,909,384.99 456,689.07 2.49 4,625.74 MWD+IFR-AK-CAZ-SC(6) 7,658.00 38.61 239.24 5,540.47 5,391.50 -2,541.12 -3,916.48 5,909,372.16 456,667.25 0.00 4,651.03 PROJECTED to TD 3 1/2"x 4-3/4" 1/7/2015 1.00:01PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-337 Project: Kuparuk River Unit TVD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-337C actual @ 148.97usft(Nabors 9ES) Well: 2N-337 North Reference: True Wellbore: 2N-337C Survey Calculation Method: Minimum Curvature Design: 2N-337C Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (") (') (usft) (usft) (usft) (usft) (ft) (ft) (11001 (ft) Survey Tool Name 7,667.00 38.61 239.24 5,547.50 5,398.53 -2,543.99 -3,921.31 5,909,369.31 456,662.41 0.00 4,656.64 PROJECTED to TD 1/7/2015 1:00:01PM Page 5 COMPASS 5000.1 Build 65 l 'I'ii t 333 uses, S . rpt! Pyr_r ue _iii 7e (-ON E12 O1 SI AN P,\i-\f 1.? Alicrlerocu Arcs c, 7 35;2 J, Graham L. Alvord 1 Drilling Manager ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2N-337C ConocoPhillips Alaska, Inc. Permit No: 214-121 Surface Location: 117' FNL, 997' FEL, Sec. 3, T09N, R07E, UM Bottomhole Location: 2616' FNL, 4869 FEL, Sec. 3, T09N, R07E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, //°) /tA- Cathy P oerster Chair DATED this �JD day of August, 2014. 71, ��Y gni""` '7: 7 ,1Y STATE OF ALASKA P :A OIL AND GAS CONSERVATION COMA )N "L'' 1 2 ?0I 1 PERMIT TO DRILL N r,., , 20 AAC 25.005 °''`1.-."� • _ la.Type of Work: lb.Proposed Well Class. Development-Oil ❑ Service- Winj ❑ Single Zone ❑✓ • lc.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas El Gas Hydrates 0 Redril❑., . Reentry ❑ Exploratory 0 Service- WAG ❑D , Service-Disp ❑ Geothermal 0 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q, Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 59-52-180 . 2N-337C • 3.Address: 6.Proposed Depth: 12.Field/Pool(s). P.O.Box 100360 Anchorage,AK 99510-0360 MD: 7546.53'' TVD: 5450'• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Field ' Surface: 116.4'FNL,996.36'FEL,Sec3,TO9N,RO7E,UM.• ADL 375074 ' Tarn Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2509.66'FNL,4668.73'FEL,Sec3,TO9N,RO7E,UM% 4602 10/21/2014 Total Depth: 9.Acres in Property: 14 Distance to Nearest Property: 2615.23'FNL,4868.58'FEL,Sec3,TO9N,RO7E,UM . 2560 2568' 4b.Location of Well(State Base Plane Coordinates-NAD 27ry�i 10.KB Elevation above MSL: . 148.9 feet 15.Distance to Nearest Well Open Surface: 4' S"Zone-4 - GL Elevation above MSL: . 120.9 feet to Same Pool. 16.Deviated wells: Kickoff depth: 2900 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle. 69 degrees • Downhole: 2800 , Surface. 2403 , 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) 16" 62.58# H-40 Welded 9-7/8" 7-5/8" 29.7# L-80 BTCM 2829.1' 29.3' 29.3' 2858 4' 2312.7' Existing to surface 6-3/4"x7-1/2 5-1/2" 15.5# L-80 HYD563 6927.11' 29.2' 29 2' 6956.31' 5000' 303 Sx Class G @ 15.8 ppg 4-3/4" 3-1/2" 9.3# L-80 HYD511 846.53' 6700' 4804.59' 7546.53' 5450' 59 Sx Class G @ 15.8 ppg 3-1/2" 9.3# L-80 EUE 6673' 27' 27' 6700' 4804.59' 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): 9950' 5330' 9931.9' 5492 3' Casing Length Size Cement Volume MD TVD Conductor/Structural 78.8' 16" 108' 108' Surface 2829.1' 7-5/8" 226 bbl ASII&50 bbl Class G 2858.4' 2312.7' Intermediate Production 9902.7' 5-1/2"x3-1/2" 240 sx 15.8 ppg Class G 9931.9' 5492.3' Liner 9123.5' 3-1/2" N/A-Tubing 9150 5' 4912.7' Perforation Depth MD(ft): 9600'-9615' Perforation Depth TVD(ft): 5240.7'-5252.1' 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program Q • Time v.Depth Plot El Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ , 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 8/11/2014 22. I hereby certify that the foregoing is true and correct. Scott Brunswick 263-4249 L� Contact scott.a.brunswick a(�cop com Email Printed Name aa,.._._ ( _ 4,-,,A Title )ht-c ,1, I e- Signature (- Q Phone 246-6 Ito Date vi((((Z!1 (4 /// Commission Use Only Permit to Drill API Number: Permit Approyt it J LI See cover letter for other Number: 11.9 -'I,L' 50- 03--azo..2 6 2- 03-00 Date: 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: ySamples req'd: Yes 0,.No V� Mud log req'd:Yes❑ No E ' 130 P f e S Y -1-0 To G P5 / H2S measures. Yes[r No❑ Directional svy req'd:Yes Er No❑ Spacing exception req'd: Yes❑ No[+" Inclination-only svy req'd:Yes❑ No[✓' APPROVED BY 8-/C-1(( -��^/ Approved by. .7 COMMI SSIONER THE COMMISSION Date. permitI I ��pt�l(�ISubs i Form aneForm 10-001(Revised 10/2012) This is v fOr 4 It]s ate of approval 20 AAC 25.005(8)) Attachments in Duplicate v'Lfi 5//4,/IiL , 97,2/74) ConocoPhillips Alaska, Inc. 9 ice` J ; N Post Office Box 100360 Anchorage,Alaska 99510-0360 ,U j 2 2014 ConocoPhillips Telephone 907-276-1215 00C .: Auguse 11,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill 2N-337C Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore injection well 2N-337C from the Tarn 2N drilling pad. The intended spud date for this well is October 21st, 2014 using Nabors Rig 9ES. 2N-337C is planned to be a slant Bermuda sand injector. The existing well 2N-337B will be plugged and abandoned before the rig moves on. The rig will pull the tubing,then perform a cut&pull of the production casing to sidetrack&re-drill the well to a new bottom hole location. The intermediate hole section will be drilled with a 6-3/4"bit and under reamed to 7-1/2"for 5-1/2"casing connection clearance and a 5-1/2"casing long string will be top set above the Bermuda sand and cemented in place. The production section will be drilled with a 4-3/4"bit,with a 3-1/2"liner run and cemented to the liner top. 3-1/2"tubing will be run and tied back to surface. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005(a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer Attachments cc: 2N-337C Well File/Sharon Allsup-Drake ATO 1530 Chip Alvord ATO 1570 Liz Jolley ATO 1568 A! ion for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 2N-337C Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005(c)(14) 8 2N-337C APD Page 1 of 14 O R I G I A L Printed: 11-Aug-14 Al ion for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Proposed Well Schematic 8 2N-337C APD Page 2 of 14 Printed: 11-Aug-14 ORIGINAL Al on for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2N-337C. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a slant injector to improve Bermuda oil recovery and pattern sweep efficiency at Tarn. The rig will move onto the 2N-337B well after a pre-rig abandonment operation has been performed, refer to previous sundry to abandon. Once rigged up & prepared for operations the existing pre-cut tubing will be pulled from the well and laid down. A cut& pull operation of the production casing will be performed, followed by pumping cement into the open hole& into the existing surface casing for sidetracking &drilling the well to a new bottom hole location. The intermediate hole section will be sidetracked drilled using a 6-3/4" bit, opening the section with use of an under-reamer to 7-1/2"for 5-1/2" casing connection OD clearance. The intermediate casing will be 5-1/2"top set above the Bermuda sand &cemented in place. The production section will be drilled using a 4-3/4" bit, & run a 3-1/2" liner with cement placed to the liner top. 3-1/2"tubing will be run &tied back to surface. Location at Surface 116.39' FNL, 996.36' FEL, Sec 03, T09N, R7E, UM NAD 1927 RKB Elevation 148.9' AMSL Northings: 5,911,892.60 Eastings: 460,596.52 Pad Elevation 120.9' AMSL Location of existing 7 5/8" Surface 951.72' FNL, 1939.81' FEL, Sec 3, T09N, R7E, UM Csg shoe Nad 1927 Measured Depth, RKB: 2,858.4' Northings: 5,911,062.32 Eastings: 459,650.10 Total Vertical Depth, RKB: 2,312.7' _ Total Vertical Depth, SS: 2,162' Location of existing 5 1/2" 2436.71' FNL, 4530.58' FEL, Sec 03, T09N, R7E, UM Intermediate Csg shoe Nad 1927 Measured Depth, RKB: 6,956.36' Northings: 5,909,591.74 Eastings: 457,054.16 Total Vertical Depth, RKB: 5,000.00' Total Vertical Depth, SS: 4,851.10' Location at Top of Productive 2509.66' FNL, 4668.73' FEL, Sec 03, T09N, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 7,197.58' Northings: 5,909,519.58 Eastings:456,915.75 Total Vertical Depth, RKB: 5,183.90' Total Vertical Depth, SS: 5,035.00' Location at Total Depth 2615.23' FNL, 4868.58' FEL, Sec 03, T09N, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 7,546.59' Northings: 5,909,415.17 Eastings: 456,715.54 Total Vertical Depth, RKB: 5,450.00' Total Vertical Depth, SS: 5,301.10' 2N-337C APD ORIGINAL. Page 3of14 Printed.' 11-Aug-14 Al ion for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore ASP Casing Size Depth Gradient pressure Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 108/ 108 10.9 N/A N/A 7-5/8 2858.4/2312.7 14.5 N/A N/A 5-1/2 6956/5000 15 2314** 2,083 3-1/2 7456/5450 15 2800** 2,403 • NOTE: The Nabors 9ES 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. • ** NOTE: Pore pressure is estimated reservoir pressure. — — — PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A)ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below surface casing (7-5/8") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2,312.7' = 1,512.5 psi OR 2N-337C APD Page 4 of 14 ORIGINAL Printed: 11-Aug-14 At ion for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 ASP = FPP—(0.1 x D) =(0.052*5000*8.9)—(0.1 x 2,312') = 2,083 psi 2. Drilling below intermediate casing (5-1/2") ASP = [(FG x 0.052)—0.1] D = [(15 x 0.052)—0.1]x 5,000' = 3,400 psi OR ASP = Reservoir Pressure—(0.1 x D) = (0.052*5450*10.4)—(0.1*5450) =2,403 psi (B) Data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C)Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; The bottom-hole pressures from the 2N-337C's offset wells are: Well Pressure @ Date SI time prior to Comments datum (psi) Measured measurement (days) 2N-349A 3,208 7/26/2011 392 Injector, SI since Sep 09 Located along the same 2N-319 2,617 10/1/2009 129 conduit as 2N-349A, SI since Jul 09 2N-325 3,141 3/19/2014 79 Injector 2N-327 1,157 4/14/2014 15 2N-339 1,229 6/23/2012 9 2N-345 3,288 2/24/2003 381 SI since Jan 2003. 2N-345A 1,622 1/24/2009 3 Due to the history of the Tarn field being unpredictable for formation pressures as the result of fractures emanating from existing injection wells, the Bermuda formation is assumed to be over pressured and the 5-1/2" intermediate casing will be top set above the Bermuda, but below the Iceberg formation. Please see Attachment 2—Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20AAC 25.005(c)(5)) Drill out from casing shoes and perform LOT or FIT in accordance with the Kuparuk 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 Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.58 H-40 Welded 78.8' 29.2' 108'/108' Driven 2N-337C APD Page 5 of 14 Printed: 11-Aug-14 ORIGINAL AI ion for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 Existing Cemented to Surface 7-5/8 9-7/8 29.7 L-80 BTCM 2829.1' 29.3' 2858.4/2312.7 6- Hydril Cemented to minimum of 500 ft MD 5-1/2 3/4x7- 15.5 L-80 563 6927' 29.2' 6956.31/5000 above C37 top w/303 sx class G @ 15.8 1/2 ppg H drilCemented to liner top w/59 sx class G @ 3-1/2 4-3/4 9.3 L-80 511 846' 6700'/4804' 7546'/5450' 15.8 ppg Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85%of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTCM 4790 4071 6890 5856 5-1/2" 15.5 L-80 3 Hyd563 4990 4241 7000 5950 3-1/2" 9.3 L-80 3 Hyd511 10530 8950 10160 8636 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Nabors 9ES. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and water-based LSND mud system having the following properties: Intermediate Production 6-3/4" hole 4-3/4" hole 5-1/2" Casing 3-1/2" Liner Density 9.6— 10.0 ppg .. 10.6— 10.8 ppg YP 18-22 18-22 PV 12 - 16 14 - 18 Initial Gels 4—8 4 -6 10 minute gels <18 <8 API Filtrate 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 <12 <5 PH 9.5- 10.5 9.5- 10.5 Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight at or below 10.6 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. Production Hole Section: LSND mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda 2N-337C APD Page 6 of 14 ORIGIN A L Printed: 11-Aug-14 A' ion for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 reservoir. Maintain minimum mud weight at or above 10.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Nabors 9ES Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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: Well Schematic. 1. End Sundry to abandon (314-432) previously submitted 2. Begin new permit to drill after the FIT/LOT has been performed. 3. Drill 6-3/4"x 7-1/2" intermediate as per approved directional plan. Proposed hole section TD of wp03 is 6956.31 ft MD & 5000 ft TVD. Ensure based on real time logs & mud logging data that the intermediate shoe is set in shale and above the Bermuda formation' Perform wiper trips every+/- 1500 ft MD. 4. Circulate bottoms up to clean hole, POOH and lay down 4" drill pipe 5. RU and run 5-1/2", 15.5#, L-80 with Hydril 563 connections on the intermediate casing to 6,956' MD/ 5,000' TVD and cement in place. 6. PU 2-7/8" DP required to drill the production section. 7. MU 4-3/4" bit on a 3-1/8" BHA and RIH. 8. Drill the 4-3/4" hole to a proposed TD of 7,546' MD/5,450' TVD. Run MWD/LWD logging tools in drill string as required for navigational monitoring and formation data gathering. (LWD: GR minimum, global availability of RES tool extremely limited, may not have access at time of drilling) a. Once 20 ft of new formation has been cut stop & perform FIT/LOT. 9. POOH laying down the 2-7/8" drill pipe 10. RU casing crew and cementers. 11. MU and run the 3 %" HYD 511 liner on a 3-1/2" PH6 tubing work string. 12. Once liner is on depth, pump sufficient cement to place cement to the top of the liner. 13. Pressure up and set liner hanger, continue to pressure up and release liner hanger from running tool 2N-337C APD Page 7 of 14 Printed: 11-Aug-14 Al 'on for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 14. Flush DP of cement, POOH laying down 3-1/2" PH6 tubing work string. 15. Perform cement bond log on wireline. 16. Run 3-1/2" completion tubing & sting seals into liner top SBE. 17. Land on depth & pressure test. 18. Set TWC &test in direction of flow. 19. ND BOPE & NU Tree 20. Remove TWC. 21. Pump diesel freeze protect. 22. Set BPV&test in direction of flow. 23. Rig down and move rig to next well. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (IR-18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (659-7212). 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic 2N-337C APD Page 8 of 14 ORIGINAL Printed: 11-Aug-14 Ar ion for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 Attachment 1 — Directional Plan 2N-337C APD Page 9 of 14 Printed: 11-Aug-14 ORIGINAL DI 2N-337Cwp03.1 5.925 Plan Summary SURVEY PROGRAM " )epth From Depth To Survey/Plan Tool 251.00 2824.36 2N-337(2N-337) MWD i/ 2888.83 2900.00 2N-337B(2N-337B) MWD+IFR-AK-CAZ-SC %/JI 2900.00 3400.00 2N-337Cwp03.1 (Plan:2N 337C) GYD-GC SS �/ 1111000 . 3400.00 4500.00 2N-337Cwp03.1 (Plan:2N-337C) MWD �/ 3400.00 6900.00 2N-337Cwp03.1 (Plan:2N-337C) MWD+IFR-AK-CAZ-SC _-ii' j��/ 6900.00 7546.53 2N-337Cwp03.1 (Plan:2N-337C) MWD /�� 7CnR G4 7FAR G"3 9N_QQ7(`..,..ntl /Dlon•Onl_9 Q7(`1 ....,n.err. wv nw,nn i CASING DETAILS TVD MD game Size /� 2311.23 2858.10 7 5/8" 7_5/8 5000.00 6956.31 5 1/2"x 7-1/2 5-1/2 5450.00 7546.53 3-1/2"x4-3/4" -4-1/9 - - �`�0° 75/8" --------------- -- _ p Z`5-- - 75/8" -5 9800 o 0 SiFi') -A 73 _ - 5 1/2"x 7-1/2 _ o - CO ro 00 5 1/2"x 7-1/2 , I____ m c- L -�- p�0 3-1/2"4-3/4" co N `' o0 0 I I I 1 1 1 1 1 I I 1 I I h I' I I 0 I I I I I I I I I I I I I I I I I I I I I I 0 2000 4000 6000 0 650 1300 1950 2600 3250 3900 4550 Measured Depth Horizontal Departure 0 PN t 337A 33^ ...--;. .--._. ,.. .... __.