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Home My WebLink About217-004ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD3-111A 50103205260100 2170040 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15.Well Class after work: Exploratory Development ServiceStratigraphic 16.Well Status after work:Oil Gas WDSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) WINJ W AG tion: tion: Gas-Mcf Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl W ater-Bbl summary: olumes used and final pressure: epth feet epth feet true vertical depth) d and true vertical depth) Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: mber):8. Well Name and Number: onic data per 20AAC25.071):10.Field/Pool(s): ry: ured feet feet tical feet feet ured feet feet tical feet feet CollapseBurstTVD 5.Permit to Drill Number: Size measuredPlugs Junkmeasured 4. W ell Class Before W ork: measured true vertical Packer MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:20 pm, Mar 31, 2020 DSR-4/8/2020VTL 4/8/20 SFD 3/31/2020 RBDMS HEW 4/2/2020 ConocoPhillips Alaska, Inc. PO Box 100360, Anchorage, AK 99510 217-004 50-103-20526-01-00 ADL 372105, 364471, 364470 CRU CD3-111A None Colville River Field/Fiord Oil Pool 11642 6922 None None 11595 6922 8008 6848 Conductor 78' 16" 114 114 Surface 2685' 9.625" 2721 2469 Intermediate 8496' 7" 8530 6933 Liner 3477' 4.5" 11609 6922 8897 - 10915 6943 - 6930 3.5" L-80 8149 6887 see attached see attached 8149 6887 8897' - 10915' MD Please see attached summary 161 119 556 999 234 226 1541 716 1113 251 N/AKaylie Plunkett Senior Production Engineer Kaylie Plunkett Kaylie.B.Plunkett@conocophillips.com 265-6450 Scale Inhibition ✔ ✔ ✔✔ ✔ CD3-111A Scale Inhibition Treatment 2/26/20 Hybrid Scale Inhibitor Squeeze Job pumped from 0300 – 1100 hrs on 2/26/20. LRS = Little Red Services x Initial pressure TBG/IA/OA – 750/950/375 x LRS pumped 113 bbls WAW5206/Diesel/M209 preflush at 1.5 – 2.5 bpm, TBG/IA/OA – 50/910/210 x LRS pumped 113 bbls Seawater and SCW3001WC scale inhibitor main treatment at 2.5 – 3.3 bpm, TBG/IA/OA – 50/910/210 x LRS pumped 1113 bbls Dead Crude/M209 overflush at 3.0 - 3.5 bpm, TBG/IA/OA – 1650/900/300 x Final pressure TBG/IA/OA – 0/900/300 Interval treated: 8897’ – 10915’ MD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 8008' MD, 6848' TVD SSSV: TRMAXX-5E TRSV, 2150' MD, 2010' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NAK U t Lu 9 1. Operations Abandon Plug Perforations Ll Fracture Stimulate Ll Pull Tubing ,._Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑� 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development E Exploratory ❑ Stratigraphic ❑ Service ❑ 217-004 3. Address: PO Box 100360 6. API Number: Anchorage, AK 99510 50-103-20526-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 364471, 364470 CRU CD3 -111A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 11642 feet Plugs measured None feet true vertical 6922 feet Junk measured None feet Effective Depth measured 11595 feet Packer measured 8008 feet true vertical 6922 feet true vertical 6848 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2685' 9.625" 2721' 2469' Intermediate Production 8496' 7" 8530' 6933' Liner 3477' 4.5" 11609' 6922' Perforation depth Measured depth Liner with frac sleeves, 8897'- 10915' True Vertical depth 6943' - 6930' Tubing (size, grade, measured and true vertical depth) 3.5" L-80 8149' MD 6887' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 8008' MD, 6848' TVD SSSV: TRMAXX-5E TRSV, 2150' MD, 2010' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8897'— 10915' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 259 359 684 1164 238 Subsequent to operation: 471 480 803 1252 251 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil R] Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Production Engineer Contact Email: Kavlie.B.Plunketta( ..coo.com Authorized Signature: ( Date: 7—G — I Contact Phone: 265-6450 ru Form 10-404 Revised 4/2017 !r Tl- 3//S// 9 "3BDMS* MAR 0 8 2019 Submit Original Only CD3 -111A Scale Inhibition Treatment 2/5/19 Hybrid Scale Inhibitor Squeeze Job pumped from 10:00 —23:00 hrs on 2/5/19. LRS = Little Red Services • Initial pressure TBG/IA/OA-750/1042/366 • LRS pumped 113 bbls WAW5206/Diesel/M209 preflush at 5.0 bpm, TBG/IA/OA-400/1007/309 • LRS pumped 113 bbls Seawater and SCW3001WC scale inhibitor main treatment at 5.0 bpm, TBG/IA/OA — 450/997/312 • LRS pumped 1720 bbls Dead Crude/M209 overflush at 3.5 bpm, TBG/IA/OA —1600/1010/470 • Final pressure TBG/IA/OA-100/1000/350 Intervaltreated: 8897'— 10915' MD STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment LI 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory❑ 217-004 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20526-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372105, 364471, 364470 CRU CD3-111A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 11642 feet Plugs measured None feet true vertical 6922 feet Junk measured None feet Effective Depth measured 11595 feet Packer measured 8008 feet true vertical 6922 feet true vertical 6848 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2685' 9.625" 2721' 2469' Intermediate RECEIVED Production 8496' 7" 8530' 6933' Liner 3477' 4.5" 11609' 6922' MAR 092018 Perforation depth Measured Depth: Liner with frac sleeves, 8897'- 10915' OGCC True Vertical Depth: 6943'-6930' Tubing(size,grade,measured and true vertical depth) 3.5", L-80, 8149' MD, 6887'TVD SCANNB ' a Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 8008' MD, 6848'TVD SSSV: TRMAXX-5E TRSV, 2150' MD, 2010'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9226'- 11550' CTMD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 457 281 704 1156 261 Subsequent to operation: 483 415 783 1200 284 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory❑ DevelopmentL Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kaylie Plunkett i IN V &o09 Email Kavlie.B.Plunkettacop.com Printed Name Kaylie Plunkett Title Production Engineer Signature -e00c-2 Phone 265-6450 Date 311 ( 1 ci V77, 3)J. /ii ,' 3/ %' RED "S t,t- rv;;, 2018 Form 10-404 Revised 5/2015 Submit Original Only • CD3-111A Scale Inhibition Treatment 2/14/18—2/17/18 Non-Aqueous Scale Inhibitor Squeeze Treatment pumped from 11:00 hrs on 2/14/18 to 04:30 hrs on 2/17/18. LRS= Little Red Services CT=Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA—283/1174/97 - RIH with CT to 11550' CTMD - Pumped 112 bbls Diesel/M209/WAW5206 pre-flush through CT at 1.6 bpm while pulling CT from 11550'—9226' CTMD. TBG/IA/OA—566/1917/141 - RBIH with CT to 11550' CTMD - Pumped 220 bbls 70/30 EG/Seawater and SCW3001 scale inhibitor through CT at 1.5 bpm while pulling CT from 11550'—9226' CTMD. TBG/IA/OA—1806/1904/13 - POOH with CT. LRS pumped 3180 bbls dead crude/M209 over-flush at 2.1-4.0 bpm. TBG/IA/OA—1850/2360/600 Interval treated: 9226'—11550'CTMD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 55 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate A Pull Tubing ❑ Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number. Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic❑ Service ❑ 217-004-0 3. Address: p O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20526-01 7. Property Designation (Lease Number): 8. Well Name and Number: CRU CD3 -111A ADL 372105, ADL 364471, ADL 364470 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NONE Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,642 feet Plugs measured None feetR EC E I V. true vertical 6,922 feet Junk measured None feet MAY 1 1 20 Effective Depth measured 11,605 feet Packer measured $008,8131 feet true vertical 6,923 feet true vertical 6848, 6883 feet q OGC Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 114' MD 114 TVD SURFACE 2,685 feet 9 5/8 " 2,721' MD 2469 TVD INTERMEDIATE 8,496 feet 7 8,530' MD 6933 TVD LINER 3,478 feet 41/2" 11,609'MD 6922 TVD Perforation depth Measured depth 0 feet True Vertical depth 0 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 8,149' MD 6,887' TVD Packers and SSSV (type, measured and true vertical depth) PACKER= Baker Premier Removable 8008 MD 6848 TVD PACKER = HRDE ZXP Liner Top 8131 MD 6883 TVD SSSV: TRMAXX-5E 2150 MD 2010 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8,888-- 10,909 - Treatment descriptions including volumes used and final pressure: Total Well -4 stages 408,300lbs placed .... See attached schematic for fulf FRAC details 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A No Pre -Frac Production Subsequent to operation: 3496 3330 3469 1580 374 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.293) 15. Well Class after work: Daily Report of Well Operations\' n Exploratory❑ DevelopmentE] Service ElStratigimphic E]Copies of Logs and Surveys Run ElkL1*1y \\ 16. Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ \a GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 317-138 Contact Name: Hanna Sylte Authorized Name: Hanna S Ite Contact Email: Hanna.Sylte@oonocophillips.com Authorized Tile: Completion Engineer C1?AmlContact Phone: (907) 265-6342 Authorized Signature: Date: 5 a evi a ,�/ RBDMS 1/t/ MAY 162017 �.¢ u y F7141/l' �l b/77�0/7 ero — — CD3 -111A FRAC STIMULATE DTTMSTJOBTYP SUMMARYOPS 4/11/17 FRACTURING Warm up equipment, fluid pack surface lines, PT 4,100, RIH, preforming WC's, at all frac sleeves, set down 10,893' CTMD, minus 10k, sleeve shifted at 2,500 psi, lost 5k CTSW, WHP 656 psi, PUH to TT, perform injectivity test, 0.5 bpm at 2,000 psi, 1.0 bpm at 2,000 psi, 1.5 bpm at 2,100 psi, POOH, Inspect INJH, RDMO, Spot up onCD3- 115 4/13/17 FRACTURING PUMP 4 STAGE FRAC PER DESIGN, PLACED 408,300 LBS OF WANLI 20/40 SAND. WELL IS FREEZE PROTECTED WITH 30 BBLS LVT JOB COMPLETE. 4/17/17 FRAC PULLED ISO SLEEVE FROM 2150' RKB. BRUSHED & FLUSHED TBG TO 8025' RKB. SET 2.81" CAT SV @ 8025' RKB. MADE MULTIPLE ATTEMPTS TO PULL DV FROM 7628' RKB, TOOLS FOULED BY FRAC SAND. PULLED CAT SV FROM 8025' RKB. IN PROGRESS. 4/18/17 FRACTURING BRUSH & FLUSH GLM's @ 7628',6286'& 3790' RKB. SET 2.81" CAT SV @ 8025' RKB. PULL DV @ 7628' RKB. REPLACE WITH 1/4" OV. PULLED DV @ 6286' RKB (LATCH SPRING DAMAGED & LATCH FLOW CUT). REPLACED WITH 3/16" GLV (TRO = 1855). PULLED DV @ 3790' RKB. REPLACED WITH 3/16" GLV (TRO = 1863). ATTEMPT TO PRESSURE TBG. IA TRACKING. PULL SUSPECT GLV @ 6286' RKB (BOTH PACKING STACKS DAMAGED WHEN SETTING/ 3/4" LONG METAL GOUGE BELOW NO-GO ON LATCH). IN PROGRESS. Hydraulic Fracturing Fluid Product Cc Dnent Information Disclosure Fracture Date State: County: API Number: Operator Name: Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Production Type: 2017-04.13 Alaska Harrison Bay 5010320626 CONOCO PHILLIPS NORTH SLOPE EBUS FIORD CD3 -111A .150.91 70.42 none Abstract True vertical Depth (TVD): Total Water Volume (gal)": 6,915 195,272 Fracturing Fluid Composition: Crystalline silica, quartz 14808-60-7 1 30.00%1 0.00574% Curad acrylic resin Proprietary 1 30.008 0.00565% phenolic resin 1Proprietary 30.0081 0.02380% 1,2-ethaned'ryq, alpha-(4- nvll-omeca-hvdroxv-. 127087-87-0 1 5.008 0.00297% I Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Number (CAS (% by mass)" HF Fluid (% by #) mass)** Sea Water Operator Base Fluid Water 7732-18-5 96.00% 75.38315% BE -6 MICROBIOCIDE Halliburton Biocide Listed Below Listed Below CL -22 UC Halliburton Crosslinker Listed Below Listed Below CL -31 Halliburton Crosslinker Listed Below Listed Below CROSSLINKER LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Listed Below MO -67 Halliburton pH Control Additive Listed Below Listed Below OPTIFLO-III DELAYED RELEASE Halliburton Breaker Listed Below Listed Below BREAKER SP BREAKER Halliburton Breaker Listed Below Listed Below WG -36 GELLING Halliburton Gelling Agent Listed Below Listed Below AGENT LVr-200 Penreco Additive Listed Below Listed Below Xinmi Wanli Wanli 20140 Industry Proppant Listed Below Listed Below Developmen I Co., Ltd Ingredients Listed Listed Above 1,2,4 Tdmethylbenzene 95-63-6 1.00% 0.00059% ve 2-Bromo-2-nitro-1,3-propanediol 5251-7 100.00% 0.00212% Acrylate polymer Proprietary 1.00% 0.00090% Crystalline silica, quartz 14808-60-7 1 30.00%1 0.00574% Curad acrylic resin Proprietary 1 30.008 0.00565% phenolic resin 1Proprietary 30.0081 0.02380% 1,2-ethaned'ryq, alpha-(4- nvll-omeca-hvdroxv-. 127087-87-0 1 5.008 0.00297% I lium glycollate 2836-32-0 1.00% 0.00090% -odium hydroxide 1310-73-2 30.00% 0.02475% Sodium persulfate 7775-27-1 100.00% 0.00047% Sodium sulfate 7757-82-6 0.10% 0.00000% Ulexite, calcined 92908-33-3 60.00% 0.05411% Water 7732-18-5 100.00% 0.13423% Total Water Volume sources may include fresh water, produced water, and/or recycled water " Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate supplier who provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Plea criteria for how this information is reported on an MSDS is sub act to 29 CFR 1910.1 200 i and Appendix D. Ingredient Mass Ibs Comments Company First Name Last Name Email Phone 1600913 Density &540 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 13 45 20 Denise Tuck, Halliburton, 3000 N. Sam Houston TX 7 E., Houston, TX 77032,281- 871-6226 Halliburton Denise Tuck Denise.Tuck @Halliburton.c om 281-871-6226 400 244880 122 120 Halliburton Denise Tuck Denise.Tuck @Halliburton.c om 281-871-6226 759 5178 380 36330 163320 64 507 Halliburton Denise Tuck Denise.Tuck @Halliburton.c om 281-871-6226 64 1150 44 524 20 66743 20 526 10 1 1150 2852 W3 and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the ise note that Federal Law protects "proprietary", Irade secret", and "confidential business information" and the 3. WNS PF 1 ConomPhillips wen naribMtes Alaska. Inc. vxobereppvuwl pwlal 33-111A 3252006 AnnMa4on Oepuffie NB) Fne Dohpnnobtlon lint MOE By EnU Deb .. ... ....... __.._. _____. .. Last Tag: Rev Reason: SIDETRACK, PULLED PLUG, ISO pop. 5110201] SLEEVE and GLV CIO HANGER: 310 a8 ng ainngs CasmR Oei[Nplion O011nl in(I.) Top boost Set Depth deal SOumipN IiV01... IN.. iI.. .,.an Top TL. CONDUCTOR 16 15010 36.0 1140 114.0 MOO J-55 Welded Paw, Da-,.,I.n OO gni ID (in) TOP(M(B) sou'pM(rtKel Set DepM(I.I... WV1ea Ill. Grant TepTh- SURFACE 9518 8.835 36.3 2.721.0 2,469.4 40.00 L-80 BTC Pasha Oasengbn OD (In) IDenlTop pool SO DooM1 In SO DepM(NDI-� Wako 11... Grade TePlb�uit- INTERMEDIATE 7 6.278 341 8,530.0 6,933.4 2600 L80 ST( Casing Desnnptmn OD(in) ID (in) Top(WB) Set DeP10(DNB) Ser DepMnVIO WVLen n... Grave Tup Thread LINER 4112 3.958 8,1315 11 60all 6,019 12.60 L-80 TXP Liner Details CONDU¢ioRI MM11140 Too (-a) Top(TV01(XNB) Toplwlrl Item Des Com Nominal to tin) 8,131.4 6,883.1 76.03 PACKER Liner Top Packer,HEIDE ZXP, vall ZbSBE 4350 8,151.4 6,88].8 76.96 NIPPLE RS Nipple, 6-12', Hyd563 4.250 8,1543 6,8884 77.09 HANGER Liner Hanger,DG FL pinned 2500 psi 4.290 0,163.3 6,8904 7751 XO Reducing XO,L-80,512" Hyd563 Box X 412'TXPPin 3.920 (Casing) 8.898.7 6,942.8 90.74 Frac Sleeve Baker Express Froc Sleeve#4(2W bll a,"9481 1.90 SAFE111.Zlx.o Tuts"I 3.1 A.3 9,226.1 6,935.7 91.11 ECP(External Sa1bl FacPacker, BTC #4 3.958 CSG Packer( 9,560.1 6,930.9 90.61 Fac Sleeve Baker Express Frac Sleeve #3(1938"ball. 1.0859D) 1.885 C. sRveavae: z.ut olds SURFACE: Sb2Rt.D 9,894.0 6,929.2 89,91 ECP (Eckman Sakes FrocPacker, BTC 93 3.956 CSG Packer) 10,237.1 6,929.5 89.91 Fac Sleeve Baker Express Frac Sleeve #2(1.0]5' ball, 1.81 1.823 Goa UR: a.nd.0 10,5730 6,929.0 90.18 ECP(Eaernal Sahel FracPacker, BTC #2 308 CSG Packer) 10,915.0 6,930.2 89.28 Frac Sleeve Baker Express Fac Steen #1(1.813"ba11,1.76'ID) 1760 11,243.9 6,921.4 91,74 ECP (External Saltel FrocPackeO BTC In 3,958 Gas LIR',.. a CSG Packer) 11,580.9 6,922.5 90.78 Port Collar Alpha Pressure Sleeve -10,50psi Burst Pressure' 3.00 GAe LIFT; Test4 11594.5 6,922.3 90.]8 Valve WIV(Wellbore l sualion valve)ball on Seat 0000 omle 7Set e Tubing Strings Tubng Description Stone Ma_. 10 (inn Top(ONE, SIN Depb m.. aN Depth (ND (-. I'm, Grade Top Gonnec0m TUBING 3112 2.992 31 0 8,149.0 6,8822 9.30 L-80 EVEBrdM Soviet pang.; Testa Completion Details Too ME) Top ".)(Mea) I Top mel I') nem Daa corn Nominal to (In) PACxER, a,poa.4 310 3101 0.09 HANGER FMC 4-12" Tubing Hanger TXP 3958 NIPKE:4ozae 753 753 022 XG Reducing CROSSOVER,412'TXP X 312'EUE,BP 2992 ,150.0 2,009.9 38.28 SAFETYVLV TRMAXX-5E, TRSV, TC -11 2812 LDcAToe; alzr.z 7,645.6 6.686.8 56.08 NIPPLE NIPPLE.UNDING}1/2",X.2813',EUE8RDM 2.813 LocniDR:B1m.1 7964.8 6,832.6 68.94 Gauge/Pump PTS Gauge Cooper, 93#L-80 EUEArd w 2.913 MULESNDE', 8, 1479 Sen40r coupling 8,0084 6,8473 70.67 PACKER Baker Prenvier Packer 3Ia'x T removable 2.870 0,024.9 6,853.1 7135 NIPPLE NIPPLE,1ANDING,312-,XN,2.813%EUEBRDM, 2.75 no- 2.813 go WARHC (pulled RHC plug on 4/9201]) 8,127.2 6,8821 7584 1 LOCATOR Mechanical Iocalor, EUE (6' OD Iocawr) 2.970 8,128.1 6,882.3 ]5.88 LOCATOR Mechanical locator shear sub 16 to shearscrews) 2.970 INTERMEgPTE; X14531X145318,147.9 68870 IS /9 1 MULE SHOE I Baker WLEG 3000 Stimulations &Treatments vmppent Desgnea06) Hma woppann Formation (to) Dam NO ncAbMnCB.esap t t 4/42013 pmppant Desynad ltb)mPwnHn Formation lie) .M D 1ments 102,009 01 4I1320n Stimulations 8 Treatments Vol Clean Pump .W. Top dKB) tom ons) Date Sminamet Fuel (bbg Volslurry(Wg 1 0.0 00 411312017 Hybor G, Gelled Soft Water 0.0 0.00 2 10,909.0 10.910.0 411 Y209 Hybor G, Gelled Sell Water 1561.0 166500 Ny4FmGMWM r. e.rao t 3 10,231.0 10,232.04/13"1017 Hybor G, Gelled Salt Wafer 112].0 1230.0 4 9,553.0 9,554.0 4/13201] Hybor G, Gaged Salt Walter 994.00 1099.60 5 8,888.0 8,IftatU 1132017 Hybor G, Gelled Salt Weser 1092.00 1200.60 Mandrel Inserts aS Np FraczlvMaM, 10.Yn0 1 � an N Top (flN81 Top jN01 (MtBI Make ModN OD (in) She", TV. TYPe TYPa type Po0SW IMI Test IWq Run Dant Com 3,790.0 3,4163 Co.. KBMG 1 GAS LIFT GLV BK 0.188 1,863.0 4/182017 2 6,2863 5,613.0 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,855.0 4/192017 High Seal PKIN G 3 7,628.4 6,6769 Camco KBMG 1 GAS LIFT OV BKO-3 0250 0.0 5132017 EXT Nye rx-Ga vemeno r toads. PAC KING WO - RS ING JI &131 S-nS l MEMORANDUM TO: Well File 2�2 1�h'Zv�(17 From: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 4/28/17 SUBJECT: Surface Casing Repair CRU CD3 -111A PTD 2170040 April 28, 2017: 1 received a notice from Roger Mouser (CPAI Well Integrity Supervisor) for opportunity to inspect the surface casing on CRU CD3 -111A on Sunday 4/30/17. Mr. Mouser travelled to CRU CD3 -pad today and requested AOGCC move up the inspection as it was the last day for the ice road. AOGCC Inspector(s) could not attend on short notice. Mr. Mouser provided photos showing the area surrounding the conductor had been excavated to make repairs on surface casing. A UT scope had been performed on the surface casing to establish wall loss on the surface casing. A 0.42 -inch reading was obtained out of the original pipe wall thickness of 0.50 inches. CPAI repairs include installing threaded plugs in the breach points, applying a Densco wrap to the surface casing from the excavated ground level to as close as possible to the bottom of the tubing hanger, and welding a pipe patch to the conductor. CPAI has been notified to update AOGCC on any and all progress or issues with said repairs on this well. Attachments: Pictures (9) Non -Confidential 2017-0428_Casing_Repair_C RU_C D3- I I I A.docx 1 of Casing Repair — CRU CD3 -111A (PTD 2170040) Photos courtesy of CPAI 4/28/2017 Conductor cut to excavation depth for surface casing repair Threaded plugs installed in breach points 2017-0428_Casing_Repair_CRU_CD3-111 A.docx 2 of 6 Liz M3 J C UT survey results; layout for planned repairs 2017-042 8_Casing_Repair_CRU_CD3-111 A. docx 6of6 DATA SUBMITTAL COMPLIANCE REPORT 7/10/2017 Permit to Drill 2170040 Well Name/No. COLVILLE RIV FIORD CD3 -111A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20526-01-00 MD 11642 TVD 6922 Completion Date 4/8/2017 Completion Status 1-0IL Current Status 1 -OIL LIC No REQUIRED INFORMATION Mud Log No Samples / No Directional Survey Yes V DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint) 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_ Com_ments ED C 28183 Digital Data 3236 5112 5/9/2017 Electronic Data Set, Filename: CPAI_CD3- 111A_Scope Gamma Ray_RM_LAS_LW D001.1as ED C 28183 Digital Data 5073 8540 5/9/2017 Electronic Data Set, Filename: CPAI_CD3- ' 111A Scope Gamma Ray_RM_LAS _LW D002.1as ED C 28183 Digital Data 8500 11642 5/9/2017 Electronic Data Set, Filename: CPAI_CD3- 111A_Scope Resistivity_RM_LAS_LW D003.las ED C 28183 Digital Data 3228 11642 5/9/2017 Electronic Data Set, Filename: CPAI_CD3- 111A_Scope Resistivity_RM_LAS.Ias - ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CD3-111 A_Scope , Resistivity_RM_LW D001.diis ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CO3-111 A_Scope ' Resistivity_RM_LW D001.html ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CD3-111A_Scope ' Resistivity_RM_LW D002.dl is ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CD3-111A_Scope . Resistivity_RM_LWD002.html ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CD3-111A_Scope , Resistivity_RM_L W D003.dlis ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CD3-111A_Scope - Resistivity_RM_LWD003.html ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CD3-111A_Scope' Resistivity_RM.dlis ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI_CD3-111A_Scope - Resistivity_RM.htm I AOGCC Page 1 of 3 Monday, July 10, 2017 DATA SUBMITTAL COMPLIANCE REPORT 7/10/2017 Permit to Drill 2170040 Well Name/No. COLVILLE RIV FIORD CD3 -111A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20526-01-00 MD 11642 TVD 6922 Completion Date 4/8/2017 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI CD3 - P 111A_Scope_Resistivity_2MD_RM.pdf ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI CD3 - 40 111A_Scope_Resistivity_2TVD_RM.pdf ED C 28183 Digital Data 5/9/2017 Electronic File: CPA[—CD3- 1P 111A__ScopeResistivity_5MD_RM.pdf , ED C 28183 Digital Data 5/9/2017 Electronic File: CPAI CD3 - 42 111A_Scope_Resistivity_5TVD_RM.pdf ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD27 EOW . Compass Surveys.pdf ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD27 [Canvas].txt ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD27 [Macro].t# ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD27 [Petrel].txt . ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD27 [Surveys].txt ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD83 EOW . Compass Surveys.pdf ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD83 [Canvas].txt ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD83 [Macro].txt ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD83 [Petrel].txt - ED C 28183 Digital Data 5/9/2017 Electronic File: CD3 -111A NAD83 [Surveys].txt Log C 28183 Log Header Scans 0 0 2170040 COLVILLE RIV FIORD CD3 -111A LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVE Completion Report Y Production Test Informatio 'Y / NA Geologic Markers/Tops Y Directional / Inclination Data Mud Logs, Image Files, Digital Data Y (6) Core Chips Y / Mechanical Integrity Test Information Y NA Composite Logs, Image, Data Files Core Photographs Y / Ali Daily Operations Summary Y� Cuttings Samples Y /5 Laboratory Analyses Y / dA AOGCC Page 2 of 3 Monday, July 10, 2017 DATA SUBMITTAL COMPLIANCE REPORT 7/10/2017 Permit to Drill 2170040 Well Name/No. COLVILLE RIV FIORD CD3 -111A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20526-01-00 MD 11642 TVD 6922 COMPLIANCE HISTORY Completion Date: 4/8/2017 Release Date: 3/1/2017 Description Comments: Compliance Revie Completion Date 4/8/2017 Completion Status 1-0I1 Current Status 1-0I1- Date Comments Date: n t UIC No AOGC''C' Page 3 of 3 Monday, July 10, 2017 STATE OF ALASKA ALAN OIL AND GAS CONSERVATION COMMIt. )N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations LJ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 111 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑lJ �'V Alter Casing ❑ Change Approved Program ElPlug for Redrill ElPerforate New Pool ElRepair Well N( Re-enter Susp Well ❑ SC Repair 0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic E) Service El6. 217-004 3. Address: API Number: P.O.Box 100360, Anchorage, Alaska 99510 50-103-20526-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105, 364471, 364470 CRU CD3 -111A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Coville River Unit / Ford Oil Pool 11. Present Well Condition Summary: Total Depth measured 11644 feet Plugs measured NA feet true vertical 6874 feet Junk measured NA feet Effective Depth measured 11609 feet Packer measured 8008 feet true vertical 6922 feet true vertical 6847 feet Casing Length Size MD TVD Burst Collapse Structural NA NA NA NA NA NA Conductor 78 16 114 114 NA NA Surface 2685 95/8 2721 2469 NA NA Intermediate 8496 7 8530 6933 NA NA Production Liner 3478 41/2 11609 6922 NA NA Perforation depth Measured depth 8897-10915 feet RECEIVED True Vertical depth 6930-6943 feet MAY 16 2017 Tubing (size, grade, measured and true vertical depth) 3 1/2, L-80, MD 8149, TVD 6887 CAMCO TRMAXX-5E, TRSV, TC -11, MD 2150, TVD 2010 Packers and SSSV (type, measured and true vertical depth) Baker Premier Packer 3 1/2 X 7 removable, MD 8008, TVD 6848 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:I NA NA NA NA NA Subsequent to operation: I NA NA NA NA NA 14. Attachments (required per 20 AAC 25.070, 25.071. & 25.283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development❑ Service ❑ Stratigmphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Of p Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 317-174 Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Field Supervisor Contact Email: N1927&bconoconhillios com C Authorized Si '403 nature: Date: Contact Phone: 659-7506 Form 10-404 Revised 4/2017 `�T�' RBDMS �L I A V 7 2� I% Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 13, 2017 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster: RECEIVE® MAY 16 2017 AOGCC Enclosed please find the 10-404 for surface casing repair on well CD3 -1 I IA, PTD 217-004, Sundry 317-174. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, C Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Enclosures: Summary of work 10-404 Pictures of damage and repair SUMMARY 4/26/2017 Verify surface casing leak - cut windows and found leaks between 14" and 17" from conductor top. 4/29/2017 Repair damaged surface casing. 5/1/2017 SCLD passed. 5/2/2017 Denso wrap and install 5.5' of 16" conductor. H 41rS��• 4 .�A n 1 THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR BILL WALKER Travis Smith Well Integrity Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3 -111A Permit to Drill Number: 217-004 Sundry Number: 317-174 Dear Mr. Smith: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy h'. Foerster Chair DATED this %day of May, 2017. RBDMS 1, --PAY 1 6 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAY 0 2 2017 AQGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: SC Repair ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 • Stratigraphic ❑ Service ❑ 217-004 3. Address: 6. API Number: P.O. Box 100360 Anchorage, AK 99510 50-103-20526-01 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' CRU CD3 -111A ' Will planned perforations require a spacing exception? Yes ❑ No Q 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 372105, 364471, 364470 + I Coville River Unit / Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (Wi Effective Depth MD: Effective Depth TVD: I!(1o1609" �tt�,32Y2+�f 11609 6922 MPSP (psi): Plugs (MD): Junk (MD): Casing Length Size MD TVD Burst Collapse Structural Conductor 78 16 114 114 Surface 2685 9% 2721 2469 Intermediate 8496 7 8530 6933 Production Liner 3478 4 M. 11609 6922 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8897 - 10915 6943— 6930 3 % L-80 8149 Packers and SSSV Type: Camco TRMAXX-5E Packers and SSSV MD (ft) and TVD (ft): 2150/2010 Baker Premier Packer 8008/6848 12. Attachments: Proposal Summary Q Wellbore schematic r7 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� . Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/29/2017 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 4 Commission Representative: V" L.9 GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Travis Smith Contact Name: Travis Smith / Rachel Kautz Authorized Title: Well I grity Supe Contact Email: 1\12549 Conoco hilli s.com Contact Phone: 659-7126 Authorized Signa re: Date: COMMIS ION U E ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: L F /1 Post Initial Injection MIT Req'd? Yes ❑ No Ltd Spacing Exception Required? Yes ❑ No Subsequent Form Required: (J — ¢ U 4)t' 2017 RBDMS MAY 16 APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: /1 /^ � A / Submit Form and Form 10-403 Revised 4/2017 U _�b\,pJv d Ii�lti n is valid for 12 months from [he date of approval. Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 27, 2017 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West r Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: RECEIVED MAY 0 2 2017 AOGCC Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well CD3 -111A (PTD# 217-004) for a proposed surface casing repair. Please contact Travis Smith or Rachel Kautz at 659-7126 if you have any questions. Sincerely, Travis Well Integrity Supervisor ConocoPhillips Alaska, Inc. ConocoPhillips Alaska, Inc. CRU CD3 -111A (PTD 217-004) SUNDRY NOTICE 10-403 APPROVAL REQUEST April 27, 2017 This application for Sundry approval for well CRU CD3 -111A is for the repair of a surface casing with a near -surface leak. Diagnostics have indicated that there are leaks 14 —17 inches beneath the wellhead, and further investigation may reveal more leaks as well. ConocoPhillips requests approval to inspect and repair the surface casing. The following general steps will be followed for the surface casing repair: 1. Verify that the well has been secured from the reservoir with a mechanical plug in the tubing, tested with a passing draw -down test. Verify the OA (7" x 9-%") has been bled to 0 psi. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around wellhead and excavate to approximately 20' depth if necessary from surface casing inspection. 4. Install nitrogen purge equipment for the conductor and the OA (if needed) so that hot work may be performed in a safe manner. 5. Cut away the conductor and the cellar and remove cement from the outside of the surface casing. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for the final integrity check. 8. Perform a low-pressure test (Open OA shoe) to confirm no fluid to surface. 9. Install anti -corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to injection. 13. File 10-404 with the AOGCC post repair. JjW WNS PROD CD3 -111A ConOCoPiiillips Wall Attributes Max Angle &M4 TD Alaska.91C. 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Grate Top road LINER 41!2 3.958 8,131.5 11,609.1 6,9221 1260LA0 TXP Liner Dealls cox.ucroR; 9ea.n.A m IIG Top 1813 Toplry Top ion nem Gas e4m Na 1141 618831 G3 8,1314 6,883.1 76 G3 PACKER Liner Top PackegNROE ZXP, 111.25' SEE 4,350 8,1514 0,087.8 76.96 NIPPLE RS Nipple, 5-112', Hyd563 4250 8,154.3 8,888.4 )].09 HANGER Liner HangeGDG FI-Noned 2580ps1 4.290 8,163.3 6,890.4 77.51 XO Reducing X0,L-80,812' HydE63 Box X 412"TXP Pin 3.920 (Casing) 6,8967 6,942.8 90.74 Frec Sleeve Baker Express Frac Slarve#4(2.00' ball, 1.848'10) 1.940 e55V; 2.+54.4 MaNlq],+513 9,228.1 8,935.7 91.11 ECP (External Salted FacPeckeq BTC #0 3058 CSGP. CSG Petl,er) 91560.1 6930.9 90.01 Fine Sleeve Baker Exeress Free Sleeve#3(1.938' bell, 1.8861D) 1.805 SURFACEg6.3-2391.0- 9,894.0 6,929.2 MAN EClogatemal Segal Ffacloacker, BTC Oct 3.958 CSG Packer) 10,237.1 6,929.5 89.91 Frec Sleeve Baker E%press Frac Sleeve#2(1.8]5"ball,1.823.10) 1.823 MaMaS 3.]800 10,573.0 8,929.0 90.18 ECP (Exlemal S811e1 FrecParkep BTC #2 3050 CSG Packer) 10,9150 6,9302 89.28 Fac Sleeve Baker Express Ftac8leeve#1(1300 ball, 1J6"ID) 1.760 11,243.9 6,9274 91.74 ECP (External Sallel FarPackee OTC #1 3.958 Maweta2aa.3 GSGP.d.o 115869 6922.5 90.)8 Poli Collar Alpha Pressure Sleeve'10,500psi Burst Pressure' 3.000 115945 6,9223 96]8 Valve WIV(Wchbole Itelate, Valve) gall on Seal 0.090 MaNeS ).899.4 NIPPLe I,6416 Tubing Strings Ting oeaoipgo4 sfn4y In a... m114) Top nna) sot onpm n_sat oepm (rvol t -wt Omfy Grade ropeonnacen4 r,r,-pradudlon 31rz 2992 31.0 8,149.0 6,0822 9.30L-80 EUE8cM ..calPmlplacer"Aser Completion Details xomina110 T.,penel Top(TVBj groin Tap In.) P) Ihm Ges core (In) 31.0 Hanger FMC 4-12' Tubing HacgerTXP 3.958 Pe¢erlTudlpj; 9.409.4 2,150.0 SSSV TRMAXX5E, TRS", TG -II 2.012 NI111-E6,42a.9 7,645.6 6,686.6 55.08 NIPPLE NIPPLE,LANDING,312',X,2.013-,EUE6RDM 2.813 wa.KK:a mz LouKK: e.laal 7,964.8 6,832.8 68.94 Gaugel Pump PTB Gauge Center, 9.3# L-80 EUE-Bed Ploo In wA.p 2.913 Sensor coupling 8,024.9 6,853.1 71 35 NIPPLE NIPPI.E,LANDING,312",XN,2.8 T,EUE8RDM, 2.75 n.- 2.813 wxere,8,143s go WIRHC 8,127.2 6,882.1 ]5.84 Locator Mechanical Israel, EUE(8' OD kcal.,) 2.970 0,128.1 6,882.3 75.88 Locator Mocnanical local., abler sub 1.5' [Barrel a..) 2.970 8.14].9 6.88].0 ]6.79 Fle Shoe Baker WLEG 3 XT) Stimulations & Treatments Pr4ppam Gesigme Onl Pmppamm F4m,au4n pal Date IMERNEOIATF, 94,+.0$300 0!4!2013 Froppanl Oeed-6b)#pant P In Pormanon(IN ..to 100,090.0 t9z9960 011912017 Hp Fora i3na.leceeae.A t I Stimulations B Treatments vol meat Pump stgw Top lnl<o) otm lnleBl .is su,4lneat Fluor (eb0 vm s44y (enq 1 60 604113200 Hybor G. Gelled Salt Wrote, 0.00 0.90 2 10,909.0 10,910.0411312017 Hb., G. Gelded Salt Water 1561.00 166500 3 10,231.0 10,232.041IW2017 Hybor G, Galled Salt Wafer 1127.00 123000 4 9,553.0 9,554.041132017 Hybor G, Gelled Sall Water 994.00 1099.00 gdFlx.Ga9eaelar,ssasA I I 5 8,888.0 8,889.0411312017 Hybor G, Gelled Sall Water 1092.00 1200.00 HP1FauGeNdreNg+.1she .B,S: 0,1314-11,8091 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, April 27, 2017 1:24 PM To: Smith, Travis T Subject: RE: CRU CD3 -111A (PTD# 217-004) Surface Casing Repair 10-403 Travis, Verbal approval is granted to proceed with the work as outlined in the attached copy of the 10-403 being submitted to the AOGCC today. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCrilalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 oryictoia.loc�akska.gov From: Smith, Travis T [mailto:Travis.T.Smith@conocophillips.com) Sent: Thursday, April 27, 2017 1:10 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: CRU CD3 -111A (PTD# 217-004) Surface Casing Repair 10-403 Hello Victoria— Attached, please find a 10-403 for CRU C133 -111A (PTD# 217-004) surface casing repair. Two original copies have been sent in hard copy. This well was recently sidetracked and during the initial flowback a leak from the surface casing to the conductor was observed. The well was shut-in and our surface casing leak detect work indicates that the leaks are 14-17" below the bottom of the wellhead. Because this producing well is of such high value, and because the ice road ending is complicating our logistics, we are requesting expedited handling of this 10-403 if possible. I will give you a call to discuss details. Thank you very much. Travis Smith STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED MAY 0 9 2017 WELL COMPLETION OR RECOMPLETION REPORT ANCkb4&;`L; 1a. Well Status: Oil 21 • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAG❑ WDSPL❑ No. of Completions: 1b. Well Class: Development Z Exploratory ❑ Service ❑ Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 4/8/2017 14. Permit to Drill Number / Sundry: 217-0041' 3. Address: P.O. Boz 100360 Anchorage, AK 99510-0360 7. Date Spudded: 322/2017 15. API Number: 50-103-20526-01-00 4a. Location of Well (Governmental Section): Surface: 3946' FNL, 874' FEL, Sec 5, T12N R5E, UM Top of Productive Interval: 3069' FNL, 1233' FEL, Sec 5, T12N, R5E, UM Total Depth: 2620' FNL, 1416' FEL, Sec 31, T13N, R5E, UM 8. Date TO Reached: 3/31/017 161 Name and Number: CD3 -111A 9. Ref Elevations: KB 49.1, L- GL: 12.9 BF: 17. Field / Pool(s): Colville River Unit/Fiord Oil Pool 10. Plug Back Depth MD/TVD: 2519/2301 - 18. Property Designation: ADL 372105, ADL 364471, ADL 364470 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 388169 y- 6003828 Zone- 4 TPI: x- 387821 y- 6004711 Zone- 4 Total Depth: x- 385069 y- 6010482 Zone- 4 11. Total Depth MD/TVD: 11642/6922 . 19. Land Use Permit: LAS21122 12. SSSV Depth MD/TVD: 2150/2010 20. Thickness of Permafrost MD/TVD: 270/269 5. Directional or Inclination Survey: Yes ❑Q (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) I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16 84 J-55 36 114 36 114 24 Pre-installed 95/8 40 L-80 36 2721 36 2469 121/4 410 sx 10.7 ppg lead, 230 sx 15 R nm fall 7 25 L-80 34 8530 34 6933 83/4 Stage 1: 237 sx 15.8 ppg Class G Stage 2: 213 sx 15.8 ppg Class G 41/2 12.6 L-80 8131 11609 6883 6922 61/8 Liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): FRAC SLEEVE @ 8897 - 6943 FRAC SLEEVE @ 9560 - 6931 FRAC SLEEVE @ 10237 - 6929 COMPLETION FRAC SLEEVE @ 10915 - 6930 DATE - 4 VERIFIED 25. TUBING RECORD SIZE I DEPTH SET (MD) PACKER SET (MDfrVD) 31/2 8149 8008/6848 8131/6883 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 4/22/2017 Method of Operation (Flowing, gas lift, etc.): FLOWING Date of Test: 4/24/2017 Hours Tested: 12 hrs Production for Test Period Oil -Bbl: 1671 Gas -MCF: 1337 Water -Bbl: 1673 Choke Size: 128/64 Gas -Oil Ratio: 800 Flow Tubing Press. Casing Press: N/A Calculated Oil -Bbl: 3341 Gas -MCF: 1 2676334729.1 Water -Bbl: Oil Gravitv - API (torr): Form 10-407 Revised 1112015 vrt' &� /'7�" CONTINUED ON PAGE 2 RBDMS tt, MAY 15 201 Submit ORIGINIAL ol& 28. CORE DATA Conventional Corals): Yes ❑ No 121 Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, 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 ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 270 269 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 2721 2469 information, including reports, per 20 AAC 25.071. TPI Formation C-20 C-10 3520 3180 K-3 4341 3899 K-2 4540 4073 Albian 97 6281 5608 Albian 96 6762 6034 HRZ 7498 6598 Kalubik 7647 6688 Kuparuk C 7871 6796 LCU 7879 6800 Nuiqsut 7879 6800 Nechelik 8431 6927 TD 11642 6922 Formation at total depth: Nechelik . 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, l report production or well test results, per 20 AAC 25.07 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Weifeno, CD 263-4324 Email: weifen .dai a co .com W Iv Printed Name CTE Alvord Title: Alaska DrillingManager or Signature: J on +"� Phone: 265-6120 Date: Z02 U INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 1112015 Submit ORIGINAL Only CD3 -111A Nechelik Producer Proposed Schematic updated 4/4/2017 2(Y'94# H40 Welded Conductor to 11(Y TRMAXX SSSV 2,130' MD 9518" 40# L-80 BTC Surface Casing 2,721' MD /2,469' TVD cemented to surface 3'/:" 9.6# L-80 EUE Tubing 6,350' MD PTS Downhole Gauge 7,950' MD Baker Premier Production Packer 8,006' MD 7" 26# L-80 BTCM Intermediate Casing 8 466MD r Upper Completion: Length 1) 4-'/2" 12.6#/FtTXP Tubing (2jts) XO to 3-%" EUE tubing 2) Shallow nipple profile with SSSV 3) 3-'/s" x 1" Camco KBMG GLM (xx°) w/ DV 7' 4)3-1/2" x 1" Camco KBMG GLM (xx°) w/ DV 7' 4)3-1/2"x 1" Camco KBMG GLM (xx°) w/DCK2 7' pinned for 2500 psi casing to tbg shear 5) PTS Downhole Gauge, Encapsulated I -Wire 1.5' w/cannon damps on every joint 6) Baker Premier Packer 7) XN nipple 2.812" ID 1.5' 8) WLEG 1.5' Lower Completion: 9) Flexlock Liner Hanger 37' XO 5" Hydril 521 Box X 4-%" IBTM pin 10) 4 W, 12.6#/ft, L-80 TXP Liner w/ ball actuated frac ports every 700' and Saltel open hole frac packers 11) WIV & Alpha Sleeve @ toe 6 1/2" Hole TD 11,644' MD I 01 1010 0 • I I --L— L Saftel Open Hole Frac Packers 4-1/2" 12.6# L-80 TXP Production Liner with Frac Sleeves 8,127'— 11,600'MD ..aerations Summary (with Timelog L,epths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Sten Time End Time Dur (hp Phase Op Code Activit' Cotle Time P -T -X Operation Stan Depth (ftl(B) End Depth (ftKB) 3/10/2017 3/10/2017 10.00 MIRU MOVE RURD P Blow down steam and water lines, 0.0 0.0 00:00 10:00 swap all mods to cold start generators. Separate motor and pits complexes from substructure. Skid dg floor, jack sub and pull shims. Back sub off CD5- 20 and spot on CD5. SIMOPS- Move GIS, pits and motors around sub, ready to exit CD5 pad. 3/10/2017 3/10/2017 2.00 MIRU MOVE MOB P Begin moving pipe shed first from 0.0 0.0 10:00 12:00 CD5, followed by GIS, pits and motors. SIMOPS- Clean pad and around well. 3/10/2017 3/10/2017 6.00 MIRU MOVE MOB P Continue moving support modules. 0.0 0.0 12:00 18:00 Warm weather and freezing rain making roads very slippery. Slow moving down hill to Nigliq channel crossing @ mile 6.3 utilizing 2 dozers to hold back each module. SIMOPS- Substructure moved .3 miles from CD5, stopped due moving system electrical issue. Mechanic, Tool/Tour pusher, Superintendent and DDI electricians troubleshooting. 3/10/2017 3/11/2017 6.00 MIRU MOVE MOB P Stopped support modules @ 11.3 mile 0.0 0.0 18:00 00:00 ice pad before C134 road to fuel up. Continue moving, utilize dozers to pull pit complex up to CD4 road, all support modules moving @ mile 13.5 on CD4 road @ midnight. Sub -structure repaired and moving @ 22:00 hin, at mile 2 coming up to K pad @ midnight. Hydraulic pump had tripped off (1 of 3) backfeeding hydraulic fluid to tank. No indications of trip. Re -set all pumps and resume moving. (Re -booted sub) 3/11/2017 3/11/2017 6.00 MIRU MOVE MOB P Continue with support modules from 0.0 0.0 00:00 06:00 miles 13.5 on CD4 road to ice pad behind C132 @ mile 16.5 @ 03:00. Park mods on ice pad for sub to go around. Sub on CD5 ice road bypass from mile 2 to mile 4.5, stopping for fuel @ K pad. 3/11/2017 3/11/2017 6.00 MIRU MOVE MOB P Continue moving sub structure on 0.0 0.0 06:00 12:00 CD5 ice road bypass. SIMOPS- Change out centrifuge pump in pump module. Stage MPD equipment in CD3 -111 cellar area, lay herculfte for rig, build containment around camp and STP. Send updated notification to AOGCC. Page 1127 ReportPrinted: 4/10/2017 . perations Summary (with Timelog r_spths) CD3-111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Sten Time End Time our (hr) Phase Op Code Actively CodaTime P-T-X Operation Start Depth (RKB) End Depth (flKa) 3111/2017 3/11/2017 6.00 MIRU MOVE MOB P Continue moving sub structure on 0.0 0.0 12:00 18:00 CD5 ice road bypass to ice pad at mile 11.3. Stop to fuel up equipment prior to CD4 road. SIMOPS- Change out centrifuge pump in pump module. Stage MPD equipment in CD3-111 cellar area, lay herculite for rig, build containment around camp and STP, R/U transformer and swap camp to Hi Line power. 3/11/2017 3/1212017 6.00 MIRU MOVE MOB P Continue moving sub structure down 0.0 0.0 18:00 00:00 CD4 gravel road, @ CD2 intersection 21:00 hrs mile 14.1. Sub @ CD2 ice ramp 15.9 @ midnight. SIMOPS- Lay mats on Tamayayak crossing per Ice road Supervisor/Eng. Peak build snow ramps. Diesel transport staged @ CD3. 3112/2017 3/12/2017 6.00 MIRU MOVE MOB P Move sub from mile 13.9 to mile 19.5 0.0 0.0 00:00 06:00 on CD3 ice road. Top off fuel @ CD2 ice pad. 3/12/2017 3/12/2017 6.00 MIRU MOVE MOB P Continue moving sub on CD3 ice road 0.0 0.o 06:00 12:00 1 from mile 19.5 to mile 24.5. 3/12/2017 3112/2017 6.00 MIRU MOVE MOB P Sub on location CD3 @ 13:00 hrs. 0.0 0.0 12:00 18:00 Spot over well @ 17:00 hrs. Continue to make adjustments to center over well. SIMOPS- Ice road foreman/ Eng inspect Tamayayak crossing no damage. 3/12/2017 3/13/2017 6.00 MIRU MOVE MOB P Support modules depart CD2 ice pad 0.0 0.0 18:00 00:00 @ mile 16.5, arrive on location mile 25.1 @ 20:00 hrs. Skid rig floor @ 21:30, move in and spot pit and motor complexes. SIMOPS- Continue centering sub. Move rig mats for spotting modules. Skid rig floor. 3/13/2017 3113/2017 3.00 MIRU MOVE MOB P Continue to shim pit complex, spot 0.0 0.0 00:00 03:00 pipeshed, work on rig acceptance. 3/13/2017 3/13/2017 3.00 MIRU MOVE RURD P Spot ball mill complex, connect steam, 0.0 0.0 03:00 06:00 - air, water, fuel lines electrical. Finalize rig acceptance checklist. Rig accepted @ 06:00. 3/13/2017 3/13/2017 3.00 MIRU WELCTL RURD P R/U tiger tank, choke skid, connect 0.0 0.0 06:00 09:00 choke / flare lines, M/U companion flanges and low torque valves on IA and OA. Thaw lines, pumps. Rig on hi line power @ 09:00. 3/13/2017 3113/2017 1.50 MIRU WELCTL RURD P Hook up air heater to pipe shed, 0.0 0.0 09:00 10:30 weatherize sub. Tested gas alarms, take on 9.8 ppg brine to rig pits. 3113/2017 3/13/2017 1.50 MIRU WELCTL MPSP P M/U lubricator, test to 3500 psi. 0.0 0.0 10:30 12:00 Attempt to pull BPV, unsuccessful. 3/13/2017 3/13/2017 1.00 MIRU WELCTL MPSP P PJSM, pull BPV and RID lubricator. 