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Home My WebLink About218-161DATA SUBMITTAL COMPLIANCE REPORT 3/29/2019 Permit to Drill 2181610 Well Name/No. KUPARUK RIV UNIT 3C -08A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-21390-01-00 PBZ• MD 12246 TVD 6664 Completion Date 12/31/2018 Completion Status 1-0I1. Current Status 1-0I1- UIC No REQUIRED INFORMATION Mud Log No ✓ Samples No ✓ DATA INFORMATION Comments List of Logs Obtained: GR/RES HEADERS Well Log Information: Electronic File: 3C -08A EOW - NAD27.pdf 1/4/2019 Log/ Electr 1/4/2019 Electronic File: 3C -08A EOW - NAD83.pdf Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Log C 30201 Log Header Scans 0 0 ED C 30201 Digital Data 2181610 KUPARUK RIV UNIT 3C -08A PBI ED C 30201 Digital Data HEADERS ED C 30201 Digital Data HEADERS ED C 30201 Digital Data Electronic File: 3C-08APB2 EOW - NAD27.pdf 1/4/2019 ED C 30202 Digital Data 1/4/2019 Electronic File: 3C-08APB2 EOW - NAD83.pdf ED C 30202 Digital Data Electronic File: 3C-08APB2 EOW - NAD83.txt ED C 30202 Digital Data HEADERS ED C 30202 Digital Data Electronic Data Set, Filename: 3C -08A GAMMA Log C 30202 Log Header Scans 0 0 Log C 30203 Log Header Scans 0 0 ED C 30203 Digital Data ED C 30203 Digital Data ED C 30203 Digital Data ED C 30203 Digital Data Log C 30205 Log Header Scans 0 0 ED C 30205 Digital Data 9348 12246 ED C 30205 Digital Data AOGCC Page 1 of 5 Directional Survey Yes ,/ (from Master Well Data/Logs) Received Comments 2181610 KUPARUK RIV UNIT 3C -08A LOG HEADERS 1/4/2019 Electronic File: 3C -08A EOW - NAD27.pdf 1/4/2019 Electronic File: 3C -08A EOW - NAD27.txt 1/4/2019 Electronic File: 3C -08A EOW - NAD83.pdf 1/4/2019 Electronic File: 3C -08A EOW - NAD83.txt 1/4/2019 Electronic File: 3C-08APB1 EOW - NAD27.pdf 1/4/2019 Electronic File: 3C-08AP81 EOW - NAD27.txt 1/4/2019 Electronic File: 3C-08APB1 EOW - NAD83.pdf 1/4/2019 Electronic File: 3C-08APB1 EOW - NAD83.txt 2181610 KUPARUK RIV UNIT 3C -08A PBI HEADERS 2181610 KUPARUK RIV UNIT 3C -08A PB2 HEADERS 1/4/2019 Electronic File: 3C-08APB2 EOW - NAD27.pdf 1/4/2019 Electronic File: 3C-08APB2 EOW - NAD27.txt 1/4/2019 Electronic File: 3C-08APB2 EOW - NAD83.pdf 1/4/2019 Electronic File: 3C-08APB2 EOW - NAD83.txt 2181610 KUPARUK RIV UNIT 3C -08A LOG HEADERS 1/7/2019 Electronic Data Set, Filename: 3C -08A GAMMA RES.Ias 1/7/2019 Electronic File: 3C -08A 2MD Final Log.cgm Friday, March 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 3/29/2019 Permit to Drill 2181610 Well Name/No. KUPARUK RIV UNIT 3C -08A MD 12246 TVD 6664 ED C 30205 Digital Data ED C 30205 Digital Data ED C 30205 Digital Data ED C 30205 Digital Data ED C 30205 Digital Data I ED C 30205 Digital Data ED C 30205 Digital Data ED C 30205 Digital Data Completion Date 12131/2018 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-21390-01-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No Electronic File: 3C -08A 5MD Final Log.cgm Electronic File: 3C -08A 5TVDSS Final Log.cgm Electronic File: 3C -08A 2MD Final Log.pdf Electronic File: 3C -08A 5MD Final Log.pdf Electronic File: 3C -08A 5TVDSS Final Log.pdf Electronic File: 3C -08A EOW - NAD27.pdf Electronic File: 3C-0SA EOW - NAD27.bd Electronic File: 3C -08A Final Surveys 12246 TD.csv Electronic File: 3C -08A Final Surveys 12246 TD.xlsx Electronic File: 3C -08A Survey Listing.txt Electronic File: 3C -08A Surveys.txt Electronic File: 3C- 08A_25_1apescan_BH I_CTK.txt Electronic File: 3C-08A_5_tapescan_BHI_CTK.txt Electronic File: 3C-08A_output.tap Electronic File: 3C -08A 2MD Final Log.tif Electronic Fife: 3C -08A 5MD Final Log.tif Electronic File: 3C -OSA 5TVDSS Final Log.tif Electronic Data Set, Filename: 3C-08APB1 GAMMA RES.Ias Electronic File: 3C-08APB1 2MD Final Log.cgm Electronic File: 3C-08APB1 5MD Final Log.cgm Electronic File: 3C-08APB1 5TVDSS Final Log.cgm Electronic File: 3C-08APB1 2MD Final Log.pdf Electronic File: 3C-08APB1 51AD Final Log.pdf Electronic File: 3C-08APB1 5TVDSS Final Log.pdf Electronic File: 3C-08APB1 EOW - NAD27.pdf 1/7/2019 1/7/2019 1/7/2019 1/7/2019 1/7/2019 1/7/2019 1/7/2019 1/7/2019 ED C 30205 Digital Data 1/7/2019 ED C 30205 Digital Data 1/7/2019 ED C 30205 Digital Data 1/7/2019 ED C 30205 Digital Data 1/7/2019 I ED C 30205 Digital Data 1/7/2019 ED C 30205 Digital Data 1/7/2019 ED C 30205 Digital Data 1/7/2019 ED C 30205 Digital Data 1/7/2019 ED C 30205 Digital Data 1/7/2019 ED C 30206 Digital Data 9348 11215 1/7/2019 ED C 30206 Digital Data 1/7/2019 ED C 30206 Digital Data 1/7/2019 ED C 30206 Digital Data 1/7/2019 ED C 30206 Digital Data 1/7/2019 ED C 30206 Digital Data 1/7/2019 ED C 30206 Digital Data 1/7/2019 ED C 30206 Digital Data 1/7/2019 AOGCC Page 2 of 5 Friday, March 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 3/29/2019 Permit to Drill MD 12246 2181610 Well Name/No. KUPARUK RIV UNIT 3C -08A Operator TVD 6664 Completion Date 12/31/2018 Completion Status CONOCOPHILLIPS ALASKA, INC. API No. 50-029-21390-01-00 1 -OIL Current Status 1 -OIL UIC No ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1 EOW - NAD27.tx1 ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1Survey Listing.txt ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1Surveys.txt ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1_Daily Surveys TD 11215.csv ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1_Daily Surveys TD 11215.xlsx ED C 30206 Digital Data 1/7/2019 Electronic File: 3C- 08A_25_tapescan_BHI CTK.txt ED C 30206 Digital Data 1/7/2019 Electronic File: 3C -08A_5_ tapescan_BHI_CTK.txt ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08A_output.tap ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1 2MD Final Log.tif ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1 51VID Final Log.tif ED C 30206 Digital Data 1/7/2019 Electronic File: 3C-08APB1 5TVDSS Final Log.tif Log C 30206 Log Header Scans 0 0 2181610 KUPARUK RIV UNIT 3C -08A PB1 HEADERS Log C 30207 Log Header Scans 0 0 2181610 KUPARUK RIV UNIT 3C -08A PB2 HEADERS ED C 30207 Digital Data 9348 11615 1/7/2019 Electronic Data Set, Filename: 3C-08APB2 GAMMA RES.Ias ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 21VID Final Log.cgm ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 51VID Final Log.cgm ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APE12 5TVDSS Final Log.cgm ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 2MD Final Log.pdf ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 5MD Final Log.pdf ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 5TVDSS Final Log.pdf ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 EOW - NAD27.pdf ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 EOW - NAD27.txt ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 Survey Lisling.txt ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 Surveys.txt AOGCC Page 3 of 5 Friday, March 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 3/29/2019 Permit to Drill 2181610 Well Name/No. KUPARUK RIV UNIT 3C -08A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-21390-01-00 MD 12246 TVD 6664 Completion Date 12/31/2018 Completion Status 1-0I1 Current Status 1 -OIL UIC No ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2_11615_TD_Final.csv ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2_11615_TD_Final.xlsx ED C 30207 Digital Data 1/7/2019 Electronic File: 3C- 08APB2_25_tapescan_BHI_CTK.bd ED C 30207 Digital Data 1/7/2019 Electronic File: 3C- 08APB2_5_tapescan_BHI_CTK.txt ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-OSAPB2_output.tap ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 2MD Final Log.tif ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 5MD Final Log.tif ED C 30207 Digital Data 1/7/2019 Electronic File: 3C-08APB2 5TVDSS Final Log.tif Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report O Production Test Information Y /F Geologic Markers/Tops COMPLIANCE HISTORY Completion Date: 12/31/2018 Release Date: 12/18/2018 Description Comments: Directional / Inclination Data Y A Mud Logs, Image Files, Digital Data Y / Core Chips Y ZA Mechanical Integrity Test Information NA Composite Logs, Image, Data Files n Core Photographs Y Daily Operations Summary o'J Cuttings Samples Y /5A Laboratory Analyses Y +!A) Date Comments AOGCC Page 4 of 5 Friday, March 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 3/29/2019 Permit to Drill 2161610 Well Name/No. KUPARUK RIV UNIT 3C -08A Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-21390-01-00 MD 12246 TVD 6664 Completion Date 12/31/2018 Completion Status 1-0I1 Current Status 1-0I1- / f UIC No Compliance Reviewed Date: AOGCC Page 5 of 5 Friday, March 29, 2019 STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMnnia—�N REPORT OF SUNDRY WELL OPERATIONS C RLEiI EB 10 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑' Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ 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: ConoeoPhillips Alaska, Inc. Development E] Exploratory ❑ Stratigraphic❑ Service ❑ 218-161 3. Address: P. 0. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21390-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 313-08A ADL 25629, ADL 25634 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A - Submitted w/10-403 Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,246 feet Plugs measured None feet true vertical 6,664 feet Junk measured None feet Effective Depth measured 12,246 feet Packer measured 9,652 feet true vertical 6,664 feet true vertical 6,459 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 116' MD 116' TVD SURFACE 5,171 feet 9 5/8 " 5,206' MD 3732' TVD PRODUCTION 9,797 feet 7 10,258' MD 6692' TVD A LINER 2,416 feet 2 3/8 " 12,247' MD 6664' TVD Perforation depth: Measured depth: 9904-9921. 9938-9954. 9976-1004 feet True Vertical depth: 6623-6634. 6645-6656. 6670-6689 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 9,962' MD 6,661' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER, PREMIER 9,652' MD 6,459' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12027-12028,11302-11303,11052-11053,10610-10611 Treatment descriptions including volumes used and final pressure: Total Well - 4 stage,222,150lbs placed .........See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 110 83 632 1 520 1 128 Subsequent to operation: 1 369 298 1893 1 460 1 202 14. Attachments (required per 20 AAC 25.00770, 25.071, & 25.283) 15, Well Class after work: Daily Report of Well OperationsLJ �,+`1`� \ Exploratory ❑ Development 0 E]Service ❑ Stratigraphic 16. Well Status after work: Oil ❑� Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ElotY Printed and Electronic Fracture Stimulation Data 12f 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: Contact Name: Sandeep Pedam Authorized Name: Sandeep Pedam Contact Email: sandeep.pedam.@cop.com Authorized Title: Com leti s Engineer 01n J contact Phone: (907) 263-4724 Authorized Si natur : Dale'. v - 1,.-�7 p Form 10-404 Revised 4/2017 terry j� '19 RBDMS_� FEB 19 2019 y / `3115 1/ Submit Original Only 'Or KUP PP"ID WELLNAME 3C -08A WELLBORE 3C -08A Well Attribute Max Angle L TD ConocoPhdl)p Fdddame wenbarcAPuuv 1.11-1 aside al•1 mDInKid ae,BlminK., Alaska. klC KUPARUK RIVER UNIT 500292139MI PROD 5010 5.00000 12,2470 slime. v,axo,sasnm Pv Last Tag veual¢I,nr®YlevluYl Annori indnhols) End Cab I Wellbore Lastall Last Tag: -0BA Ijentalf nawGeaNlER; m6_ Last Rev Reason Annoledan EM Dab WNIMre ey Rev Reason: FRAC DETAILS I 2/142019 3CA8A pprownpven Casing Strings aamg DaacopBOn o01m1 I011nl TOP tnICB) 6q Dreln MIKE) her Cash RVI)) lt..Orade TOP Thread A LINER 23/8 Irrigator 1.99 9,8306 12,24].0 460 L-90 511 Liner Details Nominal 10 T.,(nrad TOp (TV01( OO) TOpinOlfl sensors Com (in) 9,8306 45]5.0 49.35 SBR 16 901 Bore Deployment Sleeve 27WOD. 2. 5" 2250 Polished Bore CONDUCTIXt 3861180 9,8719 8,801.8 49.25 NIPPLE RProhle nipple (1781"Bore, 2J0"DD) 1.781 10.610.5 FRAC SLEEVE 93'. Ball drop trac sleeve, ID 1.656 Ball OD 1.718" - 1. GCs BFT; E..a opened 1-20-19 11,053.0 FRA LEEVE V: Ball drop fore sleeve, ID 1.EBY Ball OD 1,625" - 1625 opened 1-20-19 11.302.1 FRAC SLEEVE 51. Ball drop frac sleeve ID 143 --Ball 0D 1 1438 opened 1-20-19 12,0273 PERFDRATED an Joint(0281'. 3 SPT_ 60°) 1992. SURFACE: M ".2068—T JT Other In Hole (Wireline retrievable plugs, valves, pumps, Flsh, etc.) TOP fTVCI Top mol OLSUF1a.ID83El TOp(nna) 1KKe1 f1 CaseCan Run Oeh 1011n1 9,934.0 4642.5 4986 NS WS F1350Inner Wedge WS 11 I 8 Frac Summary slanoffi Pra,"oeaklnm Qb) Postal In Possession da, Gas urn a,aw.z 1202019 62,500.0 63,312.0 SIgY 9mRDab TOp CepM(nKB) IM inKBI Ukb Feld 6yshm VOI Cbn166g Vq Sbrryibbl 1 1202019 12,02] 0 12,028.0 Gelletl Salt Wacer, 251b Boace 1,390.00 1,459 00 sbnoalevmppant O's en. Prappwr a Formation girl 1202019 62,5000 62.81 WE LIFT 81T'v.B "i 2 Smd Orb IT."Oeplh (OKB) BM(IMBI Lmkb Flup Syabm 121012019 11,302A 11,303.0 Gelled Salt Water, 25 If Borate VWCION(baH VOISIarry(bbh 1,08460 1,132.01] filed Oam Pmp ntM wl (lb) PmpMntln Forme) 1W) 12012019 62,500.0 32,100.0 Sy1F Sbd Cqe Top Cepm rymel Bdn ryMB) LMk b Flute Syabm VOICNan (bbq VOI Slurry lbbll 4 12012019 10,8180 10,811.0 Gelletl Salt Wates 251b Borate 1,05800 1,091A0 GAS LIFT: 9.0677 Sqd Da@ PRdAdN e4gMa(Id Pmppanl In Formation did 12W2019 82,5000 62,3600 Ill ligualase TOP Depth ME) Bdn MIR Llnk b Flub Syskm VOICMen deth Vol Sluidend 3 1202019 11,052.0 11,0530 Gelled Salt Water, 251b Borate 945.00 1,042.00 Notes: General & Safety Ena care Annotator r.+a uFT; e,6a.a 11292019 NOTE'. View Schematic wl Alaska Schematic 10.0 PACKER. Reil NIPPLE, 9,69¢6 it LINER TOP PACKER: ii"O PRODUCTION:97-,D'!de0 fl N6W8;9,6a,.0 A LINER; B,BAI.r-12,2470� 3C -08A FRACTURE STIMULATE DTTM JOBTYP SUMMARYOPS START 1/18/19 DRILLING PULLED RX PLUG IN PTSA @ 9831' RKB. SUPPORT JOB COMPLETE AND READY FOR FRAC. - CAPITAL 1/20/19 DRILLING Performed mini -frac and 4 stage frac per SUPPORT- design @ 15-20 bpm (ran short of sand on CAPITAL last stage due to freezing in castle). Placed 222,150# of 20/40 Wanli with carbo scale gaurd mixed. Well freeze protected with 25 bbls of LVT. Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 2019-01-.,. State: Alaska County: Beechey Point API Number: 5002921390 Conoco Phillips, Operator Name: Alaska Inc. Well Name and Number: 3C-OBA Longitude: -149.77 Latitude: 70.4 Long/Lat Projection: NAD27 Indian/Federal: none Production Type: Oil True Vertical Depth (TVD): 6,702 Total Water Volume (galr: 187,374 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Number (CAS (% by mass)" HF Fluid (% by a) mass)`" Sea Water Operator Base Fluid Water 7732-18-5 96.00% 82.93874% BE -6 Halliburton Biocide Listed Below Listed Below MICROBIOCIDE 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-II DELAYED Halliburton Breaker Listed Below Listed Below RELEASE BREAKER OPTIFLO-III DELAYED Halliburton Breaker Listed Below Listed Below RELEASE BREAKER SP BREAKER Halliburton Breaker Listed Below Listed Below WG -36 GELLING Halliburton Gelling Agent Listed Below Listed Below AGENT LVT-200 Halliburton Freeze Protect Listed Below Listed Below Wanli 20/40 Halliburton Pro ant Listed Below Listed Below Ingredients Listed Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00085% Above 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00150% Acrylate polymer Proprietary 1.00% 0.00158% Ammonium persulfate 7727-54-0 100.00% 0.02199% Borate salts Proprietary 60.00% 0.09454% Corundum 1302-74-5 65.00% 7.69334% Crystalline silica, quartz 14808-60-7 30.00% 0.00622% Cured acrylic resin Proprietary 30.00% 0.00660% Ethanol 64-17-5 60.00% 0.05083% Guargum 9000-30-0 100.00% 0.25367% Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02541% Hydrotreated Distillate, Light C9 -C 16 64742-47-8 100.00% 1.16333% Mullite 1302-93-8 45.00% 5.32616% Naphthalene 91-20-3 5.00% 0.00424% Oxylated phenolic resin Proprietary 30.00% 0.03388% POIy(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 5.00% 0.00424% branched Potassium formate 590-294 60.00% 0.09454% Potassium hydroxide 1310-58-3 5.008 0.002054 'otassium metaborate 13709-94-9 Sodium carboxymethyl cellulose 9004-324 60.008 1.008 0.024584 0.001584 Sodium chloride 7647-14-5 4.004 3.45781% Sodium glycollate 2836-32-0 1.008 0.001584 Sodium hydroxide 1310-73-2 30.008 0.013674 Sodium persulfate 7775-27-1 100.008 0.000274 Sodium sulfate 7757-82-6 0.108 0.000008 Water 7732-18-5 100.004 0.117424 `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 1 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 subiect to 29 CFR 1910.1200(i) and Appendix D. Ingredient Mass Ibs Comments Company First Name Last Name Email Phone 1546194 Density 8.596 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 0 NA 16 28 30 Denise Tuck, Halliburton, 3000 N'Sam Houston Pkwy E., Houston, TX 77032,281- 871-6226 Halliburton Denise Tuck Denise.Tuck @Halliburton.c om 281-871-6226 410 1763 Halliburton Denise Tuck Denise.Tuck @Halliburton.c om 281-871-6226 143424 117 123 Halliburton Denise Tuck Denise.Tuck @Halliburton.c om 281-871-6225 948 4729 474 21688 99294 79 632 Halliburton Denise Tuck Denise.Tuck @Halliburton.c om 281-871-6226 79 1763 39 459 30 64464 30 255 6 1 2191 vJJ and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the se note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the HALLIBURTON Sales Order# 905405215 Conoco Phillips Alaska Kuparuk River Unit 3C -08A Intervals 0-4 A -Sand A -Sand Formation Harrison Bay County, AK API: 50-029-21390-0100 Preparedfor: Sandeep Pedam January20, 2019 Stimulation Treatment Post Job Report 25# Hybor-G Prepared By: Landon Harrison Daniel Salazar Nanook Crew Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk. HALLIBURTON Table of Contents Section Page(s) Executive Summary 3 Actual Design 4 Interval Summary 5-10 Fluid System-Proppant Summary 11 Minifmc Plots 12-17 Interval Plots I8-21 Interval Plots 22-25 Interval Plot 26.29 Interval Plots 30.33 Appendix 34 Chemical Summary 35 Planned Design 36 Water Straps 37 Water Analysis 38 Hydration Test 39 Real -Time QC 40 Wellbore Information 41 Event List 42 Farm 15 Minute Zone 1 43 Farm 15 Minute Zone 2 44 Farm 15 Minute Zone 3 45 Farm 15 Minute Zone 4 46 Chemical Lot Numbers 47 lab Testing 48-51 Conoco Phillips Alaska- Kuparuk River Unit 3C -08A TOC Engineering Executive Summary On January 20, 2019 a stimulation treatment was performed in the A -Sand formation on the Kuparuk River Unit 3C -08A well in Harrison Bay County, AK. The Kuparuk River Unit 3C -08A was a 5 stage Horizontal Sleeve Design. The proposed treatment consisted of: 0 gallons of Sea Water 0 gallons of Treated Water 163,990 gallons of 25# Hybor-G 6,824 gallons of 25# WaterFrac-G 840 gallons of Freeze Protect 250,000 pounds total of Wanli 20/40 + SG 20/40 225,000 pounds of Wanli 20/40 25,000 pounds of Scaleguard 20140 The actual treatment fully completed 4 of 5 stages. 0 stages were skipped, and 1 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 0 gallons of Sea Water 0 gallons of Treated Water 179,053 gallons of 25# Hybor-G 8,321 gallons of 25# WaterFrac-G 1,050 gallons of Freeze Protect 220,562 pounds total of Wanli 20/40 + SG 20/40 194,562 pounds of Wanli 20140 26,000 pounds of Scaleguard 20/40 A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: During the treatments of this well HES had issues with frozen sand. The frozen sand would come out of the castles in clumps that were larger than the hopper grates, which eventually would seat off the augers reducing sand concentration. The crew broke the frozen sand up to the best of their ability without compromising HSE. The final treatment interval was cut short after the issue became too severe to continue and sand stopped flowing from the Castle. Approximately 30, OOO/bs of Wanlf 20/40 was left in the frozen in the castles at this time. Instead of 25, OOOlbs of Scaleguard 20/40 being delivered to location 26, OOOlbs was delivered and the decision to pump the entire volume was made. Before the job was started pumping the origonal LA for CL-22UC had issues and the LA was swapped to a different LA. During the job the LA pumping CL-22UC began to f/uxuate. The displayed variable was changed to a weighted average of the CL-22UC. Although the intent was to meter Scaleguard proppant at a concentration of 10% by weight of proppant via manual valve manipulation, the final proppant concentration was through the 11.8% Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Thank you, Landon Harrison Technical Professional Halliburton Energy Services Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Executive Summary Conoco Phillips Alaska-gupawk River Unit 3G08A Actual Design Start Date/Time: 1/20/19 12:50 End Date/Time: 1/20/19 13:21 Pump Time: 31 min Initial Rate (Breakdown): 13.0 bpm Initial Surface Pressure (Breakdown): 6,537 psi Max Rate: 16.2 bpm Max Surface Pressure: 6,933 psi Average Rate: 15.8 bpm Average Missile Pressure: 6,258 psi Average Surface Pressure: 6,162 psi Average Missile HHP: 2,423 hhp Initial OA Pressure: 170 psi Max OA Pressure: 210 psi Max Proppant Concentration: 0.00 PPg Average Visc: 18 CP Average Temp: 70 F Average pH: 9.3 ISDP: 2078 psi Final Fracture Gradient: 0.758 psifft Final 5 min: 1801 psi Final 10 min: 1659 psi Final 15 min: 1585 psi Proppant Summary Want! 20/40 + SG 20/40 Pumped: 0 lbs Total Proppant Pumped" : 0 lbs Proppant in Formation: 0 lbs Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Interval Summary Fluid Summary (by fluid description) tnglneer Landon Harrison per customer engineerlmid request due to cold temperatures. Sea Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 25# Hybor-G Volume: 12,673 gal 302 bbis 25# WaterFrac-G Volume: 4,304 gal 102 bbls Freeze Protect Volume: 0 gal 0 bb/s Fluid Summary (by stage description) Pad Volume: 0 gal 0 bbls Proppant laden Fluid Volume: 0 gal 0 bbls Flush Volume: 4,304 gal 102 bb/s Minifrac Volume: 10,096 gal 240 bb/s Freeze Protect Volume: 0 gal 0 bb/s Ball Drop - 1.375 Volume: 2,577 gal 61 bbls Interval Status: Completed Pumped Mlndrac prior to treatments. Uidn't see closure before moving ahead wlin timt treatment tnglneer Landon Harrison per customer engineerlmid request due to cold temperatures. Treater Daniel Salazar Supervisor. Daniel Salazar 'Values for pmppant are taken from software calculations based on multiple variables. Customer Eng: Adam Klem Proppant is billed off of weight ticket volumes and may vary slightly from this number. CustOmer Re P' Paul Bessette Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Interval Summary 6 Fluid Summary (by stage description) Pad Volume: Interval Summary gal 301 bbls Start Date/Time: 1/20/19 13:45 gal 662 bbls End Date/Time: 1/20/19 15:00 gal 0 bbls Pump Time: 75 min 0 bbls Initial Rate (Breakdown): 13.0 bpm 0 bbls Initial Surface Pressure (Breakdown): 6,537 psi 24 bbls Max Rate: 15.9 bpm Max Surface Pressure: 5,887 psi Average Rate: 15.8 bpm Average Missile Pressure: 5,083 psi Average Surface Pressure: 4,978 psi Average Missile HHP: 1,968 hhp Initial OA Pressure: 238 psi Max OA Pressure: 307 psi Max Proppant Concentration: 4.06 ppg Average Visc: 18 cP Average Temp: 86 F Average pH: 9.5 Proppant Summary Wanli 20140 + SG 20140 Pumped: 63,312 lbs Total Proppant Pumped" : 63,312 lbs Proppant in Formation: 63,312 His Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bb/s Treated Water Volume: 0 gal 0 bbls 25# Hybor-G Volume: 41,467 gal 987 bbls 25# WaterFrac-G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,656 gal 301 bbls Proppant Laden Fluid Volume: 27,812 gal 662 bbls Flush Volume: 0 gal 0 bbls Minifrac Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Spacer and Ball Drop - 1.500 Volume: 999 gal 24 bbls Interval Status: Completed worked to break apart the chunks while continuing with the zone. proppant are taken from software calculations based on multiple variables. billed off of weight ticket volumes and may vary slightly from this number. Treater: Daniel Salazar Supervisor: Daniel Salazar Customer Eng: Adam Klem Customer Rep: Paul Bessette Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Interval Summary 7 Fluid Summary (by fluid description) Sea Water Volume: Interval Summary gal Start Date/Time: 1/20/19 15:01 Treated Water Volume: End Date/Time: 1/20/1916:02 0 Pump Time: 61 min Initial Rate (Breakdown): N/A bpm Initial Surface Pressure (Breakdown): N/A psi Max Rate: 20.1 bpm Max Surface Pressure: 6,811 psi Average Rale: 20.0 bpm Average Missile Pressure: 6,264 psi Average Surface Pressure: 6,140 psi Average Missile HHP: 3,071 hhp Initial OA Pressure: 321 psi Max OA Pressure: 343 psi Max Proppant Concentration: 4.39 ppg Average Vise: 18 cP Average Temp: 83 F Average pH: 9.5 ISIP: 2244 psi Initial Fracture Gradient: 0,783 psi/ft Proppant Summary Wanli 20/40 +SG 20140 Pumped: 62,880 lbs Total Proppant Pumped' : 62,880 lbs Proppant in Formation: 62,880 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 25# Hybor-G Volume: 44,684 gal 1,064 bbls 25# WaterFrac-G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 13,943 gal 332 bbls Proppant Laden Fluid Volume: 29,982 gal 714 bbls Flush Volume: 0 gal 0 bbls Minifrac Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Spacer and Ball Drop - 1.625 Volume: 759 gal 18 bb/s Interval Status: Completed proppant concentration during stages due to frozen sano getung caugm on n employees worked to break apart the chunks while continuing with the zone. for proppant are taken from software calculations based on multiple variables. t is billed off of weight ticket volumes and may vary slightly from this number. Treater: Daniel Salazar Supervisor: Daniel Salazar Customer Eng: Adam Klein Customer Rep: Paul Bessette Conoco Phillips Alaska - Kuparuk River Unit 3C -OSA Interval Summary 8 Kuparuk River Unit 3C -08A - A -Sand - Interval 3 5.5 Interval Summary Start Date/Time: 1/2011916:02 End Date/Time: 1120/1916:59 Pump Time: 57 min Initial Rate (Breakdown): 5.5 bpm 294 bbls Initial Surface Pressure (Breakdown): 4,757 psi 659 bbls Max Rale: 20.4 bpm 0 bb/s Max Surface Pressure: 6,499 psi 0 bb/s Average Rate: 20.2 bpm 0 bb/s Average Missile Pressure: 5,688 psi 22 bbls Average Surface Pressure: 5,570 psi Average Missile HHP: 2,816 hhp Initial OA Pressure: 339 psi Max OA Pressure: 362 psi Max Proppant Concentration: 4.46 Pp9 Average Visc: 19 cF Average Temp: 81 F Average pH: 9.4 Proppant Summary Wanli 20/40 + SG 20/40 Pumped: 62,360 lbs Total Proppant Pumped' : 62,360 lbs Proppant in Formation: 62,360 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 25# Hybor-G Volume: 40,937 gal 975 bbls 25# WaterFrac-G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bills Fluid Summary (by stage description) Pad Volume: 12,359 gal 294 bbls Proppant Laden Fluid Volume: 27,661 gal 659 bbls Flush Volume: 0 gal 0 bb/s Minifrac Volume: 0 gal 0 bb/s Freeze Protect Volume: 0 gal 0 bb/s Spacer and Ball Drop - 1.718 Volume: 917 gal 22 bbls Interval Status: Completed employees worked to break apart the chunks while continuing with the zone. ITreater: Daniel Salazar Supervisor. Daniel Salazar as for proppant are taken from software calculations based on multiple variables. Customer EngAdam Klem pant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessette Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Interval Summary 9 s_e-117rrrre Start Date/Time: 1/20/19 16:59 End Datelfime: 1/20/19 18:23 Pump Time: 84 min Initial Rate (Breakdown): N/A bpm Initial Surface Pressure (Breakdown): N/A psi Max Rate: 23.3 bpm Max Surface Pressure: 6,263 psi Average Rate: 17.3 bpm Average Missile Pressure: 4,676 psi Average Surface Pressure: 4,569 psi Average Missile HHP: 1,983 hhp Initial OA Pressure: 358 psi Max OA Pressure: 360 psi Max Proppant Concentration: 2.56 ppg Average Visc: 17 cP Average Temp: 76 F Average pH: 9.4 ISIP: 1665 psi Initial Fracture Gradient: 0.706 psilff ISDP: 1884 psi Final Fracture Gradient: 0.739 psifR Proppant Summary Wanli 20/40+SG 20/40 Pumped: 32,100 lbs Total Proppant Pumped` : 32,100 lbs Proppant in Formation: 32,100 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bb/s 25# Hybor-G Volume: 39,292 gal 936 bills 25# WaterFrac-G Volume: 4,017 gal 96 bbis Freeze Protect Volume: 1,050 gal 25 bb/s Fluid Summary (by stage description) Pad Volume: 14,840 gal 353 bills Proppant Laden Fluid Volume: 24,452 gal 582 bb/s Flush Volume: 4,017 gal 96 bills Minifrac Volume: 0 gal 0 bbls Freeze Protect Volume: 1,050 gal 25 bb/s Interval Status: Cut Short t pmppant concentration during stages due to frozen sand getting caught on hopper grate. tngineer. Landon Harrison S employees worked to break apart the chunks while continuing with the zone. During 2 ppg Treater: Daniel Salazar d stage couldn't get proppant out of sand castle, HES employees worked to work sand out of castle but after a solution could not be found, customer requested we cut sand and call flush. Supervisor: Daniel Salazar proppant are taken from software calculations based on multiple variables.I Customer Eng: Adam Klein billed off of weight ticket volumes and may vary slightly from this number. CuafOmer Rep: Paul Bessette Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Interval Summary 10 Customer Conoco Phillips Alaska lawmadon A -sane HALLIBURTON I "Isr °i- Enh- leas¢ Kupamk Rlvu Unit 3C -08A API 50-0M2139 0100 Date January 20, 2019 Well Summary Planned Recorded Fluids PropPants Interval ESg Hybl 254 Wa[e Fracb Freeze Protect Total Fluid Wa01120140+SG20/40 Wanli211/40 Scalegoard20/40 Total Proppant Wanli 20/40 Scaleguar020/40 Total Proppant gal blA gal bbl gal bbl gal bbl Its lbs Its lbs 0 12,673 302 4304 102 1,050 25 188,424 4,486 16,971 404 1 41,46/ 987 41,4W 982 63,312 63,312 2 44,634 1,0W 44,684 1,064 62,880 62,880 3 40,932 925 40,932 925 62,3W 62,360 4 39.292 936 4,017 96 11050 25 44,359 1,056 32,100 32,100 Minimum 12,623 302 4,012 96 1,050 25 16,972 404 32,100 32,100 Average 35,811 8553 4,161 99 1,050. 25 32,685 892 55,163 55,163 Marimum 44,684 1,064 4,304 102 1,050 25 ",684 1,064 63,312 63.312 Planned Recorded -26,000 "IFS numbers for proppant are taken from software czlmlations based an multiple variables ProppaM b billed hope Weight Ticket volumes C... Phillips Alaska- Kuparuk Rluer Unit XC SA Fluid System-Pmppant Summary 11 Fluids Proppants 25p HybonG 25N Wah Frzo6 Freeze protect Total Fluid Wang X/42+20/40 Wanli 20/40 Scaleguar020/40 Total Proppant gal bbl gal bbl gal bbl gal bbl lbs lbs Its I Total 163,990 1 1 3,905 6,824 162 .0 20 1 171,654 4.82 250,000 0 0 250,000 179,053 1 4,263 0,321 198 1,050 25 188,424 4,486 220,652 0 0 220,652 WGIght Tickets 294.562 26000 220,562 -26,000 "IFS numbers for proppant are taken from software czlmlations based an multiple variables ProppaM b billed hope Weight Ticket volumes C... Phillips Alaska- Kuparuk Rluer Unit XC SA Fluid System-Pmppant Summary 11 Pressure Test - M inifrac-Treatment 4 Treating Pressure (psi) Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) P1 Kickoilf Pressure (psi) — 10:15 10:20 10:25 10:30 10:35 10:40 10:45 112012019 1/2012019 Time Global Event Log ® Test Global KICkoUts 10:15:37 ❑3 Test Local Kickouts 10:16:08 Failed Pressure Test -No usual leaks 10:23:30 ❑5 Failed Pressure Test -No usual leaks 10:30:23 Successful Pressure Test -No usual leaks 10:40:04 ❑7 Successful Pressure Test -Confirmation 10:4378 Cusbmer. Conoco Phillips, Alaska Inc Job Date: 20Jan-2019 Sales Order* 0905403215 Well Description: Kuparuk River Unit 3C -08A U1M: 50-029-213900100 Conoco Phillips Alaska- Kuparuk RJwr Unit 3C -08A Minikac Min, 12 Nitrogen Pop -Off Test -Minifrac-Treatment4 Treating Pressure (psi) Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) Pi Kickout Pressure 1psi) ime Global E1ant Log I®° N2 Pop -Off -Failed to Pop Unit 10:49:23 W N2 Pop -Off -Successful Test (8471 psi) 10:53:51 Customer: Conoco Phillips, Alaska Inc. Job Date: 20Jan-2019 Sales Order#: 0905403215 Well Descripfion: Kuparuk River Unit 3C -08A UVW 50-029-213900100 Conoco Phillips Alaska -Kuparuk Piver Unit 3C48A Mlnifnc Plots 13 Treatment Plot - Minifrac A ITreating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppan! Conc (Ilb;yal) --- C BH Proppant Conc (Ib/gal) C n,114 Mil Description: Kuparuk Riper Unit 3C -08A I USM: 50-029-213900100 Conoco Phillips Alaska - Kuparuk River Unit 3C48A Minifrac Plocs 14 Blender Chemical Plot - Minifrac CL -22 UC Conc (gallMgal) — A - – - MO -67 Conc (gallMgal) A A 0pt1flo4II Conc (Ib/Mgal) B Optiflo-II Conc (IWMgal) B B 12:55 13:00 13:05 13:10 13:15 13:20 i/M019 1/2012019 Time Customer. Conoco Phillips, Alaska Inc. Job Date: 20 -Jan -2019 Sales Order#: 0905403215 Well Descnpflon: Kuparuk Ricer Unit 3C -08A UW1: 50-029-213900100 Conoco Phillips Kaska - Kuparuk River Unit 3C -03A MinRrac Plots ADP Chemical Plot - Minifrac A Losurf-300D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgap 6 12:55 13:00 13:05 13:10 13:15 13:20 1/202019 1I20I2019 Time Customer. Conoco Phillips, Aaska Inc. Job Date: 20 -Jan -2019 Sales Order#: 0905403215 Well Descdpbon: Kuparuk RiverIJnit3C-08A JW: 50-029-213900100 Conoco Phillips Alaska- Kuparuk River Unit 3C-O8A Minifrac Plots Net Pressure Plot - Minifrac — Net Caldd BH Pres (psi) A — BH Pmppant Conc (Ib/gal) B A Slope of Net Pressure (psi/min) c B Time (min) MIl Description: Kuparuk River Unit 3C -08A I UW: 50-029-213900100 Coraco Phillips Alaska - Kupamk River Unit 3C418A Mindrac Plots 17 Treatment Plot - Treatment 1 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conic Ob/gal) - :; BH Proppant Conic Ob/gal) C B C ume Wall Description: Kuparuk River Unit 3C -08A I U1M: 50-029-213900100 Conoco Phillips Alaska - Kuparuk River Unk 3C -08A InW,.l1 Plod 18 Blender Chemical Plot -Treatment 1 CL -22 UC Conc (gal/Mgal) — A - - ---- MO -67 Conc (gal/Mgal) A A Optiflo-III Conc (Ib/Mgal) B Optiflo-II Conc (lb/Mgal) B B 2. 