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216-009
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:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1G-11B (PTD 216-009) Request for temporary production test with TxIA communication Date:Thursday, December 5, 2024 10:44:57 AM From: Lau, Jack J (OGC) Sent: Thursday, December 5, 2024 10:45 AM To: 'Byrne, Jan' <Jan.Byrne@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Subject: RE: KRU 1G-11B (PTD 216-009) Request for temporary production test with TxIA communication Jan – The requested 30 day temporary flow test is approved. What is the monitoring and response plan during the flow test? Jack From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, December 5, 2024 10:28 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Subject: KRU 1G-11B (PTD 216-009) Request for temporary production test with TxIA communication Victoria, Jack, Gas lifted producer KRU KRU 1G-11B (PTD 216-009) has known TxIA communication through multiple tubing leaks. The well no longer meets patching metrics and is on the threshold for meeting RWO metrics. A LTP was installed at 7335’ in the liner top on 7/29/24. The LTP is premised to lower overall water production potentially bringing the well back into RWO metrics, as such, CPAI is requesting a 30-day temporary flow test to gather updated production data post LTP install for RWO justification. The original intention was to request the flow test over the Summer, but facility impacts deferred the request. We are ready currently to perform the temporary flow test. In preparation for the 30- day temporary flow test a CMIT TxIA passed to 2500 psi on 7/20/24 proving the production casing maintains integrity. Additionally, an MITOA passed to 1800 psi on 7/21/24 proving the surface casing maintains integrity. The well has been shut in since 12/14/22 so a TIO trend is not attached, but is available if needed. A wellbore schematic is attached. Please advise if the temporary flow period is acceptable. Please let me know if you have any questions or would like further information. Regards, Jan Byrne CPF1 Well Intervention | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Set LTP Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10385'feet None feet true vertical 6352' feet None feet Effective Depth measured 10385'feet 7258', 7335', 7402', 7813' feet true vertical 6352'feet 6124', 6186', 6241', 6494' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80/ J-55 7841' MD 6492' TVD Packers and SSSV (type, measured and true vertical depth) 7258' MD 7335' MD 7402' MD 7813' MD N/A 6124' TVD 6186' TVD 6241' TVD 6494' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2351' 2206' Burst Collapse Production B Liner 8151' 3041' Casing 6417' 2-3/8" 8188' 10385' 6352' 2314' 106'Conductor Surface Intermediate 16" 10-3/4" 68' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-009 05-029-21008-02-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025650 Kuparuk River Field/ Kuapruk River Oil Pool KRU 1G-11B Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 106' ~ ~~ Well Remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Retrvbl Packer Packer: Baker Hughes LT Packer Packer: Otis RRH Packer Packer: Otis WD Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 265-6471Staff Well Interventions Engineer Slots: 8474-10384' Slots: 6370-6352' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.08.23 08:27:26-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 7/20/2024 ACQUIRE DATA (AC_EVAL) CMIT-TXIA TO 2500 PSI W/ 2.3 BBL DSL (PASS),DEGAS OA FOR MITOA (IN PROGRESS) 7/21/2024 ACQUIRE DATA (AC EVAL) DEGAS IA (COMPLETE), MITOA TO 1800 PSI W/5.7 BBL DSL (PASSED). 7/28/2024 REPAIR WELL PULLED EQUALIZING PRONG FROM 2.81 CA-2 PLUG @ 7311' RKB. IN PROGRESS. 7/29/2024 REPAIR WELL PULLED 2.81" CA-2 PLUG BODY @ 7311' RKB, LOG FROM 7380' RKB TO 7117' RKB WITH CCL, LINER TOP @ 7344' RKB (17.4' DIFFERENT FROM CTD SET DEPTH) MEASURED BHP @ 7309' RKB (3116 PSI TEMP 150.5 *F), BRUSH & FLUSH TBG & LINER @ 7344' RKB, SET 2.70" BAKER LINER TOP PACKER @ 7336.61 (CE) TOP @ 7335.3' RKB (OAL 14.25' OAL) MEASURED BHP @ 7307' RKB (3114 PSI TEMP 149.5 *F), IN PROGRESS. 7/30/2024 REPAIR WELL SET 3 1/2 D&D TEST TOOL TOOL IN 2.70 BAKER KB PACKER @ 7335' RKB, CMIT TBG x IA 2000 PSI (PASS), PULLED 3 1/2 D&D TEST TOOL FROM 2.70" PACKER @ SAME. COMPLETE. 1G-11B Liner Top Packer Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 7,310.0 1G-11B 2/22/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated liner top depth based on CCL 1G-11B 8/3/2024 spilch Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 12/4/2018 lyonska Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 38.0 106.0 106.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 37.0 2,351.3 2,206.1 45.50 J-55 BTC PRODUCTION 7 6.28 37.1 8,187.7 6,416.9 26.00 J-55 BUTT B Liner w/ SBR & 2 HES SwellPackers (water swell) 2 3/8 1.99 7,344.0 10,385.0 6,351.8 4.60 L-80 ST-L Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.2 Set Depth 7,366.3 Set Depth 6,211.7 String Max No 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rd mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.2 31.2 0.00 HANGER 7.000 CIW TUBING HANGER CIW 2.992 2,726.2 2,522.7 33.03 GAS LIFT 5.968 CAMCO MMG GLM CAMCO MMG 2.915 4,148.1 3,673.7 38.19 GAS LIFT 5.968 CAMCO MMG GLM CAMCO MMG 2.915 5,320.5 4,582.8 37.92 GAS LIFT 5.968 CAMCO MMG GLM CAMCO MMG 2.915 6,185.3 5,260.1 39.00 GAS LIFT 5.968 CAMCO MMG GLM CAMCO MMG 2.915 6,832.4 5,780.0 36.16 GAS LIFT 5.968 CAMCO MMG GLM CAMCO MMG 2.915 7,171.4 6,053.4 36.02 GAS LIFT 5.968 CAMCO MMG GLM CAMCO MMG 2.915 7,227.5 6,098.8 35.87 LOCATOR 4.180 LOCATOR SUB Baker 2.990 7,228.5 6,099.6 35.87 SEAL ASSY 3.700 BAKER 80-40 SEAL ASSEMBLY Baker 80-40 2.990 7,235.8 6,105.5 35.85 PBR 5.000 BAKER 80-40 PBR Baker 80-40 PBR 4.000 7,258.3 6,123.8 35.81 PACKER 5.950 BAKER FHL RETRIEVALBE PACKER Baker FHL 2.910 7,311.1 6,166.7 35.63 NIPPLE 4.500 CAMCO DS NIPPLE "DS" Nipple "DS" - 2.812 2.812 7,359.8 6,206.3 35.23 OVERSHOT 4.530 POOR BOY TUBING OVERSHOT Baker 7" x 3.5" 3.750 Top (ftKB) 7,361.3 Set Depth 7,841.2 Set Depth 6,491.6 String Max No 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.20 Grade J-55 Top Connection FL4S ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,376.2 6,219.7 35.10 SBR 4.000 OTIS SBR (2.81" X NIPPLE PROFILE) 2.813 7,402.3 6,241.2 34.87 PACKER 6.150 OTIS RRH PACKER OTIS RRH PACKE R 2.970 7,437.7 6,270.2 34.42 PRODUCTION 5.620 OTIS SPM 2.970 7,504.8 6,325.9 33.62 PRODUCTION 5.620 OTIS SPM 2.970 7,541.7 6,356.6 33.56 BLAST RINGS 4.500 BLAST RINGS (3) 2.992 7,657.2 6,448.8 50.37 BLAST RINGS 4.500 BLAST RINGS (3) 2.992 7,775.2 6,491.9 81.95 PRODUCTION 5.620 OTIS SPM 2.970 7,812.7 6,494.1 91.37 LOCATOR 3.500 OTIS LOCATOR 2.992 7,813.1 6,494.1 91.47 PACKER 6.150 OTIS WD PACKER OTIS WD PACKE R 4.000 7,816.5 6,494.0 92.36 MILLOUT 5.750 OTIS MILL OUT EXTENSION 4.410 7,830.8 6,493.0 96.05 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,840.4 6,491.7 98.50 WLEG 4.570 OTIS WIRLINE RE-ENTRY GUIDE, ELMD TTL @ 7822 during PPROF on 9/27/2007 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,059.0 5,161.7 38.55 LEAK - TUBING TBG LEAK AT 6059' RKB IDENTIFIED BY EL LDL 5/31/2022 2.992 6,409.0 5,436.7 35.67 LEAK - TUBING TBG LEAK AT 6409' RKB IDENTIFIED BY EL LDL 3/10/2023 2.992 7,335.3 6,186.4 35.43 PACKER BAKER HUGHES LTP MID- ELEMENT AT 7336.61' RKB, OAL 14.26' 7/29/2024 1.810 7,344.0 6,193.4 35.36 CTD Liner Top CTD Liner top 2/18/2016 1.992 7,614.0 6,416.9 33.93 Whipstock Baker 3-1/2" Whipstock on Open Hole Anchor, TOWS set at 7,614', 0° HS. RA Tag 6.96' down from TOWS. 2/10/2016 1G-11B, 8/20/2024 4:39:10 PM Vertical schematic (actual) B Liner w/ SBR & 2 HES SwellPackers (water swell); 7,344.0-10,385.0 SHOE; 10,384.6-10,385.0 Slotted Liner; 8,766.1-10,384.6 SLOTS; 8,474.0-10,384.0 CTD Liner Top; 7,344.0 DEPLOY; 8,765.2-8,766.1 SHOE; 8,764.8-8,765.2 Slotted Liner; 8,474.3-8,764.8 Liner Pup; 8,470.3-8,474.3 XO Threads ; 8,468.7-8,470.3 XO Enlarging ; 8,465.4-8,468.7 SWELL PACKER; 8,450.1- 8,465.4 XO Reducing ; 8,444.8-8,450.1 XO Threads ; 8,443.0-8,444.8 PRODUCTION; 37.1-8,187.7 Liner; 7,441.1-8,443.0 WLEG; 7,840.4 NIPPLE; 7,830.8 MILLOUT; 7,816.5 PACKER; 7,813.1 LOCATOR; 7,812.7 PRODUCTION; 7,775.2 Whipstock; 7,614.0 IPERF; 7,540.0-7,590.0 PRODUCTION; 7,504.8 CEMENT PLUG; 7,493.0 ftKB PRODUCTION; 7,437.7 Liner Pup; 7,437.0-7,441.1 XO Threads ; 7,435.5-7,437.0 XO Enlarging ; 7,432.2-7,435.5 SWELL PACKER; 7,416.9- 7,432.2 XO Reducing ; 7,411.6-7,416.9 XO Threads ; 7,409.8-7,411.6 PACKER; 7,402.3 SBR; 7,376.2 Liner; 7,350.2-7,409.8 OVERSHOT; 7,359.8 SBR ; 7,344.0-7,350.2 PACKER; 7,335.3 NIPPLE; 7,311.1 PACKER; 7,258.3 PBR; 7,235.8 SEAL ASSY; 7,228.5 LOCATOR; 7,227.5 GAS LIFT; 7,171.4 GAS LIFT; 6,832.4 LEAK - TUBING; 6,409.0 GAS LIFT; 6,185.3 LEAK - TUBING; 6,059.0 GAS LIFT; 5,320.5 GAS LIFT; 4,148.1 GAS LIFT; 2,726.2 SURFACE; 37.1-2,351.3 FLOAT SHOE; 2,349.3-2,351.3 FLOAT COLLAR; 2,269.8- 2,271.5 CONDUCTOR; 38.0-106.0 HANGER; 37.1-39.8 HANGER; 31.2 KUP PROD KB-Grd (ft) 40.99 RR Date 9/19/1983 Other Elev 1G-11B ... TD Act Btm (ftKB) 10,385.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292100802 Wellbore Status PROD Max Angle & MD Incl (°) 103.42 MD (ftKB) 8,120.31 WELLNAME WELLBORE1G-11B Annotation Last WO: End Date 3/23/2015 H2S (ppm) 200 Date 12/21/2015 Comment SSSV: NONE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,726.2 2,522.7 33.03 1 GAS LIFT GLV RK 1 1/2 1,249.0 10/11/2020 Schlumb erger Camco MMG 0.188 4,148.1 3,673.7 38.19 2 GAS LIFT OV RK 1 1/2 0.0 5/10/2022 Schlumb erger Camco MMG 0.250 5,320.5 4,582.8 37.92 3 GAS LIFT DMY RK 1 1/2 0.0 10/11/2020 Schlumb erger Camco MMG 0.000 6,185.3 5,260.1 39.00 4 GAS LIFT DMY RK 1 1/2 0.0 10/9/2015 Schlumb erger Camco MMG 0.000 6,832.4 5,780.0 36.16 5 GAS LIFT DMY RK 1 1/2 0.0 3/23/2015 Schlumb erger Camco MMG 0.000 7,171.4 6,053.4 36.02 6 GAS LIFT DMY RK 1 1/2 0.0 6/22/2022 Schlumb erger Camco MMG 0.000 7,437.7 6,270.2 34.42 7 PROD DMY BK 1 0.0 6/21/2015 0.000 7,504.8 6,325.9 33.62 8 PROD DMY BK 1 0.0 6/22/2015 0.000 7,775.2 6,491.9 81.95 9 PROD OPEN BEK 1 0.0 4/23/2015 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,344.0 6,193.4 35.36 SBR 2.700 Baker SBR Deployment Sleeve (2.25" ID) Baker SBR 2.250 7,409.8 6,247.3 34.78 XO Threads 2.375 Crossover Pup 2 3/8" ST-L X Hyd511 bxp 1.992 7,411.6 6,248.7 34.75 XO Reducing 2.410 Crossover Pup 2 3/8", 4.6 ppf, L- 80 X 2 1/6", 3.35 ppf, L-80 Hyd511 bxp Haliburto n XO reducing 1.751 7,416.9 6,253.1 34.69 SWELL PACKER 2.700 Halliburton 2-1/16" Swellpacker, Water Swell Medium, (SAP# 102508668) #2 Haliburto n 2 1/6" Water swell 1.751 7,432.2 6,265.7 34.49 XO Enlarging 2.410 Crossover Pup 2 1/6", 3.25 ppf, L- 80 X 2 3/8", 4.6 ppf, L-80, Hyd511 bxp Haliburto n XO enlarging 1.751 7,435.5 6,268.4 34.45 XO Threads 2.375 Crossover Pup 2 3/8" Hyd511 X ST-L bxp 1.992 8,443.0 6,372.9 94.77 XO Threads 2.375 Crossover Pup 2 3/8" ST-L X Hyd511 bxp 1.992 8,444.8 6,372.8 94.69 XO Reducing 2.410 Crossover Pup 2 3/8", 4.6 ppf, L- 80 X 2 1/6", 3.35 ppf, L-80 Hyd511 bxp Haliburto n XO reducing 1.751 8,450.1 6,372.4 94.44 SWELL PACKER 2.700 Halliburton 2-1/16" Swellpacker, Water Swell Medium, (SAP# 102508668) #3 Haliburto n 2 1/6" Water swell 1.751 8,465.4 6,371.0 95.56 XO Enlarging 2.410 Crossover Pup 2 1/6", 3.25 ppf, L- 80 X 2 3/8", 4.6 ppf, L-80, Hyd511 bxp Haliburto n XO enlarging 1.751 8,468.7 6,370.7 95.81 XO Threads 2.375 Crossover Pup 2 3/8" Hyd511 X ST-L bxp 1.992 8,765.2 6,319.4 95.07 DEPLOY 2.625 Shorty Deployment Sleeve Baker Shorty 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,474.0 10,384.0 6,370.1 6,351.8 A-4, 1G-11 2/19/2016 SLOTS 1G-11B, 8/20/2024 4:39:11 PM Vertical schematic (actual) B Liner w/ SBR & 2 HES SwellPackers (water swell); 7,344.0-10,385.0 SHOE; 10,384.6-10,385.0 Slotted Liner; 8,766.1-10,384.6 SLOTS; 8,474.0-10,384.0 CTD Liner Top; 7,344.0 DEPLOY; 8,765.2-8,766.1 SHOE; 8,764.8-8,765.2 Slotted Liner; 8,474.3-8,764.8 Liner Pup; 8,470.3-8,474.3 XO Threads ; 8,468.7-8,470.3 XO Enlarging ; 8,465.4-8,468.7 SWELL PACKER; 8,450.1- 8,465.4 XO Reducing ; 8,444.8-8,450.1 XO Threads ; 8,443.0-8,444.8 PRODUCTION; 37.1-8,187.7 Liner; 7,441.1-8,443.0 WLEG; 7,840.4 NIPPLE; 7,830.8 MILLOUT; 7,816.5 PACKER; 7,813.1 LOCATOR; 7,812.7 PRODUCTION; 7,775.2 Whipstock; 7,614.0 IPERF; 7,540.0-7,590.0 PRODUCTION; 7,504.8 CEMENT PLUG; 7,493.0 ftKB PRODUCTION; 7,437.7 Liner Pup; 7,437.0-7,441.1 XO Threads ; 7,435.5-7,437.0 XO Enlarging ; 7,432.2-7,435.5 SWELL PACKER; 7,416.9- 7,432.2 XO Reducing ; 7,411.6-7,416.9 XO Threads ; 7,409.8-7,411.6 PACKER; 7,402.3 SBR; 7,376.2 Liner; 7,350.2-7,409.8 OVERSHOT; 7,359.8 SBR ; 7,344.0-7,350.2 PACKER; 7,335.3 NIPPLE; 7,311.1 PACKER; 7,258.3 PBR; 7,235.8 SEAL ASSY; 7,228.5 LOCATOR; 7,227.5 GAS LIFT; 7,171.4 GAS LIFT; 6,832.4 LEAK - TUBING; 6,409.0 GAS LIFT; 6,185.3 LEAK - TUBING; 6,059.0 GAS LIFT; 5,320.5 GAS LIFT; 4,148.1 GAS LIFT; 2,726.2 SURFACE; 37.1-2,351.3 FLOAT SHOE; 2,349.3-2,351.3 FLOAT COLLAR; 2,269.8- 2,271.5 CONDUCTOR; 38.0-106.0 HANGER; 37.1-39.8 HANGER; 31.2 KUP PROD 1G-11B ... WELLNAME WELLBORE1G-11B Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: TAG TOP OF LINER 7,326 RKB 1G-11 2/22/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Upper section of patch 1G-11 12/16/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 9/16/2010 ninam Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,614.0 6,416.9 33.54 TUBING PUNCH PERFORATE TUBING 7614' - 7619' WITH 2", 3SPF, 120 DEG PHASING GUNS LOADED WITH 6.7 GRAM BIG HOLE CHARGES. 7/29/2015 2.992 7,660.0 6,455.2 33.76 WHIPSTOCK TOP OF BAKER HUGHES WHIPSTOCK 3 DEG ROHS @ 7660'. LOG CORRELATED TO ATLAS CBL DATED 10/4/83. 