- noo - 3200 Oi 11... _ � � '�... azro MOO m 60 ---2N-3.178. N-337A '• - moo a300 60 moo - .,Oo d j 270 ,-a ® -1>e,,,,, 90 5500 - v 30- - t ., . . „W m 240 120 ,70 - assa 0 I I I I I I I I I I It A l i i I I I I I I I I I II I I 1 210 -- - 150 7300 T300 0 850 1700 2550 3400 4250 5100 5950 6800 7650 180 7100 7500 SECTION DETAILS 75p0 -797 Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target 1 2900.00 68.63 240.46 2326.24 2177.34 -854.71 -976.13 5910792.05 1599650.12 0.00 0.00 1263.13 2 3000.00 68.68 236.17 2362.66 2213.76 -903.62 -1055.36 5910743.57 1599570.63 4.00 -90.00 1356.05 3 3500.00 68.68 236.17 2544.43 2395.53 -1162.97 -1442.27 5910486.29 1599182.40 0.00 0.00 1819.43 4 4458.42 40.32 242.16 3095.61 2946.71 -1564.82 -2101.18 5910087.94 1598521.46 3.00 171.93 2589.87 5 7191.85 40.32 242.16 5179.58 5030.68 -2390.95 -3665.22 5909270.13 1596953.24 0.00 0.00 4358.68 6 7192.27 40.32 242.16 5179.90 5031.00 -2391.08 -3665.47 5909270.00 1596953.00 0.00 154.22 4358.96 2N-337C DB 13Jan14 Top Berm 7 7546.53 40.32 242.16 5450.00 5301.10 -2498.13 -3868.16 5909164.03 1596749.77 0.00 0.00 4588.18 Permit pack NAI 27 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 MagnetModel Date: 10-Oct-14 T M Depth Reference: Plan:120.9+28 @ 148.90usft(Nabors 9ES) ic A System(SS)Reference: Mean Sea Level Magneticnc DirectionDeclieation: a1True North/Y: 5911641.54 To convert a Magnetic to a True Direction,Add 18.90°East Ground Level/Mud Line: 120.90 East/X: 1600630.63 Rig: Nabors 9ES GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference ORIGINAL 0 0 0 v, —o 0 _0 .\. , co , ' .= /... , > co o O I-- -co 03 \CS6) . ao o - N T •��O cvi 0 Q O = _O 00� A CI N� I + Z/ \ -...'NI N }, 1 as O , N O i TN M a) x N O T L.%) _o CO• co 0 O 0 Cr) cro No CO CO 0 Zco Nh. `Y' M co co co Z z N O Zv N 0 I I I I _N 0 0 0 0 0 0 00Co Na 4. (ui/j1Tn 008) (+)u .iN l /(-)ulnos M I ORIGINAL a M ---------- 0 , o3 .1.! cn Z I C) I -CD I C\I (11) CO I 1--- •im• - co co Z C‘.1 0 0 0 CO (.0 •••• olowe 0 _ (-6 a) . ... co . 0 C3 N. •:t 1-0 C '(-1) Z D C:k C\I c--1 a c) 21 . (?0 A CD o 0 1 In v4. 0 c" ,.. 0... , ,,1,1 1" 00 C\I 7i- i 4 (NI 0 c•Q x 0i\.1 0 0 " -- -'- a C .2 X C;) CO 0 '- 0 0 in Ts SI o ---. Zr.) a --- • 1--. CO 00 02s, c\r 0 069 o 0 03 0 11`.... CO 1 1 7r cv) 009 , o \ c) I oo 0 , 0, Z \ _ CJ 1 0 0, -0 co Co in a I 0 N- C 0 I I I T I 1 C a a a a a 0 C a a a a 0 03 CO N- co in CO -1- Ln (F-1!/11sn 006) Lird00 le0R-IGA on-11 0 'flGI \ AL a) ,41.4 M co N- M C Q M C'7 N U r � C? N N Z QLD N O Q � Q o o 0 Q Q ORIGINAL as ;►rcvi E =m -0o a ati ti vr = o NM M N Y -Y L L h N N C as �. � M. Clc4 Q Y Y cZv a a a co 0 ORIGINAL co a z z w m rn oN . m N m 0 6 0 r CO ONZ I co y N O in csi O Q p 0 c) , a a a N. 2 H .'4�` H w ....... 11_, U N x ey+�az G V 6 CO CO (0 2 N w N 4,f.F; NI N d U N. + + 7 N J d' N t .r......, H', 7 °) 0) >co in ci (13 _ a N N 7 < u) > N J O) d N- l6 (0 7 C N O1 CI U -o 7 a a s H �W J y ,3 o c C p y J J d > p C -00 7 O a) C co c a m o P. t J J U . co w d o o 2 re 2 H d p y C.. 2 d U N £ a U d C 7 N a ofic U N 7 O o c 43 43 O N N LL O O 0 N £ 7 - O c O U o T N O C O 6> O V 0 i R N NO N .X = N •` d. > N N N _ N J F- 2 z y 0 y N. 0 7 7 7 0 r-- 'c7, O m W O W U1 N- O W co E � C a v .E 7 C W C 0 ca c O o H o E a) o N 7 d O N ro of La L c ce O1 a a C O1 N C o N O C N O z W (q C L IA t6 -- 0 m m c o N z w 3 '. V 9 e O N O 2 m o u) z v J C d D m v N O l0 N N Q jp O m O ." e O O� 0.41 N O r 3 A a E e o O y ° N 7 tan (%) LL .3.. N U N N N -C E (p Z 7 7 7 G D W U o N co O O .- N > N- Z O O O O 0 O 0 N Z O co p a. d' to 0 N 0 Z o N U C 2 C 0 O N- N R o N- C D V 0 N Z N p. co C z m M O co U M 7 d c 7 Z - N Z L• > a M Q Y N N N Y co. N 6. O to N a• N co, 3 N W N 2 y 2 N 0 3 2 co N CO U) < CO ? W D a a r? c D Z Q Z Y Y N m d N c c Z r •2 C a N C C) E p C O c CO V (V ca -P.3 N co 7, ei « £ ci « 7 .y d CO ry C C T eo O .O O O p O d C Z C a 7 o. y .. .0 of y u) 0 N a E :. _ d r a a 'm v � 'C p .O .d.. d a) y O o o m :: :: `O N o d N a) t0 d 7 d N 0a` u) a a 202 i) Ma ap 3 3 a. 3 2 0 < > > 03 ORIGINAL 1` CD C0 N C0 V V M M V 4!) CO N. O 0) 0 CO CO Ch CO N N N a 0 0 7 7 7 7 7 7 7 7 7 7 7 o m CL M CS (1 ww 0 0 0) N Q o � COV O V O CO 0 O a0NN O10 0 ao O )O a0 0 0.0 a O s- s- CO 0) CO O 0) N 0 O C) V N O CO CO O O O O O C O (NI (NI M M M V N 0 O Z Z U = = o > > lar` $ O O co CO O m -J-- a V J p, d V @ 7 "6 l0 O` 0 O) M O) 0 N. N 0 N- V V CO N CO 1. co N 2 Cl- m C) .0 O) Na- I. b v O n N co co O) 0 0 CO 1` + + = d (O O I. (O V' W aD Oi O r N` O N O) (v) 0) 0) 0 Y O O) 0) 0) C) CO h O CO 40 V co C) n V 0 10 CO O O M O O N O CO CO U) )0 C0 C0 C0 N 4) V V: V V co CO Z N N > O O O O O O O O Ci O O O O O O O O O (V Q CD O O O O O O co O O O O O O O O O co d O l9 ` C p ea "' 3aa1- mow "' CO O O n (O O 0 CO M C) CO N N (O )0 N V V O O O O N O O O O V O) 0 V (O N N O r d) h N- N n co O) O) O O CO co 0) co- O) C) 0) CO 0, CO V N O) r Va0 (0 N 0) CO N o v coCO CO m COCO.. ao CO. CO n N- n e (o (o (o v� N h d .0 t M O) O) CD W CO CD CD CO CO O) O 0 CO 0) CO O O O) 0 EO a O O O N U 10 in O O O 0 0 0 U U U) 0 0 K C 2 dO m N (0 C (4 0 6 CU d C O O 0 O N N CO CO CO U) CO V (O N. G., CO 4 O O CO V CO CO (0 N (O O) '- CO 03 O) V; N V Q d wA O O O N O O on M N A M ON co V M a, t, U N U W 0 0 O M N I N N V O O CO C IU ad L N 9 (1) CO CO d U Q t.' i ✓ Q C N o G J I- E Z (q 13 P, 07/ -20 -20 ~ a Y OO D Y 0 C < >.. 0Q C < .2 YO a' cn .F- a' (O a. o. LL m U a CO L.L. T. f0 T. ! T. OL'sO N- W CO CO V CO CO CO CO CO CO CO V N CO V "O O co co r 0 CO O N- N. O C0 r V N C0 N O C) M O O O N M M M N O O O M M M V V M co 1 E 0 2202222 a E y 2 = J O CO 0 0 CZo (n U) C? (6 a N Q . U 0 U 0 0 O) V C0 N N. CO CD 0 N M Y Y Y O s- 0 0 CO U) CO ro ) CO V; (1 1- co n NI. C) CO CO QUQ Q O O O I. M O O N O N O N- N C) O 1. M C0 b C0 V V V V M CO N N 0 0) CO CO ) E cc , a LL U LL. L.L. N M ',Cr N (0 N- CO O 0 N M CO. V_ AO CO .- 2 + U + + O M 0 0 ' 0 0 0 0 I- 22CD2222 2- O O 6) 0) V n N N. CO CO O OV N M 0 0 CO CO V N N- CD N M N CO h• co co co ttt O O 0OCco CO N 0] C(1 h dO Co N co O 0 O) 0) 0 O CO CO aD 03 o I. n CO U) V M 7 N N CO V O (O I. CO 0) ON M V C0 CO h CI = r r r r r r .,- r U U U U U N M M M CN.O M M M CO M M Z Z Z Z Z N N N N N C C CC C O CO V I. V N. N. 0) 0) 0 M C0 s- O CO N 0) M 0 V V O CO CO O) CO V O O 11) M V N N I. s- ic'm a a a a a L N N v O O n V 1. O O O) N6 co co O O O) V V 1. CD 0 0 0 CD O 0 O) 0 0N N N N N- c- .- N- N N N s- N N s- N N N N N (V LO R M co,?, M MppC) M M M 'NO0 0 0 0 N ° N . V - Nm U 0 O CD M M M M M M 1.-- Q N 2 M M M M M M M CO O Z Z Z Z Z Z Z N N O M (O N N CO N n V 0 M 0 0) 0 O CO y N N N N N N N N N N M (O N- O CO 1` CO N 03 V N V s- ,- V C 0 0 0 0 O O .- M 0 O V Cn 0 O O I. NNNMMd N M 0 r00 II O a r O N 0 0 0 0 V V () .. d Z 0 2 0 CO CD V: O 0) N U) C .°r > a' N M 3 F 0, N N 6 V (O r N OG' NUG M M .CiCM W Z Y Y (N a (N O 01000001 O O O O O O O O O O 0 0 0 0 0 0 0 O O CO O O O O N cci O O O O O O O O O O O O O O O 0• 00, 2 M C0060000 .4.CM r >1 66660 00666 66666 6c -. a N 03 0 V V CO a, d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C-) N N M co ([) r Z `- N CO V N CO N. CO 0) O N M V LL) CO r CO N pO M 0 $ ,- s- C .. d F- LL .3.. .a E Ca 0 0 > d a O' d .0 0) > C O~ 0 a f%) 0 Cl) '' is /� O R !. G 4 1 ). / \ L.. V CO (() 0 CO 0 V 0 0 U) (6 CO 0) CO (O CO CO (O U) 0) V co Co V co I— CO CO (O 01 N CO CO CO CO V (O CO (O I- N. r co a r r r r r N N N N M M M M M M M M M M M M M O CO W m p r O (7 U) j 0 W W 0) O CO N N a 0 0 0) N CO CO CO N- 0 N- 0) 0 0) CO (O CO V) 0 0 (() CO CO CO CO CO I,- 0 V CO )f) O 0) 0) O r co co co co co V CO CO Z Z (O I. CD 0) r N M6 (O I. (0 O N O 6) 0) 0) O) O) 0) N N 0 Or r r r r r r r r r r r r r r O O W O O O 0) 0) V V J as N w Q CO CO toM CO CO CO (O (O 0) 0 (O 0 (O N CO 0) (O CO 0 co co co N N Z 0_ (O 0 O CO O CO 0) 0 (0 0 (O 0) N (OW r O 0) M 0 N CO CO (0 h.. + + = CO M M (0 6) I- O (O (O r (O N CV • N M O O U Y (O O V 00 r CO (O I- 0) lO CO (O CO 0 0 N CO V I- 0) M O O N O M N N r O O 0 CO I� O O co co V co co co N r r 0 0) Z N N C O O O O O O 0) 0) 0) 0) 0) 0) O 0) 6) 0) O 6) 0) 0) 0) O N r r Q CO CO co co co O co co co co co U) (O (O v) (O (O (O (O (O 0) v) N N C 7 E 'y 3 V V V V V V V V V V V V V V V Cl- V V V V V V c o IT �i 0 0_ H W N CO (O O M CO (O CO C- I` N (O N. O 0) N CO M N- co N 6) 0 CO (O 0 CO N V V N CO 0 O co. < (O I- CO (NI co 00 6) N- V O O O (O O) M O N M V M O O O (O N.: (O N. y co V 0 CO I. N N- CO O O V 0) V 0) V CO O CO CO O CO O -a IT V V V M M N N 0 0 0 0) 0) CO CO CO I- N. N- co co C o C V ,- rr r r r r r r r r rO O O L t O O r r ..? ."6.1t+ 0 0) 0) CO 0) O 0) 0) 0) 0) 01 6) 0) 0) 6) 01 0) 0) 0) 0) 0) 0) 0) yO (n i6 N N N N N N N N N U) (n (n N U) O (n U) (O (( U) IY = 2 C N O 0 U ZCU OCU7. O O O O O O O N 46 C U (.) to O o V 0 N (0 CO V (O N O CO N CO CO CO CO V N rO 0 0 0 0 0 0 0 0 0 0) N- 9 w y N M NO O ON M V V ( O O O O O O O O 6cae' R r rO,1 r rrr ( 0) co0) N- I,- ,— r N Ce ce L C) d 0.1 () �. .U) O I- n 2 CO Cl I— �. J N CO N CO N- Cl- 0 V r N N (NJ O O 0 0 0 0 0 0 0 0 a' CO V O N- 0 CO N V r 0) O O O O O O O O O O O M M6 V V V V M N r O O V O O O O O O O M M co E x al 0 E 1 vo 7 J CI rO C 03 I a co O 0) M O) CO r (O CO V co r n N 0 O 0 CO CO CO co I� co r 6) co co (O r CO CO CO N- r Ni. CO 0 r 0 (f) N I,- et -a- r N 0) 0) V M O (O N I— M O O N4 O) (n «) V F- V N 0) (O I. N O 0 V O h (O O N N (O I- 0) co ON- I,- CO 0) 0) O O r r r r N N N M M CO CO M V V N NE r r r r r N N N Ni-N N N N N N N N N N N N N 0 w -2- co O O 0) M .-- 6) CO (O CO V O I- N 0 O 0 CO CO (0 N CO N. O CO N 0 V 0 N N N co 0 CO I. 0) 0 0) V co (O O O O M N 6 V O O N 0) (O N O M V M co 0) I� V 0 CO N_ n N 0) N co 0) M I,- r 0 N V CO N N. O 0)) 0 0 N N N M M M CO V V V (O (O (O (O CO ^ r r r N N N N N N N N N Ni- N N N N N N N N N FTu 2 O) N- N n 6) N 0) CO V CO O N. N. n r I,- N- I,- I• M N (O O CO O CO N (O () V O O) O N (n O I- O 0) O O O O O O O co O O O co I— L (N M co M co co M co V V V V M M M M M co M M M M N N N N N N N N N N N N N N N N N N N N N N •EN v ),. C) •N Q 0) O CO (O CO CO 0 CO (O co co GI O co O co O co O V co F. V (O u) I. co N CO O) O O 2 O O O CO O O O I� N 0i N O 0 V 6 N O (0 6 (0 N N (0 6 O OJ O O CO 6 N C -O co V V (O (O 6 O O CO O O CO CO C' CO CO O O O O O N CO CO .,..?„2. O C) a OV .-. O Oca r- O) CO W 0 U ?j 04 MU. COF a U- Q O M M Z Z 0 O 7 C') 0 N 0 0 0 0 0 0 0 0 0 0 0 0 ' O 0 O O O V O M O Mo O Z O O 00000 O O O r 0 O 0 0 0 N O O 0 (0 0 0 a TO O 0 0 O O O O O O O O J O 0 O O O co 0 Mu) 0 J O O Q. C) O 0 0 0 O O O 0 O O (O 0 00 O0 0 O 0 O V 0 D O O (o 0) 0 r N M V (O CO N- O CO 0) 0 r N CO CO V V Ci(O O I� I 3 0 .^' r N N N N N N N N N N N N w CO' y M CO- M CO- C M CO E M y co- M (N`I c ci 2 2 n N to 0 0 0) GV O C N 4 y - CA C p O .O m m y m O a in O a co ORIGINAL _ N CO CO 0) V _ co N CO 0 U) O V- CO V 0) V O O u) (0O O N M V u) h u) N N M M M V V V u) u) u) (O a CO V V V V V V V V V V V V V V V V V V V V V V V 7 O 0) W y O N U) W 0) C/)O O N N p p 0) u) O CO CO CO 00 u) CO N N V N- 1-,- 0) co r 0 N a a a CO O 0 O CO O V CO n O M u) N- O - M M u) UD O O M O@ N C7 V V u) co N- I- UCIN N Ni N N CO CO CO CO CO V V V 0 Z Z N N N N N N N N N N N N N N N N N N N (V N (s/ N N 0 O 3 W 0 0) 0) tel _V - J �` U) V U w - U)U) u) N- 0 CO N VN co (O M M ON N O V O V O O N O N O .- r V CO 0 u) rM O? 'O 0 Y uN- M <0 W V O O V CO <- dN • uNi (O O V 0) CO Is--- .- CO 0 0 V CO CO CO N- N M OO E2 O O UVO N- r O U) N OV V V co N N .- ,- 0 0 0 O O CO CO N. N- z NN Q G CO <0 W N UD 6 co- D 0OD CO W O 0 O O UD O I- N- I- - Nr. N- N ,- O . uu) uu0 co uuCl) u) Cl) CO uCO Cl) Cl) Cl) u) uuu) u) uCO TO V v v v v V V V V V V V v v v v v v V v v v V Vc c m •E a) m m E c O W .2. d d I- UJ (O CO_ N- _ CO r CO 0 CO N- CO u) CO N 0 V UO N- (O O CO 0) O V r CO O u) u) CO N` CO O O N u) N CO V O u) O O M CO u) O O 6 CO CO u) co (O CO N- N- N- O N- N- N- N- r O N 0 V 0 (0 N UO (0 CO N 0) O M 0 N� _ UO UO u) N O 0) CO V U .a 0) N Cl) u) V V M M M M N N N N 0 0 0 0 O 0) O O O C F O O O O O_ O_ O_ O_ O O O O O O O O_ O_ O - O O O O O O +V) t 0) O O O O O O O O O O O O O O O O O O O O O O O O 4- d y E O co- u) u) u) u) u) u) u) u) u) N u) u) u) u) u) u) u) u) u) u) u) u) N K c Z m O U O 0< U ca =p U V i yUO N UO O (O CO V N N 0 0 0 0 0 0 0 0 0 0 N N O (O N m M O O O O O O O O O O O 0 0 0 O O O O O 0 0 0 Q 0wN .m 0 y O O O O O D N. N- N. CO O (OO O O O O O O O O O O O O O O O U m .- e- <- N- K _• c 0 0 i id _ O 0 .... J � 2 Z O O H 0 0 0 0 0 O O O O 0 0 0 0 0 0 0 O O 0 0 0 O 0 O 0 0 0 0 0 O O O 0 0 O 0 0 0 0 0 0 O 0 O O co O O M M M M M M M M co O O O O O O O O O O O O O O O cts E E E O N 7 0 J O C co a. CO co O 0 co CO V V CO N CO 0 V N- 0 Cl) CO CO 0 N- 0 00 CO N CO M N N- N� V (0 CO e- CO CO UO O CO O cO N- 0 0 N O Cl) UD Cl) u) O N O CO V O N. CO a) Cl) N O O V co N- UD CO CO cod N N- CO 0) (O CO 0 V N. Cl) CO 0 CO Cl) CO UD O CO V 0) CO 0 LO Cl) O CO N. UO 0) 0) O O s- N N CO V Cl) U) U) (O N- UO CO UO 0) CO N -^. N N N N N N N N N M M M CO CO M M M M M M M CO M M Cl. O 0 CO co co O co CO_ V V03 N CO 0 V N- 0 Cl) O CO 0 N- 0 N. N N N O (O 0 u) r 0 N u) I- O N O V CO O O O ✓ N- V u) O_ 0) co r CO O O N6 V O N- UD M O u) (O N N- N W V N- u) O N 0 N- u) CO 0 O CO CO CO UD SiO V (O N. ti COUO 0) 0) 0 0 N N CO V Cl) Cl) CO r N- M 0 O O O • F N N N N N N M M M M M M M M M M co M CO M M CO V V CO N- Cl) UO N V N. N. N. N- N- N- N- I- N- r N. I,- N. N- N- N- N- O r CO 0 CO O ✓ W UO O O O Ni Ni N Ni N N N Ni Ni Ni N N N N N N N t CO CO co CO V V V V V V V V V V V V V V V V V V V V N N N N N N N N N N N N N N N N N N N N N N N N E N — US N Q O u) V 0) V M m co CO M CO CO CO CO CO CO CO M CO CO CO CO CO CO N- UO W UO O O O M M M M M M M CO CO CO M M M M CO CO M O) (O M O N R N O N O O O O O O O O O O O O O O O O co a m 0 M .N > a N` O U N Z M a c V > [)' N CO 3 N 0• 7 L M N. N M 0 0 fl. a.M C M .0 Q 3 = Z S Z N Z Y Y N a N 0 0 0 0 0 00 N ('! O 0 0 0 0 0 0 00 0 0 O n 0 N- 00000 00V- 000 0 0 0 0 0 O O N 0 0 0 N O <I- 6 a � O O O O O O O U7 f.2 0 O O O O6 6 O O N O O O O • Q. U) O O O O O O O N O O O O O O O O O O O O O O 0 O (y co O O - N co V V uCO n CO 0) 0 s- N CO CO V uCO co r N 3 0 CO CO V V V Ni. V V % V V V V V uuuCl) Cl) C uCl) uCl) 0uCo 0nN c d n v N 0 LO] U 0 0 N n 0 2 . .. a rn 0 .. v d 0 c va` co o a ORIGINAL CO O CO CO N CA V O CO N N 0) (0 W CO 0) CA O N N (V CO CO N- I- t` 00 CO 0) O O 3- 3- 3- N M CO CO M V V V V a ✓ V V V V V V (O (0 6 U) CO lO Cn (0 6 CO CO CO CO 6 .S Oe. m W▪ N O a w 0) W W o O > 0 N I"- N N CO CO N O I"- CC) N V CO CO CO C O) V N LO O 9 .0 CO 0 CO CO O CO o CO 3- V V r O V V o O 1••••• CO CO V N N V V V V 6 Ln Ln N (O O CO CO ti N N. CO N N CA C) 0) 0 Z Z N N N N N N N N N N N N N N N N N N N N N 0 O V) y C0 > > W w 0 0 rn rn a V V J N O co coW V CO O r CO CO OO O N CO N I-- CO O O N V CO CO CO N N C d CO N CO CO Cn 3- Ns CO O V CO N CO CO CO 3- N- - N- 1` n + + 7 N N- O N N CC) CD O M (O M (A — M N O V (A C) CO CO M 0) C) 0 . 3- CO O O V CO CO I- CO CO 0 V CO CO CO N M O o 0a r CO CO CO CO V V co CO N N N 3- O O O 0 0) C) 0) 0 Z N N C r r n r I` r n r I` I- n r r• r r I` 1� O CO CO (O N "- '- Q CO 6CO CO CO an C0 an )n CO N N 6 6 6 6 C0 C0 6 L (n C C N E to = V V V V V V V V V V V V V V -4-V V V V V V m ( (D 2 a W a a I— 2 W CO N O O 03 N- CO CO CO V N M O V 0 N. CO CO CO (0 N CO CO Cr) O O N CO CO V (n CO (O I- CO I- M .- CO N: r I- I` I- r M CO N O CO Co W m W N CO O) y M O N- r V CO CO N O O CO CO O O 0) N V N N O .1 C) O 0) CO Co CO CO n N N- N- CO 0) CO CO CO C0 )O CO CO (O CO C 0 CD CD rn 0) 0) Ci C) O) C) 0- rn CD CD• 0 C) 0) rn rn• a) CD0) L ;C V 0 0 0 0 0 co O o O O O C) O 0 o 0 O O O O 0 ..d.. m 1 0 0) C) C) C) C) C) 0) 01 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) ... CO CO CO ) CO N (O N CO CO CO CO CO CO IO CO CO N• CO (O CO x z C d p C y 0 iC o c u E 3 0 0 0 0 0 0 C. 0 0 0 C. O 0 0 0 0 0 0 0 0 N- o C O O O O O 0 0 O O 0 0 0 0 0 O O O O O CO O O ` dw (/ W O O O O O O O O O O O O O O O O O O O N-MO O ww Ce d L 0 a C6 • 0 ° 2 s- . Z (0 Q I- O O O o 0 0 0 0 0 0 O o 0 0 O C) 0 0 0 0 0 L', 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o E E do' In JO p Com.. CC a_ CO O N CO O V CO O CO 0) O CO O r W O O N- n 0) O N V r C) 3- O V (O U) OCO CO V O O CO C) Ln o- N6 V O (O M M O) C0 CO 6 ,- V O O V) co V N N 01 h CO N O N- h 01 M O O (O CD CO CO M CO C) O .