1. 1. 1. 1. 1. 0. 0. 0. 0. n 13:50 14:00 14:10 14:20 14:30 1/20/2019 Time Customer. Conoco Phillips, Alaska Inc Job Date: 20 -Jan -2019 Sales O Well Description: Kuparuk Riper Unit 3C -08A UVd: 50-029-213900100 14:40 14:50 112012019 Conoco Phillips Abska - Kuparuk River Unit 3C -08A Interval 1 Plats 19 IR 11 OwW 13:50 14:00 14:10 14:20 14:30 1/20/2019 Time Customer. Conoco Phillips, Alaska Inc Job Date: 20 -Jan -2019 Sales O Well Description: Kuparuk Riper Unit 3C -08A UVd: 50-029-213900100 14:40 14:50 112012019 Conoco Phillips Abska - Kuparuk River Unit 3C -08A Interval 1 Plats 19 ADP Chemical Plot - Treatment 1 A Losurf-300D Cone (gal/Mgal) A WG-36Conc (16IMgaI) B 6 100 90 80 70 60 50 0 30 20 10 0 13:50 14:00 14:10 14:20 14:30 14:40 14:50 1/3012019 Time 112MO19 2.0 1.8 1.4 1.2 1.0 0.8 0. 0.4 0.2 0 1. 0 6 , PITYPTIVIONOm".111 Up Well Description: Kuparuk Riper Unit 3C -08A I UVW 50-029-213900100 Conoco Phillips Alaska - Kuparuk RIwr Unit 9G08A Interval 1 Plots 20 Well Description: Kuparuk Riper Unit 3C -08A I UVW 50-029-213900100 Conoco Phillips Alaska - Kuparuk RIwr Unit 9G08A Interval 1 Plots 20 Net Pressure Plot - Treatment 1 Net Calc'd BH Pres (psi) A — BH Proppant Conc (Ib/gal) B A Slope of Net Pressure (psi/min) C Time (min) Wall Description: Kuparuk Ricer Unit 3C -08A I UVN: 50-029-213900100 Conoco Phillips Alaska - Kuparuk River Unit 3C-0BA Interval 1 Plots Treatment Plot -Treatment 2 Treating Pressure (psi) A Slurry Rate (bpm) B A -lorry P:nppani Conc rlblFall -- BH Proppant Conc (Ib/gal) C m,rta Well Description: Kuparuk River Unit 3C -08A I UW: 50-029-213900100 Conoco Phillips Alaska - Kupamk River Unit 3C -MA Interval2 Plots C 10 1.0- 0.8- 0.6- 0.4- 0.2- 11 0.0- 1500 1510 15:20 15:30 15:40 15:50 1/2012019 Time 1IM2019 Customer. Conoco Phillips, Alaska Inc. Job Date: 20Jan-2019Sales Order #: 0905403215 MIl Description: Kuparuk River Unit 3C -08A UVN50-029-213900100 Blender Chemical Plot - Treatment 2 CL -31 Conc (gal/Mgal) k M0-67 Conic (gal/Mgal) A Optiflo-111 Cone (Ib/Mgal) B Optifloal Cone Qb/Mgal) B Moping A1g Of CL -22 UC Cone (gal/Mgal) A ) 1 v.yly�.la.a�A.��,5�4wa✓1 - I„ I -3 _2 -1 U1 Conoco Phillips Alaska - Kuparuk River link 3C -08A Interval Plots 23 A 2.0- 1.8- 1.6- 1.4- 1.2- 1.0- 0.8- 0.6- 0.4- 0.2- 0.0 ADP .8- 1.6- 1.4- 1.2- 1.0- 0.8- 0.6- 0.4- 0.2- 0.0 ADP Chemical Plot -Treatment 2 Losuff-30UD Conc (gal/Mga1)A WG-36Conc (lb/Mgal) 8 15:00 15:10 15:20 15:30 15:40 15:50 112a201e v2a2019 Time Nall Descdptlon: Kuparuk Riper Unit 3C -08A I UW: 20 -Jan -2019 Sales Order#: 0905403215 50-029-213900100 6 -100 -90 -80 -70 -60 -50 40 -30 -20 NO -0 Conoco Phillips Alaska - Kuperuk River Unit X -08A Interval Plots 24 15:00 15:10 15:20 15:30 15:40 15:50 112a201e v2a2019 Time Nall Descdptlon: Kuparuk Riper Unit 3C -08A I UW: 20 -Jan -2019 Sales Order#: 0905403215 50-029-213900100 6 -100 -90 -80 -70 -60 -50 40 -30 -20 NO -0 Conoco Phillips Alaska - Kuperuk River Unit X -08A Interval Plots 24 Net Pressure Plot - Treatment 2 — Net Calc'd BH Pres (psi) A — BH Proppant Conc (It19al) B A Slope of Net Pressure (psi/min) C Time (min) Customer. Conoco Phillips, Aaska Inc. Well Description: Kuparuk River Unit 3C -08A Job Date: 20Jan-2019 JW: 50-029-213900100 Sales Orderk 0905403215 Conoco Phillips Alaska - Kuparuk River Unit 3C -ORA Interval Plots 25 Treatment Plot - Treatment 3 Treating Pressure (psi) A Slurry Rate (bpm) B A Slurry Proppant Colic llbigaij -- C BH Proppant Conc (Ib/gal) C B C I ime Customer. Conoco Phillips,0905403215 Wall Description: Kuparuk River U it 3 08A Job 50-029-213900100 Sales Order* Conoco Phillips Alaska - Kuparuk River Unit 3C -MA Interval 3 Plots 26 Blender Chemical Plot - Treatment 3 Optiflo-III Conc (Ib/Mgal) B Opliflo-ll Conc (Ib/Mgal) B A Moping A1g Of CL -22 UC Conc (gal/Mgal) A B lima Customer Conoco Phillips, Alaska Inc. Job Date: 20Jan-2019 Sales Order#: 0905403215 Well Descnption: Kuparuk River Unit 3C -08A UW: 50-029-213900100 Conoco Phillips Alaska - Kupamk River Unit 3C -OSA Interval 3 Plots ADP Chemical Plot -Treatment 3 A I Losurf-300D Cone (gal/Mgal) A WG -36 Cone (ib/Mgal) B B lime Well Descnpton: Kuparuk River Unit 3C -08A I UNA: 50-029-213900100 Conoco Phillips Alaska - Kuparuk River Unit 3C -OSA Interval Plats 28 Net Pressure Plot - Treatment 3 Net Calc'd BH Pres (psi) A —BH Proppant Canc (lb/gal) B A Slope of Net Pressure (psi/min) C Time (min) Well Description: Kuparuk Riper Unit 3C -08A I UW1: 50-029-213900100 Conoco Phillips Alaska - Kuparuk Rwer Unit 3C -OU Inteml 3 Plots Treatment Plot - Treatment 4 Treating Pressure (psi) A Slurry Rate (bpin) B A Slurry Proppmri Conic db/gap C BH Proppant Conic (Ib/gal) C B C 17:00 17:20 17:40 18:00 18:20 1/2a2019 112=H9 Time Customer. Conoco Phillips, Alaska Inc. Job Date: 20 -Jan -2019 Sales Order* 0905403215 WaIIDescnption: Kuparuk Rirer Unit 3C -08A LIM 50-029-213900100 force Phillips Alaska - Kuparuk River Unit 3C -08A interval Plots 30 A 2.0- 1.0- 0.8- 0.6- 0.4 0.2 0.0 17:00 17:10 17:20 17:30 17:40 1/MM19 Time Blender Chemical Plot - Treatment 4 CL -31 Cone (gaWgal) A MO -67 Cone (gal/Mgal) A Optiflo-lll Cone (Ib/Mgal) B Optiflo-ll Cone (Ib/Mgal) B Meting Avg Of CL -22 UC Cone (gal/Mgal) A -- k4 1 t' , i .... 7 117 17:50 18:00 18:10 Customer Conoco Phillips, Alaska Inc. Job Dale: 20 -Jan -2019 I Sales Order 4: 0905403215 Wall Description: Kuparuk River Unit 3C -08A U\M: 50-029-213900100 B -4 -3 -2 1 1 0 18:20 1/2012019 Conoco Phillips Alaska- Kuparuk River Unit 3C -MA Intental4 Plots 31 ADP Chemical Plot -Treatment 4 Losurf-300D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgap 8 i I rVy LIA 1700 17:10 17:20 17:30 17:40 112w20ts Time Well Descnption: Kuparuk Riper Unit 3C -08A I UIh1: 50-029-213900100 17:50 18:00 18:10 v2v20as B 100 90 BID 70 50 50 40 30 20 10 3 Conoco Phillips Alaska -Kuparuk River Unit 3C -OSA Interc l4 Plats 32 Net Pressure Plot - Treatment 4 Net Caled BH Pres (psi) A — BH Proppant Conc (Ib/gal) B A Slope of Net Pressure (psi/min) C Time (min) Customer: Conoco M11 Description: Kupawk RtiiverUnit 3C -08A UW: aska Inc. Job ate: 50-0292013900100 Sale50rder#: 0905403215 I Conoco Phillips Alaska-Kuparuk River Unit 3C -WA Interval 4 Plots HALLISURTON Sales Ord®r# 905403215 Conoco Phillips Alaska Kuparuk River Unit 3C -08A Intervals 0-4 A -Sand A -Sand Formation Harrison Bay County, AK API: 50-029-21390-0100 Prepared for: Sandeep Pedam January 20, 2019 Stimulation Treatment Appendix - Chemical Summary - Planned Design - Water Straps - Water Analysis - Hydration Tests - Real -Time QC - Wellbore Information - Event List - Fann 15 Minute - Chemical Lot Numbers - Lab Testing Conoco Phillips Alaska - Kuparuk River Unit 3C -08A Appendix 34 Customer Conoco Phillips Alaska Formation A -Sand HALLISURTON Enhancemane were Kuparuk River Unit 3C -08A API 50.029.21390-0300 Date 1/20/2019 Interval 5ummary - Chemicals Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Chemical Summary 35 Liquid Additives Dry Additives Interval L4Surf-3001D M047 CL -22 UC CL -31 LW -200 WG -36 BE -6 Optill.111 OpUFlo-II SP (9011 (9a1) (9a1) (9a1) (90)) ()bs) (Its) (lbs) (lbs) (lbs) Prime Up 0 0 0 0 0 0 5 0 0 0 0 17 6 17 5 0 569 3 35 4 0 1 47 19 54 15 0 1035 6 83 11 0 2 45 19 61 16 0 1109 7 89 31 0 3 el ifi 59 14 0 1018 6 82 10 0 4 66 19 60 21 3150 998 7 72 13 5 Total 210 80 250 70 3150 4729 33 360 50 5 W/o Prime Up 210 80 250 70 3150 4729 28 360 50 5 Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Chemical Summary 35 Conoco Phillips Alaska - Kuparuk River Unit 3C -08A Planned Design 36 Customer: Conoco Phillips Alaska Well: Kuparuk River Unit 3C -08A Date: 1/20/2019 Formation: A -Sand SO#: 905403215 Dav: Treatments 1-4 Conoco Phillips Alaska - Kuparuk River Unit 3C-0BA Water Straps 37 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels 1 Atigan CPF3 110 20,722 493 143 9 1,262 30 2 Atigan CPF3 109 20,529 489 114 9 1,262 30 3 Atigan CPF3 106 19,949 475 111 9 1,262 30 4 Atigan CPF3 108 20,336 484 114 9 1,262 30 5 Atigan CPF3 106 19,949 475 108 9 1,262 30 6 Atigan CPF3 103 19,368 461 110 70 12,985 309 7 Atigan CPF3 105 19,755 470 112 70 12,985 309 8 Atigan CPF3 103 19,368 461 108 9 1,262 30 9Atigan CPF3 106 19,949 475 111 9 1,262 30 10 Atigan CPF3 107 20,142 480 111 9 1,262 30 11 Atigan CPF3 104 19,562 466 111 9 1,262 30 Location Summary Starting Volume Ending VolumeTotal Used Gallons Barrels Gallons Barrels IFGallons Barrels 219,628 5,229 37,329 889 1 182,299 4,340 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 451 1 434 2 3 1,344 2,237 3 5 353 272 4 3,129 7 191 5 4,087 9 104 6 0 475 7 0 475 Conoco Phillips Alaska - Kuparuk River Unit 3C-0BA Water Straps 37 Cnmp.ng well Hame: fidd., nme: HALLISURTON Melee District Field Prcjob Water MCFryiaon Lwaaion Conoco Phillips Alaska, Inc. Treabneos: Kuparuk River Unit 3C -M Date Tena,: CPF3 14 1/16/2019 Specific Gmlry TeaOr:e TemperaW re DissoNe, Fear Iron Chlon,e a Sulfite GII ..,nealum Total Total Linear $Oa G" (me') Hardness NWHI NuoaM] Water pH Gel pX PrefroWink PH Paan{ eslink PH C.wink bacteria 'F nol mg/L m8/L ngA rgA MOIL mp/L R 1Y/H) BrIllue Ta.. HVdmm.r Oval Thermametn InIp Tlbetpn SNp Titration '..'Hardness libation $blp FPHH-35 Minus Calcium Probe Probe Probe Probe � Mµumeler 1 1,430 660 0 1, No . I'm 1,280 2.880 1M 20 J.3 13 9.] 9.9 Y B,EEl 2 1.030 66• 0 UNo . ON 1,N0 2.800 IN 20 11 J.3 9.9 ]0.1 Y 236,318 3 1,431 663 0 ]84DO 800 1,560 1.360 2.930 IN 20 70 J.J 9.7 9.8 Y 197,145 d 1,431 66.0 0 20,0.00 1300 1,240 1,600 3,810 IN 20 ]0 1.5 9.7 9.9 Y 237,865 5 1.030 65.2 0 19,2[0 1300 1,040 1,720 2,760 IN 21 ].2 1.1 9.6 9.7 Y 144,150 fi 1,430 65.0 0 19'. 1300 1,120 116M 2,720 IN 19 )1 J.6 98 10.0 Y 117,101 ] ]031 65.0 0 19,&p BCO ],IfiO [080 i.6b 180 30 ]3 J.5 9.6 9.9 V 244,016 8 0 19,6NB72. 1,360 I.IdO 3,60] 140 ]9 ]-0 ].5 9.] ]0.0 Y 98,%6 9 0 19.800 1,120 1080 3,N3 180 20 ].1 ].5 9.5 9] Y 49,338 1O 0 19300 'A. 840 3,000 160 ]9 ]2 ].6 9.] 9.9 Y 481341 ii 2 0 19. 1,480 1.080 2,560 160 20 ].0 ].d 9.] 9.8 Y dB BO]e:age 8 ffio�.t 0 19.118 ].40! ].338 3,]43 160 30 ].1 ]5 9.] 9.9Maximum 4 0 20,0000 1.800 1.]30 2,920 180 El ]3 ].] 9.9 10.11,11 m 0 0 18,400 I.WO 840 2,500 1N 19 ]A ].3 9.5 9.]flan a 0 S6N JA 800 360 80 3 0.3 0.5 0.4 OA 235,J95 HALLIBURTON Alaska District Field QC Prejob Hydration Test on Location Company: Conoco Phillips Alaska, Inc. Treatments: 1-4 Well Name: Kuparuk River Unit 3C-08 Date Tested: 1/16/2019 Water Source: CPF3 Testing Temperature Viscosity, V (From FANN-35) of (minutes, cp) Tank # Digital Thermometer 1 3 6 9 12 15 1 66.0 10 15 18 19 20 20 2 66.4 9 13 18 19 20 20 3 66.3 10 14 18 19 20 20 4 66.4 11 15 18 20 20 20 5 65.2 12 16 19 21 21 21 6 65.0 11 16 18 19 19 19 7 65.0 12 15 18 19 20 20 8 65.6 11 14 1 17 18 18 19 9 65.4 11 14 16 19 19 20 10 66.4 12 15 17 18 19 19 11 66.2 9 13 18 19 1 20 20 Average 65.8 11 15 18 19 20 20 Maximum 66.4 12 16 19 21 21 21 Minimum 5.02 13 16 18 18 19 Range 1.4 3 3 3 3 3 2 Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Hydration Tests 39 HALLIBURTON Custom¢[ Conood'hillina Alaska. Inc. Wellnameffi#3C-09 Date: January 20. 2019 Interval Santa Viu H Tem TF XL H Comments Interval Saute Linear Vise Linear H Tem °F XL H Comment 1 Mini -Fre 18 74 >I 9.3 2 Pad Ifi JO 83 96 Pad 21 ].1 91 93 120/2019 I# IB 6.9 BS 9.4 IN 29 3q 4# I8 Ifi I] IS 6.9 6.8 6.9 69 82 85 87 85 9.4 9.5 9.5 96 2# 3N dN IB IB IB 7 7.0 6 80 83 BI 9d 9.5 94 3 Pad 19 6.9 85 9.2 4 Pad 16 7.0 80 93 1# 19 68 84 9.3 I# 19 73 76 qq Zone was cut short before hininy 2# 19 7.0 83 9.5 2# 17 69 71 95 mr8et sand concentration 3# IB 72 %0 94 3# 44 18 6.9 72 9.4 49 .—Meta n.--.1.. n...—x— xa-rm.a m¢ �6nPns•e, �m ° rtlWl moaem meal iohnl. vT m. m^nx IWM Nlp)� en �N vw�.s w9 •,�.. irp Conoco Phillips Alaska - fool River Unit 3C 08A Wellbore Information ��i i i ri - am Thi Conoco Phillips Alaska - fool River Unit 3C 08A Wellbore Information Find Is linman ata p 3000 nW ^y 20M Zone 1 Crosslink Tests —1 PPG — 1 -1i I m n.m nim mm nam mm mm mm nP nn nRm tnm tt nn tem Tann Timeornmaec) Laxumber—a TempeF PU LCSURFYOD CL42UC Test 1 PPG 82 9.40 1.00 1.30 nkat concentrations ini am In galla,, per iMuaand r pounds Per thousand CLJt .021 Optigo.gl optlflall 0.35 0.50 2.00 0.25 Conn=Philip 4lnb- Fupank flip, Unit 3C -NA Fann 13 Minute Zene3 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date:_ Company: ConocoPhillips Project No: Well Name: KRU 3C -08A Stage(s):_ BHST (dF): Water Source:_ Depth: Water pH: Formation: Hydration pH: _ Analyst: Hydration Vise: cp(15 Find Is linman ata p 3000 nW ^y 20M Zone 1 Crosslink Tests —1 PPG — 1 -1i I m n.m nim mm nam mm mm mm nP nn nRm tnm tt nn tem Tann Timeornmaec) Laxumber—a TempeF PU LCSURFYOD CL42UC Test 1 PPG 82 9.40 1.00 1.30 nkat concentrations ini am In galla,, per iMuaand r pounds Per thousand CLJt .021 Optigo.gl optlflall 0.35 0.50 2.00 0.25 Conn=Philip 4lnb- Fupank flip, Unit 3C -NA Fann 13 Minute Zene3 Zone 2 Crosslink Tests �1 PPG 3" 25U0 S 2000 z 1500 1000 500 0 I nt mm It nam nsnn nam mmrp. nem tam 11m Tllne(na . ec) Al cne—W concentrtllnns °ebw na In valwm Per thousand I P W Num°rt—+ Tamp'F PH LOSURFd000 LL -3311C CLJ1 MO.T 0p11flo4h OP°floJl Test I PPG 85 9.40 1.00 1.30 0.35 0.50 2.00 0.25 fnnoee Iranapf 1I..-.0 Nrxr Unit 3. Fann]S MIn um WneI ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: Company: ConocoPhillips Project No:_ Well Name: KRU 3C -08A Stage(s):_ BHST (-F): Water Source: _ Depth: Water pH: _ Formation: Hydration pH: _ Analyst: Hydration Vise: cp0 Zone 2 Crosslink Tests �1 PPG 3" 25U0 S 2000 z 1500 1000 500 0 I nt mm It nam nsnn nam mmrp. nem tam 11m Tllne(na . ec) Al cne—W concentrtllnns °ebw na In valwm Per thousand I P W Num°rt—+ Tamp'F PH LOSURFd000 LL -3311C CLJ1 MO.T 0p11flo4h OP°floJl Test I PPG 85 9.40 1.00 1.30 0.35 0.50 2.00 0.25 fnnoee Iranapf 1I..