8/4/2015 7,700.0 6,488.4 33.95 CEMENT RETAINER RETAINER 2.75" X 1.47' 7/12/2015 7,831.0 6,597.6 33.15 PLUG CA-2 PLUG w 12ft of SAND 4/23/2015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,540.0 7,590.0 6,355.2 6,396.9 C-4, 1G-11 12/23/1983 12.0 IPERF 120 deg Phasing; 5" Dresser Atlas 7,676.0 7,722.0 6,468.5 6,506.7 C-1, 1G-11 12/23/1983 12.0 IPERF 120 deg Phasing; 5" Dresser Atlas 7,710.0 7,720.0 6,496.7 6,505.0 A-4, 1G-11 7/6/2015 3.0 APERF 120 DEG PHASING, 2" HSC HES millenium big hole charges 7,945.0 7,950.0 6,693.5 6,697.7 A-5, 1G-11 3/30/1984 4.0 APERF 90 deg Phasing; RigidJet 7,960.0 7,980.0 6,706.2 6,723.2 A-4, 1G-11 11/26/1993 4.0 APERF 180 deg. Phasing; 163 CCW orientation; 2 5/8" Titan HC 7,980.0 7,982.0 6,723.2 6,724.9 A-4, 1G-11 3/30/1984 4.0 APERF 90 deg Phasing; RigidJet Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,620.0 7,813.0 6,421.9 6,582.5 CEMENT PLUG 7/12/2015 7,493.0 7,620.0 6,316.1 6,421.9 CEMENT PLUG 7/31/2015 1G-11, 8/20/2024 4:39:11 PM Vertical schematic (actual) APERF; 7,980.0-7,982.0 APERF; 7,960.0-7,980.0 APERF; 7,945.0-7,950.0 PLUG; 7,831.0 APERF; 7,710.0-7,720.0 CEMENT RETAINER; 7,700.0 IPERF; 7,676.0-7,722.0 WHIPSTOCK; 7,660.0 WINDOW; 7,658.0-7,668.0 CEMENT PLUG; 7,620.0 ftKB TUBING PUNCH; 7,614.0 B Liner w/ SBR & 2 HES SwellPackers (water swell); 7,344.0-10,385.0 PRODUCTION; 37.1-8,187.7 IPERF; 7,540.0-7,590.0 Liner; 7,441.1-8,443.0 PRODUCTION; 7,504.8 CEMENT PLUG; 7,493.0 ftKB CTD Liner Top; 7,344.0 PRODUCTION; 7,437.7 Liner Pup; 7,437.0-7,441.1 XO Threads ; 7,435.5-7,437.0 XO Enlarging ; 7,432.2-7,435.5 SWELL PACKER; 7,416.9- 7,432.2 XO Reducing ; 7,411.6-7,416.9 XO Threads ; 7,409.8-7,411.6 PACKER; 7,402.3 SBR; 7,376.2 Liner; 7,350.2-7,409.8 OVERSHOT; 7,359.8 SBR ; 7,344.0-7,350.2 PACKER; 7,335.3 NIPPLE; 7,311.1 PACKER; 7,258.3 PBR; 7,235.8 SEAL ASSY; 7,228.5 LOCATOR; 7,227.5 GAS LIFT; 7,171.4 GAS LIFT; 6,832.4 LEAK - TUBING; 6,409.0 GAS LIFT; 6,185.3 LEAK - TUBING; 6,059.0 GAS LIFT; 5,320.5 GAS LIFT; 4,148.1 GAS LIFT; 2,726.2 SURFACE; 37.1-2,351.3 FLOAT SHOE; 2,349.3-2,351.3 FLOAT COLLAR; 2,269.8- 2,271.5 CONDUCTOR; 38.0-106.0 HANGER; 37.1-39.8 HANGER; 31.2 KUP PROD KB-Grd (ft) 40.99 RR Date 9/19/1983 Other Elev 1G-11 ... TD Act Btm (ftKB) 8,208.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292100800 Wellbore Status PROD Max Angle & MD Incl (°) 41.68 MD (ftKB) 4,900.00 WELLNAME WELLBORE1G-11B Annotation Last WO: End Date 3/15/2015 H2S (ppm) 200 Date 12/21/2015 Comment SSSV: NONE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1G-11A smsmith Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SIDETRACK, ADD LATERAL B 1G-11A 2/26/2016 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: 1G-11A Abandoned - use 1G-11B 2/25/2016 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread WINDOW 7 7,658.0 7,668.0 6,461.6 A LINER 2 3/8 1.99 7,625.8 10,030.0 6,481.7 4.60 L-80 ST-L Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,662.0 6,456.8 35.69 CUT LINER CHEM CUT 2 3/8" LINER @ 7662' RKB. PULLED 37'10" 1/25/2016 1.992 10,037.0 6,481.1 94.70 IBP IBP ran to isolate heavily water swept zone from production. 8/27/2015 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,625.8 6,426.7 33.59 SBR 2.700 BAKER SBR DEPLOYMENT SLEEVE Baker SBR 2.250 7,647.7 6,444.9 33.70 XO Threads 2.375 Crossover Pup 2 3/8" ST-L X Hyd511 bxp 1.992 7,739.2 6,504.4 63.02 XO Reducing 2.410 Crossover Pup 2 3/8", 4.6 ppf, L- 80 X 2 1/6", 3.35 ppf, L-80 Hyd511 bxp Haliburto n 2 1/6" Water swell 1.751 7,744.5 6,506.7 64.16 SWELL PACKER 2.700 HALLIBURTON SWELL PACKER, WATER MEDIUM Haliburto n 2 1/6" Water swell 1.751 7,759.7 6,512.7 69.93 XO Enlarging 2.410 Crossover Pup 2 1/6", 3.25 ppf, L- 80 X 2 3/8", 4.6 ppf, L-80, Hyd511 bxp Haliburto n 2 1/6" Water swell 1.751 8,719.3 6,485.7 96.50 XO Threads 2.375 Crossover Pup 2 3/8" Hyd511 X ST-L bxp 1.992 8,752.4 6,481.8 97.47 OPEN HOLE OPEN HOLE 3.000 8,776.4 6,478.8 96.69 DEPLOY 2.625 BAKER SHORTY DEPLOYMENT SLEEVE Baker Shorty 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,720.9 8,752.0 6,485.6 6,481.8 A-4, 1G-11 8/27/2015 SLOTS Slotted Liner 8,777.2 10,029.6 6,478.7 6,481.7 A-4, 1G-11 8/27/2015 SLOTS Slotted LIner 1G-11A, 8/20/2024 4:39:12 PM Vertical schematic (actual) IBP; 10,037.0 A LINER; 7,662.0-10,030.0 SHOE; 10,029.6-10,030.0 SLOTS; 8,777.2-10,029.6 DEPLOY; 8,776.4-8,777.2 SHOE; 8,752.0-8,752.4 SLOTS; 8,720.9-8,752.0 SWELL PACKER; 7,744.5- 7,759.7 WINDOW; 7,658.0-7,668.0 Window; 7,658.0-7,668.0 CUT LINER; 7,662.0 CEMENT PLUG; 7,620.0 ftKB TUBING PUNCH; 7,614.0 B Liner w/ SBR & 2 HES SwellPackers (water swell); 7,344.0-10,385.0 PRODUCTION; 37.1-8,187.7 IPERF; 7,540.0-7,590.0 Liner; 7,441.1-8,443.0 PRODUCTION; 7,504.8 CEMENT PLUG; 7,493.0 ftKB CTD Liner Top; 7,344.0 PRODUCTION; 7,437.7 Liner Pup; 7,437.0-7,441.1 XO Threads ; 7,435.5-7,437.0 XO Enlarging ; 7,432.2-7,435.5 SWELL PACKER; 7,416.9- 7,432.2 XO Reducing ; 7,411.6-7,416.9 XO Threads ; 7,409.8-7,411.6 PACKER; 7,402.3 SBR; 7,376.2 Liner; 7,350.2-7,409.8 OVERSHOT; 7,359.8 SBR ; 7,344.0-7,350.2 PACKER; 7,335.3 NIPPLE; 7,311.1 PACKER; 7,258.3 PBR; 7,235.8 SEAL ASSY; 7,228.5 LOCATOR; 7,227.5 GAS LIFT; 7,171.4 GAS LIFT; 6,832.4 LEAK - TUBING; 6,409.0 GAS LIFT; 6,185.3 LEAK - TUBING; 6,059.0 GAS LIFT; 5,320.5 GAS LIFT; 4,148.1 GAS LIFT; 2,726.2 SURFACE; 37.1-2,351.3 FLOAT SHOE; 2,349.3-2,351.3 FLOAT COLLAR; 2,269.8- 2,271.5 CONDUCTOR; 38.0-106.0 HANGER; 37.1-39.8 HANGER; 31.2 KUP PROD KB-Grd (ft) 40.99 RR Date 9/19/1983 Other Elev 1G-11A ... TD Act Btm (ftKB) 10,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292100801 Wellbore Status PROD Max Angle & MD Incl (°) 97.55 MD (ftKB) 8,754.89 WELLNAME WELLBORE1G-11B Annotation Last WO: End Date 3/15/2015 H2S (ppm) 200 Date 12/21/2015 Comment SSSV: NONE 1G-11AL1XX, 8/20/2024 4:39:13 PM Vertical schematic (actual) APERF; 7,980.0-7,982.0 APERF; 7,960.0-7,980.0 APERF; 7,945.0-7,950.0 PLUG; 7,831.0 APERF; 7,710.0-7,720.0 CEMENT RETAINER; 7,700.0 IPERF; 7,676.0-7,722.0 WHIPSTOCK; 7,660.0 WINDOW; 7,658.0-7,668.0 CEMENT PLUG; 7,620.0 ftKB TUBING PUNCH; 7,614.0 B Liner w/ SBR & 2 HES SwellPackers (water swell); 7,344.0-10,385.0 PRODUCTION; 37.1-8,187.7 IPERF; 7,540.0-7,590.0 Liner; 7,441.1-8,443.0 PRODUCTION; 7,504.8 CEMENT PLUG; 7,493.0 ftKB CTD Liner Top; 7,344.0 PRODUCTION; 7,437.7 Liner Pup; 7,437.0-7,441.1 XO Threads ; 7,435.5-7,437.0 XO Enlarging ; 7,432.2-7,435.5 SWELL PACKER; 7,416.9- 7,432.2 XO Reducing ; 7,411.6-7,416.9 XO Threads ; 7,409.8-7,411.6 PACKER; 7,402.3 SBR; 7,376.2 Liner; 7,350.2-7,409.8 OVERSHOT; 7,359.8 SBR ; 7,344.0-7,350.2 PACKER; 7,335.3 NIPPLE; 7,311.1 PACKER; 7,258.3 PBR; 7,235.8 SEAL ASSY; 7,228.5 LOCATOR; 7,227.5 GAS LIFT; 7,171.4 GAS LIFT; 6,832.4 LEAK - TUBING; 6,409.0 GAS LIFT; 6,185.3 LEAK - TUBING; 6,059.0 GAS LIFT; 5,320.5 GAS LIFT; 4,148.1 GAS LIFT; 2,726.2 SURFACE; 37.1-2,351.3 FLOAT SHOE; 2,349.3-2,351.3 FLOAT COLLAR; 2,269.8- 2,271.5 CONDUCTOR; 38.0-106.0 HANGER; 37.1-39.8 HANGER; 31.2 KUP PROD KB-Grd (ft) 40.99 RR Date 9/19/1983 Other Elev 1G-11AL1XX ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292100860 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1G-11B Annotation End DateH2S (ppm) 200 Date 12/21/2015 Comment Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1G-07A 50-029-20872-01 909383029 Kuparuk River Packer Setting Record Field- Final 22-Jul-24 0 1 2 1G-11B 50-029-21008-02 909469734 Kuparuk River Correlation Record ans SBHP Records Field- Final 29-Jul-24 0 1 3 1G-11B 50-029-21008-02 909469734 Kuparuk River SBHP Record Field- Final 29-Jul-24 0 1 4 1G-17 50-029-22945-00 909422685 Kuparuk River Leak Detect Log Field- Final 13-Jul-24 0 1 5 1G-17 50-029-22945-00 909422685 Kuparuk River Multi Finger Caliper Field & Processed 14-Jul-24 0 1 6 1G-17 50-029-22945-00 909422685 Kuparuk River Packer Setting Record Field- Final 13-Jul-24 0 1 7 1L-24 50-029-22170-00: 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1 8 1Q-04 50-029-21250-00 909422479 Kuparuk River Leak Detect Log Field- Final 10-Jul-24 0 1 9 1Q-04 50-029-21250-00 909422479 Kuparuk River Multi Finger Caliper Field & Processed 10-Jul-24 0 1 10 1Q-09 50-029-21209-00 909422975 Kuparuk River Multi Finger Caliper Field & Processed 19-Jul-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 218-051 216-009 199-062 191-066 184-234 184-192 T39436 T39437 T39437 T39438 T39438 T39438 T39439 T39440 T39440 T39441 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:36:38 -08'00' Correlation Record ans SBHP 2 1G-11B 50-029-21008-02 909469734 Kuparuk River Records Field- Final 29-Jul-24 0 1 3 1G-11B 50-029-21008-02 909469734 Kuparuk River SBHP Record Field- Final 29-Jul-24 0 1 216-009 By Anne Prysunka at 10:01 am, Jul 26, 2022 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-31_22029_KRU_1G-11B_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22029 KRU 1G-11B 50-029-21008-02 Caliper Survey w/ Log Data 31-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:216-009 T36687 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.08 13:39:08 -08'00' • • 0 r- O o N O E J- vD C a w O o 0 O QmmO oZ " " a > o,N 'co- U U J a a J a) •. 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Z No 110 M2 >' W re N I m 0- ICC Q = 0 Y g Q C Z E CI £ 0 m Z d • N c coI I O > m O I— co 3 N d N 'C in ' a' el or) O as C U E E O 0 2 V RECEIVED 1MAR 14 2016 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0, Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20/VC 25.110 Development L • Exploratory ❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 2/19/2016 216-009 ` 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 2/12/2016 50-029-21008-02 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 327'FSL, 806'FWL,Sec 29,T12N, R10E, UM 2/17/2016 KRU 1G-11B • Top of Productive Interval: 9. Ref Elevations: KB: 99 17. Field/Pool(s): 1558'FNL, 1256'FEL, Sec 32,T12N, R10E, UM GL: 63 BF: Kuparuk River Field/Kuparuk Oil Pool. Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4430'FNL, 1206 FEL, Sec 29,T12N, R10E, UM n/a ADL 25640 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 540585 y- 5980976 Zone- 4 10,385/6352 • 2571 TPI: x- 543820 y- 5979109 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 543848 y- 5981517 Zone- 4 n/a 1667/1624 5. Directional or Inclination Survey: Yes . E (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) 7613/6416 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res . 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGGRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 65 H-40 38 106 38 106 24 212 sx CS II 10.75 45.5 J-55 37 2351 37 2206 13.5 930 sx AS III,250 sx ASI 7 26 J-55 37 8188 37 6901 8.5 610 sx Class G, 250 sx ASI 2 3/8 4.6 L-80 7326 10385 6179 6352 3 N/A 24. Open to production or injection? Yes 2 No ❑ 25.TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 X 4.5 7841 7258/6124, 7402/6241, SLOTS @ 8474-10384 7813/6494 COMPLETION 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. DATE Was hydraulic fracturing used during completion? Yes❑ No El _zIlq/IL/ Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/28/2016 k/i$ L I Fr Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/29/2016 18 Test Period -..p 282 47 1141 176/176 166 Flow Tubing Caslog Press: Calculated Oil-Bbl:• Gas-MCF: Water-Bbl: Oil Gravity-API (corn): Press. 190 PSI 993 24-Hour Rate p 376 63 1521 21.8 Form 10-407 Revised 11/2015 1/17- 3/1-7-f i�' CONTINUED ON PAGE 2 RBDMS Lu- MAR 1 5 2016submit ORIGINIAL only • A 3*/ PIZk 1.),/W, • • 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No El If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1667 1624 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 7613 6416 information, including reports, per 20 AAC 25.071. Top C2 7629 6429 Top Cl i688 b466 Top C2 8089 6355 Top C3 8236 6407 Fault 1 (C4 DT/C2 UT) 8410 6376 Top C2 8485 6308 Top C3 8635 6341 TD(Kuparuk C4) 10385 6352 Formation at total depth: Kuparuk C4 • 31. List of Attachments: Definitive Survey, Daily Operations Summary, Schematics Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, Paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Pohler 265-6435 Email: Cody.J.PohlerAcop.com Printed Name: J. Burke Title: SR. CTD ENGINEER / Signature: Phone: 265-6097 Date: V/411 A" INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • a cp a M *`U' O f V ma N a o °a a Nu d • �o �2m U o M n T n 65 cm,�m ,L.0S O N N 01 N " 11 Q) m N O) II 60"' '-F- m _ N l0 c O H N to 0 m Q 0) y p a0 c Q^` m E W -Tri C7 C7 60 NV N M pp - a a N (m0 M a) toTo 2 2 O O r c U _ v O `Et 7 a r v m O . v g u 0 m 'gr.! 2 2E c ; ., YE - - �7 n cn N a C) C� (0 N N- V U a— ) ' t O N Zr) Y Y n + a � c n 2 n n U U n 0‘,7, 202' l N lcD -N a O O a n r--13 2 NV° .1 it r N -cc: 3 N N rL 01 O F'. v N �a a EU m re); aN m ' N- O L L N T,11- 0 N+ n N m m I c o m� as Ua 2 ca 3 3n -`21`' 2-2'2 N61nl E og = ret cot a� m 1; a al; R 'c a; �m m°Do :. 2 ‘- 0 MN c "'m E cn90 _o Eco gNo. n `m�N� 13 m do "OM -5AM C 'x.) 0. <2=z) c^-5N CNO O! OS 0 LLI 0.8 2 > n o n 2' .0-Q n 1_ CO S Ow w " mm gin..: '-. 15 a)EaErn =mnU6 £ Udn =.c y c' OI o V acow p o 232 II c J 2 J -82° `y 21-2 U C O C J v :d O J U O a U, 0)(0 a W_ N_ m Lo U C 0) 0YCnY N' ) f` sn Y-1 E ° ° E e C a N .15;41.);=.75 N�m N 01 alEE . 1- E c c c 2 c i p M (0 p2 ' j c.=2 0`-nMa tlI O'Nc -a U 01 O Of O C $� of U mu. U a .03� O NCi mM m OOUnw am Amo) a '6a - a N N YY NN ENW N NjYdYa NNNvN .N A M 01 6, y A-;„ OS OJ m OS 0{ ,..r5 A ', 07,... N M M mm MCI) Q'MO M UmUmU MOM M -.N=AA: X =1, qi 4„, epfr -- 1 1 NN: l Ii _ .I" ilk i 74 4 a i r e .; .:L.,,,,,,,,,,:_x,' aro 2 i ,-.5" - w-r----:".t. i r,„4,, i,,, im' W = V „,,.. li „,.„ t` 1 ' 4• , A .N,4'Z',A ,A,. + :,o.,41 k. .iaa E .._. .I ILS „I L� U Cf) 0 III .6 v a II 0 0a2� a. a C.) a) a a_ Q2 m ovo rn (Q t N o-.. v 0)2M Y n E m C7 cmo °2 N 1f] V.O N O n rq 0) c V NMN (nU w Nw f0 co m a tI, Z. oY CY C.O n M = acno a o� mY �_• �a _ coo v2 nm O �Np ac a w� 2 (O�1 W- y Vn m d^3� 3 a� N W I V .M UUU r a0 N rn /CD O N M m it M N D N J KUP P$OD 1G-11B ConocoPhillips . Well Attribu Max Angl D TD Alaska I/�1 Wellbore APIIUWI Field Name Wellbore Status ncl(°I MD(ft Act Btm(ftKB) Cgrloccs ttith 7 500292100802 KUPARUK RIVER UNIT PROD 103.42 8,120.31 10,385.