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Home My WebLink About216-0871. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9570'feet 8465' feet true vertical 6060' feet None feet Effective Depth measured 9570'feet 6166', 6225', 6264', 6280', 6377', 6600' feet true vertical 6060'feet 5643', 5692', 5724', 5737', 5818', 6005' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80/ J-55 6616' MD 6018' TVD Packers and SSSV (type, measured and true vertical depth) 6166' MD 6225' MD 6264' MD 6280' MD 6377' MD 6600' MD N/A 5643' TVD 5692' TVD 5724' TVD 5737' TVD 5818' TVD 6005' 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: 2727' 2727' Burst Collapse Production A Lateral 6902' 1105' Casing 6093' 2-3/8" 6934' 9570' 6061' 2693' 110'Conductor Surface Intermediate 16" 9-5/8" 75' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-087 50-029-21154-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025655, ADL0025656 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2B-02A 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) 90 Gas-Mcf MD 1200 Size 110' 1945 1265124 117 1701090 168 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 60 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: BluePack RH Max VAM TOP B/P Packer: HRP-1-SP Retrvbl Packer Packer: FB-1 Perm Packer SSSV: None Jaime Bronga Jaime.Bronga@conocophillips.com (907) 265-1053Senior Well Integrity Engineer 6526-6568', 6580-6582', 6586-6588', 6608-6610' 5943-5978', 5988-5990', 5993-5995', 6012-6014' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Jaime Bronga DN: OU=Conoco Phillips Alaska, CN=Jaime Bronga, E=jaime.bronga@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.07.17 08:59:48-08'00' Foxit PDF Editor Version: 13.1.6 Jaime Bronga By Grace Christianson at 10:33 am, Jul 17, 2025 RBDMS JSB 072525 DSR-7/21/25JJL 8/12/25 DTTMSTART JOBTYP SUMMARYOPS 7/2/2025 REPAIR WELL PULL 2.81'' PXX PLUG FROM X- NIPPLE 6326' RKB, BRUSH & FLUSH PATCH SET AREA, CLEAN DMY PATCH DRIFT TO 2.81'' D-NIPPLE 6326' RKB... IN PROGRESS 7/3/2025 REPAIR WELL SET 2.72'' P2P LWR PACKER MID ELEMENT 6266.0' RKB, SET TEST TOOL, PERFORMED PASSING 2500 PSI CMITIA, PULLED GLM # 3 EXT PACKING DMY VLV, LEFT POCKET OPEN, PULLED TEST TOOL, SET UPPER 2.72'' P2P PATCH ASSY IN LWR PACKER MID ELEMENT 6227.83 ' RKB PASSING CMITIA 2500 PSI, PULLED TEST TOOL...IN PROGRESS 7/4/2025 REPAIR WELL INSTALLED 2.78 '' X 30.94 ' PBR / POGLM PATCH ASSEMBLY W/ 1'' DMY VLV IN TOP OF LWR / UPPER PACKER , PERFORMED PASSING 2500 PSI CMITIA., INSTALLED 2.72'' X 32' UPPER PATCH ASSEMBLY IN POGLM , PERFORMED 2500 PSI MITIA.. NO SUCCESS. SET 3.5'' TTS TEST TOOL IN UPPER PATCH ASSY PERFORMED PASSING 2500 PSI MITT, LEFT TWO SEALS FROM TEST TOOL DOWN HOLE, ATTEMPT TO RECOVERY.. NO SUCCESS.. IN PROGRESS 7/5/2025 REPAIR WELL SET TTS TT IN TOP OF 2.72'' P2P UPPER PACKER, PERFORMED PASSING 2500 PSI CMIT IA X T, PULLED 1'' INTEGRAL TOP SUB DMY VLV FROM POGLM 6219' RKB (6185 SLMD), INSTALLED 1'' INTEGRAL TOP SUB .25'' PORT OV 6219' RKB (6195' SLMD), GOOD 1000 PSI BLEED DWN TEST ON IA TO VERIFY VLV SET, COMPLETE 7/14/2025 REPAIR WELL (AC EVAL) TIFL (PASSED) 2B-02 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:2B-02A pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Updated Schematic and added H2S reading 2B-02A 7/16/2025 pproven 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 15.06 35.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 34.1 2,727.3 2,726.8 36.00 J-55 BTC PRODUCTION 7 6.28 31.2 6,933.6 6,093.1 26.00 J-55 BTC A LATERAL 2 3/8 2.00 8,465.5 9,570.0 6,060.9 4.43 L-80 2.375 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.5 Set Depth … 6,354.6 Set Depth … 5,799.3 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M 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) 2,709.3 2,708.8 2.65 Mandrel – GAS LIFT 5.900 3.5" x 1.5" MMG SLB MMG 2.920 4,994.7 4,702.5 34.99 Mandrel – GAS LIFT 5.874 3.5" x 1.5" MMG SLB MMG 2.920 6,213.2 5,682.2 34.57 Mandrel – GAS LIFT 5.907 3.5" x 1.5" MMG SLB MMG 2.920 6,279.6 5,737.1 34.20 Packer 6.025 3.5" x 7" BluePack RH Max VAM TOP B/P SLB BluPak 2.894 6,326.4 5,775.8 33.91 Nipple - X 4.506 3.5" x 2.813" X-Nipple HES X 2.813 6,347.6 5,793.5 33.78 Overshot 6.030 3 1/2" x 7" Poorboy Overshot w/ 6.6' of swallow (2' space out off no-go) Inno 3.625 Top (ftKB) 6,350.7 Set Depth … 6,615.6 Set Depth … 6,018.4 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 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) 6,359.5 5,803.3 33.71 SBR 4.000 OEJ-10 SBR Camco 2.973 6,377.3 5,818.1 33.59 PACKER 5.937 HRP-1-SP RETRIEVABLE PACKER Camco 2.867 6,414.7 5,849.4 33.34 PRODUCTION 5.312 Camco KBUG 2.875 6,482.9 5,906.5 32.81 PRODUCTION 5.312 Camco KBUG 2.875 6,489.4 5,911.9 32.76 BLAST RINGS 3.500 BLAST RINGS (3) 4.500 MAX OD 2.992 6,582.1 5,990.1 32.33 PRODUCTION 5.312 Camco KBUG 2.875 6,598.7 6,004.1 32.26 SEAL ASSY 4.563 LOCATOR SEAL ASSEMBLY 3.000 6,599.6 6,004.9 32.25 PACKER 5.937 FB-1 PERMANENT PACKER Baker 4.000 6,602.1 6,007.0 32.25 SBE 4.000 SEAL BORE EXTENSION Baker 3.000 6,611.4 6,014.9 32.28 NIPPLE 4.540 D NIPPLE NO GO (MILLED ON 8/16/2016 from 2.75" to 2.80") Camco 2.800 6,614.7 6,017.7 32.28 WLEG 4.500 Shear Out Sub, ELMD TTL @ 6608' ON SWS PPROF DATED 1/5/07 Camco 2.937 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) 6,165.5 5,643.0 34.78 PACKER - PATCH - UPR 2.725" PIIP UPPER PACKER (MOE = 6167.91) & XO, OAL = 4.1' TO PULL: PACKER + SPACER + ANCHOR LATCH = 30.1' CPP3 5361 7/4/2025 1.630 6,169.6 5,646.4 34.76 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH, OAL = 25.99' CPAL 35201 7/4/2025 1.580 6,195.6 5,667.7 34.67 ANCHOR LATCH ON SPACER PIPE PBR, BELEVELED COUPLING, SPACER PIPE, & XO, OAL = 21.91' TO PULL: PBR + SPACER PIPE + POGLM + SPACER PIPE + ANCHOR LATCH = 29.83' CPPB R3503 4 7/4/2025 1.580 6,219.5 5,687.4 34.54 POGLM POGLM W/ 1/4" OV, PORT DEPTH = 6219.86' 7/4/2025 1.580 6,220.1 5,687.9 34.54 ANCHOR LATCH ON SPACER PIPE XO, SPACER PIPE, ANCHOR LATCH, OAL = 5.31' CPAL 35044 7/4/2025 1.600 6,225.4 5,692.3 34.51 PACKER - PATCH - UPR 2.725" PIIP UPPER PACKER, OAL = 4.1' TO PULL: UPPER PACKER + SPACER PIPE + BEVELED COUPLING + SPACER PIPE + ANCHOR LATCH = 36.95' TTS PIIP CPP3 5186 7/3/2025 1.625 6,229.5 5,695.7 34.48 ANCHOR LATCH ON SPACER PIPE SPACER PIPE WITH BEVELED COUPLING & ANCHOR LATCH CPAL 35164 7/3/2025 1.550 2B-02A, 7/16/2025 2:20:37 PM Vertical schematic (actual) A LATERAL; 8,465.5-9,570.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 C-SAND FRAC; 6,526.0 IPERF; 6,526.0-6,568.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 Nipple - X; 6,326.4 Packer; 6,279.6 PACKER - PATCH - LWR; 6,263.5 ANCHOR LATCH ON SPACER PIPE; 6,229.5 LEAK; 6,240.0 PACKER - PATCH - UPR; 6,225.4 ANCHOR LATCH ON SPACER PIPE; 6,220.1 POGLM; 6,219.5 Mandrel – GAS LIFT; 6,213.2 ANCHOR LATCH ON SPACER PIPE; 6,195.6 ANCHOR LATCH ON SPACER PIPE; 6,169.6 PACKER - PATCH - UPR; 6,165.5 Primary – Full Bore; 5,486.0 ftKB Mandrel – GAS LIFT; 4,994.7 SURFACE; 34.1-2,727.2 Mandrel – GAS LIFT; 2,709.3 Primary – Full Bore; 38.4 ftKB CONDUCTOR; 35.0-110.0 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD KB-Grd (ft) 38.40 RR Date 8/23/1984 Other Elev… 2B-02A ... TD Act Btm (ftKB) 9,570.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115401 Wellbore Status PROD Max Angle & MD Incl (°) 101.59 MD (ftKB) 8,690.45 WELLNAME WELLBORE2B-02A Annotation Last WO: End DateH2S (ppm) 100 Date 12/8/2022 Comment 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) 6,240.0 5,704.3 34.42 LEAK LEAK AT 6240' RKB IDENTIFIED VIA LDL (CORRECTED TO TBG TALLY) 6/14/2025 2.992 6,263.6 5,723.8 34.29 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ W-LEG, MOE = 6266' RKB OAL = 4.01' TTS PIIP CPP3 5379 7/3/2025 1.625 6,598.0 6,003.6 32.26 CTD 2 3/8" Liner 2B-02AL1-01 CTD Liner 10/27/2016 1.990 6,640.0 6,039.1 32.34 Whipstock BOT WS with OHA 10/11/2016 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) 2,709.3 2,708.8 2.65 1 GAS LIFT GLV RK 1 1/2 1,210.0 10/25/2024 SLB MMG 0.188 4,994.7 4,702.5 34.99 2 GAS LIFT GLV RK 1 1/2 1,240.0 5/11/2025 SLB MMG 0.250 6,213.2 5,682.2 34.57 3 GAS LIFT OPEN 7/3/2025 SLB 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) 8,465.5 6,118.7 89.98 Kick off Plug 2.625 Anchore d 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,526.0 6,568.0 5,942.8 5,978.2 C-4, 2B-02 10/9/1984 12.0 IPERF 120 deg. ph; 5" DA Csg Guns 6,580.0 6,582.0 5,988.3 5,990.0 A-3, A-4, A-5, 2B -02 8/16/2016 3.0 APERF 2" HSD POWERFLOW 2006 HMX 3 SPF 6,586.0 6,588.0 5,993.4 5,995.1 UNIT B, 2B-02 10/10/1984 4.0 IPERF Squeeze Perfs; 4" DA Csg Gun 6,608.0 6,610.0 6,012.0 6,013.7 A-3, A-4, A-5, 2B -02 8/16/2016 3.0 APERF 2" HSD POWERFLOW 2006 HMX 3 SPF Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,526.0 6,568.0 1 C-SAND FRAC 11/2/2006 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 38.4 2,727.0 38.4 2,726.5 Primary – Full Bore Lead 800 sx 12.2 ppg Cold Set III + Tail 300 sx 15.3 ppg Cold Set II... 9 5/8" csg. Cement w/ 800 sx Cold Set III @ 12.2 ppg. Tailed w/ 300 sx Cold Set II @ 15.3 ppg. Displaced w/ Drlg. Fluid 199 bbl. Pump plug w/ 1500# PSI CIP @ 00:35 8/18/84. Floats OK. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 6,586.0 6,588.0 5,993.4 5,995.1 Cement Squeeze Perfs 2B-02A, 7/16/2025 2:20:37 PM Vertical schematic (actual) A LATERAL; 8,465.5-9,570.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 C-SAND FRAC; 6,526.0 IPERF; 6,526.0-6,568.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 Nipple - X; 6,326.4 Packer; 6,279.6 PACKER - PATCH - LWR; 6,263.5 ANCHOR LATCH ON SPACER PIPE; 6,229.5 LEAK; 6,240.0 PACKER - PATCH - UPR; 6,225.4 ANCHOR LATCH ON SPACER PIPE; 6,220.1 POGLM; 6,219.5 Mandrel – GAS LIFT; 6,213.2 ANCHOR LATCH ON SPACER PIPE; 6,195.6 ANCHOR LATCH ON SPACER PIPE; 6,169.6 PACKER - PATCH - UPR; 6,165.5 Primary – Full Bore; 5,486.0 ftKB Mandrel – GAS LIFT; 4,994.7 SURFACE; 34.1-2,727.2 Mandrel – GAS LIFT; 2,709.3 Primary – Full Bore; 38.4 ftKB CONDUCTOR; 35.0-110.0 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD 2B-02A ... WELLNAME WELLBORE2B-02A Annotation Last WO: End Date Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SIDETRACK 2B-02AL1 9/14/2016 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread "AL1" Lateral Liner Assembly 2 3/8 1.99 8,810.8 10,222.0 5,997.0 4.60 L-80 ST-L 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) 9,164.2 6,066.6 92.92 Deployment Sleeve 2.625 Baker 1.920 2B-02AL1, 7/16/2025 2:20:38 PM Vertical schematic (actual) "AL1" Lateral Liner Assembly; 8,810.8-10,222.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 A LATERAL; 8,465.5-9,570.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 C-SAND FRAC; 6,526.0 IPERF; 6,526.0-6,568.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 Nipple - X; 6,326.4 Packer; 6,279.6 PACKER - PATCH - LWR; 6,263.5 ANCHOR LATCH ON SPACER PIPE; 6,229.5 LEAK; 6,240.0 PACKER - PATCH - UPR; 6,225.4 ANCHOR LATCH ON SPACER PIPE; 6,220.1 POGLM; 6,219.5 Mandrel – GAS LIFT; 6,213.2 ANCHOR LATCH ON SPACER PIPE; 6,195.6 ANCHOR LATCH ON SPACER PIPE; 6,169.6 PACKER - PATCH - UPR; 6,165.5 Primary – Full Bore; 5,486.0 ftKB Mandrel – GAS LIFT; 4,994.7 SURFACE; 34.1-2,727.2 Mandrel – GAS LIFT; 2,709.3 Primary – Full Bore; 38.4 ftKB CONDUCTOR; 35.0-110.0 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD KB-Grd (ft) 38.40 RR Date 8/23/1984 Other Elev… 2B-02AL1 ... TD Act Btm (ftKB) 10,230.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115460 Wellbore Status PROD Max Angle & MD Incl (°) 101.52 MD (ftKB) 9,930.15 WELLNAME WELLBORE2B-02A Annotation End DateH2S (ppm) 100 Date 12/8/2022 Comment Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SIDETRACK 2B-02AL1- 01 9/14/2016 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread "AL1-01" Lateral Liner Assembly 2 3/8 1.99 6,597.8 9,750.0 6,125.5 4.60 L-80 ST-L 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) 6,597.8 6,003.3 32.26 Deployment Sleeve 2.625 Shorty Deployment Sleeve Baker Shorty 1.000 2B-02AL1-01, 7/16/2025 2:20:39 PM Vertical schematic (actual) "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 "AL1" Lateral Liner Assembly; 8,810.8-10,222.0 A LATERAL; 8,465.5-9,570.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 C-SAND FRAC; 6,526.0 IPERF; 6,526.0-6,568.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 Nipple - X; 6,326.4 Packer; 6,279.6 PACKER - PATCH - LWR; 6,263.5 ANCHOR LATCH ON SPACER PIPE; 6,229.5 LEAK; 6,240.0 PACKER - PATCH - UPR; 6,225.4 ANCHOR LATCH ON SPACER PIPE; 6,220.1 POGLM; 6,219.5 Mandrel – GAS LIFT; 6,213.2 ANCHOR LATCH ON SPACER PIPE; 6,195.6 ANCHOR LATCH ON SPACER PIPE; 6,169.6 PACKER - PATCH - UPR; 6,165.5 Primary – Full Bore; 5,486.0 ftKB Mandrel – GAS LIFT; 4,994.7 SURFACE; 34.1-2,727.2 Mandrel – GAS LIFT; 2,709.3 Primary – Full Bore; 38.4 ftKB CONDUCTOR; 35.0-110.0 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD KB-Grd (ft) 38.40 RR Date 8/23/1984 Other Elev… 2B-02AL1-01 ... TD Act Btm (ftKB) 9,754.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115461 Wellbore Status PROD Max Angle & MD Incl (°) 101.24 MD (ftKB) 8,735.73 WELLNAME WELLBORE2B-02A Annotation End DateH2S (ppm) 100 Date 12/8/2022 Comment Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2B-02A 50-029-21154-01 910106459 Kuparuk River Multi Finger Caliper Field & Processed 14-Jun-25 0 12 2B-03B 50-029-21151-02 n/a Kuparuk River Radial Bond Record Field- Final 8-Mar-25 0 13 2F-09 50-029-21090-00 910080198 Kuparuk River Plug Setting Record Field- Final 23-May-25 0 14 2F-09 50-029-21090-00 910010602 Kuparuk River Radial Bond Record Field- Final 2-May-25 0 15 2G-17 50-029-23134-00 910106461 Kuparuk River Plug Setting Record Field- Final 9-Jun-25 0 16 2K-23 50-103-20125-00 910099510 Kuparuk River Multi Finger Caliper Field & Processed 2-Jun-25 0 17 2K-34 50-103-20688-00 910096425 Kuparuk River Multi Finger Caliper Field & Processed 15-Jun-25 0 18 2M-08 50-103-20184-00 910027001 Kuparuk River Multi Finger Caliper Field & Processed 9-May-25 0 19 2M-25 50-103-20152-00 910106929 Kuparuk River Plug Setting Record Field- Final 12-Jun-25 0 110 2M-25 50-103-20152-00 910106929 Kuparuk River Tubing Cut Record Field- Final 13-Jun-25 0 1PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:216-087223-080184-036202-243190-014214-026192-101191-021T40589T40590T40591T40591T40592T40593T40594T40595T40596T405966/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:42:29 -08'00'216-0871 2B-02A50-029-21154-01 910106459Kuparuk RiverMulti Finger CaliperField & Processed14-Jun-2501 Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-20 50-029-23164-00 910026681 Kuparuk River Packer Setting Record Field- Final 7-May-25 0 12 1D-117 50-029-22844-00 910027101 Kuparuk River Plug Setting Record Field- Final 8-May-25 0 13 1D-133 50-029-22827-00 910010225 Kuparuk River Multi Finger Caliper Field & Processed 25-May-25 0 14 1G-02 50-029-20813-00 910036496 Kuparuk River Multi Finger Caliper Field & Processed 21-May-25 0 15 1H-08 50-029-20763-00 910080713 Kuparuk River Multi Finger Caliper Field & Processed 22-May-25 0 16 1H-08 50-029-20763-00 910080713 Kuparuk River Plug Setting Record Field- Final 22-May-25 0 17 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 14-May-25 0 18 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 15-May-25 0 19 1Q-22 50-029-22595-00 910027102 Kuparuk River Plug Setting Record Field- Final 16-May-25 0 110 2B-02A 50-029-21154-01 910106459 Kuparuk River Leak Detect Log Field- Final 14-Jun-25 0 1PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:203-115197-237197-206182-138182-093184-234195-140216-087T40582T40583T40584T40585T40586T40586T40587T40587T40588T405896/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:37:34 -08'00'2B-02A50-029-21154-01 910106459Kuparuk RiverLeak Detect LogField- Final14-Jun-2501216-087 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: Replace Tubing 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 9570'feet None feet true vertical 6060' feet None feet Effective Depth measured 6406'feet 6377', 6600'feet true vertical 6363'feet 5818', 6005'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) L-80 J-55 6355' 6615' 5799' 6018' Packers and SSSV (type, measured and true vertical depth)6280' 6377' 6600' 5737' 5818' 6005' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk 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: 2727' 2727' Burst Collapse A Lateral 6903' 825' Casing 6287' 6061' 6934' 9570' 2693' 110'Conductor Surface Production 16" 9-5/8" 75' measured TVD 7" 2-3/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-087 50-029-21154-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025655, ADL0025656 Kuparuk River Field/ Kuparuk Oil Pool KRU 2B-02A 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) N/A Gas-Mcf MDSize 110' N/A 324-515 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: BluePak RH Max Packer: Camco HRP-1-SP Packer: BAKER FB-1 SSSV: None Cy Eller cy.eller@conocophillips.com (907) 265-6049 RWO/CTD Engineer 6526-6568', 6580-6582', 6586-6588 (squeezed), 6608-6610', 6620-6710' 5943-5978', 5988-5990', 5993-5995', 6012-6014', 6022-6098' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 3-1/2" 3-1/2" By Grace Christianson at 2:11 pm, Nov 05, 2024 Page 1/5 2B-02 Report Printed: 11/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 9/26/2024 12:00 9/26/2024 15:00 3.00 MIRU, MOVE MOB P Prep for rig move to 2B. Lay mats. Move rig from 1L to 1Y. 9/26/2024 15:00 9/27/2024 00:00 9.00 MIRU, MOVE MOB P Shuffle mats from 1Y to Spine. Cont. rig move to spine road. Perform preventative maintenance on rig equipment 9/27/2024 00:00 9/27/2024 12:00 12.00 MIRU, MOVE MOB P Continue with mat shuffle to get rig to spine road, rig crew performing preventative maintenance on the rig 0.0 0.0 9/27/2024 12:00 9/27/2024 19:00 7.00 MIRU, MOVE MOB P Continue rig mat shuffle laying mats from 1F to spine road. 0.0 0.0 9/27/2024 19:00 9/27/2024 20:00 1.00 MIRU, MOVE MOB P Move rig from 1F down 1F access towards spline, stage on road to double stack mats for shuffle 0.0 0.0 9/27/2024 20:00 9/28/2024 00:00 4.00 MIRU, MOVE MOB P Continue rig mat shuffle laying mats from 1F to spine road. 0.0 0.0 9/28/2024 00:00 9/28/2024 02:30 2.50 MIRU, MOVE MOB P Double stack mats behind rig to shuffle them to front of rig. Cont. rig maintenance and misc. rig projects (cellar beam trolley, mudcart winch, welded bleeder and reverse line) while waiting on mat shuffle. 0.0 0.0 9/28/2024 02:30 9/28/2024 03:30 1.00 MIRU, MOVE MOB P Roll backwards over mats to shuffle to front of rig 0.0 0.0 9/28/2024 03:30 9/28/2024 16:30 13.00 MIRU, MOVE MOB P Move rig from 1F to Spine Road. Call Security. 0.0 0.0 9/28/2024 16:30 9/29/2024 00:00 7.50 MIRU, MOVE MOB P Cont. move down the Spine to CPF2 0.0 0.0 9/29/2024 00:00 9/29/2024 18:00 18.00 MIRU, MOVE MOB P Stage rig @ CPF 2 and shuffle rig mats 0.0 0.0 9/29/2024 18:00 9/30/2024 00:00 6.00 MIRU, MOVE MOB P Cont. lay mats from CPF2 to 2B Pad. 0.0 0.0 9/30/2024 00:00 9/30/2024 09:30 9.50 MIRU, MOVE WAIT P Wait for mats to be set for rig move from CPF2 to 2B. 0.0 0.0 9/30/2024 09:30 9/30/2024 12:00 2.50 MIRU, MOVE MOB P Move rig from CPF-2 to 2B. Park rig. Allow traffic through. 0.0 0.0 9/30/2024 12:00 9/30/2024 21:30 9.50 MIRU, MOVE RURD P Hang tree in cellar. Inspect and stage WH equipment. Pull rig over 2B-02. Safe out rig. Center rig over well. Berm in cellar. Haul support equipment from 1L to 2B. Spot in hardline manifold and cuttings tank. Measure RKB's. Work through rig acceptance checklist. Accept rig @ 15:00. Take on seawater into pits. Build 35 bbl DeepClean pill. Spot in support equipment. Spot highline trailer. Spot returns tanks on ODS. Call Pad Op to pump open SSV. Gather initial pressures: T/IA/OA = 0 / 0 / 0 psi. Cont. to RU hardline and cellar hoses. Cont. to haul and spot support equipment. 0.0 0.0 9/30/2024 21:30 10/1/2024 00:00 2.50 MIRU, WELCTL KLWL P Blow air to tanks. Flood lines. Pressure test returns hardline to 3,000 psi. Circ out to tanks to check blooie line pressures. 3 BPM = 153 psi. 4 BPM = 256 psi. 5 BPM = 390 psi. PJSM. Bleed free gas from Tubing and IA. Pump 30 bbls 8.5# SW hot DeepClean pill. Chase with 340 bbls of 8.5# SW @ 4 BPM / 1041 psi. SD Pumps. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/6/2024 Page 2/5 2B-02 Report Printed: 11/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/1/2024 00:00 10/1/2024 01:00 1.00 MIRU, WELCTL KLWL P Blow air to tanks. Flood lines. Pressure test returns hardline to 3,000 psi. Circ out to tanks to check blooie line pressures. 3 BPM = 153 psi. 4 BPM = 256 psi. 5 BPM = 390 psi. PJSM. Bleed free gas from Tubing and IA. Pump 30 bbls 8.5# SW hot DeepClean pill. Chase with 340 bbls of 8.5# SW @ 4 BPM / 1041 psi. SD Pumps. 0.0 0.0 10/1/2024 01:00 10/1/2024 02:00 1.00 MIRU, WELCTL OWFF P OWFF for 30-min 0.0 0.0 10/1/2024 02:00 10/1/2024 04:00 2.00 MIRU, WELCTL NUND P Nipple down production tree, inspect hanger threads, install blanking plug 12 turns 0.0 0.0 10/1/2024 04:00 10/1/2024 06:00 2.00 MIRU, WHDBOP NUND P Nipple up BOPs get RKBs 0.0 0.0 10/1/2024 06:00 10/1/2024 08:00 2.00 MIRU, WHDBOP OTHR P Grease valves, fluid pack, attempt shell test, unable to get shell test found doors leaking 0.0 0.0 10/1/2024 08:00 10/1/2024 11:00 3.00 MIRU, WHDBOP RGRP T Change out door seals on double gates 0.0 0.0 10/1/2024 11:00 10/1/2024 16:00 5.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's, LVBRs w/ 3 1/2". Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½ EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1700 PSI, 200 PSI attained = 15 sec, full recovery attained = 107 sec. UVBR's= 5 sec, LVBRs= 5 sec. Annular= 14 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average = 2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby 0.0 0.0 10/1/2024 16:00 10/1/2024 16:30 0.50 MIRU, WHDBOP RURD P R/D test equipment. Line up equipment for hard shut in 0.0 0.0 10/1/2024 16:30 10/1/2024 17:00 0.50 COMPZN, RPCOMP MPSP P Pull blanking plug, F plug 0.0 0.0 10/1/2024 17:00 10/1/2024 18:30 1.50 COMPZN, RPCOMP THGR P Screw landing joint into hanger threads, Set down 10K. BOLDS 0.0 0.0 10/1/2024 18:30 10/1/2024 19:00 0.50 COMPZN, RPCOMP THGR P Pick up to 138K. No movement. Cycle pipe 3 times. Leave pipe in tension. Kick on pumps. 2 BBls away popped free. Dragging weight 88K up. Pull hanger to floor. 6,350.0 6,323.0 10/1/2024 19:00 10/1/2024 19:30 0.50 COMPZN, RPCOMP CIRC P Circ BU 4.5 BPM @ 800 PSI 6,323.0 6,323.0 10/1/2024 19:30 10/1/2024 20:06 0.60 COMPZN, RPCOMP RURD P Rig up HES control line spooler to control line. Break out landing joint from hanger. M/U X-O on FOFV. Changer out elevators. Pull 3 1/2" completion from cut @ 6350 6,323.0 6,323.0 10/1/2024 20:06 10/1/2024 22:30 2.40 COMPZN, RPCOMP PULL P Pull 3 1/2" completion from cut @ 6350 6,323.0 4,505.0 Rig: NORDIC 3 RIG RELEASE DATE 10/6/2024 Page 3/5 2B-02 Report Printed: 11/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/1/2024 22:30 10/2/2024 00:00 1.50 COMPZN, RPCOMP PULL P SSSV at floor. No overpulls, Came up on joint early on Jt 60 talley shows 61. Recounted pipe. Recovered 34 SS bands. Lay down HES spooler. NORM control line 4,505.0 4,505.0 10/2/2024 00:00 10/2/2024 00:30 0.50 COMPZN, RPCOMP RURD P R/D HES spooler, load out. NORM control line and 34 bands removed from well 4,505.0 4,505.0 10/2/2024 00:30 10/2/2024 04:00 3.50 COMPZN, RPCOMP PULL P Continue to pull completion from cut @ 6350'. Recover 205 full joints, 5 GLM's one cut joint @ 19.49 4,505.0 0.0 10/2/2024 04:00 10/2/2024 05:00 1.00 COMPZN, RPCOMP BHAH P Clear and clean rig floor - Install wear ring 0.0 0.0 10/2/2024 05:00 10/2/2024 07:00 2.00 COMPZN, RPCOMP BHAH P Load pipe shed with BHA // Pick up BHA# 1 clean out assembly 0.0 0.0 10/2/2024 07:00 10/2/2024 14:00 7.00 COMPZN, RPCOMP PUTB P Pick up tubing run in hole with clean out assemlby 0.0 6,320.0 10/2/2024 14:00 10/2/2024 15:00 1.00 COMPZN, RPCOMP MILL P Up wt 130 Dn Wt 105 // Dry tag top of stump 6335' N3 RKB work over stump down to 6343' // Pick up pump 4 bbls/ min @ 660 psi // Wash over stump @ 6335' 200 psi pump increase, NG @ 6343' // Pick up Rot 80 rpm 3800 ft/lbs free torque, dress off top of stump to 6336' 6,320.0 6,343.0 10/2/2024 15:00 10/2/2024 16:00 1.00 COMPZN, RPCOMP CIRC P Circulate sweeps ensure hole clean Pump S to S 6,343.0 6,330.0 10/2/2024 16:00 10/2/2024 17:00 1.00 COMPZN, RPCOMP BKRM P Dress packer setting area F/ 6300' T/ 6140' 6,330.0 6,140.0 10/2/2024 17:00 10/2/2024 18:00 1.00 COMPZN, RPCOMP PRTS P Pressure Test casing 2500 psi 30 min Unable to get test 6,140.0 6,140.0 10/2/2024 18:00 10/2/2024 19:00 1.00 COMPZN, RPCOMP PRTS P Reconfog PT. Unscrew top drive. Install head pin with block valve. Pressure up down kill. Bleed air off tubing. Well taking fluid @ 2520 PSI. Consult town. 6,140.0 6,140.0 10/2/2024 19:00 10/2/2024 22:00 3.00 COMPZN, RPCOMP TRIP P Blow down TD, Choke and kill lines. Trip out of hole for test packer 6,140.0 237.0 10/2/2024 22:00 10/2/2024 22:30 0.50 COMPZN, RPCOMP SFTY P PJSM to lay down BHA 237.0 237.0 10/2/2024 22:30 10/2/2024 23:00 0.50 COMPZN, RPCOMP BHAH P Lay down BHA #1 Drift/Dress off run 237.0 0.0 10/2/2024 23:00 10/3/2024 00:00 1.00 COMPZN, RPCOMP BHAH P Load out BHA and extra tools, Clean rig floor 0.0 0.0 10/3/2024 00:00 10/3/2024 00:30 0.50 COMPZN, RPCOMP BHAH P M/U BHA #2 test packer 0.0 13.0 10/3/2024 00:30 10/3/2024 01:30 1.00 COMPZN, RPCOMP TRIP P TIH BHA #2 13.0 2,500.0 10/3/2024 01:30 10/3/2024 02:00 0.50 COMPZN, RPCOMP PRTS P Set test packer @ 2500', Line up to pump down kill with annular shut, Get 5 minute flat line. Bleed off pressure release test packer. Blow down lines 2,500.0 2,500.0 10/3/2024 02:00 10/3/2024 04:30 2.50 COMPZN, RPCOMP TRIP P Continue in well 2,500.0 6,308.0 10/3/2024 04:30 10/3/2024 05:30 1.00 COMPZN, RPCOMP PRTS P Set packer 6308 COE. Rig up to pressure test 7" casing. Shut UPR's, Bleed air off system, Starting OA=0, S/I 2700 PSI, OA=100PSI. Good test. Bleed off casing. Release test packer R.D test equipment 6,308.0 6,308.0 10/3/2024 05:30 10/3/2024 07:30 2.00 COMPZN, RPCOMP PULD P POOH laying down tubing 6,308.0 5,387.0 10/3/2024 07:30 10/3/2024 08:15 0.75 COMPZN, RPCOMP OWFF P Stop observe well for flow // Loss of .04 bbls over 30 min 5,387.0 5,387.0 Rig: NORDIC 3 RIG RELEASE DATE 10/6/2024 Page 4/5 2B-02 Report Printed: 11/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/3/2024 08:15 10/3/2024 09:45 1.50 COMPZN, RPCOMP PRTS P Set packer 5384' COE // Test below 2000 psi // Rig down test equipment 5,387.0 5,387.0 10/3/2024 09:45 10/3/2024 11:45 2.00 COMPZN, RPCOMP PULD P POOH laying down drill pipe 5,387.0 3,542.0 10/3/2024 11:45 10/3/2024 13:15 1.50 COMPZN, RPCOMP SLPC P Slip and cut drill line 3,542.0 3,542.0 10/3/2024 13:15 10/3/2024 16:45 3.50 COMPZN, RPCOMP PULD P Lay down drill pipe 3,542.0 0.0 10/3/2024 16:45 10/3/2024 17:00 0.25 COMPZN, RPCOMP CLEN P Pull wear ring clean up floor 0.0 0.0 10/3/2024 17:00 10/3/2024 21:30 4.50 COMPZN, RPCOMP BHAH P Finish processing 3 1/2" EUE tubing, Off load 3 m1/2" drill pipe. C/O handling equipment. Verify jewelry and jewelry running order. Check tubing count, Strap pups. Modify completion tally to reposition packer away from casing collar 0.0 0.0 10/3/2024 21:30 10/3/2024 22:00 0.50 COMPZN, RPCOMP SFTY P PJSM run 3 1/2" EUE completion 0.0 0.0 10/3/2024 22:00 10/3/2024 22:30 0.50 COMPZN, RPCOMP PUTB P P/U mPoor Boy overshot, X-nipple with RHC plug installed, 10.12' pup, 10.17' pup SLB Blue packer, 8.20' pup, and joint #1 0.0 153.0 10/3/2024 22:30 10/4/2024 00:00 1.50 COMPZN, RPCOMP PUTB P Run 3 1/2" completion, C/OL joint 12 with spare "E". Same length Change out coupler Joint 11 153.0 624.0 10/4/2024 00:00 10/4/2024 02:30 2.50 COMPZN, RPCOMP PUTB P Continue to pick up 3 1/2" EUE completion. C/O Joint 33 to spare joint C. C/O collar Jt 32. C/O joint 52 to spare joint B, C/O collar joint 51, C/O Jt 64 to spare "D" 624.0 2,158.0 10/4/2024 02:30 10/4/2024 04:00 1.50 COMPZN, RPCOMP OTHR P Remove good collars from bad joints, Mark and off load bad joints. . Bring in 15 more spares and strap 2,158.0 2,158.0 10/4/2024 04:00 10/4/2024 09:30 5.50 COMPZN, RPCOMP PUTB P Continue picking up 3 1/2" EUE completion 2,158.0 6,325.0 10/4/2024 09:30 10/4/2024 10:45 1.25 COMPZN, RPCOMP HOSO P Up wt 88K Dn Wt 75K // Pump .5 bbls/min @ 67 psi // SO over stump, shear screws @ 6345' fully locate 6349' w/ 20k down on stump // Calculate space out 25.42' of pups needed, lay down jt 195 pick up pup jts, pick up jt. 195, make up hanger and landing jt, 6,325.0 6,349.0 10/4/2024 10:45 10/4/2024 12:15 1.50 COMPZN, RPCOMP DISP P Displace well w/ 8.5# CI 6,340.0 6,340.0 10/4/2024 12:15 10/4/2024 13:30 1.25 COMPZN, RPCOMP HOSO P Land hanger // Set down 10K RILDS and torque // Close pipe rams test 3000psi 10 min good test // 6,340.0 6,348.0 10/4/2024 13:30 10/4/2024 14:15 0.75 COMPZN, RPCOMP RURD P Drop ball and rod // Rig up testing manifold for packer set // 6,348.0 6,348.0 10/4/2024 14:15 10/4/2024 16:00 1.75 COMPZN, RPCOMP PACK P Pressure up 3500 psi set packer // Initial shear @ XXXX psi // hold 3500 psi 30 min (MIT-T) // Bleed tubing 1500 psi // Pressure up IA 2500 psi 30 min (MIT-IA) good test // Dump tubing shear SOV Off highline power at 16:00 6,348.0 6,348.0 10/4/2024 16:00 10/4/2024 17:30 1.50 COMPZN, RPCOMP RURD P Blow down, rig down test equipment, pull landing jt 6,348.0 0.0 10/4/2024 17:30 10/4/2024 18:00 0.50 COMPZN, WHDBOP MPSP P Set H-BPV , test from below 1000psi 10 min 0.0 0.0 10/4/2024 18:00 10/4/2024 19:30 1.50 COMPZN, WHDBOP NUND P Pull flow riser, Install boot basket, Pull trip tank hose, Accuator hose, Break bolts. Rack back stack 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/6/2024 Page 5/5 2B-02 Report Printed: 11/4/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/4/2024 19:30 10/4/2024 21:30 2.00 COMPZN, WHDBOP NUND P N/U production tree. Torque bolts. Test void 5000 PSI / 15 minutes.Rig up U tube. Rig up LRS. Pump open SSV 0.0 0.0 10/4/2024 21:30 10/5/2024 00:00 2.50 COMPZN, WHDBOP PRTS P R/U LRS and iron to tree for U tube. Pressure test tree 5K. Pull test plug. Pump FP diesel down IA returns from tubing to cuttings box 0.0 10/5/2024 00:00 10/5/2024 02:00 2.00 COMPZN, WHDBOP FRZP P Complete pumping 75 BBls down IA. FCP=200 PSI @ 2 BPM. R/D LRS. Open up U tube 0.0 0.0 10/5/2024 02:00 10/5/2024 04:00 2.00 COMPZN, WHDBOP FRZP P Shut U tube. T=0 IA=180, OA=0. Open U tube back up/ 0.0 0.0 10/5/2024 04:00 10/5/2024 04:30 0.50 COMPZN, WHDBOP RURD P R/D U tube, FSITP= 0 FIA=60, FOA=0 0.0 0.0 10/5/2024 04:30 10/5/2024 10:00 5.50 DEMOB, MOVE RURD P Work Rig Down Checklist // Pull high line trailer 0.0 0.0 10/5/2024 10:00 10/6/2024 00:00 14.00 DEMOB, MOVE WAIT P Pull off well, wait for mats to be set 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 10/6/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,750.0 2B-02 10/24/2015 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed post RWO GLD. Pull B&R/RHC. Pulled catcher & RBP 2B-02 10/26/2024 fergusp 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 15.06 35.