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Home My WebLink About219-019DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Drill 2190190 Well Name/No. KUPARUK RIV UNIT 2G -06A Operator ConocoPhillips Alaska, Inc. API No. 50-029-21121-01-00 MD 9705 TVD 6032 Completion Date 3/15/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No V Samples No ✓ i Directional Survey Yes DATA INFORMATION List of Logs Obtained: GR / Res (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30604 Digital Data 4/15/2019 _ Electronic File: 2G -06A EOW NAD27.pdf ED C 30604 Digital Data 4/15/2019 Electronic File: 2G -06A EOW NA027.txt ED C 30604 Digital Data 4/15/2019 Electronic File: 2G -06A EOW NAD83.pdf ED C 30604 Digital Data 4/15/2019 Electronic File: 2G -06A EOW NAD83.txt Log C 30604 Log Header Scans 0 0 2190190 KUPARUK RIV UNIT 2G -06A LOG HEADERS ED C 30608 Digital Data 7976 9705 4/15/2019 Electronic Data Set, Filename: 2G-G6A GAMMA RES.Ias ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A 2MD Final.cgm ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A 5MD Final.cgm ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A 5TVDSS Final.cgm ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A 21VID Final.pdf ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A 51VID Final.pdf ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A 5TVDSS Final.pdf ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A EOW NAD27.pdf ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A EOW NAD27.bd ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A Survey Listing.txt ED C 30608 Digital Data 4/15/2019 Electronic File: 2G -06A Surveys.txt ED C 30608 Digital Data 4/15/2019 Electronic File: 2G- 06A_25_tapescan_BH I_CTK.txt ED C 30608 Digital Data 4/15/2019 Electronic File: 2G- 06A_5_tapescan_BHI_CTK.t# AOGCC Page I of 2 Monday, June 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/17/2019 Permit to Orill 2190190 Well Name/No. KUPARUK RIV UNIT 2G -06A MD 9705 TVD 6032 Completion Date 3/15/2019 ED C 30608 Digital Data ED C 30608 Digital Data ED C 30608 Digital Data ED C 30608 Digital Data Log C 30608 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report s Production Test Informatior�' NA Geologic Markers/Tops O COMPLIANCE HISTORY Completion Date: 3/15/2019 Release Date: 2/19/2019 Description Comments: Interval Start Stop Operator ConocoPhillips Alaska, Inc. API No. 50-029-21121-01-00 Completion Status 1-0IL Current Status 1 -OIL UIC No Core Chips Y& 4/15/2019 Electronic File: 2G-06A_output.tap Core Photographs Y 6 4/15/2019 Electronic File: 2G -06A 2MD Final.cgm.meta.tif Laboratory Analyses Y /9A 4/15/2019 Electronic File: 2G -06A 5MD Final.cgm.meta.tif 4/15/2019 Electronic File: 2G -06A 5TVDSS Final.cgm.meta.tif 0 0 2190190 KUPARUK RIV UNIT 2G -06A LOG HEADERS Sample Set Sent Received Number Comments Directional / Inclination Data (5 Mud Logs, Image Files, Digital Data Y / ZP Core Chips Y& Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y 6 Daily Operations Summary L'/ Cuttings Samples Y / t A J Laboratory Analyses Y /9A Compliance Reviews Jr: _ _ Date Comments Date: � 17 At �( R,r Page 2 of 2 Monday, June 17, 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 15 2019 Inrrr- WELL COMPLETION OR RECOMPLETION REPORT AND LO ta. Well Status: Oil[D Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 2DAAC 25.1 05 20AAC 25.110 Development 0 Exploratory El GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Abend.: 3/15/2019 219.019 6 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 3/9/2019 50.029.21121-01-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 547' FSL, 236' FWL, Sec 32, T11 N, R9E, UM 3/10/2019 KRU 2G -06A Top of Productive Interval: 9. Ref Elevations: KBA40 17. Field / Pool(s): 1418' FNL, 1364' FEL, Sec 32, TI IN, R9E, UM GLA04 BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 5184' FNL, 1352' FEL, Sec 29, T11N, R9E, UM 9414/6041 x ADL 25656 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 508930 y- 5944135 Zone- 4 9706/6032 ' LONS 82.180 TPI: x- 512594 y- 5947455 Zone- 4 12. SSSV Depth MDlfVD: 20. Thickness of Permafrost MDlrVD: Total Depth: x- 512599 y- 5948969 Zone- 4 N/A 1500/1470 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 1 8095/5939 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT GRADE CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 38 110 38 110 24 202 sx Cold Set II 9518 36 J-55 37 3134 37 2774 12 114 1035sx PF E, 250sx PF C 7 26 J-55 36 8449 36 6224 81/2 575 Class G, 250sx PF C 2 318 4.6 L-80 8341 9414 6032 6041 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open (MDfrVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD(rVD) Size and Number, Date Perfd): 3 112 8044 7968/5841 SLOTTED LINER@: COMPLETION 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8353-9414 MD and 6036-6041 TVD DATE Was hydraulic fracturing used during completion? Yes ❑ No ❑ /S 2Lt `f VERIFIED 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: Method of Operation (Flowing, gas lift, etc.): 3121/2019 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 3/24/2019 33.2hrs Test Period 199 1 540 1 6843 176 2712 Flow Tubing Casinq Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Press. 201 1417 24 -Hour Rate -4 1 390 1 4947 24 Form 10-407 Revised 5/20178' BTL `-1t,7 G% J J/ ONTINUED ON PAGE 2 RBDMS f` APR 1 6 Z01bmit ORIGINIAL only /+ 'wf6rl/9 /"! lel 'd// lU_ 28. CORE DATA Conventional Corals): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MDrrVD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost -Top Surface Surface Permafrost - Base 1500 1470 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval - 8095 5939 information, including reports, per 20 AAC 25.071. Formation Q TPI - Kuparuk A TD 9705 r 6032 Formation at total depth: I Ku aruk A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, productionoaleontoloo cal report, or well test results. per 20 AAC 26,070, 0L 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Keith.E.Herrin Authorized Title: Staff CTD En ineer Contact Email: Kelth.E.Herrina0cob.com Authorized Contact Phone: 263-4321 Signature: Date: % �7 I; WWI; INSTRUCTIONS General: This for and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. 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 5/2017 Submit ORIGINAL Only 2G-06 Final CTD Schematic &LB°MCJS9 Noe ata4'MO Penlel WIMw ®MCT' -NCB kID Felled! High E i snsign Wedge Lest TQM ' MO kbM1 Evpanslon Wetl6e Lower Peder ham dtl ComFRlb ®e169'MO RSaaM pub smieeatl .__ etea'-M6e•MD I—' ".2ne'nesgueemtl e218' -824M N0 Wake) a Noe l eMB' MD 3-12" 9.31 L-80 EUE Ord! Tubing to surface 3-12" DS lending nipple @ 525' MD (2.875" min ID) 3-W Carrico MMG gas lilt mandrel @ 2952', 4946'.6250'• 7240. and 7898' MD Baker 3-12" PBR ® 795T MD (2.98" ID) Baker FHL pa er 7988' MD (3.03" ID) 3-12' DS landing nipple @ 8011' MD (2.813" min ID) 3-12" tubing tail @ B043.8' MD (8048 POC) W Hupanlr Liner Top Packer ® 8008 POC ee-08NI2T0=IDZat'MO zam^ sbnetl r BMnL Rerwhn sea0gra tlepMymeM sleeve TOL= HOC' MD. DOL =6403• MO .PCf stilled Mer=8252' MO 36CBL1PB1 TO Q9 8.sxg MO WMM1OW, CMS, antl Padgfh QQ M1M MO MRI Allor1 I P PROD WELLNAME 2G-06 WELLBORE 213_06 Well Aftributes Max Angle & MD TO COf1QCQPllllipS Alaska, Inc. Field Name Wellbore APIIUWI KUPARUK RIVER UNIT 500292112100 Wellbore Status PROD ncl (°) 4.60 MD(ftK8) 4,000.00 Act Stm(ftKB) 8,485.0 Comment H2S SSSV: NIPPLE 110 (ppm) Date 12/19/2017 Annotation Last WO: End Date 7/14/2010 KB-Grtl IN) 36.00 Rig Release Date 6/18/1984 -, 2G-06, VIW20198:56:20 AM Last Tag Vertical saiemafic (actuaq Annotation 1 Depth (ftKBj End Date Wellbore Last Mod By Last Tag: RKB 1 8,130.0 2/172019 213-O6 fergusp as Rev ason ruNGER; 301 Annotation End Date Wellbore Last Motl By Rev Reason: New GILD 3/23/2019 2( Jhansen8 Casing Strings Casing Description CONDUCTOR OD(in)ID 16 (in) 15.06 Top (111413) 38.0 Set Oepth(ftKB) Set 1110.0 1110.0 Depth(TVD)... MLen(I... 62.58 loran. 1 H-40 Top Thread lWelded Casing Description SURFACE OD (in) 9518 ID (in) 9.21 Top (ftKBj 37.2 Set Depth (NICE) Set 3,133.9 2,773.7 Depth WVLen (I... 36.00 Grede J-55 Tap Thread BTC Casing Description PRODUCTION 00 (in) 7 ID (in) 6.28 Top(RKe) 35.9 Set Depth IRKS) Se[Depth 8,449.1 Set Deb (ND)... WIILen(I... 26.00 Grade J-55 Top Thread BTC CONDUCTOR; 36.0-110.0 Tubing Strings Tubing Description SMng Me... TUBING WO 3112 10 (in) 2.99 Top(ftKB) 30.1 Set Depth (ft.. 7,969.3 Set Depth (TVD) I... 5,841.4 Wt(Ibttt) 9.30 Grade L-80 Top Connection EUE8,MMOO NIPPLE; 524.7 Completion Details Top(TVD) Topincl Nominal Top(ftKS) (ftKBj (°) Item Des Com ID (in) 30.1 30.11 0.09 1 HANGER Vet m/Grey Gen II TUBING HANGER 2.938 GAS LIFT;2,9515 524.7 524.61 1.18 1 NIPPLE 3.5"Cameo"DS"Nipple w/2.875 profile 2.875 7,956.6 5,831.6 39.63 PBR PBR Seal Assembly (sheared) w/ 2'space out STABBED INTO 2.980 PACKERASSEMBLY 1 Tubing Description SMng Me... 110(m) TUBING PACKER 3112 2.99 Top (ftliSet 7,968.3 Depth (ft.. 8,043.6 set Depth (TVD) I... 5,899.1 Wt (11,111) 9.30 Grade L-80 Tap Connection 8RD EUE ASSY Completion Details SURFACE; 37.2-3,133.9 Top (TVD) Topincl Nominal Top (ftKa) I (RKB) V) Item Des Co. ID (in) 7,968.31 5,840.7 39.50 PACKER FHL Packer 3.030 GAS uFr; 4,945.1 8,011.2 5,873.8 39.03 NIPPLE 2.813" DS Nipple 2.813 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (RKB) Top (TVD) I PIKE) Top Inct (1 Des Com Run Date ID (in) GAS LIFT; 6,250.3 8,006.0 5,869.8 39.10 PACKER Set 3" Kuparuk Liner top packer (85" DAL, 2.25° Seal 3/19/2019 Assembly 45" OAL, 4 Ave Seals, 1.625" Min ID Thru D&D Pack -off Set 3" Slip Stop on top Packer 8,095.0 5,939.41 38.01 WEDGE NS High Expansion Wedge WS. Set -3 deg ROHS. 2/252019 0.000 GAS LIFT; 7.2460 8,097.5 5,941.4 37.98 WINDOW HEW WS failed & fell down hole, leaving window, 1021/201 exposed in T' casing 8 2.800 8,132.0 5,968.7 37.54 WEDGE NS High Expansion Wedge WS 10/21/201 8 0.000 Note: WS slid down -hole. Likely top at 8136' MD GAS LIFT, 7.8962 (10/23/18) 8,136.0 5,971.8 37.49 WEDGE NS High Expansion Wedge WS 10/16/201 8 0.000 PER; 7.956.6 8,158.0 5,989.3 37.21 FISH LOWER PACKER FROM OLD COMPLETION, PXX 1/6/2008 PLUG, & REST OF TUBING DOWN TO WIRELINE RE- ENTRY GUIDE IS IN FILL. TAGGED HARD MUD @ 0.000 8158 SLM. PACKER; 7,968.3 ad Perforations & Slots Shot Dens Top (RKB) Btre (RKB) Top (TVD) (RKB) Btm (ND) (ftKBj Linked Zona Date (shotsin 1 Type Care NIPPLE; 6,0,1.2 8,188.0 8,198.0 6,013.3 6,021.3 A-5, 213-06 924/1988 4.0 IPERF 90 deg. Phasing; 4" Schlumberger Casi $216.0 8,246.0 6,035.7 6,059.9 A-4, 21306 924/1988 4.0 (PERF 90 deg. Phasing; 4" Schlumberger Cas! °AL2' IATERAL COMPLETION; Mandrel Inserts at ],99939,102 0 aft WEDGE; 8,0950 on Top (TVD) Port Size TRO Run N Top (111013) (RKB) Make Model 0D(m) Sen, (in) (psi) Run Date Com 1 2,951.5 2,655.4 Cameo MMG 1112 GAS LIFT 0.188 1,247.0 320/2019 9:30 2 4,945.5 3,851.9 Cameo MMG 11/2 GAS LIFT 0.188 1,246.0 3202019 10:30 tGLV kRK 3 6,250.3 4,6462 Camco MMG 11/2 GAS LIFT 0.250 0.0 3/192019 1:00 4 7,246.0 5,310.6 Cameo MMG1 1/2 GAS LIFT 0.000 0.0 2/18/2019 WEDGE; 8, 1320 5 7,898.2 5,786.8 Camco MMG 11/2 GAS LIFT 0.000 0.0 2/19/2019 Notes: General & Safety End Date Annotation WEDGE; 8,136.0 1/2/2000 NOTE WORKOVER 12/10/2007 NOTE: "' MIT TESTING WILL HAVE TO USE DS NIPPLE @8008"" I P PROD WELLNAME 213-06 WELLBORE 213-06A COIiQt40f 1�lfiPS r Alaska,InC- Well Attributes Max Angle & MD TD R Id Name Wellbore API/UWI KUPARUK RIVER UNIT 500292112101 Wellbore Status ncl(°) PROD 8.91 MD(ftKB) 8,752.59 Act Btm (ftKB) 9,705.0 Comment 112S (ppm) I 110 Data 12/19/2017 Annotation LAST WO: End Date KB-Grd (B) 36.00 Rig Release Date 6/1811984 2G -06A, V15120198:58:20 AM Last Tag Vertical schematic (eaaa) Annotation Depth (ftKB) End Data Wellbore Last Mod By LAST TAG: zu- jennalt _....................................................................... ........___.. Last Rev Reason MNGER; 30.1 Annotation End Date wellbore Last Mod By REV REASON: CTD MULTILAT 419/2019 I 2G -06A jennalt Casing Strings Casing Description "A" LATERAL DD(in) 23/8 IS (in) 1.99 Top(ftKB) 8,340.7 Set Depth(ftKB)Set 9,414.0 Depth (TVD)... 6,041.0 Wt/Len(I... 4.60 Grade L-80 Top Thread STL COMPLETION Notes: General & Safety End Date Annotation 4/92019 NOTE: View Schematic w/ Alaska SChematic10.0 CONDUCTOR: 38.0-110.0 NIPPLE: 524 ] GAS LIFT; 2,951.5 SURFACE; 37.2-3,133.9— GAS UFT; 4,945 4 GAS LIFT; 6,250.3 GAS LIEF; ],246.0 GAS LIFT: 7,898 2 - PER: ],958.6 PACKER; 7,988.3 NIPPLE; 8,011 2 .. Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Slantnine Endure Wr(hr) Phase Op Code Ac ity Code Ture P -T-% Operation (RKB) End Depth(ftKB) 10/14/2018 10/14/2018 3.00 MIRU MOVE MOB P Trucks on location, Load shop on 0.0 0.0 06:00 09:00 flatbed, PJSM with Peak for dg move. Move pits & sub off well 31-01, Jeep up, RID cellar berm and herculite 10/14/2018 10/14/2018 5.00 MIRU MOVE MOB P Move rig 31 to 2G pad 0.0 0.0 09:00 14:00 10/14/2018 10/14/2018 1.00 MIRU MOVE MOB P On 2 G pad, De jeep rig, Rig up 0.0 0.0 14:00 15:00 herculite in cellar, Scaffolding crew here. 10/14/2018 10/14/2018 2.00 MIRU MOVE MOB P Spot sub and pits 0.0 0.0 15:00 17:00 10/142018 10/14/2018 1.00 MIRU MOVE MOB P Start pre spud check list, Safe out rig, 0.0 0.0 17:00 18:00 stairs down. Ensure egress routes clear. 10/14/2018 10/142018 3.00 MIRU WHDBOP RGRP P Swap out swab #2 on stack, Work rig 0.0 0.0 18:00 21:00 up check lists 10/142018 10/14/2018 2.00 MIRU WHDBOP NUND P Nipple up stack, change out riser, 0.0 0.0 21:00 23:00 Obtain RKB's, RIG ACCEPT 21:00 10/14/2018 10/15/2018 1.00 MIRU WHDBOP SVRG P Grease stack, R valves, and drilling 0.0 0.0 23:00 00:00 choke 10/15/2018 10/152018 0.50 MIRU WHDBOP SFTY P PJSM to perform full BOPE test, Test 0.0 0.0 00:00 00:30 witness waived by Adam Ead, AOGCC 10/152016 10115/2018 8.00 MIRU WHDBOP BOPE P Start full BOPE test, Test pressure 5K, 0.0 0.0 00:30 08:30 stab INJH, test inner reel iron, inner reel valve, and pac-off. 10/15/2018 10/15/2018 0.50 MIRU WHDBOP CTOP P Valve crew on location load lubricator 0.0 0.0 08:30 09:00 into pipeshed, Unstab INJH, changeout UQV floats. 10/152018 10/15/2018 1.50 MIRU WHOBOP PRTS P Perform valve check -list, test PDL's 0.0 0.0 09:00 10:30 and tiger tank line. 10/152018 10/15/2018 1.20 MIRU WHDBOP PRTS P PJSM, P/T Lube, pull BPV 0.0 0.0 10:30 11:42 10115/2018 10/15/2018 0.30 MIRU WHDBOP CTOP P Load out Valve crew egiupment 0.0 0.0 11:42 12:00 10/15/2018 10/1512018 0.30 SLOT WELLPR CTOP P Move INJH forward remove UQC, 0.0 0.0 12:00 12:18 boot a -line, stab INJH 10/15/2018 10/15/2018 0.60 SLOT WELLPR CTOP P Line up and pump slack 0.0 0.0 12:18 12:54 manangement. 10/152018 10/15/2018 0.30 SLOT WELLPR CTOP P Unstab INJH, rig up hydraulic CT 0.0 0.0 12:54 13:12 cutter 10/152018 10/15/2018 3.80 SLOT WELLPR CTOP P PJSM, start trimming coil, found wire, 0.0 0.0 13:12 17:00 continue trimming coil, RD cutter and dress CT for CTC. *** Note: Found wire @ 28' 10/15/2018 10/15/2018 1.50 SLOT WELLPR CTOP P PJSM, install CTC, pull test to 35 k 0.0 0.0 17:00 18:30 10/152018 10/152018 0.60 SLOT WELLPR CTOP P Re -head BHI upper quick connect, 0.0 0.0 18:30 19:06 1 test e -line (good -test), install floats 10/15/2018 10/152018 0.40 SLOT WELLPR CTOP P PT connections and re -head 4,500 psi 0.0 0.0 19:06 19:30 1 (good test) 10/15/2018 10/15/2018 1.00 SLOT WELLPR PULD P PJSM, slide cart back, load both 0.0 0.0 19:30 20:30 POL's 10/15/2018 10/15/2018 1.30 SLOT WELLPR PULD P PD cleanout BHA#1, perform surface 0.0 51.3 20:30 21:48 test (good test) 10/15/2018 10/15/2018 1.90 SLOT WELLPR TRIP P Tag up, reset counters, RIH with 51.3 7,990.0 21:48 23:42 Cleanout BHA, PUW @ 4,000'124 k 10/15/2018 10/152018 0.10 SLOT WELLPR DLOG P Log the Kt marker correction of+2', 7,990.0 8,019.0 23:42 23:48 PUW=381< 10/15/2018 10/16/2018 0.20 SLOT WELLPR PRTS P Start static BHP, TVD 5872, 8,019.0 8,030.0 23:48 00:00 1 1 I Ann=3778, EMW=12.38 Page 1119 Report Printed: 311912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slant Depth SMTinne End Tire Dur(Itd Phase Op Code Ac dy Code Tie P -T -x Operation (RKB) End Depth(MB) 10/16/2018 10/16/2018 0.20 SLOT WELLPR PRTS P Static BHP, TVD 5872, Ann=3778, 8,030.0 8,030.0 00:00 00:12 EMW=12.38 10/16/2018 10/16/2018 0.30 SLOT WELLPR TRIP P Trip in to 8158 dry. PUH to 8000 for 8,030.0 8,000.0 00:12 00:30 CCL pass 10/16/2018 10/16/2018 0.20 SLOT WELLPR DLOG P Log CCL down to 8158, Bit to CCL 8,000.0 8,158.0 00:30 00:42 39.5 ' 10/16/2018 10/16/2018 0.40 SLOT WELLPR CIRC P recip CT waiting on sweeps 8,158.0 8,158.0 00:42 01:06 10/16/2018 10/16/2018 1.60 SLOT WELLPR TRIP P Sweeps out trip out displacing well to 8,158.0 56.8 01:06 02:42 1 used PwrPro 10/16/2018 10/16/2018 1.10 SLOT WELLPR PULD P At surface, PJSM PUD BHA #1 56.8 0.0 02:42 03:48 10/16/2018 10/16/2018 1.90 PROD1 RPEQPT PULD P Assemble Northern High Expansion 0.0 73.5 03:48 05:42 Wedge whipstock, M/U to Coil track and deploy. M/U to coil and surface test. Check pack offs. 10/16/2018 10/1612018 1.60 PROD1 RPEQPT TRIP P RIH BHA #2 NS HEW whip stock 73.5 8,020.0 05:42 07:18 10/16/2018 10/16/2018 0.20 PROD1 RPEQPT DLOG P Tie into Kl marker for A% PUW=37K 8,020.0 8,043.0 07:18 07:30 10/16/2018 10/16/2018 0.10 PROD1 RPEQPT TRIP P Continue in hole to setting depth 8,043.0 8,142.8 07:30 07:36 10/16/2018 10/1612018 0.10 PROD1 RPEQPT TRIP P 8142, at set depth oriented to HS. 8,142.8 8,142.8 07:36 07:42 Close EDC pull slack from CT. Pumps on .5 BPM see tool shift 4200 PSI Set down lightly on whipstock 10/16/2018 10/16/2018 1.50 PRODi RPEQPT TRIP P POOH after setting whip stock 8,142.8 61.0 07:42 09:12 10/16/2018 10/16/2018 0.90 PROD1 RPEQPT PULD P Tag up at surface. Space out. PJSM 61.0 0.0 09:12 10:06 PUD BHA#2 10/16/2018 10/16/2018 1.10 PRODi WHPST PULD P M/U and PD BHA #3 to mill window. 