0.0 0.0 12:00 13:00 Observe ice buildup/ plug in master valves causing difficuly pulling BPV. Page 2127 Report Printed: 4110/2017 operations Summary (with Timelog Lrepths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log staM1Tme End Time our (hr) Phase Op Code Activity Code Time P -T -x Operafion Start Depth (n De End Depth (flKB) 3/13/2017 3113/2017 2.50 MIRU WELCTL RURD P Rig up circulating lines and 0.0 0.0 13:00 15:30 equipment. Blow down lines to tiger tank, steam heat. Blow down and PT with air 120 psi good. Fill with water and PT to 500/3500 psi, good. SITP=O, SIIAP=O 3/13/2017 3/13/2017 0.50 MIRU WELCTL KLWL P Line up and pump 9.8 ppg brine down 0.0 0.0 15:30 16:00 IA, taking returns out tubing to clear out diesel cap. Pump 4 bpm, 360 psi through tubing cut @ 3,115' MD. 3/13/2017 3/13/2017 0.50 MIRU WELCTL KLWL P Line up to pump down tubing, taking 0.0 0.0 16:00 16:30 returns out IA circulating out diesel freeze protection. Pumped 4 bpm, 500 psi tubing, 430 psi IA. With choke full open FCP=500 psi tubing, 300 psi IA. Pumped 150 bbl, 9.8 ppg brine in and out, 410 psi tubing, 210 psi IA @ 4 bpm. 3/1312017 3/13/2017 0.50 MIRU WELCTL OWFF P Shut down, monitor pressure @ 0 psi. 0.0 0.0 16:30 17:00 1 1 1 Blow down lines to choke skid. 3/1312017 3113/2017 1.00 MIRU WELCTL OWFF P Open tubing and IA to atmosphere, 0.0 0.0 17:00 18:00 monitor well static for 30 minutes. SIMOPS- R/D circulating lines and equipment. 3/13/2017 3/13/2017 1.00 MIRU WELCTL MPSP P Set BPV, lest to 2000 psi via IA for 10 0.0 0.0 18:00 19:00 minnutes charted. (Testing cement plug, hanger seals and 7" casing. 3/13/2017 3/1312017 2.50 MIRU WHDBOP NUND P N/D tree, inspect hanger threads- 0.0 0.0 19:00 21:30 good. Install blanking plug, 10% RH turns. Prep wellhead for NIU. SIMOPS- PJSM for N/U slack and MPD equipment, steam thaw bottom of stack due ice on stump. 3/1312017 3/13/2017 0.50 MIRU WHDBOP NUND P N/U BOP stack 0.0 0.0 21:30 22:00 3113/2017 3/14/2017 2.00 MIRU WHDBOP MPDA P PJSM, rig up MPD equipment, flow 0.0 0.0 22:00 00:00 box, flow line, Orbit valve, Katch Kan, hole fill lines, MPD manifold. 3/1412017 3/14/2017 2.00 MIRU WHDBOP MPDA P Tested rotary head to 200/1200 psi 0.0 0.0 00:00 02:00 against the test plug for 5 min. 3/14/2017 3/14/2017 1.50 MIRU WHDBOP MPDA P Pulled MPD test plug and installed trip 0.0 0.0 02:00 03:30 nipple. Installed 3.5" test joint. 3/14/2017 3/14/2017 1.50 MIRU WHDBOP RURD P R/U BOP test equipment, fill stack with 0.0 0.0 03:30 05:00 H2O and purge air. Page 3127 Report Printed: 4/1012017 %iperations Summary (with Timelog L epths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) Phase Op Code Activiry Code Time P -T -X Operation Stan Depth (tMB) End Depth (W) 3114/2017 3/14/2017 7.00 MIRU WHDBOP BOPE P Test BOPE with 3.5" and 4%z" test 0.0 0.0 05:00 12:00 joints. AOGCC Chuck Scheve waived witness. Test Annular to 250/2500 psi, all rams and valves to 250/3500 psi 5 min each charted. 3.5" TJ test annular preventer, Choke valves #1,12,13,14, Upper IBOP/ Upper VBR, 4" Demco kill/ CV #9,11, lower IBOP, HCR kill/ CV #5,8,10/ CV #4,6,7/ CV #2/ HCR Choke / Manual choke and kill/ Lower VBR's. Change to 4Y2" TJ, test annular/ Upper VBR's, 4" XT -39 Dart/ Lower VBR's, XT -39 FOSV. Perform accumulator function test. System pressure=2950 psi, Manifold pressure=1500 psi, Annular pressure=750 psi. System pressure after functioning all rams and HCR's=1300 psi. 200 psi attained @ 36 sec, Full system recovery @ 184 sec. 4 bottle N2 average=2000 psi. Operate remote stations. Pull test joint and test blind rams, Tested gas detecters, function flow meter, check PVT alarms. 3/14/2017 3/14/2017 2.50 MIRU WHDBOP BOPE T The heat trace on the choke line failed 0.0 0.0 12:00 14:30 while testing and froze up. The lines were thawed out before proceeding. 3/14/2017 3/14/2017 0.50 MIRU WHDBOP ROPE P Perform choke draw down test. 0.0 0.0 14:30 15:00 3/14/2017 3/14/2017 1.00 MIRU WHDBOP RURD P RID test equipment, Blow down lines, 0.0 0.0 15:00 16:00 and pull plug. 3/14/2017 3/14/2017 1.50 SLOT RPCOMP PULL P M/U Landing joint and pull hanger 0.0 0.0 16:00 17:30 free. P/U 100k and weighted 2 min, continued to 110k and hanger came free. 3/14/2017 3/14/2017 0.50 SLOT RPCOMP CIRC P Circulated BU wl6 bpm, 230 psi. 0.0 0.0 17:30 18:00 3/14/2017 3/14/2017 5.00 SLOT RPCOMP PULL P Pulled hanger to dg floor, connected 0.0 0.0 18:00 23:00 control line to spool and continued to puIVLD 2 its of 4.5" tubing, 96 jts of 3.5" tubing, SSSV, and 15.8' cut joint. 71 SSCL Bands were recovered. 3/14/2017 3/14/2017 0.50 SLOT RPCOMP WWWH P Installed 9" wear bushing, 0.0 0.0 23:00 23:30 3/14/2017 3/15/2017 0.50 SLOT RPCOMP PULD P RID tubing equipment and clear floor. 0.0 0.0 23:30 00:00 3/15/2017 3/15/2017 1.00 SLOT RPCOMP RURD P UD Tubing equipment, control line 0.0 0.0 00:00 01:00 spool, and installed mouse hole. 3/15/2017 3/15/2017 0.50 SLOT PLUG BHAH P M/U CIBP easy as per Baker rep. 0.0 0.0 01:00 01:30 3/15/2017 3/15/2017 5.00 SLOT PLUG PULD P Singled in the hole with 4" 15.7# DP 0.0 3,088.0 01:30 06:30 out of the pipe shed to 3,088' MB 3/15/2017 3/15/2017 0.50 SLOT PLUG MPSP P Set CIBP at 3,088' MD. 3,088.0 3,088.0 06:30 07:00 3/15/2017 3/15/2017 0.75 SLOT PLUG CIRC P Circulated s/s @ 6 bpm, 300 psi and 3,088.0 3,088.0 07:00 07:45 B/D TD. 3/15/2017 3/15/2017 1.00 SLOT PLUG SLPC P Slip & Cut 80' of drill line. 3,088.0 3,088.0 07:45 08:45 Page 4127 ReportPrinted: 4110/2017 operations Summary (With Timelog L,vpths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our hr ( ) Phase 0 Code P Activity Code N Time P -T- % Operation (ftKB) End Depth iflKB) 3/15/2017 3/15/2017 0.50 SLOT PLUG SVRG P Serviced TD, blocks, and drawworks. 3,088.0 3,088.0 08:45 09:15 3/15/2017 3/15/2017 1.75 SLOT PLUG TRIP P POOH f/ 3,088'to surface and L?D 3,088.0 0.0 09:15 11:00 running tool. 3/15/2017 3115/2017 0.25 SLOT PLUG BHAH P M/U 7" casing cutter easy. 0.0 13.0 11:00 11:15 3/15/2017 3/15/2017 2.75 SLOT PLUG TRIP P RIH f/ 13' to 3,088' MD and tagged 13.0 2,921.0 11:15 14:00 CIBP, P/U= 100k, S/0= 100k. Established circulation at 2.5 bpm, and located collar at 2,899' MD. Continued up to cutting depth of 2,921' MD. 3/15/2017 3/15/2017 1.00 SLOT PLUG CPBO P Cul 7" casing at 2,921' MD w/ 80 rpm, 2,921.0 2,921.0 14:00 15:00 1k TO, 4.5 bpm, and 700 psi. Observed pressure drop to 250 psi, confirming casing cut. 3/15/2017 3/15/2017 0.50 SLOT PLUG CIRC P Lined up the OA to take returns, 2,921.0 2,921.0 15:00 15:30 closed annular and attempted to circulate the OA. Staged pressure up to 750 psi at 0.5 bpm with no returns, pushed 0.6 bbI away. Bleed off pressure and observed well, static. (OA 10 psi at surface) 3/15/2017 3/15/2017 2.50 SLOT PLUG CIRC T Circulated BU at 4 bpm, 180 psi, and 2,921.0 2,921.0 15:30 18:00 OWFF with slight flow. Circulated BU at same rate while adding deforter and OWFF with slight flow. circulated a surface to surface, OWFF with slight Flow. 3/15/2017 3/15/2017 1.50 SLOT PLUG CIRC T Weighted up brine with viscosifler and 2,921.0 2,921.0 18:00 19:30 barite f19.8 ppg to 10.3 ppg at 8 bpm, 600 psi. 3115/2017 3/1512017 0.50 SLOT PLUG OWFF T POOH f/2,921'to 2,866' MD, BD TD, 2,921.0 2,866.0 19:30 20:00 and OWFF. Slight flow w/ increasing rate. 3/15/2017 3/15/2017 0.50 SLOT PLUG CIRC T Circulated 153 bbl at 4 bpm, 620 psi. 2,866.0 2,866.0 20:00 20:30 OWFF, slight flow. 3/15/2017 3/15/2017 0.50 SLOT PLUG TRIP T RIH and orient at original cut depth of 2,866.0 2,921.0 20:30 21:00 2,921' MD. 3/15/2017 3/15/2017 1.00 SLOT PLUG CIRC T Weighted up f/ 10.3 ppg to 10.8 ppg at 2,921.0 2,921.0 21:00 22:00 6 bpm, 370 psi. 3115/2017 3/15/2017 0.50 SLOT PLUG OWFF T OWFF, slight flow. 2,921.0 2,921.0 22:00 22:30 3/15/2017 3/16/2017 1.50 SLOT PLUG CIRC T Weighted up f/ 10.8 ppg to 11.3 ppg 2,921.0 2,921.0 22:30 00:00 MIN. 13/16/2017 3/16/2017 0.75 SLOT PLUG CIRC T OWFF, w/ slight flow. Circulated BU 2,921.0 2,921.0 00:00 00:45 and continued to see slight flow. 3/16/2017 3116/2017 1.25 SLOT PLUG CIRC T Weight up f/ 11.3 ppg to 11.8 ppg w/ 6 2,921.0 2,921.0 00:45 02:00 bpm, 470 psi. 3116/2017 3/16/2017 0.50 SLOT PLUG OWFF T OWFF, slight flow. 2,921.0 2,921.0 02:00 02:30 3/16/2017 3/16/2017 0.75 SLOT PLUG CIRC T Weight up to 12 ppg MW w/ 6 bpm, 2,921.0 2,921.0 02:30 03:15 500 psi. 3/16/2017 3/16/2017 0.50 SLOT PLUG TRIP T POOH f/ 2,921' MD to 2,866' MD. BD 2,921.0 2,866.0 03:15 03:45 1 TO and OWFF, well static. 3/16/2017 3/16120171 0.50 SLOT PLUG TRIP P POOH f12,866'to 2,679' MD and 2,866.0 2,686.0 03:45 04:15 engaged pumps. S/O to first casing collar at 2,686' MD and P/U T to cut depth @ 2,686' MD Page 5127 Report Printed: 4/10/2017 operations Summary (with Timelog Lepths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Time End Time our (m) 1 0 Phase O Code p Acevi Code ry Time P -T- % Operation siert Depth (pKB) End Depth fa(B) 3/16/2017 3/16/2017 1.00 SLOT PLUG CPEO P Cut 7" Csg @ 2,686' MD w/ 175 gpm, 2,686.0 2,686.0 04:15 05:15 800 psi, 80 rpm, and 2k TO. Observed 730 psi build on the OA, indicating csg cut. 3116/2017 3116/2017 0.75 SLOT PLUG CIRC P Circulated BU in 7" csg @ 175 gpm, 2,686.0 2,686.0 05:15 06:00 790 psi. 3/16/2017 3/16/2017 1.25 SLOT PLUG DISP P Closed annular and lined up to take 2,686.0 2,686.0 06:00 07:15 returns from the OA to the choke and displaced out 50 bbl of diesel, -40 bbl of H2O with 12 ppg mud. 3116/2017 3116/2017 1.25 SLOT PLUG CIRC P Circulated 1.5 BU through the OA @ 2 2,686.0 2,686.0 07:15 08:30 bpm, 270 psi. 3/16/2017 3/16/2017 0.50 SLOT PLUG CIRC P Open the annular, close OA, and 2,686.0 2,686.0 08:30 09:00 circulate BU in 7" csg. 311612017 3/16/2017 0.25 SLOT PLUG TRIP P POOH f/ 2,686' to 2,676' MD, BD TD. 2,686.0 2,676.0 09:00 09:15 3/16/2017 3/16/2017 0.75 SLOT PLUG OWFF P OWFF, well static. 2,676.0 2,676.0 09:15 10:00 3/16/2017 3/16/2017 1.75 SLOT PLUG TRIP P POOH f/ 2,676' to 13' MD w/ cutting 2,676.0 13.0 10:00 11:45 assy. 3/16/2017 3/16/2017 0.25 SLOT PLUG SHAH P LID 7" rasing cutting assy. 13.0 0.0 11:45 12:00 3/16/2017 3/16/2017 3.00 SLOT PLUG BOPE P Changed out BOP rams to 7" SBRs. 0.0 0.0 12:00 15:00 Installed test plug w/ 7" test joint and R/U testing equipment. 3116/2017 3/16/2017 1.00 SLOT PLUG BOPE P Tested annular to 250/2500 psi and 0.0 0.0 15:00 16:00 attempted to test rams. Observed loss of pressure at the BOP speed head flange. 3/16/2017 3/16/2017 1.50 SLOT PLUG BOPE T Tightened flange segments on the 0.0 0.0 16:00 17:30 speed head. 3/16/2017 3/16/2017 0.50 SLOT PLUG BOPE T Tested annular to 25012500 psi, 7" 0.0 0.0 17:30 18:00 rams to 2500/3500 psi. TEST GOOD. 3/16/2017 311612017 1.00 SLOT PLUG BOPE P Pulled test joint and plug. R/D test 0.0 0.0 18:00 19:00 equipment, clean and Geared floor. 3/162017 3/16/2017 1.00 SLOT PLUG PULL P MIN 7" pack off retrieval tool and RIH. 0.0 0.0 19:00 20:00 1 set down I Ok on pack off and removed lock down screws. Pulled to surface and L/D retrieval tool. 3/16/2017 3/16/2017 0.50 SLOT PLUG RURD P Set 10 318" ID wear ring. 0.0 0.0 20:00 20:30 1 3/16/2017 3/1612017 1.00 SLOT PLUG PULL P WU 7" casing spear and engage 7" 0.0. 0.0 20:30 21:30 casing hanger. pulled hanger free w/ 122k and pulled to rig floor. P/U= 115k. 3116/2017 3/16/2017 1.50 SLOT PLUG CIRC P Circulate surface to surface staging up 0.0 0.0 21:30 23:00 from 2 bpm to 5 bpm, 190 psi. Pumped 25 bbl deep clean pill. SinnOps. R/U 7" casing equipment. 3/16/2017 3/17/2017 1.00 SLOT PLUG BHAH P Release casing spear and L/D. BD 0.0 0.0 23:00 00:00 TD. SimOps finish R/U casing tools. 3/172017 3/17/2017 0.50 SLOT PLUG OWFF P OWFF, well static. 0.0 0.0 00:00 00:30 3/17/2017 3/17/2017 4.50 SLOT PLUG PULL P POOH and L/D 62 jnts of 7" casing. 0.0 0.0 00:30 05:00 Jnt * 62 was cut and flared out. 3/17/2017 3/17/2017 0.50 SLOT PLUG RURD P Drained stack and cleaned dg floor. 0.0 0.0 05:00 05:30 3/17/2017 3/172017 1.00 SLOT PLUG BOPE P Changed upper rams to 3 1/2" x 6" 0.0 0.0 05:30 06:30 variable rams. Page 6127 Report Printed: 4/1 012 01 7 . perations Summary (with Timelog L vpths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Time Nr(hr) Phase Op Cade Activity Code Time P -T -X Operation (ftKB) End Depth (WS) 3117/2017 3/17/2017 0.50 SLOT PLUG BOPE P Remove wear ring and installed lest 0.0 0.0 06:30 07:00 plug as per FMC. 3/17/2017 3/17/2017 0.75 SLOT PLUG BOPE P R/U BOP test equipment and fill stack 0.0 0.0 07:00 07:45 w/ H2O. 3/17/2017 3/17/2017 1.50 SLOT PLUG BOPE P Test annular to 250/2500 psi and 0.0 0.0 07:45 09:15 3.5"x6" ram to 250/3500 psi with both 3 1/2" and 4" test joints. R/D test equipment. 3/17/2017 3117/2017 0.50 SLOT PLUG BOPE P Remove test plug and install 10" ID 0.0 0.0 09:15 09:45 wear ring. 3/17/2017 3117/2017 0.50 SLOT PLUG BHAH P P/U fishing equipment to dg floor. 0.0 0.0 09:45 10:15 3117/2017 3/17/2017 2.50 SLOT PLUG BHAH P M/U 7" spear assy as per Baker rep to 0.0 235.0 10:15 12:45 235' MD. 3/17/2017 3/17/2017 1.25 SLOT PLUG TRIP P RIH f/ 235'to 2,421' MD with spear 235.0 2,421.0 12:45 14:00 assy. 3/17/2017 3117/2017 0.25 SLOT PLUG WASH P Break circulation and wash down f/ 2,421.0 2,612.0 14:00 14:15 2,421' to 2,612' MD w/ 3 bpm, 150 psi. 3/17/2017 3/17/2017 2.25 SLOT PLUG FISH P M/U stand #26 and engage 7" casing 2,612.0 2,683.0 14:15 16:30 fish at 2,663' MD. Attempted to pull free staging up to 200k overpull w/ jars and 300k straight pull, no go. Held 200 psi w/ 200k overpull w/ jars and 250 strait pull, no go. 3/17/2017 3/17/2017 1.75 SLOT PLUG FISH T Attempted to release 7" spear with 10k 2,683.0 2,683.0 16:30 18:15 TO and 175k P/U, no go. BD TD, Staged up overpull and fired jars @ 200k, Worked down weight. 3/17/2017 3/17/2017 0.75 SLOT PLUG SFTY T Performed derrick inspection due to 2,683.0 2,683.0 18:15 19:00 jarring. 3/17/2017 3/17/2017 2.00 SLOT PLUG FISH T Continued attempting to release 7" 2,683.0 2,683.0 19:00 21:00 spear w/ 150k overpull and 5k TO. working up to 325k straight overpull. Alternating between firing jars and hitting down. 3/17/2017 3/17/2017 1.00 SLOT PLUG SFTY T Performed derrick inspection due to 2,683.0 2,683.0 21:00 22:00 jarring. 3/17/2017 3/17/2017 0.75 SLOT PLUG FISH T Continued to attempt to free 7" spear 2,683.0 2,683.0 22:00 22:45 w/ 175k overpull and firing jars. 3/17/2017 3/17/2017 1.00 SLOT PLUG PULD T P/U Baker surface jars to dg floor and 2,683.0 2,683.0 22:45 23:45 make up to DP. 3/17/2017 3/18/2017 0.25 SLOT PLUG FISH T Fired surface jars w/ 100k overpull 2,683.0 2,683.0 23:45 00:00 and released 7" spear. Confirmed free w/ 125k straight pull. 3/18/2017 3/18/2017 0.50 SLOT PLUG PULD P LID surface jars and XOs 2,683.0 2,683.0 00:00 00:30 3/18/2017 3/18/2017 0.75 SLOT PLUG CIRC P Circulated BU w 5 bpm, 200 psi. 2,683.0 2,683.0 00:30 01:15 SimOps, performed derrick inspection. 3/18/2017 3/1812017 0.75 SLOT PLUG OWFF P OWFF, well static. BD TD. 2,683.0 2,683.0 01:15 02:00 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P POOH f/ 2,670'to 235' MD w/ spear 2,683.0 235.0 02:00 03:30 assy. 3/18/2017 3/1812017 0.25 SLOT PLUG OWFF P OWFF, well static. 235.0 235.0 03:30 03:45 3/18/2017 3/18/2017 1.50 SLOT PLUG BHAH P Rack back drill collars and LID spear 235.0 0.0 03:45 05:15 easy as per baker. Clean and clear floor. Page 7127 ReportPrinted: 4/1 012 01 7 . peraticns Summary (With TimelOy L.4pths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log shirt Depth Stan Time End Time Dur (hr) Phase Op Catle Activity Code TimP-T-X Operation (NKB) End Depth (MB) 3/18/2017 3/18/2017 0.25 SLOT PLUG BHAH P M/U 7" cutting easy w/ new cutters as 0.0 13.0 05:15 05:30 per Baker. 3/18/2017 3/18/2017 2.25 SLOT PLUG TRIP P RIH on 4" DP from derrick f/ 13' to 13.0 2,820.0 05:30 07:45 2,820' MD. P/U= 97, S/O= 95. 3/18/2017 3/18/2017 0.75 SLOT PLUG CPBO P Located collar 2,819' MD while 2,820.0 2,822.0 07:45 08:30 washing down w/ 2 bpm, 250 psi, and S/O 5k. Dropped cutters 3' below collar at 2,822' MD and cut casing w/ 4.3 bpm, 800 psi, 80 rpm, 2.5k TQ. Observed a 560 psi pressure drop, indicating a clean cut. 3/18/2017 3/18/2017 0.50 SLOT PLUG CIRC P Circulated BU w/ 6 bpm, 370 psi. 2,822.0 2,822.0 08:30 09:00 SimOps, mobilized spear assy to dg floor. 3/18/2017 3/182017 0.50 SLOT PLUG OWFF P OWFF, Well static. RIB a stand to 2,822.0 2,771.0 09:00 09:30 2,771' MD and BD TD. 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P POOH f/ 2,771'to 13' MD. 2,771.0 13.0 09:30 11:00 3/18/2017 3/182017 0.50 SLOT PLUG SHAH P L/D cutting easy and Gear rig floor. 13.0 0.0 11:00 11:30 3/18/2017 3/18/2017 1.75 SLOT PLUG BHAH P M/U 7" spear assy as per Baker. 0.0 230.0 11:30 13:15 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P RIH f/ 230'10 2,608' MD. 230.0 2,608.0 13:15 14:45 3/18/2017 3/18/2017 1.25 SLOT PLUG FISH P Engage fish at 2,692' MD and set 2,608.0 2,692.0 14:45 16:00 down 5k. P/U to 150k and confirmed engagement. attempted to free fish w/ 200k overpull while firing jars. worked up to 300k over straight pull with now success. 3/18/2017 3/18/2017 0.75 SLOT PLUG SVRG P Performed a derrick inspection due to 2,692.0 2,692.0 16:00 16:45 jarring. 3/18/2017 3/18/2017 0.75 SLOT PLUG FISH P Attempt to release from 7" casing. w/ 2,692.0 2,692.0 16:45 17:30 200k pull and firing jars. worked up to 300k straight pull. Applied downward force w/ 5k TQ in string. No Go. 3/18/2017 3/182017 0.50 SLOT PLUG FISH P P/U surface jar and a single. WU to 2,692.0 2,692.0 17:30 18:00 string and fire with 120k P/U to release spear. 3/182017 3/18/2017 0.50 SLOT PLUG RURD P RID surface jars and L/D. 2,692.0 2,692.0 18:00 18:30 3/18/2017 3/18/2017 1.00 SLOT PLUG CIRC P Circulate BU at 5 bpm, 200 psi. 2,692.0 2,692.0 18:30 19:30 SimOps, perform derrick inspection. B/D TD and OWFF. 3/18/2017 3/18/2017 1.50 SLOT PLUG TRIP P POOH f/ 2,692'to 230' MD. 2,692.0 230.0 19:30 21:00 3/18/2017 3/18/2017 1.00 SLOT PLUG BHAH P L/D spear assy in 2 segments and RID 230.0 0.0 21:00 22:00 drill collars. 3/182017 3/18/2017 0.50 SLOT PLUG BHAH P WU 7" cutting easy. 0.0 13.0 22:00 22:30 3/18/2017 3/192017 1.50 SLOT PLUG TRIP P RIH f/ 13'to 2,782' MD on 4" 15.7# 13.0 2,782.0 22:30 00:00 DP, 3/19/2017 3/19/2017 0.50 SLOT PLUG CPBO P Positioned cutter at 2,782' MD and cut 2,782.0 2,782.0 00:00 00:30 w/ 4.3 bpm, 800 psi, and 24.K TQ. Observed a 530 psi drop and confirmed a clean cut. 3/192017 3/19/2017 0.75 SLOT PLUG CIRC P Circulated BU and OWFF. 2,782.0 2,782.0 00:30 01:15 Page 8/27 Report Printed: 4110/2017 ..aerations Summary (with Timelog �. pths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Depth Start Time EM Time our (hr) Phase Op Code Activity Coda Time P -T -X Operation (r1KB) End Depth (ItKB) 3/19/2017 3/19/2017 0.50 SLOT PLUG CPBO P Positioned cutter at 2,739' and made 2,782.0 2,739.0 01:15 01:45 5th cut, 4.3 bpm, 800 psi, 2.3k TO, and 80 rpm. Observed 530 psi pressure drop and confirmed cut. 3/19/2017 3/19/2017 0.75 SLOT PLUG CIRC P Circulated BU and OWFF. BD TD. 2,739.0 2,739.0 01:45 02:30 3/19/2017 3/19/2017 1.50 SLOT PLUG TRIP P POOH f/ 2,739' to 13' MD wl cutting 2,739.0 13.0 02:30 04:00 1 1 1 assy. 3/19/2017 3/1912017 0.25 SLOT PLUG BHAH P UD cutter assy as per Baker. Cutters 13.0 0.0 04:00 04:15 were in good condition after a total of 3 cuts. 3/19/2017 3/19/2017 1.00 SLOT PLUG BHAH P PIU 7" spear assy to 230' MD. 0.0 230.0 04:15 05:15 3/19/2017 3/19/2017 1.25 SLOT PLUG TRIP P RIH f/ 230'to 2,512' MD on 4" DP. 230.0 2,512.0 05:15 06:30 3/19/2017 311912017 0.50 SLOT PLUG WASH P Washed down f/ 2,512'to 2,608'MD 2,512.0 2,608.0 06:30 07:00 w/ 3 bpm, 140 psi, P/U= 107, S/0= 100. 3/19/2017 3/19/2017 1.00 SLOT PLUG FISH P Engage fish at 2,686' MD and P/U 2,608.0 2,608.0 07:00 08:00 115k to confirm. Worked parameters up and fired jars at 190k and pulled free to 160k. Established circulation w/ 1 bpm, 390 psi. Pulled to 2,608' MD and CBU at 7 bpm, 340 psi. 3/1912017 3/19/2017 0.25 SLOT PLUG OWFF P OWFF, Well static. BD TD. 2,608.0 2,608.0 08:00 08:15 3/19/2017 3/19/2017 1.75 SLOT PLUG TRIP P POOH with 7" casing fish f/ 2,608'to 2,608.0 230.0 08:15 10:00 230' MD, 3/19/2017 3119/2017 0.75 SLOT PLUG BHAH P Rack back drill collars and UD jars. 230.0 0.0 10:00 10:45 3/1912017 3119/2017 1.00 SLOT PLUG PULD P R/U 7" casing equipment and UD 53' 0.0 0.0 10:45 11:45 7" casing fish. clear and clean dg Floor. 3/19/2017 3/192017 0.75 SLOT PLUG BHAH P MN 7" casing spear assy as per 0.0 230.0 11:45 12:30 Baker. 3/19/2017 3/19/2017 1.00 SLOT PLUG TRIP P RIH with spear assy f/230'to 2,608' 230.0 2,608.0 12:30 13:30 MD. 3/19/2017 3/19/2017 1.25 SLOT PLUG WASH P Wash down f/ 2,608'to 2,736' MD w/ 2,608.0 2,736.0 13:30 14:45 6.5 bpm, 550 psi, P/U= 106, S/0= 1 G0. 3/19/2017 311912017 0.75 SLOT PLUG FISH P Engaged 7" casing fish at 2,745' MD 2,736.0 2,643.0 14:45 15:30 and PIU to 125k to confirm. staged up - to 150k overpull firing jars and P/U 225k over to free fish. P/U to 2,643' MD to confirm. 3/19/2017 311912017 0.75 SLOT PLUG CIRC P Circulated 2 BU at 7 bpm, 350 psi. 2,643.0 2,643.0 15:30 16:15 SimOps, performed derrick inspection. 3/19/2017 3/192017 0.50 SLOT PLUG OWFF P OWFF, Well static. 2,643.0 2,643.0 16:15 16:45 3/19/2017 3119/2017 1.75 SLOT PLUG TRIP P POOH with 7" casing fish fl 2,643' to 2,643.0 230.0 16:45 18:30 230' MD. 3119/2017 3/19/2017 2.50 SLOT PLUG BHAH P UD Jars, R/B drill collars and released 230.0 0.0 18:30 21:00 from fish. 20k TQ and down weight were required to break spear out. 3/19/2017 3/19/2017 0.50 SLOT PLUG PULD P UD 44.24'7" casing fish. 0.0 0.0 21:00 21:30 3/19/2017 3/19/2017 1.00 SLOT PLUG BHAH P M/U spear assy as per Baker. 0.0 230.0 21:30 22:30 Page 9/27 ReportPrinted: 4/10/2017 operations Summary (with Timelog L,epths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Time End Time Our (hr)Phase Op Code Activity Cotle Time P -T -X Operation Start Depth ME) End Depth MKS) 3/19/2017 3/19/2017 1.25 SLOT PLUG TRIP P RIH with spear easy f/ 230'to 2,608' 230.0 2,608.0 22:30 23:45 MD. 3/19/2017 3/20/2017 0.25 SLOT PLUG WASH P Wash down f/ 2,608' MD to 2,703' MD 2,608.0 2,703.0 23:45 00:00 w/ 6.5 bpm, 330 psi. 3/20/2017 3/20/2017 2.25 SLOT PLUG FISH P Wash down f/ 2,703' MD to 2,737' MD 2,608.0 2,703.0 00:00 02:15 w/ 6.5 bpm, 330 psi. Observed slight pack offs f/ 2,737' to 2,739' MD. rotated down to 2,766' MD. shutdown pumps and engaged 7" casing at 2,787' MO. PIU 125k to confirm spear engaged. jarred 5 times w/ 250k and pulled fish free wl 330k. P/U to 2,703' and confirmed the spear had the fish. 3/20/2017 3/20/2017 1.75 SLOT PLUG CIRC P Circulated 2 BU wl4 bpm, 350 psi. 2,703.0 2,703.0 02:15 04:00 BD TD and OWFF. 3/20/2017 3/20/2017 2.50 SLOT PLUG TRIP P POOH f/ 2,703' to 230' MD. R/B 4" 2,703.0 230.0 04:00 06:30 DP. 3/20/2017 3/20/2017 2.00 SLOT PLUG BHAH P L/D drill collars, spear easy and 43' 230.0 0.0 06:30 08:30 long 7" casing fish as per Baker. 3/20/2017 3/2012017 2.00 SLOT PLUG RURD P UD fishing tools from rig floor and 0.0 0.0 08:30 10:30 change out 7" casing tools for 3 1/2" tubing tools. M/U XO to TIW valve. 3120/2017 3/20/2017 1.75 SLOT PLUG PULD P PIU 30 jts of 3 1/2" tubing and RIH 0.0 926.0 10:30 12:15 with mule shoe for cmt stinger. MIN XO to 4" XT39 and rig down 3 1/2" equipment. 3/20/2017 3/20/2017 2.75 SLOT PLUG TRIP P RIH w/ cmt stinger on 4" 14# DP f/ 926.0 3,088.0 12:15 15:00 944'to 3,088' MD and tag CIBP w/ 51k. 3/20/2017 3/20/2017 0.50 SLOT PLUG RURD P R/U headpin. swing, hoses, valves, 3,088.0 3,088.0 15:00 15:30 and cmt line. filled lines w/ mud. 3/20/2017 3/20/2017 1.25 SLOT PLUG CMNT P Tested lines to 2000 psi and pumped 3,088.0 3,088.0 15:30 16:45 25.4 bbl of 12.5 ppg spacer, 43.4 bbl 17 ppg cement, and 4.6 bbl of 12.5 ppg tail spacer. displaced w/ 18.8 bbl of 12 ppg brine. Balanced plug in place @ 16:45. 3/20/2017 3/20/2017 0.75 SLOT PLUG TRIP P RID head pin and cmt lines. Pull out 3,088.0 2,521.0 16:45 17:30 of cmt plug f/ 3,088, to 2,521' MD. 3/20/2017 3/2012017 2.25 SLOT PLUG CIRC P Drop nerf ball and circulate @ 7 bpm, 2,521.0 2,452.0 17:30 19:45 210 psi, and pump nut plug sweep. 3/20/2017 3/20/2017 1.25 SLOT PLUG OWFF P OWFF, well static. Pumped 15 bbl, 2,452.0 2,452.0 19:45 21:00 13.3# dry job to stop DP overflowing. 3/20/2017 3/20/2017 0.75 SLOT PLUG TRIP P POOH f/ 2,452'to 944' MD. 2,452.0 944.0 21:00 21:45 3/20/2017 3/20/2017 2.00 SLOT PLUG PULD P UD 30 jts of 3 1/2" tubing. 944.0 0.0 21:45 23:45 3/20/2017 3/21/2017 0.25 SLOT PLUG RURD P RID tubing running tools. 0.0 0.0 23:45 00:00 3/21/2017 3/21/2017 0.50 SLOT PLUG RURD P R/D tubing running tools and clear 0.0 0.0 00:00 00:30 1 floor. 3/21/2017 3/21/2017 1.00 SLOT PLUG W W WH P Removed wear ring as per FMC and 0.0 0.0 00:30 01:30 flushed stack w/ 10 bpm, 20 psi, and 5 rpm. BD TD. 3/21/2017 3/21/2017 1.00 SLOT WHDBOP RURD P Installed test plug and 4" test joint. 0.0 0.0 01:30 02:30 Filled stack w/ H2O and purged it of air. Page 10127 Report Printed: 4110/2017 a,aerations Summary (with Timelog L„ pths) CD3 -111 • _ Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log sten Depth Stan Time End Time Our (m) Phase Op Code Activity Code Time PJ.X Operation ffl(B) EM Depth(WER) 3/21/2017 3/21/2017 4.50 SLOT WHDBOP BOPE P Test SOPS with 4" test joint. AOGCC 0.0 0.0 02:30 07:00 Brian Bixby witnessed. Test Annular to 250/2500 psi, all rams and valves to 250/3800 psi 5 min each charted. 4" TJ test annular preventer, Choke valves #1,12,13,14, Upper IBOP/ Upper VBR, 4" Demco kilt/ CV #9,11, lower IBOP, HCR kill/ CV #5,8,10/ CV #4,6,7/ CV #2/ HCR Choke / Manual choke and klIV Lower VBR's. Perform accumulator function test. System pressure=2900 psi, Manifold pressure=1450 psi, Annular pressure=850 psi. System pressure after functioning all rams and HCR's=1300 psi. 200 psi attained @ 32 sec, Full system recovery @ 186 sec. 4 bottle N2 average=2000 psi. Operate remote stations. Pull test joint and test blind rams, Tested gas detecters, function flow meter, check PVT alarms. 3/21/2017 3/21/2017 1.00 SLOT WHDBOP RURD P RID BOP test equipment and removed 0.0 0.0 07:00 08:00 test plug. Installed 10" ID wear ring and bleed down lines. 3/21/2017 3/21/2017 1.00 SLOT PLUG RURD P Mobilize BHA components to the rig 0.0 0.0 08:00 09:00 floor and clear floor. Removed skate roller. 3/21/2017 3/21/2017 3.00 SLOT PLUG PULD P MIN and rack back 29 stands of 4" 0.0 0.0 09:00 12:00 14# OR 3/21/2017 321/2017 0.75 SLOT PLUG PULD P PIU fishing tools to rig floor and break 0.0 0.0 12:00 12:45 1 1 off XOs from surface jars. 3/21/2017 321/2017 1.75 SLOT PLUG SHAH P WU motor drill out assy as per SLB to 0.0 447.0 12:45 14:30 447' MD. 3/21/2017 3/21/2017 2.00 SLOT PLUG PULD P Singled in the hole w/ 4" 14# DP from 447.0 2,048.0 14:30 16:30 the pipe shed f/ 447' to 2,048' MD. 3/21/2017 3/21/2017 0.25 SLOT PLUG TRIP P RIH f/ 2,048'to 2,331' MD 2,048.0 2,331.0 16:30 16:45 3/212017 3/21/2017 0.50 SLOT PLUG DHEQ P Shallow tested MWD tools w/450 2,331.0 2,331.0 16:45 17:15 1 gpm, 1190 psi. 3/21/2017 3/21/2017 0.25 SLOT PLUG RURD P R/U casing test equipment and tested 2,331.0 2,331.0 17:15 17:30 lines to 2500 psi. 3/212017 3/21/2017 0.75 SLOT PLUG PRTS P Pressure tested rasing to 2500 psi for 2,331.0 2,331.0 17:30 18:15 30 min. 3/21/2017 3/212017 0.25 SLOT PLUG RURD P R/D casing test equipment and BD 2,331.0 2,331.0 18:15 18:30 lines. 3/21/2017 3/21/2017 0.75 INTRMI DRILL WASH P Wash down f/ 2,331'to 2,519' MD at 2,331.0 2,519.0 18:30 19:15 450 gpm, 1260 psi and tagged TOC @ 2,519' MD. 3/21/2017 3/21/2017 3.00 INTRMI DRILL DRLG P Drill out cmt f/ 2,519' to casing shoe at 2,519.0 2,721.0 19:15 22:15 2,721' MD. 500 gpm, 1560 psi, 50 rpm, 4k TQ. 321/2017 3/22/2017 1.75 INTRMI DRILL DDRL P Drilled f/ 2,721'to 2,777' MD, kicking 2,721.0 2,777.0 22:15 00:00 off of cmnt plug. 3/222017 3/22/2017 7.00 INTRMI DRILL DDRL P Drill N 2,777' [0 3,274' MD w/ 575 2,777.0 3,274.0 00:00 07:00 gpm, 1800 psi, 50 rpm, 51k TO. Pumped 25 bbl of 11 ppg spacer and displaced well to 9.6 ppg LSND on the fly. 2,958' TVD. Page 11127 ReportPrinted: 4110!2017 „aerations Summary (with Tim®log L._pths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Slad Depth Start Time End rime Dur (hr) Phase Op Cotle Ac ty Cotle Time P -T-% Operation (ftKB) End Depen (fU(B) 3/22/2017 3/22/2017 0.75 INTRMI DRILL CIRC P Pumped 31 bbl nut plug sweep and 3,274.0 3,274.0 07:00 07:45 circulated well clean w/ 575 gpm, 1540 psi, and 50 rpm. 3/22/2017 3122/2017 0.25 INTRMI DRILL OWFF P OWFF, Well Static, 3,274.0 3,274.0 07:45 08:00 3/22/2017 3/22/2017 1.25 INTRMI DRILL SRW P Drop gyro tool and pump down w/ 3 3,274.0 2,804.0 08:00 09:15 bpm, 170 psi, and land above the float. Took gyro shots every 30'f/ 3,274'to 2,803' MD. 3/22/2017 3122/2017 2.25 INTRM1 DRILL TRIP P POOH f/ 2,803'to 448' MD. 2,804.0 448.0 09:15 11:30 3/22/2017 3/22/2017 1.50 INTRM1 DRILL BHAH P RIB HWDP and UD motor assy. 448.0 0.0 11:30 13:00 3/22/2017 3/22/2017 2.25 INTRMI DRILL SHAH P M/U 8 3/4” rotary steerable BHA as 0.0 484.0 13:00 15:15 per SLB. 3/22/2017 3/22/2017 0.75 INTRMI DRILL TRIP P RIH f/484'to 1,895' MD. 484.0 1,895.0 15:16 16:00 3/2212017 3122/2017 0.50 INTRMI DRILL DHEQ P Shallow test MWD w/ 450 gpm, 930 1,895.0 1,895.0 16:00 16:30 psi. BD TD. 3/22/2017 3/22/2017 0.50 INTRMI DRILL TRIP P RIH f/ 1,895'to 2,650' MD. 1,895.0 2,650.0 16:30 17:00 3/222017 3/22/2017 1.00 INTRMI DRILL SLPC P Slip and Cut 45' of drill line. 2,650.0 2,650.0 17:00 18:00 3/2212017 3/2212017 0.50 INTRMI DRILL SVRG P Service TO and drawworks. 2,650.0 2,650.0 18:00 18:30 3222017 3/22/2017 1.25 INTRMI DRILL REAM P Washed down f/ 2,650'to 3,246' MD 2,650.0 3,246.0 18:30 19:45 due to weight w/ 3 bpm, 240 psi, 20 rpm, 3.5k TO. 3/222017 3/22/2017 0.50 INTRMI DRILL DHEQ P Took Initial parameters at 600 gpm, 3,246.0 3,246.0 19:45 20:15 1870 psi, 40 rpm, TRPM 3125, and 3.6k TO. Dropped 1.25" ball and pumped down w/ 150 gpm, 230 psi, 30 rpm. Observed shear w/440 psi at 250 stks. Increased flow to 600 gpm and compared parameters. 1520 psi, 40 rpm, TRPM 2578, 3.5k TO. Turned pumps off and S/O w/ 8k WOB. REAMED OPEN 3/2212017 3/23/2017 3.75 INTRMI DRILL DDRL P Drill f/ 3,274'to 3,782' MD, pumping 3,246.0 3,782.0 20:15 00:00 high vis sweep every other stand. 3/23/2017 3/23/2017 8.75 INTRMI DRILL DDRL P Drill f13,782'to 5,01V MD, pumping 3,782.0 5,011.0 00:00 08:45 high vis sweep every other stand. 3/23/2017 3123/2017 1.00 INTRMI DRILL CIRC P Pumped low vis 24 bbl anti jamming 5,011.0 5,011.0 08:45 09:45 pill to trouble shoot MWD issues. 3/23/2017 3/23/2017 1.50 INTRMI DRILL DDRL P Drilled f/ 5,011'to 5,111' MD, trouble 5,011.0 5,111.0 09:45 11:16 shooting MWD communication issues w/ low vis sweeps. Communication with tool continued to decline. 3/23/2017 323/2017 0.25 INTRMI DRILL TRIP T Racked back a stand to 5,106' MD 5,111.0 5,106.0 11:15 11:30 3/23/2017 3/232017 1.50 INTRMI DRILL CIRC T Circulated at 750 gpm, 3110psi and 5,106.0 4,917.0 11:30 13:00 160 rpm 6k TO, while trying to establish communication with MWD. No success. BD TD. 3/23/2017 3/23/2017 1.75 INTRMI DRILL TRIP T POOH f/ 4,917'to 3,499'MD. 4,917.0 3,T9-9-0- 13:00 14:45 3/2312017 3/23/2017 0.25 INTRMI DRILL OWFF T OWFF, Well Static. 3,499.0 3,T9-9-0- 14:45 15:00 Page 12127 Report Printed: 411012017 aerations Summary (with Timelog "pths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stag Time End Time Dw(hq Phase DP Cafe Activlty Code Time P -T -K Operation start Depth (itKB) End Depth(ftKB) 3/23/2017 3/23/2017 3.50 INTRMI DRILL TRIP T POOH f/ 3,499'to 484' MD. 3,499.0 484.0 15:00 1830 Encountered tight spots @ 2,964', 2,933', and 2,792' MD. 3/23/2017 3/23/2017 1.75 INTRMI DRILL BHAH T RIB HWDP and drill collars. UD MWD 484.0 0.0 18:30 20:15 and power drive. 3/23/2017 3/2312017 0.50 INTRM1 DRILL CLEN T Clear and dean dg Floor of clay. 0.0 0.0 20:15 20:45 3/23/2017 3/23/2017 1.00 INTRM1 DRILL SHAH T M/U 8 3/4" BHA w/ new MWD tools. 0.0 485.0 20:45 21:45 3/23/2017 3/23/2017 0.75 INTRMI DRILL TRIP T RIH f/ 485' to 1,896' MD. 485.0 1,896.0 21:45 22:30 3/23/2017 3123/2017 0.50 INTRMI DRILL DHEQ T Shallow tested MWD w/550 gpm, 1,896.0 1,896.0 22:30 23:00 1210 psi. BD TD. 3123/2017 3/24/2017 1.00 INTRMI DRILL TRIP T RIH f/ 1,896' to 3,123' MD. 1,896.0 3,123.0 23:00 00:00 3/24/2017 3124/2017 1.75 INTRMI DRILL TRIP T RIH f/ 3,123'to 5,012'MD. 3,123.0 5,012.0 00:00 01:45 3/24/2017 3/24/2017 0.50 INTRMI DRILL REAM T Ream down f/ 5,012'to 5,111' MD w/ 3,123.0 5,111.0 01:45 02:15 600 gpm, 2400 psi, 100 rpm, and 5.5k TQ. 3/24/2017 3/24/2017 9.75 INTRM1 DRILL DDRL P Drilled U 5,11 V ID 6,294'MD, 5,620 5,111.0 5,620.0 02:15 12:00 TVD. 3/24/2017 3/24/2017 2.25 INTRMI DRILL DDRL P Drilled f/ 6,294' to 6,523' MD. 5,620.0 6,523.0 12:00 14:15 3/24/2017 3/24/2017 1.00 INTRMI DRILL CIRC P Circulated 2 BU at 750 gpm, 3800 psi, 6,523.0 6,523.0 14:15 15:15 140 rpm, 7k TQ. 3/24/2017 3/24/2017 0.75 INTRMI DRILL MPDA P Removed trip nipple and installed 6,523.0 6,523.0 15:15 16:00 RCD bearing. Rotated at 50-100 rpm to break in bearing. 3/24/2017 3/25/2017 8.00 INTRMI DRILL DDRL P Drilled f/6,523'to 7,187' MD, 6,391' 6,523.0 7,187.0 16:00 00:00 TVD. Weighted up to 10.3 ppg on the fly, as per plan. 3/25/2017 3/25/2017 11.00 INTRMI DRILL DDRL P Drilled f/ 7,187'to 8,004' MD. 7,187.0 8,004.0 00:00 11:00 3125/2017 3125/2017 0.50 INTRMI DRILL SVRG P Lubricated TD and changed out swab 8,004.0 8,004.0 11:00 11:30 and liner on pump #2. Circulated mud at 400 gpm, 1710 psi, 100 rpm, and 7.5k TQ. 3/25/2017 3/25/2017 0.25 INTRMI DRILL CIRC P Took slow pump rates. 8,004.0 8,004.0 11:30 11:45 3/25/2017 13/26/2017 3/25/2017 0.25 INTRMI DRILL DDRL P Drilled f/ 8,004'to 8,011' MD, 6.853' 8,004.0 8,011.0 11:45 12:00 TVD. ,3/25/2017 12.00 INTRMI DRILL DDRL P Drilled f/ 8,01 Vic, 8,419'MD, 6,927' 8,011.0 8,419.0 12:00 00:00 TVD. 3/26/2017 3/26/2017 3.00 INTRMI DRILL DDRL P Drilled f/ 8,450'to TD of 8,540' MD, 8,419.0 8,540.0 00:00 03:00 6,935' TVD. 3126/2017 3/2612017 5.75 INTRMI CASING CIRC P Circulated well clean w/ 8 BU while 8,540.0 8,424.0 03:00 08:45 POOH to 8,424' MD. Weighted up to a 10.8 ppg MW while cleaning hole. 660 gpm, 4030 psi, 150 rpm, 9k TQ. 3/26/2017 3/26/2017 0.75 INTRMI CASING CIRC P Closed UR with 1.625" ball. Pumped 8,424.0 8,424.0 08:45 09:30 down w/ 654 stks and observed ball seat w/ 1940 psi. Confirmed UR dosed with increase in turbine RPM, and increase pump pressure. Took slow pump rates. 3/26/2017 3/26/2017 0.25 INTRMI CASING OWFF P OWFF, well static. 8,424.0 8,424.0 09:30 09:45 Page 13127 Report Printed: 4/1012017 _perations Summary (with Timelog .. pths) CD3-111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start DWh Sfsd Time End Time Dur(hr) Phase Op Code AcIiAy Code Time P-T-% Opera9an (aKB) End Depth (110) 3/26/2017 3/26/2017 6.75 INTRMI CASING STRP P SOOH f/ 8,424'to 2,715' MD holding 8,424.0 2,715.0 09:45 16:30 100-170/30 psi outlin slips. Observed tight spots at 7,211', 6,274', and 2,971' MD w/ 25-35k over pull. 3/26/2017 3/26/2017 0.75 INTRMI CASING CIRC P Circulate a BU at the 9 5/8" casing 2,715.0 2,715.0 16:30 17:15 shoe. 640 gpm, 2260 psi, 90 rpm, 3.5k TO. 3/26/2017 3/26/2017 0.50 INTRMI CASING OWFF P OWFF, well static. B/D lines. 2,715.0 2,715.0 17:15 17:45 3/26/2017 3/26/2017 1.50 INTRMI CASING SMPD P SOOH f/ 2,715' to 485' MD holding 2,715.0 485.0 17:45 19:15 30/170 psi in/out of slips. 3/26/2017 3/26/2017 0.25 INTRMI CASING OWFF P OWFF, well static. 485.0 485.0 19:15 19:30 3/26/2017 3/26/2017 0.50 INTRMI CASING MPDA P Removed RCD bearing and installed 485.0 485.0 19:30 20:00 trip nipple. 3/26/2017 3/26/2017 2.00 INTRMI CASING BHAH P UD Intermediate BHA as per SLB. 485.0 0.0 20:00 22:00 3/26/2017 3/26/2017 0.75 INTRMI CASING RURD P Cleaned and cleared rig floor, 0.0 0.0 22:00 22:45 changed elevators, M/U stack washing Pool and flushed the stack. 3/26/2017 3/27/2017 1.25 INTRMI CASING BOPE P Pulled the wear ring and changed out 0.0 0.0 22:45 00:00 upper rams to 7". SimOps, UD tools from rig floor. 3/27/2017 3/27/2017 1.75 INTRMI CASING BOPE P Tested 7" rams to 250/3800 psi and 0.0 0.0 00:00 01:45 annular to 250/2500 psi. w/ 7" test joint. R/D test equipment and installed 10.25" ID wear ring. 3/27/2017 3/27/2017 1.25 INTRMI CASING RURD P R/U Volant tool, bail extensions, 7" 0.0 0.0 01:45 03:00 elevators, and 350T Spider Slips. P/U shoe joint and remove bell guide from TD. 3/27/2017 3/27/2017 10.00 INTRMI CASING PUTB P RIH wl 7" 26# L80 casing f/ surface to 0.0 5,640.0 03:00 13:00 5,640' MD. Checked floats at surface and Bakorloked first 5 its. 3/27/2017 3/27/2017 1.50 INTRMI CASING CIRC P Circulated BU as per plan at 5,640' 5,640.0 5,640.0 13:00 14:30 MD w/ 430 gpm, P/U 175, S/O= 140 3/27/2017 3/27/2017 6.25 INTRMI CASING PUTB P RIH W/ 7" casing f/ 5,640'to 8,495' 5,640.0 8,495.0 14:30 20:45 MD. 3/27/2017 3/27/2017 0.50 INTRMI CASING HOSO P M/U hanger, landing joint and land 8,495.0 8,530.0 20:45 21:15 casing at 8,530' MD. 3/27/2017 3/27/2017 0.50 INTRM1 CEMENT CIRC P Established circulation at 1 bpm, 640 8,530.0 8,530.0 21:15 21:45 psi and reciprocated pipe. 3/27/2017 3/27/2017 0.50 INTRMI CEMENT RURD P Rigged up cement lines to Volant 8,530.0 8,530.0 21:45 22:15 closed IBOP. 3/27/2017 3/28/2017 1.75 INTRMI CEMENT CIRC P Circulated and conditioned mud, 8,530.0 8,530.0 22:15 00:00 staging up f/ 0.5 bbl to 8 bbl at 720 psi. 3/28/2017 3/28/2017 1.25 INTRMI CEMENT CIRC P Continue circulate and condition for 8,530.0 8,530.0 00:00 01:15 cement job @ 8 bpm, 720 psi. SIMOPS- Rig down rasing elevators, load pipe shed with 3-1/2" tubing. Hold PJSM on cement job. Page 14/27 Report Printed: 4/1012017 perations Summary (with Timelotg "piths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stag Time End Time Writer) Phase Op Cotle Activity Cafe Time P -T -x OpIllon sten Depth (flKe End Depth (110) 3128/2017 3/28/2017 1.75 INTRMI CEMENT CMNT P SLB flood and test surface lines to 8,530.0 4,699.0 01:15 03:00 4000 psi- good. Bleed off pressure. SLB pumped 40 bbl 12.5 ppg MudPush II spacer 3.4 bpm 340 psi. Drop bottom (bypass) plug. SLB pumped 49.1 bbl 15.8 ppg Qannik ( Yield 1.16 cuf /sx)(238 sks) slurry @ 4 bpm 338-205 psi. Shut down and load top (shutoff) plug, SLB kick out plug with 10.1 bbl water. Rig displace cement with 10.8 ppg LSND @ 8 bpm 470-900 psi FCP for 3000 stks, slow rate to 3 bpm 470 psi and bump plug @ 3111 stks. Pressure up to 970 psi and hold for 5 min. OWFF- Static. Bleed off pressure and check floats - good. Pressure up to 3000 psi and observe stage collar open (4,699' MD). Full returns throughout cement job, landed on hanger no reciprocation. 3/28/2017 3/28/2017 1.00 INTRMI CEMENT CIRC P Establish circulation through stage 4,699.0 4,699.0 03:00 04:00 collar, stage up from 2-8 bpm, 140- 530 psi, CBU. SIMOPS- PJSM on second stage cement job. 3/28/2017 3/28/2017 1.25 INTRMI CEMENT CMNT P SLB pumped 30 bbl 11.5 ppg 4,699.0 0.0 04:00 05:15 MudPush II @ 3.6 bpm, 220 psi, follow with 44.1 bbl 15.8 ppg Qannik ( Yield 1.16 cuft/sx)( 214 sks) slurry @ 4.7 bpm, 300 psi. Shut down and drop closing plug. SLB kick out plug with 10 bbl water, rig displace with 10.8 ppg LSND @ 8 bpm 330-780 psi, reduce to 3 bpm 540 psi @ 1400 stks, bump plug @ 1697 stks. Pressure up to 2200 psi, observe stage collar shift closed @ 1620 psi. Hold 2200 psi for 3 min per HES, bleed off pressure and OWFF static. 3/28/2017 3/28/2017 2.00 INTRMI CEMENT RURD P Rig down Volant CRT, lay down 7" 0.0 0.0 05:15 07:15 hand slips and bushings. Blow down top drive, lay down landing joint. 3/28/2017 3/28/2017 1.25 INTRMI CEMENT W WSP P FMC pull wear ring and set 9-518" x7" 0.0 0.0 07:15 08:30 packoff. RILLDS and test 7" packoff to 5000 psi, witnessed by CPA[. SIMOPS- PJSM- change out saver sub and Auto/Manual IBOP's 3/28/2017 3/28/2017 1.25 INTRMI CEMENT RURD P Change out upper rams from 7" SBR 0.0 0.0 08:30 09:45 to 3-112" x 6" VBR's. SIMOPS- Change out saver sub and IBOP's. 3/28/2017 328/2017 3.75 INTRMI CEMENT RURD P Continue installing saversub, install 0.0 0.0 09:45 13:30 bell guide and safety wire bolts. 3/28/2017 3/28/2017 0.50 INTRMI CEMENT SVRG P Service iron roughneck and 0.0 0.0 13:30 14:00 drawworks. Page 15127 ReportPrinted: 4/10/2017 _perations Summary (with Timelog ., pths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Mme End Mme Dur Mr) Phase Op Code Activity CodeTime P -T -X Opewtlon Start Depth (ftKB) End Depth (ttKB) 3/28/2017 3/28/2017 1.50 INTRM1 WHDBOP RURD P M/U floor valve, dart valve, P/U 3-1/2" 0.0 0.0 14:00 15:30 test joint and set test plug. R/U and fill lines/ stack / manifold for BOPE testing. 3/28/2017 3/28/2017 5.75 INTRMI WHDBOP BOPE P Test annular to 250/2500 psi, all other 0.0 0.0 15:30 21:15 BOPE to 250/3800 psi w/3%" R 4%" TJ. AOGCC Guy Cook waived witness. With 3Y2" TJ test annular 250/2500 psi. Test Upper 3W' x 6" VBR's, lower 3%" x 6" VBR's, choke valves #1-14, choke needle valve above valve 1, HCR choke and kill, manual choke and kill, 4" Demco kill, Auto and manual IBOP, 4" XT -39 FOSV and Dart valves to 250-3800 psi. Change to 4W' test joint, test annular 250/2500 psi, Test Upper VBR's, Lower VBR's to 250/3800 psi, all tests 5 min ea charted. SIMOPS- Replace stem seals on manual choke. 3/28/2017 3/28/2017 0.25 INTRMI WHDBOP BOPE P Perform accumulator test, Initial 0.0 0.0 21:15 21:30 system pressure=2975 psi, Pressure after functioning=1475, 200 psi attained with electric pump=35 sec, Full system recovery with electric and air pumps=187 sec. 4 bottle N2 average=2000 psi. 3/28/2017 3/28/2017 0.50 INTRMI WHDBOP ROPE P Pull test joint, Test blind rams to 0.0 0.0 21:30 22:00 250/3800 psi, drawdown test manual and super auto choke to 1200 psi. SIMOPS- GIS performed annular flush and freeze protect on CD3 -111A. Formation broke over readily @ 790 psi with 2 bbl pumped. Continue 300 bbl water Flush, followed by 20 bbl warm diesel from GIS and 40 bbl recovered from de -completion. 3/28/2017 3/28/2017 0.75 INTRMI WHDBOP RURD P Rig down test equipment, remove test 0.0 0.0 22:00 22:45 plug and set 7" ID wear ring. SIMOPS- blow down choke and kill. 3/28/2017 3/29/2017 1.25 INTRM1 CEMENT BHAH P PJSM, Make up 6-1/8" RSS 0.0 155.0 22:45 00:00 production BHA per DD/MWD to 155' MD 3/29/2017 3/29/2017 1.50 INTRMI CEMENT PULD P Single in hole from 155' MD to 1,750' 155.0 1,750.0 00:00 01:30 MD with production BHA, picking up 4" 14# Drill Pipe from pipe shed 3/29/2017 3/29/2017 0.50 INTRMI CEMENT DHEQ P Shallow lest MWD, 210 gpm, 1310 1,750.0 1,750.0 01:30 02:00 psi. Good test. P/U=85k, S/0=85k 3/29/2017 329/2017 2.50 INTRMI CEMENT PULD P Continue single in hole 1,750' MD to 1,750.0 4,577.0 02:00 04:30 4,577' MD picking up 4" 14# drill pipe from pipe shed, fill pipe every 20 stands. 3/29/2017 329/2017 0.25 INTRMI CEMENT REAM P Precautionary wash/ ream down from 4,577.0 4,655.0 04:30 04:45 4,577' MD to 4,655' MD @ 200 gpm, 1440 psi, 40 rpm, 3k Tq. Tag firm cement Cot 4,655' MD. P/U=125k, S10=1 05k, R0T=115k. Page 16127 Report Printed: 4110/2017 ..aerations Summary (with Timelog Lr pths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log start Time End rime Our (hr) Phase Op Code Aotiviy Code Time P -T-% OparaGon StanDepthDepth 0) End Depth(WEn 3/29/2017 3/29/2017 1.00 INTRMI CEMENT DRLG P Drill out cement and stage collar from 4,655.0 4,700.0 04:45 05:45 4,655' MD to 4,700' MD with stands from derrick. Tag stage collar on depth @ 4,699', 5-10k WOB, 130-200 gpm, 670-1440 psi, 40-50 rpm, 4-7k Tq. 3/29/2017 3/29/2017 1.00 INTRMI CEMENT REAM P Wash/ ream down from 4,700' MD to 4,700.0 4,955.0 05:45 06:45 4,955' MD out of derrick, 200 gpm, 1370 psi, 50 rpm, 4k Tq. Blow down top drive and OWFF static. 3/29/2017 3/29/2017 0.25 INTRMI CEMENT TRIP P POOH from 4,955' MD to 4,577' MD 4,955.0 4,577.0 06:45 07:00 racking stands back in derrick. 3/29/2017 3/29/2017 1.25 INTRMI CEMENT PULD P Continue single in hole 4,577' MD to 4,577.0 5,807.0 07:00 08:15 5,807' MD picking up 4" 14# drill pipe from pipe shed, fill pipe every 20 stands. 3/29/2017 3/29/2017 0.50 INTRMI CEMENT QEVL P P/U stand to 5,705', downlink to 5,807.0 5,807.0 08:15 08:45 Sonicsco a 210 p gpm, 1550 psi. Pumps off. Log down from 5,705' MD to 5,807' MD @ 900 fph to obtain free ring signature. 3/29/2017 3/29/2017 0.75 INTRMI CEMENT PULD P Continue single in hole 5,807' MD to 5,807.0 6,755.0 08:45 09:30 6,755' MD picking up 4" 14# drill pipe from pipe shed, 3/29/2017 3/29/2017 2.50 INTRMI CEMENT QEVL P Continue singling in hole with 4" DP 6,755.0 7,826.0 09:30 12:00 from shed, 6,755' MD to 7,826' MD, logging with Sonirscope @ 900 fph, 3/29/2017 3/29/2017 1.75 INTRM1 CEMENT QEVL P Continue singling in hole with 4" DP 7,826.0 8,262.0 12:00 13:45 from shed, 7,826' MD to 8,262' MD, String took weight @ 8,007' and 8,237', wash and ream @ 200 gpm, 1520-1580 psi, 50 rpm, 6-6.5k Tq. 3/29/2017 3/29/2017 0.50 INTRMI CEMENT RURD P Blow down topdrive and dg up for 8,262.0 8,262.0 13:45 14:15 casing lest. 3/29/2017 3/29/2017 0.75 INTRMI CEMENT PRTS P Test casing to 3500 psi for 30 minutes 8,262.0 8,262.0 14:15 15:00 -good, 4.1 bbl pumped. SIMOPS- PJSM on cut/slip drilling line. 3/29/2017 3/29/2017 0.25 INTRMI CEMENT RURD P Blow down lines and rig down test 8,262.0 8,262.0 15:00 15:15 equipment. 3/29/2017 3/29/2017 1.00 INTRM1 CEMENT SLPC P Slip and cut 38' of drilling line, 8,262.0 8,262.0 15:15 16:15 calibrate block height. 3/2912017 3/29/2017 0.50 INTRMI CEMENT SVRG P Service top drive and draworks. 8,262.0 8,262.0 16:15 16:45 3/29/2017 3/29/2017 0.75 INTRMI CEMENT COCF P Wash and ream from 8,262' MD to 8,262.0 8,392.0 16:45 17:30 8,392'tag firm cement. 