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 34.1 2,727.3 2,726.8 36.00 J-55 BTC PRODUCTION 7 6.28 31.2 6,933.6 6,286.8 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.5 Set Depth 6,354.6 String Max No 3 1/2 Set Depth 5,799.3 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L80 Top Connection EUE-M 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) 2,709.3 2,708.8 2.65 Mandrel GAS LIFT 5.900 3.5" x 1.5" MMG, GLM, GLM SLB MMG 2.990 4,994.7 4,702.5 34.99 Mandrel GAS LIFT 5.874 3.5" x 1.5" MMG, GLM, SLB MMG 2.990 6,213.2 5,682.2 34.57 Mandrel GAS LIFT 5.907 3.5" x 1.5" MMG, GLM, SLB MMG 2.920 6,279.6 5,737.1 34.20 Packer 6.025 3.5" x 7" BluePack RH Max VAM TOP B/P SLB BluePac k 2.894 6,326.4 5,775.8 33.91 Nipple - X 4.506 3.5" x 2.813" X-Nipple w/ RHC Plug, Halliburt on X 2.813 6,347.6 5,793.5 33.78 Overshot 6.030 3 1/2" x 7" Poorboy Overshot w/ 6.6' of swallow (2' space out off no-go) Inno Poorboy Oversho t 3.625 Top (ftKB) 6,350.7 Set Depth 6,615.6 String Max No 3 1/2 Set Depth 6,018.4 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 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) 6,359.5 5,803.3 33.71 SBR 4.000 CAMCO OEJ-10 SBR 2.973 6,377.3 5,818.1 33.59 PACKER 5.937 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 6,414.7 5,849.4 33.34 PRODUCTION 5.312 CAMCO KBUG 2.875 6,482.9 5,906.5 32.81 PRODUCTION 5.312 CAMCO KBUG 2.875 6,489.4 5,911.9 32.76 BLAST RINGS 3.500 BLAST RINGS (3) 4.500 MAX OD 2.992 6,582.1 5,990.1 32.33 PRODUCTION 5.312 CAMCO KBUG 2.875 6,598.7 6,004.1 32.26 SEAL ASSY 4.563 LOCATOR SEAL ASSEMBLY 3.000 6,599.6 6,004.9 32.25 PACKER 5.937 BAKER FB-1 PERMANENT PACKER 4.000 6,602.1 6,007.0 32.25 SBE 4.000 BAKER SEAL BORE EXTENSION 3.000 6,611.4 6,014.9 32.28 NIPPLE 4.540 CAMCO D NIPPLE NO GO (MILLED ON 8/16/2016 from 2.75" to 2.80") 2.800 6,614.7 6,017.7 32.28 WLEG 4.500 CAMCO SHEAR OUT SUB, ELMD TTL @ 6608' ON SWS PPROF DATED 1/5/07 2.937 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) 6,640.0 6,039.1 32.34 Whipstock BOT WS with OHA 10/11/2016 6,685.0 6,077.1 32.45 FISH 3" OK-1 Arm ASSY Lost Downhole on 9/12/96 9/12/1996 0.000 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) 2,709.3 2,708.8 2.65 1 GAS LIFT GLV RK 1 1/2 1,210.0 10/25/2024 SLB MMG 0.188 4,994.7 4,702.5 34.99 2 GAS LIFT GLV RK 1 1/2 1,242.0 10/25/2024 SLB MMG 0.250 6,213.2 5,682.2 34.57 3 GAS LIFT OV RK 1 1/2 0.0 10/25/2024 SLB MMG 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,526.0 6,568.0 5,942.8 5,978.2 C-4, 2B-02 10/9/1984 12.0 IPERF 120 deg. ph; 5" DA Csg Guns 6,580.0 6,582.0 5,988.3 5,990.0 A-3, A-4, A-5, 2B -02 8/16/2016 3.0 APERF 2" HSD POWERFLOW 2006 HMX 3 SPF 6,586.0 6,588.0 5,993.4 5,995.1 UNIT B, 2B-02 10/10/1984 4.0 IPERF Squeeze Perfs; 4" DA Csg Gun 6,608.0 6,610.0 6,012.0 6,013.7 A-3, A-4, A-5, 2B -02 8/16/2016 3.0 APERF 2" HSD POWERFLOW 2006 HMX 3 SPF 6,620.0 6,710.0 6,022.2 6,098.1 A-3, A-4, A-5, 2B -02 10/9/1984 4.0 IPERF 120 deg. ph; 4" JJ Csg Gun Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,526.0 6,568.0 1 C-SAND FRAC 11/2/2006 0.0 0.00 0.00 2B-02, 11/5/2024 1:19:06 PM Vertical schematic (actual) PRODUCTION; 31.2-6,933.6 FLOAT SHOE; 6,931.8-6,933.6 FLOAT COLLAR; 6,851.1- 6,852.6 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 Slotted Liner; 6,616.8-9,749.6 CTD 2 3/8" Liner ; 6,598.0 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 WLEG; 6,614.7 NIPPLE; 6,611.4 APERF; 6,608.0-6,610.0 Liner - Pup; 6,598.6-6,616.8 SBE; 6,602.1 PACKER; 6,599.6 SEAL ASSY; 6,598.7 Deployment Sleeve; 6,597.8- 6,598.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 C-SAND FRAC; 6,526.0 IPERF; 6,526.0-6,568.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 SBR; 6,359.5 Overshot; 6,347.6 Nipple - X; 6,326.4 Packer; 6,279.6 Mandrel GAS LIFT; 6,213.2 Mandrel GAS LIFT; 4,994.7 Annular Fluid - Seawater; 2,000.0-6,352.0; 10/4/2024 SURFACE; 34.1-2,727.2 FLOAT SHOE; 2,725.4-2,727.2 Mandrel GAS LIFT; 2,709.3 FLOAT COLLAR; 2,644.8- 2,646.4 Annular Fluid - Diesel; 32.5- 2,000.0; 10/4/2024 CONDUCTOR; 35.0-110.0 HANGER; 34.1-39.1 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD KB-Grd (ft) 38.40 RR Date 8/23/1984 Other Elev 2B-02 ... TD Act Btm (ftKB) 6,976.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115400 Wellbore Status PROD Max Angle & MD Incl (°) 39.17 MD (ftKB) 4,200.00 WELLNAME WELLBORE2B-02A Annotation End DateH2S (ppm) 65 Date 11/21/2015 Comment Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,586.0 6,588.0 5,993.4 5,995.1 Cement Squeeze Perfs 2B-02, 11/4/2024 1:02:56 PM Vertical schematic (actual) PRODUCTION; 31.2-6,933.6 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 IPERF; 6,526.0-6,568.0 C-SAND FRAC; 6,526.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 Nipple - X; 6,326.4 Packer; 6,279.6 Mandrel GAS LIFT; 6,213.2 Mandrel GAS LIFT; 4,994.7 SURFACE; 34.1-2,727.2 Mandrel GAS LIFT; 2,709.3 CONDUCTOR; 35.0-110.0 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD 2B-02 ... WELLNAME WELLBORE2B-02A Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 2B-02A pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2B-02A 9/23/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Tubing hanger from 2024 RWO has H BPV profile in it. 10/6/2024 spilch Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread A LATERAL 2 3/8 2.00 8,465.5 9,570.0 6,060.9 4.43 L-80 2.375 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) 6,598.0 6,003.6 32.26 CTD 2 3/8" Liner 2B-02AL1-01 CTD Liner 10/27/2016 1.990 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) 8,465.5 6,118.7 89.98 Kick off Plug 2.625 Anchore d 1.000 2B-02A, 11/4/2024 1:02:56 PM Vertical schematic (actual) A LATERAL; 8,465.5-9,570.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 IPERF; 6,526.0-6,568.0 C-SAND FRAC; 6,526.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 Nipple - X; 6,326.4 Packer; 6,279.6 Mandrel GAS LIFT; 6,213.2 Mandrel GAS LIFT; 4,994.7 SURFACE; 34.1-2,727.2 Mandrel GAS LIFT; 2,709.3 CONDUCTOR; 35.0-110.0 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD KB-Grd (ft) 38.40 RR Date 8/23/1984 Other Elev 2B-02A ... TD Act Btm (ftKB) 9,570.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115401 Wellbore Status PROD Max Angle & MD Incl (°) 101.59 MD (ftKB) 8,690.45 WELLNAME WELLBORE2B-02A Annotation Last WO: End DateH2S (ppm) 65 Date 11/21/2015 Comment 2B-02A, 11/4/2024 1:02:57 PM Vertical schematic (actual) A LATERAL; 8,465.5-9,570.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.6 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 IPERF; 6,526.0-6,568.0 C-SAND FRAC; 6,526.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 Nipple - X; 6,326.4 Packer; 6,279.6 Mandrel GAS LIFT; 6,213.2 Mandrel GAS LIFT; 4,994.7 SURFACE; 34.1-2,727.2 Mandrel GAS LIFT; 2,709.3 CONDUCTOR; 35.0-110.0 Hanger H Profile w/ 3.5" EUE Top Threads ; 32.5 KUP PROD 2B-02A ... WELLNAME WELLBORE2B-02A Annotation Last WO: End Date ORIGINATED TRANSMITTAL DATE: 9/24/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5080 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5080 2B-02A 50029211540100 Tubing Cut Record 23-Sep-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 216-087 T39586 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.24 10:05:29 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9570'6060' 6406' 5842'2700' 6406' None Casing Collapse Conductor Surface Production A Lateral Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-265-6049 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Cy Eller cy.eller@conocophillips.com CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 6377'MD/5818'TVD 6600'MD/6005'TVD 1891'MD/1891'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025655, ADL0025656 216-087 P.O. Box 100360, Anchorage, AK 99510 50-029-21154-01-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 6616' MD 110' 2727' 110' 2727' 6287'7" 16" 9.625" 75' CAMCO HRP-1-SP Baker FB-1 SSSV: Otis FMX Safety valve 2693' 6934' Perforation Depth MD (ft): KRU 2B-02A 6526-6568' 6580-6582' 6586-6588' (Squeezed) 6608'-6610' 6620-6710' 6903' 2.375" 5943-5978' 5988-5990' 5993-5995' 6012-6014' 6022-6098' 10/8/2024 9570'825' 3-1/2" 6061' m n P s 2 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:19 pm, Sep 09, 2024 324-515 VTL 9/19/2024 DSR-9/11/24 9/28/2024 A.Dewhurst 11SEP24 X 10-404 BOP test to 3000 psig Annular preventer to 2500 psig X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.23 08:37:40 -08'00'09/23/24 RBDMS JSB 092324 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 9, 2024 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 for Sundry Approval to work over Kuparuk Producer 2B-02A (PTD# 216-087). Well 2B-02 was drilled in August of 1984 with Nabors 26E and completed in October of 1984 by Roll’N #4 as a Kuparuk A and C sand producer. In 2016 the A and C sands were cemented and the well was CTD’d with Nabors CDR2 and had been online until it failed a TIFL in 2020 and subsequent diagnostics revealed a tubing leak at 6345’ RKB. A tubing patch was installed over the leak and the well was brought online again until it failed another TIFL in 2023. To bring the well back online, we request approval to proceed with a rig workover to pull and replace the tubing. The 3-1/2” tubing will be pulled from a pre-rig cut above the packer, and a new 3-1/2” completion including a non-sealing overshot, gas lift mandrels, and a stacked packer will be installed. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 2B-02A Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 216-087 Page 1 of 2 PPre-Rig Work Remaining 1. T-POT/PPPOT and IC-POT/PPPOT. 2. Function test LDS. 3. Pull catcher and RBP at 6405’ RKB. 4. Get updated SBHP survey. 5. Set RBP below upper packer. 6. Pull GLV’s and install DV’s, leaving GLM above the upper packer open for a circulation point. 7. CMIT-TxIA against plug. 8. MIT-OA. 9. CDDT-TxIAxOA. 10. Tubing cut at ~6,350’ RKB. Punch hole in tubing above cut if necessary for circulation point. 11. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 2B-02A. No BPV will be set for MIRU due to Nordic 3 internal risk assessment. 2. Circulate seawater. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. Circulate KWF as needed. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve 3-1/2” Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the pre-rig cut at ~6,350’ RKB. a. If all tubing down to pre-rig cut cannot be pulled, move to “Contingency: Grow and stretch 7” casing” section. 6. If significant corrosion is seen on tubing cut joint, PU DP and RIH with fishing BHA, engage tubing stub and jar sealing overshot free. a. The Camco packer at 6377’ RKB is retrievable, but a C-sand cement squeeze was pumped on 8/19/2016, so we do not anticipate releasing the packer while jarring. b. If tubing cut joint is in good condition, move to “Install 3-1/2” completion with Stacked Packer” section. Contingency: Grow and stretch 7” casing 7. MU bait sub to tubing, RIH with DP and drop off tubing on tubing stub. 8. Set plug or storm packer in 7” casing. PT to confirm plug is set. 9. ND BOPE. ND tubing head using Cameron casing detensioning system to grow casing. Pull casing in tension and land in slips. Cut off excess casing and set packoffs, NU tubing head. 10. NU BOPs. Test flange breaks. 11. Release and pull plug/storm packer. 12. Pull remaining tubing section down to pre-rig cut at ~6350’ RKB. 2B-02A Kuparuk Producer Pull and Replace Tubing with Stacked Packer RWO PTD: 216-087 Page 2 of 2 Install 3-1/2” Completion with Stacked Packer 13. RIH with casing scraper and dress off mill to tubing stub and dress off stub as needed. 14. MU new 3-1/2” completion with non-sealing overshot, packer, nipple profile, and GLMs. RIH to tubing stub. 15. Once on depth, space out as needed. Circulate corrosion inhibited fluid. 16. Land tubing hanger, RILDS, drop ball/rod, and set packer. 17. Pressure test tubing to 3,000 PSI. 18. Pressure test IA to 2,500 PSI. ND BOP, NU Tree 19. Shear out SOV with pressure differential. 20. Install BPV and test. ND BOPE. NU tree. PT Tree and packoffs. 21. Pull BPV and freeze protect well. 22. RDMO. PPost-Rig Work 1. Pull DVs and SOV. Install GLD. 2. Pull ball/rod used for setting packer. 3. Pull RBP and catcher. General Well Information: Estimated Start Date: 10/8/2024 Current Operations: Shut-In Well Type: Producer Wellhead Type: Vault PC S-218 11”- 3M casing head top flange. 7-1/16”- 5M tubing head top flange. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Static BHP: 3,284 psi / 5,837’ TVD measured on 9/15/2023 MPSP: 2,700 psi using 0.1 psi/ft gradient Scope of Work: Pull the existing 3-1/2” completion to a pre-rig cut, fish the sealing overshot if concerns of future access through it are seen based on tubing condition, install a new 3-1/2” completion with a stacked packer. Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Reservoir Surveillance Engineer: Mandy Pogany Production Engineer: Kristian Fredagsvik Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:2B-02A pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled patch, set RBP & Catcher sub 2B-02A 9/15/2023 rogerba Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread A LATERAL 2 3/8 2.00 8,465.5 9,570.0 6,060.9 4.43 L-80 2.375 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.5 Set Depth … 6,615.6 Set Depth … 6,018.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD 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) 30.5 30.5 0.00 HANGER 8.000 GRAY TUBING HANGER 3.500 1,891.4 1,891.3 0.73 SAFETY VLV 5.937 OTIS FMX SAFETY VALVE, LOCKED OUT 4/18/98 2.813 1,929.0 1,928.9 0.73 GAS LIFT 5.312 CAMCO KBUG 2.875 3,478.3 3,458.2 21.04 GAS LIFT 5.312 CAMCO KBUG 2.875 4,837.0 4,574.3 36.51 GAS LIFT 5.312 CAMCO KBUG 2.875 5,863.9 5,397.0 35.96 GAS LIFT 5.312 CAMCO KBUG 2.875 6,324.7 5,774.4 33.92 GAS LIFT 5.312 CAMCO KBUG 2.875 6,359.5 5,803.3 33.71 SBR 4.000 CAMCO OEJ-10 SBR 2.973 6,377.3 5,818.1 33.59 PACKER 5.937 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 6,489.4 5,911.9 32.76 BLAST RINGS 4.500 BLAST RINGS (3) 2.992 6,598.7 6,004.1 32.26 SEAL ASSY 4.563 LOCATOR SEAL ASSEMBLY 3.000 6,599.5 6,004.9 32.25 PACKER 5.937 BAKER FB-1 PERMANENT PACKER 4.000 6,602.0 6,007.0 32.25 SBE 4.000 BAKER SEAL BORE EXTENSION 3.000 6,611.4 6,014.9 32.28 NIPPLE 4.540 CAMCO D NIPPLE NO GO (MILLED ON 8/16/2016 from 2.75" to 2.80") 2.800 6,614.7 6,017.7 32.28 WLEG 4.500 CAMCO SHEAR OUT SUB, ELMD TTL @ 6608' ON SWS PPROF DATED 1/5/07 2.937 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) 6,345.0 5,791.3 33.80 LEAK - TUBING LDL found tubing leak @6345' 8/28/2020 2.992 6,397.6 5,835.0 33.47 CATCHER Set catcher sub on top of RBP 9/15/2023 0.000 6,405.6 5,841.7 33.41 RBP Set PIIP RBP (OAL = 9.89') 4.01' from top of packer to EQ valve. Set mid-element @ 6408' RKB TTS CPP3 5326/ CPEQ 35042 9/15/2023 0.000 6,598.0 6,003.6 32.26 CTD 2 3/8" Liner 2B-02AL1-01 CTD Liner 10/27/2016 1.990 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) 1,929.0 1,928.9 0.73 1 GAS LIFT GLV BK 1 1,275.0 5/2/2022 Camco BK 0.156 3,478.3 3,458.2 21.04 2 GAS LIFT GLV BTM 1 1,317.0 5/3/2022 0.188 4,837.0 4,574.3 36.51 3 GAS LIFT GLV BTM 1 1,314.0 5/2/2022 0.188 5,863.9 5,397.0 35.96 4 GAS LIFT GLV BK 1 1,308.0 5/2/2022 0.188 6,324.7 5,774.4 33.92 5 GAS LIFT OV BTM 1 0.0 7/9/2023 0.188 6,414.7 5,849.4 33.34 6 PROD CMT CMT 1 6/26/2016 CMT 6,482.9 5,906.5 32.81 7 PROD CMT CMT 1 6/26/2016 CMT 6,582.1 5,990.1 32.33 8 PROD CMT CMT 1 6/26/2016 CMT 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) 8,465.5 6,118.7 89.98 Kick off Plug 2.625 Anchore d 1.000 2B-02A, 9/17/2023 10:12:02 AM Vertical schematic (actual) A LATERAL; 8,465.5-9,570.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.5 IPERF; 6,586.0-6,588.0 Cement; 6,586.0 ftKB PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 IPERF; 6,526.0-6,568.0 C-SAND FRAC; 6,526.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 RBP; 6,405.5 CATCHER; 6,397.6 PACKER; 6,377.3 LEAK - TUBING; 6,345.0 GAS LIFT; 6,324.7 GAS LIFT; 5,863.9 GAS LIFT; 4,837.0 GAS LIFT; 3,478.3 SURFACE; 34.1-2,727.2 GAS LIFT; 1,929.0 SAFETY VLV; 1,891.3 CONDUCTOR; 35.0-110.0 KUP PROD KB-Grd (ft) 38.40 RR Date 8/23/1984 Other Elev… 2B-02A ... TD Act Btm (ftKB) 9,570.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115401 Wellbore Status PROD Max Angle & MD Incl (°) 101.59 MD (ftKB) 8,690.45 WELLNAME WELLBORE2B-02A Annotation Last WO: End DateH2S (ppm) 65 Date 11/21/2015 Comment SSSV: LOCKED OUT COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 110 110 16 15.06 62.5 H-40 Welded Surface 2,727.30 2,726.80 9-5/8 8.92 36 J-55 BTC Production 6,933.60 6,286.80 7 6.28 26 J-55 BTC "A" Liner 9,570 6,060.90 2-3/8 1.992 4.6 L-80 ST-L "AL1" Liner 10,222 5,997.00 2-3/8 1.992 4.6 L-80 ST-L "AL1-01" Liner 9,750 6,125.50 2-3/8 1.992 4.6 L-80 ST-L Tubing (Existing)6,615 6,017.70 3-1/2 2.992 9.3 J-55 EUE 8RD Tubing (Proposed)6,359.50 5,803.30 3-1/2 2.992 9.3 L-80 EUE 8RD 2B-02A Proposed Schematic 9-5/8" 36# J-55 shoe @ 2727' MD 7" 26# J-55 shoe @ 6934' MD 16" 62# H-40 shoe @ 110' MD A-sand perfs (sqz'd) 6,620' - 6,710' MD KOP @ 6640' MD C-sand perfs (sqz'd) 6,526' - 6,568' MD 6,586' - 6,588' MD 2B-02A TD = 9570' MD 2-3/8" slotted liner w/ anchored billet TOL = 8,466' MD, BOL = 9570' MD 2B-02AL1 TD = 10230' MD 2-3/8" slotted liner w/ anchored billet TOL = 8808' MD, BOL = 10222' MD2B-02AL1-01 TD = 9754' MD 2-3/8" slotted liner w/ deployment sleeve TOL = 6598' MD, BOL = 9750'MD PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" x 1-1/2" Gas Lift Mandrels @ TBD 3-1/2" x 7" Packer 3-1/2" x 2.813" X Nipple 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Camco OEJ-10 SBR (Sealing overshot section pulled)@ 6,359' RKB (2.973" min ID) Camco HRP-1-SP Retrievable Packer @ 6,377' RKB Blast Rings @ 6,489' RKB 3-1/2" Camco production mandrels @ 6,415', 6,483', 6582' RKB Baker Locator Assembly @ 6,599' RKB Baker FB-1 packer @ 6,599' RKB (6588' PDC) (4.0" ID) Baker SBE @ 6,602' RKB 3-1/2" Camco DS nipple @ 6,611' RKB (6600' PDC) Milled out to 2.80" ID pre-CTD Camco SOS @ 6,615' RKB (6604' PDC) 2B-02APB1 TD = 8070' MD Anchored billet = 7580' MD 1 Christianson, Grace K (OGC) From:Eller, Cy <Cy.Eller@conocophillips.com> Sent:Thursday, September 19, 2024 12:53 PM To:Loepp, Victoria T (OGC) Cc:Hobbs, Greg S Subject:RE: [EXTERNAL]RE: KRU 2B-02 10-403 Hi Victoria, Here is what I was able to Ʊnd to answer your questions from our phone call. The 7” production casing TOC is estimated to be 5,486’ RKB, per the 9/17/1984 CBL that was run. The anticipated set depth for the new packer is approximately 6,280’ RKB. Please let me know if you have any other questions. Thank you! Cy Eller RWO/CTD Engineer ConocoPhillips Alaska OƯice: 907-265-6049 Cell: 907-232-4090 From: Eller, Cy Sent: Thursday, September 19, 2024 8:48 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Manning, Leslie <Leslie.Manning@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2B-02 10-403 Hi Victoria, I wanted to inform you that the expected date for commencing operations on the 2B-02 workover will be as soon as 9/28/24, instead of the 10/8/24 date listed on the 10-403. The rig workover on 1L-08 has been moving much faster than anticipated. No drift issues were observed so we did not replace the 7” casing. This has accelerated the Nordic 3 rig schedule, we expect to move to 1L-28 tomorrow and 2B-02 is the next well after that. I apologize for the rush on these sundry applications lately, thank you for your patience. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska OƯice: 907-265-6049 2 Cell: 907-232-4090 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Monday, September 9, 2024 4:21 PM To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com > Cc: Eller, Cy <Cy.Eller@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com > Subject: [EXTERNAL]RE: KRU 2B-02 10-403 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. This application has been received for processing. Thank you, GGrace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain conƱdential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without Ʊrst saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Monday, September 9, 2024 3:10 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Eller, Cy <Cy.Eller@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com > Subject: KRU 2B-02 10-403 Hello – See attached 10-403 for KRU 2B-02. Please let me know if you need additional information. Thank you, Jenna 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. TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 2BͲ01 50Ͳ029Ͳ21147Ͳ00 184115_2BͲ01_PPROF_18Feb2023 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 2DͲ07 50Ͳ029Ͳ21169Ͳ00 184143_2DͲ07_IPROF_10Jun2023 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 2DͲ15 50Ͳ029Ͳ21184Ͳ00 184160_2DͲ15_PPROF_04Jun2023 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 2FͲ13 50Ͳ029Ͳ21032Ͳ00 183156_2FͲ13_WFL_29Jun2023 2HͲ02 50Ͳ103Ͳ20032Ͳ00 184073_2HͲ02_IPROFͲWFL_13Jun2023 6 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38362 T38363 T38364 T38365 T38366 T38367 T38368 T38369 T38370 T38371 T38733 216-087 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:48:05 -08'00' Originated:Delivered to:9-Nov-20 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 # 1 1A-24 50-029-22984-00 906642121 Kuparuk River Plug Setting Record Field- Final 5-Aug-20 0 1 2 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 25-Aug-20 0 1 3 1F-19 50-029-22660-00 906642776 Kuparuk River Packer Setting Record Field- Final 6-Aug-20 0 1 4 1Y-27 50-029-22379-00 n/a Kuparuk River Production Profile Field- Final 29-Aug-20 0 1 5 2B-02A 50-029-21154-01 906679203 Kuparuk River Multi Finger Caliper Field- Processed 29-Aug-20 0 1 6 2C-15 50-029-21219-00 n/a Kuparuk River Packer Setting Record Field- Final 30-Aug-20 0 1 7 2G-08 50-029-21125-00 906659316 Kuparuk River Packer Setting Record Field- Final 16-Aug-20 0 1 8 2L-301 50-103-20588-00 906671629 Kuparuk River Plug Setting Record Field- Final 24-Aug-20 9 2L-301 50-103-20588-00 906671629 Kuparuk River Tubing Punch Record Field- Final 25-Aug-20 10 2M-33 50-103-20240-00 906598622 Kuparuk River Leak Detect Log Field- Final 13-Aug-20 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: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 2160870 E-Set: 34224 Originated:Delivered to:9-Nov-20 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 # 1 2N-345A 50-103-20264-01 906623204 Tarn Perforation Record Field- Final 25-Jul-20 0 1 2 2U-02 50-029-21268-00 906648446 Kuparuk River Packer Setting Record Field- Final 11-Aug-20 0 1 3 CPF-1A 50-029-21243-00 n/a Shallow Sands Leak Detect Log Field- Final 26-Aug-20 0 1 4 2G-08 50-029-21125-00 906640095 Kuparuk River Leak Detect Log and Plug Setting RecordField- Final 4-Aug-20 0 1 5 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 7-Aug-20 6 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 8-Aug-20 7 2M-33 50-103-20240-00 906598622 Kuparuk River Multi Finger Caliper Field- Processed 9-Aug-20 0 1 8 1A-23 50-029-22131-00 n/a Kuparuk River Leak Detect Log Field- Final 11-Aug-20 0 1 9 2B-02A 50-029-21154-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Aug-20 0 1 10 2M-10 50-103-20157-00 906659029 Kuparuk River Multi Finger Caliper Field- Processed 15-Aug-20 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: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 2160870 E-Set: 34223 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch ConocoPhillips Alaska, Inc.Development Exploratory 3. Address: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 9570 feet N/A feet true vertical 6060 feet N/A feet Effective Depth measured 6598 feet 6377 feet true vertical 6004 feet 5818 feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth)3.5" J-55 6616' MD 6018' TVD Packers and SSSV (type, measured and true vertical depth)Packer CAMCO HRP-1 SP 6377' MD 5818' TVD SSSV OTIS FMX 1891' MD 1891' TVD 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: 9/23/2020 Contact Phone: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist N/A Authorized Name: Authorized Signature with date: ----- Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure N/A Representative Daily Average Production or Injection Data 6526-6568, 6580-6582, 6586-6588, 6608-6610, 6620-6710 5943-5978, 5988-5990, 5993-5995, 6012-6014 ,6022-6098 ----- N/AProduction6903769346287N/A N/ASurface26939 5/8 2727 2727 N/A Packer measured true vertical Casing Length Burst Collapse Conductor 75 16 110 110 N/A N/A Kuparuk River/Kuparuk River Oil Plugs measured Junk measured Size MD TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: 216-087 50029211540100 ADL0025655/ADL0025656 KRU 2B-02A P.O. Box 100630, Anchorage, Alaska 99508 N/A t Fra O 216 6. A G L PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:19 am, Sep 25, 2020 Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.09.23 16:07:21 -08'00' SFD 9/25/2020 RBDMS HEW 9/28/2020 DSR-9/28/2020VTL 10/01/20 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 23, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 2B-02A (PTD 216-087). Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.09.23 16:06:41 -08'00' Date Event Summary for 2B-02A Executive Summary Set tubing patch from 6339'-6359' over known tubing leak at 6345'. 09/21/20 RAN 3 1/2 TTS TEST TO UPPER 2.72" P2P @ 6339.25' RKB, CMIT TBG x IA 2500 PSI PASSED. JOB COMPLETE. PRE MIT 1075/1075/650 INITIAL MIT 2575/2575/660 15 MINS 2560/2525/660 30 MINS 2550/2510/660 ***** PASSED**** 09/20/20 BRUSH n' FLUSH TBG FROM 6400' TO 6300', TIE INTO CALIPER LOG SET LOWER 2.72" P2P @ 6353' RKB (ME) (OAL 4.01' / SN:CPP35278), RAN 3 1/2 TTS TEST TOOL TO LOWER PACKER @ 6353' RKB WHILE PRESSURING TBG &IA UP FOR COMBO LOWER PACKER MOVED DOWN 6359.5' RKB (ME), CMIT 2500 PASS, RAN SMART 3 1/2 TTS TOOLS TIE IN CALIPER LOG TAG PACKER @ 6359' RKB (ME), SET UPPER 2.72" PATCH ASSEMBLY (OAL 21'.1" / SN: CPP35296 / CPAL35169), GOOD DRAW DOWN ON IA. IN PROGRESS. PRESSURE TBG & IA TO TEST INITIAL T/I/O= 2525/2500/570, 15 MIN T/I/O= 2500/2475/570, 30 MIN T/I/O= 2500/2425/570 ****PASS***** 08/27/20 RAN LDL FROM 6409' RKB TO SURFACE, DURING LDL D&D PACK OFF PLUG @ 6409' RKB FAILED TO HOLD PRESSURE, ABLE TO STILL PERFORM LDL & FIND LEAK POINT @ 6345' RKB, SET 2ND 3.5" D&D PACKOFF @ 6404' RKB (TOP), SET 3.5" SLIP STOP @ 6403' RKB (TOP), SET 3.5" AVA CATCHER ON SLIP STOP @ 6403' RKB, PULLED OV @ 6325' RKB, LRS TO CIRC WELL OUT OVERNIGHT. IN PROGRESS PUMPED 152 BBL CI S/W FOLLOWED BY 70 BBLS DIESEL DOWN TBG TAKING RETURN OFF IA INTO PRODUCTION. U-TUBE FOR TUBING AND IA FREEZE PROTECT CMIT TXIA TO 2500 PSI ***PASSED*** JOB COMPLETE C-MIT TO 2500 PSI T/I/O PRE MIT 1075/1075/650 INITIALS 2575/2575/660 15 MINS 2560/2525/660 30 MINS 2550/2510/660 ***** PASSED**** 06/11/20 (AC EVAL) SI-TIFL (FAILED DUE TO HIGH INITIAL IA FLUID LEVEL) T/I/O = SI 900/1325/800. T FL @ SF. IA FL @ 2358'' (3966' above st #5, OV). Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:2B-02A pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET TUBING PATCH 9/20/2020 2B-02A condijw Casing Strings Casing Description A LATERAL OD (in) 2 3/8 ID (in) 2.00 Top (ftKB) 8,465.5 Set Depth (ftKB) 9,570.0 Set Depth (TVD) … 6,060.9 Wt/Len (l… 4.43 Grade L-80 Top Thread 2.375 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 30.5 Set Depth (ft… 6,615.6 Set Depth (TVD) (… 6,018.4 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.5 30.5 0.00 HANGER GRAY TUBING HANGER 3.500 1,891.4 1,891.3 0.73 SAFETY VLV OTIS FMX SAFETY VALVE, LOCKED OUT 4/18/98 2.813 6,359.5 5,803.3 33.71 SBR CAMCO OEJ-10 SBR 2.973 6,377.3 5,818.1 33.59 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 6,489.4 5,911.9 32.76 BLAST RINGS BLAST RINGS (3) 2.992 6,598.7 6,004.1 32.26 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 6,599.5 6,004.9 32.25 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,602.0 6,007.0 32.25 SBE BAKER SEAL BORE EXTENSION 3.000 6,611.4 6,014.9 32.28 NIPPLE CAMCO D NIPPLE NO GO (MILLED ON 8/16/2016 from 2.75" to 2.80") 2.800 6,614.7 6,017.7 32.28 WLEG CAMCO SHEAR OUT SUB, ELMD TTL @ 6608' ON SWS PPROF DATED 1/5/07 2.937 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,339.5 5,786.7 33.83 PATCH - PACKER 2.72" PATCH ASSEMBLY, OAL 21.1' 9/20/2020 1.620 CPP35296 6,343.5 5,790.0 33.81 SPACER PIPE 2-1/16" P110 SPACER PIPE 9/20/2020 CPAL35169 6,345.0 5,791.3 33.80 LEAK - TUBING LDL found tubing leak @6345' 8/28/2020 2.992 6,359.5 5,803.3 33.71 PATCH - PACKER 2.72" P2P SET @ 6353' RKB (ME), SLIPPED TO 6359.5, 4.01' OAL 9/20/2020 1.620 CPP35278 6,598.0 6,003.6 32.26 CTD 2 3/8" Liner 2B-02AL1-01 CTD Liner 10/27/2016 1.990 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 1,929.0 1,928.9 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,280.0 6/14/2018 2 3,478.3 3,458.2 CAMCO KBUG 1 GAS LIFT GLV BTM 0.188 1,329.0 6/14/2018 3 4,837.0 4,574.3 CAMCO KBUG 1 GAS LIFT GLV BTM 0.188 1,336.0 6/13/2018 4 5,863.9 5,397.