0.0 76.8 10:06 11:12 WFT V fixed bend motor, 2.80 Window mill, and 2.79 string reamer. M/U to coil and surface test 10116/2018 10/16/2018 420 PROD1 WHPST TRIP P RIH BHA#3 to mill window, close EDC 76.8 8,025.0 11:12 15:24 @ 500' Pumps on @ 1.80 BPM @ 4111 PSI. Take screen shots. Continue in well, Stacked out hard @ 4790'. Nothing in the area. PUH Inspect pipe and injector. Good. Trip in. Stack out. Roll pump @,7 BPM and roll TF to HS. Taking weight every -30 feet. Continue in well pumping at reduced speed 10/16/2018 10/16/2018 0.20 PROD1 WHPST DLOG P Log K1 for -3', PUW=34K 8,025.0 8,049.0 1524 15:36 10/16/2018 10/16/2018 0.50 PROD1 WHPST TRIP P Continue in well, Dry tag pinch point 8,049.0 8,137.0 1536 16:06 @ 8137.8', PUH 10/16/2018 10/16/2018 2.70 PROD? WHPST MILL P Bring pumps on 1.8 BPM @ 3803 PSI 8,137.4 8,140.0 16:06 18:48 FS, Start milling @ 8137.4 10116/2018 10/1612018 1.50 PROD1 WHPST MILL P Continue milling window per 8,140.0 8,142.0 18:48 20:18 procedure, 1.8 bpm, BHP = 3986 psi, WHIP = 394 psi, BOW called at 8140.2' (WOB & dip fall off), string reamer through window 10/16/2018 10/1612018 3.20 PROD1 WHPST MILL P Begin pushing, milling rat-hole,CWT= 8,142.0 8,163.0 20:18 23:30 11.8K, WOB=0.7K-3K, BHP=3846 psi, WHP = 406 psi, -5.5 bph losses, pump 5 x 5 sweeps 10/16/2018 10/17/2018 0.50 PRODt WHPST REAM P Begin reaming passes per procedure 8,163.0 8,163.0 23:30 00:00 1 I I (HS, 30L, & 30R) Page 2/19 ReportPrinted: 3119/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tune End Tim our (hr) Phase Op Cade Activay Cafe Time P4A Operation Sm1art Depth End Depth (nxa) 10/17/2018 10/17/2018 0.80 PROD1 WHPST REAM P Complete reaming passes per 8,163.0 8,163.0 00:00 00:48 procedure (HS, 30L & 30R), dry drift window, clean up & down, PUW = 35K 10/17/2018 10/17/2018 2.10 PROD1 WHPST TRIP P POOH, slight overpull at 4781', 8,163.0 76.0 00:48 02:54 slowed, Gose EDC, PJSM 10/17/2018 10/17/2018 1.10 PROD1 WHPST PULD P PUD BHA #3 (1.8-AKO motor, RB 76.0 0.0 02:54 04:00 Hughes bit), mill & string reamer came out 2.79" no-go 10/17/2018 10/17/2018 1.10 PROD- DRILL PULD P PD BHA#3 Buildfrum Assembly (1.8' 0.0 72.0 04:00 05:06 AKO motor, RS Hughes bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 10/17/2018 10/17/2018 1.70 PROD1 DRILL TRIP P RIH w/ BHA #4, Set down @ 5077 72.0 8,031.0 05:06 06:48 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P Log Kt for -1.5', PUW=35K 8,031.0 8,031.0 06:48 06:54 10/17/2018 10/17/2018 0.10 PROD1 DRILL TRIP P Continue in well, clean pass through 8,031.0 8,165.0 06:54 07:00 1 1 window, Tag up and drill from 8165 10/17/2018 10/17/2018 0.50 PROD1 DRILL DRLG P 8165', Drill 1.77 BPM @ 3790 PSI FS, 8,165.0 8,180.0 07:00 07:30 BHP=3810 10/17/2018 10/17/2018 1.20 PROD1 DRILL DRLG P 8180 stall, Pick up, PUW=40K loosing 8,180.0 8,010.0 07:30 08:42 returns,pulling heavy, DHWOB=-14K, Pull up into casing. Orion shut down. WITTS running very slowly. Restart BHI and orion computers - Gas in returns at surface. Divert to tiger tank. Pump bottoms up. PUH 10/17/2018 10/17/2018 0.40 PROD1 DRILL WPRT P PUH to log K1 for+1', trip in and log 8,010.0 8,029.0 08:42 09:06 RA @ 8141, TOWS=8134, TOW=8137, BOW=8140 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P RBIH to drill, returns fall off- 8178'. 8,029.0 8,181.0 09:06 09:18 Work to bottom 10/17/2018 10/17/2018 0.20 PROD1 DRILL DRLG P 8181', Drill 1.78 BPM @ 4010 PSI FS, 8,181.0 8,195.0 09:18 09:30 BHP=4130, RIW=12.8K 10/1712018 10/17/2016 0.20 PROD1 DRILL WPRT P 8195 Pick up stacking, Overpulling, 8,195.0 8,175.0 09:30 09:42 DHWOB=-10K, Initial PUW=55K with - 20K DHWOB 10/17/2018 10/17/2018 1.70 PRODi DRILL WPRT T 8175 Stuck, work pipe, Try to orient 8,175.0 8,175.0 09:42 1124 looks bit stuck. Diminshed / no returns. Reduce well head. Shut down pump to relax. Circulate 8 BBIs LVT down CT Spot 2 BBIs out, lel soak. Work pipe. Spot 3 more bbls out. Let soak. Work pipe and pop free 10/17/2018 10/17/2018 0.10 PROD- DRILL WPRT P Continue wiper to cased hole 8,175.0 8,122.0 11:24 11:30 10/17/2018 10/17/2018 1.80 PROD1 DRILL CIRC P Pump 10 X 10 sweeps and circulate 8,122.0 8,013.0 11:30 13:18 1 bottoms up. Little material coming overshaker 10/17/2018 10/17/2018 0.10 PROD1 DRILL DLOG P 8013 tie into K1 for 1.5' correction 8,013.0 8,030.0 13:18 13:24 10/1712018 10/17/2018 0.50 PROD1 DRILL WPRT P RBIH, stop @ 8127 and perfor static 8,030.0 8,127.0 13:24 13:54 pressure test, TVD 5931.4, Annular pressure 3935, EMW=12.7. Holding 12.8 PPG at window 10/17/2018 10/17/2018 0.10 PROD1 DRILL WPRT P RBIH to drill, stack and loose returns 8,127.0 8,195.0 13:54 14:00 1 @ 8178 work through 10/17/2018 10/17/2018 0.30 PROD1 DRILL DRLG P 8195', Drill, 1.77 BPM @ 3860 PSI 8,195.0 8,205.0 14:00 14:18 FS, BHP=3850 10/17/2018 10/17/2018 0.90 PROD1 DRILL WPRT P 8205, PUH into casing. Pressures all 8,205.0 8,111.0 14:18 15:12 over. Circ bootoms up. Sample to geo. Calls it B shale. Blow down micro motion Page 3/19 Report Printed: 3119/2019 r Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start-nnt End TNre Dur(hr) Please Op Code Activity code Time P-T-X operation (W) End Deph(N(B) 10/17/2018 10/17/2018 0.20 PROD1 DRILL WPRT P RBIH to drill 8,111.0 8,207.0 15:12 15:24 10/17/2018 10/17/2018 0.70 PRODt DRILL DRLG P 8207', Drill, 1.76 BPM @ 3860 PSI 8,207.0 8,210.0 15:24 16:06 FS, BHP=4250, frequent pick ups. On pick up from 8210 became stuck @ 8190. Work pipe up to 50K, DHWOB=- 16K. Down to zero. DHWOB=6K 10/17/2018 10/17/2018 0.60 PRODt DRILL DRLG T Pipe stuck, Pump 8 BBIs LVT down 8,210.0 8,210.0 16:06 16:42 1 1 CT 10/17/2018 10/17/2018 1.60 PROD1 DRILL WPRT P Get two bbls out CT lel soak. Work 8,210.0 8,075.0 16:42 18:18 pipe. Pump 3 more bbls out let soak. Pull free. Trip to cased hole. Pump 10 X 10 sweeps, circulate multiple bottoms up, pump addilioal sweep 10/17/2018 10/17/2018 1.80 PROD1 DRILL TRIP T Decision mae to POOH for cleanout 8,075.0 72.0 18:18 20:06 assembly, silt/shale over shakers, not sticky, low clay content, fairly benign 10/17/2018 10/17/2018 0.80 PROD1 DRILL PULD T PJSM, PUD BHA #4 72.0 0.0 20:06 20:54 10/17/2018 10/17/2018 1.90 PROD1 DRILL PULD T PJSM, make up new tools, PD BHA 0.0 63.0 20:54 22:48 #5 (1.0' AKO motor, string reamer, D331 w/ridge-set, no Res tool), slide in cart, check pack-offs, MU to coil, tag up, set counters, blow down choke & micro-motion 10/17/2018 10/18/2018 1.20 PROD1 DRILL TRIP T RIH w/ BHA#5 63.0 5,500.0 22:48 00:00 10/18/2018 10/18/2018 0.50 PROD1 DRILL TRIP T RIH w/ BHA#5 5,500.0 8,005.0 00:00 00:30 10/1812018 10/18/2018 0.10 PROD1 DRILL DLOG T Log Kl for -1' correction 8,005.0 8,037.0 00:30 00:36 10/18/2016 10/18/2018 0.50 PROD1 DRILL DLOG T Continue RIH to 8100, close EDC, 8,037.0 8,137.0 00:36 01:06 PUW = 35K Stop, obtain SBHP It min): MD = 8120.6', TVD-senor = 5932.9', BHP = 4050 psi, WHIP = 1367 psi, EMW = 13.13 ppg, pressure climbed during test 10/18/2018 10/18/2018 2.30 PROD1 DRILL REAM T Work to end of rat-hole in 10' bites, 8,137.0 8,137.0 01:06 03:24 PUW's = 35K, FS = 394 psi @ 1.8 bpm, BHP = 4071 psi Perfrom reaming passes of window & rat-hole (8137'to 8166'): HIS down- hole. 30L, 30R, HIS, & 2 passes LS all up-hole (1 fpm through window, 5 fpm in rat-hole), pump multiple sweeps 10/18/2018 10/18/2018 1.90 PROD1 DRILL TRIP T POOH, open EDC, pre-loaded DS 8,137.0 59.0 03:24 05:18 PDL 10/18/2018 10/18/2018 1.00 PROD1 DRILL PULD T At surface, Tag up and space out. 59.0 0.0 05:18 06:18 PUD BHA#5 10/18/2018 10/18/2018 0.40 PROD1 DRILL PULD T Reconfigure pre loaded tool to remove 0.0 0.0 06:18 06:42 UltraSlimResislivity tool from BHA 10118/2018 10/18/2018 1.10 PROD1 DRILL PULD T Pressure deploy BHA #6 with 1.8° 0.0 62.6 06:42 07:48 AKO motor, RR HCC bi center. No agitator or USR. Make up to coil and surface test. Check pack offs 10/18/2018 10/18/2018 1.70 PRODt DRILL TRIP T Trip in hole, BHA #6, Test HOT on 62.6 8,010.0 07:48 09:30 1 1 1 stop 10/18/2018 10/18/2018 0.10 PROD1 DRILL DLOG T Log K1 for-1/2', Close EDC, 8,010.0 8,030.0 09:30 09:36 PUW=34K Page 4/19 ReportPrinted: 3/1912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sam rim End TMe Dur (hr) PaaseSf Op Code Activity Code Time P -T -X Operation an (ftKa)� EM Depth (111(13) 10/18/2018 10/18/2018 0.40 PROD1 DRILL TRIP T Trip in well, initial tag up @ 8176 work 8,030.0 8,210.0 09:36 10:00 down to next tag up @ 8195. Work down to 8209. recip up to 8160. Clear on way up. No overpulls on DHWOB. RBIH stack at 8179. work pipe down to 8210 10/18/2018 10118/2018 0.40 PROD1 DRILL DRLG T 8210', Drill, 1.79 BPM @ 3850 PSI 8,210.0 8,216.0 10:00 10:24 FS, BHP=4075, Hard to maintain differential pressure. Able to get all DHWOB. Tool is hanging up above bit. Multiple pick ups to get back to bottom with Diff pressure 10/18/2018 10/18/2018 0.60 PROD1 DRILL WPRT T 8216, stacking out. PUH, PUW=50K. 8,216.0 8,216.0 10:24 11:00 Stuck @ 8190. Work pipe within limits of HOT. Seeing negative weight. Unable to orient. Work free. PUH to 8150. RIH to drill. Have to work 8178 down 10118/2018 10/18/2018 1.40 PROD1 DRILL DRLG T 8216', Drill, 1.8 BPM 3995 PSI FS. 8,216.0 8,236.0 11:00 12:24 Returns coming and going. Start gel gas in returns. Ship returns to tiger tank, Frequent pickups to get differential pressure. Unable to maintain steady state drilling 10/18/2018 10/18/2018 0.20 PROD1 DRILL WPRT T One of many pickups over pull and 8,236.0 8,236.0 12:24 12:36 stuck, Not showing any WOB. Able to orient freely. Work pipe. Little returns. Not showing any pull on HOT. Work free @ 70K 10/18/2018 10/18/2018 1.40 PROD1 DRILL WPRT T After pulled free BHA shorted out. 8,236.0 8,075.0 12:36 14:00 PUH to cased hole. Pump 10 X 10 sweeps. Circulate gas out of well Trouble shoot surface electrical componets. Shorted down hole 10/1812018 10/18/2018 2.30 PROD1 DRILL TRIP T Trip out maintain 1 to 1. At 500' well 8,075.0 63.0 14:00 16:18 unloaded heavy shales. Jog back in hole. Pull to surface, Tag up and space out. Swap chokes and lost all . WHP. Open up tangos. MP line showed zero. Open up whitey valve on riser. No pressure 10/18/2018 10118/2018 1.00 PRODi DRILL TRIP T Trip in hole to find pack off / bridge 63.0 63.0 16:18 17:18 holding 1100 PSI WHP. RIH to 750'.Saw nothing. Blleed off WHP to 650 PSI. Bridge must be down much lower. POOH 10/18/2018 10/18/2018 1.30 PROD1 DRILL PULD T PUD BHA#6, DBV bent (pictures on 63.0 0.0 17:18 18:36 S: drive), bit came out a 1-3 (7 broken reamer cutters & 1 plugged nozzle) 10/18/2018 10/1812018 1.00 PROD1 DRILL PULD T Decision made to PU build assembly, 0.0 63.0 18:36 19:36 PD BHA #7 Build Assembly #3 (1.8" AKO motor, RR Dynamus bit, no RES tool), slide in cart, check pack -offs, MU to coil, tag up, set coutners 10/18/2018 10/18/2018 2.00 PROD1 DRILL TRIP T RIH wl BHA V, EDC closed, RIH 63.0 8,005.0 19:36 21:36 pumping anticipating bridge -off at unknown depth 10/1812018 10/18/2018 0.20 PRODt DRILL DLOG T Log K1 for -0.5' correction, PUW = 8,005.0 8,030.0 21:36 21:48 34K 10/18/2018 10/1812018 0.50 PROD? DRILL TRIP T Continue RIH, clean down to 8120', 8,030.0 8,100.0 21:48 22:18 pump 5x5 sweeps 10/18/2018 10/18/2018 0.40 PROD1 DRILL TRIP P Begin working through window, stack 8,100.0 8,133.0 22:18 22:42 8K WOB at 8133' (believe found bridge -off at window stopping flow to surface), allow sweeps to exit bit Page 5119 Report Printed: 3119/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Daum Stan Time End rare Phase Op code AcWty Code Time P-T-X Operdlion (WEI) End Depth(ftKB) 10/18/2016 10/1912018 DRILL TRIP T EDC open, POOH for FCO assembly 8,133.0 600.0 22:42 00:00 10/19/2018 10/19/2018 PRODt DRILL TRIP T EDC open, POOH for FCO assembly, 600.0 63.0 00:00 00:30 rl.301PROD1 tag up, PJSM 10/19/2018 10/19/2018 PRODt DRILL PULD T PUD BHA#7, bit came out balled up 63.0 0.0 00:30 01:18 with Gay from seldom at TOWS, 2 plugged nozzles 10/19/2018 10/19/2018 PROD1 DRILL PULD T PD BHA#8 FCOAssembly(1.0°AKO 0.0 63.0 01:18 02:30 motor, D331 w/ ridge-set), slide in cart, check pack-offs, MU to coil, tag up, set counters 10/19/2018 10/1912018 1.80 PROD1 DRILL TRIP T RIH w/ BHA#8, corrupt data on Baker 63.0 8,005.0 02:30 04:18 screen, trouble-shoot & resolve issue 10119/2018 10/19/2018 0.10 PR0D1 DRILL DLOG T Log K1 for +4.5' correction, close EDC 8,005.0 8,027.0 04:18 04:24 10/19/2018 10/1912018 0.20 PROD1 T RIHto TOWS, PUW = 35K 8,130.0 04:24 04:36 10/19/2018 10/19/2018 0.70 PRDD1 TRIP T FCO from TOWS, 1.8 bpm, FS = 360 8,163.0 04:36 05:18 psi, circ = 3792, BHP = 4080 psi, WHIP rDRILLTRIP = 780 psi, 390 Ib motorwork beginning r8,027.0 at 8146', PUW = 37K from 8147', pull up through window. Continue in-hole to end of rat-hole (8163'), PUH to BOW, PUW = 37K 10/19/2018 10/19/2018 1.00 PROD1 DRILL TRIP T Continue FCO, 1.77 BPM. Set down 8,163.0 8,150.0 05:18 06:18 @ 8186, Pull heavy 52K, -6K DHWOB. PUH pack off RBIH to 8173. PUH to window. 10/19/2018 10119/2018 0.10 PROD1 DRILL DLOG T Log RA for +1'correction 8,150.0 8,173.0 06:18 06:24 10/19/2018 10/19/2018 2.80 PROD1 DRILL WPRT T RBIH, stckout @ 8175 recip up hole to 8,173.0 7,960.0 06:24 09:12 8098. RBIH to 8216. Packoff with overpull, 70K. PUH to 8150. RBIH to bottom @ 8234, Pumping multiple sweeps. Getting medium amount of shales on shaker. Pull up through window at full rate. PUH through 7" to 7960, 10/19/2018 10/19/2018 0.20 PROD1 DRILL WPRT T RBIH, clean pass through window 7,960.0 8,139.0 09:12 09:24 slack at 8175. PUH stuck at window 8139. 1.10 PROD1 DRILL WPRT T Work pipe out of window, PUH to 8,139.0 7,960.0 10:30 8070. RBIH clean through window. Stack out at 8175. Pick up sticky 65K with -17K DHWOB. PUH to TT at full F9/2201810/19/2018 rate with more sweeps 10/19/2018 2.00 PROD1 DRILL WPRT T 7960 RBIH clean through window. run 7,960.0 8,063.0 12:30 past 8275 @ 4 FPM with 90% returns. Full returns back @ 8285. Continue to bottom @ 8126. Recipt twice to 8143. Pumping sweeps. Maintaining full returns. Hole looks clean. Not stacking or over pulls. Pump 10 X 10 sweeps 10/19/2018 10/1912018 1.80 PROD1 DRILL WPRT T Sweeps out, Chase to swab. Jog @ 8,063.0 60.0 12:30 14:18 729' Hole unloading. Same shales as yesterday 10/19/2018 10/19/2018 1.50 PROD1 DRILL WPRT T Tag up at surface, Set counters, RBIH 60.0 8,010.0 14:18 15:48 10/19/2018 10/19/2018 0.10 PROD1 DRILL DLOG T Log Kt for +1', PUW=32K 8,010.0 8,030.0 15:48 15:54 10/19/2018 10/19/2018 0.10 PROD1 DRILL WPRT T Continue in well. Clean through 8,030.0 8,234.0 15:54 16:00 window and past 8175 to 8185 area with returns Page 6119 Report Printed: 3/1912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur(hn PhaseOp Code Activity Code Time P -T -X � � Start Depth (MB) End Deplh(MB) 10/19/2018 10/19/2018 0.40 PROD1 DRILL WPRT T PUH to 7". Clean trip through build 8,234.0 8,130.0 16:00 16:24 with no overpulls no packoff events. Start sweeps down CT 10/19/2018 10/19/2018 0.10 PROM DRILL WPRT T Sweeps close to bit. RBIH to 8200. 8,130.0 8,200.0 16:24 16:30 Clean trip to 8200 10/19/2018 10/1912018 1.70 PRODt DRILL WPRT T Sweeps at bit, POOH pumping 1.8 8,200.0 63.0 16:30 18:12 BPM, PUW=33K, open EDC, PJSM 10/19/2018 10/19/2018 0.90 PROD1 DRILL PULD T PUD BHA#8, mill came out 2.80" no- 63.0 0.0 18:12 19:06 1 go 10/19/2018 10/19/2018 1.00 PROD1 DRILL PULD T PD BHA#9 (Build Assembly, 1.8° AKO 0.0 63.0 19:06 20:06 motor, RR P104 bit, & no res tool), slide in cart MU to coil, change out pack -offs, tag up, set counters 10/19/2018 10/19/2018 1.60 PROD1 DRILL TRIP T RIH w/ BHA#9, lost COMMS to BHA 63.0 7,975.0 20:06 21:42 at 4146', stop trouble -shoot, resolved 10/19/2018 10/19/2018 0.60 PROM DRILL DLOG T Did not see Ki on first pass, PUH to 7,975.0 8,025.0 21:42 22:18 7975 to re -log, +34.5' correction 10/19/2018 10/1912018 0.40 PRODt DRILL TRIP T Continue RIH, PUW = 38K, log RA for 8,025.0 6,236.0 22:18 22:42 1 +1' correction, bring up rate 10/19/2018 10/19/2018 0.80 PROD1 DRILL DRLG P OBD, 1.88 bpm, FS = 525 psi, circ = 8,236.0 8,330.0 22:42 23:30 4313 psi, CWT = 13K, WOB = 1.8K, BHP = 4120 psi, WHP = 710 psi, pump sweeps, Begin packing off at 8330', losing returns 10/19/2018 10/20/2018 0.50 PROD1 DRILL WPRT P Wiper, PUW = 45K, continue to pull 8,330.0 8,050.0 23:30 00:00 heavy, working up & down to release pack -off, pulling up to 68K, density out drops, clear packoff, pull up through window, begin taking returns to TT, begin circulating bottoms up 10/20/2018 10/20/2018 0.50 PROD1 DRILL WPRT P Continue circulating bottoms up in 7" 8,050.0 8,050.0 00:00 00:30 casing, sweeps coming to surface, density out climbs to 8.94 ppg, bring returns back inside after 42 bbls Sample to geo: -50% savings, remaining 50% mixutre of cuttings (shale & sand) 10/20/2018 10/20/2018 0.40 PRODt DRILL WPRT P RBIH, stack weight at 8164', PUW = 8,050.0 8,175.0 00:30 00:54 38K, stack again at 8169', again at 8170', begin packing off, begin losing returns, pull -1 OK WOB, wiper to bottom of window, tum around 10/20/2018 10/20/2018 0.90 PROM DRILL WPRT P RBIH at 7 fpm, taking bites & PUH, 8,175.0 7,835.0 00:54 01:48 begin packing off at 8205', erratic returns, reciprcate pipe to dear pack - off, PUW = 45K, pulling heavy up to 66K Pull up to tubing tail & circulate, 8.9 ppg slug over shakers, rate out drops while in 7", circulate bottoms up, pull 500' into tubing tail 10/20/2018 10/20/2018 1.40 PROM DRILL WPRT T Circulating, pins/ retaining -stops on 6 7,835.0 7,835.0 01:48 03:12 gripper block plates sheared pff, elastomers worn, circulate awaiting mechanic, 10/20/2018 10/20/2018 4.70 PROD? DRILL TRIP T POOH @ 50 fpm, EDC open 7,835.0 63.0 03:12 07:54 Decision made to POOH, replace failed gripper block plates & elastomers on Nabors rig repair time Page 7119 ReportPrinted: 3119/2019 . - Operations Summary (with Timelog Depths) 2G-06 ...• Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tine End Tnne Dw (hr) Phase Op Code Activity Code Time P-T-X Operation (NCB) End Depth (MB) 10/20/2018 10/20/2018 1.60 PROD1 DRILL PULD T PJSM, PUD BHA #9, Lay down BHA 63.0 0.0 07:54 09:30 10/20/2018 10120/2018 3.00 PROD1 DRILL RGRP T Continue with repairs to chains, 0.0 0.0 09:30 12:30 Change out all elastomers Confer with town asset, drilling, & rig. Decision made to cleanout down to 7" & set backup '• 8 his agreed upon for Nabors rig repair time (SIMOPS w/ replanning of second WS) 10/20/2018 10/2012018 1.20 PROD1 DRILL PULD T Repairs complete, Start making up 0.0 0.0 12:30 13:42 build section BHA. Plan change going to run whipstock 10/20/2018 10/20/2018 0.90 PROD1 DRILL PULD T M/U BHA#10. FCO BHA with 1° motor 0.0 62.3 13:42 14:36 and D-331. Pressure deploy. Make up to coil and surface test 10/20/2018 10/20/2018 1.80 PROD1 DRILL TRIP T Trip in hole to clean 7" casing for 62.3 7,995.0 14:36 16:24 whipstock set 10/20/2018 10/20/2018 0.10 PROD1 DRILL DLOG T 7995', Log K1 for - 12', PUW=39K, 7,995.0 8,031.0 16:24 16:30 1 1 1 Pumping sweeps 10/20/2018 10/20/2018 1.80 PROD1 DRILL CIRC T PUH circulating sweeps DH 8,031.0 8,128.0 16:30 18:18 10120/2018 10/20/2018 1.60 PROD1 DRILL TRIP T POOH, open EDC 6,128.0 62.0 18:18 19:54 10/20/2018 10/20/2018 1.00 PROD1 DRILL PULD T PUD BHA#10 62.0 0.0 19:54 20:54 10120/2018 1020/2018 1.90 PROD1 RPEQPT PULD T MU & PU HEW, PD BHA#11 (HEW 0.0 74.0 20:54 22:48 Whipstock #2), slide in cart, MU to coil, tag up, set counters 10/20/2018 10/21/2018 1.20 PROD1 RPEQPT TRIP T RIP w/ BHA #11 74.0 5,400.0 22:48 00:00 10/212018 10/21/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH w/ BHA#11, EDC open 5,400.0 8,015.0 00:00 00:24 10/21/2018 10/21/2018 0.10 PROD1 RPEQPT DLOG T Log Kt for-1' correction 8,015.0 8,043.0 00:24 00:30 10/21/2018 10/21/2018 0.40 PROD1 RPEQPT TRIP T Continue RIH, arrive at setting depth 8,043.0 8,103.8 00:30 00:54 (8103.78'), PUW = 38K, RBIH, close EDC, bring up pump, shear off @ 5100 psi, set down 2K on WS, PUW = 37K, TOWS -8095', oriented HS 10/21/2018 10/21/2018 1.40 PROD1 RPEQPT TRIP T POOH, EDC open, PJSM 8,103.8 65.0 00:54 02:18 1021/2018 10/21/2018 1.10 PROD1 RPEQPT PULD T PUD BHA#11 65.0 0.0 02:18 03:24 1021/2018 10/21/2018 1.50 PROD1 WHPST PULD T PD BHA#12 Window Assembly(1.0° 0.0 77.0 03:24 04:54 AKO motor, string reamer, window mill), slide in cart, check pack-offs, clean up metal built around brass & pressure wash, MU to coil, tag up, set counters 10/21/2018 10/21/2018 1.80 PROD1 WHPST TRIP T RIH w/ BHA#12, Tagged up on collar 77.0 8,025.0 04:54 06:42 @ 4965', Work through, Coninue in 10/21/2018 10/21/2018 0.20 PROD1 WHPST DLOG T Log K1 for-1.5' cometion, PUW=36K, 8,025.0 8,046.0 06:42 06:54 close EDC 10/21/2018 1021/2018 0.10 PROD1 WHPST TRIP T Continue in well, Dry tag pinch point 8,046.0 8,099.0 06:54 07:00 @ 8099, PUH 10/21/2018 1021/2018 2.60 PROD1 WHPST MILL T Pumps on 1.8 BPM @ 4530 PSI FS, 8,099.0 8,100.4 07:00 09:36 BHP=4095. Call pinch point 8097.5. Start milling window per procedure Page 8/19 Report Printed: 311912019 Operations Summary (with Timelog Depths) 2G-06 .. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Slab Depth ut De Stan Time End Time Dur(M Phase Op Code Activity CMe Time P -T-% Operation End Depth (flKB) 10/21/2018 10/21/2018 2.40 PROD? WHPST MILL T Call BOW 8100.4 Time Milling 8,100.4 8,100.3 09:36 12:00 formation 10/21/2018 10/21/2018 1.50 PRODi WHPST MILL T Milling rathole, Stall @ 8103.19 8,100.3 8,103.3 12:00 13:30 Restart and stall here again 10/21/2018 10/21/2018 4.40 PROD1 WHPST MILL T Continue milling rathole, 1.81 BPM @ 8,103.3 8,122.0 13:30 17:54 4620 PSI FS, BHP=4050 10121/2018 10/21/2018 2.10 PRODi WHPST REAM T Perform reaming passes 1 fpm 8,122.0 8,122.0 17:54 20:00 through window, 5fpm in rat -hole (HS, 30L, 30R, LS), dry drift up & down, dean 10/21/2018 10/21/2018 1.70 PROD1 WHPST TRIP T POOH, EDC open, lost WITS data, 8,122.0 77.0 20:00 21:42 trouble -shoot, reboot Caning server, up & running. 10/21/2018 10/21/2018 1.20 PROD1 WHPST PULD T PUD & LD BHA#12, mill came out 77.0 0.0 21:42 22:54 2.79" no-go, string reamer came out 2.80" no-go 10/212018 10/22/2018 1.10 PROD1 DRILL CTOP T Clear floor, MU nozzle, stab on &jet 0.0 0.0 22:54 00:00 stacK Sunday Safety Meeting in dog -house (SIMOPS) 10122/2018 10/22/2018 0.50 PROD1 DRILL CTOP T Break off nozzle, dear floor, break 0.0 0.0 00:00 00:30 down & snake MM 10122/2018 10122/2018 1.30 PROD1 DRILL PULD T PJSM, PD BHA#13 Build Assembly 0.0 62.0 00:30 01:48 (2.4° AKO motor, RR Hughes bit), MU to coil, check pack -offs, tag up, set counters 10/22/2018 10/22/2018 1.60 PROD1 DRILL TRIP T RIH w/BHA #13 62.0 8,010.0 01:48 03:24 10/22/2018 10/22/2018 0.20 PRODi DRILL DLOG T Log K1 for -1' correction, close EDC, 8,010.0 8,F3-0-0- 03:24 03:36 1 1 PUW = 38K 10/22/2018 10/22/2018 0.40 PROD1 DRILL TRIP T Continue RIH, did not find bottom at 8,030.0 8,136.0 03:36 04:00 8122', found it at 8136', stalled, PUW = 38K 10222018 10/22/2018 0.80 PRODt DRILL TRIP T PUH to log RA, did not see it & tag at 8,136.0 8,136.0 04:00 04:48 8134', PUW = 38, RIH to find bottom, stall 10222018 10/222018 0.30 PROD1 DRILL TRIP T PUH to log K1 & find RA. Log K1 for 0' 8,136.0 8,136.0 04:48 05:06 correction, do not see RA tag, PUW = 38K, PUH 10/222018 10/22/2018 0.20 PRODi DRILL TRIP T Confer with town, attempt to find RA 8,136.0 8,136.0 05:06 05:18 1 1 1 an additional time, 10/222018 10/22/2018 1.60 PROD1 DRILL TRIP T No sign of R4 marker, POOH. Open 8,136.0 65.0 05:18 06:54 EDC @ 8024 10/22/2018 10/22/2018 1.20 PROD1 DRILL PULD T Tag up / space out, PJSM. PUD BHA 65.0 0.0 06:54 08:06 #13 10122/2018 10/22/2018 0.30 PROD1 DRILL BOPE P Perform Bi Weeekly BOPE function 0.0 0.0 08:06 08:24 test 10/22/2018 10/222018 3.10 PROD1 DRILL WAIT T Stand by for Caliper, Inspect CT .195 0.0 0.0 08:24 11:30 min wall thickness found. Pull all gripper blocks and check elastomers - Allgood 10/222018 10/22/2018 1.00 PROD1 DRILL PULD T HES on location, M/U caliper and put 0.0 25.7 11:30 12:30 in well. Rig up HES computer 10/22/2018 1012212018 2.10 PROD1 DRILL TRIP T Trip in with BHA #14 HES caliper 25.7 8,029.0 12:30 14:36 10/22/2018 10/2212018 0.10 PROD1 DRILL DLOG T Log K1 for+20, Continue in 8,029.0 8,U5-00- 14:36 14:42 10/22/2018 10/2212018 0.10 PROD1 DRILL TRIP T Continue in well 8,050.0 8,126.0 14:42 14:48 10/22/2018 10/22/2018 0.30 PROD1 DRILL DLOG T 8126. run 2 logging passes up to 8,126.0 8,000.0 14:48 15:06 8000' Page 9119 Report Printed: 3119/2019 - Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stet beptn Stat Time End Time Dur(te) Phase Op Code Activity Code TIM P -T -x Operation (5(13) End Depth (WB) 10/22/2018 10/22/2018 1.30 PRODt DRILL TRIP T POOH with HES caliperr 8,000.0 25.0 15:06 16:24 10/22/2018 10/22/2018 1.50 PROD1 DRILL PULD T At surface, Lay down BHA#14 HES 25.0 0.0 16:24 17:54 caliper 10/22/2018 10/22/2018 0.20 PROD1 DRILLP SF Crew change, PJSM Ice dg 0.0 0.0 17:54 18:06 valves 10/22/2018 10122/2018 0.90 PROD1 DRILL RG P Service no valilli 0.0 0.0 18:06 19:00,00o 10/22/2018 10/22/2018 0.60 PROD1 DRIL PULD P PJ /U nozzle and stinger. Put in .0 16.8 19:00 19:36 and hook up coil. M/U injector to Il. Tag up 10/22/2018 10/22/2018 1.90 DEMOB HDBOP DISP P Trip in hole. Seawater here load into 16.8 8,050.0 19:36 21:30 suction pit. Start pumping sewater time to get to nozzle @ 8050 10/2212018 10/22/2018 1.60 PR WHDBOP FRZP P 10 BBls seawater out of CT. Tr' ut. 8,050.0 17.0 21:30 23:06 Freeze protect from 2500' w' diesel 10/22/2018 10/23/2016 0.9 ROD1 WHDBOP P P At surface, Tag up and s swabs. 17.0 0.0 23:06 00:00 Lay down BHA#15 r " 1400 psi WHP 10/23/2018 10/23/2018 1.00 DEMOB WHO CTOP P Complete jetti ack & surface lines 0.0 0.0 00:00 01:00 10/23/2018 10123/ 8 2.30 DEMOB BOP CTOP P Await vaWrtrew, crews prepping to 0.0 0.0 01:00 03: A move ' oro -scope stack 10/23/2018 3/2018 1.00 DEMOB WHDBOP RURD PSel 0.0 0.0 03:18 4:18 10123/201 10/23/2018 2.70 DE WHDBOP RURD P ear floor, prep for move, await plan 0.0 0.0 04:18 07:00 forward 10/23) 8 10/23/2016 2.50 MOB WHDBOP RURD P Freeze protect tree, work RD 0.0 0.0 07:0 09:30 checklist, ND BOPE " Rig Released: 10/23/18 @ 9:30 AM 3/5/2019 3/5/2019 4.70 MIRU MOVE MOB P Trucks on location, PJSM Pull off well. 0.0 0.0 13:00 17:42 Sub off Q 16:00, Pits off 16:45. DSO change out on location 17:30. Leave 3M 17:45 3/5/2019 3/6/2019 6.30 MIRU MOVE MOB P Travel to 2G 0.0 0.0 17:42 00:00 3/6/2019 316/2019 3.00 MIRU MOVE MOB P Travel to 2G 0.0 0.0 00:00 03:00 3/6/2019 3/6/2019 1.00 MIRU MOVE MOB P On 2G, De Jeep, Rig up cellar lay 0.0 0.0 03:00 04:00 hercu lite 3/6/2019 3/612019 2.00 MIRU MOVE MOB P Spot sub and pits 0.0 0.0 04:00 06:00 3/6/2019 3/612019 1.00 MIRU MOVE RURD P PJSM, Safe out rig. Start working rig 0.0 0.0 06:00 07:00 up check list 3/6/2019 3/6/2019 1.50 MIRU MOVE RURD P PJSM, R/U Putz, R/U Steam. R/U to 0.0 0.0 07:00 08:30 unstab Coil 31612019 3/6/2019 1.50 MIRU MOVE OTHR P Unstab CT and secure to storage 0.0 0.0 08:30 10:00 spool 3/6/2019 3/6/2019 1.50 MIRU MOVE OTHR P remove riser from injector, remove 0.0 0.0 10:00 11:30 stuffing box, remove gripper blocks 3/6/2019 3/6/2019 3.00 MIRU MOVE OTHR P Disconnect Injector electrical service, 0.0 0.0 11:30 14:30 hydraulic lines, and instrumentation 3/6/2019 3/6/2019 1.50 MIRU MOVE OTHR P PJSM, Rig up injector to crane, Pull up 0.0 0.0 14:30 16:00 on injector unbolt cart bolts. Lift injector out of rig to ground 316/2019 1.50 MIRU MOVE OTHR P Prep new injector for lift into rig 0.0 0.0 16:00 17:30 1 13/6/2019 3/6/2019 3/6/2019 1.00 MIRU MOVE OTHR P Pick & set new injector onto rig 1 0.0 0.0 17:30 18:30 1 I Page 10119 ReportPrinted: 3/19/2019 . Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sfart7ima End Time Dw (hr) Phase op Code Activity Code TMe P4 -X Operation Stan Depth WS) End Depth (MB) 3/6/2019 3/6/2019 3.00 MIRU MOVE OTHR P Begin connecting electrial & hydraulic 0.0 0.0 18:30 21:30 lines, tighten/adjust goose -neck (Nabors electrician & Peter O'Brian houred out, went back to camp to rest), secure injector to cart 3/6/2019 3/7/2019 2.50 MIRU MOVE OTHR P Clear rig floor, slide injector back, NU 0.0 0.0 21:30 00:00 BOPE, continue connecting hydraulic lines, visa up seawater for window milling 3/7/2019 3/7/2019 1.50 MIRU MOVE OTHR P Grease surface valves in prep for BOP 0.0 0.0 00:00 01:30 test, install BOP riser 377/2019 317/2019 1.50 MIRU MOVE OTHR P Verify Koomey bottle levels, inspect 0.0 0.0 01:30 03:00 mud pump #1, fill injector fluids, grease master, swabs, & tangos, open up & inspect chokes (both look good) 3/7/2019 3!7/2019 3.00 MIRU MOVE OTHR P Clean up hammer union "ears", 0.0 0.0 03:00 06:00 change out mud -pump #1 worn valve/seat 3/7/2019 377/2019 7.00 MIRU MOVE OTHR P Crew change, Continue to hook up 0.0 0.0 06:00 13:00 injector, Complete MP #1 reconditioning 3/7/2019 3/7/2019 1.00 MIRU WHDBOP OTHR P Move injector// Prep for full BOPE 0.0 0.0 13:00 14:00 test. Test witness waived by Adam Earl, AOGCC 3/7/2019 3/7/2019 5.00 MIRU WHDBOP BOPE P Start full BOPE test, fail/pass on 0.0 0.0 14:00 19:00 Tango 1 (250 psi low 14800 psi high) Working injector in SIMOPS (Nabors/Peter O'Brina/HydraRig rep) 317/2019 3/7/2019 4.00 MIRU WHDBOP BOPE P Continue w/ BOP test, continue 0.0 0.0 19:00 23:00 injector tests in SIMOPS, install gripper blocks, perfrom draw -down test, laydown test jm, clear floor 3/7/2019 3/7/2019 0.20 MIRU WHDBOP OTHR P PU & install stripper & riser 0.0 0.0 23:00 23:12 3/7/2019 3/8/2019 0.80 MIRU WHDBOP OTHR P Crew change, PJSM, begin stabbing 0.0 0.0 23:12 00:00 coil, pull test crapple to 900 psi, good, remove reel chains, unlock reel, pull pipe through injector 3/8/2019 3/8/2019 0.80 MIRU WHDBOP OTHR P Complete stabbing pipe, break down 0.0 0.0 00:00 00:48 grapple, tugger line & snatch block, clear floor, injector error (motor differential detected), confer w/ O'Brain, continue running pipe through injector, break off nozzle /8/2019 3/8/2019 0.90 MIRU WHDBOP OTHR P Install UQC, re -head a -line & test, PT 0.0 0.0 00:48 01:42 UQC to 4500 psi 3/8/2019 3/8/2019 1.30 MIRU WHDBOP PRTS P MU nozzle, check pack -offs, stab -on, 0.0 0.0 01:42 03:00 test IRV & stripper Small hydraulic leak from stripper T - fitting (call out mechanic to repair) 3/812019 3/8/2019 1.00 MIRU WHDBOP PRTS P PT tiger -tank line & PDUs, adjust 0.0 0.0 03:00 04:00 goose -neck 3/8/2019 3/8/2019 0.60 MIRU WHDBOP OTHR P Continue goose -neck adjustments 0.0 0.0 04:00 04:36 3/8/2019 3/8/2019 0.40 MIRU WHDBOP OTHR P Open up well, 1280 pdi, bleed off to 0.0 0.0 04:36 05:00 TT, slowly building pressure on MP line, blow down TT line 3/8/2019 3/8/2019 4.50 MIRU WHDBOP OTHR P Install checks, MU nozzle, RIH, 0.0 0.0 05:00 09:30 Pumping seawater returns to tiger tank. Recip while ARP making adjustments / taking readings. Do not run in deeper then 300' Page 11119 Report Printed: 3/1912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tore Dur(hr) Phase Dip Coes Ac ycote Timm P -T -X operation (ftKe) Ertl Depth (WB) 3/8/2019 3/8/2019 0.50 MIRU WHDBOP OTHR P Unstab injector. remove ri=le. M/U 0.0 0.0 09:30 10:00 pull plate. Pull test injector to 45K in 1 OK steps. Hold 45K. Relax coil. End of surface testing 3/8/2019 3/8/2019 1.30 PROD1 WHPST PULD P M/U BHA#16 with Weatherford V 0.0 77.2 10:00 11:18 fixed bend motor, 2.80 Dimond window mill, and RR string reamer 3/8/2019 3/8/2019 1.80 PROD1 WHPST TRIP P RIH BHA#16, EDC open pumping 77.2 8,020.0 11:18 13:06 seawater @ .4 BPM. Monitoring injector 318/2019 3/82019 0.10 PROD1 WHPST DLOG P Log K1 for 4, PUW=30K 8,020.01 8,045.0 13:06 13:12 3/82019 3/8/2019 0.80 PROD1 WHPST CIRC P Displace coil / well to viscosified 8,045.0 8,066.0 13:12 14:00 milling Fluid 318/2019 3/82019 0.10 PROD1 WHPST TRIP P Continue in, tag top of cement @ 8,066.0 8,085.0 14:00 14:06 8085, PUH 3/8/2019 302019 1.10 PROD1 WHPST MILL P Bring on pumps 1.8 BPM @ 3725 PSI 8,085.0 8,097.9 14:06 15:12 FS, Call TOC @ 8084. Tough to get going. Once going ROP - 20 FPH. Roll toolface to 10" ROHS to handle walking in mini pilot hole 3/8/2019 3182019 2.30 PROD1 WHPST MILL P ROP stopped, Call this pinch point. 8,097.9 8,099.4 15:12 17:30 Roll TF to HS. 1.79 BPM @ 3757 PSI FS. Start time milling window per procedure 1 Northern soulotions rep (TOW = 80983). Hold at least 11.8PPG in rathole (per engineer) 3/812019 3/8/2019 2.30 PRODt WHPST MILL P Continue milling window, CWT= 8,099.4 8,100.0 17:30 19:48 11.7K, WOB = 2.1 K, annular = 3280 psi, pump = 4017 psi, 1 for 1 returns, milling slows down, PU from 8099.9', FS = 610 psi 3/8/2019 3/82019 1.40 PROD1 WHPST MILL P Milling window, CWT= 10.6K, WOB = 8,100.0 8,100.4 19:48 21:12 3.21K, annular = 3281 psi, pump = 4101 psi, 1.8 bpm, bleed down IA, slow milling progress, NS rep requests WOB increase to 4K. .• Pre -load ODS PDL 3/8/2019 3/92019 2.80 PROD1 WHPST MILL P Continued slow milling, PU per NS 8,100.4 8,101.5 21:12 00:00 rep, PUW = 27K, FS = 600 psi, begin seeing weight at 6,099.9' (made footage from last PU), call BOW @ 8101' (2.7' window) 3/9/2019 3/9/2019 0.60 PROD1 WHPST MILL P Continue milling window from 8101.5', 8,101.5 8,102.3 00:00 00:36 CWT= 12K, WOB =.9K, annular= 3283 psi TOW = 8098.3', BOW = 8101' 3/9/2019 3/92019 2.40 PROD1 WHPST MILL P String reamer exits window, milling rat- 8,102.3 8,124.0 00:36 03:00 hole, begin pushing on it, CWT = 1 OK WOB = 3.2K, increase ECD at window to 12.4 ppg, WHIP = 549 psi, dirt in samples 3/9/2019 3/912019 1.80 PROD1 WHPST REAM P PUW = 27K, pump 5x5 sweep, 8,124.0 8,124.0 03:00 04:48 perform reaming passes, 2 HS, 30L, 30R, & LS, dry drift window up & down, dean, confirm rat -hole TD, pump 5x5 sweeps 3/92019 3/9/2079 1.60 PROD1 WHPST TRIP P POOH, PUW = 28, open EDC 8,124.0 77.0 04:48 06:24 3/92019 3/9/2019 1.20 PROD1 WHPST PULD P Al surface, tag up and space out. PUD 77.0 0.0 06:24 07:36 BHA#16. Mill out 2.79 No go Page 12119 ReportPrinted: 311912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EM Time Dor(hr) Phase Op Code Activity ComaTime P -T -X operation sten Depth (flKB) EM Depth (tIKB) 3/92019 3/9/2019 0.90 PROD1 DRILL CTOP P Make up nozzle and jet stack 0.0 0.0 07:36 08:30 3/9/2019 3/9/2019 1.40 PROD1 DRILL PULD P PD BHA#17 with 2.5" AKO motor and 0.0 72.2 08:30 09:54 RB HCC bit with Dynamus cutters. TX25207. PDL was preloaded. Make up to coil and surface test. Check packoffs. 