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 19-118,3/7120164:0117 PM SSSV: NONE 200 12/21/2015 Last WO: 3/23/2015 40.99 9/19/1983 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date „. HANGER;31.z le Last Tag:SLM 7,310.0 2/22/2016 Rev Reason:SIDETRACK,ADD LATERAL B lehallf 2/26/2016 Casing Strings III 01 [ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len g...Grade Top Thread _ulas.�,�.. ,m:::: .. r„iu,n,CONDUCTOR 16 15.250 38.0 106.0 106.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 11 SURFACE 103/4 9.950 37.0 2,351.3 2206.1 45.50 J-55 BTC s''''CONDUCTOR;38.0-106.0~ CasingDescription OD(in) ID(in) TopftKB Set Depth ftKB Set Depth ND Wt/Len(I...Grade Top Thread Pion (ftKB) P (ftKB) P (TVD)... I WINDOW 7 7,658.0 7,668.0 6,455.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE;37.1-2,351.39-t r, . I. PRODUCTION 7 6.276 37.1 8,187.7 6,416.9 26.00 J-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread GAS LIFT;2,726.2 B Liner w/SBR&2 HES 2 3/8 1.992 7,326.6 10,385.0 6,351.8 4.60 L-80 ST-L 11 SwellPackers(water MI swell) Liner Details GAS LIFT;4,148.1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,326.6 6,179.3 35.50 SBR Baker SBR Deployment Sleeve#2(2.25"ID) 2.250 GAS LIFT;5,320 7,394.2 6,234.5 34.95 XO Reducing Crossover Pup 2 3/8",4.6 ppf,L-80 X 2 1/6",3.35 1.751 ppf,L-80 Hyd511 bxp 7,399.5 6,238.8 34.90 SWELL Halliburton 2-1/16"Swellpacker,Water Swell 1.751 GAS LIFT;6,185.3- 4;_, PACKER Medium,(SAP#102508668) 7,414.8 6,251.4 34.71 XO Enlarging Crossover Pup 2 1/6",3.25 ppf,L-80 X 2 3/8",4.6 1.751 GAS LIFT;6,832.4if ;. : ppf,L-80,Hyd511 bxp 8,444.8 6,372.8 94.69 XO Reducing Crossover Pup 2 3/8",4.6 ppf,L-80 X 2 1/6",3.35 1.751 ppf,L-80 Hyd511 bxp GAS LIFT;7,171.4- :.. -,ft9 8,450.1 6,372.4 94.44 SWELL Halliburton 2-1/16"Swellpacker,Water Swell 1.751 PACKER Medium,(SAP#102508668) #3 '.. 8,465.4 6,371.0 95.56 XO Enlarging Crossover Pup 2 1/6",3.25 ppf,L-80 X 2 3/8",4.6 1.751 LOCATOR;7,227.5 ppf,L-80,Hyd511 bxp SEAL ASSY;7,228.5 - PBR;7,235.8 { 8,765.2 6,319.4 95.07 DEPLOY Shorty Deployment Sleeve 1.920 PACKER;7,258.3 ® Casing Description00(in) ID(in) Top(ftKB) Set Depth(BOB) Set Depth(N . W D).. ULen(I...Grade Top Thread -- c ^' A LINER I 2 3/81 1.9921 7,625.81 10,030 .01 6,369. 81 4.601 L- 80 ST-L Liner Details NIPPLE;7,311.1 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 7,625.8 6,426.4 38.55 SBR BAKER SBR DEPLOYMENT SLEEVE 2 250 7,739.2 6,484.4 74.70 XO Reducing Crossover Pup 2 3/8",4.6 ppf,L-80 X 2 1/6",3.35 1.751 ppf,L-80 Hyd511 bxp OVERSHOT;7,359.8 �- �;�. 7,744.5 6,485.8 75.65 SWELL HALLIBURTON SWELL PACKER,WATER MEDIUM 1.751 PACKER SBR;7,376.2 < 7,759.7 6,489.2 78.36 XO Enlarging Crossover Pup 2 1/6",3.25 ppf,L-80 X 2 3/8",4.6 1.751 I ppf,L-80,Hyd511 bxp ijial 8,752.4 6,320.7 96.18 OPEN HOLE OPEN HOLE 3.000 PACKER;7,402.3 8,776.4 6,318.5 94.11 DEPLOY 'BAKER SHORTY DEPLOYMENT SLEEVE 1.920 O Tubing Strings Tubing Description Ma...ID(int Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt gb/ft) Grade Top Connection TUBING-WO 2015 'String 3 1/21 2.9921 31.21 7,366.31 6 211.71 9.301 L-80 !Top mod PRODUCTION;7,437.7 Completion Details PRODUCTION;7,504.8 " Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°I Item Des Com (in) (PERF;7,540.0-7,580.0.. 31.2 31.2 0.00 HANGER CIW TUBING HANGER 2.992 7,227.5 6,098.8 35.87 LOCATOR LOCATOR SUB 2.990 Whipstock;7,614.0 - 7,228.5 6,099.6 35.87 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 lil 7,235.8 6,105.5 35.85 PBR BAKER 80-40 PBR 4.000 7,258.3 6,123.8 35.81 PACKER BAKER FHL RETRIEVALBE PACKER 2.910 7,311.1 6,166.7 35.63 NIPPLE CAMCO DS NIPPLE(PULLED RHC AND BALL AND 2.812 ROD,4 15 15) WINnOW,75500-7s68.0 - 7,359.8 6,206.3 35.23 OVERSHOT POOR BOY TUBING OVERSHOT 3.750 Tubing Description Ma...ID(in) Top(ROB) Set Depth(ft..Set Depth(ND)(...Wt(Ibtft) Grade Top Connection y TUBING-ORIGINAL 'String 41/21 2.9921 7,361.3 7,8412186,491.61 9.21 3-55 [Top Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) PRODUCTION;7,775.2 7,376.2 6,219.7 35.10 SBR OTIS SBR(2.81"X NIPPLE PROFILE) 2.813 LOCATOR,7,812.7, - 7,402.3 6,241.2 34.87 PACKER OTIS RRH PACKER 2.970 PACKER 7,813.1 r► 7,541.7 6,356.6 33.56 BLAST BLAST RINGS(3) 2.992 MILLOUT,7,816.5 `■ r RINGS NIPPLE;7,830.8 r" 7,657.2 6,448.8 50.37 BLAST BLAST RINGS(3) 2.992 WLEG,7,840.4 q RINGS f 7,812.7 6,494.1 91.37 LOCATOR OTIS LOCATOR 2.992 ( 7,813.1 6,494.1 91.47 PACKER OTIS WD PACKER 4.000 PRODUCTION;37.1-8,187.7- - 7,816.5 6,494.0 92.36 MILLOUT OTIS MILL OUT EXTENSION 4.410 a 7,830.8 6,493.0 96.05 NIPPLE CAMCO D NIPPLE NO GO 2.750 ® 7,840.4 6,491.7 98.50 WLEG OTIS WIRLINE RE-ENTRY GUIDE,ELMD TTL I/7822 3.015 during PPROF on 9/27/2007 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) 1"/ Des Corn Run Date ID(In) 7,614.0 6,416.9 33.93 Whipstock Baker 3-1/2"Whipstock on Open Hole Anchor, 2/10/2016 I!, TOWS set at 7,614',0°HS.RA Tag 6.96'down from TOWS. SLOTS;8,474.0-10,384.0 -' A LINER;7,662.0-10,030.0 B Liner w/SBR 6 2 HES SwellPackers(water swell(, 7,326.6-10,3850 1 KUP P OD ell1 G-11 B ateig ConocoPhillips Alaska<Inc. Ci)kar. 10-116,3/7/2016 4'.01'.17 PM Vertical schematic(actual) HANGER,31.2 /.N -.ll Perforations&Slots Iit JI snot <,•n~' w,w,•w nA.,<'<,II� <�^ Top(ftKB Btm(ftKB T(11KB)D) et(ftKB(ND) Dens w (shots/ Zone Date _ ft) Type Com �ti CONDUCTOR;38.0-1060 8.474.0 10,384.0 6,370.1 6,351.8 A-4,1G-11 2/19/2016 SLOTS II Mandrel Inserts St SURFACE;37.1-2,351.3 i ati onTop(TVD) Valve Latch Port Size TRO Run OM Nr Top(ftKB (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GAS LIFT;2,726.2 _ _ 1 2,726.2 2,522.7 CAMCO MMG 1 1/2 GAS UFT GLV RK 0.188 1,319.0 2/24/2016 AIM 2 4,148.1 3,673.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,297.0 2/23/2016 GAS LIFT;4,148.13 5,320.5 4,582.8 CAMCO MMG 11/2 GAS UFT OV RKB 0.250 0.0 2/23/2016 4 6,185.3 5,260.1 CAMCO MMG 1 1/2 GAS UFT 'DMY RK 0.000' 0.0 10/9/2015 03 OM 5 6,832.4 5,780.0 CAMCO MMG 1 1/2 GAS UFT DMY RK 0.000 4 0.0 3/23/2015 GAS LIFT,5,320.5 AI 6 7,171.4 6,053.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 ma 7 7,437.7 6,270.2 OTIS SPM 1 PROD DMY MBK 0.000 0.0 6/21/2015 8 7,504.8 6,325.9 OTIS SPM 1 PROD DMY BK 0.000 0.0 6/22/2015 GAS LIFT;6,185.3 9 7,775.2 6,491.9 OTIS SPM 1 PROD OPEN BEK 0.000 0.0 4/23/2015 Notes:General&Safety GAS LIFT;6,832.4End Date Annotation 2/26/2016 NOTE:SBR AT 7326'IS ABLE TO ACCOMODATE FUTURE LINER TOP PACKER. GAS LIFT;7,171.441 LOCATOR;7,227.5 SEAL ASSY,7,228.5 PBR;7,235.8 t PACKER;7,258.3 NIPPLE;7,311.1 Ki OVERSHOT;7,359.8 II II SER;7,376.2 P Ill PACKER;7,4023 PRODUCTION;7,437.7 ■ ,. PRODUCTION;7,504.8 ".' IPERF;7,540.0.7,590.0 l Whipstock;7,614.0 IAMB > I WINDOW;7,658.0-7,668.0 f 1 ' F 1i it.3 PRODUCTION;7,775.2 ' LOCATOR;7,812.7 I; PACKER;7,813.1 MILLOUT;7,816.5 I'" 11 NIPPLE;7,830.8 t WLEG;7,840.4 PRODUCTION;37.1-8,187.7 .Te i ! ll gl� SLOTS;8,474.0-10,384.0 1`T A LINER,7,662.0-10,030.0'{ B Liner w/SBR 82 HES BwellPeokers(wager 00411),-\ }l 7,326.6-10,385.0�J operations Summary (with Timeloggepths) &Wells t 1G-11 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKe) 2/9/2016 2/9/2016 3.50 MIRU MOVE MOB P PJSM with Peak and rig crew. Load 0.0 0.0 03:00 06:30 shop. Pull Sub and Pits off of 3G-04, install jeeps,ready to move. 2/9/2016 2/9/2016 5.00 MIRU MOVE MOB P Mobilize Sub and Pits and shop to 3G- 0.0 0.0 06:30 11:30 pad to 1G-11. 2/9/2016 2/9/2016 2.50 MIRU MOVE MOB P Remove jeeps,prep well,remove tree 0.0 0.0 11:30 14:00 caps,spot Sub and Pits over well. Send truck back to retrieve shop from pervious location. 2/9/2016 2/9/2016 5.00 MIRU MOVE RURD P RU interconnect,work on post rig 0.0 0.0 14:00 19:00 move checklist,communications. 2/9/2016 2/9/2016 1.75 MIRU WHDBOP NUND P Nipple up BOPE stack,change out 0.0 0.0 19:00 20:45 riser,and secure cellar,Check all tree bolts,none found loose,load stack. ""Note:Check Tree Bolts 0.5 hrs. ""Rig Accept: 19:00 hrs 2/9/2016 2/10/2016 3.25 MIRU WHDBOP BOPE P Begin initial BOPE test 250/3,000 0.0 0.0 20:45 00:00 psi,Annular 2,500 psi.Test witness waived by AOGCC rep.Chuck Scheve. 2/10/2016 2/10/2016 3.00 MIRU WHDBOP BOPE P Continue initial BOPE test 250/3,000 0.0 0.0 00:00 03:00 psi,Annular 2,500 psi.Test witness waived by AOGCC rep.Chuck Sheve. 2/10/2016 2/10/2016 1.50 MIRU WHDBOP PRTS P Inspect and service Bowen nuts on 0.0 0.0 03:00 04:30 PDL's,Test TT line and blow down. 2/10/2016 2/10/2016 1.00 MIRU WHDBOP MPSP P PJSM with rig and valve crew, RU 0.0 0.0 04:30 05:30 lubricator and BPV equipment. Pull TWCV.Off load BPV equipment. 2/10/2016 2/10/2016 4.00 MIRU WHDBOP PRTS P Pressure test lines and PDL. PT inner 0.0 0.0 05:30 09:30 reel iron. 2/10/2016 2/10/2016 1.50 PROD1 RPEQPT PULD P PJSM.make up whipstock BHA#1 0.0 74.0 09:30 11:00 and pressure deploy. 2/10/2016 2/10/2016 3.00 PROD1 RPEQPT TRIP P RIH with whipstock BHA#1.Tie in to 74.0 7,624.8 11:00 14:00 the K1 for a-8 ft correction.Weight check at 7405ft=32klbs PUW. RIH to set depth. 2/10/2016 2/10/2016 0.25 PROD1 RPEQPT WPST P Close EDC. Bring pumps up to set 7,624.8 7,624.8 14:00 14:15 anchor.Whipstock set at 0°HS. TOWS at 7614'. 2/10/2016 2/10/2016 1.75 PROD1 RPEQPT TRIP P POOH.Swap hole to seawater. 7,624.8 74.0 14:15 16:00 Continue pulling out of the hole. 2/10/2016 2/10/2016 0.50 PROD1 RPEQPT OWFF P Flow check. PJSM 74.0 74.0 16:00 16:30 2/10/2016 2/10/2016 0.50 PROD1 RPEQPT PULD P LD BHA#1,Check pack offs. 74.0 0.0 16:30 17:00 2/10/2016 2/10/2016 0.85 PROD1 WHPST PULD P PJSM-MU BHA#2 0.6°motor,string 0.0 74.3 17:00 17:51 mill and HCC DSM,MU to CoilTrak, surface test. 2/10/2016 2/10/2016 2.50 PROD1 WHPST TRIP P RIH with BHA#2,Tie in to K1 for 74.3 7,613.4 17:51 20:21 minus 8.5 ft correction. RIH.PUW at 7,552 ft is 35k.Dry tag TOWS at 7,613.6 ft. PU.RIW 11.7k 2/10/2016 2/11/2016 3.65 PROD1 WHPST WPST P Mill 3-1/2"window exit 1.67 bpm at 7,613.4 7,615.8 20:21 00:00 2,730 psi,BHP 3,212 psi, IA 834,OA 279 Page 1/8 Report Printed: 2/22/2016 Drilling !perations Summary (with Timelog�epths) &Wellss 1G-11 ConocoPhilltps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/11/2016 2/11/2016 3.95 PROD1 WHPST WPST P Mill 3-1/2"window exit 1.67 bpm at 7,615.8 7,619.4 00:00 03:57 2,760 psi, BHP 3,197 psi, IA 605,OA 288. Drill off 3-1/2"at 7,619.1 ft. Contact 7"at 7,619.4 ft. 2/11/2016 2/11/2016 0.20 PROD1 WHPST REAM P Back ream 3-1/2"window 7,619.4 7,605.0 03:57 04:09 2/11/2016 2/11/2016 1.35 PROD1 WHPST TRIP P POOH for 7"window milling assembly. 7,605.0 74.3 04:09 05:30 2/11/2016 2/11/2016 0.70 PROD1 WHPST OWFF P Monitor well for flow.crew change. 74.3 74.3- 05:30 06:12 2/11/2016 2/11/2016 2.50 PROD1 WHPST PULD P PJSM-LD BHA#2, PU Weatherford 74.3 75.7 06:12 08:42 BHA#3,with 2°fixed bend motor and 2.80"no-go fat radius mill. Note: Primary mill was 2.79"no-go. Changed out and ran back up mill. SIMOPS:change out gripper blocks on injector. 2/11/2016 2/11/2016 2.30 PROD1 WHPST TRIP P MU injector,Tag up and reset depth. 75.7 7,620.0 08:42 11:00 RIH with milling BHA#3.Tie in to K1 for a-8.5 ft correction.Continue in the hole.Weight check at 7418 ft. PUW= 36klbs.Dry tag 7"at 7620 ft. 2/11/2016 2/11/2016 6.25 PROD1 WHPST WPST P Begin milling 7"per program 15° 7,620.0 7,625.6 11:00 17:15 ROHS.SOW=12.5klbs,pumping1.61 BPM at 2800 psi FS.Bottom of window called at 7622.6 ft. 2/11/2016 2/11/2016 1.00 PROD1 WHPST DRLG P Continue milling rathole highside at 1 7,625.6 7,638.6 17:15 18:15 fph,pumping 1.6 BPM at 2800psi FS. 200 lbs WOB,CTW 8.4klbs. 2/11/2016 2/11/2016 2.00 PROD1 WHPST REAM P Back ream dual string exit 45°R/L, 7,638.6 7,638.6 18:15 20:15 PUW 35k,dry drift clean,pump 5x5 sweep.Open EDC. 2/11/2016 2/11/2016 1.45 PROD1 WHPST TRIP P POOH for drilling assembly 7,638.6 75.7 20:15 21:42 2/11/2016 2/11/2016 0.50 PROD1 WHPST OWFF P Monitor well for flow. PJSM 75.7 75.7 21:42 22:12 2/11/2016 2/11/2016 0.65 PROD1 WHPST PULD P LD BHA#3,string mill and FRDSM 75.7 0.0 22:12 22:51 both 2.79"no-go. Minor chipping on outside of mill. 2/11/2016 2/11/2016 0.50 PROD1 DRILL SVRG P Flush choke,service injector and 0.0 0.0 22:51 23:21 check pack offs. 2/11/2016 2/12/2016 0.65 PROD1 DRILL PULD P PJSM-MU drilling BHA#4,2.25°AKO 0.0 72.2 23:21 00:00 motor and HCC Bi-center bit,had to work down through tree. 2/12/2016 2/12/2016 0.75 PROD1 DRILL PULD P Crew change out. MU drilling BHA#4, 72.2 72.2 00:00 00:45 2.25°AKO motor and RB HCC Bi- center bit to CoilTrak.Surface test. 2/12/2016 2/12/2016 1.75 PROD1 DRILL TRIP P RIH with BHA#4.Stack 10k at 7,367 72.2 7,367.0 00:45 02:30 ft(Otis SBR)several attepmts to pass with different TF and speed,pass through with TF 30°ROHS,pump off at 10 fpm. 2/12/2016 2/12/2016 0.20 PROD1 DRILL DLOG P Tie in to K1 for minus 9 ft correction. 7,367.0 7,395.0 02:30 02:42 2/12/2016 2/12/2016 0.80 PROD1 DRILL CIRC P RIH to 7,600 ft. Curculate around 9.0 7,395.0 7,639.0 02:42 03:30 ppg FloPro drilling mud.PUW 33k. Close EDC.RBIH,clean thru window. Page 2/8 Report Printed: 2/22/2016 •Operations Summary (with Timelo Depths) :; &Wells ,. 1G-11 ConocaePhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/12/2016 2/12/2016 5.50 PROD1 DRILL DRLG P 7,639 ft. OBD 1.65 bpm at 3,450 psi 7,639.0 7,837.0 03:30 09:00 FS, BHP 3,585 psi,CWT 10.0k,WOB 1.5k,WHP 22, IA 0,OA 292 2/12/2016 2/12/2016 0.15 PROD1 DRILL WPRT P Mini Wiper from 7837 ft to 7789 ft. 7,837.0 7,837.0 09:00 09:09 PUW 33 klbs,SOW= 12 klbs. 2/12/2016 2/12/2016 1.45 PROD1 DRILL DRLG P OBD 1.69 bpm at 3,755 psi FS,BHP 7,837.0 7,915.0 09:09 10:36 3,585 psi,CWT 11.5k,WOB 1.0k. ROP 40-70 FPH.Send sweep ahead of reaching TD. TD build section at 7915 ft.Average DLS=45°/100'. 2/12/2016 2/12/2016 1.75 PROD1 DRILL TRIP P POOH with build BHA#4. 