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,341.0 6/13/2018 5 6,324.7 5,774.4 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 8/28/2020 6 6,414.7 5,849.4 CAMCO KBUG 1 PROD CMT CMT 6/26/2016 CMT 7 6,482.9 5,906.5 CAMCO KBUG 1 PROD CMT CMT 6/26/2016 CMT 8 6,582.1 5,990.1 CAMCO KBUG 1 PROD CMT CMT 6/26/2016 CMT 2B-02A, 9/21/2020 5:38:47 AM Vertical schematic (actual) A LATERAL; 8,465.5-9,570.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.5 Cement; 6,586.0 ftKB IPERF; 6,586.0-6,588.0 PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 C-SAND FRAC; 6,526.0 IPERF; 6,526.0-6,568.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 PATCH - PACKER; 6,359.5 SPACER PIPE; 6,343.5 LEAK - TUBING; 6,345.0 PATCH - PACKER; 6,339.5 GAS LIFT; 6,324.7 GAS LIFT; 5,863.9 GAS LIFT; 4,837.0 GAS LIFT; 3,478.3 SURFACE; 34.1-2,727.2 GAS LIFT; 1,929.0 SAFETY VLV; 1,891.3 CONDUCTOR; 35.0-110.0 KUP PROD KB-Grd (ft) 38.40 Rig Release Date 8/23/1984 2B-02A ... TD Act Btm (ftKB) 9,570.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292115401 Wellbore Status PROD Max Angle & MD Incl (°) 101.59 MD (ftKB) 8,690.45 WELLNAME WELLBORE2B-02A Annotation Last WO: End DateH2S (ppm) 65 Date 11/21/2015 Comment SSSV: LOCKED OUT 2B-02A, 9/21/2020 5:38:48 AM Vertical schematic (actual) A LATERAL; 8,465.5-9,570.0 "AL1-01" Lateral Liner Assembly; 6,597.8-9,750.0 CTD 2 3/8" Liner ; 6,598.0 PRODUCTION; 31.2-6,933.6 FISH; 6,685.0 IPERF; 6,620.0-6,710.0 Whipstock; 6,640.0 APERF; 6,608.0-6,610.0 PACKER; 6,599.5 Cement; 6,586.0 ftKB IPERF; 6,586.0-6,588.0 PRODUCTION; 6,582.1 APERF; 6,580.0-6,582.0 C-SAND FRAC; 6,526.0 IPERF; 6,526.0-6,568.0 PRODUCTION; 6,482.9 PRODUCTION; 6,414.7 PACKER; 6,377.3 PATCH - PACKER; 6,359.5 SPACER PIPE; 6,343.5 LEAK - TUBING; 6,345.0 PATCH - PACKER; 6,339.5 GAS LIFT; 6,324.7 GAS LIFT; 5,863.9 GAS LIFT; 4,837.0 GAS LIFT; 3,478.3 SURFACE; 34.1-2,727.2 GAS LIFT; 1,929.0 SAFETY VLV; 1,891.3 CONDUCTOR; 35.0-110.0 KUP PROD 2B-02A ... WELLNAME WELLBORE2B-02A Annotation Last WO: End Date 2 160 87 3 0 3 5 7 RECEIVED Conoc+ Phillips FEB 11 2019 TRANSMITTAL A®GCC FROM: Sandra D. Lemke, ATO -704 TO: Abby Bell ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. Th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 26-02A DATE: 02/11/2019 Transmitted: CC: 26-02A - e -transmittal well folder Receipt: Date: Alaskaff GGRE I Con oc illips Alaska I Office: 907.265.6947; Mobile 907 440 4512 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160870 Well Name/No. KUPARUK RIV UNIT 213-02A n F 1-0 Operator CONOCOPHILLIPS ALASKA INC MD 9570 TVD 6060 Completion Date 10/27/2016 Completion Status 1-0I1- Current Status 1 -OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log C 27706 Log Header Scans ED C 27706 Digital Data ED C 27706 Digital Data ED C 27707 Digital Data ED C 27707 Digital Data Log C 27707 Log Header Scans ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data ED C 27743 Digital Data AOGCC API No. 50-029-21154-01-00 UIC No Samples Nov Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 0 0 2160870 KUPARUK RIV UNIT 2R-n2A I nC; 11/9/2016 11/9/2016 11/9/2016 11/9/2016 0 0 6376 9570 12/6/2016 12/6/2016 12/6/2016 12/6/2016 p 12/6/2016 12/6/2016 12/6/2016 12/6/2016 12/6/2016 12/6/2016 12/6/2016 12/6/2016 Page I of 4 HEADERS Electronic File: 213-02A EOW - NAD27.pdf Electronic File: 26-02A EOW - NAD27.txt Electronic File: 213-02AP131 EOW - NAD27.pdf ' Electronic File: 213-02AP61 EOW - NAD27.txt - 2160870 KUPARUK RIV UNIT 213-02AP61 LOG HEADERS Electronic Data Set, Filename: 213-02A GAMMA RES.Ias Electronic File: 26-02A 21VID Final.cgm Electronic File: 26-02A 5MD Final.cgm Electronic File: 26-02A 5TVDSS Final.cgm' Electronic File: 26-02A 21VID Final.pdf Electronic File: 213-02A 5MD Final.pdf - Electronic File: 213-02A 5TVDSS Final.pdf , Electronic File: 213-02A EOW - NAD27.pdf Electronic File: 213-02A EOW - NAD27.txt Electronic File: 213-02A Survey Listing.txt Electronic File: 213-02A Surveys.txt Electronic File: 213-02A_Final Surveys TD 9570 confirmed.csv Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160870 Well Name/No. KUPARUK RIV UNIT 213-02A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21154-01-00 MD 9570 TVD 6060 Completion Date 10/27/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 27743 Digital Data 12/6/2016 Electronic File: 213- 02A_25_tapescan_B H I_CTK.txt ED C 27743 Digital Data 12/6/2016 Electronic File: 2B-02A_5_tapescan_BHI_CTK.txt' ED C 27743 Digital Data 12/6/2016 Electronic File: 2B-02A_output.tap ' ED C 27743 Digital Data 12/6/2016 Electronic File: 26-02A 2MD Final.tif ED C 27743 Digital Data 12/6/2016 Electronic File: 213-02A 51VID Final.tif ' ED C 27743 Digital Data 12/6/2016 Electronic File: 26-02A 5TVDSS Final.tif Log C 27743 Log Header Scans 0 0 2160870 KUPARUK RIV UNIT 213-02A LOG HEADERS Log C 27744 Log Header Scans 0 0 2160870 KUPARUK RIV UNIT 26-02AP61 LOG HEADERS ED C 27744 Digital Data 6376 8070 12/6/2016 Electronic Data Set, Filename: 213-02AP61 GAMMA RES.Ias ED C 27744 Digital Data 12/6/2016 Electronic File: 213-02AP61 21VID Final.cgm , ED C 27744 Digital Data 12/6/2016 Electronic File: 213-02AP131 5MD Final.cgm ED C 27744 Digital Data 12/6/2016 Electronic File: 2B-02APB1 5TVDSS Final.cgm ED C 27744 Digital Data P12/6/2016 Electronic File: 26-02APB1 21VID Final.pdf ` ED C 27744 Digital Data ` 12/6/2016 Electronic File: 26-02AP61 51VID Final.pdf ' ED C 27744 Digital Data 12/6/2016 Electronic File: 2B-02APB1 5TVDSS Final.pdf ED C 27744 Digital Data 12/6/2016 Electronic File: 2B-02APB1 EOW - NAD27.pdf . ED C 27744 Digital Data 12/6/2016 Electronic File: 213-02AP131 EOW - NAD27.txt ED C 27744 Digital Data 12/6/2016 Electronic File: 213-02AP61 Survey Listing.txt ED C 27744 Digital Data 12/6/2016 Electronic File: 213-02AP151 Surveys.txt ED C 27744 Digital Data 12/6/2016 Electronic File: 2B-02APB1_Final Survey.csv ' ED C 27744 Digital Data 12/6/2016 Electronic File: 213- 02APB1_25_tapescan_BHI_CTK.txt ' ED C 27744 Digital Data 12/6/2016 Electronic File: 213- 02APB 1 _5_tapescan_B H I_CTK.txt+ ED C 27744 Digital Data 12/6/2016 Electronic File: 26-02AP61_output.tap ED C 27744 Digital Data 12/6/2016 Electronic File: 2B-02APB1 2MD Final.tif , ED C 27744 Digital Data 12/6/2016 Electronic File: 213-02AP131 51VID Final.tif , AOGCC' Page 2 of 4 Friday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160870 Well Name/No. KUPARUK RIV UNIT 213-02A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21154-01-00 MD 9570 TVD 6060 Completion Date 10/27/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 27744 Digital Data 12/6/2016 Electronic File: 213-02AP131 5TVDSS Final.tif ED C 27747 Digital Data 11/15/2016 Electronic File: 2B-02A_MFC24_11OCT16.pdf . ED C 27747 Digital Data 11/15/2016 Electronic File: 26- 02A_MFC24_11 OCT 16_LAS .zi p ED C 27747 Digital Data 11/15/2016 Electronic File: 213- 02A_M F C24_11 OCT 16_Report. pdf ED C 27747 Digital Data 11/15/2016 Electronic File: 213- 02A_MFC24_11 OCT16_img.tif ED C 27747 Digital Data 11/15/2016 Electronic File: 28- 02A_MFC24_11OCT16_CENTERED.cmi- ED C 27747 Digital Data 11/15/2016 Electronic File: 26- 02A_MFC24_11 OCT16_CENTERED.wvd ED C 27747 Digital Data 11/15/2016 Electronic File: 213- 02A_MFC24_11 OCT16_CENTERED.wvp ED C 27747 Digital Data 11/15/2016 Electronic File: 213- 02A_MFC24_11 OCT 16_UNCENTERED.cmi ED C 27747 Digital Data 11/15/2016 Electronic File: 26- 02A_MFC24_11OCT16_UNCENTERED.wvd , ED C 27747 Digital Data 11/15/2016 Electronic File: 213- 02A_MFC24_11OCT16_UNCENTERED.wvp ' Log C 27747 Log Header Scans 0 0 2160870 KUPARUK RIV UNIT 26-02AP61 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report 0 Production Test Informatiocy NA Geologic Markers/Tops O COMPLIANCE HISTORY AOGCC Directional / Inclination Data 0 Mud Logs, Image Files, Digital Data Y /� Core Chips Y / Mechanical Integrity Test Information Y /10A Composite Logs, Image, Data Files 9 Core Photographs Y /'� Daily Operations Summary 0 Cuttings Samples Y / lA Laboratory Analyses Y / �lA/ Page 3 of 4 Fiiday, February 17, 2017 DATA SUBMITTAL COMPLIANCE REPORT 2/17/2017 Permit to Drill 2160870 Well Name/No. KUPARUK RIV UNIT 2B -02A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21154-01-00 MD 9570 TVD 6060 Completion Date 10/27/2016 Completion Status 1-0I1- Current Status 1-0I1- UIC No Completion Date: 10/27/2016 Release Date: 8/16/2016 Description Date Comments Comments: Compliance Reviei Date: AOGC(' Page 4 of 4 Friday, February 17, 2017 ECEIV E M12 DEC 16 BAKER PRINT DISTRIBUTION LIST HUGHES AOGGG COMPANY ConocoPhillips Alaska, Inc. WELL NAME 213-02A FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Riderp_bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. SO* PERSON ATTENTION C+] �4- 27 74 3 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED %2-/ t3/ao1cq 700 G Street. M. K. BENDER Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 27, 2016 TODAYS DATE December 5, 2016 Revision No Details: Requested by: --- FIELD FINAL CD 1 CD LOGS LOGS I (digital/image) Surveys (Final Surveys) # OF PRINTS # Ur NKiN 1 S # OF COPIES # OF COPIES # OF COPIE *** Stamp "confidential' on all material deliver to DNR IG 4 4 4 4 4 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. 0 0 0 Attn: Ricky Elgaricio ATO 3-344 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska 0 0 0 Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 (Anchorage, AK 99503 4 State of Alaska - AOGCC 1 1 1 Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** 0 1 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 1 1 1 6 �BP Exploration (Alaska) Inc. 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 7 ConocoPhilli s p DEC 0 6 201L ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B -02A 50-029-21154-01 Baker Hughes INTEQ //a I Definitive Survey Report HUGFIES 04 November, 2016 ConocoPhillips //ar ConocoPhillips Definitive Survey Report KER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 26-02 Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (213-02) Site: Kuparuk 213 Pad MD Reference: 26-02 @ 126.00usft (213-02) Well: 213-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2B-02 Well Position +N/-S 0.00 usft Northing: 5,954,890.07usft Latitude: 70° 17' 16.702 N +E/-W 0.00 usft Easting: 508,370.93usft Longitude: 149° 55'56,081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 26-02A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I 1') (nT) BGG M2016 10/11/2016 17.90 80.90 57,541 Design 213-02A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,560.37 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (I 126.00 0.00 0.00 200.00 Survey Program Date 11/1/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 28-02 (213-02) GCT-MS Schlumberger GCT multishot 1/12/2001 6,640.00 7,560.37 213-02AP131 (26-02AP81) MWD MWD - Standard 10/8/2016 10/15/2016 7,580.00 9,535.13 213-02A (213-02A) MWD MWD - Standard 10/16/2016 10/18/2016 11/4/2016 7:31 24AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips F/RI ConocoPhilli p s BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well 2B-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (26-02) Site: Kuparuk 2B Pad MD Reference: 213-02 @ 126.00usit (2B-02) Well: 213-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W DLS (usft) (°) (� (usft) (usft) (usft) (usft) Northing East) (0/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 7,560.37 91.08 190.01 6,095.85 5,969.85 -2,708.85 -852.92 5,952,180.54 507,521.11 11.43 2,837.20 MWD (2) TIP 7,580.00 91.22 192.09 6,095.45 5,969.45 -2,728.11 -856.68 5,952,161.28 507,517.37 10.62 2,856.58 MWD (3) KOP 7,610.75 87.82 192.82 6,095.71 5,969.71 -2,758.13 -863.31 5,952,131.26 507,510.78 11.31 2,887.06 MWD (3) 7,640.61 86.99 195.95 6,097.06 5,971.06 -2,787.02 -870.72 5,952,102.36 507,503.40 10.83 2,916.75 MWD (3) 7,670.70 88.50 202.17 6,098.25 5,972.25 -2,815.42 -880.53 5,952,073.95 507,493.62 21.26 2,946.79 MWD (3) 7,700.71 86.28 204.13 6,099.62 5,973.62 -2,842.99 -892.32 5,952,046.38 507,481.87 9.86 2,976.72 MWD (3) 7,730.33 87.14 207.97 6,101.32 5,975.32 -2,869.55 -905.30 5,952,019.80 507,468.91 13.26 3,006.12 MWD (3) 7,760.29 89.57 211.73 6,102.18 5,976.18 -2,895.51 -920.20 5,951,993.82 507,454.04 14.94 3,035.62 MWD (3) 7,790.53 88.77 216.84 6,102.61 5,976.61 -2,920.49 -937.23 5,951,968.83 507,437.04 17.10 3,064.91 MWD (3) 7,820.01 90.03 221.67 6,102.92 5,976.92 -2,943.31 -955.88 5,951,945.99 507,418.42 16.93 3,092.73 MWD (3) 7,850.77 88.80 225.19 6,103.24 5,977.24 -2,965.64 -977.02 5,951,923.64 507,397.31 12.12 3,120.95 MWD (3) 7,880.40 87.79 228.51 6,104.12 5,978.12 -2,985.89 -998.62 5,951,903.36 507,375.73 11.71 3,147.37 MWD (3) 7,910.38 87.51 232.94 6,105.35 5,979.35 -3,004.85 -1,021.81 5,951,884.38 507,352.57 14.79 3,173.12 MWD (3) 7,940.31 86.43 235.66 6,106.93 5,980.93 -3,022.29 -1,046.07 5,951,866.92 507,328.32 9.77 3,197.80 MWD (3) 7,970.56 84.25 239.53 6,109.39 5,983.39 -3,038.45 -1,071.52 5,951,850.74 507,302.90 14.65 3,221.69 MWD (3) 8,000.68 86.47 243.16 6,111.83 5,985.83 -3,052.84 -1,097.86 5,951,836.32 507,276.58 14.09 3,244.22 MWD (3) 8,030.53 87.79 246.92 6,113.32 5,987.32 -3,065.41 -1,124.88 5,951,823.71 507,249.57 13.33 3,265.28 MWD (3) 8,060.34 89.08 250.86 6,114.14 5,988.14 -3,076.14 -1,152.68 5,951,812.95 507,221.79 13.90 3,284.87 MWD (3) 8,090.45 90.00 255.25 6,114.38 5,988.38 -3,084.92 -1,181.47 5,951,804.15 507,193.01 14.90 3,302.96 MWD (3) 8,120.51 89.39 259.26 6,114.54 5,988.54 -3,091.55 -1,210.78 5,951,797.49 507,163.71 13.49 3,319.22 MWD (3) 8,150.35 89.42 263.34 6,114.85 5,988.85 -3,096.06 -1,240.27 5,951,792.94 507,134.23 13.67 3,333.54 MWD (3) 8,180.51 89.69 268.26 6,115.08 5,989.08 -3,098.27 -1,270.34 5,951,790.70 507,104.16 16.34 3,345.90 MWD (3) 8,210.41 88.10 272.17 6,115.66 5,989.66 -3,098.16 -1,300.23 5,951,790.78 507,074.28 14.11 3,356.02 MWD (3) 8,240.15 88.59 276.58 6,116.52 5,990.52 -3,095.89 -1,329.86 5,951,793.01 507,044.65 14.91 3,364.02 MWD (3) 8,270.47 88.96 280.43 6,117.17 5,991.17 -3,091.41 -1,359.84 5,951,797.46 507,014.67 12.75 3,370.06 MWD (3) 8,300.34 90.58 283.72 6,117.29 5,991.29 -3,085.16 -1,389.04 5,951,803.67 506,985.46 12.28 3,374.18 MWD (3) 8,330.45 87.57 287.33 6,117.77 5,991.77 -3,077.10 -1,418.04 5,951,811.70 506,956.46 15.61 3,376.53 MWD (3) 8,360.47 88.46 291.19 6,118.81 5,992.81 -3,067.21 -1,446.36 5,951,821.56 506,928.13 13.19 3,376.92 MWD (3) 8,390.71 90.83 296.07 6,119.00 5,993.00 -3,055.09 -1,474.05 5,951,833.64 506,900.43 17.94 3,375.00 MWD (3) 8,420.74 89.97 294.18 6,118.79 5,992.79 -3,042.34 -1,501.24 5,951,846.36 506,873.23 6.91 3,372.32 MWD (3) 11/4/2016 7 31:24AM Page 3 COMPASS 5000.1 Build 74 Survey ConocoPhillips .. ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (213-02) Site: Kuparuk 2B Pad MD Reference: 26-02 @ 126.00usft (26-02) Well: 213-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 2B-02 Database: EDM Alaska NSK Sandbox Survey HEkv BAKER HUGHES 11/4/2016 7:31:24AM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/-S+E1-W Northing rth g Eag DLS Section on Survey Tool Name Annotation (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 8,450.91 90.34 290.81 6,118.71 5,992.71 -3,030.80 -1,529.11 5,951.857.87 506,845.35 11.24 3,371.01 MWD (3) 8,480.88 89.60 286.88 6,118.73 5,992.73 -3,021.12 -1,557.47 5,951.867.52 506,816.98 13.34 3,371.61 MWD (3) 8,510.24 90.09 282.49 6,118.81 5,992.81 -3,013.68 -1,585.86 51951,874.93 506,788.58 15.05 3,374.33 MWD (3) 8,540.39 90.61 279.17 6,118.62 5,992.62 -3,008.02 -1,615.47 5,951,880.56 506,758.97 11.15 3,379.13 MWD (3) 8,570.37 91.97 275.73 6,117.95 5,991.95 -3,004.13 -1,645.18 5,951,884.41 506,729.26 12.34 3,385.65 MWD (3) 8,600.26 94.58 273.49 6,116.24 5,990.24 -3,001.73 -1,674.92 5,951.886.77 506,699.52 11.50 3,393.56 MWD (3) 8,630.38 96.43 271.96 6,113.35 5,987.35 -3,000.31 -1,704.87 5,951,888.17 506,669.57 7.96 3,402.47 MWD (3) 8,660.24 98.78 268.99 6,109.40 5,983.40 -3,000.06 -1,734.46 5,951,888.38 506,639.99 12.61 3,412.35 MWD (3) 8,690.45 101.59 266.13 6,104.05 5,978.05 -3,001.32 -1,764.16 5,951,887.09 506,610.29 13.17 3,423.70 MWD (3) 8,720.23 101.33 263.33 6,098.14 5,972.14 -3,004.00 -1,793.22 5,951,884.37 506,581.24 9.26 3,436.16 MWD (3) 8,750.32 100.74 260.57 6,092.38 5,966.38 -3,008.14 -1,822.46 5,951.880.20 506,552.00 9.21 3,450.04 MWD (3) 8,780.32 99.55 257.32 6,087.09 5,961.09 -3,013.80 -1,851.44 5,951,874.51 506,523.03 11.38 3,465.28 MWD (3) 8,810.30 96.80 254.50 6,082.83 5,956.83 -3,021.03 -1,880.21 5,951,867.25 506,494.27 13.07 3,481.91 MWD (3) 8,840.24 94.98 251.87 6,079.75 5,953.75 -3,029.64 -1,908.72 5.951,858.61 506,465.78 10.64 31499.75 MWD (3) 8,870.33 91.78 247.65 6,077.98 5,951.98 -3,040.03 -1,936.89 5,951.848.19 506,437.62 17.58 3,519.15 MWD (3) 8,900.33 91.23 244.05 6,077.19 5,951.19 -3,052.30 -1,964.25 5,951,835.89 506,410.28 12.14 3,540.04 MWD (3) 8,930.34 91.17 241.36 6,076.56 5,950.56 -3,066.06 -1,990.91 5,951.822.10 506,383.63 8.96 3,562.08 MWD (3) 8,960.33 93.19 238.45 6,075.42 5,949.42 -3,081.08 -2,016.83 5,951.807.05 506,357.73 11.81 3,585.07 MWD (3) 8,990.31 92.58 235.03 6,073.91 5,947.91 -3,097.50 -2,041.87 5,951,790.61 506,332.72 11.57 3,609.06 MWD (3) 9,020.28 91.32 231.09 6,072.89 5,946.89 -3,115.50 -2,065.80 5,951,772.59 506,308.80 13.79 3,634.16 MWD (3) 9,050.46 91.35 228.44 6,072.19 5,946.19 -3,134.99 -2,088.83 5,951.753.07 506,285.80 8.78 3,660.35 MWD (3) 9,080.28 92.95 225.43 6,071.07 5,945.07 -3,155.33 -2,110.60 5,951,732.71 506,264.05 11.42 3,686.91 MWD (3) 9,110.40 94.64 221.67 6,069.08 5,943.08 -3,177.11 -2,131.30 5,951,710.91 506,243.38 13.66 3,714.45 MWD (3) 9,140.56 95.10 218.50 6,066.51 5,940.51 -3,200.10 -2,150.65 5,951,687.90 506,224.06 10.58 3,742.67 MWD (3) 9,170.29 94.36 214.87 6,064.06 5,938.06 -3,223.85 -2,168.35 5.951,664.13 506,206.39 12.42 3,771.05 MWD (3) 9,200.64 93.32 211.65 6,062.03 5,936.03 -3,249.17 -2,184.95 5,951,638.79 506,189.81 11.13 3,800.52 MWD (3) 9,230.39 92.98 208.02 6,060.39 5,934.39 -3,274.93 -2,199.73 5,951.613.02 506,175.07 12.24 3,829.78 MWD (3) 9,260.45 91.14 205.79 6,059.31 5,933.31 -3,301.72 -2,213.32 5,951,586.22 506,161.51 9.61 3,859.60 MWD (3) 9,290.47 90.67 202.27 6,058.84 5,932.84 -3,329.13 -2,225.54 5,951,558.80 506,149.32 11.83 3,889.54 MWD (3) 9,320.55 90.68 199.67 6,058.48 5,932.48 -3,357.21 -2,236.31 5,951,530.70 506,138.59 8.64 3,919.61 MWD (3) 9,350.37 91.10 195.83 6,058.02 5,932.02 -31385.60 -2,245.39 5,951,502.31 506,129.53 12.95 3,949.40 MWD (3) HEkv BAKER HUGHES 11/4/2016 7:31:24AM Page 4 COMPASS 5000.1 Build 74 Annotation eAks BAKER HUGHES 11/4/2016 7:31:24AM Page 5 COMPASS 5000.1 Build 74 )W' ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (213-02) Site: Kuparuk 2B Pad MD Reference: 2B-02 @ 126.00usft (28-02) Well: 213-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing DLS Easting Section (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100') Survey Tool Name (ft) (ft) (ft) 9,380.29 89.51 193.01 6,057.86 5,931.86 -3,414.58 -2,252.84 5,951,473.33 506,122.11 10.82 3,979.17 MWD (3) 9,410.62 88.80 190.04 6,058.31 5,932.31 -3,444.29 -2,258.90 5,951,443.61 506,116.09 10.07 4,009.16 MWD (3) 9,440.41 88.93 186.48 6,058.90 5,932.90 -3,473.76 -2,263.18 5,951,414.14 506,111.84 11.96 4,038.32 MWD (3) 9,470.23 88.96 182.79 6,059.45 5,933.45 -3,503.47 -2,265.59 5,951,384.43 506,109.47 12.37 4,067.06 MWD (3) 9,500.47 88.13 177.94 6,060.22 5,934.22 -3,533.69 -2,265.78 5,951,354.21 506,109.31 16.27 4,095.53 MWD (3) 9,535.13 89.91 175.53 6,060.81 5,934.81 -3,568.29 -2,263.81 5,951,319.62 506,111.32 8.64 4,127.36 MWD (3) 9,570.00 89.91 175.53 6,060.86 5,934.86 -3,603.05 -2,261.09 5,951,284.86 506,114.08 0.00 4,159.10 PROJECTED to TD Annotation eAks BAKER HUGHES 11/4/2016 7:31:24AM Page 5 COMPASS 5000.1 Build 74 F'P'daa BAKER DEC 09 ?Of;' HUGHES PRINT DISTRIBUTION LIST v COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2B-02APB1 FIELD Prudhoe Bay Unit COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bakerhughes.com 21 6087 27 74 4 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp DATA LOGGED 700 G Street. l2/t3/201Co M. K. BENDER Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE October 27, 2016 TODAYS DATE December 5, 2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BO$ PERSON ATTENTION FIELD FINAL CD 0 CD 0 LOGS LOGS (digital/image) Surveys 1# (Final Surveys) # OF PRINTS # OF NKIN 16 # OF COPIES OF COPIES # OF COPIE]:::::] 1 3 ExxonMobil, Alaska 0 0 0 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. 1 1 1 Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn: Ricky Elgaricio 5 DNR -Division of Oil & Gas *** 0 1 'ATO 3-344 Attn: Resource Evaluation 700 G Street X550 West 7th Avenue, Suite 1100 Anchorage, AK 99510 Anchorage, Alaska 99501 3 ExxonMobil, Alaska 0 0 0 IAttn: Lynda M. Yaskell and/or Leonardo Elias 13201 C Street, Suite 505 Anchorage, AK 99503 41,StateofAlaska -AOGCC 1 1 1 Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR -Division of Oil & Gas *** 0 1 1 Attn: Resource Evaluation X550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. 1 1 1 Petrotechnical Data Center, LR2-1 X900 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 s� ConocoPhillips , F. I�f0 DEC 0 6 2016 lOG (A a ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B-02APB1 50-029-21154-70 Baker Hughes INTEQ Definitive Survey Report 04 November, 2016 21E787 2774, MIA a I BAKER HUGHES ConocoPhillips F/&I ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 26-02 @ 126.00usft (213-02) Site: Kuparuk 215 Pad MD Reference: 2B-02 @ 126.00usft (26-02) Well: 2B-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2B-02 Well Position +N/ -S 0.00 usft Northing: 5,954,890.07usft Latitude: 700 17' 16.702 N +E/ -W 0.00 usft Easting: 508,370.93usft Longitude: 1490 55'56.081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2B-02APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I V) (nT) BGGM2016 10/1/2016 17.90 80.90 57,541 Design 213-02AP131 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,600.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 126.00 0.00 0.00 200.00 Survey Program Date 10/15/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 26-02 (213-02) GCT -MS Schlumberger GCT multishot 1/12/2001 6,640.00 8,040.05 26-02APB1 (26-02AP61) MWD MWD - Standard 10/8/2016 10/15/2016 11/4/2016 7:27:42AM Page 2 COMPASS 5000 1 Build 74 ConocoPhillips /GF1I ConocoPhillips Definitive Survey Report NVER Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (26-02) Site: Kuparuk 28 Pad MD Reference; 26-02 @ 126.00usft (213-02) Well: 213-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS +N/ -S +E1 -W Map Map DLS Vertical (usft) (°) (1) (-ft) W) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name (ft) (ft) (ft) 6,600.00 32.25 197.72 6,005.25 5,879.25 -1,819.78 -673.36 5,953,069.72 507,699.67 0.49 1,940.34 MWD (2) 6,640.00 32.34 197.88 6,039.06 5,913.06 -1,840.13 -679.89 5,953,049.37 507,693.16 0.31 1,961.69 MWD (2) 6,661.15 38.27 195.74 6,056.31 5,930.31 -1,851.83 -683.41 5,953,037.67 507,689.65 28.64 1,973.89 MWD (2) 6,690.35 49.50 193.69 6,077.33 5,951.33 -1,871.38 -688.50 5,953,018.11 507,684.58 38.76 1,994.01 MWD (2) 6,720.22 61.41 192.16 6,094.24 5,968.24 -1,895.32 -693.97 5,952,994.17 507,679.14 40.09 2,018.37 MWD (2) 6,750.21 73.50 191.38 6,105.71 5,979.71 -1,922.39 -699.60 5,952,967.10 507,673.54 40.38 2,045.73 MWD (2) 6,782.11 86.10 189.29 6,111.35 5,985.35 -1,953.21 -705.21 5,952,936.27 507,667.96 40.02 2,076.62 MWD (2) 6,810.68 95.72 189.29 6,110.90 5,984.90 -1,981.37 -709.82 5,952,908.11 507,663.39 33.67 2,104.65 MWD (2) 6,840.67 100.03 189.92 6,106.79 5,980.79 -2,010.66 -714.78 5,952,878.82 507,658.46 14.52 2,133.87 MWD (2) 6,870.60 100.68 191.86 6,101.41 5,975.41 -2,039.57 -720.34 5,952,849.91 507,652.94 6.74 2,162.94 MWD (2) 6,900.67 97.42 194.40 6,096.68 5,970.68 -2,068.48 -727.08 5,952,820.99 507,646.22 13.68 2,192.41 MWD (2) 6,930.80 95.41 189.88 6,093.31 5,967.31 -2,097.74 -733.38 5,952,791.72 507,639.96 16.33 2,222.06 MWD (2) 6,960.75 93.13 186.09 6,091.08 5,965.08 -2,127.31 -737.52 5,952,762.15 507,635.85 14.74 2,251.27 MWD (2) 6,990.75 90.71 182.80 6,090.08 5,964.08 -2,157.20 -739.85 5,952,732.26 507,633.56 13.61 2,280.15 MWD (2) 7,020.80 89.29 180.16 6,090.08 5,964.08 -2,187.24 -740.62 5,952,702.23 507,632.82 9.98 2,308.64 MWD (2) 7,050.63 88.80 183.87 6,090.57 5,964.57 -2,217.04 -741.67 5,952,672.43 507,631.80 12.54 2,337.00 MWD (2) 7,080.87 88.50 188.10 6,091.29 5,965.29 -2,247.10 -744.82 5,952,642.37 507,628.68 14.02 2,366.32 MWD (2) 7,110.73 88.34 192.27 6,092.11 5,966.11 -2,276.47 -750.10 5,952,612.99 507,623.44 13.97 2,395.73 MWD (2) 7,141.31 91.47 197.32 6,092.16 5,966.16 -2,306.02 -757.90 5,952,583.44 507,615.67 19.43 2,426.17 MWD (2) 7,170.25 91.01 201.47 6,091.53 5,965.53 -2,333.31 -767.51 5,952,556.14 507,606.09 14.42 2,455.10 MWD (2) 7,200.03 89.75 203.82 6,091.34 5,965.34 -2,360.79 -778.97 5,952,528.65 507,594.66 8.95 2,484.84 MWD (2) 7,230.37 87.79 206.79 6,091.99 5,965.99 -2,388.21 -791.94 5,952,501.22 507,581.73 11.73 2,515.04 MWD (2) 7,260.43 88.07 204.42 6,093.07 5,967.07 -2,415.30 -804.92 5,952,474.12 507,568.78 7.93 2,544.93 MWD (2) 7,290.33 89.02 200.73 6,093.83 5,967.83 -2,442.89 -816.39 5,952,446.52 507,557.34 12.74 2,574.79 MWD (2) 7,320.44 88.37 196.84 6,094.52 5,968.52 -2,471.38 -826.08 5,952,418.02 507,547.68 13.10 2,604.88 MWD (2) 7,350.42 87.27 193.08 6,095.66 5,969.66 -2,500.32 -833.82 5,952,389.07 507,539.98 13.06 2,634.71 MWD (2) 7,380.46 88.86 189.60 6,096.67 5,970.67 -2,529.75 -839.72 5,952,359.64 507,534.11 12.73 2,664.39 MWD (2) 7,410.71 89.29 185.78 6,097.16 5,971.16 -2,559.72 -843.76 5,952,329.67 507,530.10 12.71 2,693.93 MWD (2) 7,440.21 89.35 182.34 6,097.51 5,971.51 -2,589.14 -845.85 5,952,300.25 507,528.05 11.66 2,722.29 MWD (2) 7,470.75 89.82 178.50 6,097.73 5,971.73 -2,619.67 -846.08 5,952,269.72 507,527.86 12.67 2,751.06 MWD (2) Annotation TIP KOP 11/4/2016 7:27 42AM Page 3 COMPASS 5000 1 Build 74 ConocoPhillips BAKER•• ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 28-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (26-02) Site: Kuparuk 28 Pad MD Reference: 213-02 @ 126.00usft (26-02) Well: 213-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc AN TVD TVDSS +N1S +El -W Northing Northing EMap DLS Section Section Survey Tool Name (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (°1100') 7,500.35 91.69 182.25 6,097.34 5,971.34 -2,649.26 -846.27 5,952,240.13 507,527.70 14.16 2,778.93 MWD (2) 7,530.35 91.47 186.60 6,096.52 5,970.52 -2,679.15 -848.58 5,952,210.24 507,525.42 14.51 2,807.81 MWD (2) 7,560.37 91.08 190.01 6,095.85 5,969.85 -2,708.85 -852.92 5,952.180.54 507,521.11 11.43 2,837.20 MWD (2) 7,590.32 91.29 193.18 6,095.23 5,969.23 -2,738.18 -858.93 5,952,151.21 507,515.13 10.61 2,866.82 MWD (2) 7,620.32 93.38 196.60 6,094.01 5,968.01 -2,767.14 -866.63 5,952,122.24 507,507.46 13.35 2,896.67 MWD (2) 7,650.35 93.13 200.61 6,092.30 5,966.30 -2,795.55 -876.20 5,952,093.83 507,497.93 13.36 2,926.63 MWD (2) 7,685.35 92.52 203.51 6,090.57 5,964.57 -2,827.94 -889.33 5,952,061.42 507,484.84 8.46 2.961.56 MWD (2) 7,710.16 94.49 206.52 6,089.06 5,963.06 -2,850.38 -899.80 5,952,038.97 507,474.40 14.48 2,986.23 MWD (2) 7,740.29 96.15 209.71 6,086.26 5,960.26 -2,876.84 -913.93 5,952,012.51 507,460.29 11.89 3,015.92 MWD (2) 7,770.31 95.26 212.71 6,083.28 5,957.28 -2,902.38 -929.41 5,951,986.95 507,444.85 10.38 3,045.22 MWD (2) 7,800.29 91.57 213.83 6,081.49 5,955.49 -2,927.40 -945.82 5,951,961.91 507,428.46 12.86 3,074.34 MWD (2) 7,830.39 87.73 214.63 6,081.68 5,955.68 -2,952.28 -962.75 5,951,937.02 507,411.56 13.03 3,103.51 MWD (2) 7,860.17 83.85 215.72 6,083.86 5,957.86 -2,976.55 -979.85 5,951,912.73 507,394.49 13.53 3,132.17 MWD (2) 7,890.74 80.34 217.05 6,088.07 5,962.07 -3,000.92 -997.81 5,951,888.34 507,376.56 12.26 3,161.22 MWD (2) 7,921.01 79.12 219.96 6,093.46 5,967.46 -3,024.23 -1,016.35 5,951,865.01 507,358.05 10.28 3,189.46 MWD (2) 7,950.58 78.03 223.48 6,099.32 5,973.32 -3,045.86 -1,035.64 5,951,843.36 507,338.79. 12.24 3,216.38 MWD (2) 7,980.51 77.44 227.46 6,105.68 5,979.68 -3,066.37 -1,056.48 5,951,822.84 507,317.97 13.14 3,242.78 MWD (2) 8,010.38 76.99 231.10 6,112.30 5,986.30 -3,085.37 -1,078.55 5,951,803.81 507,295.92 11.98 3,268.18 MWD (2) 8,040.05 75.88 234.84 6,119.26 5,993.26 -3,102.73 -1,101.57 5,951,786.42 507,272.92 12.61 3,292.38 MWD (2) 8,070.00 75.88 234.84 6,126.56 6,000.56 -3,119.46 -1,125.32 5,951,769.67 507,249.20 0.00 3,316.22 PROJECTED to TD Annotation 111412016 7:27 42AM Page 4 COMPASS 5000.1 Build 74 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑� Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[:] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑✓ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 10/27/2016 14. Permit to Drill Number / Sundry: 216-087 . 