3/92019 3/9/2019 2.30 PROD1 DRILL TRIP P Trip in BHA# 17 to drill build / tum 72.2 8,005.0 09:54 12:12 section rolling CT to mud system #1 3/9/2019 3/9/2019 0.10 PROD1 DRILL DLOG P Log Kt for -5.5' 8,005.0 8,033.0 12:12 12:18 3/9/2019 3/9/2019 0.70 PROD1 DRILL TRIP P Continue trip in. Complete fluid swap 8,033.0 8,124.0 12:18 13:00 Clean pass through window, Tag up and drill ahead @ 8124 3/9/2019 3/9/2019 3.10 PRODt DRILL DRLG P 8124', Drill, 1.8 BPM @ 4691 PSI FS, 8,124.0 8,259.0 13:00 16:06 BHP=3771, RIW=9.1K, DHWOB=I.5K 3/9/2019 319/2019 0.10 PROD1 DRILL WPRT P 8259, BHA Wiper, PUW=28K 8,259.0 8,259.0 16:06 16:12 3/9/2019 3/92019 1.80 PROD1 DRILL DRLG P 8259', Drill, 1.9 BPM @ 4874 PSI FS, 8,259.0 8,403.0 16:12 18:00 BHP=3940 3/92019 319/2019 1.00 PROD? DRILL WPRT T PUW = 29K, allow DD to grab survey. 8,403.0 8,080.0 18:00 19:00 Discover boll walked out on pillow - block, pull into cased hole to install, dragging -4K WOB through 8370' 319/2019 3/9/2019 0.50 PROD1 DRILL DLOG P Log K1 for +4.5' correction, log RA at 8,080.0 8,140.0 19:00 19:30 1 8102' 3/9/2019 3/92019 0.20 PROW DRILL WPRT P RIH to drill, 2.3K WOB spike at 8263', 8,140.0 8,403.0 19:30 19:42 RIW = 8.3K 3/9/2019 3/9/2019 0.30 PROD1 DRILL DRLG P Drilling, FS = 600 psi, CWT = 6.6K, 8,403.0 8,450.0 19:42 20:00 WOB = 2.2K, bhp = 3980 psi, pump = 5078 psi, WHIP = 522 psi (12.7 ppg @ window), pump 5x5 sweeps 3/9/2019 3/9/2019 1.70 PROD1 DRILL TRIP P POOH, PUW = 26K, clean through 8,450.0 72.0 20:00 21:42 build & window, open EDC, tag up, PJSM 3/9/2019 3/9/2019 1.30 PROD1 DRILL PULD P PUD BHA#17, once cart slid back, 72.0 0.0 21:42 23:00 lock -out storage reel, check and tighten hub & saddle clamp bolts, blow -down MM, bit came out 1-1, ballet & 1 plugged nozzle 3/9/2019 3/10/2019 1.00 PROD1 DRILL PULD P Begin PD BHA#18 "A" Lateral 0.0 78.0 23:00 00:00 Assembly (NOV Agitator, 0.5" AKO motor, RB HYC A3 bit), lock -out injector, roll chains, check/inspect gripper blocks Note: Welli-ink moved forward 1 hr for DLS time prior to RIH (@ -23:00 hrs) 3/10/2019 3/1012019 0.40 PROD1 DRILL PULD P Complete PD BHA#18, slid in cart, 78.0 78.0 00:00 00:24 check pack -offs, MU to coil, set counters 3/102019 3/10/2019 1.50 PROD1 DRILL TRIP P RIH w/ BHA #18 78.0 8,015.0 00:24 01:54 3/10/2019 3/10/2019 1.20 PROD1 DRILL DLOG P Log K1 for -5' correction, close EDC, 8,015.0 8,047.0 01:54 03:06 PUW = 28K (Note: Added 1 hour in this cell to account for daylight saving time) 3/102019 3/10/2019 0.30 PROD1 DRILL TRIP P Continue RIH, RIW = 9.5K, captured 8,047.0 8,450.0 03:06 03:24 1 agitator transducer screens Page 13119 ReportPrinted: 3119/2019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log seen Depth Sean Tme End Time Dur (hr) Phase OP Code Activity Code Time P -T -X Operatmn (tIKB) End Deplh(fiKB) 3/10/2019 3/10/2019 1.60 PROD1 DRILL DRLG P Drilling, FS = 940 psi @ 1.85 bpm, 8,450.0 8,663.0 03:24 05:00 CWT = 7K, WOB = 1.7K, annular = 4006 psi, WHP = 595 psi, pump = 5382 psi, dip = 1347 psi, 1 for 1 returns, by-pass MM & blow -down again, -1/2"shate pieces from MM blow down 3/10/2019 3/10/2019 1.80 PROD1 DRILL DRLG P Drilling, CWT = 3.9K, WOB = 2K, 8,663.0 8,900.0 05:00 06:48 annular = 4069 psi, pump 5505 psi, WHP = 496 psi, PUW = 28K from 8686' 3/10/2019 3/10/2019 0.60 PROD1 DRILL WPRT P 8900', Wiper trip, PUW=29K 8,900.0 8,900.0 06:48 07:24 3/10/2019 3/10/2019 2.60 PROD1 DRILL DRLG P 8900', Drill, 1.9 BPM @ 5254 PSI FS, 8,900.0 9,172.0 07:24 10:00 BHP=4014 3/10/2019 3/10/2019 0.10 PROD1 DRILL WPRT P 9172', BHA wiper, PUW=31K 9,172.0 9,172.0 10:00 10:06 3/10/2019 311012019 0.60 PROD1 DRILL DRLG P 9172', Drill, 1.9 BPM @ 5229 PSI FS, 9,172.0 9,300.0 10:06 10:42 BHP=4061 3/10/2019 311012019 1.00 PROD1 DRILL WPRT P 9300', Wiper to jet 7" and tie in, With 9,300.0 8,015.0 10:42 11:42 sweeps off bottom and another set in 7', PUW=30K 3/10/2019 311012019 0.10 PRODt DRILL DLOG P Log Tie in for+.5' 8,015.0 8,042.0 11:42 11:48 3/10/2019 3/10/2019 0.60 PROD1 DRILL WPRT P Continue in well. Set down in build 8,042.0 9,300.0 11:48 12:24 -8124'. Work pipe, reduce rate momentarily to pass. Continue in 3/10/2019 3/10/2019 0.50 PROD1 DRILL DRLG P 9300', Drill, 1.9 BPM @ 5240 PSI FS, 9,300.0 9,380.0 12:24 12:54 BHP=4107, RIW=3.2K, DHWOB=.8K 3/10/2019 3/10/2019 4.80 PROD1 DRILL DRLG P 9380', Started encountering Ankorite 9,380.0 9,705.0 12:54 17:42 stringers. ROP 200 FPH to 15' FPH back and forth. Better after 9540', drilled to called TD of 9705' 3/10/2019 3/10/2019 3.90 PRODt DRILL WPRT P Pump sweeps, wiper to 7550' (500' 9,705.0 78.0 17:42 21:36 into 3-1/2"), RBIH to ECB, pump sweeps, pull into 7" & circulate bottoms up, complete wiper to swab 3/10/2019 3110/2019 1.50 PROD1 DRILL WPRT P RBIH 78.0 8,015.0 21:36 23:06 3/10/2019 3110/2019 0.10 PRODt DRILL DLOG P Log K1 for -3' correction 8,015.0 8,037.0 23:06 23:12 3/10/2019 3/10/2019 0.10 PROD1 DRILL TRIP P Continue RIH 8,037.0 8,085.0 23:12 23:18 3/10/2019 3/11/2019 0.70 PRODt DRILL DLOG P SBHP: Depth_bit = 8085', 8,085.0 8,085.0 23:18 00:00 TVD sensor= 5893.3', annular= 4003, EMW = 13.075 ppg Attempt bleeding down 3 times, well climbs to -13.08 ppg each time Confer with town, drop to 12.7 ppg (3909 psi on annular), well climbs back to 13.13 ppg overtime 3/11/2019 3/11/2019 1.50 PRODt DRILL CIRC T Confer w/ town, begin circulating, 8,085.0 8,085.0 00:00 01:30 working KWF plan forward, working to find avalability of Micronized Barite & ammounts required for current lateral (mix recipe) 3/11/2019 3/11/2019 5.20 PROD1 DRILL CIRC T Identify Micronized Barite available in 8,085.0 8,085.0 01:30 06:42 Alpine, begin hat-shotting from Alpine to MI plant, offload 12.8 ppg K - Formate from rig in clean truck to MI plant to be weighted up to 13.35 ppg, continue circulating at window Page 14119 Report Printed: 311912019 . Operations Summary (with Timelog Depths) 2G-O6 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S'(Depth StaM1Time Ertl Time Our (hr) PhaseOp Code Activity Code Time P-T-X Operation h ftKB) End Depth(ftKe) 3/11/2019 3/11/2019 0.70 PROM DRILL CIRC T Shut down pump. Monitir well, 13.1 8,085.0 8,085.0 06:42 07:24 PPG EMW 3/11/2019 3/11/2019 7.00 PROD1 DRILL CIRC T Continue to circulate waiting on KWF 8,085.0 8,015.0 07:24 14:24 3/11/2019 3/11/2019 0.40 PROD? DRILL DLOG P Log K1 for no correction 8,015.0 8,040.0 14:24 14:48 3/11/2019 3111/2019 1.10 PRODI DRILL TRIP P Trip in hole to condition hole, Get to 8,040.0 9,400.0 14:48 15:54 9408. Circulate 13.1 PPG Beaded liner running pill down CT. No setdowns or stacking. Hole in very good codition 3/11/2019 3/11/2019 0.70 PROM DRILL TRIP P 13.1 beaded liner pill at bit. PUH 9,400.0 7,867.0 15:54 16:36 1 pumping pill 3/11/2019 3/11/2019 1.00 PROD1 DRILL TRIP P RBIH to pump 13.3 WARP 7,867.0 8,450.0 16:36 17:36 3/11/2019 3/11/2019 1.70 PROD1 DRILL TRIP P Trip out pumping 13.3 K-Formate 8,450.0 65.0 17:36 19:18 W/micronized barite, Paint EDP flags 8304, & 6900 3/11/2019 3/11/2019 1.30 PROM DRILL PULD P At surfae, Flow check well- Static. 65.0 0.0 19:18 20:36 Unstab injector. Lay down Drilling BHA #18, bit came out 1-2 & balled up 3/11/2019 311112019 0.90 COMPZI CASING RURD P Rig up floor to run liner, PJSM to run 0.0 0.0 20:36 21:30 liner 3/11/2019 3/11/2019 1.70 COMPZI CASING PUTB P M/U BHA#19 A lateral completion with 0.0 1,061.0 21:30 23:12 non ported bullnose, 36 As slotted liner, and shorty deployment sleeve 3/11/2019 3/12/2019 0.80 COMM CASING PULD P PJSM, P/U coiltrak and M/U to 1,061.0 1,061.0 23:12 00:00 completion 3/1212019 3112/2019 0.70 COMPZI CASING PULD P Complete PU liner running tools BHA 1,061.0 1,061.0 00:00 00:42 #19 3/12/2019 3/12/2019 2.20 COMPZI CASING RUNL P RIH W BHA#19, -3.9' correction to 1,061.0 9,414.0 00:42 02:54 window flag, PUW = 30K, continue RIH to 9414', PUW = 35K, RBIH, PU slack, bring up pumps, release off liner, PUW = 29K 3/12/2019 3/1212019 3.10 COMM CASING DISP P Displace well to drilling fluid, pumping 9,414.0 8,088.0 02:54 06:00 fluid to the bit at 0.25 bpm, 14.5 ppg at window 3/12/2019 3112/2019 2.30 COMPZI CASING TRIP P With drilling fluid at bit, begin 8,808.0 45.0 06:00 08:18 1 1 increasing rate, POOH 3/12/2019 3/12/2019 1.00 COMPZI CASING PULD P PUD BHA #19, WHP = 1400 psi 45.0 0.0 08:18 09:18 3/12/2019 3/12/2019 1.10 COMPZI CASING PULD P PD BHA#20 Liner Run #2 (Anchored 0.0 -72-0- 2009:18 09:18 10:24 Billet), slide in cart, check pack-offs, MU to coil, tag up, set counters 3/12/2019 3112/2019 1.90 COMPZI CASING RUNL P RIH w/BHA #20 72.0 8,010.0 10:24 12:18 3/1212019 3/12/2019 0.20 COMPZI CASING DLOG P Log K1 for -5.5' correction 8,010.0 8,046.0 12:18 12:30 3/122019 3/12/2019 0.50 COMPZI CASING RUNL P PUW = 24K, close EDC, continue RIH 8,046.0 8,052.0 12:30 13:00 W BHA#20, setdown 2K at 8102 twice (possible setting down on slips in bottom of window), orient 90' ROHS, again set down, PU & orient to 180°, get through. Arrive at set depth, PU slack, bring on pumps, shear off at 4900 psi, set down 4K, TOB -8340' 3/12/2019 3/12/2019 1.70 COMPZI CASING TRIP P . POOH, PJSM 8,052.0 78.0 13:00 14:42 Page 151119 Report Printed: 3/19/2019 „ Operations Summary (with Timelog Depths) 2G-06 VW Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth SW Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operaeon (W) End Mph^B) 3/12/2019 3112/2019 1.00 COMPZI CASING PULD P PUD BHA#20 72.0 0.0 14:42 15:42 3/12/2019 3112/2019 1.10 PRODS STK PULD P PD BHA#21 AL2 KO/Tum Assembly 0.0 78.0 15:42 16:48 (2.3` AKO motor, RB Hughes bit) 3/12/2019 3/12/2019 1.30 PROD3 STK TRIP P RIH w/BHA #21 78.0 8,005.0 16:48 18:06 3/12/2019 3/12/2019 0.20 PRODS STK DLOG P Tie into the K1 for a -5.5' correction. 8,005.0 8,035.0 18:06 18:18 3/12/2019 3/12/2019 0.20 PRODS STK TRIP P Close EDC 8,035.0 8,339.6 18:18 18:30 PU wt 25 k lbs, pass through the window, clean. Tag TOB - 8339.6'- WOB 2.4k 3/12/2019 3/12/2019 1.00 PRODS STK KOST P PU Wt 28 k lbs, Set rate and RBIH 8,339.6 8,340.5 18:30 19:30 CT 4913 psi, @ 1.83 bpm in, 1.83 bpm out, diff 614 psi. WH 660 psi, IA 30 psi, OA 358 psi, BHP 4073 psi holding 13.0 ppg EMW @ the window CT RIH Wt 9 k lbs, see motor work 8338.9' engage auto drill, WOB fell off to neg, bummed it up to see a little motor work and WOB, re-engaged auto drill at 1'ft per hr. 3/1212019 3/12/2019 0.50 PRODS STK KOST P Increase to 2 ft(hr. 8,340.5 8,341.5 19:30 20:00 CT Wt 8.3 k lbs, WOB 0.06 k lbs. 3/12/2019 3/12/2019 0.25 PROD3 STK KOST P Increase to 3 fUhr. 8,341.5 8,342.5 20:00 20:15 CT Wt 8.3 k lbs, WOB 0.06 k lbs. 3/12/2019 3/12/2019 1.35 PRODS DRILL DRLG P Drill ahead up to 230 ft/hr, 8,342.5 8,464.0 20:15 21:36 Gamma Spike to 91 API, @ 8410'. Drilling dropped from 200 ft(hr to 100 - ft/hr over area then jumped back up. Resistivity pinched in as well. 8460' sudden drop in ROP to 8 ft/hr, resistivity suggests ankerite 3/12/2019 3/12/2019 0.20 PROD3 DRILL WPRT P PU Wt 28k lbs, 8,464.0 8,322.0 21:36 21:48 Saw neg WOB to -1.2 k lbs, pulling up past 8410' Billet clean 3/12/2019 3112/2019 0.10 PRODS DRILL WPRT P RBIH, Billet dry drift clean 8,322.0 8,464.0 21:48 21:54 Saw WOB spike to 1.5 k Ib @ 8410' 3/12/2019 3/12/2019 0.50 PRODS DRILL DRLG P CT 4731 psi @ 1.83 bpm in and 1.83 8,464.0 8,502.0 21:54 22:24 bpm out, diff 646 psi. WH 672 psi, IA 229 OA400 psi, BHP 4116 psi holding 13 ppg EMW at the window. WOB 2.4 k CT 4.8 k lbs, ROP 13 ft/hr 8,468' break out ROP up to 200 + ft/hr 3/1212019 3/1212019 1.30 PRODS DRILL DRLG P 8502', WOB stacked out, motor work 8,502.0 8,737.0 22:24 23:42 went away, PU 33k lbs - 8 k Itis over. Losses of 0.3 bpm. RBIH, tried to restart, had to PU again, 33k lbs, Ct Wt. RBIH, New mud at the bit Q 8,528', surface 8620'- 23:05 3/1212019 3/13/2019 0.30 PRODS DRILL DRLG P PU, 35 k lbs, - 1 00'wipe, RBIH, 8,737.0 8,766.6- 23:42 00:00 1 1 Drill ahead to midnight depth of 8766' 3/13/2019 3/13/2019 1.90 PRODS DRILL TRIP P PU, 28 k lbs, billet and window cleen. 8,766.0 66.0 00:00 01:54 1 1 I Open EDC, continue OOH. 3/13/2019 3/13/2019 1.30 PRODS DRILL PULD P Bump up, space out, PUD BHA # 21 66.0 0.0 01:54 03:12 1 3/13/2019 3/1312019 0.40 PRODS DRILL BOPE P Vac down stack, Perform BOP 0.0 0.0 03:12 03:36 1 I function test - good Page 16119 ReportPrinted: 311912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SMTIM End Tme Dur(hr) Phase Op Code Atrivity Coca Time P-T-X Operation Sten Depth (flKB) End Depth (f KB) 3/13/2019 3/13/2019 1.30 PROD3 DRILL PULD P PD BHA# 22, check pack offs - good. 0.0 66.0 03:36 04:54 Bump up, set counters 3/13/2019 3/13/2019 1.50 PRODS DRILL TRIP P RIH, close EDC, shallow test agitator. 66.0 8,010.0 04:54 06:24 3113/2019 3/13/2019 0.10 PRODS DRILL DLOG P Log Kt for -5' correction, PUW = 25K 8,010.0 8,042.0 06:24 06:30 3/13/2019 3/13/2019 0.50 PR0D3 DRILL TRIP P Coninue RIH, see weight at 8153', 8,042.0 8,766.0 06:30 07:00 1 1 continue through, RIW = IOK 3/13/2019 3/13/2019 0.50 PR0D3 DRILL DRLG P Drilling FS = 1200 psi @ 1.9 bpm, 8,766.0 8,783.0 07:00 07:30 CWT =7.5K, WOB =1K, annular= 4113 psi, pump = 5444 psi, WHP = 691 psi, diff less than FS, PUW = 25K, grab new parameters 3/13/2019 3/13/2019 2.00 PROD3 DRILL DRLG P Drilling FS = 1048 psi @ 1.9 bpm, 8,783.0 9,166.0 07:30 09:30 CWT= 5.5K, WOB = 1K, annular= 4142 psi, WHP = 718 psi, pump = 5300 psi, pump sweeps 3/13/2019 3/1312019 0.30 PRODS DRILL WPRT P Wiper up-hole, PUW = 28K 9,166.0 8,375.0 09:30 09:48 3/13/2019 3/13/2019 0.30 PRODS DRILL WPRT P RBIH, RIW = 8K 8,375.0 9,166.0 09:48 10:06 3/13/2019 3/1312019 2.30 PROD3 DRILL DRLG P Drilling, FS = 1060 psi @ 1.9 bpm, 9,166.0 9,566.0 10:06 12:24 CWT = 4.8K, WOB = 1.5K, annular = 4169 psi, WHP = 723 psi, pump = 5466 psi, drilling w/ negative CWT shortly after wiper, pump sweeps Drop ECD at window to 12.9 ppg (rate in = 1.9 bpm, rate out = 1.96 bpm), unble to maintain 1-for-1 returns, pinch back into 13.0 ppg 3/13/2019 3/13/2019 1.00 PRODS DRILL WPRT P Wiper to 7" casing, PUW = 27K, pump 9,566.0 8,010.0 12:24 13:24 additional sweeps time for EOB, (faulty pressure readings from DPS at -8280), dean past fault, slight negative pull through window 3/132019 3/13/2019 0.10 PRODS DRILL DLOG P log K1 for +1'correction 8,010.0 8,036.0 13:24 13:30 3/13/2019 3/13/2019 0.50 PRODS DRILL WPRT P RBIH, clean through window, stacked 8,036.0 9,566.0 13:30 14:00 5.5K weight at 8223', PU, dean through, clean past billet, clean past fault at 8764', RIW = 5.3K 3/132019 3/13/2019 2.50 PRODS DRILL DRLG P Drilling, FS = 1060 psi @ 1.88 bpm, 9,566.0 9,894.0 14:00 16:30 CWT = 5K, WOB = 1.5K, annular= 4183 psi, WHP= 577 psi, pump = 5393 psi, losing -0.03 bpm, ran into low ROP beginning at 9611', breakout by 9644' 3/13/2019 3/132019 1.10 PRODS DRILL DRLG P Drilling, CWT=-6.4K, WOB =1.6K, 9,894.0 10,009.0 16:30 17:36 annular= 4213 psi, WHP = 559 psi, pump = 5521 psi, PUW = 30K from 9914' Pump 10x 10 sweeps in anticipation of TO 3/13/2019 3/13/2019 0.60 PRODS DRILL WPRT P Discussion of extending TD, PU W130 10,009.0 9,012.0 17:36 18:12 1 k lbs, pull wiper trip while deciding path forward, to drill or TD. 3/13/2019 3/132019 0.80 1 PRODS DRILL WPRT P RBIH to drill 9,012.0 10,009.0 18:12 19:00 Page 17119 Report Printed: 3/1912019 . Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Lop StartTme EM nd rime our(hr) Phase op Cade Activity Code Time P -T -X OAeration De pth n 5tartoi) EM oepN (fixe) 3/13/2019 3/13/2019 4.10 PRODS DRILL DRLG P CT 5012 psi @ 1.83 bm in and 1.83 10,009.0 10,260.0 19:00 23:06 bpm out. Diff 911 psi. Drilling, CWT = 0 to -4 K, WOB = 1 K, annular = 4219 psi, WHIP = 586 psi Drill ahead with diminishing resistivity until Geo's railed TD @10260. 3/13/2019 3/14/2019 0.90 PRODS DRILL WPRT P PU Wt 35 k Ibs, PUH chasing 10 x 10 10,260.0 8,368.0 23:06 00:00 TO sweeps up hole. 3/14/2019 3114/2019 0.30 PRODS DRILL WPRT P PU Wt 35 k Ibs, PUH chasing 10 x 10 8,368.0 7,554.0 00:00 00:18 TD sweeps up hole. 3/14/2019 3/14/2019 0.50 PRODS DRILL WPRT P RBIH to EOB staging 10 x 10 sweep 7,554.0 8,840.0 00:18 00:48 to the bit. 3/14/2019 3/14/2019 1.00 PRODS DRILL WPRT P PUH chasing sweeps, Pull though 8,840.0 8,085.0 00:48 01:48 billet and window clean. Once in casing pump a bottoms up. 3/14/2019 3/14/2019 0.30 PRODS DRILL WPRT P Park @ 8085.05, 5893.5 TVD, trap 8,085.0 8,085.0 01:48 02:06 4037 psi - pressure slowly falling, bleed to 3992 psi observe pressure stabalize @ 3987 psi, bleed to 3960 psi, pressure increased and stabilized 2 3983 psi -13.00 ppg 3114/2019 3/1412019 1.40 PRODS DRILL WPRT P Continue out of hole on swab wiper. 8,085.0 67.0 02:06 03:30 3/14/2019 3/14/2019 1.50 PRODS DRILL TRIP P Bump up, set counters, RBIH 67.0 8,005.0 03:30 05:00 3/14/2019 3114/2019 0.20 PRODS DRILL DLOG P Tie int the K1 for -5.5' correction, by 8,005.0 8,037.0 05:00 05:12 pass HP screens. 