- ,- .- N CO V V) N 10 CO I- OO CO CO CD C) O O O 0 CA N ' CO- V V V V V V V V V V V V V V V V (0 l0 C0rts Q 0 0 - V CO O N CO O V CO C) N CD 0 CO 0 N. 03 O O ✓ CO CC C) CO CO CO 0 C) CO N n CD 0 0 N C0 CO 0) O) W V O O r M C) N N (0 V 0 M h O M CO CA m CO O) IN IN V N 0) N- C0 N N O CO CO CO O CO 0 N- n co N N CO V V (O CO N- h CC CO 0) CD O O E V V V V V V V V V V V V V• V V (O (O N h 6 CO n N- r r r N N- r N- N I,- N- r n r IN IN N- N- CO CO . . • N N N N N N N N N N N N N N N N N N N N N L V V V V V V V V V V V V V V V V V4 V V V N N N N N N N N N N N N N N N N N N N N N E — N C6 74 Q co Co M M M co co CO M M CO CO M CO CO CO CO CO CO N O N M CO M CO CO CO CO CO M M CO M CO CO M M M CO CO CO 2 CO O O O O O O O O O O O O O O O O O O O O > d N O V V V V V V V V V V V V V I. V M cv co .g a U r) ( 0) N. O 0) .,•-.,•-••Nj Z CO Cl. el CO C :r ;.-- E, C > > n Z 0 /0 U 0 N M H a O Q Q M M p C RL c Z Y Y N0_ N O O O N O O O O O 0) O O O O) O CO < O O V Z NI O CO Co 03 C O O O O O O O O CC O O O O CO O M ^ O o O N COM CO E a >. 0 0 o O O o 6 6 (7 0 0 o C0 o N O o J N N r.: 4 (yNNCV O O O O Po O O O O C) O O O M O LO CC O O CD 0 C) (y W CD CO O O O .0 '- N CO V TO u) O r A CO 0) C) NO 'T- )- m 0N uo CO CC CO 0 (O co- O 6 0 N o O 7 O CO r n I-- t t`- VI r 0 C n CO Q. a, 1= F h N N u .0 • m o• a. co33o a 00 0 IGINAL N u) (0 c0N N N (0 `Cl" V V V (O (O (A (O (O (0 -Q (n U 6 IN 0) (A (A (n cc; c i 3 o) n m w` a00 a U) N- o0 W 7 N V 0) COco (n •co O O W W C N N 0) 0) O) y ,62 J °O O a O O 0) O N N N CO CO CO (0 LO JD .0 V O O OO (O (O (O n n n Z Z N CO OM OM CO CO CO CO CO CO 0 O _ N N z Z 7 7 Co o YJ V (0 CO a ) O 7 N ao a0 ea q� 7 m 0) G N O co N O n (0 O COM (O N O V N- V J n n Q. CO CO O O CO N N V (O (O n 'F + 7 N 7 C- n ai O O N O (n cn co O O 0 . — (o co a) a) U) V V r) O O E ca N W CO CO N- N- n n N- N- n s- Cc6 cO N Q v' (00 (00 (00 (00 (O (0 (co- 00 (0 (0 (0 a) m m a £_ 2 .y a) v v v v v v v v 'Cr v o m c m v, n d d F i W UJ ` N 0 N N- a) U) co ,- sr co co co CO a) n c' V V .E ) CO ( w O V N 7 7 7 7 0 ca W N 00 W V M a) co co 10 (0 a y W co co co co N N W U .a O) (0 V V t V V V V sr ' c c o) a) rn rn rn o) rn rn a) o) t .E ){' O O C) O O O O O O o y CO a) o) a) a) a) a) y 2 o w 030) 0)(n 0 U) (n (n U) (O (n (n ((i C Z N (O d O N d c U d C — V N 7 O O O O O O O O O O O) U) a c c i u o 0 0 0 0 0 0 0 0 o Ca CD-c a m m To o 0 0 0 0 0 0 0 0 o c o O O w 0 0 ai a) a) 0 m >. R y 'C ` 6 (n O K t m a v G c) >> D O Z ) m ° z J ~ E Z O) 0 F v 0 0 0 0 0 0 0 0 0 0 a' o O o 0 0 0 0 0 0 0 (6 O O O O O O O O O O N n E E C ui E O CO d ;3 (m CO J 0 0 W .07.. Ci CO' 0 C Z. Cl.03 N O LO CO CI o O co CO O O M O O (UO O co O r;W 0 n (o ' M a) (0 (0 O •-. 6'' M co Ocol T al ,- o co(0 (o (o 0 o O •- N N N N CO CO Z r. co (\j N y o) N (0 (O (0 (O (0 (0 (0 (0 u') + a (o v N Z a) O ^ O co O a) CO O O 0) O (a O O O a) n CO CO N W a) 7 0) a) O N a) O (0 N co O) M 7 (D O) O (CQ� N- N CO CO M V V V V V > 0 V d U) o E (A LO Lo- (0 l0 co- (O l0 (0 cr hhh"' 7Fy W 3 O N V O 0 O CO (o CO CO (O CO CO CO (o co O O O O N N N N N N N N N N .c V V V V V' V V V sr ^ . (0 N N N N N N N N N N a L' 7 _ O N ° R a) n 'N co Q 0 0 0 O U) O N N N N N N N N N N W O N 7 0 co co co co co co co co co co p) 00 C C N 0 M a N• Q) W n 0 c co d >• CC N M 3 C ... C O O 0 = M N M U O C O Q a M O M (q N M F U 01 Q 7 7 Z u Z'm o) o) v Z Y Y N a N O CO (n O O o y CO O co co < a) N N C 2 O O E 0 O CO a a 0 (O M (O a al N 7 (0 C.0)7 0. 0. T O W o O N O 7 O M (O (O t0 N U "O sr y O co 0 O O 7 CO a 0 O V K V h Y R N C) N N 0 CO V V d ' co co co co N w N D n n o n n n c n n n CO n N n CO E w y E a t M A O C U C U C .. Ci .8 2 v I- F m o M F Z E ,a, O (0- o (0 5 V O c W Y'+ ? .a dao N a 0 .-4- 0. r 0. d .. .0 O) cc 0 03 0 O) ( N O M O E o :: m m w m a O a CO S o d I- I- O N CO GflGINAL CO a m 0 0 O w 0) Cb al a ` ON O z o z 00 _ _ (0 N D 7 O O 0 W W a V V V (4 cQ 0 co co 2 0- 1-... + I` + + = (p M 6) O 0 Y M6 O N Z N N C C ? c C a a r Ci u c c N L • w C) W 2 co V N Ce N M c r 61 O W O) V r. c d O O ? 2 m ° •••• o v d c, 0 o O m w m O m w > y O a y = d a 0 0 'C Z 16. m N o 0 0 0 0 0 0 0 0 0 0 0 0 O 0 O R 0 0 0 0 0 0 0 0 0 0 0 0 0 .� Z fq :: c� (n O. o 0 0 0 0 0 0 0 0 0 0 0 0 Ecr 3L• L- E) (o U 0 t6 E E = T co co C C co d J co 4) on (0 a_ N R Z d A Z c N J) M r xx N 092. CO (V N fl" r = N a 2' Q) CL r CO N n m 1� co u7 O CDD C.V O ca 03 C'N )i (o N.M O M On CO CO O I- 0 0 H F- c0(6 i.- 0 0 0 0 E N 6) O 6i O 0 0 0 0 0 0 0 0 0 0 0 0 0 V O 6) 6) 6) 6) 6) 6) 6) 6) 6) 6) 6) 6) 6) 2 464 M V O R = 6) N (o M N M O Oo M (o M r CO V, Q O-' N (n (n � Q M V (0 m N 0 N CO r LO V r d O ` (o N CO V (f) (o V V CO V N (o (o C c n ..- 2 O N .(` > d O O co (O LO CO 4) 'Q. N (`M') 3 N = _ to V) O O V I'4 6) co CO N 6) I(C M CO CO (o V (o MI CO N N CO 0 r O (o N V (o r (o C Y Y_ N 0 7 4 4g DO (o W ` ((j r 0) OJ (o O N M M I� 0 CO M R W N N- CO 3 = 0 O 6) CO CO 0 6) 0 W V o W CI (0 l6 M M y 0 `_-' m C. . V co CO CO N V O (o CO N V (o r PI n zN W N 2 v co" () (O n r (o o LS (ri M I- NQ YYd 2 a v 2 co C H M 5, ii0. o a d _ a rn c E O. y O U a t 3 0 C �O m m OR1GIALN (0 a m d 0 Lei w w h 12 12CL O 0 m � 0 z z U 0) NN 7 O O W W O O V V V 13 = O f0 O_ r co CO 0) M O O) 0 Y f4 (v) O o CV CV E m 0 7 Q N N (0 N ? C a a a r 2 LW d a c C O iL d E re C 0( . O t0 N r C y 0 m a c f?)o Lv. y c O iai N w � K U w U N To. C4 L C>) 9 m J > 5 2 y 8 a a0 2 N (6 0 V [.... CO E O O m M co O O LO I- N E O o d M O) = O) O � V M ,- r.-- (/) - C0 07 0 -O 0 !0 @ ~ 171 O 1- L 1- O d O L O N O L LO .. V O M N a- N O m N -, ri c 0) 00 J co J u LO a LO a NO co ( a, l6 N N N (0 l6 O U O) V) O) O) O) O) H 0. a Q CO N- CO N M N N CO N. C (O LC) N 0 LO LC) 00 r LO 'Cr O CO CO CO Q O 'Cr .- O (O CO W N M M M W W + is C a `o 0 UN n N O) 0 LC) Tan CO O) N. LC) CO W U -J0 03 V) 0 CO LOO M CO ct ' i Z U N N N N CD R (O CO OO) O U L N CON0 O) m W ca LO E O-y co co LO O a- a- V .0 j 0 a N N N CO- O LO LO O N j d N- O N M d CN Ti 0 0 0 N M M O) O Y Y Z 0 a co O O V coLn ` ^ N n d L O O O O O) N O O O 0 LLn O) LO ° n n M C M y �•N Q) O LO V LO N M M V R r z Y Y N d N m 0 "' CD 2 CI. C .. M C N (`I ` 0 C - d N 61 C 0 o C E O ..-.. W C) 0 A Uain33o o 0 com ORIGINAL N^ ii a I 1 N • U C v + §- N N N nd - w^� E, ,D. O G O `V w 3 W y U x o Ce M + L M z O /A t z •- • O \/� C N h r N CU �, _ _ _ U — E c r h w R Q _ . Te. ,--,-,.. C ,ctS �. Z W L.. y N E 0 6 a R E d9mu) R O 01 N . M m m v 3 Cl) E 12 - HH1I Q oo.alIM W_iii � 0 S C ■ N Z a u °- W N N R V U F E I. Cl) i� .' a } O N J ALA`` V ■mak o y y Q is LL O W ti O C Tr O` C - 3 .'L_ J ) � O L S o opo, o � °� o VO N M 3 co 0 N A o � m' o � � � m y a m m � � CJ'J c� z . Z U V N d d C L M N R C 2 2 ti N h CU+ • = a o ui c' o 0 IC M4 M C M W }, 7 o x m l c F F a a . C . E12 � a� o ♦ ♦ m = Z 2 z V Q ' w - = F, Ra .L22 0 Y Y N a N O it � 3 o m in � > in y - .,„ , 7 ...... _.. _ '.M: • ;".... . ,.�..,: I'—, i ---:--...=:-., ,-e-r,, a d,,,;',,.a--. eN4tEGizii„ 3'., -7-.- fIG_kG _s 2_ ORIGINAL C., O 0) x ) a C a � 0 .C2 ,-. x CS ce. C N 1) ..1C;) N N N N N N N N Y/1 N N Cd .2 a' ,..::.`. ,): a a a a a met a a a a y ¢ lU es = m O O Y O O O O O O O O O O O Q o. 2 2 2 2 2 2 2 2 2 2 2 2 2 CA N N N N N N N COMMON N C N N CO CO N N N N N N CO CO N CO CO CO UI CO CO CO m CO CO CO CO (U a s a a a a a a a a a a a .0 O OC C.1 'a _ N E O O 08888 888 O U U O U U U U U C U U U U O m E co C m W N (U O) N C N N CO 0) U C LL LL d u_ LL IL LL LL (U LL a a (L d d d N d d d d d N d d d d C C) C) 00000 0 0 0 0 0 0 G C C CCCC C C C C C E N N d co co co co co d co co co co 7 co co C lU (U (U (U co C lU lU (U co y d dIII d d d d d d d d d d d 0 0 0 0 0 00 00555 0 (O N . 00 n CO (C1 N V 0 10 0) d O V O CO (O V M N 0 V N N M U N .O+ Q1 NCO N n n (Il ltj CO CO W O) O 0 U) .. d LL U 0 0 0 0 0 0 0 0 0 0 0 0 v o 0 0 0 0 0 ,i0 0 0 0 0 0 O O O (O O l0 (O ( u7 (O O N l0 (() 7 L e 0 (O N 0 n N N N N. (O N N N CI) 0) M M N CO N N N N (O (O N N CO p2 V CO O) 00 N. 01 0 n CO (0 N. 0) V C 00 O V O V N :f.)). O) M 00 O d 0 O) CO V O CO O) CO (O Ne-s N. 0) 0) 0) COOO CO CO O O) to to O O. E N v N. IO U) (O Cr CO Ix- n (O W d C) N O 'p O O) N. O O O O (N OO O O O N V r 0 0 0 O a0 1� O O O 01 O L O 0) .N- O O O O O (O O O O N N G.' 0) 0) 0) 01 0) O) 0) V (O CO 0) 0) Q CD d = N N N M N N N N (0 co N N N D v 6 d E (O N CO V U) LL)n O N.CO ( CO N _ n (O CO CO n 0) n (0 CO n N C E U N. (oO Cn0 ON) N Nn (0 ((0 (OO (O 7 V an 7 7 N E C w CO N N N CO CO o CO N N CO CO N C C N 7 O 0 r Ili 07 Mo o .- O N. 0 0 0 0 N N 0 0 0 CJ N a O N N O O O O N O O O O CS ..- E O V n O O O O OD n O O O V w o L 0 W LO O O CJ O O (O 0 0 0 c o a N ti,,, N rn rn rn 0) CO Cb O) v (O 0) CO 0) F2 Q 07 7 N N N CO N N N N co (O N N N 0 d 3 W 4o ti A CI . L• M C") C z .a 1 O N d Z Z N . n E 1 N M M Zz L N C N a al M el 3 C 01 0 O N 1 NO 'O 7 0 ZC1 0O •n `o d o N M A 0 a o 0- if 0 d LL Z 3 (� M 4-• O N U C ` M m 0) o t c -a N c a V C (0n ✓ R O A CO CO CO N Tu b O N N m n °n° z z z o Q .' N y 0 M (O n CO C1 0) 0) M (O V N N O N M Of CO (O A/ E n �' E M M . Z Z M M M M M Z to 03 O O) M N Q, Li x N N N 'a Z Z Z N N ZZZZZ 01 .0-1. Z1.0° C Z N N N N N N N N CO CO N CO C O 16 LO ONO N d M N n ra- °N. 0) 0) CO (O (a0 N N 0 N a N CO CO CO CO CO CO CO V V V V (O y O �' C p z M M M M M M M M M M M C C M C : Z .0) m m C Z Z Z Z Z Z Z Z Z Z Z m �O Z 0 C0) 3 N N' N d N N N N N N N N N N N N a s N d CO •O C ci a7 .3 W CO �' M (O n I� n Q1 M ( M N N O) O) O O N O O. CO CO CO CO CO CO CO V V V V V V (O (O C) = U C 'a Z E Q M M M M M M M CO M M M M M CO CO C O d K ce •' o = ZZZZZ Z Z Z 10 0 Y j C C d) N N N N N N N N N N N N N N N a < t d V (d) F- K N to ORIGINAL r ,--' C ' co 7 Q Y •0 4.3 a >_ O C O~ CS con G, c Qcon 4 .0 O U O O 0 V N 0 F N N N w <0 0 Z Y Y Y 3 Q (I) Q Q co ct ce LL 0 LL LL + O + + 0 0 } co `o M C a a a) a a) 0 coc 0 `m U- N CO ai of 6a co 0 00000 0 Q. 3 3 3 3 3U' 0 0 0 0 0 r aN W N N N r 0 M CO M M M C M M M M M 0 0 IN. Z Z Z Z Z U• N s CO N N N N N N 2 E CO ao a m c Z co O O O O M M N 3 N (6 N M 0 0 0 0 U) U) C C 1 o a20 Si N Si (4) lam() °" N m E N N CO- 7 CO- I� n O U) 0 E M r Na) E M o 0 c w 'c Z o o m o 2 > o N N OMOOOOC) ZN a Y L i O M0000UN 0) W 0 0 0 0 O F) O Q)C O ' 0 CO O O O O VNN N 1.1 0 ONN m 0) vva) U) NL d . il- v NNMMcO f� OU m N L • N C • Oco O (0 0. 7:3O0 ONNU 0 N C L 00 0 O 0 YOU U O O_ 'oN N U O U U N G N 3 N O N C 3 U U 3 ••0 E N 0 0 O 'O j a U 0 Q O y O O O LL 0 O 03 V 'a O o 0 O C c0 C a U n a (0 Q , O N N _ W 0 C0 0 0 0 ORIGINAL N H ci > > cC E2 zI2. a a Y > N N M N N > N N m 111 .L Q Coo 77 N N (N >CV CO > > > > > > M > > > < r > > > > > LO > > > U . N N N M 2 M M M M CO M N CO CO CO CO CO CO M CO � C c ., - ( N (N 2 2 2 (N (N 2 2 2 N N 2 2 L 2 2 N 2 2 2 C < 0 .0 Q N Q N N N N N N CO N N (N < m N N N N �N} Q N N N , r 0,G N N N 2 2 L 2 G 2 2 2 2 2 2 L 2 2 2 2 2 G 2 2 2 2 G N - v - N N N (N (N N N_ N N N N N N N N N_ N N N N N N (N f N N N M M L (O (- a1 N N M In r r r 6) N M (n (t7 t` 0) O) 'V N N N N N N N N N CO M CO CO CO CO CO CO CO V V '(C V V 'ct 'cY V 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2N (N (N (N CON (N (N (N V 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 I 1 1 1 I I IA a —Lf) ! I I Lo 0 1 a o I i v N 41 O �' 4) I �� CO .? -,.., 416 r 13 w ^` Ilkc.". 1 __Lx.) I I I oi,, 3 LC I „ I 0 Z 1 CZ I 0 M Wrn �yo C . M 0 Zn o I I M N cmi Z . I I aci " .(')(7) I I I,. `m w o I I M a� 0, o 1 1 C) , mN (j I I I r - Y i I Z Z © m () I I I N N a) Q <2 a L 2 + M wI I Lf) 0 I- 0o o rn > I I 1 r I i L > g O ( I i 0 m a, a v ! 1 I I __ _. p T- 1 1 of CO m O 1 I I W m (> u) o v -6 N D O� O N N N o 2 E .N 0 O 0 rn •N o m N c 0 0 0 ti) 13 a Y a) CO M m 0 o 2 (ui�lsn 00£) uoi1eaedeg alivaj of aJquej U • N N t2 8 ''L' C1GJNAL a 0 co a x 0 co 0 U C U R - O o - a c, N CI m0 CO a > N N N M M IR. i''' N N > 1. I E N N O co Q_ LC) N G Q N d dCV> < > > > > > > N > > > n m 0C/ rn CO Q o 00 N N. > > > > > to > > > 1N M CO CO CO 1N CO CO N- M N CO LO N- CO M O) Ni co 1f) V' N. co M{ O G N N N M1N L M1N 1M 1NM 1M 1M ,M1 N M 1M 1M 2 2 MSM M A yA � A A, M T. N C L N L G L L L G 2 G G N N L (N G 01 L N 01 G G < C C N CQQC�33 N N N N N N m N N N N N_ N N N N N N U NP " " " " " " M M 0,1 M M C N- N.NCv.� m M N CO 11) 10 N. Op a�a C M 'R .R .R M M y M y M M M M M Cv) M M M M .M1 M y M < f a) a) a) 2 2 G G 2 ± t 2 2 JL JL t 2 G 2 2 2 2 2 2 2 N -I -I N N N N N N N N N N N N N N N N N N N N N pNppq N C ci N N N N co N N N N N CO CO) N COMM M M M M A A A A g A C M co 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 222 22 f (�') f 04 (N c�'1 ('. 2 : 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 N CI I I '.. 0 .. O I to . , ...._1.... ro f . —O n ,• • 0 - - us a '�r o ,' —� L i 0 - c 9 i' _ uu)) R T— 11•-07 - C 11 �R M Z Nlir iro N N cl I/ —90 M >i } M w o 1 Z N N 0 O E c O CU O Q1 y O CL o _� v r .- d o C - N fA as o g r to N O N- Ot N .D0 O O U O V = p OJ N tO to N: N O (u!/09.6 aopoed uo!;eaedas c as 0 Q U UIGINAL Se- 'ID Inc Az: TVD -Ni-S +E/-W DLeg TFace VSec T ' 0 68.63 240.46 2326.24 -854.71 -976.13 0.00 0.00 1263.13 2N-337Cwp03.1 4.00 -90.00 1356.05 J6 68.68 2 .236.17 2 .43 -1162.97 -1055.36 0.00 0.00 1819.43 0 2900 4 ese8.42 40.32 242.16 3095.61 -1564.82 -2101.18 3.00 171.93 2589.87 2900.00 To 7546.53 57191.85 40.32 242.16 5179.58 -2390.95 -3665.22 0.00 0.00 4358.68 2900 3200 6 7192.27 40.32 242.16 5179.90 -2391.08 -3665.47 1.00 154.22 4358.96 2N-337C DB 13Jan14 Top Semi 77546.53 40.32 242.16 5450.00 -2498.13 -3868.16 0.00 0.00 4588.18 3200 3500 9:04,August 08 2014 3500 3800 Iiiij 3800 4100 GLOBAL FILTER APPLIEI 4100 -- 4400 4400 4700 e09 From Depen m Survey Plan 700 4700 5000 251.00 2824.36 37(271-347) MWD 2288 2000 00 X0.80 229.43; I(Pen:22-370) ere-ec55 c.zsc 5000 5200 3400.00 4500.00 29.33]06003.1(P87:22.-3370) .6 3400.00 6900.00 21633706.303.1(P8n2 216337.1 58D4I00-0({4290 5200 __�___-__- 5500 6900.00 7546.53 2N-337Cwp031(Plan:263370) MWD 7548.53 7546.53 271-397Cwp031(Plan:343370) 180/134IFI488L1Z-SC 5500 5700 CASING DETAILS 5700 6000 TVD MO Name Size 6000 6200 2311.23 2858.10 75/8' 7-5/8 5000.00 6956.31 51/2"x 7-1/2 5-1/2 5450.00 7546.53 3-1/2"x4-3/4" 3-1/2 6200 6500 6500 6700 0/360 6700 -- 6956 300 sllr,/'" 6956 7000 -30/330 ..44:7,�j�,IV� 280 30 7000 __.-___.. 7100 lopEz �F % 260 , 7100 7200 �.��=_` 50 240------,---____T 7200 7200 7300 ,1\>>�Q��_ 220 7300 7300 11� ��`��:.;: 200 �` 7300 7400 ��,1``�`�.\immlitli t• `` 7400 7500 ♦�.44-4,� `diV gtf, 180 c T.O .a.""WZIrC:t', , 7500 - 7547 -60/300 #®�A� •!ir: t 160 60 ` •' p,��wo, 140 `�®Ip��e�n�iQ4 61 \\ 124 `�tires• 101 11111114.4.... 00111t ii *1' 80 : ' \ �� \, \ ISM ,f 61 ,:\\\ \\‘ \ \\\\I ,.........., k, ,,, \/: \ ,\ ,,,..7,, 41 ''',,.s \ ii..146 26 90/270 ,MI`, �iGu`_ 90 `, \ 41 7f,:, ,1tt�� ` 1 j 0Ni'imiHmo' 0 11� / f�llf II 141 -120/240 161 ! 120 180 4' / % 200 . 220 :� 240 -150/210 280 / 150 300 :_i -180/180 -s- 2N $ 25830.0103~254323500 -A-3 04337.,200726 -X- 2N .8- -0- 0 44-24 .0433,0.033,006 - - 28349 000:0m)06 � 254 3 3:�").293370.,6.W 44- 28 .e- 2» � 28353.223350.28350 V2 4- 214342.282422214342.we,nw.6200 $ 29 - - 34 -0. 29 3566,63.300 -6- a -6- 254 .3- 254 .e. pan 284330.,03.0 -0- 254 -_-• 254 -x- 254340µ303,24H3011 •.- 2»22(0 h2N.01,29,24.,0360 -x- 2 -43 2 -� 0 9 03 333 peac).254333254330(4040`.0 -x- .322lvartm 2343214 aw -x- 2 •460 w + s28 1r55A:!2005O2 0 88 <,P, g'4n Ill 0 Oc. ' 3 0) 2288 11 N O s Z$ i �ab0 N na + I. O § z �/� O 0 NM1 N NN t1J cl LI" '$a ZN M `• i _ 1 N ✓ `218 W o Iii 0ca AA 1 N O g �II� ti� O cl Ear � � i � 2C a �/ Zf$._ `` as 0� 3� O cn el 2 4 )//c" / r, \VIII�: T b. 214 O u M• •.� e'z.. •b' ._ 0 Utz. o co O. a) b 11-NZ t�E`, 11 / 6.E, Z 318 %.yj131 — „yZ 2N=3' , v 2 £" t � O N. L - ... – --- LEE x.=333 335..._.__ O CV) CD ece Nt �R. _O CO ''"'"' 9ZE NZ rn 3A1 2N=341 CV 0 A` O O 35p O 2P' N ._2.,;SAS T O ✓ Q Lr) CO r II I I H 0 0 0 0 0 0 O ' 3 O O O O O 0 rn O O O O 0 0 a O) CO CO co c0 d) r (u!