3/29/2017 3/29/2017 2.25 INTRMI CEMENT DRLG P Drill out baffle collar, Float collar, shoe 8,392.0 8,540.0 17:30 19:45 track, float shoe on depth and rathole from 8,392' MD to 8,540' MD, 130-200 gpm, 930-1720 psi, 40-80 rpm, 8-11 k Tq, 5-15k WOB. 3/29/2017 3/29/2017 0.50 INTRMI CEMENT DDRL P Drill new formation from 8,540' MD to 8,540.0 8,560.0 19:45 20:15 8,560' MD, 6,936' TVD, 200 gpm 1740 psi, 80 rpm, 10.5k Tq. ADT=.35 hrs. 3/29/2017 3/29/2017 0.50 INTRMI CEMENT CIRC P Circulate and condition for FIT, pump 8,560.0 8,560.0 20:15 20:45 bottoms up @ 200 gpm 1780 psi, 80 rpm, 8.5k Tq. MW 10.75 ppg in/out. 3/29/2017 3/29/2017 0.50 INTRMI CEMENT TRIPP Pump out of hole from 8,560'to 8,420' 8,560.0 8,420.0 20:45 21:15 MD @ 200 gpm, 1560 psi. Page 17/27 ReportPrinted: 4110/2017 —Aerations Summary (With Timelog L dpths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stan Time End Time our (hr) Phase Op Code Activity Cotle Time P -T-% Operation Sun Depth (WIS) End Depth(IIKB) 3/29/2017 3129/2017 0.25 INTRMI CEMENT RURD P Rig up for FIT, OWFF static. 8,420.0 8,420.0 21:15 21:30 3/29/2017 3/29/2017 0.75 INTRMI CEMENT FIT P Perform FIT to 12.5 ppg EWM, 8,420.0 8,420.0 21:30 22:15 pumped .7 bbl, 631 psi with 10.75 ppg mud. Rig down and blow down lines. 3129/2017 3/29/2017 0.50 PROD1 DRILL MPDA P Pull trip nipple and install MPD 8,420.0 8,420.0 22:15 22:45 bearing/elements. 3/29/2017 3/29/2017 0.50 PROD1 DRILL TRIP P RIH from 8,420' MD to 8,560' MD 8,420.0 8,560.0 22:45 23:15 3/29/2017 3/30/2017 0.75 PROD1 DRILL DDRL P Directional drill 8,560' MD to 8,617' 8,560.0 8,617.0 23:15 00:00 MD, 6,940' TVD. 210 gpm, 2070 psi, 80 rpm, 11k Tq. P/U=205k, S/0=135k, ROT=150k. Displace to 10.0 ppg FloThru on the fly. ADT=.88 hrs. OA pressure @ 23:59 hrs=750 psi 3/30/2017 3/30/2017 0.50 PROD1 DRILL DDRL P Directional drill 8,617' MD to 8,642' 8,617.0 8,642.0 00:00 00:30 MD, 6,940' TVD. 210 gpm, 2070 psi, 80 rpm, Ilk Tq. P/U=205k, S/0=135k, ROT=150k. Continue displace to 10.0 ppg FloThru on the 6y. ADT=.31 hrs. 3/30/2017 3/30/2017 0.25 PROD1 DRILL DISP P Circulate and complete FloThru 8,642.0 8,642.0 00:30 00:45 displacement 200 p gpm, 1650 psi, 100 rpm, 6.5k Tq. obtain SPR's with 10.0 Ppg 3/30/2017 3/30/2017 0.75 PROD1 DRILL OWFF P Monitor well with MPDE, shut in and 8,642.0 8,642.0 00:45 01:30 build to 186 psi in 35 minutes. (10.52 ppg EMM 3/30/2017 3/30/2017 5.50 PROD1 DRILL DDRL P Directional drill 8,642' MD to 9,489' 8,642.0 9,489.0 01:30 07:00 MD, 6,932' TVD. 220 gpm, 2015 psi, ECD=11.34 ppg, 150 rpm, Tq onloff= 10WA. P/U=172k, S/0=123k, ROT=145k. ADT=4.2 hrs. 3/30/2017 3/30/2017 1.25 PROD1 DRILL OWFF P Monitor well with MPDE and exhale 9,489.0 9,489.0 07:00 08:15 test. Shut in and build to 170 psi in 15 minutes, bleed off 1.5 bbl in 10 minutes. Shut in and build 113 psi in 15 minutes, bleed off 1 bbl in 10 minutes. Shut in and build 74 psi in 15 minutes. 3/30/2017 3/30/2017 3.75 PROD1 DRILL DDRL P Directional drill 9,489' MD to 10,100' 9,489.0 10,100.0 08:15 12:00 MD, 6,929' TVD. 220 gpm, 2090 psi, ECD=11.4 ppg, 130 rpm, Tq on/off= 10.5W7k. P/U=170k, S/0=123k, ROT=143k. Tour ADT=6.98 hrs. OA pressure=750 psi @ 11:00 hrs 3/30/2017 3/30/2017 2.50 PROD1 DRILL DDRL P Directional drill 10,100' MD to 10,526 10,100.0 10,526.0 12:00 1430 MD, 6,929' TVD. 220 gpm, 2090 psi, ECD=11.4 ppg, 130 rpm, Tq on/off= 10.5k/7k. P/U=170k, S/0=123k, ROT=143k. ADT=1.81 hrs. Page 18127 Report Printed: 4/10/2017 -.perations Summary (with Timeiog L epths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log StenTime Eno Time our ( Phase Op Cptle Activity Code rime P -T-% Operation Start Depth (MB) End DepN (MB) 3/30/20117 3/30/2017 0.7.7 5 PROD1 DRILL OWFF P Formation fingerprint test, shut in and 10,526.0 10,526.0 14:30 15:15 monitor build up to 395 psi in 15 minutes. Bled back 3.5 bbl in 4 minutes. Shut in and monitor build up to 391 psi in 15 minutes. 3/30/2017 3/30/2017 1.25 PROD1 DRILL CIRC P CBU @ 220 gpm, 2230 psi, 90 rpm, 10,526.0 10,526.0 15:15 16:30 6.5k, taking returns through gas buster. Slight gas cut on bottoms up 8.8 ppg mud balance. Decision to weight up from 10.0 ppg to 10.3 ppg. 3/30/2017 3/30/2017 4.00 PROD1 DRILL CIRC P Circulate, rotate and reciprocate while 10,526.0 10,526.0 16:30 20:30 weight up active system from 10.0 ppg to 10.3 ppg. 220 gpm, 40-60 rpm, 5-6k Tq. Taking returns through gas buster. 3/30/2017 3/30/2017 1.00 PROD1 DRILL OWFF P Formation fingerprint test, shut inand 10,526.0 10,526.0 20:30 21:30 monitor build up to 467 psi in 15 minutes. Bled back 2 bbl in 8 minutes. Shut in and monitor build up to 444 psi in 15 minutes. (Note: No cuttings load in annulus due weight up) Decision to weight up to 10.5 ppg on the fly, continue monitoring shut in pressures. 3/30/2017 3/31/2017 2.50 FROM DRILL DDRL P Directional drill 10,526' MD to 10,860' 10,526.0 10,860.0 21:30 00:00 MD, 6,930' TVD. 216 gpm, 2270 psi, ECD=12.05 ppg, 130 rpm, Tq on/off- 1lk/5.5k. P/U=165k, S/0=125k, ROT=145k. Tour ADT=3.31 hrs. Weight up FloThru mud system from 10.3 ppg to 10.5 ppg on the fly while drilling. Return mud path to flowline (vs Gas Buster) to monitor flow out and gas in returns. OA pressure Cot 23:00 hrs= 700 psi 3/31/2017 3/31/2017 6.00 PROD1 DRILL DDRL P Directional drill 10,860' MD to 11,6440' 10,860.0 11,644.0 00:00 06:00 MD, 6,921' TVD. 216 gpm, 2270 psi, ECD=12.10 ppg, 130 rpm, Tq on/off- n/off=11 1 lk/6k. P/U=172k, S/0=115k, ROT=142k. ADT=3.91 hrs. Weight up FloThru mud system from 10.5 ppg to 10.7 ppg on the fly while drilling due increase in trapped pressure on connections. (504, 536 psi) 3/31/2017 3/31/2017 3.25 PROM CASING CIRC T Circulate and condition @ 210 gpm, 11,644.0 11,582.0 06:00 09:15 2260 psi, 40 rpm, 6.5k Tq maintaining 12.2-12.3 ppg ECD with MPDE back pressure. Observe -1-2 ppg gas cut mud in returns. Observe gas cut in returns dissipate after -12.5 ppg ECD. Rack back stand and install FOSV in string. Observe pressure build to 563 psi while racking back stand. Page 19127 Report Printed: 4/10/2017 —aerations Summary (With Timelog -. pths) CD3-111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Time End Time Dur(hr)Phase op code Activity Code Time P-T-X Dperaeon Stan Depth (RKB) End Depth(RKB) 3/31/2017 3/31/2017 1.75 PROD1 CASING LOT T Perform dynamic LOT with MPD and 11,582.0 11,582.0 09:15 11:00 PWD. Slowly close choke to apply back pressure monitoring ECD and gain/loss. Initial 12.4 ECD, 150 psi back pressure. Stage up in .1 ppg increments (approx 36 psi) monitoring gain loss. At 13.2 ppg ECD (440 psi) observed leak off to formation @ 20 bph. Relieve back pressure to 12.7 ppg, losses reduced to 4 bph. 3/31/2017 3/31/2017 1.00 PROD1 CASING CIRC T Circulate @ 210 gpm, 2340 psi, 40 11,582.0 11,582.0 11:00 12:00 rpm, 6k Tq. Reciprocate from 11,582' to 11,517' MD. Holding 12.7 ppg EMW with MPDE. Discuss plan forward with drilling team. Determined pressure operating window 12.6 ppg-13.2 ppg. OA pressure @ 12:00 hrs=750 psi 3/31/2017 4/1/2017 12.00 PROD1 CASING WAIT T Circulate @ 210 gpm, 2350 psi, 40 11,582.0 11,582.0 12:00 00:00 rpm, 6k Tq. Reciprocate from 11,582' to 11,517' MD. Holding 12.7 ppg EMW with MPDE. Waiting on 11.4 ppg Flo Pro to be built at Alpine bulk plant for intitial dislplacement, and 12.8 ppg formate brine being built at Deadhorse mud plant for displacement in casing. OA pressure @ 21:30 hrs=675 psi 4/1/2017 4/1/2017 11.00 PROD1 CASING WAIT T Circulate @ 210 gpm, 2350 psi, 40 11,582.0 11,582.0 00:00 11:00 rpm, 6k Tq. Reciprocate from 11,582' to 11,517' MD. Holding 12.7 ppg EMW with MPDE, Waiting on 11.4 ppg Flo Pro to be built at Alpine bulk plant for intitial dislplacement, and 12.8 ppg formate brine being built at Deadhorse mud plant for displacement in casing. 4/1/2017 4/1/2017 1.00 PROD1 CASING DISP P Begin displacement to 11.4 ppg Flo 11,582.0 11,582.0 11:00 12:00 Pro, pump 36 bbl Hi Vis spacer, chase with 11.4 ppg Flo pro @ 210 gpm, 2330 psi, 40 rpm, 6k Tq. 4/1/2017 4/1/2017 1.00 PROD1 CASING DISP P Continue displacement to 11.4 Flo Pro 11,582.0 11,582.0 12:00 13:00 @ 210 gpm, 2380 psi, 40 rpm, 5k Tq, 12.84 ppg ECD final. 4/1/2017 4/1/2017 1.00 PROD1 CASING OWFF P Perform formation fingerprint @ 11,582.0 11,582.0 13:00 14:00 11,584' MD, 11.4 ppg mud. Shutdown and Gose in chokes, observe max - pressure increase of 422 psi in 30 minutes. (12.6 ppg) , Bleed off pressure briefly and shut in, pressure build to 413 psi in 5 minutes. Bleed off again and repeat, pressure build to 434 psi flatlined. (12.6 ppg EMW) 4/1/2017 4/1/2017 2.00 PROD1 CASING CIRC P Circulate and observe for gas, max 11,582.0 11,582.0 14:00 16:00 gas at bottoms up 155 units. Establish circulation stage up to 5 bpm, 2230 psi, 40 rpm, 7k Tq, CBU x 2. Page 20127 ReportPrinted: 4/10/2017 . perations Summary (with Timelog . epths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Cotla Activity Code Time P -T -X Operation Start Dept, (ttKB) End Deph(W5) 4/1/2017 4/2/2017 8.00 PROD1 CASING PMPO P Pump out of hole from 11,582' MD to 11,582.0 9,780.0 16:00 00:00 9,780' MD, maintaining 12.75 ppg ECD with MPD. Making dynamic connections with MPD, holding 540 psi on connections. Pulling speed —500 fph. P/U=165k. OA pressure @ 21:30 hrs=600 psi 4/2/2017 4/2/2017 4.00 PROD1 CASING PMPO P Continue pumping out of hole from 9,780.0 8,830.0 00:00 04:00 9,870' MD to 8,830' MD @ 210 gpm, 2050 psi holding 80 psi annular pressure pulling and 540 psi in slips. Making dynamic connections with MPD. P/U=165k, S/0=122k. 4/2/2017 4/2/2017 1.25 PROD1 CASING PMPO P Pump and lay in 20 bbl HV 11.4 ppg 8,830.0 8,452.0 04:00 05:15 Flo Pro pill. Pump to bit @ 5 bpm, 2020 psi, slow to .8 bpm 870 psi, holding 500 psi annular pressure and pulling 1000 fph laying in 5 bbl per stand from 8,830' MD to 8,452' MD. 4/2/2017 4/2/2017 4.75 PROD1 CASING CIRC P Circulate @ 210 gpm 1960 psi 8,452.0 8,452.0 05:15 10:00 maintaining 12.75 ppg ECD with MPD. Reduce Flo Pro from 11.4 ppg to 11.3 ppg while circulating to facilitate displacement. Prep pit 5 and pill pit with 12.8 ppg Formate brine and HV spacer. 4/2/2017 4/2/2017 1.50 PROD1 CASING PMPO P Pump and lay in 25 bbl HV 12.8 ppg 8,452.0 7,980.0 10:00 11:30 Formate pill. Pump to bit @ 5 bpm, 2020 psi, slow to .8 bpm 870 psi, holding 500-540 psi annular pressure and pulling 1000 fph laying in 5 bbl per stand from 8,452' MD to 7,980' MD. OA pressure @ 11:00 hrs= 550 psi 4/2/2017 4/2/2017 2.50 PRODt CASING DISP P Displace well to 12.8 ppg clear 7,980.0 7,980.0 11:30 14:00 formate brine per schedule 4.4 bpm- . tbpm to maintain ECD below 13.2 ppg. No gains or losses. Pumped total 344 bbl for even 12.8 ppg inlout. 4/2/2017 4/212017 1.00 PROD1 CASING OWFF P Shut down pumps and close chokes 7,980.0 7,980.0 14:00 15:00 observe 7 psi initial, buid to 14 psi. Open chokes to atmosphere and observe well static for 30 minutes. Blow down top drive. 4/2/2017 413/2017 9.00 PRODt CASING SMPD P Strip out R hole with MPD from 7,980' 7,980.0 2,224.0 15:00 00:00 MD to 2,224' MD holding 75 psi annular pressure at all times to offset potential swab. Observe losses of 1-2 bph in addition to pipe displacement. P/U=165k. OA pressure @ 23:45= 420 psi 4/3/2017 4/3/2017 1.50 PROD? CASING TMPD P Continue strip out with MPD from 2,224.0 997.0 00:00 01:30 2,224' MD to 997' MD holding 75 psi to offset potential swab. Observe losses of 1 bph in addition to pipe displacement. Page 21127 Report Printed: 4110/2017 -Aerations Summary (with Timeiog-dpths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Siert Time End Time Our (hr) Phase Op Code Activlry Cote Time P -T -X Operation sun DOM (flKB) End Depth (MB) 4/3/2017 4/3/2017 0.25 PRODI CASING OWFF P Observe well for flow prior to pulling 997.0 997.0 01:30 01:45 MPD, static for 15 minutes. PJSM on pulling MPD and install trip nipple. 4/312017 4/3/2017 0.50 PROW CASING MPDA P Pull MPD element and strip off pipe, 997.0 997.0 01:45 02:15 install trip nipple. Leak check and OWFF static slight drop. 4/3/2017 4/3/2017 1.50 PROD1 CASING TRIP P POOH on elevators from 997' MD to 997.0 162.0 02:15 03:45 162' MD. Lay down 2 stands HWDP and jars. 4/3/2017 4/3/2017 1.25 PRODI CASING SHAH P Lay down BHA per DD / MWD reps. 162.0 0.0 03:45 05:00 Clean and clear rig floors of BHA components and MPD element. Total trip from shoe, Calc 1111=46.18 bbl, Actual Fill=55 bbl. 4/3/2017 4/3/2017 2.00 COMPZN CASING RURD P Rig up double stack power tongs, 4%" 0.0 0.0 05:00 07:00 tubing elevators, air slips... Rig up fillup line. SIMOPS- Inspect top drive, Verify pipe and jewelry count and placement, PJSM on running liner. 4/3/2017 4/3/2017 5.00 COMPZN CASING PUTB P P/U and RIH with 4X" TXP frac liner 0.0 2,141.0 07:00 12:00 per detail to 2,141' MD Fill pipe every 10 jts, 50 jts in hole. PIU=75k. 4/3/2017 4/3/2017 3.00 COMPZN CASING PUTB P Continue PIU and run 4W' TXP frac 2,141.0 3,444.0 12:00 15:00 liner per detail from 2,141' MD to 3,444' MD, 82 its total. S/0=90k. 4/3/2017 4/3/2017 1.00 COMPZN CASING OTHR P M/U liner hanger assembly as per 3,444.0 3,476.0 15:00 16:00 Baker, XO to XT39 DP connection. SIMOPS- RID casing equipment. 4/3/2017 4/3/2017 0.50 COMPZN CASING RUNL P RIH with liner on 4" DP to 3,585' MD. 3,476.0 3,585.0 16:00 16:30 4/3/2017 413/2017 0.50 COMPZN CASING CIRC P RIU head pin and establish circulation. 3,585.0 3,585.0 16:30 17:00 Stage pump to 2 bpm, 140 psi. Circulate liner volume. 4/3/2017 4/4/2017 7.00 COMPZN CASING RUNL P Continue running liner on 4" DP @ 3,585.0 17:00 00:00 1000 fph from 3,585' MD to 8,063' MD. Fill pipe every 10 stands. S/0=125k. OA pressure @ 22:00 hm=400 psi 4/4/2017 4/4/2017 0.75 COMPZN CASING RUNL P Continue RIH with 4'R' TXP Frac liner 8,063.0 8,490.0 00:00 00:45 assembly on 4" DP from 8,063' IV to 6,490' MD. 4/4/2017 4/4/2017 0.25 COMPZN CASING OWFF P Observe well for flow, static. PJSM on 8,490.0 8,490.0 00:45 01:00 pulling trip nipple and install MPD bearing. 4/4/2017 4/4/2017 0.50 COMPZN CASING MPDA P Pull trip nipple and install MPD 8,490.0 8,490.0 01:00 01:30 bearinglelement. Install 4" FOSV with 5' pup on top of string. 4/4/2017 4/4/2017 0.50 COMPZl' CASING SFTY P PJSM on displacing well from 12.8 8,490.0 8,490.0 01:30 02:00 ppg brine to 11.4 ppg Flo Pro, applying back pressure and monitoring returns. Page 22127 Report Printed: 4/10/2017 . perations Summary (with Timelog �dpths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stan Time EM Time our (hr) Phase Op Code ActivityCode Time P -T -x Operation Stan Depth (We) End Depth (N(B) 4/4/2017 4/4/2017 4.00 COMPZN CASING DISP P Stage pumps up from .5 bpm to 2 8,490.0 8,490.0 02:00 06:00 bpm, 210 psi observe no losses. Pump 15 bbl HV Flo Pro spacer, follow with 330 bbl 11.4 ppg Flo Pro. Pump 11.4 ppg to shoe @ 810 psi FCP. Maintain 800-830 psi string pressure via closing MPD choke as 11.4 comes up annulus. FCP's 830 psi with 340 psi annular back pressure. Ramp down to dynamic connection @ 505 psi AP. Close FOSV, break top drive connection and slowly open FOSV to check that floats are holding, good. Blow down top drive, R/D FOSV with 5' pup. P/U=165k, S/0=125k @ 8,490' MD. 4/4/2017 4/4/2017 6.00 COMPZN CASING RUNL P Continue running liner on drill pipe into 8,490.0 10,981.0 06:00 12:00 open hole from 8,490' MD to 10,981' MD, stripping in with MPD holding 505 annular back pressure. Stage running speed from 250 fph to 700 fph monitoring displacement, - 1 bph losses. S10=1 12k @ 10,981' MD. 4/4/2017 4/4/2017 2.00 COMPZN CASING RUNL P Continue running liner on drill pipe 10,981.0 11,604.0 12:00 14:00 from 10,981' MD to 11,604' MD, stripping in with MPD holding 505 annular back pressure. 500 fph monitoring displacement, - 1 bph Posses. P/U=190k, S/0=105k. 4/4/2017 4/4/2017 2.50 COMPZN CASING CIRC P M/U FOSV and single, put liner 11,604.0 11,605.0 14:00 16:30 hanger/ packer on depth. Establish circulation @ .5 bpm, 850 psi with 420 psi back pressure. Stage rates up to 2 bpm, 1280 psi with 320 psi back pressure. Circulate and condition, CBU observe no gas on returns, some heavy mud 11.7 ppg. FCP=970 psi, 320 psi AP. 4/4/2017 4/4/2017 2.00 COMPZN CASING PACK P Break single, drop 1.25" WIV ball, 11,605.0 8,154.0 16:30 18:30 pump down @ 2 bpm, 980 psi. Ball on seat @ 1178 stks. Set liner hanger with 2600 psi (320 psi AP). Slack off to 60k, hanger set. P/U to neutral, Pressure up to 3500 psi, bleed off Pressure. Pressure up to 4000 psi and hold 2 min, bleed off pressure. Bleed off 320 psi annular back pressure. Close chokes and observe no pressure build. Slack off to 60k, pressure up and observe shear @ 3400 psi, bleed off pressure. P/U 175k, pull up 6'to expose dog sub, rotate 20 rpm 5k, set down 40k. Running tool free, pick up to neutral weight. Lay dawn single and FOSV. Liner set @ 11,609' MD, TOL @ 8,131.45' MD. 4/4/2017 4/4/2017 1.00 COMPZN CASING PRTS P Rig up and pressure test casing 8,154.0 8,154.0 18:30 19:30 annulus and packer to 3000 psi for 15 minutes charted. 2.3 bbf pumped to pressure up. Page 23127 Report Printed: 4/10/2017 . perations Summary (With Timelog Depths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Start Time End Tune our (m) Phase Op Code Activity Code Time PJA Operabon Stan Depth (flKB) End DepM(aKB) 4/4/2017 4/4/2017 0.50 COMPZN WELLPR PULD P Pull running tool clear from liner top, 8,154.0 8,092.0 19:30 20:00 lay down 2 singles. Blow down testing lines. 4/412017 4/4/2017 0.50 COMPZN WELLPR OWFF P Flow check well for 30 minutes static 8,092.0 8,092.0 20:00 20:30 with 11.4 ppg Flo Pro. 4/4/2017 4/4/2017 1.50 COMPZN WELLPR DISP P PJSM, displace well over to 9.8 ppg 8,092.0 8,092.0 20:30 22:00 brine @ 5 bpm, ICP=1210 psi, FCP=520 psi, 62% flow out. Pumped total 340 bbl. Blow down top drive. 4/4/2017 4/4/2017 1.50 COMPZN WELLPR OWFF P Line up MPD to cellar and monitor well 8,092.0 8,092.0 22:00 23:30 appeared out of balance. Slight trickle, reducing for (.3 gpm to <.1 gpm) 1 hour, observe until static 30 min. SIMOPS- Prep and PJSM for removing MPD. 4/4/2017 4/5/2017 0.50 COMPZN WELLPR MPDA P Remove MPD bearing/element, install 8,092.0 8,092.0 23:30 00:00 trip nipple. Fill and leak check. Observe well again static. OA pressure @ 22:00 hrs= 385 psi 4/5/2017 4/5/2017 0.25 COMPZN WELLPR OWFF P Observe well for flow after install 8,092.0 8,092.0 00:00 00:15 MPD. Fill trip nipple with hole fill, shut off and observe well static for 15 minutes. 4/5/2017 4/5/2017 7.50 COMPZN WELLPR PULD P POOH laying down 4" DP from 8,080' 8,092.0 0.0 00:15 07:45 MD. Shut down hole fill and flow check static @ 4,300' and 152'. Function rams. Calc Fill=45.9 bbl, Actual F111=46 bbl. 4/5/2017 4/5/2017 0.75 COMPZN WELLPR SHAH P Lay down Baker liner running tools, 0.0 0.0 07:45 08:30 clean and clear rig floor. SIMOPS- FMC pull 7.0625" ID wear ring and install 9" ID retrievable wear ring. 4/5/2017 4/5/2017 3.25 COMPZN RPCOMP RURD P R/U to run completion, P/U Grippy 0.0 0.0 08:30 11:45 clamp crates, P/U I -Wire and SSSV spools / sheaves, hang sheaves and run lines through. P/U and R/U double stack power tongs, air slips, hand tools and equipment for tubing run. 4/5/2017 4/5/2017 0.25 COMPZN RPCOMP SFTY P Verify pipe and jewelry counts, PJSM 0.0 0.0 11:45 12:00 on running completion with CPA], DDI crew, DDI casing, PTS, Baker completion & SLB. 4/5/2017 4/5/2017 1.50 COMPZN RPCOMP PUTB P P/U WLEG locator assy, 3W' EUE 0.0 181.0 12:00 13:30 8rdmod tubing, 2.813 XN nipple w/ RHC plug 2.75 no-go, Baker Premier Packer to 181' MD. Break out collar on 2' pup for gauge carder. 4/5/2017 4/5/2017 1.00 COMPZN RPCOMP-7 P M/U PTS gauge carrier to lower 2' pup 181.0 181.0 13:30 14:30 and Baker Lock. Remove gauge carrier upper pup, replace with 4' pup and Baker Lock. 4/5/2017 4/5/2017 1.50 COMPZN RPCOMP PUTB P Terminate I -Wire to gauge and test 181.0 181.0 14:30 16:00 per PTS, CPAI witness. Page 24127 Report Printed: 4110/2017 . perations Summary (With Timelog L epths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log SfartTime End Time Dur(hr) Phase Op Code ActivM1y Cotle Tlme P -T-% Oparatlon Start Depth aKS End Depth (N(9) 4/5/2017 4/6/2017 8.00 COMPZN RPCOMP PUTB P Continue P/U and run 3h" upper 181.0 4,959.0 16:00 00:00 completion from 181' MD to 4,959' MD, (154 its total, 2.813 X nipple, GLM w/SOV 2500 psi, 2 GLM with dummy.) Clamping with PTS Grippy clamp every collar. ]-Wire under constant test while running. S/0=92k. OA pressure @ 22:00 hrs= 400 psi 4/6/2017 4/6/2017 1.50 COMPZN RPCOMP PUTB P Continue P/U and run 3W' EUE-8rdM 4,959.0 5,980.0 00:00 01:30 completion from 4,959' MD to 5,980' MD per detail, installing PTS Grippy clamp on every collar. 4/6/2017 4/6/2017 0.50 COMPZN RPCOMP SSSV P Make up SLB Camco TRMAXX-5 5,980.0 6,010.0 01:30 02:00 SSSV, instal and pressure test control line 5200 psi 10 minutes good. Instal clamps above and below SSSV. 4/6/2017 4/6/2017 3.50 COMPZN RPCOMP PUTB P Continue P/U and run 3W' EUE-8rdM 6,010.0 8,062.0 02:00 05:30 completion from 6,010' MD to 8,062' MD per detail, installing PTS Grippy clamp over both I Wire and SSV control line on every collar. 416/2017 4/6/2017 0.50 COMPZN RPCOMP PUTB P RIH with its 254, 255 and 25' in on 8,062.0 8,152.0 05:30 06:00 256, tag TOL @ 8151', set down 8k and shear locator sub screws. Continue in and fully locate 26' in on it #256 @ 8,152.34' MD with 10k, P/U and repeat to verify. PIU=126k, S/0=105k. 4/6/2017 4/6/2017 0.25 COMPZN RPCOMP PULD P Lay down its 256, 255 and 254 to 8,152.0 8,062.0 06:00 06:15 8,062' MD. 4/6/2017 4/6/2017 1.00 COMPZN RPCOMP HOSO P M/U FMC wear ring puller and retrieve 8,062.0 8,072.0 06:15 07:15 9" ID wear ring. WU 8.1' space out pup and 4Y2" TXP x 3%" EUE XO to 8,072'. 4/6/2017 4/6/2017 2.00 COMPZN RPCOMP THGR P Make up 4'h" TXP joint and hanger. 8,072.0 8,117.0 07:15 09:15 Orient hanger production port. SLB / PTS / FMC terminate I -Wire and SSSV control line through hanger. Test Swedge lock connections to 5000 psi, good. Ensure SSSV is open. SIMOPS- Prep for spotting Cl brine, R/D double stack tongs, OWFF for 30 minutes static. 4/6/2017 4/6/2017 1.75 COMPZN RPCOMP CRIH P RIH to 8,145' MD. R/U and pump 23.5 8,117.0 8,117.0 09:15 11:00 bbl 9.8 ppg corrosion inhibited brine, displace with 66 bbl 9.8 ppg neat brine @ 2-2.4 bpm, 160-230 psi. Shut down, drain stack, blow down choke and kill lines. SIMOPS- Lay down clamp crates via Beaverslide. 4/6/2017 4/6/2017 0.50 COMPZN TPCOMP P RIH and land hanger @ 8,148.97' MD, 8,117.0 8,149.0 11:00 11:30 (3.37' off fully located) FMC RILDS. Final P/U=125k, S/0=100k. Total clamps in hole= 258 ea- 3Y2" Full clamps, 3 as - 4Y2" single clamps, 2 ea - SS bands. SIMOPS- RID I -Wire and SSSV line sheaves. Prep pressure testing equipment. Page 25/27 Report Printed: 411012017 a _perations Summary (with Timelog---pths) CD3-111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr) Phase Op Code Activit' Cotle Time P-T-x Operation Sten Depth dtKa) End Depth (MR) 4/6/2017 4/6/2017 1.00 COMPZN RPCOMP THGR P R/U and pressure test hanger seals to 8,149.0 8,149.0 11:30 12:30 250/5000 psi 10 minutes each with test pump and chart recorder. 4/612017 4/6/2017 1.00 COMPZN RPCOMP RURD P Rig up surface lines to set and test 8,149.0 8,149.0 12:30 13:30 packer. Pressure test lines to 4100 psi, good. 4/6/2017 4/6/2017 2.50 COMPZN RPCOMP PACK P_ Set and test packer. Pressure up 8,149.0 8,149.0 13:30 16:00 down tubing observe shear @ 2,450 and 3,450 psi, continue pressure up to 4100 psi chart for 30 min (tubing test). Bleed pressure to 1500 psi, pressure up on annulus to 3000 psi for 30 minutes charted. Observe OA pressure increase from 400-500 psi. Bleed IA then tubing, with tubing open pressure up down IA, observe SOV shear out @ 2750 psi. Pump 1.5 bpm 990 psi through SOV. Shut down and pump down tubing 1.5 bpm 570 psi for 3 bbl. 4/6/2017 4/6/2017 0.25 COMPZN WHDBOP RURD P Blow down dg down lines, lay down --U-49.0 0.0 16:00 16:15 landing joint A. 4/6/2017 4/6/2017 0.75 COMPZN WHDBOP MPSP P FMC set HP-BPV, R/U landing joint B 0.0 0.0 16:15 17:00 and test HP-BPV to 2500 psi for 15 minutes charted. Verify barriers. 4/6/2017 4/6/2017 0.50 COMPZN WHDBOP RURD P Blow down rig down lines, lay down 0.0 0.0 17:00 1730 landing joint B. 4/6/2017 4/6/2017 3.00 COMPZN WHDBOP CLEN P Lay down PTS and SLB completion 0.0 0.0 17:30 20:30 equipment from rig Floor. Clean under pipe racks, rotary table, drip pan and flow box. 4/6/2017 4/6/2017 0.50 COMPZN WHDBOP WWWH P P/U stack washer, flush BOP stack 0.0 0.0 20:30 21:00 and flowline@ 430 gpm, 100 psi, 10 rpm r 4/6/2017 4/6/2017 1.00 COMPZN WHDBOP MPDA P R/D MPD equipment, valves, hoses, 0.0 0.0 21:00 22:00 Orbit valve, flow box. 4/6/2017 4/6/2017 1.75 COMPZN WHDBOP NUND P N/D SOPE from wellhead and set on 0.0 0.0 22:00 23:45 stump. OA pressure @ 22:00 hrs= 400 psi 4/6/2017 4/7/2017 0.25 COMPZN WHDBOP NUND P FMC /SLB /PTS prep to terminate 1 0.0 0.0 23:45 00:00 wire and SSSV control line through wellhead. 4/7/2017 4/7/2017 2.25 COMPZN WHDBOP NUND P PTS Terminate and test I-wire 0.0 0.0 00:00 02:15 penetration out wellhead. SIMOPS- Prep test equipment, disconnect choke/ flare lines outside for rig move. Drain both mud pumps and remove valves, springs and caps for pad move. Install mouse hole, rig down mud line in mezzanine, remove drain plugs from pumps in centrifugal room. 4/7/2017 4/7/2017 1.25 COMPZN WHDBOP NUND P N/U tree per FMC, pressure test 0.0 0.0 02:15 03:30 adapter flange void and I-Wire/SSSV penetrations to 5000 psi for 10 minutes CPAI witnessed. R/D test equipment. SSSV pumped up to 5000 psi in open position. 4!7/2017 4/7/2017 1.50 COMPZN WHDBOP PRTS P R/U and test tree to 250/5000 psi, 10 0.0 0.0 03:30 05:00 minutes each charted. Rig down test equipment. Page 26/27 Report Printed: 4/10/2017 . perations Summary (with Timelog � epths) CD3 -111 Rig: DOYON 19 Job: DRILLING SIDETRACK Time Log Stag Tim End Time Dur (hr)Phase Op Code Activiry Code me P -T-% Time Opemtien Depth (MKT End Dep1h(KKB) 4/7/2017 4/7/2017 0.50 COMPZN WHDBOP MPSP P FMC pull HP -HPV. 0.0 0.0 05:00 05:30 4/7/2017 4/7/2017 0.25 COMPZN WHDBOP RURD P Rig up lines to freeze protect well with 0.0 0.0 05:30 05:45 GIS. 4/7/2017 4/7/2017 1.50 COMPZN WHDBOP FRZP P PJSM on freeze protect. Ball Mill 0.0 0.0 05:45 07:15 pressure test lines to 2500 psi. Pump total 75 bbl diesel down IA (20 bbl heated diesel from GIS, 34 bbl recycled LEPD, follow with 21 bbl heated diesel) taking returns out tubing. SIMOPS- BWM on BOPE 4/7/2017 4/7/2017 0.50 COMPZN WHDBOP FRZP P Line up tubing and IA and U-tube 0.0 0.0 07:15 07:45 diesel for 30 minutes, 200 psi on tubing and IA. SIMOPS- BWM on ROPE 4/7/2017 4/7/2017 0.25 COMPZN WHDBOP RURD P Rig down freeze protect lines. 0.0 0.0 07:45 08:00 417/2017 4/7/2017 1.50 COMPZN WHDBOP MPSP P FMC rig up lubricator and lest to 2700 0.0 0.0 08:00 09:30 psi. Set BPV and lay down lubricator. 4/7/2017 4/7/2017 1.00 COMPZN WHDBOP PRTS P Pressure test BPV in direction of flow 0.0 0.0 09:30 10:30 to 2500 psi charted, via IA with GIS pump. Blow down lines and squeeze manifold, rig down. 417/2017 4/7/2017 1.50 DEMOB MOVE RURD P Secure well, rig down double annulus 0.0 0.0 10:30 12:00 valves, install flanges and gauges. Rig down working platform on tree. Lay down lubricator from rig floor, prep to lay down 4" DP. Tubing= 250 psi, IA= 250 psi, OA= 400 psi Final readings on downhole gauge, 3493 psi, 70`C, 45.59 V. 4/7/2017 4/7/2017 10.50 DEMOB MOVE PULD P Lay down 97 stands 4" DP via 0.0 0.0 12:00 22:30 mousehole. SIMOPS- Prep rig modules for separation, blow down water lines, - check tires, clean up ancillary materials, secure roof items, clear snow/ prep rig mats. Off HiLine @ 17:30 hrs. 417/2017 4/8/2017 1.50 DEMOB MOVE RURD P Lay down mousehole, continue prep 0.0 0.0 22:30 00:00 for separating modules, blow down steam, swap electrical to cold starts. Trucks on location @ midnight. Rig release @ 00:00 hrs 4/8/17. Page 27127 Report Printed: 411I0/2017 NADConversion Western North Slope CD3 Fiord Pad CD3 -111A Definitive Survey Report 04 May, 2017 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3 -111 Project: Western North Slope TVD Reference: CD3 -111A actual (off 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Weil: CD3 -111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEDMP2 Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3 -111 Audit Notes: Weil Position -NIS 0.00 usft Northing: 6,003,828.92 usft Latitude: 701 25'9.865 N ACTUAL +E/ -W 0.00 usft Easting: 388,169.17 usft Longitude: 150° 54'39.717 W Position Uncertainty D)rectlon 0.00 usft Wellhead Elevation: usft Ground Level: 12.90 usft Vellbore� CD3 -111A nagnatics Model Name Sample Date Declination Dip Angle Field Strength (1 (1) (nT) BGGM2016 3/22/2017 17.39 80.90 57,518 Design CD3 -111A Date Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 2,726.87 Vertical Section: Depth From (TVD) +N/ -S +E/ -W D)rectlon 569.15 (usft) (usft) (usft) (1) 2,757.44 36.70 0.00 0.00 324.00 Survey Program Date From To Map Map (usft) (usft) Survey (Waltham) Tool Name Description Survey Date 81.20 442.30 CD3 -111 Srvy 1 CB -GYRO -SS (CD3 -111 CB -GYRO -SS Camera based gyro single shot 3/6/2006 12:00:[ 569.15 2,726.87 CD3 -111 MWD+IFR-AK-CAZ-SC(CD3-1 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/6/200612:00:( 2,757.44 3,184.18 CD3 -111A Srvy 1 - GYD-GC-SS (CD3 -11 GYD-GC-SS Gyrodata gyro single shots 3/21/2017 9:37, 3,184.18 8,474.53 CD3 -111A Srvy 2- SLB _MWD+GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/27/2017 4:08> 8,474.53 11,522.02 CD3 -111A Srvy 3 -St -B W~+GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/21/2017 9:39: 5142017 1:05:29PM Page 2 COMPASS 5000. 1 Build 74 Map Map Vertical MD Inc Azt TVD TVDSS +N/S +EI -W Northing Easgng DLS Section (-ft) (1) (9 (usft) (usft) tush) (usft) (ft) (it) (1/100') (it) Survey Tool Name 81.20 0.50 208.00 81.20 31.60 -0.17 -0.09 6,003,828.75 388,169.08 1.12 -0.09 CB-GYRO-SS(1) 169.20 0.50 224.00 169.20 119.60 .079 -0.54 6,003,828.14 388,168.62 0.16 -0.32 CB -GYRO -SS (1) 260.20 0.85 240.00 260.19 210.59 AA1 -140 6,003,827.53 388,16715 043 -0.32 GB -GYRO -SS (1) 350.20 0.85 266.00 350.18 300.58 -1.79 -2.64 6,003,827.17 388,166.50 0.42 0.11 CBGYRO-SS(1) 44220 1.80 308.00 442.16 392.56 495 -0.46 6,003,828.04 388,164.69 1.41 1.86 CBGYROSS(1) 56915 4.95 328.80 568.87 51927 4.97 5.87 6,003,834.02 388,160.37 2.62 9.23 MWD+IFR-AKGAZ-SC(2) 658.W 7.59 346.95 65754 607.94 14.0 -12.20 6,003,843.10 388,157.18 367 18.49 MWD+IFR-AK-CAZSC(2) 748.00 10.59 348.17 746.06 696.46 27.83 -15.22 6,003,856.98 388,154.37 3.35 31.46 MWD+IFR-AK-CAZSC(2) 839.07 13.31 344.72 835.14 785.54 46.14 -19.70 6,003,875.35 388,150.16 3.09 48.91 MWD+IFR-AK-CAZ-SC(2) 933.92 15.77 340.80 926.95 877.35 68.85 -26.82 6,003,898.16 388,143.39 2.79 7146 MWD+IFR-AK-CAZ-SC(2) 5142017 1:05:29PM Page 2 COMPASS 5000. 1 Build 74 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CO3-111 Project: Western North Slope TVD Reference: CO3-111A actual Q 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Well: CD3 -111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEOMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +N/.S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (uslt) (ft) (ft) C/1001 (R) Survey Tool Name 1,029.31 18.32 339.66 1,018.14 968.54 95.15 -36.29 6,003,924.60 388,134.31 2.70 98.31 MWD+IFR-AK-CAZ-SC(2) 1,12444 20.03 337.84 1,107.99 1,058.39 124.26 47.64 6,003,953.67 388,123.40 1.90 128.53 MWD+IFR-AK-CAZ-SC(2) 1,219.40 20.54 334.70 1,197.07 1,14747 154.38 50.89 6,003,984.19 388,11060 1.27 160.69 MWD+IFR-AK-CAZSC(2) 1,314.55 21.38 334.60 1,285.92 1,236.32 185.14 -7546 6,004,015.16 388,096.49 0.88 194.14 MWD+IFR-AK-CAZSC(2) 1,409.48 23.01 334.86 1,373.81 1,324.21 217.57 -90.77 6,004,047.81 388,081.68 1.72 229.37 MW0+1FR-AK-CAZ-SC(2) 1,504.98 24.50 337.62 1,461.22 1,411.62 252.78 -106.24 6,004,08324 388,066.74 1.95 266.95 MWD+IFR-AK-CAZ-SC (2) 1,600.19 25.99 340.64 1,547.34 1,497.74 290.72 -120.67 6,004,121.39 388,052.87 2.07 30613 MWD+IFR-AK-CAZ-SC(2) 1,694.62 28.42 340.75 1,631.32 1,581.72 331.46 -134.94 6,004,162.34 388,039.22 2.57 347.48 MWD+IFR-AK-CAZSC(2) 1,790.15 30.43 339.62 1,714.52 1,654.92 37561 -150.86 6,004,206.71 388,023.96 2.18 392.55 MWD+IFR-AK-CAZSC(2) 1,884.91 32.52 338.90 1,795.33 1,745.73 421.87 -168.39 6,004,253.23 388,007.13 2.24 440.28 MVJD+IFR-AK-CAZSC (2) 1,979.03 35.51 337.25 1,873.34 1,823.74 470.69 -188.08 6,004,302.34 387,988.18 3.32 491.35 MWD+IFR-AK-CAZSC(2) 2,075.43 37.24 336.37 1,950.96 1,901.36 523.24 -210.60 6,004,355.21 387,966.45 1.87 547.09 MWD+IFR-AK-CAZ-SC (2) 2,170.18 38.56 337.20 2,025.72 1,976.12 576.73 -233.53 6,004,409.04 387,944.32 1.49 603.85 MWD+IFR-AK-CAZ-SC(2) 2,265.95 39.59 337.61 2,100.07 2,050.47 632.46 -256.72 6,004,465.11 387,921.97 1.11 662.57 MWD+IFR-AK-CAZ-SC(2) 2,361.16 38.21 33646 2,174.16 2,124.56 687.51 -280.04 6,004,520.50 387,899.48 1.64 720.81 MWD+IFR-AK-CAZ-SC(2) 2,456.49 35.92 337.00 2,250.23 2,200.63 740.29 -302.75 6,004,573.60 387,877.57 2.43 776.86 MWD+IFR-AK-CAZ-SC (2) 2,550.20 32.87 337.28 2,327.55 2,277.95 789.06 -323.31 6,004,622.67 387,857.74 3,26 828.40 MWD+IFR-AK-CAZ-SC(2) 2,646.56 34.16 335.08 2,407.88 2,358.28 837.91 -344.38 6,004,671.83 387,837.41 1.50 880.31 MWD+IFR-AK-CAZ-SC(2) 2,684.30 34.24 336.12 2,439.10 2,389.50 857.31 -352.98 6,004,69135 387,829.10 022 901,05 MWD+IFR-AK-CAZSC(2) 2,721.20 34.71 336.25 2,469.52 2,419.92 876.42 -36141 6,004,710.58 387,82096 128 921.47 MWD+IFR-AK-CAZSC(2) 9S/S" x 12414- 2.725.87 34.78 336.27 2,474.18 2,424.58 879.37 -362.71 6,004,713.56 387,819.70 1.28 92462 MWD+IFR-AK-CAZ-SC(2) 2,757.44 31.42 337.14 2,499.78 2,450.18 894.70 569.32 6,004,728.98 387,813.33 11.10 940.91 GYD-GCSS (3) 2,750.07 29.20 33764 2,527.09 2,4T/.49 9094" -375.46 6,004,743.80 387,807.41 7.06 956.44 GYD-GC-SS(3) 2,817.65 27.39 337.99 2,552.25 2,502.65 921.98 -380.57 6,004,750.42 387,602.48 6.36 969.59 GYD-GC-SS (3) 2,848.72 26.79 337.82 2,579.91 2,530.31 935.09 585.89 6,004,769.61 387,797.36 1.95 983.33 GYD-GCSS (3) 2,880.44 28.49 337.04 2,608.26 2,558.66 946.22 591.35 6,OD4,782.82 387,792.10 1.45 997.16 GYD-GCSS (3) 2,907.57 26.26 336.57 2,632.57 2,582.97 959.30 -396.10 6,OD4,793.97 387,787.52 1.14 1,008.91 GYD-GCSS (3) 2,939.20 26.26 338.84 2,650.94 2,611.34 972.25 401.41 6,004,806.99 387,782.40 3.18 1,022.51 GYD-GC-SS (3) 2,970.16 26.60 34060 2,68866 2,639.06 985.17 -406.18 6,004819.98 387,777.82 2.76 1,035.77 GYD-GCSS(3) 3,001.58 26.61 340.74 2,716.75 2,66).15 998.45 -410.84 6,004,833.33 387,773.37 0.20 1,NR25 GYD-GC-SS (3) 3,034.49 26.39 340.12 2,746.21 2,696.61 1,012.29 415.76 6,004,84724 387,768.66 1.07 1,063.33 GYD-GC-SS(3) 3,064.07 26.15 339.91 2,772.73 2,723,13 1,024.59 -420.23 6,004,859.60 387,764.37 0.87 1,07592 GYD-GC-SS(3) 3,094.60 25.80 339.12 2,800.18 2,750.58 1,037.12 424.91 6,004,872.20 387,759.88 1.61 1,08880 GYD-GC-SS(3) 3,126.32 25.90 33941 2,828.72 2,779.12 1,050.05 429.81 6,004,88520 387,755.18 0.51 1,102.14 GYD-GC-SS(3) 3,184.18 26.49 342.15 2,850.64 2,831.04 1,074.16 438.21 6,ON,909.44 387,747.14 2.33 1,126.59 GYD-GC-SS(3) 3,242.51 25.99 339.45 2,932.96 2,883.36 1,098.52 446.68 6,004,933.91 387,739.03 222 1,151.27 MWD+IFR-AK-CAZSC(4) 3,337.69 26.52 339.66 3,018.32 2,968.72 1,137.97 461.39 6,004,973.58 387,724.92 0.57 1,191.83 MWD+IFR-AK-CAZSC(4) 3,432.01 27.84 337.83 3,102.23 3,052.63 1,178.11 477.02 6,005,013.94 387,709.89 1.66 1,233.50 MWD+IFR-AK-CAZSC(4) 3,526.06 28.42 337.45 3,185.17 3,135.57 1;219.12 493.89 6,005,055.20 387,693.64 0.65 1,276.59 MWD+IFR-AK-CAZSC(4) 5142017 1:05:29PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well C133-111 Project: Western North Slope TVD Reference: CD3-111Aactual Q 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: C133 -111A actual @ 49.60usft (Doyon 19) Well: CD3 -111 North Reference True Wellbore: C133 -111A Survey Calculation Method: Minimum Curvature Design: C133 -111A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NAS +EI -W Northing Easting DLS Section (usft) (*) (°) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 3,620.48 29.02 338.63 3,267.97 3,218.37 1,26120 510.85 6,005,09752 387,677.31 087 1,32060 MWD+IFR-AK-CAZ-SC(4) 3,715.04 28.85 338.47 3,350.73 3,301.13 1,303.78 -527.58 6,005,140.34 387,661.22 0.20 1,364.88 MWD+IFR-AK-CAZSC(4) 3,809.79 29.07 338.86 3,43363 3,384.03 1,346.51 54427 6,005,183.32 387,645.17 0.31 1,409.27 MWD+11FR-AK-CAZ-SC(4) 3,904.80 28.92 341.02 3,516.74 3,467.14 1,389.76 -560.07 6,005,226.80 387,630.03 1.11 1,453.54 MWD+IFR-AK-CAZ-SC(4) 3,999.26 28.90 341.90 3,599.43 3,549.83 1,433.06 574.59 6,005,270.30 387,616.16 0.45 1,497.10 MWD+IFR-AK-CAZ-SC(4) 4,091.61 28.98 343.29 3,680.24 3,630.64 1,475.70 -587.95 6,005,313.14 387,603.44 0.73 1,539.46 MWD+IFR-AK-CAZ-SC(4) 4,185.45 28.78 34344 3,762.41 3,712.81 1,519.12 500.93 6,005,356.75 387,591.11 0.23 1,582.21 MWD+IFR-AK-CAZSC(4) 4,281.60 28.90 342.86 3,846.64 3,797.04 1,563.51 514.37 6,005,401,33 387,578.34 0.32 1,626.03 MWD+IFR-AK-CAZSC(4) 4,377.36 28.87 343.46 3,930.48 3,880.88 1,607.78 827.77 6,005,445.79 387,565.60 0.30 1,669.72 MWD+IFR-AK-CAZSC(4) 4,471.74 28.83 343.57 4,013.15 3,963.55 1,651.45 840.70 6,005,489.65 387,553.34 0.07 1,712.64 MWD+IFR-AK-CAZSC(4) 4,566.16 29.03 343.83 4,095.79 4,046.19 1,695.29 853.52 6,005,533.67 387,541.18 0.25 1,755.65 MM+IFR-AK-CAZSC (4) 4,662.04 28.84 343.52 4,179.70 4,130.10 1,739.81 866.55 6,005,578.37 387,528.81 0.25 1,799.33 MWD+IFR-AK-CAZSC(4) 4,755.17 28.92 342.39 4,262.12 4,212.52 1,783.27 879.88 6,005,622.03 387,516.14 0.59 1,842.32 MWD+IFR-AK-CAZSC(4) 4,849.53 28.43 341.42 4,344.03 4,294.43 1,825.85 893.79 6,005,664.81 387,502.87 0.72 1,884.95 MWD+IFR-AK-CAZ-SC(4) 4,94489 28.31 340.53 4,42794 4,378.34 1,868.69 -708.56 6,005,707.86 387,48874 0.46 1,928.28 MWD+IFR-AK-CAZ-SC(4) 5,046A8 28.30 340.19 4,51703 4,46743 1,913.88 -724.69 6.005.753 28 387,473.29 0.16 1,974.32 MWD+IFR-AK-CAZ-SC(4) 5,135.21 28.44 340.54 4,595.46 4,545.86 1,953.77 -738.92 6,005,79337 387,459.66 024 2,01496 MWD+IFR-AK-CAZ-SC(4) 5,230.17 27.53 341,41 4,679.31 4,629.71 1,995.89 -753.45 6,005,835.70 387,445.77 1.05 2,057.57 MWD+IFR-AK-CAZ-SC (4) 5,324.49 28.12 341.42 4,762.73 4,713.13 2,037.62 -76748 6,005,877.64 387,432.36 0.63 2,099.58 MWD+IFR-AK-CAZ-SC(4) 5,419.49 27.91 341.02 4,84860 4,797.00 2,079.87 -781.84 6,005,920.09 387,418.63 0.30 2,142.20 MWD+IFR-AK-CAZ-SC(4) 5,514.39 27.99 341.23 4,930.43 4,88083 2,121.95 -796.23 6,005,962.38 387,404.88 0.13 2,184.71 MWD+IFR-AK-CAZ-SC(4) 5,606.50 28.05 341.44 5,011.74 4,962.14 2,162.95 810.08 6,006,003.58 387,391.65 0.13 2,226.02 MWD+IFR-AK-CAZ-SC(4) 5,703.21 27.83 341.62 5,097.18 5,047.58 2,205.93 824.44 6,006,046.76 387,377.94 0.24 2,269.23 MWD+1FR-AK-CAZ-SC (4) 5,798.70 27.86 341.55 5,181.61 5,132.01 2,248.25 838.53 6006,089.28 387,364.49 0.05 2,311.74 MWD+IFR-AK-CAZSC(4) 5,890.94 27.95 34082 5,263.13 5,213.53 2,289.11 85245 6,005,130.35 387,351.18 0.38 2,352.98 MWD+IFR-AK-CAZSC(4) 5,983.81 2770 33970 5,345.26 5,295.66 2,329.91 867.09 6,006,171.36 387,337.15 0.62 2,394.60 MWD+IFR-AK-CAZSC(4) 6,078.03 27.86 338.54 5,428.62 5,379.02 2,370.94 88274 6,006,212.61 387,322.12 0.60 2,436.99 MWD+IFR-AK-CAZ-SC(4) 6,172.80 27.76 338.28 5,512.44 5,462.84 2,412.05 899.01 6,006,253.96 387,306.47 0.17 2,479.81 MWD+IFR-AK-CAZSC(4) 6,268.98 27.69 33797 5,597.58 5,547.98 2,453.57 -915.68 6,006,295.72 387,290.42 0.17 2,52321 MWD+IFR-AK-CAZ-SC(4) 6,363.16 27.95 338.08 5,680.88 5,631.28 2,494.33 -932.13 6,006,336.72 387,274.59 0.28 2,565.85 MWD+IFR-AK-CAZ-SC(4) 6,458.23 27.88 338.37 5,764.88 5,715.28 2,535.66 -948.64 6,006,378.29 387,25870 0.16 2,608.99 MM+IFR-AK-CAZ-SC(4) 6,550.89 27.76 33866 5,846.83 5,79723 2,575.90 -964.48 6,006,418.76 387,243.47 0.20 2,650.86 MWD+IFR-AK-CAZSC(4) 6,645.42 27.78 33845 5,930.48 5,880.88 2,616.90 -980.58 6,006,459.99 387,227.98 0.11 2,693.49 MWD+IFR-AK-CAZSC(4) 6,740.49 27.59 338.58 6,014.66 5,965.06 2,658.00 -996.76 6,006,501.33 387,212.42 0.21 2,736.25 MWD+IFR-AK-CAZSC(4) 6,834.57 29.50 339.22 6,097.30 6,047.70 2,699.94 -1,012.93 6,006,543.50 387,196.88 2.06 2,779.69 MWD+IFR-AK-CAZ-SC(4) 6,930.00 31.61 341.46 6,17948 6,129.88 2746.63 -1,029.22 6,006,589.42 387,18128 2.51 2,826.22 MWD+IFR-AK-CAZ-SC(4) 7,025.37 35.35 341.79 6,259.01 6,203.41 2,795.55 -1,045.80 6006,639.58 387,165.45 3.93 2,876.35 MWD+IFR-AK-CAZ-SC(4) 7,120.50 39.50 341.59 6,334.54 6,284.94 2,850.42 -1,063.96 6,006,694.72 387,148.12 4.36 2,931.42 MWD+IFR-AK-CAZ-SC(4) 7,217.00 43.13 341,17 6,407.01 6,357.41 2,910.78 -1,084.31 6,006,755.37 387,128.68 377 2,992.21 MWD+IFR-AK-CAZ-SC(4) 7,311.83 46.11 340.40 6,474.50 6,424.90 2,97367 -1,106.24 6,00681857 387,107.69 3.19 3,055.98 MWD+IFR-AK-CAZSC(4) 51412017 1:05:29PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3 -111 Project: Western North Slope TVD Reference: CD3 -111A actual (g? 49.60usff (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-111Aactual Q 49.60us@ (Doyon 19) Well: CD3 -111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEDMP2 Sumay Map Map Vertical NW Inc Azl TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (') (-ft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 7,407.37 48.32 338.12 6,53940 6,489.80 3,039.22 -1,131.09 6,006,884.48 387,083.83 2.90 3,123.62 MW)+IFR-AK-CAZ-SC(4) 7,503.14 50.83 335.81 6,601.50 6,551.90 3,106.29 -1,159.63 6,005,951.97 387,056.30 3.20 3,194.66 MWD+IFR-AK-CAZ-SC(4) 7,598.07 54.03 334.34 6,659.38 6,609.78 3,174.50 -1,191.36 6,007,020.64 387,025.60 3.59 3,268.49 MWD+IFR-AK-CAZSC(4) 7,693.40 58.14 334.26 6,712.56 6,652.96 3,245.77 -1,225.66 6,007,092.41 386,992.37 4.31 3,346.31 MWD+IFR-AK-CAZSC(4) 7,788.39 62.13 335.14 6,759.85 6,710.25 3,320.23 -1,260.84 6,007,167.39 386,958.31 428 3,427.23 MW0+1FR-AK-CAZSC(4) 7,883.50 65.97 335.00 6,601.46 6,751.86 3,397.77 -1,296.89 6,007,245.45 386,923.44 4.04 3,511.14 MWD+IFR-AK-CAZSC(4) 7,979.08 6946 334.41 6,837.70 6,788.10 3,477,72 -1,334.67 6,007,325.94 386,886.85 370 3,598.03 MWD+IFR-AK-CAZSC(4) 8,072.81 73.32 333.77 6,867.60 6,818.00 3,557,60 -1,373.49 6,007,406.39 386,94925 4.17 3,685.47 MWD+IFR-AK-CAZSC(4) 8,168.14 77.73 332.86 6,891.43 6,841.83 3,640.05 -1,414.93 6,007,489.44 386,809.04 4.72 3,776.54 MWD+IFR-AK-CAZ-SC(4) 8,262.38 82.35 332.05 6,907.72 6,858.12 3,722.30 -1,457.84 6,007,572.33 385,767.38 4.98 3,868.30 MPID+IFR-AK-CAZ-SC (4) 8,358.48 83.78 331.75 6,919.33 6,869.73 3,806.47 -1,502.78 6,007,657.15 386,723.70 1.52 3,962.81 MWD+IFR-AK-CAZ-SC(4) 8,453.84 85.21 331.56 6,92847 6,878.87 3,890.01 -1,547.85 6,007,741.35 386,679.90 1.51 4,055.88 MWD+IFR-AK-CAZ-SC(4) 8,474.53 86.24 332.81 6,93002 6,88042 3,908.26 -1,557.47 6,007,759.73 386,670.55 7.82 4,077.31 MWD+IFR-AK-CAZSC(4) 8,530.00 86.80 333.73 6,933.38 6,883.78 3,957.70 -1,582.38 6,007,809.55 386,646.39 1,94 4,131.95 MWD+IFR-AK-CAZSC(5) 7" x 8-314" 8,572.69 87.24 334.43 6,935.60 6,886.00 3,996.05 -1,601.02 6,007,848.16 386,626.33 1.94 4,173.92 MWD+IFR-AK-CAZSC(5) 8,632.05 87.17 334.47 6,938.49 6,888.89 4,00.9.54 -1,626.59 6,007,902.02 385,603.56 0.14 4,232.23 MWD+IFR-AK-CAZ-SC(5) 8,675.71 88.06 333.22 6,940.31 6,890.71 4,088.69 -1,645.62 6,007,941.46 386,584.93 3.51 4,275.21 MWD+IFR-AK-CAZ-SC(5) 8,770.22 89.00 332.51 6,942.73 6,893.13 4,172.77 -1,688.91 6,008,026.17 386,543.10 125 4,368.56 MWD+IFR-AK-CAZ-SC(5) 8,863.59 9046 330.78 6,943.17 6,893.57 4,254.93 -1,73325 6,008,108.98 386,500,00 2.42 4,461.09 MWD+IFR-AK-CAZSC(5) 8,955.96 9125 330.08 6,941.78 6,892.18 4,3WA3 -1,779.32 6,008,19085 386,455.16 1.13 4,553.86 MWD+IFR-AK-CAZSC(5) 9,05t56 9t38 329.71 6,939.61 6,890.01 4,417.95 -1,826.76 6,006,273.36 386,408.95 0.41 4,647.94 MWD+IFR-AK-CAZ-SC(5) 9,145.99 91.31 329.48 6,937.39 6,887.79 4,499.37 -1,874.53 6,008,355.48 386,362.40 0.25 4,741.89 MWD+IFR-AK-CAZ-SC(5) 9,240.18 91.07 32804 6,935.44 6,885.84 4,579.88 -1,923.37 6,008,436.71 385,31418 1.55 4,835.73 MWD+IFR-AK-CAZ-SC(5) 9,333.87 90.72 326.44 6,933.97 6,884.37 4,656.66 -1,97406 6,008,516.23 386,265.28 1.75 4,929.26 MWD+IFR-AK-CAZ-SC(5) 9,428.33 90.90 326.41 6,932.64 6,883.04 4,737.35 -2,026.30 6,008,595.69 386,214.24 0.19 5,023.62 MWD+IFR-AK-CAZ-SC(5) 9,522.80 90.69 32562 6,931.33 6,881.73 4,815.68 -2,079.10 6,008,674.79 386,162.62 0.87 5,118.03 MWD+IFR-AK-CAZ-SC(5) 9,617.62 90.48 326.23 6,930.36 6,880.76 4,894.21 -2,132.22 6,008,754.10 386,110.69 068 5,212.79 MWD+IFR-AK-CAZ-SC(5) 9,712.41 90.42 326.31 6,929.61 6,880.01 4,973.N -2,184.85 6,008,833.71 386,059.24 0.11 5,307.50 MWD+IFR-AK-CAZ-SC(5) 9,806.52 90.11 32621 6,929.18 6,879.58 5,051.30 -2,237.12 6,008,912.73 386,008.16 0.35 5,401.53 MWD+IFR-AK-CAZ-SC(5) 9,900.26 89.90 325.94 6,929.17 6,879.57 5,129.08 -2,289.44 6,008,991.28 385,957.01 0.36 5,495.21 MWD+IFR-AK-CAZ-SC(5) 9,994.80 89.79 325.31 6,929.43 6,879.83 5,207.11 -2,342.82 6,009,070.10 385,004.82 0.68 5,589.71 MWD+IFR-AK-CAZ-SC(5) 10,089.73 90.11 324.91 6,929.51 6,879.91 5,284.98 -2,397.12 6,009,148.76 385,851.69 0.54 5,684.63 MWD+IFR-AK-CAZSC(5) 10,183.94 89.97 325.43 6,929.44 6,879.84 5,362.31 -2,450.92 6,009,226.88 385,799.06 0.57 5,778.82 MWD+IFR-AK-CAZSC(5) 10,278.73 89.86 327.11 6,929.58 6,879.98 5,441.14 -2,503.56 6,000,306.49 385,74761 1.78 5,873.53 MWD+IFR-AK-CAZSC(5) 10,371.82 WAS 328.48 6,929.55 6,879.95 5,519.91 -2,553.17 6,009,385.98 385,699.19 1.51 5,966.41 MW3+1FR-AK-CAZSC(5) 10,466.95 90.14 330.91 6,929.29 6,879.69 5,602.03 -2,601.17 6,009,468.81 385,652.43 2.55 6,06L06 MWD+IFR-AK-CAZ-SC(5) 10,550.65 90.14 331.35 6,929.06 6,879.46 5,684.08 -2,646.41 6,009,551.52 385,608.43 0.47 6,154.04 MWD+IFR-AK-CAZ-SC(5) 10,654.37 90.47 334.92 6,928.56 6,878.96 5,767.67 -2,68815 6,009,635.73 365,567.35 3.83 6,246.55 MWD+IFR-AK-CAZ-SC(5) 10,748.90 89.48 336.85 6,928.60 6,879.00 5,853.95 -2,727.37 6,009,722.57 385,530.03 2.29 6,339.05 MWD+IFR-AK-CAZ-SC(5) 10,843.61 89.49 335.03 6,92945 6,879.85 5,940.42 -2,765.96 6,009,809.60 385,492.72 192 6,43171 MWD+IFR-AK-CAZ-SC(5) 5142017 1:05:29PM Page 5 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CD3 -111 Project: Western North Slope TVD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Sita: CO3 Fiord Pad MD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Well: CD3 -111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -IIIA Database: OAKEDMP2 Survey O Surface Coordinates 0 Declination & Convergence Q GRS Survey Corrections Survey Tool Codes SLB DE. guUta/+,w, /¢1n, 5/U2017 Weifen Dai;„;e„s«ate:«`� Client Representative: g Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,937.90 89.21 335.51 6,930.52 6,880.92 6,026.06 -2,805.42 6,009,895.81 385,454.57 0.59 6,524.17 MWD+IFR-AK-CAZSC(5) 11,035.05 89.72 $33.19 6,931.43 6,881.83 6,113.63 -2,847.47 6,009,983.99 385,413.84 2.44 6,619.73 MWD+IFR-AK-CAZSC(5) 11,132.51 91.36 329.48 6,930.51 6,880.91 6,199.12 -2,894.21 6,010,070.17 385,368.39 4.16 6,716.37 MWD+IFR-AK-CAZ-SC(5) 11,230.29 91.76 32562 6,927.85 6,87825 6,281.59 -2,946.65 6,010,153.40 385,317.20 3.97 6,813.91 MWD+IFR-AK-CAZ-SC(5) 11,327.07 91.60 322.81 6,925.01 6,875.41 6,360.05 3,003.21 6,010,232.70 385,261.83 2.91 6,910.63 MWD+IFR-AK-CAZSC(5) 11,424.28 89.80 321.09 6,923.82 6,874.22 6,436.59 -3,063.11 6,010,310.13 385,203.08 2.56 7,007.77 MWD+IFR-AK-CAZSC(5) 11,52292 90.78 321.29 6,923.33 6,873.73 6,512.75 -3,124.37 6,010,387.19 385,142.98 1.02 7,105.39 MWD+IFR-AKCAZSC(5) 11,609.00 90.78 321.29 6,922.14 6,872.54 6,580.62 -3,178.76 6,010,455.85 385,089.61 0.00 7,192.26 PROJECTED to TD 4.1/T' z 6.118" 11,642.00 90.78 321.29 6,921.69 6,872.09 6,606.37 3,199.40 6,010,48191 385,069.37 0.00 7,225.22 PROJECTEDIOTD rinal Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. M Yes No 1 have checked to the best of my ability that the following data is correct: O Surface Coordinates 0 Declination & Convergence Q GRS Survey Corrections Survey Tool Codes SLB DE. guUta/+,w, /¢1n, 5/U2017 Weifen Dai;„;e„s«ate:«`� Client Representative: g Date: 5/412017 5/42017 1:05: 29PM Page 6 COMPASS 5000.1 Build 74 Cement Detail Report CD3 -111 String: Intermediate Casing Cement Job: Cement Details Description Cementing Star[ Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/28/2017 01:15 3/28/2017 05:15 CD3 -111A Comment SLB flood and test surface lines to 4000 psi- good. Bleed off pressure. SLB pumped 40 bbl 12.5 ppg MudPush II spacer 3.4 bpm 340 psi. Drop bottom (bypass) plug. SLB pumped 49.1 bbl 15.8 ppg Qannik slurry @ 4 bpm 338-205 psi. Shut down and load top (shutoff) plug, SLB kick out plug with 10.1 bbl water. Rig displace cement with 10.8 ppg LSND @ 8 bpm 470-900 psi FCP for 3000 stks, slow rate to 3 bpm 470 psi and bump plug @ 3111 stks. Pressure up to 970 psi and hold for 5 min. OWFF- Static. Bleed off pressure and check floats- good. Pressure up to 3000 psi and observe stage collar open (4,699' MD). Full returns throughout cement job, landed on hanger no reciprocation. CBU. SLB pumped 30 bbl 11.5 ppg MudPush II @ 3.6 bpm, 220 psi, follow with 44.1 bbl 15.8 ppg Qannik slurry @ 4.7 bpm, 300 psi. Shut down and drop closing plug. SLB kick out plug with 10 bbl water, rig displace with 10.8 ppg LSND @ 8 bpm 330-780 psi, reduce to 3 bpm 540 psi @ 1400 stks, bump plug @ 1697 stks. Pressure up to 2200 psi, observe stage collar shift dosed @ 1620 psi. Hold 2200 psi for 3 min per HES, bleed off pressure and OWFF static. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Son Plug? Intermediate Casing Cement 700 feet from 7,840.0 8,540.0 Yes Yes Yes Cement casing shoe up to 7766 Q Pump Init (bbl/m...Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Rectp? Stroke (ft) Rotated? Pipe RPM (rpm) 4 8 8 420.0 970.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill OM Diameter (In) Comment SLB flood and lest surface lines to 4000 psi- good. Bleed off pressure. SLB pumped 40 bbl 12.5 ppg MudPush II spacer 3.4 bpm 340 psi. Drop bottom (bypass) plug. SLB pumped 49.1 bbl 15.8 ppg Qannik slurry @ 4 bpm 338-205 psi. Shut down and load top (shutoff) plug, SLB kick out plug with 10.1 bbl water. Rig displace cement with 10.8 ppg LSND @ 8 bpm 470-900 psi FCP for 3000 stks, slow rate to 3 bpm 470 psi and bump plug @ 3111 slks. Pressure up to 970 psi and hold for 5 min. OWFF- Static. Bleed off pressure and check floats- good. Pressure up to 3000 psi and observe stage collar open (4,699' MD). Full returns throughout cement job, landed on hanger no reciprocation. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 7,840.0 8,540.0 237 G 49.1 Yield (ft /sack) Mix H2O Ratio (gausa... Free Water (%) Density(ib/gal) Plastic Viscoslty(Pa•s) Thickening Time (hr) CmprStr t (psi) 1.16 5.07 15.80 134.0 I 4.75 Additives Additive Type Concentration Cone Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Cone Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Cone Unit label Retarder D177 0.02 gal/sx Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? She Plug? Intermediate Casing Place 500' of cement 4,200.0 4,700.0 Yes No No Cement above Qannik Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke IN) Rotated? Pipe RPM (rpm) 4 8 8 560.0 560.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment SLB pumped 30 bbl 11.5 ppg MudPush II @ 3.6 bpm, 220 psi, follow with 44.1 bbl 15.8 ppg Qannik slurry @ 4.7 bpm, 300 psi. Shut down and drop dosing plug. SLB kick out plug with 10 bbl water, rig displace with 10.8 ppg LSND @ 8 bpm 330-780 psi, reduce to 3 bpm 540 psi @ 1400 stks, bump plug @ 1697 silts. Pressure up to 2200 psi, observe stage collar shift closed @ 1620 psi. Hold 2200 psi for 3 min per HES, bleed off pressure and OWFF static. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (RKB)Est Btrn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,200.0 4,700.0 213 G 44.1 Yield (ftYsack) Mix H2O Ratio (gal/sa... Free Water (%) Density llblgal)Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.18 5.07 15.80 159.0 5.75 Additives AtlditiveType Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Page 112 Report Printed: 5/8/2017 Cement Detail Report CD3-111 String: Intermediate Casing Cement Job: Additives Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 I 0.02 gal/sx Page 212 Report Printed: 5/8/2017 Cement Detail Report CD3 -111 String: KOP Job: DRILLING SIDETRACK, 3/10/201700:00 Cement Details Description KOP Cementing Start Date 20171530 3/20/201715:30 End Date 3/20/201716:45 Wellbore Name CD3 -111 Comment Tested lines to 2000pai and pumped 25.4 bbl of 12.5 ppg MudPush, 43.4 bbl of 17 ppg class G cmt, and 4.6 bbl tail 12.5 ppg Mud Push. Displaced w/ 18.8 bbl of 12 ppg brine, under displaced by 1.5 bbl. Cement Stages Stage # 0 Description KOP 1 Objective 1 Top Depth (ftKB) 2,521.0 Bottom Depth (ftKB) 3,088.0 Full Return? No Vol Cement... Top Plug? No I Btm Plug? No Q Pump Init (bbl/m... 3 Q Pump Final (bbl/... 4 Q Pump Avg (bbl/... 6 P Pump Final (psi) 603.0 P Plug Bump (psi)Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Plug Back Cement Fluid Description Estimated Top (ftKB) 2,521.0 Est Btm (ftKB) 3,088.0 Amount (sacks) Class G Volume Pumped (bbl) 43.3 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal)Plastic 17.00 Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 5/5/2017 RECEIVED 21 7 0 04 MAY 0 9 2017 28 18 3 Schlumberger AOGCC Transmittal#: 09MAY17-SPOI Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 5 12d201-1 M K BENDER Customer: Conoco Phillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD3 -1I IA Date Dispatched: 9 -May -17 Job#: 17AKA0009 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E -Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity Scope Resistivity Scope Resistivity Scope Resistivity 2" MD 2" TVD 5" MD 5" TVD x x x x x x x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x As -Built Survey 1 Contents on CD Nad83 x EOW CD 1 Contents on CD Data: DLIS /ASCII Graphics: pdf Survey: pdf/ txt x x x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a)conocophillips.com Alaska PTSPrintCenter(slb.corn Attn: Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 P✓ "9 / , �r� Received By: y OrJ1 21 7004 28183 RECEIVED MAY 0 9 2017 FINAL AOGcc NADConversion Western North Slope C133 Fiord Pad CD3 -111A Definitive Survey Report 04 May, 2017 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3 -111 Project: Western North Slope TVD Reference: CD3.111A actual @ 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Well: CD3A11 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEDMP2 Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD3 -111 Audit Notes: Well Position +NI -S 0.00 usft Northing: 6,003,828.92 usft Latitude: 70° 25'9.865 N ACTUAL +EI -W O.DO usft Easting: 388,169.17 usft Longitude: 150' 54' 39.717 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 12.90 usft Wellbore CD3 -111A 36.70 0.00 0.00 324.00 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 11,522.02 CD3 -111A Srvy 3-SLB_MWD+GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC (°) (°) (nT) 1.12 BGGM2016 3/22/2017 17.39 80.90 57,518 Design CD3 -111A Date Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 2,726.87 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction 569.15 (usft) (usft) (usft) (°) 2,757.44 36.70 0.00 0.00 324.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 81.20 442.30 CD3 -111 Srvy 1 CB -GYRO -SS (CD3 -111 CB -GYRO -SS Camera based gyro single shot 3/6/2006 12:00:( 569.15 2,726.87 CD3 -111 MWD+IFR-AK-CAZ-SC(CD3-1 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/6/2006 1200+C 2,757.44 3,184.18 CD3 -111A Srvy 1 - GYD-GC-SS (CD3 -it GYD-GC-SS Gyrodata gyro single shots 3/21/2017 9:37: 3,184.18 8,474.53 CD3 -111A Srvy 2-SLB_MWD+GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/27/2017 4:08: 8,474.53 11,522.02 CD3 -111A Srvy 3-SLB_MWD+GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/21/2017 9:39: Survey 54/2017 1:05:29PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +FJ -W Northing Easting DLS Section (usft) (I V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 81.20 0.50 208.00 81.20 31.60 -0.17 -0.09 6,003,82875 388,169.08 1.12 -0.09 CB-GYRO-SS(1) 169:20 0.50 224.00 169.20 119.60 -0.79 -0.54 6,003,828.14 388,16862 0.16 -0.32 CB-GYRO-SS(1) 260.20 0.85 240.00 260.19 210.59 -1.41 -1.40 6.003,827.53 388,167.75 0.43 -0.32 CB-GYRO-SS(1) 350.20 0.85 266.00 350.18 300.58 4.79 -2.64 6,003,827.17 388,166.50 0.42 0.11 CB-GYRO-SS(1) 442.20 180 308.00 442.16 392.56 -0.95 i.46 6,003,828.04 388,164.69 1.41 1.86 CB-GYRO-SS(1) 569.15 495 328.80 568.87 519.27 4.97 -8.87 6,003,83402 388,160.37 2.62 923 MWD+IFR-AK-CAZ-SC(2) 658.35 7.59 346.95 657.54 607.94 14.00 -12.20 6,003,84310 388,157.18 3.67 18.49 MWD+IFR-AK-CAZ-SC 12) 74800 10.59 348.17 746.06 69646 2783 -15.22 6,003,856.98 388,154.37 3.35 31.46 MWD+IFR-AK-CAZ-SC(2) 839.07 13.31 344.72 835.14 785.54 46.14 -19.70 6,003,875.35 388,150.16 3.09 48.91 MWD+IFR-AK-CAZ-SC(2) 933.92 15.77 340.80 926.95 877.35 68.85 -26.82 6,003,898.16 388,143.39 2.79 71.46 MWD+IFR-AK-CAZ-SC(2) 54/2017 1:05:29PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3 -111 Project: Western North Slope TVD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -111A actual a@ 49.60usft (Doyon 19) Well: CD3 -111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEDMP2 Survey 5142017 1:05:29PM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1029.31 18.32 $3966 1,018.14 968.54 95.15 -36.29 6.003,924.60 388,134.31 270 98.31 MWD+IFR-AK-CAZ-SC(2) 1124.44 20.03 337.84 1.107.99 1,058.39 124.26 47.64 6,003,95387 388,123.40 1.90 128.53 MWD+IFR-AK-CAZ-SC(2) 1,219.40 20.54 334.70 1,197.07 1,147.47 154.38 -60.89 6,003,984.19 388,110.60 1.27 160.69 MWD+IFR-AK-CAZ-SC(2) 1,314.55 21.38 334.60 1,285.92 1,236.32 185.14 -75.46 6,004,015.16 388,096.49 0.88 194.14 MWD+IFR-AK-CAZ-SC(2) 1409.48 23.01 334.86 1,373.81 1.324.21 217.57 -9077 6,OD,047.81 388,081.68 172 229.37 MWD+IFR-AK-CAZ-SC(2) 1,504.98 24.50 337,62 1461.22 1,411.62 252.78 -106.24 6,004.083.24 388,066.74 1.95 266.95 MWD+IFR-AK-CAZ-SC(2) 1,600.19 25.99 340.64 1,547.34 1,49774 290.72 -12067 6,004,121.39 388,052.87 2.07 306.13 MWD+IFR-AK-CAZ-SC(2) 1,694.62 28.42 34075 1631.32 1,581.72 331.46 -13494 6,004,162.34 386,039.22 2.57 347.48 MWD+IFR-AK-CAZ-SC (2) 1,790.15 3043 339.62 1,714.52 1,664.92 375.61 -150.86 6,004,206.71 388,023.96 2.18 392.55 MWD+IFR-AK-CAZ-SC(2) 1,884.91 32.52 338.90 1,795.33 1,745.73 421.87 -168.39 6,004,25323 386007.13 2.24 440.28 MWD+IFR-AK-CAZ-SC(2) 1,979.03 35.51 337,25 1,873.34 1.823.74 470.69 -188.08 6,004,302.34 387,988.18 3.32 491.35 MWD4IFR-AK-CAZ-SC(2) 2,075.43 37.24 336.37 1,950.96 1,901.36 523.24 -210.60 6,004,355.21 387,966.45 1.87 547.09 MWD+IFR-AK-CAZ-SC (2) 2,170.18 38.56 337.20 2,025.72 1,976.12 576.73 -233.53 6,004,409.04 387,944.32 149 603.85 MWD+IFR-AK-CAZ-SC(2) 2,265.95 39.59 337.61 2,100.07 2,05047 632.46 -25672 6,004.465.11 387,921.97 1.11 662.57 MWD+IFR-AK-CAZ-SC(2) 2,361.16 38.21 336.46 2,174.16 2,124.55 687.51 -280.04 6,004,520.50 387,899.48 1.64 720.81 MWD+IFR-AK-CAZ-SC(2) 2,456.49 35.92 337.00 2,250.23 2,200.63 740.29 -302.75 6,004,57360 387,877.57 2.43 776.86 MWD+IFR-AK-CAZ-SC(2) 2,550.20 32.87 337.28 2,327.55 2,277.95 789.06 -323.31 6,004,62267 387,857.74 3.26 82840 MWD+IFR-AK-CAZ-SC(2) 2,646.56 34.16 336.08 2,407.88 2.358.28 837.91 -344.38 6,00,67183 387,837.41 1.50 880.31 MWD+IFR-AK-CAZ-SC (2) 2,684.30 34.24 336.12 2.439.10 2.389.50 857.31 -35298 6,00,691.35 387,629.10 022 901.05 MWD+IFR-AK-CAZ-SC(2) 2,721.20 34.71 336.25 2,469.52 2,41992 876.42 -361.41 6,00,710.58 387,820.96 1.28 921.47 NOT eD IaL1aN SIWry 9-5/8" x 12.114" 2,726.87 34.78 336.27 2,474.18 2,424.58 87937 -36271 6,004,713.56 387,819.70 1.28 924.62 MWD+IFR-AK-CAZ-SC(2) 2,757.44 31.42 337.14 2,49978 2,40018 894.70 -369.32 6,004,728.98 387,81333 11.10 940.91 GYD-GC-SS(3) 2,789.07 2920 337.64 2,527.09 2,477.49 909.44 -37546 6,004,74380 387,807.41 706 95644 GYD-GC-SS(3) 2.817,65 27.39 337.99 2,552.25 2,502.65 921.98 -380.57 6,004,756.42 387,80248 6.36 969.59 GYD-GC-SS(3) 2,848.72 2679 337.82 2,579.91 2,530.31 935.09 -385.89 6,004,769,61 387,797.36 1.95 983.33 GYD-GC-SS (3) 2,88044 2649 337.04 2,608.26 2.558.66 948.22 -391.35 6.004,782.82 387,792.10 1.45 997.16 GYD-GC-SS(3) 2,907.57 26.26 336.57 2,632.57 2,582.97 959.30 -396.10 6,004,793.97 387,787.52 1.14 1,008.91 GYD-GC-SS (3) 2,93920 26.26 338.04 2,660.94 2,611.34 972.25 401.41 6.004,806.99 387,782.40 3.18 1,022.51 GYD-GC-SS(3) 2,970.16 26.60 34060 2,68866 2,639.06 985.17 '106.18 6,004,81998 387,777.82 276 1,035.77 GYD-GC-SS(3) 3,001.58 2661 340.74 2,716.75 2,667.15 99845 -410.84 6,004,833.33 387,773.37 0.20 1049.25 GYD-GC-SS(3) 3,034.49 26.39 340.12 2,74621 2,698.61 1,01229 -415.76 6,00,84]24 367,768.66 1.07 1,063.33 GYD-GC-S5(3) 3,064.07 26.15 339.91 2,772.73 2,723.13 1,024.59 420.23 6,004,859.60 387,764.37 0.87 1,075.92 GYD-GC-SS (3) 3,094.60 25.80 339.12 2,800.18 2,750.58 1,037.12 -024.91 6,004,872.20 387,759.88 1.61 1,088.80 GYD-GC-SS (3) 3,126.32 2590 33941 2.828.72 2.779.12 1,D50.05 429.81 6,004,885.20 387,755.18 0.51 1,102.14 GYD-GC-SS(3) 3,184.18 26.49 342.15 2,880.64 2,831.04 1,074.16 438.21 6,004,909.44 387,747.14 2.33 1,126.59 GYD-GC-SS(3) 3,242.51 25.99 339.45 2,932.96 2,883.36 1,098.52 446.68 6,004,933.91 387,739.03 2.22 1,151.27 MAD+IFR-AK-CAZ-SC(4) 3,33769 26.52 339.66 3,018.32 2,968.72 1,13797 -461.39 6.004.973.58 387,724.92 0.57 1,191.83 MWD+IFR-AK-CAZ.SC(4) 3,43201 27.84 337.83 3,10223 3,05263 1.178.11 -477.02 6,005,013.94 387,709.89 166 1,233.50 MWD+IFR-AK-CAZ.SC(4) 3,526.06 2842 337.45 3,185.17 3,135.57 1,219,12 -493.89 6,005,05520 387,69364 0.65 1,276.59 MWD+IFR-AK-CAZ-SC(4) 5142017 1:05:29PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CD3 -111 Project: Western North Slope TVD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Well: C133-111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,62048 29.02 338.63 3,267.97 3,218.37 1.26120 -510.85 6,OD5,09752 387,677.31 0.67 1,32060 MWD+IFR-AK-CAZ-SC(4) 3,715.04 2885 338.47 3,350.73 3,301.13 1303.78 -527.58 6.005,140.34 387,661.22 0.20 136488 MWD+IFR-AK-CAZ-SC (4) 3.809.79 29.07 338.86 3,433.63 3,384.03 1,346.51 -544.27 6,005,183.32 387,645117 0.31 1,409.27 MWD+IFR-AK-CAZ-SC(4) 3,904.80 28.92 341.02 3,516.74 3,467.14 1389.76 -560.07 6,005,22680 387,630.03 1.11 1,453.54 MWD+IFR-AK-CAZ-SC(4) 3,99926 28.90 341.90 3,599.43 3,549.83 1,433.06 -574.59 6,D05,270.30 387,616.16 0.45 1,497.10 MWD+IFR-AK-CAZ-SC(4) 4,091.61 28.98 343.29 3,680.24 3,630.64 1,47530 -587.95 6,005,313.14 387,60344 073 1,53946 MWD+IFR-AK-CAZ-SC(4) 4.18545 28.78 343.44 3,76241 3,712.81 1,519.12 -600.93 6,005,356.75 387,591.11 0.23 1,582.21 MW0+IFR-AK-CAZ-8C(4) 4,281.60 28.90 342.86 3,846.64 3,797.04 1,563.51 614.37 6,005,401.33 387,578.34 0.32 1,62603 MWD+IFR-AK-CAZ-SC(4) 4,377.36 28.87 343.46 3,930.48 3,880.88 1,607.78 -627.77 6,005,445.79 387,565.60 0.30 1,66972 MWD+IFR-AK-CAZ-SC 14) 4,47174 2883 343.57 4,013.15 3,963.55 165145 61.70 6,005,489.65 387,553.34 0.07 1712.64 MWD+IFR-AK-CAZ-SC(4) 4,566.16 29.03 343.83 4,09579 4,046.19 1,695.29 -653.52 6,005,53367 387,541.18 0.25 1,755.65 MWD+IFR-AKCAZ-SC(4) 4,652.04 28.84 343.52 4,179.70 4,130.10 1,73981 -666.55 6,005,578.37 387,52881 0.25 1,799.33 MWD+IFR-AK-CAZ-SC(4) 4756.17 28.92 342.39 4,262.12 4,212.52 1,783.27 -679.88 6,005,622.03 387,516.14 0.59 1,842.32 MWD+IFR-AK-CAZ-SC(4) 4,849.53 2843 341.42 4,344.03 4,294.43 1,825.85 -69379 6,005,664.81 387,502.87 072 1,884.95 MWD+IFR-AK-CAZ-SC(4) 4,944.89 28.31 340.53 4,427.94 4,378.34 1,868.69 -708.56 6,005,707.86 387,486.74 0.46 1,928.28 MWD+IFR-AK-CAZ-SC (4) 5,046.08 2830 340.19 4,517.03 4,457,43 1,913.88 -724.69 6,005,753.28 387,473.29 0.16 1,974.32 MWD+IFR-AK-CAZ-SC(4) 5,135.21 2844 340.54 4,595.46 4,545.86 1,95377 -738.92 6,005,793.37 387,459.66 0.24 2,014% MWD+IFR-AK-CAZ-SC(4) 5,230.17 2753 34141 4,679.31 4,629.71 1,995.89 -75345 6,005,83570 387,445.77 1.05 2,057.57 MWD+IFR-AK-CAZ-SC(4) 5,324.49 28.12 341.42 4,762.73 4,713.13 2,037.62 -767.48 6,005,877.64 387,432.36 0.63 2,099.58 MWD+IFR-AK-CAZ-$C(4) 5,419.49 27.91 341.02 4,846.60 4,797.00 2,079.87 -781.84 6,005,920.09 387.418.63 0.30 2,142.20 MWD+IFR-AK-CAZ-SC(4) 5,514.39 27.99 34123 4,930.43 4,880.83 2,121.95 -796.23 6,005,962.38 387,40488 0.13 2,184.71 MW0+1FR-AK-CAZ-SC(4) 5,606 50 28.05 341.44 5,011.74 4,962.14 2,162.95 -810.08 8,006,003.58 387,391.65 0.13 2,226.02 MWD+IFR-AK-CAZ-SC (4) 5,70321 27.83 341.62 5,097.18 5,047.58 2,205.93 -82444 6,00,04676 387,377.94 0.24 2269.23 MWD+IFR-AK-CAZ-SC(4) 5,798.70 27.86 341.55 5,181.61 5,132.01 2.248.25 638.53 6,006,089 28 387.35449 0.05 2,311.74 MWD+IFR-AK-CAZ-SC(4) 5,890.94 2795 340.82 5,20,13 5,213.53 2,289.11 65245 6,006.130 35 387,351.18 0.38 2,352.98 MWD+IFR-AK-CAZ-SC(4) 5.963.81 27.71) 33970 5,345.26 5,295.66 2.329.91 -86709 600,17136 387,337.15 0.62 2,394.60 MWD+IFR-AK-CAZ-SC(4) 6,078.03 27.86 338.54 5,42862 5,379.02 2,370.94 -882.74 6,00.212.61 387,322.12 0.60 2,436.99 MWD+IFR-AK-CAZ-SC(4) 6,172.80 27.76 338.28 5,512.44 5,462.84 241205 -899.01 6.006 253.96 387,30647 0.17 2,479.81 1AWD+IFR-AK-CAZ-SC(4) 6,268.98 2769 337,97 5,597.58 5,547.98 2,453.57 -91568 8,00,295.72 387,290.42 0.17 2,52321 MWD+IFR-AK-CAZ-SC(4) 6,363.16 27.95 338.08 5,680.88 5,63128 2,494.33 -932.13 6,00,33672 387,274.59 0.28 2,56585 MWD+IFR-AK-CAZ-SC (4) 6,458.23 27.88 338.37 5,76488 5,715.28 2,535.66 -94864 6,00,378.29 387,258.70 0.16 2,608.99 MWD+IFR-AK-CAZ-SC(4) 6,55089 27.76 338.66 5,846.83 5,797.23 2,575.90 -964.48 6.00,41876 387,24347 0.20 2,650.86 MWD+IFR-AK-CAZ-SC(4) 6,645.42 27.78 338.45 5,930.48 5,880.88 2,616.90 -00.58 6,006,459.99 387,227.98 0.11 2,693.49 MWD+IFR-AK-CAZ-SO(4) 6,740.49 27.59 338,58 6,014.0 5,05.06 2,658.00 -99676 6006.501.33 387,212.42 0.21 2,736.25 MWD+IFR-AK-CAZ-SC(4) 6,834.57 29.50 339.22 6,09730 6,047.70 2,699.94 -1,012.93 6,00 ,543.50 387.196.88 2.06 2,779.69 MWD+1FR-AK-CAZ-SC(4) 6,930.00 31.61 341.46 6,179.48 6.129.88 2,745.63 -1,029.22 6,00,58942 387,181.28 2.51 2,82622 MWD+IFR-AK-CAZ-SC(4) 7,025.37 35.35 34179 6,259.01 6,20941 2,795.55 -1,045.80 6,00,639.58 387,165.45 3.93 2,876.35 MWD+IFR-AK-CAZ-SC(4) 7,120.50 39.50 341.59 6,334.54 6.284.94 2,850.42 -1,03.96 6,00669472 387,148.12 4.36 2,931.42 MWD+IFR-AK-CAZ-SC (4) 7,217.00 43.13 341.17 6,407.01 6,357.41 2,910.78 -1,084.31 6,006,755.37 387,12868 3.77 2,992.21 MWD+IFR-AK-CAZ-SC(4) 7,311.83 46.11 340.40 6,474.50 6,424.90 2,973.67 -1,10.24 6,006,818.57 387,107.69 3.19 3,055.98 MWD+IFR-AK-CAZ-SC(4) 5142017 1:05:29PM Page 4 COMPASS 5000.1 Build 74 a Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3 -111 Project: Westem North Slope TVD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Well: CD3 -111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEDMP2 Survey Map Map Vertical MD Inc AZI TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,407.37 48.32 338.12 6,539.40 6,489.80 3,039.22 -1,131.09 6,006,88448 387,083.83 2.90 3,123.62 MWD+IFR-AKCAZ-SC(4) 7,503.14 50.83 33581 6,601.50 6,551.90 3,106.29 -1,159.63 6,006,951.97 387,056.30 3.20 3,194.66 MWD+IFR-AK-CAZ-SC(4) 7,598.07 54.03 334.34 6,659.38 6,609.78 3,174.50 -1,19136 6,007,020.64 387,02560 3.59 3,268.49 MWD+IFR-AK-CAZ-SC(4) 7,693.40 56.14 334.26 6,712.56 6,662.96 3,245.77 -1,225.66 6,007,092.41 386,992.37 4.31 3,346.31 MWD+IFR-AK-CAZ-SC(4) 7,788.39 62.13 335.14 6,759.85 6,71025 3,320.23 -1,260.84 6,007,16739 386.958.31 4.28 3,427.23 MWD+IFR-AK-CAZ-SC(4) 7,883.50 65.97 335.00 6,80146 6,751.86 3,397.77 -1,296.89 6,007,24545 386,923.44 4.04 3,511.14 MWD+IFR-AK-CAZ-SC (4) 7,979.08 69.46 334.41 6,837.70 6,788.10 3,477.72 -1,334.67 6,007,325.94 386,886.85 370 3,598.03 MWD+IFR-AK-CAZ-SC l4) 8,072.81 73.32 33377 6,86760 6,818.00 3,55760 -1,373.49 6,007,406.39 385,849.25 4.17 3,685.47 MWD+IFR-AK-CAZ-SC(4) 8,168.14 77.73 332.86 6,691.43 6,641.83 3,640.05 -1,414.93 6,007,48944 386,809.04 472 3,776.54 MWD+IFR-AK-CAZ-SC(4) 8,262.36 82.35 332.05 6,907,72 6,858.12 3,722.30 -1,457.84 6.007,572.33 386,767.38 4.98 3,868.30 MWD+IFR-AK-CAZ-SC(4) 8,35848 8378 33175 5.919.33 6,869.73 3,806 47 4,50278 6,007,657.15 386.723.70 1.52 3,962.81 MWD+IFR-AK-CAZ-SC(4) 8,453.64 85.21 331.56 8,92847 6.878.87 3,890.01 -1,547.65 6,007,741.35 386,679.90 1.51 4,056.88 MWD+IFR-AK-CAZ-SC(4) 8,474.53 8624 332.81 6,930.02 6,880.42 3,908.26 -1,55747 6,007,759.73 386,670.55 7.82 4,077.31 MWD+IFR-AK-CAZ-SC(4) 8,530. DO 86.80 333.73 6,93338 6,883.78 3,957.70 -1,582.38 6,007,809.55 386,646.39 1.94 4,131.95 NOT BR flCNM($Ilfy� 7" x 8414" 8,57269 87.24 334.43 6,93560 6,886.00 3,99605 -1,601.02 6.007,848.16 386,628.33 1.94 4,173.92 MWD+IFR-AK-CAZ-SC(5) 8,632.05 87.17 33447 6,938.49 6,888,89 4,049.54 -1,626.59 6,007,90202 386,60356 0.14 4,232.23 MWD+IFR-AK-CAZ-SC(5) 8,67571 88.06 33322 6,940.31 6,890.71 4,08669 -1,645.82 6,007.941.46 386,584.93 3.51 4,275.21 MWD+IFR-AK-CAZ-SC(5) 8,770.22 69.00 332.51 6,942.73 6,893.13 4,172.77 -1,688.91 6,008,026.17 386,543.10 1.25 4,368.56 MWD+IFR-AK-CAZ-SC(5) 8,863.59 90.46 330.78 6,943.17 6,893.57 4254.93 -1,733.25 6,008,108.98 386,500.00 2.42 4,46109 MWD+IFR-AK-CAZ-SC(5) 8,956.96 91.25 330.08 6,941.78 6,892.18 4,336,13 -1.779.32 6,008,190.85 386,455.16 1.13 4,553.86 MWD+IFR-AK-CAZ-SC (5) 9,051.56 91.38 329.71 6,939.61 6,890.01 4,417.95 -1826.76 8,00827336 386,408.95 0.41 4,647.94 MWD+IFR-AK-CAZ-SC(5) 9,145.99 91.31 329.48 6,937.39 6,887.79 4,499.37 -1,874.53 6,008,35548 385,362.40 0.25 4,741.89 MWD+IFR-AK-CAZ-SC(5) 9,240AS 91.07 328.04 6,93544 6,885.84 4,579.88 -1,923.37 6,008,436.71 386,314.78 1.55 4,835.73 MWD+IFR-AK-CAZ-SC(5) 9,333.87 90.72 326.44 6,933.97 6,884.37 4,65866 -197406 6,008,51623 386,265.28 175 4,929.26 MWD+IFR-AK-CAZ-SC(5) 9,428.33 90.90 326.41 6.932.64 6,883.04 4,737.35 -2,026.30 6,008,59569 386,214.24 0.19 5,023.62 MWD+1FR-AK-CAZ-SC(5) 9,522.80 90.69 325.62 6,931.33 6,86173 4,81568 -2.079,10 6.008.674.79 386,162.62 0.87 5,118.03 MWD+IFR-AK-CAZSC(5) 9,617.62 90.48 326.23 6,930.36 6,880.76 4,894.21 -2,132.22 6,006,754.10 388.110.69 066 5,212.79 MWD+IFR-AK-CAZ-SC(5) 9,71241 90.42 326.31 6,929.61 6,880.01 4,973.04 -2.184.85 8,008,83371 386.059.24 0.11 5,307.50 MWD+IFR-AK-CAZ-SC(5) 9,806.52 90.11 326.21 6,929.18 6,879.58 5,051.30 -2,237.12 6,008,91273 386008.16 0.35 5,401.53 MWD+IFR-AK-CAZ-SC (5) 9,900.26 89.90 325.94 6,929.17 6,879.57 5,129.OB -2,289.44 8,008,99128 385,957.01 0.36 5,495.21 MWD+IFR-AWCAZ-SC (5) 9,994.60 8979 325.31 6,92943 6,87983 5.207.11 -2,342.82 6,009,070.10 385,904.62 0.68 5,589.71 MWD+IFR-AK-CAZ-SC(5) 10,089.73 90.11 324.91 6,929.51 6,879.91 5,284.98 -2,397.12 6,009,148.76 385,85169 0.54 5,684.63 MWD+IFR-AK-CAZ-SC(5) 10,183.94 89.97 325.43 6,92944 6,879.84 5362.31 -2,450.92 6,009,226.88 385,799.06 0.57 5,778.82 MWD+IFR-AK-CAZ-SC(5) 10,278,73 89.86 327.11 6,929.58 6,879.98 5,441.14 -2,5D3.56 6,009,306.49 385,747.61 1.78 5.873.53 MWD+IFR-AK-CAZ-SC(5) 10,371.82 90.18 328.48 6,929.55 6,879.95 5,519.91 -2.553.17 6,009,385.96 385,699.19 1.51 5,966.41 MWD+IFR-AK-CAZ-SC(5) 10,466.95 90.14 330.91 6,929.29 6,87969 5.602.03 -2,601.17 6.009468.61 385,652.43 2.55 6,061.06 MWD+IFR-AK-CAZ-SC(5) 10,560.65 90.14 331.35 6,929.06 6,879.46 5,684.08 -2,64641 6,009,551.52 385,608.43 0.47 6,154.04 MWD+IFR-AK-CAZ-SC(5) 10,654.37 90.47 334.92 6,928.56 6,87896 5.767.67 -2.688.75 6,009,635.73 385,567.35 3.83 6,24655 MWD+IFR-AK-CAZ-SC (5) 10,748.90 8948 336.85 6,928.60 6,879.00 5,653.95 -2,727.37 6,009.722.57 365,530.03 2.29 6,339.05 MWD+IFR-AK-CAZ-SC(5) 10,843.61 89.49 335.03 6,92945 6,879.85 5,94042 -2,76598 6,009,809.60 385,492.72 1.92 6,431.71 MWD+IFR-AK-CAZ-SC(5) 5/42017 1:05:29PM Page 5 COMPASS 5"..1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD3 -111 Project: Western North Slope TVD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3 -111A actual @ 49.60usft (Doyon 19) Well: CD3 -111 North Reference: True Wellbore: CD3 -111A Survey Calculation Method: Minimum Curvature Design: CD3 -111A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (-1100-) (ft) Survey Tool Name 10,93790 89.21 335.51 6,930.52 6,880.92 6,026.06 -2,805.42 6,009,89581 385,454.57 0.59 6.524.17 MWD+IFR-AK-CAZ-SC(5) 11,035.05 89.72 333.19 6,931.43 6,881.83 6,113.63 -2.84747 6,009,98399 385,413.84 2.44 6,61913 MWD+IFR-AK-CAZ-SC (5) 11,132.51 91.36 329.48 6,930.51 6,880.91 6,199.12 -2.89421 6,010,070.17 385,368.39 4.16 8,716.37 MWD+IFR-AK-CAZ-SC 15) 11,230.29 91.76 325.62 6,927.85 6,878.25 6,281.59 -2,946.65 6,010,153.40 385,317.20 3.97 6,813.91 MWD+IFR-AK-CAZ-SC(5) 11.327.07 91.60 322.81 6,925.01 6,875.41 6,360.05 -3,003.21 6,010,232.70 385,261.83 2.91 6.910.63 MWD+IFR-AK-CAZSC(5) 11424.28 89.80 321.09 6,923.82 6,874.22 6,436.59 -3,063.11 6,010,310.13 385,203.08 2.% 7,007.77 MWD+IFR-AK-CAZ-SC(5) 11,522.02 90.78 321.29 6,923.33 6,873.73 6,512.75 -3.124.37 6,010,387.19 385,142.98 102 7,105.39 MWD+1FR-AK-CAZ-SC(5) 11,609.00 90.78 321.29 6,922.14 6,872.54 6,580.62 -3.178.76 6,010,455.85 385,089.61 0.00 7,192.26 NOT BU ACtIHI $UIVey 44/2' x 6-1/8" 11,64200 90.78 321.29 6,92169 6,872.09 6,606.37 -3,19940 6,010,48191 385.069.37 0.00 7,225.22 PROJECTED to TD rinal Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Q Yes E) No 1 have checked to the best of my ability that the following data is correct: L,J Surface Coordinates E] Declination & Convergence E) GRS Survey Corrections F±) Survey Tool Codes SLB DE. 5/4/2017 Client Representative : WeIfEfIQ Dai o:IOM-m, Date: 5!4/2017 5142017 1:05:29PM Page 6 COMPASS 5000.1 Build 74 21 7004 28 183 RECEIVED MAY 0 9 2017 FINAL AOGCO ConocoPhill ips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3 -111A NAD 83 Definitive Survey Report 04 May, 2017 Company: ConomPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD3 Fiord Pad Well: CD3 -111 Wellbore: CD3 -111A Design: CD3 -111A Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: r Well CD3 -111 CD3 -111A actual @ 49.60usft (Doyon 19) CD3 -111A actual @ 49.60usft (Doyon 19) True Minimum Curvature OAKEDMP2 rroject Western North Slope, North Slope Alaska, United States tap System: US State Plane 1983 System Datum: Mean Sea Level ;so Datum: North American Datum 1983 Using Well Reference Point tap Zone: Alaska Zone 4 Using geodetic scale factor wall CD3 -111 Audit Notes: From To Well Position -NIS 0.00 usft Northing: 6,003,576.13 usft Latitude: 70° 25'8.6991 +N1 -S +E/ -W 0.00 usft Easting: 1,528,201.08 usft Longitude: 150° 54'51,095 V 'osition Uncertainty 0.00 0.00 usft Wellhead Elevation: usft Ground Level: 12.90 ust Wellbore CD3 -111A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (°) (nT) BGGM2016 3/22/2017 17.39 80.90 57,518 Design CD3 -111A Date 5/4/2017 Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 2,726.87 Vertical Section: Depth From (TVD) +N1 -S +EI -W Direction 442.30 CD3 -111 Srvy 1 CB -GYRO -SS (CD3 -111 (usft) (usft) (usft) (°) 569.15 36.70 0.00 0.00 324.00 Survey Program Date 5/4/2017 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 81.20 442.30 CD3 -111 Srvy 1 CB -GYRO -SS (CD3 -111 CB -GYRO -SS Camera based gyro single shot 3/6/2006 12:00:[ 569.15 2,726.87 CD3 -111 MWD+IFR-AK-CAZ-SC(CD3-1 MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/6/200612-00:C 2,757.44 3,184.18 CD3 -111A Srvy 1 - GYD-GC-SS (CD3 -11 GYD-GC-SS Gyrodata gyro single shots 3/21/2017 9:37: 3,184.18 8,474.53 CD3 -111A Srvy 2- SLB _MWD+GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/27/2017 4:08: 8,474.53 11,522.02 CD3 -111A Srvy 3-SLM B_WD+GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/21/2017 9:39: 6,003,57596 1,528,20099 1.12 -0.09 CB -GYRO -SS (1) 169.20 Survey 5142017 11:31:32AM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 81.20 0.50 208.00 81.20 31.60 -0.17 -0.09 6,003,57596 1,528,20099 1.12 -0.09 CB -GYRO -SS (1) 169.20 0.50 224.00 169.20 119.60 -079 -0.54 6,003,575.35 1,528,200.53 0.16 -0.32 CB-GYRO-SS(1) 26020 0.85 240.00 260.19 210.59 -141 -140 6,003,574.74 1,528,199.66 0.43 -0.32 CB-GYRO-SS(1) 350.20 0.85 266.00 350.18 300.58 -179 -2.64 6,003,574.38 1,528,19841 0.42 0.11 CB-GYRO-SS(1) 442.20 1.80 308.00 442.16 392.56 -0.95 -046 6,003.575.25 1,528,196.60 1.41 1.86 CB-GYRO-SS(1) 569.15 4.95 328.80 568.87 519.27 4.97 $.87 6,003,581.23 1,528,19228 2.62 9.23 MWD+IFR-AK-CAZ-SC(2) 658.35 7.59 346.95 657.54 607.94 14.00 42.20 6,003,590.31 1,528,189.10 3.67 18.49 MWD+IFR-AK-CAZ-SC(2) 748.00 10.59 348.17 746.06 696.46 27.83 -15.22 6,003,604.19 1,528,18628 3.35 31.46 MWD+IFR-AK-CAZ-SC(2) 839.07 13.31 344.72 835.14 785.54 46.14 -19.70 6,003,622.56 1,528,182.08 3.09 48.91 MWD+IFR-AK-CAZ-SC (2) 933.92 15.77 340.80 926.95 877.35 68.86 -26.82 6,003,645.37 1,528,175.30 219 71.46 MWD+IFR-AK-CAZ-SC(2) 5142017 11:31:32AM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: CD3 Fiord Pad MD Reference: Well: CD3 -111 North Reference: Wellbore: CD3 -111A Survey Calculation Method: Design: CD3 -111A Database: Survey l Well CD3 -111 CD3 -111A actual @ 49.60usft (Doyon 19) CD3 -111A actual @ 49.60usft (Doyon 19) True Minimum Curvature OAKEDMP2 5142017 11:31:32AM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/4 +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) lusft) Pt) (ft) (°1100') (ft) Survey Tool Name 1,029.31 1832 339.66 1,018.14 968.54 95.15 -36.29 6,OD3,67181 1,528,16622 270 98.31 MWD+IFR-AK-CAZ-SC(2) 1,12444 20.03 337.84 1,107.99 1,058.39 124.26 4764 6,003,70108 1,528,15532 1.90 128.53 MWD+IFR-AK-CAZ-SC(2) 1,219.40 20.54 334.70 1,197.07 1,147.47 154.38 60.89 6,003,731.40 1,528,142.52 1.27 160.69 MWD+IFR-AK-CAZ-SC (2) 1,314.55 21.38 334.60 1,285.92 1,236.32 185.14 -75.46 6,003,762.37 1,528,12841 0.88 194.14 MWD+IFR-AK-CAZ-SC(2) 1,409.48 23.01 334.86 1,373.81 1,324.21 217.57 -90.77 6,003,795.02 1,528,113.60 112 229.37 MWD+IFR-AK-CAZ-SC(2) 1,504.98 24.50 337.62 1.461.22 1,411.62 252.78 406.24 6,003,83046 1,528,09866 1.95 266.95 MWD+IFR-AK-CAZ-SC(2) 1,600.19 25.99 340.64 1,547.34 7497.74 290.72 -12067 6,003,868.61 1,528,084.80 207 306.13 MWD+IFR-AK-CAZ-SC(2) 169462 2842 340.75 1,631.32 1,581.72 331.46 -134.94 6,003,909.55 1,528,071.15 2.57 34748 MW0+1FR-AK-CAZ-SC(2) 1,790.15 3043 339.62 1714.52 1,664.92 37561 -150.86 6,003,953.93 1,528,055.89 2.18 392.55 MWD+1FR-AK-CAZ-SC(2) 1,884.91 32.52 338.90 1,795.33 1,74573 421.87 -16839 6,004,000.45 1528,03906 2.24 440.28 MWD+IFR-AK-CAZ-SC(2) 1,979.03 35.51 337.25 1,873.34 1,82374 470.69 -188.08 6,004,049.56 1,528,020.12 3.32 491.35 MWD+IFR-AK-CAZ-SC(2) 2.07543 37.24 336.37 1,950.96 1,901.36 523.24 -210.60 6,004,102.43 1,527,998.39 1.87 547.09 MWD+1FR-AK-CAZ-SC(2) 2,170.18 38.56 33720 2,025.72 1,976.12 576.73 -233.53 6,004,15626 1,527,976.26 1.49 60385 MWD+IFR-AK-CAZ-SC(2) 2,26595 39.59 337.61 2,100.07 2,050.47 632.46 -256.72 6,004,212.33 1,527,95391 1.11 662.57 MWD+IFR-AK-CAZ-SC(2) 2,361.16 38.21 336.46 2,174.16 2,124.56 687.51 -280.04 6,004,267.72 1.527,931 43 1.64 720.61 MWD+IFR-AK-CAZ-SC(2) 2,456.49 35.92 337.00 2,250.23 2,200.63 740.29 -30235 6,004,320.82 1,527,909.52 2.43 77686 MWD+IFR-AK-CAZ-SC(2) 2,550.20 32.87 337.28 2,327.55 2,277.95 789.06 -323.31 6,004,369.89 1,527,889.69 326 82840 MWD+IFR-AK-CAZ-SC(2) 2646.56 34.16 338.08 2,407.88 2,358.28 837.91 -344.38 6,004,419.05 1,527,869.36 1.50 880.31 MWD+IFR-AK-CAZ-SC(2) 2.684.30 34.24 336.12 2,439.10 2,389.50 857.31 -352.98 6,004,43857 1,527,861.06 0.22 901.05 MWD+IFR-AK-CAZ-SC(2) 2,721.20 34.71 336.25 2,469.52 2,419.92 876.42 -361.41 8,004,457.80 1,527,852.92 128 92147 NOT an Actual Survey 9-6/8" x 124/4" 2,726.87 3418 336.27 2,474.18 2.424.58 879.37 -362.71 6,004,46018 1,527,851.66 1 28 924.62 MWD+IFR-AK-CAZ-SC (2) 2,75744 31.42 337.14 2,49978 2,450.18 89410 -369.32 6,00447621 1,527,84528 11.10 940.91 GYD-GC-SS(3) 2,789.07 29.20 337,64 2,527.09 2,47749 909.44 -375.46 6,004,491.03 1,527,839.37 7.06 956.44 GYD-GC-SS(3) 2,817.65 27.39 337.99 2,552.25 2,50265 921.98 -380.57 6,004,50365 1,527,834.44 6.36 969.59 GYD-GC-SS(3) 2,648.72 26.79 337.82 2,579.91 2,530.31 935.09 -385.89 6,004,516.83 1,527,829.32 1.95 983.33 GYD-GC-SS (3) 2,880.44 2649 337.04 2,608.26 2,558.66 94822 -391.35 6,004,53005 1,527,82405 1.45 997.16 GYD-GC-SS(3) 2,907.57 2626 336.57 2,632.57 2,58297 959.30 -396.10 6,004,541.19 1,527,819.48 1.14 1,008.91 GYD-GC-SS(3) 2,939.20 2626 338.84 2,66094 2.611.34 972.25 -401.41 6,004,554.22 1,527,814.37 3.18 1,022.51 GYD-GC-SS(3) 2,970.16 26.60 340.60 2,688.66 2,639.06 985.17 -406.18 6,004,567.21 1,527,809.79 2.76 1,035.77 GYD-GC-SS (3) 3,001.58 2661 340.74 2,716.75 2,667.15 998.45 -410.84 6,004,580.56 1,527,605.33 0.20 1,04925 GYD-GC-55(3) 3,034.49 26.39 340.12 2,746.21 2,696.61 1,012.29 415.76 6.004,59447 1,527,800.62 1.07 1,063.33 GYD-GC-SS(3) 3,064.07 26.15 339.91 2,77213 2,723.13 1,024.59 -420.23 6004606.83 1,527,796.33 0.87 1,075.92 GYD-GC.SS (3) 3,09460 25.80 339.12 2,800.18 2,750.58 1,037,12 -424.91 6,004,619.43 1,527,791.84 1.61 1,088.80 GYD-GC-SS l3) 3,126.32 25.90 339.41 2,828.72 2,779.12 1,050.05 -429.81 6,004,632.43 1,527787.14 0.51 1,102.14 GYD-GC-SS(3) 3,184.18 26.49 342.15 2,880.64 2,831.04 1,074.16 438.21 6,004,656.67 1,527,779.11 2.33 1,126.59 GYD-GC-SS(3) 3,242.51 25.99 33945 2,932.96 2,883.36 1,098.52 -046.68 6,004,681.14 1,527.771.00 2.22 1,151.27 MWD+IFR-AK-CAZ-SC(4) 3,337.69 26.52 339.66 3,018.32 2,968.72 1,137.97 -461.39 6,004,720.81 1,527,756.89 0.57 1,191.83 MWD+IFR-AK-CAZ-SC (4) 3,432.01 27.84 337.83 3,102.23 3,052.63 1,178.11 -477.02 6,004,761.18 1,527,74186 1.66 1,233.50 MWD+IFR-AK-CAZ-SC(4) 3,52606 28.42 337.45 3,185.17 3,135.57 1,219.12 -493.89 6,004,80243. 1,527,72561 0.65 1,276.59 MWD+IFR-AK-CAZ-SC(4) 5142017 11:31:32AM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: CD3 Fiord Pad MD Reference: Well: CD3 -111 North Reference: Wellbore: CD3 -111A Survey Calculation Method: Design: CD3 -111A Database: Well CD3 -111 CD3 -111A actual @ 49.60usft (Doyon 19) CD3 -111A actual @ 49.60usft (Doyon 19) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +EI -W Northing Easting DLS Section (usft) P) (°I (usft) (usft) (use) (usft) (ft) (ft) (°1100') (R) Survey Tool Name 3,62048 29.02 338.63 3,267.97 3,218.37 1,261.20 -51085 6,004,844.75 1,527.70829 0.67 1,320.60 MWD+IFR-AK-CAZ-SC (4) 3,715.04 28.85 33847 3.350.73 3,301.13 1,303.78 -527.58 6,004,88756 1,527.69320 020 1,364.88 MWD+IFR-AK-CAZ-$C(4) 3.809.79 29.07 338.86 3,433.63 3,384.03 1,346.51 -544.27 6,004,930.56 1,527.677.16 0.31 1,409.27 MWD+IFR-AK-CAZ-SC(4) 3,904.80 28.92 341.02 3,516.74 3,467.14 1,389.76 -56D.07 6,004,974.04 1527,662.01 1.11 1,453.54 MWD+IFR-AK-CAZ-SC(4) 3,99926 28.90 341.90 3,599.43 3,549. B3 1,433.06 -574.59 6,005,017.54 1,527,648.15 0.45 1,497.10 MWD+IFR-AK-CAZ-SC(4) 4,091.61 28.98 393.29 3,680.24 3.630.64 1,475.70 -587.95 6,005,060.37 1.527,63542 0.73 1,53946 MWD+IFR-AK-CAZ-SC(4) 4,185.45 28.78 343.44 3,762.41 3,712.81 1,519.12 60093 6,005,103.98 1,527,623.10 0.23 1,58221 MWD+IFR-AK-CAZ-SC (4) 4,281.60 26.90 342.86 3,84664 3,797.04 1,563.51 -614.37 6,005,148.57 1,527,610.33 0.32 1,62603 MWD+IFR-AK-CAZ-SC(4) 4,377.36 28.87 343.46 3,930.48 3,880.88 160738 -62717 6,005,19303 1,527,597.60 0.30 1,659]2 MWD+IFR-AK-CAZ-SC (4) 4,471.74 2883 343.57 4,013.15 3,963.55 1,651.45 -640.70 6,005,236.86 1,527,585.33 0.07 1,712.64 MWD+IFR-AK-CAZ-$C(4) 4,566.16 29.03 343.83 4,095.79 4,046.19 169529 -653.52 6.005,280.91 1,527,573.18 0.25 1,755.65 MWD+IFR-AK-CAZ-SC(4) 4,662.04 2884 343.52 4,179.70 4,130.10 1,739.81 -666.55 6,005,32661 1527,560.81 0.25 1,799.33 MAV+IFR-AK-CAZ-5C(4) 4.756.17 28.92 342.39 4,262.12 4,212.52 1,783.27 -679.88 6,005,369.27 1.527,548.14 0.59 1,84232 MWD+IFR-AK-CAZ-SC(4) 4,849.53 28.43 34142 4,344.03 4,29443 1,825.85 -693]9 6,005,41205 1527,534.87 0.72 1,884.95 10WD+1FR-AK-CAZ-SC(4) 4,944.89 28.31 340.53 4,427.94 4,378.34 1,868.69 -708.56 6,005455.10 1,527,520.75 0.46 1,92828 MWD+IFR-AK-CAZ-SC(4) 5,04808 28.30 340.19 4,517.03 4.467.43 1,913.88 -724.69 6,W5,M)OZ2 1,527.50530 0.16 1,974.32 MWD+IFR-AK-CAZ-SC(4) 5.135.21 2844 340.54 4,595.46 4,545.86 1,953.77 -738.92 6,005,54062 1,527,49168 0.24 2,014.96 MWD+IFR-AK-CAZ-SC(4) 5,230.17 2753 34141 4,679.31 4,629.71 1,995.89 -753.45 6,005,582.95 1,527,47778 1.05 2,057.57 MWD+1FR-AK-CAZ-SC(4) 5,324.49 28,12 341.42 4,762.73 4,713.13 2,037.62 -767.48 6,005,624.88 1.527,464.38 0.63 2,099.58 MWD+IFR-AK-CAZ-SC(4) 5,419.49 27.91 341.02 4,846.60 4,797.00 2,079.87 -781.89 6,005,667.34 1,527,45065 0.30 2,142.20 MWD+IFR-AK-CAZ-SC(4) 5,514.39 27,99 341.23 4,930.43 4,880.83 2,121.95 -796.23 6,005,709.63 1,527,436.90 0.13 2,184.71 MWD+IFR-AK-CAZ-SC (4) 5,606.50 28.05 341.44 5,011.74 4,962.14 2,162.95 -810.08 6,005,750.83 1,527,42367 0.13 2,226.02 MWD+IFR-AK-CAZ-SC (4) 5,70321 27.83 341.62 5,097.18 5,047.58 2,205.93 -824.44 6,005,794.01 1,52740996 0.24 2,269.23 MWD+IFR-AK-CAZ-SC(4) 5,798.70 27.86 341.55 5,181.61 5,132.01 2,248.25 -838.53 6,005,836.53 1,527,396.51 0.05 2,31174 MWD+IFR-AK-CAZ-SC(4) 5,89094 2795 340.82 5,263.13 5.213.53 2,289.11 -852.45 6,005,87760 1,527,383.21 0.38 2,352.98 MWD+IFR-AK-CAZ-$C(4) 5,9B3.81 27.70 33970 5,34626 5,295.66 2,329.91 -867.09 6,005,918.61 1,527,369.19 0.62 2,394.60 MWD+IFR.AK-CAZ-SC(4) 6,078.03 2786 338.54 5,42662 5,379.02 2,370.94 -882.74 6,005,959.86 1,527,354.15 0.60 2,436.99 MWD+IFR-AK-CAZ-SC(4) 6,172.80 2776 338.28 5,512.44 5,462.84 2,412.05 -89901 6,00800121 1,527,338.51 0.17 2,479.81 MWD+IFR-AK-CAZ-SC(4) 6,268.98 2769 337.97 5,597.58 5,547.98 2,453.57 -91568 6,006,042.98 1,527,32246 0.17 2,523.21 MWD+IFR-AK-CAZ-SC(4) 6,363.16 27.95 33808 5,680.88 5,631.28 2,494.33 -932.13 6,006,083.98 1,527,30663 0.28 2,565.85 MWD+IFR-AK-CAZ-SC(4) 6,458.23 27.88 338.37 5,764.88 5,715.26 2,535.66 -948.64 6,006,125.55 1,527,29014 0.16 2,608.99 MWD+IFR-AK-CAZ-SC(4) 6,55089 27,76 33866 5,846.83 5,797.23 2,575.90 -%4.48 6,006,166.02 1,527,275.51 0.20 2,650.86 MWD+1FR-AK-CAZ-$C(4) 6,645.42 27.78 338.45 5,930.48 5,880.88 2,616.90 -980.58 6,006,207.25 1,527,260.03 0.11 2,69349 MWD+IFR-AK-CAZ-SC(4) 6,740.49 27.59 338.58 6,014.66 5,965.06 2,658.00 -996.76 6,0W,24858 1,527,244.47 0.21 2,736.25 MWD+IFR-AK-CAZ-SC(4) 6,834.57 29.50 339.22 6,097.30 6,047.70 2,699.94 -1.012.93 6,006.290.76 1,527,228.93 2.W 2,779.69 MWD+IFR-AK-CAZ-SC(4) 6,930.00 31.61 341.46 6,17948 6,129.88 2,745.63 -1,029.22 6,006,33668 1,527,213.33 2.51 2,826.22 MWD+IFR-AK-CAZ-SC(4) 7,025.37 35.35 341.79 6,259.01 6,209.41 2,795.55 -1,045.80 6,006,386.84 1,527,197.51 3.93 2,876.35 MWD+IFR-AK-CAZ-SC (4) 7,120.50 39.50 341.59 6,334.54 6,284.94 2,850.42 -1,063.96 6,006,441.96 1,527,180.18 4.36 2,931 42 MWD+IFR-AK-CAZ-SC (4) 7,217.00 43.13 341.17 6,407.01 6,35741 2.910.7B -1,084.31 6,OW,502.63 1,527,160.74 377 2,992.21 MWD+IFR-AK-CAZ-SC (4) 7,311.83 46.11 340.40 6,474.50 6424.90 2,973.67 -1,106.24 6,006,565.83 1,527,13876 3.19 3,055.96 MWD+IFR-AK-CAZ-SC (4) 5/42017 11:31:32AM Page 4 COMPASS 5000 1 Build 74 Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Project: Western North Slope TVD Reference: Site: CD3 Fiord Pad MD Reference: Well: CD3 -111 North Reference: Wellbore: CD3 -111A Survey Calculation Method: Design: CD3 -111A Database: Survey Well CD3 -111 CD3 -111A actual @ 49.60usft (Doyon 19) CD3 -111A actual @ 49.60usft (Doyon 19) True Minimum Curvature OAKEDMP2 5142017 11:31: 32AM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (") 0 (usft) (usft) (waft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7.407.37 48.32 338.12 6,539.40 6,489.80 3,039.22 -1,131.09 6,006 631.75 1,527,115.90 290 3,12362 MWD+IFR-AK-CAZ-SC(4) 7.503.14 50.83 335.81 6,601.50 6,551.90 3,106.29 -1.159.63 6,006,699.23 1,527,088.37 3.20 3,194.66 MWD+IFR-AK-CAZ-SC(4) 7,598.07 54.03 334.34 6,659.38 6,60918 3,174.50 -1,191 36 6.006,767.91 1,527,057.68 3.59 3,268.49 MWD+IFR-AK-CAZ-SC (4) 7,69340 58.14 33426 6,712.56 6.662.96 3,245.77 -1,225.66 6,006,839.68 1,527,02445 4.31 3,346.31 MWD+IFR-AK-CAZ-SC (4) 7,788.39 62.13 335.14 6,759.85 6,710.25 3,320.23 -1,260.84 6,005 91466 1,526,990.40 4.28 3,427.23 MWD+IFR-AK-CAZ-SC(4) 7,883.50 65.97 335.00 6,80146 6,751.86 3,397.]] -1,296.89 6,006,992.72 1,526,955.53 4.04 3,511.14 MWD+IFR-AK-CAZ-SC(4) 7,979.08 69.46 33441 6.83730 6,788.10 3,477.72 -1,33467 6,007,073.22 1,526,918.95 370 3,598.03 MWD+IFR-AK-CAZ-SC(4) 8,07281 73.32 333.77 6,86760 6,818.00 3,557.60 -1,373.49 6,007,153.67 1,526,88134 4.17 3,685.47 MWD+IFR-AK-CAZ-SC(4) 8,168.14 7773 332.86 6,891.43 6,841.83 3,640.05 -1414.93 6,007,23672 1526,841.14 4.72 3.776.54 MWD+IFR-AK-CAZ-SC(4) 8,262.36 8235 332.05 6,90]]2 6,858.12 3,722.30 -1,457.84 6,007.319.61 1,526,79948 4.98 3,868.30 MND+IFR-AK-CAZ-SC(4) 8,358.48 83.78 33135 6,919.33 6,869.73 3,806.47 -1,502.78 6,007,404.43 1.52675581 1.52 3,962.81 VM,IFR-AK-CAZ-SC (4) 8,453.84 85.21 331.56 6,92847 6,878.87 3890.01 -1,547.85 6,007,48863 1,526,]12,01 1.51 4,056.88 MWD+IFR-AK-CAZ-SC(4) 8,474.53 86.24 332.81 6,930.02 6,880.42 3,908.26 -1,557.47 6,007,50702 1,526,70266 7.82 4,077.31 MWD+IFR-AK-CAZ-SC(4) 8.530.00 86.80 333.73 6,933.38 6,883.78 3,957.70 -1.582.38 6,007.556.83 1,52867851 1.94 4,131.95 NOTaDAOWNSufaey 7' x 6-3/4" 8,57269 87.24 33443 6,935.60 6,886.00 3,996.05 -1,60102 6,007,59545 1.526,66045 1.94 4,173.92 MWD+IFR-AK-CAZ-SC(5) 8,63205 87.17 334.47 6,938.49 6,888.89 4,049.54 -1,626.59 6,00],649.31 1,526,63569 0.14 4,232.23 MWD+IFR-AK-CAZ-SC(5) 8,6]5.]1 88.06 333.22 6.940.31 6,89031 4,088.69 -1,845.82 6,007,688.75 1,526,617.05 3.51 4,275.21 MWD+IFR-AK-CAZ-SC(5) 8,770.22 89.00 332.51 6,942.73 6,893.13 4,1]2.7] -1,688.91 6,007,7]3.46 1,526,57523 1.25 4,368.56 MWD+IFR-AK-CAZ-SC(5) 8,863.59 90.46 330.78 6.943.17 6,893.57 4,254.93 -1,733.25 6.007,85627 1,526,532.14 242 4,461.09 MWD+IFR-AK-CAZ-SC(5) 8,956.96 91.25 33008 6,941.7B 6,892.18 4,336.13 -1,779.32 6,007,93815 1,526,487.29 1.13 4,553.88 MWD+IFR-AK-CAZ-SC(5) 9,051.56 91.38 329.71 6.93961 6,890.01 4,417.95 -1,826.76 6,008,020.66 1526,441.10 0.41 4,647.94 MWD+IFR-AK-CAZ-SC(5) 9,145.99 91.31 32948 6.937.39 6,887.79 4,499.37 -1,874.53 6.008,10218 1,526,394.55 0.25 4,741.89 MWD+IFR-AK-CAZ-SC(5) 9,240.18 91.07 328.04 8,935.44 6,885.84 4,579.88 -1,92337 6,00818401 1,526.34693 1.55 4,835.73 MWD+IFR-AK-CAZ-SC(5) 9,333.87 90.72 326.44 6,933.97 6,88437 4,658.66 -1,974.