7,915.0 0.0 10:36 12:21 2/12/2016 2/12/2016 0.50 PROD1 DRILL OWFF P Flow check well.Static.PJSM for LD 72.2 72.2 12:21 12:51 BHA. 2/12/2016 2/12/2016 0.65 PROD1 DRILL PULD P LD BHA#4, Bit condition 1-1-PN-N-X-I 72.2 0.0 12:51 13:30 -NO-BHA.check pack offs. 2/12/2016 2/12/2016 1.10 PROD1 DRILL PULD P PJSM-MU drilling BHA#5,0.5°AKO 0.0 72.2 13:30 14:36 motor and New HYC Bi-center bit.MU to CoilTrak.Surface test. 2/12/2016 2/12/2016 1.45 PROD1 DRILL TRIP P RIH with BHA#5 72.2 7,380.0 14:36 16:03 2/12/2016 2/12/2016 0.15 PROD1 DRILL DLOG P Tie in to K1 for minus 9 ft.correction. 7,380.0 7,397.0 16:03 16:12 2/12/2016 2/12/2016 0.50 PROD1 DRILL TRIP P RIH.PUW at 7,600 ft 31k. RBIH. 7,397.0 7,915.0 16:12 16:42 Close EDC.slight bobble at 7,619 ft. 2/12/2016 2/13/2016 7.30 PROD1 DRILL DRLG P 7,915 ft. OBD 1.69 bpm at 3,760 psi 7,915.0 8,166.0 16:42 00:00 FS,BHP 3,698 psi,CWT 10.4k,WOB 1.0k, ROP 25-60 fph. 2/13/2016 2/13/2016 2.75 PROD1 DRILL DRLG P 8,166 ft. OBD 1.69 bpm at 3,772 psi 8,166.0 8,315.0 00:00 02:45 FS,BHP 3,729 psi,CWT 10.0k,WOB 2.0k, ROP 60-80 fph. Losses seen at 10 bph at 8,295 ft 2/13/2016 2/13/2016 0.40 PROD1 DRILL WPRT P Wiper trip up hole to 7,650 ft.PUW 8,315.0 7,650.0 02:45 03:09 34k. 2/13/2016 2/13/2016 0.30 PROD1 DRILL WPRT P Wiper back in hole. RIW 12.0k 7,650.0 8,315.0 03:09 03:27 2/13/2016 2/13/2016 5.25 PROD1 DRILL DRLG P 8,315 ft. OBD 1.69 bpm at 3,868 psi 8,315.0 8,532.0 03:27 08:42 FS,BHP 3,690 psi,CWT 10.0k,WOB 2.0k, ROP 60-80 fph. Losses 5-10 bph.Crossed fault at 8410 ft.No change in loss rate. 2/13/2016 2/13/2016 0.15 PROD1 DRILL WPRT P BHA wiper. PUW=37klbs,SOW= 13 8,532.0 8,532.0 08:42 08:51 klbs. 2/13/2016 2/13/2016 4.50 PROD1 DRILL DRLG P 8,532 ft. OBD 1.67 bpm at 3,871 psi 8,532.0 8,715.0 08:51 13:21 FS,BHP 3,777 psi,CWT 10.3k,WOB 2.0k, ROP 35-50 fph. 2/13/2016 2/13/2016 0.65 PROD1 DRILL WPRT P Wiper trip up hole, PUW 39k,RBIH, 8,715.0 8,715.0 13:21 14:00 RIW 9.5k 2/13/2016 2/13/2016 2.00 PROD1 DRILL DRLG P 8,715 ft. OBD 1.67 bpm at 3,850 psi 8,715.0 8,775.0 14:00 16:00 FS, BHP 3,771 psi,CWT 10.0k,WOB 1.4k,ROP 40-50 fph. 2/13/2016 2/14/2016 8.00 PROD1 DRILL WPRT T 8,775 ft. Entire field in Phase III,pump 8,775.0 7,600.0 16:00 00:00 sweep,pick up into 3-1/2"tubing, open EDC,circulate around until Phase III weather breaks. 2/14/2016 2/14/2016 3.70 PROD1 DRILL CIRC T Continue to circulate around until 7,600.0 7,600.0 00:00 03:42 Phase III weather breaks.PUH and tie in to K1 for a plus 2 ft correction. Page 3/8 Report Printed: 2/22/2016 ._. Iterations Summary (with Timelog Depths) Drilling 1G-11 ConocoPhi[flps AEsska Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Star:Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 2/14/2016 2/14/2016 0.15 PROD1 DRILL WPRT T PUH slowly to 7,350 ft.for tie in at K1. 7,600.0 7,355.0 03:42 03:51 2/14/2016 2/14/2016 0.30 PROD1 DRILL DLOG T Tie in to K1 for plus 2 ft correction. 7,355.0 7,575.0 03:51 04:09 2/14/2016 2/14/2016 3.35 PROD1 DRILL WPRT T RIH to 7,575 ft,continue to circulate 7,575.0 7,575.0 04:09 07:30 around until Phase III weather breaks. 2/14/2016 2/14/2016 4.50 PROD1 DRILL CIRC T Crew change on bus with heavy 7,575.0 7,575.0 07:30 12:00 equipment escort.Circulate through EDC at 0.45 BPM,WHP= 125 psi, 10.9 ppg EMW ECD. Losses= 1.5 BPH. 2/14/2016 2/14/2016 7.50 PROD1 DRILL CIRC T Continue circulating WOW.Perform 7,575.0 7,566.0 12:00 19:30 checks around rig and shop. Circulate through EDC 0.45 BPM,WHP= 125 psi, 10.9 ppg EMW ECD. Losses 1.5 BPH. 2/14/2016 2/15/2016 4.50 PROD1 DRILL CIRC T Crew change on bus with heavy 7,566.0 7,566.0 19:30 00:00 equipment escort.Circulate through EDC at 0.40 bpm,WHP 116, 10.9 ppg EMW ECD. Losses=-1.5 bph. 2/15/2016 2/15/2016 5.00 PROD1 DRILL CIRC T Continue to circulate through EDC at 7,566.0 7,554.0 00:00 05:00 0.40 bpm,WHP 108, 10.9 ppg EMW ECD.Losses=-1.5 bph. 2/15/2016 2/15/2016 2.00 PROD1 DRILL CIRC T Weather conditions reduced to Phase 7,554.0 7,554.0 05:00 07:00 II,PJSM-clean up pad around vac trucks,prep for mud swap, bring up 2nd gen,changeout 2/15/2016 2/15/2016 0.50 PROD1 DRILL TRIP T Weather upgraded from Phase 3 to 7,554.0 8,775.0 07:00 07:30 Phase 2.After crew change,RBIH washing to bottom at 1.6 bpm. 2/15/2016 2/15/2016 2.50 PROD1 DRILL DRLG P OBD 1.61 bpm at 3,850 psi FS,BHP 8,775.0 8,878.0 07:30 10:00 3,790 psi,CWT 11.0k,WOB 2.0k, ROP 50-60 fph.Losses 5 bph.Started new mud in the coil. Note-New 8.6 ppg FloPro Lite out bit at 8,878 ft. 2/15/2016 2/15/2016 3.50 PROD1 DRILL DRLG P New mud at the bit,8878 ft.Continued 8,878.0 9,180.0 10:00 13:30 drilling ahead.Pumping 1.7 bpm at 3,445 psi FS, BHP 3,512 psi,CTW 9.5k,WOB 1.5k,ROP80-120 fph. Losses 2-4 bph. 2/15/2016 2/15/2016 0.85 PROD1 DRILL WPRT P Planned wiper trip from 9180 ft to 9,180.0 9,180.0 13:30 14:21 8099 ft. RBIH.Clean trip. 2/15/2016 2/15/2016 5.15 PROD1 DRILL DRLG P OBD 1.69 bpm at 3,500 psi FS,BHP 9,180.0 9,540.0 14:21 19:30 3,539 psi,CWT 8.4k,WOB 1.9k, ROP 50-100 fph. Losses 1-2 bph.Getting very little drop, need left turn,stack out at 9,415 ft and 9,498 ft,PUW 45k 2/15/2016 2/15/2016 2.10 PROD1 DRILL WPRT T 9,540 ft. Wiper trip,confer with town 9,540.0 72.2 19:30 21:36 of possible polygon breech,need for larger AKO motor,possible bit. POOH for motor and bit if needed.Open EDC,continue OOH. 2/15/2016 2/15/2016 0.50 PROD1 DRILL OWFF T On surface,monitor well for flow. 72.2 72.2 21:36 22:06 PJSM-LD BHA in open hole. 2/15/2016 2/15/2016 0.65 PROD1 DRILL PULD T LD BHA#5,Bit condition 1-1-BU-G-X- 72.2 0.0 22:06 22:45 I-ER-BHA. Page 4/8 Report Printed: 2/22/2016 ,,, iterations Summary (with Timelog Depths) c. W1 ens 1G-11 GoriocoPhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/15/2016 2/15/2016 0.75 PROD1 DRILL PULD T MU drilling BHA#6, 1.0°AKO motor 0.0 72.2 22:45 23:30 and RR HCC bi-center bit to same upper BHA.MU to CoilTrak,surface test. 2/15/2016 2/16/2016 0.50 PROD1 DRILL TRIP T RIH with drilling BHA#6 72.2 3,200.0 23:30 00:00 2/16/2016 2/16/2016 1.00 PROD1 DRILL TRIP T Continue RIH with drilling BHA#6 3,200.0 7,380.0 00:00 01:00 2/16/2016 2/16/2016 0.20 PROD1 DRILL DLOG T Tie in to K1 for a minus 9 ft correction, 7,380.0 7,400.0 01:00 01:12 PUW 35k. 2/16/2016 2/16/2016 0.80 PROD1 DRILL TRIP T RIH with BHA#6. 7,400.0 9,540.0 01:12 02:00 2/16/2016 2/16/2016 1.00 PROD1 DRILL DRLG P 9,540 ft. OBD 1.70 bpm at 3,720 psi 9,540.0 9,669.0 02:00 03:00 FS,BHP 3,692 psi,CWT 10.0k,WOB 1.8k, ROP 130 fph.Getting 6°DLS, slow rate to 1.5 bpm psi, BHP 3691 psi,CWT 10.0k,Hold 2.0k WOB,ROP 180 fph,getting 2°DLS 2/16/2016 2/16/2016 0.45 PROD1 DRILL WPRT T 9,669 ft. DD wiper,confer with town 9,669.0 9,669.0 03:00 03:27 about drilling outside polygon with low DLS,wait on orders from town.Verbal to drill ahead. 2/16/2016 2/16/2016 2.40 PROD1 DRILL DRLG P 9,669 ft. OBD 1.35 bpm at 3,000 psi 9,669.0 9,890.0 03:27 05:51 FS, BHP 3,584 psi,CWT 9.6k,WOB 1.4k,ROP 170 fph. 2/16/2016 2/16/2016 0.60 PROD1 DRILL WPRT P 9890 ft.Short wiper up hole to 8984 9,890.0 8,984.0 05:51 06:27 ft.,PUW 38k 2/16/2016 2/16/2016 0.60 PROD1 DRILL WPRT P 8984 ft,Wiper back in hole to bottom, 8,984.0 9,890.0 06:27 07:03 RIW 10k 2/16/2016 2/16/2016 6.50 PROD1 DRILL DRLG P 9890 ft.BOBD 1.28 bpm at 2789 psi, 9,890.0 10,069.0 07:03 13:33 BHP 3922,WHP 01, IA 489,OA 264 2/16/2016 2/16/2016 0.30 PROD1 DRILL WPRT P 10069 ft,Wiper up hole to 9568 ft, 10,069.0 9,568.0 13:33 13:51 PUW 28k 2/16/2016 2/16/2016 0.30 PROD1 DRILL WPRT P 9568 ft.Wiper back in hole,RIW 10k 9,568.0 10,069.0 13:51 14:09 2/16/2016 2/16/2016 1.50 PROD1 DRILL DRLG P 10069 ft.BOBD 1.68 bpm at 3749 psi, 10,069.0 10,110.0 14:09 15:39 BHP 4342,WHP 0, IA 511,OA 271, 2/16/2016 2/16/2016 2.35 PROD1 DRILL DRLG T 10110 ft.Stall motor, PU,bring pump 10,110.0 72.2 15:39 18:00 back up,differential is high,looks like we chunked motor,verified stator rubber over shaker with bottoms up, POOH 2/16/2016 2/16/2016 0.50 PROD1 DRILL OWFF T On surface,monitor well for flow. 72.2 72.2 18:00 18:30 PJSM-LD BHA 2/16/2016 2/16/2016 0.60 PROD1 DRILL PULD T LD BHA#6, Bit condition 1-1-BT-N-X-I 72.2 0.0 18:30 19:06 -PN-DNM. 2/16/2016 2/16/2016 0.50 PROD1 DRILL BOPE T Function test BOPE. 0.0 0.0 19:06 19:36 2/16/2016 2/16/2016 0.60 PROD1 DRILL CTOP T Change out UQC(timed out), MEGG 0.0 0.0 19:36 20:12 test good,check pack offs. 2/16/2016 2/16/2016 0.80 PROD1 DRILL PULD T MU drilling BHA#7, 1.1°AKO motor 0.0 72.2 20:12 21:00 and RR HYC bi-center bit. MU to CoilTrak,surface test. 2/16/2016 2/16/2016 1.45 PROD1 DRILL TRIP T RIH with drilling BHA#7 72.2 7,380.0 21:00 22:27 2/16/2016 2/16/2016 0.20 PROD1 DRILL DLOG T Tie in to K1 for minus 8.5 ft correction. 7,380.0 7,405.0 22:27 22:39 PUW 31k. Page 5/8 Report Printed: 2/22/2016 , thrilling Operations Summary (with Timelo Depths) w, Welts 1 G-11 Conn coPhitlip}s Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/16/2016 2/16/2016 1.20 PROD1 DRILL TRIP T RIH with drilling BHA#7,clean thru 7,405.0 10,110.0 22:39 23:51 window. Note:8.5 hrs BHI non billable. 2/16/2016 2/17/2016 0.15 PROD1 DRILL DRLG P 10,110 ft. OBD 1.68 bpm at 3,761 psi 10,110.0 10,125.0 23:51 00:00 FS,BHP 3,842,WHP 0, IA 226,OA 259 2/17/2016 2/17/2016 1.25 PROD1 DRILL DRLG P 10,125 ft. OBD 1.68 bpm at 3,954 10,125.0 10,146.0 00:00 01:15 psi,BHP 3,815,WHP 3, IA 272,OA 260,weight transfer issues,stacking, trouble getting it to drill pump 5x5 sweep. 2/17/2016 2/17/2016 1.45 PROD1 DRILL WPRT P 10146 ft. Wiper up hole to 8,900 ft. 10,146.0 8,900.0 01:15 02:42 PUW 34k 2/17/2016 2/17/2016 1.15 PROD1 DRILL WPRT P Wiper back in hole,same issues 8,900.0 10,146.0 02:42 03:51 RBIH,20 fpm at.45 bpm, RIW 3k-4k, any faster stops forward progress. 2/17/2016 2/17/2016 4.00 PROD1 DRILL DRLG P 10,146 ft. BOBD 1.5 bpm at 3,687 psi 10,146.0 10,314.0 03:51 07:51 FS, BHP 3,753 psi,WHP 0, IA 328, OA 264,stacking at 10,180 ft.pump lube pill 2/17/2016 2/17/2016 0.25 PROD1 DRILL WPRT P 10314 ft.Short 500 ft.wiper up hole to 10,314.0 9,820.0 07:51 08:06 9820 ft. PUW 36k 2/17/2016 2/17/2016 0.25 PROD1 DRILL WPRT P 9820 ft.Wiper back in hole, RIW 7k 9,820.0 10,314.0 08:06 08:21 2/17/2016 2/17/2016 3.75 PROD1 DRILL DRLG P 10314 ft,BOBD drilling 1.3 bpm at 10,314.0 10,378.0 08:21 12:06 3022 psi,BHP 3822,WHP 0, IA 385, OA 267 2/17/2016 2/17/2016 0.50 PROD1 DRILL WPRT P 10384 ft.Short 500 ft wiper up to 9860 10,378.0 9,860.0 12:06 12:36 ft.PUW 30k 2/17/2016 2/17/2016 0.50 PROD1 DRILL WPRT P 9860 ft,Wiper back in hole RIW 7k 9,860.0 10,378.0 12:36 13:06 2/17/2016 2/17/2016 2.00 PROD1 DRILL DRLG P 10378 ft. BOBD 1.2 bpm at 2680 psi, 10,378.0 10,384.0 13:06 15:06 BHP 3738,WHP 0, IA 376,OA 268 2/17/2016 2/17/2016 1.50 PROD1 DRILL WPRT P 10384 ft.trouble with weight transfer, 10,384.0 7,380.0 15:06 16:36 perform wiper up hole,TD called, RBIH to bottom,pump 10x10 sweep, perform wiper up to the K1 marker. 2/17/2016 2/17/2016 0.25 PROD1 DRILL DLOG P 7380 ft.Tie into the K1 marker 7,380.0 7,393.0 16:36 16:51 correction of plus 4.0 ft. 2/17/2016 2/17/2016 1.75 PROD1 DRILL WPRT P 7393 ft, RBIH to confirm TD,when 7,393.0 10,385.0 16:51 18:36 brought pumps on right outside window,starting stacking multiple times from 8,195 ft.,adjust rate and speed to get back to bottom. 2/17/2016 2/17/2016 0.40 PROD1 DRILL CIRC P 10,385 ft.Confirmed TD.pump 10,385.0 10,385.0 18:36 19:00 beaded pill. 2/17/2016 2/17/2016 2.60 PROD1 DRILL 'DISP P POOH laying in 8.6 ppg beaded liner 10,385.0 72.2 19:00 21:36 running pil,paint Flags at 8,700 ft (Yellow)and 5,900 ft(White) 2/17/2016 2/17/2016 0.75 PROD1 DRILL 'OWFF P 'On surface,monitor well for flow. 72.2 72.0 21:36 22:21 PJSM-LD BHA 2/17/2016 2/17/2016 0.75 PROD1 DRILL PULD P LD BHA#7, Bit condition 1-1-CT-G-X-I 72.0 0.0 22:21 23:06 -NO-TD. 2/17/2016 2/17/2016 0.50 COMPZ1 CASING PUTB P Prep floors for liner run,inspect Top 0.0 0.0 23:06 23:36 Drive, PJSM with Baker rep. 2/17/2016 2/18/2016 0.40 COMPZ1 CASING PUTB P Begin MU of bull nose,56 jts slotted 0.0 116.0 23:36 00:00 and shorty deployment sleeve. Page 6/8 Report Printed: 2/22/2016 • • . ['lrii Operations Summary (with Timelog Depths) :{ &Wens 1G-11 ConocoPhillips , hkxka Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/18/2016 2/18/2016 2.25 COMPZ1 CASING PUTB P MU"B"lower liner assembly, bull 116.0 1,619.8 00:00 02:15 nose,56 jts slotted and shorty deployment sleeve. 2/18/2016 2/18/2016 0.95 COMPZ1 CASING PULD P PJSM-MU"B"lower liner assembly to 1,619.8 1,664.0 02:15 03:12 BHA#8.MU to CoilTrac,surface test. 2/18/2016 2/18/2016 2.00 COMPZ1 CASING RUNL P RIH with BHA#8.corrected to the 1,664.0 5,900.0 03:12 05:12 EOP 5,900 ft flag for minus 12.6 ft. PUW 33k. 2/18/2016 2/18/2016 0.75 COMPZ1 CASING RUNL P Tie into the K1 marker correction of 5,900.0 10,385.0 05:12 05:57 plus 3.0 ft,Continued RIH to bottom at 10,385 ft 2/18/2016 2/18/2016 0.25 COMPZ1 CASING RUNL P 10,385 ft. PUW 36k, bring pump up, 10,385.0 8,765.2 05:57 06:12 release liner on bottom, PUW 28 k. 2/18/2016 2/18/2016 2.50 COMPZ1 CASING RUNL P Open EDC in open hole, lay in liner 8,765.2 44.2 06:12 08:42 running pill with beads up to 6000', displace well to 10.0 ppg completion fliud while POOH 2/18/2016 2/18/2016 0.50 COMPZ1 CASING OWFF P Check well for flow,PJSM for LD BHA 44.2 44.2 08:42 09:12 2/18/2016 2/18/2016 1.00 COMPZ1 CASING PULD P LD Coiltrak and BOT setting tools, 44.2 0.0 09:12 10:12 2/18/2016 2/18/2016 0.50 COMPZ1 CASING PULD P PJSM,and prep rig floor for running 0.0 0.0 10:12 10:42 liner, 2/18/2016 2/18/2016 4.25 COMPZ1 CASING PULD P Starting making up upper section of 0.0 1,483.0 10:42 14:57 liner 2/18/2016 2/18/2016 1.90 COMPZ1 CASING RUNL P RIH with upper liner assembly,HES 1,483.0 7,583.0 14:57 16:51 swell packers,pumping min rate,with EDC closed.corrected to the EOP 6,100 ft flag for minus 12.6 ft. PUW 33k. 2/18/2016 2/18/2016 0.60 COMPZ1 CASING RUNL P Continue RIH to bottom no problem 7,583.0 8,765.0 16:51 17:27 2/18/2016 2/18/2016 0.20 COMPZ1 CASING RUNL P 8,765 ft. Bring pump up,release liner 8,765.0 7,326.0 17:27 17:39 on bottom, PUW 28k.Top of SBR at 7,326 ft. re-set counters. 