/l)tSn 0000) (+)U�aoN/(-)u4noS ORIGINAL. g g g g I— = cs, . F , ,- 0§ •o . kr .. —0 , a) ../. . co L ! W LIE 2 8 8 [ \ iNi I 3 \ ; $ $4: 8 4 E ZO _ ill 1 CD .. .‘? CD § r-- s:1 (g.4: 1 /, +ni to h to • +rag' rcg 2.9.. r. 0 L' P Pi i 0 , —7r :\11113 1 . 1 .s. + .- I 1 = ..........7 --, a 1 A ES : IF.? g r 52 0 " , 0 Ps csi . a) el •..... —Lo O. a) •_ .' 0 2 il c s ir,c1x, 8 1. A \ : c, IIIin T1: ' I c) 1)%•• L. _ cpl Z —.9 111 -- -- \ -.1 0 CN \ 1 1 N. 1 CI 2.I'VSs9 I CY) Nt C:) Tr i.. j C) CD co \0'31 LO TA 20-333 2N-344 ?NV 31B 2N-337A z bgpcive 1 , I" z a I I r-: 0 0 0 0 0 0 0 V ci 0 0 0 0 0 0 CO CD •c1- C\I 0 CO I -- C\I CO Nt Nzt (u0}511 IOUS) (t)L-11Aul\l/(-)(-1111uS oRrE .m. A 1 88 RA <A 8 F;8 c W O C$ 2 vein Zf1 0 22 O U v U N- a "'�8 1 n 1 a .7c A aN.2g h g .Agi G/1 --a 6o O 6 - O V) ......... r --,.. — Li', T rl O I -‘1:1' T O1 N 1 n M 3 U - CI Za� CD ti O `, �1 a p ,AIII NA V) F w o M •1ri. • = j - a1 pM m M E Pi y r t C? yTr \6 N 1 ni isj I d I a N CO o rn CV 1 - el 2N.339 I I O `f O O (NI CO co LO N 3 3 Q 1 1 1 [ 1 1 ,n p O O O O O O O O O O O O O 00 to d N O 00 (u0}5i1 uu8) (?)NP uivi(-)ii1� S "Cf 1, • • C) • '•,ii / ■_ • .Y • :4 M • • • • Z M .t; N Z .. \ if.• • N T o M ONW/ t. • • ZNI" M M Z N • : : N • { :r' ORtUINAL 2N-337C wp03 Surface Location r I IZI CPA!Coordinate Converter ! t 1' From: -- To:- Datum: 1NAD27 .j Region: f alaska J Datum: 'NAD27 ] Region: jalaska J Latitude/Longitude 'Decimal Degrees .� r Latitude/Longitude 'Decimal Degrees .1 r-" UTM Zone:' r South r UTM Zone:r rue r South ii ( State Plane Zone:r4-71 Units: 'us-ft .j T State Plane Zone:14 �( Units: us-ft . C Legal Descoption lti:,,l2r oniti is Legal Description(NAD27 only) i — — — J -Starting Coordinates:- Legal Description — - -- X: 1460596.52 Township: Grir IN .i Rang. 007 E . Y: 15911892.60 Meriden: 1U I Section:I-3 1 {moi '_ FNL 116.39624 FEL 996.36483 Transform 1 Quit 1 Help I N. V6SnPfA.IMIIIIINMMESIYIMIMII•MMIMt2N-337C wp03 7-5/8" Casing Shoe I�. CPA!Coordinate Converter f "�� ""R From: To: Datum: NAD27 . Region: lalaska J Datum: 1NAD27 .1 Region: jalaska .1 - Latitude/Longitude 'Decimal Degrees .' C Latitude/Longitude Decimal Degrees . C UTM Zone:I r South r UTM Zone:[True F-- South i State Plane Zone: Id .1 Units: Ius-ft .d C State Plane Zone: 14 . Units: 1-us-ft . C L�y"sl(i->cripriuu 1N- = I-,Drily! i:- Legal Description(NAD27 only) 54. -4 Starting Coordinates: Legal Description 4 X= 1459650.10 I Township 1009 1N 007 E ( : R j Y: 15911062.32 Meridian: lu j Section:13 FNL 1951.72434 1FEL 2L1 11939.8132 1 1. I Transform Quit 1 Help 1 41 0 1 G 1 N L 2N-337C wp03 Kick off Point � �tj CPA!Coordinate Converter r, = + From: -To: Datum: INAD27 z..j Region: jalaska J Datum: 1NAD27 .) Region: lalaska .J Latitude/Longitude [Decimal Degrees J r Latitude/Longitude 'Decimal Degrees .I - UTM UTM Zone: I -- I-" South C' UTM Zone:I True r South r� State Plane Zone: 'q-- Units: (us-ft 11 C State Plane Zone:I •q . Units: us-ft C Legal Description(NAD27 only �: Legal Description(NAD27 only) Starting Coordinates: Legal Description- X: 1459616.05 Township: I e— N Range: 1007 IE_1 i Y: 15911043.06 Meridian lb J Section:13 1FNL -J 1971.16570 FEL . 11973.7971 Transform Quit I Heb I i 2N-337C wp03 Intermediate Casing CPA!Coordinate Converter 1- E ! 1" ,,a:, 1~ t� From: To: Datum: INAD27 H Region: Ialaska Datum: INAD27 Region: laska r Latitude/Longitude Decimal Degrees J C Latitude/Longitude [Decimal Degrees J C UTM Zone: (-- South C UTM Zone: ��-- True r South is State Plane Zone:{4 ,1 Units: lus-ft LI r State Plane Zone:14 7.j Units: lus-it .1 { r € g.,l L nptm EN ?y=:a tyj ( Legal Description(NAD27 only) --Starting Coordinates: — Legal Description X: 1457054.16 Township: 1009 IN .J Range: 1007 IE .1 Y: 15909591.74 Meridian: lu J Section:13 jFNL H [2436.7136 IFEL vI 14530.5751 Transform_._._.._.1 Quit I Help 1 ORIGINAL 2N-337C wp03 Top Bermuda L! CPA!Coordinate Converter ; C i " 1* From: _— __- - o.__ --- Datum: Datum: NAD27 Region: ;alaska A DatumNAD27 g J Region: alaska _- Latitude/Longitude {Decimal Degrees J C Latitude/Longitude (Decimal Degrees .j r-- UTM Zone: 1, 1- South r UTM Zone: True r South i 1 t State Plane Zone:14 Units 2.11jus-ft . C State Plane Zone: 4 . Units: us-ft • ! C !_.:aI Description(N.61327 only1 a Legal Desaiption(NAD27 only) Starting Coordinates: -- Legal Description X 1456915.75 Tomship: 009 1N A Range: (PT IE .i i Y: 09519.58 Meridian lb: j Section:13 IFNL . 12509.6555 FED. 14668.7343 Transform I Qua I Help I I. 2N-337C wp03 TD l . CPA!Coordinate Converter = I '" 4... From:. _ . To: Datum: INAD27 Region: alaska .� Datum: 1NAD27 Region: alaska 7_1_ -- Latitude/Longitude [Decimal Degrees J C Latitude/Longitude (Decimal Degrees UTM Zone:! r South C UTM Zone: T111e r South r State Plane Zone:I4 A Units: 1us•ft .J r State Plane Zone:1 4 _,,,:i Units: jus•ft . r Legal Description itgAD27 nnli! is Legal Description(NAD27 only) Starting Coordinates: — Legal Description X 4%715.541007 - - Toavnship: � � .j Range: 1007 jE .� Y: 15909415.17 Meridian: IU J Section:13 FNL . 12615.2304 FEL 14868.5774 , o' Transform On 1 Help 1 i ii ORIGINAL Ap )n for Permit to Drill,Well 2N-337C Saved' 11-Aug-14 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2N-337C Drilling Hazards Summary 6-3/4" x 7-1/2" Hole/ 5-1/2" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, and Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 4-3/4" Hole / 3-1/2" Liner Interval Event Risk Mitigation Strategy Level Plan mud weight according to expected Abnormal pressure pressure. Flow check immediately upon encountered Moderate entering Bermuda, and again —50' into Bermuda. Have mud additives ready and prepared to weight up if needed. Condition mud & clean hole prior to trips. High ECD/Tight hole on Monitor ECDs with PWD tool while drilling trips/Swabbing Moderate across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Keep hole clean—use PWD to monitor hole Lost circulation Moderate cleaning. If losses occur—reduce pump rates and mud rheology, use LCM Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. In general, no significant clearance issues exist with the 2N-337C well plan. The closest well in is 2N-339 with a separation factor of 2.87. The well is 190.47' distance between ellipses at a depth of 3000' MD. Drilling Area Risks: Reservoir Pressure: Offset injection conduits have the potential to increase reservoir pressure over predicted, although this is unlikely, the rig will be prepared to weight up if required. Due to the greater degree of reservoir pressure uncertainty in the Bermuda targeted interval, the Bermuda will first be topset to keep the shallower unstable shale behind pipe prior to penetrating the Bermuda. 2N-337C APD Page 10 of 14 Printed.11-Aug-14 i ' Y I 1 I Ap in for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 Lower Shale Stability: Higher mud weights in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. 2N-337C APD Page 11 of 14 Printed: 11-Aug-14 , , i► E t rig Ar on for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 Attachment 3— Proposed Well Schematic Tarn 2N-337C Stennis potary Sidetrack Tnpset Conventional Slant ir.;•,-..•-zr,1- ConocoPhillips Proposed Wellbore Schematic FMC Gen V -:•TFEE Erurs.vldc 5,11,14 J ,.. 16"Existing Cemented Conductor: 16"62.5#H-40 108'MD ' 3!ti•C.3"33 01 ..SND Nro<23-3- 1 yN{•C -.6 PPG Et .on't need t•, •.-•-•rine 1!i'r I'Ca-co SPX:- ' existing Surface Casing: 7-518"29.7#L-80 BTCM 2,851'MDI 2,309'TVD a 69° 3'..ar Ca'-co PAX O d£:r3:t KO z or Uhler t mug a-5&6 degrees In open hoe a-2.20:'NJ �arnpar:ian Top 3,443'MJ 12E:4 7-volk. - .. .. . ? Tubing: 3 r.-ca r.i: w 3-1/_'9.3#L-80 EUE8RD _SND -r.6—10-0 PPG Keep up with TC, 15 5 e 64/2"x7112" Dilution Fdg 8;+'•_,20C +� Intermediate Hole 4"DP : \ xta a rrolx;nro • Iteherg Tope C30'NA ID 2n n: 1 t, • Baker CMS IId M e.. • o w.' •+ 2717'Ca •q33.P EI. MD t LC.Lher?CC Faces X'W3..tact LRr Ha-we, a' Ce'•w D'.e .27s` . t.? M_ , O •_•• \ a-1c_,SEM ` Intermediate Casino Topset: \ 5-1/2"15.5#L-80 Hydril 563 connections ^; 6,956'MD 15,000'TVD 40° r 4. ', P. • Ua Hsi + . dL tot FD1t z 1 £�P x�r 5` PHS I;;: 1D: Pi B • •:• ,#., tivap i&tiol witii BE 1 tii 15 Fi>teP aS1u '£ , = v£,--1Ei4 ; 1 PP'. "1..Ec l , 8tiu .i n 0, I It .[.. 9 s3z''. 5 4e2 TvO '-' .'.. .'. 'l:. { .. .. .. -.- ...... .. Ease Derr Jda 7,3U' .. 1MO 5.327'TVD Cemented Production Liner: 3-1/2"9.3#L-80 Hydril 511 7,54T MD/5,450'TVD(e�403 2N-337C APD ORI (�`^ I N A L Page 12 of 14 Printed: 11-Aug-14 Ar on for Permit to Drill,Well 2N-337C Saved: 11-Aug-14 Attachment 4-Cement Summary 5-1/2" Intermediate Casing Cement Job Cement 5-1/2" casing from shoe @ 6,956' MD to 5,200' MD (minimum of 500' above the top of the C37) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the open hole volume. Assume under-reamer to bit distance of 100 ft. Lead Slurry: (6,956'-6,856') x 0.0834 ft3/ft x 1.40 (40%excess) = 11.7 ft3 in open hole (6,856'-5,200')x 0.1417 ft3/ft x 1.40 (40% excess) = 328.52 ft3 in open hole 80' shoe track x 0.1335 ft3/ft x 1.0 (0% excess) = 10.68 ft3 Total volume = 11.7 ft3 + 328.52 ft3+ 10.68 ft3= 350.9 ft3=> 302.5 Sx @ 1.16 ft3/sk System: 303 Sx Class G @ 15.8 PPG 3-1/2" Liner Cement Job Cement 3-1/2" liner from TD @ 7,546' MD to liner top @ +/- 6,700' MD (minimum of 200' inside the 5-1/2" 15.5# casing) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the annular volume, 0%excess inside casing. Lead Slurry: (7,546'-6,956')x 0.0562 ft3/ft x 1.40 (40% excess) =46.42 ft3 in open hole 256' inside 5-1/2" 15.5#casing x 0.0668 ft3/ft x 1.00 (0% excess) = 17.1 ft3 80' shoe track x 0.0488 ft3/ft x 1.0 (0% excess) = 3.90 ft3 Total volume=46.42 ft3+ 17.1 ft3+ 3.90 ft3=>67.42 ft3=> 59 Sx @ 1.16 ft3/sk System: 59 Sx Class G @ 15.8 PPG 2N-337C APD IGIPage 14 ft O A L Printed: 11-Aug-14 -14 Ferguson, Victoria L (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Thursday,August 14,2014 11:52 AM To: Ferguson,Victoria L(DOA) Subject: RE:2N-337C(PTD 214-121)AOR Attachments: 2N-339 Surface Cement Daily Drilling Report.pdf;2N-339 Production Cement Daily Drilling Report.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria 2N-339: Surface cement job was a 2 stage job. 15t stage was 50 sacks AS3 & 240 Sacks class G, bumped plug&floats held. Opened the stage tool & pumped 117 bbl. 10.5 ppg cement, plug bumped & held. Production cement job pumped 49 bbl. cement, bumped plug&floats held. I've attached the daily reports for the cement jobs on 2N-339 here also. Let me know if there is more needed on 2N- 339. For 2N-337C BHP the estimates from the reservoir group are ranged from 1800 to 3200 psi with the most likely value of 2800 psi. If one takes the total depth TVD of 5450 ft, yes the 10.4 ppg would calculate to 2947 psi. I used the top of the productive formation TVD of 5184 ft to calculate expected pressure of 2800 psi as it more closely matches the reservoir engineers expected pressure of 2800 psi for the plans. For the purposes of the PTD, should we use the total depth TVD in the future? Thanks Scott From: Ferguson, Victoria L(DOA) [ma ilto:victoria.ferguson()alaska.gov] Sent:Thursday, August 14, 2014 8:58 AM To: Brunswick, Scott A Subject: [EXTERNAL]RE: 2N-337C(PTD 214-121)AOR Scott, For the AOR for this injector, please provide cement job information for 2N-339 which is within the % mile radius. Thanx, Victoria From: Ferguson, Victoria L(DOA) Sent:Thursday, August 14, 2014 8:46 AM To: Brunswick, Scott A(Scott.A.Brunswick@)conocophillips.com) Subject: 2N-337C(PTD 214-121) 1 Scott, The reservoir pressure used in the ASP calculation is 2947 psi(10.4 ppg). Should this be the maximum downhole pressure instead of the 2800 psi? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria.ferguson@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 2 Security Level: AK Development OS Daily Drilling Report 2N-339 irge6/ Cvnoau+Philhp6 Report Number: 3 Akxka Rig: DOYON 141 Report Date: 5/22/1998 Wet Type AFE Typ Network/ID# AFE*Supp Amt(Cost) Development AK9501 Wellbore Field Name DFS(days) DOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) 2N-339 TARN PARTICIPATING AREA 3.00 3.0 0.0 0.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) Actual Start Date Original Spud Date AFE Duration Total(days) 'Projected Job Duration(days)'Job Days Ahead(days) Projected Job End Date 5/20/1998 5/20/1998 Last Casing String SURFACE,2,963.3ftKB Ops and Depth @ Morning Report 24hr Forecast Nippling up BOPE Last 24hr Summary General Remarks Weather Head Count Supervisor Title RWS Supervisor Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 01:00 1.00 SURFAC Np DH 1,243.0 2,970.0 TROUBLE SHOOT CASING TONGS. See comments above. See comments above. 01:00 03:00 2.00 SURFAC P 2,970.0 2,970.0 RUN 7.625""CSG. 03:00 04:00 1.00 SURFAC CIRC P 2,970.0 2,970.0 BREAK CIRC @ 1650'. 04:00 06:00 2.00 SURFAC P 2,970.0 2,970.0 CONTINUE RIH W/CSG. 06:00 09:00 3.00 SURFAC CIRC P 2,970.0 2,970.0 CIRC AND CONDITION MUD. 09:00 '10:00 1.00 SURFAC CEMENT PLUG P 2,970.0 2,970.0 PUMP 1ST STAGE CMT JOB, W/50 SX AS3 AND 240 SX CLASS G W/ADDITIVES DISPLACED TO CALC AMT+.6 BBL,BUMPED PLUG,FLOATS HELD OPEN DV STAVE TOOL W/DART @ 2900#. 10:00 18:00 8.00 SURFAC CIRC P 2,970.0 2,970.0 CIRC AND CONDITION MUp, PACKING OFF PROBLEMS AT CASING HANGER,WASH HANGER. 18:00 20:30 2.50 SURFAC CEMENT PLUG P 2,970.0 2,970.0 HELD PJSM F/2ND STAGE CMT JOB,TESTED LINES AND CEMENTED W/5 BBL H20,30 BBL 10.5#SPACER, 117 BBL 10.5 CMT DISPLACED W/72.2 BBL H20,PLUG BUMPED AND HELD 2100 PSI,CIP @ 2030 HRS. 20:30 00:00 3.50 SURFAC NUND P 2,970.0 2,970.0 N/D DIVERTER SYSTEM. Wellbores Wellbore Name Wellbore API/UWI 2N-339 501032026100 Section Des Size(in) Act Top(ftKB) Act Btm(EKE) Start Date End Date CONDI 18 0.0 108.0 5/19/1998 5/19/1998 SURFAC 9 5/8 108.0 2,970.0 5/20/1998 5/21/1998 PROD1 6 3/4 2,970.0 8,239.0 5/24/1998 5/27/1998 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS("/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Head Count/Manhours Function Company Name Count Note Latest BOP Test Data Date I Com Page 111 Report Printed: 8/14/2014 Security Level: AK Development of 8 Daily Drilling Report a 2N-339 ConocoPhitlips Report Number: 10 Rig: DOYON 141 Report Date: 5/29/1998 Well Type AFE Typ Network/ID# AFE+Supp Amt(Cost) Development AK9501 Wellbore Field Name DFS(days) fOL(days) Depth Progress(ft) Start Depth(ftKB) End Depth(ftKB) 2N-339 TARN PARTICIPATING AREA 10.00 10.0 0.0 0.0 Daily Mud Field Est(Cost) Cumulative Mud Cost(Cost) Daily Cost Total(Cost) Cumulative Cost(Cost) Actual Start Date Original Spud Date AFE Duration Total(days) Projected Job Duration(days) Job Days Ahead(days) Projected Job End Date 5/20/1998 5/20/1998 Last Casing String PRODUCTION 5.5"x3.5"@ 7575',8,227.6ftKB Ops and Depth @ Morning Report 24hr Forecast Running 3.5""completion tubing Last 24hr Summary General Remarks Weather 'Head Count Supervisor Title DB Supervisor Time Log Time Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 00:00 04:00 4.00 PROD P 8,239.0 8,239.0 CONTINUE RUNNING 3.5""X 5.5""PRODUCTION CSG. SEE CSG DETAIL FOR ADDITIONAL INFO. 04:00 08:30 4.50 PROD CIRC P 8,239.0 8,239.0 ESTABLISH CIRC @ 2.5 BPM W/PARTIAL RETURNS,9.7 PPG IN, 10.1 PPG OUT. CONDITIONED MUD TO 9.7 PPG IN,9.7 PPG OUT W/FULL RETURNS @ 3.5 BPM. 08:30 10:30 2.00 PROD CEMENT PLUG P 8,239.0 8,239.0 PUMPED 5 BBLS WATER,10 BBLS PREFLUSH,40 BBLS t SPACER AND 49 BBLS OF CMT.1 DISPLACES W/179.8 BBLS OF FRESH WATER,BUMPED PLUGS,CIP @ 1012 HRS. CHECKED FLOATS,GOOD. OBSERVED FLOW FROM ANNULUS,SHUT IN WELL. 10:30 14:30 4.00 PROD P 8,239.0 8,239.0 MONITOR WELL,SICP 130 PSI IN 50 MIN,NO FURTHER INCREASE. WOC. 14:30 16:00 1.50 PROD P 8,239.0 8,239.0 BLED OFF 130 PSI,OPEN WELL AND MONITOR RETURNS. INITIAL RATE 4 BPH,FINAL 1.1 BPH. 16:00 20:30 4.50 PROD Np DH 8,239.0 8,239.0 ND BOPE,INSTALL EMERGENCY SLIPS AND PACKOFF. NU