-.0 Nrxr Unit 3. Fann]S MIn um WneI LW NunlW, All themlol concentrations Rural "enshm a1200p Zone 3 Crosslink Tests 3000 2SW a zoo two 0 A 100 i so 0 00'.W 01'.W 02:W aa:o M:o as00 0600 o]W 08:00 0900 low 11th 1200 13:W 1400 15:W Tmelmimseal clow are In gallons per thousand / pounds per thousand PH LOSURfdWO o.uc CL.l M"7 o0se,al 0,da l Test 7 PPG 84 9.30 1.00 1.30 0.35 0.50 2.00 0.25 lln1t3. fmn35Minu43une3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: Company: ConocoPhillips Project No: Well Name: KRU 3C -08A Stage(s): _ BHST (°F): Water Source: _ Depth: Water pH: _ Formation: Hydration pH: _ Analyst: Hydration Viso: cp(9 LW NunlW, All themlol concentrations Rural "enshm a1200p Zone 3 Crosslink Tests 3000 2SW a zoo two 0 A 100 i so 0 00'.W 01'.W 02:W aa:o M:o as00 0600 o]W 08:00 0900 low 11th 1200 13:W 1400 15:W Tmelmimseal clow are In gallons per thousand / pounds per thousand PH LOSURfdWO o.uc CL.l M"7 o0se,al 0,da l Test 7 PPG 84 9.30 1.00 1.30 0.35 0.50 2.00 0.25 lln1t3. fmn35Minu43une3 ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: _ Company: ConocoPhillips Project No:_ Well Name: KRU 3C.08A Stage(s): BHST (°F): Water Source: _ Depth: Water pH: _ Formation: Hydration pH: _ Analyst: Hydration Visc: cp4 I- a, m0ro Zone 4 Crosslink Tests 2500 2000 V 1500 Z ° 1NO IM, 0 All chemical—ntrdione Wl— In gallons perOOVuW I p LOI N..W, Tempi PH LOSURF5000 Cl- 3 U CI -411 MOd] OpUMJII coflo l Test 1 PPG 76 9.40 1.00 1.30 0.35 0.50 2.00 0.25 Conon PIMP, AW12-Fupawk SWe, Unit 3c f.nn is Mmuf..o .4 1 1 1 1, 1 1 1 1 1 1 1 1 1 n. Time (min:se) Chemical Lot Numbers Loaded MO -67 CHY-407638 CL-22UC 173-18-1 CL -31 KK7CO250A0 Lo -Surf 300D 115 OptiFlow-II M041718 -23Z OptiFlow-III G040318 -11P SP Breaker 2094378 WG -36 N/A Conoco Phillips Alaska- Kuparuk River Unit 3C -08A Chemical Lot Numbers 47 • Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2066068 Customer: ConocoPhillips Well Name & Number: KRU 3C-08 Fluid System: Hybor G Date: January 16, 2019 10 minutes at 511 1/sec l0 minutes the shear rate was decreased to 100 1 /sec SL#992 additive samples SL4947b, e, SL#961g, h, SL4982b, d, SL#993a, c Technician(s) Performing Testing: Reviewed & Approved By: Customer: ConocoPhillips .JOB INFORNIA rION AND TESTING Fluid System: CONDITIONS Hybor G Bob Type: B5 Well Name: KRU 3C-08 Water Source: Seawater Shear Rate (I/sec): 5111100 Date: January 16, 2019 BHST ("F): 155 Lab Project ID: 2066068 FLUID DESIGN Test No: I z 3 a s Water Analysis Lot# Chemical Units Chemical Concentrations Sample ID: SL#992 BE -6 ppt 0.15 0.15 0.15 0.15 Total Hardness (ppm) 425 LoSurF3001) gpt 1.00 1.00 1.00 1.00 Alkalinity (ppm as WG -36 ppt 25.00 25.00 25.00 25.00 CaCO3 180 Chloride(ppm) 16970 MO -67 gpt 0.40 0.40 0.40 0.40 Iron m 10 CL -22 plat 1.25 1.25 1.30 130 Sulfate m L) >1600 CL31 opt 0.40 0.40 0.35 0.35 Ions tested using Strip S in Lab H 6.75 Optiflo 111 ppt 0.00 2.00 0.00 2.00 $ eei is ravity 1.028 Optiflo II pin 0.00 0,25 0.00 025 Temperature (OF) 76.00 SP Breaker ppt 0.00 0.00 0.00 0.00 4alnJored values FLUID PROPERTIES Teat No: 1 1 2 1 3 1 d 1 56 Gel Hydealiov (517ls) Water pH 6.75 6 75 6.75 6.75 blip. N,s,,u i y (cP) Temp, (oF): Base Gel (#) 25.00 25.00 25,00 25.00 1 10.0 76 Base Gel Vise (eP) 21.0 21.0 210 21.0 2 19.0 76 Base Gel pH 768 T68 7.68 7.68 3 20.0 76 Base Gel Temp. (eF) 76 76 76 76 4 20.0 76 Buffered pH 9.75 9.75 9.70 9.70 5 20.0 76 Crosslink pH 9.91 9.91 9.89 9.89 10 21 76 Final pH 9.16 9.08 9.32 9.20 Test Temp. (°F) 155 155 155 155 Break Time(hrmin) N/A 1:08 N/A 2.17 Test Notes: .......... Shear Rate -Viscosity .......... Shear Rate-Vvuosity - ---Shear Rate-Vluosity 5hear Rate ---Viscosity .......... Shear Rate-V,.osiW . Shear Rate -Viscosity - - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature 800 180 160 700 t �s1�d 140 600 J+t a I't• i l 120 soo 1 Y 100 H iz 400 t I i 0 300 60 I 200 40 100 -. _____._.-__-__w__�.. ...____.____._._.__._.--._-._-s_____�_ _.._._.._._.___.._.- ,_.-. 20 - 0 a,_... 0:00 0:28 0:57 1:26 1:55 2:24 2:52 3:21 Time, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2066199-1 Customer: ConocoPhillips Well Name & Number: KRU 3C-08 Fluid System: Hybor G Date: January 31, 2019 10 minutes at 511 l/sec 10 minutes the shear rate was decreased to 100 1/sec Water SL#998 Technician(s) Performing Testing: Jason Reviewed & Approved By: Customer: ConocoPhillips .JOB INFORMATION ANDTESTING CONDITIONS Fluid System: Hybor G Bob Type: B5 Well Name: KRU 3C-08 Water Source: Seawater Shear Rate(I/sec): 511/100 Date: January 31, 2019 BHST ("F): 140 Lab Project ID: 2066199-1 FLUID DESIGN 'fest No 1 1 z 1 3 1 Water Analysis Lot# Chemical Units Chemical Concentrations Sample ID: SL#998 BF -6 pPt 0.15 0.15 0.15 0.15 1 Total Hardness m) 1 425 Lti 300D gpt 1.00 1.00 1.00 1.00 Alkalinity (ppm as WG -36 pot 25.00 25.00 2500 25.00 I80 CaCO3) Chloride m) 16970 M0-67 apt 040 0.40 040 0.40 Iron (rtl ) 5 CL -22 ppt 1.30 1.30 1.30 1.30 Sulfate (m L) 1600.00 CL3I plat 0.35 0.35 0.35 0.35 Ions tested using Strip s in Lab H 6.93 Optiflo 111 ppt 0.00 2.00 2.00 2.00 ISpecific Gravity 1.028 Opfiflo 11 plu 0.00 0.25 0.25 0.25 Temperature ('F) 75.00 SP Breaker Rpt 0.00 0.00 0.25 0.50 AE `m(culated valuer FLUID PROPERTIES Test No: 12 4 0 n Gel Hydrio oo (5I I/s) Water pH 6.93 6.936.93 Min. Viscosity (0) Tern, (or). Base Gel (#) 25.00 25.0025.00 1 10.0 Base Gel Vise (cP) 2100 21.0210 2 18.0 Base Gel pH 7.62 7.62765 3 200 Base Gel Temp. (OF) d7.65 4 20.0 Buffered pH 9.70 9709.71 5 20.0 Crossllnk pH 9.83 9.839.84 10 21 Final pH 922 9.078.99 Test Temp. (OF) 155 155155 Break Time (hr:min) 2:26 2:26 2:05 1'.15 Test Notes: ^ ^Shearflate �Vizconty ..^^^^Shear Rate -Viscosity ---'Shear Rate-Viscozdy Shear Hate ---Viscosity Shear Rate -Viscosity -- -- Shear Rite -Viscosity - - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature 180 700 160 600 140 500 .......... - N ti 120 ¢ 400 it 100 l m 2j3 0 s" eo 200 40 0 100 20 0 0 1 1 0:00 0:28 0:57 1:26 1:55 2:24 2:52 3:21 3:50 Time, h:mm STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION h` to 0v JAN 3 0 2019 WELL COMPLETION OR RECOMPLETION REPORT ANAMWIC ta. Well Status: Oil RJ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAS WDSPL❑ No. of Completions: 1b. Well Class: Development Exploratory Service E] Stratigraphic Test E] 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 12/31/2018 14. Permit to Drill Number / Sundry: 218-161 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 12/23/2018 15. API Number: 50-029-21390-01-00 4a. Location of Well (Governmental Section): Surface: 522' FNL, 1013' FEL, Sec 14, T12N, R9E, UM Top of Productive Interval: 1164' FNL, 1292' FEL, Sec 12, T12N, R9E, UM Total Depth: 72V FNL, 3860" FEL, Sec 7, T12N, R10E, UM 8. Date TD Reached: 12/30/2018 16. Well Name and Number: KRU 3C -08A 9. Ref Elevations: KB:82 GL: 47 BF: 17. Field / Pool(s): Kuparuk River PoollKuparuk River Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: , ADL 25629, ADL 25634, ADL 25628 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 528558 y- 5995910 Zone- 4 TPI: x- 533537 y- 6000568 Zone- 4 Total Depth: x- 635743 y- 6001017 Zone- 4 11. Total Depth MD/TVD: 12246/6664 19. DNR Approval Number: LONS 83.131 12. SSSV Depth MD/TVD: NONE 20. Thickness of Permafrost MD/TVD: 1523/1484 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 1 9935/6643 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 16 62.58 H-40 36 116 36 116 24 213 sx CS 1 9.625 36 J-55 35 5206 35 3732 12.25 1580 sx ASIII, 340sx Class G 7 26 J-55 34 10258 34 6857 8.5 450 sx Class G, 250 sx AS 1 23/8 4.6 L80 9831 12246 6575 6664 3 Uncemented Liner 24. Open to production or injection? Yes ❑� No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): FRAC SLEEVES @: 10601-10610 MD and 6712-6713 TVD... 12/31/2018 11053-11071 MD and 6723-6721 TVD... 12/31/2018 COMPLETION 11302-11330 MD and 6692-6691 TVD... 12/30/2018 DATE SLOTTED LINER@: I Z 31 12027-12057 MD and 6689-6686 TVD... 12/31/2018 ---l(� VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 9962 9652/6459, 983016574 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): IN TESTING Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casino Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10-407 Revised 512017 VLTL 1�/VJ,7 CONTINUED ON PAGE 2 RBDMS M� 0 r,:"�1 3 0 2019 Submit l iORIGINAL Nonly 28. CORE DATA Conventional Core(s): Yes ❑ No ❑Q Sidewall Cores: Yes ❑ No ❑Z If Yes, list formations and intervals cored (MD/TVD, Fromfro), 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1523 1484 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9935 6643 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A3 3C-08APB1 11215 6725 3C-08APB2 11609 6693 TD 12246 6664 Formation at total depth: Kuparuk A5 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloalcal report. productionwell test results,r 20 AA 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Keith Herrin Authorized Title: Staff WQ Engineer Contact Email: Keith.E.Herrin a co .com Authorized/ 3D /� Contact Phone: 263-4321 Signature: Date: 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 ta: 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 farm and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas! Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 3C -08A Final CTD Schematic 16" 62# H40 shoe @ 116' MD 9-518" 36# J55 shoe @ 5206' MD KOP @ 9,935 MD A -sand penis 9904'- 9921' MD 9938'- 9954' MD 9976'- 10004'MD 7" 269 J-55 shoe @ 10,258' MD 3-1/2" 9.3# L-80 EUE Tubing to surface 3-1/2" x 1-1/2" MMG Camco gas lift mandrels @ 2955', 5271', 6972', 8179', 9071 8 9626'MD. Baker Premier packer @ 9655' MD 3-1/2" X -Nipple @ 9679' MD (2.813" min ID) Top of Tandem Wedge #1 Ass @ 9910' MD 3-1/2" X -Nipple @ 9928' MD (2.813" min ID) Top of Tandem Wedge #2 Ass @ 9929' MD 3-1/2" X -Nipple @ 9947MD (2.813" min ID) Tubing tail @ 9960' MD Pro osed CTD Completion Run Length Description Depth ID Ball DD Post Rig SST -SPAN Liner Top PTSA Tie -Back Seals 1.877 1.781 10' heal Bore Oe to mens Sleeve 9,830' 2.250 2-318" Blank Liner, 4.6#/h, LEO, H d511 R Profile Nipple 9,872' 1.781 2E/8" Blank Liner, 4.6#/#, LEO, Hyd511 Sig 4. Batt Drop Frac Sleeve 10,610' 1.656 1.718 1 2A/8" Blank Liner, 4.6#/ft, LEO, Hyd5ll Si 3: BAN Drp Frac Sleeve 11.053, 1.563 1.625 2-318" Blank Liner, 4.6#/1t, LA0, Hyd511 St 2: Bal Dr Frac Sbeve 11.30Y 1.438 1.500 2318" Blank Liner, 4.6#!8, LA0, Hyd511 6t is Pert JdN (0.281-, 3 SPF, 60'I 12 02T Aluminum Parted Bull Nose 1.000 1.375 3C-0BA TD =12,246 MD 2-318" blank liner w/ frac sleeves 8 pedlaint TOL = 9,830' MD, BOL =12,246 MD _3CE8APB2 TD = 11,609' MD Anchored billet =10,490' MD Anchored billet 10.510' MD (failed' 3C-0eAPBi TD =11,215' MD Andwred billet - 70,290' MD KUP PROD WELLNAME 3C-08 WELLBORE 3C_0$ w,ConocoPh�a Well Attribul Max Angle 'O 7D )I''ie�AQKZ'1A=K NW¢IIMreAdi ""Uhr¢sbrue nclr) MOI. ACIBIm Othim Ala5ta.lnc. RIVER UNIT 500292139000 PROD 020 5000.UU 102340 NIPPLE 965 3Cue.+reverBlomxAM Last Tag VwOGelvtlengE 0o"i Annotation Dapth(XUIR Eno Dale Welbore Last Moo By .............. ................................... ................. ..........__.. __.... _ Last Tag'. IRKS (Est 4of Fol) 10000.012/18/2019 3C-08 izeddi 1 TO. ...E. He Last Rev Reason Annolatbn End Dale Weepers Last MM By Rev Reason: Installed .at frac GLD I 112312019 '-do l.rgUaP Casing Strings Casing DescriptionOO hin 1D Description( Tap idea) set peace lM(BI she Depth ITVDj... WULen 11...Indian TOPThrean CONDUCTOR 16 15.06 36.0 116.0 1160 62.58 H40 WELDED Ca."pooreptet..,In,I'D Iin1 Top Me) sepopeop(B) eepepm(rVDL..ohnuen in TOPThove Ie. SURFACE 95/8 8.92 34.8 5,205.8 3,732.1 3800 -55 BTC j Caere DauNptbnOD(m) 1U) Topml, SNpph,runi se0,anina0)...Wlrten ll..... 1h TM1wM CONDUCioRaa.nneo jr. PRODUCTION 7 6.28 337 10,258.0 26.00 J-55 BTC Tubing Strings Tobin. Dsa¢riphon sting ko...IDgn) TUBING 3112 299 Top tlKBl 296 Ise lR..SN 9,9616 depth ITVD) 1... 66607 W((IWM1I 9.30 Grant L-80 Top ConnMion EUE Bid Mod GV4 LIFT. 2.96D PRODUCTION Completion Details Top two rop Incl NiTop tons) oth BI (•I Item Des Cam eD 11111 9,652.1 6459.0 4972 Packer Packer Baker, Premier s ,(Cut to release Pan#H7 2,910 SURFACE: Miss ae.8� 6069 9680.6 6,477.5 4964 NIPPLE Nipple, Halliburton, 2.813-X profile, S#:3902635 2813 GAS IIFr: sess 9.9153 6,630.2 4908 WEDGE ASSY Wedge Assembly, Northern Solutions 2,992 9,929.3 6,6394 4699 NIPPLE Nipple, Halliburton, 2.813-X profile, 2.813 9946.1 6,650.5 48.88 WEDGE ASSY Pup Joint, 3-112",939. L-80, EUE Brtl Mod Box x Pin 2,992 9.950.0 6,653.0 48.86 NIPPLE Pup Joint, 3-12".9.34. L-80, EUE Brtl Mod Box x Pin 2.813 Gas UFT: Be3ez Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) TOP(WD) Topmd Top pacm WID) rt o¢: Co. Run Me 10 nim 9,830.0 6,5745 49.35 LINER TOP Owen Liner Top Packer with Locator sub and Positive 1117/2019 1.781 GASUFT e,nse PACKER test seal assembly with 1.781" R Nipple profile. Max OD 2.716' DAL 14' 9,830.6 6,574.9 4935 CID Line,or 3C -08A line, Lined up into3S'TBG, Uner Top@ 12731201 2.250 the A lateral 9830.6'. Hasa 2.25" ID X 10' SBR On top. (Be. 3C -08A 8 schematic for details) GAs uFi; 9,CHLT ,950.0 6,853.0 -78- -8 281 X -lock 2.81"X -lock wl Flaw Thru Sub 12I18I201 750 8 10,068.0 8731.1 48.41 FISH t 112" GLV In Ratbole 311411996 0.000 10084.0 67417 48.38 FISH 518"X1/4" JDS Skin Lost in Hole 8131/1989 .000 GAS LIFT; Ra Perforations & Slots Fcbr: aes2.1 an., D.n Top 0"') Bim I`vg (amt:ln Tap We) Ban (mcel We) (MM unkad inn. Data ) Type Com 9,904.0 9,9210 6, 6,74D A -0 ,A -3,3C-08 &2311885 4.0 (PERF eg_D ase; "Carrier xiwLE BSW.aHJ II 9,938.0 9,9540 ,645.1 6 557 A-3, 3C-08 WN1985 0.0 IPERF e9.D ase; arner HJ II 9,976-0 10,004. 8,870.2 ,6 .J A-2,3 -OB 82311885 00 (PERF p au: arrier HJ II Mandrel Inserts m LWERT0PPACNEk,e,a30.0 N Tap Onang Valw tseze tahh PpTRO Run Tap IXKB) mB) Mab Model Do (in) Into,Type Tyre or) tpsp Run Dane Co. 1 2,9524 2,514.1 Camco RK 112 GAS LIFT GLV RK 0.188 1243.0 122/2019 2 52683 3,765.3 Cameo RK 112 GAS LIFT OV RK 0250 00 1/22/2019 3 69692 4,7896 Cameo RK 112 GAS LIFT DMY RK 0.000 00 111012019 4 8,1759 55388 Carrico RK 112 GAS LIFT DMY RK 0000 00 1/1012019 5 9L677 6090.2 Cameo RK 112 GAS LIFT DMY RK 0.000 00 111012019 6 9,623.4 6440.5 Camco RK 112 GAS LIFT DMY RK 0.000 0.0 1/1112019 Notes: General & Safety End mm poor eeon IPERF:...04.9210-. 7114/2010 NOTE: View Schrmaac wl Alaska Schoor ic9.0 11172018 NUI L: VIM bMeMMiC W Alaska Schematic 100 WEOGEAssY; B,BISa NIPPLE;tierva IPERF', ep38auaosk0� WEEGEASSY;BB14.1 tin t. .44110 1 I NIpPLGe,ds IPERF. 9.on8 10.pa. O� FIBK:10,088.0 FIBH:lo... PRODUCTION: 33.7-10,340 11131111 KUP PROD WELLNAME 3C-08 WELLBORE 3C-O8A Conoi:4 hillips Alaska. Inc. ae R traam9seuiOun Casing Strings VeRiwlxlenFx poem) Casing Description00 (nl A Liner 12318 mon) 199 -0 Me) 9.830.6 Set Wlo Los.) I.Oep0 TVD)... WULen It Grade 12,2420 4 60 L-80 rop r1. 511 ___ _.._............ ............._..__... Liner Details MIRING NPNOER;AB Nominal ID Top (ental Toplrvpl OtNel rop mm Pl IMm as coin fin/ 9,830.6 SBR 10 Seat Bare Deployment Sleeve D, 2.25" 2250 PDIisM1e1l Bore 9,871.9 Nipple R Profile nipple (1]81 -Bore, 2,79 DID) 1.781 10,610.5 Frac Sleeve #3: Ball drop frac gleese, ID 1.656' -Ball OD 1.718" 1.6516 11,053.0 Frac Sleeve #2: Ball drop frac glees, ID 1,563" -Ball OD 1,625" 1.625 11,M2.1 Frac Sleeve #1: Ball drop free sleeve, ID 1438 --Ball OD 1.500' 1.438 LONOULTOR: aA011fi0 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) rop(rv01 Tapmol Top (XNBI aHRI °) Oes Lom ars..... 1O (in) 9,934.0 NS WS f11n,, mon, Weo0e WS 12/22/201 ws uR;;es19 0 90RFAeP..,.a— ONSLIFT', 5gyra ORS 11Fr: 6,9093 j; GFB LIFT: 6, 1Ti.9 Gib LIFT: 9.W]] GAS LIR; 9.89.4 Pecan: 9,6521 NIPPLE, 9 O8 LINER TOP PACKER, 9,059.0 XTIO, 9.]-laetOo PRODN' R NS WS: 9,990 P las; 9,0.T.8-1139]0.7 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depm Start Time End lime Dur (hr) Phase Op Code AnAy Code Time P -T -X Operation (WS) Erol Deem (KKB) 12/20/2018 12/2012018 2.00 MIRU MOVE RURD P Continue RD checklist, breakdown TT 0.0 0.0 09:00 11:00 hard line, secure BOP & reel 12/20/2018 12/20/2018 2.00 MIRU MOVE RURD P Disconnect PUTZ, move mats away 0.0 0.0 11:00 13:00 from rig exterior, complete RD checklist, break down tree platform, Peak trucks arrive on pad 12/20/2018 12120/2018 1.00 MIRU MOVE RURD P PJSM, dg up shop & 1/2 -way house 0.0 13:00 14:00 12/20/2018 12120/2018 1.50 MIRU MOVE RURD P PJSM, rig up to sows, pull mats, pull 0.0 0.0 14:00 15:30 off well, jeep up 12/20/2018 12/20/2018 2.00 MIRU MOVE MOB P Move from 1 B -Pad to 3C -Pad 0.0 0.0 15:30 17:30 12/20/2018 12/20/2018 1.00 MIRU MOVE MOB P Hold at the Y for field and rig crew 0.0 0.0 17:30 18:30 change. 12/20/2018 12/20/2018 2.50 MIRU MOVE MOB P Roll out toward 3C-08, 0.0 0.0 18:30 21:00 Short pause < 5 min @ 10 to let trafc by. 20:30 pas CPF3 12/20/2018 12/20/2018 0.40 MIRU MOVE MOB P On pad - 21:00. Contact DSO, Paul, 0.0 0.0 21:00 21:24 nights lead. Permission obtained to back over well and RU. S/I OA, all other valves closed. IA 1,300 psi, OA 200 psi. ••• Note Well has a BPV installed. Drop both sub and service mod jeeps. 12/20/2018 12/20/2018 0.75 MIRU MOVE RURD P Spot Sub over well, leaning tree. 0.0 0.0 21:24 22:09 12/2012018 12/2012018 0.25 MIRU MOVE RURD P Tuck in mats around perimeter. 0.0 0.0 22:09 22:24 12/2012018 12120/2018 0.30 MIRU MOVE RURD P Mats in, lifted stack to clear blanking 0.0 0.0 22:24 22:42 flange on top of tree. 12/20/2018 1212012018 0.30 MIRU MOVE RURD P Set down sub, DTH started install of 0.0 0.0 22:42 23:00 scaffold well platform. Sot service mod next to sub 12/2012018 12/20/2018 0.60 MIRU MOVE RURD P Service mod in place, tuck mats under 0.0 0.0 23:00 23:36 12/2012018 12/21/2018 0.40 MIRU MOVE RURD P Set down Service mod, rig spotted an 0.0 0.0 23:36 00:00 level, drop landings and stairs. 