3/14/2019 3/14/2019 0.20 PRODS DRILL DLOG P RIH and park @ 8084.99' CTMD / 8,037.0 8,076.0 05:12 05:24 589345' TVD. Trap 4007 psi - bleed to 3989 psi and observed pressure stabilize at 3989 psi- 13.0 ppg PU Wt 25 k lbs 3/14/2019 3/1412019 1.00 PRODS DRILL TRIP P RIH, confirm TO @ 10,261', PUW = 8,076.0 10,261.0 05:24 06:24 28K 3114/2019 3/14/2019 2.90 PRODS DRILL DISP P Lay in15 bbl LRP (build from drilling 10,261.0 8,370.0 06:24 09:18 fluid, followed by 5 bbl of 13.1 ppg K - Formats spacer), followed by 13.35 ppg WARP to surface, flow check 3/14/2019 3/14/2019 1.20 PRODS DRILL DISP P LD BHA#22, PJSM, check pipe for flat 8,370.0 0.0 09:18 10:30 -spots (good) 3/14/2019 3114/2019 3.70 COMPZ3 CASING PUTS P PU Liner (NP bullnose, 67 jnts slotted, 0.0 2,245.0 10:30 14:12 8 jnts blank, pup, & sealbore deployment sleeve), loss rate minimal 3/14/2019 3114/2019 0.60 COMPZ3 CASING PULD P PU liner running tools BHA#23, slide 2,245.0 2,305.0 14:12 14:48 in cart, MU to coil, tag up, set counters 3/14/2019 3/14/2019 3.20 COMPZ3 CASING RUNL P RIH w/ BHA#23, slowdown to reduce 2,305.0 9,370.0 14:48 18:00 losses (-.2 bpm @ 60 fpm), -4.9' correction to window flag, PUW = 30K, RIH, stack weight at 9618, PUW = 40K, work pipe at -9618', dragging negative WOB, stack at 9606', PUH heavy, losing hole, continue dragging heavy, sete down 9533', continue to work pipe, 3/14/2019 3/14/2019 1.00 COMPZ3 CASING RUNL T Continue to work completion to 9,370.0 9,528.0 18:00 19:00 bottom. Snubbing up to -12 k lbs, PU Wts 48-50 k lbs, Neg WOB up to -23k lbs, was -10 k lbs in open hole. Picking up from 9513' PU Wt 60 k Ibs, 20 k lbs over normal pick up. 3/14/2019 3/14/2019 1.00 COMPZ3 CASING WAIT T Discuss plan forward with engineering 9,528.0 9,503.0 19:00 20:00 support. Page 18119 Report Printed: 311912019 Operations Summary (with Timelog Depths) 2G-06 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan DepN Stan Tme End-rim Dur(N) Mn Op Code Pttivdy Code Tme P.T-X Opareuon (8Ka) End Depin(WE) 3/14/2019 3/14/2019 2.00 COMPZ3 CASING PULL T POOH with AL2 liner and running 9,503.0 2,293.0 20:00 22:00 assembly, repaint white window flag @ 8003.54' Pumped 26 bbls KW to replace pipe voidage - 26 bbl of WARP remaining in pits. 3/14/2019 3/14/2019 0.70 COMPZ3 CASING PULL T LD AL2 liner running assembly-BHA 9,503.0 2,293.0 22:00 22:42 #23 3/14/2019 3/15/2019 1.30 COMPZ3 CASING PULL T LD 8 solid joints and 8 slotted joints 2,293.0 1,767.0 22:42 00:00 1 1 1 fill hole - 1 bbl 3115/2019 3/15/2019 1.00 COMPZ3 CASING RUNL T LD 20 slotted joints, Fill hole 1 bbl 1,767.0 1,150.0 00:00 01:00 3/15/2019 3/15/2019 0.40 COMPZ3 CASING PUTS T PU 8 solid joints 1,150.0 1,402.0 01:00 01:24 3/15/2019 3/15/2019 0.80 COMPZ3 CASING PULD T BHA#23, AL@ liner running assembly 1,150.0 1,447.0 01:24 02:12 - second attempt. 3/15/2019 3/15/2019 1.50 COMPZ3 CASING RUNL T RIH with AL2 completion, 85 ft/min 1,447.0 7,159.0 02:12 03:42 running speed with minimal losses, 0.07 bpm. Tie into the window flag for 6.78' correction. 3/15/2019 3/15/2019 1.20 COMPZ3 CASING RUNL T Continue to RIH, PU Wt 28 k lbs, 7,159.0 9,402.8 03:42 04:54 WOB -9.5 k lbs, RIH, drive by yellow TO flag for+3' correction. PU Wt 32 k lbs, unable to RBIH, PU wt 40 k lbs, RBIH to 9402'. Pump 1.34 bpm, CT 5608 psi, diff 1034 psi, PU Wt 23 k lbs, 3/15/2019 3115/2019 2.40 COMM CASING DISP P Park, reset counters, displace well 9,402.8 2,500.0 04:54 07:18 bore to seawater 3/15/2019 3/15/2019 1.80 COMPZ3 CASING FRZP P PJSM, freeze protect from-2500'to 2,500.0 50.0 07:18 09:06 surface 3/15/2019 3/15/2019 1.00 COMPZ3 CASING PULD P PUD BHA #24 (SITP = 1481 psi) 50.0 0.0 09:06 10:06 3/15/2019 3/15/2019 0.90 DEMOB WHDBOP CIRC P M/U nozzle stab on injector and flush 0.0 0.0 10:06 11:00 ROPE and rig surface lines 3/15/2019 3/15/2019 1.00 DEMOB WHDBOP RURD P Break off injector, vac stack, freeze 0.0 0.0 11:00 12:00 protect tree, secure injector, begin RD checklist 3/15/2019 3/15/2019 3.00 DEMOB WHOBOP NUND P Continue RD check list, off-load fluids 0.0 0.0 12:00 15:00 from rig, swap out Tango valves, NO BOP NES trucks arrive at 1400 hrs (to move shop & 1/2-way house ahead of rig) " Rig Release: 3/15 @ 1500 hrs Page 19119 Report Printed: 3/19/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2G Pad 2G -06A 60-029-21121-01 Baker Hughes INTEQ Definitive Survey Report 10 April, 2019 BA ER F�UGHES GEcompany 61gIK#ES Well 2G-06 ConocoPhillips (_OnoCOPhillips Oefinitive Survey Report Comping CanowPMllps Alaska lnc Kupamk Lool Cnoreinate Reference: We02GA6 Project: Kupamk River Unit TVG Reference: 2G-06@ 140.00us8(2G-0B) Shv: Kopeisk 2G Pad MO Reference: 2G06@ 140.00usfl(20-06) Well: 26-06 North Reference: True Wellbmc 2CrO6A Survey Glculation Method; Minimum Curvature Design: 2G06A Database: EDT 14 Alaska Production protect Kupamk River Unit North Slope Alaska, United Shales 0.00 usfl Wellbore Map System: US State Plane 1927 (Exact solution) System outum: Mean Sea Level Gem Damm: NAD 1927 (NAOCON CONUS) Using Well Reference Point Map Zone: Alaska Zeno 04 Usity geockme style factor 61gIK#ES Well 2G-06 .-_... _. Well Position INIS 0.00 usg Northing: 5, 944, 13531 ush Lztitude: 70°15'30.911N +EI -W 0.00 usfl Easting: 508,929.90us8 L ,lip tle: 149° 55' 40.165 W Position Uncertainty 400 usfl Wellhead Elevation: vab Ground Level: 0.00 usfl Wellbore 2G -06A Magnetics Madel Name Sample Doh Daelnatbn DipAngle Field semnglki (9 19 0111 BGGM2018 4112019 16.57 80.80 57,411 Design 2G46A Autlli Nates: Version'. 19 Phase. ACTUAL T..onD¢pthl 6,000.00 vertiol Semon: Depth From(TVD) eW5 4E1'W DlRagan (.an) (ush) (ase) (I 140.0D 0.60 400 0 0u Survey Program Dak Survry Survey From (use) To (ese) sus,(Wegboh) Taal Mama Description slut Date End West 200.00 8,00000 2G-06(26-06) SEEKER MS BHI Seeker mullishat 11122001 8,09500 8,212.60 2G-06AMWD4NC(2G-WA) MWD-ING_ONLY MWD -INC _ONLY FILLER M12019 319/2019 8,24271 9,671.07 2C.OBA MWD(2G416A) MWD MWD Standard 3/102019 VIW2019 Patter COMPASS 5000.14 BMM 850 4 OdVlll 8:2502AAf ConocoPhillips spm__ O GowcoPhillips Defingive Survey Report '�'`''`' ! Company. Conecolahillps Alaska Inc Kupamk Local DeaNhmte Rehtence: Mll2G-06 Project: Kupamk River Unit TVD Reference: 2&06@140.00usn(2G46) Sgt: Kupamk 20 Pad MD Reference: 2&06 @ 140.0usn (2GA6) Mile 2G-06 North Reference: True 1Wellbttc 20,06A Survey Calcalation Method Minimum Curvature Oesigm 2&06A Database: EDT 14 Alaska ProducBon Surtai, Map Nap Vertical WD gm lul 11N 28155 +Nld +u.w Northing C OLS Section Survey Toot M. Annotation hmM M M (damp lea IMsN lusnl Int (ft) MI 1'71 W) pt) Seato0 39.17 48.95 6,865.16 5,85.16 322603 3.6M.30 5947,41601 51{54&03 Tw 3.276.03 MN0.1NC ONLY (2) TIP 0 ee-an 38.01 43.00 5.939.42 5,79342 3,315.70 3,880.10 5,942,45493 512,69320 122 3.315.711 Bn5'DA4C_DNLY(2) KOP %mita 44.08 39,24 5.96012 50M12 3,322829 3680.20 SM7.468.O:t 512,60636 33.39 3328.29 F INC_ONLY(2) Immpolated Aaloulh 8.16284 59.63 31.20 5,928.59 6838.59 3,340.21 3,691.54 .5942.482.42 512,AM10 53.02 334&21 M JIJC_ONLY (2) Interpolated Amondlo 8.10242 71M 25.31 5,92851 5,x65.51 3,321+92 3,202.35 5.942.511.23 512,63288 48.65 337192 M INC _ONLY (2) Inkryoleted Azimuth 11,21200 7351 ISM 5993.32 5,858.32 3.33ae1 3,718.49 5,90.538.09 513.643.65 12.0 3,398.01 M INC ONLYR) Intelpalaled Azimuth 8,28221 Met 14.80 6W A. 586749 3.4522 3]7.05 5,942,565.55 512.65251 1820 3426.22 MD x2878 25.01 M41 6.015,35 5p25.35 3,454.65 3.73587 590,593.5 512,661.30 17.65 345a.W MWD(3) SM61 76.52 5.87 60 se 688294 3,480.45 3,749.04 690.613.25 512874.4 4220 3,aoc. "D(3) 8,333.18 75.02 47.39 6,030.5 5.a5o5 350.15 \ 3268.115 590,65108 512.93.42 4059 3,5@.15 MWo(3) 536315 75.08 45.53 6,032.95 5,09]95 352210 3,289.04 5942,661,0 51271439 6.0 3.52210 MND(3) ,,330.55 26.18 3299 8,028.78 5,904.28 3,54263 3,805.79 5947,602.65 512231.10 44.85 3,54263 MWD(3) 0.419.0 Mid 840 entiox 5,91027 3,56&20 3,013.12 5,917.202.58 512,244.46 40.59 3,558.20 MND(3) 8.050.65 Bem 13,15 505215 5.912.15 3,592.16 3,020.55 5,947.708.65 51225380 5.90 3,592.18 MO (3) %aaTw 0.31 1027 6.051M 5,91'91 3.622.01 3,804.82 5.90,75SAO 512,760.03 10.46 3.62TO1 M6➢(3) 0,51052 91.63 7.62 6.51.41 5,911.41 3656.16 3,83928 5,947,295.55 512,26x.59 10.3 3&5616 MJvep3 11,540.51 91.60 AM 6.00.52 5,910.57 3,685.91 3,84252 5,942 ,85.30 512]62.81 9.0 3,089.91 wneop) ' 6521.83 b1.an 1.56 548.59 5,909.59 321&0 3,844+43 5,947,85635 54,269.53 10.24 3,216.98 MWD(3) 8,601.37 So= 359.74 6,048.28 590824 3,746.08 3844.22 5947.83605 5122179.84 2.44 3,246.65 "D(3) 6830.23 920 359.. 6,046.84 5,30664 3775.98 38x3.08 5,90,91535 512768.92 10.04 3,775.0 MD i8,660.42 93.76 354.32 8.044.03 5,904.89 300555 3841.59 5,942.944.9x 512266.59 &75 3.805.56 MD %600.21 94.58 351,70 8.0269 5,90269 3,,35.49 3832.94 5,90,974.7 5122620 8.28 3.835.49 MD (3) 0.8073 92.14 351.8 6,039.62 5.899.62 3,865.5 3,03365 59x6654.41 54,75859 0.53 3,955.05 MWD(3) 015259 seat 351.8 6,035.7 5,695.12 3,89628 31029.11 5948.035.2 54,754.01 Son 3,896.26 SND (3) 8,281.211 9675 35363 6,030.21 5.090.21 3,924.79 3,025.2 5,918..4.14 512.765.8 6.12 3924.79 IRWOD) 881075 0.6,1 354.86 ti,mm 5,886.82 3,95343 3.82251 5,948,092.8 512742.34 8.58 3.963.43 MND(3) 8.40.15 94.50 355.82 6023.34 54883.94 3.903.59 3,85]4 5,940,121.93 512,244,94 T.0 3,0259 MND(3) 92.65 355.64 602219 5,88219 4.01249 3,817.92 5,940,151.93 51224268 8.32 4.01249 MM (3) 8,900.7 L8.0%820.19 90.65 356.04 a021b5 5681.5 4,042.29 381&26 5946161.62 512,240.48 7.12 4,0425 MtND(3) 0.16 88.59 357.19 6,OMM 5,00202 4,0832 3,813.90 5.948.211,64 512238.67 6.05 4.07232 MIND (3) WSaPASS5000.14&x2805D 4I 19 9:25.O2pM Fag.3 ConocoPhillipsi3wEs ConocoPhIMPS Definitive Survey Report Compan, ConocoPhili Alaska lnc Kupamk Local CooNinale Rehrenee: Mil20-06 Project: Kupamk River Unit WO Reference: 2G06 III 140.00usR(2G-06) &Re: Kupamk 26 and MO Reference: 2G @140.00usR(2G-06) Well: 2Gm North Reference: True Wellbore: 2606A Survey Calculation National: Minimum CutvaWre Desl9n: 2C06A Oatabaoe: EDT 14 Alaska Proaluction Survey Map Map Venlcal MO Nle M TVO 11NSS +994 e MNorthingM1in9 Eastin9 OLS . Section Survey Tool Name AnnotaliOn wam i7 n (MM (USM (netq IU m) (R) 1100 ) 0,95031 159.. 359.02 1.&.02250 5,8152511 4,10245 3,812.90 5,940.X1.]! 51]]37.64 6.50 4,102.45 MWO(3) - B,Po0.2] BB.1] 0.52 6,02300 SAWS 9,132.40 481285 5,948,2]1.)2 512]3].48 5.30 4,1M.40 MW9(3) 9.020.19 06.M 359.99 6,024.30 5,884.30 4,16230 3,813.W 5,948.301.81 512737.50 160 4,18230 MWD(3) 9.061.n 04.0 357.71 6,428.61 5,%&62 4,18334 3,012Y 5.948.3]255 5127m,. 9." 4,193.24 MWD(3) 9.080,90 04.90 3%.27 6,M.25 5,809.25 4,22274 3,810.9 5946352.04 512.735.08 8.22 4.]1174 AV!)(3) 9,111.b No 353.35 5.02"M 5,691.0 4,252.90 3,807.56 5,940,39227 51273203 am 4,25290 MWD(3) 9.14105 85.95 350.89 6033.52 5,8%,52 4,20230 3,803.50 5840,421.59 5lZ7V.R 0.. 4,20230 MNO(3) 9,17219 ae. 347.05 6,035.71 5,895.71 4,31270 3.797.55 5,949,45205 512,721.95 1230 4,31270 MJ40(3) 9,2(223 0815 345% 6,037.E 5,087.22 4,341% 3,7.56 5,919,401E 512T140 8.32 4,341.96 IMO(3) 9.231M 8853 315% 6,03&04 5,09804 4,370." 3,783.35 5,948.599.69 512.701. 142 /,370.4 Nei 9.26228 89.66 313.87 6,03853 509653 4,400.01 3]75.30 5,946539.26 512,699.% 6.88 4,400.01 MVVDo) B,2a1% 09)0 3".89 6.99867 5.0%67 4,420.52 3767.33 5.948,557.3 512681.W 147 4.420.52 Move (3) 9,32.71 6B.m 347.15 6.39.07 5,899.07 44%A9 3,760.30 5948,595.71 512,604.60 8.76 4,455.49 MM (3) 9,3W.Q 59133 NNW 6,039.59 5899.59 /.485ea 3,7wa 5,946CH.3 51267839 6.16 4,405.56 MM (3) 9.38261 81219 351.39 BWO.H 5,9%.29 45925 3,746.05 5,946.658.45 51287283 8.65 4,51715 Me 9.409.55 89.02 353.1 6.040194 5,90.94 4,546.64 3,74&10 5.916683.13 512.641 B.I. 4,543.94 MND(3) ' 9,444.2 07.82 351.18 6,04189 5,90189 4,570.05 3.7Q.B 5,946,79.27 512.664.58 7.34 4,57808 MN➢(3) 9,47463 knew 35083 6,(42% 5,90265 4699,31 3,735.70 5,948747.46 512,659.3 5.16 4,638.31 MrYl)(3) ( 6504.51 ..59 347.99 6,04618 5,90110 4637.67 3,73021 &949.7".04 512.6W.N 805 4,07.57 Me 9,536.05 912 347.27 6,013E 5,9Pim 4,668.46 3.72.46 5,9481.7.61 512.647.45 &77 4,66646 Me (3) 6%5.61 910 348]3 6,d1. 5,901.89 4,89725 3,716.81 5,MB,82.M 51264077 9.11 4,69725 MD (3) 9,59859 93.17 3",to 6,03996 5699.05 4,7282 3,70tk,41 5.918,.5.% 51262.33 7.14 4,716.2 MWD I3) 9.625.35 I 9292 341.05 6.038.30 5,889.31 4,754.60 3,700.04 5,918093.80 512,824.2 9.51 4)54.68 WIND (3) 9,655.2 84.21 340.99 6,03645 5,8..45 4,782.0 3,691.34 5.Meaz05 512,815.2 5.19 4,3205 M63) 9,61,07 0.01 3W.52 6,0359 5,861,11 4,187.85 3,605,14 5,946936.95 512,",% 585 /.27,85 101 9,.505 95.01 3W.52 8,03221 5,89221 4,829.72 3,674.87 5.940,969.% _- 512.598.67 0. 4,829.72 PROEC7ED to TO Pape4 COMPAS55000./48v9tl 850 4/10!1018 9:25.021" BA ER PRINT DISTRIBUTION LIST I UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 2G -06A FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(�bakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. 60X) PERSON ATTENTION V I BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 Exxonklobil, Alaska .Ann: Lynda M. Vaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 219019 30606 se sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. i Osterkamp (WINS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE March 11, 2019 TODAYS DATE April 12, 2019 Revision Details: Rev. Requested by: --- FIELD I FINAL FINAL PRELIM ICD/DVD (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES j#QFGQPIFS # OF COPIES RECEIVED 4'.Sat to of Alaska -AOGCC 1 7 .Arlo: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, .Alasle 99501 51DNR-Division ofOil&Gas *** Ann: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** StamD "confidential" on all material deliver to DNR 6BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 BA ER BAT a GE company Date: April 12, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 21901 30 60 4 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 se find enclosed the directional survey data for the following well(s): 2G -06A 2G-OAL2 RECEIVED APR 15 2019 AOGCC (2) 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. Harvey Finch, Baker Hughes, Wellplanner Harvey. Finch PBakerHushes.com 30 30 604 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 2G Pad 2G -06A 50-029-21121-01 Baker Hughes INTEQ BAi�`UGHES a GE company Definitive Survey Report 10 April, 2019 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Project- Kupamk River Unit TVD Reference: Site: Kuparuk 2G Pad MD Reference: Well: 2G-06 North Reference: Wellbore: 2G -06A Survey Calculation Method: Design: 2G -06A Database: Project Kuparuk River Unit, North Slope Alaska, United States Longitude! Map System: US State Plane 1927 (Exact solution) System Datum: Can Datum: NAD 1927 (NADCON CONUS) Survey (Wellbore) Map Zone: Alaska Zone 04 57.411 Well 2G-06 2G -06A MWD -INC (2G -06A) Well Position -NI-S 0.00 usft Northing: 3/10/2019 +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 2G -00A Magnetics Model Name Sample Date BGGM2018 4/1/2019 Design 2G -06A Audit Notes: Well 2G-06 2G-06 @ 140.00usft (2G-06) 2G-06 @ 140.00usft (2G-06) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,944,135.21 usft 508,929.90usft usft Declination (°I 16.57 Bea Latitude: 70" 15'30.911 N t Longitude! 149° 55'40,165 W Ground Level: 0.00 usft i Dip Angle Field Strength Survey (Wellbore) 200.00 80.60 57.411 Version: 1.0 Phase: ACTUAL Tie On Depth: 8,000.00 Vertical Section: Depth From (TVD) +N/3 +E/ -W Direction (usft) (usft) (usft) (°) 140.00 0.00 0.00 0.00 Survey Program Date From To Description (usft) (usft) Survey (Wellbore) 200.00 8,000.00 2G-06 (2G-06) g t 8,095.00 8,212.80 2G -06A MWD -INC (2G -06A) 8,242.71 9,671.07 2G -06A MWD (2G -06A) 4/102019 9:25:02AM Page 2 COMPASS 5000.14 Build 850 Survey Burney Tool Name Description Start Date End Date SEEKER MS BHI Seeker multishot 1/12/2001 MWD-INC—ONLY MWD-INC—ONLY—FILLER 3/9/2019 3/9/2019 MWD MWD -Standard 3/10/2019 3/10/2019 4/102019 9:25:02AM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc Kuparuk Local Co-ordinate Reference: Well 2G-06 Project: Kuparuk River Unit TVD Reference: 2G-06 @ 140.00usft (2G-06) Site: Kuparuk 2G Pad MD Reference: 2G-06 @ 140.00usft (2G-06) Well: 2G-06 North Reference: True Wellbore: 2G -06A Survey Calculation Method: Minimum Curvature Design: 2G -06A Database: EDT 14 Alaska Production Survey BA ER F�1,GtwS Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 4/102019 9:25:02AM Page 3 COMPASS 5000.14 Build 85D Map Map vertical MD Inc Azi TVD TVDSS +N/-5 +E/ -W DLS (usft) V) V) (usft) (usft) (usft) (usft) Northing Easting (`/100'} Section Survey Tool Name Y (ft) (ft) (ft) 8,000.00 39.17 48.95 5,865.16 5,725.16 3,276.83 3,623.38 5,947,416.01 512,549.03 1.06 3276.83 MWD -INC _ONLY (2) 8,095.00 38.01 49.06 5,939.42 5,799.42 3,315.70 3,668.10 5,947454.93 512,593.70 1.22 3,315.70 MWD-INC_ONLY (2) 8,122.61 44.88 39.74 5,960.12 5,820.12 3,328.79 3,68078 5,947,468.03 512,606.36 33.39 3,32879 MWD -INC -ONLY (2) 8,152.84 59.63 31.70 5,978.59 5,838.59 3,348.21 3,694.54 5,947,48747 512,620.10 53.07 3,348.21 MWD -INC _ONLY (2) 8,182.42 72.79 25.31 5,990.51 5,850.51 3,371.97 3,707.35 5,947,51123 512,632.88 48.65 3,371.97 MWD -INC _ONLY (2) 8,212.80 73.51 19.75 5,999.32 5,859.32 3,398.81 3,71849 5,947,538.09 512,643.98 17.68 3,398.81 MWD -INC ONLY(2) 8,242.71 74.81 1490 6,007.49 5,867.49 3,426.27 3,72705 5,947,565.55 512,652.51 16.20 3,426.27 MWD (3) 8,272.86 75.01 20.41 6,015.35 5,875.35 3,454.00 3,73587 5,947,593.29 512,661.30 17.66 3,454.00 MM (3) 8,303.61 76.52 33.87 6,022.94 5,882.94 3,400.45 3,749.44 5,947,619.75 512,674.84 42.70 3,480.45 MWD(3) 8,333.18 75.07 47.39 6,030.23 5,890.23 3,502.15 3,768.05 5,947,64148 512,693.42 44.59 3,502.15 MWD(3) 8,363.15 75.08 45.53 6,037.95 5,897.95 3,522.10 3,789.04 5,947,661.45 512,71439 6.00 3,522.10 MWD (3) 8,390.56 76.18 32.89 6,044.78 5,904.78 3,542.63 3,805.79 5,947,68200 512,731.10 44.85 3,542.63 MWD (3) 8,419.99 82.36 2248 6,050.27 5,910.27 3,568.20 3,819.17 5,947,707.58 512,744.46 40.59 3,568.20 MWD (3) 8,450.55 90.58 13.45 6,052.15 5,912.15 3,597.16 3,828.55 5,947,73655 512,753.80 39.90 3,597.16 MWD (3) 8,481.05 90.31 10.27 6,051.91 5,911.91 3,627.01 3,834.82 5,947,766.40 512,760.03 10.46 3,627.01 MWD(3) 8,510.57 91.63 7.62 6,051.41 5,911.41 3,656.16 3,839.41 5,947,79555 512,764.59 10.03 3,656.16 MWD(3) 8,540.51 91.60 490 6,050.57 5,910.57 3,685.91 3,842.67 5,947,82530 512,767.81 9.08 3,685.91 MWD(3) 8,571.63 92.00 1.58 6,049.59 5,909.59 3,716.96 3,844.43 5,947,85635 512,769.53 10.74 3,716.96 MWD (3) 8,601.37 93.23 359.74 6,48.24 5,908.24 3,746.66 3,844.77 5,947,88605 512,769,84 7.44 3,74666 MWD(3) 8,630.73 92.98 356.80 6,046.64 5,90664 3,775.96 3,843.88 5,947,915.35 512,768.92 10.04 3,775.96 MWD(3) 8,66047 93.78 354.32 6,044.89 5,904.89 3,805.56 3,841.59 5,947,944.94 512,768.59 8.75 3,805.56 MWD(3) 8,690.71 94.58 351.78 6,04269 5,902.69 3,835.49 3,837.94 5,947,974.87 512,762.90 878 3,835.49 MWD(3) 8,720.73 97.14 351.72 6,039.62 5,899.62 3,865.05 3,833.65 5,948,04.41 512,758.59 8.53 3,86505 MWD(3) 8,752.59 98.91 35172 6,035.17 5,895.17 3,896.26 3,829.11 5,948,035.62 512,754.01 5.56 3,896.26 MWD(3) 8,781]0 98.75 353.53 6,03071 5,89071 3,924.79 3,825.42 5,948,84.14 512,750.28 6.17 3,924.79 MWD (3) 8,810.75 96.64 354.85 6,026.82 5,886.82 3,953.43 3,822.51 5,948,09277 512,747.34 8.56 3,95343 MWD (3) 8,840.15 94.58 355.87 6,023.94 5,883.94 3,982.59 3,820.14 5,948,12193 512,744.94 7.80 3,982.59 MWD (3) 8,870.19 9209. 