BOPE. Report does not say,but assume the casing stuck off bottom and the hanger would not set into the wellhead. Used emergency slips, which is a back-up for the Gen V mandrel hanger.This was one of the three production casing strings (out of 23 wells)which required the emergency slips to be empolyed. Latest BOP Test Data Date I Com Page 112 Report Printed: 8/14/2014 Security Level: AK Development 0 Daily Drilling Report r� 2N-339 c«,ocoPhillips Report Number: 10 Rig: DOYON 141 Report Date: 5/29/1998 Time Log Time Start Depth Start Time End Time •Dur(hr) Phase Op Code Activity Code P-T-X Trbl Code Trbl Class (ftKB) End Depth(ftKB) Operation 20:30 21:00 ' 0.50 PROD P 8,239.0 8,239.0 TEST PACKOFF AND CSG SPOOL T/3200 PSI. TEST TBG SPOOL T/3500 PSI. 21:00 22:30 1.50 COMPZN CMPLTN 'RUNT P 8,239.0 8,239.0 RU TO RUN 3.5""TBG,HELD SAFETY MEETING WITH GBR AND RIG CREW. 22:30 00:00 ' 1.50 COMPZN CMPLTN RUNT P 8,239.0 8,239.0 RUN 3.5""COMPLETION. Welibores Wellbore Name Wellbore APIIUWI 2N-339 501032026100 Section Des Size(in) Act Top(ftKB) Act Btm(ftKB) Start Date End Date CONDI 18 0.0 108.0 5/19/1998 5/19/1998 SURFAC 9 5/8 108.0 2,970.0 5/20/1998 5/21/1998 PROD1 6 3/4 2,970.0 8,239.0 5/24/1998 5/27/1998 Survey Data MD(ftKB) Incl(°) Azm(°) TVD(ftKB) VS(ft) NS(ft) EW(ft) DLS(°/100(t) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Head Count/Manhours Function Company Name Count Note Page 2/2 Report Printed: 8/14/2014 Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Tuesday, August 12, 2014 3:56 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2N-337C: Permit to Drill Hi Patricia We will not pre-produce the 2N-337C wellbore. Regards Scott From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, August 12, 2014 3:42 PM To: Brunswick, Scott A Subject: [EXTERNAL]KRU 2N-337C: Permit to Drill Good afternoon Scott, Will the KRU 2N-337C well be pre-produced 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.bettisPalaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, August 12, 2014 3:42 PM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: KRU 2N-337C: Permit to Drill Good afternoon Scott, Will the KRU 2N-337C well be pre-produced 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. c L -^L' L c WELL NAME: 334 C DIY -I� ) Fxp! ra ert' Stratigr=ph,ic.Test IYO:1-':_O'!t'Cr;ll01-,o' Check Eox for Appropriate LeU:er/ Paragraphs to cue included in ransmit i Letter C;i:ECIC OPTIONS TEXT FOR APPROVAL IMER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 To N o N N a a) n U V7 N 0 C O 7 m a> O O Ti) c Lo m 0 Q a U c LN L o_ N N L m U a) y U c 3 3 i\ o o 0 C 0 00 LO O a`) c -0 Y - 0 Qo 3 m E 3 O CO > O w Q1 a) m . ix L m a o) a N 0 a W w O 'OC E a oO O ,_ 3 a) coO 0 0 a) C O 3 O O — E. E O O E aa' co CO 3 -00 ti CD c a`) a) o of 7 a) O O X _ ca a) 3 N C 7 N 0 a 8 m 0 c @ 3 *iii C o c o N o - _ ,to •-0 o m w O, co p n T a) — ` 0 ami Q -0 aa)) N 3 D c-° .O L O U O c 3 as 0 a> U @ N U `• 0 co O M a) Ts N 2 •3 = .E C 0 N- c ` C N co c o o W Q .3 a) co o m c — a _ >> O n Z >O w a) a) N 0 "p ` n N N > `k C. X O 0 O Z O N .0 0 n a) a)8 o O d cc O 7 W O O Lo K aO m co -O E >O m O M @ d 0 a C Q o — L E 0 U a E O 0 N n 'O n m V 3 L O N L N CO > w E 0) •a m co > >, 3 O W 3 O N Qj V a > co O L -0 -a N m �' N J m co CO h O N a) co _N CO m p 2 L L m 0 coV 0 Y `O .� C Z co 0 N 4' E N :7 3 a) O) CC - CC a CO N NN N Z ".7- a 3 M o U) a) 0 C •o �y T O c CC O 0 Q m M N "O E — U O 0 O N a) m CO a CO ~ 0- M `00 M Z - m 00 m V N CO 3 7 U a) a E a> 2 V M W a) a) m Y C >' N Cr ,- N 0 Y m C w 0 E Z Y C N N Z C 7 N N O. O C O Q L O a) U) c N co a QO O U > L U L N U C C C @ CO m M N C C N y ip 7 v co o o = ri 3 N E a) c a 7 r v0i c E � o Y c co 3 M U U a) fQ/. V7 uO) a N N 3 0 -p a 7 ) Z a) a 0 'o a) m CO CO N < N E O <0 N m 7 U U U m N0 O w0 a E co N U Z 0 O Q O = D w -o m m L U CO �? a) a) O a) z 0 C D 0 0 0 O o o = = o 0) 0 C ccoo a N Z co a (1) m , W Q Y Y a. U < Y CO O cn U) a a a < 2 2 I N 2 W ct c a CC w (1) < a CO a) a) Cl)) a) a) a) a) a) a) a) a) a) o < < Q < < a) a) a) a) a) < a) a> a) a) a) a> a) o a> < < < Q z > >- r r >- > >- >- >- >- >- >- >- z z z z z z >- r >- >- >- z r r r >- >- >- >- z >- z z z 'r• >, F- o m i^ N v m N >n 0 1 m U f° 0 00 C To a) o E E 3 — E a) O 0 U j 0 c N Oo .- N LL T .O.- _T 7 �- c L O LLE in it o C• a> U CI co a) 3 E 3 0 _ a N O 0 M C o O @ 0 C 0 •E 0 .S LC 0 ami E m J i U N N Q Q) O E 'c3 co N a ,�( o "O > O cu • 0 Q m 00 LL N N 0 ``/\ Z 7 O LLL c -t N m 7 C c / Zr) O- Q "6 .� Q N C O` C cr a) p) V a) m N a= o Q -2 a a) U 0 U m 0 a) coN co w a) C O C O w • J C E L CO CO C > E O 2 w 3 _ 0 > @ 'o a) o O U) o co 0 0 C 0 Ln n 2 3 �' 00 `> N > CC (6 3 w 70 �. 0-) 7 0 O. a> -Q - a ''=.- N a) 7 a) m T c> -p o xs E a) co co O 7 _ CC U "c 0) i > N m 7 3 2 2O co c O) L C N 3 0- L9 7 Q N N (0170, Q) Z "0 0 C -0 o N C O m a) 0- • D O C 0 m 0 O D) 0 L 0 c •• Y Q E E = 0Q S c E `r m o C C N F- c o E> ot) aa) c r 0 a N r a �)c CC o o a` 7 o 0 c ,,,co o o m Lj 'n a p c) o •ai d ° - .3 0 > co N T Eh g CL 32 Q 4 o a) a) — .0 T O C C o -0 m •(p Y m O O p 0 m 0 E - as (p Q CO N > O Q) O 0 c N D E a U U 0 o o C c — a c o - . E 3 aa) o a L (6 3 w a> E Y < a) 7 c c C m 0 L L m 7 N a ap 0 0 m - 0 m o N p n 3 p 0 3 o)E ti c :° co co o n -O m m -O E 0 N c N co c`p co L a) O o C T Q T:, U) 0 N N m 3 .3 0 _12 .. o .- ° r. 3 m '- o Q 0 "' a ._ 7 m o 3 0 L 0 o Ill U O a .O 'a .0 'O -0 co>TT) N .a "o _o >O m 0 c o N O o C ' V 0 -Qp N a a o 0) c -o C N Z 0 a s m a m o p N 0 E Y as 0 o N E 0 cp E L 0 a) n N c �) J o a a) -o O. a a) -2 0 n N N a 0 V a) OU a O2 a) a) — a N 0 "O @ E C OU N N C O O 'O 2 U m E m O O C a) @ a N N cap L < 'C N 0) a U c p} N 0 m 1`0 0 O > ._ -O 3 2 'C N O N O a a a 0 3 m CO O) N 41' (` O 'N. O co 0 c C N >' N L L L 3 L O) C a) N > D) C m a) n L 0 o U a) C T :C N LL 8 m L — N a) O co c C = N c0i 0 N -Q -Q O 'co L 3 OCT -O p UN) c 0 U m �c 0 c 0 N g3 m ii2m m m m m 3 7 ° `O U m m = o a) — F 'O 2 m — c _U m N m Q C F' Z C 0 o 0 0 m ° ° .0 w 0 0 o c 0 a) 0 0 m o m s vi n E '3 N c 0 02 0 -0 0' U1 O 0 7 0 0 0 .� m m Q o a a o 7 U > > 3 c 7 2 7 Cr 0 CC) W W 0 0 L a E 0 m ai J U m 0 .E a) a) a) = -o n n a`> a`) co a) 3 E o 0 c 2 2 2 co -0 m 0 = O O C 0 a a a`) w a>0 to a) o 0 m 0 , a J > > > (n .. O O a a O a a Z U (n C) U c.) c.) a �- a .= 0 CO to U N g a o (n (n U W n O N M V C) (0 O O) O N M V c) (0 CO O ''c N M v L[) (0 CO Q) E N co V (C) CO N. CO 0) C r- '- 'r h. ' N N N N N N N N N N M M C') C) C) ('') (''> c'':-, C') C) 4? o w2,r O C •"0' NO - O O (N V 0 1i. N O 0 - O) 0 ,_ O N ED z d V " c0 ` 00 W N E J N E N o c W aIE a ma c a ; a a s 0 as a W a c9 a Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk Rig: Nabors 9ES Date: December 30, 2014 Surface Data Logging End of Well Report 2N-337C TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Inc. Rig: Nabors 9ES Well: 2N-337C Field: Kuparuk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20262-03-00 Sperry Job Number: AK-AM-0901889899 Job Start Date: 28 November 2014 Spud Date: 06 December 2014 Total Depth: 7667’ MD, 5547’ TVD North Reference: True Declination: 18.832° Dip Angle: 80.753° Total Field Strength: 57547.651 nT Date Of Magnetic Data: 25 November 2014 Wellhead Coordinates N: North 70° 10’ 11.67229” Wellhead Coordinates W: West 150° 19’ 12.75228“ Drill Floor Elevation 148.97’ Ground Elevation: 120.90’ Permanent Datum: Mean Sea Level SDL Engineers: Jacob Hanson, Leigh Ann Rasher, Hilary Garney SDL Sample Catchers: Justin Wiseman, Mario Luescher Company Geologist: Kelly Umlauf, Eric Bressler Company Representatives: Josh Riley, Don Mickey SSDS Unit Number: 121 DAILY SUMMARY 11/28/2014 SDL arrived on location and began to rig up the unit. 11/29 - 12/1/2014 Continued rigging up the unit. Installed gas trap. Installed and calibrated gas equipment. Set up computers and configure. 120/2/2014 Observed a shut in pressure of 320-350 pounds per square inch and began performing well control while circulating 10 barrels per 30 minutes then monitored the well for 30 minutes. In the process, the well was bled off with a 7.2 barrel gain over 18 minutes. Then the well was displaced with 10 pounds per gallon brine and observed flow. Then the weight was increased to 10.2 pounds per barrel and flow was observed. 12/03/2014 The well was displaced with a 10.4 pound per gallon mud weight which then the well was monitored for flow and the well was static. Afterwards, 5.5” casing was pulled from the hole and a BOP test was performed. Then tripping into the hole with 4” drill pipe with the cement stinger began. 12/04/2014 The cement plug was pumped down hole then pulled out above the plug to circulate and condition the mud. Cement was pumped at 200 pounds per square inch into the hole. The mud was circulated and conditioned again before tripping out of the hole. Then 3.5” tubing and the cement stringer was laid down and e-line and dutch riser began rigging up. 12/05/2014 Ran into the hole with caliper tool and logged 7 5/8” casing then pulled out and laid down the tools. Afterwards, drill pipe was picked up and singled into the hole then out while cleaning out the mud system. Drill pipe was picked up again and tripped into the hole to tag cement at 2635’ MD. The mud was circulated and conditioned then the pressure test of the casing to 2500 pounds per square inch for 30 minutes, which failed when p750 pounds per square inch was lost. The well was then flow checked and then mud was circulated and conditioned. Then pipe was tripped out of the hole and waited on parts for further testing. 12/06/2014 Waited on tools and began to load 5.5” casing into the pipe shed. Then began the trip into the hole and made up the packer where it was inspected by a Baker representative and ran into the hole with drill pipe to 2612’ MD. The packer was set at 2606’ MD and pressure tested casing to 2500 psi for 30 minutes then bled off pressure. The packer was set and tripped out of the hole. BHA #1 was then picked up and ran into the hole to 1578’ MD where the tools underwent a shallow hole test. Continued to run into the hole and tagged cement at 2635’ MD, then began to drill out the shoe track to 2718’ MD. Gas: The max gas was 21 units at 2703’ MD and the average gas was 12 units. Fluid: No losses reported. 12/07/2014 Continued to drill through cement and officially kicked off at 2886’ MD. Drilled 20’ of new formation to 2906’ MD and monitor well, which was static. The mud was displaced to 9.8 pounds per gallon LSND and monitored the well again, which was static. Pulled out of the hole into the casing and performed a formation integrity test to 14.3 equivalent mud weight. Washed down to 2906’ MD and drilled ahead to 3450’ MD. Gas: The max gas was 88 units at 3410’ MD and the average gas was 32 units. Fluid: No losses reported. Geology: Samples consisted of 80% to 100% light grey claystone with trace very fine to fine grain sandstone from 2900’ MD to 3300’ MD and 40% to 60% very fine to fine grain sandstone with 20% to 30% claystone and 10% to 40% siltstone from 3350’ MD to 3450’ MD. 12/08/2014 Continued to drill ahead from 3450’ MD to 4501’ MD while pumping sweeps every 300’ to keep ECD’s between 11.5 and 11.7 pounds per gallon. Gas: The max gas was 45 units at 3866’ MD and the average gas was 22 units. Fluid: No losses reported. Geology: Samples consisted of 30% to 60% grey claystone with trace siltstone and sandstone from 3450’ MD to 4050’ MD and mainly siltstone with trace sandstone and claystone from 4100’ MD to 4600’ MD. No fluorescence seen in samples. 12/09/2014 Continued drilling from 4501’MD to 5197’MD from which a completed a wiper trip to the shoe at 2851’MD was performed. The last stand was washed to bottom and currently circulating bottoms up. Gas: The max gas was 41 units at 5106’MD the average gas was 20 units. Fluid: No losses reported. Geology: Samples consisted of 60% to 80% medium to dark grey siltstones with 20% to 40% sandstones with some traces of claystones from 4600’MD to 5000’MD. The siltstone percentages increased to 80% to 100% from 5000’MD to 5197’MD with some traces of sand. No fluorescence seen in samples. 12/10/2014 Continued to drill ahead from 5197’MD to 6868’MD from which no major issues where encountered. Gas: The max gas was 433 units at 6223’MD the average gas was 55 units. Fluid: No losses reported. Geology: Samples consisted of 70% to 100% of siltstones and sandstones. The lithology transitioned from siltstone to sandstone at 5950’MD to 6868’MD. Some fluorescence and cuts were found between 5200’MD to 6400’MD. 12/11/2014 Continued drilling ahead to TD 7039'MD. Started circulating bottoms up and observed 9,878 units of gas from a connection at 7005'MD. The mud was weighted up to 10.0 mud weight while continued to circulate and checked to see if well was static. Then continued to weigh up to a 10.5 mud weight in and out then started to pull out of the hole. Gas: Max Gas is 9878 units at 7005’ MD the average gas was 270 units Fluid: No losses reported Geology: Sample consisted of 70% sandstone with occasionally 10% to 30% siltstone and shale. Samples had an increase in siltstone and shale closer to TD 7039’MD. 12/12/14 Back reamed hole from 6,244'MD to 6,149'MD, then circulated bottoms up. Monitored well for 65 minutes for gas and flow and observed a 5.6 barrel gain. Tripped out of the hole to 6,500'MD and circulated bottoms up then monitored well for swabbing while observing 0 barrels fill. Continued to trip out of the hole. Gas: Max Gas is 551 units at 7039’ MD, the average gas was 50 units. Fluid: 51 Barrels lost down hole. 12/13/14 Reamed and washed from 3578’MD to 3008’MD. Circulated bottoms up and monitored well for swabbing. Continued to trip out of hole to 2810’MD and monitored well for flow and observed a 0.5 barrel gain on the trip tank. Circulated bottoms up and monitored well for flow for one hour. Continued tripping out of the hole and laid down BHA. Gas: Max Gas is 75 units at 7039’ MD, the average gas was 3 units. Fluid: No losses reported 12/14/14 Ran casing to 2858’ MD stopped to circulate and condition mud. Continued running casing to 4956’ MD, circulated a bottoms up while washing down a single joint from 4956’ MD to 5168’MD and observed a 7 barrel loss while circulating. Gas: Max Gas is 55 units at 7039’ MD, the average gas was 0 units. Fluid: 7 Barrels reported lost to hole 12/15/14 Ran casing to bottom periodically reaming , washing, circulating and conditioning mud. Cemented casing in at 7030’MD’ MD. Laying down drill pipe at time of report Gas: No significant gas data. Fluid: No losses reported 12/16/14 Laid down 71 stands of 4” drill pipe. Rigged up to test BOPs and began testing. Gas: No significant gas data. Fluid: No losses reported 12/17/14 Finished testing BOP. Tested casing shoe to 3500 psi for 30 min. Picked up BHA and ran in the hole to 1500’ MD of drill pipe. Tested MWD tools. Gas: No significant gas data. Fluid: No losses reported 12/18/14 Continued tripping in the hole to 6914’ MD had to stop to service the top drive. Service was completed and continued tripping in the hole. The top of the Cement was tagged at 6938' MD. Came off bottom to circulate a bottoms up to make sure mud weight was 10.5 in and out. Mud Check was complete. Went back to bottom and control drilled from 6938' MD to 7011' MD at time of report Gas: No significant gas data. Fluid: No losses reported 12/19/14 Finished drilling out shoe plus 20' of open hole. Tripped out three joints and preformed FIT test to 16.0 ppg. equivalent mud weight. Drilled ahead to 7396 MD'. Gas: Max gas was 1012 units at 7387’ MD, the average gas was 128 units. Fluid: No losses reported Geology: Samples consisted of mostly unconsolidated sandstone with minor siltstone; an interval of mostly siltstone was encountered from approximately 7100’ to 7180’ MD. 12/20/14 Continued drilling ahead from 7394' MD to TD at 7667' MD. Circulated multiple bottoms up and began TOOH at time of Report. Gas: Max gas was 381 units at 7467’ MD, the average gas was 102 units. Fluid: No losses reported Geology: Samples consisted of mostly unconsolidated sandstone with minor siltstone; an interval of mostly siltstone was encountered from approximately 7180’ to 7500’ MD. Samples from 7500’ MD to 7667’ MD increased in siltstone and shale percentages. 