12/2112018 12/21/2018 5.00 MIRU MOVE RURD P PJSM, lunch, Start working RU 00:00 05:00 checklist. Set stack @ 3:00. Hard line to tiger tank rigged up and tested to lair. 12/21/2018 12/2112018 2.00 MIRU MOVE NUND P Continue RU check list, NU BOP 0.0 0.0 05:00 07:00 •' Rig Accepted: 12/21/18 @ 07:00 him 12/2112018 12121/2018 1.00 MIRU MOVE RURD P Complete RU checklist, grease swab, 0.0 0.0 07:00 08:00 tangos, & HCR's 12/21/2018 12/2112018 0.50 MIRU WHDBOP PRTS P Fluid pack lines 0.0 0.0 08:00 08:30 12/21/2018 12/21/2018 0.50 MIRU WHDBOP PRTS P Shell test, good, PT TT line to 2300 0.0 0.0 08:30 09:00 psi (begin bleeding off IA), test gas alarms 12/21/2018 12/2112018 2.10 MIRU WHDBOP BOPE P BOPE test 0.0 0.0 09:00 11:06 •• Per PTD, 250 psi low, 4500 psi high (witness waived by Matt Herrera of AOGCC) 12/21/20111 12/21/2018 0.60 MIRU WHDBOP BOPE T Difficulty holding low on test #5, close 0.0 0.0 11:06 11:42 C8, hold on low, grease C7 (fail pass on C7) Page 1117 ReportPrinted: 1/8/2019 operations Summary (with Timelog Depths) 3l Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stall Time End Time Dur (hr) Phase Op Code Actively Code Time P -T -X Operation (ftKB) End Depth (ttKB) 1212112018 12/21/2018 3.80 MIRU WHDBOP BOPE P Continue BOP test, install test joint, 0.0 0.0 1142 15:30 continue test, check N2 levels, draw down test, RD test int (Bled IA down to 850 psi) 12/21/2018 12/21/2018 3.00 MIRU WHDBOP MPSP P Clear floor, suck out riser, PJSM, rig 0.0 0.0 15:30 18:30 up lubricator, PT lubricator to 2300 psi, not showing on lubricator gauge, trouble -shoot, pull BPV, LD lubricator,crew change 12121/2018 12/21/2018 1.60 MIRU WHDBOP PRTS P Test IRV, PT PDLS's 0.0 0.0 18:30 20:06 12/21/2018 12/21/2018 1.80 PROD1 RPEQPT PULD P PU & PD BHA#1, NS whipstock. 0.0 74.0 20:06 21:54 Check packoffs, change. 12/21/2018 12/22/2018 2.10 PROD1 RPEQPT TRIP P RIH,pumping min rale, laking returns 74.0 8,333.0 21:54 00:00 to the tiger tank. WH 1128 psi, 12/22/2018 12/22/2018 0.20 PROD1 RPEQPT TRIP P RIH,pumping min rate, taking returns 8,333.0 9,372.0 00:00 00:12 to the tiger tank. WH 1128 psi, 12/22/2018 12/22/2018 0.20 PROD1 RPEQPT DLOG P Tie into the Kt for -3' correction. 9,372.0 9,406.2 00:12 0024 12/22/2018 12/22/2018 0.30 PROD1 RPEQPT TRIP P RIH to lowest Ioggin depth (9850') 9,406.2 9,598.0 00:24 00:42 since no WOB when logging W CCL PU Wt 40 k lbs. 12/22/2018 12/22/2018 0.70 PROD1 RPEQPT DLOG P Log CCL from 9550-9750'@ 16 fl/min. 9,598.0 9,947.0 00:42 01:24 Log appears to be off by 4'. SID @ 9947', 12/22/2018 12/22/2018 0.30 PROD1 RPEQPT TRIP P PU 40 klbs, PUH to relog the K1 9,947.0 9,301.0 01:24 01:42 12/22/2018 11212212018 0.80 PRODt RPEQPT DLOG P Tie into the K1 for no coneclion 9,301.0 9,429.0 01:42 02:30 12122/2018 12/22/2018 0.80 PROD1 RPEQPT WPST P RBIH, S/D @ 9946' Set 2 k WOB, 9,429.0 9,946.0 02:30 03:18 consult with town enginering. PU 36k to neutral weight. Close EDC, Pump 0.5 bpm, Sheared at 3300 psi, 4 k WOB. *•' TOWS @ 9934' O'ROHS 12/2212018 12/22/2018 2.80 PROW RPEQPT TRIP P PU 40 k lbs, PUH, swap to DuoVis 9,946.0 80.0 03:18 06:06 milling fluid, new mud at the bit @ 9899'. POOH pumping 2.4 bpm holding 11.8 ppg @ the window, 1forl returns, metal over shakers & packed -off MM at surface, PJSM 12/22/2018 12/22/2018 1.30 PROD1 RPEQPT PULD P PUD & LD BHA #1 (pumping MP) 80.0 0.0 D6:06 07:24 12/22/2018 12/22/2018 1.00 PROD1 WHPST PULD P PD BHA#2 Window Milling Assembly 0.0 74.0 07:24 08:24 (0.6° AKO motor, string reamer, & window mill), slide in cart, check pack - offs, MU to coil, tag up 12/22/2018 12/22/2018 1.60 PROD1 WHPST TRIP P RIH w/ BHA#2 74.0 9,385.0 08:24 10:00 12/22/2018 12122/2018 0.20 PROD1 WHPST DLOG P log K1 for 4.5' correction, PUW = 9,385.0 9,410.0 10:00 10:12 34K, Gose EDC 12/22/2018 12/22/2018 0.40 PROD1 WHPST TRIP P Continue RIH, dry lag WS pinch -point 9,410.0 9,935.2 10:12 10:36 @ 9936', PUW = 37K, tag pumping at 9935.2 Page 2117 Report Printed: 1/8/2019 Uperations Summary (with Timelog Depths) 3C-O8 16 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Shut Depth StartTime I End Time Our (no Prtase Op Corte AdW* Code Time P-T-X Operabon (ftKB) End Depth (Po(B) 12/22/2018 12/22/2018 1.70 PROD? WHPST WPST P Milling window per procedure, HS, FS 9,935.2 9,936.6 10:36 12:18 = 460 psi @ 1.9 bpm, CWT = 14.3K, WOB = 1.1 K, BHP = 4030 psi, WHP = 456 psi, circ = 4433 psi, IA= 891 psi, milling slows down -1 ft in, avg ROP = 0.82 pfh 12/22/2018 12/22/2018 2.30 PROD1 WHPST WPST P Milling, CWT= 12K, WOB =2.8K, dp 9,936.6 9,937.4 12:18 14:36 = 677 psi, avg ROP = 0.35 fph "Preload DS PDL w/ build BHA 12/22/2018 12/22/2018 2.00 PROD1 WHPST WPST P Milling, CWT = 12K, WOB = 2.9K, dp 9,937.4 9,938.5 14:36 16:36 = 676 psi, avg ROP = 0.55 fph 12/22/2018 12/22/2018 1.40 PROD1 WHPST WPST P Milling, CWT =11.7K, WOB =3.OK, 9,938.5 9,939.0 16:36 18:00 circ = 4343 psi, BHP = 4085 psi, WHP = 397 psi 12/22/2018 12/23/2018 6.00 PROD1 WHPST WPST P Milling, CWT= 15K, WOB = 2.9K, circ 9,939.0 9,141.4 18:00 00:00 = 4524 psi, BHP = 4069 psi, WHIP = 377 psi 12/23/2018 12/23/2018 0.90 PROD? WHPST WPST P Milling, CWT = 11.6K, WOB = 2.7K, dp 9,141.4 9,141.6 00:00 00:54 = 657 psi, circ = 4374 psi, BHP = 4086 psi, WHP = 399 psi 12/23/2018 12/23/2018 2.30 PRODi WHPST WPST P Stall, PU 38 k lbs, RBIH 9,141.6 9,941.7 00:54 03:12 CWT =17 klbs, WOB =2.7k lbs, dp= 481 psi, circ = 4492 psi, BHP = 4048 psi, WHP = 361 psi 12/23/2018 12/23/2018 2.10 PROD1 WHPST WPST P Stall, PU 41 k lbs pull -5 k WOB, RBIH 9,941.7 9,941.3 03:12 05:18 CWT = 15 k lbs, WOB = 1.2 k lbs, dp = 517 psi, circ = 4521 psi, BHP = 4031 psi, WHP = 332 psi Weight not milling off. holdin 2.10 WOB 12/23/2018 12/23/2018 1.90 PROD1 WHPST TRIP P Confer w/ town, decision made to 9,941.3 74.0 05:18 0712 POOH to inspect tools, PJSM 12/23/2018 12/23/2018 0.80 PROD1 WHPST PULD P PUD, pumping MP, string reamer & 74.0 0.0 07:12 08:00 mill gauged 2.79" no-go, pictures of mill on S: drive, DO inspected motor which looked good "SIMOPS: swap out Charlie 7 12/23/2018 12/23/2018 0.80 PRODi WHPST PULD P PD BHA#3, new window mill (2.80" no 0.0 74.0 08:00 08:48 -go), slide in cart, check pack-offs, MU Ito coill, tag up 12/23/2018 12/23/2018 1.70 PRODi WHPST TRIP P RIH w/ BHA#3, new window mill 74.0 9,385.0 08:46 10:30 " Park @ 795', Gose EDC, FS = 514 psi @ 1.9 bpm, confer w/ town, continue in-hole 12/23/2018 12/23/2018 0.10 PRODt WHPST DLOG P Log K1 for +1'correction, PUW = 32K 9,385.0 9,404.0 10:30 10:36 12/23/2018 12/2312018 0.30 PROD1 WHPST TRIP P Continue RIH, dry lag deepest depth 9,404.0 9,941.6 10:36 10:54 @ 9941.7', PUW = 40K, slight motor work at 9941.2', easily through, milling from 9941'6 12/23/2018 12/23/2018 1.70 PROD1 WHPST WPST P Milling, FS = 500 psi @ 1.9 bpm, CWT 9,941.6 9,943.5 10:54 12:36 = 13K, WOB = 2K, circ = 4528, BHP = 4041 psi, WHIP = 369 psi, dp = 614 psi, WOB falls off beginning @ 9942.5' (BOW), control mill @ 1fph, allow string reamer to exit 7" " TOW & TOWS = 9935.2', BOW = 9942.5', 7.3' window Page 3/17 Report Printed: 1/8/2019 operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log scan Depth start Tinre End Time Dur(hr) Phase Op Code AcOM CoEe rime P -T -X Opereaon (WB) End Depth(ftKe) 12/23/2016 12/23/2018 1.50 PROD1 WHPST MILL P Milling rat -hole, CWT = 13.5K, WOB = 9,943.5 9,960.0 12:36 14:06 2.4K, BHP = 4055 psi, WHP = 368 psi, sand in samples 12/23/2018 12123/2018 2.20 PROW WHPST REAM P Perform reaming passes, HS, 30R, 9,960.0 9,960.0 14:06 16:18 30L, & LS (2 passes) @ 1 fpm, dry drift, clean up & down, tag rat -hole TD, pump sweeps, PUW = 37K 12/23/2018 12/23/2018 1.70 PROD1 WHPST TRIP P POOH, Crewchange, PJSM, 9,960.0 74.0 16:18 18:00 12/23/2018 12123/2018 1.50 PROD1 WHPST TRIP P Bump up, PUD & LD BHA *3. 74.0 0.0 18:00 19:30 ""Speed mill 2.80" No Go 12/2312018 12123/2018 0.90 PROD1 DRILL CIRC P MU side jet n=le, stab on, jet stack. 0.0 0.0 19:30 20:24 12/23/2018 12123/2018 1.00 PRODi DRILL PULD P Unstab, PD BHA# 4, 2.2 °AKO w/ BH 0.0 72.2 20:24 21:24 TX19610 rebuilt bit. Inspect pack offs, - shot, clean everything, reinstall new with new extrusion rings. Bump up, space out. 12/23/2018 12/23/2018 1.70 PROD1 DRILL TRIP P RIH. fuming coil over to clean duovis 72.2 9,370.0 21:24 23:06 1 1 ifluid. 12/23/2018 12/23/2018 0.20 PROD1 DRILL DLOG P Tie into the K1, miss tie in, PU to 9,370.0 9,404.0 23:06 23:18 9354', tie in for +14.5'. 12/23/2018 12/2312018 0.40 PROD1 DRILL TRIP P Continue to RIH, new mud at the bit 9,404.0 9,960.0 23:18 23:42 9810', Park. Close EDC, continue to RIH, window clean. 12/23/2018 12/24/2018 0.30 PROD1 DRILL DRLG P CT 4510 psi @ 1.89 bpm in, 1.80 bpm 9,960.0 9,997.0 23:42 00:00 out, Delta P= 537 psi BHP 4055 psi. WH 250 psi IA 801 psi, 288 psi. OBD, CT Wt 13.4 k lbs, WOB 1.24 k lbs, ROP 100 ft/hr 12/24/2018 12/24/2018 0.90 PROD1 DRILL DRLG P CT 4856 psi @ 1.88 bpm in, 1.88 bpm 9,997.0 10,070.0 00:00 00:54 out, BHP 4093 psi, 11.78 ppg EMW @ the window. CT Wt 15.7 k lbs, WOB 1.7 k lbs, ROP 144 ft/hr Ran into something hard @ 10,059', ROP dropped to - 40 ft/hr 12/24/2018 12/24/2018 1.80 PROD1 DRILL TRIP P PU 41 k lbs, POOH for let ddllig 10,070.0 67.0 00:54 02:42 assembly, neg 1.5k lbs WOB tug coming throuhg the window - 9944', Park, open EDC, continue to POOH. bump up. 12/24/2018 12/24/2018 0.70 PROD1 DRILL PULD P Space out, PUD BHA #4. 68.2 68.4 02:42 03:24 12/24/2018 12/24/2018 1.70 PROD1 DRILL PULD T DS PDL wire appeared to part when 2- 68.2 0.0 03:24 05:06 3/8" deployment rams were opened. Close 2-318" deployment rams, blow down lubricator, Pop off lubricator, confirm wire parted. Appears to be a couple feet above the rope socket. Set down PDL. PJSM for change of scope. Skid injector cart toward PDL for use as work platform, EDC down 15.2', should be spaced out right below to lower 2-318" deployment ram. Closed bag for additional barrier from well. Retrieve wire. 12/24/2018 12/24/2018 0.90 PROD1 DRILL PULD T Slipe wire and begin rehead. 68.2 0.0 05:06 06:00 Page 4/17 Report Printed: 1/812019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftKa) End Depth (ftK8) 12/24/2018 12/24/2018 1.80 PRODi DRILL PULD T Crew change, stand back DS PDL, 0.0 0.0 06:00 07:48 move ODS PDL over mouse -hole, work to free SL, attach sash cord to tools & lie -off to riser, payout slack on SL & PU w/ PDL, BHA moves, add additional tools to bottom of tools in PDL (more hanging weight), work SL up & down, free LD tools from ODS PDL (2nd window milling BHA) 12/24/2018 12/24/2018 0.90 PROD1 DRILL PULD P PUD BHA#4, bit came out a 1-1 (one 0.0 0.0 07:48 08:42 chipped reamer cutter) 12/24/2018 12/24/2018 1.30 PRODi DRILL PULD P PD BHA#5 Lateral Assembly (NOV 0.0 78.0 08:42 10:00 Agitator, 0.5" AKO motor, & HYC A3 bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 12/24/2018 12/24/2018 1.80 PRODt DRILL TRIP P RIH w/ BHA#5, close EDC, surface 78.0 9,380.0 10:00 11:48 test agitator, good Shallow test: 1.9 bpm, rip = 1276 psi, circ = 5320 psi (transducer currently down, scavenged parts for MWD) Begin reheading SL on DS PDL 12/24/2018 12/24/2018 0.10 PROD1 DRILL DLOG P Log K1 for -4' correction, PUW =35K, 9,380.0 9,402.0 11:48 11:54 begin sending PowerPro system #1 12/24/2018 12/24/2018 0.40 PROD1 DRILL TRIP P Continue RIH, log RA@ 9940' 9,402.0 10,070.0 11:54 12:18 TOWS & TOW = 9935.2', BOW = 9942.5' 12/24/2018 12/24/2018 0.70 PROD1 DRILL DRLG P Drilling, 1.86 bpm, CWT= 14K, WOB 10,070.0 10,145.0 12:18 13:00 = 1.31K, BHP = 4113 psi, WHIP = 286 psi, circ = 5274 psi, new mud a bit 10,080', rip = 1459 psi, PUW = 41 K from 10,145' to get new parameters 12/24/2018 12/24/2018 1.30 PROD1 DRILL DRLG P Drilling. FS= 1264 psi, Q 1.87 bpm, 10,145.0 10,343.0 13:00 14:18 CWT = 14.7K, WOB = 1.1 K, BHP = 4055 psi, WHIP = 461 psi, circ = 4982 psi, PUW = 4K from 10,337' "Agitator transducer functioning again 12/24/2018 12/24/2018 0.80 PROM DRILL WPRT P Geo wiper, PUW = 42K, PUH to 10,343.0 10,343.0 14:18 15:06 window (call wiper #1) 12/24/2018 12/24/2018 3.00 PROD1 DRILL DRLG P Drilling, CWT= 15.5K, WOB = 2.61K, 10,343.0 10,795.0 15:06 18:06 BHP = 4129 psi, WHIP = 424 psi, circ = 5300 psi, pump 5x5 sweep 12/24/2018 12/24/2018 0.50 PROD1 DRILL WPRT P Wiper up -hole, PUW = 41 K, see a bit 10,795.0 10,095.0 18:06 18:36 of motorwork at 10,425', RIH, stacking at 10,445', PUW = 52K, dragging to - 3K WOB. Watch higher gamma interval ('130,330 to 10,500') 12/24/2018 12/24/2018 1.10 PROD1 DRILL WPRT P Wiper in-hole, slack weight at 10,350' 10,095.0 9,365.0 18:36 19:42 through to 10,402' (up to -41K WOB), PUW = 45K, drop rate to 1.5 bpm, stack 6K WOB Q 10,436', PUH to window, confer w/ town, agree to attempt to reduce rate to get through higher gamma interval Pump sweeps, pull into cased hole, circulate bottoms up, PUH to K1 Page 6117 Report Printed: 1/812019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Don thin Phase Op Code Activity Code Time P -T -X Operation dtKB) End Depth(ftKB) 12/24/2018 12/24/2018 0.20 PROD1 DRILL DLOG P Log K1 for+3' correction 9,365.0 9,995.0 19:42 1954 12/24/2018 12/24/2018 0.70 PROD1 DRILL WPRT P RBIH, slack weight at 10,463' @ 1.25 9,995.0 10,795.0 1954 2036 bpm, PUW = 45K, attempt at 0.5 bpm, get through clean past 10,525, begin ramping rate back up to drilling rate once past high gamma interval, PUW = 46K from 10,640', annular fluctuates w/ slight pack -off events, stack weight at 10,630, PUW = 53K, pump sweeps, RIH to bottom 12/24/2018 12/24/2018 1.00 PROD1 DRILL DRLG P Drilling, CWT = 13.7K, WOB = 2K, 10,795.0 10,957.0 20:36 21:36 BHP = 4132 psi, WHP = 260 psi 12/24/2018 12/24/2018 1.30 PROM DRILL WPRT P Projections indicate potential of not 10,957.0 10,957.0 21:36 2254 staying in southern edge of polygon, confer w/ town, PUH slowly as decison is made (currently requires -8° DLS to stay within polygon), souhern polygon border extended, return to drilling 12/24/2018 12/25/2018 1.10 PROD? DRILL DRLG P CT 51180 psi @ 1.9 bpm in, 1.9 bpm 10,957.0 11,128.0 22:54 00:00 out, Della P 1226 psi, BHP 4130 psi CT Wt 12.8 k WOB 2 k Ibs, ROP average overr interval - 155 12/25/2018 12/25/2018 0.40 PROD1 DRILL DRLG P CT 51180 psi @ 1.9 bpm in, 1.9 bpm 11,128.0 11,215.0 00:00 00:24 out, Delta P 1226 psi, BHP 4130 psi CT Wt 12.8 k WOB 2 k lbs, ROP average over interval - 155 Launch 5x5 in anticipation of wiper trip, chase out of hole. Average ROP over interval 217 ft/hr 12/25/2018 12/25/2018 1.00 PROD1 DRILL WPRT P PU 43 k Ibs on wiper #1, send 5x5 11,215.0 9,950.0 00:24 01:24 sweep. CT Wt - 38 k Ibs. 10416' , start pulling heavy, up to 50 k, -5 k Is WOB RBIH, stack out @ 10420, CT 4 k Ibs, WOB 2k Ibs Work pipe, stack out again 10429, 7.8 k Ibs WOB. PUH Ct 37. k Its dragging - 1 k Ibs, Cleaned up around 10,300' Off bottom sweep landed, lots of dirt, no rocks. Second sweep similar returns, slightly larger caving's, very small. Cuttings ratio climbed from 0.98 pre trip to 1.0 12/25/2018 12/25/2018 0.20 PROD1 DRILL DLOG P Tie into the RA tag for +1' correction. 9,950.0 9,974.7 0124 0136 Page 6/17 ReportPrinted: 1/8/2019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stun Depth Stan Time End Time our (hr) Phe% Op Code AOvity Code Time P -T -X operation (ftm) BM Depth(ftKB) 12/25/2018 12/25/2018 0.50 FROM DRILL WPRT T RBIH, 9,974.7 10,535.0 01:36 02:06 Reduce pump rate to 1.5 bpm before suspect trouble zone, 10300- 10500'.10,402' SID CT Wt to 7 k WOB to 5 it lbs PU 41 k lbs, pull to 10311', dragging up to -3 k WOB, RBIH 10,630', Start stacking coil wt and seeing annular up to 4400 psi, packing off PU, 43 k lbs, PUH, to 10,610' RBIH,start @ 0.6 bpm, ramp up to 1 bpm. 10,640, Annular to 4653, packing off, 13.5 EMW at the window. Work pipe and vary pump rate trying to clean up circulation, launch sweep. 12/25/2018 12/25/2018 0.50 FROM DRILL TRIP T PUH, 10,535.0 9,918.0 02:06 02:36 10448', start pulling heavy, RBIH, SID PU, 58 k CT Wt -14 k WOB, 10,436 work pipe. 10,382, Ct 56k lbs, -7 k lbs, send 5x5. Cleaned up @ 10,290' Window clean 12/25/2018 12/25/2018 1.00 FROM DRILL TRIP T Sweep landed, full of larger siltstone. 9,918.0 10,330.0 02:36 03:36 CR up to 1.05 now. Pump 5x5 sweep, RBIH on clean out run. 12/25/2018 12/25/2018 2.20 PROD1 DRILL TRIP T POOH chasing sweeps to surface, 10,330.0 72.7 03:36 05:48 window clean. 12/25/2018 12/25/2018 1.90 FROM DRILL PULD T Crew change, PJSM, atempt to PUD 72.7 0.0 05:48 07:42 with DS PDL. Frozen. Swap to ODS PDL, PUD BHA#5. Bit came out 1,1. 12/25/2018 12/25/2018 1.20 FROM STK PULD T PU & PD BHA #13, open hole anchored 0.0 72.8 07:42 08:54 billet. Verify EDC open, 12/25/2018 12/25/2018 1.60 FROM STK TRIP T RIH 72.8 9,385.0 08:54 10:30 12/25/2018 12/25/2018 0.20 FROM STK DLOG T Tie into the K1 for a -4' correction. 