355.64 6,022.19 5,882.19 4,012.49 3,817.92 5,948,151.83 512,74268 8.32 4,01249 VIM (3) 8,90007 90.00 356.04 6,02165 5,88165 4,042.29 3,815.76 5,948,181.62 512,740.48 7.12 4,042.29 MWD (3) 8,930.16 8859 357.19 6,022.02 5,882.02 4,07232 3,813.98 5.948211 64 512738.67 605 4,072.32 MWD(3) BA ER F�1,GtwS Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 4/102019 9:25:02AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips W"� p Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 2G-06 Project: Kuparuk River Unit TVD Reference: 2G-06 @ 140.00usft (2G-06) Site: Kuparuk 2G Pad MD Reference: 2G-06 @ 140.00usft (2G-06) Well: 2G-06 North Reference: True Wellbore: 2G -06A Survey Calculation Method: Minimum Curvature Design: 2G -06A Database: EDT 14 Alaska Production Survey Annotation 4/10/2019 9:25:02AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azl Tt/D TVDSS +N/ -S +EIW DLS (usft) (°) (°) (usft) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Name (ft) (ft) (ft) 8,960.31 89.29 359.02 6,022.58 5,882.58 4,102.45 3,812.98 5,948,241.77 512,737.64 6.50 4,102.45 MM (3) 8,990.27 88.77 0.52 6,023.08 5,883.08 4,132.40 3,812.86 5,948,271.72 512,737.48 5.30 4,132.40 MWD (3) 9,020.19 86.56 359.99 6,024.30 5,884.30 4,162.30 3,81300 5,948,301.61 512,737.58 7.60 4,162.30 MWD (3) 9,051.23 84.90 357.72 6,026.61 5,886.62 4,193.24 3,812.38 5,948,332.55 512,736.92 9.04 4,193.24 MWD (3) 9,080.90 84.90 35527 6,029.25 5,889.25 4,222.74 3,810.57 5,948,352.04 512,735.08 8.22 4,222.74 MWD (3) 9,111.38 86,4 353.35 6,031.55 5,891.55 4,252.98 3,807.56 5,948,39227 512,732.03 8.06 4,252.98 MWD (3) 9,141.05 85.95 35089 6,033.52 5,893.52 4,282.30 3,803.50 5,946421.59 512,727.94 8.44 4,282.30 MWD(3) 9,172.19 86.00 347.05 6,035.71 5,895.71 4,312.78 3,79756 5,946452.06 512,721.96 12.30 4,312.78 MWD (3) 9,202.23 88.25 345.96 6,037.22 5,897.22 4,341.96 3,79056 5,948,48122 512,714.93 8.32 4,391.96 MWD (3) 9,231.62 88.53 345.65 6,038.4 5,898.04 4,370.44 3,783.35 5,948,509.69 512,70769 1.42 4,37044 MWD(3) 9,262.28 89.66 343.87 6,038.53 5,898.53 4,400.01 3,775.30 5,948,539.26 512,699.60 6.88 4,400.01 MWD (3) 9,291.88 89.78 344.89 6,03867 5,89867 4,428.52 3,767.33 5,948,567.75 512,691.60 3.47 4,428.52 MWD (3) 9,320.71 88.65 347.15 6,039.07 5,89907 4,456.49 3,760.36 5,948,595.71 512,664.60 8.76 4,456.49 MWD (3) 9,350.43 89.33 348.85 6,039.59 5,899.59 4,485.56 3,764.18 5,948,624.76 512,678.39 6.16 4,485.56 MM (3) 9,382.61 88.19 351.39 6,04029 5,900.29 4,517.25 3,748.66 5,948,656.45 512,672.83 8.65 4,517.25 MWD (3) 9,409.55 89.2 353.41 6,040.94 5,900.94 4,543.94 3,745.10 5,948,683.13 512,669.24 8.10 4,543.94 MWO(3) 9,444.02 87.82 351.18 6,041.89 5,90189 4,578.08 3,740.48 5,948,717.27 512,664.58 7.34 4,578.08 MWO(3) 9,474.63 89.36 350.83 6,042.65 5,90265 4,608.31 3,735.70 5,948,747.48 512,659.76 5.16 4,608.31 MWD (3) 9,504.51 88.59 $47.99 6,043.18 5,903.18 4,637.67 3,730.21 5,948,776.84 512,654.24 9.85 4,637.67 MM (3) 9,536.03 91.26 347.27 6043.22 5,903.22 4,668.46 3,723.46 5,948,807,61 512,647.45 8.77 4,668.46 MWD (3) 9,56561 93.90 346.73 6,041.89 5,901.89 4,697.25 3,716.81 5,948,836.39 512,640.77 9.11 4,697.25 MWD (3) 9,595.59 93.47 344.63 6,039.96 5,899.96 4,726.23 3,709.41 5,948,865.36 512,633.33 7.14 4,726.23 MM (3) 9,625.35 92.92 341.85 6,038.30 5,898.31 4,75468 3,700.84 5,948,893.80 512,624.73 9.51 4,754.68 MWD(3) 9,655.23 94.21 340.99 6,036.45 5,896.45 4,782.95 3,691.34 5,948,922.05 512,615.20 5.19 4,782.95 MViD(3) 9,671.07 95.01 340.52 6,035.17 5,895.17 4,797.85 3,686.14 5,948,936.95 512,609.98 5.85 4,797.85 MWD(3) 9,705.00 95.01 340.52 6,032.21 5,892.21 4,829.72 3,674.87 5,948,96880 512,598.67 0.00 4,829.72 PROJECTED to TD Annotation 4/10/2019 9:25:02AM Page 4 COMPASS 5000.14 Build 85D Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, March 1, 2019 10:05 AM To: 'Herring, Keith E' Cc: Guhl, Meredith D (DOA); Boyer, David L (DOA); Kair, Michael N (DOA) Subject: RE: Issue with APIs for recent KRU 2G-06 wells Keith, I made a mistake when assigning API numbers to CPAI's planned KRU 2G -06A redrill and its laterals that must be corrected. Please accept my apology. To fix this as painlessly as possible: • For consistency with past practices, the API number for KRU 2G -06A must be changed from 50-029-21121-64-00 (wrong API) to 50-029-21121-01-00 (correct API) on all forms and in all databases. To minimize the paperwork chaos that could ensue for the remaining laterals (2G-06AL1, 2G-06AL2, and 2G- 06AL2-01), I propose leaving the API numbers that I assigned to those laterals unchanged and simply not assigning 50-029-21121-64-00 to any lateral. A copy of this email and an explanatory "Note to File" in CPAI's and AOGCC's well history files for 2G -06A and 2G-06AL1 will adequately explain to future users why API number 50-029-21121-64-00 was never assigned. • Please note that all assigned Permit to Drill numbers will remain unchanged. All production from laterals 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 must be reported against redrilled well KRU 2G -06A, API number 50-029-21121-01-00, Permit to Drill number 219-019. Please forward this email to anyone affected by this change, and please extend my apologies for this mistake. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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($). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC Is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesQalaska.gov. From: Guhl, Meredith D (DOA) Sent: Wednesday, February 27, 2019 2:54 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.gov> Subject: Issue with APIs for recent KRU 2G-06 wells Hi Steve and Dave, We've got an API number issue with recently permitted KRU 25-06 wells. AN WELL # I PTD # I Conf I MITPermit# I O er Name I Well Name I Status I Status DI 1121-00-00 1840820 1 No CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-06 1121-60-00 2181120 1 No CONOCOPHILLIPS ALASKA INC. KUPARUK RIV UNIT 2G-061-1 CONOCOPHILLIPS ALASKA, INC i KUPARUK RIV UNIT 2G-061-1-01 1121-61-00 2181130 No 1121-62-00 2181140 No _ CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-0611-02 1121-63-00 2181150 No CONOCOPHILLIPS ALASKA, INC. KUPARUK RIV UNIT 2G-061-1-03 CONOCOPHILLIPS ALASKA, INC. I KUPARUK RIV UNIT 2G-06AL1 LN_PN7 The highlighted well should have an API of 50-029-21121-01-00 as it is a sidetrack from the mainbore, and then the API needs to be adjusted for the laterals following. Unless we've changed our numbering conventions? Thanks, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.eov. 2 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Kai Starck CTD Director ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G -06A ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-019 Surface Location: 547' FSL, 236' FWL, SEC. 32, TI IN, R9E, UM Bottomhole Location: 5177' FNL, 1392' FEL, SEC. 29, TI IN, R9E, UM Dear Mr. Starck: Enclosed is the approved application for the permit to re -drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, oe7�� Daniel T. Seamount, Jr. Chair DATED thisl f1v of February, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISa ON PERMIT TO DRILL 20 AAC 25.005 RECOVED C�� a 1a. Type of Work: I Drill ❑ Lateral ❑ Redrill R] • Reentry ❑ 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Stratigraphic Test ❑ Development - Oil Q ' Service - Winj ❑ Single Zone Q ' Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1c. Specify if well is proposed for. Coalbed Gas ❑ Gas Hydrates ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: Conoco Phillips Alaska, Inc. 5. Bond: Blanket Q . Single Well ❑ Bond No. 5952180. 11. Well Name and Number: KRU 2G -06A 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9750' • TVD: 6027' 12. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 547' FSL, 236' FWL, Sec 32, Tl l N, R9E, UM Top of Productive Horizon: 1418' FNL, 1365' FEL, Sec 32, T11 N. R9 E, UM Total Depth: 5177' FNL, 1392' FEL, Sec 29, T11 N, R9E, UM 7. Property Designation: ADL 25656 8. DNR Approval Number: LONS 82-180 13. Approximate Spud Date: 2/26/2019 '/ 9. Acres in Property: 2491 14. Distance to Nearest Property: 23075' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 508930. y- 5944135 ' Zone- 4 10. KB Elevation above MSL (ft): 140' GL / BF Elevation above MSL (ft): 104' 15. Distance to Nearest Well Open to Same Pool: 525', 2F-20 16. Deviated wells: Kickoff depth: 8095' . feet Maximum Hole Angle: 100 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4,908 • Surface: 4,320 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 ST -L 1350' 8400' • 6052' 9750' 6027' Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 8485' 6253' N/A 8368' 6158' 8136' Casing Length Size Cement Volume MD TVD Conductor/Structural 72' 16" 202 sx Cold Set II 110' 110' Surface 3097' 9-5/8" 1035 sx PF E, 250 sx PF C 3134' 2774' Production 8413' T' 575 sx Class G, 250 sx PF C 8449' 6224' Perforation Depth MD (ft): 81881- 8198' Perforation Depth TVD (ft): 6013' - 6021' 8216'- 8246' 6035'- 6060' Hydraulic Fracture planned? Yes❑ No 7 20. Attachments: Property Plat ❑ BP SketchDiveOer Sketch e Dysis Sleabed Report B DriBi ing Program g Fluid P FrogaDepth tm a 20 AAC 25.050 requ emShallow Hazard lentse 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: Kai Starck Contact Email: Keith. E. Herrin Co .Com Authorized Title: CTD Director Contact Phone: 907-263-4321 Authorized Signature: Dale: 2--R--let Comm ssion use Only Permit to Drill Q Number: �l / ��% IZ API Number: '' 50- bG/ ��,��'--'L/ / �� Permit Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane as hydrates, or gas contained in shales: Other: %30P rCS f 'io 9 Samples req'd: Yes ❑ No[Y Mud log req'd: Yes ❑ No [b{/ X86 0 � r � 71 Z SDo measures: Yes I No❑ , Directional svy req'd: Yes No ❑ /iiJr/v/LL/ rCVG�Ir iGS ,--,7 ,��// P Spacing exception mq'd: Yes ❑ No Ltd Inclination -only svy all Yes E] Nord Post initial injection MIT req'd: Yes ❑ No 53 APPROVED BY Approved by: O I O E THE COMMISSION Date: ` Form 10401 Revised 5/2017 This pe n is wall f 4 o 1h\J4AJWp1111I Submit Form and per 20 AAC 25.005(g) chments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 08, 2018 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 sundry application to set a mechanical whipstock and cement squeeze the A -sand perforations in the KRU well 2G-06 (PTD# 184-082). ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 2G-06 (PTD #184-082) using the coiled tubing drilling rig, Nabors CDR3-AC. Pre -rig operations are scheduled to begin in late February with CTD operations following in early March 2019. The objective will be to drill four laterals, KRU 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 targeting the Kuparuk A -sand interval. ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging _ ._-.- method to isolate the 2G-06 A -sand perforations utilizing an A -sand cement squeeze via service coil. To account for geologic 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. Attached to the sundry application are the following documents: - 10403 Sundry Application for KRU 2G-06 - Operations Summary in support of the 10-403 sundry application - Current Wellbore Schematic - Proposed CTD Schematic Attached to the permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 - Detailed Summary of Operations - Directional Plans for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) 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)). . ...... I ... 1.1 ............ I r ............ ....... ..................... I.. r ............. ........ r ........ ..................................... -3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................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))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 7 (Requirements of 20 AAC 25.050(b))......................................................................................................................................................7 16. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 laterals....................................7 Attachment 2: Current Well Schematic for 2G-06...........................................................................................................7 Attachment 3: Proposed Well Schematic for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 laterals......................7 Page 1 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01. All laterals will be classified as "Development -Oil' 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 forms for surface and subsurface coordinates of each of the laterals. 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 CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,800 psi. Using the maximum formation pressure in the area of 4,908 psi in 2B-05 (i.e. 15.5 ppg EMW), the maximum potential surface pressure in 2G-06, assuming a gas gradient of 0.1 psi/ft, would be 4,320 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 2G-06 was measured to be 3,829 psi (12.4 ppg EMW) on 10/13/2018. The maximum downhole pressure in the 2G-06 vicinity is the 213-05 at 4,908 psi or 15.5 ppg EMW on 7/7/2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 2G-06 laterals. If 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 2G-06 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 2G-06 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 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 2G -06A 8,400' 9,750' 5,912' 5,887' 2%", 4.7#, L-80, ST -L slotted liner; Surface 110' 1640 670 Surface aluminum billet on to 2G-06AL1 8,300' 9,750' 5,913' 5,859' 2%", 4.7#, L-80, ST -L slotted liner; 2774' 3520 2020 Production 7" aluminum billet on to 2G-06AL2 8,400' 9,900' 5,914' 5,898' 2%", 4.7#, L-80, ST -L slotted liner; 1 4980 4320 Tubing 3-1/2" 9.3 aluminum billet on to 2G-06AL2-01 8,006' 9,900' 5,730' 51873' 2%", 4.7#, L-80, ST -L slotted liner/blank; 10,540 blank; de to ment sleeve on to Existing CasinglUner Information Category OD Weigh t Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 110' Surface 110' 1640 670 Surface 9-5/8" 36 J-55 BTC Surface 3134' Surface 2774' 3520 2020 Production 7" 26 J-55 BTC Surface 8449' Surface 6224' 1 4980 4320 Tubing 3-1/2" 9.3 L-80 EUE8rdMOD Surface 8044' Surface 5899' 1 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-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 CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro drilling mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using ��..- MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 12.6 ppg potassium formate completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. If higher formation pressures are encountered the completion brine will be weighted up with potassium formate. Page 3 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 2G-06 laterals we will target a constant BHP of 12.4 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 2G-06 Window (8,095' MD, 5,939' TVD) 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 2G-06 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the Kuparuk A -sands to the north and south of the existing 2G-06 wellbore. The laterals will reclaim resource from the long term shut in rock producer 2G-06 and provide additional offtake in a high-pressure area. E -line will set a high expansion wedge in the 7" production casing at the planned kick off point at 8095' MD. Service coil will cement the high expansion wedge in the 7" casing and squeeze cement the A -sand perforations. Page 4 of 7 February 08, 2019 Pumps On 1.8 bpm) Pumps Off Formation Pressure 12.4 3829 psi 3829 psi Mud Hydrostatic 8.6 2655 psi 2655 psi Annular friction i.e. ECD, 0.080psi/ft) 647 psi 0 psi Mud + ECD Combined no chokepressure) 3302 psi underbalanced ^527psi) 2655 psi underbalanced -1174psi) Target BHP at Window 12.4 3830 psi 3830 psi Choke Pressure Required to Maintain Target BHP 528 psi 1175 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 2G-06 is a Kuparuk producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the Kuparuk A -sands to the north and south of the existing 2G-06 wellbore. The laterals will reclaim resource from the long term shut in rock producer 2G-06 and provide additional offtake in a high-pressure area. E -line will set a high expansion wedge in the 7" production casing at the planned kick off point at 8095' MD. Service coil will cement the high expansion wedge in the 7" casing and squeeze cement the A -sand perforations. Page 4 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 CDR3-AC will cut a window in the 2G-06 production casing and drill the 2G -06A sidetrack to a planned TD at 9,750' MD, targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD '� up to 8,400' MD with an aluminum billet for kicking off the 2G-06AL1 lateral. The 2G-06AL1 lateral will drill to a TD of 9,750' MD targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 8,300' MD with an aluminum billet for kicking off the 2G-06AL2 lateral. The 2G-06AL2 lateral will drill to TD of 9,900' MD targeting the A sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 8,400' MD with an aluminum billet for kicking off the 2G-06AL2- 01 lateral. The 2G-06AL2-01 lateral will drill to TD of 9,900' MD targeting the A sand to the south. It will be completed with 2-3/8" slotted/blank liner from TD up into the 3-1/2" tubing at 8,006' MD with a deployment sleeve. Pre -CTD Work 1. RU Slickline: Obtain caliper of 7" casing. 2. RU E -line: Set high expansion wedge in 7" casing. 3. RU Service Coil: Cement high expansion wedge and squeeze cement the A -sand perforations. 4. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2G -06A Sidetrack (A4 sand - North) a. Mill 2.80" window at 8,095' MD. b. Drill 3" bi-center lateral to TD of 9,750' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 8,400' MD. 3. 2G-06AL1 Lateral (A4 sand -North) a. Kick off of the aluminum billet at 8,400' MD. b. Drill 3" bi-center lateral to TD of 9,750' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,300' MD. 4. 2G-06AL2 Lateral (A4 sand - South) a. Kickoff of the aluminum billet at 8,300' MD. b. Drill 3" bi-center lateral to TD of 9,900' MD. c. Run 2%" slotted liner with aluminum billet from TD up to 8,400' MD. 5. 2G-06AL2-01 Lateral (A4 sand - South) a. Kickoff of the aluminum billet at 8,400' MD. b. Drill 3" bi-center lateral to TD of 9,900' MD. c. Run 2%" slottediblank liner with deployment sleeve from TD up to 8,006' MD. 6. Obtain SBBP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return to production. Page 5 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 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 - 2G-06 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. - While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 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). Page 6 of 7 February 08, 2019 PTD Application: 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(6)) - 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. v� - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 2G -06A 23,075' 2G-06AL1 23,075' 2G-06AL2 22,200' 2G-06AL2-01 22,200' - Distance to Nearest Well within Pool Lateral Name Distance Well 2G -06A 525' . 2F-20 2G-06AL1 525' 2F-20 2G-06AL2 1285' 2G-08 2G-06AL2-01 1285' 2G-08 16. Attachments Attachment 1: Directional Plans for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 laterals. Attachment 2.' Current Well Schematic for 2G-06. Attachment 3. Proposed Well Schematic for 2G -06A, 2G-06AL1, 2G-06AL2, and 2G-06AL2-01 laterals. Page 7 of 7 February 08, 2019 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2G Pad 2G-06 2G -06A Plan: 2G-06A_wp06 Standard Planning Report 06 February, 2019 BT�a GHES GE company ConocoPhillips BAKER COf1000Plillips Planning Report UGHES aGEmmpany Database: OAKEDMP7 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project. Kuparuk River Unit Site: Kuparuk 2G Pad Well: 2G-06 Wellbore: 2G -06A Design: 2G-06A_wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 2G-06 Mean Sea Level 2G-06 Q 140.00usft (2G-06) True 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 Site Kuparuk 2G Pad 2G-06 +N/ -S +E/ -W 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: Site Position: Northing: 5,944,015.12 Usti, Latitude: 70° 15'29,734 N From: Map Easting: 508,649.96 usft Longitude: 149° 55'48.314 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.07 ° Well Well Position Position Uncertainty 2G-06 +N/ -S +E/ -W 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: 5,944,135.21 usft - 508,929.90 usft , usft Latitude: Longitude: Ground Level: Measured TFO (°M00usft) TVD Below (°/100usft) _ Wellbore 2G -06A Azimuth System +N/ -S +E/ -W Magnetics Model Name Sample Data Declination l°I Dip Angle V) (usft( BGGM2017 2/112018 39.17 17.14 80.85 Design 2G-06A_wp06 8,095.00 38.01 49.06 5,799.42 Audit Notes: 3,668.10 8,124.00 43.81 49.06 5,821.32 Version: 3,682.44 Phase: PLAN 75.31 Tic On Depth: 8.00( Vertical Section: 3,367.19 Depth From (TVD) +N/ -S +E/ -W Directior 5,873.21 3,423.53 (usft) (usft) (usft) (°) 5,889.69 3,483.54 0.00 0.00 0,00 0.00 Plan Sections Build Turn Rate Rate Measured TFO (°M00usft) TVD Below (°/100usft) V) Depth Inclination Azimuth System +N/ -S +E/ -W (usft) (°) (1) (usft) (usft) (usft( 8,000.00 39.17 48.95 5,725.16 3,276.83 3,623.38 8,095.00 38.01 49.06 5,799.42 3,315.70 3,668.10 8,124.00 43.81 49.06 5,821.32 3,328.14 3,682.44 8,194.00 75.31 49.06 5,856.34 3,367.19 3,727.46 8,264.00 77.51 16.71 5,873.21 3,423.53 3,763.77 8,339.42 78.00 51.46 5,889.69 3,483.54 3,804.40 8,438.63 95.00 9.94 5,896.01 3,566.70 3,853.38 8,508.63 94.98 5.02 5,889.91 3,635.82 3,862.46 8,608.63 87.98 5.02 5,887.33 3,735.34 3,671.20 8,940.00 88.14 341.81 5,898.68 4,062.09 3,833.48 9,010.00 89.17 346.60 5,900.32 4,129.41 3,814.45 9,200.00 100.67 353.33 5,884.05 4,315.38 3,781.44 9,300.00 94.08 355.72 5,871.22 4,414.04 3,772.00 9,390.00 89.25 351.68 5,868.60 4,503.41 3,762.13 9,750.00 85.08 326.79 5,886.69 4,836.93 3,635.80 70' 15'30 91 1 N 149'55'40.1165 W 0.00 usft Field Strength (nT) 57,466 Dogleg Build Turn Rate Rate Rate TFO (°M00usft) (°/100usft) (°/100usft) V) 0.00 0.00 0.00 0.00 1.22 -1.22 0.12 176.66 20.00 20.00 0.00 0.00 45.00 45.00 0.00 0.00 45.00 3.15 -46.22 270.00 45.00 0.65 46.08 93.00 45.00 17.14 41.85 290.00 7.00 -0.03 -7.03 270.00 7.00 -7.00 0.00 180.00 7.00 0.05 -7.00 270.00 7.00 1.46 6.85 78.00 7.00 6.05 3.54 30.00 7.00 -6.59 2.39 160.00 7.00 -5.37 4.49 220.00 7.00 -1.16 -6.91 260.00 Target 262019 11:55:30AM Page 2 COMPASS 5000.14 Build 85D �ConocoPhillips A ConoaC ;hi �Ip5 Planning Report BF�UERGHES a GEr=m ry Database: OAKEDMP7 Local Coordinate Reference: Wall 2G-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project. Kuparuk River Unit MD Reference: 2G-06 Qa 140.00usft (2G-06) Site: Kuparuk 2G Pad North Reference: True Well: 2G-06 Survey Calculation Method: Minimum Curvature Wellbore: 2G -06A Depth Inclination Design: 2G-06A_wp06 tNiS ♦El -W Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System tNiS ♦El -W Section Rate Azimuth Northing Basting (usft) (a) (o) (usft) (usft) (usft) lush) ('1100usft) (1) (usft) (usft) 8,000.00 39.17 48.95 5,725.16 3,276.83 3,623.38 3,276.83 0.00 0.00 5,947416.01 512,549.03 TIP 8,095.00 38.01 49.06 5,799.42 3,315.70 3,668.10 3,315.70 1.22 176.66 5,947,454.93 512,593.70 KOP 8,100.00 39.01 49.06 5,803.33 3,317.74 3,670.45 3,317.74 20.00 0.00 5,947,456.97 512,596.05 8,124.00 43.81 49.06 5,821.32 3,328.14 3,682.44 3,328.14 20.00 0.00 5,947,467.38 512,608.02 End 20 dis, Start 46 dis 8,194.00 75.31 49.06 5,856.34 3,367.19 3,727.46 3,367.19 45.00 0.00 5,947,506.48 512,652.99 4 8,200.00 75.33 46.27 5,857.87 3,371.10 3,731.75 3,371.10 45.00 -90.00 5,947,510.39 512,657.27 8,264.00 77.51 16.71 5,873.21 3,423.53 3,763.77 3,423.53 45.00 -89.29 5,947,562.86 512,689.24 6 8,300.00 77.18 33.31 5,881.15 3,455.24 3,778.56 3,455.24 45.00 93.00 5,947,594.58 512,703.98 8,339.42 78.00 51.46 5,889.69 3,483.54 3,804.40 3,483.54 45.00 89.34 5,947,622.91 512,729.79 6 8,400.00 88.19 25.95 5,897.09 3,530.11 3,841.52 3,530.11 45.00 -70.00 5,947,669.52 512,766.85 8,438.63 95.00 9.94 5,896.01 3,566.70 3,853.38 3,566.70 45.00 -66.87 5,947,706.12 512,778.67 End 45 dis, Start 7 dis 8,500.00 94.99 5.63 5,890.66 3,627.26 3,861.66 3,627.26 7.00 -90.00 5,947,766.69 512,786.87 8,508.63 94.98 5.02 5,889.91 3,635.82 3,862.46 3,635.82 7.00 -90.38 5,947,775.24 512,787.66 8 8,600.00 88.59 5.02 5,887.07 3,726.75 3,870.45 3,726.75 7.00 -180.00 5,947,866.18 512,795.54 8,608.63 87.98 5.02 5,887.33 3,735,34 3,871.20 3,735.34 7.00 -180.00 5,947,874.77 512,796.28 9 8,700.00 87.99 358.62 5,890.54 3,826.56 3,874.10 3,826.56 7.00 -90.00 5,947,965.98 512,799.07 8,800.00 88.04 351.62 5,894.01 3,926.08 3,865.60 3,926.08 7.00 -89.78 5,948,065.48 512,790.46 8,900.00 88.11 344.61 5,897.37 4,023.82 3,645.03 4,023.82 7.00 -89.53 5,948,163.18 512,769.77 8,940.00 88.14 341.81 5,898.68 4,062.09 3,833.48 4,062.09 7.00 -89.30 5,948,201.43 512,758.18 10 9,000.00 89.02 345.92 5,900.17 4,119.70 3,816.82 4,119.70 7.00 78.00 5,948,259.02 512,741.45 9,010.00 89.17 346.60 5,900.32 4,129.41 3,814.45 4,129.41 7.00 77.90 5,948,268.72 512,739.07 11 9,100.00 94.62 349.76 5,897.35 4,217.41 3,796.03 4,217.41 7.00 30.00 5,948,356.69 512,720.55 9,200.00 100.67 353.33 5,884.05 4,315.38 3,781.44 4,315.38 7.00 30.10 5,948,454.63 512,705.85 12 9,300.00 94.08 355.72 5,871.22 4,414.04 3,772.00 4,414.04 7.00 160.00 5,948,553.27 512,696.29 13 9,390.00 89.25 351.68 5,868.60 4,503.41 3,762.13 4,503.41 7.00 -140.00 5,948,642.63 512,686.31 14 9,400.00 89.13 350.99 5,868.74 4,513.30 3,760.62 4,513.30 7.00 -100.00 5,948,652.51 512,684.79 9,500.00 87.92 344.09 5,871.32 4,610.85 3,739.06 4,610.85 7.00 -99.99 5,948,750.03 512,663.12 9,600.00 86.75 337.18 5,875.97 4,705.03 3,705.96 4,705.03 7.00 -99.81 5,948,844.16 512,629.91 9,700.00 85.62 330.26 5,882.64 41794.44 3,661.81 4,794.44 7.00 -99.49 5,948,933.51 512,585.66 9,750.00 85.08 326.79 5,886.69 4,836.93 3,635.80 4,836.93 7.00 -99.03 5,948,975.97 512,559.60 Planned TD at 9760.00 2/62019 11:55:30AM Page 3 COMPASS 5000.14 Build 85D Plan Annotations Measured Vertical Local Coordinates ConocoPhillips ConocoPhillips Depth Planning Report Database: OAKEDMP1 (usft) Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project. Kupamk River Unit 3,276.83 MD Reference: Site: Kupamk 2G Pad 5,799.42 North Reference: Well: 2G-06 8,124.00 Survey Calculation Method: Wellbore: 2G -06A End 20 cls, Start 45 dls 8,194.00 Design: 2G-06A_wp06 3,727.46 4 ng Paints — 3,423.53 3,763.77 r Measured Vertical 3,483.54 3,804.40 Depth Depth 5,896.01 3,566.70 (usft) (usft) Name 5,889.91 9]50.00 5.886.69 2 3/8' 8 Plan Annotations Measured Vertical Local Coordinates Diameter Depth Depth -NI-S +El -W (usft) (usft) (usft) (usft) Comment 8,000.00 5,725.16 3,276.83 3,623.38 TIP 8,095.00 5,799.42 3,315.70 3,668.10 KOP 8,124.00 5,821.32 3,328.14 3,682.44 End 20 cls, Start 45 dls 8,194.00 5,856.34 3,367.19 3,727.46 4 8,264.00 5,873.21 3,423.53 3,763.77 5 8,339.42 5,889.69 3,483.54 3,804.40 6 8,438.63 5,896.01 3,566.70 3,853.38 End 45 cis, Start 7 dls 8,508.63 5,889.91 3,635.82 3,862.46 8 8,608.63 5,887.33 3,735.34 3,871.20 9 8,940.00 5,898.68 4,062.09 3,833.48 10 9,010.00 5,900.32 4,129.41 3,814.45 11 9,200.00 5,884.05 4,315.38 3,781.44 12 9,300.00 5,871.22 4,414.04 3,772.00 13 9,390.00 5,868.60 4,503.41 3,762.13 14 9,750.00 5,886.69 4,836.93 3,635.80 Planned TO at 9750.00 BA ER BAT Well 2G-06 Mean Sea Level 2G-06 @ 140.00usft (2G-06) True Minimum Curvature Casing Hole Diameter Diameter (in) (in) 2.375 3.000 2/62019 11:55:30AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BA_ ICER Con000P11llips Travelling Cylinder Report UGHES a GFcompany Company: ConocoPhillips (Alaska) Ina -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 2G Pad Site Error: 0.00 usft Reference Well: 2G-06 Well Error: 0.00 usft Reference Wellbore 2G -06A Reference Design: 2G-06A_wp06 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2G-06 2G-06 @ 140.00u5ft (2G-06) 2G-06 @ 140.00usft (2G-06) True Minimum Curvature 1.00 sigma OAKEDMPI Offset Datum teference 2G-06A_wP06 Casing �ifter type: GLOBAL FILTER APPLIED. All wellpaths within 200'+ 100/1000 of reference Depth interpolation Method: MO Interval 100.00usft Error Model: ISCWSA )epth Range: Unlimited Scan Method: Tray. Cylinder North tesults Limited by: Maximum center -center distance of 1,161.00 usft Error Surface: Pedal Curve Survey Tool Program From (usft) 200.00 8,000.00 Casing Points Date 2/6/2019 To (usft) Survey (Wellbore) 8,000.00 2G-06 (2G-06) 9,750.00 2G -06A wp06 (2G -06A) Tool Name SEEKER MS MWD Description BHI Seeker multishot MWD - Standard Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,750.00 6,026.69 2 3/8" 2.375 3.000 Summary Kupafuk 2F Pad- 2F -20 -2F -20-2F-20 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) venial (usft) Onset Kuparuk 2F Pad Onset Wellbore Centre Casing- Centre to No Do Allowable Warning 2F -20 -2F -20-2F-20 9,730.36 7,300.00 802.45 253.60 549.35 Pass - Major Risk Kupamk 2G Pad Hole Sire Centre Revive neviadon Ruse) )rift) (usm 2G -05 -2G -05 -2G -O5 1,003.12 1,000.00 44.65 27.97 16.68 Pass - Major Risk 2G -06 -2G -06 -2G -O6 8,000.00 8,000.00 0.00 0.25 -0.25 FAIL - Minor 1/10 2G-06-2G-06AL1-2G-06A1-1_wp05 8,000.00 8,000.00 0.00 0.23 -0.22 FAIL - Minor 1/10 2G-06-2G-06AL2-2G-06AL2_wp03 8,000.00 8,000.00 0.00 0.23 -0.22 FAIL - Minor 1/10 2G-06-2G-06AL2-01-2G-06AL2-07_wp03 8,000.00 8,000.00 0.00 0.23 -0.22 FAIL - Minor 1/10 2G-06-2G-06LIPB1-2G-06L1PB7 8,000.00 8,000.00 0.00 0.23 -0.22 FAIL - Minor 1/10 2G-07 - 2G-07 - 2G-07 598.27 600.00 60.09 14.58 45.52 Pass - Major Risk 2G-08 - 2G-08 - 2G-08 596.56 600.00 118.57 14.65 103.92 Pass - Major Risk Offset Design Kupafuk 2F Pad- 2F -20 -2F -20-2F-20 onset sne Error: 0.00 usa survey Program: 282- Rule Assigned: Meior Risk Onset WellEear: 0.00 it Reference Onset Semi Major Avis Measured Vertical Measured venial Reference Onset Toollace+ Onset Wellbore Centre Casing- Centre to No Do Allowable Warning Deptb north Depth Depth Atimutl, -NI-8 ♦Et -ss Hole Sire Centre Revive neviadon Ruse) )rift) (usm faun) lusul neem (1) Nan) lural Un) (volo lasnl (ush) %660.42 6.419.77 alki 5.42.47 64.39 59.22 31.70 5,242.66 4,537.91 6.312 1,150.58 230.59 915.98 Pass -Major Risk 9,700.00 6.022.64 7.000.0) 5,494.50 64.43 60,26 30.61 5,240.84 4,460.56 6.312 1,062.07 244.91 825.42 Pass - Major Risk 9,700.0 6,022." 7,100.0 5,56(1.26 64.43 61.31 32.35 5,238.18 4,398.90 6.312 973.48 246.42 730.90 Pass -Major Risk 9,700.0 6,022." 7,200,0 $.637J9 64.43 62.39 34.41 5,235.04 4,329.15 6.312 857.02 247.93 637.72 Pass-Ma)gr Rlek 9730.36 6.05.04 7.300.0 5.709.19 64.46 63.45 31.97 5,23131 4,259.21 6.312 602.45 253.60 1549.35 Pass- Major Risk, CC, Ea SF CC - Min centre to center distance or covergent point. SF - min separation factor, ES - min ellipse separation ZS2019 11:30:45AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips BAJ(ER ConocoP fillips Travelling Cylinder Report IJGHE$ a GEcompany Company: ConocoPhillips (Alaska) Inc -Kup2 Project: Kupamk River Unit Reference Site: Kuparuk 2G Pad Site Error: 0.00 Left Reference Well: 2G-06 Well Error: 0.00 usft Reference Wellbore 2G -06A Reference Design: 2G -06A wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 2G-06 2G-06 @ 140.00usft (2G-06) 2G-06 @ 140,00usft (2G-06) True Minimum Curvature 1.00 sigma OAKEDMPI Offset Datum Reference 2G-06A_wp06 Fiber type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 8,000.00 to 9,750.