12/21/14 Finished tripping out of the hole. Laid down 2 7/8" drill pipe and BHA. Rigged up and function tested wireline tools. Run in hole to 3012' Md couldn’t get any deeper with the tool. Pulled out of the hole and picked up a wireline tractor. Gas: No significant gas data. Fluid: No losses reported 12/22/14 Ran open hole logs. Pulled out of the hole with wire line and rigged down tools. Picked up third party tools 2 7/8 XO on TD savor sub circulate out guide blocks on TD from 2 7/8" drill pipe. Bring pipe in pipe shed and 511 liner. Pick up 3rd party tools Rig up GBR double stack tongs, elevators continue to Service top drive. Rig up casing run liner PJSM running liner make up shoe track and make up float shoe, float collar, run liner to 844' MD fill every 15 joints circulate and conditions circulate with packer and hanger circulate bottoms up, blow down top drive. Gas: No significant gas data. Fluid: No losses reported 12/23/14 Pick up drill pipe and continue running liner on 3.5” PH-6 Work string. Run in hole from 1783' MD to 6222' MD. Call and fill every 15 joints. Control running speeds for ECDs with packer in hole. Run liner continued to run in 3.5” liner from 6222' MD to 7005' MD. Circulate and condition circulated 2 bottoms up at 5.5" casing shoe monitor shakers for cuttings. Observed 1080 units of gas on the first bottoms up then blew down top drive. Run liner from 7005' MD to 7667' MD. Install cement lines pick up cement head install hoses on head make up top drive, circulate, cement, and displace 2 bottoms up. Staged pump to 2 barrels a minute watch for losses and monitor mud weight in and out. Gas: There was a max trip gas of 1081 units. Fluid: No losses reported 2600 3600 4600 5600 6600 7600 0 5 10 15 20 25 30 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2N-337C OPERATOR: ConocoPhillips Alaska Inc. MUD CO: MI Swaco RIG: Nabors 9ES SPERRY JOB: AK-XX-0901889899 Days vs. Depth 28 November 2014 Sperry SDL Arrived on Location LOCATION: Kuparuk AREA: North Slope Borough STATE: Alaska SPUD: 7-Dec-2014 TD: 20-Dec-2014 Commenced 6.75" Intermediate Hole Section On Bot: 06:00 07 Dec 2014 Drill 6.75" hole to 5197'MD Wiper Tripped to the shoe at 2852'MD 09 Dec 2014 TD Intermediate Hole Section 7039' MD, 4642' TVD Off Bot: 03:30 12 Dec 2014 Landed 5.50" Casing 7029' MD, 5062' TVD 15 Dec 2014 Commenced 4.875" Production Hole Section On Bot: 03:00 19 Dec 2013 TD Production Hole Section 7667' MD, 5547 TVD Off Bot: 11:14 20 Dec 2014 Landed 3.5" Casing 7658' MD, 5440' TVD 23 Dec 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG: Nabors 9ES HOLE SECTION: Intermediate EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 AK-XX-0901889899 Alaska 2N-337C Kuparuk a ConocoPhillips Alaska Inc.North Slope Borough Jacob Hansen 22-Dec-2014 What went as, or better than, planned: Good sample program that was created before the job so that we could be prepared before the job started. This helped with good organization, unit cleanliness of the unit and a plan. Difficulties experienced: We had some difficulties with WITS from the MWD in the middle of drilling but it was resolved by frequently importing LAS data instead. Recommendations: We need to establish a working relationship with the pit watcher to get more information when transfering pits, adding or removing fluid from pits and working together on calculating daily losses and/or gains in pits. Innovations and/or cost savings: N/A Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: HOLE SECTION: Production DATE: Sperry Drilling Confidential Document v 3.0 AK-XX-0901889899 Alaska 2N-337C Kuparuk a ConocoPhillips Alaska Inc.North Slope Borogh RIG: Nabors 9ES EMPLOYEE NAME: Jacob Hansen 22-Dec-2014 What went as, or better than, planned: This well went better than planned. There was good organization and good communication amongst SDL and the rig crews. Difficulties experienced: There was a power failure on the rig and caused some difficulty with data collection. Everything was eventually fixed and minimum data was lost. Recommendations: Make sure battery backups are in place and charged. If the power goes out this will give us time to properly shut down the computers and gas equipment. Innovations and/or cost savings: N/A Surface Data Logging After Action Review Surface Data Logging 2N-337C ConocoPhillips Alaska Inc. MI Swaco Nabors 9ES AK-XX-0901889899 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 2-Dec 3044 10.20 30 ---------------Well Control 3-Dec 3044 10.40 36 ---------------Testing BOPE 4-Dec 3026 10.40 36 ---------------Rigging up Wireline/Slickline 5-Dec 3046 10.40 36 ---------------Pressure Test Casing 6-Dec 3044 10.40 37 ---------------Drilling Cement 7-Dec 3386 9.80 40 10 20 10/14/15 4.9 40/30/25/19/9/6 1/-6.5 2/92 -1.00 9.8 5.0 .80/1.22 6300 80 Drilling 6.75" Hole 8-Dec 4348 9.60 44 13 18 9/18/28 4.6 44/31/24/17/7/6 1/-7.0 2/91 -0.42 9.9 10.0 .32/.80 6000 60 Drilling 6.75" Hole 9-Dec 5197 9.60 46 14 18 12/13/18 4.6 46/32/26/19 1/-7.0 *3/90 *-0.55 9.8 7.5 .32/.90 3000 56 Wiper trip 10-Dec 6623 9.60 40 10 16 8/10/10 3.9 36/26/21/16 1/-7.0 *3/90 *-0.26 9.2 15.0 .12/.75 2000 48 Drilling 6.75" Hole 11-Dec 7039 10.50 42 16 20 9/11/16 3.4 52/36/29/21 1/-10.5 *3/87 *-0.25 9.4 17.5 .17/.80 2000 60 POOH 12-Dec 7039 10.50 59 18 24 12/15/19 3.4 60/42/33/24 1/-11.0 *2/87 *-0.30 9.9 20.0 .20/.90 2000 60 POOH 13-Dec 7039 10.50 56 17 19 7/9/12 3.3 53/36/28/20/8/6 1/-11.0 2/87 -0.40 9.7 20.0 0.3/0.9 2000 60 Running 5-1/2" Casing 14-Dec 7039 10.50 52 14 13 7/8/9 3.4 41/27/23/18/7/6 1/-11.0 2/87 -0.30 9.4 20.0 0.20/0.90 2000 60 Running 5-1/2" Casing 15-Dec 7039 10.4 54 13 18 8/11/13 3.4 44/31/26/19 1/-10 *2/88 *-0.3 8.5 22.5 .20/2.30 2000 60 L/D Drill Pipe 16-Dec 7039 10.5 55 14 22 9/15/23 3.5 50/36/30/22 1/-10.5 2/88**-0.6 9.5 23.75 .55/2.40 2000 60 Testing BOPE 17-Dec.7039 10.5 52 13 19 11/12/18 3.5 45/32/27/21 1/-10.5 2/88**-0.6 9.5 25 .55/2.40 2000 60 TIH 18-Dec.7039 10.5 48 13 16 9/11/15 3.5 42/29/24/18 1/-11 2/87**-0.8 10.5 25 .60/3.00 2000 60 TIH Rig Service 19-Dec.7394 10.5 45 14 23 9/10/10 4.7 51/37/32/25 1/-9.5 2/89**-0.7 10.2 5 .35/1.25 800 60 Drilling ahead 20-Dec 7667 10.8 45 13 27 10/11/11 4.2 50/40/33/26/10/8 1/-12 2.5/85.5 *-0.5 10.3 6.25 .3/1.2 800 60 TD Production 21-Dec 7667 10.8 54 14 25 *9/10/11 4.1 53/39/33/25 1/-12 3/86**-0.55 10.3 6.25 .30/1.20 2000 60 Wireline 22-Dec 7667 10.8 54 15 29 *9/10/11 4.0 59/44/36/27 1/-11.5 *2/87 *-0.4 10.2 6.25 .33/1.20 2200 60 RIH with Liner 23-Dec 7667 10.8 45 12 20 *8/9/10 4.0 44/32/26/19 1/-12.25 *2/86 *-0.38 10.1 6.25 .33/1.28 2200 60 Cement Liner Casing Record SPUD:6-Dec-2014 SPERRY JOB:TD:20-Dec-2014 Remarks 7.625" Casing @ 2858' MD, 2312' TVD 5.5" Casing @ 7029' MD, 5062' TVD 3.5" Liner @ 7658' MD, 5540' TVD WELL NAME:LOCATION:Kuparuk OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG: W a t e r a n d O i l B a s e d M u d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 SLB SDi515 PDC 6.75 2858 7039 4181 54.90 0.448 76.2 8 120 2570 340 2-4-CT-A-X-I-WT-TD TD Intermediate Section 2 200 2 FX62 - PDC 4.75 7039 7667 628 16.40 0.331 38.4 4.2 80 2500 148 1-1-NO-G-X-1-CT-TD TD Production Section WELL NAME:2N-337C LOCATION:Kuparuk OPERATOR:ConocoPhillips Alaska Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901889899 TD:20-Dec-2014 MI Swaco STATE:Alaska RIG:Nabors 9ES SPUD:6-Dec-2014 B i t R e c o r d . . * 24 hr Recap:Well control, observed shut in pressure of 320-350 psi. Circulated 10 bbl / 30 minutes. Monitored well for 30 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - - 12/2/2014 11:55 PM Current Pump & Flow Data: 9 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 9ES Report For: ConditionBit # -10.2010.20 Size brine and observed flow. Displaced well with 10.2 ppg brine and flow was observed. 100% Gas In Air=10,000 UnitsN/AConnection - Tools N/A API FL Chromatograph (ppm) WOB N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min N/ABackground (max) Trip Average N/A Mud Type Lst Type WBM - Other -3044'- Depth in / out YP (lb/100ft2) - --- -- CementChtSilt C-4i C-4n 24 hr Max Weight - Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Well Control PV Footage D. Mickey / J. Riley ShClyst TuffGvlCoal cP - Gas Summary - -- (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 3246' 3246' 0' Max @ ft Current N/AN/A Date: Time: minutes. Bled well off with 7.2 bbl gain. Bled well down on choke with 7 bbl gain over 18 minutes. Displaced well with 10 ppg N/A in N/A -Minimum Depth C-5n - N/A C-2 N/A SPP (psi) Gallons/stroke TFABit Type Depth -30 MBT - pH - - - Siltst 0 0 Units* Casing Summary Lithology (%) -- - (907)659-7092Unit Phone: - A. Wilderom Maximum Report By:Logging Engineers:A. Wilderom / H. Garney Set AtSize Grade (max)(current) - - Cly - Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Displaced well with 10.4 pound per gallon mud weight. Monitored well and declared well static. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - - 3-Dec-2014 11:55 PM Current Pump & Flow Data: 8 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 9ES Report For: ConditionBit # -10.4010.40 Size 100% Gas In Air=10,000 UnitsN/AConnection - Tools N/A API FL Chromatograph (ppm) WOB N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min N/ABackground (max) Trip Average N/A Mud Type Lst Type WBM-Other -3046'- Depth in / out YP (lb/100ft2) - --- -- CementChtSilt C-4i C-4n 24 hr Max Weight - Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 RIH w/ cement stinger PV Footage D. Mickey / J. Riley ShClyst TuffGvlCoal cP - Gas Summary - -- (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 3246' 3246' 0' Max @ ft Current N/AN/A Date: Time: Pulled out the hole with 5.5" casing. Performed BOP Test. Currently running in hole with 4" drill pipe with cement stinger. N/A in N/A -Minimum Depth C-5n - N/A C-2 N/A SPP (psi) Gallons/stroke TFABit Type Depth -36 MBT - pH - - - Siltst 0 0 Units* Casing Summary Lithology (%) -- - (907)659-7092Unit Phone: - A. Wilderom Maximum Report By:Logging Engineers:A. Wilderom / H. Garney Set AtSize Grade (max)(current) - - Cly - Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade (907)659-7092Unit Phone: 0 A. Wilderom Maximum Report By:Logging Engineers:A. Wilderom / H. Garney 0 0 N/A N/A Units* Casing Summary Lithology (%) 0 MBT 0' pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -36 C-5n - N/A C-2 N/A in N/A -Minimum Depth Time: Circulated and conditioned mud and tripped out of the hole. Laid down 3 1/2" tubing and cement stinger. Rigged up N/A 3026' 3026' 0' Max @ ft Current N/AN/A Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D. Mickey / J. Riley ShClyst TuffGvlCoal cP - Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Rigging up Wireline PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) - 000 Brine -3046'- Depth in / out Mud Type Lst Type Average N/AN/ABackground (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 slickline/wireline and Dutch Riser. ConditionBit # -10.4010.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 9ES Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope ROP ROP (ft/hr) 2.96 @ Mud Data Depth 4-Dec-2014 11:55 PM Current Pump & Flow Data: 9 Max 0 Chlorides mg/l - Pumped cement plug and pulled out of hole above plug. Circulated and conditioned. Held 200 psi on cement. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Tested Dutch Riser. Ran in the hole with caliper tool - logged 7 5/8" Casing. Laid down tools. Picked up drill pipe Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 0 5-Dec-2014 11:55 PM Current Pump & Flow Data: 8 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 9ES Report For: ConditionBit # -10.4010.40 Size out of the hole. Currently waiting on parts for further testing. tested the casing to 2500 psi for 30 minutes. Failed test - lost 750 psi. Flow checked. Circulated and conditioned. Tripped mud system. Picked up drill pipe. Tripped in the hole and tagged the cement at 2635' MD. Circulated and conditioned. Pressure 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools N/A API FL Chromatograph (ppm) WOB Avg Min Comments RPM ECD (ppg) ml/30min N/ABackground (max) Trip Average N/A Mud Type Lst Type WBM -3046'- Depth in / out YP (lb/100ft2) - 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Waiting on Parts PV Footage D. Mickey / J. Riley ShClyst TuffGvlCoal cP - Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 2635' 2635' 0' Max @ ft Current N/AN/A Date: Time: and singled in the hole. Tripped out of the hole. Picked up drill pipe and ran in the hole. Tripped out of the hole. Cleaned out the N/A *Depth adjustment: current hole depth is the top of cement. in N/A -Minimum Depth C-5n - N/A C-2 N/A SPP (psi) Gallons/stroke TFABit Type Depth -36 MBT 0' pH 0 0 0 Siltst N/A N/A Units* Casing Summary Lithology (%) 00 0 (907)659-7092Unit Phone: 0 A. Wilderom Maximum Report By:Logging Engineers:A. Wilderom / H. Garney Set AtSize Grade (max)(current) 0 0 Cly 0 . . * 24 hr Recap: (max)(current) 5 0 Cly 151 Set AtSize 29.7 L-80 Grade 7.625" (907)659-7092Unit Phone: 6 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney 142 13 240 81 Units* Casing Summary Lithology (%) 4 MBT 2718' pH 0.446 0 5 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -36 C-5n 2703' 30.2 C-2 21 in 0 2640'Minimum Depth Time: 2612' MD & set packer @ 2606' MD. Pressure test csg to 2500 psi for 30 min & bleed off. Unset packer & TOOH. P/U BHA & RIH to 12 2635' 2718' 83' Max @ ft Current 2642'52.6 Date: Avg to2635' Yesterday's Depth: Current Depth: 24 Hour Progress: 91.3 Flow In (gpm) Flow In (spm) Gas Summary 0 30 12 (current) D. Mickey / J. Riley ShClyst TuffGvlCoal cP - Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Drill out cmt PV 24 hr Max Weight 5 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) - 0150 WBM -3046'- Depth in / out Mud Type Lst Type Average N/A8Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 100% Gas In Air=10,000 UnitsN/AConnection 7 midnight. Max gas observed was 21 units. 1578' MD. Circ & cond mud & SHT MWD tools. Cont to RIH & tag cmt @ 2635' MD. Begin to drill out shoe track to 2718' MD as of 2858' ConditionBit # 1 - 6.75 10.40 SLB SDi515 PDC 10.