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/13/2016 15. API Number: 50-029-21154-01-00 , 4a. Location of Well (Governmental Section): Surface: 744' FSL, 273' FEL, Sec. 19, T11 N, R9E, UM Top of Productive Interval: 2996' FSL, 1826' FEL, Sec 30, T11 N, R9E, UM Total Depth: 2419' FSL, 2547' FEL, Sec 30, T11 N, R9E, UM 8. Date TD Reached: 10/17/2016 16. Well Name and Number: KRU 213-02A 9. Ref Elevations: KB: 126' GL 92' BF: 92' 17. Field / Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25656 J.6 SSS 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 508371 y- 5954890 Zone- 4 TPI: x- 506832 y- 5951862 Zone- 4 Total Depth: x- 506114 y- 5951284 Zone- 4 11. Total Depth MD/TVD: 9570' / 6060' 19. Land Use Permit: ALK 2582 12. SSSV Depth MD/TVD: 1891'/ 1891' 20. Thickness of Permafrost MD/TVD: 1526'/ 1526' 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 6640'/ 6039' 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 V RECEI GR/RES NOV 2 2 2016 AOGC 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD HOLE SIZE CEMENTING RECORD SETTING DEPTH TVD CASING FT TOP BOTTOM TOP BOTTOM AMOUNT PULLED 16" 62.5# H-40 35' 110' 35' 110' 24 119 sx Cold Set II 9-5/8" 36.0# J-55 34' 2727' 34' 2727' 12-1/4" 800 sx Cold Set III & 300 sx Cold Set II 7" 26.0# J-55 31' 6934' 31' 6287' 8-1/2" 280 sx Class G & 250 sx Cold Set I 2-3/8" 4.6 L-80 8465' 9570' 6119' 6060' 3 Slotted Liner 24. Open to production or injection? Yes ❑✓ No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): Slotted Liner: 8465' - 9570'/ 6119'- 6060' TVD COMPLETION DAT (oh --l- II (P VERIFIED L v 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2" 6616' 6377'/ 5818' 6600'/ 6005' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 11/7/2016 Method of Operation (Flowing, gas lift, etc.): Gas lift Date of Test: 11/8/2016 Hours Tested: 17:08 Production for Test Period Oil -Bbl: 169 Gas -MCF: 1799 Water -Bbl: 535 Choke Size: 176 Gas -Oil Ratio: 3152 Flow Tubing Press. 182 Casinq Press: 1188 Calculated 24 -Hour Rate Oil -Bbl: 237 Gas -MCF: 749 Water -Bbl: 2520 Oil Gravity - API (corr): Not sampled Form 10-407 Revised 11/2015 V/% L 7i!/_ //7-C_ONTINUED ON PAGE 2 Submit ORIGINAL onl�r eve �l/�,/��- ��1 ��7 �t�DMS �v NOV 2 3 2016 /� Jt 28. CORE DATA Conventional C. s): Yes ❑ No 0 Sidewall Cores. es ❑ No 0 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 El If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1526' 1526' Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. Top of Productive Interval 6640' 6039' (Kuparuk A Sand) Formation at total depth: 9570' 6060' (Kuparuk A Sand) 31. List of Attachments: Summary of daily operations, schematic and final directional surveys. 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Keith Herring @ 263-4321 Email: Keith. E. HerrirgjQgpp.com Printed Name: G. Eller Title: CTD Team Lead Signature: Phone: 263-4172 Date: W b INSTRUCTIONS General: This form and the req>5ired attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only 16" 62# H-40 shoe MD '40# J-55 @ 2727' P C -sand perfs (sqz'd) 6,526' - 6,568' MD 6,586'- 6,588' MD KOP @ 6640' MD A -sand perfs (sgz'd) 6,620' - 6,710' MD 7" 26# J-55 shoe @ 6934' MD 2B-02 CTD Schematic Modified by KEH 10/31/16 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Otis FMX SSSV at 1812' RKB (locked out 4/98) 3-1/2" Camco gas lift mandrels @ 1,929', 3,478', 4,837', 5,8641, 6,325' RKB Camco OEJ-10 SBR @ 6,359' RKB (2.973" min ID) Camco HRP -1 -SP Retrievable Packer @ 6,377' RKB Blast Rings @ 6,489' RKB 3-1/2" Camco production mandrels @ 6,415', 6,483', 6582' RKB Baker Locator Assembly @ 6,599' RKB Baker FB -1 packer @ 6,599' RKB (6588' PDC) (4.0" ID) Baker SBE @ 6,602' RKB 3-1/2" Camco DS nipple @ 6,611' RKB (6600' PDC) Milled out to 2.80" ID pre -CTD Camco SOS @ 6,615' RKB (6604' PDC) 2B-02AL1 TO = 10230' MD 2B-02AL1-01 TO = 9754' MD 2-3/8" slotted liner w/ anchored billet 2-3/8" slotted liner w/ deployment sleeve TOL = 8808' MD, BOL = 10222' MD TOL = 6598' MD, BOL = 9750'MD ----- ----- ----------- ---- 2B-02A TO = 9570' MD 2B-02APB1 2-3/8" slotted liner w/ anchored billet TO = 8070' MD TOL = 8,466' MD, BOL = 9570' MD Anchored billet = 7580' MD uperations Summary (with Timelog 6,dpths) r . 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/8/2016 10/8/2016 3.50 MIRU MOVE RURD P Trucks on location, PJSM, hook up 06:00 09:30 jeeps, secure cellar, perform premove check list, secure pit module, 10/8/2016 10/8/2016 3.50 MIRU MOVE MOB P Spot modules over well 02, release 09:30 13:00 trucks, lower BOPE's, work on post rig move check list. 10/8/2016 10/8/2016 3.00 MIRU MOVE RURD P Start rig up checklist. Hook up steam. 13:00 16:00 berm celler. Hook up PUTZ interconnect. RU flowline. 10/8/2016 10/8/2016 2.00 MIRU MOVE NUND P NU BOPE. Install choke hose and 16:00 18:00 annular hydraulics. Check tree bolts. Grease tree valves and BOP valves. 10/8/2016 10/8/2016 3.50 MIRU WHDBOP RURD P MU test joint. Fluid pack an shell 18:00 21:30 test.Test swabs. Circulate air out of coiled tubing into sump, Test inner reel valve RIG ACCEPT 18:00 10/8/2016 10/9/2016 2.50 MIRU WHDBOP BOPE P Begin testing BOPE to 250/3750 psi. 21:30 00:00 2,500 psi on the annular. State witness by Jeff Jones. 10/9/2016 10/9/2016 6.00 MIRU WHDBOP BOPE P Continue testing BOPE to 250/3750 0.0 0.0 00:00 06:00 psi. 2,500 psi on the annular. State witness by Jeff Jones. 10/9/2016 10/9/2016 2.00 MIRU WHDBOP RURD P RD testing equipment, freeze protect 0.0 0.0 06:00 08:00 test pump, store test joint back onto rack in pipe shed. Load out AC unit. 10/9/2016 10/9/2016 1.00 MIRU WHDBOP CTOP P Install checks in Upper Quick, PIT 0.0 0.0 08:00 09:00 tiger tank line and pac-off, send 30 slings out the beaver slide 10/9/2016 10/9/2016 2.50 MIRU WHDBOP MPSP P PJSM, load BPV equipment, PT 0.0 0.0 09:00 11:30 lubricator 2,500 psi, pull BPV, 10/9/2016 10/9/2016 1.50 PROD1 RPEQPT PULD P PJSM, MU milling BHA# 1 0.0 62.5 11:30 13:00 10/9/2016 10/9/2016 1.75 PROD1 RPEQPT TRIP P RIH with Milling BHA# 1, with a 0.9° 62.5 6,410.0 13:00 14:45 bend motor and D331 mill, pumping SW. 10/9/2016 10/9/2016 0.50 PROD1 RPEQPT DLOG P Logged the K1 correction of minus 3.5 6,410.0 6,593.0 14:45 15:15 ft,PUW 31 k 10/9/2016 10/9/2016 4.50 PROD1 RPEQPT MILL P Tag TOC at 6,593 ft, PUH, bring rate 6,593.0 6,598.0 15:15 19:45 up to 1.5 bpm at 3,050 psi, BHP 2,971, WHP 38, IA 4, OA 0, start milling cement. Held up at 6598 ft. Multiple stalls. Can't get re -started. Vary milling parameters to try and improve milling rate. Added powervis to seawater system to help move material. 10/9/2016 10/9/2016 1.50 PROD1 RPEQPT MILL P Roll toolface to 180°. Contine to mill 6,598.0 6,600.0 19:45 21:15 cement. Multiple stalls. 10/9/2016 10/9/2016 1.25 PROD1 RPEQPT MILL P Roll toolface back to 20° ROHS. 6,600.0 6,603.0 21:15 22:30 Continue milling cement. Multiple stalls and re -starts. 10/9/2016 10/9/2016 1.25 PROW RPEQPT MILL P Roll toolface to 180°. Continue milling 6,603.0 6,603.0 22:30 23:45 cement. Multiple stalls and re -starts. 10/9/2016 10/10/2016 0.25 PROD1 RPEQPT MILL P Roll toolface back to 20° ROHS. 6,603.0 6,604.0 23:45 00:00 Continue milling cement. Multiple stalls and re -starts. Page 1115 Report Printed: 1 0131 /2 01 6 uperations Summary (with Timelog bepths) 2B-02 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) 10/10/2016 10/10/2016 1.50 PROD1 RPEQPT MILL P Continue milling cement pilot hole. 1.6 6,604.0 6,618.0 00:00 01:30 bpm at 2200 psi, BHP 2,900, WHP 0. Add 0.5% SafeLube to the system to try and improve milling parameters. 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT MILL P Continue milling cement. Multiple 6,618.0 6,619.0 01:30 02:30 stalls and re -starts. Picked up slightly heavy at 38KIbs. 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P Wiper trip up to 6565 ft. 6,619.0 6,565.0 02:30 02:45 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P RBIH. SOW= 13KIbs. 6,565.0 6,619.0 02:45 03:00 10/10/2016 10/10/2016 3.50 PROD1 RPEQPT MILL P Continue milling cement pilot hole. 6,619.0 6,627.0 03:00 06:30 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P PUH for a tie in PUW 35 k 6,627.0 6,435.0 06:30 06:45 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT DLOG P log the K1 correction of plus 2.0 ft. 6,435.0 6,462.3 06:45 07:00 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P RBIH, RIW 12 k 6,462.3 6,627.0 07:00 07:15 10/10/2016 10/10/2016 10.00 PROD1 RPEQPT MILL P BOBM 1.3 bpm at 1691 psi, BHP 6,627.0 6,670.0 07:15 17:15 2906, WHIP 0, IA 2, OA 0 Multiple stalls and re -starts No tool face changes after 6630 ft, maintaining TF at 20° ROHS. TD pilot hole at 6670 ft. 10/10/2016 10/10/2016 1.50 PROD1 RPEQPT DLOG P PUH and log the K1. No correction. 6,670.0 6,670.0 17:15 18:45 RBIH and confirm TD at 6670 ft. 10/10/2016 10/10/2016 0.75 PROD1 RPEQPT OWFF P PUH. Stop at 6550 ft. Flow check well. 6,670.0 6,550.0 18:45 19:30 Static. 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT CIRC P Pump sweeps, RBIH. 6,550.0 6,670.0 19:30 20:30 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT TRIP P POOH chasing sweeps. Observed 6,670.0 3,000.0 20:30 21:30 loose wraps on the reel. 10/10/2016 10/10/2016 0.50 PROD1 RPEQPT SVRG P Service reel and injector PLC's. 3,000.0 3,000.0 21:30 22:00 Restart electronics. 10/10/2016 10/11/2016 2.00 PROD1 RPEQPT RGRP T Troubleshoot loose wraps on the reel. 3,000.0 3,000.0 22:00 00:00 Suspect ODS pillow block/bearing on reel. Continue troubleshooting. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT TRIP P POOH with BHA#1, monitoring reel 3,000.0 62.0 00:00 00:30 wraps. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT OWFF P At surface. Flow check well. Static. 62.0 62.0 00:30 01:00 10/11/2016 10/11/2016 1.25 PROD1 RPEQPT PULD P LD milling BHA #1. Mill was measured 62.0 0.0 01:00 02:15 2.79" no-go. 10/11/2016 10/11/2016 0.75 PROD1 RPEQPT WWWH P MU nozzle. Clean and flush BOP 0.0 0.0 02:15 03:00 stack. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT SVRG P Service rig, Adjust pillow blocks at the 0.0 0.0 03:00 03:30 reel. 10/11/2016 10/11/2016 1.00 PROD1 RPEQPT PULD P RU HAL. PJSM. PU HAL caliper. Stab 0.0 26.0 03:30 04:30 lubricator. 10/11/2016 10/11/2016 1.75 PROD1 RPEQPT TRIP P RIH with Halliburton caliper. Tie-in to 26.0 6,663.0 04:30 06:15 the K1 for a -1 ft correction. 10/11/2016 10/11/2016 0.75 PROD1 RPEQPT DLOG P Perform two logging passes, pulling 6,663.0 6,200.0 06:15 07:00 up hole at 30 fpm to 6200 ft. 10/11/2016 10/11/2016 1.50 PROD1 RPEQPT TRIP P POOH with HAL caliper. 6,200.0 26.0 07:00 08:30 Page 2/15 Report Printed: 10/31/2016 Uperations Summary (with Timelog Uepths) 2B-02 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) 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT OWFF P Flow check at surface. Static. 26.0 26.0 08:30 08:45 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT PULD P LD HAL Caliper BHA. Caliper data is 26.0 0.0 08:45 09:15 in town for processing. 10/11/2016 10/11/2016 1.00 PROD1 RPEQPT PULD P PJSM. PU and MU whipstock BHA#3 0.0 73.0 09:15 10:15 with open hole anchors. 10/11/2016 10/11/2016 3.00 PROD1 RPEQPT TRIP P RIH with whipstock assembly. Log K1 73.0 6,650.8 10:15 13:15 for a -6 ft correction. No issues RIH. Pilot hole in good condition. 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT WPST P Set WS per Baker rep. 6,650.8 6,650.8 13:15 13:30 10/11/2016 10/11/2016 1.50 PROD1 RPEQPT TRIP P POOH with whipstock running tools. 6,650.8 62.0 13:30 15:00 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT OWFF P Flow check at surface. Static. 62.0 62.0 15:00 15:15 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT PULD P PJSM. LD whipstock setting BHA #3. 62.0 0.0 15:15 15:45 10/11/2016 10/11/2016 0.50 PROD1 WHPST PULD P PJSM. PU and MU window milling 0.0 62.0 15:45 16:15 BHA #4 with 0.6° AKO motor and 2.79" string mill and 2.80" window mill. 10/11/2016 10/11/2016 3.00 PROD1 WHPST TRIP P Run in hole with BHA #4. Log K1 for a 62.0 6,607.0 16:15 19:15 -7ft correction. Finish displacing well over to milling fluid. Clean trip in the hole until stacked out at 6611 ft. PUH and try to run back through area with no success. Stack out at 6607 ft. 10/11/2016 10/11/2016 2.00 PROD1 WHPST TRIP T Multiple attempts made to try and 6,607.0 6,607.0 19:15 21:15 work past 6607 ft. Various combinations of toolfaces, pump rates and running speeds were tried with no successs. PUW's between 30KIbs and 35KIbs. PUH and tie-in to the K1 for a +1 ft correction to confirm depth Discuss hole condtions with town. Make 2 more attempts to work past 6607 ft. Made decsion to POOH. 10/11/2016 10/11/2016 1.50 PROD1 WHPST TRIP T POOH with BHA #4. No issues on the 6,607.0 75.0 21:15 22:45 way out of the hole. 10/11/2016 10/11/2016 0.50 PROD1 WHPST OWFF T Flow check at surface. Static. 75.0 75.0 22:45 23:15 10/11/2016 10/12/2016 0.75 PROD1 WHPST PULD T PJSM. LD BHA#4. 75.0 0.0 23:15 00:00 10/12/2016 10/12/2016 0.75 PROD1 RPEQPT PULD T PJSM. MU BHA #5 with 0.9° AKO 0.0 62.0 00:00 00:45 motor and D331 mill with side structure. 10/12/2016 10/12/2016 1.50 PROD1 RPEQPT TRIP T RIH with BHA #5. Tie in to the K1 for a 62.0 6,630.0 00:45 02:15 -6ft correction. RIH at 20fpm and minimum rate. No issues running past 6607 ft. Observed 1 Klb bobble at 6620 ft. Clean run to 6630 ft. 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T PUH at 180° TF, pumping 1.5 bpm 6,630.0 6,630.0 02:15 03:30 pulling 1 fpm. Small bobble at 6608 ft. Ream down pumping 1.5 bpm at 5 fpm. Ream up hole at 1 fpm. Page 3/15 Report Printed: 10/31/2016 uperations Summary (with Timelog Uepths) 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WEI) 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T Dry drift pilot hole. Weight bobbles at 6,630.0 6,630.0 03:30 04:45 6621 ft and 6623 ft. Discuss results with town. Made decision to perform 2 more reaming passes. 10/12/2016 10/12/2016 0.25 PROD1 RPEQPT TRIP T Dry drift transition area. Continue to 6,630.0 6,640.0 04:45 05:00 dry drfit down and tag TOWS at 6640 ft. 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T PUH to 6585. Open EDC. Continue to 6,640.0 62.0 05:00 06:15 POOH with BHA #5. 10/12/2016 10/12/2016 0.50 PROD1 RPEQPT OWFF T Flow check well. Static. 62.0 62.0 06:15 06:45 10/12/2016 10/12/2016 0.75 PROD1 RPEQPT PULD T PJSM. LD BHA #5. 62.0 0.0 06:45 07:30 10/12/2016 10/12/2016 0.50 PROD1 WHPST PULD T PJSM. MU BHA #6 with 0.6° AKO 0.0 74.0 07:30 08:00 motor, string mill, and window mill. 10/12/2016 10/12/2016 2.25 PROD1 WHPST TRIP T RI with BHA #6. Tie in to the K1 for - 74.0 6,640.0 08:00 10:15 6.5 ft correction. Close EDC. Continue running in the hole and dry tag top of whipstock at 6640 ft. Clean trip through pilot hole. 10/12/2016 10/12/2016 10.00 PROD1 WHPST WPST P Begin milling window per program and 6,640.0 6,649.0 10:15 20:15 Baker rep. Observed sand in samples from BU at 6644 ft. 10/12/2016 10/12/2016 2.00 PROD1 WHPST WPST P Mill rathole to 6661 ft. 6,649.0 6,661.0 20:15 22:15 10/12/2016 10/12/2016 1.25 PROD1 WHPST REAM P PU and dress window in 4 passes. 6,661.0 6,661.0 22:15 23:30 High side, 30° ROHS, 30°LOHS and 180°. Dry drift window. Clean. 10/12/2016 10/13/2016 0.50 PROD1 WHPST OWFF P PUH to 6590 ft. Close choke, bleed 6,661.0 6,590.0 23:30 00:00 WHP to zero in stages. Well static. Manual MW = 8.8 ppg. 10/13/2016 10/13/2016 0.50 PROD1 WHPST MPDA P Open EDC. Bring pump up to drilling 6,590.0 6,590.0 00:00 00:30 rate. Hold 11.8ppgemw at the window. WHP = 484 psi. Friction pressure = 78 psi/1000ft. 10/13/2016 10/13/2016 1.50 PROD1 WHPST TRIP P POOH with BHA #6. Tag up and 6,590.0 67.0 00:30 02:00 space out. 10/13/2016 10/13/2016 0.50 PROD1 WHPST PULD P PJSM. PUD BHA #6. Floats not 67.0 67.0 02:00 02:30 holding. 10/13/2016 10/13/2016 0.50 PROD1 WHPST OWFF P Flow check well. Static. 67.0 67.0 02:30 03:00 10/13/2016 10/13/2016 1.00 PROD1 WHPST PULD P PJSM, lay down BHA #6 over a dead 67.0 0.0 03:00 04:00 well. 10/13/2016 10/13/2016 1.00 PROD1 DRILL PULD P PJSM. MU build BHA #7 with 2.2 ° 0.0 72.0 04:00 05:00 AKO motor and RB HCC bit. Surface test. 10/13/2016 10/13/2016 2.00 PROD1 DRILL TRIP P RIH with BHA V. Tie into the K1 for a 72.0 6,660.0 05:00 07:00 -3 ft correction. Tag bottom of 6660 ft. 10/13/2016 10/13/2016 3.00 PROD1 DRILL DRLG P Drill build section pumping 1.45bpm at 6,660.0 6,717.0 07:00 10:00 4050 psi. BHP = 3750 ft. WOB = 1.7KIbs CTW = 10.0 Klbs. 10/13/2016 10/13/2016 0.50 PROD1 DRILL WPRT P Wiper trip. Tie in to K1 for a +2.5 ft 6,717.0 6,717.0 10:00 10:30 correction. RBIH, log the RA for no correction. 10/13/2016 10/13/2016 3.00 PROD1 DRILL DRLG P Continue drilling the build section to 6,717.0 6,800.0 10:30 13:30 planned section TD. Pump sweeps. 10/13/2016 10/13/2016 2.25 PROD1 DRILL TRIP P POOH with BHA #7. Tag up and 6,800.0 72.0 13:30 15:45 space out. Page 4/15 Report Printed: 10/31/2016 sr �u= operations Summary (with Timelog bepths) 2B-02 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 (f KB) End Depth (ftKB) 10/13/2016 10/13/2016 2.00 PROD1 DRILL PULD P PJSM. PUD build BHA#7. 72.0 0.0 15:45 17:45 10/13/2016 10/13/2016 1.25 PROD1 DRILL PULD P PJSM. PU lateral BHA #8 with 0.8° 0.0 72.0 17:45 19:00 AKO motor and new HCC bit. Tag up and rest depth. 10/13/2016 10/13/2016 2.50 PROD1 DRILL TRIP P RIH with BHA #8. Tie in to K1 for a - 72.0 6,800.0 19:00 21:30 5.5ft correction. Clean pass through window and open hole. 10/13/2016 10/14/2016 2.50 PROD1 DRILL DRLG P Continue drilling A lateral. Pump 1.5 6,800.0 6,894.0 21:30 00:00 bpm at 3940 psi. BHP = 3750 psi.WOB = 1.5KIbs. CTW 10 Klbs. Mud swap. New mud at the bit at 6820 ft. 10/14/2016 10/14/2016 6.50 PROD1 DRILL DRLG P Continue drilling A lateral. Pumping 6,894.0 7,210.0 00:00 06:30 1.53 bpm at 4126 psi. BHP = 3770 psi.WOB = 1.5KIbs. CTW 9 Klbs. ROP 30-50 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P Wiper trip. PUW 36 Klbs 7,210.0 6,660.0 06:30 06:45 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P RBIH. SOW=13KLbs. Clean trip in and 6,660.0 7,210.0 06:45 07:00 out of the hole. 10/14/2016 10/14/2016 4.25 PROD1 DRILL DRLG P BOBD. Purring 1.55 bpm at 4150 psi. 7,210.0 7,406.0 07:00 11:15 BHP 3780 psi. WHP 380 psi. WOB 1.2 -1.9KIbs. CTW = 9 Klbs. ROP 30-60 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P PUH for BHA wiper. PUW 37KIbs. 7,406.0 7,406.0 11:15 11:30 SOW 9KIbs. 10/14/2016 10/14/2016 4.25 PROD1 DRILL DRLG P BOBD. Puming 1.54 bpm at 4130 psi. 7,406.0 7,610.0 11:30 15:45 BHP 3785 psi. WHP 390 psi. WOB 2.1 Klbs. CTW = 5 Klbs. ROP 30-60 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P Wiper trip. PUW = 37 Klbs. 7,610.0 6,759.6- 15:45 16:00 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P RBIH. SOW 9KIbs 6,759.0 7,610.0 16:00 16:15 10/14/2016 10/14/2016 3.75 PROD1 DRILL DRLG P BOBD. Puming 1.54 bpm at 4130 psi. 7,610.0 7,763.0 16:15 20:00 BHP 3785 psi. WHP 390 psi. WOB 2.1 Klbs. CTW = 5 Klbs. ROP 30-60 fph. 10/14/2016 10/14/2016 0.75 PROD1 DRILL WPRT P Geo wiper. PUH. PUW=36 Klbs. Tie in 7,763.0 6,665.0 20:00 20:45 to the RA for a +5.5ft correction. 10/14/2016 10/14/2016 0.50 PROD1 DRILL WPRT P RBIH. SOW 9KIbs. 6,665.0 7,763.0 20:45 21:15 10/14/2016 10/15/2016 2.75 PROD1 DRILL DRLG P BOBD. Pumping 1.50 bpm at 4160 7,763.0 7,876.0 21:15 00:00 psi. BHP 3812 psi. WHP 380 psi. WOB 2.2 Klbs. CTW = 4 Klbs. Start cross cut down. 10/15/2016 10/15/2016 4.75 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 7,876.0 8,070.0 00:00 04:45 1.50 bpm at 4400 psi. BHP 3860 psi. WHP 420 psi. WOB 2.2 Klbs. CTW = 4 Klbs. Continue cross cut down. 10/15/2016 10/15/2016 2.25 PROD1 DRILL TRIP T Pump sweeps. POOH. Tag up. Space 8,070.0 72.0 04:45 07:00 out. 10/15/2016 10/15/2016 2.00 PROD1 DRILL PULD T PJSM. PUD BHA#8. 72.0 0.0 07:00 09:00 10/15/2016 10/15/2016 2.00 PROD1 STK PULD T PJSM. PU BOT Anchored billet 0.0 7,286.0 09:00 11:00 assembly. Load PDL. PD Anchored billet BHA #9. Page 5/15 Report Printed: 10/31/2016 "➢ Uperations Summary (with Timelog Depths) ,_. 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/15/2016 10/15/2016 3.25 FROM STK TRIP T RIH. Log K1 for a -3.5 ft correction. 7,286.0 7,590.0 11:00 14:15 Close EDC. Wt check 6475 ft = 29 Klbs. Saw weight bobble at 7231 ft. Position billet assembly on depth. 10/15/2016 10/15/2016 0.25 PROD1 STK WPST T Bring up pump. Set anchors. Top of 7,590.0 7,590.0 14:15 14:30 billet at 7580 ft. Set down 5KIbs to confirm set. 10/15/2016 10/15/2016 2.00 PROM STK TRIP T POOH. Tag up and space out. 7,590.0 70.0 14:30 16:30 10/15/2016 10/15/2016 2.50 PROD1 STK PULD T PJSM. PUD anchored billet running 70.0 0.0 16:30 19:00 tools BHA #9. Bled off riser. LEL alarm at shaker went off briefly due to gas cap in riser. Non-essential personnel relocated to the shop as a precaution. Crew change, then continued to PUD. 10/15/2016 10/15/2016 0.50 PROM STK BOPE P Function test BOP 0.0 0.0 19:00 19:30 10/15/2016 10/15/2016 1.50 PROM STK CTOP P Change out, rehead BOT UQC. 0.0 0.0 19:30 21:00 Houred out. 10/15/2016 10/15/2016 1.00 PROM STK PULD T PJSM. PD lateral drilling BHA #10 with 0.0 72.0 21:00 22:00 0.8° AKO motor and RR HCC bit. 10/15/2016 10/16/2016 2.00 PROD1 STK TRIP T Run in hole with BHA #10 72.0 5,079.0 22:00 00:00 10/16/2016 10/16/2016 1.50 FROM STK TRIP T Continue RIH. While running in hole, 5,079.0 7,580.0 00:00 01:30 observed decrease in MW out. Sent returns to the tiger tank. Brought mud back inside after 70 bbls. Dry tag billet at 7580 ft. 10/16/2016 10/16/2016 4.25 PROM STK KOST T Time mill off of billet. Aluminum 7,580.0 7,625.0 01:30 05:45 observed over the shaker at BU. One stall. Blow down choke. Continue milling. Dry drift billet area. Clean. 10/16/2016 10/16/2016 4.25 FROM DRILL DRLG T Continue drilling ahead. Pumping 7,625.0 7,980.0 05:45 10:00 1.50 bpm at 4330 psi. BHP 3840 psi. WOB 0.9 Klbs. CTW = 9 Klbs. ROP 70 -110 fph. Start mud swap. New mud at the bit at 7980 ft. 10/16/2016 10/16/2016 0.75 PROD1 DRILL WPRT T Wiper trip. PUW = 33KIbs. 7,980.0 7,100.0 10:00 10:45 10/16/2016 10/16/2016 0.75 PROM DRILL WPRT T RBIH. SOW =10 Klbs 7,100.0 7,980.0 10:45 11:30 10/16/2016 10/16/2016 1.25 FROM DRILL DRLG T Continue drilling ahead. Pumping 7,980.0 8,070.0 11:30 12:45 1.50 bpm at 4245 psi. BHP 3910 psi. WOB 1.3 Klbs. CTW = 4-6 Klbs. ROP 70 fph. 10/16/2016 10/16/2016 5.25 PROM DRILL DRLG P Continue drilling ahead. Pumping 8,070.0 8,380.0 12:45 18:00 1.50 bpm at 4245 psi. BHP 3910 psi. WOB 1.3 Klbs. CTW = 4-6 Klbs. ROP 50-70 fph. 10/16/2016 10/16/2016 0.50 PROD1 DRILL WPRT P Wiper trip. PUW = 36 Klbs 8,380.0 7,180.0 18:00 18:30 10/16/2016 10/16/2016 0.50 PROD1 DRILL WPRT P RBIH. SOW = 8KIbs 7,180.0 8,380.0 18:30 19:00 Page 6115 Report Printed: 10/31/2016 Uperations Summary (with Timelog Depths) 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth (ftKB) 10/16/2016 10/17/2016 5.00 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 8,380.0 8,659.0 19:00 00:00 1.53 bpm at 4200 psi. BHP 3970 psi. WOB 1.0 Klbs. CTW = -3 to -7 Klbs. ROP 40-140 fph. 10/17/2016 10/17/2016 2.25 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 8,659.0 8,767.0 00:00 02:15 1.53 bpm at 4200 psi. BHP 3970 psi. WOB 1.0 Klbs. CTW = -3 to -7 Klbs. ROP 40-140 fph. 10/17/2016 10/17/2016 1.00 PROD1 DRILL WPRT P Pull up hole for tie-in wiper. PUW = 36 8,767.0 6,650.0 02:15 03:15 Klbs. Tie-into the RA for a +5.5 ft correction. 10/17/2016 10/17/2016 1.00 PROD1 DRILL WPRT P RBIH. SOW = 9 Klbs. No significant 6,650.0 8,767.0 03:15 04:15 increase in material over the shaker with sweep at surface. 10/17/2016 10/17/2016 10.50 PROD1 DRILL DRLG P BOBD. Pumping 1.52 bpm at 4100 8,767.0 9,170.0 04:15 14:45 psi. BHP 3930 psi. WOB 1.2 Klbs. CTW = 0 to -3 Klbs. ROP 30-60 fph. BHA wipers at 8955 ft, 9023 ft and 9155 ft. 10/17/2016 10/17/2016 0.25 PROD1 DRILL WPRT P PUH for wiper trip. PUW = 37 Klbs 9,170.0 8,180.0 14:45 15:00 10/17/2016 10/17/2016 0.50 PROD1 DRILL WPRT P RBIH. SOW = 7 Klbs. 8,180.0 9,170.0 15:00 15:30 10/17/2016 10/17/2016 8.25 PROD1 DRILL DRLG P BOBD. Pumping 1.52 bpm at 4100 9,170.0 9,570.0 15:30 23:45 psi. BHP 3930 psi. WOB 1.2 Klbs. CTW = 0 to -3 Klbs. ROP 30-60 fph. 10/17/2016 10/18/2016 0.25 PROD1 DRILL WPRT P PUH for wiper trip. PUW = 37 Klbs 9,570.0 9,150.0 23:45 00:00 10/18/2016 10/18/2016 1.00 PROD1 DRILL WPRT P Continue POOH. 9,150.0 6,600.0 00:00 01:00 10/18/2016 10/18/2016 1.00 PROD1 DRILL SIPB P PUH to 6600 ft MD. 6005 ft TVDrkb for 6,600.0 6,600.0 01:00 02:00 SBHP test. Shut choke with annular pressure of 3750 psi. WHP 900 psi. No change in pressure. Bleed WHP down to 700 psi. Build back up to 900 psi. Annular pressure = 3747 psi. EMW = 12.0 ppg. 10/18/2016 10/18/2016 1.50 PROD1 DRILL WPRT P Continue wiper trip to the swab valve. 6,600.0 95.0 02:00 03:30 10/18/2016 10/18/2016 4.00 PROD1 DRILL WPRT P RBIH, to tie in depth. 95.0 6,647.0 03:30 07:30 10/18/2016 10118/2016 0.25 PROD1 DRILL DLOG P 6647 ft, log RA marker for +18.5 ft 6,647.0 6,679.0 07:30 07:45 correction. 10/18/2016 10/18/2016 2.00 PROD1 DRILL CIRC T PUH and wait on fluids. RIH and log 6,679.0 6,679.0 07:45 09:45 RA marker again for -.5 correction 10/18/2016 10/18/2016 2.00 PROD1 DRILL WPRT P RIH to confirm TD, start stacking wt at 6,679.0 9,500.0 09:45 11:45 9543 ft, RIH 10 FPM. Unable to get past 9543 ft. 10/18/2016 10/18/2016 0.75 PROD1 DRILL CIRC P PUH to 9500 ft. Start circulating 9,500.0 9,540.0 11:45 12:30 beaded liner pill to bottom, 5 bbls pumped, slow to min rate .3 BPM. 10/18/2016 10/18/2016 1.00 PROD1 DRILL WPRT P RBIH to confirm TD, 25 FPM, stack 9,540.0 9,570.0 12:30 13:30 39K. Confirm TD at 9570 ft. 10/18/2016 10/18/2016 4.00 PROD1 DRILL TRIP P POOH laying in beaded liner running 9,570.0 72.2 13:30 17:30 pill to surface and completion fluid, 12.2 PPG completion fluid, 50 FPM, 33K PU WT. Paint flags at 8372 ft and 5472 ft. Continue POOH. Page 7115 Report Printed: 10/31/2016 t - Uperations Summary (with Timelog Depths) 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/18/2016 10/18/2016 0.50 PROD1 DRILL OWFF P Perform 30 min flow check. 72.2 72.2 17:30 18:00 10/18/2016 10/18/2016 0.50 PROD1 DRILL PULD P PJSM, LD drilling BHA# 10 72.2 0.0 18:00 18:30 10/18/2016 10/18/2016 0.50 COMPZ1 CASING PUTB P PJSM, Prep rig floor for MU A lateral 0.0 0.0 18:30 19:00 liner assembly. 10/18/2016 10/18/2016 1.50 COMPZ1 CASING PUTB P MU 36 jts of slotted liner with 10.08' 0.0 1,105.0 19:00 20:30 pup joint. 10/18/2016 10/18/2016 1.00 COMPZ1 CASING PULD P PJSM, MU Coiltrak tools 1,105.0 1,150.0 20:30 21:30 10/18/2016 10/18/2016 2.00 COMPZ1 CASING RUNL P RIH, (open EDC) with A lateral liner 1,150.0 6,576.9 21:30 23:30 assembly with open hole anchored billet 10/18/2016 10/18/2016 0.25 COMPZ1 CASING RUNL P Minus 11.38' correction at the 5,400' 6,579.9 7,530.0 23:30 23:45 EOP flag 10/18/2016 10/19/2016 0.25 COMPZ1 CASING DLOG P 7530', tie into the K1 correction of plus 7,530.0 7,563.0 23:45 00:00 4.5' 10/19/2016 10/19/2016 0.75 COMPZI CASING RUNL P Continue RIH with A liner assembly 7,563.0 9,570.0 00:00 00:45 10/19/2016 10/19/2016 0.25 COMPZ1 CASING RUNL P PUW 36 k, RIH, bring pump up to 9,570.0 8,465.4 00:45 01:00 4,650 psi, release liner on bottom 9,570', TOL 8,465.45', remove liner length from counters 10/19/2016 10/19/2016 1.75 COMPZ1 CASING TRIP P POOH, with setting tools 8,465.4 60.7 01:00 02:45 10/19/2016 10/19/2016 0.50 COMPZ1 CASING OWFF P PJSM, checked well for flow 60.7 60.7 02:45 03:15 10/19/2016 10/19/2016 0.50 COMPZ1 CASING PULD P LD liner setting tools 60.7 0.0 03:15 03:45 10/19/2016 10/19/2016 1.00 PROD2 DRILL PULD P PJSM, PU/MU ALI lateral 0.0 72.2 03:45 04:45 kickoff/drilling BHA# 12, changeout pac-off elements. 10/19/2016 10/1912016 4.00 PROD2 DRILL TRIP P RIH w/ ALI lateral drilling BHA#12 72.2 8,444.0 04:45 08:45 and displace 12.2 completion fluid to 8.9 FloPro (System 2). 10/19/2016 10/19/2016 3.00 PROD2 DRILL KOST P RIH and dry tag TOB at 8466'. PU 8,444.0 8,495.0 08:45 11:45 and start pumping. RBIH and start time milling (Dig trough, 2 FPH for 1', 3 FPH 1', 10 FPH for 5', 20 FPH for 2'). DHWOB 1.2k 10/19/2016 10/19/2016 1.00 PROD2 DRILL DRLG P Drill ahead to 8510. 8,495.0 8,510.0 11:45 12:45 10/19/2016 10/19/2016 0.25 PROD2 DRILL DRLG P PUH and dry drift from 8440' to 8510'. 8,510.0 8,440.0 12:45 13:00 No issues. 10/19/2016 10/19/2016 3.50 PROD2 DRILL DRLG P Drill ahead to 8562' and perform BHA 8,440.0 8,606.0 13:00 16:30 wiper, PU WT 35K. Pump 5x5 sweep. Continue drilling ahead, rotate TF to 50 degrees ROHS, DHWOB 1.51K, ROP 50. 