9,385.0 9,407.1 10:30 10:42 12/25/2018 12/25/2018 0.20 FROM STK TRIP T PU Wt 35 k Ibs, Continue to RIH. 9,407.1 9,900.0 10:42 10:54 Park at 9900 12/25/2018 12/25/2018 0.30 FROM STK WAIT T Wait on setting depth and slip 9,900.0 9,900.0 10:54 11:12 orientation from town. 12/25/2018 12/25/2018 0.30 FROM STK WPST T Receive orders from engineering, 9,900.0 10,301.2 11:12 11:30 Close EDC, RIH, window clean, PU 33k slack, Slips oriented 150 ROHS, CT Wt 33.41 k IDS, WOB 0.37 k Itis, Pump on 0.5 bpm, sheared at 4300 psi, WOB climbed to 3.68 klbs, SID 5.5 k lbs 12/25/2018 12/25/2018 1.80 FROM STK TRIP T PU 36 k lbs, POOH. 10,301.2 72.0 11:30 13:18 12/25/2018 12/25/2018 1.00 FROM STK PULD T Bumped up, PUD BHA # 6. 72.0 0.0 13:18 14:18 12/25/2018 12/25/2018 1.20 FROM STK PULD T PU # PD BHA V. ALateral drilling 0.0 72.0 14:18 15:30 assembly. inspect pack offs, -great. 12/2512018 12/25/2018 1.80 FROM STK TRIP T RIH W BHA#7- A lateral drilling 72.0 9,380.0 15:30 17:18 assembly, Close EDC, Shallow lest agitator, 1010 psi diff. 12/25/2018 12/25/2018 0.20 FROMSTK DLOG T Tie into the K1 for -3.5" correction. 9,380.0 9,399.3 17:18 17:30 Page 7117 Report Printed: 11812019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Time Dur hr) Phase Op Cade Activity Code Tune P-T-X Operation (MB) End Depth(flKB) 12/25/2018 12125/2018 0.30 PROD1 STK TRIP T Dry tag TOB @ 10,291', PUH obtain 9,399.3 10,290.0 17:30 17:48 pump parameters 12/25/2018 12/25/2018 2.25 PROD1 STK KOST T Start time milling, 1.9 bpm @ 5,303 10,290.0 10,290.7 17:48 20:03 psi, WHP=207, BHP=4,139, IA=822, OA=304, stall @ 10,290.4', 10,290.44, 10,290.68, and 10,290.68', PUH, PUW 39 k, circulate 5x5 lubed pill down coil. load additional lubes from hot shack. 12/25/2018 12/25/2018 0.60 PROD? STK KOST T Attempt to kickoff billet 1.52 bpm @ 10,290.7 10,290.7 20:03 20:39 4,052 psi FS, WHP=206, BHP=4,147, IA=204, OA=303, stall again 10,290.64', PUW 39 k 12/25/2018 12125/2018 0.70 PROD1 STK KOST T Circulate 25 bbl tubed pill 1.8 bpm @ 10,290.7 10,290.8 20:39 21:21 4,989 psi, WHP=208, BHP=4,148, IA=822, OA=304, stall again 10,290.64' 12/25/2018 12/25/2018 0.70 PROD1 STK KOST T Attempt to kickoff billet 1.5 bpm @ 10,290.8 10,291.0 21:21 22:03 4,111 psi FS, WHP=203, BHP=4,147, IA=822, OA=304, stall again 10,290.8' 12/25/2018 12/25/2018 0.50 PROD1 STK KOST T Circulate 50 bbl beaded drilling fluild 10,291.0 10,291.0 22:03 22:33 pill, 1.8 bpm @ 5,069 psi FS, WHP=211, BHP=4,147, IA=822, OA=304 12/25/2018 12/25/2018 1.35 PROD1 STK KOST T Time Milling @ 1 fl/hr 10,291.0 10,291.2 22:33 23:54 12/25/2018 12/26/2018 0.10 PRODt STK KOST T Time Milling @ 2 ft/hr 10,292.2 10,292.2 23:54 00:00 12/26/2018 12/26/2018 0.30 PROD1 STK KOST T Time Milling @ 2 ft/hr, 1.8 bpm @ 10,291.7 10,292.0 00:00 00:18 5,069 psi, WHP=202, BHP=4,148, IA=818, OA=303 12/26/2018 12/26/2018 0.30 PROD1 STK KOST T Time Milling @ 3 fl/hr, 1.8 bpm @ 10,292.0 10,293.0 00:18 00:36 5,069 psi, WHP=202, BHP=4,148, IA=818, OA=303 12/26/2018 12/26/2018 0.30 PROD1 STK KOST T Time Milling @ 4 ft/hr, 1.8 bpm @ 10,293.0 10,294.0 00:36 00:54 5,069 psi, WHP=202, BHP=4,148, IA=818, OA=303 12/26/2018 12126/2018 0.30 PROD1 STK KOST T Control drill ahead, 1.8 bpm @ 5,069 10,294.0 10,303.0 00:54 01:12 psi, WHP=202, BHP=4,148, IA=818, OA=303 12126/2018 12/2612018 0.90 PROD1 DRILL DRLG T Drill Ahead @ 1.8 bpm @ 5,069 psi, 10,303.0 10,437.0 01:12 02:06 WHP=202, BHP=4,148, IA=818, OA=303 12126/2018 12/26/2018 0.50 PROD1 DRILL TRIP T Stall Motor, PUW 39 k, bring pump on- 10,437.0 9,907.0 02:06 02:36 line, seems to be locked up, continue PU slowly, line up across the lop, holding MP schedule continue Pulling into tubing. Line back up down the coil, still locked up, bleed pump down. 12/26/2018 12/26/2018 1.00 PROD1 DRILL TRIP T Open EDC, POOH, started plugging 9,907.0 3,343.0 02:36 03:36 off choke, swap to choke "A", flush choke "B", looks like we plugged off choke "A", line back up on choke "B", both chokes plugged off, park at 3,343', blow down chokes, found there to be aluminum pekes and stator rubber, 12/26/2018 12/26/2018 0.75 PROD1 DRILL TRIP T Started plugging off choke, swap to 3,343.0 3,343.0 03:36 04:21 choke "A", flush choke "B", looks like we plugged off choke "A", line back up on choke "B", both chokes plugged off, park at 3,343', blow down chokes, found there to be aluminum pieces and multiple stator rubber pieces, Page 8117 Report Printed: 11812019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sian Dep1h Start Time End Time cor (hr) Phase Op Code Actvity Cotle Time P -T -X Operebon MKS) End Depth (aKa) 12126/2018 12/26/2018 1.00 PROD1 DRILL TRIP T Continue POOH, taking returns back 3,343.0 77.0 04:21 05:21 through choke "B" 12/26/2018 12/26/2018 1.50 PRODi DRILL PULD T Bump up, PUD BHA V, Crew 77.0 0.0 05:21 06:51 Change, PJSM, Contine to PUD. 12/26/2018 12/26/2018 1.20 PRODt DRILL PULD T PU BHA #8, new for us motor, and 0.0 78.2 06:51 08:03 agitator, RS P104 Baker bit. Stab on, inspect pack offs, bump up, set ounters. 12/26/2018 12126/2018 1.70 PRODt DRILL TRIP T RIH, park shallow, close EDC, Shallow 78.2 9,380.0 08:03 09:45 test aglator, delta P @ 1.8 bpm = 1095 psi. Continue to RIH. 12/26/2018 12126/2018 0.20 PROD1 DRILL DLOG T Tie into the K1 for+4' correction. 9,380.0 9,427.0 09:45 09:57 Geo, questioned the tie in, will log RA. 12/26/2018 12/26/2018 0.20 PROD1 DRILL TRIP T Continue to RIH, Window clean 9,427.0 9,963.0 09:57 10:09 12/26/2018 12/26/2018 0.10 PROD1 DRILL DLOG T Tie into the RA tag for a -0.75' 9,963.0 9,975.7 10:09 10:15 1 1 1 correction. 12/26/2018 12/26/2018 0.20 PRODi DRILL TRIP T Continue to RIH, Dry drift billet - clean. 9,975.7 10,437.0 10:15 10:27 12/2612018 12/26/2018 1.40 PROM DRILL DRLG T CT 5218 psi @ 1.88 bpm in, 1.88 out, 10,437.0 10,647.0 10:27 11:51 Delta P 1111 psi, BHP 4162 psi - 11.8 EMW @ the window. OBD, CT Wt 13 k lbs, WOB 2.4 k lbs, ROP -200 ft/hr Average ROP over interval 150 ft/hr 12/26/2018 12/26/2018 0.20 PROD1 DRILL WPRT T PU, BHA wiper -200' 10,647.0 10,647.0 11:51 12:03 RBIH 12/26/2018 12/26/2018 0.80 PRODt DRILL DRLG T CT 5189 psi @ 1.86 bpm in 1.85 bpm 10,647.0 10,795.0 12:03 12:51 out, Delta P 1089 psi, BHP 4155 psi. OBD, CT Wt 13.6 k lbs, WOB 2 k lbs, ROP 200 ft/hr Average ROP over interval 193 ft/hr 12/26/2018 12/26/2018 0.40 PROD1 DRILL DRLG T CT 5189 psi @ 1.86 bpm in 1.65 bpm 10,795.0 10,879.0 12:51 13:15 out, Delta P 1089 psi, BHP 4155 psi. OBD, CT Wt 13.6 k lbs, WOB 2 k lbs, ROP 200 Whir Average ROP over interval 193 ft/hr 12/26/2018 12/26/2018 0.20 PROM DRILL WPRT T PU Wt 38 k lbs. BHA wiper- 280' 10,879.0 10,879.0 13:15 13:27 RBIH 12/26/2018 12/26/2018 1.00 PRODi DRILL DRLG T CT 5189 psi @ 1.86 bpm in 1.85 bpm 10,879.0 11,000.0 13:27 14:27 out, Delta P 1089 psi, BHP 4155 psi. OBD, CT Wt 13.6 k lbs, WOB 2 k lbs, ROP 200 ft/hr Average ROP over interval 121 ft/hr 12126/2018 12/26/2018 0.40 PROD1 DRILL WPRT T PU Wt 39 k lbs. Wiper #1 - Billet clean 11,000.0 10,005.0 14:27 14:51 12/26/2018 12/26/2018 0.40 PRODt DRILL WPRT T RBIH, -Billet clean. 10,005.0 11,000.0 14:51 15:15 12/26/2018 12126/2018 1.70 PROD1 DRILL DRLG T CT 5335 psi @ 1.86 bpm in 1.85 bpm 11,000.0 11,231.0 15:15 16:57 out, Delta P 1089 psi, BHP 4229 psi. OBD, CT Wt 10 k lbs, WOB 1.8 k lbs, ROP 150 ft/hr Average ROP over interval 136 f 1hr 12/26/2018 12/26/2018 0.20 PROD1 DRILL WPRT P PU Wt 39 k lbs. BHA wiper- 132' 11,231.0 11,231.0 16:57 17:09 1 1 IRBIH 12/26/2018 12/26/2018 1.50 PRODi DRILL DRLG P CT 5356 psi @ 1.81 bpm in 1.80 bpm 11,231.0 11,465.0 17:09 18:39 out, Delta P 1120 psi, BHP 4197 psi. OBD, CT Wt 13 k lbs, WOB 1.58 k lbs, ROP 70 ft/hr Average ROP over interval XXXX ft/hr 12/26/2018 12/26/2018 0.40 PROM DRILL WPRT P 1,000', Wiper up hole with sweeps, 11,465.0 10,465.0 18:39 19:03 PUW 41 k Page 9117 Report Printed: 11812019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Ad" Code Time P -T -X Operation (*1KB) End Depth (WIS) 12/26/2018 12/26/2018 0.33 PROD1 DRILL WPRT P Wiper back in hole, RIW 12 k 10,465.0 11,465.0 19:03 19:22 12/26/2018 12/2612018 0.88 PROW DRILL DRLG P BOBD, 1.8 bpm at 5,283 psi, Diff --907 11,465.0 11,609.0 19:22 20:15 psi, WHP=136, BHP=4,202, IA=824, OA=307 12/26/2018 12/26/2018 2.40 PROD1 DRILL DRLG P Stall motor 6@11,609',11,607', 11,609.0 11,609.0 20:15 22:39 11,606', 11,605', 11,605' and 11,606', PUW 41-58 k, 12/26/2018 12/26/2018 1.00 PROD1 DRILL WPRT P Wiper to the window w/5x5 sweep, 11,609.0 9,955.0 22:39 23:39 PUW 43 12/26/2018 12126/2018 0.15 PRODi DRILL DLOG P Log the RA marker correction of plus 9,955.0 9,976.0 23:39 23:48 5.0' 12/26/2018 12127/2018 0.19 PROD1 DRILL WPRT P Continue wiper back in hole, RIW 13 k 9,976.0 11,427.0 23:48 00:00 Note: seen drag from 11,230'- 11,240' with 1.7 k DHWOB 12/27/2018 12127/2018 0.20 PROD1 DRILL WPRT P Continue wiper back in hole, RIW 13 k 11,427.0 11,608.0 00:00 00:12 12/27/2018 12127/2018 1.00 PROD1 DRILL DRLG P BOBO, 1.8 bpm at 5,073 psi, 11,608.0 11,608.0 00:12 01:12 Diff --1,055, WHP=151, BHP=4,211, IA=820, OA=301, unable to drill ahead ••* Note: New Mud at the bit @ 11,609' 12/27/2018 12/27/2018 0.75 PROD1 DRILL WPRT T POOH 11,608.0 9,916.0 01:12 01:57 12127/2018 12/27/2018 1.90 PRODt DRILL TRIP T Open EDC, failed position error, 9,916.0 79.1 01:57 03:51 1 reboot system, Open EDC, PJSM 12127/2018 12/27/2018 1.50 PROD1 DRILL PULD T PUD, drilling BHA#8 79.1 0.0 03:51 05:21 ••' Note: Inspect Coiled Tubing @ 12' up from CTC 0.206 avg, 5' up from CTC 0.148 inch 12127/2018 12/27/2018 1.50 PROD1 DRILL PULD T PD BHA #9, inspect packoffs - good, 0.0 79.1 05:21 06:51 12/27/2018 12/27/2018 1.60 PROD1 DRILL TRIP T RIH, close EDC, Test agitator 1123 psi 79.1 9,380.0 06:51 08:27 @ 1.88 bpm, LD BHA#8 coilTrak. 12127/2018 12/27/2018 0.20 PRODt DRILL DLOG T Tie into to K1 for a -4' correction. 9,380.0 9,398.1 08:27 08:39 12127/2018 12127/2018 0.50 PROD1 DRILL TRIP T Continue to RIH, 1 k WOB blip @ 9,398.1 11,300.0 08:39 09:09 9940', window and billet clean. 11,197' S/D 8 k lbs WOB, Pu CT W 39 k Ibs, attempt to RBIH, 11,186' S/D 3 k Ibs, PU 37 k Ibs, RBIH, modulate pump, min rate to get going, RIH to 13,300', top of A3 silt, 12/27/2018 12/27/2018 0.60 PROD1 DRILL WPRT T PU back through touble zone to 11,300.0 11,400.0 09:09 09:45 11,100, zero for bottoms up, dragging up to -1.7 k WOB, some motor work. RBIH 1.2 bpm, clean. 12/27/2018 12/27/2018 0.20 PROW DRILL TRIP T RIH 11,400.0 11,608.0 09:45 09:57 Ct RIH Wt 14 k Ibs 12/27/2018 12/27/2018 0.20 PROD1 DRILL DRLG T CT 5022 psi @ 1.88 bpm in, 1.88 bpm 11,608.0 11,612.0 09:57 10:09 out, Delt P 1070 psi, BHP 4164 psi OBD, CT Wt 1 O up to 4 k WOB, driled ahead, ratty. 12/27/2018 12/27/2016 0.40 PRODII DRILL WPRT T PU Wt 50 k Ibs, dragging -7 WOB, fell 11,612.0 11,610.0 10:09 10:33 1 1 I off to -3 k, Tum around @ 1110, still showing -3 K WOB, zero WOB RBIH Page 10117 ReportPrinted: 1/8/2019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start Time End Time our (hr) Phase Op Cade Adrvity Code Tuna P -T -X Operation (ftKB) End Depth (RKB) 12/27/2018 12/27/2018 3.20 PROD1 DRILL DRLG T CT 5161 psi @ 1.91 bpm in, 1.91 bpm 11,610.0 11,608.0 1033 13:45 out, Dell P 1119 psi, BHP 4248 psi OBD, CT Wt 10k up to 4 k WOB, driled ahead, ratty. 11610, PU dragging -3 WOB, RBIH, tagup 10609' RBIH, find bottom @ 10608', 11 stalls, lube up pill pits, send 5x5, no noticable change, roll tool face from 60 to 180, continue to stall @ or very near 11608' Hole is clean, very low amount of solids being returned. 12/27/2018 12/27/2018 1.30 PROD1 DRILL DRLG T Restat after a stall, dril ahead from 11,608.0 11,614.0 13:45 15:03 11608.6 to 11613.4' PU Restart and drill slowly to 11614', Atempt to pick up for a restart, Bump against CT Wt trips at 65 k Ibs, -14 k WOB, work pipe up to 70 k lbs, -17.9 MOB, pop free on 4th cycle. 12/27/2018 12/27/2018 1.20 PROM DRILL WPRT T PUH on wiper trip, drug negative WOB 11,614.0 9,953.0 15:03 16:15 from 11218 - 1181'. 12/27/2018 12/27/2018 0.20 PROD? DRILL DLOG T Tie into the RA tag +4.5' correction 9,953.0 9,976.7 16:15 16:27 12/27/2018 12/27/2018 1.70 PROM DRILL TRIP T Open EDC, POOH for a new bit. 9,976.7 72.0 16:27 18:09 12/27/2018 12/27/2018 1.00 PROM DRILL PULD T PUD, Drilling BHA#9, bit grade 3-2 72.0 0.0 18:09 19:09 balled up 12/27/2018 12/27/2018 0.85 PROM DRILL PULD T PD, Drilling BHA #10 0.0 9,380.0 19:09 20:00 12/27/2018 12/27/2018 1.80 PROD1 DRILL DLOG T Log the K1 marker correction of minus 9,380.0 9,401.0 20:00 21:48 8.0' 12/27/2018 12/27/2018 0.60 PROD1 DRILL TRIP T Continued RIH 9,401.0 11,229.0 21:48 22:24 12/27/2018 12/28/2018 1.60 PROD1 DRILL TRIP T Work down, setting down @ 11,250, 11,229.0 11,277.0 22:24 00:00 11,265', 11,225', 11190', 11196', 11,259', and 11,277', PUH circulating BU w/sweep 12/28/2018 12/28/2018 0.80 PRODt DRILL TRIP T Wiper back in hole, work pipe down 11,277.0 11,604.0 00:00 00:48 11,197'seen 2.2 k weight bobble, continue IH 12/28/2018 12/28/2018 0.30 PRODt DRILL TRIP T Set down weight fell oft, continue lH 11,604.0 11,606.0 00:48 01:06 1 1 Iset down 11,606', PUH PUW 49 k 12/28/2018 12/28/2018 1.00 PRODt DRILL TRIP T Continue to work towards bottom, 1.87 11,606.0 11,608.8 01:06 02:06 bpm at 5,388 psi, IA=814, OA=262 11,604'49k minus 3.8k DHWOB 11,606.9'50k, minus 3.3k DHWOB 11,609.5'41 k, minus 2.6k DHWOB 11,608.8'60k, minus 10.0k DHWOB 12/28/2018 12/28/2018 1.50 PRODt DRILL TRIP T Continue working towards bottom, 11,608.8 11.608.8 02:06 03:36 1.87 bpm at 5,410 psi, IA=814, OA=262 11604.1' minus 1.3k DHWOB 11603.8' minus 4.Ok DHWOB 11,609.1' minus 5.5k DHWOB 11,603' minus 4.5k DHWOB 12/28/2018 12/28/2018 0.20 PROD1 DRILL TRIP T Pull wiper up hole to 11,388' 11,608.8 11,388.0 03:36 03:48 1 I 12/2812018 11212812018 0.20 PROD11 DRILL TRIP T Wiper back in hole, observe WOB @ 11,388.0 11,603.0 03:48 04:00 I I 11,603', start time drilling Page 11117 Report Printed: 118/2019 Operations Summary (with Timelog Depths) 3C -O8 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time I End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(nKB) 12/28/2018 12/28/2018 1.20 PROD1 DRILL DRLG T Observe WOB @ 11,603', start time 11,603.0 11,605.0 04:00 05:12 drilling 1.87 bpm at 5,381 psi, Diff -1,218 psi, WHP=182, BHP=4,251, IA=816, OA=268 12/28/2018 12/28/2018 2.20 PROD1 DRILL TRIP T PUH on a wiper, PU 48 k Itis - 11,605.0 9,370.0 05:12 07:24 dragging -4 k WOB. Pulled -90 lbs WOB thrugh A3 LS - 11,172', some motor work. 12/28/2018 12/28/2018 0.20 FROM DRILL DLOG T Tie into K1 for a +6' correction 9,370.0 9,408.0 07:24 07:36 12/28/2018 12/28/2018 0.20 FROM DRILL CIRC T Circulate bottoms up chasing sweeps 9,408.0 9,918.0 07:36 07:48 to surface, no sign of gravel 12/28/2018 12/28/2018 0.30 FROM DRILL TRIP T RIH to 11,150 above A31 -S, time out 9,918.0 11,150.0 07:48 08:06 sweeps, 12/28/2018 12/28/2018 2.50 FROM DRILL TRIP T Chase sweeps out of hole on swab 11,150.0 73.4 08:06 10:36 wiper trip. Pre load OS PDL. Sweeps didnt return much in the line of solids, a few rocks and mostly metal from 824' bit depth, Jog the hole, little returns. 12/28/2018 12/28/2018 1.00 FROM DRILL PULD T Bump up, PD BHA#10. Lay down 73.4 0.0 10:36 11:36 bottom half, need to swap HOT. 12/28/2018 12/28/2018 0.50 FROM DRILL BOPE P Function test BODE - Good test 0.0 0.0 11:36 12:06 12/28/2018 12/28/2018 1.60 PRODt STK PULD T PU & PD BHA#11, Anchored billet, 0.0 73.0 12:06 13:42 inspect pack offs, - good, Bump up, set counters. 