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 9ES Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope ROP ROP (ft/hr) 2.96 @ Mud Data Depth 6-Dec-2014 24:00 Current Pump & Flow Data: 1305 Max 5 Chlorides mg/l - Wait on tool & begin to load 5.5" csg into shed. TIH & M/U packer. Inspect packer per Baker rep & RIH w/ DP to Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont to drill cmt & officially kick off at 2886' MD. Drill 20' of new hole to 2906' MD & monitor well, static. Displace well Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 6300.00 5 7-Dec-2014 24:00 Current Pump & Flow Data: 1685 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Nabors 9ES Report For: ConditionBit # 1 6.5 6.75 9.80 SLB SDi515 PDC 9.80 Size trace vf-f gr sst f/ 2900' MD to 3300' MD & 40%-60% vf-f gr sst w/ 20%-30% clyst & 10%-40% sltst f/ 3350' MD to 3450' MD. MD as of midnight. Max gas observed the past 24 hrs was 88u @ 3410' MD. Samples have consisted of 80%-100% lt gry clyst w/ 2858' 100% Gas In Air=10,000 UnitsN/AConnection 20 11 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 11.0012.00 Avg Min Comments RPM ECD (ppg) ml/30min 24Background (max)Trip Average 80 Mud Type Lst 40 Type LSND 4.93386'20 Depth in / out YP (lb/100ft2) 9.80 742635 00 CementChtSilt C-4i C-4n 24 hr Max Weight 13 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Drilling 6.75" hole PV Footage D. Mickey / J. Riley ShClyst TuffGvlCoal cP 10 Gas Summary 0 28 34 (current) Avg to2718' Yesterday's Depth: Current Depth: 24 Hour Progress: 560.7 Flow In (gpm) Flow In (spm) 2718' 3450' 732' Max @ ft Current 2909'69.6 Date: Time: to 9.8 ppg LSND & monitor well, static. POOH into csg & perform FIT to 14.3 EMW. Wash down to 2906' MD & drill ahead to 3450' 32 in 1 2915'Minimum Depth C-5n 3410' 34.9 C-2 88 SPP (psi) Gallons/stroke TFABit Type Depth 5.040 MBT 3450' pH 0.446 0 11 0 Siltst 317 108 Units* Casing Summary Lithology (%) 10 40 4253 41 (907)659-7092Unit Phone: 69 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) 40 0 Cly 12352 . . * 24 hr Recap: (max)(current) 20 0 Cly 4597 Set AtSize 29.7 L-80 Grade 7.625" (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney 60 2980 20 345 117 Units* Casing Summary Lithology (%) 0 MBT 4501' pH 0.446 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.044 C-5n 3410' 81.8 C-2 45 in 0 2915'Minimum Depth Time: Max gas observed the past 24 hrs was 45u @ 3410' MD. Samples have consisted of 30%-60% gry clyst w/ some sltst & sst f/ 22 3450' 4501' 1051' Max @ ft Current 3579'71.2 Date: Avg to3450' Yesterday's Depth: Current Depth: 24 Hour Progress: 245.7 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D. Mickey / J. Riley ShClyst TuffGvlCoal cP 13 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Drilling 6.75" hole PV 24 hr Max Weight 18 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 030 LSND 4.64348'18 Depth in / out Mud Type Lst 20 Type Average N/A14Background (max)Trip 11.0012.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 100% Gas In Air=10,000 UnitsN/AConnection 20 0 in the past 24 hrs. 3450' MD to 4050' MD & mainly sltst w/ small amount of sst & clyst from 4100' MD to 4600' MD. No fluor have been seen in samples 2858' ConditionBit # 1 7.0 6.75 9.60 SLB SDi515 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Nabors 9ES Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Surface ROP ROP (ft/hr) 2.96 @ Mud Data Depth 8-Dec-2014 24:00 Current Pump & Flow Data: 2229 Max 0 Chlorides mg/l 6000.00 Cont to drill ahead f/ 3450' MD to 4501' MD as of midnight. Pump sweeps every 300' to keep ECDs b/w 11.5 to 11.7. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued drilling from 4501' MD to 5197' MD. Wiper tripped to the shoe at 2851' MD. RIH to 5100' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 3000.00 0 9-Dec-2014 24:00 Current Pump & Flow Data: 2450 Max Surface ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Nabors 9ES Report For: ConditionBit # 1 7.0 6.75 9.60 SLB SDi515 PDC 9.60 Size 2858' 100% Gas In Air=10,000 Units32Connection 8 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 11.0012.00 Avg Min Comments RPM ECD (ppg) ml/30min 18Background (max)Trip Average 179 Mud Type Lst Type WBM 4.65197'18 Depth in / out YP (lb/100ft2) 9.80 030 00 CementChtSilt C-4i C-4n 24 hr Max Weight 18 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Circulating B/U PV Footage D. Mickey / J. Riley ShClyst TuffGvlCoal cP 14 Gas Summary 0 5 0 (current) Avg to4501' Yesterday's Depth: Current Depth: 24 Hour Progress: 245.7 Flow In (gpm) Flow In (spm) 4501' 5197' 696' Max @ ft Current 3579'71.2 Date: Time: Wash last stand to bottom. Currently circulating bottoms up at time of report. 20 in 0 2915'Minimum Depth C-5n 5106' 0.0 C-2 41 SPP (psi) Gallons/stroke TFABit Type Depth 7.546 MBT 5197' pH 0.446 0 3 0 Siltst 344 116 Units* Casing Summary Lithology (%) 02980 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) 49 0 Cly 7205 100 . . * 24 hr Recap:24 hours of drilling ahead. Drilling ahead at report time. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 69 10-Dec-2014 24:00 Current Pump & Flow Data: 2411 Max Surface ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Nabors 9ES Report For: ConditionBit # 1 7.0 6.75 9.60 SLB SDi515 PDC 9.60 Size 2858' 100% Gas In Air=10,000 Units111Connection 1301 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 11.0012.00 Avg Min Comments RPM ECD (ppg) ml/30min 59Background (max)Trip Average N/A Mud Type Lst 100 Type WBM 3.96623'16 Depth in / out YP (lb/100ft2) 9.20 0170 00 CementChtSilt C-4i C-4n 24 hr Max Weight 206 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Drilling Ahead PV Footage J. Haynes / J. Riley ShClyst TuffGvlCoal cP 10 Gas Summary 0 411 102 (current) Avg to5197' Yesterday's Depth: Current Depth: 24 Hour Progress: 245.7 Flow In (gpm) Flow In (spm) 5197' 6868' 1671' Max @ ft Current 3579'60.8 Date: Time: 55 in 25 2915'Minimum Depth C-5n 5106' 50.6 C-2 433 SPP (psi) Gallons/stroke TFABit Type Depth 15.040 MBT 6868' pH 0.446 0 174 0 Siltst 341 115 Units* Casing Summary Lithology (%) 104847 0 (907)659-7092Unit Phone: 190 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) 2503 0 Cly 35248 . . * 24 hr Recap: (max)(current) 226 185 Cly 6540 Set AtSize 29.7 L-80 Grade 7.625" (907)659-7092Unit Phone: 10 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney 30 8041 5124 107 36 Units* Casing Summary Lithology (%) 54 MBT 7039' pH 0.446 73 16 14 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.542 C-5n 6998' 0.0 C-2 235 in 33 6829'Minimum Depth Time: 7005'MD. Weighted up to 10.0 mud weight. Continued to circulate and checked to see if well was static. Continued to weight up to 270 6868' 7039' 171' Max @ ft Current 6977'8.4 Date: Avg to6868' Yesterday's Depth: Current Depth: 24 Hour Progress: 135.2 Flow In (gpm) Flow In (spm) Gas Summary 8 30 5 (current) J. Haynes / J. Riley ShClyst TuffGvlCoal cP 16 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A POOH PV 24 hr Max Weight 375 Hours C-3 425 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.40 4111922 WBM 3.47039'20 Depth in / out Mud Type Lst 70 Type Average N/A20Background (max)Trip 11.0012.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 100% Gas In Air=10,000 Units9878Connection 87 a 10.5 mud weight in and out. Started POOH. Currently POOH at report time. 2858' ConditionBit # 1 10.5 6.75 10.50 SLB SDi515 PDC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Nabors 9ES Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Surface ROP ROP (ft/hr) 2.96 @ Mud Data Depth 11-Dec-2014 24:00 Current Pump & Flow Data: 34 Max 206 Chlorides mg/l 2000.00 Continued drilling ahead to TD 7039'MD. Started circulating a bottoms up. Saw 9,878 gas units from connection at Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Back reamed from 6,244'MD to 6,149'MD. Circulated bottoms up. Monitored well for 65 minutes for flow Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 206 12-Dec-2014 24:00 Current Pump & Flow Data: 1153 Max Surface ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.00 Nabors 9ES Report For: ConditionBit # 1 11.0 6.75 10.50 SLB SDi515 PDC 10.50 Size Observed 0 barrels fill. Currently tripping out of the hole. 2858' 100% Gas In Air=10,000 UnitsN/AConnection 42 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 11.0012.00 Avg Min Comments RPM ECD (ppg) ml/30min 16Background (max)Trip Average N/A Mud Type Lst 70 Type WBM 3.47039'24 Depth in / out YP (lb/100ft2) 9.90 4111922 00 CementChtSilt C-4i C-4n 24 hr Max Weight 375 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A POOH PV Footage J. Haynes / J. Riley ShClyst TuffGvlCoal cP 18 Gas Summary 0 12 0 (current) Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7039' 7039' 0' Max @ ft Current 0'0.0 Date: Time: Observed 5.6 barrel gain. Tripped out of the hole to 6,500'MD. Circulated bottoms up and monitored well for swabbing. 50 in 0 7039'Minimum Depth C-5n 7039' 0.0 C-2 551 SPP (psi) Gallons/stroke TFABit Type Depth 20.059 MBT 7039' pH 0.446 0 10 0 Siltst 204 69 Units* Casing Summary Lithology (%) 54 30 8041 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) 248 0 Cly 11028 . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize 29.7 L-80 Grade 7.625" (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney 30 0 0 0 0 Units* Casing Summary Lithology (%) 0 MBT 7039' pH 0.446 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.056 C-5n 7039' 0.0 C-2 75 in 0 7039'Minimum Depth Time: hole to 2810' and monitored well for flow. Observed .5 bbls gain on trip tank. Circulated bottoms up and monitored well for flow for 3 7039' 7039' 0' Max @ ft Current 0'0.0 Date: Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J. Haynes / J. Riley ShClyst TuffGvlCoal cP 17 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A L/D BHA PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 WBM 3.37039'19 Depth in / out Mud Type Lst 70 Type Average N/A0Background (max)Trip 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 one hour. Finished tripping out of hole, and laid down BHA. 2858' ConditionBit # 1 11.0 6.75 10.50 SLB SDi515 PDC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Surface ROP ROP (ft/hr) 2.96 @ Mud Data Depth 13-Dec-2014 24:00 Current Pump & Flow Data: 8 Max 0 Chlorides mg/l 2000.00 Reamed and washed from 3578' to 3008'. Circulated bottoms up and monitored well for swabbing. Tripped out of Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Ran casing to 2858' MD stopped to circulate and condition mud. Continued running casing to 4956'MD, circulated Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 14-Dec-2014 24:00 Current Pump & Flow Data: 0 Max Surface ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: ConditionBit # 1 11.0 6.75 10.50 SLB SDi515 PDC 10.50 Size 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 2635' WOB 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 70 Type WBM 3.37039'19 Depth in / out YP (lb/100ft2) 9.70 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Running Casing PV Footage J. Haynes / J. Riley ShClyst TuffGvlCoal cP 17 Gas Summary 0 0 30.8 (current) Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7039' 7039' 0' Max @ ft Current 0'0.0 Date: Time: a bottoms up while washing down a single joint from 4956'MD to 5168'MD and observed a 7 barrel loss while circulating, 3 in 0 7039'Minimum Depth C-5n 7039' 0.0 C-2 55 SPP (psi) Gallons/stroke TFABit Type Depth 20.056 MBT 7039' pH 0.446 0 0 0 Siltst 0 0 Units* Casing Summary Lithology (%) 0 30 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) 63 0 Cly 261 . . * 24 hr Recap: (max)(current) Intermediate 63 0 Cly 261 Set AtSize 29.7 L-80 Grade 7.625" (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney 30 0 0 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 L-80 MBT 7039' pH 0.446 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 22.554 C-5n 7039' 0.0 C-2 0 in 0 7039'Minimum Depth Time: 7029' MD. Laying down drill pipe at time of report. 0 7039' 7039' 0' Max @ ft Current 0'0.0 Date: Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 30.8 (current) J. Haynes / J. Riley ShClyst TuffGvlCoal cP 13 4181' Footage 54.90 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Running Casing PV 24 hr Max 15.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.50 000 120.0 WBM 3.47039'18 Depth in / out Mud Type Lst 70 Type Average N/A0Background (max)Trip 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 8.02635' 7039' WOB Surface 100% Gas In Air=10,000 UnitsN/AConnection 0 5' 2858' Condition 2-4-CT-A-X-I-WT-TD Bit # 1 10.0 6.75 10.40 SLB SDi515 PDC 10.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope ROP ROP (ft/hr) 2.96 @ Mud Data Depth 15-Dec-2014 24:00 Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 2000.00 Ran casing to bottom periodically reaming, washing, circulating and conditioning mud. Cemented casing in at Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Laid down 71 stands of 4" drill pipe. Rigged up to test BOPs and began testing Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 16-Dec-2014 24:00 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 10.5 6.75 10.50 SLB SDi515 PDC 10.50 Size 5' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 70 Type 120.0 WBM 3.57039'22 Depth in / out YP (lb/100ft2) 9.50 000 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Testing BOP PV 4181' Footage 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 30.8 (current) Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7039' 7039' 0' Max @ ft Current 0'0.0 Date: Time: 0 in 0 7039'Minimum Depth C-5n 7039' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 23.855 L-80 MBT 7039' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 30 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 63 0 Cly 261 . . * 24 hr Recap:Finished testing BOPE. Tested casing shoe to 3500 psi for 30 min. Picked up BHA and ran in the hole to 1500' MD Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 17-Dec-2014 24:00 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 10.5 6.75 10.50 SLB SDi515 PDC 10.50 Size 7030' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 70 Type 120.0 WBM 3.57039'19 Depth in / out YP (lb/100ft2) 9.50 000 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A TIH PV 4181' Footage 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 13 Gas Summary 0 0 0 (current) Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7039' 7039' 0' Max @ ft Current 0'0.0 Date: Time: of drill pipe. Tested MWD tools. 0 in 0 7039'Minimum Depth C-5n 7039' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 25.052 L-80 MBT 7039' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 30 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 0 0 Cly 0 . . * 24 hr Recap:Continued tripping in the hole had to stop to service the top drive. Service was completed and continued Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0.00 0 17-Dec-2014 24:00 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 0.0 6.75 0.00 SLB SDi515 PDC 0.00 Size at time of report mud weight was 10.5 in and out. Mud Check was complete. Went back to bottom and control drilled from 6938' MD to 7011' MD 7030' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools PowerDrive X6, Impulse, VPWD, adnVISION API FL Chromatograph (ppm) 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 70 Type 120.0 WBM 0.00'0 Depth in / out YP (lb/100ft2) 0.00 000 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A TIH PV 4181' Footage 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 0 Gas Summary 0 0 0 (current) Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7039' 7039' 0' Max @ ft Current 0'0.0 Date: Time: tripping in the hole. The top of the Cement was tagged at 6938' MD. Came off bottome to circulate a bottoms up to make sure 0 No Mud data was reported in 0 7039'Minimum Depth C-5n 7039' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 0.00 L-80 MBT 7039' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 30 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 0 0 Cly 0 . . * 24 hr Recap:Finished drilling out shoe plus 20' of open hole. Tripped out three joints and preformed FIT test to 16.0 ppg Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800.00 660 19-Dec-2014 24:00 Current Pump & Flow Data: 2704 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 9.5 6.75 10.50 SLB SDi515 PDC 10.50 Size 7030' 2858' 100% Gas In Air=10,000 Units131Connection 5014 Tools Impulse API FL Chromatograph (ppm) 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 55Background (max)Trip Average N/A Mud Type Lst 90 Type 120.0 WBM 4.77332'23 Depth in / out YP (lb/100ft2) 10.20 6529157 014 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 821 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Drilling ahead PV 4181' Footage 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 14 Gas Summary 0 2288 363 (current) Avg to7039' Yesterday's Depth: Current Depth: 24 Hour Progress: 134.9 Flow In (gpm) Flow In (spm) 7039' 7394' 355' Max @ ft Current 7389'20.4 Date: Time: equivalent mud weight. Drilled ahead to 7396'. 