10/19/2016 10/19/2016 4.00 PROD2 DRILL DRLG P New mud at the bit 8,606', continue 8,606.0 8,698.0 16:30 20:30 drilling ahead 10/19/2016 10/19/2016 0.25 PROD2 DRILL WPRT P BHA wiper up hole to 8,600', PUW 39 8,698.0 8,698.0 20:30 20:45 k 10/19/2016 10/19/2016 0.75 PROD2 DRILL DRLG P BOBD 1.57 bpm at 3,580 psi off 8,698.0 8,715.0 20:45 21:30 bottom, BHP 3938, WHP 556, IA 10, OA 11, CTSW= minus 2.0 k, DHWOB=1.4 k. 10/19/2016 10/19/2016 0.25 PROD2 DRILL WPRT P BHA wiper up hole to 8,628', PUW 38 8,715.0 8,715.0 21:30 21:45 k Page 8/15 Report Printed: 1 013112 01 6 uperations Summary (with Timelog Vepths) >YY 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth (ftKB) 10/19/2016 10/20/2016 2.25 PROD2 DRILL DRLG P BOBD 1.58 bpm at 3850 psi off 8,715.0 8,811.0 21:45 00:00 bottom, BHP 3965, WHP 564, IA 10, OA 11, CTSW= minus 7.0 k, DHWOB=1.3 k. 10/20/2016 10/20/2016 1.50 PROD2 DRILL DRLG P OBD 1.56 bpm at 4245 psi, BHP 8,811.0 8,860.0 00:00 01:30 3951, WHP 562, IA 10, OA 11, CTSW=minus 7 k, DHWOB=1.3 k 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole, PUW 37 k 8,860.0 7,660.0 01:30 02:00 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 7 k 7,660.0 8,860.0 02:00 02:30 10/20/2016 10/20/2016 4.50 PROD2 DRILL DRLG P BOBD 1.57 bpm at 3580 psi off 8,860.0 8,983.0 02:30 07:00 bottom, BHP 3,963, WHP 530, IA 15, OA 13 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole, PUW 37K 8,983.0 8,000.0 07:00 07:30 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 7K 8,000.0 8,983.0 07:30 08:00 10/20/2016 10/20/2016 2.00 PROD2 DRILL DRLG P BOBD 1.47 BPM at 4309 psi off 8,983.0 9,030.0 08:00 10:00 bottom, BHP 4338 psi 10/20/2016 10/20/2016 4.00 PROD2 DRILL DRLG P Pump 25BBL beaded pill & 25BBL 9,030.0 9,220.0 10:00 14:00 FloPro sweeps and continue drilling. ROP up to 50 ft/hr. 10/20/2016 10/20/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 44K 9,220.0 9,050.0 14:00 14:15 10/20/2016 10/20/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 6K 9,050.0 9,220.0 14:15 14:30 10/20/2016 10/20/2016 1.00 PROD2 DRILL DRLG P BOBD 1.43 BPM at 4269 psi off 9,220.0 9,260.0 14:30 15:30 bottom, BHP 4418 psi. Continue with beaded pill sweeps 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole, PUW 38K 9,260.0 8,200.0 15:30 16:00 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 6K. 8,200.0 9,260.0 16:00 16:30 10/20/2016 10/20/2016 2.00 PROD2 DRILL TRIP P POOH 9,260.0 72.2 16:30 18:30 10/20/2016 10/20/2016 0.25 PROD2 DRILL PULD P PJSM, PUD/LD drilling BHA# 12 72.2 72.2 18:30 18:45 10/20/2016 10/20/2016 2.25 PROD2 DRILL PULD T Check well for flow, checks aren't 72.2 72.2 18:45 21:00 holding, swap to undeploying with closed EDC, function closed EDC, EDC is holding, looks like the upper checks aren't holding, strip up and close double ball valves, bleed pressure from coil, DBV holding, go back to manage pressure on well bore, 10/20/2016 10/20/2016 1.50 PROD2 DRILL PULD P Continue PUD as per standard 72.2 0.0 21:00 22:30 procedure. 10/20/2016 10/21/2016 1.50 PROD2 DRILL PULD P PU/MU/PD Drilling BHA# 13, inspect 0.0 78.3 22:30 00:00 pac-off element 10/21/2016 10/21/2016 0.75 PROD2 DRILL PULD P Continue PD BHA# 13 78.3 78.3 00:00 00:45 10/21/2016 10/21/2016 1.25 PROD2 DRILL TRIP P RIH with BHA# 13 with agitator and 78.3 6,445.0 00:45 02:00 0.8 bend motor and RR bi-center bit. 10/21/2016 10/21/2016 0.25 PROD2 DRILL DLOG P Log K1 marker correction of minus 6,445.0 6,469.0 02:00 02:15 5.0', PUW 10/21/2016 10/21/2016 1.25 PROD2 DRILL TRIP P Continue RIHTB 6,469.0 9,260.0 02:15 03:30 Page 9/15 Report Printed: 10/31/2016 - operations Summary (with Timelog Depths) t- 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P OBD 1.4 bpm at 4400 psi, BHP 4008, 9,260.0 9,354.0 03:30 05:30 WHP 463, IA 12, OA 9 10/21/2016 10/21/2016 025 PROD2 DRILL WPRT P Wiper up hole, PUW 39K 9,354.0 9,254.0 05:30 05:45 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 5K 9,254.0 9,354.0 05:45 06:00 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi, BHP 3985 9,354.0 9,418.0 06:00 08:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 40K 9,454.0 9,254.0 08:00 08:15 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 4K 9,254.0 9,454.0 08:15 08:30 10/21/2016 10/21/2016 2.50 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi, BHP 3977 9,454.0 9,521.0 08:30 11:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 45K, pump 5 bbl 9,521.0 9,302.0 11:00 11:15 to -vis sweep 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 2K, pump 5 9,302.0 9,521.0 11:15 11:30 bbl hi -vis sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P BOBD 1.44 bpm at 4400 psi, BHP 9,521.0 9,530.0 11:30 12:00 3977, DWOB 1.5K, ROP 20 ft/hr, pump 5x5 sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P Wiper up hole (1000'), PUW 43K. 9,530.0 8,530.0 12:00 12:30 Pump 10bb1 hi -vis sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 5K. Pump 8,530.0 9,530.0 12:30 13:00 10bbi to -vis sweep 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi, BHP 4000 9,530.0 9,622.0 13:00 15:00 psi, DHWOB 1K 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 43K 9,622.0 9,522.0 15:00 15:15 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 4K 9,522.0 9,622.0 15:15 15:30 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD, 1.4 bpm, ROP 33ft/hr, 9,622.0 9,697.0 15:30 17:30 DHWOB .9K 10/21/2016 10/21/2016 3.25 PROD2 DRILL DRLG P OBD 1.4 bpm at 4549 psi, BHP 4038, 9,697.0 9,778.0 17:30 20:45 WHP 450, IA 7, OA 11 10/21/2016 10/21/2016 1.25 PROD2 DRILL WPRT P Wiper up hole to 6,650', PUW 45 k. 9,778.0 6,650.0 20:45 22:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL DLOG P Log the RA correction of plus 7.0', 6,650.0 6,676.0 22:00 22:15 10/21/2016 10/21/2016 1.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 10 k 6,676.0 9,778.0 22:15 23:30 10/21/2016 10/22/2016 0.50 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4500 psi, BHP 9,778.0 9,792.0 23:30 00:00 4050, WHP 426, IA 8, OA 12 10/22/2016 10/22/2016 4.50 PROD2 DRILL DRLG P OBD 1.4 bpm at 4,700 psi, BHP 4040, 9,792.0 9,905.0 00:00 04:30 WHP 437, IA 8, OA 11 10/22/2016 10/22/2016 0.25 PROD2 DRILL DRLG P Start pumping bead pills. 9,905.0 9,905.0 04:30 04:45 10/22/2016 10/22/2016 5.00 PROD2 DRILL DRLG P Continue drilling ahead, 1.37 bpm at 9,905.0 9,976.0 04:45 09:45 4617 psi, BHP 4054, WHP 416, IA 14, OA 12 10/22/2016 10/22/2016 0.75 PROD2 DRILL WPRT P Wiper up hole, PUW 45K 9,976.0 9,776.0 09:45 10:30 10/22/2016 10/22/2016 0.75 PROD2 DRILL WPRT P Wiper back in hole, RIH 6.5K 9,776.0 9,976.0 10:30 11:15 10/22/2016 10/22/2016 5.00 PROD2 DRILL DRLG P BOBD 1.35 bpm at 4750 psi, BHP 9,976.0 10,083.0 11:15 16:15 4054, WHP 390, IA 7, OA 11, ROP 20 ft/hr, DHWOB 1 K Page 10/15 Report Printed: 10/31/2016 Uperations Summary (with Timelog Depths) -.,r. 2B-02 Ww Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/22/2016 10/22/2016 0.25 PROD2 DRILL WPRT P 200' wiper up hole, PUW 45 k 10,083.0 9,883.0 16:15 16:30 10/22/2016 10/22/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW - 2.Ok 9,883.0 10,083.0 16:30 16:45 10/22/2016 10/22/2016 3.25 PROD2 DRILL DRLG P BOBD 1.35 k at 4,100' psi, BHP 4057, 10,083.0 10,150.0 16:45 20:00 WHP 352, IA 6, OA 11 10/22/2016 10/22/2016 0.50 PROD2 DRILL WPRT P Geo wiper up hole 10,133', PUW 42 k 10,150.0 10,150.0 20:00 20:30 10/22/2016 10/23/2016 3.50 PROD2 DRILL DRLG P BOBD 1.37 bpm at 4,460 psi, WHP 10,150.0 10,203.0 20:30 00:00 4,046, IA 6, OA 11, blow pop off on pump, swap out pop off, and restart drilling. 10/23/2016 10/23/2016 2.00 PROD2 DRILL DRLG P OBD 1.37 bpm at 4642 psi, BHP 10,203.0 10,227.0 00:00 02:00 4058, WHP 357, IA 7, OA 11 10/23/2016 10/23/2016 4.00 PROD2 DRILL WPRT P PUH, PUW 36 k, TD AU lateral, 10,227.0 6,694.0 02:00 06:00 pump 1 0x1 0 bbls sweep, clean hole 9,850'-9,530'. Continue POOH. 10/23/2016 10/23/2016 0.25 PROD2 DRILL WPRT P Perform choke calibration at 6,694'. 6,694.0 6,694.0 06:00 06:15 Full rate 12 ECD, Ann Pres 3756 psi, WH 307 psi, DI 8.97 ppg, DO 8.87 ppg, Pump Pres 4320 psi, choke 300, EDC 12.18 10/23/2016 10/23/2016 1.00 PROD2 DRILL WPRT P Continue PUH for swab wiper 6,694.0 78.0 06:15 07:15 10/23/2016 10/23/2016 1.00 PROD2 DRILL WPRT P RBIH, to tie in depth. 78.0 6,400.0 07:15 08:15 10/23/2016 10/23/2016 0.25 PROD2 DRILL DLOG P Log K1 marker for +22 ft correction. 6,400.0 6,469.0 08:15 08:30 10/23/2016 10/23/2016 0.50 PROD2 DRILL DLOG P RIH and perform static BHP at 6,594'. 6,469.0 6,678.0 08:30 09:00 RIH and log RA marker for-.5 correction. 10/23/2016 10/23/2016 2.00 PROD2 DRILL WPRT P Continue RIH. Stack down XX'. 6,678.0 10,230.0 09:00 11:00 Confirm TD at 10,230'. 10/23/2016 10/23/2016 3.50 PROD2 DRILL DISP P POOH laying in beaded liner pill and 10,230.0 78.0 11:00 14:30 12.2 ppf completion fluid. Paint flags at 8,778 and 5,178. Continue POOH 10/23/2016 10/23/2016 0.50 PROD2 DRILL OWFF P Conduct 30 min flow check 78.0 78.0 14:30 15:00 10/23/2016 10/23/2016 0.50 PROD2 DRILL PULD P PJSM, Lay down BHA #13 78.0 0.0 15:00 15:30 10/23/2016 10/23/2016 3.00 PROD2 WHDBOP RURD P Clean and clear rig floor in preparation 0.0 0.0 15:30 18:30 for BOP test. 10/23/2016 10/23/2016 1.50 PROD2 WHDBOP RURD P MU Nozzle, flush stack and surface 0.0 0.0 18:30 20:00 lines while displacing coil to fresh water, Valve crew on location greasing tree valves. 10/23/2016 10/24/2016 4.00 PROD2 WHDBOP BOPE P Perform bi-weekly BOP test, witness 0.0 0.0 20:00 00:00 waived by state tester Brian Bixby, Test pressure 3,750 psi high / 250 psi low / 2,500 psi annular. 10/24/2016 10/24/2016 4.00 PROD2 WHDBOP BOPE P Continue bi-weekly BOP test, witness 0.0 0.0 00:00 04:00 waived by state tester Brian Bixby, Test pressure 3,750 psi high / 250 psi low / 2,500 psi annular. Test complete, no failures. 10/24/2016 10/24/2016 4.50 PROD2 WHDBOP BOPE P Calibrate In and Out MicroMotion. 0.0 0.0 04:00 08:30 Test inner real valve, replace packoffs. Displace coil back to completion fluid. Page 11115 Report Printed: 10/31/2016 uperations Summary (with Timelog Vepths) 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WB) 10/24/2016 10/24/2016 0.50 PROD2 CASING PUTB P PJSM, Prep rig floor for MU A lateral 0.0 0.0 08:30 09:00 liner assembly. 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P MU 34 jts of slotted liner with 8.09' pup 0.0 0.0 09:00 10:30 joint. Perform BOP drill 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P PJSM, MU Coiltrak tools (BHA#15), 0.0 1,102.0 10:30 12:00 test tools and QTC 10/24/2016 10/24/2016 1.50 PROD2 CASING RUNL P RIH, with lower AL1 lateral liner 1,102.0 6,202.0 12:00 13:30 assembly to EOP flag 10/24/2016 10/24/2016 0.25 PROD2 CASING RUNL P Minus 11.5' correction at the EOP flag 6,202.0 6,202.0 13:30 13:45 10/24/2016 10/24/2016 0.50 PROD2 CASING DLOG P WT CK 36K at 7470. Shut down 6,202.0 7,492.0 13:45 14:15 pumps. Log the K1 marker for a correction of +5.5'. 10/24/2016 10/24/2016 1.00 PROD2 CASING RUNL P RIH to TD at 10,230', PUW 40K. 7,492.0 10,230.0 14:15 15:15 Bring pump online to 4,650 psi, 1.4 bpm, IA 12, OA 4, WH 0. Release liner on bottom 10,230', TOL at 9,172', remove liner length from counters. 10/24/2016 10/24/2016 3.00 PROD2 CASING TRIP P POOH, with setting tools and paint 10,230.0 61.0 15:15 18:15 EOP flags 10/24/2016 10/24/2016 0.50 PROD2 CASING OWFF P At surface, perform flow test 61.0 61.0 18:15 18:45 10/24/2016 10/24/2016 1.75 PROD2 CASING PUTB P PU/MU 11 joints slotted liner, OH 61.0 0.0 18:45 20:30 anchored billet, and liner running assembly BHA #15. Perform BOP drill 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P PJSM, MU Coiltrak tools (BHA#15) 0.0 0.0 20:30 22:00 10/24/2016 10/24/2016 1.00 PROD2 CASING RUNL P RIH, with upper AL1 lateral liner 0.0 6,514.0 22:00 23:00 assembly to EOP flag at 6144' 10/24/2016 10/24/2016 0.50 PROD2 CASING RUNL P Minus 10' correction at the EOP flag. 6,514.0 6,514.0 23:00 23:30 WT CK = 32K at 6,514'. Pumps offline, EDC closed. 10/24/2016 10/25/2016 0.50 PROD2 CASING RUNL P RIH to K1 marker 6,514.0 6,790.0 23:30 00:00 10/25/2016 10/25/2016 0.50 PROD2 CASING DLOG P Log the K1 marker for a correction of 6,790.0 6,824.0 00:00 00:30 plus 4.5' 10/25/2016 10/25/2016 0.50 PROD2 CASING TRIP P Continue RIH to bottom 6,824.0 9,168.0 00:30 01:00 10/25/2016 10/25/2016 0.25 PROD2 CASING TRIP P Tag bottom, PUW 36 k, bring pump up 9,168.0 9,168.0 01:00 01:15 to shear at 4,300 psi 10/25/2016 10/25/2016 0.60 PROD2 CASING TRIP P POOH, pumping with closed EDC 9,168.0 6,585.0 01:15 01:51 10/25/2016 10/25/2016 1.25 PROD2 CASING OWFF P trace of crude to surface, transfer 6,585.0 6,585.0 01:51 03:06 additional 12.2 ppg completion fluid to active pit, circulate bottoms up, check well for flow, well is dead. 10/25/2016 10/25/2016 1.50 PROD2 CASING PULD P Continue POOH, pumping pipe 6,585.0 60.8 03:06 04:36 displacement 10/25/2016 10/25/2016 0.50 PROD2 CASING OWFF P OOH, check well for flow, PJSM 60.8 60.8 04:36 05:06 10/25/2016 10/25/2016 1.25 PROD2 CASING PULD P LD AL1 liner setting tools on a dead 60.8 0.0 05:06 06:21 well. 10/25/2016 10/25/2016 0.50 PROD3 DRILL SFTY P Crew change, valve check list, PJSM 0.0 0.0 06:21 06:51 10/25/2016 10/25/2016 1.25 PROD3 DRILL PULD P PJSM, make up BHA# 16 on a dead 0.0 78.4 06:51 08:06 well. Page 12/15 Report Printed: 10/31/2016 operations Summary (with Timelog Depths) 2B-02 Rig: NABORS CDR2-AC Time Log Start Time End Time Dur (hr) Phase Op Code Acti 10/25/2016 10/25/2016 1.50 PRODS DRILL TRIP 08:06 09:36 6,440.0 agitator and RR bi-center bit. 10/25/2016 10/25/2016 0.25 PRODS DRILL DLO( 09:36 09:51 7.0'. 10/25/2016 10/25/2016 1.00 PRODS DRILL TRIP 09:51 10:51 8,810.0 8,810.0 10/25/2016 10/25/2016 1.00 PRODS DRILL DISP 10:51 11:51 P Log the RA correction of plus 1.5' 6,650.0 10/25/2016 10/25/2016 0.50 PRODS DRILL TRIP 11:51 12:21 Tag top of billet, PUH, bring pump up 8,810.0 8,853.0 10/25/2016 10/25/2016 0.50 PRODS DRILL DLO( 12:21 12:51 P PUH, PUW 36 k, drift billet area, clean 10/25/2016 10/25/2016 0.60 PRODS DRILL TRIP 12:51 13:27 P BOBD, 1.3 bpm at 4460 psi FS, BHP 8,791.0 8,870.0 10/25/2016 10/25/2016 1.00 PRODS DRILL KO -S- 13:27 14:27 8,870.0 9,080.0 10/25/2016 10/25/2016 0.25 PRODS DRILL WPR 14:27 14:42 Note: New mud out bit at 9,037 ft. 10/25/2016 10/25/2016 2.15 PRODS DRILL DRLC 14:42 16:51 4,003 psi, WHP 542, IA 10, OA 7 10/25/2016 10/25/2016 4.35 PRODS DRILL DRLC 16:51 21:12 pump 5x5 sweep 10/25/2016 10/26/2016 2.80 PRODS DRILL DRLC 21:12 00:00 38k, pull 6k over at 9,071 ft and 8,659 10/26/2016 10/26/2016 0.35 PRODS DRILL DRLC 00:00 00:21 8,210.0 9,210.0 P 10/26/2016 10/26/2016 0.50 PRODS DRILL WPR' 00:21 00:51 P PU off bottom for a geo wiper, PUW 9,405.0 10/26/2016 10/26/2016 0.55 PRODS DRILL WPR- 00:51 01:24 pulling up hole for a tie in. 10/26/2016 10/26/2016 4.50 PRODS DRILL DRLC 01:24 05:54 P Wiper back in hole, RIW 8 k 10/26/2016 10/26/2016 1.00 PRODS DRILL WPR- 05:54 06:54 4024, WHP 464, IA 10, OA 9 10/26/2016 10/26/2016 0.25 PRODS DRILL DLOC 06:54 07:09 9,446.0 9,750.0 10/26/2016 10/26/2016 0.75 PRODS DRILL WPRI 07:09 07:54 46k, pump 10x10 sweeps. 10/26/2016 10/26/2016 3.00 PRODS DRILL DRLG 07:54 10:54 PUW 46k, Jog at EOB, Jog at 600 ft 10/26/2016 10/26/2016 0.25 PRODS DRILL WPRI 10:54 11:09 10/26/2016 10/26/2016 10.00 PRODS DRILL DRLG 11:09 21:09 10/26/2016 10/27/2016 2.85 PRODS DRILL WPRI 21:09 00:00 Job: DRILLING SIDETRACK L Page 13115 Report Printed: 10/31/2016 Start Depth Code Time P -T -X Operation (ftKB) End Depth (ftKB) P RIH wtih AL1 -01 drilling BHA# 16, 78.4 6,440.0 agitator and RR bi-center bit. P Log K1 marker correction of minus 6,440.0 6,472.0 7.0'. P Continue RIH to billet 6,472.0 8,810.0 P Tag TOB, 8,810', PUH and displace 8,810.0 8,810.0 well to drilling fluid. P PUH 8,810.0 6,650.0 P Log the RA correction of plus 1.5' 6,650.0 6,684.0 P RBIH to confirm TOB 6,684.0 8,810.0 P Tag top of billet, PUH, bring pump up 8,810.0 8,853.0 to 1.3 bpm at 4450 psi, trough above billet, kickoff of billet as per procedure. P PUH, PUW 36 k, drift billet area, clean 8,853.0 8,791.0 RBIHTB P BOBD, 1.3 bpm at 4460 psi FS, BHP 8,791.0 8,870.0 3952, WHP 212, IA 10, OA 7 P OBD, 1.3 bpm at 4521 psi, BHP 3943, 8,870.0 9,080.0 WHP 217, IA 10, OA 7, PUW at 9,080 ft 38k. Note: New mud out bit at 9,037 ft. P BOBD 1.42 bpm at 4,402 psi FS, BHP 9,080.0 9,200.0 4,003 psi, WHP 542, IA 10, OA 7 P OBD 1.42 bpm at 4,450 psi FS, BHP 9,200.0 9,210.0 3,975 psi, WHP 556, IA 11, OA 8. pump 5x5 sweep P 9,210 ft. Wiper up hole 1,000 ft, PUW 9,210.0 8,210.0 38k, pull 6k over at 9,071 ft and 8,659 ft. P 8,210 ft Wiper back in hole, RIW 9.Ok 8,210.0 9,210.0 P BOBD 1.40 bpm at 4,429 psi, BHP 9,210.0 9,405.0 4,008, WHP 561, IA 11, OA 8 P PU off bottom for a geo wiper, PUW 9,405.0 6,650.0 36 k, discuss plan forward, continue pulling up hole for a tie in. P Log the RA marker correction of plus 6,650.0 6,650.0 5.0' P Wiper back in hole, RIW 8 k 6,650.0 9,405.0 P BOBD 1.4 bpm at 4,330 psi, BHP 9,405.0 9,446.0 4024, WHP 464, IA 10, OA 9 P Short 100' wiper up hole 9,446.0 9,446.0 P BOBD 1.4 bpm at 3600 psi FS, BHP 9,446.0 9,750.0 4075, WHP 618, IA 10, OA 11, couple of PU's for restarts, PUW(s) 44k & 46k, pump 10x10 sweeps. P 9,750 ft. Called TD. Wiper to swab. 9,750.0 675.0 PUW 46k, Jog at EOB, Jog at 600 ft from surface. L Page 13115 Report Printed: 10/31/2016 3' U. -x Uperations Summary (with Timelog Depths) 2B-02 s • r 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 (WB) 10/27/2016 10/27/2016 0.25 PRODS DRILL WPRT P Continue wiper to swab, tag up, restet 675.0 78.4 00:00 00:15 counters. 10/27/2016 10/27/2016 1.25 PRODS DRILL TRIP P RBIH to confirm TD 78.4 6,430.0 00:15 01:30 10/27/2016 10/27/2016 0.20 PRODS DRILL DLOG P Tie in to K1 for minus 1 ft correction 6,430.0 6,470.0 01:30 01:42 10/27/2016 10/27/2016 1.45 PROD3 DRILL TRIP P Continue RIH, stop at window for 6,470.0 9,754.0 01:42 03:09 SBHP at 6,641 ft (Bit at 6,690 ft at 01:49) BHP 3,797 psi, 5 minutes 3,798 psi= 12.1 ppg EMW at window, bring pumps back on and continue RIH, clean past billets at 7,580 ft, 8,465 ft and 8,808 ft, stacked 1 k at 9,412 ft, clean to corrected TD at 9,754 ft, CWT 6k. 10/27/2016 10/27/2016 0.85 PROD3 DRILL DISP P 9,754 ft. Tag corrected TD, PUW 40k, 9,754.0 9,754.0 03:09 04:00 pump 12.2 ppg beaded liner pill. 10/27/2016 10/27/2016 3.00 PRODS DRILL DISP T Lost prime on pump at 20 bbis away, 9,754.0 9,754.0 04:00 07:00 noticed 10.8 ppg fluid at the in MM, Diagnose problem and found that the suction valve was still cracked open, contaminating the liner pill, circulate contaminated flud out of hole 10/27/2016 10/27/2016 3.00 PROD3 DRILL TRIP P POOH, laying in liner running pill with 9,754.0 78.6 07:00 10:00 alpine beads up to the window painting EOP flags, 10/27/2016 10/27/2016 0.50 PROD3 DRILL OWFF P Check well for flow, PJSM 78.6 78.6 10:00 10:30 10/27/2016 10/27/2016 0.50 PRODS DRILL PULD P LD drilling BHA# 16 78.6 0.0 10:30 11:00 10/27/2016 10/27/2016 0.50 COMPZ3 CASING PUTB P PJSM, prep rig floor for MU AL1 -01 0.0 0.0 11:00 11:30 liner assembly 10/27/2016 10/27/2016 4.50 COMPZ3 CASING PUTB P MU AL1 -01 liner assembly wtih 102 jts 0.0 3,152.3 11:30 16:00 of slotted liner with 2 pups. 10/27/2016 10/27/2016 1.25 COMPZ3 CASING PULD P PU/MU Surface test Coiltrak tools 3,152.3 3,196.5 16:00 17:15 10/27/2016 10/27/2016 3.50 COMPZ3 CASING RUNL P RIH, w/ Liner BHA# 17 102 jts of 3,196.5 9,750.0 17:15 20:45 slotted liner and shorty deployment sleeve. Minus 12.0 ft correction at flag, PUW 49k, RBIH, started stacking at 8,040 ft, work liner, plus 2 ft at bottom flag, work to 9,750 ft. 10/27/2016 10/27/2016 0.30 COMPZ3 CASING RUNL P 9,750 ft. On depth, PUW 56k, on line 9,750.0 6,598.0 20:45 21:03 1.3 bpm to release off liner, PUW 28k, reset counters, TOP of liner at 6,598 ft. 10/27/2016 10/27/2016 1.30 COMPZ3 CASING DISP P 6,598 ft. Displace well to seawater, 6,598.0 6,598.0 21:03 22:21 LRS on site, PJSM with LRS 10/27/2016 10/27/2016 0.75 COMPZ3 CASING TRIP P POOH pumping seawater to 2,500 ft. 6,598.0 2,500.0 22:21 23:06 LRS P/T lines and equipment. 10/27/2016 10/28/2016 0.90 COMPZ3 CASING FRZP P 2,500 ft. LRS pump 30 bbis diesel, 2,500.0 2,500.0 23:06 00:00 RDMO LRS. 10/28/2016 10/28/2016 1.00 COMPZ3 CASING TRIP P POOH pumping diesel. PJSM- PUD 2,500.0 44.2 00:00 01:00 BHA 10/28/2016 10/28/2016 1.75 COMPZ3 CASING PULD P PUD/LD running tool BHA #17. 44.2 0.0 01:00 02:45 Page 14/15 Report Printed: 10/31/2016 �Y^ S Uperations Summary (with Timelog Depths) - 2B-02 Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (MB) End Depth (ftKB) 10/28/2016 10/28/2016 2.00 DEMOB WHDBOP MPSP P PJSM- Bring in BPV equipment, MU 0.0 0.0 02:45 04:45 and lubricate in 3" GRAY BPV, Final TBG 1,230 psi, close master half way, bleed above BPV to 450 psi, holding good, bleed to zero, close master, RDMO BPV equipment and crew. 10/28/2016 10/28/2016 1.25 DEMOB WHDBOP RURD P PJSM- Skid cart, MU nozzle, flush 0.0 0.0 04:45 06:00 coil, jet BOP stack and surface lines 10/28/2016 10/28/2016 6.00 DEMOB WHDBOP RURD P Start Rig move check list, blow down 0.0 0.0 06:00 12:00 steam lines, blow down coiled tubing reel, disconnect PUTZ, nipple down BOPE, etc .... Trucks on location PJSM for moving subs off of well. Rig Released 12:00 noon Page 15115 Report Printed: 10/31/2016 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B -02A 50-029-21154-01 Baker Hughes 1NTEQ Definitive Survey Report 04 November, 2016 Few al BAKER HUGHES ConocoPhillips wails ConocoPhillips sHKUGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 28-02 @ 126.00usft (213-02) Site: Kuparuk 213 Pad MD Reference: 2B-02 @ 126.00usft (28-02) Well: 2B-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 28-02 Database: EDM Alaska NSK Sandbox Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor well 213-02 Well Position -NI-S 0.00 usft Northing: 5,954,890.07usft Latitude: 70° 17' 16.702 N +E/ -W 0.00 usft Easting: 508,370.93usft Longitude: 149" 55'56,081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2B -02A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) l°) (nT) BGGM2016 10/1/2016 17.90 80.90 57,541 Design 2B -02A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,560.37 Vertical Section: Depth From (TVD) -NI-S +FJ -W Direction !usft) (usft) (usft) (I 126.00 0.00 000 200.00 Survey Program Date 11/1/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 26-02(213-02) GCT -MS Schlumberger GCT multishot 1/12/2001 6,640.00 7,560.37 2B-02APB1 (213-02AP131) MWD MWD - Standard 10/8/2016 10/15/2016 7,580.00 9,535.13 2B -02A(2 B -02A) MWD MWD - Standard 10/16/2016 10/18/2016 11/412016 7 31 24AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips NO ComicoPhillips KER HUGHES Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference. 28-02 @ 126.00usft (213-02) Site: Kuparuk 2B Pad MD Reference: 28-02 @ 126.00usft (28-02) Well: 28-02 North Reference: True Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature Design: 2B-02 Database: EDM Alaska NSK Sandbox Survey Map Map Vertical MD (M�) Inc (1) Axl (1) TVD (usn) TVDSS (usn) +N/S 05111) +F1iAl 1-ft) Northing Easting DLS (°1100.) Section Surve Tool Name Y Annotation (() (n) (n) 7,560.37 91.08 190.01 6,095.85 5,969.85 -2,708.85 -852.92 5,952,180.54 507,521.11 11.43 2,837.20 MWD (2) TIP 7,580.00 91.22 192.09 6,095.45 5,969.45 -2,728.11 -856.68 5,952,161.28 507,517.37 10.62 2,856.58 MWD (3) KOP 7,610.75 87.82 192.82 6,095.71 5,969.71 -2,758.13 -863.31 5,952,131.26 507,510.78 11.31 2,887.06 MWD (3) 7,640.61 86.99 195.95 6,097.06 5,971.06 -2,787.02 -870.72 5,952,102.36 507,503.40 10.83 2,916.75 MWD (3) 7,670.70 88.50 202.17 6,098.25 5,972.25 -2,815.42 -880.53 5,952,073.95 507,493.62 21.26 2,946.79 MWO(3) 7,700.71 86.28 204.13 6,099.62 5,973.62 -2,84299 -892.32 5,952,046.38 507,481.87 9.86 2,976.72 MWD (3) 7,730.33 87.14 207.97 6,101.32 5,975.32 -2,869.55 -905.30 5,952,019.80 507,468.91 13.26 3,006.12 MWD (3) 7,760.29 89.57 211.73 6,102.18 5,976.18 -2,895.51 -920.20 5,951,993.82 507,454.04 14.94 3,035.62 MWD (3) 7,790.53 88.77 216.84 6,102.61 5,976.61 -2,920.49 -937.23 5,951,968.83 507,437.04 17.10 3,064.91 MWD (3) 7,820.01 90.03 221.67 6,102.92 5,976.92 -2,943.31 -955.88 5,951,945.99 507,418.42 16.93 3,092.73 MWD (3) 7,850.77 88.80 225.19 6,103.24 5,977.24 -2,965.64 -977.02 5,951,923.64 507,397.31 12.12 3,120.95 MWD (3) 7,880.40 87.79 228.51 6,104.12 5,978.12 -2,985.89 -998.62 5,951,903.36 507,375.73 11.71 3,147.37 MWD (3) 7,910.38 87.51 232.94 6,105.35 5,979.35 -3,004.85 -1,021.81 5,951,884.38 507,352.57 14.79 3,173.12 MWD (3) 7,940.31 86.43 235.66 6,106.93 5,980.93 -3,022.29 -1,046.07 5,951,866.92 507,328.32 9.77 3,197.80 MWD (3) 7,970.56 84.25 239.53 6,109.39 5,983.39 -3,03845 -1,071.52 5,951,850.74 507,302.90 14.65 3,221.69 MIND (3) 8,000.68 86.47 243.16 6,111.83 5,985.83 -3,052.84 -1,097.86 5,951,836.32 507,276.58 14.09 3,244.22 MWD (3) 8,030.53 87.79 246.92 6,113.32 5,987.32 -3,065.41 -1,124.88 5,951,823.71 507,249.57 13.33 3,265.28 MWD (3) 8,060.34 89.08 250.86 6,114.14 5,988.14 -3,076.14 -1,152.68 5,951,812.95 507,221.79 13.90 3,284.87 MWD (3) 8,090.45 90.00 255.25 6,114.38 5,988.38 -3,084.92 -1,181.47 5,951,804.15 507,193.01 14.90 3,302.96 MWD (3) 8,120.51 89.39 259.26 6,114.54 5,988.54 -3,091.55 -1,210.78 5,951,797.49 507,163.71 13.49 3,319.22 MWD (3) 8,150.35 89.42 263.34 6,114.85 5,988.85 -3,096.06 -1,240.27 5,951,792.94 507,134.23 13.67 3,333.54 MWD (3) 8,180.51 89.69 268.26 6,115.08 5,989.08 -3,098.27 -1,270.34 5,951,790.70 507,104.16 16.34 3,345.90 MWD (3) 8,210.41 88.10 272.17 6,115.66 5,989.66 -3,098.16 -1,300.23 5,951,790.78 507,074.28 14.11 3,356.02 MWD (3) 8,240.15 88.59 276.58 6,116.52 5,990.52 -3,095.89 -1,329.86 5,951,793.01 507,044.65 14.91 3,364.02 MWD (3) - 8,270.47 88.96 280.43 6,117.17 5,991.17 -3,091.41 -1,359.94 5,951,797.46 507,014.67 12.75 3,370.06 MWD (3) 8,300.34 90.58 283.72 6,117.29 5,991.29 -3,085.16 -1,389.04 5,951,803.67 506,985.46 12.28 3,374.18 MWD (3) I 8,330.45 87.57 287.33 6,117.77 5,991.77 -3,077.10 -1,418.04 5,951,811.70 506,956.46 15.61 3,376.53 MWD (3) 8,360.47 88.46 291.19 6,118.81 5,992.81 -3,067.21 -1,446.36 5,951,821.56 506,928.13 13.19 3,376.92 MWD (3) 8,39071 90.83 296.07 6,119.00 5,993.00 -3,055.09 -1,474.05 5,951,833.64 506,900.43 17.94 3,375.00 MWD (3) 8,42074 89.97 294.18 6,118.79 5,992.79 -3,042.34 -1,501.24 5,951,846 36 506,873.23 6.91 3,372.32 MWD (3) 11/4/2018 7:31: 24AM Page 3 COMPASS 5000.1 Build 74 Survey ConocoPhillips h IN ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2B-02 MD Project: Kuparuk River Unit TVD Reference: 28-02 @ 126.00usft (2B-02) TVDSS Site: Kuparuk 2B Pad MD Reference: 28-02 @ 126.00usft (28-02) Eason 9 Well: 2B-02 North Reference: True (1) Wellbore: 28-02 Survey Calculation Method: Minimum Curvature (usft) Design: 211-02 Database: EDM Alaska NSK Sandbox (=�p0�) Survey Map Map al MD Inc Azi TVD TVDSS +N1S +EI -W Northing g Eason 9 DLS Sea`on (usft) (1) V) (usft) (usft) (usft) (usft) (=�p0�) Survey Tool Name Annotation ( ) ) (ft) 8,450.91 90.34 290.81 6,118.71 5,992.71 -3,030.80 -1,529.11 5,951,857.87 506,845.35 11.24 3,371.01 MWD(3) 8,480.88 89.60 286.88 6,118.73 5,992.73 -3,021.12 -1,557.47 5,951,867.52 506,816.98 13.34 3,371.61 MWD(3) 8,510.24 90.09 282.49 6,118.81 5,992.81 -3,013.68 -1,585.86 5,951,874.93 506,788.58 15.05 3,374.33 MWD (3) 8,540.39 90.61 279.17 6,118.62 5,992.62 -3,008.02 -1,615.47 5,951,880.56 506,758.97 11.15 3,379.13 MWD (3) 8,570.37 9197 275.73 6,117.95 5,991.95 -3,004.13 -1,645.18 5,951,884.41 506,729.26 12.34 3,385.65 MWD (3) 8,600.26 94.58 273.49 6,116.24 5,990.24 -3,001.73 -1,674.92 5,951,886.77 506,699.52 11.50 3,393.56 MWD (3) 8,630.38 96.43 271.96 6,113.35 5,987.35 -3,000.31 -1,704.87 5,951,888.17 506,669.57 7.96 3,402.47 MWD (3) a 8,660.24 98.78 268.99 6,109.40 5,983.40 -3,000.06 -1,734.46 5,951,888.38 506,639.99 12.61 3,412.35 MWD (3) 8,690.45 101.59 266.13 6,104.05 5,978.05 -3,001.32 -1,764.16 5,951,887.09 506,610.29 13.17 3,423.70 MWD (3) 8,720.23 101.33 263.33 6,098.14 5,972.14 -3,004.00 -1,793.22 5,951,884.37 506,581.24 9.26 3,436.16 MWD (3) 8,750.32 100.74 260.57 6,092.38 5,966.38 -3,008.14 -1,822.46 5,951,880.20 506,552.00 9.21 3,450.04 MWD (3) 8,780.32 99.55 257.32 6,087.09 5,961.09 -3,013.80 -1,851.44 5,951,874.51 506,523.03 11.38 3,465.28 MWD (3) 8,810.30 96.80 254.50 6,082.83 5,956.83 -3,021.03 -1,880.21 5,951,867.25 506,494.27 13.07 3,481.91 MWD (3) 8,840.24 94.98 251.87 6,079.75 5,953.75 -3,029.64 -1,908.72 5,951,858.61 506,465.78 10.64 3,499.75 MWD (3) 8,870.33 91.78 247.65 6,077.98 5,951.98 -3,040.03 -1,936.89 5,951,848.19 506,437.62 17.58 3,519.15 MWD (3) 8,900.33 91.23 244.05 6,077.19 5,951.19 -3,052.30 -1,964.25 5,951,835.89 506,410.28 12.14 3,540.04 MWD (3) 8,930.34 91.17 241.36 6,076.56 5,950.56 -3,066.06 -1,990.91 5,951,822.10 506,383.63 8.96 3,562.08 MWD (3) 8,960.33 93.19 238.45 6,075.42 5,949.42 -3,081.08 -2,016.83 5,951,807.05 506,357.73 11.81 3,585.07 MWD (3) 8,990.31 92.58 235.03 6,073.91 5,947.91 -3,097.50 -2,041.87 5,951,790.61 506,332.72 11.57 3,609.06 MWD(3) 9,020.28 91.32 231.09 6,072.89 5,946.89 -3,115.50 -2,065.80 5,951,772.59 506,308.80 13.79 3,634.16 MWD (3) 9,050.46 91.35 228.44 6,072.19 5,946.19 -3,134.99 -2,088.83 5,951,753.07 506,285.80 8.78 3,660.35 MWD (3) 9,080.28 92.95 225.43 6,071.07 5,945.07 -3,155.33 -2,110.60 5,951,732.71 506,264.05 11.42 3,686.91 MWD (3) 9,110.40 94.64 221.67 6,069.08 5,943.08 -3,177.11 -2,131.30 5,951,710.91 506,243.38 13.66 3,714.45 MWD(3) 9,140.56 95.10 218.50 6,066.51 5,940.51 -3,200.10 -2,150.65 5,951,687.90 506,224.06 10.58 3,742.67 MWD (3) 9,170.29 94.36 214.87 6,064.06 5,938.06 -3,223.85 -2,168.35 5,951,664.13 506,206.39 12.42 3,771.05 MWD(3) 9,200.64 93.32 211.65 6,062.03 5,936.03 -3,249.17 -2,184.95 5,951,638.79 506,189.81 11.13 3,800.52 MWD (3) 9,230.39 92.98 208.02 6,060.39 5,934.39 -3,274.93 -2,199.73 5,951,613.02 506,175.07 12.24 3,829.78 MWD(3) 9,260.45 91.14 205.79 6,059.31 5,933.31 -3,301.72 -2,213.32 5,951,586.22 506,161.51 9.61 3,859.60 MWD (3) 9,290.47 90.67 202.27 6,058.84 5,932.84 -3,329.13 -2,225.54 5,951,558.80 506,149.32 11.83 3,889.54 MWD (3) " 9,320.55 90.68 199.67 6,058.48 5,932.48 -3,357.21 -2,236.31 5,951,530.70 506,138.59 8.64 3,919.61 MWD (3) ' 9,350.37 91.10 195.83 6,058.02 5,932.02 -3,385.60 -2,245.39 5,951,502.31 506,129.53 12.95 3,949.40 MWD (3) 11/4/2016 731: 24AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips RUN ConocoPhillips Definitive Survey Report �jES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project. Kuparuk River Unit Site: Kuparuk 2B Pad Well: 28-02 Wellbore: 2B-02 Design: 28-02 Survey MD Inc Azi TVD TVDSS +N1S (waft) (°) (°) (ustt) (ush) (usit) 9,380.29 89.51 193.01 6,057.86 5,931.86 -3,414.58 9,410.62 88.80 190.04 6,058.31 5,932.31 -3,444.29 9,440.41 88.93 186.48 6,058.90 5,932.90 -3,473.76 9,470.23 88.96 182.79 6,059.45 5,933.45 -3,503.47 9,500.47 88.13 177.94 6,060.22 5,934.22 -3,533.69 9,535.13 89.91 175.53 6,060.81 5,934.81 -3,568.29 9,570.00 89.91 175.53 6,060.86 5,934.86 -3,603.05 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 28-02 2B-02 @ 126.00usft (2B-02) 28-02 @ 126.00usft (2B-02) True Minimum Curvature EDM Alaska NSK Sandbox Annutation 111412016 7r31:24AM page 5 COMPASS 5000.1 Build 74 Map Map Vertical +E1 -W Northing Easting DLS Section Survey Tool Name (u�) (ft) (ft) (°1100') (ft) -2,252.84 5,951,473.33 506,122.11 10.82 3,979.17 MWD (3) -2,258.90 5,951,443.61 506,116.09. 