% 6,008263.54 1,526,297.44 1.75 4,929.26 MWD+IFR-AK-CAZ-SC(5) 9,428.33 90.90 326.41 6,932.64 6,883.04 4,737.35 -2,026.30 6.008,343.00 1,526,24840 0.19 5,023.62 MWD+IFR-AK-CAZ-SC(5) 9,522.80 9069 325.62 6,931.33 6,8B1.73 4,815.68 -2,079.10 6,006,422.10 1,526,194.78 0.87 5,118.03 MWD+IFR-AK-CAZ-SC(5) 9,617.62 90.48 326.23 6,930.36 6,880.76 4,894.21 -2,132.22 6,008,501.42 1,526,14285 0.68 5,21279 MWD+IFR-AK-CAZ-SC(5) 9,71241 90.42 326.31 6,929.61 6,880.01 4,973.04 -2,184.85 6,0N,581 03 1,526,09141 0.11 5,307.50 MWD+IFR-AK-CAZ-SC(5) 9,803.52 90.11 326.21 6,929.18 6,879.58 5,051.30 -2,237.12 6,008,660.05 1,526,040.33 0.35 5,401.53 MWD+IFR-AK-CAZ-SC(5) 9,900.26 89.90 325.94 6,929.17 6,879.57 5,129.08 -2,28944 6,008,738.61 1,525,989.19 0.36 5,495.21 MWD+IFR-AK-CAZ-SC (5) 9,994.80 89.79 325.31 6,929.43 6,879.83 5,207.11 -2,342.82 6,008,81742 1,525,93]00 068 5,58931 MWD+IFR-AK-CAZ-SC(5) 10,08933 90,11 324.91 6,929.51 6,879.91 5,284.98 -2,39].12 6,008,896.09 1,525,883.88 0.54 5,684.63 MWD+IFR-AK-CAZ-SC(5) 10.18394 89.97 325.43 6,929.44 6,879.84 5,362.31 -2,450.92 6,008,974.22 1,525,831.25 0.57 5,778.82 MWD+IFR-AK-CAZ-SC(5) 10,278.73 89.86 327.11 6,929.58 6,879.98 5,441.14 -2,503.56 6,009,053.82 1,525,779.81 1.78 5,873.53 M010+1FR-AK-CAZ-SC 15) 10,371.82 90.18 328.48 6,929.55 6,879.95 5,519.91 -2,553.17 6,00),133.32 1,525,731.39 1.51 5.966.41 MWD+IFR-AK-CAZ-SC(5) 10,466.95 90.14 330.91 6,92929 6,879.69 5,602.03 -2,601.17 6,009,216.15 1,525,684.64 2.55 6,061.06 MWD+IFR-AK-CAZ-SC(5) 10,56065 90.14 331.35 6,929.06 6,87946 5,684.08 -2,64641 6,009,298.86 1,525,640.64 0.47 6,154.04 MWD+IFR-AK-CAZ-SC(5) 10,654.37 90.47 334.92 6,926.56 6,878.96 5,]6].67 -2,688.75 6,009,383.07 1,525,599.56 3.83 6,246.55 MWD+1FR-AK-CAZ-SC(5) 10,748.90 89.48 336.85 6,928.60 6,879.00 5,853.95 -2,72].3] 6,009,46991 1,525.562.24 2.29 6,339.05 MWD+IFR-AK-CAZ-SC(5) 10,843.61 89.49 335.03 6,929.45 8,879.85 5.940.42 -2,765.98 6.009,556.95 1,525,524.94 192 6,431.71 MWD+IFR-AK-CAZ-SC(5) 5142017 11:31: 32AM Page 5 COMPASS 5000.1 Build 74 Company: ConowPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD3 Fiord Pad Well: CD3 -111 Wellbore: CD3 -111A Design: CD3 -111A Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Weil CD3 -111 CO3-IIIA actual @ 49.60usft (Doyon 19) CD3 -111A actual @ 49.60usft (Doyon 19) True Minimum Curvature OAKEDMP2 Survey Map Map vertical MD Inc AN TvD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) 11 (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 10,937.90 89.21 335.51 6,930.52 6.880.92 6,02606 -2,80542 6,009,643.18 1,525,48679 0.59 6,524.17 MVV)+IFR-AK-CAZ-SC(5) 11,035.05 89.72 333.19 6,931.43 6,881.83 6,11363 -2,847.47 6,009,731.34 1,525,446.07 2.44 8619.73 MWD+1FR-AK-CAZ-SC(5) 11,132.51 91.36 329.48 6,930.51 6,880.91 6,199.12 -2,894.21 6,009.817.52 1,525,40063 4.16 6,716.37 MWD+IFR-AK-CAZ-SC(5) 11,230.29 91.76 325.62 6,927.85 6,878.25 6,281.59 -2,946.65 6,009,90016 1,525,34944 3.97 6,813.91 MWD+IFR-AK-CAZ-SC(5) 11,327.07 91.60 322.81 6,925.01 6,875.41 6,36005 -3,003.21 6,009,980.06 1525,294.07 2.91 6,91063 MWD+IFR-AK-CAZ-SC(5) 11,424.28 89.80 321.09 6.923.82 6,874.22 6,436.59 -3,063.11 6,010,057.49 1,525,235.33 2.56 TWT77 MWD+IFR-AK-CAZ-SC(5) 11,522.02 9038 321.29 6,923.33 6,87373 6,51275 -3124.37 6.010,134.55 1.525,175 23 1.02 7,105.39 MWD+IFR-AK-CAZ-SC(5) 11,609.00 90.78 321.29 6,922.14 6,872.54 6,580.62 .3,178.76 6,010,203.22 1,525,121.87 0.00 7,192.26 NOT an Actual Survey 4412' x 6.118" 11.642.00 90.78 321.29 6,921.69 6,872.09 6,606.37 -3,199.40 6,010,229.28 1,525,101.62 0.00 7,225.22 PROJECTEDto TD rinal Definitive Survey Verified and Signed -off All targets andfor welt position objectives have been achieved. 1.1 Yes ❑ No I have checked to the best a1 my ab9ify that the following data is correct: P1 Surface Coordinates Declination & Convergence GRS Survey Corrections L�1 Survey Tool Codes SLB DE: 13�.eit %¢hyp>De S 2017 Yfrm°eyWh.90: Client Representative. Weifeng Dai Date: 514!2017 51412 01 7 11:31:32AM ar. ue 5 COMPASS 5000.1 Build 74 THE STATE °fALASKA GOVERNOR BILL WALKER Hanna Sylte Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3 -111A Permit to Drill Number: 217-004 Sundry Number: 317-138 Dear Ms. Sylte: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this /]"qday of April, 2017. Sincerely, *�� CayFoerster Chair RSDFAS 11,SPR 1 2 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED APR 0 5 2017 OGC6 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 9 Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development Q.217-004 Stratigraphic ElService ❑ 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20526-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CRU CD3 -111A ` Will planned perforations require a spacing exception? Yes ❑ No ❑O J 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 372105, 364471, 364470 Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 11,644' 6874' 11,605' 6923' 7,500 Casing Length Size MD TVD Buret Collapse Structural Conductor Surface 2685' 9-5/8" 2721' 2469' Intermediate 8494' 7" 8530' 6935' Production 8094' 3.5" 8130' 6891' Liner 3475' 4.5" 11,605' 6923' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 1/2" L80 8130' planned Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premier Production packer, TRMAXX-5E TRSV Packer at 8060' MD/ TVD, SSSV at 2,130' MD / 1,994' TVD 12. Attachments: Proposal Summary Wellbore schematic 141 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/10/2017 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Hanna Sylte, 907-265-6342 Email Hanna.Sylte@ConocoPhillips.com Printed Name Hanna Sylte Title Completions Engineer ^�a'k Lf L/ X201 Signature V Phone 907-265-6342 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ rr Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: RBI)NIS APR 12 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4- _ Form 10-403 evised 11/2015 alid for 12 months from the date of approval. ?Jkil `+5117- 0WmINAE, ()DW 4,7,.0,7 Submit Fc m and Attachments in Duplicate CD3 -111A Nechelik Producer 20"94# HAO Welded Conductor to 11(T TRMAXX SSSV 2,130' MD 9-5J8" 40# L-80 BTC Surface Casing 2,721' MD 12,469' TVD cemented to surface V/? 9.69 LA0 EUE Tubing 8,350' MD PTS Downhole Gauge 7,950' MD Baker Premier Production Packer 8,006' MD 7" 26# L-80 BTCM intermediate Casing 8,466' MD Upper Completion: I PTM 1) 4-Y:" 12.601 TXP Tubing (2 jts) XO to 3-35' EUE tubing 2) Shallow nipple profile with SSSV 3) 3-h" x 1" Camco KBMG GLM (xx°) w/ DV T 4) 3-W x 1"Camco KBMG GLM (xx°) wl DV 7' 4) 3-'h" x 1"Camco KBMG GLM (xx°) w1DCK2 T pinned for 2500 psi casing to tbg shear 5) PTS Downhole Gauge, Encapsulated I -Wire 1.5' wlcannon damps on every joint 6) Baker Premier Packer 7) XN nipple 2812" ID 1.5' 8) WLEG 1.5' Lower Completion: 9) Flexlock Liner Hanger 37' XO 5" Hydril 521 Box X 4-%" IBTM pin 10) 4 %-, 12.6#1ft, LM TXP Liner wl ball actuated frac ports every 700' and SalffiI open hole frac packers 11) WP/ 8 Alpha Sleeve @ toe 6112" Hot: TD 11,644' MD I 0 o c o • I ' I Salel Open Hole Frac Packers VA" 12.6# LA0 TXP Production Liner with frac Sleeves 8,127'—11,600MD Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE :-�ASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason E. Lyons Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD3 -111A Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) herein. Jason E. Lyons, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jason E. Lyons. I am over 19 years old and have personal knowledge of the matters set forth 2. 1 am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAP') 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On April 4, 2017, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 4'h day of April, 2017. STATE OF ALASKA M THIRD JUDICIAL DISTRICT son E. Lyons This instrument was acknowledged before me this 41h day of April, 2017, by Jason E. Lyons. Notary Public, State of Alaska My Commission Expires: ConocoPhillips Alaska, Inc. April 4", 2017 To: Operator and Owners (shown on Exhibit 2) Jason Lyons Staff Landman Alaska Land & BD ConocoPhillips Company 700 G Street, ATO -1478 Anchorage, AK 99501 Office: 907-265-6002 Fax: 907-263-4966 jason.lyons@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (I) for CD3 -11 IAWell ADL372105 and ADL364471 Colville River Unit, Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit ("CRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the CD3 -111A Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about April 4, 2017. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well has been drilled as a directional horizontal well on leases ADL372105 and ADL364471 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 3,945' 874' T12N R5E 5 Umiat Heel 4,970' 5,237' T13N R5E 32 Umiat Bottomhole 2,619' 1,414' T13N R5E 31 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, Jason Lyons Staff Landman Rttachments: Exhibits 1 & 2 Bee: Hanna Sylte Brian Buck Kevin Donley Stephen Thatcher ADL388527 ADL364470 ADL389725 Ti3NR4 T13NP.5E t T12NRSE ADL372105 • Frac Points — Trajectory Open Interval Half Mile Frac Point Radius Q Half Mile Trajectory Radius Wells within Trajectory Radius Exhibit 1 Fiord Kuparuk PA N A L.._. j Fiord Kuparuk PA 0 0.2 0.4 0.6 0.8 = CPAI Leases AD C Miles ADL372104 I ConocoPhillips Alaska, Inc. CD3 -111A Lease Plat 4/4/2017 Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, NS Development Manager Owner (Non -Operator): Anadarko E&P Onshore LLC P.O. Box 1330 Houston, TX 7725 1-1 33 0 Attention: Mike Nixson, Director Land — Alaska Petro -Hunt, L.L.C. 2101 Cedar Springs Road, Suite 600 Dallas, Texas 75201 Attn: Pete Arnett Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Chantal Walsh, Director Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0187 Attention: Joe Nukapigak, President Section 2 — Plat 20 AAC 25.283 (a)(2) 1: Wells within .5 miles ADL388527 ADL389725 T13NR4— T1 T`27N;R.51- • Frac Points — Trajectory Open Interval Half Mile Frac Point Radius Half Mile Trajectory Radius Wells within Trajectory Radius L.._. Fiord Kuparuk PA CPAI Leases ADL364470 ADL372105 Fiord Kuparuk PA N A 0 0.2 0.4 0.6 0.8 Miles ADL372104 i ConocoPhillips Alaska, Inc. CD3 -111A Lease Plat 4!4/2017 Table 1: Wells within .5 miles CD3 -106 501032061100 WELL ACTIVE WELL NAME API TYPE STATUS CD3 -106 501032061100 PROD ACTIVE CD3 -1061-1 501032061160 PROD ACTIVE CD3 -107 501032052901 PROD ACTIVE CD3 -1071-1 501032052960 PROD ACTIVE CD3 -108 501032050700 INJ ACTIVE CD3 -109 501032051000 PROD ACTIVE CD3 -110 501032050900 INJ ACTIVE CD3 -111 501032052600 PROD ACTIVE CD3 -1111-1 501032052660 PROD ACTIVE CD3 -112 501032052700 INJ ACTIVE CD3 -113 501032054100 PROD ACTIVE CD3 -114 501032054400 INJ ACTIVE CD3 -115 501032059300 PROD ACTIVE CD3 -117 501032059600 PROD ACTIVE CD3 -118 501032057000 INJ ACTIVE CD3 -119 501032065300 PROD ACTIVE CD3-119PB1 501032065370 EXPEND PA CD3 -121 501032061500 INJ ACTIVE CD3 -122 501032060900 PROD ACTIVE CD3 -123 501032061700 INJ ACTIVE CD3 -124 501032061200 INJ ACTIVE CD3 -125 501032063200 PROD ACTIVE CD3-125PB1 501032063270 EXPEND PA CD3 -127 501032063400 PROD ACTIVE CD3-127PB1 501032063470 EXPEND PA CD3 -128 501032063800 INJ ACTIVE CD3 -130 501032067700 PROD ACTIVE CD3-130PB1 501032067770 EXPEND PA CD3-130PB2 501032067771 EXPEND PA CD3 -198 501032063700 INJ ACTIVE CD3 -199 501032063500 PROD ACTIVE CD3 -301 501032054300 PROD PA CD3 -301A 501032054301 PROD ACTIVE CD3-301APB1 501032054371 EXPEND PA CD3-301PB1 501032054370 EXPEND PA CD3 -302 501032052200 INJ PA CD3 -302A 501032052201 INJ ACTIVE CD3-302PB1 501032052270 EXPEND PA CD3-302PB2 501032052271 EXPEND PA CD3-302PB3 501032052272 EXPEND PA CD3 -303 501032056800 INJ ACTIVE CD3 -304 501032059800 PROD ACTIVE CD3 -305 501032058900 INJ ACTIVE CD3-305PB1 501032058970 EXPEND PA CD3 -307 501032052900 PROD PA CD3 -316 501032055900 INJ PA C133 -316A 501032055901 INJ PA CD3-316APB1 501032055970 EXPEND PA CD3 -316B 501032055903 PROD ACTIVE CD3-316BPB1 501032055971 EXPEND PA C133-320 501032066700 PROD SUSP SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. / See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. ✓ SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 9-5/8" casing cement pump report on 3/8/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1100 psi and the floats were checked and they held. The 7 casing cement report on 3/28/2017 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were not seen throughout the job. The plug bumped at 970 psi, and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 3/21/2017 the 10-3/4" casing was pressure tested to 2,500 psi for 30 mins. The casing will be pressure tested to 3,000 psi on rig. The tubing will be pressure tested to 4,100 psi on rig. The 3.5" tubing will be pressure tested to 5,260 psi prior to frac'ing. The 7" casing will be pressure tested to 3,000 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,500 Annulus pressure during frac 2,720 Annulus PRV setpoint during frac 2,850 7" Annulus pressure test 3,06-0- 3 1/2" Tubing pressure Test 5,260 Nitrogen PRV 8,788 Highest pump trip 8,588 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 9-5/8" 40 L-80 5,750 psi 3,090 psi 7" 26 L-80 7,240 psi 5,410 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Wellbore pressure ratings Bleed / Taft Tale Tank Stimulation Surface Rig -Up T m� r �e Mdrul dWrld U E" 0 Pop -OR Tent .{pZ> Frac Pomp �-- Frac Pump ji • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 2,850 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. Pap -0R Ta* Pump Tnxk Frac Pump Frac Pump Stimulation Tree Saver OPEN POSITION )PRIOR TO MANDREL INSERTION) CONNECTION .REMOTE OPERATED MASTER VALVE MASTER VALVE Slinger MANDREL 'UE AND VALVE WELL V, WELLHEAD VALVES CLOSED \ -4 QUAD PAI ASSEM PUCE IN T TLRRNO CLOSED POSITION )MANDREL INSERTED) • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 %2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm VENT —VANE OPEN Alpine Wellhead System �®�o6ot�o-aeooa�� A GPIODO Cti OODDomsCM mm 7�6®R19 m¢maraa� IM. u.low srsm .i Ic IZW4 SIM 5]1F11 YR/i 4LM fGLSMWAMM mw---.... SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Nechelik interval is approximately 80' TVD thick at the heel of the lateral and thinning to 70' TVD toward to the toe. The Nechelik sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Nechelik is estimated to be at 8,424' MD/6,877' TVDSS. The estimated fracture gradient for the Nechelik sandstone is 12.5 ppg. The overlying confining zone consists of greater than 700' TVD of Kalubik and HRZ mudstones. The estimated fracture gradient for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 6,916' MD/6,119' TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales, based on nearby well control and was not penetrated in the CD3 -111A wellbore. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casino & Cement assessments for all wells that transect the confining zone: CD3 -121: The 7" casing cement report on 3/20/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were seen throughout the job. The plug bumped at 900 psi, and the floats were checked and they held. CD3 -199: The T' casing cement report on 2/23/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were not seen throughout the job. The plug bumped at 1100 psi and the floats were checked and they held. CD3 -301A: The 7" casing cement report on 3/26/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were not seen throughout the job. The plug bumped at 1150 psi and the floats were checked and they held. CD3-301APB1: CD3-301APB1 was plugged as per state regulations on 3/9/2010. CD3 -110: The 7" casing cement report on 4/19/2005 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1400 psi, and the floats were checked and they held. C133-198: The T' casing cement report on 3/26/2011 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were not seen throughout the job. The plug bumped at 1967 psi, and the floats were checked and they held. CD3 -112: The 7" casing cement report on 4/2/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg class G cement. Full returns were seen throughout the job. The plug bumped at 950 psi, and the floats were checked and they held. CD3 -106: 7" casing cement pump report on 2/08/2008 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.6 ppg mud. Reciprocated pipe throughout the job. The plug bumped @ 1200 psi and the floats were checked and they held. CD3 -111 Fracture Stimulation Area of Review Top of Fiord 011 Tap of NechelikTop of Cement Top of Cement Top of Cement Cement Operations WELLNAME STATUS Caring Size Pool (MD) Oil Pool (MD) Ils/0581 Determined By Reservoir Status Zonal Isolation Summary Mechanical Integrity rrVDSS) 3/28/26 MIT -IA passed to 3000 psi. f Open for injection TOC Packer 41 bbls 15.8 ppe clan G Known T%IA for CD3112 Inl T' 8007 -6751 7588 6421 Ulculated hole @7588'&@8,023 cement only on gas, waivered water injeciton only. C133-310 Inj T 8067 -6752 5356 4701 N CaCalculated!Calculated!Open hole for injection TOC@5356'&Packer @79]2' 49 bbls 15.8 pip, class Gmens 2/23/2014 MIT -IA passed to 2735 psi 61 bbls 15.8 poll class G 10/19/2015 CMIT-TxlA passed to C03303A Prod 7- 10517 -675 9200 6324 ✓ Calculated Open hole for production TOC @ 9200' & Packer @ 9892' 2500 cement psi MD 303AP81 PA 7" 10312 -6726 Top plug at8560' 5,924 Calculated Plugged and abandoned Cement plugs, top plug at 6560' 43 bbl, 17 pp` class G N/A s! cemen31 1/28/2017 MMIA passed to 3300 psi. 00}198 in! T' 867) -6957 7,597 6,504 Soniclog Slatted liner for injection TOC@7597'@Packerat813)' bbls 15.8 poll class G Known TAA only on gas, wakened for r cement water injection only TOC III ]81W&Seal assembly at 536bls IS.8ppgc1asaG 3/11/2011 MIT -IA passed fo 3500 psi. CD3 -199 Prod T' 8308 -6741 7810 6480 Calculated Frac sleeves open for Production 8743' cement 8/1112036 FL -IA TIM ".ad CD3 -106 Prod ]" 33452 -6819 13900 6672 Calculated Slotted liner for Production TOC@11900&Packer at 63 bbl, 15.8 ppe clas,G 3/19/20361A TIFL passed 12,006 cement SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that no faults or fracture systems transect the Nechelik Formation or enter the confining zone within one half mile radius of the wellbore trajectory for CD3 -111A. Based on our knowledge of the principle stress direction in the Nechelik Formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. 2: CD3 -111A Fault ADL388527 ADL38a470 ABL389725 T13NR4 _ TQNR5E T'12NR5E Mn 114 • Frac Points — Trajectory — Open Interval Q Half Mile Frac Point Radius O Half Mile Trajectory Radius — Wells within Trajectory Radius Ilb_Nechelik_faultyaps_21 Feb2017 L.—A Fiord Kuparuk PA = CPAI Leases is Fiord Kuparuk PA ADL372105 LD3� ADL372104 \ N ConocoPhillips Alaska, Inc. CD3 -111A D 0.2 o.a o.s 0.e Lease Plat mommmi Miles SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD3 -111A will be completed in 2017 as a horizontal producer in the Nechelik formation. The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1 s' stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 20 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 15,000 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pressure test the tubing to 5260 psi 9. Slowly increase annulus pressure to 2730 psi. 10. Increase tubing pressure to 7500 psi to set the Saltel frac packers 11. Pump the 310 bbl breakdown stage (25# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 12. Perform a hard shut down, Obtain ]SIP and fluid efficiency estimates. 13. Pump the Frac job by following attached HES schedule @ 25bpm with a maximum expected treating pressure of 7,500 psi. • 5 stages, — 500,000 lbs of 20/40 Wanli proppant 14. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 15. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). CUSTOMER ConcroPbillips Alaska, Inc. API 50103-20526 FD(Ib/gal) 8.5a LAT 7041936 LEASE CD3 -111A SALESORDER BHST(°F) 165 LONG 350.9111 FORMATION ASena NALLIBURTON j ConocoPhillips Alaska, Inc. - CD3 -111A Planned Design Prop urry can can urry rap Cage nterva - osurhNnr, - u um 2 LIC - c _....._......._. p O"ocastmen Stagg Fluid Stage proppant Coni Rate Volume Volume Volume TOWI ¶Ira Time Buffer Go[tllnker Goselnker FeRe Protect Gel alo[IEe trader BrS.lar Interval Number Description Description Description Ion ( ) b m (gal) (bW (bbl lbs) (hhm ms (hhurul t) (got) lops) (And (Pd (APO I (pPU pt) 1-1 Freeze Protect Freeze Protect 5 2,100 50 50 0:10:00 1:14:11 1000.00 I-2 25#H bore ShNt Alpha Sleeve 5 1,000 24 24 0:04:46 1:04:11 1.00 1.00 0.90 0.45 25.00 0.15 2.00 0.25 1-3 25#H borG Mini -Frit 25 13,000 310 310 0:12:23 0:59:25 1.00 1.00 0.90 0.45 25.00 0.15 2.00 0.25 co 1.4 25p Linear Flush 25 5,080 121 121 0:04:51 0:4]:02 1.00 25.00 0.15 2.00 0.25 1-5 Shut -In Shut -In 0:42:12 n 1.6 25#H borG Pad 25 12,600 300 300 0:12:00 0:42:12 I.DO 1.00 0.90 0.45 25.00 0.15 2.01) y 1-] 25# H borG Pro ant Laden Fluid WanIi 20/40 1.OD 25 3,355 80 83 3,355 0:03:20 0:30:12 1.00 1.00 0.9D 0.45 25.00 0.15 2.00 c< 1-8 25#H bore PropplantLaden Fluid WanIi 20140 2.00 25 3,355 80 e] 6,]SD 0:03:29 0:26:51 1.00 1.00 0.90 0.45 25.00 0.15 2.00 1-9 25pH bore Pro nt Laden Fluid WanIi 20/40 3.00 25 3,541 84 95 10,623 1 D:03:50 0:23:22 1 1.00 1.00 0.90 D.45 25.00 0.15 2.00 1.10 25#H borG pro ant Laden Fluid WanIi 20140 4.00 25 6,664 159 186 25,656 0:07:30 0:19:32 1.00 1.00 0.90 0.45 25.00 0.15 2.00 1-11 25#H borG Pro ant Laden Fluid WanIi 20140 5.0025 4,940 118 143 24,700 0:05:47 0:12:02 1.00 1.00 0.90 0.45 25.00 0.15 2.00 1-12 25#H borG Proppa nt Laden Fluid Well)20/40 6.00 25 1 4,660 111 140 27,960 0:05:39 O:D6:15 1.OD 1.0 0.90 1 0.45 25.00 0.15 200 1-13 25#H bore Spacer & DroBall 1.813" 25 630 15 15 0:00:36 0:00:36 1.00 1.00 0.90 1 0.45 25.00 0.15 2,00 as 2.1 25#H bore Pad 25 12,600 300 300 0:12:00 0:42:12 1.00 1.00 0.90 1 0.45 25.00 0.15 2.00 2-2 25#HborG Proant Laden Fluid Wari 20/40 1.00 25 3,355 80 83 3,355 0:03:20 0:30:12 1.00 1.00 0.90 0.45 25.00 0.15 2,00 a: 2d 25#HborG Proper Laden Fluid WanIi 20/40 2.00 25 3,355IR 80 BJ 6710 0:03:29 0:26:51 1.00 1.00 0.90 0.45 25.00 1 0.15 2.00 24 25p HyborG Pro ant Laden Fluid WanIi 20/40 3.OD 25 3,503 84 95 10,623 0:03:50 0:23:22 1.00 1.00 0.90 0.45 25.00 0.15 2.00 $Q� 2-5 25p NyborG Pro tt naden Fluid Wank20/40 4.00 25 6,664 159 186 26,656 0:07:30 0:19:32 1.00 1.00 0.90 0.45 25.00 0.15 2.00 se 2-6 25#HborG P.Npant Laden Fluid WanIi 2040 5.D0 25 4,940 118 143 24,700 0:05:47 0:12:02 1.00 1.00 0.90 OAS 25.00 0.15 2.00 6 2-] 25#NborG P.Ppent Laden Fluid Wan1120/40 6.00 25 4,660 111 140 1 27,960 0:05:39 0:06:15 1 1.00 1.00 0.90 0.45 25.00 0.15 2.00 2-e 250H bore Spacer&Dro Ball 1.875" 25 630 SS 15 0:00:36 0:00:36 1.00 S.OD 0.90 0.45 25.00 0.15 2.00 on 3-1 25#H bore Pad 25 12,600 300 300 0:12:00 0:42:12 1.00 1.00 0.90 0.45 25.00 0.15 200 3-2 25#H borG Pro ant Laden Fluid Wan1120/40 1.00 25 3,355 80 83 3,355 0:03:20 0:30:12 1.00 1.00 0.90 0.45 25.00 0.15 2.00 ry 3-3 15pH bore Pro an[laden Fluid WanIi 20/40 2.00 25 3,355 a0 87 6,]10 0:03:29 0:26:51 1.00 1.00 0.90 0.05 25.00 0.15 2.OD L�o� 34 25#H bore Pro ant Laden Fluid WanIi 20/40 3.00 25 3,541 84 95 10,623 0:03:50 0:23:22 1.00 1.00 0.90 0.45 25.00 0.15 2DD e Q' 3-5 25#H bore Pro an[laden Fluid Wars 20140 4.OD 25 6,660 159 186 26,656 0:0]:30 0:19:32 1.00 1.00 0.90 0.05 25.00 0.15 2.OD Fa 3-6 25NH bore P211221 laden Fluid Wanll 20/40 S.OD 25 4,940 118 143 24,700 0:05:07 0:12:02 1.00 1.00 0.90 0.45 25.00 0.15 2.00 3-] 25#H bore Pm ant Laden Fluid Wan1120/40 6.OD 25 4,660 111 140 27,960 0:05:39 0:06:15 1.00 1.00 0.9D 0.45 25.00 0.15 2.00 jg 3-e 25#H bore S cer&Dro Ba113.938" 25 630 15 15 D'A0:36 0:00:36 1.00 1.00 0.90 0.45 25.00 0.15 2.00 ConocoPhillips Alaska, Inc. - CD3 -111A Planned Design CUSTOMER ConOcoPhlllipa Alaska, Inc. API 50103-20526 FD(Ib/golf 8.54 IAT 70.41936 LEASE Ong 11M SALESORDER BHST(i 165 LONG -150.9111 HALLIBL67TON i Proppant Type sign Tcr i(IbsJ wanli 20/OO SOD,D20 Initial Design gores 1-5 224,745 5,351 500,020 Max Additive Rat Min Additive Rat LaLrf300D MO -67 CL-22UC CL-31LV -200 WG -36 -..._ rop um _.__.._ can --- --I urry Prop Stage Interval o- u I PPm sm"..,.�.,,,,,,.e. 1.1 1.1 0.9 0.5 __.__._....- o- SP featmen Stage Fluid Stage Proppant Cone Rate Volume Volume Volume Total Time Time SurRnant auHer crossllnker Crozshrier Fleeze Pmlerl Gel 91n[Ide interval Number Description Description pescriptionaa_ / pp) (bpm) ( Il (bbll (bbll (IbsJ (hh:mmss hh:mmss/ (9pt) (9PU (9 tl (9Pt) (apt) (Pot; (ppt) liar r 1ppt Breaker (p Ll 4-1 25NH bprG Pad 25 121600 300 300 0:12:00 0:42:12 1.00 LED 0.90 0.45 1 25.00 0.15 2.00 i 44 25NH borG Propant Laden Fluid WanIi 20/40 LOD 25 3,355 e0 83 3,355 0:03:20 0:30:12 IeD 1.00 0.90 045 1 25.00 0.15 2DD sir 4-3 259N borG Pro ant Laden Fluid WanIi 20/40 2.00 25 3,355 80 87 6,710 0:03:29 0:26:51 1.00 1.00 0.90045 25.00 0.15 2.00 i Ic 4-4 25#H borG Pro ant Laden Fluid WanIi 2040 3.00 25 3,541 84 95 10,623 0:03:50 0:23:22 1.00 1.00 0.90 0.45 25.00 0.15 2.80 e Q 4-5 25NH borG Pro ant Laden Fluid Wank 20/40 4.00 25 6,664 159 186 26,656 0:07:30 0:19:32 1A0 1.00 0.90 0.45 1 25.00 0.15 2.00 so us 4-6 25# H bor G Proppent Laden Fluid Wanli 20/40 S.OD 25 4,940 118 143 24,700 0:05:47 0:12:02 1.00 1.00 0.90 OAS 25.00 0.15 2.00 4-7 25R H bor G Pro ant Laden Fluid Wanli 20/40 6A0 25 4,660 111 140 27,960 0:05:39 0:06:15 1.00 1:00 0.90 OAS 25.00 0.15 2.00 4-8 25# HitterG Sperear&Dro Ball 2.000" 25 1 630 1 15 15 1 1 0:00:36 0:00:36 1 1.00 1.00 0.90 0.45 25.OD D.15 1 2.00 5-1 25#H borG Pad 25 12,600 300 300 1 D:12:00 0:46:48 1.00 100 0.90 0.45 2500 0.15 2.00 5-2 25#H borG Proppant Laden Fluid WanIi 2040 1.00 25 3,355 80 83 1 3,355 0:03:20 D:34.48 LOD 1.00 DAD OAS 25.00 0.15 2.00 Y1 5-3 25#H bore Pro n[Latlen Fluid WanIi 20/40 2.00 25 3,355 80 87 6,]10 0:03:29 0:31:28 1.00 1.00 0.90 0.45 25.00 0.15 2.00 a m 5-4 25#X bore Proppant Laden Fluid Wai 20/40 3.00 25 3,541 84 95 10,623 0:03:50 0:2]:58 1.00 1.00 0.90 0.45 25.00 0.15 2.00 y✓,an as 5-5 25#H bore pro ant Laden Fluid Wan1120/40 4.00 25 6,664 159 186 26,656 0:0]:30 0:24:!18 I.OD 1.00 0.90 0.45 25.00 0.15 2.OD =Q 55 25pH bore Proand Laden Fluid WanIi2040 5.00 25 4,940 118 143 24,700 0:05:4] 0:16:38 I.00 1.00 0.90 0.45 25.00 0.15 2.00 0.25 5-] 25Nso H bore Proant Laden Fluid WanIi 20/40 EO0 25 4,660 ill 140 2],960 0:05:39 0:10:51 1.00 1.00 0.90 0.45 25.00 0.15 2.OD 0.25 5-8 25p Linear Flush 25 3,366 80 80 0:03:12 0:05:12 1.00 25.00 0.15 2.00 0.50 5-9 Freeze Protect Freeze Protect 25 2,100 50 50 0:02:00 0:02:00 Ip00,00 Proppant Type sign Tcr i(IbsJ wanli 20/OO SOD,D20 Initial Design gores 1-5 224,745 5,351 500,020 Max Additive Rat Min Additive Rat LaLrf300D MO -67 CL-22UC CL-31LV -200 WG -36 BE -6 OptiFlo-III Sp (9Pm1 m (9Pm) / pm) /9pm At m I PPm ppm 1.1 1.1 0.9 0.5 1,050.0 26.3 0.2 2.1 0.5 0.2 0.2 1 0.2 0.1 210.0 5.3 0.0 0.4 0.1 lea na 194 95 4200 5514 33 441 9 ConoeoPhillips Alaska, Inc. - CD3 -111A Planned Design 2 CD3 -111 Alpine A Multi -stage Frac Model Frac Design Stage 1 Stage Number Fluid Description Stage Description Prop Conc (ppg) Proppant Description Design Clean Volume (gal) 1-1 LVT Freeze Protect 2,100 1-2 25#Hybor G Shift Alpha Sleeve 1,000 1-3 25# HyborG Mini -Frac 13,000 1-4 25# Linear Flush 5,084 1-5 Shut -In Shut -In 1-6 25# Hybor G Pad 12,600 1-7 25# Hybor G Proppant Laden Fluid 1.00 Wanli 20/40 3,555 1-8 25# Hybor G Proppant Laden Fluid 2.00 Wanli 20/40 3,555 1-9 25# Hybor G Proppant Laden Fluid 3.00 Wanli 20/40 3,541 1-10 25# Hybor G Proppant Laden Fluid 4.00 Wanli 20/40 6,664 1-11 25# Hybor G Proppant Laden Fluid 5.00 Wanli 20/40 4,940 1-12 25# Hybor G Proppant Laden Fluid 6.00 Wanli 20/40 4,660 1-13 25# Hybor G Spacer and Drop Ball 630 Frac Design Stages 2-5 Stage Number Fluid Description Stage Description Prop Cone (ppg) Proppant Description Design Clean Volume (gal) 2-1 25# Hybor G Pad 12,600 2-2 25# Hybor G Proppant Laden Fluid 1.00 Wanli 20/40 3,555 2-3 25# Hybor G Proppant Laden Fluid 2.00 Wanli 20/40 3,555 2-4 25# Hybor G Proppant Laden Fluid 3.00 Wanli 20/40 3,541 2-5 25# Hybor G Proppant Laden Fluid 4.00 Wanli 20/40 6,664 2-6 25# Hybor G Proppant Laden Fluid 5.00 Wanli 20/40 4,940 2-7 25# Hybor G Proppant Laden Fluid 6.00 Wanli 20/40 4,660 2-8 25# Linear Spacer and Drop Ball 630 25# Hybor G 25# Linear 20/40 Wanli Totals (5 stages) 212,095 gal 8,450 gal 520,000 lbs Model Results CD3 -111 Stages Job Size Top TVD Btm TVD Propped Fracture Avg (Ib) (ft) (ft) Half- Height (ft) Fracture length (ft) Width (in) 1-5 1001000 6925 7055 380 130 0.29 • Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. Hydraulic Fracturing Fluid product Component Information Disclosure FrwM Oate ]01]NN Hbts N»b counts : ."a - .h.aaAvlxmnmr. API mormainsmmmsm NIXRX S"E operator Nam EBVS well Name and Number'. CWAtU L 1s1.aa Larnade' IDs! mse:me, LoneXeetbn 1umydrinnm,@rapnow True o bl ar Walve r, .,.am ".Q.: TOme al': iM.Fb Hydrauhk F—Wrine rUd Comwsltlan: Chamibal Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier purpose Ingredients Sewfce ConFmN.lon In Additive Concentration in Ingredient Mass Commems Company Fimt Name Last Name Email phone Number (CAB I%by mead. HF fluid 1% by the 11) mass'• Sea WNer coma Be. FIUM Webr ]]321. all., Dwass=85w 91E8 He l.— Blake Us. BeYvx U. eakw PO81OCmE 0 !U O0 Crw9lnker L. Sato, Iiebd BeFwr C NR CL31 hath'. GrLernIN¢ VstM Beed Ile1M BNw CPO68LINKER 0 fU LOSUFF-3hrD HNibunm Nmiorvc 6urracpM Mils— FN MO -8] Moslems PHCmt,l Pod'T.e Liaktl Helve dd Helm 0 NA OPTIFL0411 ECIIED mrs,mam &wFer L2ttd yet-, usear Below, PELEPSE 0 NA HPEPKEP SP SNEAKER Heilman, \newer tiaWBdsn' 14W Bebe 0 NA WG36 GELLING Xellibwwn C46p Agn1 Ilsbd Bebe Used InMm' AGENT o NA LVT.NA PbSRw LXW Bekw LhYa Babe 0 NA Yumywhi ]1rW Wytll noway Mortara L. Bebe Listed Belcw hekprdd 0 NA LW mandiumbeLiibEAbaa LISMPbaw 1.2.4 T—elobenaene 93$M1B 11 2Bmmo21.113-gowrmlid 5234] 100.009 0.001989 as w Can. heramenm'. Dmke.TLCX® Mryla. Polymer Pmge4ry r-1 p NHam XwAm PM E.. IbusYn, HLXoulm Wvra Tuck Ha4Wtmw i916]18]R T PO 2 284 6]16II8 A 'um ,am. M. 100.001 0.01al9\ M2 C—dons 13R -]LS 55.009 11.316131 prop ciyanxime sime amrs ta& 7 30.00% 0.00555t 138 teres Cie. aoyuc resin PrcpXeby 30. 1.00Si6a 139 HetlbKn B er arim WM. Tuck 4W.pt-0]I-0i28 in Ethanal is,", 011035 was Guargum 91U3Oe M14 Hw 4olcmars. 60]42A05 1% HdroowtMDe(um ae, Was L416 60]424]3 ffiI Mullet i... 22WA 8120] Washmene: -... Se Dwbs.TleF® OglxM nh m iF rests PmFMbry pltlbMon Dxhm To P, xNRu2n.w 'm1d]1E2ID Pdytoayfzrewradry0. alPma.I4 nomyloronyr—ass-nybmy-, m0B] . 1.11,,. 9a vedrd, olessum loran. sao-z9a6 Ix] P.bssan ,—we 131058-3 5.009 53 Pmeau. rnebMrXe 13] 365 623 SSdurs urban axes Icellulcse 9004324 p 6xfurathbride .1145 7.1 sedum ".. 2a34321 D sodium h owd. 1313-782 an Eatiwnouss. asp -1 11 6M wlleY ]]51d2a 1 ulWe. caltire] Si9N333 138] wtlx P92n use 35Bi •Total year Volume sources may names Wish water, produced water, and orrcyded water _ Intormaeom is based on the maximum marl el for cdnpnOatwn and thus Me WWI may be ower 100% Nam For FI¢N contentment Produce (rouses that begin Win FOP), si lerel only hermNbn has been prwlded All comp hers information listed was obtained ham the suppliers Maleral Safely Data Boom IMHO6). As soon Me Operator is net respwsibk forionswaste order incomplete i mlmmalon. My quessons rryaNing se content of the MSO. should beMost to the supplier who prandM t The Occupational Sally and XmNh Adminimatimis (0.511A) regulations gmrem the comma for se disclosure Orris Ime ordson. Meme note that Federal Lax proleds'pmpre ar'f. %ode sxrer. and'emadenlal business intorma isor and theanexam for how this information is method on an MINES is suEed to l9 CFR 1910 120010 and A erAh D. c,b6w/ 4/7/'^ 2017 SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. CRU CD3 -111A (PTD No. 217-004; Sundry No. 317-138) Paragraph Sub -Paragraph I Section Complete? (a) Application for (a)(1) Affidavit Sundry Approval (a)(2) Plat — (o)(2)(A) Well location (a)(2)(B) Each water well within X mile (o)(2)(C) Identify all well types within X mile (a)(3) Freshwater aquifers: geological name (a)(3) Freshwater aquifers: measured and true vertical depth (a)(4) Baseline water sampling plan (a)(5) Casing and cementing information (a)(6) Casing and cementing operation assessment (a)(6)(A) Casing cemented below lowermost freshwater aquifer and _ conforms to 20 AAC 25.030 (a)(6)( 8) Each hydrocarbon zone is isolated (a)(7) Pressure test: information and pressure -test plans for casing and tubing installed in well Dated 1/13/2017. Provided with application. On 1/13/2017, operator sent Notice of Operations (Notice) to all owners, landowners, surface owners, and operators PKB within one-half mile radius of proposed well trajectory. Provided as Exhibit 1 within application PKB Legal description of well, (surface, target and bottomhole locations) provided in Notice dated 1/13/2017. PKB None per DNR Water Estate Map (1/23/17) PKB 22 wells within % miles radius of CRU CD5-18 wellbore trajectory. Wells identified, as wells as well type and well PKB status. No freshwater aquifers or underground sources of drinking water within a %: mile radius of proposed wellbore trajectory. (See Conclusion number 3 of the Area Injection PKB Order AIO 018.000 -Colville River Field.) NA PKB NA PKB provided VTL provided VTL Per AID 018.000 and current AID 018C, no freshwater PKB aquifers present. Cementing records provided. VTL Plan to test tubing to 4100 psi on rig and casing to 3000 psi. Plan to retest casing to 3000 psi and 5260 psi tubing prior CDW to frac. AOGCC Page 1 April 10, 2017 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. CRU CD3 -111A (PTD No. 217-004; Sundry No. 317-138) Paragraph Sub -Paragraph Section Complete? (a)(8) Pressure ratings and schematics: IA 7240 psi, tubing 10,160 psi, surface piping 10,000 psi, wellbore, wellhead, BOPE, treating head tree saver 15,000 psi. CDW (A) Fracturing and confining zones: Fracturing zone will be the Alpine A sandstone. It is — 30" ithol lithologic description for each zone thick, true vertical thickness. Upper confining zones are the Miluveach, Kalubik and HRZ shales, 400+ feet thick. PKB (aJ(9)(B) Geological name of each zone The lower confining zone consists of approximately 1,800' of Kingak shales. (a)(9)(C) and (a)(9)(D) Measured and true Top Alpine A is at 15,217' MD (7,017' TVDss). vertical depths Top HRZ is at 12,786' MD (6,940' TVDss). PKB Kingak shale not penetrated by CD5-99A. Alpine A est. fracture gradient is 12.5 ppg. (a)(9)(E) Fracture pressure for each zone Miluveach est. fracture gradient is 15 ppg and Kalubik/HRZ PKB fracture gradient is 16 g ppg. Kingak est. fracture gradient is 15-18 ppg. (a)(10) Location, orientation, report on mechanical condition of each well provided CDW (a)(11) Sufficient information to determine wells will not interfere with containment Provided CDW within/: mile Operator identified three northwest trending faults that transect the Alpine A formation or may enter the confining ) Faults and fractures, Location, zone within''/: mile radius of the CD5-18 wellbore orientation orient trajectory. Faults range in throw from 3 to 29 feet. Any faults that are within the half mile radius of the wellbore J Faults and fractures, Sufficientmation do not extend up through the confining interval and PKB nfor information to determine no interference fracture gradients within the top seal intervals would not with containment within''/: mile be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Principal stress direction in the Alpine A formation, along with the well path, is northwest -southeast. All of the AOGCC Page 2 April 10, 2017 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. CRU CD3 -111A (PTD No. 217-004; Sundry No. 317-138) Paragraph Sub -Paragraph Section complete? fractures will be longitudinal, running parallel to the wellbore. Because of this, the fractures will only intersect faults that intersect the wellbore. AOGCC Page 3 April 10, 2017 Mitigation: If there are indications that a fracture has intersected a fault during fracturing operations, the operator would flush and terminate the stage immediately. (a)(12) Proposed program for fracturing operation Provided CDW — _ (a)(12)(A) Estimated volume 500K Ib prop, 5351 bbl clean vol, 5865 bbl slurry - detailed CDW a 12 8 ( )( )( ) Additives: names, purposes, detailed --- CDW concentrations _ (a)(12)(C) Chemical name and CAS number Confidential chemical CAS provided or previously provided _ of each and on file with AOGCC. CDW (a)(12)(D) Inert substances, weight or volume of each detailed CDW (a)(12)(E) Maximum treating pressure with supporting info to determine Max 7500 psi, 20 bpm. CDW appropriateness for program (a)(12)(F) Fractures —height length, MD and TVD to top, description of fracturing Table provided. 5 intervals CDW model (o)(13) Proposed program for post- Class I disposal well plan CD1-01A. CDW fracturing well cleanup and fluid recovery (b)Testing of casing Plan to retest to 3000 psi casing prior to frac. Email or intermediate Tested >110% of max anticipated pressure clarifies max IA during frac stated as 2720 psi. PRV set as CDW casing 2850 psi (cJ Fracturing string (c)(1) Packer >I00' below TOC of Outlined in provided table VTL production or intermediate casing AOGCC Page 3 April 10, 2017 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. CRU CD3 -111A (PTD No. 217-004; Sundry No. 317-138) Paragraph Sub -Paragraph I Section Complete? (c)(2) Tested >110% of max anticipated pressure differential (d) Pressure relief Line pressure <= test pressure, remotely valve controlled shut-in device (e) Confinement Frac fluids confined to approved formations (f) Surface casing Monitored with gauge and pressure relief pressures device (g) Annulus pressure monitoring & 500 psi criteria notification (h) Sundry Report (i) Reporting (j) Post frac water sampling plan (k) Confidential (I) Variances (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (i)(I) FrocFocus Reporting (i)(2) C -C Reporting: printed & electronic Clearly marked and specific facts supporting nondisclosure Modifications of deadlines, requests for variances or waivers Plan to test surface to 9000 psi. Plan to test tubing to 5260 psi. Maximum differential pressure is 4780 psi (7500 psi CDW string with 2720 IA backpressure). Surface line tested to 9000 psi. 8588 psi pump trip, nitrogen PRV set as 8788 psi. IA PRV set at 2850 psi. Max CDW treating pressure estimated 7500 psi. CDW CDW AOGCC Page 4 April 10, 2017 Loepp, Victoria T (DOA) From: Sylte, Hanna<Hanna.Sylte@conocophillips.com> Sent: Monday, April 10, 2017 3:19 PM To: Loepp, Victoria T (DOA); Wallace, Chris D (DOA) Subject: CD3 -111A (PTD# 217-004) Frac Sundry Application Update Follow Up Flag: Follow up Flag Status: Flagged Victoria and Chris, We have decided not to pressure test C133 -111A (PTD# 217-004) to the full 5260 psi as stated in the frac sundry application in the interest of saving time and will instead be pressure testing the tubing to 5000 psi. Pressure testing to the full 5250 psi would require two extra days to rig up and rig down the tree saver, and we need to be off of CD3 before the ice road goes out so are trying to save time where possible. We are hoping to frac this well as early as Wednesday, will this work for you? I know this is requesting a quick response but we are time limited due to the ice road so would greatly appreciate it if you would be able to accommodate this request. Please let me know if you have any questions or concerns about this change in the tubing pressure test or the sundry application. AOGCC Required Pressures [all in psi] Originally Submitted Updated Maximum Predicted Treating Pressure (MPTP) 7,500 7,275 Annulus pressure during frac 2,720 2,720 Annulus PRV setpoint during frac 2,850 2,850 7" Annulus pressure test 3,000 3,000 3 1/2" Tubing pressure Test 5,260 5,000 Nitrogen PRV 8,788 8,000 Highest pump trip 8,588 7,500 Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office: (907) 265-6342 Mobile: (713) 449-2197 p7-0 72-o�4 Loepp, Victoria T (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Saturday, April 01, 2017 5:25 PM To: Loepp, Victoria T (DOA) Subject: RE: CD3 -111 (PTD# 217-004) Packer Depth Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for the quick response, I will be sure to include this with the PTD. Have a good weekend, Hanna From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Saturday, April 01, 2017 4:45 PM To: Sylte, Hanna<Hanna.Sylte@conocophillips.com> Subject: [EXTERNAL]Re: CD3 -111 (PTD# 217-004) Packer Depth Hanna, The packer depth change as outlined below is approved. Please include this approval with the approved PTD. Thanx, Victoria Sent from my iPhone On Apr 1, 2017, at 3:10 PM, Sylte, Hanna<Hanna.Sylte@conocophillips.com> wrote: Victoria, I have attached the original and updated schematics. Please let me know if you have any questions or would like more information. Thank you, Hanna From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.gov] Sent: Saturday, April 01, 2017 2:39 PM To: Sylte, Hanna <Hanna.5vlte@conocophillips.com> Subject: [EXTERNAL]Re: CD3 -111 (PTD# 217-004) Packer Depth Do you have the original WBS and the new WBS? Sent from my iPhone On Apr 1, 2017, at 9:32 AM, Sylte, Hanna<Hanna.Svlte@conocophillios.com> wrote: Victoria, On CD3-111(PTD# 217-004) we are planning to change the packer depths from what was submitted in the permit to drill. The new production packer depth will be at 8,060' MD and the liner top packer will be at 8,120' MD. This should still meet all AOGCC requirements for a producer that we are planning to hydraulically fracture, pending the sonic log will verify the planned top of cement >100' above the production packer depth. Please let me know if you have any questions or concerns with this change, we are planning to run the lower completion around midnight tonight. I apologize for the last minute notice, we decided to call TO early and are running the liner a few days earlier than planned. Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office: (907) 265-6342 Mobile: (713) 449-2197 <CD3 -111 Re -drill Schematic - Updated 4_1.pdf> <CD3 -111 Re -drill Schematic.pdf> CD3 -111 Nechelik Producer Proposed Schematic updated 3/2417 by H. 2(Y'94# H-40 Welded Conductor to 110' TRMAXX SSSV 2 130' MD H 3'7x'8 8EUE Tubing PTS Downhole Gauge 7,986' MD Upper Completion: Length 10-3/4" XO to 3-'/" EUE tubing Hyd 5631B63BTC 2) Shallow nipple profile with SSSV Surface Casing 7' 4) 3-%" x 1" Camco KBMG GLM (xx°) w/ DV 2.721' MD / 2.2.469' ND I I 7' cemented to surface H 3'7x'8 8EUE Tubing PTS Downhole Gauge 7,986' MD Upper Completion: Length 1) 4-'/" 12.6#/ft TXP Tubing (2 its) XO to 3-'/" EUE tubing 2) Shallow nipple profile with SSSV 3) 3-%"x 1" Camco KBMG GLM (xx') w/ DV 7' 4) 3-%" x 1" Camco KBMG GLM (xx°) w/ DV 7' 4) 3-%" x 1" Camco KBMG GLM (xx°) w/DCK2 7' pinned for 2500 psi casing to tbg shear 5) PTS Downhole Gauge, Encapsulated I -Wire 1.5' w/cannon damps on every joint 6) Baker Premier Packer 7) XN nipple 2.812" ID 1.5' 8) WLEG 1.5' Lower Completion: 9) Flexlock Liner Hanger 37' XO 5" Hydril 521 Box X 4-/" IBTM pin 10) 4 MV, 12.6#/ft, L-80 TXP Liner w/ ball actuated frac ports every 700' and Saltel open hole frac packers 11) WN & Alpha Sleeve @ toe Baker Premier Production Packer 8,300MD .:.:...:.:..:..:::.. I O O 101 1 o O O O O o 101 1 O ®k1l, _____ ___t____—_______- SaRel Open Hde Frac Packers 6 1/2" Hole TD 17,470' MD 7" 29.7# L-80 BTCM Intermediate Casing 4-%" 12.6# L-80 TXP 8,466' MD Production Liner with Frac Sleeves 8.350' - 17 450' M D CD3 -111 Nechelik Producer Proposed Schematic updated 4/1/2017 2(Y'94# H-40 Welded Conductor to 11(Y TRMAXX SSSV 2.130' MD 10-3/4" 45.5# L-80 Hyd 563/BTC Surface Casing 2,721' MD / 2.2.469' ND cemented to surface 3-1/2" 9.6# L-80 EUE Tubing 8 350' MD PTS Downhole Gauge 7 986' MD Baker Premier Production Packer 8,062' MD 7" 29.7# L-80 BTCM Intermediate Casing 8.466' MD Upper Completion: Length 1) 4-'/V 12.6#/ftTXP Tubing (2jts) XO to 3-'/" EUE tubing 2) Shallow nipple profile with SSSV 3) 3-'/" x 1" Camco KBMG GLM (xx°) w/ DV 7' 4) 3-'/=" x 1" Camco KBMG GLM (xx°) w/ DV 7' 4) 3-'/2" x 1" Camco KBMG GLM (xx°) w/DCK2 7' pinned for 2500 psi casing to tbg shear 5) PTS Downhole Gauge, Encapsulated I -Wire 1.5' w/cannon clamps on every joint 6) Baker Premier Packer 7) XN nipple 2.812" ID 1.5' 8) WLEG 1.5' Lower Completion: 9) Flexlock Liner Hanger 37' XO 5" Hydril 521 Box X 4-'/" IBTM pin 10) 4'/", 12.6#/ft, L-80 TXP Liner w/ ball actuated frac ports every 700' and Saltel open hole frac packers 11) WIV & Alpha Sleeve @ toe 6 1/2" Hole TD 11.644' MD I 00 0 0 I Saltel Open Hole Frac Packers VA" 12.6# L-80 TXP Production Liner with Frac Sleeves 8,129'-11,690'Nf ' J-,) 7-D a!