128 in 15 7057'Minimum Depth C-5n 7387' 55.0 C-2 1012 SPP (psi) Gallons/stroke TFABit Type Depth 5.045 L-80 MBT 7394' pH 0.446 33 888 6 Siltst 5.50'' 169 56 Units* Casing Summary Lithology (%) 113 10 10782 1474 (907)659-7092Unit Phone: 445 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 7493 62 Cly 89306 . . * 24 hr Recap:Continued drilling ahead from 7394' MD to TD at 7667' MD. Circulated multiple bottoms up and began TOOH at Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800.00 455 20-Dec-2014 24:00 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 12.0 6.75 10.80 SLB SDi515 PDC 10.80 Size 7030' 2858' 100% Gas In Air=10,000 Units357Connection 2104 Tools Impulse API FL Chromatograph (ppm) 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 68Background (max)Trip Average N/A Mud Type Lst 10 Type 120.0 WBM 4.27667'27 Depth in / out YP (lb/100ft2) 10.30 12536598 4794 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 524 Hours C-3 40 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A TD for Production CSG PV 4181' Footage 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 13 Gas Summary 33 815 158 (current) Avg to7394' Yesterday's Depth: Current Depth: 24 Hour Progress: 139.4 Flow In (gpm) Flow In (spm) 7394' 7667' 273' Max @ ft Current 7458'19.9 Date: Time: time of Report. 102 in 20 7612'Minimum Depth C-5n 7467' 0.0 C-2 381 SPP (psi) Gallons/stroke TFABit Type Depth 6.345 L-80 MBT 7667' pH 0.446 93 295 31 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 128 50 6297 977 (907)659-7092Unit Phone: 213 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 2638 89 Cly 31495 . . * 24 hr Recap:Finished tripping out of the hole. Laid down 2 7/8" drill pipe and BHA. Rigged up and function tested wireline tools. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 21-Dec-2014 24:00 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 20 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 12.0 6.75 10.80 SLB SDi515 PDC 10.80 Size 7030' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools Impulse API FL Chromatograph (ppm) 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 10 Type 120.0 WBM 4.17667'25 Depth in / out YP (lb/100ft2) 10.30 000 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 40 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A R/U Wireline PV 4181' Footage 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 0 (current) Avg to7667' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7667' 7667' 0' Max @ ft Current 0'0.0 Date: Time: Run in hole to 3012' Md couldn’t get any deeper with the tool. Pulled out of the hole and picked up a wireline tractor. 0 in 0 7667'Minimum Depth C-5n 7667' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 6.354 L-80 MBT 7667' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 50 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 0 0 Cly 0 . . * 24 hr Recap:Ran open hole logs. Pulled out of the hole with wire line and rigged down tools. Picked up third party tools 2 7/8 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2200.00 0 22-Dec-2014 24:00 Current Pump & Flow Data: 0 Max 1-1-NO-G-X-1-CT-TD ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 21 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 11.5 6.75 10.80 SLB SDi515 PDC 10.80 Size 2 with packer and hanger circulate bottoms up, blow down top drive. make up shoe track and make up float shoe, float collar, run liner to 844' MD fill every 15 joints circulate and conditions circulate tools Rig up GBR double stack tongs, elevators continue to Service top drive. Rig up casing run liner PJSM running liner 7030' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools Impulse API FL Chromatograph (ppm) 4 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 10 Type 80 120.0 FX62-PDC WBM 4.0 7039' 7667'29 7667' Depth in / out YP (lb/100ft2) 10.20 000 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 40 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A TIH with liner PV 4181' 4.75 0.331 Footage 16.40 628' 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 15 Gas Summary 0 0 0 (current) Avg to7667' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7667' 7667' 0' Max @ ft Current 0'0.0 Date: Time: XO on TD savor sub circulate out guide blocks on TD from 2 7/8" drill pipe. Bring pipe in pipe shed and 511 liner. Pick up 3rd party 0 in 0 7667'Minimum Depth C-5n 7667' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 6.354 L-80 MBT 7667' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 50 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 0 0 Cly 0 . . * 24 hr Recap:Pick up drill pipe and continue runninng liner on 3.5 PH-6 Work string. Run in hole from 1783' MD to 6222' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2200.00 0 23-Dec-2014 24:00 Current Pump & Flow Data: 0 Max 1-1-NO-G-X-1-CT-TD ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 22 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 12.3 6.75 10.80 SLB SDi515 PDC 10.80 Size 2 cement head install hoses on head make up top drive circulate , cement , and displace 2 bottoms up stage pump to 2 barrels 1080 units of gas on first bottoms up blow down top drive. Run liner from 7005' MD to 7667' MD. Install cement lines pick up 6222' MD to 7005' MD. Circulate and condition circulated 2 bottoms up at 5.5" casing shoe monitor shakers for cuttings. Observed 7030' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 562 Tools Impulse API FL Chromatograph (ppm) 4 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 1081 Mud Type Lst 10 Type 80 120.0 FX62-PDC WBM 4.0 7039' 7667'20 7667' Depth in / out YP (lb/100ft2) 10.10 14408.1 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 40 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A TIH with liner PV 4181' 4.75 0.331 Footage 16.40 628' 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 10.5 (current) Avg to7667' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7667' 7667' 0' Max @ ft Current 0'0.0 Date: Time: Call and fill every 15 joints. Control running speeds for ECDs with packer in hole. Run liner continue to run 3.5 liner from 19 a minute watch for losses and monitor mud weight in and out in 0 7667'Minimum Depth C-5n 7667' 0.0 C-2 1081 SPP (psi) Gallons/stroke TFABit Type Depth 6.345 L-80 MBT 7667' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 50 81 0 (907)659-7092Unit Phone: 66.6 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 29.7 L-80 Grade 7.625" (max)(current) Intermediate 3407 0 Cly 7036 . . * 24 hr Recap:PJSM with SLB for cementing. Cemented casing circulated and condition mud circulate out cement displace to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0.00 0 24-Dec-2014 24:00 Current Pump & Flow Data: 0 Max 1-1-NO-G-X-1-CT-TD ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 23 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 0.0 6.75 8.50 SLB SDi515 PDC 8.50 Size 2 to surface completion pick up and lay down BHA make up tools. clean trip tank and lay down pipe PJSM Lay down pipe slip and cut drill line rig up casing tongs lay down drill pipe from 3000' MD Pump high vis spacer pump 190 8.5 ppg seawater lake all returns to cuttings box service top drive service blocks crown drawworks 7030' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools Impulse API FL Chromatograph (ppm) 4 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 10 Production Type 80 120.0 FX62-PDC Brine 0.0 7039' 7667'0 7667' Depth in / out YP (lb/100ft2) 0.00 000 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 40 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Cut and Slip PV 4181' 4.75 0.331 Footage 16.40 628' 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 0 Gas Summary 0 0 0 (current) Avg to7667' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7667' 7667' 0' Max @ ft Current 0'0.0 Date: Time: completion fluid PJSM with MI and crew displaced to completion fluid pump high vis spacer pump 250 barrels of 9.7 brine. 0 in 0 7667'Minimum Depth C-5n 7667' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 0.028 L-80 MBT 7667' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 50 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 29.7 L-80 Grade 7667' 7.625" 3.50'' (max)(current) Intermediate 0 0 Cly 0 . . * 24 hr Recap:instal and remove ware bushing wash and cleaned BOPs TIH with completion tubing PJSM tripping with tubing Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0.00 0 25-Dec-2014 24:00 Current Pump & Flow Data: 0 Max 1-1-NO-G-X-1-CT-TD ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Condition 2-4-CT-A-X-I-WT-TD Bit # 1 0.0 6.75 8.50 SLB SDi515 PDC 8.50 Size 2 Pick up LD make up tools BHA circulate down the string into SBE rig up long bails. Pressure testing casing shoe- close top rams circulate down tubing test casing and liner to 3000 psi 7030' 2858' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools Impulse API FL Chromatograph (ppm) 4 8.02635' 7039' WOB Surface 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average N/A Mud Type Lst 10 Production Type 80 120.0 FX62-PDC Brine 0.0 7039' 7667'0 7667' Depth in / out YP (lb/100ft2) 0.00 000 00 CementChtSilt C-4i C-4n 24 hr Max 15.0 Weight 0 Hours C-3 40 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A Circulating thru tubing PV 4181' 4.75 0.331 Footage 16.40 628' 54.90 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 0 Gas Summary 0 0 0 (current) Avg to7667' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 7667' 7667' 0' Max @ ft Current 0'0.0 Date: Time: run tubing from surface to 3678' MD trip tubing from 3678' MD to 6798' MD rig up head pin with cement line circulate s/s prep 0 in 0 7667'Minimum Depth C-5n 7667' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 0.028 L-80 MBT 7667' pH 0.446 0 0 0 Siltst 5.50'' 0 0 Units* Casing Summary Lithology (%) 0 50 0 0 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 29.7 L-80 Grade 7667' 7.625" 3.50'' (max)(current) Intermediate 0 0 Cly 0 WELL INFORMATION Created On : Jan 15 2015 Customer :ConocoPhillips Alaska Inc. Well Name :2N-337C Job Number :AK-XX-0901889899 Rig Name :Nabors 9ES Field Name :Kuparuk Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 28.00 0.00 0.00 28.00 0.00 N 0.00 E 0.00 0.00 251.00 0.67 142.46 250.99 1.03 S 0.79 E -0.10 0.30 341.74 1.88 183.94 341.71 2.94 S 1.02 E 0.75 1.60 432.43 4.16 198.23 432.27 7.55 S 0.12 W 4.21 2.63 521.02 7.44 200.71 520.40 15.97 S 3.15 W 11.33 3.71 607.93 10.40 208.49 606.25 28.13 S 8.88 W 22.76 3.67 699.62 14.01 205.01 695.85 45.47 S 17.53 W 39.45 4.02 790.28 16.01 197.19 783.42 67.36 S 25.86 W 58.36 3.14 880.55 15.80 199.98 870.24 90.80 S 33.74 W 77.73 0.88 971.58 15.43 200.52 957.91 113.79 S 42.22 W 97.35 0.44 1062.20 16.20 198.91 1,045.10 137.04 S 50.54 W 116.99 0.98 1153.87 16.29 200.42 1,133.11 161.19 S 59.17 W 137.37 0.47 1245.29 19.29 203.95 1,220.15 187.01 S 69.78 W 160.32 3.49 1338.92 21.32 212.44 1,307.98 215.52 S 85.19 W 188.77 3.82 1434.67 22.74 218.59 1,396.75 244.68 S 106.08 W 222.16 2.83 1529.77 25.33 225.21 1,483.61 273.39 S 131.99 W 259.52 3.93 1623.33 29.03 229.10 1,566.83 302.36 S 163.36 W 301.61 4.39 1718.03 32.88 228.72 1,648.03 334.38 S 200.06 W 349.82 4.07 1813.63 35.91 229.19 1,726.90 369.83 S 240.79 W 403.29 3.18 1909.13 39.76 229.54 1,802.31 407.96 S 285.24 W 461.33 4.04 2004.20 42.92 230.64 1,873.68 448.23 S 333.41 W 523.66 3.41 2096.50 46.32 231.94 1,939.37 488.75 S 384.01 W 588.16 3.81 2191.97 50.23 235.27 2,002.91 530.96 S 441.37 W 659.26 4.85 2286.74 54.04 235.82 2,061.07 573.27 S 503.06 W 734.03 4.05 2379.76 57.86 237.48 2,113.15 615.61 S 567.44 W 811.09 4.36 2475.61 61.89 238.43 2,161.24 659.58 S 637.70 W 893.96 4.29 2569.31 65.42 239.52 2,202.82 702.84 S 709.65 W 977.86 3.91 2662.62 67.66 239.74 2,239.97 746.11 S 783.50 W 1063.37 2.41 2757.79 69.03 240.81 2,275.08 789.96 S 860.31 W 1151.67 1.78 INSITE V8.1.10 Page 1Job No:AK-XX-0901889899 Well Name:2N-337C Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2824.37 68.76 241.33 2,299.06 820.01 S 914.67 W 1213.63 0.83 2901.28 69.65 235.97 2,326.38 857.41 S 976.04 W 1285.47 6.62 2970.71 69.26 233.13 2,350.75 895.11 S 1,029.00 W 1350.42 3.87 3062.04 69.50 234.40 2,382.92 945.63 S 1,097.94 W 1435.75 1.33 3159.40 68.94 232.94 2,417.46 999.56 S 1,171.28 W 1526.62 1.52 3253.21 67.81 236.86 2,452.04 1,049.70 S 1,242.60 W 1613.74 4.07 3349.78 67.69 234.87 2,488.61 1,099.85 S 1,316.58 W 1703.10 1.91 3445.53 67.70 234.57 2,524.95 1,151.01 S 1,388.89 W 1791.61 0.29 3543.39 68.38 237.86 2,561.56 1,201.47 S 1,464.31 W 1882.35 3.19 3636.92 64.84 239.48 2,598.68 1,246.11 S 1,537.62 W 1968.14 4.11 3729.74 61.01 241.52 2,640.93 1,286.82 S 1,609.52 W 2050.62 4.57 3827.93 59.07 241.56 2,689.96 1,327.36 S 1,684.30 W 2135.42 1.98 3923.89 56.71 242.77 2,740.96 1,365.32 S 1,756.17 W 2216.36 2.68 4019.20 54.43 243.01 2,794.85 1,401.14 S 1,826.14 W 2294.56 2.40 4114.30 51.28 244.11 2,852.27 1,434.90 S 1,894.00 W 2369.86 3.44 4208.94 47.79 243.19 2,913.68 1,466.84 S 1,958.51 W 2441.37 3.76 4303.02 45.17 240.59 2,978.46 1,498.95 S 2,018.69 W 2509.33 3.43 4397.47 41.98 239.50 3,046.88 1,531.43 S 2,075.10 W 2574.33 3.47 4492.93 39.06 240.88 3,119.44 1,562.28 S 2,128.89 W 2636.25 3.20 4587.04 39.76 241.70 3,192.15 1,590.98 S 2,181.29 W 2695.83 0.93 4683.05 39.90 242.17 3,265.88 1,619.91 S 2,235.56 W 2757.10 0.35 4777.88 40.23 241.46 3,338.46 1,648.74 S 2,289.36 W 2817.92 0.59 4873.88 40.24 241.86 3,411.75 1,678.17 S 2,343.93 W 2879.73 0.27 4967.03 40.31 241.85 3,482.81 1,706.58 S 2,397.03 W 2939.73 0.08 5062.66 40.27 242.63 3,555.76 1,735.38 S 2,451.75 W 3001.31 0.53 5159.81 40.37 241.39 3,629.83 1,764.88 S 2,507.26 W 3063.94 0.83 5255.05 40.61 241.23 3,702.26 1,794.57 S 2,561.51 W 3125.60 0.27 5350.59 40.58 239.88 3,774.81 1,825.13 S 2,615.64 W 3187.65 0.92 5445.60 40.46 238.20 3,847.04 1,856.88 S 2,668.57 W 3249.34 1.16 5540.74 40.61 239.04 3,919.35 1,889.08 S 2,721.36 W 3311.15 0.60 5636.18 40.69 240.76 3,991.76 1,920.26 S 2,775.15 W 3373.23 1.18 5730.60 40.57 242.18 4,063.42 1,949.62 S 2,829.16 W 3434.53 0.99 5825.66 40.63 242.08 4,135.60 1,978.54 S 2,883.85 W 3496.15 0.09 5921.02 40.67 241.95 4,207.95 2,007.69 S 2,938.70 W 3558.03 0.10 6015.74 40.65 242.71 4,279.80 2,036.35 S 2,993.36 W 3619.48 0.52 6113.41 40.54 242.14 4,353.96 2,065.77 S 3,049.70 W 3682.76 0.40 6211.84 40.66 241.05 4,428.70 2,096.24 S 3,106.04 W 3746.61 0.73 6306.42 40.70 240.59 4,500.43 2,126.30 S 3,159.86 W 3808.12 0.32 6395.21 40.06 241.35 4,568.06 2,154.21 S 3,210.16 W 3865.51 0.91 6490.35 40.16 240.69 4,640.83 2,183.91 S 3,263.78 W 3926.65 0.46 6586.45 40.02 240.87 4,714.35 2,214.12 S 3,317.79 W 3988.41 0.19 6681.62 39.90 240.55 4,787.29 2,244.03 S 3,371.10 W 4049.40 0.25 6776.36 40.12 241.69 4,859.86 2,273.44 S 3,424.43 W 4110.16 0.81 6872.45 40.03 242.35 4,933.39 2,302.47 S 3,479.06 W 4171.78 0.45 6967.93 39.68 242.60 5,006.68 2,330.74 S 3,533.32 W 4232.69 0.40 INSITE V8.1.10 Page 2Job No:AK-XX-0901889899 Well Name:2N-337C Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 7002.69 40.01 242.27 5,033.37 2,341.05 S 3,553.07 W 4254.87 1.13 7086.06 39.36 245.32 5,097.54 2,364.56 S 3,600.82 W 4307.72 2.46 7121.53 39.79 242.78 5,124.88 2,374.45 S 3,621.13 W 4330.14 4.72 7202.65 39.31 241.85 5,187.43 2,398.44 S 3,666.87 W 4381.58 0.94 7274.61 38.71 241.56 5,243.34 2,419.91 S 3,706.75 W 4426.72 0.87 7308.10 38.52 242.15 5,269.51 2,429.77 S 3,725.18 W 4447.55 1.24 7401.78 39.32 239.13 5,342.40 2,458.63 S 3,776.46 W 4506.27 2.20 7498.06 40.15 239.41 5,416.44 2,490.08 S 3,829.36 W 4567.77 0.88 7590.52 38.94 240.17 5,487.74 2,519.71 S 3,880.23 W 4626.56 1.41 7617.42 38.61 239.24 5,508.71 2,528.20 S 3,894.77 W 4643.39 2.49 7667.00 38.61 239.24 5,547.45 2,544.03 S 3,921.36 W 4674.31 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 242.00 degrees (Grid) - A total correction of 18.83 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 7,667.00 feet is 4,674.31 feet along 237.03 degrees (Grid) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 3Job No:AK-XX-0901889899 Well Name:2N-337C Survey Report