10.07 4,009.16 MWD (3) -2,263.18 5,951,414.14 506,111.84 11.96 4,038.32 MWD (3) -2,265.59 5,951,384.43 506,109.47 12.37 4,067.06 MWD (3) -2,265.78 5,951,354.21 506,109.31 16.27 4,095.53 MWD (3) -2,263.81 5,951,319.62 506,111.32 8.64 4,127.36 MWD (3) -2,261.09 5,951,284.86 506,114.08 0.00 4,159.10 PROJECTED to TO Annutation 111412016 7r31:24AM page 5 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B-02APB1 50-029-21154-70 Baker Hughes INTEQ Definitive Survey Report 04 November, 2016 WIN al BAKER HUGHES 11/412016 7242AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips FAFN ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2B-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (28-02) Site: Kuparuk 2B Pad MD Reference: 28-02 @ 126.00usft (213-02) Well: 213-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 26-02 Well Position NI -S 0.00 usft Northing: 5,954,890.07 usft Latitude: 70° 17' 16.702 N +EI -W 0.00 usft Easting: 508,370.93usft Longitude: 149° 55'56.081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 2B-02APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) 1°1 (nT) BGGM2016 10/1/2016 17.90 80.90 57,541 Design 2B-02APB1 Audit Notes: Version: 1.0 Phase: ACTUAL 7e On Depth: 6,600.00 Vertical Section: Depth From JVD) +NI -S +El -W Direction (usft) (usft) (usft) (°) 126.00 0.00 0.00 200.00 Survey Program Date 10/15/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 2B-02 (213-02) GCT -MS Schlumberger GCT multishot 1/12/2001 6,640.00 8,040.05 2B-02APB1 (2B-02APB1) MWD MWD - Standard 10/8/2016 10/15/2016 11/412016 7242AM Page 2 COMPASS 5000.1 Build 74 10-1 ConocoPhillips HAN ConocoPhillips Definitive Survey Report HIKER GHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 28-02 Inc Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (28-02) -NI-S Site: Kuparuk 2B Pad MD Reference: 26-02 @ 126.00usft (28-02) DLS Well: 26-02 North Reference: True (usft) Wellbore: 2B-02 Survey Calculation Method: Minimum Curvature t*YI Design: 26-02 Database: EDM Alaska NSK Sandbox 32.25 Survey Vertical Section Survey Tool Name (ft) 1,940.34 MWD (2) 1,961.69 MWD (2) 1,973.89 MWD (2) 1,994.01 MWD (2) 2,018.37 MWD (2) 2,045.73 MWD (2) 2,076.62 MWD (2) 2,104.65 MWD (2) 2,133.87 MWO(2) 2,162.94 MWD (2) 2,192.41 MWD (2) 2,222.06 MWD (2) 2,251.27 MWD (2) 2,280.15 MWO(2) 2,308.64 MWO(2) 2,337.00 MWD (2) 2,366.32 MWD (2) 2,395.73 MWD (2) 2,426.17 MWD (2) 2,455.10 MWD (2) 2,484.84 MWD (2) 2,515.04 MWD (2) 2,544.93 MWD(2) 2,574.79 MWD (2) 2,604.88 MWD (2) 2,634.71 MWD (2) 2,664.39 MWD (2) 2,693.93 MWD (2) 2,722.29 MWD (2) 2,751.06 MWD (2) Annotation TIP KOP 11/412016 7.27:42AM Page 3 COMPASS 5000. 1 Build 74 Map Map MD Inc Az1 TVD TVDSS -NI-S +E1 -W Northing Ea(t) DLS lust[) (usft) Waft) (usft) (usft) t*YI (ft) (%100' ) 6,600.00 32.25 197.72 6,005.25 5,879.25 -1,819.78 -673.36 5,953,069.72 507,699.67 0.49 6,640.00 32.34 197.88 6,039.06 5,913.06 -1,840.13 -679.89 5,953,049.37 507,693.16 0.31 6,661.15 38.27 195.74 6,056.31 5,930.31 -1,851.83 -683.41 5,953,037.67 507,689.65 28.64 6,690.35 49.50 193.69 6,077.33 5,951.33 -1,871.38 -688.50 5,953,018.11 507,684.58 38.76 6,720.22 61.41 192.16 6,094.24 5,968.24 -1,895.32 -693.97 5,952,994.17 507,679.14 40.09 6,750.21 73.50 191.38 6,105.71 5,979.71 -1,922.39 -699.60 5,952,967.10 507,673.54 40.38 6,782.11 86.10 189.29 6,111.35 5,985.35 -1,953.21 -705.21 5,952,936.27 507,667.96 40.02 6,810.68 95.72 189.29 6,110.90 5,984.90 -1,981.37 -709.82 5,952,908.11 507,663.39 33.67 6,840.67 100.03 189.92 6,106.79 5,980.79 -2,010.66 -714.78 5,952,878.82 507,658.46 14.52 6,870.60 100.68 191.86 6,101.41 5,975.41 -2,039.57 -720.34 5,952,849.91 507,652.94 6.74 6,90067 97.42 194.40 6,096.68 5,970.68 -2,068.48 -727.08 5,952,820.99 507,646.22 13.68 6,930.80 95.41 189.88 6,093.31 5,967.31 -2,097.74 -733.38 5,952,791.72 507,639.96 16.33 6,960.75 93.13 186.09 6,091.08 5,965.08 -2,127.31 -737.52 5,952,762.15 507,635.85 14.74 6,990.75 90.71 182.80 6,090.08 5,964.08 -2,157.20 -739.85 5,952,732.26 507,633.56 13.61 7,020.80 89.29 180.16 6,090.08 5,964.08 -2,187.24 -740.62 5,952,702.23 507,632.82 9.98 7,050.63 88.80 183.87 6,090.57 5,964.57 -2,217.04 -741.67 5,952,672.43 507,631.80 12.54 7,080.87 88.50 188.10 6,091.29 5,965.29 -2,247.10 -744.82 5,952,642.37 507,628.68 14.02 7,110.73 88.34 192.27 6,092.11 5,966.11 -2,276.47 -750.10 5,952,612.99 507,623.44 13.97 7,141.31 91.47 197.32 6,092.16 5,966.16 -2,306.02 -757.90 5,952,583.44 507,615.67 19.43 7,170.25 9101 201.47 6,091.53 5,965.53 -2,333.31 -767.51 5,952,556.14 507,606.09 14.42 7,200.03 89.75 203.82 6,091.34 5,965.34 -2,360.79 -778.97 5,952,528.65 507,594.66 8.95 7,230.37 87.79 206.79 6,091.99 5,965.99 -2,388.21 -791.94 5,952,501.22 507,581.73 11.73 7,260.43 88.07 204.42 6,093.07 5,967.07 -2,415.30 -804.92 5,952,474.12 507,568.78 7.93 7,290.33 89.02 200.73 6,093.83 5,967.83 -2,442.89 -816.39 5,952,446.52 507,557.34 12.74 7,320.44 88.37 196.84 6,094.52 5,968.52 -2,471.38 -826.08 5,952,418.02 507,547.68 13.10 7,350.42 87.27 193.08 6,095.66 5,969.66 -2,500.32 -833.82 5,952,389.07 507,539.98 13.06 7,380.46 88.86 189.60 6,096.67 5,970.67 -2,529.75 -839.72 5,952,359.64 507,534.11 12.73 7,410.71 89.29 185.78 6,097.16 5,971.16 -2,559.72 -843.76 5,952,329.67 507,530.10 12.71 7,440.21 89.35 182.34 6,097.51 5,971.51 -2,589.14 -845.85 5,952,300.25 507,528.05 11.66 7,47075 89.82 178.50 6,097.73 5,971.73 -2,619.67 -846.08 5,952,269.72 507,527.96 12.67 Vertical Section Survey Tool Name (ft) 1,940.34 MWD (2) 1,961.69 MWD (2) 1,973.89 MWD (2) 1,994.01 MWD (2) 2,018.37 MWD (2) 2,045.73 MWD (2) 2,076.62 MWD (2) 2,104.65 MWD (2) 2,133.87 MWO(2) 2,162.94 MWD (2) 2,192.41 MWD (2) 2,222.06 MWD (2) 2,251.27 MWD (2) 2,280.15 MWO(2) 2,308.64 MWO(2) 2,337.00 MWD (2) 2,366.32 MWD (2) 2,395.73 MWD (2) 2,426.17 MWD (2) 2,455.10 MWD (2) 2,484.84 MWD (2) 2,515.04 MWD (2) 2,544.93 MWD(2) 2,574.79 MWD (2) 2,604.88 MWD (2) 2,634.71 MWD (2) 2,664.39 MWD (2) 2,693.93 MWD (2) 2,722.29 MWD (2) 2,751.06 MWD (2) Annotation TIP KOP 11/412016 7.27:42AM Page 3 COMPASS 5000. 1 Build 74 11/42016 777.42AM Page 4 COMPASS 5000.1 Build 74 ConocoPhillips RAN ConocoPhillips BAKER Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2B-02 Project: Kuparuk River Unit TVD Reference. 28-02 @ 126.00usft (2B-02) Site: Kuparuk 28 Pad MD Reference: 2B-02 @ 126.00usft (2B-02) Well: 28-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVO TVDSS +N1-S +Ef-W P Map OLS cal (uste) (°) i i iusk) (usR) (usnt (usR) N rthin g East n g (°/tgo') Section Survey Tool Name AJ1f10t8tIOt1 (ft) (110 Int 7,500.35 91.69 182.25 6,097.34 5,971.34 -2,649.26 -846.27 5,952,240.13 507,527.70 14.16 2,778.93 MWD (2) 7,530.35 91.47 186.60 6,096.52 5,970.52 -2,679.15 -848.58 5,952,210.24 507,525.42 14.51 2,807.81 MWD (2) 7,560.37 91.08 190.01 6,095.85 5,969.85 -2,708.85 -852.92 5,952,180.54 507,521.11 11.43 2,83220 MWD (2) 7,590.32 91.29 193.18 6,095.23 5,969.23 -2,738.18 -858.93 5,952,151.21 507,515.13 10.61 2,866.82 MWD (2) 7,620.32 93.38 196.60 6,094.01 5,968.01 -2,767.14 -866.63 5,952,122.24 507,507.46 13.35 2,896.67 MWD (2) 7,650.35 93.13 200.61 6,092.30 5,966.30 -2,795.55 -876.20 5,952,093.83 507,497.93 13.36 2,926.63 MWD (2) 7,685.35 92.52 203.51 6,090.57 5,964.57 -2,827.94 -889.33 5,952,061.42 507,484.84 8.46 2,961.56 MWD(2) 7,710.16 94.49 206.52 6,089.06 5,963.06 -2,850.38 -899.80 5,952,038.97 507,474.40 14.48 2,986.23 MWD (2) 7,740.29 96.15 209.71 6,086.26 5,960.26 -2,876.84 -913.93 5,952,012.51 507,460.29 11.89 3,015.92 MWD (2) 7,770.31 t 95.26 212.71 6,083.28 5,957.28 -2,902.38 -929.41 5,951,986.95 507,444.85 10.38 3,045.22 MWD (2) 7,800.29 91.57 213.83 6,081.49 5,955.49 -2,927.40 -945.82 5,951,961.91 507,428.46 12.86 3,074.34 MWD (2) 6` 7,830.39 87.73 214.63 6,081.68 5,955.68 -2,952.28 -962.75 5,951,937.02 507,411.56 13.03 3,103.51 MWD(2) 7,860.17 83.85 215.72 6,083.86 5,957.86 -2,976.55 -979.85 5,951,912.73 507,394.49 13.53 3,132.17 MWD (2) 7,890.74 80.34 217.05 6,088.07 5,962.07 -3,000.92 -997.81 5,951,888.34 507,376.56 12.26 3,161.22 MWD (2) . 7,921.01 79.12 219.96 6,093.46 5,967.46 -3,024.23 -1,016.35 5,951,865.01 507,358.05 10.28 3,189.46 MWD (2) 7,950.58 78.03 223.48 6,099.32 5,973.32 -3,045.86 -1,035.64 5,951,843.36 507,338.79 12.24 3,216.38 MWD (2) 7,980.51 77.44 227.46 6,105.68 5,979.68 -3,066.37 -1,056.48 5,951,822.84 507,317.97 13.14 3,242.78 MWD (2) 8,010.38 76.99 231.10 6,112.30 5,986.30 -3,085.37 -1,078.55 5,951,803.81 507,295.92 11.98 3,268.18 MWD (2) 8,040.05 75.88 234.84 6,119.26 5,993.26 -3,102.73 -1,101.57 5,951,786.42 507,272.92 12.81 3,292.38 MWD (2) 8,070.00 75.88 234.84 6,126.56 6,000.56 -3,119.46 -1,125.32 5,951,769.67 507,249.20 0.00 3,316.22 PROJECTED to TD 11/42016 777.42AM Page 4 COMPASS 5000.1 Build 74 21 6Qg7 RECEIVED 27 74 7 NOV 15 2616 WELL LOG TRANSMITTAL #903595241 AOCCC To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: 213-02A Run Date: 10/11/2016 November 10, 2016 DATA LOGGED M K BENDER The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 2B -02A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer I CD Rom 50-029-22151-01 Multi Finger Caliper (Field Log) 1 color log 50-029-22151-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed: ✓sl��l-iot,� WE P k- 2 BAKER HUGHES To: RECEIVED Nov 0 9 2u iJ Letter of Transmittal AOGCC Date: DATA LOGGED November 8, 2016 M. K. BENDER Makana Bender AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes INTEQ 795 East 94th Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2 160 87 27 70 7 2B-02APB1 2B -02A 2 1 6 0 87 L 7 7 0 6 2B-02AL1 2 1 6 0 88 27 70 8 213-02AL1-01 2 1 6 0 89 27 70 9 (4) Total prints 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. Michael Soper, Baker Hughes, Project Engineer Michael. Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com 11 6087 27itID'6 ConocoPhilli s ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B -02A 50-029-21154-01 Baker Hughes INTEQ //a I Definitive Survey Report HKlEGN tES 04 November, 2016 ConocoPhillips H/%S ConocoPhillips Definitive Survey Report sHUGHES 11/4/2016 7:31:24AM Page 2 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (213-02) Site: Kuparuk 213 Pad MD Reference: 213-02 @ 126.00usft (213-02) Well: 2B-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 2B-02 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 213-02 Well Position +N/ -S 0.00 usft Northing: 5,954,890.07 usft Latitude: 700 17' 16.702 N +E/ -W 0.00 usft Easting: 508,370.93usft Longitude: 149° 55'56.081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 213-02A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 10/1/2016 17.90 80.90 57,541 Design 2B -02A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,560.37 g Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction s (usft) (usft) (usft) (°) 126.00 0.00 0.00 200.00 Survey Program Date 11/1/2016 1 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 213-02 (2B-02) GCT -MS Schlumberger GCT multishot 1/12/2001 6,640.00 7,560.37 213-02APB1 (213-02AP131) MWD MWD- Standard 10/8/2016 10/15/2016 7,580 00 9,535.13 2B 02A (213-02A) MWD MWD Standard 10/16/2016 10/18/2016 11/4/2016 7:31:24AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips Company: Project: Site: Well: Wellbore: Design: Survey MD (usft) 7,560.37 7,580.00 7,610.75 7,640.61 7,670.70 7,700.71 7,730.33 7,760.29 7,790.53 7,820.01 7,850.77 7,880.40 7,910.38 7,940.31 7,970.56 8,000.68 8,030.53 8,060.34 8,090.45 8,120.51 8,150.35 8,180.51 8,210.41 8,240.15 8,270.47 8,300.34 8,330.45 8,360.47 8,390.71 8,420.74 ConocoPhillips Definitive Survey Report //.a6 BAKER HUGHES ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Kuparuk River Unit TVD Reference: 26-02 @ 126.00usft (2B-02) Kuparuk 2B Pad MD Reference: 2B-02 @ 126.00usft (2B-02) 213-02 North Reference: True 26-02 Survey Calculation Method: Minimum Curvature 26-02 Database: EDM Alaska NSK Sandbox ) DLS (°/100') 11.43 10.62 11.31 10.83 21.26 9.86 13.26 14.94 17.10 16.93 12.12 11.71 14.79 9.77 14.65 14.09 13.33 13.90 14.90 13.49 13.67 16.34 14.11 14.91 12.75 12.28 15.61 13.19 17.94 691 Vertical Section Survey Tool Name Annotation (ft) 2,837.20 MWD (2) 2,856.58 MWD (3) 2,887.06 MWD (3) 2,916.75 MWD (3) 2,946.79 MWD (3) 2,976.72 MWD (3) 3,006.12 MWD (3) 3,035.62 MWD (3) 3,064.91 MWD (3) 3,092.73 MWD (3) 3,120.95 MWD (3) 3,147.37 MWD (3) 3,173.12 MWD (3) 3,197.80 MWD (3) 3,221.69 MWD (3) 3,244.22 MWD (3) 3,265.28 MWD (3) 3,284.87 MWD (3) 3,302.96 MWD (3) 3,319.22 MWD (3) 3,333.54 MWD (3) 3,345.90 MWD (3) 3,356.02 MWD (3) 3,364.02 MWD (3) 3,370.06 MWD (3) 3,374.18 MWD (3) 3,376.53 MWD (3) 3,376.92 MWD (3) 3,375.00 MWD (3) 3,372.32 MWD (3) TIP 11/4/2016 7:31:24AM Page 3 COMPASS 5000.1 Build 74 Map Map Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting (usft) (usft) (usft) (usft) (ft) (ft) 91.08 190.01 6,095.85 5,969.85 -2,706.85 -852.92 5,952,180.54 507,521.11 91.22 192.09 6,095.45 5,969.45 -2,728.11 -856.68 5,952,161.28 507,517.37 87.82 192.82 6,095.71 5,969.71 -2,758.13 -663.31 5,952,131.26 507,510.78 86.99 195.95 6,097.06 5,971.06 -2,787.02 -870.72 5,952,102.36 507,503.40 88.50 202.17 6,098.25 5,972.25 -2,815.42 -880.53 5,952,073.95 507,493.62 86.28 204.13 6,099.62 5,973.62 -2,842.99 -892.32 5,952,046.38 507,481.87 87.14 207.97 6,101.32 5,975.32 -2,869.55 -905.30 5,952,019.80 507,468.91 89.57 211.73 6,102.18 5,976.18 -2,895.51 -920.20 5,951,993.82 507,454.04 88.77 216.84 6,102.61 5,976.61 -2,920.49 -937.23 5,951,968.83 507,437.04 90.03 221.67 6,102.92 5,976.92 -2,943.31 -955.88 5,951,945.99 507,418.42 88.80 225.19 6,103.24 5,977.24 -2,965.64 -977.02 5,951,923.64 507,397.31 87.79 228.51 6,104.12 5,978.12 -2,985.89 -998.62 5,951,903.36 507,375.73 87.51 232.94 6,105.35 5,979.35 -3,004.85 -1,021.81 5,951,884.38 507,352.57 86.43 235.66 6,106.93 5,980.93 -3,022.29 -1,046.07 5,951,866.92 507,328.32 84.25 239.53 6,109.39 5,983.39 -3,038.45 -1,071.52 5,951,850.74 507,302.90 86.47 243.16 6,111.83 5,985.83 -3,052.84 -1,097.86 5,951,836.32 507,276.58 87.79 246.92 6,113.32 5,987.32 -3,065.41 -1,124.88 5,951,823.71 507,249.57 89.08 250.86 6,114.14 5,988.14 -3,076.14 -1,152.68 5,951,812.95 507,221.79 90.00 255.25 6,114.38 5,988.38 -3,084.92 -1,181.47 5,951,804.15 507,193.01 89.39 259.26 6,114.54 5,988.54 -3,091.55 -1,210.78 5,951,797.49 507,163.71 89.42 263.34 6,114.85 5,988.85 -3,096.06 -1,240.27 5,951,792.94 507,134.23 89.69 268.26 6,115.08 5,989.08 -3,098.27 -1,270.34 5,951,790.70 507,104.16 88.10 272.17 6,115.66 5,989.66 -3,098.16 -1,300.23 5,951,790.78 507,074.28 88.59 276.58 6,116.52 5,990.52 -3,095.89 -1,329.86 5,951,793.01 507,044.65 88.96 280.43 6,117.17 5,991.17 -3,091.41 -1,359.84 5,951,797.46 507,014.67 90.58 283.72 6,117.29 5,991.29 -3,085.16 -1,389.04 5,951,803.67 506,985.46 87.57 287.33 6,117.77 5,991.77 -3,077.10 -1,418.04 5,951 , 811.70 506,956.46 88.46 291.19 6,118.81 5,992.81 -3,067.21 -1,446.36 5,951,821.56 506,928.13 90.83 296.07 6,119.00 5,993.00 -3,055.09 -1,474.05 5,951,833.64 506,900.43 89.97 294.18 6,118.79 5,992.79 -3,042.34 -1,501.24 5,951,846.36 506,873.23 DLS (°/100') 11.43 10.62 11.31 10.83 21.26 9.86 13.26 14.94 17.10 16.93 12.12 11.71 14.79 9.77 14.65 14.09 13.33 13.90 14.90 13.49 13.67 16.34 14.11 14.91 12.75 12.28 15.61 13.19 17.94 691 Vertical Section Survey Tool Name Annotation (ft) 2,837.20 MWD (2) 2,856.58 MWD (3) 2,887.06 MWD (3) 2,916.75 MWD (3) 2,946.79 MWD (3) 2,976.72 MWD (3) 3,006.12 MWD (3) 3,035.62 MWD (3) 3,064.91 MWD (3) 3,092.73 MWD (3) 3,120.95 MWD (3) 3,147.37 MWD (3) 3,173.12 MWD (3) 3,197.80 MWD (3) 3,221.69 MWD (3) 3,244.22 MWD (3) 3,265.28 MWD (3) 3,284.87 MWD (3) 3,302.96 MWD (3) 3,319.22 MWD (3) 3,333.54 MWD (3) 3,345.90 MWD (3) 3,356.02 MWD (3) 3,364.02 MWD (3) 3,370.06 MWD (3) 3,374.18 MWD (3) 3,376.53 MWD (3) 3,376.92 MWD (3) 3,375.00 MWD (3) 3,372.32 MWD (3) TIP 11/4/2016 7:31:24AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2B-02 Project: Kuparuk River Unit TVD Reference: 2B-02 @ 126.00usft (2B-02) Site: Kuparuk 2B Pad MD Reference: 2B-02 @ 126.00usft (2B-02) Well: 213-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 213-02 Database: EDM Alaska NSK Sandbox Survey _. Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name Annotation (ft) (ft) (ft) 8,450.91 90.34 290.81 6,118.71 5,992.71 -3,030.80 -1,529.11 5,951,857.87 506,845.35 11.24 3,371.01 MWD (3) 8,480.88 89.60 286.88 6,118.73 5,992.73 -3,021.12 -1,557.47 5,951,867.52 506,816.98 13.34 3,371.61 MWD (3) 8,510.24 90.09 282.49 6,118.81 5,992.81 -3,013.68 -1,585.86 5,951,874.93 506,788.58 15.05 3,374.33 MWD (3) 8,540.39 90.61 279.17 6,118.62 5,992.62 -3,008.02 -1,615.47 5,951,880.56 506,758.97 11.15 3,379.13 MWD (3) 8,570.37 91.97 275.73 6,117.95 5,991.95 -3,004.13 -1,645.18 5,951,884.41 506,729.26 12.34 3,385.65 MWD (3) 8,600.26 94.58 273.49 6,116.24 5,990.24 -3,001.73 -1,674.92 5,951,886.77 506,699.52 11.50 3,393.56 MWD (3) 8,630.38 96.43 271.96 6,113.35 5,987.35 -3,000.31 -1,704.87 5,951,888.17 506,669.57 7.96 3,402.47 MWD (3) 8,660.24 98.78 268.99 6,109.40 5,983.40 -3,000.06 -1,734.46 5,951,888.38 506,639.99 12.61 3,412.35 MWD (3) 8,690.45 101.59 266.13 6,104.05 5,978.05 -3,001.32 -1,764.16 5,951,887.09 506,610.29 13.17 3,423.70 MWD (3) 8,720.23 101.33 263.33 6,098.14 5,972.14 -3,004.00 -1,793.22 5,951,884.37 506,581.24 9.26 3,436.16 MWD (3) 8,750.32 100.74 260.57 6,092.38 5,966.38 -3,008.14 -1,822.46 5,951,880.20 506,552.00 9.21 3,450.04 MWD (3) 8,780.32 99.55 257.32 6,087.09 5,961.09 -3,013.80 -1,851.44 5,951,874.51 506,523.03 11.38 3,465.28 MWD (3) 8,810.30 96.80 254.50 6,082.83 5,956.83 -3,021.03 -1,880.21 5,951,867.25 506,494.27 13.07 3,481.91 MWD (3) 8,840.24 94.98 251.87 6,079.75 5,953.75 -3,029.64 -1,908.72 5,951,858.61 506,465.78 10.64 3,499.75 MWD (3) 8,870.33 91.78 247.65 6,077.98 5,951.98 -3,040.03 -1,936.89 5,951,848.19 506,437.62 17.58 3,519.15 MWD (3) 8,900.33 91.23 244.05 6,077.19 5,951.19 -3,052.30 -1,964.25 5,951,835.89 506,410.28 12.14 3,540.04 MWD (3) 8,930.34 91.17 241.36 6,076.56 5,950.56 -3,066.06 -1,990.91 5,951,822.10 506,383.63 8.96 3,562.08 MWD (3) 8,960.33 93.19 238.45 6,075.42 5,949.42 -3,081.08 -2,016.83 5,951,807.05 506,357.73 11.81 3,585.07 MWD (3) 8,990.31 92.58 235.03 6,073.91 5,947.91 -3,097.50 -2,041.87 5,951,790.61 506,332.72 11.57 3,609.06 MWD (3) 9,020.28 91.32 231.09 6,072.89 5,946.89 -3,115.50 -2,065:80 5,951,772.59 506,308.80 13.79 3,634.16 MWD (3) 9,050.46 91.35 228.44 6,072.19 5,946.19 -3,134.99 -2,088.83 5,951,753.07 506,285.80 8.78 3,660.35 MWD (3) 9,080.28 92.95 225.43 6,071.07 5,945.07 -3,155.33 -2,110.60 5,951,732.71 506,264.05 11.42 3,686.91 MWD (3) 9,110.40 94.64 221.67 6,069.08 5,943.08 -3,177.11 -2,131.30 5,951,710.91 506,243.38 13.66 3,714.45 MWD (3) 9,140.56 95.10 218.50 6,066.51 5,940.51 -3,200.10 -2,150.65 5,951,687.90 506,224.06 10.58 3,742.67 MWD (3) 9,170.29 94.36 214.87 6,064.06 5,938.06 -3,223.85 -2,168.35 5,951,664.13 506,206.39 12.42 3,771.05 MWD (3) 9,200.64 93.32 211.65 6,062.03 5,936.03 -3,249.17 -2,184.95 5,951,638.79 506,189.81 11.13 3,800.52 MWD (3) 9,230.39 92.98 208.02 6,060.39 5,934.39 -3,274.93 -2,199.73 5,951,613.02 506,175.07 12.24 3,829.78 MWD (3) 9,260.45 91.14 205.79 6,059.31 5,933.31 -3,301.72 -2,213.32 5,951,586.22 506,161.51 9.61 3,859.60 MWD (3) 9,290.47 90.67 202.27 6,058.84 5,932.84 -3,329.13 -2,225.54 5,951,558.80 506,149.32 11.83 3,889.54 MWD (3) 9,320.55 90.68 199.67 6,058.48 5,932.48 -3,357.21 -2,236.31 5,951,530.70 506,138.59 8.64 3,919.61 MWD (3) 9,350.37 91.10 195.83 6,058.02 5,932.02 -3,385.60 -2,245.39 5,951,502.31 506,129.53 12.95 3,949.40 MWD (3) 11/4/2016 7 31:24AM Page 4 COMPASS 5000.1 Build 74 `- ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2B Pad MD Reference: Well: 213-02 North Reference: Wellbore: 2B-02 Survey Calculation Method: Design: 213-02 Database: Survey SPA .I BAKER HUGHES Well 2B-02 213-02 @ 126.00usft (2B-02) 213-02 @ 126.00usft (2B-02) True s Minimum Curvature 8 EDM Alaska NSK Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Surve Tool Name y (ft) (ft) (ft) 9,380.29 89.51 193.01 6,057.86 5,931.86 -3,414.58 -2,252.84 5,951,473.33 506,122.11 10.82 3,979.17 MWD (3) 9,410.62 88.80 190.04 6,058.31 5,932.31 -3,444.29 -2,258.90 5,951,443.61 506,116.09 10.07 4,009.16 MWD (3) 9,440.41 88.93 166.48 6,058.90 5,932.90 -3,473.76 -2,263.18 5,951,414.14 506,111.84 11.96 4,038.32 MWD (3) 9,470.23 88.96 182.79 6,059.45 5,933.45 -3,503.47 -2,265.59 5,951,384.43 506,109.47 12.37 4,067.06 MWD (3) 9,500.47 88.13 177.94 6,060.22 5,934.22 -3,533.69 -2,265.78 5,951,354.21 506,109.31 16.27 4,095.53 MWD (3) 9,535.13 89.91 175.53 6,060.81 5,934.81 -3,568.29 -2,263.81 5,951,319.62 506,111.32 8.64 4,127.36 MWD (3) 9,570.00 89.91 175.53 6,060.86 5,934.86 -3,603.05 -2,261.09 5,951,284.86 506,114.08 0.00 4,159.10 PROJECTED to TO Annotation 11/4/2016 7:31:24AM Page 5 COMPASS 5000.1 Build 74 ConocoPhilli s p 6 0GO ; ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2B Pad 2B-02APB1 50-029-21154-70 Baker Hughes INTEQ Definitive Survey Report 04 November, 2016 21 6087 27 70 7 FIA FA I BAKER HUGHES �.- ConocoPhillips FS as ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (213-02) Site: Kuparuk 2B Pad MD Reference: 213-02 @ 126.00usft (213-02) Well: 213-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design: 2B-02 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit, North Slope Alaska, United States pp 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 .....-.._,,.,..........._,.F..�_.._......�,_�..�._..�...-_-,-,�-�..-._._.. Well 2B-02 __...��.....,�_..�...r�_...-.r__....n.�....�..W�..�,...m..�,.,�_._._�.._w......,,..,®.nom..-�..�.....».�.._.._ Well Position +N/ -S 0.00 usft Northing: 5,954,890.07 usft Latitude: 70° 17' 16.702 N +E/ -W 0.00 usft Easting: 508,370.93 usft Longitude: 149° 55' 56.081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 213-02AP131 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 6 (I (I (nT) BGGM2016 10/1/2016 17.90 80.90 57,541 Design 213-02AP151 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,600.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 126.00 0.00 0.00 200.00 Survey Program Date 10/15/2016 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 6,600.00 213-02 (2B-02) GCT -MS Schlumberger GCT multishot 1/12/2001 6,640.00 8,040.05 213-02AP131 (2B-02APB1) MWD MWD - Standard 10/8/2016 10/15/2016 11/4/2016 7:27:42AM Page 2 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Definitive Survey Report Azi FeAks BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Map Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (2B-02) Site: Kuparuk 2B Pad MD Reference: 213-02 @ 126.00usft (2B-02) (usft) Well: 26-02 North Reference: True Northing Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Survey Tool Name Design: 213-02 Database: EDM Alaska NSK Sandbox Survey _ (ft) MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Map DLS Vertical (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name (ft) (ft) (ft) 6,600.00 32.25 197.72 6,005.25 5,879.25 -1,819.78 -673.36 5,953,069.72 507,699.67 0.49 1,940.34 MWD (2) 6,640.00 32.34 197.88 6,039.06 5,913.06 -1,840.13 -679.89 5,953,049.37 507,693.16 0.31 1,961.69 MWD (2) 6,661.15 38.27 195.74 6,056.31 5,930.31 -1,851.83 -683.41 5,953,037.67 507,689.65 28.64 1,973.89 MWD (2) 6,690.35 49.50 193.69 6,077.33 5,951.33 -1,871.38 -688.50 5,953,018.11 507,684.58 38.76 1,994.01 MWD (2) 6,720.22 61.41 192.16 6,094.24 5,968.24 -1,895.32 -693.97 5,952,994.17 507,679.14 40.09 2,018.37 MWD (2) 6,750.21 73.50 191.38 6,105.71 5,979.71 -1,922.39 -699.60 5,952,967.10 507,673.54 40.38 2,045.73 MWD (2) 6,782.11 86.10 189.29 6,111.35 5,985.35 -1,953.21 -705.21 5,952,936.27 507,667.96 40.02 2,076.62 MWD (2) 6,810.68 95.72 189.29 6,110.90 5,984.90 -1,981.37 -709.82 5,952,908.11 507,663.39 33.67 2,104.65 MWD (2) 6,840.67 100.03 189.92 6,106.79 5,980.79 -2,010.66 -714.78 5,952,878.82 507,658.46 14.52 2,133.87 MWD (2) 6,870.60 100.68 191.86 6,101.41 5,975.41 -2,039.57 -720.34 5,952,849.91 507,652.94 6.74 2,162.94 MWD (2) 6,900.67 97.42 194.40 6,096.68 5,970.68 -2,068.48 -727.08 5,952,820.99 507,646.22 13.68 2,192.41 MWD (2) 6,930.80 95.41 189.88 6,093.31 5,967.31 -2,097.74 -733.38 5,952,791.72 507,639.96 16.33 2,222.06 MWD (2) 6,960.75 93.13 186.09 6,091.08 5,965.08 -2,127.31 -737.52 5,952,762.15 507,635.85 14.74 2,251.27 MWD (2) 6,990.75 90.71 182.80 6,090.08 5,964.08 -2,157.20 -739.85 5,952,732.26 507,633.56 13.61 2,280.15 MWD (2) 7,020.80 89.29 180.16 6,090.08 5,964.08 -2,187.24 -740.62 5,952,702.23 507,632.82 9.98 2,308.64 MWD (2) 7,050.63 88.80 183.87 6,090.57 5,964.57 -2,217.04 -741.67 5,952,672.43 507,631.80 12.54 2,337.00 MWD (2) 7,080.87 88.50 188.10 6,091.29 5,965.29 -2,247.10 -744.82 5,952,642.37 507,628.68 14.02 2,366.32 MWD (2) 7,110.73 88.34 192.27 6,092.11 5,966.11 -2,276.47 -750.10 5,952,612.99 507,623.44 13.97 2,395.73 MWD (2) 7,141.31 91.47 197.32 6,092.16 5,966.16 -2,306.02 -757.90 5,952,583.44 507,615.67 19.43 2,426.17 MWD (2) 7,170.25 91.01 201.47 6,091.53 5,965.53 -2,333.31 -767.51 5,952,556.14 507,606.09 14.42 2,455.10 MWD (2) 7,200.03 89.75 203.82 6,091.34 5,965.34 -2,360.79 -778.97 5,952,528.65 507,594.66 8.95 2,484.84 MWD (2) 7,230.37 87.79 206.79 6,091.99 5,965.99 -2,388.21 -791.94 5,952,501.22 507,581.73 11.73 2,515.04 MWD (2) 7,260.43 88.07 204.42 6,093.07 5,967.07 -2,415.30 -804.92 5,952,474.12 507,568.78 7.93 2,544.93 MWD (2) 7,290.33 89.02 200.73 6,093.83 5,967.83 -2,442.89 -816.39 5,952,446.52 507,557.34 12.74 2,574.79 MWD (2) 7,320.44 88.37 196.84 6,094.52 5,968.52 -2,471.38 -826.08 5,952,418.02 507,547.68 13.10 2,604.88 MWD (2) 7,350.42 87.27 193.08 6,095.66 5,969.66 -2,500.32 -833.82 5,952,389.07 507,539.98 13.06 2,634.71 MWD (2) 7,380.46 88.86 189.60 6,096.67 5,970.67 -2,529.75 -839.72 5,952,359.64 507,534.11 12.73 2,664.39 MWD (2) 7,410.71 89.29 185.78 6,097.16 5,971.16 -2,559.72 -843.76 5,952,329.67 507,530.10 12.71 2,693.93 MWD (2) 7,440.21 89.35 182.34 6,097.51 5,971.51 -2,589.14 -845.85 5,952,300.25 507,528.05 11.66 2,722.29 MWD (2) 7,470.75 89.82 178.50 6,097.73 5.971.73 -2,619.67 -846.08 5,952,269.72 507,527.86 12.67 2,751.06 MWD (2) Annotation 11/4/2016 7:27:42AM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips wed &I ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 213-02 Project: Kuparuk River Unit TVD Reference: 213-02 @ 126.00usft (213-02) Site: Kuparuk 26 Pad MD Reference: 213-02 @ 126.00usft (2B-02) ) Well: 28-02 North Reference: True Wellbore: 213-02 Survey Calculation Method: Minimum Curvature Design 213-02 Database: EDM Alaska NSK Sandbox Survey ) Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°/100') Section Survey Tool Name Annotation (ft) (ft) (ft) 7,500.35 91.69 182.25 6,097.34 5,971.34 -2,649.26 -846.27 5,952,240.13 507,527.70 14.16 2,778.93 MWD (2) 7,530.35 91.47 186.60 6,096.52 5,970.52 -2,679.15 -848.58 5,952,210.24 507,525.42 14.51 2,807.81 MWD (2) 7,560.37 91.08 190.01 6,095.85 5,969.85 -2,708.85 -852.92 5,952,180.54 507,521.11 11.43 2,837.20 MWD (2) 7,590.32 91.29 193.18 6,095.23 5,969.23 -2,738.18 -858.93 5,952,151.21 507,515.13 10.61 2,866.82 MWD (2) 7,620.32 93.38 196.60 6,094.01 5,968.01 -2,767.14 -866.63 5,952,122.24 507,507.46 13.35 2,896.67 MWD (2) 7,650.35 93.13 200.61 6,092.30 5,966.30 -2,795.55 -876.20 5,952,093.83 507,497.93 13.36 2,926.63 MWD (2) % 7,685.35 92.52 203.51 6,090.57 5,964.57 -2,827.94 -889.33 5,952,061.42 507,484.84 8.46 2,961.56 MWD (2) 7,710.16 94.49 206.52 6,089.06 5,963.06 -2,850.38 -899.80 5,952,038.97 507,474.40 14.48 2,986.23 MWD (2) 7,740.29 96.15 209.71 6,086.26 5,960.26 -2,876.84 -913.93 5,952,012.51 507,460.29 11.89 3,015.92 MWD (2) 7,770.31 95.26 212.71 6,083.28 5,957.28 -2,902.38 -929.41 5,951,986.95 507,444.85 10.38 3,045.22 MWD (2) € 7,800.29 91.57 213.83 6,081.49 5,955.49 -2,927.40 -945.82 5,951,961.91 507,428.46 12.86 3,074.34 MWD (2) 7,830.39 87.73 214.63 6,081.68 5,955.68 -2,952.28 -962.75 5,951,937.02 507,411.56 13.03 3,103.51 MWD (2) 7,860.17 83.85 215.72 6,083.86 5,957.86 -2,976.55 -979.85 5,951,912.73 507,394.49 13.53 3,132.17 MWD (2) 7,890.74 80.34 217.05 6,088.07 5,962.07 -3,000.92 -997.81 5,951,888.34 507,376.56 12.26 3,161.22 MWD (2) 7,921.01 79.12 219.96 6,093.46 5,967.46 -3,024.23 -1,016.35 5,951,865.01 507,358.05 10.28 3,189.46 MWD (2) 7,950.58 78.03 223.48 6,099.32 5,973.32 -3,045.86 -1,035.64 5,951,843.36 507,338.79 12.24 3,216.38 MWD (2) 7,980.51 77.44 227.46 6,105.68 5,979.68 -3,066.37 -1,056.48 5,951,822.84 507,317.97 13.14 3,242.78 MWD (2) 8,010.38 76.99 231.10 6,112.30 5,986.30 -3,085.37 -1,078.55 5,951,803.81 507,295.92 11.98 3,268.18 MWD (2) 8,040.05 75.88 234.84 6,119.26 5,993.26 -3,102.73 -1,101.57 5,951,786.42 507,272.92 12.81 3,292.38 MWD (2) 8,070.00 75.88 234.84 6,126.56 6,000.56 -3,119.46 -1,125.32 5,951,769.67 507,249.20 0.00 3,316.22 PROJECTED to TD 11/4/2016 7:27 42AM Page 4 COMPASS 5000.1 Build 74 THE STATE of I-ILASKA GOVERNOR BILL WALKER Jason Burke CTD Coordinator ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Cas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 213-02A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-087 Surface Location: 744' FSL, 273' FEL, SEC. 19, Tl 1N, R9E, UM Bottomhole Location: 1968' FSL, 2478' FEL, SEC. 30, TI IN, R9E, UM Dear Mr. Burke: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this %G' "day of August, 2016. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 71 RECEIVED JUL 13 2016 1`\OGCC 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG L Service - Disp 1c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑✓ ' Service - Winj ❑ Single Zone 8 Coalbed Gas ❑ Gas Hydrates ❑ Redrill 0' Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 5952180 11146.1213-02A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 9900' TVD: 1 6095 Kuparuk River Field/ Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease NumbvL) Surface: 744' FSL, 273' FEL, Sec 19, T11N, R9E, UM ADL 25656 S5 }7� Top of Productive Horizon: 8. Land UsePermit: 13. Approximate Spud Date: 2964' FSL, 1771' FEL, Sec 30, T11 N, R9E, UM ALK 2582 9/15/2016 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1968' FSL, 2478 FEL, Sec 30, T11 N, R9E, UM 2560 ' a+q $O 18000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): ��(Q 15. Distance to Nearest Well Open Surface: x-508371 y-5954890 Zone -4 GL Elevation above MSL (ft): 92' to Same Pool: 950' (213-07) 16. Deviated wells: Kickoff depth: 6640 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 99 degrees Downhole: 3973 psi � Surface: 3369 psi , 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" 2-3/8" 4.7# L-80 ST -L 1515' 8385' 6119' 9900' 6095' N/A 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): 6976 6322 N/A 6851 6216 Fish - 6685' MD Casing Length Size Cement Volume MD ND Conductor/Structural 110' 16" 119 sx Cold Set II 110' 110' Surface 2727' 9.625" 800 sx Cold Set III, 300 sx Cold Set II 2727' 2727' Intermediate Production 6934' 7" 280 sx Class G, 250 sx Cold Set I 6934' 6287' Liner Perforation Depth MD (ft): 6526'-6568', Perforation Depth TVD (ft): 5943'-5978', 6022'-6098' 6620'-6710' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 7 /6 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not mike Callahan 263-4180 be deviated from without prior written approval. Contact mike. callahan&cop.com Email Printed Name Jason Burke Title CTD Coordinator Signature Phone 265-6097 Date Commission Use Only Permit to Dri API Number: Permit Approval See cover letter for other Number: ' Q 50- ltli'Q Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other:Samples req'd: Yes Nod Mud log req'd: Yes❑ Nod 130P fe' S f re -5 5 Vr C to 3 S U p S 1 �" ✓ ,�Nviv�a V�rztry t��T f J' o SGU t HZS measures: Yes [0 No❑ Directional svy req'd: Yes [✓ No[-]✓�r� Spacin7e'xception req'd: Yes ❑ Nod Inclination -only svy req'd: Yes ❑ Noy Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401 (Revised 11/2015) This permit is valid for 24 months from t e date of approval (20 AAC 25.005(g)) Attachments in Duplicate ORIGINAL 1.00e /9 ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 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 applications for permits to drill 5 laterals out of the Kuparuk Well 213-02 using the coiled tubing drilling rig, Nabors CDR2-AC or CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. A sundry application is attached to plug the KRU 213-02 (184-122) perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A/C -sand perforations in 213-02. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 213-02 (184-122) — Operations Summary in support of the 10-403 sundry application — 10-401 Applications for 213-02A, 213-02AL1, 213-02AL1-01, 213-02AL1-02, and 213-02AL2 — Detailed Summary of Operations — Directional Plans for 213-02A, 213-02AL1, 213-02AL1-01, 213-02AL1-02, and 213-02AL2 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, i Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORSw;ASKA 2B -02A, AL1, AL1 -01, AL2 & AL2 -01 CIM, Application for Permit to Drill Document 2At 1. Well Name and Classification...........................................................................................................2 (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))......................................................................................................................2 2. Location Summary.............................................................................................................................2 (Requirements of 20 AAC 25.005(c)(2))...................................................................................................................................................... 2 3. Blowout Prevention Equipment Information...................................................................................2 (Requirements of 20 AAC 25.005(c)(3))..................................................................................................................................................... 2 4. Drilling Hazards Information and Reservoir Pressure....................................................................2 (Requirements of 20 AAC 25.005(c)(4))..................................................................................................................................................... 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 AAC 25.005(c)(8))...................................................................................................................................................... 3 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9))...................................................................................................................................................... ...............................................................................4 4 10. Seismic Analysis................................................................................................................................4 (Requirements of 20 AAC 25.005(c)(10)).................................................................................................................................................... 4 11. Seabed Condition Analysis...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11)) .................................................................................................................................................... 4 12. Evidence of Bonding.........................................................................................................................4 (Requirements of 20 AAC 25.005(c)(12)).................................................................................................................................................... 4 13. Proposed Drilling Program...............................................................................................................4 (Requirements of 20 AAC 25.005(c)(13)). --r .................... .......................................................................... ..... .......... .......... ....... ........ 4 Summaryof Operations.................................................................................................................................................. 4 LinerRunning.................................................................................................................................................................. 6 14. Disposal of Drilling Mud and Cuttings.............................................................................................7 (Requirements of 20 AAC 25.005(c)(14)).................................................................................................................................................... 7 15. Directional Plans for Intentionally Deviated Wells..........................................................................7 (Requirements of 20 AAC 25.050(b)).......................................................................................................................................................... 7 16. Attachments.......................................................................................................................................7 Attachment 1: Directional Plans for 213-02A, AL1, AL1 -01, AL12 & AL2 -01 laterals....................................................... 7 Attachment 2: Current Well Schematic for 213-02........................................................................................................... 7 Attachment 3: Proposed Well Schematic for 213-02A, AL1, AL1 -01, AL2 & AL2 -01 laterals ........................................... 7 Page 1 of 7 July 13, 2016 PTD Application: 213-02A. AL1. AL1 -01_ AL2 P. All 2-ni 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 213-02A, 213-02AL1, 2B-02AL1-01, 213-02AL2, & 213- 02AL2-01. All laterals will be classified as Production wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 2B -02A, 213-02AL1, 26-02AL1-01, 213-02AL2, & 2B-02AL2-01. 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. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. iv0G3 rV 0 — Pipe rams, blind rams and the CT pack off will be pre ure tested to 250 psi and to 3750 psi. Using the maximum formation pressure in the area of 397 psi in 2B-08 (12.6 ppg EMW), the maximum potential surface pressure in 213-02, assuming a gas gradient of 0.1 psi/ft, would be 3369 psi./See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 213-02 was measured to be 2142 psi (6.9 ppg EMW) on 5/7/2016. The maximum downhole pressure in the 213-02 vicinity is to the west in the 213-08 injector at 3973 psi (12.6 ppg 7 EMW) from March of 2014. Pressure management in the area is expected to bring the formation pressure down to —11.0 ppg by the time of drilling. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) Wells on 2B pad have injected gas, so there is a chance of encountering free gas while drilling the 213-02 laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 26-02 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 213-02 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 July 13, 2016 PTD Application: 213-02A, AL1, AL1 -01, AL2 & AL2 -01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm;5871' Top Liner Btm Top MD Btm MD MD MD S TVDSS Liner Details 2B -02A 8385' 9900'3' Welded 5969` 2-3/8", 4.7#, L-80, ST -L slotted liner; TVD 0' TVD 110' psi 1640 psi 670 Surface aluminum billet on top 2B-02AL1 8500' 10425'' 0' 5899, 2-3/8", 4.7#, L-80, ST -L slotted liner; 2727' 3620 2020 Production 7 aluminum billet on to 2B-02AL1-01 6630' 9800' 5989' 2-3/8", 4.7#, L-80, ST -L slotted liner; 4980 4320 Tubing 3-1/2" 9.3 de to ment sleeve on to 26-02AL2 8300' 9900' 5997' 5965' 2-3/8', 4.7#, L-80, ST -L slotted liner; 7400 aluminum billet on to 26-02AL2-01 6600' 10500' 5879' 5896' 2-3/8", 4.7#, L-80, ST -L slotted liner; deployment sleeve on to Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top Btm Burst Collapse Conductor 16" 62.5 H-40 Welded 0' 110' TVD 0' TVD 110' psi 1640 psi 670 Surface 9-5/8" 36.0 J-55 BTC 0' 2727' 0' 2727' 3620 2020 Production 7 26.0 J-55 BTC 0' 6934' 0' 6287' 4980 4320 Tubing 3-1/2" 9.3 J-55 EUE-8rd 0 6616' 0 6019' 6980 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based FloVis mud (8.6 ppg) — Drilling operations: Chloride -based FloPro mud (8.6 ppg)../This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid (unless unexpected, higher pressure is encountered, in which case higher density NaBr or potassium formate will be used) in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole 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 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 213-02 laterals we will target a constant BHP of 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 Page 3 of 7 July 13, 2016 PTD Application: 213-02A, AL1, AL1 -01. AL2 & AL2 -01 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. Pressure at the 2B-02 Window 6640' MD 6039' ND) Usina MPD 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 well 213-02 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize up to five laterals to target the A3/A4 sands to the north and south of 213-02. Prior to CTD operations, E -Line will punch 2' of holes in the 3-1/2" tubing tail at 6609' MD and the "D" nipple at 6611' MD will be milled out to a 2.80" ID. The existing C -Sand perforations will be squeezed with cement to abandon the C -Sand. A second cement job will then be performed to cover the A -Sand perfs and provide the cement pilot hole for the kick -out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand and C -sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 6650' MD and set a mechanical whip -stock in the 2.80" pilot hole to kick off at 6640' MD. All five laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 July 13, 2016 Pumps On (1.5 b m Pumps Off A -sand Formation Pressure (6.9 p ) 2158 psi 2158 DSi Mud Hydrostatic 8.6 ) 2701 psi 2701 nsi Annular friction i.e. ECD, 0.090 psi/ft 598 psi 0 psi Mud + ECD Combined no choke pressure)P 3299 psi 2701 si Target BHP at Window 11.8 3706 psi 3706 psi Choke Pressure Required to Maintain Target BHP 407 psi p 1005 psi 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 well 213-02 is a Kuparuk A/C -sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize up to five laterals to target the A3/A4 sands to the north and south of 213-02. Prior to CTD operations, E -Line will punch 2' of holes in the 3-1/2" tubing tail at 6609' MD and the "D" nipple at 6611' MD will be milled out to a 2.80" ID. The existing C -Sand perforations will be squeezed with cement to abandon the C -Sand. A second cement job will then be performed to cover the A -Sand perfs and provide the cement pilot hole for the kick -out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand and C -sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 6650' MD and set a mechanical whip -stock in the 2.80" pilot hole to kick off at 6640' MD. All five laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Page 4 of 7 July 13, 2016 PTD Application: 2B -02A, AL1, AL1 -01, AL2 & AL2 -01 213-02A southern lateral will exit the cement pilot hole at 6640' MD and TD at 9900' MD, targeting the A4 and A3 Sands. It will be completed wit 2- " slotted liner from TD up to 8385'MD with an aluminum billet for kicking off the 213-02AL 1. The 213-02AL1 lateral will kickoff of the aluminum billet at 8385' and drill to the north to a TD of 10425' MD targeting the A4 Sand. It will be completed with 2-3/8" slotted liner from TD up to 8500' MD with an anchored billet for kicking off the 213-02AL1-01. The 213-02AL1-01 lateral will kickoff the anchored billet at 8500' and drill to the north to a TD of 9800' MD, targeting the A3 Sand. It will be completed with 2-3/8" slotted liner from TD back into the cement pilot hole with a deployment sleeve. The 213-02AL2 lateral will exit the cement pilot hole at 6630' and drill to the south to a TD of 9900' MD. It will be completed with 2-3/8" slott liner from TD up to 8300' MD with an anchored billet for kicking off the 2B-02AL2-01. The 2B-02AL2-01 lateral will kickoff the anchored billet at 8300' and drill to the north to a TD of 10500' MD. It will be completed with 2-3/8" slotted liner from TD back into the 3-1/2" tubing tail with a deployment sleeve. Pre -CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E -line: Punch 2' of holes in the 3'/2" tubing tail at 6609' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out "D" nipple and cement squeeze the C -sand perforations. Wait on cement for 72 hours. 5. RU Service Coil: Cement squeeze A -Sand perforations and leave plug for cement pilot hole. 6. RU Slick -line: Tag top of cement and pressure test cement. 7. Prep site for Nabors CDR2-AC and set BPV. Rid Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 213-02A Sidetrack (A3/A4 Sands - South) Drill 2.80" high -side pilot hole through cement to 6670' MD Caliper pilot hole iii. Set top of whip -stock at 6640' MD iv. Mill 2.80" window at 6640' MD. v. Drill 3" bi-center lateral to TD of 9900' MD. vi. Run 2%" slotted liner with an aluminum billet from TD up to 8385' MD. 3. 213-02AL1 Lateral (A4 Sand - North) i. Kickoff of the aluminum billet at 8385' MD. ii. Drill 3" bi-center lateral to TD of 10425' MD. iii. Run 2%" slotted liner with anchored billet from TD up to 8500' MD. Page 5 of 7 July 13, 2016 PTD Application: 2B -02A, AL1. AL1 -01. AL2 & AL2_01 4. 213-02AL1-01 Lateral (A3 Sand -North) i. Kick off of the aluminum billet at 8500' MD. ii. Drill 3" bi-center lateral to TD of 9800' MD. iii. Run 2%" slotted liner with deployment sleeve from TD up to 6635' MD. 5. 213-02AL2 Lateral (A3/A4 Sand - South) i. Set top of whipstock at 6630' MD. ii. Mill 2.80" window at 6630' MD iii. Drill 3" bi-center lateral to TD of 9900' MD. iv. Run 2%" slotted liner with anchored billet from TD up to 8300' MD. 6. 2B-02AL2-01 Lateral (A3/A4 Sand - North) i. Kick off of the aluminum billet at 8300' MD. ii. Drill 3" bi-center lateral to TD of 10500' MD. iii. Run 2%" slotted liner with deployment sleeve from TD up to 6600' MD. 7. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post -Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to 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 using 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 slick -line. — 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. Liner Running — The 26-02 laterals will be displaced to an overbalancing fluid (11.8 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. Page 6 of 7 July 13, 2016 PTD Application: 213-02A, AL1, AL1 -01, AL2 & AL2 -01 — While running 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 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 (1 R-18 or 1 B 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 Plans — 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 open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name I Distance 26-02A 18000' 2B-02AL1 18900' 2B-02AL1-01 18900' 2113-02AL2 18000' 2B-02AL2-01 18900' — Distance to Nearest Well within Pool Lateral Name Distance Well - 2B -02A 950' 26-07 213-02AL1 1580' 213-08 2B-02AL1-01 1475' 213-08 2B-02AL2 950' 213-07 2B-02AL2-01 1465' 213-08 16. Attachments Attachment 1: Directional Plans for 2B -02A, AL 1, AL 1-01, AL2 & AL2 -01 laterals Attachment 2: Current Well Schematic for 2B-02 Attachment 3: Proposed Well Schematic for 2B -02A, AL 1, AL 1-01, AL2 & AL2 -01 laterals Page 7 of 7 July 13, 2016 L �w�®i®ss wii �.' •J :.:.szssas�es = �s ConocoPhillips ConocoPh i I I i ps ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 213 Pad 2B-02 2B -02A Plan: 2B-02A_wp05 Standard Planning Report 11 July, 2016 WE & I BAKER HUGHES ConocoPhillips Database: EDM Alaska NSK Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2B Pad Well: 2B-02 Wellbore: 2B -02A Design: 2B-02A_wp05 ConocoPhillips Planning Report Local Co-ordinate Reference: Well 213-02 TVD Reference: Mean Sea Level MD Reference: 2B-02 @ 126.00usft (2B-02) North Reference: True Survey Calculation Method: Minimum Curvature 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 rias BAKER HUGHES Wellbore 213-02A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1) (nT) BG G M 2016 10/1/2016 17.90 80.90 57,541 Design 2B-02A_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,600.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 0.00 0.00 0.00 200.00 7/11/2016 12:01:57PM Page 2 COMPASS 5000.1 Build 74 Site Kuparuk 213 Pad Site Position: Northing: 5,954,944.68 usft Latitude: 70° 17' 17.239 N From: Map Easting: 508,346.10 usft Longitude: 149° 55'56.803 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.06 ° Well 2B-02 Well Position +N/ -S 0.00 usft Northing: 5,954,890.07 usft Latitude: 70° 17' 16.702 N +E/ -W 0.00 usft Easting: 508,370.93 usft Longitude: 149° 55'56.081 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 213-02A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1) (nT) BG G M 2016 10/1/2016 17.90 80.90 57,541 Design 2B-02A_wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,600.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 0.00 0.00 0.00 200.00 7/11/2016 12:01:57PM Page 2 COMPASS 5000.1 Build 74 I i ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2B-02 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 213-02 @ 126.00usft (213-02) Site: Kuparuk 2B Pad North Reference: True Well: 2B-02 Survey Calculation Method: Minimum Curvature Wellbore: 213-02A Azimuth System Design: 2B-02A_wp05 Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (1) V) (usft) (usft) (usft) (°1100ft) (°/100ft) (°/100ft) (1) Target 6,600.00 32.25 197.72 5,879.25 -1,819.78 -673.36 0.00 0.00 0.00 0.00 6,640.00 32.34 197.88 5,913.06 -1,840.13 -679.89 0.31 0.23 0.40 43.59 6,661.00 36.54 197.88 5,930.38 -1,851.43 -683.53 20.00 20.00 0.00 0.00 6,802.57 96.00 197.88 5,984.83 -1,969.31 -721.56 42.00 42.00 0.00 0.00 6,900.00 98.89 186.45 5,972.16 -2,063.57 -741.92 12.00 2.97 -11.73 285.00 7,010.00 88.03 178.92 5,965.53 -2,173.01 -747.01 12.00 -9.87 -6.85 215.00 7,225.00 86.05 204.68 5,976.81 -2,381.41 -790.52 12.00 -0.92 11.98 95.00 7,375.00 89.32 186.96 5,982.92 -2,525.02 -831.19 12.00 2.18 -11.81 280.00 7,455.00 97.17 181.43 5,978.40 -2,604.58 -837.04 12.00 9.82 -6.92 325.00 7,525.00 92.31 188.31 5,972.61 -2,674.02 -842.98 12.00 -6.94 9.83 125.00 7,725.00 87.27 211.78 5,973.35 -2,860.54 -911.03 12.00 -2.52 11.74 102.00 7,875.00 85.86 229.76 5,982.41 -2,973.47 -1,008.39 12.00 -0.94 11.99 95.00 7,945.00 85.90 238.18 5,987.45 -3,014.50 -1,064.80 12.00 0.06 12.03 90.00 8,015.00 89.48 245.79 5,990.27 -3,047.32 -1,126.49 12.00 5.11 10.87 65.00 8,315.00 89.58 281.79 5,992.82 -3,079.24 -1,419.84 12.00 0.03 12.00 90.00 8,385.00 90.31 290.16 5,992.89 -3,059.99 -1,487.08 12.00 1.05 11.95 85.00 8,455.00 90.31 281.76 5,992.51 -3,040.76 -1,554.32 12.00 0.00 -12.00 270.00 8,555.00 98.76 273.20 5,984.60 -3,027.76 -1,652.97 12.00 8.45 -8.55 315.00 8,705.00 98.95 254.99 5,961.32 -3,042.93 -1,799.75 12.00 0.12 -12.15 272.00 8,805.00 97.71 242.92 5,946.78 -3,078.41 -1,891.91 12.00 -1.23 -12.06 265.00 8,905.00 89.93 233.76 5,940.11 -3,130.72 -1,976.66 12.00 -7.78 -9.16 230.00 9,305.00 89.21 185.76 5,943.28 -3,467.89 -2,169.45 12.00 -0.18 -12.00 269.00 9,405.00 87.16 173.93 5,946.46 -3,567.65 -2,169.18 12.00 -2.05 -11.83 260.00 9,605.00 87.41 197.96 5,956.08 -3,764.89 -2,189.73 12.00 0.12 12.01 90.00 9,900.00 87.89 162.53 5,968.60 -4,054.95 -2,190.94 12.00 0.16 -12.01 270.00 7/11/2016 12:01:57PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 26-02 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 213-02 @ 126.00usft (2B-02) Site: Kuparuk 2B Pad North Reference: True Well: 213-02 Survey Calculation Method: Minimum Curvature Wellbore: 213-02A Depth Inclination Design: 2B-02A_wp05 +N/ -S +E/ -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 6,600.00 32.25 197.72 5,879.25 -1,819.78 -673.36 1,940.34 0.00 0.00 5,953,069.72 507,699.67 TIP 6,640.00 32.34 197.88 5,913.06 -1,840.13 -679.89 1,961.69 0.31 43.59 5,953,049.37 507,693.16 KOP 6,661.00 36.54 197.88 5,930.38 -1,851.43 -683.53 1,973.56 20.00 0.00 5,953,038.07 507,689.52 End 20 dls, Start 42 dis 6,700.00 52.92 197.88 5,957.99 -1,877.46 -691.93 2,000.89 42.00 0.00 5,953,012.03 507,681.16 6,800.00 94.92 197.88 5,985.07 -1,966.87 -720.78 2,094.78 42.00 0.00 5,952,922.59 507,652.41 6,802.57 96.00 197.88 5,984.83 -1,969.31 -721.56 2,097.34 42.00 0.00 5,952,920.15 507,651.63 End 42 dls, Start 12 dls 6,900.00 98.89 186.45 5,972.16 -2,063.57 -741.92 2,192.87 12.00 -75.00 5,952,825.88 507,631.38 5 7,000.00 89.02 179.60 5,965.27 -2,163.01 -747.14 2,288.10 12.00 -145.00 5,952,726.44 507,626.27 7,010.00 88.03 178.92 5,965.53 -2,173.01 -747.01 2,297.45 12.00 -145.47 5,952,716.45 507,626.41 6 7,100.00 87.13 189.69 5,969.34 -2,262.54 -753.76 2,383.89 12.00 95.00 5,952,626.92 507,619.77 7,200.00 86.25 201.68 5,975.13 -2,358.48 -780.70 2,483.26 12.00 94.54 5,952,530.96 507,592.94 7,225.00 86.05 204.68 5,976.81 -2,381.41 -790.52 2,508.16 12.00 93.85 5,952,508.02 507,583.14 7 7,300.00 87.66 195.81 5,980.94 -2,451.59 -816.40 2,582.97 12.00 -80.00 5,952,437.82 507,557.34 7,375.00 89.32 186.96 5,982.92 -2,525.02 -831.19 2,657.02 12.00 -79.51 5,952,364.38 507,542.63 8 7,400.00 91.77 185.24 5,982.69 -2,549.87 -833.85 2,681.29 12.00 -35.00 5,952,339.53 507,540.00 7,455.00 97.17 181.43 5,978.40 -2,604.58 -837.04 2,733.79 12.00 -35.02 5,952,284.82 507,536.87 9 7,500.00 94.05 185.86 5,974.00 -2,649.25 -839.90 2,776.75 12.00 125.00 5,952,240.15 507,534.07 7,525.00 92.31 188.31 5,972.61 -2,674.02 -842.98 2,801.07 12.00 125.43 5,952,215.38 507,531.01 10 7,600.00 90.42 197.11 5,970.82 -2,747.09 -859.46 2,875.37 12.00 102.00 5,952,142.30 507,514.61 7,700.00 87.89 208.84 5,972.29 -2,838.98 -898.42 2,975.04 12.00 102.21 5,952,050.38 507,475.76 7,725.00 87.27 211.78 5,973.35 -2,860.54 -911.03 2,999.61 12.00 102.04 5,952,028.81 507,463.18 11 7,800.00 86.52 220.76 5,977.42 -2,920.85 -955.28 3,071.43 12.00 95.00 5,951,968.45 507,418.99 7,875.00 85.86 229.76 5,982.41 -2,973.47 -1,008.39 3,139.04 12.00 94.51 5,951,915.77 507,365.96 12 7,900.00 85.86 232.77 5,984.22 -2,989.07 -1,027.83 3,160.35 12.00 90.00 5,951,900.15 507,346.53 7,945.00 85.90 238.18 5,987.45 -3,014.50 -1,064.80 3,196.89 12.00 89.78 5,951,874.69 507,309.59 13 8,000.00 88.71 244.16 5,990.04 -3,040.98 -1,112.90 3,238.22 12.00 65.00 5,951,848.16 507,261.52 8,015.00 89.48 245.79 5,990.27 -3,047.32 -1,126.49 3,248.83 12.00 64.72 5,951,841.80 507,247.94 14 8,100.00 89.49 255.99 5,991.04 -3,075.11 -1,206.70 3,302.37 12.00 90.00 5,951,813.93 507,167.78 8,200.00 89.52 267.99 5,991.91 -3,089.02 -1,305.54 3,349.25 12.00 89.91 5,951,799.91 507,068.96 8,300.00 89.57 279.99 5,992.71 -3,082.07 -1,405.11 3,376.78 12.00 89.80 5,951,806.74 506,969.39 8,315.00 89.58 281.79 5,992.82 -3,079.24 -1,419.84 3,379.15 12.00 89.71 5,951,809.56 506,954.66 1s 8,385.00 90.31 290.16 5,992.89 -3,059.99 -1,487.08 3,384.06 12.00 85.00 5,951,828.73 506,887.41 16 8,400.00 90.31 288.36 5,992.81 -3,055.04 -1,501.24 3,384.25 12.00 -90.00 5,951,833.66 506,873.25 8,455.00 90.31 281.76 5,992.51 -3,040.76 -1,554.32 3,388.99 12.00 -90.01 5,951,847.89 506,820.15 17 8,500.00 94.12 277.93 5,990.77 -3,033.07 -1,598.60 3,396.91 12.00 -45.00 5,951,855.52 506,775.86 7/11/2016 12:01:57PM Page 4 COMPASS 5000.1 Build 74 `, ConocoPhillips ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 26-02 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 26-02 @ 126.00usft (26-02) Site: Kuparuk 2B Pad North Reference: True Well: 213-02 Survey Calculation Method: Minimum Curvature Wellbore: 213-02A Design: 2B-02A_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (o) (o) (usft) (usft) (usft) (usft) (°1100ft) V) (usft) (usft) 8,555.00 98.76 273.20 5,984.60 -3,027.76 -1,652.97 3,410.51 12.00 -45.15 5,951,860.77 506,721.50 18 8,600.00 98.91 267.74 5,977.68 -3,027.39 -1,697.41 3,425.37 12.00 -88.00 5,951,861.09 506,677.06 8,700.00 98.95 255.59 5,962.10 -3,041.68 -1,794.97 3,472.16 12.00 -88.84 5,951,846.70 506,579.53 8,705.00 98.95 254.99 5,961.32 -3,042.93 -1,799.75 3,474.97 12.00 -90.73 5,951,845.44 506,574.75 19 8,800.00 97.78 243.52 5,947.46 -3,076.18 -1,887.48 3,536.22 12.00 -95.00 5,951,812.10 506,487.06 8,805.00 97.71 242.92 5,946.78 -3,078.41 -1,891.91 3,539.83 12.00 -96.67 5,951,809.86 506,482.64 20 8,900.00 90.32 234.21 5,940.12 -3,127.78 -1,972.61 3,613.82 12.00 -130.00 5,951,760.41 506,402.00 8,905.00 89.93 233.76 5,940.11 -3,130.72 -1,976.66 3,617.97 12.00 -130.61 5,951,757.46 506,397.96 21 9,000.00 89.74 222.36 5,940.38 -3,194.11 -2,047.20 3,701.67 12.00 -91.00 5,951,694.00 506,327.49 9,100.00 89.54 210.36 5,941.01 -3,274.49 -2,106.38 3,797.44 12.00 -90.97 5,951,613.56 506,268.41 9,200.00 89.37 198.36 5,941.97 -3,365.42 -2,147.55 3,896.96 12.00 -90.89 5,951,522.60 506,227.34 9,300.00 89.22 186.36 5,943.21 -3,462.91 -2,168.92 3,995.89 12.00 -90.78 5,951,425.09 506,206.08 9,305.00 89.21 185.76 5,943.28 -3,467.89 -2,169.45 4,000.74 12.00 -90.63 5,951,420.12 506,205.56 22 9,400.00 87.26 174.52 5,946.21 -3,562.68 -2,169.69 4,089.90 12.00 -100.00 5,951,325.33 506,205.43 9,405.00 87.16 173.93 5,946.46 -3,567.65 -2,169.18 4,094.40 12.00 -99.65 5,951,320.36 506,205.94 23 9,500.00 87.22 185.34 5,951.13 -3,662.38 -2,168.59 4,183.21 12.00 90.00 5,951,225.65 506,206.64 9,600.00 87.39 197.36 5,955.85 -3,760.13 -2,188.21 4,281.78 12.00 89.44 5,951,127.88 506,187.13 9,605.00 87.41 197.96 5,956.08 -3,764.89 -2,189.73 4,286.77 12.00 88.87 5,951,123.12 506,185.62 24 9,700.00 87.46 186.55 5,960.35 -3,857.48 -2,209.83 4,380.65 12.00 -90.00 5,951,030.52 506,165.61 9,800.00 87.62 174.54 5,964.66 -3,957.20 -2,210.77 4,474.68 12.00 -89.49 5,950,930.81 506,164.78 9,900.00 87.89 162.53 5,968.60 -4,054.95 -2,190.94 4,559.75 12.00 -88.97 5,950,833.09 506,184.72 Planned TD at 9900.00 7/11/2016 12:01 57PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips re.