-7 —o e, L Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, March 14, 2017 10:42 AM To: Njoku, Johnson Cc: Kanady, Randall B (Randall.B.Kanady@conocophillips.com) Subject: RE: Waiver Request not to Run Resistivity Logs on C133 -111A Johnson, This waiver is granted as written. Thanx, Victoria From: Njoku, Johnson[mailto:Johnson.Njoku@conocophillips.com] Sent: Monday, March 13, 2017 11:28 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Quick, Michael J (DOA) <michael.quick@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwa rtz@alaska.gov>; Black, Randy C <Randy.C.Black@conocophillips.com>; Hayden, Philip <Philip.Hayden@conocophillips.com> Subject: Waiver Request not to Run Resistivity Logs on CD3 -111A Victoria, Doyon 19 is currently rigged up on CD3 -111 to perform a side track of the intermediate section and the production hole. This will involve cutting and pulling the existing 7" intermediate casing and re -drilling the intermediate and production holes. When the original well (CD3 -111) was drilled both GR and Resistivity was acquired as shown in the attached file. The file also shows that the current well (CD3 -111A) is mostly less than 250ft from the original wellbore (see between center distance) in the intermediate hole section. Because the intermediate section is in such close proximity to the original wellbore, running a Resistivity log in the new intermediate section will provide very similar results from the original intermediate section. Therefore CPA would like to propose for the intermediate hole on CD3 -111A, to only run a GR to correlate the existing logs on the original well. CPA is requesting a waiver not to run the resistivity log in the intermediate hole. We will run both GR and resistivity in the lateral hole. I am available to discuss this information with AOGCC. Let me know if you have any questions or concerns. Best regards, Johnson Njoku Engineering Supervisor- Drilling +907 317 1529 'The Success of E very MIT Opportunity is Important, but what is most Important is the boldness to pursue the Opportunity and the Honest Optimism for Success'- JCN CD5 - 20 Alpine A/C Dual Lateral Producer Schematic with Exact Depths - 3/8/2017 TNT Production R at 11,283 MD CMU Sliding sleeve Selectivity 11,309- IVID 3-1/2"x 1" GLM 11.196' MD C sand Lateral 6 3/4" Hoe TD 11,979'- 22,523' MD -------------------------------------------- 4-''12.6#L-80/2TXP Liner w/ perf pups 0 0 0 0 0 0 0 01b __________________________________________I TNT Production Packer at 3-1/2" 9.3# TN I I OSS 12,063'MD --- -------------------------------- 4-%"12.6#L-80 TXP Liner w/ frac Dorts A sand Lateral ZXP liner top packer (whipstock 6 3/4" Hole TD base) at 12,119' MD 12,303'- 24,119' MD 2(Y'94# H-40 Welded Upper Completion: Conductorto 115' MD 1) 3-1/2" 9.3#tft eue8rd 2) Shallow nipple profile 2.812" ID 3) 3-1/2"x 1" Carnro KBMG GLM (xx') w/DCK2 pinned for 2500 psi casing to tbg shear 4) TNT Packer 5) X Nipple profile, 2.813" 6) TNT Packer 7) XN Nipple profile, 2.813" 10-3/4" 45.5# L-80 HYD 563 x Lower Completion: BTC 8) Plop and drop liner in G sand Surface Casing at 2.357' MD - no junction -4.5" 12.6# L-80 w/ perf pups 9) ZXP liner top packer & Flexiock Liner Hanger 3-Y." x V GLM XO YHydril 521 Box X 4-1/." lBTM pin 5 078' M D -4.5" TXP 12.60 L-80 w/ Frac Ports 3-1/2" 9.3# L-80 eue8rd 3-%"x 1" GLM 9,086' MD 7 5/8" 29.7# L-80 Flyd 563 x BTC Intermediate Casing at 12,290' MD TNT Production R at 11,283 MD CMU Sliding sleeve Selectivity 11,309- IVID 3-1/2"x 1" GLM 11.196' MD C sand Lateral 6 3/4" Hoe TD 11,979'- 22,523' MD -------------------------------------------- 4-''12.6#L-80/2TXP Liner w/ perf pups 0 0 0 0 0 0 0 01b __________________________________________I TNT Production Packer at 3-1/2" 9.3# TN I I OSS 12,063'MD --- -------------------------------- 4-%"12.6#L-80 TXP Liner w/ frac Dorts A sand Lateral ZXP liner top packer (whipstock 6 3/4" Hole TD base) at 12,119' MD 12,303'- 24,119' MD THE STATE 0fALASKA GOVERNOR BILL WALKER Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Colville River Field, Fiord Oil Pool, CRU CD3 -111A ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-004 Surface Location: 3946' FNL, 874' FEL, Sec. 5, T12N, R5E, UM Bottomhole Location: 3520' FNL, 99' FEL, Sec. 25, TUN, R4E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc,alaska.gov Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy A Foerster Chair DATED this _ day of March, 2017. STATE OF ALASKA 4 A OIL AND GAS CONSERVATION COMA ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED JAN 17 2017 AQQQQ 1a. Type of Work: Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral ❑ 11b. Stratigraphic Test ❑ Development - Oil ❑✓ • Service - Winj ❑ Single Zone ❑7 - Coalbed Gas ❑ Gas Hydrates ❑ edrill ❑D - Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑� Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. - Bond No. 59-52-180 • CRU CD3 -111A ' 3. Address: 6. Proposed De s$ 6�9 11�4a. 12. Field/Pool(s): 10 P.O. Box 100360 Anchorage, AK 99510-0360 MD: TVD: 7 90 Colville I��IvIeLr Unit] Fiord Ne eft Pool Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 3946' FNL, 874' FEL, Sec. 5, T12N, RBE, UM 4 ADL 372105,364471,364470 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 266' FNL, 2733' FEL, Sec. 5, T12N, R5E, UM LAS21122 2/15/2017 Total Depth: 9. Acres in Propertv: N! 14. Distance to Nearest Properly: 3520' FNL, 99' FEL, Sec, 25, T13N, R4E, UM 311X I/, 3 (' -3890'to CRU boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 49.2 ' 15. Distance to Nearest Well Open Surface: x- 388169 y- 6003828.9' Zone- 4 • GL Elevation above MSL (ft): 12.9 • to Same Pool: CD3 -110 2,067' 16. Deviated wells: Kickoff depth;2 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees . Downhole: 4,150- Surface: 3,461- 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 42" 16" 62.5 H-40 Welded 77 36 36 114 114 Portland Cement 12.25" 9.625" 40 L-80 BTC -M 2685 36 36 2,721 2,469 Cemented 410 sacks 10.7ppg leadslurry+ 230 sacks 15.8ppg tail sl (r357j: 8.75" 7" 26 L-80 H-563/BTC 8431 36 36 8,467 6,9391 st stage: 5.8 ppg G 2ndstage:l ppg 6.125" 4-1/2" 12.6 L-80 TXP 9037 8,454 6,889 17,491 6,889 Uncem nted liner w/ frac ports VI 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 16,645 6,855 16,645 6,855 Casing Length Size Cement Volume MD TVD Conductor/Structural 114.00 16 Pre-installed 114 114 Surface 2,685.00 9.625 410 sacks 10.7ppg lead+230 sacks 2,721 2,469 15.8ppg tail Intermediate 8,624.00 7 39.2 bbls 15.8 ppg slurry 8,660 6,932 Production Liner 8,123.00 1 3.51 Production tubing 8,1591 6,788 Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑' Time V. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ AAC 25.050 requirements❑✓ ,,qq20 21. Verbal Approval: Commission Representative: Data LIJe G ez'% 1/8/2017 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Weffeng 263-4324 be deviated from without prior written approval. Contact weifena. dai(cDcop. com Email Printed Name Chip Alvord Title Drilling Manager Signature DCo Phone 265-6120 Date J -13-2w Commission Use Only permit to Drill API Number: r^t Permit Approval See cover letter for other Number: p� - �Q r 50- 1 O3- K� O "�� Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed ritethine, gas hydrates, or gas contained in shales: Other: Boa fie st prrss vrr 3 Samples req'd: Yes ❑ No( Mud log req'd: Yes No r/ �/ HzS measures: Yes No L❑CJ Directional Yes Ll -r y h'i 11 7 q f" p re -V L /'% t ✓ 5 ,_,( svy req'd: No L❑ rr5 g v✓r 4-0Z �U D p ! Spacing exception req'd: Yes No E Inclination -only svy req'd: Yes El No Post initial injection MIT req'd: Yes F-1 No L"J APPROVED BY 2, Approved omrar�J r v a e:SytlmM1 �� lay IAI i ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 Jan 81". 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Re -Drill CD3 -111A Dear Commissioner: lo,I ConocoPhillips ConocoPhillips Alaska Inc. hereby applies for a permit to sidetrack the CD3 -111A Alpine slant injector from the CD3 pad. This original CD3 -111 well was drilled and completed in 2006 as a bare foot producer, the well was suspected a downhole formation collapse lately. The purpose of the well is substitute the original lateral and capture the remaining resource in the pool. The schedule spud day for this well is around 15th of February, 2017 by rig Doyon 19. Prior to Doyon 19 rig move to CD3 -111A, pre -rig work includes spot P&A cement plug and cut existing tubing below surface casing. After rig Doyon 19 move onto the well, the proposed plan is to retrieve existing 3-1/2" tubing string, run and set CIBP in the 7" casing, then cut and pull 7" casing at +/- 2,700'. A 17.Oppg kick off cement plug will be spotted subsequently. Then sidetrack 8.75" intermediate section to section TD @ +/-8,467' IND, case the hole with 7" 1-80 26# casing and cement same. Drill 6-1/8" production to TD @ +/-17,490' MD, run 4-1/2" liner with frac ports, followed by 3-1/2" upper completion string. The sidetrack will be fracture stimulated after rig move off the well. Please find attached the information required by 20 AAC 25.005 (a) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Weifeng Dai at 263- 4324 or Chip Alvord at 265-6120. Sincerely, Weifeng Dai Drilling Engineer CD3 -111A Nechelik Producer Proposed Schematic 16" 84# J55 Welded Conductor to 114' 95/8" 40# L-80 BTC Surface Casing 2.721' MD / 2-469' ND cemented to surface Stage Top of Cement - 4 000' M D 3'/z" 9.6# L-80 EUE Tubing 1" Stage Top of Cement - 7.467' MD Upper Completion: Length 1)4-1/2" 12.6#/fl TXP Tubing (2 jts) XO to 3-'/" EUE tubing 2) Shallow nipple profile 3) 3-1/2" x 1" Camco KBMG GLM (xx) w/ DV 7- 4)3-1/2" ' 4)3'/" x 1" Camco KBMG GLM (xx") w/ DV 7- 4)3-1/2" ' 4)3'/" x 1" Camco KBMG GLM (xx°) w/DCK2 7' pinned for 2500 psi casing to tbg shear 5) SLB BHP Gauge, Encapsulated I -Wire 1.5' w/cannon clamps on every joint 6) Baker Premier Packer 7) X nipple 2.812" ID 1.5' 8) WLEG 1.5' Lower Completion: 9) Flexlock Liner Hanger 37' XO 5" Hydril 521 Box X 4-'/z" IBTM pin 10) 41/", 12.6#/ft, L-80 TXP Liner w/ ball actuated frac ports every 750' 11) Perforated pup @ toe 3-34" x 7" Baker Premier Production Packer 8,300' MD EMIR 7" 26# L-80 HYD5631BTCM Intermediate Casing -8,467' MD 4-%" 12.6# L-80 TXP Production Liner 15.100' MD 61/8` Hole TD -17,471' MD Applic ..,m for Permit to Drill, Well CD3 -111A 14 -Feb -17 CD3 -111A Application for Permit to Drill Document f�, Oen r _ � CawcoPhiOips tjA Table of Contents 1. Well Name (Requirements of 20 AAC 25.005(1))............................................................3 2. Location Summary (Requirementsof20AAC25.005(c)(2))............................................3 Requirementsof 20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(0(3)).3 4. Drilling Hazards Information (Requirements of20AAC25.005©(4))..........................3 ASP CALCULATIONS for 9-518" and 7" Casing..............................................................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5))...........................................................................................................................4 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(0(6)) ....................4 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ..........................5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) ....................................5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ..........................................6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) .........................6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ...................................6 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) .........................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................7 (Requirements of 20 AAC 25.005 (c)(14)).............................................................................7 CD3 -111A APD Page I of 11 14 -Feb -17 Applic,....,n for Permit to Drill, Well CD3 -111A 14 -Feb -17 15. Attachments................................................................................................................7 AttachmentI Directional Plan...................................................................................................................7 Attachment 2 Drilling Hazards Summary....................................................................................................7 Attachment 3 Proposed Well Schematic.......................................................................................................7 Attachment4 Cement program....................................................................................................................7 CD3 -111A APD Page 2 of 11 14 -Feb -17 Apph.._ .on for Permit to Drill, Well CD3 -111A 14 -Feb -17 1. Well Name (Requirements of20 AAC 25.005 (n) The well for which this application is submitted will be designated as CD3 -111A. 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 3946 FNL 874 FEL Sec 5 T12N R5E NAD 1927 Northings: 6,003,829 Eastings: 388,169 RKB Elevation 49.2' AMSL Pad Elevation I 12.9'AMSL Location at Top of Productive Horizon 266 FNL 2733 FEL Sec 5 T12N R5E Nad 1927 Northings: 6,007,536 Eastings: 386,355 Measured De th, RKB: 8,660' Total Vertical De th, RKB: 6,932' Total Vertical De t,% SS 1 6,883' Location at Total Depth 3520 FNL 99 FEL Sec 25 TI 3N R4E Nad 1927 Northings: 6,014,923 Eastings: 381,188 Measured Depth, RKB.• 17,470' Total Vertical Depth, RKB: 6,894' Total Vertical De t,% SS: 6,845' Requirements of 20 AAC 25.050(6) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.0050(3)) Please reference BOP schematics on file for Doyon 19. 4. Drilling Hazards Information (Requirements of2OAAC25.005(0(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD(ft) Fracture Gradient (lbs. / al(psi) Pore pressure (psi) ASP Drilling 16 114/114 10.9 N/A N/A 95/8 2,721 / 2,469 17.4 1,043 7 8,467 / 6,939 12.5 3,370 1,987 4.5 1 17,491/6,889 1 12.5 4,150 1 3,461 • NOTE: The Doyon 19 5000 psi BOP a g�� 1 Yj y p equipment is adequate. Test BOP lams to 3,5 psi and annular to 2,500psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP=[(FGx0.052)—O.11D CD3 -111A APD Page 3 of 11 14 -Feb -17 Applic_ ..,n for Permit to Drill, Well CD3 -111A 14 -Feb -17 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib. /gal to psi/ft 0.1 =Gas gradient in psi/ft D = True Vertical Depth of casing seat in ft RKB OR 2) ASP=FPP—(O.1xD) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS for 9-5/8" and 7' Casing (C) Drilling below surface casing (9-5/8") ASP = [(FG x 0.052) — 0.1] D _ [(17.4 x 0.052) — 0.1 ] x 2,469 = 1,987 psi OR ASP = FPP — (0.1 x D) =3,370 — (0.1 x 6,932') = 2,677 psi (C) Drilling below intermediate casing (7") ASP = [(FG x 0.052) — 0.11 D _ [(12.5 x 0.052) —0.1] x 6,939 = 3,816psi OR ASP = FPP — (0.1 x D) —4,150—(0.1 x6,889')=3,461 psi (B) data on potential gas zones, The well bore is not expected to penetrate any gas zones. © data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking, Please see Attachment 2 — Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 ©(5)) 1. The LOT below the existing surface casing shoe was conducted to reach 17.4ppg EMW in the original wellbore back in 2006, the well hasn't been used as annular injection well and the formation integrity around surface casing shoe can be reasonably assumed stays the same. 2. Drill out 7" casing shoe track and continue drill 20' new formation, circulate hole clean and ensure mud weight in and out equal, then perform FIT to 12.5 ppg equivalent mud weight. 6. Casing and Cementing Program (Requirements of20AAC25.005©(6)) CD3 -11 fA APD Page 4 of 11 14 -Feb -17 Appll�_,on for Permit to Drill, Well CD3 -111A 14 -Feb -17 Casing and Cementio Program Csg/rbg Hole Size Weigh Grade Conn. Length Top MDITVD Btm MDITVD Cement Program OD (in) Density t (1bl t) 9.6-11.0 10.0-11.0 (R) (R) (Rl 10 16 24 62.5 H40 Welded 77 Surf 114/114 Pre-set Ib./100 ftz <20 8 API Fluid Loss cc/30 min. <10 <10 HPHT Fluid Loss Cemented on 12/29/2006. <10 <10 pH 9.5-10.0 9.0-9.5 276bbls 10.7ppg ASL lead slurry and 9-5/8 12-1/4 40 L-80 OTC -M 2,685 Surf 2,721 / 2,469 49bbls Class G 15.8ppg tail slurry. Full return with 160bbls 10.7ppg cement return to surface. 2 stage cement. 8-3/4 x H- Primary stage:363 sx 15.8ppg Class G 7 9-7/8 26 L-80 563/BT 8,624 Surf 8,467 / 6,939 slurry. C -M 2n° stage: 168 sx 13.Sppg Class G slurry. 41/2 6-1/8 12.6 L-80 TXP 8,454 8,460/ 17,491 / 6,889 Solid 4-1/2" liner with frac ports, no 6,900 cement job. 7. Diverter System Information (Requirements of20AAC25.005(c)(7)) N/A — Application will not include diverter system in the well operation. 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to --11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (Flo-thro) weighted to 10.0 ppg with calcium carbonate and KCL, coupled with MPD system during drilling to ensure overbalance, the well will be displaced to KWF at TD based on pore pressure finger print result. CD3-111AAPD Page 5 of 11 14 -Feb -17 Intermediate Production Hole Size in. 8.75 x 9.875 6.125 Casing Size in. 7 4.5 Density PPG 9.6-11.0 10.0-11.0 PV cP ALAP 10 YP Ib./100 ftz 20-26 10- 15 Initial Gels Ib./100 ftz 8-15 6 10 Minute Gels Ib./100 ftz <20 8 API Fluid Loss cc/30 min. <10 <10 HPHT Fluid Loss cc/30 min. <10 <10 pH 9.5-10.0 9.0-9.5 Intermediate #1: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to --11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (Flo-thro) weighted to 10.0 ppg with calcium carbonate and KCL, coupled with MPD system during drilling to ensure overbalance, the well will be displaced to KWF at TD based on pore pressure finger print result. CD3-111AAPD Page 5 of 11 14 -Feb -17 Applic.....m for Permit to Drill, Well CD3 -111A 14 -Feb -17 Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information(Requirements of20AAC25.005(c)(9)) The well bore is not expected to penetrate any abnormally pressured formation 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 of20 AAC 25.005 (c)(1/)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20AAC25.005 (e)(/2)) Evidence of bonding for Conoco Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of20AAC25.005(x)(/3)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. Ria Work Plan (Follow CD3 -111A Sunday Permit Operation) 1. Run in hole with RSS BHA to kick off, drill 8-3/4" x 9-7/8" intermediate section to top of HRZ with 9.6ppg LSND mud. 2. Wait up mud to 10.3ppg and continue drill intermediate section to TD @ -8,660' MD. 3. Circulate hole clean, weight up mud to 10.8ppg, trip out drilling BHA. 4. Swap BOP upper VBR to 7" casing ram and test to,�.apsi. 3 50'0 p 5- ca� 5. Run 7", 26#, L-80 casing to bottom and cement same. u� 6. RIH 6-1/8" BHA, test rasing to 3,500 psi for 30 minutes. � ° � c r � ' �- it 7. Drill out shoe track and 20' rat hole, perform FIT to 12.5ppg EMW. C C"r, t hr z Vu 8. Drill 6-1/8" hole to well TD +1-17,470' MD with MPD and 10.Oppg Flow-thru WBM, geo-steering in sand. 9. Circulate hole clean and pull out of hole BHA. 10. Run 4-1/2" solid liner with frac ports, set liner hanger and LH top packer. 11. Run 3-1/2", 12.6 ppf, L-80 IBT-M TD upper completion string, displace well to inhibited brine. 12. Drop the Ball & Rod assembly, pressure test tubing and annulus to 3,500 psi respectively. 13. Pressure test hanger seals to 5,000 psi, Install 2 way check and test from direction of flow to 3,500 psi. Nipple down BOP. 14. Install tubing head adapter assembly and tree. Pressure test adapter assembly and tree to 5,000 psi. CD3 -111A APD Page 6 of 11 14 -Feb -17 Applic.....o for Permit to Drill, Well CD3 -111A 14 -Feb -17 15. Remove 2 way check valve. 16. Freeze protection in tubing & IA. 17. Install BPV, secure well. 18. Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) A majority of the fluid needs will be supported by the M-1 SWACO mud plant in Alpine mixing plant. All the drilling fluid waste will be disposed into the class I disposal well at CD1-01A(Class I & II approved). Back up plan is to truck all the drilling fluid waste to Kuparuk class I disposal well if CD1-01A well is down. 15. Attachments Attachment I Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment Cement program CD3 -111A APD Page 7 of 11 14 -Feb -17 Applic ..,n for Permit to Drill, Well CD3 -111A 14 -Feb -17 Attachment 1— Directional Plan CD3 -111 A APD Page 8 o111 14 -Feb -17 Loepp, Victoria T (DOA) From: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Sent: Thursday, February 23, 2017 11:25 AM To: Loepp, Victoria T (DOA) Subject: RE: CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight We have dedicated mud plant mixing mud supply at CD1 pad in Alpine, delivery time for kill -weight mud is within hours, shouldn't be a big concern. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, February 23, 2017 9:48 AM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]RE: CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight How far away are facilities that can mix kill -weight mud? What would the delivery time for kill -weight mud? From: Dai, Weifeng [mailto:Weifeng.Dai@conocophillips.com] Sent: Wednesday, February 22, 2017 4:22 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight Victoria, Good question, we will implement MPD in the lateral to monitor the connection pressure which can give us real pore pressure in the situation the mud weight is underbalanced, we will weight up mud if necessary based on the connection pressure. We hesitate to start with heavy mud then could easily incur severe losses with ECD when drilling which is what we have seen in the past. That's pretty much the reasoning behind it. Doyon 19 has been utilizing MPD in lateral drilling in the last 1-2 years with plenty of experience from the crew to handle this situation. Weifeng Office: (907)-263-4324 Cell Phone:(907)-342-9508 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, February 21, 2017 2:14 PM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight Weifeng, The maximum formation pressure encounter during drilling is 4150 psig which equates to an 11.6 ppg EMW. Planned mud weights during drilling are 9.6 to 11.0 ppg EMW. Should the mud weight be increased through this interval? What mitigation measures will be taken should the higher pore pressure be encountered? Applic..-.n for Permit to Drill, Well CD3 -111A 14 -Feb -17 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8-3/4" it 9-7/8" Hole Event Risk Level Mitigation Strate Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Iost circulation material Differential sticking Moderate Minimize drill string static time, mud property Hole swabbing on trips Moderate monitoring, control fluid loss. Optimize mud weight to control overbalance. Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent Abnormal Reservoir Low circulating density (ECD) monitoring, weighted Pressure sweeps. Abnormal Reservoir Low Well control drills, increased mud weight. No Pressure Low mapped faults occur in the planned wellbore. Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control radices, mud scavengers 6-1/8" Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7 shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density ECD monitoring,weighted sweeps. Abnormal Reservoir Low BOPE drills. Check for flow during connections Pressure and if needed, increase mud weight. Well control drills increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavenge Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. CD3 -111 Awp04 fails major risk analysis with the parent wellbore C133-111 while kick off below surface casing shoe, but will separate from original wellbore quickly and clear of anti -collision after that. The original CD3 -111 well will be P&A with cement plug prior to kick off. In general, no significant clearance issue exists with sidetrack well plan. Drilling Area Risks: Reservoir Pressure: The Alpine C sand is significantly depleted due to production from offset producers without sufficient support. The possibility that reservoir pressure higher than prediction is low, nevertheless the rig will be prepared to weight up if required. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. CD3 -111A APD Page 9 of 11 14 -Feb -17 Applica,..o for Permit to Drill, Well CD3 -111 A 14 -Feb -17 Attachment 3 — Proposed Well Schematic CD3 -111A Necheiik Producer 16' 84i JSS Yielded Conductor to 114' S W 40C LSM BTC Surface Casing 2.721' MD 12,45MTVO cercemed to surface of Cement MD 3-:4" 9.6P LSM EUE Tubing 1" Stage Tap of Cement \.e.-7.46TMD Upper Completion_ 1) 4-W 12 -MR TXP Tubing (2 its) XO to 3-54 EUE tubing 2) Shallow nipple proF@ 3) 3-14' x 1"Camco KBMG GLM (m') w/ DV 4) 3-W x 1" Camco KBMG GLM w1 DV 4) 3-14- x l' Campo KBMG GLM (xx°) %dDCK2 pinned for 2500 psi casing to tbg shear 5) SLB BHP Gauge, Encapsulated 1 -Wire wlcannon camps on every joint 0) Baker Premier Packer 7) X nipple 2.812" ID 8) WLEG Lower Completion: e) Ftexkxk Liner Hanger XO 5' Hydril 521 Box X 4-W IBTM pin 10) 4 W. 12.OY(L L-80 TXP Urter w/ ball actuated frac ports every 750' 1 1) Perforated pup @ we 3-1R° x r Maker premier Production Packer -8,300 MD 7- 26M L40 HYD5631BYCM Mbemredate Casing -846T MD V4- 12.60 LSU TXP Production Liner 15, 1W MD Attachment 4 — Cement Program 6 1 I HDle TD -17471' MD APD )f 11 b-17 Applin ,,on for Permit to Drill, Well CD3 -1I IA 15 -Feb -17 17# Kick Off Plug from 2,920' MD / 2,633' TVD to 2,520' MD/ 2,302' Cement from 2,920' MD to 2,520 with Class G + Adds. @ 17.0 PPG. Assume 150% excess annular volume in open hole and 0% excess in surface casing. Tail slurry from 2,920' MD to 2,633' MD with 15.8 ppg Class G + additives Open Hole (2,920'— 2,7211 X 0.4176 ft3/ft X 2.50 (150% excess) = 208 ft3 Cased Hole (2,721'- 2,5201 X 0.4257 ft3/ft X 1.0 (0% excess) =86W Total Volume = 208 + 86 = 294 ft' _> 294 sx of 17.0 ppg Class G + 0.2% D046 antifoamer, 1% D065 dispersant, 0.33% D167 Fluid Loss and 0.005 gal/sk Retarder @ 1 ft33/sk I" stage 7" Intermediate Casine run to 8,466' MD / 6,939' TVD, hole size is 9.875" Top of slurry is designed to be at 7,466' MD, which is 1,000' above the Nechelic. Assume 40% excess annular volume. Slurry from 8,466' MD to 7,466' MD with 15.8 ppg Class G + additives Annular Volume (8,466'- 7,4661 X 0.2646 ft3/ft X 1.40 (40% excess) = 371 ft3 Shoe Joint (80� X 0.0383 R3/ft X 1.0 (0% excess) = 18 ft3 Total Volume = 371 + 18 + 20 = 409 ft3 => 363 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% S002 accelerator @ 1.16 ft3/sk 2nd stage 7" Intermediate Casine, stage collar at 4,774' MD, hole size is 9.875" Top of slurry is designed to be at 4,053' MD, which is 500' above the Qannik. Assume 40% excess annular volume. Tail slurry from 4,774' MD to 4,053' MD with 13.5 ppg Class G + additives Annular Volume 1 (4,774'- 4,053') X 0.2646 ft3/ft X 1.40 (40% excess) = 268 ft3 Total Volume = 268 + 20 = 288 ft3 => 168 sx of 13.5 ppg Class G + 0.2% D046 antifoamer, 2% D079 extender and 0.4 gal/sk 0310 retarder @ 1.71 W/sk CD3 -111A APD Page 11 of 11 15 -Feb -17 Applic ..on for Permit to Drill, Well CD3 -111A 14 -Feb -17 17# Kick Off Plug from 2,920' MD / 2 633' TVD to 2520' MD/ 2302' Cement from 2,920' MD to 2,520 with Class G + Adds. @ 17.0 PPG. Assume 150% excess annular volume in open hole and 0% excess in surface casing. Tail slurry from 2,920' MD to 2,633' MD with 15.8 ppg Class G + additives Open Hole (2,920'— 2,721 X 0.4176 ft3/ft X 2.50 (150% excess) = 208 ft3 Cased Hole (2,721'— 2,520 X 0.4257 ft3/ft X 1.0 (0% excess) = 86 ft3 Total Volume = 208 + 86 = 294 ft3 => 294 sx of 17.0 ppg Class G + 0.2% D046 antifoamer, 1% D065 dispersant, 0.33% D167 Fluid Loss and 0.005 gal/sk Retarder @ 1 ft3/sk 1" stage 7" Intermediate Casing run to 8,466' MD / 6,939' TVD, hole size is 9.875" Top of slurry is designed to be at 7,466' MD, which is 1,000' above the Nechelic. Assume 40% excess annular volume. 1 Slurry from 8,466' MD to 7,466' MD with 15.8 ppg CI G a itives Annular Volume (8,466'— 7,466 X404 f, ft3/ X 1.40 (40% excess) = 371 ft3 Shoe Joint (80) X 0.0383 R3/1' t (0% excess) = 18 ft3 Total Volume = 371 + 18 + 20 = 409 ft3 => 363 sx of 15.8 ppg Class G + 0.20/a D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.16 ft3/sk 2nd stage 7" Intermediate Casing, stage collar at 4,774' MD, hole size is 9.875" Top of slurry is designed to be at 4,053' MD, which is 500' above the Qannik. Assume 40% excess annular volume. Tail slurry from 4,774' MD to 4,053' MD with 13.5 ppg Class G + additives Annular Volume (4,774'-4,053') X 0.0471 ft3/ft X 1.40 (40% excess) =268W Total Volume = 268 + 20 = 288 ft3 => 168 sx of 13.5 ppg Class G + 0.2% D046 antifoamer, 2% D079 extender and 0.4 gal/sk D110 retarder @ 1.71 f 3/sk CD3-111AAPD Page 11 of 11 14 -Feb -17 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 Jan 811, 2017 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Re -Drill CD3 -111A Dear Commissioner: ConocoPhillips RECEIVED .IAN 17 2017 AOGCG ConocoPhillips Alaska Inc. hereby applies for a permit to sidetrack the CD3 -111A Alpine slant injector from the CD3 pad. This original CD3 -111 well was drilled and completed in 2006 as a bare foot producer, the well was suspected a downhole formation collapse lately. The purpose of the well is substitute the original lateral and capture the remaining resource in the pool. The schedule spud day for this well is around 15th of February, 2017 by rig Doyon 19. Prior to Doyon 19 rig move to CD3 -111A, pre -rig work includes spot P&A cement plug and cut existing tubing below surface casing. After rig Doyon 19 move onto the well, the proposed plan is to retrieve existing 3-1/2" tubing string, run and set CIBP in the 7" casing, then cut and pull 7" casing at +/- 2,700'. A 17.Oppg kick off cement plug will be spotted subsequently. Then sidetrack 8.75" intermediate section to section TD @ +/-8,467' MD, case the hole with 7" L-80 26# casing and cement same. Drill 6-1/8" production to TD @ +/-17,490' MD, run 4-1/2" liner with frac ports, followed by 3-1/2" upper completion string. Please find attached the information required by 20 AAC 25.005 (a) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Weifeng Dai at 263- 4324 or Chip Alvord at 265-6120. Sincerely, Weifeng Dai Drilling Engineer App in for Permit to Drill, Well CD3 -111A 16 -Jan -17 CD3 -111A Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f))............................................................ 3 2. Location Summary (Requirements of20AAC 25.005(c)(2)) ............................................ 3 Requirements of20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of20 AAC 25.005©(3)). 3 4. Drilling Hazards Information (Requirements of20AAC 25.005 (0(4)) .......................... 3 ASP CALCULATIONS for 9-5/8" and 7" Casing............................................................. 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (' (5))........................................................................................................................... 4 6. Casing and Cementing Program (Requirements of20AAC 25.005©0) ....................4 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ......................... 5 8. Drilling Fluid Program (Requirements of20 AAC 25.005(c)(8)) ....................................5 9. Abnormally Pressured Formation Information (Requirements of20AAC 25.005 (c)(9)) ................................................................................................................................... 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ......................................... 6 11. Seabed Condition Analysis (Requirements of20AAC 25.005 (c)(11)) ........................ 6 12. Evidence of Bonding (Requirements of20 AAC 25,005 (c)(12)) ................................... 6 13. Proposed Drilling Program (Requirements of20 AAC 25.005 (c)(13)) .........................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 (Requirements of 20 AAC 25.005(c)(14))............................................................................. 7 CD3 -111A APD Page 1 of 11 16 -Jan -17 15. Attachments .............................. Attachment I Directional Plan ............... Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic ... Attachment 4 Cement program ................ APP m for Permit to Drill, Well CD3 -111A 16 -Jan -17 ................................................................ 7 ........... .......................... .......................... I.............. 7 ...................................................................... 7 ...................................................................... 7 .............................................................................. 7 CD3 -11 IA APD Page 2 of 11 16 -Jan -17 App m for Permit to Drill, Well CD3 -111A 16 -Jan -17 1. Well Name (Requirements of20AAC25.005 ()9) The well for which this application is submitted will be designated as CD3 -111A. 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 3946 FNL 874 FEL Sec 5 T12N R5E NAD 1927 Northings: 6,003,829 Eastings: 388,169 RKB Elevation49.2' AMSL Pad Elevation 12.9'AMSL Location at Top of Productive Horizon 266 FNL 2733 FEL Sec 5 T12N R5E Nad 1927 Northings: 6,007,536 Eastings: 386,355 Measured De th, RKB: 8,660' Total Vertical Dejoth, RKB: 6,932' Total Vertical Depth, SS: 6,883' Location at Total De th 3520 FNL 99 FEL Sec 25 T13N R4E Nad 1927 Northings: 6,014,923 Eastings: 381,188 Measured De th, RKB: 17,470' Total Vertical Depth, RKB: 6,894' Total Vertical Depth, SS: 6,845' Requirements of 20 AAC 25.050(6) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.0050(3)) Please reference BOP schematics on file for Doyon 19. 4. Drilling Hazards Information (Requirements of2OAAC25.0050(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD(ft) Fracture Gradient (lbs. / al Pore pressure (psi) ASP Drilling (psi) 16 114/114 10.9 N/A N/A 95/8 2,721 / 2,469 17.4 1,043 7 8,467 / 6,939 12.5 3,370 1,987 4.5 17,491/6,889 12.5 4,150 3,461 • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP rams to 3,500 psi and annular to 2,500psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052) — 0.1]D CD3 -1I IA APD Page 3 of 11 16.1an-17 App( m for Permit to Drill, Well CD3.111A 16 -Jan -17 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from Ib. /gal to psi/ft 0.1 = Gas gradient in psi/ft D = True Vertical Depth of casing seat in ft RKB OR 2) ASP =FPP — (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS for 9-5/8" and 7" Casing (C) Drilling below surface casing (9-5/811) ASP = [(FG x 0.052) — 0.11 D = [(17.4 x 0.052) — 0.1] x 2,469 = 1,987 psi OR ASP= FPP — (0.1 x D) =3,370 — (0.1 x 6,932') = 2,677 psi (C) Drilling below intermediate casing (711) ASP = [(FG x 0.052) — 0.1] D = [(12.5 x 0.052) — 0.11 x 6,939 = 3,816psi OR ASP = FPP — (0.1 x D) =4,150 —(0.1 x 6,889') = 3,461 psi ' (B) data on potential gas zones, The well bore is not expected to penetrate any gas zones. © data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking, Please see Attachment 2 — Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of2OAAC25.005 (0(5)) 1. The LOT below the existing surface casing shoe was conducted to reach 17.4ppg EMW in the original wellbore back in 2006, the well hasn't been used as annular injection well and the formation integrity around surface casing shoe can be reasonably assumed stays the same. 2. Drill out 7" casing shoe track and continue drill 20' new formation, circulate hole clean and ensure mud weight in and out equal, then perform FIT to 12.5 ppg equivalent mud weight. 6. Casing and Cementing Program (Requirements of20AAC25.005©(6)) CD3 -11 fA APD Page 4 of 11 16 -Jan -17 App( m for Permit to Drill, Well CD3 -111A 16 -Jan -17 Casing and Cementin Z Program Csg/fbg Hofe We Grade Conn. Length Top MD/TVD Btm MDITVD Cement Program OD (in) iz t (Ib/ft) PPG 9.6-11.0 (h) (d) (re) ALAP 16 24 62.5 H-40 Welded 77 Surf 114/114 Pre-set 10 Minute Gels Ib./100 ftz <20 8 API Fluid Loss cc/30 min. <10 <10 Cemented on 12/29/2006. cc/30 min. <10 <10 PH 9.5-10.0 9.0-9.5 276bbis 10.7ppg ASL lead slurry and 9-5/8 12-1/4 40 L-80 BTC -M 2,685 Surf 2,721 / 2,469 49bbls Class G 15.8ppg tail slurry. Full return with 160bbis 10.7ppg cement return to surface. 2 stage cement. 8-3/4 X H- Primary stage:37.5bbls 15.8ppg Class G 7 9-7/8 26 L-80 563/13T 8,624 Surf 8,467 / 6,939 slurry. C -M 2nd stage: 26.2bbls 15.8ppg Class G slurry. 41/2t6 -1/t812.6 L-80 UP 8,454 8,460 / 17,491 / 6,889 Solid 4-1/2" liner with frac ports, no 6,900 cement job. 7. Diverter System Information (Requirements of20AAC25.005(c)(7)) N/A — Application will not include diverter system in the well operation. 8. Drilling Fluid Program (Requirements of2OAAC25.005(c)(8)) Intermediate #1: I/ Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to —11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (Flo-thro) weighted to 10.0 ppg with calcium carbonate and KCL, coupled with MPD system during drilling to ensure overbalance, the well will be displaced to KWF at TD based on pore pressure finger print result. CD3 -111A APD Page 5 of 11 16 -Jan -17 Intermediate Production Hole Size in. 8.75 x 9.875 6.125 Casing Size in. 7 4.5 Density PPG 9.6-11.0 10.0-11.0 PV cP ALAP 10 YP Ib./100 ftz 20-26 10-15 Initial Gels Ib./100 ftz 8-15 6 10 Minute Gels Ib./100 ftz <20 8 API Fluid Loss cc/30 min. <10 <10 HPHT Fluid Loss cc/30 min. <10 <10 PH 9.5-10.0 9.0-9.5 Intermediate #1: I/ Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to —11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (Flo-thro) weighted to 10.0 ppg with calcium carbonate and KCL, coupled with MPD system during drilling to ensure overbalance, the well will be displaced to KWF at TD based on pore pressure finger print result. CD3 -111A APD Page 5 of 11 16 -Jan -17 App )n for Permit to Drill, Well CD3 -111A 16 -Jan -17 Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005(c)(9)) The well bore is not expected to penetrate any abnormally pressured formation 10. Seismic Analysis (Requirements of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. ll. Seabed Condition Analysis(Requirements of20AAC25.005(c)(1/)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program(Requirements gf20AAC25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. Rip Work Plan 1. Move rig Doyon 19 onto the well. 2. R/U test full BOP as per PTD. 3. Pull existing 4-1/2" tubing cut at —2,700'. 4. Run and set CIBP at —2,680'. 5. Cut 7" at approximately 2,650' MD and pull out 7" casing. 6. Run 3-1/2" cement stinger and spot 17# kick off plug, bring top of plug —200' inside casing. 7. Run in hole with RSS BHA to kick off, drill 8-3/4" intermediate section to top of HRZ with 9.6ppg LSND mud. 8. Wait up mud to 10.3ppg and continue drill intermediate section to TD @ —8,660' MD. 9. Circulate hole clean, weight up mud to 10.8ppg, trip out drilling BHA. 10. Swap BOP upper VBR to 7" casing ram and test to 3,500psi. 11. Run 7", 26#, L-80 casing to bottom and cement same. 12. RIH 6-1/8" BHA, test casing to 3,500 psi for 30 minutes. 13. Drill out shoe track and 20' rat hole, perform FIT to 12.5ppg EMW. 14. Drill 6-1/8" hole to well TD +/-17,470' MD with MPD and I O.Oppg Flow-thru WBM, geo-steering. 15. Circulate hole clean and pull out of hole BHA. CD3 -111A APD Page 6 of 11 16 -Jan -17 App m for Permit to Drill, Well CD3 -111A 16 -Jan -17 16. Run 4-1/2° solid liner with frac ports, set liner hanger and LH top packer. 17. Run 3-1/2", 12.6 ppf, L-80 IBT-M TD upper completion string, displace well to inhibited brine. 18. Drop the Ball & Rod assembly, pressure test tubing and annulus to 3,500 psi respectively. 19. Pressure test hanger seals to 5,000 psi, Install 2 way check and test from direction of flow to 3,500 psi. Nipple down BOP. 20. Install tubing head adapter assembly and tree. Pressure test adapter assembly and tree to 5,000 psi. 21. Remove 2 way check valve. 22. Freeze protection in tubing & IA. 23. Install BPV, secure well. 24. Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of20 AAC 25.005 (c)(14)) A majority of the fluid needs will be supported by the M-1 SWACO mud plant in Alpine mixing plant. All the drilling fluid waste will be disposed into the class I disposal well at CD1-01A(Class I & II approved). Back up plan is to truck all the drilling fluid waste to Kuparuk class I disposal well if CD1-01A well is down. i 15. Attachments Attachment I Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cement program CD3 -11 fA APD Page 7 of 11 16 -Jan -17 App >n for Permit to Drill, Well CD3 -111A 16 -Jan -17 Attachment 1— Directional Plan CD3 -111A APD Page 8 of 11 16,1an-17 App in for Permit to Drill, Well CD3 -111A 16 -Jan -17 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8-3/4" x 9-7/8" Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Differential sticking Moderate Minimize drill string static time, mud property Hole swabbing on trips Moderate monitoring, control fluid loss. Optimize mud weight to control overbalance. Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent Abnormal Reservoir Low circulating density (ECD) monitoring, weighted Pressure sweeps. Abnormal Reservoir Low I Well control drills, increased mud weight. No Pressure Low mapped faults occur in the planned wellbore. Hydrogen Sulfide gas LowHzS drills, detection systems, alarms, standard well control ractices, mud scavengers 6-1/8" Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density ECD monitoring, weighted sweeps. Abnormal Reservoir Low BOPE drills. Check for flow during connections Pressure and if needed, increase mud weight. Well control drills increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. CD3 -11 lAwp04 fails major risk analysis with the parent wellbore CD3 -111 while kick off below surface casing shoe, but will separate from original wellbore quickly and clear of anti -collision after that. The original CD3 -111 well will be P&A with cement plug prior to kick off. In general, no significant clearance issue exists with sidetrack well plan. Drilling Area Risks: Reservoir Pressure: The Alpine C sand is significantly depleted due to production from offset producers without sufficient support. The possibility that reservoir pressure higher than prediction is low, nevertheless the rig will be prepared to weight up if required. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. CD3 -1I IA APD Page 9 of 1 i 16 -Jan -17 App Attachment 3 — Proposed Well Schematic CD3 -111 Nechelik Producer H sAte 19" 84#J55 Welded CondLctor lo 114 91-518"40# L-801TTC surface Casing 2,721' MD 12,4$9' ND cemented to surface 3-V9.6# L-80 Etff Tubing 8,350' MD ,n for Permit to Drill, Well CD3 -111A 16 -Jan -17 Upper Completion: 1) 4-V7126#fltTXP Tubing (2 Its) XO to 3-W EUE tubing 2) Mallow nipple pmlile 3) 3-Y:' x 1" Camm KBMG GLM (xx') w/ DV 4) 3-34' x 1' Camm KBMG GLM (xx°) w/ DV 4) 3-34" x 1" Camco KBMG GLM (xx') wIDCK2 pinned for 2500 psi casing to tbg shear 5) SLB BHP Gauge, Encapsulated I -Wire w/cannon damps on every joint 6) Baker Premier Packer 7) X nipple 2.812" ID 8) WLEG Lower Completion: 9) Flexlack Liner Hanger XO 5" Hydril 521 Box X4-rh IBTM pin 10) 4 W, 12.6#1ft, L-80 TXP Liner w/ ball actuated frac pals every 7517 11) Perforated pup @ toe 3-W x7" Baker Premier Production Packer 8,300' MD 7" 26# L-80 HYD563,BTCM Intermediate Casing 8,454' MD Length T 7' T 15' 1.5' 1.5' 37' __________________________- ------------------------- 6 1118'Hde _______________6118"F1de TD 17,470' MD 4-1/" 12,0 L-80 TXP Production Liner 15,100' MD CD3 -111A APD Pads 10 of 11 n-17 App -n for Permit to Drill, Well CD3 -111A 16 -Jan -17 Attachment 4 — Cement Program CD3 -111 A APD Page 11 of 11 16 -Jan -17 F If 0 DI CD3 -111 Awp04 6.804 K-1 FCS HRZ 1 5 Cao C-20 Nanuq .416911 I1/rU+•I,,1/��IIFIIII I Bse K41 Y R IK-2(Oamlik)11 1 I! \\\ 1 u 11 f 0 1500 9318' x 12-1/4" I Gemm etic Datum: North American Datum 19M Depth Reference: Plan:12.9+38.3 ® 49.20us0(Doyon 19) Rig: Doyon 19 412' x 6-1I8" I p m 4� CO3-11i Plan Summary 0 0 or m m o I I 1 I a 0 - 2711 2n1 - 2960 2960 - 3150 3150 - 3340 stud - 3530 3530 - 3]20 3720 - 3910 3910 - 4100 4100 - 4660 4660 5230 5230 - 5790 5790 - fi350 6350 - 6910 6910 - 7470 74]0 - 8040 8040 - 8500 8600 - 9710 9710 - 1082 10820 - 1193 11930 - 1306 13040 - 1416 14160 152 100 0 2500 5000 7500 10000 12500 15000 17500 240 T SURVEY PROGRAM 4, Magnetic Detli0Mat 17.50° Dee TO Goran a Magnetic O.ction la a True. O9dYlon, Add 17.50° East 2497.2 Annotation NOP: 2.8°1100 OLS, 170° TF, for 30• Surface Location \ epih From Depth TO Survey/Plan Hold lar 3761.06' Tool Ia . NOM /Y 6003576.13 Hem Ica 20' 80.80 441.80 CD3111 gyro (CW -111) Ham for 2204.54• CB -GYRO -SS Ea6t / X: 12.90 .08 568.75 27]0.80 CD&111 (CD3111) MWD+IFR-AK-CAZ-SC Pad Elevation: 12.90 j1,�fOa--ik1 2770.80 3120.80 CD3-111AWp04 (Plan: CD3111A) IN- R -Z 3120.80 4520.80 CO3-111AwpO4 (Plan: CD3111A) MWD CASING DETAILS 3120.80 8466.57 CD3-111AWp04 (Plan: CD3 -111A) MWD+IFR-AK-CAZSC M66.5] 9966.57 CD3-111AWp04 (Plan: CD3 -111A) MWD TVD MD Name 8466.57 17490.58 CD3-111AwpO4 (Plan: CD3.111A) MWD+IFR-AK-SC-SC 6939.20 8488.57 7'x8-3/4" U89 20 17490.58 4 -1/2'x6 -1B" SECTION DETAILS Sec MD Inc AllTVD +N/-8 4EFW Dleg TFace VSM Target 1 2]]0.80 34.64 336,75 2510.22 432.53 47277 0.00 0.00 949.27 2 2800.80 33.02 337.01 2535.02 918.05 479.40 2.80 170.00 965.72 3 286000 32.55 339.02 2585.24 948.49 -391.70 2.80 14000 997.58 4 3033.al 2].]4 340.22 2734.81 1029.87 -422.01 2.60 1]3,3] 1081.24 5 6794.89 2774 310.22 6063.67 2677.11 -101449 0.00 0.00 2762.13 e 8466.57 88.00333.00 6939.20 3093.72 -157420 3.50 -8.45 4075.38 C 111AW.HeeI011017JC 7 8486.57 86.00 333.00 6940.60 3911.50 -1583.26 0.00 0.00 4095.08 8 8818.99 9040 328.07 6950.98 4195.7/-1745.59 7.00 48.36 4422.91 9 11021.43 90.40 328.07 6935.62 6069.67 -2911.57 0.00 0.00 6621." 1011221.61 90.41 324.06 6904.20 6235.71 4023.28 200 -89.81 8821.85 CD3-HIA02.Tgt1011017 JC 11 17490.50 90.41 324.06 6889.20 11311.42 870232 0.00 0.0013090.66 CD3-111A03.TDO1f017JC 0 - 2711 2n1 - 2960 2960 - 3150 3150 - 3340 stud - 3530 3530 - 3]20 3720 - 3910 3910 - 4100 4100 - 4660 4660 5230 5230 - 5790 5790 - fi350 6350 - 6910 6910 - 7470 74]0 - 8040 8040 - 8500 8600 - 9710 9710 - 1082 10820 - 1193 11930 - 1306 13040 - 1416 14160 152 100 CD3 -111 & 111L1 Base K-2 ri SteW-7- TCR required ering in the lateral section. TCRs 56051 required for both. AIb97 5977.2 Nanuq 6264.3 FOS HRZ 677].2 K-1 By signing this I a immledge Mat I have been informed of all asks, checkad that the data is comets, ensured We completeness, and all surrouneing wells are assignee to the proper position and I approve the scan and roafted Prepared by: Checked by Accepted by: j Approved by: Brij Penis Nate Beck Enk Stark pal, Dews 52 1638( - 1638 16380 - 17491 MagnelK Model BGGM2016 T Magnetic Me Dle'. 