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,161.00 usft Error Surface: Pedal Curve Survey Tool Program Date 2/6/2019 From To Reference Offset (usft) (usft) Survey (Wellbore) Tool Name Description i 200.00 8000.00 2G-06 (2G-06) SEEKER MS BHI Seeker multishot Deviation 8,000.09 9,750.00 2G-06A_wp06(2G-06A) MWD MWD - Standard Distance Casing Points from Plan Offset Well - Wellbore - Design (usft) Measured Vertical (usft) Casing Hole Portical Depth Depth onset Diameter Diameter Casing- (usft) (usft) Name (in)- (in) j 7,275.00 9,750.00 6,926.69 23/8" - 252.47 2.375 3.900 J Summary Kuparuk 2F Pad- 2F -20 -2F -20-2F-20 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) Medical (usft) Portical Kupamk 2F Pad onset Tooaace♦ OHut Wa80ore Cemre Casing- centre to NO Go 2F -20 -2F -20-2F-20 9,725.00 7,275.00 823.28 252.47 571.43 Pass - Major Risk Kupamk 2G Pad ♦10,6 EAW Note Size Can" under a lean iation 2G -O6 -2G -OB -2G -O6 8,100.00 8,100.00 0.05 0.31 -0.30 FAIL - Minor 1/10 2G-06 - 2G-06AL1 - 2G-06AL1_wpO5 8,100.00 8,100.00 0.05 0.29 -0.28 FAIL - Minor 1/10 2G-06-2G-OSAL2-2G-06AL2_wp03 8,100.00 8,100.00 0.05 0.29 -0.27 FAIL - Minor 1/10 2G-06-2G-06AL2-01-2G-06AL2-01_wp03 8,100.00 8,100.00 0.05 0.29 -0.27 FAIL - Minor 1/10 2G -O6 -2G-061_1 PBI -2G -06L7 PBI 8,100.00 8,100.00 0.05 0.29 -0.27 FAIL - Minor 1/10 Offset Design Kuparuk 2F Pad- 2F -20 -2F -20-2F-20 onset see Eman 0.00usrt Survey Program: 282- RUM Assigned: Major Risk Olfeet wall Error. 0.00 usft Reference One. Semi Malm Axis Measured Medical Measured Portical gardened onset Tooaace♦ OHut Wa80ore Cemre Casing- centre to NO Go Alknend, winning Degan began Detain Depth Azimuth ♦10,6 EAW Note Size Can" under a lean iation (usnl (usft) (uaftl luaft) (part) into I°) (usft) (ndft) lin) Iuaftl (usft) lust" 9660,42 6,019.77 6,900.00 5,42247 64.40 59.22 31.70 5,24268 4.537.91 6.312 1,150.58 238.57 915.99 Pass - Major Risk 9.664.26 6,020.03 6,925.00 5.440.51 64.40 59A6 31.80 5,24228 4,520.59 6.312 1,128.21 239.38 092.80 Pa. - Major Risk 9,675.00 9020.79 6.950.00 5,458.52 64.41 59.74 3t47 5,24188 4,503,26 6.312 1,105.95 241.05 859.88 Pass -Major Risk 8675+0 6,020.79 6,975.00 5,08,52 64.41 60.00 31.64 9241_38 4,485.92 6.312 1,63.67 241.41 846.19 Pass -Major Risk 9675.00 6,020.78 7,000.00 5,494.50 64.41 80.26 32,23 5,240.84 4,460.56 6.312 1.061.47 241.77 822.56 Pass Major Risk 9,675.00 6,020.79 7.025.00 5,512.46 64,41 60.52 32.64 5,240.25 4,451.18 6,312 1,039.30 242.13 798.98 Pass Major Risk 9,664.33 9021.46 7,050+0 5,530,41 64.42 60.79 32.48 6.239.61 4,433.79 6.312 1,17.30 243.67 776.27 Pass - Major Risk 9.680.54 6,021.78 7.075,00 5,540.34 64.42 61.05 32.63 5,230.92 4,416.38 6,312 995.32 244.58 753.16 Pass - Major Risk 9,692.82 6,022.09 7,100.00 5,566.28 64.43 61.31 32.81 5,238.18 4,398.96 6.312 973.43 245.49 730,12 Pass -Major Risk 9700.00 9022.84 7,125.00 5.584.16 64.43 61.58 32.03 5.237.42 4.381.53 6.312 951.64 246.80 707.46 Pass -Major Risk 9.700.00 6,022.64 7,150.00 5.602.05 64.3 61,05 33.33 5,236.65 4,364.08 6.312 929.94 247.17 604.11 Pass - Major Risk 9700.00 6,022.64 7.175.00 5.619.93 64A3 62.12 33.86 5,23585 4,346.63 6,312 908.40 247,55 660.86 Pass - Malar Risk CC - Min centre to center distance nr cnvernent mint RF - min Renaratinn fnnnr FR - min aninm ennnmNnn 2/6/2019 1131: 28AM Page 2 COMPASS 5000,14 Build 85D Mean: 5250 5000 4750 4500 4250 c000 v,3 1350 +3250 f 03000 s750 02500 2250 2000 1750 Project Kupawk River Unit Site: Kup mk 20 Pad Well 2G.06 WELLBORE DETAILS: 2G -06A RERMENCE INFORWRON BA UGHES Parent Mllbore: 20-06 Tie on MD: 8000.00 Domdnea (NE) R�smw Wdl 2M Tm N� V� (TVD) lid... � fa. i,,,vi S.I. (VS) � �DA QW) Gonoco*P�hiffips[ Wellbore: 2"SA Plan: 20.06k�06 (2G4612046A) +E/ -W Northing , 1,1neirn) DWM FsAiene, 2G(6 @ M000st r�) M Latitude Longitude 0.00 C�wesn mw W. C,nnw� Mean: 5250 5000 4750 4500 4250 c000 v,3 1350 +3250 f 03000 s750 02500 2250 2000 1750 WELL DETAILS: 2G-06 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5944135.21 508929.90 70* 15'30.911 N 149* 55'40.165 W Sec MD Inc Azi TVDSS +N/ -S +E/ -W Meg TFace VS ecl Annotation 1 8000.00 39.17 48.95 6725.16 3276.83 3623.38 0.00 0.00 3276.83 TIP 2 8095.00 38.01 49.06 5799.42 3316.70 3668.10 1.22 176.66 3315.70 KOP 3 8124.00 43.81 49.06 5821.32 3328.14 3682.44 20.00 0.00 3328.14 End 20 dis, Start 45 dis 4 8194.00 75.31 49.06 5856.34 3367.19 3727.46 45.00 0.00 3367.19 4 5 8264.00 77.51 16.71 5873.21 3423.53 3763.77 45.00 270.00 3423.53 5 6 8339.42 78.00 51.46 5889.69 3483.54 3804.40 45.00 93.00 3483.54 6 7 8438.63 95.00 9.94 5896.01 3566.70 3853.38 45.00 290.00 3566.70 End 45 d1s, Start 7 dis 8 8508,63 94.98 5.02 5889.91 3635.82 3862.46 7.00 270,00 3635.82 8 9 8608.63 87.98 5.02 5887.33 3735.34 3871.20 7.00 180.00 3735.34 9 10 8940.00 88.14 341.81 5898.68 QUM 383148 7.00 270.00 4062.09 10 11 9010.00 89.17 346.60 5900.32 4129.41 3814.45 7.00 78.00 4129.41 11 12 9200.00 100.67 353.33 5884.05 4316.38 3781.44 7.00 30.00 4315.38 12 13 9300.00 94.08 355.72 5871.22 4414.04 3772.00 7.00 160.00 4414.04 13 14 9390.00 89.25 351.68 5868,60 4503.41 3762.13 7.00 220.00 4503.41 14 15 9750.00 85.08 326.79 5886.69 4836.93 3635.80 7.00 260.00 4836.93 Planned TD at 9750.00 Mean: 5250 5000 4750 4500 4250 c000 v,3 1350 +3250 f 03000 s750 02500 2250 2000 1750 o West( -)/East(+) (250 usft/in) 5650 0 TI 5750 EMEMMI O Sam C_ op IMMEME loom NONE End 21Is d1s, S m 45, �G-061!"6, Ll 5850 MEN 2&(6/2G( 5AL2.)l 5900 M■NMI ONE 204W74 AL2 X- . 13 14 5950 0 1 2 P nnell. M 9 75000 NMI nd 45 Is, SW t 7 d1i 2G - G 6000 - 2LI ftl ---------- I■NONE - - - - - - HE HE 6100 - ON ONEEN�■....■.� .2G 620 16 - - - Ise NOON■■OI MINE --- ME 0 1 o West( -)/East(+) (250 usft/in) 5650 0 TI 5750 O Sam C_ op End 21Is d1s, S m 45, �G-061!"6, Ll 5850 2&(6/2G( 5AL2.)l 5900 204W74 AL2 X- . 13 14 5950 4 5 6 - 1 2 P nnell. M 9 75000 nd 45 Is, SW t 7 d1i 2G - G 6000 - 2LI ftl ---------- 6050 - - - - - - #- 6100 - .2G 620 16 - - - Ise Vertical Section at O.UU' (50 ustvin) ConocoPhillips mu72G-(07 Nb22G-02 Project: Kuparok Rivef UnitwFe,ue Site: Kuparuk 2G Pad PamWemTnw Wu xe,n-n+r N'prelw Fba WELLBORE DETAILS: 2G-OBA REFERENCE INFORMATION Parent Wellbore 2G -O6 comsreleN Za Well: 22.06 s+b,M1n s7AaA.e++, Tie on MD: 8100.00 yygylljypl :2G a28�1ip�M�GL6) Ex Re W9I wpDre: 2(22 Plan: 2G-06A_vrp06 (20-0fi/2G-06A) 0.p y+ B MreweJ DvIb Re.: 2Ga61@0140Maft RMO MUW eooAaan ctlwktia+ McMpi Mninm cxrnwa 600011100 5700 1-4\li, s'11-1- 5400 I UGHES a GEto.,, 5100 r.� 4800 • j� 4500 �_(: +•,1 4200 _ 3900 3600 \ 3300 I"0° .. / 1 x a:�u o 2aL12cOI 9 10 -900-600 � 0 `:`300 ..600 900 1200 1500 1800 2100 2400 2700 3000 1300 1600 3900 421 40 00 4500 4%00 SIDO 50 5]00 6000 6}i 20 M-0-16 :c.15rsa-Is 20uqa� --'.r -... West( -)/East(+) (300 usfflin) 2G-06 @ 140.00us0 (2G-06)- 10 7500 7800 8100 6400 6700 !'2F.n 2F'y�A2F-171.1 2' :17 Y 72F-111.11.2 21-1121 -"A 2F -IMF -IR 41IM 'I' -122E-12 1 :FM2F+L 2T 4)=F415X 21 AI I IIIV \� �`— / 2F<n2en} 5100 r.� 4800 • j� 4500 �_(: +•,1 4200 _ 3900 3600 \ 3300 I"0° .. / 1 x a:�u o 2aL12cOI 9 10 -900-600 � 0 `:`300 ..600 900 1200 1500 1800 2100 2400 2700 3000 1300 1600 3900 421 40 00 4500 4%00 SIDO 50 5]00 6000 6}i 20 M-0-16 :c.15rsa-Is 20uqa� --'.r -... West( -)/East(+) (300 usfflin) 2G-06 @ 140.00us0 (2G-06)- 10 7500 7800 8100 6400 6700 !'2F.n 2F'y�A2F-171.1 2' :17 Y 72F-111.11.2 21-1121 -"A 2F -IMF -IR 41IM 'I' -122E-12 1 ,jjPj_k_ _ KUP PROD WELLNAME 213-06 LLBORE 213-06 COr10C0P'1IllIpS Alaska, InL. To .-..0 Attributes MaxAngle&MD TD Ni Name Wellbme FPINWI WHIMre StaWs ncl(°I hunig mK61 KUPARUK RNER UNIT 500292132ID0 PROD 4.60 ING 4,000.00 B.d85.0 Cammem H1S( ll Dah concess Ertl 0111 NRGM pg RIp ReNaeaDW $SSV: NIPPLE 110 12/19/201] Lan WO: 7/142010 36.00 6118/1984 3DDs. zna+s a.3xaPAM Last Tag Wrestschemate recruit Annotation I DryMmKBI End Dale Wl1 ' Lash Mal By Last Tag: RKB 8,.H.0 2/6/2019 2G -O6 aembaej I lur,ocn ml- Last Rev Reason Annuesain End Data welmara Gua.kday Rev Reason; Pulled Reekscreen B Updated Tag Depth 2/62019 2GOfi aepron, Casing Strings Cason Dencrotion OD lin) ID tin) TOP IXK81 $e, Deon, lneig SO Dep,I U`v 1n. WLLen (I... Gratle Top Th ...d CONDUCTOR 16 15.116 38.0 110.0 110.0 6258 H -0D Welded Cesl,p .."Ince, ODlin) IDtinl TaPrI Se10epy Ker SN DepM (IVDL.. WLLen ll... re Top Inead Tdsn's'an"ou SURFACE 9518 9.21 37.2 3.133.9 2,78.7 36.00 J-55 BTC " DDlinl m(Inl top (nne) sn Depth mKa) seh Uepm liVOl... wean n_6nda in traced PRODUCTION ] 6.28 35.9 8,449.1 6223.8 26.0 J-55 aTC CONDDOTOR SID-11GO Tubing Strings Turing Pec iltion stanp "I... ID pnl T,P pi set De Po (X.. Se Depm HrVVp (.. W heal G,ade Top Connection TUBING WO 3112 299 30.1 7,9693 5,8414 9.30 L-80 EN dABMOD I MPPLE:447 Completion Details TnPfTD) Top Act Nominal Top IXND 1 1 1 (°I Hem Des Loin 1D lip 30.1 30.1 0.09 HANGER Velcos3ray Gen II TUBING HANGER 2938 524.7 524.6 1.18 NIPPLE 3YCmnco'DS Nipple cal 2.875 profile 2.875 OAS LIFT: 2851.a 7, 56.6 EMUS39.63 PBR PBR boo Assem6ly(sheared) WI 2' apace out STABBED INTO 2.980 PACKER ASSEMBLY Tunhp Dauflgbn SXhq Ma... to lIn) TaPKI San Issues Jr.. us, Depto IIVD) r Grade icp LonneGun TUBING PACKER 312 2.99 7.968.3 8.0436 I 5,899.1 jWDnml 9.30 L80 BRD EUE ASSY completion Details ToplrvDl 'DAct Nominal SURFACE, szzlaae- a Tap Pon) IXKD) (-) Nem Dez Com ID lin) ],966.3 5,840] 39.50 PACKER FHL Packer 3.030 8,011.2 5,8]3.8 39.03 NIPPLE 1OrY SNipple 2813 GAS LIFT: 4.5424 Other In Hole lWireline retrievable plugs, valves, pumps, fish, oto -P I'D) TOPlncl rnP mKD) mKag I°) Des tons Run Dpm ID lip 8.097.5 5941.4 37.98 Wirikeen 7' HEW WS failed 8 fell down hole, leaving evndow 10121201 2.800 casing exposed in 7' casing 8 GAS UFT d2Aa .132.0 59687 37.54 NS High Expansion NS High Expansion Wedge WS 1021201 8 0.000 Wedge WS NOWT INS Sid downhole. Likely lap at 8139 MD (10231181 8,136.0 5,971.8 37.49 High NS High Expansion Wedge WS 10/161201 0.000 Expansion 8 GAs LIFT: "N6.o Wedge WS e 158.0 5,989.3 3721 FISH LOWER PACKER FROM OLDOMPLETION,pxx V60008 OBOO PLUG, 8 REST OF TUBING DOWN TO WIRELINE RE- ENTRY GUIDE IS IN FILL. TAGGED HARD MUD@ 8158 SUA GAS LIFT T'�.y Pertorotions &Slots anw Den TaPIrvDI s,m lrv01 fseamm ropmMel elm mKe) mKel (X,02) Lne ) TypeCom 8,188.0 8,198.0 6,013.3 6,021.3 A -5.2G-06 9/24/198 4.0 WERE 90 deg Phasing; 4' 5. PHR?562 SchrumbeigeCast 8.216.0 8,246.0 fi.035J 5059.9 Ai M-06 W2411988 4.0 /PERF 90 peg. Phanng;4- PPCKEfl:].X63 1 SChlemberger Capi Mandrel Inserts 51 atl NIPPLE', 5011.3 at iap(N01 Who Latch PoXeNe TRORun N TopllMel (--)Mak¢ ModelODK Sen Type Tyfu tip feed) Run Date Com 2,951.5 55.1 amen MMG 112 GAS LIFT GLV RK .188 1, 4 .0 / 8 930 4,915.5 3,851.9 Camco MMG 112 GAS LIF VV RK 0.188 1,220.0 2/82018 1030 3 6,250.3 4,6462 Camco MMG 112 GA LIFT LV RK 0.188 1,21].0 2/82018 :00 4 1,246.0 5, 1 .fi Camco MMG 112 GAS LIFT GLV RK 0.186 1, .0 / / 018 9.30 5 ],898.2 578fi8 Camco MMG 11/2 GAS LIFT OV RK 0.250 0.0 20/2018 1030 Notes: General & Safety End Oat, annIXrtun HS Ker E,-. wedgl 1122000 NOTE; WORKOVER e .,To- 12110200] NOTE "MIT TESTING WILL HAVE TO USE DS NIPPLE @8008"" NS Mtn EAsecon Walge Ws, 12/10200] NOTE: WORKOVER a.tssa ]/22009 NOTE 5305' = TIGHT SPOT, UNABLE TO WORK 2.6- GAUGE RING PA 7 9 ]/2]2009 NOTE: VIeeShcematicwl Alaska SdremaKhO FIS"U'lac9.D IPERF:rustraa,15a0- IPERF', a31aDa.2esO� PRODUCTION; 35.$$445.1 2G-06 Proposed CTD Schematic 9-5/8" 36# J-55 shoe @ 3134' MD High Expansion Wedge @ 8095' MD, 38.01.49.06 Partial Window @ 8107' - 8109' MD Failed High Expansion Wedge Last Tag @ 8136' MD High Expansion Wedge @ 8134' MD Lower Packer from Old Completion @ 8158'M A5 -sand perfs squeezed 81881- 8198' MD A4 -sand perfs squeezed 8216'- 8246' MD _ 7" 26# J-55 shoe @ — 8449' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" DS landing nipple @ 525' MD (2.875" min ID) 3-1/2" Carrico MMG gas lift mandrel @ 2952', 4946', 6250', 7246'. and 7898' MD Baker 3-1/2" PBR @ 7957' MD (2.98" ID) Baker FHL packer @ 7968' MD (3.03" ID) 3-1/2" DS landing nipple @ 8011' MD (2.813" min ID) 3-1/2" tubing tail @ 8043.6' MD (8048' PDC) 2G-06LiPB1 TD @ 8,330' MD Washout, Cavings, and Packoffs @ –8170' MD 2G-06AL2-01 wp03 TD @ 9,900' MD Liner top at 8006' MD 2G-06AL2wp03 TD @ 9,900' MD �•�1 Liner Billet @ 8.400' MD 2G-06AL7 wp05 TD @ 9,750' MD Liner Billet @ 8,300' MD 2G-06Awp06 TD @ 9,750' MD Liner Billet @ 8,400' MD I TRANSMITTAL LETTER CHECKLIST WELL NAME: K�vl 26 / PTD: L G - 0 101 Development _Service _Exploratory _ Stratigraphic Test Non -Conventional FIELD: / CI POOL: /� Q. ru Gc i✓��l/ r ! Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _-� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: / Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs nm 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 2G-06A Program DEV Well bore seg Q PTD#: 2190190 Company CONOCgPHIL LIPS ALASKA INC Initial Classfrype DEV LP-END GeoArea 890 Unit 1116tL On/Off Shore On _ Annular Disposal ❑ Administration 1 Permit fee attached . . . . . . . . . . . . . . .. . . . . . . . . . . . . ............... NA....... _ _ _ _ _ _ 2 Lease number appropriate. . ......... . ............ . . . . . . . . . . . . . . . . Yes _ . _ _ _ _ _ Entire Well lies within A01,0025656.. 3 Unique well name and number - - - - - - - - - - - - - - - _ . .............. Yes ... _ 4 Well located in a. defined pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . Yes - - - - - - KUPARUK RIVER, -KUPARUK _RIV OIL-490100. 5 Well located proper distance from drilling unit. boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Kuparuk River Oil Pool, governed by Conservation Order No. 4320 _ _ .... 6 Well located proper distance from other wells_ _ _ _ _ . ............... Yes ..... _ Conservation Order No. 4320 has no interwellspacing.restrictions. Wellbore will be. more than 50Y 7 Sufficient acreage available indrilling unit... _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - from an external property linewhereownership or landownership changes. As proposed,well will. 8 If deviated, is. wellbore plat included...... Yes .... conform to-spacing-requirements.. 9 Operator only affected party.. - - - _ Yes - - - - - - - - - - - - --- -- - - - - - - - - - - - - - _ _ 10 Operator has. appropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ .. Yes. 11 Permit can be issued without conservation order . . . . . . ......... . . . . . . . . . . Yes Appr Date 12 Permit can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ ____ _ _ _ Yes 13 Can permit be approved before 15-day wait. ... _ _ _ _ Yes ...... . SFD 2/11/2019 14 W ellJocated within area and strata authorized by Injection Order # (put 10# in comments).(For. NA_ 15 All wells. within 114.mile area of review identified (For service well only).... ..... NA________ 16 Pre-produced injector; duration of pre Production lessi then.3 months (For service well only) NA . . . . . . . . . .................... . 17 18 Nongonyen, gas conforms to AS31,05.03%..1.A),(fZ-A-D) _ _ _ ........... . ... Conductor string. provided .. _ _ _ _ _ _ _ _ _ _ ... _ _ _ NA.......... NA- _ _ _ _ - Conductor set for KRU_ 2G-06 _ . - Engineering 19 Surface casing. protects all known. USDWs .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ Surface casing set in KRU 2G-06. 20 CMT. vol adequate to circulate on conductor& surf csg ...... _ _ .. NA _ _ _ Surface casing Set and fully cemented 21 CMT-vol adequate to tie4n long string to surf csg. . . . . . . . . . . .......... NA.... 22 CMT-will cover all known productive horizons .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ - Productiveintervalwill 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; all. waste-to approved disposal wells.. 25 If a_re-drill, has a 10x403 for abandonment been approved Yes _ _ _ _ - PTD 184-082, Sundry 319-065_ ....... 26 Adequate wellbore separation proposed........ .. _ _ _ _ _ _ Yes _ _ Anti-oollision analysis complete; no major risk failures 27 if diverterrequired, does it meet regulations_ _ _ _ _ .. _ _ _ _ _ _ NA...... Appr Date 28 Drilling fluid program schematic& equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ Max formation pressure is 4908 psig(15..5 ppg EMW),* will drill w/ 8,6-ppg EMW and. maintain overbal w/ MPD VTL 2/15/2019 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 30 SOPE_press rating appropriate; test to (put prig in comments) ........... . . . . . . Yes MPSP is 4320 psig; will test BOPs_to 4800-psig- 31 Chokemanifoldcomplies w/API. RP-53 (May 84). . . . . . . . . . . . . ........... Yes 32 Work will occur without operation shutdown..... _ _ _ _ _ _ _ Yes _ _ ... _ ...... I _______ 33 Is presence of 112S gas probable . . . . . . . . . .. . . . . . . ............ . . . . . Yes _ _ _ H2S measures required 34 .Mechanical-condition of wells within AOR verified (Forservice wall only) .............. NA......................... 35 Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ - Wells. on 2G-Pad are KS-bearing. 112S measures required, ........... . . Geology 36 Data.presented on potential overpressure zones. _ - _ _ _ _ _ _ _ _ . - . Yes _ - - _ - _ Max. potential res. pressure is 15.5 ppg EMW: expected-res. pressure is 12.4 ppg EMW, Well will be ..... Appr Date 37 Seismic analysis of shallow gas zones _ ....................... NA........ drilled using 8,6, ppg mud,.a coiled-tubing rig, andmanagedpressure drilling technique to control SFD 2/11/2019 38 Seabed condition survey (if off-shore) . . . . . . . . . . ..................... NA........ formation pressures and stabilize shale sections withconstantBHP of about12.4 ppg EMW. _ . 39 Contact name/phone for weekly.progress reports [exploratory only] . . . . .. . ...... . . .. NA .... . NOTE: Chance of encountering free gas while drilling due to gas injection performed in-this area. _ Geologic Date: Engineering Date Public Date Commissioner: Commissioner: Z �S �te Commissioner