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2B-02 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2B-02 @ 126.00usft (2B-02) Site: Kuparuk 2B Pad North Reference: True Well: 213-02 Survey Calculation Method: Minimum Curvature Wpllbore: 2B -02A (usft) Latitude Longitude Design: 2B-02A_wp05 -5,573.361,137,954.28 5,950,584.00 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (°) (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 2B-02A_T11 0.00 0.00 5,969.00 -5,573.361,137,954.28 5,950,584.00 1,646,217.00 70° 2'21.620 N 140° 48'10.421 W plan misses target center by 1138633.82usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 2B-02A_Faultl 0.00 0.00 0.00 -4,064.721,139,312.09 5,952,094.00 1,647,573.00 70° 2' 34.277 N 140° 47' 25.345 W plan misses target center by 1140002.82usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Rectangle (sides W1,000.00 H1.00 D0.00) 2B-02 CTD Polygon Soy 0.00 0.00 0.00 -3,303.661,139,325.94 5,952,855.00 1,647,586.00 70° 2'41.646 N 1400 47'21.678 W plan misses target center by 1140015.42usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Polygon Point 1 0.00 0.00 0.00 5,952,855.00 1,647,586.00 Point 2 0.00 -207.95 -66.23 5,952,647.00 1,647,520.01 Point 3 0.00 -450.95 -87.49 5,952,404.00 1,647,499.02 Point 0.00 -603.91 -139.66 5,952,251.00 1,647,447.03 Point 0.00 -895.90 -177.97 5,951,958.99 1,647,409.05 Point 0.00 -1,058.81 -276.15 5,951,795.99 1,647,311.06 Point 0.00 -1,131.70 -387.24 5,951,722.98 1,647,200.06 Point 0.00 -1,148.53 -553.28 5,951,705.97 1,647,034.05 Point 0.00 -1,107.38 -689.25 5,951,746.96 1,646,898.05 Point 10 0.00 -1,086.18 -876.24 5,951,767.95 1,646,711.06 Point 11 0.00 -1,126.98 -1,071.30 5,951,726.94 1,646,516.06 Point 12 0.00 -1,213.81 -1,234.41 5,951,639.94 1,646,353.07 Point 13 0.00 -1,362.65 -1,397.59 5,951,490.93 1,646,190.07 Point 14 0.00 -1,560.58 -1,487.81 5,951,292.92 1,646,100.08 Point 15 0.00 -1,762.58 -1,502.02 5,951,090.93 1,646,086.09 Point 16 0.00 -1,974.58 -1,527.25 5,950,878.92 1,646,061.10 Point 17 0.00 -2,293.59 -1,544.59 5,950,559.92 1,646,044.12 Point 18 0.00 -2,546.56 -1,600.87 5,950,306.91 1,645,988.13 Point 19 0.00 -2,772.51 -1,663.11 5,950,080.92 1,645,926.14 Point 20 0.00 -2,835.88 -1,323.14 5,950,017.93 1,646,266.15 Point 21 0.00 -2,609.91 -1,273.90 5,950,243.93 1,646,315.13 Point 22 0.00 -2,224.92 -1,225.49 5,950,628.94 1,646,363.11 Point 23 0.00 -1,915.91 -1,204.16 5,950,937.94 1,646,384.09 Point 24 0.00 -1,647.90 -1,192.87 5,951,205.94 1,646,395.08 Point 25 0.00 -1,461.05 -1,033.66 5,951,392.95 1,646,554.07 Point 26 0.00 -1,398.24 -852.57 5,951,455.95 1,646,735.07 Point27 0.00 -1,450.51 -599.60 5,951,403.97 1,646,988.07 Point 28 0.00 -1,443.76 -362.57 5,951,410.98 1,647,225.07 Point 29 0.00 -1,344.01 -119.44 5,951,510.99 1,647,468.07 Point 30 0.00 -1,146.17 50.79 5,951,709.00 1,647,638.06 Point 31 0.00 -948.22 117.00 5,951,907.01 1,647,704.04 Point 32 0.00 -670.24 165.30 5,952,185.01 1,647,752.03 Point 33 0.00 -503.27 210.49 5,952,352.01 1,647,797.03 Point 34 0.00 -257.27 231.75 5,952,598.01 1,647,818.01 Point 35 0.00 -80.32 294.94 5,952,775.02 1,647,881.00 Point 36 0.00 0.00 0.00 5,952,855.00 1,647,586.00 213-02A_T08 0.00 0.00 5,983.00 -4,545.851,138,484.47 5,951,612.00 1,646,746.00 70° 2' 30.820 N 140° 47'50.938 W plan misses target center by 1139161.10usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 2B-02A_T06 0.00 0.00 5,993.00 -4,602.151,138,747.44 5,951,556.00 1,647,009.00 70° 2'29.887 N 140° 47'43,705 W plan misses target center by 1139424.20usft at 6600.00usft MD (5879.25 TVD, -1819.78 Point N, -673.36 E) 28-02A_T07 0.00 0.00 5,993.00 -4,570.011,138,632.46 5,951,588.00 1,646,894.00 700 2' 30.368 N 1400 47'46.836 W plan misses target center by 1139309.14usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 7/11/2016 12:01:57PM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips 13AN ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 2B-02 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2B-02 @ 126.00usft (2B-02) Site: Kuparuk 2B Pad North Reference: True Well: 213-02 Survey Calculation Method: Minimum Curvature Wellbore: 213-02A Point Design: 2B-02A_wp05 5,951,465.99 1,646,801.00 2B-02 CTD Polygon Nor 0.00 0.00 0.00 -4,754.151,138,740.27 5,951,404.00 1,647,002.00 700 2' 28.422 N 140° 47'44,562 W plan misses target center by 1139432.57usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Polygon Point 1 0.00 0.00 0.00 5,951,404.00 1,647,002.00 Point 0.00 62.22 -200.95 5,951,465.99 1,646,801.00 Point 3 0.00 187.45 -405.84 5,951,590.98 1,646,595.99 Point 0.00 350.59 -523.68 5,951,753.97 1,646,477.98 Points 0.00 632.70 -596.39 5,952,035.97 1,646,404.97 Point 0.00 850.69 -565.15 5,952,253.98 1,646,435.96 Point 0.00 1,041.60 -470.94 5,952,444.97 1,646,529.95 Point 0.00 1,159.51 -366.81 5,952,562.99 1,646,633.94 Point 9 0.00 1,326.44 -286.62 5,952,729.99 1,646,713.93 Point 10 0.00 1,528.41 -241.40 5,952,931.99 1,646,758.92 Point 11 0.00 1,746.36 -175.16 5,953,149.99 1,646,824.91 Point 12 0.00 1,896.32 -119.00 5,953,300.00 1,646,880.90 Point 13 0.00 2,493.14 103.66 5,953,897.00 1,647,102.87 Point 14 0.00 2,433.82 398.63 5,953,838.02 1,647,397.88 Point 15 0.00 1,832.99 182.97 5,953,237.01 1,647,182.91 Point 16 0.00 1,590.04 109.70 5,952,994.00 1,647,109.92 Point 17 0.00 1,309.08 46.40 5,952,713.00 1,647,046.94 Point 18 0.00 1,093.16 -43.84 5,952,497.00 1,646,956.95 Point 19 0.00 920.26 -155.04 5,952,323.99 1,646,845.95 Point 20 0.00 718.34 -256.26 5,952,121.98 1,646,744.97 Point 21 0.00 500.32 -252.49 5,951,903.99 1,646,748.98 Point 22 0.00 350.15 -106.64 5,951,754.00 1,646,894.98 Point 23 0.00 297.97 59.32 5,951,702.01 1,647,060.98 Point 24 0.00 0.00 0.00 5,951,404.00 1,647,002.00 2B-02A_T09 0.00 0.00 5,952.00 -4,581.631,138,286.41 5,951,576.00 1,646,548.00 70° 2' 30.763 N 140° 47' 56.722 W plan misses target center by 1138963.12usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 2B-02A_T02 0.00 0.00 5,965.00 -3,681.781,139,398.53 5,952,477.00 1,647,659.00 70° 2'37.868 N 140° 47' 21.241 W plan misses target center by 1140073.41 usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 2B-02A_T10 0.00 0.00 5,942.00 -4,864.351,138,005.07 5,951,293.00 1,646,267.00 70° 2'28.431 N 140° 48' 5.933 W plan misses target center by 1138682.50usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 2B-02A_Fault3 0.00 0.00 0.00 -4,570.011,138,632.46 5,951,588.00 1,646,894.00 70° 2' 30.368 N 140'47'46.836 W plan misses target center by 1139324.31 usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 2B-02A_Fault2 0.00 0.00 0.00 -4,602.151,138,747.44 5,951,556.00 1,647,009.00 70° 2'29.887 N 140° 47'43.705 W plan misses target center by 1139439.36usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 26-02A T01 0.00 0.00 5,985.00 -3,472.791,139,428.76 5,952,686.00 1,647,689.00 70° 2' 39.853 N 140'47'19.482 W plan misses target center by 1140103.32usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 2B -02A T04 0.00 0.00 5,971.00 -4,287.701,139,277.84 5,951,871.00 1,647,539.00 70° 2' 32.162 N 140° 47'27.277 W plan misses target center by 1139953.87usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 2B-02A_T03 0.00 0.00 5,983.00 -4,064.721,139,312.09 5,952,094.00 1,647,573.00 70° 2'34.277 N 140° 47'25.345 W plan misses target center by 1139987.66usft at 6600.O0usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Point 26-02AL1_Fault1 0.00 0.00 0.00 -3,525.931,138,649.63 5,952,632.00 1,646,910.00 70° 2'40.481 N 140° 47'41.861 W plan misses target center by 1139339.43usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) Rectangle (sides W1,000.00 1-11.00 D0.00) 26-02 CTD Polygon We: 0.00 0.00 0.00 -4,661.861,138,482.34 5,951,496.00 1,646,744.00 70° 2'29.697 N 140° 47'51.497 W - plan misses target center by 1139174.42usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) - Polygon Point 1 0.00 0.00 0.00 5,951,496.00 1,646,744.00 Point 2 0.00 83.16 -138.93 5,951,579.00 1,646,604.99 7/11/2016 12:01:57PM Page 7 COMPASS 5000.1 Build 74 ConocoPhillips ConocoPhillips r�� {� Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 213-02 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2B-02 @ 126.00usft (26-02) Site: Kuparuk 2B Pad North Reference: True Well: 213-02 Survey Calculation Method: Minimum Curvature Wellbore: 2B -02A 5,952,460.99 1,646,413.95 Design: 2B-02A_wp05 1,107.29 -165.84 Point 0.00 253.37 -322.76 5,951,748.99 1,646,420.99 Point 0.00 489.49 -416.52 5,951,984.98 1,646,326.98 Point 5 0.00 732.51 -413.26 5,952,227.98 1,646,329.97 Point 0.00 965.45 -329.01 5,952,460.99 1,646,413.95 Point 0.00 1,107.29 -165.84 5,952,602.99 1,646,576.94 Point 8 0.00 1,211.08 35.29 5,952,707.00 1,646,777.94 Point 0.00 1,256.87 237.36 5,952,753.01 1,646,979.94 Point 10 0.00 1,134.84 260.23 5,952,631.02 1,647,002.94 Point 11 0.00 971.79 292.06 5,952,468.02 1,647,034.95 Point 12 0.00 940.93 157.02 5,952,437.01 1,646,899.96 Point 13 0.00 902.03 55.96 5,952,398.00 1,646,798.95 Point 14 0.00 843.11 -27.11 5,952,339.00 1,646,715.95 Point 15 0.00 767.16 -79.19 5,952,262.99 1,646,663.96 Point 16 0.00 663.18 -111.31 5,952,158.99 1,646,631.96 Point 17 0.00 538.17 -107.44 5,952,034.00 1,646,635.97 Point 18 0.00 444.12 -69.54 5,951,940.00 1,646,673.97 Point 19 0.00 350.03 6.37 5,951,846.00 1,646,749.98 Point 20 0.00 294.93 90.32 5,951,791.00 1,646,833.98 Point 21 0.00 0.00 0.00 5,951,496.00 1,646,744.00 2B-02A_T05 0.00 0.00 5,990.00 -4,559.461,139,033.51 -1,891.91 5,951,599.00 1,647,295.00 70° 2'29.882 N 140° 47'35.390 W plan misses target center by 1139710.17usft at 6600.00usft MD (5879.25 TVD, -1819.78 N, -673.36 E) 21 Point 5,943.28 -3,467.89 -2,169.45 22 9,405.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,900.00 5,968.60 2 3/8" 2.375 3 000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 6,600.00 5,879.25 -1,819.78 -673.36 TIP 6,640.00 5,913.06 -1,840.13 -679.89 KOP 6,661.00 5,930.38 -1,851.43 -683.53 End 20 dls, Start 42 dls 6,802.57 5,984.83 -1,969.31 -721.56 End 42 dls, Start 12 dls 6,900.00 5,972.16 -2,063.57 -741.92 5 7,010.00 5,965.53 -2,173.01 -747.01 6 7,225.00 5,976.81 -2,381.41 -790.52 7 7,375.00 5,982.92 -2,525.02 -831.19 8 7,455.00 5,978.40 -2,604.58 -837.04 9 7,525.00 5,972.61 -2,674.02 -842.98 10 7,725.00 5,973.35 -2,860.54 -911.03 11 7,875.00 5,982.41 -2,973.47 -1,008.39 12 7,945.00 5,987.45 -3,014.50 -1,064.80 13 8,015.00 5,990.27 -3,047.32 -1,126.49 14 8,315.00 5,992.82 -3,079.24 -1,419.84 15 8,385.00 5,992.89 -3,059.99 -1,487.08 16 8,455.00 5,992.51 -3,040.76 -1,554.32 17 8,555.00 5,984.60 -3,027.76 -1,652.97 18 8,705.00 5,961.32 -3,042.93 -1,799.75 19 8,805.00 5,946.78 -3,078.41 -1,891.91 20 8,905.00 5,940.11 -3,130.72 -1,976.66 21 9,305.00 5,943.28 -3,467.89 -2,169.45 22 9,405.00 5,946.46 -3,567.65 -2,169.18 23 9,605.00 5,956.08 -3,764.89 -2,189.73 24 9,900.00 5,968.60 -4,054.95 -2,190.94 Planned TD at 9900.00 7/1112016 12:01:57PM Page 8 COMPASS 5000.1 Build 74 ..• ConocoPhillips Alaska, 4r,,. HANGER, CONDUCTOR, 35-110 SAFETY VLV, 1,891 GAS LIFT, 3,478 GAS LIFT. 4.837 GAS LIFT, 5.864 GAS LIFT, 6.325 SBR, 6.359 PACKER. 6.377 PRODUCTION, 6,415 PRODUCTION, fi.483 IPERF. 6,526-6,568 C -SAND FRAC, 6,526 PRODUCTION, 6,582 IPERF, 6.516-6,568 Cement. 6.586 SEAL ASSY, _ 6,599 'ACKER.6.600- SEE. 6.502- NIPPLE, 6,611 - IPERF, 6,620-6,710 FISH, 6,685 PRODUCTION, 31-6,934 TD, 6.976 KUP 26-n2 WeN Attributes - Max An le & MD TA�I.KOB, WellboreAPI/UWI Field Name Well Stt KUPARUK RIVER UNIT39.77 Inl °) MD (ftKB) Act500292115400 4,200.00 Comment H2S (ppm) Data Annotation End Date KB-Grd (ft) Rig Release Date SSSV: LOCKED OUT 100 12/162012 Last W0: 38.40 823/1984 Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,683.0 5/19/2011 Rev Reason: H2S, DRILLING DEPTHS/DATES Last ori nd Date 13 Casin Strin s Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top ThirdCONDUCTOR 16 15.062 35.0 110.0 110.0 62.50 H100 WELDED Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt.. String ... String Top Thrd SURFACE 95/8 8.921 34.1 2,727,2 2,726.8 36.00 J-55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)..... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 31.2 6,933.6 6,286.8 26.00 J-55 BTC TubIn Strin s -�- Tubing Description String 0... String ID ... Top (ftKB) get Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd TUBING 31/2 2.992 30.5 6,615.6 6,018.5 9.30 J-55 EUESRD Com Ietion Details _ -- Top Depth - (TVD)Top Incl (ftKB) (ftKB) Nomi... lop M Item Description Comment ID (in) 30.5 30.5 0.01 HANGER GRAY TUBING HANGER 3.500 1,891.4 1,891.3 0.73 SAFETY VLV OTIS FMX SAFETY VALVE, LOCKED OUT 4/18/98 2.813 6,359.5 5,803.4 33.71 SBR CAMCO OEJ-10 SBR 2.978 6,377.3 5,818.1 33.59 PACKER CAMCO HRP -I -SP RETRIEVABLE PACKER 2.867 6,489.4 5,911.9 32.73 BLAST RINGS BLAST RINGS (3) 2.994 6,598.7 6,004.1 32.26 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 6,599.5 6,004.9 32.25 PACKER BAKER FB -1 PERMANENT PACKER 4.000 6,602.0 6,007.1 32.49 SBE BAKER SEAL BORE EXTENSION 3.000 6,611.4 6,015.0 32.49 NIPPLE CAMCO D NIPPLE NO GO 2.750 6,614.7 6,017.8 32.49 WLEG CAMCO SHEAR OUT SUB, ELMD TTL CO) 6608' ON SWS PPROF 2.937 DATED 1/5/07 Other In Hole irellne retrievable lu s valvesspunlPs�fish, etc__ Top Depth (TVD) Topincl Top (ftKB) (ftKB) (•) Description Comment Run Date ID (In) 6,685.0 6,077.1 32.48 FISH WOK -1 Arm ASSY Lost Downhole on 9/12/96 9/12/1996 0.000 Perforations & Slots Shot Top (TVD) Btm(TVD) Dens Top (111<13) Btm(ftK8) (ftKB) (ftKB) Zone Date (ah.- Type Comment 6,526.0 6,568.0 5,942.8 5,978.2 C-4, 2B-02 10/9/1984 12.0 (PERF 120 deg. ph; 5" DA Csg Guns 6,586.0 6,588.0 5,993.4 5,995.1 UNIT B, 2B-02 10/10/1984 4.0 IPERF Squeeze Pers. 4" DA Csg Gun 6,620.0 6,710.0 6,022.2 6,098.2 A-3, A-4, A-5, 10/9/19844.0 (PE 28-02 RF 120 deg. ph; 4" JJ Csg Gun Stimulations & Treatments Min Top Depth (ftKB) ElmTop Depth (TVD) (ftKB)(ftKB) Boftom Depth (TVD) Type Date Comment 6,526.0 gDepth 5,942.8 5,978.2 C -SAND FRAC 1122006 Pump C sand fracture treatment at 20 bpm using 50# X-linked gel. Pump total of 138,341# of 1620 ceramic proppant, placing 126,640# prop behind pipe with 10 ppa on perfs. Screened out while on flush, recovered all tree saver rubber, Cement S ueezes Top De Depth (TVD) Top (ftKB) atm (ftKB) (ftKB) Elm Depth (TVD) (ftKB) Description --- Start Date Commem 6,586.0 6,588.0 5,993.4 5,995.1 Cement Squeeze 10/10/1984 Squeeze Perfs Notes: General & Safety End Date Annotation -� - 9/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 5/192011 NOTE: MANDREL 3 -SLIGHTLY BENT LATCH Mandrel Details _ --- Top Depth Top -- -'- Port S... (TVD) Incl OD Valve Latch Size TRO Run N... Top(ftKB) (ftKB) (°) Make Model (in) Sent Type Type (in) (psi) Run Date Com... 1 1,929.0 1,928.9 0.73 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,244.0 11/72006 2 3,478.3 3,458.1 20.84 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,245.0 11/712006 3 4,837.0 4,574.3 36.06 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,274.0 11!12006 Note 4 5,863.9 5,396.9 35.53 CAMCO BUG 1 GAS LIFT GLV BK 0.188 1,266.0 11/12006 5 6,324.7 5,774.5 33.92 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 11/6/2006 6 6,414.75,849.4 33.05 CAMCO KBUG 1 PROD HFCV BEK 0.000 0.0 5202011 7 6,482.9 5,906.5 32.75 CAMCO KBUG 1 PROD HFCV BEK 0.000 0.0 5202011 8 6,582.1 5,990.1 32.33 CAMCO KBUG 1 PROD HFBEK 0.000 0.0 5202011 CV Proposed 2B-02 CTD Schematic 16" 62# H-40 shoe @ 110' '40# J-55 @ 2727'N C -sand perfs (sqz'd) 6,526' - 6,568' MD 6,586' - 6,588' MD A -sand perfs (sqz'd) 6,620' - 6,710' MD E726# J-55 shoe34' 55 Modified by MSC 7/13/16 3-1/2" 9.3# L-80 ELIE 8rd Tubing to surface 3-1/2" Otis FMX SSSV at 1812' RKB (locked out 4/98) 3-1/2" Cameo gas lift mandrels @ 1,929', 3,478', 4,8371, 5,864', 6,325' RKB Cameo OEJ-10 SBR @ 6,359' RKB (2.973" min ID) Cameo HRP -1 -SP Retrievable Packer @ 6,377' RKB Blast Rings @ 6,489' RKB 3-1/2" Cameo production mandrels @ 6,415', 6,483', 6582' RKB Baker Locator Assembly @ 6,599' RKB Baker FB -1 packer @ 6,599' RKB (4.0" ID) Baker SBE @ 6,602' RKB Tubing tail perfs at 6609' MD 3-1/2" Cameo DS nipple @ 6,611' MD (2.75" ID) Milled out to 2.80" ID pre -CTD Cameo SOS @ 6,615' RKB 2B-02AL2 wp02 TD @ 9,900' MD Liner Bille ; 8300' MD TD @2AL10�425oMD 2Br02A wp05 TD @ 9,900' MD 2B-02AL2-01 wp01 TD @ 10,425' MD Lat #5 Lat#4 - -------------------- " ---- ��,,.. '` \ Lat #3 2B-02AL1-01 wp 2 - TD 0- 9,800' MD --"- --- - - --' ---- -- - --11 Lat #1 VVELLBORE DETAILS: 213-02A :1 , Tie on IVID: 6600.00 111 �.%-A■� �•NtfJ�■.�fI�.1.Y 11 MS- 7-14 AV�,�w■■pV■��J,Simnow. rl ®��Fiji 3500-" FAME -4000-'jjjM�;b\'�{:dl. •1.: N ■p�6.0■■�YO -4250-1 -5000-1 11 n�ii7ia. ®iii ■i■'�i� ::GiiY�i=•�GTiii 1 1■ 1 1� nn■■■ter ■ :■■■ :■'/■■■■■ R'WiFI." �: -5500 -5750 .111 . ■■■■■■■ N■■■■■■�,■■ p.:NN �■■M■N■I REFERENCE INFORMATION C(Mq hale (NIE) Refere : Well 213-02, True North V-dwl (TVD) Reference: 20-02 @ 126.00uefl (213-02) Section (VS) Refereme: Slot - (O.00N, O.00E) Measured Depth Referenw: 28-02 @ 126.00usR (2&02) FS R-1 BAKER HUGHES 6000 -5750 -5500 -5250 -5000 -4750 -4500 -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -West- / 150 -1 I 000 750 n50 1750 2000 2250 2500 2750 30 L - —_ -/E _— r- 0 - -1250 -1 - - 0 -250 0 250 500 750 1000 1250 1500 - 00 3250 ast + 250 usft/i ) �r - -�.-�� 1 -{III T } �I -7ZT: 241 TT t�qj-,,j L da -1!j I I _ - 1ti + r1 0,„ _ µ Ii SIJ _13 OJT -- li f_li U J 6000 -5750 -5500 -5250 -5000 -4750 -4500 -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -West- / 150 -1 I 000 750 n50 1750 2000 2250 2500 2750 30 L - —_ -/E _— r- 0 - -1250 -1 - - 0 -250 0 250 500 750 1000 1250 1500 - 00 3250 ast + 250 usft/i ) Project: Kuparuk River Unit Site: Kuparuk 2B Pad Azimuths to True North Magner, North n. 90• MField eld WELLBORE DETAILS: 2B -02A REFERENCE INFORMATION r�.■ Parent Wellbore: 2B-02 Coardinate(WE) Reference. Well 2B-02, True North Well: 2B-02 Wellbore: 2B -02A Asn Strength: Angle oip Angle: 80 .90' Te on MD: 6600.00 Vertical (TVD) Reference: Mean Sea Level Section (VS) Reference: Slot - (O OOH, O.00E) BAKER ConocoP �p5 Plan: 2B -02A 05 2B -02/26.02A - ( I nate 1 01112 01 6 Model: BGGM2016 Measured Depth Reference: 28-02@126.00usft(2B-02) CaIWla6m Method: Minimum Curvature HUGHES -300 C -600 -900 -1200 -1500 1800 c -2100 0-2400 0 -2700 t: -3000 O G ^-3300 -3600 O tn -3900 -4200 -4500 -4800 -4200 -3900 -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -960 -600 -300 6 300 600 900 1200 WELL DETAILS: 2B-02 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 ALl 5954890.07 508370.93 70° 17' 16.702 N 149° 55'56.081 W Sec MD Inc 2s-02 2-01. Azi TOSS +N/ -S +E/ -W Dleg TFace VSect Annotation 1 6600.00 32.25 197.72 P 5879.25 -1819.78 -673.36 0.00 0.00 1940.34 TIP 2 6640.00 OP 32.34 197.88 5913.06 -1840.13 -679.89 0.31 43.59 1961.69 d 20 d KOP 3 6661.00 36.54 197.88 5930.38 -1851.43 2B-02 Ll -0--"--.. -683.53 42 dl 20.00 0.00 1973.56 End 20 dis, Start 42 dis 4 6802.57 96.00 197.88 5984.83 -1969.31 -721.56 42.00 0.00 2097.34 End 42 d1s, Start 12 dis 5 6900.00 98.89 2B -)2A 186.45 5972.16 -2063.57 -741.92 12.00 285.00 2192.87 ...., ,:.&.__. 5 6 7010.00 88.03 178.92 5965.53 -2173.01 -747.01 _... ... 12.00 215.00 2297.45 6 7 7225.00 86.05 204.68 B-02 T07-' 5976.81 -2381.41 -790.52 12.00 95.00 2508.16 7 8 7375.00 02A_ 08 89.32 -- 186.96 5982.92 -2525.02 -831.19 12.00 280.00 2657.02 _._ 8 9 7455.00 04 97.17 181.43 5978.40 -2604.58 2 -837.04 09._.. 12.00 325.00 2733.79 9 10 7525.00 92.31 188.31 - 5972.61 -2674.02 -02A -842.98 12.00 125.00 2801.07 10 11 7725.00 -02A - 87.27 '. 19 1 1' ', 16�, 15 1 211.78 5973.35 -2860.54 -911.03 12.00 102.00 2999.61 11 12 7875.00 85.86 229.76 5982.41 -2973.47 -1008.39 12.00 95.00 3139.04 12 13 7945.00 85.90 238.18 5987.45 -3014.50 22 2B-02A_F a [2 -1064.80 12.00 90.00 3196.89 13 14 8015.00 89.48 245.79 5990.27 -3047.32 -1126.49 12.00 65.00 3248.83 2 14 15 8315.00 89.58 281.79 5992.82 -3079.24 -1419.84 12.00 90.00 3379.15 15 16 8385.00 90.31 2B 290.16 07 5992.89 -3059.99 ZmZJ -1487.08 12.00 85.00 3384.06 16 17 8455.00 90.31 281.76 5992.51 -3040.76 -1554.32 12.00 270.00 3388.99 17 18 8555.00 98.76 273.20 5984.60 -3027.76 -1652.97 12.00 315.00 3410.51 18 19 8705.00 98.95 254.99 5961.32 -3042.93 -1799.75 12.00 272.00 3474.97 19 20 8805.00 97.71 242.92 5946.78 -3078.41 -1891.91 12.00 265.00 3539.83 20 21 8905.00 89.93 233.76 5940.11 -3130.72 -1976.66 12.00 230.00 3617.97 21 22 9305.00 89.21 185.76 5943.28 -3467.89 -2169.45 12.00 269.00 4000.74 22 23 9405.00 87.16 173.93 5946.46 -3567.65 -2169.18 12.00 260.00 4094.40 23 24 9605.00 87.41 197.96 5956.08 -3764.89 -2189.73 12.00 90.00 4286.77 24 25 9900.00 87.89 162.53 5968.60 -4054.95 -2190.94 12.00 270.00 4559.75 Planned TD at 9900.00 C -600 -900 -1200 -1500 1800 c -2100 0-2400 0 -2700 t: -3000 O G ^-3300 -3600 O tn -3900 -4200 -4500 -4800 -4200 -3900 -3600 -3300 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -960 -600 -300 6 300 600 900 1200 Vertical Section at 200.00° (80 usft/in) 2B -0212B-0 ALl zao 2s-02 2-01. 2B-0 /2B-04 T P 2B- 2AL1 Faultl A- OP " - E d 20 d s, Stari 42 dis 2B-0 2B-02 Ll -0--"--.. _"._ r.En 42 dl ,Start 2 dls 2B -)2A T)2 ...., ,:.&.__. ..._..._. 2B -02k -Faultl 2B-0 A_T06 _... ... ----_.... B-02 T07-' 2B 02A_ 08 -.. .".. ....... -T........ -- _._ -- 2B 02A 04 2 -02A 09._.. .._._ =.� �-1 - ---"-2 -02A OS 2B -02A - 107 "- - '. 19 1 1' ', 16�, 15 1 z0 2.1 2B-02A_Fa6dt3 22 2B-02A_F a [2 24 2 -02A . ,.- 11--_1-1,12,p .. --Pla Led at 9900.00 B-02/ B-02 2B 07/2B 07 ZmZJ 2 -02/2 -02A 2 2B -03/2B-03 Vertical Section at 200.00° (80 usft/in) ConocoPhillips FIAP.. ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2B Pad Site Error: 0.00 usft Reference Well: 213-02 Well Error: 0.00 usft Reference Wellbore 2B -02A Reference Design: 2B-02A_wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2B-02 2B-02 @ 126.00usft (213-02) 26-02 @ 126.00usft (26-02) True Minimum Curvature 1.00 sigma EDM Alaska ANC Prod Offset Datum Reference 2B-02A_wp05 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,600.00 to 9,900.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,177.40 usft Error Surface: Elliptical Conic Survey Tool Program Date 7/8/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 200.00 6,600.00 213-02 (213-02) GCT -MS Schlumberger GCT multishot 6,600.00 9,900.00 2B-02A_wp05 (213-02A) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 9,900.00 6,094.60 2 3/8" 2-3/8 3 Summary Kuparuk 2B Pad - 2B-02 - 213-02 - 213-02 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) Measured (usft) Reference Kuparuk 2B Pad Toolface+ Offset Wellbore Centre Casing - Centre to No Go 2B-02 - 213-02 - 213-02 6,650.00 6,650.00 0.17 1.82 -1.64 FAIL - Major Risk 2B-02 - 2B-02AL1 - 2B-02AL1_wp02 8,399.99 8,400.00 0.41 0.56 -0.03 FAIL - Minor 1/10 2B-02 - 2B-02AL1-01 - 2B-02AL1-01_wp02 8,399.99 8,400.00 0.41 0.56 -0.03 FAIL - Minor 1/10 2B-02 - 2B-02AL2 - 2B-02AL2_wp02 6,625.00 6,625.00 0.00 0.46 -0.45 FAIL - Minor 1/10 213-02 - 2B-02AL2-01 - 26-02AL2-01_wp01 6,625.00 6,625.00 0.00 0.46 -0.45 FAIL - Minor 1/10 213-03 - 2B-03 - 2B-03 2-11/16 0.00 1.01 -0.96 FAIL - Major Risk, CC 6,650.00 Out of range 2B-03 - 2B -03A - 213-03A 6,047.51 0.11 0.28 17.20 -1,845.22 Out of range 2B-04 - 2B-04 - 213-04 0.17 1.82 -1.64 FAIL- Major Risk, ES, SF 6,674.70 6,066.96 Out of range 2B-06 - 2B-06 - 26-06 0.11 0.42 17.34 -1,857.96 -685.67 Out of range 26-07 - 213-07 - 213-07 9,790.36 7,600.00 955.10 279.97 700.17 Pass - Major Risk Offset Design Kuparuk 2B Pad - 2B-02 - 213-02 - 213-02 Offset Site Error: 0 00 usft Survey Program: 200 -GCT -MS Rule Assigned: Major Risk Offset Well Error: 0 00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth -N/-S +EI -W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (") (usft) (usft) (usft) 6,625.00 6,026.39 6625.00 6,026.39 0.07 0.14 -152.13 -1,832.49 -677.43 2-11/16 0.00 1.01 -0.96 FAIL - Major Risk, CC 6,650.00 6,047.41 6,650.00 6,047.51 0.11 0.28 17.20 -1,845.22 -681.53 2-11/16 0.17 1.82 -1.64 FAIL- Major Risk, ES, SF 6,674.70 6,066.96 6,675.00 6,068.62 0.11 0.42 17.34 -1,857.96 -685.67 2-11/16 2.47 3.09 -0.62 FAIL- Major Risk 6,697.95 6,082.74 6,700.00 6,089.71 0.12 0.56 17.44 -1,870.71 -689.83 2-11/16 8.85 4.44 4.41 Pass - Major Risk 6,718.70 6,094.21 6,725.00 6,110.80 0.13 0.70 17.51 -1,883.47 -694.00 2-11/16 19.02 5.57 13.45 Pass - Major Risk 6,736.55 6,101.88 6,750.00 6,131.89 0.13 0.84 17.57 -1,896.23 -698.17 2-11/16 32.31 6.47 25.84 Pass - Major Risk 6,751.57 6,106.66 6,775.00 6,152.99 0.14 0.98 17.61 -1,908.99 -702.34 2-11/16 48.05 7.17 40.88 Pass - Major Risk 6,764.11 6,109.44 6,800.00 6,174.08 0.15 1.12 17.65 -1,921.75 -706.50 2-11/16 65.67 7.70 57.96 Pass - Major Risk 6,774.56 6,110.88 6,825.00 6,195.17 0.16 1.26 17.67 -1,934.51 -710.67 2-11/16 84.71 8.13 76.60 Pass - Major Risk 6,783.32 6,111.48 6,850.00 6,216.26 0.17 1.40 17.68 -1,947.27 -714.83 2-11/16 104.85 8.51 96.42 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 7/8/2016 10: 12 10A Page 2 COMPASS 5000.1 Build 74 TRANSMITTAL LETTER CHECKLIST WELL NAME: K a U- 02 .. 0 PTD: 9,1(o .p V- Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: 9('A� POOL: Kupox�U�J' ��/ 01 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 onpermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where sample 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) 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 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK_RIV UNIT 213-02A Program DEV Well bore seg ❑ PTD#:2160870 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030Q.1_.A),(j.2.A-D) - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 Permit fee attached- - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate- - - - - - - - - - - - - - -- Yes - - - - - - - ADL0025655, Surf;-ADL0025656, Top Prod Intery & TD. - 3 -Unique well name -and number --- _ - - . - - - - - - - - - Yes_ - - - - _KRU 26-02A- - - - - - - - - -- - - - - - - - - - - - - - - - 4 Well located in a_defined -pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - KUPARUK RIVER,_KUPARUK RIV OIL. -490100,_ governed -by Conservation_ Order -No. 4a2D. 5 Well located proper distance from drilling unit _boundary - - - - - _ .. - - - - - -- - - - - - - - - Yes - - - - - - - CO 432D contains no spacing restrictions with respect to drilling unit boundaries. - - - - - - 6 Well located proper distance from other wells- - - - - - - Yes - - - - - - CO 432D has no interwell-spacing_restrictions- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage available in_dril_ling unit - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ _ - - - - - - - - - _ - - - - - - - - - - - - - - - . - . _ - - _ _ - _ - - - - - - - - - - - - - - - 8 If -deviated, -is wellbore plat -included - - - _ - - Yes -- - - - - - - - 9 Operator only affected party - - - - - - - - - -- - - - - - Yes - - - - - - Wellbore -will be more than 500' from an external property line where ownership or landownership- changes.- 10 Operator has -appropriate bond in force - Yes - - - - - - - - - - - - - - - - - - - - - _ - .. - - - - - - Appr Date 11 Perm it can be issued without conservation order- - - - - - - Yes _ - - - - - - - - . _ - - - - - . 11 -- - - - - 12 Permit can be issued without administrativ_e_appr_oval - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - PKB 7/14/2016 13 C_anpermitbeapprovedbefore15-daywait_ - - - - - - - - - _ Yes_ - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - 14 Well located within area and -strata authorized by -injection Order# (put 10# in_comments)_(For_ NA- -- - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 _All wells- within 1/4_mile-area-of review identified (For service well only)- - .. - - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector; duration of pre production Less than 3 months_ (Forservice well only) NA_ - - - - - - - - - - - - - - - - - - - - -- -- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - 18 Conductor string_ provided _ _ . _ _ - - NA - - - - - Con_ductor set-in KRU 2B-02 - - _ - - - - - - - - _ Engineering 19 Surface casing_ protects all known_ U, - - - NA_ Surface casing set in KRU 213-02 20 CMT_vol_adequate-to circul_ate_on conductor & surf _ _ _ _ . _ N_ - _ _ - - - - - Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf esg_ - - - - - _ _ NA- _ ---------- --- - - - - - - . 22 CMT will coverall known -productive horizons- - - - - - - - - - - - - - - - No_ - - - - - - Productive interval will be completed with uncemented slotted liner 23 Casing designs adequate for C,_T, B &_permafrost_ - Yes ---- - - - - _ - - 24 Adequate -tankage or reserve pit Yes - - - - Rig has steel tanks; allwaste_to approved disposal wells_ - - - - - - - - 25 _If_a_re-drill, has_a 1.0-403 for abandonment been approved _ _ _ _ - _ Yes _ _ _ _ _ _ _ PTD 184-122,_Sundry 316-362_ _ _ _ _ 26 Adequate wellbore separation -proposed Yes - - - - Anti -collision analysis complete; no major risk failures 27 If_diverterrequired, does it -meet regulations - -------- --- ---- _N_A- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - . - - - . Appr Date 28 Drilling fluid_ program schematic & equip -list-ad equate _ - Yes . Max formation_ pressure is 3973 psig(12.6 ppg_EMW); will drill w/ 8.6_ppg EMW and maintain overbal_ w/ MPD VTL 8/15/2016 29 BOPEs,_do they meet regulation - - _ - Yes - - - - - - - - - - - 30 BOPE_press rating appropriate; test to -(put psig in comments)- - Yes - _ - - MPSP is 3369 psig; will test BOPs_to 21750-psig - _ . - _ - _ - - - ------------------------- 31 Choke -manifold complies w/API_RP-53 (May 84)_ - - Yes _ - - - - - - - - - - - - - -- -32 32 Work will occurwithout operation shutdown ___ ___-. - -- -- - - - -- Yes--------- ------------------------ 33 Is presence -of H2S gas probable _ Yes - - 1-12S measures required -- - .. - - .. - 34 Mechanical condition of wells within AOR verified (For service well only) N_A----- - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogensulfidemeasures No Wells -on 213 -Pad are_H2S74earing. H2$ measured_ required. Geology 36 _Data -presented on potential overpressure zones - - - - - - Yes Max potential reservoir pressure is 12,6_ ppg EMW; Will -be drilled using 8.6 ppg mud and MPD_ technique. Appr Date 37 Seismic analysis of shallow gas_zones_ - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - . . _ - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - PKB 7/13/2016 38 Seabed condition survey (if off_ -shore) - - - - - - - NA- - 39 Contact name/phone for weekly_ progress reports [exploratory only] - _ - - - - NA_ - - - - - - - Onshore development sidetrack to_ be -drilled - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public Date: Date Date Commissioner: Commissioner, ommission