11.50--17 4, Magnetic Detli0Mat 17.50° Dee TO Goran a Magnetic O.ction la a True. O9dYlon, Add 17.50° East 2497.2 Annotation NOP: 2.8°1100 OLS, 170° TF, for 30• C-30 Attest TF to 140°, for 69 Adjust TF to 173.37°, for 173,01' 2882.2 Hold lar 3761.06' Stat 3.5'1100 DLS. 845° V. for 1671.68' Hem Ica 20' Stall 2°1100' OLS, -48,W TE for 330.31- Ham for 2204.54• C -2o Start 2.110P OLS. 49.81- TF. for 200.19' Hold for 6268.90' TD: 17490.5& MD, 68897 WD j1,�fOa--ik1 CD3 -111 & 111L1 Base K-2 ri SteW-7- TCR required ering in the lateral section. TCRs 56051 required for both. AIb97 5977.2 Nanuq 6264.3 FOS HRZ 677].2 K-1 By signing this I a immledge Mat I have been informed of all asks, checkad that the data is comets, ensured We completeness, and all surrouneing wells are assignee to the proper position and I approve the scan and roafted Prepared by: Checked by Accepted by: j Approved by: Brij Penis Nate Beck Enk Stark pal, Dews CD3 -111A wp04 gDpz..u.aw3nWmn sari n _ . Pla ami w..vm. Toel: wn.a�. 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IN o e° W.T*p N SC03 Pe1,CO3-I 11N1 PWn lDlfetl al a ACw{M Dili 1AnD4 NOTES 111G2013 0°°PM J 13:37, January 16 CD3-111Awp 4 N CD3 -11 `\\D3 -111L \ CD3 -111 CD3 -112 Mc_ C `C D3-113 41CD3-1 CD3 D3-118 17 Z CD3 -1 Nigliq \ \ \ CD3 -124 Easting (3500 usft/in) CD3 -1 CD3 -109 ,7 D3-12 ntermediate CD3 -1Z 1 CD3 -199 CD3 -121 CD3 Fiord Pad CD3 -122 CD3 -123 CD3 -125 CD3 -12 Easting (3500 usftlin) Li CD3 -316 CD3 -307 CD3 -316A CD3 -303 CD3 -304 CD3-305PB1 D3-320 CD3-111Awp04 1 4-1/2" x 6-1/8----------- CD3-11 1 A -- -CD3-111A 03.TD 011017 C , 10000 v� 06 �� 8000 26000 Plan View 6000 GOO, 00 '�`ti0 CD3 -111A 02.Tgt1 011017 C _0000 CD3 -111A Polygon 011017 P $000 CD3 -111A 01.Heel 011017 C 7" x 8-3/4" _ 90p0 0 u 9-5/8" x 12-1/4 0- 00 4 9 -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 West( -)/East(+) WWI CD3-111Awp04 Plan View Willi 5- "�Stearing 2700 G� 0 p0 250 2250— CD3 199 is below planned well at this point. I + z9 800 L 7 U) 1350- 3509009-5/8" 900- 9-5/8"x 12-1/4" ^g0 L°°° 450 -2250 -1800 -1350 -900 -450 0 450 900 1350 West( -)/East(+) IMME s r 0 , MA CD3-111Awp04 goo 0 Plan View Bring into twpses or �5 uncertainty overlap 6 OO Polygon only later in the lateral. allows 50' of O deviation to the �D O west. 00 00 �O N O �O N O �O � O FA o0 TCR required o0 o -6300 -6000 -5700 -5400 -5100 -4800 -4500 West( -)/East(+) -4200 W.�., CD3-111Awp04 Section View 9-5/8" x 12-1/4" \ ------------------------------------ L V03000 - - -------------------------- ------. --- -----------------' 4500 E -5000 7" x i cou,u Vertical Section at 324.000 4-1/2" x I CD3.111Awp04 Section View all 32 9-5/8" x 1/4 000 ------------- - O? C-20 4000 - r.+ __------------ Q - pal m U 4800 ..W1 K-2 (Qannik) Base K-2 Alb97 ---------- I ---------------------------------- ----------------------- -- --- �gOO 10 v Nanuq w FCS HRZ r Uv w r D M F _ ___ J o 6400 r v o A ,A� 00 0 011 �� o W� o 0 U roo - - ---------------------------------- -------- K-1 0 500 1000 1500 2000 2500 3000 3500 4000 Vertical Section at 324.000 CD3 -111 Awp04 0 n N N 06900 FU U_ Ul o O 00 ~ 6930 0 �O 7" x 8-3/4" cc)) 4500 6000 Section View :a 3 stee�ng 7500 9000 10500 12000 13500 Vertical Section at 324.00° v 5 v W r D F v 0 A , i , :a 3 stee�ng 7500 9000 10500 12000 13500 Vertical Section at 324.00° ConocoPhillips(Alaska) Inc. MINIS Western North Slope CD3 Fiord Pad CD3 -111 Plan: CD3 -111A Plan: CD3-111Awp04 Standard Proposal Report 16 January, 2017 Database: EDM Production Company: ConomPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD3 Fiord Pad Well: CD3 -111 Wellborn: Plan: CD3 -111A Design: CD3-111Awp04 SLB Standard Proposal Report Local Co-ordinate Reference: Well CD3 -111 TVD Reference: Plan:12.9+36.3 @ 49.20usft (Doyon 19) MD Reference: Plan:12.9+36.3 @ 49.20usft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site CD3 Fiord Pad CD3 -111 Site Position: Northing: 6,003,634.02 usft Latitude: 70° 25'9,315 N From: Map Easting: 1,528,520.01 usft Longitude: 150° 54'41.768 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.86 ° Well CD3 -111 Audit Notes: Well Position +N/ -S 0.00 usft Northing: 6,003,576.13 usft Latitude: 70" 268.699 N Vertical Section: +EI -W 0.00 usft Easting: 1,528,201.08 usft Longitude: 150° 54'51.095 W Position Uncertainty (•) 0.00 usft Wellhead Elevation: usft Ground Level: 12.90 usft Wellbore Plan: CD3 -111A Magnetics Model Name Sample Date Declination Dip Angie Field Strength 1°) (°) (nT) BGGM2016 1/11/2017 17.50 80.90 57,519 Design CD3-111Awp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 2,770.80 Vertical Section: Depth From (TVD) +N141 +E/ -W Direction (usft) (usft) (usft) (•) Turn 36.30 0.00 0.00 324.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NbS +E/ -W Rate Rate Rate Tool Face (usft) (^) (°) (usft) usft (usft) (usft) (°11100usft) 1°1100usft) (°/100usft) (°) 2,770.80 34.64 336.75 2,510.22 2,461.02 902.53 -372.77 0.00 0.00 0.00 0.00 2,800.80 33.82 337.01 2,535.02 2,485.82 918.05 -379.40 2.80 -2.76 0.87 170.00 2,860.80 32.55 339.02 2,585.24 2,536.04 948.49 -391.70 2.80 -2.12 3.35 140.00 3,033.81 27.74 340.22 2,734.81 2,685.61 1,029.87 -422.01 2.80 -2.78 0.69 173.37 6,794.89 27.74 340.22 6,063.67 6,014.47 2,677.11 -1,014.49 0.00 0.00 0.00 0.00 8,466.57 86.00 333.00 6,939.20 6,890.00 3,893.72 -1,574.20 3.50 3.49 -0.43 -8.45 8,486.57 66.00 333.00 6,940.60 6.891.40 3,911.50 -1,583.26 0.00 0.00 0.00 0.00 8,816.89 90.40 328.07 6,950.98 6,901.78 4,198.77 -1,745.59 2.00 1.33 -1.49 -48.36 11,021.43 90.40 328.07 6,935.62 6,886.42 6,069.67 -2,911.57 0.00 0.00 0.00 0.00 11,221.61 90.41 324.06 6,934.20 6,685.00 6,235.71 -3,023.29 2.00 0.01 -2.00 -89.61 17,490.58 90.41 324.06 6,889.20 6,840.00 11,311.42 -6,702.32 0.00 0.00 0.00 0.00 1116/2017 1:20:23PM Page 2 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Project: Western North Slope MD Reference: Site: CD3 Fiord Pad North Reference: Well: CD3 -111 / Survey Calculation Method: Wellbore: Plan: CD3 -111A Map Design: CD3-111Awp04 SLB Standard Proposal Report Well CD3 -111 Plan:12.9+36.3 @ 49.20usft (Doyon 19) Plan:12.9+36.3 @ 49.20usft (Doyon 19) True Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting US Vert Section (usft) V) V) (usft) usft (usft) (usft) (usft) (usft) 2,461.02 2,770.80 34.64 336.75 2,510.22 2,461.02 902.53 -372.77 6,OD4,484.08 1,527,841.95 0.69 949.27 KOP: 2.8°/100' DLS, 170° TF, for 30' 2,800.80 33.82 337.01 2,535.02 2,485.82 918.05 -379.40 6,004,499.70 1,527,835.55 2.80 965.72 Adjust TF to 140°, for 60' 2,860.80 32.55 339.02 2,585.24 2,536.04 948.49 -391.70 6,004,530.32 1,527,823.71 2.80 997.58 Adjust TF to 173.37°, for 173.01' 2,900.00 31.46 339.26 2,618.48 2,569.28 967.90 -399.10 6,004,549.83 1,527,816.61 2.80 1,017.63 3,000.00 28.68 339.95 2,705.02 2,655.82 1,014.85 -016.57 6,004,597.04 1,527,799.85 2.80 1,065.68 3,033.81 27.74 340.22 2,734.81 2,685.61 1,029.87 -422.01 6,004,612.14 1,527,794.63 2.80 1,081.24 Hold for 3761.08' 3,100.00 27.74 340.22 2,793.39 2,744.19 1,058.86 -432.44 6,004,641.28 1,527,784.65 0.00 1,110.82 3,200.00 27.74 340.22 2,881.90 2,832.70 1,102.86 448.19 6,004,685.31 1,527,769.55 0.00 1,155.51 3,200.34 27.74 340.22 2,882.20 2,833.00 1,102.81 -048.24 6,004,685.46 1,527,769.50 0.00 1,155.66 C-20 3,300.00 27.74 340.22 2,970.41 2,921.21 1,146.46 -463.94 6,004,729.33 1,527,754.46 0.00 1,200.20 3,400.00 27.74 340.22 3,058.92 3,009.72 1,190.25 -079.69 6,004,773.36 1,527,739.37 0.00 1,244.89 3,500.00 27.74 340.22 3,147.43 3,098.23 1,234.05 495.45 6,004,817.36 1,527,724.28 0.00 1,289.58 3,600.00 27.74 340.22 3,235.93 3,186.73 1,277.85 -511.20 6,004,861.41 1,527,709.19 0.00 1,334.28 3,700.00 27.74 340.22 3,324.44 3,275.24 1,321.64 -526.95 6,004,905.43 1,527,694.10 0.00 1,378.97 3,800.00 27.74 340.22 3,412.95 3,363.75 1,365.44 -542.71 6,004,949.46 1,527,679.01 0.00 1,423.66 3,900.00 27.74 340.22 3,501.46 3,452.26 1,409.24 -558.46 6,004,993.46 1,527,663.91 0.00 1,468.35 4,000.00 27.74 340.22 3,589.97 3,540.77 1,453.04 -57421 6,005,037.51 1,527,648.82 0.00 1,513.04 4,100.00 27.74 340.22 3,678.47 3,629.27 1,496.83 -589.96 6,005,081.53 1,527,633.73 0.00 1,557.74 4,200.00 27.74 340.22 3,766.98 3,717.78 1,540.63 -605.72 6,005,125.56 1,527,618.64 0.00 1,602.43 4,300.00 27.74 340.22 3,855.49 3,606.29 1,584.43 -621.47 6,005,169.58 1,527,603.55 0.00 1,647.12 4,400.00 27.74 340.22 3,944.00 3,894.80 1,628.22 -637.22 6,005,213.61 1,527,588.46 0.00 1,691.81 4,500.00 27.74 340.22 4,032.51 3,983.31 1,672.02 -652.98 6,005,257.63 1,527,573.37 0.00 1,736.50 4,553.89 27.74 340.22 4,080.20 4,031.00 1,695.62 -661.46 6,005,281.36 1,527,565.23 0.00 1,760.59 K-2 (Qannik) 4,600.00 27.74 340.22 4,121.01 4,071.81 1,715.82 -668.73 6,005,301.66 1,527,558.28 0.00 1,781.19 4,673.65 27.74 340.22 4,186.20 4,137.00 1,748.07 -680.33 6,005,334.08 1,527,547.16 0.00 1,814.11 Base K-2 4,700.00 27.74 340.22 4,209.52 4,160.32 1,759.61 -684.48 6,005,345.68 1,527,543.18 0.00 1,825.89 4,800.00 27.74 340.22 4,298.03 4,248.83 1,803.41 -700.23 6,005,389.71 1,527,528.09 0.00 1,870.58 4,900.00 27.74 340.22 4,386.54 4,337.34 1,847.21 -715.99 6,005,433.73 1,527,513.00 0.00 1,915.27 5,000.00 27.74 340.22 4,475.05 4,425.85 1,891.01 -731.74 6,005,477.76 1,527,497.91 0.00 1,959.96 5,100.00 27.74 340.22 4,563.55 4,514.35 1,934.80 -747.49 6,005,521.78 1,527,482.82 0.00 2,004.65 5,200.00 27.74 340.22 4,652.06 4,602.86 1,978.60 -763.25 6,005,565.81 1,527,467.73 0.00 2,049.35 5,300.00 27.74 340.22 4,740.57 4,691.37 2,022.40 -779.00 6,005,609.83 1,527,452.64 0.00 2,094.04 5,400.00 27.74 340.22 4,829.08 4,779.88 2,066.19 -794.75 6,005,653.86 1,527,437.54 0.00 2,138.73 5,500.00 27.74 340.22 4,917.59 4,868.39 2,109.99 -810.50 6,005,697.88 1,527,422.45 0.00 2,183.42 5,600.00 27.74 340.22 5,006.09 4,956.89 2,153.79 -826.26 6,005,741.91 1,527,407.36 0.00 2,228.11 5,700.00 27.74 340.22 5,094.60 5,045.40 2,197.58 -842.01 6,005,785.93 1,527,392.27 0.00 2,272.80 5,800.00 27.74 340.22 5,183.11 5,133.91 2,241.38 -857.76 6,005,829.96 1,527,377.18 0.00 2,317.50 5,900.00 27.74 340.22 5,271.62 5,222.42 2,285.18 -873.52 6,005,873.99 1,527,362.09 0.00 2,362.19 1/162017 1:20:23PM Page 3 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConowPhillips(Alaska) Inc. -WNS TVD Reference: Project: Western North Slope MD Reference: Site: CD3 Fiord Pad North Reference: Well: CD3 -111 Survey Calculation Method: Wellbore: Plan: CD3 -111A Design: CD3-111Awp04 SLB Standard Proposal Report Well CD3 -111 Plan:12.9+36.3 (03 49.20usft (Doyon 19) Plan: 12.9+36.3 @ 49.20usft (Doyon 19) True Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 5,310.93 6,000.00 27.74 340.22 5,360.13 5,310.93 2,328.98 -889.27 6,005,918.01 1,527,347.00 0.00 2,406.88 6,100.00 27.74 340.22 5,448.63 5,399.43 2,372.77 -905.02 6,005,962.04 1,527,331.90 0.00 2,451.57 6,200.00 27.74 340.22 5,537.14 5,487.94 2,416.57 -920.77 6,006,006.06 1,527,316.81 0.00 2,496.26 6,276.89 27.74 340.22 5,605.20 5,556.00 2,450.25 -932.89 6,006,039.91 1,527,305.21 0.00 2,530.63 AIb97 6,300.00 27.74 340.22 5,625.65 5,576.45 2,460.37 -936.53 6,006,050.09 1,527,301.72 0.00 2,540.96 6,400.00 27.74 340.22 5,714.16 5,664.96 2,504.16 -952.28 6,006,094.11 1,527,286.63 0.00 2,585.65 6,500.00 27.74 340.22 5,802.67 5,753.47 2,547.96 -968.03 6,006,138.14 1,527,271.54 0.00 2,630.34 6,600.00 27.74 340.22 5,891.17 5,841.97 2,591.76 -983.79 6,006,182.16 1,527,256.45 0.00 2,675.03 6,697.19 27.74 340.22 5,977.20 5,928.00 2,634.33 -999.10 6,006,224.95 1,527,241.78 0.00 2,718.47 Nanuq 6,700.00 27.74 340.22 5,979.68 5,930.48 2,635.56 -999.54 6,006,226.19 1,527,241.36 0.00 2,719.72 6,794.89 27.74 340.22 6,063.67 6,014.47 2,677.11 -1,014.49 6,006,267.96 1,527,227.04 0.00 2,762.13 Start 3.6°/100' DLS, -8.46° TF, for 1671.68' 6,800.00 27.92 340.16 6,068.19 6,018.99 2,679.36 -1,015.30 6,006,270.22 1,527,226.26 3.50 2,764.42 6,900.00 31.38 339.16 6,155.08 6,105.88 2,725.73 -1,032.50 6,006,316.84 1,527,209.76 3.50 2,812.05 7,000.00 34.85 338.38 6,238.82 6,189.62 2,776.64 -1,052.29 6,006,368.04 1,527,190.74 3.50 2,864.87 7,031.27 35.94 338.15 6,264.31 6,215.11 2,793.47 -1,059.00 6,006,384.96 1,527,184.28 3.50 2,882.43 FCS HRZ 7,100.00 38.33 337.70 6,319.10 6,269.90 2,831.92 -1,074.59 6,006,423.64 1,527,169.27 3.50 2,922.70 7,200.00 41.81 337.12 6,395.61 6,346.41 2,891.34 -1,099.33 6,006,483.42 1,527,145.43 3.50 2,985.31 7,300.00 45.29 336.62 6,468.08 6,418.88 2,954.69 -1,126.40 6,006,547.16 1,527,119.32 3.50 3,052.47 7,400.00 46.78 336.17 6,536.22 6,487.02 3,021.73 -1,155.71 6,006,614.63 1,527,091.02 3.50 3,123.94 7,500.00 52.26 335.77 6,599.79 6,550.59 3,092.21 -1,187.14 6,006,685.57 1,527,060.65 3.50 3,199.43 7,600.00 55.75 335.40 6,658.55 6,609.35 3,165.87 -1,220.59 6,006,759.72 1,527,028.32 3.50 3,278.68 7,700.00 59.24 335.06 6,712.28 6,663.08 3,242.43 -1,255.92 6,006,836.80 1,526,994.15 3.50 3,361.39 7,800.00 62.73 334.75 6,760.77 6,711.57 3,321.62 -1,293.00 6,006,916.52 1,526,958.27 3.50 3,447.25 7,836.65 64.01 334.64 6,777.20 6,728.00 3,351.24 -1,307.00 6,006,946.35 1,526,944.71 3.50 3,479.44 K-1 7,900.00 66.22 334.46 6,803.86 6,754.66 3,403.12 -1,331.70 6,006,998.59 1,526,920.80 3.50 3,535.94 8,000.00 69.71 334.18 6,841.37 6,792.17 3,486.64 -1,371.87 6,007,082.70 1,526,881.89 3.50 3,627.12 6,100.00 73.20 333.91 6,873.17 6,823.97 3,571.88 -1,413.36 6,007,168.54 1,526,841.69 3.50 3,720.46 8,200.00 76.69 333.65 6,899.13 6,849.93 3,658.50 -1,456.01 6,007,255.78 1,526,800.35 3.50 3,815.61 8,300.00 80.18 333.41 6,919.17 6,869.97 3,746.18 -1,499.68 6,007,344.11 1,526,758.01 3.50 3,912.21 8,400.00 83.68 333.16 6,933.21 6,884.01 3,834.61 -1,544.18 6,007,433.19 1,526,714.84 3.50 4,009.91 8,466.57 86.00 333.00 6,939.20 6,890.00 3,893.72 -1,574.20 6,007,492.74 1,526,685.72 3.50 4,075.38 Hold for 20'- 7" x 8.3W' 8,486.57 66.00 333.00 6,940.60 6,891.40 3,911.50 -1,583.26 6,007,510.65 1,526,676.93 0.00 4,095.08 Start 2°N 00' DLS, -48.36° TF, for 330.31' 8,500.00 86.18 332.80 6,941.51 6,892.31 3,923.42 -1,589.36 6,007,522.66 1,526,671.01 2.00 4,108.32 8,600.00 87.51 331.30 6,947.02 6,897.82 4,011.62 -1,636.16 6,007,611.55 1,526,625.55 2.00 4,207.18 8,700.00 88.84 329.81 6,950.20 6,901.00 4,098.66 -1,685.29 6,007,699.30 1,526,577.74 2.00 4,306.47 8,800.00 90.17 328.32 6,951.06 6,901.86 4,184.42 -1,736.69 6,007,785.83 1,526,527.64 2.00 4,406.07 8,816.89 90.40 328.07 6,950.98 6,901.78 4,198.77 -1,745.59 6,007,800.31 1,526,518.95 2.00 4,422.91 Hold for 2204.64' 1/162017 1:20:23PM Page 4 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well CD3 -111 Company: ConomPhillips(Alaska) Inc. -WNS TVD Reference: Plan:12.9+36.3 @ 49.20usft (Doyon 19) Project: Western North Slope MD Reference: Plan:12.9+36.3 ,a 49.20usft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3 -111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -111A Depth Inclination Design: CD3-111Awp04 TVDss +N! -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N! -S +El -W Northing Easing DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,901.20 8,900.00 90.40 328.07 6,950.40 6,901.20 4,269.31 -1,789.55 6,007,871.49 1,526,476.06 0.00 4,505.81 9,000.00 90.40 328.07 6,949.70 6,900.50 4,354.17 -1,842.44 6,007,957.13 1,526,424.46 0.00 4,605.56 9,100.00 90.40 328.07 6,949.00 6,899.80 4,439.04 -1,895.33 6,008,042.78 1,526,372.86 0.00 4,705.30 9,200.00 90.40 328.07 6,948.31 6,899.11 4,523.91 -1,948.22 6,008,128.42 1,526,321.25 0.00 4,805.05 9,300.00 90.40 328.07 6,947.61 6,898.41 4,608.77 -2,001.11 6,008,214.06 1,526,269.65 0.00 4,904.79 9,400.00 90.40 328.07 6,946.91 6,897.71 4,693.64 -2,054.00 6,008,299.71 1,526,218.04 0.00 5,004.54 9,500.00 90.40 328.07 6,946.22 6,897.02 4,778.50 -2,106.89 6,008,385.35 1,526,166.44 0.00 5,104.29 9,600.00 90.40 326.07 6,945.52 6,896.32 4,863.37 -2,159.78 6,008,471.00 1,526,114.84 0.00 5,204.03 9,700.00 90.40 328.07 6,944.82 6,895.62 4,948.23 -2,212.67 6,008,556.64 1,526,063.23 0.00 5,303.78 9,800.00 90.40 328.07 6,944.13 6,894.93 5,033.10 -2,265.56 6,008,642.28 1,526,011.63 0.00 5,403.52 9,900.00 90.40 328.07 6,943.43 6,894.23 5,117.96 -2,318.45 6,008,727.93 1,525,960.02 0.00 5,503.27 10,000.00 90.40 328.07 6,942.73 6,893.53 5,202.83 -2,371.34 6,008,813.57 1,525,908.42 0.00 5,603.01 10,100.00 90.40 328.07 6,942.04 6,892.84 5,287.69 -2,424.23 6,008,899.21 1,525,856.82 0.00 5,702.76 10,200.00 90.40 328.07 6,941.34 6,892.14 5,372.56 -2,477.12 6,008,984.66 1,525,805.21 0.00 5,802.51 10,300.00 90.40 328.07 6,940.64 6,891.44 5,457.43 -2,530.01 6,009,070.50 1,525,753.61 0.00 5,902.25 10,400.00 90.40 328.07 6,939.95 6,890.75 5,542.29 -2,582.90 6,009,156.14 1,525,702.00 0.00 6,002.00 10,500.00 90.40 328.07 6,939.25 6,890.05 5,627.16 -2,635.79 6,009,241.79 1,525,650.40 0.00 6,101.74 10,600.00 90.40 328.07 6,938.55 6,889.35 5,712.02 -2,688.68 6,009,327.43 1,525,598.80 0.00 6,201.49 10,700.00 90.40 328.07 6,937.86 6,888.66 5,796.89 -2,741.57 6,009,413.08 1,525,547.19 0.00 6,301.23 10,800.00 90.40 328.07 6,937.16 6,887.96 5,881.75 -2,794.46 6,009,498.72 1,525,495.59 0.00 6,400.98 10,900.00 90.40 328.07 6,936.46 6,887.26 5,966.62 -2,847.35 6,009,584.36 1,525,443.98 0.00 6,500.72 11,000.00 90.40 328.07 6,935.77 6,886.57 6,051.48 -2,900.24 6,009,670.01 1,525,392.38 0.00 6,600.47 11,021.43 90.40 328.07 6,935.62 6,886.42 6,069.67 -2,911.57 6,009,688.36 1,525,381.32 0.00 6,621.84 Start 2.1100- DLS, -89.81° TF, for 200.18' 11,100.00 90.40 326.50 6,935.07 5,885.87 6,135.77 -2,954.04 6,009,755.09 1,525,339.86 2.00 6,700.28 11,200.00 90.41 324.50 6,934.35 6,885.15 6,218.17 -3,010.68 6,009,838.32 1,525,284.47 2.00 6,800.24 11,221.61 90.41 324.06 6,934.20 6,885.00 6,235.71 -3,023.29 6,009,856.05 1,525,272.12 2.00 6,821.85 Hold for 6268.98' 11,300.00 90.41 324.06 6,933.64 6,884.44 6,299.19 -3,069.30 6,009,920.20 1,525,227.08 0.00 6,900.24 11,400.00 90.41 324.06 6,932.92 6,883.72 6,380.15 -3,127.99 6,010,002.03 1,525,169.62 0.00 7,000.24 11,500.00 90.41 324.06 6,932.20 6,683.00 6,461.12 -3,186.67 6,010,083.86 1,525,112.16 0.00 7,100.23 11,600.00 90.41 324.06 6,931.48 6,882.28 6,542.08 -3,245.36 6,010,165.70 1,525,054.70 0.00 7,200.23 11,700.00 90.41 324.06 6,930.77 6,881.57 6,623.05 -3,304.04 6,010,247.53 1,524,997.25 0.00 7,300.23 11,800.00 90.41 324.06 6,930.05 6,880.85 6,704.01 -3,362.73 6,010,329.36 1,524,939.79 0.00 7,400.22 11,900.00 90.41 324.06 6,929.33 6,880.13 6,784.98 -3,421.42 6,010,411.19 1,524,882.33 0.00 7,500.22 12,000.00 90.41 324.06 6,928.61 6,879.41 6,865.95 -3,480.10 6,010,493.02 1,524,824.87 0.00 7,600.22 12,100.00 90.41 324.06 6,927.89 6,878.69 6,946.91 -3,538.79 6,010,574.85 1,524,767.42 0.00 7,700.22 12,200.00 90.41 324.06 6,927.18 6,877.98 7,027.86 -3,597.48 6,010,656.69 1,524,709.96 0.00 7,800.21 12,300.00 90.41 324.06 6,926.46 6,877.26 7,108.84 -3,656.16 6,010,738.52 1,524,652.50 0.00 7,900.21 12,400.00 90.41 324.06 6,925.74 6,676.54 7,189.61 -3,714.85 6,010,820.35 1,524,595.04 0.00 8,000.21 12,500.00 90.41 324.06 6,925.02 6,875.82 7,270.77 -3,773.53 6,010,902.18 1,524,537.59 0.00 8,100.21 12,600.00 90.41 324.06 6,924.31 6,875.11 7,351.74 -3,832.22 6,010,984.01 1,524,480.13 0.00 8,200.20 12,700.00 90.41 324.06 6,923.59 6,874.39 7,432.70 -3,890.91 6,011,065.84 1,524,422.67 0.00 8,300.20 12,800.00 90.41 324.06 6,922.67 6,873.67 7,513.67 -3,949.59 6,011,147.67 1,524,365.21 0.00 8,40D.20 12,900.00 90.41 324.06 6,922.15 6,872.95 7,594.63 -4,008.28 6,011,229.51 1,524,307.76 0.00 6,500.20 1/16,2017 1:20:23PM Page 5 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well CD3 -111 Company: ConomPhillips(Alaska) Inc. -WNS ND Reference: Plan:12.9+36.3 @ 49.20usft (Doyon 19) Project: Western North Slope MD Reference: Plan:12.9+36.3 @ 49.20usft (Doyon 19) Site: CD3 Fiord Pad North Reference: True Well: CD3 -111 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3 -111A (usft) V) Design: CD3-111Awp04 usft (usft) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +El -W Northing Easting DLS Vert Section (usft) V) V) (usft) usft (usft) (usft) (usft) (usft) 6,872.23 13,000.00 90.41 324.06 6,921.43 6,672.23 7,675.60 -4,066.97 6,011,311.34 1,524,250.30 0.00 8,600.19 13,100.00 90.41 324.06 6,920.72 6,871.52 7,756.57 4,125.65 6,011,393.17 1,524,192.84 0.00 8,700.19 13,200.00 90.41 324.06 6,920.00 6,670.80 7,837.53 -4,184.34 6,011,475.00 1,524,135.36 0.00 8,800.19 13,300.00 90.41 324.06 6,919.28 6,870.08 7,918.50 4,243.02 6,011,556.83 1,524,077.93 0.00 8,900.19 13,400.00 90.41 324.06 6,918.56 6,869.36 7,999.46 -4,301.71 6,011,638.66 1,524,020.47 0.00 9,000.18 13,500.00 90.41 324.06 6,917.85 6,868.65 8,080.43 -4,360.40 6,011,720.50 1,523,963.01 0.00 9,100.18 13,600.00 90.41 324.06 6,917.13 6,867.93 8,161.39 -4,419.08 6,011,802.33 1,523,905.55 0.00 9,200.18 13,700.00 90.41 324.06 6,916.41 6,867.21 8,242.36 -4,477.77 6,011,884.16 1,523,848.10 0.00 9,300.17 13,800.00 90.41 324.06 6,915.69 6,866.49 8,323.32 -4,536.46 6,011,965.99 1,523,790.64 0.00 9,400.17 13,900.00 90.41 324.06 6,914.97 6,865.77 8,404.29 4,595.14 6,012,047.82 1,523,733.18 0.00 9,500.17 14,000.00 90.41 324.06 6,914.26 6,865.06 8,485.25 4,653.83 6,012,129.65 1,523,675.72 0.00 9,600.17 14,100.00 90.41 324.06 6,913.54 6,864.34 6,566.22 4,712.51 6,012,211.48 1,523,618.27 0.00 9,700.16 14,200.00 90.41 324.06 6,912.62 6,863.62 8,647.19 -4,771.20 6,012,293.32 1,523,560.81 0.00 9,800.16 14,300.00 90.41 324.06 6,912.10 6,862.90 8,728.15 -4,829.89 6,012,375.15 1,523,503.35 0.00 9,900.16 14,400.00 90.41 324.06 6,911.38 6,862.18 6,809.12 -4,888.57 6,012,456.98 1,523,445.89 0.00 10,000.16 14,500.00 90.41 324.06 6,910.67 6,861.47 8,890.08 -4,947.26 6,012,536.81 1,523,368.44 0.00 10,100.15 14,600.00 90.41 324.06 6,909.95 6,660.75 8,971.05 -5,005.95 6,012,620.64 1,523,330.98 0.00 10,200.15 14,700.00 90.41 324.06 6,909.23 6,860.03 9,052.01 -5,064.63 6,012,702.47 1,523,273.52 0.00 10,300.15 14,800.00 90.41 324.06 6,908.51 6,859.31 9,132.98 -5,123.32 6,012,784.31 1,523,216.06 0.00 10,400.15 14,900.00 90.41 324.06 6,907.80 6,858.60 9,213.94 -5,182.00 6,012,866.14 1,523,158.60 0.00 10,500.14 15,000.00 90.41 324.06 6,907.08 6,657.68 9,294.91 -5,240.69 6,012,947.97 1,523,101.15 0.00 10,600.14 15,100.00 90.41 324.06 6,906.36 6,857.16 9,375.88 -5,299.38 6,013,029.80 1,523,043.69 0.00 10,700.14 15,200.00 90.41 324.06 6,905.64 6,856.44 9,456.84 -5,358.06 6,013,111.63 1,522,986.23 0.00 10,800.14 15,300.00 90.41 324.06 6,904.92 6,855.72 9,537.81 -5,416.75 6,013,193.46 1,522,928.77 0.00 10,900.13 15,400.00 90.41 324.06 6,904.21 6,855.01 9,616.77 -5,475.44 6,013,275.29 1,522,871.32 0.00 11,000.13 15,500.00 90.41 324.06 6,903.49 6,854.29 9,699.74 -5,534.12 6,013,357.13 1,522,813.86 0.00 11,100.13 15,600.00 90.41 324.06 6,902.77 6,853.57 9,780.70 -5,592.81 6,013,438.96 1,522,756.40 0.00 11,200.12 15,700.00 90.41 324.06 6,902.05 6,652.85 9,861.67 -5,651.49 6,013,520.79 1,522,698.94 0.00 11,300.12 15,800.00 90.41 324.06 6,901.34 6,852.14 9,942.63 -5,710.18 6,013,602.62 1,522,641.49 0.00 11,400.12 15,900.00 90.41 324.06 6,900.62 6,851.42 10,023.60 -5,768.87 6,013,664.45 1,522,584.03 0.00 11,500.12 16,000.00 90.41 324.06 6,899.90 6,650.70 10,104.56 -5,627.55 6,013,766.28 1,522,526.57 0.00 11,600.11 16,100.00 90.41 324.06 6,899.16 6,849.98 10,185.53 -5,886.24 6,013,848.12 1,522,469.11 0.00 11,700.11 16,200.00 90.41 324.06 6,898.46 6,849.26 10,266.50 -5,944.93 6,013,929.95 1,522,411.66 0.00 11,800.11 16,300.00 90.41 324.06 6,897.75 6,848.55 10,347.46 -6,003.61 6,014,011.78 1,522,354.20 0.00 11,900.11 16,400.00 90.41 324.06 6,897.03 6,647.83 10,428.43 -6,062.30 6,014,093.61 1,522,296.74 0.00 12,000.10 16,500.00 90.41 324.06 6,896.31 6,847.11 10,509.39 -6,120.98 6,014,175.44 1,522,239.28 0.00 12,100.10 16,600.00 90.41 324.06 6,895.59 6,846.39 10,590.36 -6,179.67 6,014,257.27 1,522,181.83 0.00 12,200.10 16,700.00 90.41 324.06 6,894.87 6,845.67 10,671.32 -6,238.36 6,014,339.10 1,522,124.37 0.00 12,300.10 16,800.00 90.41 324.06 6,894.16 6,844.96 10,752.29 -6,297.04 6,014,420.94 1,522,066.91 0.00 12,400.09 16,900.00 90.41 324.06 6,893.44 6,844.24 10,833.25 -6,355.73 6,014,502.77 1,522,009.45 0.00 12,500.09 17,000.00 90.41 324.06 6,892.72 6,843.52 10,914.22 -6,414.42 6,014,584.60 1,521,952.00 0.00 12,600.09 17,100.00 90.41 324.06 6,892.00 6,842.80 10,995.18 -6,473.10 6,014,666.43 1,521,894.54 0.00 12,700.09 17,200.00 90.41 324.06 6,691.29 6,842.09 11,076.15 -6,531.79 6,014,748.26 1,521,837.08 0.00 12,800.08 17,300.00 90.41 324.06 6,890.57 6,841.37 11,157.12 -6,590.47 6,014,630.09 1,521,779.62 0.00 12,900.08 17,400.00 90.41 324.06 6,889.85 6,840.65 11,238.08 -6,649.16 6,014,911.93 1,521,722.17 0.00 13,000.08 1/16/2017 1:20:23PM Page 6 COMPASS 5000.1 Build 74 Database: EDM Production Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD3 Fiord Pad Well: CD3 -111 Wellbore: Plan: CD3 -111A Design: CD3-111Awp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: SLB Standard Proposal Report Well CD3 -111 Plan:12.9+36.3 @ 49.20usft (Doyon 19) Plan:12.9+36.3 @ 49.20usft (Doyon 19) True Minimum Curvature Planned Survey TVD +NIS -E/-W (1) 0 Measured Vertical (usft) (usft) Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E1 -W Northing Easting DLS Vert Section (usft) (1) (usft) usft (usft) (usft) (usft) (usft) 6,840.00 17,490.58 90.41 324.06 6,889.20 6,840.00 11,311.42 -6,702.32 6,014,986.05 1,521,670.12 0.00 13..090.65 "TD: 17490.68' MD, 6889.2' TVD .4-1/2" x 6-118" Point 6,894.20 2,346.24 -1,451.87 Targets Target Name - hit/miss target Shape CD3-lllA 02 Tgtl 011017 JC - plan hits target center - Point CD3 -111A 01.Heel 011017 JC - plan hits target center - Point Dip Angle Dip Dir. TVD +NIS -E/-W (1) 0 (usft) (usft) (usft) 0.00 0.00 6,934,20 6,235.71 -3,023.29 Northing Basting (usft) (usft) 6,009,856.05 1,525,272.12 0.00 0.00 6,939.20 3,893.72 -1,574.20 6,007,492.74 1,526,685.72 CD3 -111A 03.71)011017 JC 0.00 0.00 6,889.20 11,311.42 -6,702.32 - plan hits target center Depth 6,015,043.52 1,521,751.96 - Point 6,014,957.32 1,521,629.20 CD3 -111A Polygon 011017 BP 0.00 0.00 6,894.20 3,946.35 -1,489.16 - plan misses target center by 109.55usft at 8471.70usft MD (6939.56 TVD, 3898.27 N, -1576.52 E) 6,889.20 4-1/2"x6-1/8" - Polygon 6-1/8 Point 1 6,894.20 0.00 0.00 Point 6,894.20 2,346.24 -1,451.87 Point 6,894.20 7,423.77 -5,132.19 Point 6,894.20 7,335.73 -5,253.65 Points 6,894.20 2,260.93 -1,575.27 Point 6,894.20 -78.93 -127.57 Casing Points 6,014,986.05 1,521,670.12 6,007,544.08 1, 526, 771.54 6,007,544.08 1,526,771.54 Casing 6,009,911.68 1,525,355.23 Depth 6,015,043.52 1,521,751.96 (usft) 6,014,957.32 1,521,629.20 6,009,828.24 1,525,230.57 7 6,007,467.08 1,526,642.81 6,889.20 4-1/2"x6-1/8" 4-1/2 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 8,466.57 6,939.20 7"x8-3/4" 7 8-3/4 17,490.58 6,889.20 4-1/2"x6-1/8" 4-1/2 6-1/8 1/162017 1:20:23PM Page 7 COMPASS 5000.1 Build 74 Database: EDM Production Local Coordinates Local Co-ordinate Reference: Company: ConocoPhillips(Alaska) Inc. -WNS +EbW TVD Reference: Project: Western North Slope (usft) MD Reference: Site: CD3 Fiord Pad -372.77 North Reference: Well: CD3 -111 -379.40 Survey Calculation Method: Wellbore: Plan: CO3-111A -391.70 3,033.81 Design: CD3-111AWp04 -422.01 6,794.89 Formations 2,677.11 -1,014.49 8,466.57 6,939.20 Measured Vertical Vertical -1,574.20 8,486.57 6,940.60 Depth Depth Depth SS -1,583.26 8,816.89 6,950.98 (usft) (usft) -1,745.59 Name 6,935.62 3,200.34 2,882.20 C-20 11,221.61 6,934.20 4,553.89 4,080.20 K-2 (Qannik) 17,490.58 6,889.20 6,276.89 5,605.20 AIb97 4,673.65 4,186.20 Base K-2 7,836.65 6,777.20 K-1 2,754.97 2,497.20 C-30 6,697.19 5,977.20 Nanuq 7,031.27 6,264.31 FCS HRZ Measured Vertical Local Coordinates Depth Depth +N/ -S +EbW (usft) (usft) (usft) (usft) 2,770.80 2,510.22 902.53 -372.77 2,800.80 2,535.02 918.05 -379.40 2,860.80 2,585.24 948.49 -391.70 3,033.81 2,734.81 1,029.87 -422.01 6,794.89 6,063.67 2,677.11 -1,014.49 8,466.57 6,939.20 3,893,72 -1,574.20 8,486.57 6,940.60 3,911.50 -1,583.26 8,816.89 6,950.98 4,198.77 -1,745.59 11,021.43 6,935.62 6,069.67 -2,911.57 11,221.61 6,934.20 6,235.71 -3,023.29 17,490.58 6,889.20 11,311.42 -6,702.32 Comment SLB Standard Proposal Report Well CD3 -111 Plan:12.9+36.3 @ 49.20usft (Doyon 19) Plan:12.9+36.3 @ 49.20usft (Doyon 19) True Minimum Curvature Lithology KOP: 2.8°/100' DLS, 170° TF, for 30' Adjust TF to 140°, for 60' Adjust TF to 173.37', for 173.01' Hold for 3761.08' Start 3.5°/100' DLS, -8.45° TF, for 1671.68' Hold for 20' Start 2°/100' DLS, -08.36° TF, for 330.31' Hold for 2204.54' Start 2°/100' DLS, -89.81 ° TF, for 200.18' Hold for 6268.98' TD: 17490.58' MD, 6889.2' TVD Dip Dip Direction 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.OD 1/18/2017 1:20.'23PM Page 8 COMPASS 5000.1 Build 74 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3 -111 Plan: C133 -111A 501032052600 CD3 -111 Awp04 Clearance Summary Anticollision Report 16 January, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -CD3 -111 -Plan: CD3-111A-CD3-111Awp04 Well Coordinates: 6,003,576.13 N, 1,528,201.08 E (70° 25' 08.70" N, 150° 54' 51.09" W) Datum Height: Plan:12.9+36.3 @ 49.20usR (Doyon 19) Scan Range: 2,770.80 to 17,490.58 usft. Measured Depth. Scan Radius is 1,945.43 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Failed Ani d'`on . ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for CD3 -111 - CD3-111Awp04 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -CD3 -111 -Plan: CD3-111A-CD3-111Awp04 Scan Range: 2,770.80 to 17,490.68 usR. Measured Depth. Scan Radius is 1,946.43 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited CD3 -114 -CD3 -114 -CD3 -114 2,771.35 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name CD3 -119 -CD3 -119 -CD3 -119 Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usit) (usft) usft 946.51 CD3 Fiord Pad 18.787 Clearance Factor Pass - Major Risk CD3 -121 -CD3 -121 -CD3 -121 2,771.67 417.03 2,771.67 CD3 -106 -CD3 -106 -CD3 -106 2,775.00 2,796.66 641.77 2,796.66 585.69 3,075.00 11.444 Centre Distance Pass - Major Risk CD3 -106 -CD3 -106 -CD3 -106 269.22 3,182.86 698.96 3,162.86 470.76 3,475.00 3.063 Clearance Factor Pass - Major Risk CD3 -106 -CD3 -106L1 -CD3 -10611 2,782.99 2,796.66 641.77 2,796.66 585.69 3,075.00 11.444 Centre Distance Pass -Major Risk CD3 -106 -CD3 -106L7 -CD3 -10611 1,144.67 3,182.86 698.98 3,182.86 470.76 3,475.00 3.063 Clearance Factor Pass - Major Risk CD3 -108 -CD3 -108 -CD3 -108 2,774.87 2,767.33 1,786.25 2,787.33 1,730.06 3,475.00 31.790 Clearance Factor Pass - Major Risk CD3 -109 -CD3 -109 -CD3 -109 CD3 -130 - CD3-130PB2 - CD3-130PB2 2,774.88 1,263.69 2,774.88 1,210.13 3,175.00 23.596 Clearance Factor Pass - Major Risk CD3 -110 -CD3 -110 -CD3 -110 Pass - Major Risk 2,773.91 636.78 2,773.91 784.39 2,950.00 15.972 Centre Distance Pass - Major Risk CD3 -110 -CD3 -110 -CD3 -110 Centre Distance 3,084.22 945.33 3,064.22 756.08 3,225.00 4.995 Clearance Factor Pass - Major Risk CD3 -111 -CD3-111 -CD3-111 CD3 -111 -CD3-111 -CD3.111 1297 Clearance Factor Pass - Major Risk CD3 -301 -CD3 -301 -CD3 -301 r Risk 929.66 2,770.80 874.43 2,950.00 16.832 Clearance Factor Pass -Major Risk isk CD3 -111 -CD3 -111L -CD3 -1111-1 CD3 -111 - CD3 -11 -CD3 -1111-1 ® 2,778.40 877.79 2,950.00 16.732 Clearance Factor - CD3 - -l -112 - CD3.112 -CD3-712 2,793.90 569.11 2,793.90 511.42 2,875.00 9.865 Centre Distance Pass - Major Risk CD3 -112 -CD3 -112 -CD3 -112 3,106.68 660.41 3,106.68 455.44 3,200.00 3.222 Clearance Factor Pass - Major Risk CD3 -113 -CD3 -113 -CD3 -113 2,782.D6 1,032.16 2,782.06 977.19 3,150.00 18.776 Clearance Factor Pass - Major Risk CD3 -114 -CD3 -114 -CD3 -114 2,771.35 1,572.76 2,771.35 1,516.41 3,425.00 27.912 Clearance Factor Pass - Major Risk CD3 -119 -CD3 -119 -CD3 -119 2,770.80 999.72 2,770.80 946.51 3,125.00 18.786 Clearance Factor Pass - Major Risk CD3-119-CD3-119PB1-CD3-119PB1 2,770.80 999.72 2,770.80 946.51 3,125.00 18.787 Clearance Factor Pass - Major Risk CD3 -121 -CD3 -121 -CD3 -121 2,771.67 417.03 2,771.67 362.47 2,775.00 7.644 Centre Distance Pass - Major Risk CD3 -121 -CD3 -121 -CD3 -121 3,195.36 498.49 3,195.36 269.22 3,225.00 2.174 Clearance Factor Pass - Major Risk CD3 -122 -CD3 -122 -CD3 -122 2,782.99 940.25 2,782.99 884.93 2,950.00 16.997 Clearance Factor Pass - Major Risk CD3-123-CD3-123-CD3.123 2,779.41 1,144.67 2,779.41 1,087.43 3,025.00 19.999 Clearance Factor Pass - Major Risk CD3 -130 -CD3 -130 -CD3 -130 2,774.87 695.36 2,774.87 641.40 3,200.00 12.868 Clearance Factor Pass - Major Risk CD3 -130 - CD3-130PB2 - CD3-130PB2 2,774.86 695.34 2,774.86 641.54 3,200.00 12.925 Clearance Factor Pass - Major Risk CD3 -199 -CD3 -199 -CD3 -199 2,794.00 279.49 2,794.00 229.39 2,925.00 5.579 Centre Distance Pass - Major Risk CD3 -199 -CD3 -199 -CD3 -199 7,268.38 346.92 7,268.38 79.46 7,875.00 1297 Clearance Factor Pass - Major Risk CD3 -301 -CD3 -301 -CD3 -301 2,770.80 929.66 2,770.80 874.43 2,950.00 16.832 Clearance Factor Pass -Major Risk CD3 -301 -CD3 -301A -CD3 -301A 2,778.40 933.58 2,778.40 877.79 2,950.00 16.732 Clearance Factor Pass - Major Risk 16 January, 2017 - 13.21 Page 2 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for CD3 -111 - CD3-111Awp04 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3.111 - Plan: CD3.111A-CD3-111AWp04 Scan Range: 2,770.80 to 17,490.68 usft. Measured Depth. Scan Radius is 1,946.43 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 16 January, 2017 - 13:21 Page 3 of 6 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft CD3 -301 - CD3-301APB1 - CD3-301APBI 2,778.40 933.58 2,778.40 877.76 2,950.00 16.725 Clearance Factor Pass - Major Risk CD3 -301 -CD3 -301 FBI -CD3 -301 P81 2,770.80 929.66 2,770.80 874.58 2,950.00 16.879 Clearance Factor Pass - Major Risk CD3 -302 -CD3 -302 -CD3 -302 2,787.90 1,164.50 2,787.90 1,112.74 3,100.00 22.501 Centre Distance Pass - Major Risk CD3302-CD3.302-CD3-302 3,192.19 1,242.65 3,192.19 1,033.01 3,425.00 5.927 Clearance Factor Pass - Major Risk CD3-302-CD3302A-CD3-302A 2,794.78 1,269.22 2,794.78 1,216.73 3,150.00 24.183 Centre Distance Pass - Major Risk CD3 -302 -CD3 -302A -CD3 -302A 2,876.46 1,300.31 2,876.46 1,214.71 3,200.00 15.190 Clearance Factor Pass - Major Risk CD3-302-CD3-302P81-CD3-302PB1 2,793.91 1,213.15 2,793.91 1,160.97 3,125.00 23.245 Centre Distance Pass - Major Risk CD3 -302 - CD3-302PBI - CD3-302PB1 3,047.39 1,296.93 3,047.39 1,135.81 3,300.00 8.049 Clearance Factor Pass - Major Risk CD3 -302 - CD3-302PB2 - CD3-302PB2 2,793.91 1,213.15 2,793.91 1,160.97 3,125.00 23.245 Centre Distance Pass - Major Risk CD3 -302 - CD3-302PB2 - CD3-302PB2 3,047.39 1,296.93 3,047.39 1,135.81 3,300.00 8.049 Clearance Factor Pass - Major Risk CD3 -302 - CD3-302PB3 - CD3-302PB3 2,787.90 1,164.50 2,787.90 1,112.65 3,100.00 22.459 Centre Distance Pass - Major Risk CD3 -302 - CD3-302PB3 - CD3-302PB3 3,192.19 1,242.65 3,192.19 1,032.91 3,425.00 5.925 Clearance Factor Pass - Major Risk Plan :CD3 -129 -Plan: CD3-129-CD3-129wp07 2,783.16 1,094.77 2,783.16 1,038.89 3,375.00 19.592 Clearance Factor Pass - Major Risk Survey too/ orogra111 From To Survey/Plan Survey Tool (usft) (usft) 80.80 441.80 CB -GYRO -SS 568.75 2,770.80 MWD+IFR-AK-CAZ-SC 2,770.80 3,120.80 CD3-111Awp04 INC -TREND 3,120.80 4,620.80 CD3-111AWp04 MWD 3,120.80 8,466.57 CD3-111Awp04 MWD+IFR-AK-CAZ-SC 8,466.57 9,966.57 CD3-111Awp04 MWD 8,466.57 17,490.56 CD3-111AWp04 MWD+IFR-AK-CAZ-SC 16 January, 2017 - 13:21 Page 3 of 6 COMPASS Centre to Centre Separation Centre to Centre Separation 0 0 CD o o o_ m V 0 TTNN T TTOOO TOS ^ o VVOOO NOB _ _. g`'�. CO3-199 d_ __ 1pC :3 �_'.. tOTTNNV� A d -_ OTT000- 6 TCT (0 W CU Co 00 .y -_ A c0a.111L1 00000000 O ,- 0000000c c J7 o - WwWWwwWz d o __ FDDDDD�+� :E rp - - aaaAAo� < U) 7 DG) A 00000{ O �o - 000000M wwwwwDQ +� - -�CO(n m DDDDDOn A i d 0� a 0 w g 0 m d 0000 ut + 00 y m =9;0 m N 3 ;a.. m 0DT.Q i 0 SD. x O o - D D o N N N i o Q n • E Q 0 0 r c S m�0 Ill, i m IV IJ W a0 N 7 o i o \SV m �rn D m rn o x W V O z O N M K q O N ry o m 0 - -_ x x — -coo-nv m Q w Z o �w°1 • OOA� TCR required CD3 -111 Awp04 2770.80 To 17490.58 13:30, January 16 2017 CASING DETAILS TVD ND Nanie 6939.20 8466.57 Tx 8-314" 6889.20 17490.58 4-112" . 6-118" mm MD Inc Azi TVD 2770.80 34.64 336.75 2510.22 2800.80 33.82 337.01 2535.02 2860.80 32.55 339.02 2585.24 3033.81 27.74 340.22 2734.81 6794.89 27.74 340.22 6063.67 8466.57 86.00 333.00 6939.20 8486.57 86.00 333.00 6940.60 8816.89 90.40 328.07 6950.98 11021.43 90.40 328.07 6935.62 11221.61 90.41 324.06 6934.20 17490.58 90.41 324.06 6889.20 0/360 Dleg TFace Targ 0.00 0.00 - 3340 2.80 170.00 3530 2.80 140.00 3910 2.80 173.37 4100 - 0.00 0.00 5230 3.50 -8.45 CD3 -111A 01.Hee1 011017 JC 0.00 0.00 6910 2.00 -48.36 7470 - 0.00 0.00 8600 2.00 -89.81 CD3 -111A 02.Tgtl 011017 JC 0.00 0.00 CD3 -111A 03.TD 011017 JC vveus uus- i .i i and CD3 -111 L1 turned off in this view, only to show which other offset wells are in the 2771 -- 2960 2960 3150 3150 - 3340 3340 3530 3530 3720 3720 3910 3910 --- 4100 4100 - 4660 4660 5230 5230 5790 5790 6350 6350 6910 6910 - 7470 7470 - 8040 8040 8600 8600 9710 9710 10820 0820 - ""- 11930 1930 - 13040 3040 " 14160 4160 15270 5270 16380 6380 17491 -180/ 180 M January 16 CD3-111Awp 4 CD3 -11 D3 -111L CD3 -111 CD3 -112 `\C\D3 113 CD3 -114 \ CD3 -118`\CD3 -115 CD3 -117 CD3 Fiord Pad Easting (3500 usftlin) CD3 -1 CD3 -109 d06 D3-11 CD3 -199 CD3 -121 CD3 -122 CD3 -123 Easting (3500 usttlin) 1 CD3 -316 CD3 -307 CD3 -316A CD3 -303 CD3-305PB1 CD3 -304 �c S AC Flipbook ConocoPhillips(Alaska) Inc. MNS Western North Slope CD3 Fiord Pad CD3 -111 501032052600 Plan: CD3 -111A Plan: CD3-111Awp04 Error Ellipse Survey Report 16 January, 2017 Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CD3 Fiord Pad Well: CD3 -111 Wellbore: Plan: CD3 -111A Design: CD3-111Awp04 Survey Tool Program Date 1/16/2017 From To (usft) (usft) Surrey(Weiibone) SLB Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: 80.80 441.80 CD3 -111 Srvy 1 CB -GYRO -SS (CD3 -111) 568.75 2,770.80 CD3 -111 MWD+IFR-AK-CAZ-SC (CD3 -111 2,770.80 3,120.80 CD3-111Awp04 (Plan: CD3 -111A) 3,120.80 4,620.80 CD3-111Awp04 (Plan: CD3A11A) 3,120.80 8,466.57 CD3-111AWp04 (Plan: CD3 -111A) 8,466.57 9,966.57 CD3-111Awp04 (Plan: CD3 -111A) 8,466.57 17,490.58 CD3-111Awp04 (Plan: CD3 -111A) Well CD3 -111 Plan:12.9+36.3 @ 49.20usft (Doyon 19) Plan:12.9+36.3 @ 49.20usft (Doyon 19) True Minimum Curvature 1.00 sigma EDM Production Tool Name Description CB -GYRO -SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC INC+TREND Inclinometer + known an trend MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Position uncertainty and bias at survey station Measured Orciination A imud, Vertical Highs Lateral Vanipl Ma8n6ude Serni .pr S.Mi Mm Uepth Deptb Error BMs Error Bias Error BMs of Bias Error Error Aa9neM Tod (nsn) (11 (') 11 ) (lul) W) (-s) (um) (.00 (use) Inan) (uso) (use) (1) 277080 34.64 33575 2.510.22 291 -0.09 538 0.01 1]3 078 0.89 5.38 2,78 154.66 MWD*IFRAWCA -SC (1 2) 280080 33.82 337.01 2.535.02 294 0.08 633 000 1.73 080 0.91 633 2.82 15545 INC+TREND(1, 3) 2.66080 32.55 339.02 2,565.24 3.13 -008 1]07 -0.01 1.82 On 0.95 17ce 2.94 157.56 INC+TREND(1, 3) 3,03381 27.74 340.22 2,734.91 4.23 0.02 W62 -0.02 2.30 093 107 50.63 3.72 158.97 INC+TREND(1. 3) 3,200.34 27.74 340,22 2,882.20 505 002 71.81 -006 2.60 1.04 1.19 71.82 4.43 15934 MWD (1, 4) 4.553.09 27.74 34022 4,00020 502 002 72.90 -1.12 308 2.18 2.72 72.91 5.13 159.35 MWD (1, 4) 4,67365 27.74 34022 4.188.20 5A6 002 7205 4.02 2.94 2.28 2.59 7208 4.81 159.34 MW0HFR-AK-CA-SC(2,4) 6,276a9 27.74 340.22 5180520 6.57 002 7261 -0.02 3.51 4.12 467 7282 5.80 159.31 MWD+1FR-AI60A2-SC(2,4) 8.897.19 27.74 340.22 5,9820 6.92 0.02 7280 -002 369 4,67 529 72.81 6.12 159.30 MWDNFR-AK-CA-SC(2,4) 6,794.89 27.74 340.22 6,08367 7.00 002 72.04 -002 3.73 4.80 5.44 72.85 6.19 15930 MWD.IFR-AK-CA-SC(2,4) 7,031.0 35.94 330.15 6,264.31 7.29 -1.02 73.01 0.09 3.87 5.21 5.92 73.04 6.46 15929 MWDHFR-AK-CALSC(2,4) 7,838.65 64.01 334.64 6.777.20 7,09 -3.93 73.60 029 4.51 5.94 7.01 73.85 7.00 16822 MWDNFR-AK-CAZ-W(2.4) 9,68857 W.W 33300 6,93920 5.55 -578 74.23 025 5.07 6.10 7.50 7465 7.54 159.13 MWD (2. 5) 9.406.67 88.00 333.00 6,94060 5.55 -570 7427 0.16 667 CIO 7,51 74.70 7.54 159.13 MWD (2,5) 0,818.09 WAO 328.07 6,950.98 522 -6.14 7427 -0.03 528 6.11 7.77 75.62 7.64 15899 MWD(2. 5) 11.021,43 9040 328.07 6.93562 6.84 4.14 76.24 0,77 6.87 6.10 9.67 77.51 8.21 158.53 MWDHFR-N(-CPZ-SC(3, 5) 11,221.61 9041 324.W 6,936.20 L09 5.14 7540 1.24 7.12 6.10 921 77.81 8.29 15645 MW IFR-AK-CAZ-SC(3,5) 17,49058 90.41 924,5 6.88920 16.99 -6.14 93.37 124 17.00 805 13.93 94.05 12.92 15435 MWD.IFR-AK-CAZ-=(3, 5) 1/162017 1:49:40PM Page 2 COMPASS 5000. 1 Build 74 Pool Report CD3-111AwPO4 Surface Location Cj. CPAI Coordinate Co -- -From: --- ------ ------ To: Datum; NAD83 Region FlaskDatum: NAD27 . Region: alaska r Latitude/Longitude iDecimalDegfees . r Latitude/Longitude Decimal Degrees + C UTM Zone: f— r South r UTM Zone: True r- South r State Ptane Zone: F-----3 Units: us -ft r- State Plane Zone: F—�-] Units: us -ft . C Legal Description (NAD27 only) r- Legal Description (NAD27 only) r Starting Coordinates: --- Ending Coordinates: - x 1528201.08 x- 388169.168969377 Y: 6003576.13 Y: 6003828.92240073 Transform Quit Help CD3-111Aw 04 Surface Location n CPAI Coordinate Converter. �-From: ---_. _.---- To: — i Datum: NAD83 Region: alaska . Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees r Latitude/Longitude IDecimalDegrees + j C" UTM Zone:1 — r South !" UTM Zone: True r South 6 State Plane Zone: q Units: us -ft r State Plane Zone: F--] Units: us -Ft . C Legal Description (NAD27 only) r Legal Description (NAD27 only) rStarting Coordinates: Legal Description-------- p 012 X 1528201.08 Townshi N . Range: 005 E F 1 Y: 16003576.13 Meridian: U � Section:F5— I FNL . 3945.7416 FEL .-j 1674.37201 �_, Transform— Quit Help ,jCD3-111Awp04 Surface Casing M . CPAI Coordinate Convener Datum: D83 Region: alaska F6837 C Latitude/Longitude IDecimalDegfees r UTM Zone: [_ r South f• State Plane Zone: 4 - Units: us -ft r: Legal Description (NAD27 only) Starting Coordinates: X: 11527852 92 Y: 16004457.80 CD3-111Aw 04 SurfaceCasing d CPAICoordinate Corn.,erter F Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees r" UTM Zone: True r South 0 State Plane Zone: F___-3 Units: us -ft C Legal Description (NAD27 only) Ending Coordinates:— X: 387821.032448181 Y: 6004710.61055531 Transform Hel ❑ J................................................. Quit Datum: NAD83 Region: jalaska j (Latitude/Longitude Decimal Degrees D r UTM Zone: I r South r State Plane Zone: q Units: us -ft C Legal Description (NAD27 only) Starting Coordinates: - X: 11527852.92 Y: 16004457.80 -To: Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees t"- UTM Zone: True r South C State Plane Zone: rq7:-:1 Units: us -ft {7 Legal Description (NAD27 only) Legal Description— --- --------------- Township: Fo—l2FN—,-1 Range: 005 E Meridian: U SectionF5 FNL 3069.3050 FEL - 1233.122] Transform Quit Help CD3-111Awp04 Kick-off Point Datum:NAD83 Region: alaska r Latitude/Longitude IDecimalDegrees J r UTM Zone:— r South r State Plane Zone: F-----] Units: us -ft (– Legal Description (NAD27 only) Starting Coordinates: – -- 5C 11527841.95 Y: 16004484.00 Datum NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees —� r UTM Zone: True r South C•' State Plane Zone: F__-] Units: us -ft (– Legal Description (NAD27 only) Ending Coordinates: X: 387810.063150174 Y: 6004736.89112077 – ( ................-Transform,...,,.._,..., Quit Help j,CD3-111Awp04 Kick-off Point IM CPAt Coordinate Convert -From: -------------- Datum: NAD83 Region: alaska C' Latitude/Longitude Decimal Degrees I i Y` UTM Zone: r`— r South t State Plane Zone:Iq ---J Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: X: 11527841.95 Y: 16004484.06 -To: --------____.. _.-- Datum: NAD27 Region:alaska f Latitude/Longitude IDecimalDegrees r UTM Zone: True r South T State Plane Zone:I' � Units: us -ft r Legal Description (NAD27 only) Description — ---- -------- Township: 012 N Range: o05 E Meridian:U - Section: 5— FL 3043.1937 FEL 1244.4102 ��_.__Transform__Y_ Quit Help CD3-111Awp04 To of Production f-11 CPAI Coordinate Converter o From: -------._.----—...--- To: ---- — ----.. _.__, Datum: NAD83 Regions alaska Datum: NAD27 . Region: alaska r Latitude/Longitude iDecimalDegrees . r Latitude/Longitude IDecimalDegrees, r UTM Zone: r— F- South C UTM Zone: True r South P State Plane Zone: F-----3 Units: us -ft . G State Plane Zone: F-----3 Units: us -ft r" Legal Description (NAD27 only) C Legal Description (NAD27 only) I _ r Starting Coordinates: — Ending Coordinates: --- -- X: 1526665.72 X: 366653.91300399 — Y: 16007492.74 Y: 6007745.6116636 (Transform � Quit Hel p I CD3-111Aw 04 To of Production Q CPAI Coordinate Converter rfa-,•0-. From: To:— Datum: NRD83Region: jalaska . Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees r Latitude/Longitude IDecimalDegrees r UTM Zone: r-- r- South r UTM Zone: True r South f: State Plane Zone: 4 , Units: us -ft r~ State Plane Zone: F-----] Units: us -ft I i ! _. al Deaaiption 111AD27 onDrl l: Legal Description (NAD27 only) Starting Coordinates:— -- -- Legal Description--- X: escription X: 11526685.72 Township: 012 N . Range: 005 E Y: 6007492.74 Meriden: U Section: F FNL 52.033558 FEL 2436.7894 Tranorm Quit Help jCD3-111Awp04 Intermediate Casing I fj CPA] Coordinate Converter Datum: NRegion: a AD83 laska . r Latitude/Longitude IDecimalDegrees r UTM Zone: r South C State Plane Zone: 4 Units: us -ft . r Legal Description (NAD27 only) Starling Coordinates: Y 1526685.72 Y: 160074S2.74 Datum: NAD27 Region: alaska r' Latitude/Longitude IDecimaiDegrees r UTM Zone: True r South C•- State Plane Zone: q - Units: us -ft . r" Legal Description (NAD27 only) Ending Coordinates: X 386653.91300399 Y: 6007745.6116636 I_...............Transform................; Quit Help jCD3-111Aw 04 Intermediate Casing I r Q CPAI Coordinate ConverteYv ItP�l��i From: -- Datum: NAD83 Region: alaska C Latitude/Longitude IDecimaiDegrees t- UTM Zone: r- r South C. State Plane Zone: q Units: us--ft--,l r Legal Description [NAD27 ontd) - S tatting Coordinates: - ----- X: 11526685.72 Y: 16007492.74 i To:— Datum:NAD27 Region: alaska r Latitude/Longitude IDecimalDegfees r UTM Zone: True r South i" State Plane Zone: F-----3 Units: us -ft . (- Legal Description (NAD27 only) Legal Description Township: 012 N . Range: 005E . Meridian: U Section: r5 FNL 52.033558 IFEL 2436.7894 Transform _1 Quit Help CD3-111AwPO4 TD d CPAI Coordinate Con - From: ---... To: Datum: NAD83 Region: alaska 1 Datum: INAD27 I Region: lalaska r Latitude/Longitude IDecimalDegteas Latitude/Longitude IDecimaiDegtees C UTM Zone:I - r South C UTM Zone: True r South r State Plane Zone: q Units: us -ft C State Plane Zone: r4 Units: usFt C Legal Description (NAD27 only) f Legal Description (NAD27 only) - Starting Coordinates: Ending Coordinates: -- ------ X: 11521670.12 X: 381638.519821384 y 16014986.05 Y: 6015239.15965693 -- .- p Transform ._._._.__._._......_........................... Quit Help CD3-111Aw 04 TD [^� CPAI Coordinate Converter From- To: ----- To: Datum: NAD83 Region: alaska . Datum: NAD27 Region. alaska C Latitude/Longitude �Decima-1 De rees�Latitude/Longitude Decimal Degrees :_ f UTM Zone: F_ r South C" UTM Zone: True r- South i ! C•` State Plane Zone: F___-3 Units: usft D r State Plane Zone: Iq E Units: us ft D C Legal Description (NAD27 only) r Legal Description (NAD27 only) I _ r Starting Coordinates: Legal Description — X: 1521670.12 Township: 013 [R-3, Range: 005 Y 6014986.05 Meriden: �� Section: 30 FNL 3196.6435 FEL - 4902.3004 Transform Quit Help 16:26, January 16 2017 CD3-111Awp04 No, WELLBORE TARGET DETAILS (MAP C6ORDINATES) WD Phane Quarter Mile View CDSfl1A CDS111A CDS111A CDSN1A 01 Hee101101]JC 02.Tg11011017 JC 03.TD01101] C 91eeIC9Ue 6939.20 P.,nt 6939.20 Point 6009.20 Point 6939.20 Dtrde 132Up0) ODSI1A PUygon011017 BP (Re6ius: 6690.20 Polygon CDS111A Toe CnUe 6609.20 Clrcle (Re6iu5'. 1320.09) 15000 0031 ^00 i - ', G03•�p6�1 003 - I 12500 O C 0000 D3 07L1 7- 3.11'1-_. — 33g,� CO n d - ',.. j ^69 C,03162 N 003 .F GO,S.1 II. lt7500 �'! Z 7 U)5000- I W — -- X307- -- -. -- �1y 003 i � eg1 i 2500 160 3 110 I � 0' 00 , 3 ,ryti I, ' 00 0031'4 003199 -10000 -7500 -5000 -2500 0 OAe1 2500 5000 7500 10000 15:32, January 16 2017 w� ORE TARGET' DETALLS (MAP Co-OMNATesl CD3-111Awp04 RAme Tw p ml, CD1111A IA 03.M 111177 JC 69]8.20 Point CM111A 02.TgI1 011017 JC 8.4120 pent hM Quarter Mile View CDY A Xeel CeF 17 C 6Ng6838.20 CIm10 (Rselus 13M.00) CD3.111A Polypon 011017 BP 6684,20 Polygon CD0.111A Toe Ckpk 6869.20 Cncls (Radius, 1320.00) 15000 12500 - - --._ Go oA• � j _ I 90000- LO 000 N GO 1111 t7500- - z U) 5000 t - -- - - I : i 2500 OA ` G GOA -10000 -7500 -5000 -2500 0 2500 5000 7500 10000 CD3-111Awp04 Section View C� Itj 6840- 840 6880- 68804to m6920 4 r O t _N O pl o 0 p m UC) o O 4-1/2" x 6-1/8" ' U o O 3 Q o p _ m 0 ri 0o H 6960 0 Q 7" x 8-3/4" 7000 rn W 0 U 7040- 3000 4500 6000 7500 9000 10500 12000 13500 Vertical Section at 324.000 D3-111 AWD04 I 3-C I Tollerable Collision Risk Worksheet As -built REVI DATE 1BY1 CK 1APP1 DESCRIPTION IREVI DATE I BY I I � iAPP DESCRIPTION 1012/2/111 CZ I DB I C.A. I UPDATED PER K110003ACS ill 14/11/111 CZ I GD I C.A. UPDATED PER K110003ACS ALL CONDUCTORS WELL Y' ARE LOCATED IN PROTRACTED SEC.5, T 12 SEC.LINE X' LAT.(N) LONG.(W) FSL N, R 0 S EL 5 E, GND U. M. EXIST PAD CD3-198 003 630.37 1,528.434.35 70' 5' 0 150' 54 44.278 7.3 12.5 CD3-199 6,003,625.99 415.38 5' 09.221" 150' 54' 44.833" 7.3 12.8 CD3-301A 6,003,621.33 1 5 9 .56 ' 25' 09.1 150' 54 45.411" 7.3 13.5 CD3-302A 6,003,616.72 1 528 376.38 25' .124" 150' S4' 45.972 377' 700' 7.3 13.2 CD3-303 6,003,612.52 28 356.72 5' 150' 54' 46.547" 13 7.3 13.3 CD3-304 3 607.82 1 528 337.04 ' 25' 9 nil 150' S4' 47.122 1368' 739' 7.3 13.4 CD3-305 6,003,603.48 1 5 8 317.56 70* 150' 54' 47.691" 1363' 7.3 13.6 CD3-106 3 599.3 1 528 29 .3 ' 5' 8.9 150' 54' 48.252 1359' 777' 7.3 13.4 CD3-107 6,003,594.38 1 528 278.93 70' 25' 08.890" 150' S4 48.820 1354' 797' 7.3 13.2 CD3-108 6,003,589.85 1 5 8 59.61 150' 54' 49.385 1349' 816' 7.3 CD3-109 6.003.585.27 1 528 239.85 70' 25' 08.794" 150' 54 49.962 1344' 836 7.3 13.1 CD3-111 6,003,576.13 1 528 201.0 70* 25' 08.699" 150' 54' 51.095 1334" 4' 7.3 12.9 CD3-113 6,003,567.62 1 528 161.38 70' 25' 08.609' 150' 54 52.255 1325' 914' 7.3 CD3-114 6,003,563.04 1 p 528 142.21 70' 25' 08.561" 150' 54 52.815 1320' 933' 7.3 CD3-115 6,003,558.57 1 528 122.60 70' 25' 08.515" 150' 54 53.388 1,315' 7.3 CD3-316A 6,003,554.04 1 528 103.39 ' 0 .467" 150' 54 53.950 1311' 972' 7.3 13.9 CD3-117 6,003,549.51 1 528 083.99 0' 25' 08. 150' 54 54.516 1 7.3 CD3-118 6.003.544.88 1 528 064.44 ' 25' 08.372" 150' 54' 55.086 1301' 1011' 7.3 12.8 CD3-X19 16.003.540.17 1.528.044.86 150' 54 55.660 7.3 12.8 CD3-X2016.003.535.95 1.528.025.39 150' 54' 56.229" 7.3 12.6 CD3-121 6,003,531.41 1 528 006.04 150' 54 56.794" 7.3 12. CD3-122 6 003 527. 1 527 986.67 150' S4' 57.360 7.3 126 CD3-123 6,003.52Z43 1 527 967.12 150' 54' 57.932" 7.3 12.6 CD3-124 6,003,518.17 527 947.59 091" 150' 54' 58.502 7.3 125 CD3-125 6,003,513.62 1 27.89 5' 150' 54' 59.078" 7.3 12.6 CD3-X26 6,003,508.97 527 908.70 0' 25' 07.995" 150' 54' 59.639' 7.3 CD3-127 6,003,504.45 1 .527.889.34 70' 5' 7. 150' 55' 00.204" 7.3 126 CD3-128 6,003,500.08 1 527 870.01 .90 " 150' 55' 00.769 7.3 12.6 CD3-X29 6 003 495.32 1 7 850.64 7 ' 150' 55' 01.335" 7.3 12.6 CD3-X30 6 003 490.74 1 527 831.05 0' S' 0 150' S5' 01.908' 7.3 12.5 CD3-X31 6,003,486.58 1 27 11.73 7 150' 55 02.472 7.3 12.3 CD3-X32 6,003,482.02 1,527.792.33 0' 5' 7. 150' 55' 03.039 7.3 .1 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) CenocePhillips Alaska, Inc. ALPINE MODULE:CD30 ALPINE PROJECT CD-3 WELL CONDUCTORS AS-BUILT LOCATIONS UNIT: CD CADD FILE N0. 05-03-03-1A-2 3-17-05 DRAWING N0: CE-CD30-111 PART: 2 OF 3 REV: 11 REV 11 ATE IBY ICKIAPPI DESCRIPTIONvi DATE I BY I i,_ APP DESCRIPTION 8 5/12/10 1 CZ I GD I C.A. I UPDATED PER K100002ACS 9 4/11/11 1 CZ I GD I C.A. I UPDATED PER K110003ACS N 0 R 51 0- 0 T L CD3 LOCATION OF y PNN THIS SURVEY z PIN ALPINE SATELLITE DEVELOPMENT I TI'N VICINITY MAP NOT TO SCALE OF PAO DEgGN SHDUlOER CD -3 CD34 PAD a$mm �NJE 1T DN D31 C00 CAl g3� NO 888_$$$ ig8_ 8 �o GENERAL R p35 g8888888.i-='•__,•__-" UCON •_ PRH3 BATOR 88 • • _ -' SEP CD3C G 5K1D M00� E CDffid WP ENpUSE PLANT N CD3NNCy ANC EMERA tERS pU 13'00'00' w w UI N LEGEND: 0 O PROPOSED CONDUCTOR .� w �� N N • EXISTING CONDUCTOR �A ZT r ON v Z V o� 0 0 GKUUKPIK ou L.CMFuz "o 1W E61VMe.MYegYW WIO IWII ZIYI� N{F.OAYe pn�ewA Alpine Survey Office ALPINE MODULE:CD30 UNIT: CD ConocoPhillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. 05-03-03-1A 11/3/02. DRAWING NO: CE—CD30-111 PART: 1 OF 3 REV: 9 6 14/17/101 CZ I DB I C.A. I UPDATED PER K100003ACS 17 14/11/11 I CZ I DB I C.A. I UPDATED PER K110003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD -3 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, MARCH 2005 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS CD3 -108, CD3 -109, CD3 -110, CD3 -111, 3/16/05, FB 2005-08 PGS 52-53; CD3 -301, CD3 -302, 3/19/05, FB 2005-09 PGS. 24-25; CD3 -304, 4/16/05, FB 2005-12 PGS 35-37. CD3 -303 2/10/06, FB 2006-03 PG 11. CD3 -112, 2/23/06, FB 2006-05 PGS 29-31. CD3 -107, 3/26/06, FB 2006-09, PGS.9,25-27. CD3 -305, CD3 -106, CD3 -113, CD3 -114, CD3 -115, CD3 -116, CD3 -117, 5/2/06, FB 2006-11 PGS 57-61; CD3 -X18, 4/7/07, FB 2007-07 PG. 67; CD3 -X98, CDX-99, CD3 -X19, CD3 -X20, CD3 -X21, CD3 -X22, CD3 -X23, CD3 -X24, 4/13/09, FB 2009-05 PGS. 70-72; CD3 -X25, CD3 -X26, CD3 -X27, 4/16/10, FB 2010-03 PGS. 62-63; CD3 -X28, 4/6/11, FB 2011-05 PG. 18; CD3 -X29, CD3 -X30, 4/8/11, FB 2011-05 PG. 24; CD3 -X31, CD3 -X32, 4/10/11, FB 2011-05 PG. 29. �'•5 PSE OF Atq;'Q �1 *r 49th SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE: REGISTRATION NO. LS -5077 a Donald G. Bruce f i : i •••,n�F9% %... No... LS -5077 " 4J r KUUKPIK m ana.a..wno.o..0.a xew. Pmmaaano LCMFuc ry,.as. wrem.r» SAIpine Survey Office ALPINE MODULE:CD30 UNIT: CD ConocoPhillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE N0. I DRAWING NO: PART: REV: 05-03-03-1A-3 3-17-05 CE-CD30-111 1 3 OF 3 7 Haagen Dazs Necessary Plan Request (NPR) ■ Tier 1: Standard Section ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30° of horizontal inclination AND drilling within 30°of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges ■ Tier 1: ■ Directional interval across which no special mitigations are needed ■ Tier 2: ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3: ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4: ■ Consider all Tier 2 & 3 mitigations String: 7' Intermediate Stage 2 Well Name: CD3-1I1A Company: CPAI Field: Alpine Contact: Weifeng Dai Well Location: Alpine Proposal Number: 1 Date: 1/9/2017 Made By: Stephen Lauper Service from District: Prudhoe Bay District Phone: (907)659-2434 Objective: Place 700 -ft of Cement around the stage collar to isolate the Qannik Acceptance Criteria: Pump per program (Density, Volume, Rate) D,:d&..r N..,H &Hi-.lAm.."th:eoomml.rim me W...hs&UBmml. a —...6 w.nem peas.[ mleiFIm Rmhwwrenn � wTEI.R, maT.mwamml.ry.Nml ,aryb�I pm�flH.eslmiMN� m Schlumberger moansmw vmmn, eu.wDms ew mMma:mel ere mm NmwNe. G4ealmx ve eamales hauD m pmiD. AApnwDm. AN wwuws.lemmmmmlrym. v peeiuims are oo�ims mry. NJ WMANitt6fNENCOKFANNG ACCIIflA[VOHCOMFIEIENESS Cf pAi0. WfOAMAiY]NEAESENRfl FFff7MHF550MATEFRX, FAODVTS OR FUMES RE OM MW MONS MME, OR FESMS Of THE KNEES RENDERED h---.inhnganml Ma-HR..IF,1111..fSnLnmmpnp o.1,11o1 m brimmed.. F. i.e11 ¢I piup1,0...... dtvd The cementing program incorporates the following data : Ri T e Land Fluids Return to Ri Floor BHST I 99 de F Well Data Summary All depths take the rig floor as reference Mud Line De th 0.0 ft Mud Return De th 0.0 ft Section MD 8454.0 ft Section TVD 6949.5 ft Prev Casing 2720.0 1 95/8 1 40.0 1 40.0 1 8.835 L-80 2780 4920 Official 114.0 1 16 1 40.0 1 65.0 1 151/4 H-40 630 1640 Official Casing 4700.0 1 7 40.0 1 26.0 1 6.276 1 L-80 1 4870 6210 Off tial Landing Collar I 4690.0 Serial number Float Shoe M Op Inclination (deg) HttizorRal Departure (ft) a NI 40 as RO irO n 1. . . n. 11m — HorvOnta DeQartwe Im Qs >e 2 of 16 Schlumherger Total Volume 447.7 bbl Minimum Diameter 8.750 in Maximum Diameter 8.750 in Mean Diameter 8.750 in Mean Annular Excess 40.0% Mean Equivalent Diameter 8.965 in wo rvc all 0 0 0 -32 M M Iblgal 9.5 10 10.5 11 11.5 12 12.5 13 Formation Frac Pore Top Bottom Bottom Frac Bottom Pore Bottom Res. MD MD TO Top ED ED Top ED ED Lithology Fluid Name ft it ft Ib/gal Ib/gal lb/.al lb/al 0.0 2720.0 2468.8 12.50 12.50 9.00 9.00 2720.0 8454.0 6949.5 12.50 12.50 1 9.00 9.00 3of16 Schlumberger f .VCP'.i tY Temperature Name Top MD Bottom MD ft It Bottom TO it Temperature d F Gradient d F/100ft Relative Gradient de F/100ft Sea Current fVmin Surface 0.0 0.0 0.0 20 0.00 0.00 Rock 0.0 1212.0 1190.2 32 1.01 1.01 0.00 BHST 1212.0 4700.0 4222.2 99 1.87 2.21 0.00 Rock 4700.0 8454.0 6949.5 159 2.00 2.21 0.00 Geothermal Profile (degF) 20 40 60 BO 100 120 140 160 — Ge**MW temp. (c,*gF) E'er M O O O O 4of16 Schlumhuger Fluids Summary Fluids Type Name Density b/ al Conditions K Ibf.s"n/ft2 n Ty Ibf/100ft2 Mud 10.10 Custom80de F Ti 1.05E-2 0.55 6.69 Fresh Water 8.32 Manual 1.04E-4 1.00 0.00 Sd MUDPUSH II 11.50 Custom 120 de F T2 4.47E-2 0.35 13.95 Qannik Slur 15.80 Manual 9.27E-3 0.78 0.00 CW100 8.33 Manual 1.04E-4 1.00 0.00 wmpressiure nneotogy varamerers ano uensmes are otsptayea at r--7 atm ano t=zu aegc (owegF) 0 0 200 400 600 800 1000 1200 Shear Rate (Ils) 5 o 16 Schlumberger Fluid Mud Ambient Tem erature 100degF Number of Circulation 7.41 Min Differential Pressure psi Correction Slope 0.00 Total Volume at Ambient T 2450.0 bbl Success Fracturing123 2720.0 Pumping Stages Fluid Pump Rate Duration V01ume bblImin hr:mn bbl Mud 1 7.0 05:50 2450.0 Well Security Status Description Min Differential Pressure psi At Depth it At Time hr:mn Success Fracturing123 2720.0 05:50 Success Production/Influx 141 2720.0 05:50 Success Burst 5896 0.0 05:50 Success Collapse 4641 4700.0 05:50 psi 0 1000 2000 3000 4000 500( 0 Pae Weesee Ips} Fret Preeelve (ps) — LUX kmlar Preeeae (peel �\ Mm Annular Preavre 1peR 0 099 colo GIA olm 0A 016 v5m ells TRIC (hrmR) 6of16 Schlumberger Fluid Placement Surface Densities are computed at P-1 atm and T=Surface Temperature (20 degF) Fluid Placement in Annulus Bottom MD ft Length ft Volume bbl Surface Density lb/gal Fluid Name Top MD ft Bottom MD ft Length ft 169.5 10.10 Volume bbl Surface Density Ib! al Mud 0.0 2932.9 2932.9 84.8 10.10 MUDPUSH II 2932.9 4000.0 1067.1 40.0 11.50 Qannik Slurry 4000.0 4700.0 700.0 26.2 15.80 PlacementFluid Fluid Name Pipe Top MD ft Bottom MD ft Length ft Volume bbl Surface Density lb/gal Mud 0.0 4428.6 4428.6 169.5 10.10 Fresh Water 4428.6 4690.0 261.4 10.0 8.32 Qannik Slurry 4690.0 4700.0 10.0 0.4 15.80 ao 7ot16 Schlumberger y Pumping Schedule Pumping Schedule Fluid Name Duration hr:mn Volume bbl Pump Rate bbl/min Injection Temperature de F Cumulated Comment Time hr:mn MUDPUSH II 00:06 40.0 7.0 68 00:06 Pause 00:10 00:16 Qannik Slurry 00:04 26.6 7.0 68 00:20 Top Plug 00:10 00:30 Fresh Water 00:01 10.0 7.0 68 00:31 Mud : 00:23 169.5 > Mud 00720 159.58.0 68 00:51 > Mud 00:0310.0 3.0 68 00:54 Maximum Required Hydraulic Horsepower (HHP) 1 101.4 hh at 00:51 hr:mn 8of16 Schlumberger k Su v m PmePnle(Mv.)--Peturn Rate{ Tb .) i l i N O 0000 0010 00:20 00:30 0040 00.50 Time (hymn) S — Pop press e (pg, — Certent ReM presure (Psp 0 0 0 8 � 0 0000 00:10 0020 0030 00:40 00.50 Time (hrmn) O — M11M hb Prea9We ED(BJgal) Pore PrMbiee N Bonar Ht _ Fra Pressure At Hole _ Static Masson Mtmttan ED(Ngap ED OMgafi ED ("A 00:00 0010 0020 00.30 00-40 Time (hr mn) 00:50 } 9 of 16 Schlumberger • ti Well Security Well Security Status Description Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 4 4700.0 00:51 Success Production/Influx 141 2720.0 00:54 Success Burst 5671 0.0 00:54 Success Collapse 4370 4700.0 00:54 N/A Dead -End Collapse 0 0.0 00:00 N/A Dynamic u-tubingin Dead -End 0 0.0 00:00 NIA Balanced u-tubingin Dead -End 0 0.0 00:00 psi 0 1000 2000 3000 4000 500( Pare Preswe (ps) — Ma(Aruerhr Pressure (psil — Mn Anular Pressure (psi) Frac Pressure (}rsij t 10 of 16 Schlumberger 4 Temperature Outputs Temperature Summary Table Static Tem erature. at TOC 20 de F Simulated HCT at TOC 68 de iF Max First SK Temperature 84 de F At time 00:50hr:mn 2 Static Temperature at BH 99 de F Simulated HCT at BH 84 de F Max Last SK Temperature 84 de F At time 00:54 hr:mn T at eotIM Hole fdegF) — Qannk SUM I Fresh Water _ Mud IIJUQPUSH II interface Interface Temp (C"F) Temp (deg F) _ Fresh WaW I hind Interface . MUOPUSHIII pannkSlurry Temp(degF) InterfaceTemp (te9F) 00.00 00-10 0020 00:30 00-40 0050 Time (hymn) degF 20 40 60 80 100 121 O — fieatnermal temp (ae9F) — T in annulus at time (dfi9F) T in Dyne at tinge (C"F) 11 of 16 Schlumberger i 71 Centralization Centralizers Bottom MD Joints Centralizer Alias Pattern Min STO Depth ft Alias Manufacturer Commercial Name Type 4700.0 17.50 1501570 -7 -6 -Positive 1 1/1 1 0.0 1 4037.6 Contig Csg OD in Min OD in Max OD in Caunt A1611570-7-0- RIGIDB Houma Not Set rigid Not Set 7 8.500 8.500 0 1501570 -7 -6 -Positive Houma 1501570 did Positive 7 8.500 8.500 17 Pattern Placement Bottom MD Joints Centralizer Alias Pattern Min STO Depth ft I I it 4000.0 100.00 1501570 -7 -6 -Positive 10 1 0.0 1 2.4 4700.0 17.50 1501570 -7 -6 -Positive 1 1/1 1 0.0 1 4037.6 '. SIaMORdWCenU®1¢515 IS6I � StandOfl at cenheRaP�S MD Computation time: Cement Tums 00.49 12 of 16 Schlumberger 0 m F 8 uid concentration in annulus Average Concentration (%) 20 40 60 80 100 — MW in ann. (%) — Fresh Water in ann. (%Y — MUDPUSH It in ann, t%i Qannik Slurry in ann. j%t tY '� WELLCLEAN* III Average Concentration (%) 0 20 40 50 80 152 120 0 0 8 — MLO in pipe (%) — Fresh Water in pipe %1 — h1l1DPUSH II in pipe t%) aanni'. Slum in pip. t%) 13 of 16 Schlumberger Ilk . & ft 14 of 16 Schlumberger Contact Tlme (seco tlJ MUO On.1I RISN - O.O None ® 3llq . lOw - 434 7 MEtlIUT 652.1 H19M1 - 869.5 15 of 16 Schlumberger Document Control Document Name and Version : Once approved by Schlumberger and the Operator, any deviation from this program requires document agreement (SLB OHSE Standard 5010 Management of Change and Exemption Standard) Approvals Date Version Descrl tion Author Name i Signature i Date Author Stephen Lauper Schlumberger review Rianne Campbell Via BPM Schlumberger Approval Customer Approval Weifen Dai "By signing this document (or confirmation email), 1 confirm 1 have reviewed and approved it as the basis for the well cementing program." Distribution List : HistoryRevision Date Version Descrl tion Author 19 V1 Initial Desi n I slau er 16 of 16 Schlumberger io 00 A 1. String: 7° Intermediate Stage 1 Well Name: CD3 -IIIA Company: CPAI Field: Alpine Contact: Weifeng Dai Well Location: Alpine Proposal Number: 1 Date: 1/6/2017 Made By: Stephen Lauper Service from District: Prudhoe Bay District Phone: (907)659-2434 Objective: Place 1000 -ft of Cement around the shoe. Provide a competent shoe for drilling forward Acceptance Criteria: Pump per program (Density, Volume, Rate) %islaimer Nn�ire $TlunMpP yEmM1i NYkNmeni wiq Re h'NM1loli�alM9mgX,e��iTl,dnOg ]aiiM1¢IOOmace( IM1ielmNmaM1eai.pp��.��m�paX,a�Wm��pad�.,e�pmh.epim�dl�p��a�Ppa�,e.I�ipM1w,wwd. Schlumberger moeelsmw.v,a�a,c.amrmuwam ide,enzaeNipe�d iroeumle. 1;lylaliret TESD Nsm URNINt ECidmNOm OREKE wt rtOFDATk me.ppMv'timsde JWUNmIIE NJWIS,FF YISGNENOFECONSMQE, YBIBLEI OFIHE%NCES50f OPi0. WHIXMAiIfM PXESfNRO FifFCiNENE550FAWiFPo4.Vp0011CISOfl SUYfLF$,RCCMMWUAIIF,"M EEf, Uflfl[SIhIS OIIFE-SEICFSXFNUEISU haMnnlrrvn nM1inpm¢i�alprynRlapalpi�ynry�yusdyJiWiMypnmdlxrsisnotb MlnNnM aMno imellxuel pgary�igMaaepfivtlhiaby. i Rr wR" Well Data Summary The cementing program incorporates the following data : RigType Land Fluids Retum to Rig Floor Section MD 8454.0 ft Section TO 6949.5 ft BHST 159 de F All depths take the rig floor as reference Mud Line Depth 0.0 ft Mud Return Depth 0.0 ft Section MD 8454.0 ft Section TO 6949.5 ft Prev Casing2720.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 Official 114.0 16 40.0 65.0 15 1/4 H-40 630 1640 Official Casing 8454.0 7 1 40.0 1 26.0 1 6.276L-80 1 4870 6210 Offcial -----T- LandingCollar 8374.0Serial number Float Shoe MD De Indinatim (�) is�c.®y Haizaital Depanure (H) Ems n " dD eD Ra 1M n w m an e v craw Q—�rcfrtyunl�i 8 N O Q 6 C W f Q—Ha�lalOMatwe lKl 25 8� O op� O 8 2of18 Schlumberger r .�.._ -,00100,,.. 4 ft CEn M 9 95 10 105 it 11.5 12 12.5 13 0 8 N Pore Pres ED ([.v9M) — Frac Pressure ED (Vgaq Total Volume 487.9 bbl Minimum Diameter 8.750 in Maximum Diameter 8.750 in Mean Diameter 8.750 in Mean Annular Excess 40.0% Mean Equivalent Diameter 9.359 in 4 ft CEn M 9 95 10 105 it 11.5 12 12.5 13 0 8 N Pore Pres ED ([.v9M) — Frac Pressure ED (Vgaq 4 Formation Frac Pore Top Bottom Bottom N Bottom Pore Bottom j MD 1 TVD W QI Top ED ED Lhhology Fluid Name it ft it Ib/gal lb/gal Ibl al O A 2720.0 2468.8 12.50 O � I I 9.00 o 2720.0 8454.0 6949.5 12.50 12.50 O 9.00 O O Q� 4 Formation Frac Pore Top Bottom Bottom Frac Bottom Pore Bottom Res. MD MD TVD Top ED ED Top ED ED Lhhology Fluid Name it ft it Ib/gal lb/gal Ibl al lb/gal 0.0 2720.0 2468.8 12.50 12.50 9.00 9.00 2720.0 8454.0 6949.5 12.50 12.50 9.00 9.00 3of18 Schlumberger 000 e i�Rs � ran9l�rTillM Temperature Name Top MD ft Bottom MD ft Bottom TVD ft Temperature de F Gradient de F/100ft Relative Gradient de F/100ft Sea Current ft min Surface 0.0 0.0 0.0 20 0.00 0.00 Rock 0.0 1212.0 1190.2 32 1.01 1.01 0.00 BHST 1212.0 8454.0 6949.5 159 2.00 2.21 0.00 20 o M Geothermal Profile (degF) 40 60 80 100 120 140 160 — cWtItermaltamp. ix.7Fi 4 of 18 Schlumberger Fluids Summary Fluids Type Name Density Ib/al Conditions K n Ibf.s"n/ft2 I Ty Ibf/100ft2 Drilling Fluid Mud 11.00 Manual 1.05E-2 0.55 6.69 Wash Fresh Water 8.32 Manual -0 1.00 0.00 Spacer MUDPUSH II 12.50 Custom 120 de F T2 0.35 13.95 Slu Qannik Slur 15.80 Manual N4.47E-2 -3 0.78 0.00 Wash CW100 8.33 Manual -4 1.00 0.00 - uompressmie rmeoiogy Parameters and uenslties are displayed at P=1 atm and 7=20 degC (65degF) O ' 0 200 400 660 800 1000 1200 Shear Rate (11s) 5 of 18 Schlumberger I Mud Circulation Fluid Mud Ambient Temperature 100 de F Number of Circulation 3.98 Correction Slope0.00 Total Volume at Ambient T 2450.0 bbl Pumping Stages I'l - Fluid Pump Rate Duration Volume bbl/min hr:mn bbl Mud 1 7.0 05:50 2450.0 Well Security Pore Rf55iBE lGsi M ipi Status Description F, Min Differential Pressure psi At Depth ft At Time hr:mn Success Fracturing 14 2720.0 05:50 Success Production/Influx 256 2720.0 05:50 Success Burst 5700 0.0 05:50 Success Collapse 4459 8454.0 05:50 6of18 psi n innn min nnm erm cm 6 — Bon= k*temv. (CBgF) R-- 0 aam a�w area a,�. mso auu mea a:aa Time (hrnvo Schlumberger Pore Rf55iBE lGsi M ipi ��—Mn Rrtmtlar pessmej�� 52 25 F, 6 — Bon= k*temv. (CBgF) R-- 0 aam a�w area a,�. mso auu mea a:aa Time (hrnvo Schlumberger Fluid Placement Surface Densities are computed at"atm and T=Surtace Temperature (20 degF) Fluid Placement in Annulus Bottom MD ft Fluid Name Top MD ft Bottom MD ft Length ft Volume bbl 8112.6 Surface Density Ib/ al Mud0.0 Fresh Water 6386.9 6386.9 214.2 11.00 MUDPUSH II 6386.9 7454.0 1067.1 40.0 12.50 QannikSlur 7454.0 8454.0 1000.0 37.5 15.80 Fluid Placement Fluid Name in • .- Top MD ft Bottom MD ft Length Volume ft bbl Surface Density lb/al Mud 0.0 8112.6 8112.6 310.4 11.00 Fresh Water 8112.6 8374.0 261.4 10.0 8.32 Qannik Slur 8374.0 8454.0 80.0 3.1 15.80 MD 7 of 18 Schlumberger Pumping Schedule Pumping. Fluid Name Duration hr:mn Volume bbl Pump Rate bbl/min Injection Temperature degF Comment Cumulated Time hr:mn MUDPUSH II 00:06 40.0 7.0 68 Pump Spacer Ahead (2-8 BPM 00:06 Plug 00:00 Drop Bottom Plug 00:06 Qannik Slurry 00:06 40.5 7.0 68 Mix/Pump Slurry 2-7 BPM 00:12 Top Plug 00:00 Drop Top Plug 00:12 Fresh Water 00:01 10.0 1 7.0 68 Pump out plug with water 00:13 Mud : 00:51 310.4 > Mud 00:31 250.4 8.0 68 00:44 > Mud 00:20 60.0 3.0 68 Slow Rate for ECDS/Plug Bump 01:04 I Maximum R uired Hydraulic Horsepower (HHP) 187.4 hhp at 00:00 hr:mn 8of18 Schlumberger —Reap rate(WYM) -- Retma Race RWVm,M N 0000 00.10 0020 00.--30 0(Y40 00:50 01 OD Time (hrmn) $ o �jo—Fwtrypres�we(pa)—CementlreaOWem*ef�7 $ o a o Qo �6j o $ o ,Pr o o 00:00 0010 0020 00:30 0040 00:50 01.01) Time (hymn) N a —EdemaholeprESSme ED(b+a➢ PorePe AIBc Ho* Fra Reaae MBoftaHme __.. _SuacP eae ootlmn ED JW;af, ED(b'ga4 N _ ED(b" a oN 0 N 0600 00:10 0020 0630 0640 0050 0100 Time (hr mm) 9of18 Schlumberger i Well Security Well Security Status Description Min Differential Pressure psi At Depth it At Time hr:mn Success Fracturing 3 2723.1 00:44 Success Production/Influx 256 2720.0 01:04 Success Burst 5631 0.0 01:04 Success Collapse 4298 8454.0 01:04 N/A Dead -End Collapse 0 0.0 00:00 N/A Dynamic u-tubingin Dead -End 0 0.0 00:00 NIA Balanced u-tubingin Dead -End 1 0 1 00:00 psi 0 1000 2000 3000 4000 50IX Pore Presswe (ps, — Max AwAr Premae Ipsij — Mm Annular Pressure Ips, — Frs Pressure (pN! 1 v... 10of18 Schlumberger Temperature Outputs Temperature Summary Table Static Temperature. at TOC 20 de F Simulated HCT at TOC 68 de F Max First SK Temperature 118 d F At time 01:04 hr:mn fEil- 09 0 0 Static Temperature at BH 159 de F Simulated HCT at BH 116 d F Max Last SK Temperature 116 deg F Attime 017041r:mn T at Bo mHole(cle9F) pazmk Slurry/Fresh Water _ WO 7 MUDPUSH 11 Interface Interface Tenp{4a3F) Temp (aegF) _ Fres/ Wad, I Nful Interfax MUOPUSH II I park Slurry TeWidef) Interface Temp degF) m 00:00 00:10 0020 00.30 06:46 00:50 01-00 Time (hymn) degF 20 40 60 to 100 120 0 0 140 160 —Ceoft raal fang.(®a9F) —TIn affhLlLLS atter {aagF} T h Pp a at tM (eegF) 11 of 16 Schlumberger i Centralization Centralizers Alias Manufacturer Commercial Name Type Config Csg OD in Min OD in Max OD in Count A1611570-7-0- RIGIDB Houma Not Set rigid Not Set 7 8.560 8.500 0 1501570-7-6-Posifive Houma 1501570 ri id I Positive 1 7 1 8.500 1 8.500 25 Pattern Placement Bottom MD Joints Centralizer Alias Pattern Min STO Depth . It I I I it 7454.0 186." 0 0.0 1.5 8454.0 25.00 1501570 -7 -6 -Positive 1/1 0.0 7472.5 MD % Oft 0 20 40 60 8o 100 0 M _ St31u0�if G+ur eenllaAZErS l�1 Maroon w centraioa • �1 Mud Computation time: Cement Tums 00.•52 12ot18 Schlumberger Average Fluid concentration in annulus Average Concentration (%) 0 20 40 60 80 7D0 I — mud nam, j%} 11 Fresh Water in am. (%) — MUDPUSH II wam. 1%) Qanmk Slurry it arm. (%) g ti 0 m 0 o� WELLCLEAN* III Average Concentration (%) 20 40 80 S0 10D ( —Mvw mplce f%} — Fresh Water in tvpei%) — MUDPUSH II Ap"(%) ganrtik Slurry m pipe (%) 11 I 13 of 18 Schlumberger 14 of 18 4_ Fwla- cwcenl�anoPa . Mutl - F�esM1 Wa[e� - MVOPVSN II Qdnnik Slurry 0 Schlumberger COII[3CL TImP (5econ[f) Mu0 On Wall R15K 663 5 LOw - 1327.1 MCulum 1990.6 F11pM1 2654.1 15 of 18 Schlumberger Operator Summary Volume Fluid Name Pumped Volume bbl Prepared Fluid Dead Volume bbl Required QuantityQuanti Loadout Loadout Items Prepared Fluid bbl Mix Fluid Dead Volume bbl Silo dead volume ton Qarmik 51urrV 40.5 1 0.0 1 40.5 0.0 0 MUDPUSH II40.0 0.00 gal 0.0 40.0 0.0 0 Fresh Water 10.0 0.0 1 10.0 0.0 0 Material Summary Additive Pumped Quantit Required QuantityQuanti Loadout Loadout Items Pack. Name Pack. Comment Size Fresh Water 2824.82 al 2824.82 al 2824.82 al 0.00 0.00 gal D031 9048.3 lb 9048.3 lb 9048.3 lb 82.26 sack 110.0 Ito D182 234.71b 234.7 lb 234.7 lb 4.69 sack 50.01b QannikSlu Blend 18431.2lb 18431.2 lb 18431.2 lb 0.00 bulk 0.0 lb D046 36.91b 36.9 lb 36.9 lb 0.74 sack 50.0 Ito D065 55.31b 55.3 lb 55.3 lb 1.11 sack 50.0 lb D167 73.7lb 73.7 lb 73.7 lb 2.95 sack 25.0 lb D177 1.96 gal 1.96 gal 1 1.96 gal 0.04 drum 55.00 gal 16 of 18 Schlumberger MY - d Freparation Clannik Slurry Pumped Volume: 40.5 bbl Density:15.80 Ib/gal SVF : 40.7 % Yield :1.16 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 5.093 al/sk VBWOB 18597.1 Ib 18597.1 Ib 9048.3 Ib Oannik Slurry Blend: 94.0 lb per sack 18431.2 lb 18431.2 lb 18431.2 It - G 941b/sk WBWOB 18431.2 lb 18431.2 It 18431.2 It D046 0.2%BWOB 36.9 lb 36.9 It 36.9 lb D065 0.3%BWOB 55.3 lb 55.3 It 55.31b D167 0.4 %BWOB 73.7 lb 73.7 It 73.7 It Liquid Phase Concentration Pumped Quant' Re uired Quantit Loadout Quantity Total Mix Fluid 5.093 al/sk VBWOB 998.49 al 998.49 al 9048.3 Ib Fresh Water 5.083 al/sk VBWOB 996.53 al 996.53 al 996.53 al D177 0.010 al/skVBW06 1.96 al 1.96 al 1.96 gal MUDPUSHII Pumped Volume: 40.0 bbl Density:12.50 Ib/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quan!lty MUDPUSH II Weighting Matedal: 5.391b/gal WBVOSpacer 9048.3 lb 9048.3 lb 9048.3 Ib - D031 5.39lb/gal WBVOSpaoer 9048.3 lb 1 9048.3 It Base Fluid Concentration Pumped QuantityRequired QuantityLoadout Quantity Total Liq! Phase 0.9 bbl/bbl BVOS acer 1429.60 al 1429.60 al Fresh Water 0.8 bbl/bbl BVOS acer 1408.30 al 1408.30 al 1408.30 al D182 7.00lb/bbl WBVOBF 234.7 lb 234.7 lb 234.71b Fresh Water Pumped Volume :10.0 bbl Density: 8.321b/gal Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 1.0 bbl/bbl BVOWash420.00 gal li 420.00 gal Fresh Water 1.0 bbl/bbl BVOWash 1 420.00 gal 420.00 gal 42000 gal 17o11B Schlumberger tofc^ Document Control Document Name and Version : Once approved by Schlumberger and the Operator, any deviation from this program requires document agreement (SLB OHSE Standard 5010 Management of Change and Exemption Standard) Approvals Name i Signature Date Author Stephen Lauper 1/6/2017 Schlumberger review Rianne Campbell Via BPM SchlumbergerApproval Customer Approval Weifen Dai "By signing this document (or confirmation email), I confirm 1 have reviewed and approved B as the basis for the well cementing program." Distribution List : 18 of 18 Schlumberger Loepp, Victoria T (DOA) From: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Sent: Friday, February 24, 2017 9:35 AM To: Loepp, Victoria T (DOA) Subject: RE: CRU CD3-111A(PTD 217-004) Intermediate Cement Evaluation Morning Victoria, The current plan is to use Sonic tool in lateral BHA to log it just like what we are doing nowadays at Alpine. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, February 24, 2017 9:27 AM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CRU CD3-111A(PTD 217-004) Intermediate Cement Evaluation Weifeng, What are your plans concerning cement evaluation of the intermediate cement? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeoordalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Vicforic.Loepp@alaska.gov Loepp, Victoria T (DOA) From: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Sent: Thursday, February 23, 2017 11:25 AM To: Loepp, Victoria T (DOA) Subject: RE: CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight We have dedicated mud plant mixing mud supply at CD1 pad in Alpine, delivery time for kill -weight mud is within hours, shouldn't be a big concern. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, February 23, 2017 9:48 AM To: Dai, Weifeng<Weifeng.Dai @conocophiIli ps.com> Subject: [EXTERNAL]RE: CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight How far away are facilities that can mix kill -weight mud? What would the delivery time for kill -weight mud? From: Dai, Weifeng [mailto:Weifeng.Dai@conocophillips.coml Sent: Wednesday, February 22, 2017 4:22 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight Victoria, Good question, we will implement MPD in the lateral to monitor the connection pressure which can give us real pore pressure in the situation the mud weight is underbalanced, we will weight up mud if necessary based on the connection pressure. We hesitate to start with heavy mud then could easily incur severe losses with ECD when drilling which is what we have seen in the past. That's pretty much the reasoning behind it. Doyon 19 has been utilizing MPD in lateral drilling in the last 1-2 years with plenty of experience from the crew to handle this situation. Weifeng Office: (907)-263-4324 Cell Phone:(907)-342-9508 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, February 21, 2017 2:14 PM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CRU CD3-111A(PTD 217-004) Max Reservoir Pressure and Mud Weight Weifeng, The maximum formation pressure encounter during drilling is 4150 psig which equates to an 11.6 ppg EMW. Planned mud weights during drilling are 9.6 to 11.0 ppg EMW. Should the mud weight be increased through this interval? What mitigation measures will be taken should the higher pore pressure be encountered? Loepp, Victoria T (DOA) From: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Sent: Wednesday, February 15, 2017 10:49 AM To: Loepp, Victoria T (DOA) Subject: RE: CRU CD3-111A(PTD 217-004) 1st Stg Intermediate Casing Cement Calculations Attachments: CD3 -111A PTD_Final.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, You are right, I fat fingered bbl/ft number as ft3/ft in the equation, the final sx were right. Anyway, I change the ft3/ft number in the attached, please replace the old one with it. Thanks for the help. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Loepp, Victoria T (DOA) jmailto:victoria.loepp@alaska.gov] Sent: Wednesday, February 15, 2017 10:08 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CRU CD3-111A(PTD 217-004) 1st Stg Intermediate Casing Cement Calculations Weifeng, Please check cement calculations for the intermediate casing. The annular volume(ft3/ft) does not appear to be correct. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeop(o7a laska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or victoria Loeoo@alaska aov Loepp, Victoria T (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Tuesday, February 14, 2017 4:42 PM To: Loepp, Victoria T (DOA) Subject: RE: CRU CD3-111(PTD 206-030); CD3-111L1(PTD 206-042) Plug for Redrill; CD3-111A(PTD 217-004) Sidetrack: Modifications Needed Attachments: CD3 -111A PTD_Final.pdf; Cover letter for PTD.pdf; CD3 -111A Re -drill Schematic.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Please review the attached files as per request. The cover letter includes the statement that we will frac the well. I add cement program in the PTD and also the schematic attached. Please let me know if any other information is needed. Thanks. Weifeng Office: (907)-263-4324 Cell Phone:(907)-342-9508 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, February 14, 2017 9:37 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com>; Brown, H Marshall <H.Marshall.Brown@conocophillips.com> Subject: [EXTERNAL]RE: CRU CD3-111(PTD 206-030); CD3-111L1(PTD 206-042) Plug for Redrill; CD3-111A(PTD 217-004) Sidetrack: Modifications Needed Weifeng, Please provide a cement summary for sidetrack that includes cement volumes, sx, yield, TOC for each stage. Please provide a WBS that shows cement, both stages and depths Also, the cover letter needs to include a statement that the sidetrack will be fracture stimulated. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Tuesday, February 14, 2017 9:07 AM To: Dai, Weifeng(Weifeng.Dai@conocophillips.com) <Weifeng.Dai@conocophillips.com>; h. marshal).brown@conocophillips.com Cc: Eller, J Gary (J.Gary.Eller@conocophillips.com) <J.Gary.Eller o)conocophillips.com>; Bearden, J Daniel (J.Daniel.Bearden@conocophillips.com) <J.Daniel.Bearden@conocophillips.com> Subject: CRU CD3-111(PTD 206-030); CD3-111L1(PTD 206-042) Plug for Redrill; CD3-111A(PTD 217-004) Sidetrack: Modifications Needed Importance: High Marshall, Weifeng, The plug-for-redrill sundries need to include operations up to milling the window. The plug-for-redrill sundries need a summary paragraph outlining the operations. Need a better wellbore schematic showing the two laterals that are being plugged and plugs with plug depths, retainer depth, TOC etc The MPSP is inconsistent between the plug-for-redrill sundries and the PTD. The BOP test pressure is not sufficient. Needs to be 3800 -4000 psig I would suggest you look at a typical Kuparuk plug for redrill sundry and associated sidetrack PTD as a go-by. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCda laska. oov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907) 7931247 or Victoria.Loepp@aloska.gov Loepp, Victoria T (DOA) From: Njoku, Johnson <Johnson.Njoku@conocophillips.com> Sent: Friday, February 10, 2017 9:51 AM To: Loepp, Victoria T (DOA) Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Quick, Michael J (DOA); Kanady, Randall B; Hayden, Philip Subject: RE: CRU CD5-20(PTD 216-161) Approval to run Sonic LWD on Intermediate Casing Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for the approval to use LWD-Sonic for TOC evaluations on CD5-20. And all provisions for use of LWD-Sonic as TOC evaluation tool is well noted. Let me know if you have any questions or concerns. Best regards, Johnson Njoku Engineering Supervisor- Drilling +907 317 1529 'The Success of Every MIT Opportunity is Important, but what is most Important is the boldness to pursue the Opportunity and the Honest Optimism for Success'- JCN From: Loepp, Victoria T (DOA) imailto:victoria.loepp@alaska.gov] Sent: Friday, February 10, 2017 9:42 AM To: Njoku, Johnson <Johnson.Njoku @conocophiIIips.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Quick, Michael J (DOA) <michael.quick@alaska.gov> Subject: [EXTERNAL]CRU CD5-20(PTD 216-161) Approval to run Sonic LWD on Intermediate Casing Johnson, We have reviewed the comparison information CPAI has provided between the LWD-Sonic and the Wireline- SCMT. Approval is granted to run the LWD-Sonic on upcoming well CRU CD5-20 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPA] is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Victoria Bettis, Patricia K (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Thursday, January 19, 2017 12:32 PM To: Bettis, Patricia K (DOA) Subject: RE: CRU CD3 -111A (PTD 217-004): Permit to Drill Application Morning Patricia, The 17,409.58' is correct, sorry I misplaced the number there. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, January 19, 2017 11:51 AM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CRU CD3 -111A (PTD 217-004): Permit to Drill Application Good morning Weifeng, On form 10-401, Box 6 Proposed Depth, it says 23,558' MD. However, the Standard Proposal Report shows the proposed TD as 17,490.58' MD. Please verify which depth is correct. If 23,558' MD is correct, then a revised wellbore survey will need to be submitted. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.eov. Bettis, Patricia K (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Wednesday, January 18, 2017 2:21 PM To: Bettis, Patricia K (DOA) Subject: RE: CD3 -111A (PTD 217-004): Permit to Drill Application Good afternoon Patricia, Please see the comments below. Weifeng Office: ( 907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, January 18, 2017 12:00 PM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CD3-111A (PTD 217-004): Permit to Drill Application Weifeng, Three questions: 1. What logs does ConocoPhillips plan to run within the CD3 -111A well? GR and Resistivity for both intermediate and production section. 2. What is the reservoir objective for the well and its anticipated depth? Colville River Unit/Fird Nechelik is the objective, TVD is approximately 6,890' TVDss. Heel is 8,467' MD, TD at 17,491' MD. 3. What is the deepest formation to be penetrated by the well? Nechelik, we plan stay in the sand all the time. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7t^ Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov. Bettis, Patricia K (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Wednesday, January 18, 2017 1:05 PM To: Bettis, Patricia K (DOA) Subject: RE: CD3 -111A (PTD 217-004): Permit to Drill Application My bad, it is a development well, a producer to replace original CD3 -111, a producer that suspect downhole collapse. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, January 18, 2017 10:46 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CD3-111A (PTD 217-004): Permit to Drill Application Good morning Weifeng, On Form 10-402, Box 1b, the development -oil box is checked. However, on the accompanying cover letter, it is stated that the CD3 -111A will be an injector. Please verify as to whether CD3 -111A will be a development or an injection well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 71h Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.¢ov. Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, January 18, 2017 9:48 AM To: 'H.Marshall.Brown@conocophillips.com' Subject: CRU CD3 -1111_1 (PTD 206-042) Sundry Application Good morning Marshal, AOGCC received the sundry application for CD3 -111 (PTD 206-030) for the plug for redrill. However, ConocoPhillips also needs to submit a Sundry Application for the plug for redrill for CRU CD3 -111L1 (PTD 206-042). Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7" Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.eov. Bettis, Patricia K (DOA) From: Brown, H Marshall <H. Marsha ll.Brown@conocoph ill ips.com> Sent: Wednesday, January 18, 2017 8:43 AM To: Dai, Weifeng; Bettis, Patricia K (DOA) Subject: RE: CRU CD3 -111 and CRU CD3 -111L1 Patricia, We are submitting the "plug for redrill" sundry today. Please let me know if you have any questions. Cheers, H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. ATO -1309 Office: 907.265.6218 Mobile: 281.732.5844 H.Marshall.Brown@ConocoPhillips.com From: Dai, Weifeng Sent: Tuesday, January 17, 2017 4:40 PM To: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Cc: Brown, H Marshall <H.Marshall.Brown@conocophillips.com> Subject: RE: CRU CD3 -111 and CRU CD3 -111L1 Patrician, I copy Marshall Brown here, he is the wells engineer taking care of Sundry permit. Another side note here, this well is a cut and pull existing casing, then sidetrack. It is single lateral well named CD3 -111A other than multi -lateral. Weifeng Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.aov] Sent: Tuesday, January 17, 2017 3:48 PM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CRU C133-111 and CRU CD3 -111L1 Good afternoon Weifeng, Received the Permit to Drill for CRU CD311A today. Has ConocoPhillips submitted the Sundry Applications for the "plug for redrill" for CRU CD3 -111 and CD3 -1111.1? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 71h Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.aov. TRANSMITTAL LETTER CHECKLIST WELL NAME:nn CLk /k- ALJ 1— III A PTD: oC I 7�— a0y /Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: l/l� ��V�I POOL: <�Oltjil , j—Iord 5t Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- _- _ Production in API number are _. should continue to be reported as a function of the original API number stated between 60-69) above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the Pilot Hole pilot hole must be clearly differentiated in both well name ( PH) and API number (50- -_ _ ) from records, data and logs acquired for well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval Spacing Exception to produce / inject is contingent upon issuance of a conservation order approving pP g 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 Commission must be in no greater than Dry Ditch Sample 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: Non- Production or production testing of coal bed methane is not allowed for name of Conventional well until after (Company Name) has designed and implemented a water well Well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, FIORD OIL - 120120 PTD#:2170040 Company CONOCOPHILLIPS ALASKA INC _ Initial Class/Type Well Name: COLVILLE RIV FIORD CD3 -111A Program DEV _ Well bore seg ❑ DEV / PENDGeoArea 890 -- — ___ _ Unit 50360On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gasconforms to AS31,05.0300.1.A),0.2.A-D) NA 1 Permit fee attached _ _ _ _ NA 2 Lease number appropriate.. Yes ADL0372105, Surf Loc & Top. Prod Interv; ADL0364471, Portion Prod.lnterv; ADL0364470 TD. 3 Unique well. name and number Yes CRU CD3 -111A 4 Well located in a defined pool _ _ _ Yes COLVILLE RIVER, FIORD OIL - 120120, governed by Conservation Order No. 569. 5 Well located proper distance from drilling unit. boundary. Yes CO 569 contains no spacing restriction with respect to drilling. unit boundaries.. 6 Well located proper distance from other wells. Yes CO 569 has no interwell spacing. restrictions, 7 Sufficient acreage available in. drilling unit..... Yes 8 If. deviated, is wellbore plat included Yes 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit. can be issued without administrative approval _ _ _ _ Yes _ PKB 1124/2017 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string provided _ _ _ _ _ _ _ NA Conductor set in CRU CD3 -111 _ Engineering 19 Surface casingprotects all. known USDWs NA Surface casing set in CRU CD3 -111 20 CMT vol adequate. to circulate. on conductor & surf csg _ NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will Cover all known productive horizons No Productive interval will be completed with. uncement liner w/ frac ports 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all wasteto approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved Yes PTD 206-030,. Sundry 317-077 & PTD 206-042, Sundry 317-035 26 Adequate wellbore separation. proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations. NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 4150 psig(11.5 ppg EMW); will drill w/ 9.6-11.0 ppg EMW and. maintain overbal w/MPD VTL 2/24/2017 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3461 psig; will test BOPS to 3800 psig 31 Choke. manifold complies w/API_RP-53(May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 11.61 ppg EMW; will be drilled using 9.6 to 11.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA 7" csg shoe to be set at top of Nechelik ss. PKB 1/24/2017 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Development sidetrack to be drilled. Geologic Engineering Public Commissioner: Date: Commissioner Date Com ssioner Date 0is 21II17 � ` 3"'_17 UY�1 1 "S1r(t-:