12/28/2018 12/28/2018 1.60 FROM STK TRIP T RIH 73.0 9,380.0 13:42 1518 12/28/2018 12/28/2018 0.20 PROD1 STK DLOG T Tie into the K1 for -2' correction 9,360.0 9,404.8 15:18 15:30 12/28/2018 12/28/2018 1.20 FROM STK WPST T PU WT 39 k lbs, Close EDC, RIH to 9,404.8 10,522.0 15:30 16:42 setting depth, PU to neutral weight. Slips oriented 180 *ROHS, zero weight, pump @ 0.25 bpm, sheared at 4400 psi,see 0.72 WOB, attempt to SID weight, billet pushed down hole WOB0.9-0.8. Consult w town. 12/28/2018 12/28/2018 1.90 PROM STK TRIP T PU Wt 40 k Is, PUH into casing, open 10,522.0 72.0 16:42 18:36 EDC. POOH 12/28/2018 12/28/2018 1.10 FROM STK PULD T PUD, Billet setting tools, BHA#11 72.0 0.0 18:36 19:42 Note: Inspect Coiled Tubing above CTC w/UT tester 0.148" inch 12/28/2018 12/28/2018 1.30 PROM STK PULD T PD, OH Anchored billet #2 0.0 73.6 19:42 21:00 12/28/2018 12/28/2018 1.67 FROM STK TRIP T RIH 73.6 9,375.0 21:00 22:40 12/28/2018 12/28/2018 0.15 FROM STK DLOG T Log the Kt marker collection of minus 9,375.0 9,405.0 22:40 22:49 4.0' 12/28/2018 12/28/2018 0.10 PROM STK TRIP T Continue IH closer to TOW, function 9,405.0 9,900.0 22:49 22:55 closed EDC, PUW 38 k 12/28/2018 12/28/2018 0.33 PRODt STK TRIP T Continue RIH to setting depth 9,900.0 10,501.8 22:55 23:15 12/28/2018 12/28/2018 0.10 FROM STK WPST T PUH 32 k (10,500.8'), bring pump 10,501.8 10,490.0 23:15 23:21 online, 0.5 bpm 1,040 psi to shear @ 4,750 psi, Set down 4.3 k (10,503.5% PUW 38 k 12/28/2018 12/29/2018 0.65 FROM STK TRIP T POOH 10,490.0 6,517.0 23:21 00:00 I 12/29/2018 12/29/2018 1.00 FROM STK TRIP T Continue POOH 6,517.0 73.6 00:00 01:00 Page 12117 ReportPrinted: 1/812019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Start rime End Time Our (hr) phase Op Code Adivity Code Time P -T -X Operation (Wti) End Depth (WB) 12/29/2018 12/29/2018 0.75 PROD1 STK PULD T At surface, spaceout, PUD & LD 73.6 0.0 01:00 01:45 selling tools BHA #12 12/29/2018 12/29/2018 1.00 PRODi STK PULD T PD, kickoff/drilling BHA#13, surface 0.0 78.3 01:45 02:45 test BHI CoilTrak tools (good -test) 12/29/2016 12/29/2018 1.66 PROM STK TRIP T Tag up reset counters, RIH 78.3 9,380.0 02:45 04:24 Note: Surface test Agitator (0212- 0040) @ 586' (Level4 vibs) 12/29/2018 12/29/2018 0.10 PROD1 STK DLOG T Log the K7 correction of minis 4.0', 9,380.0 9,399.7 04:24 04:30 PUW 38 12/29/2018 12/29/2018 0.33 PROD1 STK TRIP T Continue IH, dry tag TOB @ 10,490.3' 9,399.7 10,490.0 04:30 04:50 12/29/2018 12/29/2018 0.16 PROD1 STK TRIP T PUH, obtain pump parameters, 1.87 10,490.0 10,490.0 04:50 05:00 bpm at 5,684 psi, Diff --1,343 psi, WHP=116, BHP=4,123, IA=795, OA=227 12/29/2018 12/29/2018 1.60 PROD1 STK KOST T Time mill off billet @ 10,490' 10,490.0 10,493.0 05:00 06:36 tft/hr for a foot MOB -0.7 k lbs - 5:45 2fUhr for foot - WOB -0.5 k lbs - 6:17 311/hr for a foot - WOB 0.1 k lbs, 12/29/2018 12/29/2018 0.50 PROD1 STK KOST T Up ROP to 15 ft/hr, Drilling, WOB 0.28 10,493.0 10,502.0 06:36 07:06 k lbs, CT Wt 12.7 k lbs @10,495'- increase ROP to 25 ft/hr - 12/29/2018 12/29/2018 0.90 PROD1 DRILL DRLG T Drill ahead, CT Wt 14 k lbs, OB Cl 10,502.0 10,640.0 07:06 08:00 5840 psi @ 1.87 bpm in 1.83 out, BHP 4174 psi, 11.8 ppg EMW @ the window, WOB 2 k lbs, ROP 100-200 Nhr. Pump 5x5 sweep. Average ROP 153 Nhr 12/29/2018 12/29/2018 0.20 PROD1 DRILL WPRT T PU 45 k lbs, PUH and dry drift billet, 10,640.0 10,640.0 08:00 08:12 1 1 clean, short wiper 176' RBIH 12/29/2018 12/29/2018 1.80 PROM DRILL DRLG T CT 5407 psi, 1.86 bpm in, 1.86 bpm 10,640.0 10,900.0 08:12 10:00 out, Delta P 1240 psi, BHP 4141 psi, 11.8 ppg EMW @ the window, CT Wt 16 1 lbs, WOB 1-3 k lbs, ROP 50-150 ft/hr 10728, PU Wt 45 k lbs 10839'PU Wt 40 k lbs Average ROP 144 Nhr 12/29/2018 12/29/2018 0.10 PROM DRILL WPRT T PU 45 k lbs, BHA, w 5x5 sweep, 140' 10,900.0 10,900.0 10:00 10:06 1 1 RBIH 12/29/2018 12/29/2018 0.90 PROM DRILL DRLG T CT 5523 psi, 1.86 bpm in, 1.86 bpm 10,900.0 11,030.0 10:06 11:00 out, Delta P 1290 psi, BHP 4194 psi, 11.8 ppg EMW @ the window, CT Wt 16.51 lbs, WOB 1-3 k lbs Average ROP 144 ft/hr 12/29/2018 12/29/2018 0.40 PROD1 DRILL WPRT T PU 40 k lbs, Wiper#1, to EOB- 960' 11,030.0 9,960.0 11:00 11:24 w 5x5 sweep, CT Wt 36 k Itis @ billet #2 clean, billet #1 -clean Geo discussion turned wiper #1 into a fie in to be most efficient with time. 12/29/2018 12/29/2018 0.20 PROD1 DRILL DLOG T Tie into RA tag for+1' correction 9,960.0 9,985.0 11:24 11:36 1 1 I I I 12/29/2018 12/29/2018 0.30 PROD1 DRILL TRIP T RBIH, 9,985.0 11,030.0 11:36 11:54 - 0.35 bbls of cutting returned on the 1 trip, CR climbed from 0.81 to 0.9 Still - 0.49 bbl cuttings in the hole Page 13117 ReportPrinted: 1/8/2019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Staft Depth Sant Time EM Time our (hr) Phase Op Code Activay Code Time P -T-% Operation (WEI) End Depth (MB) 12/29/2018 12/29/2018 1.20 PROD1 DRILL DRLG T Spud twice, PU for restarts 11,030.0 11,156.0 11:54 13:06 CT 5631 psi @ 1.88 bpm in, 1.88 bpm out, Delta P 1268 psi, BHP 4244 psi, 11.8 ppg EMW @ the window, CT 12 k lbs, WOB 2.5 k lbs 91 ° Near bit, ROP drop @ 11,117', 95.74° Near bit, estimate 97 ° @ the bit Appeared to pop out of the lower lense @ 11126' bt depth, actual bit inc was 97° as we entered the A3 LS Drill ahead, 60 -80 ROP - 3 k WOB, CT 9 k lbs. 12/29/2018 12/29/2018 0.40 PRODi DRILL DRLG T Roll tool face from HS to LS, near bit 11,156.0 11,192.0 13:06 13:30 inc, 99 ° near bit depth 11137'. Targeting 2-3 k WOB, CT Wt 10 k lbs, 12/29/2018 12/29/2018 1.40 PROD1 DRILL DRLG T PU, reduce pump rate to 1.5 bpm, 11,192.0 11,355.0 13:30 14:54 RBIH Near bit inc fell off to - 97.5° and is holding, ROP up and down following Gamma. Drilled into something hard, inc fell, all good. 12/29/2018 12/29/2018 0.10 PROD1 DRILL WPRT T PU38 k lbs, Wiper to above hot 11,355.0 11,081.0 14:54 15:00 1 gamma. - clean 12/29/2018 12/29/2018 0.10 PRODt DRILL WPRT T RBIH, -clean 11,081.0 11,355.0 15:00 15:06 12/29/2018 12/29/2018 1.60 PRODi DRILL DRLG T CT 5570 psi, @ 1.85 bpm in 1.85 bpm 11,355.0 11,454.0 15:06 16:42 out, Delta P 1253 psi, BHP 4235 psi, 11.8 ppg EMW @ the window, CT Wt 9.9 k lbs, 3.8 k WOB, 11443', PU Wt 41 k lbs, 11448' PU Wt 41 k IbsHard stuff 11,442 caught a sampe, Geo says Ankerite 12/29/2018 12/29/2018 0.40 PROD1 DRILL DRLG T Broke out, Drilled ahead, CT 5897'@ 11,355.0 11,505.0 16:42 17:06 1.85 bpm, BHP 4257 psi, WH 216 psi, 11.8 ppg EMW @ the window. IA 816 psi, OA 276 psi 12/29/2018 12/29/2018 0.40 PROD1 DRILL WPRT T PU 40 k lbs, wiper #1. 11,505.0 10,505.0 17:06 17:30 12/29/2018 12/29/2018 0.35 PROD1 DRILL WPRT T RBIH 10,505.0 11,505.0 17:30 17:51 12/29/2018 12/29/2018 0.88 PROD1 DRILL DRLG T BOBD, 1.86 bpm @ 5,104 psi, Diff= 11,505.0 11,615.0 17:51 18:43 945 psi, WHP=152, BHP=4,277, IA=821, OA=284, avg/ROP 92 fph @ 11,602' spiked up DHWOB 2.1 - 3.2 Ilk 12/29/2018 12/29/2018 1.35 PROD? DRILL DRLG P BOBD, 1.86 bpm @ 5,104 psi, Diff= 11,615.0 11,725.0 18:43 20:04 945 psi, WHP=152, BHP=4,277, IA=821, OA=284 12/29/2018 12/29/2018 0.10 PROD? DRILL WPRT P Stall Motor, PUW 44 k 11,725.0 11,687.0 20:04 20:10 12/29/2018 12/29/2018 0.15 PROD1 DRILL WPRT P RIBH, 11,687.0 11,725.0 20:10 20:19 12/29/2018 12/29/2018 1.80 PROD1 DRILL DRLG P BOBD, 1.87 bpm @ 5,690 psi, 11,725.0 11,905.0 20:19 22:07 Diff=1,101, WHP=140, BHP=4,313, IA=820, OA=284, 12/29/2018 12/29/2018 0.30 PROD1 DRILL WPRTP Wiper up hole, PUW 38 11,905.0 11,199.0 22:07 22:25 12/292018 11M912018 0.30 PRODi DRILL WPRTP Wiper back in hole, RIW 11 k 11,199.0 11,905.0 22:25 22:43 Page 14/17 Report Printed: 1/812019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End rime our (hr) Phase Op Code Adrvny Code Ttme P -L% Opere n (fiKB) End Depth (MB) 12129/2018 12/30/2018 1.27 PROD1 DRILL DRLG P BOBD, 1.87 bpm @ 5,540 psi, 11,905.0 12,078.0 22:43 00:00 Diff -1,354 psi, WHP=146, BHP=4,290, IA=833, OA=297, 12/30/2018 12/30/2018 1.75 PROD1 DRILL DRLG P OBD, 1.86 bpm @ 6,148 psi, 12,078.0 12,197.0 00:00 01:45 Diff --1,342 psi, WHP=96, BHP=4,307, IA=836, OA=304 12/30/2018 12/30/2018 0.75 PROD1 DRILL WPRT P Wiper up hole to the window 12,197.0 9,955.0 01:45 02:30 w/sweeps, PUW 46 k 12130/2018 12/30/2018 0.15 PROD1 DRILL DLOG P Log the RA marker correction of plus 9,955.0 9,973.0 02:30 02:39 5.0' 12/30/2018 12/30/2018 1.00 PROD1 DRILL WPRT P Wiper back in hole, RIW 15 k 9,973.0 12,197.0 02:39 03:39 12/30/2018 12/30/2018 1.10 PROD1 DRILL DRLG P BOBD, Drill ahead, CT Wt -2 k lbs, 12,197.0 12,246.0 03:39 04:45 WOB 2.7 k lbs, ROP 58 Mr. Drill into - 150 API gamma. Consult w town. 12/30/2018 12/30/2018 3.70 PROD1 DRILL WPRT P PU, stage TD sweeps to the bit, 12,246.0 78.3 04:45 08:27 POOH on swab wiper. Uncorrected TD - 12,246' Jog open hole @ 11,250', -1200 Ib WOB tug @ 10,937', no spike in motor work. -400 lbs WOB spike @ 10,488', 2nd billet, 1st billet clean, time out sweeps to EOB, jog open hole, Window clean, chase additional sweep in the tubing. 12/30/2018 12/30/2018 1.80 PROD1 DRILL TRIP P RBIH 78.3 9,385.0 08:27 10:15 12/30/2018 12/3012018 0.20 PROD1 DRILL DLOG P Tie into the K1 for a -45' correction. 9,385.0 9,399.8 10:15 10:27 12/30/2018 12/30/2018 0.20 PROD1 DRILL TRIP P Continue in hole, Park at 9923.80 MD 9,399.8 9,399.8 10:27 10:39 and 6604.01 'TVD Trap 4155 psi / 12.1 ppg EMW and monitor BHP Elapsed time min. BHP EMW 1 4149 12.08 2 4129 12.02 5 4086 11.89 9 4046 11.78 12/30/2018 12/30/2018 1.00 PROD1 DRILL TRIP P Ct PU Wt 36 k lbs. 9,399.8 12,227.0 10:39 11:39 Continue to RIH, window and both bilets clean. Pack off event with no WOB @ 11282, PU clean and continue to RIH Two more minor increases in BHP @ 11,438 and 11,718', suspect pack off events near 11117'funel point. Continue in hole, SID 12199, PU, reduce rate to 0.9 bpm , RBIH stack out @ 12,185', PU, 43 k lbs, RBIH, SID 12,227' PU 52 k lbs, -5 k lbs WOB. 12/30/2018 1.50 PROD1 DRILL CIRC P Jog and circulate @ 1.5 bpm while 12,227.0 12.216.0 112/30/2018 11:39 13:09 building liner running pill and pump to the bit. Page 15117 Report Printed: 1/8/2019 Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time Ertl Time Dur(hr) Phase Op Code Acfiviy Cotle Time P -T -X Operation Start Depth (fiKB) End! Depth(ftKB) 12/30/2018 12/30/2018 2.40 PROD1 DRILL DISP P PU 42 k lbs, POOH laying in 51 bbl 12,216.0 100.0 13:09 15:33 liner running pill. Painting flags, TO yellow 9858.26' and Window, white @ 7478.26' Top of liner running pill 8700' Continue out of hole laying in kill weight. 12/30/2018 12/30/2018 1.50 PROD1 DRILL PULD P Bump up, Flow check, LD over a dead 100.0 0.0 15:33 17:03 well. 12/30/2018 12/30/2018 1.50 COMPZI CASING PUTB P Prep the floor for running liner. PJSM. 0.0 0.0 17:03 18:33 Verify tubing tally with crew and NS rep 12/30/2018 12/30/2018 4.20 COMPZ1 CASING PUTB P Pick up liner 0.0 2,416.0 18:33 22:45 12/30/2018 12/30/2018 0.75 COMPZ1 CASING RUNL P PU/MU, Seal Bore Assembly, GS 2,416.0 2,460.1 22:45 23:30 (NS), and CoilTrak tools 12/30/2018 12/31/2018 0.50 COMPZ1 CASING RUNL P RIH, with Liner assembly BHA#14, 2,460.1 5,148.0 23:30 00:00 hanging weight 5.4 k 12/31/2018 12/31/2018 0.84 COMPZ1 CASING RUNL P Continue RIH with frac sleeve liner 5,148.0 9,866.0 00:00 00:50 completion BHA#14 12/31/2018 12/31/2018 0.20 COMPZt CASING RUNL P Correct to the EOP flag minus 6.11', 9,866.0 9,866.0 00:50 01:02 PUW 40 k, minus 11.9 DHWOB 12/31/2018 12/31/2018 0.50 COMPZt CASING RUNL P Continue IH 9,866.0 11,765.0 01:02 01:32 12/31/2018 12/31/2018 0.15 COMPZ1 CASING RUNL P Log the Kt marker minus 0.5', no 11,765.0 12,247.0 01:32 01:41 correction 12/31/2018 12/31/2018 0.23 COMPZ1 CASING RUNL P Liner on bottom, Bring pump on line 12,247.0 9,830.6 01:41 01:55 1.7 bpm at 5,255 psi, Diff=1,749 psi, PUW 12/31/2018 12/31/2018 0.26 COMPZ1 CASING RUNL P Remove liner length from BHA, line up 9,830.6 9,816.0 01:55 02:10 to SW, Open EDC, "` Note: Check Wellhead bolts, (no torque needed) Perform Static Pressure Survey: Park at 9,816' CTMD and sensor depth 6,556.25' TVD Trap 4,130 psi / 12.1 ppg EMW and monitor BHP Elapsed time 5 min. BHP EMW 5 4107 12.2 10 4100 12.05 15 4098 12.02 12/31/2018 12/31/2018 1.00 COMPZ1 CASING DISP P Line up and pump SW down coil 9,816.0 9,816.0 02:10 03:10 12/31/2018 12/31/2018 1.40 COMPZI CASING DISP P POOH, while displacing well to SW, 9,816.0 2,927.0 03:10 04:34 LRS on location 02:55 am 12/31/2018 12/31/2018 0.90 COMPZ1 CASING DISP P Circulate in 30 bbls diesel freeze 2,927.0 70.0 04:34 05:28 protect, diesel from 2927' to surface. 12/31/2018 12/31/2018 1.50 COMPZ1 CASING PULD P Bump up, space out, PUD BHA#14. 70.0 0.0 05:28 06:58***Left 1,200 psi below the master 12/31/2018 12/31/2018 2.00 DEMOB WHDBOP CIRC P Jet stack, Flush lines, blow down, 0.0 0.0 06:58 08:58 12/31/2018 12/31/2018 2.80 DEMOB WHDBOP CTOP P Cut pipe, rehead, while Bore O 0.0 0.0 08:58 11:46 scoping. Unhappy with initial CC after re -head. Cut pipe and re re -head. Pull test to 35 k lbs - good Bore O Scope found tear in upper 2- 3/8" seal will replace prior to move. 12/3112018 12131/2018 0.70 DEMOB WHDBOP CTOP P DD/MWD rehead and test wire, 400 m 0.0 0.0 11:46 12:28 ohms and 66 ohms. Page 16117 ReportPrinted: 1/8/2019 - Operations Summary (with Timelog Depths) 3C-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stats Time End Time Dur (hr) Phase Op Code Activity Code Time P -T-% Operation (tKB) End Depth (ftKB) 12/31/2018 12/31/2018 0.68 DEMOB WHDBOP RURD P Replce dammaged upper 2-3/8" ram 0.0 0.0 12:28 13:09 12/31/2018 12/31/2018 1.40 DEMOB WHDBOP RURD P Work RD check fist, 0.0 0.0 13:09 1433 12/31/2018 12/31/2018 1.44 DEMOB WHDBOP NUND P ND BOP 0.0 0.0 1433 1600 "Rig Released: 12/31/18 @ 16:00 hrs Page 17/17 ReportPrinted: 1/8/2019 �/ ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C -08A 50-029-21390-01 Baker Hughes INTEQ Definitive Survey Report 03 January, 2019 BA ER F�UGHES E,. p,,, ConocoPhillips O n CoocoPhillips Definitive Survey Report M' Company. Com000Phlalps(Masks) Inc.-Kup2 Project. Kuparuk Reser Unit Site Kupamk 3C Pad Well: 3C-08 Wellbore: 3C -08A Design: 3C -08A Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Well 3C-08 Local Coordinate Rehrena: Voll 3C-00 TVD Reference: 3C48 ® 82AOus8 (3C48) MO Reference: 3C -0B (tg 82.00usg (3C48) North Reference: True survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Production Well Position e1114 0.04 us8 Northing: +Vi 0.00 usfi Seems, Poshionumartaimy 400 uses Wellhead Elevation: Wellbore 3C -()SA Magnetics Model Name Sample Ooh 6GGM2018 11112018 Design 3C -08A Audit Notes Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (us") 34 90 Mean Sea Level Using Vast Reference Paint Using geodetic scale hour 5,995,910.44usfi 528,55]]1 usfi us8 Designation (1) 16.89 Latitude: Longitude: Ground Level: Dip Angle M 80.92 Tie On Depth: 10,470.34 ♦1113 aEYW Donald. (vett) Instil V) ON 0.00 90.00 7,0° 23' 59.663 N 149° 46' 3.299 W 4].10 usfi Field Strength 1-n 57,444 YZ5=19 2:36.'44PM Page 2 COMPASS 5000.148udd e5D r, ConocoPhillips BA((FR__ • �I�� corlot4lllllps Definhive Survey Report Company: CanocoPFilips(Alaska) Inc, Kup2 Local Ooatdinate Reference: M11 3C-08 Proki Kuparuk River Unit ND Reference: 30-08 @ 82.00usfl (30-00) sne: Kupruk 3C Pad MO Reference: 30-084P82.ODusR(3C40) Well 30-09 North Reference: True Wallace: 3C -08A Survey Calculation Method Minimum Curvature Design: 30 08A Database: EDT 14 Alaska Ptaduc80n Survey Pmgmm Dace 1132019 From To Survey Survry (usn) luau) Burvey(WelWore) Tool Name Description Soft Data EM Dela 10000 8,900.00 3C-09(30-08) GCT -MS Schlumberger GCT mulishal 111mool 9935.00 10,mi1td, 3C-08APB1 MWD4NC(KC08APB1) MWAINC_ONLY MWD -INC _ONLY _FILLER 12/242018 12242010 10,D49S9 10,271.01 3C-00APB1(3O(GAPB1) MWD MWD - Standard 1L252018 122512010 10290.00 10,470.34 3C4BAPB2 MAID(3(-0OMPB2) MWD MWD -StandaN IMW2018 122512018 10090.00 12.246.00 3C480, BHGE CTK MWD 804]0.34-12 MWD MWD -StandaM 1213012018 12/302018 Survey ship Map Wnlcal MD Inc pN TVD TVp86 aWd rFJ4M NoIft) Bass^9 DLS se(a)l survey Taol Name Annotation (seam 19 III (1"11) loan) (aan) (1sn) nl (•llo0'1 (all (0,4]0.34 87.91 01.40 6,689.01 6,61]8] 4,881.08 S,ISt03 6,000,61103 533,909.51 33, 11.73 5,451.03 MND(0) TIP 10,9660 8]71 04.51 0)00.81 6,610.61 400280 5.470.59 6.000.81300 534,3605 0.91 5,470.59 Mots) KOP 1(1521.07 85.05 0304 6.282.55 6620.55 8886.34 5,50141 6.000,817.28 534.039.07 9,95 8,50101 MJID(5) 10,55D.03 8212 01.96 4]05.88 6823.88 4,800.20 SSb73 6,000,82125 534,069.16 1040 5.53073 M T)(5) 10,58193 83.42 BD.56 6709,78 8.62]]9 4,094.09 5,561.22 6000,82605 5. ,058.. 6.12 5.50122 MWD(5) 10,611.41 0394 78.83 6,71104 5,63104 4,900.13 5,59005 600003141 534]28.44 6.09 5,59005 evict (5) 10.84118 Key, 78.98 8,]1578 6.633.70 4,905.89 5.619.43 6000,837,20 SM 157,W 5.54 5.61943 MWD(5) 10.671.75 87.39 7601 6717.63 6,635.63 4,911,92 5.649.04 600D.84342 5..18738 6,T2 5,618.01 MWD(5) 10,701.91 8]]6 76.58 6710,91 8,616.91 4910.44 5678.46 8,000.80000 5.,21671 359 5.678.48 MWD(5) 10.73137 8678 ]52] 6.80.31 6113631 4,925.49 570702 6002851.21 534.24531 6.71 5,707.02 MWD(5) 10.761.43 8702 7685 6.5821.]2 663972 4,932.8 5736.16 6.400,86956 534.274.42 629 5736.16 Maoist 1D M,03 88'. 78.54 6.M,66 6640.65 4,939.24 5,]6605 6000.8]1.19 5.,3".27 619 SM6.05 MW➢(5) ID.88.25 08.36 BO." 0,]2118 6,64110 4,944.70 5,795.76 6,000,8]6.76 534,33358 7.30 5,]95]6 MWID(5) 10.651.58 88.25 00.97 6,=79 6,64199 494940 S824.79 8,000,881.5] 53436297 3." 5.824.79 MWD (5) 10.881.42 88.60 00,16 6,84,59 8,64259 4954.38 5,854.13 6,000,800,% 534,39229 308 5.854.13 MND(5) 10,910.62 8951 W12 68506 6,643.115 4,95930 5,08200 6.000,89167 534.42103 205 5,600.00 MWD(5) 10,841& MM2 A.65 6,M.34 664334 4,985.29 5.91353 6000.697 00 534.451.64 792 5,91353 MWD(5) 10.97226 91.01 7942 6,]25.23 664323 49]1.34 5,943.34 6.000,903 .96 53448142 7.82 5843.34 MWO(5) 11,00353 91.75 8267 6II447 664247 4976.21 5,974.22 6.000900.94 534,51228 1058 5,97422 MWD(5) 1/ 0192:36'44PM Pose COMPASS 500. 