2/18/2016 2/18/2016 0.70 COMPZ1 CASING DISP P Displace hole to seawater 7,326.0 7,326.0 17:39 18:21 2/18/2016 2/18/2016 3.15 DEMOB WHDBOP FRZP P POOH,stop at 4,600 ft and bullhead 7,326.0 44.2 18:21 21:30 10 bbls seawater,FP from 2500' 2/18/2016 2/18/2016 1.75 DEMOB WHDBOP RURD P At surface,PJSM, PUD BHA#9, LD 44.2 0.0 21:30 23:15 Liner running BHA. 2/18/2016 2/19/2016 0.75 DEMOB WHDBOP RURD P Install nozzle,flush coil,jet stack and 0.0 0.0 23:15 00:00 BPV profile. 2/19/2016 2/19/2016 0.50 DEMOB WHDBOP RURD P Finish jetting stack and BPV profile, 0.0 0.0 00:00 00:30 flush coil. PJSM with valve crew. 2/19/2016 2/19/2016 1.50 DEMOB WHDBOP MPSP P Bring in BPV equipment, P/T lubricator 0.0 0.0 00:30 02:00 250/1,000 psi,Set BPV with 110 psi SITP, RD and off load BPV equipment. 2/19/2016 2/19/2016 3.00 DEMOB WHDBOP RURD P Blow down and flush surface 0.0 0.0 02:00 05:00 lines/stack.Continue offloading fluids from the rig.Start rig move checklist. Continue staging equipment at 3G pad. Page 7/8 Report Printed: 2/22/2016 Mnitirg operations Summary (with Timeloggepths) &Wells 1 G-11 ConocoPhiilips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 2/19/2016 2/19/2016 1.00 DEMOB WHDBOP NUND P ND BOPE, Freeze protect and secure 0.0 0.0 05:00 06:00 cellar.Flange bolts checked(30 minutes)Finish rig down check list. Rig Released at 06:00 Page 8/8 Report Printed: 2/22/2016 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-11B 50-029-21008-02 Baker Hughes 1NTEQ V I Definitive Survey Report ?ASfl1ES 19 February,2016 • ConocoPhillips fditA ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc.-Kupt Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(10-11) Well 1G-11 North Reference: True Wellbore: 1G-11 Survey Calculation Method: Minimum Curvature Design: 1G-11 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States '.,i Map Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level 1 Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1G-11 --- Well Position +NIS 0.00 usft Northing: 5,980,976.13usft Latitude: 70°21'32.246 N t-EI-W 0.00 usft Easting: 540,585.50 usft - Longitude: 149°40'13.280 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1G-11B Magnetics Model Name - Sample Date DeClination DipAngle Field Strength r. ,- - :'Y„ r (°) (nT) BGGM2015 3/1/2016 1861 8099 57496 Design 1G-11B Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,600.00 Vertical Section: Depth From(TVD) 4-NI-S CE/-W Direction (usft) (usft) (usft) (°) 99.00 0.00 0.00 350 00 .'.Survey Program Date 2/19/2016 From To Survey Survey (usft)] (usft) Survey(Wellbore) Tool Name Description Start Date End Date 100.00 7,600.00 1G-11(1G-11) BOSS-GYRO Sperry-Sun BOSS gyro multishot 1/8/2001 7,613.00 1034504 1G-11B(1G-11B) MWD MWD-Standard 2/8/2016 2/18/2016 2/19/2016 1:10:06PM Page 2 COMPASS 5000.1 Build 74 • • ConocoPhillips Milli ConocoPhillips Definitive Survey Report HUGHES Company;:, ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 10-11 Project Kuparuk River Unit TVD Reference: 10-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Well: 10-11 North Reference: True Wellbore: 10-11 Survey Calculation Method: Minimum Curvature Design:,. 10-11 Database: EDM Alaska NSK Sandbox Survey MD Inc' Azl TVD TVDSS +NIS Map Map Vertical (uaft}' {°) (°) (usft) (usft) (usft) (usft Northing Easting (°fl 00) Section Survey Tool Name Annotation 1 (ft) (ft) (ft) ) 7,60000 33.47 128.40 6,405.23 6,306.23 -1,880.13 3,219.15 5,979,113.66 543,814.48 023 -2,410.57 MWD(2) TIP 7,613.00 33.53 128.33 6,416.07 6,317.07 -1,884.58 3,224.78 5,979,109.23 543,820.13 0.55 -2415.93 MWD(2) KOP 7,639.07 43.77 122.72 6,436.41 6,337.41 -1,893.95 3,238.05 5,979,099.94 543,833.45 41.48 -2,427.46 MWD(2) ll 7,670.35 55.14 118.18 6,456.71 6,357.71 -1,905.90 3,258.54 5,979,088.10 543,854.00 37.97 -2,442.79 MWD(2) 1 7,700.53 66.08 114.91 6,471.51 6,372.51 -1,917.60 3,282.04 5,979,076.53 543,877.56 37.45 -2,458.38 MWD(2) t 7,730.34 73.12 101.98 6,481.93 6,382.93 -1,926.34 3,308.48 5,979,067.93 543,904.05 46.98 -2,471.59 MWD(2) tg 7,760.27 78.45 88.59 6,489.31 6,390.31 -1,928.96 3,337.29 5,979,065.47 543,932.87 46.86 -2,479.17 MWD(2) 7,790.44 85.51 75.49 6,493.53 6,394.53 -1,924.81 3,366.79 5,979,069.78 543,962.34 48.92 -2,480.20 MWD(2) t - 7,820.28 93.35 63.09 6,493.83 6,394.83 -1,914.28 3,394.63 5,979,080.46 543,990.11 49.13 -2,474.67 MWD(2) 7,850.39 101.05 50.29 6,490.04 6,391.04 -1,897.95 3,419.53 5,979,096.92 544,014.93 49.29 -2,462.91 MWD(2) 7,880.61 101.59 34.76 6,484.08 6,385.08 -1,876.19 3,439.50 5,979,118.79 544,034.78 50.42 -2,444.95 MWD(2) 7,910.04 102.76 19.58 6,477.84 6,378.84 -1,850.68 3,452.60 5,979,144.37 544,047.74 50.57 -2,422.10 MWD(2) ) 7,940.23 102.41 15.15 6,471.25 6,372.25 -1,822.56 3,461.39 5,979,172.53 544,056.38 14.37 -2,395.94 MWD(2) ) 7,970.34 101.91 12.73 6,464.91 6,365.91 -1,794.00 3,468.48 5,979,201.13 544,063.31 8.03 -2,369.04 MWD(2) t 8,000.35 102.10 10.99 6,458.67 6,359.67 -1,765.27 3,474.51 5,979,229.88 544,069.19 5.71 -2,341.80 MWD(2) I 8,030.30 102.69 9.29 6,452.24 6,353.24 -1,736.48 3,479.66 5,979,258.70 544,074.18 5.88 -2,314.34 MWD(2) } 8,060.36 102.84 7.14 6,445.60 6,346.60 -1,707.47 3,483.85 5,979,287.73 544,078.21 6.99 -2,286.49 MD(2) , W 8,093.89 103.24 5.30 6,438.03 6,339.03 -1,674.99 3,487.39 . 5,979,320.22 544,081.57 5.48 -2,255.13 MWD(2) z 8,120.30 103.42 3.85 6,431.94 6,332.94 -1,649.38 3,489.44 5,979,345.84 544,083.49 5.39 -2,230.26 MWD(2) 8,150.67 103.23 2.07 6,424.94 6,325.94 -1,619.87 3,490.97 5,979,375.36 544,084.85 5.74 -2,201.46 MWD(2) il 8,180.36 102.09 0.50 6,418.43 6,319.43 -1,590.91 3,491.62 5,979,404.32 544,085.34 6.43 -2,173.05 MWD(2) ''/ 8,210.55 101.22 358.38 6,412.33 6,313.33 -1,561.34 3,491.33 5,979,433.88 544,084.89 7.46 -2,143.89 MWD(2) 8,240.41 101.41 356.96 6,406.48 6,307.48 -1,532.09 3,490.14 5,979,463.13 544,083.54 4.71 -2,114.87 MWD(2) 8,270.52 100.90 355.22 6,400.65 6,301.65 -1,502.62 3,488.12 5,979,492.58 544,081.37 5.92 -2,085.50 MWD(2) tt 8,300.53 101.01 352.39 6,394.95 6,295.95 -1,473.33 3,484.94 5,979,521.85 544,078.03 9.27 -2,056.10 MWD(2) 8,330.50 101.26 350.37 6,389.16 6,290.16 -1,444.26 3,480.54 5,979,550.89 544,073.47 6.67 -2,026.70 MWD(2) 8,360.11 100.73 348.83 6,383.51 6,284.51 -1,415.67 3,475.29 5,979,579.45 544,068 07 5.41 -1,997.64 MWD(2) g 8,390.28 97.92 348.07 6,378.62 6,279.62 -1,386.50 3,469.33 5,979,608.58 544,061.95 9.64 -1,967.88 MWD(2) t 8,420.44 95.84 346.71 6,375.01 6,276.01 -1,357.29 3,462.79 5,979,637.76 544,055.25 8.22 -1,937.97 MWD(2) 8,450.28 94.43 345.61 6,372.34 6,273.34 -1,328.43 3,455.68 5,979,666.57 544,047.99 5.98 -1,908.32 MWD(21 211912018 1:10:06PM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips ConocoPhillips Definitive Survey Report BAKER- HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) jj weft; 1G-11 North Reference: True Wellbore: '1G-11 Survey Calculation Method: Minimum Curvature Design: 1G-11 Database: E DM Alaska NSK Sandbox Survey MD Inc Am TVD'. '[VDSS +N1-S 41/44 NOM, DLS Vertical (off) (o) i') (off) (u ;(ems (USN Ne1lit) Fasting ('/100') Section Survey Tool Name Annotation t) (ft) (ft) 8,480 31 96.68 346.06 6,369.43 6,270.43 -1,299.45 3448.37 5,973695.51 544,040 52 7.64 -1,878.51 MWD(2) 8510 38 98.78 346.34 6,365.39 6,266.39 -1,270.52 3441.26 5,979,724.40 544033.26 7.04 -1,848.78 MWD(2) 8,540.30 101.00 346.54 6,360.25 6,261.25 -1,241.86 3,43435 5,979,753.01 544,026.19 745 -1,819.37 MWD(2) 8, 8,570.61 101.88 345.97 8354.24 6,255.24 -1,213.01 3,42729 5,979,781.83 544,018.98 344 -1,789.72 MWD(2) 8,600.91 101.65 344.77 6,348.06 6,249.06 -1,184.31 3,419.80 5,979,810.49 544,011.33 3.95 -1,760.16 MWD(2) t8,630.44 102.28 343.85 6,341.94 6,24294 -1,156.50 3,411.99 5,979,838.25 544,003.37 3.72 -1,731.41 MWD(2) z 8,660.42 10127 346.14 6,335.82 6,236.82 -1,128.15 3,404.39 5,979,866.55 543,995.62 8.20 -1,702.18 MWD(2) 14 j 8,690.44 100.79 348.55 6,330.07 6,231.07 -1,09940 3,397.94 5,979,895.26 543,989.01 8.04 -1,672.74 MWD(2) 8,720.40 99.07 350.62 6,324.91 6,225.91 -1,070.38 3,39260 5,979,92425 543,983.52 8.90 -1,643.24 MWD(2) 8,750.48 96.34 350.77 6,320.87 6,221.87 -1,040.97 3,387.78 5,979,95364 543,978.54 9.09 -1,613.43 MWD(2) 8,780.29 93.78 350.84 6,318.24 6,21924 -1,011.66 3,383.04 5,979,982.92 543,973.64 8.59 -1,583.75 MWD(2) 8,810.50 91.04 351.98 6,316.97 6,217.97 -981.81 3,378.53 5,980,012.73 543,968.97 9.82 -1,55357 MWD(2) 4, 8,840.56 88.16 353.00 6,317.18 6,218.18 -95202 3,374.60 5,980,042.50 543,96488 10.16 -1,52355 MWD(2) g j 8,870.78 86.71 353.87 6,318.54 6,219.54 -92203 3,371.15 5,980,072.47 543,961.27 5.59 -1,493.41 MWD(2) 18,900.54 85.42 355.55 6,320.58 6,221.58 -89246 3,368.41 5,980,102.02 543,958.37 7.11 -1,463.83 MWD(2) 8,930.54 85.51 353.70 6,322.95 6,223.85 -86269 3,365.61 5,980,131.77 543,955.41 6.15 -1,434.02 MWD(2) 8,960.36 86.93 352.55 6,324.92 6,225.92 -833.15 3,362.05 5,980,161.29 543,951.69 6.12 -1,404.31 MWD(2) I. 8,990.72 8499 353.22 6,327.06 6,228.06 -803.10 3,358.30 5,980,191.32 543,947.77 6.76 -1,37406 MWD(2) 9,025.70 85.79 354.21 6,329.87 6,230.87 -768.45 3,354.48 5,980,225.95 543,943.77 363 -1,339.27 MWD(2) geg 9,050.71 87.08 354.71 6,331.42 6,232.42 -74360 3,352.07 5,980,250.78 543,941.22 5.53 -1,314,39 MWD(2) ¢ 9,080.78 87.79 355.94 6,332.77 6,233.77 -713.66 3,349.63 5,980,280.70 543,938.61 4.72 -1,284.48 MWD(2) d) 9,110.84 88.19 357.79 6,333.82 6,234.82 -683.67 3,347.98 5,980,310.68 543,936.81 6.29 -1,254.65 MWD(2) 9,140.76 88.53 359.42 6,334.68 6,235.68 -653.77 3,347.25 5,980,340.57 543,935.92 5.56 -1,225.08 MWD(2) 9,170.84 88.28 1.32 6,335.52 6,236.52 -623.70 3,34745 5,980,370.64 543,935.95 6.37 -1,195.51 MWD(2) 1 9,200.69 86.90 286 6,336.77 6,237.77 -593.90 3,348.54 5,980,400.44 543,936.88 6.92 -1,166.34 MWD(2) 1 9,230.34 86.44 466 6,338.49 6,239.49 -56437 3,350.46 5,980,429.98 543,938.66 6.26 -1,137.60 MWD(2) i 9,260.67 86.13 6.81 6,340.46 6,241.46 -534.25 3,353.50 5,980,460.11 543,941.52 7.15 -1,108.47 MWD(2) 9,290.44 88.37 7.70 6,341.69 6,24289 -504.76 3,357.26 5,980,489.62 543,945.11 8.10 -1,080.07 MWD(2) 9,320.50 88.34 8.77 6,342.75 6,243.75 -475.02 3,361.56 5,980,519.38 543,949.25 3.56 -1,051.53 MWD(2) 1 9,350.31 88.56 10.56 6,343.56 6,244.56 -445.64 3366.56 5,980,548.78 543,954.10 6.05 -1,023.47 MWD(2) '.,',, 9 380 49 88 31 11 78 6,344 38 6,245 38 -416.05 3,372 41 5,980 578.40 543 959 78 4 12 995.34 MWD(2) 2/99/2018 1;10:06PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips aril ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc-Kup1 Local Co-ordinate Reference: Well 10-11 Project: Kuparuk River Unit TVD Reference: 10-11 @ 99.00usft(1G-11) f Site: Kuparuk 1G Pad MD Reference: 10-11 @ 99.00usft(1G-11) Well: 1G-11 North Reference: True Wellbore: 10-11 Survey Calculation Method: Minimum Curvature Design: 1G-11 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Az) TVD. TVDSS +N/-S +E/-W ILS Northing Easting Section Survey Tool Name Annotation 3 (usft)' 1°) (1 (usft) (usft) (usft) (usft) (ft) on (1/1000 (ft) .. 9,41067 8847 1281 6,34523 6,246.23 -386.57 3,378.83 5,980,607 91 543,966.04 3.45 -967.43 MWD(2) 9,440.62 88.01 13.91 6,34615 6,247 15 -357.45 3,385.75 5,980,637 07 543,972.80 3.98 -939.95 MWD(2) 9,470.65 88.50 14.57 6,347.06 6,248.06 -328.35 3,393.13 5,980,666.20 543,980.03 2.74 -912.58 MWD(2) s 9,500.23 88.43 15.32 6,347.86 6,248.86 -299.78 3,400.76 5,980,694.81 543,987.50 2.55 -885.77 MWD(2) 9,530.94 87.91 14.65 6,348.84 6,249.84 -270.13 3,408.69 5,880,724.50 543,995.27 2.76 -857.94 MWD(2) 9,560.92 88.00 12.72 6,349.91 6,250.91 -241.03 3,415.78 5,980,753.64 544,002.20 6.44 -830.51 MWD(2) 1 9,591.34 87.97 10.73 6,350.98 6,251.98 -211.26 3,421.96 5,980,783.44 544,008.22 6.54 -802.27 MWD(2) 9,623.19 88.59 10.57 6,351.93 6,252.93 -179.97 3,427.84 ' 5,980,814.75 544,013.93 2.01 -772.48 MWD(2) 9,655.00 88.62 8.55 6,352.71 6,253.71 -148.62 3,433.12 5,980,846.13 544,019.04 6.35 -742.51 MWD(2) 9,666.13 87.94 5.20 6,353.64 6,254.64 -117.73 3,436.85 5,980,877.04 544,022.60 10.98 -712.74 MWD(2) 9,716.05 88.62 4.38 6,354.54 6,255.54 -87.93 3,439.35 5,980,906.85 544,024.93 3.56 -683,83 MWD(2) I 9,745.90 88.62 4.33 6,355.26 6,256.26 -58.17 3,441.61 5,980,936.61 544,027.04 0.17 -654.92 MWD(2) f 9,775.84 89.14 4.94 6,355.84 6,256.84 -28.33 3,444.03 5,980,966.46 544,029.30 2.68 -625.95 MWD(2) I. 9,805.88 87.54 3.16 6,356.71 6,257.71 1.62 3,446.15 5,980,996.42 544,031.25 7.97 596.83 MWD(2) I9,841.11 88.28 3.54 6,358.00 6,259.00 36.76 3,448.21 5,981,031.57 544,033.12 2.36 -562.57 MWD(2) 9,870.16 89.05 272 6,358.68 6,259.68 65.76 3,449.79 5,981,060.57 544,034.55 3.87 534.29 MWD(2) 1 9,900.69 87.70 358.99 6,359.54 6,260.54 96.27 3,450.25 5,981,091.08 544,034.84 12.99 -504.32 MWD(2) 4. 9,930.42 88.25 359.40 6,360.59 6,261.59 125.98 3,449.83 5,981,120.78 544,034.26 231 -474.99 MWD(2) I 9,960.67 84.68 358.15 6,362.46 6,263.46 156.16 3,449.19 5,981,150.96 544,033.45 12.50 -445.16 MWD(2) £ 9,990.41 82.99 353.48 6,365.65 6,266.65 185.64 3,447.03 5,981,180.42 544,031.14 16.61 -415.75 MWD(2) 10,020.62 84.56 349.84 6,368.93 6,269.93 215.34 3,442.68 5,981,210.10 544,026.62 13.06 -385.74 MWD(2) 9 10,050.58 85.45 344.86 6,371.54 6,272.54 244.46 3,436.14 5,981,239.18 544,019.93 16.82 -355.94 MWD(2) 10,080.38 87.76 343.39 6,373.30 6,274.30 273.07 3,428.00 5,981,267.74 544,011.64 9.18 -326.35 MWD(2) 10,109.32 91.23 341.19 6,373.56 6,274.56 300.63 3,419.20 5,981,295.25 544,002.69 14.20 -297.68 MWD(2) 10,140.54 95.84 340.35 6,371.63 6,272.64 330.04 3,408.94 5,981,324.61 543,992.27 15.01 -266.93 MWD(2) I 10,170.59 99.62 337.59 6,367.59 6,268.59 357.83 3,398.26 5,881,352.33 543,981.44 15.53 -237.71 MWD(2) y 10,200.51 95.96 33246 6,363.54 6,264.54 384.68 3,385.75 5,981,379.12 543,968.78 20.93 -209.09 MWD(2) 11 0,230.50 92.73 329.19 6,361.26 6,262.26 410.79 3,371.17 5,981,405.14 543,954.07 15.30 -180.85 MWD(2) 10,26040 92.49 324.37 6,359.90 6,260 90 435.77 3,354.81 5,981 430.02 543,937.57 1612 153 41 MWD(2) 10,29014 92.70 319.28 6,358.55 6,259 55 459.11 3,336.46 5 981 453.27 543,919.09 17.11 127 23 MWD(2) 10,320 43 9486 314.38___6256 56 6,257 56 481.15 3,315.79 5,981,475.19 543890 31 1265 -101 94 MWD(2) 211912016 5:10:06PM Page S COMPASS 5000.1 Build 74 • • ConocoPhillips Ell BAKER ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc.-Kupl Local Coordinate Reference: Well 1G-11 Project: Kuparuk River Unit ND Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usfl(10-11) Well. 10-11 North Reference: True Wellborn: 10-11 Survey Calculation Method: Minimum Curvature Design: 1G-11 Database. EDM Alaska NSK Sandbox Survey MD Inc Azi ND rt/DSS .,•81/-S ,Er-V9Map DLS Vertical(usft) (°) (°) (usft) (usft) (usft) (usft) NorN9? 1 �.,��, Fasting ('M00') SeM IS Survey Tool Name Annotation f19) (ft) (ft) 10345.04 94.12 309.52 635463 6,25563 497.55 3,297.55 5,981,491 49 543,879 98 19.92 -82.63 MWD(2) 10,385 00 94.12 309.52 6351 76 6,252.76 522.91 3,266 80 5,981,516.68 543,849 10 0.00 -52.31 PROJECTED to TD 2!99/2016 1:10:06PM Page 6 COMPASS 5000.1 Build 74 RECEIVED R 2 1 60 09 MAR 0 9 2016 Z 6 AOGCC Letter of Transmittal ring BAKER Date: DATA LOGGED 3 /2016 HUGHES March 8, 2016 K BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1G-11B (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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'71 0^ v } ) 2 ) k \ _ = z > 2 C CL CL , . . o - » + • 0 Y 2 2 2 ,- 3 \ ° ° 2 \ S 0 C k \ oCO - Uo a - k = = - [ ` CO ) \ . o n. a f J / Q \ 0 0 RECEIVES1110 1 6 0 o 9 I*U FEB 2 9 2016 PRINT DISTRIBUTION LIST 2 6 8 6 7 BAKER A HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED WELL NAME 1G-11B 700 G Street. /2016M.K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE February 17,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE February 26,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #ur F'HIN i 5 #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I 0 1 0 I 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 I 0 I 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 I 1 I 1 I I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 I 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 Q, • 0 O Q to co to CNSI CN IP 110 II Z LI SO -112 az Ca 01 T 0 ES CC iv- O.O. 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(� I� OD N W W O O O '- '- '- N N N N M . O Q. . . ap rn of of of 0i ai of m rn a of of of o m of oS m a of ai o 0 0 0 0 0 0 0 0 0 0 l 0 E m = w Z . • is __ . , , , , , , ,... , ,„,,.,„, , ,,4,,,,,,„,.t„,„„,.., ,,. . , ,;,,,,,,,,,,,,‘,..,, , W.11111 � ,,,...m ,, ,,,,,,,,,,_.„.„, . h ,..0 o ra o c Q O U if ij Li., -1 a 1 M woo, e t0 M e.m LL'l o - 8 Li s r I w w y '§ T` rn o 3 o o Z 4 0 $ of o g - rn rn U CO d v°.- 8 ch © 0 E `0 d E 2 IT o � of of ice . O NQ cum S g'_v_ Oij rn Cv. m 0 w f c9 4CJ c M 2 Z N O 4 13 V N Z , { v N0 g. NN i , N) r- om c s m Y N , gg N N Q "C i t 0) 0) ° QN d 1 (r N L w 0 ao Y N to 1 U Y Y C7 0. C7 P... rn rn A p co • 1., OF T • e\l7,�s THE STATES Alaska Oil and Gas LAsKA. ;wd�-9a of /� Conservation Commission 333 West Seventh Avenue :__ - Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 Op,A �� LASFax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-11B ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-009 Surface Location: 327' FSL, 806' FWL, SEC. 29, T12N, R10E, UM Bottomhole Location: 4544' FNL, 1397' FEL, SEC. 29, T12N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 76)61- 7 Cathy P Foerster Chair DATED this day of January, 2016. RECEIVED • STATE OF ALASKA • JAN 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Dis ❑ 1c.Specify if well is proposed for Drill El Lateral ❑ Stratigraphic Test ❑ Development-Oil 0. Service- Winj ❑ Single Zone 0 . Coalbed Gas ❑ Gas Hydrates ❑ Redrill 0• Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0, Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska Inc ` Bond No. 59-52-180 • KRU 1G-11B 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: • 10303 TVD: • 6389 Kuparuk River Field/ 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk Oil Pool Surface: 327'FSL,806'FWL,Sec.29,T12N, R10E, UM - ADL 25640 Top of Productive Horizon: 8. Land Use Permit 13.Approximate Spud Date: 1559'FNL, 1256'FEL,Sec.32,T12N,R10E, UM 2571 3/1/2016 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 4544'FNL, 1397'FEL,Sec.29,T12N,R10E, UM 2459 20200' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL(ft): ' 99 15. Distance to Nearest Well Open Surface: x-540585 • y- 5980976 • Zone-4 • GL Elevation above MSL(ft): • 63 to Same Pool: 1G-14, 1040 16.Deviated wells: Kickoff depth: • 7614 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 102 degrees Downhole: 2898 • Surface: 2267 - 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) 3" 2.375" 4.7# L-80 ST-L 2416 7580 6388 10303 6389 slotted liner 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): 10533 6455 7831 10030 6481 none Casing Length Size Cement Volume MD TVD Conductor/Structural 68' 16" 212 sx CS II 106' 106' Surface 2314' 10.75" 930 sx AS III,250 sx ASI 2351' 2206' Production 8151' 7" 610 sx Class G,250 sx ASI 8188' 6901' Liner 2355' 2.375" 10030' 6481' Perforation Depth MD(ft): 7540-7590,7676-7722,7945-7950, Perforation Depth TVD(ft): 6355-6397,6469-6507,6694-6698,6706-6725 7960-7982 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Cody Pohler @ 265-6435 Email Cody.J.Pohleranconocophillips.com Printed Name . enhaus Title CTD Engineering Supervisor91,7 W P Signature , II Phone 263-4372 Date 1"— /LI — i ' Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: l( — OO 50- op- a 1 O -a2 --Qc. Date: t [a.a.I 1(p 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: Other: eep t-,-/- -fz .D£7C7 p 5 i Samples req'd: YesNo 2( Mud log req'd:Yes❑ No[i. inn via r pre-V V Pr.- try t to 2 5-00p measures: Yes[ No❑ Directional svy req'd:Yes C( No❑ z. Spacing exception req'd: Yes❑ No[Qi/ Inclination-only svy req'd:Yes❑ No[ Post initial injection MIT req'd:Yes❑ No Et APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:/ 22—/co v f 2i/i� Submit Form and Form 10-401(Revised 11/2015) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate ORIGINAL i ØØJ ,,,,6 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 13, 2016 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application to drill one sidetrack out of the KRU 1G-11A using the •coiled tubing drilling rig, Nabors CDR2-AC. Drilling operations are scheduled to begin in March 2016. The objective is to abandon the 1G-11A sidetrack and drill the 1G-11B sidetrack targeting the Kuparuk C3/4 sands. Attached to this application are the following documents: — 10-401 Application for KRU 1G-11B — Detailed Summary of Operations — Directional Details for 1G-11 B — Current schematic — Proposed CTD schematic — 10-403 Application to plug KRU 1G-11A for redrill If you have any questions or require additional information please contact me at 907-263-4172. Sincerely, CS61);PC44‘- Cody Pohler ConocoPhillips Alaska Coiled Tubing Drilling Engineer • i Kuparuk CTD Laterals NABORtSA\LA$KA 1G-11B CIJ `°°° "" Application for Permit to Drill Document AC 1. Well Name and Classification 1 2. Location Summary 2 3. Blowout Prevention Equipment Information 2 4. Drilling Hazards Information and Reservoir Pressure 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AA C 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AA C 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AA C 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AA C 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AA C 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AA C 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 6 (Requirements of 20 AAC 25.402) 6 17. Attachments 6 Attachment 1: Directional Plans for 1G-11B 6 Attachment 2: Current Well Schematic for 1G-11A 6 Attachment 3: Proposed Well Schematic for 1G-11B 6 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) Page 1 of 6 1/13/2016 S S PTD Application: 1G-11B The proposed 1G-11B sidetrack described in this document will be classified as a"Development—Oil' well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 1G-11B will target the C3/4 sand packages in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1G-11B. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the maximum formation pressure in the area of 2898 psi in the 1H-08,the maxis ium potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 2267 psi.v See the"Drilling Hazards Information and Reservoir Pressure" section for more details. 4 Q 0?`') — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure g %z (Requirements of 20 AAC 25.005(c)(4)) 2 •d $ t Reservoir Pressure and Maximum Expected Downhole Pressure ilvv`A •cf 17 A static bottom hole pressure of 1G-11 C sand in September 2015 indicated a reservoir pressure of 2775 psi or 8.3 ppg equivalent mud weight/The maximum down hole pressure in the 1G-11 pattern is at 1H-08 with 2,898 --'- psi. It is not expected that the 1G-11 reservoir pressure will be as high as 1H-08 since we are drilling north; closest point is 3500' away. In the northern fault block the maximum formation pressure in the area of 2890 in 1 H-03, the maximum potential surface pressure would be 2250 psi. The closest we drill towards 1H-03 is 1900'. Potential Gas Zones • No specific gas zones will be drilled. Gas injection has been performed on 1G pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems Exposed shale while drilling the 1G-.),1 laterals, especially at fault crossings, has the potential to cause hole problems. Managed pressure drillingequipment will be used to keep pressure on the well bore to minimum of 11.8 ppg, which has historically kept shale sections stabilized at Kuparuk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A-Thru-tubing drilling operations are not required to perform formation integrity tests. Page 2 of 6 January 13, 2016 • S PTD Application: 1G-11B 6. Casing and Cementing Program (Requirements of 20 AA C 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2%', 4.7#, L-80, ST-L slotted liner; 1G-11B 7,580' 10,303' 6,388' 6,389' with a shorty deployment sleeve. Optionally a liner top packer and a swell packer pending geology. Existing Casing/Liner Information Category OD Weight Grade Conn. Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 38' 106' 38' 106' 1640 630 Surface 10-3/4" 45.5 J-55 BTC 37' 2,351' 37' 2,206' 3580 2090 Casing 7" 26 J-55 BTC 37' 8,188' 37' 6,901' 7240 5410 Tubing 31/2" 9.3 L-80 EUE8Rd mod 31' 7,366' 37' 6,212' 6990 7400 CTD Liner 2-3/8" 4.7 L-80 ST-L 7,625' 10,030' 6,426' 6,482 11780 11200 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A-A diverter system is not required for through-tubing drilling operations. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Sodium chloride weighted FloVis water-based mud (8.9 ppg) • — Drilling operations: Sodium chloride weighted FloVis water-based muc''(8.9 ppg). This mud weight will • hydrostatically overbalance the reservoir pressure. — Completion operations: Liner running operations will be done with 11.8 ppg sodium bromide weighted completion fluid to maintain well bore stability during completion operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the coiled tubing stripper and MPD choke which are not part of the BOP equipment but are tested to the same pressure and frequency as the BOPE as detailed in section 3 "Blowout Prevention Equipment Information". The targeted MPD BHP will be 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 January 13,2016 S PTD Application: 1G-11B Pressure at the 1G-11B Window(7614' MD, 6417' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off C-sand Formation Presse(:.3 ppg) 2775 psi 2775 psi Mud Hydrostats. (9.1 ..g) 2970 psi 2970 psi • Annular friction (i.e. 9, 1.090 psi/ft) 685 psi 0 psi Mud + ECD Combined 3655 psi 2970 psi (no choke pressure) (over balanced (over balanced —881 psi) —195 psi) Target BHP at Window(11.8 ppg) 3938 psi 3938 psi • Choke Pressure Required to Maintain 283 psi 968 psi • Target BHP 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 for a land-based 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)) Summary of Operations Background KRU 1G-11B will be a single lateral producer. The 1G-11A CTD sidetrack was drilled in the summer 2015 but production has been disappointing. The objective is to abandon the 1G-11A sidetrack and drill one • lateral north of a major E-W fault to develop the C3/4 sand in the area. • 1G-11A sidetrack will be abandoned via a cast iron bridge plug(CIBP)set at 7650' MD in the 3'/2" completion above the window exit depth of 7660' MD. There is insufficient room to place cement as required by regulation, so ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to abandon the 1G-11A sidetrack in this manner. 1G-11B will kick off in the C2 sand via a 2 string cemented window exit. The well bore will drop into the . C1 before turning up to acquire the C3/4 interval. The well will be geo-steered in pay until TD at 10,303' MD. The lateral will be completed with 23/8" slotted liner with the liner top set inside the window at 7,609' MD. Page 4 of 6 January 13,2016 • • PTD Application: 1G-11 B • Pre-CTD Work • Slickline: Dummy all GLMs. Pull the 31/4" KB liner-top packer at 7625 MD • E-line: Chemical cut the 23/8"liner at 7662' MD • Slickline: Pull and lay down the 37' of 23/s" liner fish • E-line: Set CIBP for 3%"liner at 7650' MD. Pressure test CIBP. • E-line: Set a 3'/2" monobore whip-stock at 7,614' MD at high-side orientation CTD Rig Work • 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16"BOPE, test. 2. 1G-11B Sidetrack(C3/4 sand-North) i. Mill 2.80"window at 7,614' MD ii. Drill 2.70" x 3.00" bi-center lateral to TD of 10,303' MD iii. Run 2%"slotted liner with deployment sleeve from TD up to 7,609' MD 1. Optionally a liner top packer and a swell packer pending geology 3. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-CTD Work 1. Pull BPV 2. Obtain static BHP. 3. Put back on production Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. • If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures ✓ there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Page 5 of 6 January 13,2016 S • PTD Application: 1G-11B Liner Running — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. — The 1G-11 CTD sidetrack will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this 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 (1R-18 or 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. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. • — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) LatterarName Df t'artcemu 1G-11B 19,950' — Distance to Nearest Well within Pool (measured to offset well) 1G-11B 990' 1 G-10BL2 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A— 1G-116 is intended as a production well. • 17. Attachments Attachment 1: Directional Plans for 1G-11B Attachment 2: Current Well Schematic for 1G-11A Attachment 3: Proposed Well Schematic for 1G-11B Page 6 of 6 January 13, 2016 • H � _ I• p tai - .... xw mss' , o c5 c5 tx� - _. .......... _ _ o • • , o ` m o m •• �@ �� • LL 3, f S ( Owe d ' LLK¢¢K o •< ii • • 4- -_ ._----- _..___. ___ _ ___ -...- ..__...__ _ . _-_-_ ......._ _ p R• < < , < O O O R p 8 v Uco te'm C7 I J < 1 ~ $� C7 �: r B1yU _ W M O =e 1 . e� J • 3 ( 1 - M W O . w °. nl o �,, M D u 6'90. � $ N m f �t 'gypo m • N a • rm mo- • t . r... W • J • • N � 3 ...r:... ,.., • • 21 .'a a a O s g 1. 1 .. ^ r.-6 -�< 1 0t o •• ••'t' 0,F.,- .1, -----........7.:„.. ir...... .........._ :: .• . : : •.,_,,,,) 2 tal .C4 V4.'Y 1 • n Rid kith. A I , ' � gs .� a C7 c !--..7 ., 0, FA 2 .: .._, 8 o p S tad' 1O O Op 0. ',„,-;,op --ce - p. O o o 0 O o o o h O OO 0 0p O� O OF .-: -SY i Cio t-o Wi N N .-. a N N d V V d' U - -' - (u?/13sn oSZ)(+)ya.zoN/(-)91noSN a 7 U r • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-11 1G-11B Plan: 1G-1 1 B_wp03 111111011111111111140 Standard Planning Report 12 January, 2016 A011,1,111,1,101,4„9,111 le 1 11111 F;7100-F,11; 1,4111111111,101 1111 BAKER 1 HUGHES • • /grill ConocoPhillips Planning Report BAKER HUGHES a.,r;;.,. EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 ConocoPhillips(Alaska)Inc -Kup1 TVD Reference;:'..'.41:%P:',1-',..4,-..,,,,,-;, Mean Sea Level -..:(::„.:1-1,- r_7,--=-7Kuparuk River Unit MD Reference: i:° 1G-11 @ 99.00usft(1G-11) Kuparuk 1G Pad North Reference: True _1G-11 Sury !; i r Minimum Curvature • 1G-11B '.1G-11B_wp03 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 I11:,1;-•„ ; Ku�aruk 1G Pad �,iii aaw�r�� jai iii a miaiNnN a a..»ate, '- P . Site Position: Northing: 5,981,540.78 usft Latitude: 70°21'37.826 N From: Map Easting: 540,089.12 usft Longitude: 149°40'27.705 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.31 ° Well 1G-11 Well Position +N/-S 0.00 usft Northing: 5,980,976.13 usft , Latitude: 70°21'32.246 N +E/-W 0.00 usft Easting: 540,585.50 usft , Longitude: 149°40'13.280 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft 111111 !NINA not"manaammMINIIIiemaimimimimleaeia.,_ anmmnummaN14,= amore 1G-11B asig------ noucs Model Name ,x, •te.Date Deci :,4-L.7.-,..r.„11. �i !,-:.,11,,,,,i,,. BGGM2015 3/1/2016 18.61 80.99 57,496 9 _ 1G-1113 wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,600.00 f I IIII p'" E/-W Direction �� ���i�., ,l.- .° usft) (°) 0.00 0.00 0.00 350.00 Page 2 COMPASS 5000.1 Build 61 i 0 . ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: 0111 , Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11B Design: 1 G-11 B_wp03 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +EI-W Rate Rate Rate TFO (usft) ,, (°) (0) (usft) (usft) (usft) (°1100ft) i 'r r_1.0,¢t) (^ ��zz, Target i'll, P oll1 ,i 7,600.00 33.47 128.40 6,306.23 -1,880.13 3,219.15 0.00 0.00 0.00 0.00 7,614.00 33.54 128.33 6,317.90 -1,884.93 3,225.21 0.57 0.50 -0.50 -28.93 7,639.00 43.54 128.33 6,337.43 -1,894.57 3,237.42 40.00 40.00 0.00 0.00 7,669.00 56.87 125.56 6,356.59 -1,908.35 3,255.83 45.00 44.44 -9.25 350.00 7,699.00 68.21 117.26 6,370.42 -1,922.10 3,278.53 45.00 37.78 -27.64 325.00 7,729.00 75.37 105.20 6,379.82 -1,932.33 3,305.04 45.00 23.87 -40.20 300.00 7,799.00 84.66 74.59 6,392.24 -1,931.95 3,373.04 45.00 13.27 -43.73 284.00 7,869.00 102.21 48.29 6,387.98 -1,899.09 3,433.71 45.00 25.08 -37.58 304.00 7,939.00 101.43 16.09 6,373.27 -1,841.92 3,469.66 45.00 -1.12 -45.99 272.00 8,249.00 101.72 353.94 6,310.31 -1,541.43 3,496.07 7.00 0.09 -7.15 273.00 8,529.00 101.70 333.92 6,252.92 -1,279.42 3,420.59 7.00 -0.01 -7.15 272.00 8,629.00 100.17 340.88 6,233.94 -1,188.84 3,382.90 7.00 -1.54 6.96 102.00 8,783.32 90.00 344.55 6,220.28 -1,042.27 3,337.32 7.00 -6.59 2.38 160.00 8,933.32 84.77 353.67 6,227.13 -895.34 3,309.03 7.00 -3.49 6.08 120.00 9,233.32 87.97 14.47 6,246.32 -598.39 3,330.25 7.00 1.07 6.93 82.00 9,433.32 88.27 0.46 6,252.91 -400.69 3,356.16 7.00 0.15 -7.00 271.00 9,933.32 88.59 325.45 6,267.05 69.76 3,211.94 7.00 0.06 -7.00 270.00 10,303.32 84.37 351.06 6,290.15 409.78 3,076.14 7.00 -1.14 6.92 100.00 Page 3 COMPASS 5000.1 Build 61 • • rails ConocoPhillips Planning Report BAKER HUGHES illbatabase: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 Mean Sea Level a'. •'ect: Kuparuk River Unit1 G-11 @ 99.00usft(1G-11) Kuparuk 1G Pad -eferen6e True 1G-11od; Minimum Curvature (:, 1G-11B _ Iild11li lulalllbIAi �luI11101l1( II mn1G-u1B_wp03 � j„ 1 °,) pr ,uammm MN UNarommmMEMNmmiimuimMim mavrNUWWWUriiiiiiiiI ; i _ m ,MD^WW,iiMM W4,, iii n 16,roiirAM nii , ,,,,g1I iiia iii fpm,,OMMiiiiiiiiiiipiiiiiiiiiii@it;iiiiI ,, k E 2 t (l 1k E)� iII (1110Eg4 1 i liiliia 1�l 1411 1 k ir 1p I1� i � 1 ,1 w 1a - , 1yk �� aV, '', u , � ,, ",,, ,,,, VR � � r Ver cal!-="-T_ Dogleg T�ce 'Ma ® lination Azimuth System +N/-S +E1 $eco Ash 'r sting (°} t (11°I° 4100 (usf# ' °il'i���i�31�ii�� E 910111 l l $W{uMfli` i1 7,600.00 33.47 128.40 6,306.23 -1,880.13 3,219.15 -2,410.57 0.00 0.00 5,979,113.66 543,814.48 TIP 7,614.00 33.54 128.33 6,317.90 -1,884.93 3,225.21 -2,416.34 0.57 -28.93 5,979,108.89 543,820.56 KOP 7,639.00 43.54 128.33 6,337.43 -1,894.57 3,237.42 -2,427.96 40.00 0.00 5,979,099.31 543,832.82 End 40 dls,Start 45 dls 7,669.00 56.87 125.56 6,356.59 -1,908.35 3,255.83 -2,444.73 45.00 -10.00 5,979,085.64 543,851.30 4 7,699.00 68.21 117.26 6,370.42 -1,922.10 3,278.53 -2,462.21 45.00 -35.00 5,979,072.01 543,874.08 5 7,700.00 68.43 116.85 6,370.79 -1,922.52 3,279.36 -2,462.77 45.00 -60.00 5,979,071.59 543,874.91 7,729.00 75.37 105.20 6,379.82 -1,932.33 3,305.04 -2,476.89 45.00 -59.85 5,979,061.92 543,900.64 6 7,799.00 84.66 74.59 6,392.24 -1,931.95 3,373.04 -2,488.32 45.00 -76.00 5,979,062.68 543,968.63 7 7,800.00 84.91 74.22 6,392.33 -1,931.68 3,374.00 -2,488.22 45.00 -56.00 5,979,062.95 543,969.58 7,869.00 102.21 48.29 6,387.98 -1,899.09 3,433.71 -2,466.50 45.00 -55.97 5,979,095.85 544,029.11 8 7,900.00 102.33 34.01 6,381.36 -1,876.35 3,453.58 -2,447.55 45.00 -88.00 5,979,118.71 544,048.86 7,939.00 101.43 16.09 6,373.27 -1,841.92 3,469.66 -2,416.44 45.00 -91.05 5,979,153.21 544,064.75 End 45 dls,Start 7 dls 8,000.00 101.62 11.74 6,361.08 -1,783.92 3,484.03 -2,361.82 7.00 -87.00 5,979,211.29 544,078.81 8,100.00 101.79 4.59 6,340.76 -1,687.07 3,497.94 -2,268.85 7.00 -87.87 5,979,308.21 544,092.18 8,200.00 101.79 • 357.44 6,320.30 -1,589.26 3,499.68 -2,172.83 7.00 -89.32 5,979,406.01 544,093.39 8,249.00 101.72 353.94 6,310.31 -1,541.43 3,496.07 -2,125.10 7.00 -90.79 5,979,453.82 544,089.53 10 8,300.00 101.82 350.29 6,299.91 -1,491.98 3,489.23 -2,075.22 7.00 -88.00 5,979,503.22 544,082.42 8,400.00 101.88 343.14 6,279.34 -1,396.80 3,466.76 -1,977.58 7.00 -88.74 5,979,598.27 544,059.44 8,500.00 101.77 335.99 6,258.82 -1,305.15 3,432.61 -1,881.39 7.00 -90.21 5,979,689.73 544,024.80 8,529.00 101.70 333.92 6,252.92 -1,279.42 3,420.59 -1,853.97 7.00 -91.68 5,979,715.38 544,012.64 11 8,600.00 100.63 338.87 6,239.17 -1,215.62 3,392.71 -1,786.29 7.00 102.00 5,979,779.03 543,984.42 8,629.00 100.17 340.88 6,233.94 -1,188.84 3,382.90 -1,758.21 7.00 102.96 5,979,805.76 543,974.46 12 8,700.00 95.49 342.58 6,224.27 -1,122.06 3,360.86 -1,688.62 7.00 160.00 5,979,872.40 543,952.06 8,783.32 90.00 344.55 6,220.28 -1,042.27 3,337.32 -1,605.96 7.00 160.23 5,979,952.06 543,928.09 13 8,800.00 89.42 345.56 6,220.36 -1,026.16 3,333.02 -1,589.34 7.00 120.00 5,979,968.15 543,923.71 8,900.00 85.93 351.64 6,224.43 -928.27 3,313.28 -1,489.52 7.00 119.99 5,980,065.91 543,903.43 8,933.32 84.77 353.67 6,227.13 -895.34 3,309.03 -1,456.34 7.00 119.75 5,980,098.82 543,899.01 14 9,000.00 85.44 358.31 6,232.82 -829.08 3,304.38 -1,390.29 7.00 82.00 5,980,165.04 543,894.00 9,100.00 86.49 5.24 6,239.87 -729.44 3,307.47 -1,292.70 7.00 81.60 5,980,264.69 543,896.55 9,200.00 87.59 12.17 6,245.03 -630.79 3,322.58 -1,198.17 7.00 81.12 5,980,363.41 543,911.12 9,233.32 87.97 14.47 6,246.32 -598.39 3,330.25 -1,167.59 7.00 80.76 5,980,395.85 543,918.62 15 9,300.00 88.06 9.80 6,248.63 -533.26 3,344.25 -1,105.88 7.00 -89.00 5,980,461.05 543,932.27 9,400.00 88.22 2.80 6,251.89 -433.98 3,355.21 -1,010.01 7.00 -88.84 5,980,560.38 543,942.69 9,433.32 88.27 0.46 6,252.91 -400.69 3,356.16 -977.39 7.00 -88.61 5,980,593.67 543,943.45 16 9,500.00 88.28 355.80 6,254.92 -334.09 3,353.99 -911.43 7.00 -90.00 5,980,660.25 543,940.92 9,600.00 88.31 348.79 6,257.90 -235.10 3,340.59 -811.62 7.00 -89.86 5,980,759.16 543,926.99 Page 4 COMPASS 5000.1 Build 61 • I ConocoPhillips Planning Report BAKER HUGHES Datati EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 G-11 Company: ' ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Weilbore: 1G-11B Design: 1 G-11 B_wp03 �s Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map DepthInclination Azimuth System +N/-S +E/-W Section Rate Azimuth • Northing Easting (usft) (°) (°) (usft) (usft) (usft) .(°/100ft) (0) 4 (usft) (us' iiia 9,700.00 88.36 341.79 6,260.80 -138.48 3,315.23 -712.06 7.00 -89.65 5,980,855.63 543,901.10 9,800.00 88.44 334.79 6,263.59 -45.67 3,278.27 -614.24 7.00 -89.45 5,980,948.23 543,863.65 9,900.00 88.55 327.79 6,266.22 41.95 3,230.27 -519.62 7.00 -89.25 5,981,035.58 543,815.18 9,933.32 88.59 325.45 6,267.05 69.76 3,211.94 -489.04 7.00 -89.07 5,981,063.29 543,796.70 17 10,000.00 87.78 330.05 6,269.17 126.11 3,176.39 -427.38 7.00 100.00 5,981,119.44 543,760.85 10,100.00 86.60 336.96 6,274.07 215.45 3,131.86 -331.67 7.00 99.85 5,981,208.52 543,715.84 10,200.00 85.47 343.89 6,280.99 309.38 3,098.45 -233.36 7.00 99.52 5,981,302.26 543,681.93 10,300.00 84.41 350.83 6,289.82 406.51 3,076.66 -133.92 7.00 99.04 5,981,399.27 543,659.61 10,303.32 ' 84.37 351.06 6,290.15 409.78 . 3,076.14 • -130.61 7.00 98.42 5,981,402.53• 543,659.08 ` Planned TD at 10303.32 Page 5 COMPASS 5000.1 Build 61 • ConocoPhillips Planning Report BAKER a __ . HUGHES r , moonmowin Database: EDM Alaska Sandbox Local Co-ordinate Reference:' Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference 1 Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11B Design: 1G-11 B_wp03 gig AgEll Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +NI-S +El-W Northing -Shape (°) (°) (usft) (usft) (usft) q Latitude Longitude 1G-11B_T01 0.00 0.00 6,394.00 -8,352.851,143,516.24 5,978,820.00 1,684,018.00 70°5'58.782 N 140°28'10.525 W -plan misses target center by 1140036.63usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Point 1G-11 CTD Polygon Nor 0.00 0.00 0.00 -8,462.31 1,143,229.62 5,978,709.00 1,683,732.00 70°5'58.143 N 140°28'19.168 W -plan misses target center by 1139768.19usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Polygon Point 1 0.00 0.00 0.00 5,978,709.00 1,683,732.00 Point2 0.00 152.40 114.83 5,978,862.00 1,683,845.99 Point 3 0.00 299.01 190.63 5,979,009.01 1,683,920.99 Point4 0.00 491.09 180.66 5,979,201.01 1,683,909.98 Point 5 0.00 646.33 137.48 5,979,356.00 1,683,865.96 Point6 0.00 810.71 71.36 5,979,520.01 1,683,798.96 Point7 0.00 1,047.03 16.62 5,979,756.00 1,683,742.95 Point 8 0.00 1,306.12 5.01 5,980,015.00 1,683,729.93 Point 9 0.00 1,591.94 44.55 5,980,301.00 1,683,767.92 Point 10 0.00 1,806.04 29.70 5,980,515.00 1,683,751.91 Point 11 0.00 2,089.89 -121.80 5,980,797.99 1,683,598.89 Point 12 0.00 2,271.27 -189.83 5,980,978.99 1,683,529.89 Point 13 0.00 2,409.48 -226.09 5,981,116.98 1,683,492.88 Point 14 0.00 2,480.37 169.33 5,981,190.01 1,683,887.87 Point 15 0.00 2,346.20 198.61 5,981,056.01 1,683,917.88 Point 16 0.00 2,240.89 254.06 5,980,951.01 1,683,973.89 Point 17 0.00 1,875.93 424.12 5,980,587.02 1,684,145.91 Point 18 0.00 1,542.79 444.33 5,980,254.02 1,684,167.92 Point 19 0.00 1,289.00 398.96 5,980,000.02 1,684,123.93 Point20 0.00 1,058.87 419.73 5,979,770.02 1,684,145.95 • Point 21 0.00 875.52 479.75 5,979,587.02 1,684,206.95 Point 22 0.00 650.03 567.55 5,979,362.03 1,684,295.96 Point 23 0.00 435.86 594.41 5,979,148.03 1,684,323.98 Point 24 0.00 83.13 536.51 5,978,795.03 1,684,268.00 Point 25 0.00 -84.77 327.58 5,978,626.01 1,684,060.00 Point26 0.00 -83.67 122.56 5,978,626.00 1,683,855.00 Point27 0.00 0.00 0.00 5,978,709.00 1,683,732.00 1G-11B_Fault2 0.00 0.00 0.00 -7,227.251,143,429.33 5,979,945.00 1,683,925.00 70°6'9.838 N 140°28'8.115 W -plan misses target center by 1139961.12usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Rectangle(sides W395.00 H1.00 D0.00) 1G-11 B_T05 0.00 0.00 6,237.00 -7,188.531,143,482.55 5,979,984.00 1,683,978.00 70°6'10.135 N 140°28'6.431 W -plan misses target center by 1139996.62usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Point 1G-11B_T06 0.00 0.00 6,261.00 -6,543.691,143,341.02 5,980,628.00 1,683,833.00 70°6'16.604 N 140°28'7.665 W -plan misses target center by 1139852.12usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Point 1G-118_704 0.00 0.00 6,220.00 -7,483.831,143,531.95 5,979,689.00 1,684,029.00 70°6'7.195 N 140°28'6.305 W -plan misses target center by 1140047.52usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Point 1G-11B_T02 0.00 0.00 6,315.00 -7,936.181,143,586.51 5,979,237.00 1,684,086.00 70°6'2.723 N 140°28'6.714 W -plan misses target center by 1140104.50usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Point 1G-11B_T07 0.00 0.00 6,297.00 -6,006.031,143,228.92 5,981,165.00 1,683,718.00 70°6'21.989 N 140°28'8.525 W -plan misses target center by 1139737.81 usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Point 1G-118_T03 0.00 0.00 6,253.00 -7,676.001,143,557.91 5,979,497.00 1,684,056.00 70°6'5.291 N 140°28'6.399 W -plan misses target center by 1140074.49usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Point Page 6 COMPASS 5000.1 Build 61 r ConocoPhillips Planning Report BAKER HUGHES Database: ��.� EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: I � 1G-11 @ 99.00usft(1G-11) 41711-10,11A.Site: Kuparuk 1G Pad North Reference: True Well: 1 G-11 Survey Calculation Method: Minimum Curvature Wellbore; 1G-118 Design: 1 G 11 B wp03 1G-11 CTD Polygon Sot 0.00 0.00 0.00 -8,468.51 1,143,266.59 5,978,703.00 1,683,769.00 70°5'58.029 N 140°28'18.141 W -plan misses target center by 1139805.19usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Polygon Point 1 0.00 0.00 0.00 5,978,703.00 1,683,769.00 Point2 0.00 286.79 230.57 5,978,991.01 1,683,997.99 Point 3 0.00 175.08 361.98 5,978,880.02 1,684,129.99 Point 4 0.00 0.73 423.05 5,978,706.02 1,684,192.00 Point 5 0.00 -242.03 373.74 5,978,463.02 1,684,144.01 Point6 0.00 -467.28 229.52 5,978,237.02 1,684,001.03 Point 7 0.00 -653.15 13.50 5,978,050.00 1,683,786.04 Point8 0.00 -797.46 -303.31 5,977,903.99 1,683,470.04 Point9 0.00 -826.66 -640.51 5,977,872.96 1,683,133.04 Point 10 0.00 -867.00 -949.76 5,977,830.95 1,682,824.04 Point 11 0.00 -1,035.86 -1,165.69 5,977,660.94 1,682,609.05 Point 12 0.00 -1,226.13 -1,305.73 5,977,469.93 1,682,470.06 Point 13 0.00 -1,378.75 -1,379.55 5,977,316.93 1,682,397.08 Point 14 0.00 -1,701.12 -1,503.30 5,976,993.93 1,682,275.09 Point 15 0.00 -1,898.75 -1,576.37 5,976,795.92 1,682,203.10 Point 16 0.00 -2,044.58 -1,612.15 5,976,649.92 1,682,168.11 Point 17 0.00 -1,972.43 -2,010.81 5,976,719.90 1,681,769.10 Point 18 0.00 -1,764.69 -1,957.69 5,976,927.90 1,681,821.09 Point 19 0.00 -1,574.21 -1,856.66 5,977,118.91 1,681,921.08 Point20 0.00 -1,383.83 -1,737.62 5,977,309.91 1,682,039.07 Point 21 0.00 -1,012.86 -1,537.61 5,977,681.92 1,682,237.05 Point22 0.00 -847.67 -1,383.71 5,977,847.93 1,682,390.04 Point23 0.00 -723.52 -1,223.02 5,977,972.94 1,682,550.04 Point 24 0.00 -592.96 -951.29 5,978,104.95 1,682,821.03 Point 25 0.00 -401.15 -353.19 5,978,299.98 1,683,418.02 Point26 0.00 -302.13 -168.64 5,978,399.99 1,683,602.02 Point27 0.00 -173.75 -49.94 5,978,529.00 1,683,720.01 Point28 0.00 -84.04 5.55 5,978,619.00 1,683,775.00 Point 29. 0.00 0.00 0.00 5,978,703.00. 1,683,769.00 1G-11B_Fault1 0.00 0.00 0.00 -7,947.361,143,619.45 5,979,226.00 1,684,119.00 70°6'2.566 N 140°28'5.823 W -plan misses target center by 1140155.02usft at 8200.00usft MD(6320.30 TVD,-1589.26 N,3499.68 E) -Rectangle(sides W400.00 H1.00 D0.00) , 1x+'!4$#1iF Oji'# �! { figiNFORIKKOLo, ,int =�:., =.:, ��. �MOUiimtitl Iii i .wa.F_. :_ 10,303.32 6,290.15 2 3/8" 2.375 3.000 Page 7 COMPASS 5000.1 Build 61 0 • ConocoPhillips Planning Report BAKER HUGHES Dara ',- ,,,IIMIWANIVAMOZWAME4M,' EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11B Design: 1 0-11 B_wp03 Plan Annotadons It Measured Vertical Local Coordinates _ , 11 ����p� pr�,�i1����i�l�, �Ip l, Depth Depth +NI-5 +E/-W W (usft) (usft) (usft) (usft) Comment I1,,,(14411;'1111,(111:1110 r 7,600.00 6,306.23 -1,880.13 3,219.15 TIP 7,614.00 6,317.90 -1,884.93 3,225.21 KOP 7,639.00 6,337.43 -1,894.57 3,237.42 End 40 dls,Start 45 dls 7,669.00 6,356.59 -1,908.35 3,255.83 4 7,699.00 6,370.42 -1,922.10 3,278.53 5 7,729.00 6,379.82 -1,932.33 3,305.04 6 7,799.00 6,392.24 -1,931.95 3,373.04 7 7,869.00 6,387.98 -1,899.09 3,433.71 8 7,939.00 6,373.27 -1,841.92 3,469.66 End 45 dls,Start 7 dls 8,249.00 6,310.31 -1,541.43 3,496.07 10 8,529.00 6,252.92 -1,279.42 3,420.59 11 8,629.00 6,233.94 -1,188.84 3,382.90 12 8,783.32 6,220.28 -1,042.27 3,337.32 13 8,933.32 6,227.13 -895.34 3,309.03 14 9,233.32 6,246.32 -598.39 3,330.25 15 9,433.32 6,252.91 -400.69 3,356.16 16 9,933.32 6,267.05 69.76 3,211.94 17 10,303.32 6,290.15 409.78 3,076.14 Planned TD at 10303.32 I Page 8 COMPASS 5000.1 Build 61 • • o • 0 • N ai • • • • • • r 1 I •• Q • S N Q • N 9 00 • 00 Q Q • • ^ N O •• • • MO •S :-- a (:� Q • p Q ^ O • .Ox o 9 00 O • c • Ua� W 7 ^ • .o • F1. oS c� _ • e roLOSHC-Jl5 • _o �a m-a o �L � : WIII(. • O 2 w Q • • • • 5PNE Q r[V Z 3 3 O . 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CO Co i-a000 c-NM V C1C01-00 ZO + c°,3 (u►/jsn 06)it;do It?oia ian anal V a • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-11 1G-11B 1 G-11 B_wp03 Travelling Cylinder Report 12 January, 2016 11111 116-4 IOW I E �=Gijil�G r' 1 BAKER HUGHES • • Baker Hughes INTEQ Nag ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: 1G-11 @ 99.00usft(1G-11) Reference Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.00 usft North Reference: True Reference Well: 1G-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1G-11B Database: OAKEDMP2 Reference Design: 1 G-11 B_wp03 Offset TVD Reference: Offset Datum Reference 1 G-11 B_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,600.00 to 10,303.32usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,220.43 usft Error Surface: Elliptical Conic Survey Tool Program Date 1/12/2016 From To ) l (usft) (usft) Survey(Wellbore) , Tool Name Description 100.00 7,600.00 1G-11 (1G-11) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,600.00 10,303.07 1 G-11 B_wp03(1G-11B) MWD MWD-Standard Casing Points', Measured Vertical Casing Hole 1 Depth Depth Diameter Diameter (rift) (usft) Name (..) (") 10,303.32 6,389.15 2 3/8" 2-3/8 3 Summary Reference Offset Centre to '''lip DisNo-Gotance Allowabl¢Deviation1 fi � 1.` Measured Measured Centre :` Wr`arning Sib! i Site#ame ) Depth Depth Distance (usft) from Plan i ili1 Pr. * a ' (usft) (usft) (usft) (usft) Kuparuk 1G Pad 1 G-09-1 G-09-1 G-09 Out of range 1G-10-1G-10-1G-10 Out of range 1G-10-1G-10A-1 G-10A Out of range 1G-10-1G-10B-1 G-10B Out of range 1G-10-1 G-10BL1-1 G-10BL1 Out of range 1G-10-1 G-10BL2-1 G-10BL2 10,303.32 8,950.00 990.95 211.82 779.80 Pass-Major Risk 1G-10-1 G-10BPB1-1 G-10BPB1 Out of range, 1G-11-1G-11-1G-11 7,624.98 7,625.00 0.42 1.33 -0.86 FAIL-Major Risk , 1G-11-1G-11A-1G-11A 7,624.98 7,625.00 0.42 1.07 -0.65 FAIL-Major Risk 1G-12-1G-12-1 G-12 Out of range 1G-12-1G-12L1-1G-12L1 7,890.00 11,360.00 627.07 185.38 457.06 Pass-Major Risk 1G-12-1G-12L1-01-1G-12L1-01 Out of range 1G-12-1 G-12L1-01 PB1-1 G-12L1-01 PB1 Out of range Offset Design Kuparuk 1G Pad- 1 G-10-1 G-10BL2-1 G-10BL2 onset site Error:W 0.00 use Survey Program: 95-BOSS-GYRO,6390-MWD.7481-MWD,7897-MWD Rule Assigned:Major Risk Offset Well Error:== 0D usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface t Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-w Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) ''- (P) (usft) (usft) (") (usft) (usft) (usft) 10,126.16 6,374.69 9,400.00 6,615.67 49.11 38.24 -123.02 -202.39 2,028.06 2-11/16 1,205 22 216.70 988.81 Pass-Major Risk 10,133.54 6,375.17 9,375.00 6,615.63 49.16 38.17 -122.67 -179.67 2,038.50 2-11/16 1,187.48 216.42 971.37 Pass-Major Risk 10,150.00 6,376.29 9,300.00 6,616.25 49.25 37.99 -121.96 -109.69 2,065.36 2-11/16 1,138.91 215.60 923.69 Pass-Major Risk 10,150.00 6,376.29 9,325.00 6,616.05 49.25 38.04 -121.85 -133.36 2,057.31 2-11/16 1,154.17 215.85 938.68 Pass-Major Risk 10,150.00 6,376.29 9,350.00 6,615.87 49.25 38.10 -121.73 -156.69 2,048.33 2-11/16 1,170.50 216.10 954.74 Pass-Major Risk 10,166.82 6,377.48 9,275.00 6,616.41 49.35 37.94 -120.97 -85.73 2,072.49 2-11/16 1,124.46 215.28 909.59 Pass-Major Risk 10,176.09 6,378.16 9,250.00 6,616.70 49.40 37.90 -120.46 -61.53 2,078.75 2-11/16 1,111.05 215.00 896.47 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/12/2016 2:30:30PM Page 2 COMPASS 5000.1 Build 74 • I ❑ M M un 0 O O V ❑ 0 F- 0 Q II C N n E d N y W p a 2 ❑ t a 2 -- m o Lo ❑ n II M { a II' to m 0 a _ c rl - c m 3 N ❑ 14/111 Lr) co m E 2 N £ 2 =o n it '-E� N N t0 NLn i ❑ ❑ C ❑ Cl -"E'"O w00 co <N9 mj r Y 0I m ❑ W E O II E C 00 v U a ) 2 a < . 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VA Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-11A.1/14/2016 11 01 53 AM SSSV:NONE 100 12/16/2013 Last WO: 40.99 9/19/1983 Vertical schematic(actual) Annotation Depth IRKS) End Date Annotation last Mod By End Date HANGER;312 I�:tir o Last Tag: Rev Reason:ADD PACKER TO SCHEMATIC lehallf 1/8/2016 lasing Strings I, r I Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 k I',I' CONDUCTOR 16 15.250 38.0 106.0 106.0 65.00 H-40 WELDED Casing Description OD(in) ID in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 10����I iiii SURFACE (in) 9.950 37.0 2,3588KB)3 2,)TVD).. 45.50G..J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...Wt/Len p...Grade Top Thread CONDUCTOR;38.0-106.0 . PRODUCTION 7 6.276 37.1 8,187.7 6,521.5 26.00 J-55 BUTT Casing Description OD(in) SID(in) Top(MB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread I A LINER 2 3/8 1.992 7,625.8 10,030.0 6,481.7 4.60 L-80 ST-L Liner Details SURFACE;37.1-2,351.3 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) MI GAS LIFT;2,7262 7,625.8 6,426.7 33.59 SBR BAKER SBR DEPLOYMENT SLEEVE 2.250 I ..I 7,739.2 6,504.4 63.02 XO Reducing Crossover Pup 2 3/8",4.6 ppf,L-80 X 2 1/6",3.35 1.751 ppf,L-80 Hyd511 bxp gal 7,744.5 6,506.7 64.16 SWELL HALLIBURTON SWELL PACKER,WATER MEDIUM 1.751 GAS LIFT;4,148..1 _ PACKER I . I 7,759.7 6,512.7 69.93 XO Enlarging Crossover Pup 2 1/6",3.25 ppf,L-80 X 2 3/8",4.6 1.751 ppf,L-80,Hyd511 bxp GAS LIFT;5,320.5 8,752.4 6,481.8 97.47 OPEN HOLE OPEN HOLE 3.000 ME I 8,776.4 6,478.8 96.69 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.920 Tubing Strings GAS LIFT,6,185.3 Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-WO 2015 3 1/2 2.992 31.2 7,366.3 6,211.7 9.30 L-80 EUE8rd mod lit! Completion Details GAS LIFT;6,832.4Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) FIR. ' 31.2 31.2 0.00 HANGER CIW TUBING HANGER 2.992 7,227.5 6,098.8 35.87 LOCATOR LOCATOR SUB 2.990 GAS LIFT;7,171.67,228.5 6,099.6 35.87 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 7,235.8 6,105.5 35.85'PBR BAKER 80-40 PBR 4.000 7,258.3 6,123.8 35.81 PACKER BAKER FHL RETRIEVALBE PACKER 2.910 LOCATOR;7,227.5 SEAL ASSY;7,228.5 _ 7,311.1 6,166.7 35.63 NIPPLE CAMCO DS NIPPLE(PULLED RHC AND BALL AND 2.812 P8R;7,235.8 ROD,4 15 15) PACKER;7,258.3 7,359.8 6,206.3 35.23 OVERSHOT POOR BOY TUBING OVERSHOT 3.750 iMI .111 Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt Ib/ft) Grade Top Connection AB TUBING-ORIGINAL 41/2 2.992 7,3613 7,841.2 6,523.3 9.20 J-55 FL4S NIPPLE;7,311.1 IITabing -" Completion Details fiE Nominal ID OE Top(ftKB) Top(ND)(ftKB) Top Incl I) Item Des Corn (in) 1111 7,376.2 6,219.7 35.10 SBR OTIS SBR(2.81"X NIPPLE PROFILE) 2.813 OVERSHOT;7,358.8 Er 7,402.3 6,241.2 34.87 PACKER OTIS RRH PACKER 2.970 7,541.7 6,356.6 33.56 BLAST BLAST RINGS(3) 2.992 SBR;7,376.2 - RINGS PACKER,7,402.3 - 7,657.2 6,4529 33.75 BLAST BLAST RINGS(3) 2.992 RINGS PRODUCTION;7,4377 7,812.7 6,522.3 86.98 LOCATOR OTIS LOCATOR 2.992 PRODUCTION;7,504.8 '. : 7,813.1 6,522.3 87.01 PACKER OTIS WD PACKER 4.000 Ns 4 7,816.5 6,522.5 87.25 MILLOUT OTIS MILL OUT EXTENSION 4.410 (PERF;7,540.0-7,590.0- kAIIII 7,830.8 6,523.0 8825 NIPPLE CAMCO D NIPPLE NO GO 2.750 �' t: ' 6,523.3 88.57 WLEG OTIS WIRLINE RE-ENTRY GUIDE,ELMD TTL @ 7822 3.015 PACKER;7,613.0, `-'�f-° during PPROF on 9/27/2007 TUBING PUNCH;7,614.0 jip Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl I:n Top(ftKB) (ftKB) 0) Des Com Run Date ID(in) ' 7,613.0 6,416.1 33.53 PACKER 35 KB LINER TOP PACKER 9/1/2015 1.830 10,037.0 6,481.1 94.70 IBP IBP ran to isolate heavily water swept zone from 8/27/2015 production. WINDOW;7,658.0-7,668.0 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) Zone Date 5) Type Com YIN. 8,720.9 8,752.0 6,485.6 6,481.8 A-4,1G-11 8/27/2015 SLOTS Slotted Liner 8,777.2 10,029.6 6,478.7 6,481.7 A-4,1G-11 8/27/2015 SLOTS Slotted Liner Mandrel Inserts PRODUCTION;7,775.2 ''- St ati on Top(ND) Valve Latch Port Size TRO Run LOCATOR;7,812.7 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn PACKER;7,813.1 1 2,726.2 2,522.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,310.0 10/11/2015 MILLOUT;7,816.5111 2 4,148.1 3,673.7 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 10/9/2015 NIPPLE;7,830.8 - 1•:. 3 5,320.5 4,582.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/11/2015 WLEG;7,840.4 a 4 6,185.3 5,260.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/9/2015 I 1 5 6,832.4 5,780.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 6 7,171.4 6,053.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 PRODUCTION;37.1-8,1877 7 7,437.7 6,270.2 OTIS SPM 1 PROD DMY BK 0.000 0.0 6/21/2015 8 7,504.8 6,325.9 OTIS SPM 1 PROD DMY BK 0.000 0.0 6/22/2015 SLOTS;8,720.9-8,752.0iri 9 7,775.2 6,517.2 OTIS SPM 1 PROD OPEN BEK 0.000 0.0 4/23/2015 Notes:General&Safety End Date I Annotation SLOTS;8,777.2-10,029.6 IIINOTE A LINER,7,825.8-10,030.0 IBP,10,037.0 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: 2/& ~ �� ✓ Development Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: Gt ci.4— ( ?Lr��/ POOL: / 1- Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 • • El El m 0) a , 4) N a 0 M , • Q Cr Cr ' 3: N p (0: c (0 a w ani: E a >: 0, C, 0' 0 0. a) = (0: N� o 0: w, N: O LU 3: EO: CA a 0 a • O CO E' 3: 6 u) E O m. , 2: Q, a 4 Y, @ �: �j: W' a c a o, , o m 3: _ 1 5 E ami r �: E m� ca �: �': a > 5: w u) 2 -0 �: 0 L• �' a): O 0) co a: w� (0: 0. I- O, U o. y ;, > E. as w E a 0) 4 c G C-... co a c co p. �, p. 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