14 Budd 850 CoflocoPNlllps ConocoPhillips Definitive Survey Report Ari Company: ConocaPhilips Alaska) Inc.-Nup2 Local CaonEinam Reference: Well 3C-00 Project Nupamk River Unit TVO Refemn<e: 3C4B@82.00us8(3C-08) Som Rupamk 3C Pad MO Reference: X48 @ 82.1(3C-08) Well: 30-08 NaRh Reference: True Wellhora: 3C-0BA Survey Calculation Method: Minimum CurvaWm Design: 3C 11A Database: EDT 14 Alaska Production Survey MD Inc Ari TVD TVDSS fwk!; ♦Ef-W Map Map O/s Vertical Northing Eaanng Section Survey Tool Name (uafj (°) (9 (-am (-am I. -ft) loan) MI In) (.now) IDI 11,031.21 91.78 83.69 672362 6,64162 6979.49 600169 6 WA12M 534,539.73 3fie 6,COtfi9 MW0(5) 11051.40 93.84 83.65 6.112.14 6.6`0.14 4,982.&5 6.03113 6,000.915.61 534,569,76 682 6,03193 WIC(5) 11 p902J 95.35 W,65 8719.83 6.837.83 4,98.04 6,OSO21 6000.919.11 534.598.22 5.20 6,060.21 MW➢(5) 11,11655 96.8 0252 6.]1108 6,635.08 4989.20 6,0819 8,80.922.36 534.624.19 853 6,086.19 MMI) 1tp4a Se100.54 01.45 6.71215 6,630.15 4.993.75 6,11&53 680,92704 534,655.8 12.20 6,11853 MJUO(5) 11.18028 100.19 023] 6,7%62 662062 4.998.00 8,14&43 6,80931.40 534,68839 3.16 6,14&43 VIVA) (5) 11.21124 90.73 Mel 6.701.63 6Il.43 5.001.76 6,178.73 6,00,93529 6 71867 5]] 6,1]0,]3 MMA) (5) 11.23990 9T82 84.45 6,697.41 6615.41 5,004.]] 6203.93 6,000,83&40 534]44.% 4.79 6.2%,83 own, (5) 11,01,76 85.18 85.42 6.693.8 8611.8 5,00757 6,238.48 6.80.941.32 534.]]639 &79 6,238.48 MND(5) f 11301.31 83.01 BTt1 669169 11111 5,89.49 6,17.87 6,000.943.35 534,005.]] 9.97 6,57.07 MWD(5) j 11.M25 Was 88.5 6690.62 6,600.62 5,010.71 6,296.77 6,000.944.03 534.036.67 TTS 6,58]7 MD (5) i 11,51.8 00.74 9].30 6,69310 6.60870 5,91105 6.325.01 6,08.945.14 534,865.90 108 8.328.01 MWD(5) i11.39220 85.98 92.43 6692.11 6.610.11 5,01032 6,358.% 8.08,920.53 534,&%.55 11.35 8,358.8 MWD(5) 1145.M 87.8 928 6,603.80 6,611.04 5,208.22 636714 6033.9'a,M 534,95.8 414 6,30].14 MW0(5) 11,451.33 8.3] 91.]5 6.88.50 6,611358 5,08.8 641]65 6,000 42.65 534955.54 Z. 641765 MVA(5) 11,4818 %44 8.97 6.%7.97 6.615.50 5.007.50 6,440.13 6.08.9428 534,98.8 2.`& 6,440.13 M ID(5) 11,510.51 BT46 91.02 6.693.03 6.61703 5.097.00 6.40175 6,0.o."tea 535,014.0 3.53 6,4]6]5 MMA) (5) 11,540.44 00.97 8,91 6,78.22 661022 5.097.50 6505.62 6,80,84.27 535,04451 1.78 648862 M (5) 11,570.32 STS 88.99 6.701.46 6,619.46 5,006,52 6,5547 6809414 53507436 6.97 6.53647 MND(5) 11,80.47 8&40 87.48 6,70259 6,620.59 5,00745 65%50 68094245 Ssaijeo fi 6.19 6.566.58 Mom (5) 11,em.88 89.81 8.58 6,703.03 6,62104 5,009,03 6,596.95 6,80,944.14 55.134,03 5]B 659595 MND(5) 11,661.05 91.08 8.74 6,702.11 6,62010 5,010.79 6,69.07 6,8D945.01 535.164.92 392 6,627,07 MAID (5) 11,8085 90.]4 05.5] 670230 6,620.30 5,01211 6,85810 6.08,9411.13 96194.64 409 6,65519 MD (5) 71.7205] BB8] 04.92 6702,12 6.620.12 5,0155 6.88.41 6,08.950.70 535.224.25 339 6.E86.41 MWD (5) 11,M..77 90.40 83.b 6,702.02 6,63002 5,01&32 6.71645 6,08.953.89 535,54.9 525 6.71645 MWD (5) 11.70066 91.17 54.5 6701.61 6,619.61 5,8154 6746.16 .0.000.5723 536281.97 301 6746.16 MWD(5) j 11010.9 92.18 8214 6.70174 6,61874 5,02494 6.]05.8] 6,000.960 73 535,313.8 6.02 6,]]58] MWO(5) 11,840.81 92.58 03.8 6.69749 661749 5.02844 6110570 6,0.U.961.35 535.3.43.47 3.92 6,S%]0 MrY➢(5) 11,870.57 93.63 83.40 6,80.07 66158] 5,03176 803544 6,0.00.96779 535.3]316 381 6,83541 INA (5) 11,901.1] 92.8 8201 6.69615 6,614.15 5,03543 606 5]4 608.9719 53540340 333 6.%5]4 ~(5) 11,93109 9295 8.28 6694.65 661265 503902 609529 600097o 1 53543301 &46 6,89529 ~(5) Annotation �I�WHES 1!3/2019 2:36:44PM Page 4 COMPASS 500014 BuBd 850 `. ConocoPhillips a A CofloC8�billips Defindive Survey Report Company. ConamPhilips(Alaska) Inc.-Kup2 Prefect: Kupaml, River Und Saa: Kuparuk 3C Pad Wen: 3608 Wand.; 3C -08A Detlan: 3C -OSA Survey Local CooNinate Reference: TVD Reference: MO Reference: sons Reference: Survey Calculation MetM1eLL Database: Nall 3C-08 3C-08 ® 82.00usa (SC48) 3C-08 ® 82.00usa (3C48) True Minimum Curvature EDT 14 Alaska PmEuclion Attttotation f/SQ019 2:36:44PM Paga 5 COMPASS 600014 Budtl 85D Map lassfical MD Inc Aei TVD Mae -NIS +Ef-W DLS P) fl (ana) (-am Ran) W) NM., of h, Eseanp I -sial Sambn Survey Tool Namlose) Ia) (r) lal 11.960.57 93.63 82.07 6692.% 661698 504034 6, MAW 6000,980.]0 635.462..7 6.49 6.91037 MWD(5) 11 991,40 9332 79.S 6691.09 6,609.09 5,049.33 6,854.]4 600696581 535.49241 8.15 6.95674 MU 12,021.50 94.71 7954 6688.98 6,66.98 5,054.85 69"25 6000.93144 535521.90 L71 6.984.25 MWD (5) 12.M.59 95.78 60.52 6,M.M 6,60632 5,05987 ].012]8 6,001.,57 535550.41 490 ],012]8 MJJD (5) 12660.46 9607 61.35 6.M.24 6,601.24 5.064.55 7,04212 61001."'1.36 5355]9.]3 293 7,042.12 MD (5) f 12,110.47 96.62 8235 6.679,91 8,597.92 5,06976 ],0]1.64 6,001.00570 535.609.23 3.79 ],0]1.64 MND (5) 1.21.40.55 97.21 83.60 66]6.30 6,594.30 50MA2 7,101.29 6,001.009.40 MOWN 4.69 7,101.29 MWD (5) 12,1]603 97.14 85.85 66]262 6,590.62 5,DMIO 7,130.40 8,001012.24 53566].7 7.45 7,130.M MWC(5) 12.10.19 9646 96.88 6658.05 6,587.05 5,07699 71W.M 8,001.014.25 53568784 404 ],1W.ID MWC)5) 12,21229 8572 8]N 666].]6 6.555.76 5,0]].63 7,1M31 6,001.01494 535,][065 .24 7,18.31 MID 12.2MM 95.]2 87.03 6.664A0 6,58240 5.0]9.3] 7,20580 bn]t01600 535,743.34 600 7,205.80 PROJECTED 0 TO Attttotation f/SQ019 2:36:44PM Paga 5 COMPASS 600014 Budtl 85D ®I ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C-08APB1 50-029-21390-70 Baker Hughes INTEQ Definitive Survey Report 03 January, 2019 BA (ER 42 UGHES �i.,GE'�', ,. CollocoPhillips Conocolahillips Definitive Surrey Report Using Well Reference Point Company: ConocoPhillipa(Alaska) Inc.-Kup2 Local Coordinate Reference: Well 3C-08 Protect: Kuparuk River Unit ND Reference: 3008®82.00usd(3C43) She: Kupamk 3C Pad MD Reference: 3C-00 @ 82,00ush (3C48) Well: 3C-08 North Reference: True Walloons: 3C-08 Survey Calculation Method Minimum Curvature Design: 3C-08 Database: EDT 14 Alaska Produc50n ProjeW Kupamk River Unit, NOM Slope Alaska, United States Using Well Reference Point Map System: US Stele Plane 1927 (Ekect solution) System Damm: Geo Damm: NAD 1927(NADCON CONUS) 528,557.71 un0 Map Zone: Alaska Zane 04 ground Level: Well 3C-08 -_-- Well Position -NIS 0.00 ..it Northing: (-ft) ♦H -W 0.00 us8 Eaating: Fashion Uncertainty 0.00 ush Wellhead Elevation: Wellbons 3C-08APB1 90A0 MagnNlea Madel Name Sample Dake -----_---_--- Date 11312019 BGGM2018 11112010 Design 3C-08AP81 From Autln Notes: Mean Sea Level 1.0 Using Well Reference Point TIe On Depth: 9,900.00 Using geodetic scam factor 5,995.910.44us0 Uthude: 528,557.71 un0 LengNude: usd ground Level: o 70° 23'59.683 N 149° 45' 3.299 W 47.10 ush Dec0ssion Dip Angle FleldStrength (1) M ton 16.89 80.92 57,440 Version'. 1.0 Phase: ACTUAL TIe On Depth: 9,900.00 Vertical Section'. Depth From (TVD) +dl .EI -0a Direction luanl (usrt) (-ft) (°I 34 90 0.00 0.90 90A0 Survey Pro9mm -----_---_--- Date 11312019 From To Survey Suety push) lusRl Survey lWelWare) TOW same Deielpden StartW End Dam 10000 9,900.00 3C -OS (3C-08) GCT -MS Schlumberger GCT muOishot 1112/2001 9935,00 10,021.09 3C-08APB1 MWD -INC (3C-08AP01) MWD -INC ONLY MAID -INC_ ONLY FILLER 12/2412018 12Y,IWI8 10049.59 11,181.39 3C-08APB1(3008APB1) MWD MWD -Standard! 121252018 12252018 132019 2:29 41PM Page 2 COMPASS 5000.14 Build 85D ConocoPhtlllp5 Conocc Phillips Definitive Survey Report Company: CoaacOPhllllps(Alaska) Inc. -K.,2 Local Ooondnate Reference: VVell 3C4)8 Project: Kupamk River Unit ND Reference: 30-08@8250us8(3C40) Sloe: Ku,ruk 3C Pad MO Reference: X48 @ 82.00us8 (3C48) Well: 3C-08 North Reference: True Wellbore' 3C-0BAPe1 Survey Calculation Method: Minimum Curvature Design: 3 08APB1 Database: EDT 14 Alaska Production Survey mg 9 Annotation TIP KOP InksMalated Aamulh Inlerpalaled Azimulh 1J 192:29:41PM Page3 COMPASSS0011413vW85D MD lusnl Inc 1'1 Aad (1) rvD sent rvD55 Joan) +0143 (u9R) 4EIiN (latnl Nampa., Exalting DLI; (.11oal Sedum Survey Tool Name (n) (M (M 990000 49.10 54,07 662023 6530.23 4623]] 4,97614 6.00].552]4 533515.65 040 4,976.14 MWD -INC _ONLY (2) 8.93600 48.95 SLM 6,643.16 6.561.16 463930 493]54 6,000.56.4.34 533536.99 Of8 4,997.54 MW41NC_ONLY(2) 9.960.17 54.10 M.W 6,65662 6.576.82 4,65087 5,01346 6,000.5]997 533,54.89 2046 5.013.0 MWUINC ONLY (2) 9.00083 6357 52.00 6.67AM ifao'56 4650.55 5,034.26 0,0005&5]3 533,573.60 31.59 5,00426 MJv41NC ONLY(2) 10,001.09 ]2.2] 50.00 6.685.00 6,604.00 4.684.31 56%16 6000,613.5] 533,595.44 29.20 5006.16 MJ40-INC ONLY(2) 10.049.89 80.63 47,91 6.60075 6610]5 4]02.68 S,a]]25 6,00063203 M61615 298] 56]].25 MD (a) tO,O70.54 8963 48.18 8.894.00 6,612.50 071643 5,092.54 6,000,645.93 533,631.68 43W 5408254 MWD (3) 10,100.43 91.50 0.31 6694.211 61.11220 4,735.94 5,115.17 6,000,665.42 533654.24 9.53 5,115.17 MW➢(3) 10.13036 9089 53.84 6693.58 6611.58 4]54.33 5,139.]] 6M.GnW 533,67].7 1187 5.138.77 NAND (3) 10,180.00 90.55 59.46 6.682.95 6,61D.95 4,781.65 5,100.29 5,00,711.38 533.719.17 11.32 5.1W29 MMD(3) 10,21033 9050 6100 6.0265 6610.66 4,796.8 5,20.54 6000,]2629 533.74500 7.40 5,266.54 UN)(3) 10,240.61 90]] 64.89 B.M30 6.1O30 4,810.11 5233.60 6,000,740.04 5337)245 10.55 5,233.68 AND (3) 10,271.01 91.01 ken 6691.82 6600.4 4922.07 5,261.61 6,000.74.10 533,80034 12.79 5,261.61 MWD(3) 1028995 9.40 R.W 6691.47 6609.47 4,031]0 5.288.90 6,000.]61.@ 533627.59 11.55 5,288.90 NaN9(3) 10,329.32 9.71 74.18 .691.18 6,609.18 4840.30 5,31698 690.]]0.54 533055.63 7.34 5,316.98 MND(3) t0E609 912 76.73 6,690,6,4 6,608.64 4,84772 5.345.59 600077607 533.884.21 0.91 5,345.59 MND(3) 10,39D.19 00.77 ]].82 6.690.04 6008.04 A054.61 5,3]6.12 ti3OW785.00 43,914.71 004 5,376.12 IMN(3) 10.4(1.51 069 77.38 6,6935 6EC6.35 4,881.13 540.72 6.00079171 43941.28 90] 5,4DE72 MD 10,45089 85.21 75.84 6.692.12 6,610.12 4,80,10 5435.00 6,000.]98]0 533,9]3.4 1071 5,435.00 MWD (3) 1040050 0397 77.0 669493 6.61293 4,83.7 5,463.80 6,00.95.8] 534.002.30 SR 5,46380 MND(3) 1050084 94.65 78.71 669695 6,614.95 4,079.33 5,483 fie 6000.810.20 534022.15 8.02 5483.66 MW➢(3) 1052.49 64.92 81.51 669920 8.61738 4,803.71 5,511.9.92 6,000 814.68 534.04729 lo.9 6500.4 MND (3) 10,553.74 8613 85.93 6.701.1 661941 4600.68 5,535.82 600061]]1.1 534074.27 16]] 552.92 MND(3) 10,500.]0 08.00 00.50 6]00.63 limes 4,887.52 5,54.3 6,00081670 534.101A7 19.39 5,562]3 MWD(3) 10,610.37 0794 9300 6.M.51 662151 4886.39 5,59238 6,000817.60 53413001 1156 5,59236 MWD (3) 10,641.01 8185 X. 6,]2.00 6822.63 488300 5,M.78 6.0.00.014.41 534161.24 1841 5,62270 MVA(3) 106]0.]5 89.56 19.13 67050 6823.56 4,0]682 5651.84 solooeLb.34 5341932 2114 5651.84 MVC(3) 10690.17 .16 107.99 6.70.12 6.62412 4,071.29 5,67045 6MOM.80 534208.94 1486 5670.45 MNO(3) 10.721]0 B8.[5 100,00 6,707.00 6,62550 4.851 82 5,7959 6000.]9353 534,239.12 3.04 5,70.59 NNND(3) 10.7517! 88.00 108.03 6707.88 6625.80 4,80.4 SM19 6.000 784,65 534.26].]5 4.40 5,729.19 AND (3) mg 9 Annotation TIP KOP InksMalated Aamulh Inlerpalaled Azimulh 1J 192:29:41PM Page3 COMPASSS0011413vW85D Annotation 1/582019 2:29:41PM Paseo COMPA855000.149udC88O Conocofshillips ConOCO�hhll(PS Definitive Survey Report Co.,.,: ConamPhillips(Alaska) Ina-Kup2 Local Coordinate Reference: Wall 3C-08 Protect: Kupamk River Unit ND Reference: =48 a 82 ODusS (3C48) Sake: Kupamk 3C Pad MD Reference: 3C48 ® B2.00ua8 (3C48) Well: 3CAS North Reference: True WelOore: 30-o8AP81 Survey Calculation Method: Minimum Curvature Design: 3C-OBAPBI Oalaea9e: EDT 14 Alaska P.ducuon Survey Map Map Witical MO Inc Ab TVD mss 41418 ♦EI -W No1 Eaftln9 OLS Section sarvey Tool Name batt) r) N (-am (uelt) (uan) luau) (ti l (n) NOV) l til ID,780.45 6929 100.62 6]OBX 6,826.58 4,843.82 5756.41 60.'b,]]5 74 534,295.00 4.95 5,756.41 MAD Iii 10,011.12 88.03 floor 6]09.2] 6627.27 4,033.46 576526 60.U,765A9 534.323.89 641 5,705.5 MWD(3) 10,04126 6656 113.14 6,71014 fi,.20,06 4,021.17 5,813,20 6,000754.31 534,351.55 6]4 5,813.20 MAD (3) 10,87189 67.11 115.87 6.711.11 6620.11 4,800.52 5.64107 6,O1 534,3]9.]8 1023 S,M1.07 Men) (3) 10,55166 6845 119.93 6,712.01 6,630.01 4,]96.]0 5,867.30 6.000,728.00 534.406.05 1637 5,86].30 Men) (3) 10,11240 87.00 116.43 6,712.82 6,630.02 4,70114 5.694.46 6.000 713.59 534.433.28 12W 5.09446 MWD(3) 10.14087 06.37 114.26 6714.32 6,63232 476806 5,919.96 6.000.70161 534.450.61 8.71 5,919,90 MWD(3) 10.99129 87.94 112.58 6715.. 6,633.84 4,756.90 5,948.04 6,OW.6B8.% 534,48594 7,50 5,94B.o4 MND(3) 11,03233 09.97 114.34 6716.59 6,800.59 4740.57 5.998.67 6033.8]33] 534524.63 655 5,985.67 MWD(3) 11 Wt. as to 111.40 6117.59 6635.59 4,]2942 6,012.10 om.66233 500551.10 17.12 6,012.10 NAND (3) 11,00110 B5. 111.00 6.71969 6,83768 4,]164] 604602 6"651.48 534579.05 0.33 6,.0.02 must p) 11.125.13 0653 114,19 6,72193 6,639.93 470.96 6,07196 61000.84610 534,611.414 8.69 6,071% MA4D(3) 11,15157 87,32 106.29 615.35 5,841]5 4,698.13 609]1] 6.000632.37 $4,636.28 717 6,097.9 MD 1118139 8625 105.24 8,72414 664250 4691.. 6.12565 6.000,624.39 534664.90 4.70 6,125.85 Man (3) 11.215.00 8825 105.24 6,7553 6.3.53 4682.21 6.1565 6.000,61560 534.697. O.W 6,158.5 PROJECTED IO TO Annotation 1/582019 2:29:41PM Paseo COMPA855000.149udC88O ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C-08APB2 50-029-21390-71 Baker Hughes INTEQ Definitive Survey Report 03 January, 2019 BA ER F�UGHES E< , , r. ConocoPhillips 1141(%50 Conoc0P11ll1ps Definitive Survey Report 9 Company. ConocoPhillips(Aleaka) Inc.-Kup2 Local Coordinate Reference: MR 3048 Project Kuperuk River Unit TVD Reference: 3"Is Q 82.00usft (3C48) She: Kupmuk 3C Pad MD Reference: 3C-00 @ 82.00uaft (3C-08) Well: 3Co8 North Reference: True Wellbore: 3C-08APB2 Survey Calculation Method: Minimum Curvature Design: 3C-08AP82 Database: EDT 14 Alaska Production Project Kupamk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Eirscl solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geadeVc scale factor Well 3C-08 Well Position N/4t 0.00 usft Northing: 5,995,910.44usft Latitude: 70.23'59.683N .ELW 0.90 usft euding: 528,557.7lusft Longitude: 149.46 3.299 W Position Uncertainty 0.00 usft Wellhead Elevation: ..it Ground boost 47.10 usB Wellbore 3C-DBAP82 Magnetics Mail Noma Sample Dale Mchrodon DIPM96 Hold Strength 1°I 11 (nT) l BGGM2018 111112018 16.89 80.92 57,440 Design 3O 11APB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,271.01 Vertical Section: Depth Frim(TVD) •W4 aE4/ Direction (-am (Nan) (uelt) (°) 34.90 0.00 9 Oo 90.00 Survey Prognm Data 1/42019 From To somey sups, (usft) lisft) SurveylWallbare) Tool Name Description Sun Dab End Data 1000o 9,900.00 3C-08 (3C-08) GCT -MS SchlumhGrgef GCT muhichol VIV2001 9,935.00 10,021.09 3C-0BAPB1 MWD-INC(3"SAPBI) MWD-INC_ONLY MWD -INC ONLY FILLER 12/2412018 122412018 10,049.89 10,271.01 3C-08APB1(3(-0 PBi) MWD MWD -Standard 12/2512018 122512018 10,290.00 11,585.59 3C-0MPB2 MWO(3C-08APB2) MWD MWD-Slandord 121252018 1225/2018 1y 192:3IttleM Paget COMPASS604014Bugd850 1/ 192:M 10FI81 Patio Annotation TIP KOP �� 4 1 UGXFS ConocoPhillips ConocoPhillips Definitive Survey Report Company- ConocoPhillips (Alaska) Ine.-Kup2 Local CO hdimte Reference: Wall 21C.08 R Jacc Ku,nuk River Unh TVD Reference: 30-08 ® 82.00uag (30418) Slla: Kupemk 3C Pad MD Reference: 3C-00 @ 82.00ueg (3C48) WIN: 3048 North Reference: True Wegbom: 3"8APB2 Survey Calculation Method Minimum Curvature 11valgn: 3C-08APB2 Database: EDT 14 Alaska Production Survey Map Map Venlcal a1D loo,Atl 11/0 TW88 .1,1145 v*` Nan) Each, OLS OLS Section Survey Toel Name (Nag) 1.1 P) lust) Nam (waft) (.111i RI IRI el 10,21101 Bt 01 E6"T7 6691.02 6609.83 4,022.07 5,28,81 8,007.75210 53J,BC034 12.79 526161 MWD (3) 10,10007 9061 ]0.93 .,fiat% 6,609% 4,02661 5,279.44 6.000,75891 533,818.14 11.57 5,279." MND pI 10,320.011 80.28 60.39 6.69,85 6,609.05 4,639.06 5,307,82 6.003.76927 533846.20 1147 5,307.62 MND MI 10.35216 8655 NO 6,69328 6,61,30 4807.% 5,337.40 ItCO3]812] 533,976.01 547 5,33740 WD (4) 10,302.28 0554 ]D.4] 6.6%.3] 6,61331 40615] 5,36fi54a 60."0.79300 533,90405 65] 5,38540 MWD(4) 10"0.69 87.82 79.14 6.699.]6 6,616]6 4,816.07 5.421.8 6MrW7." 533,96022 15M 5,421.8 MD (4) 10,410.34 67n 84.40 6.659.87 6,69.87 4,801.00 5,451.03 6AW,81183 533.989.51 ITTI 5,45110 MWI](4) 10,500.47 6770 91.9 6]0102 6819,42 4,883.67 5,48100 6000814.04 534,01947 0.80 5,48100 NMA) (4) 10,53D.51 8714 0.51 6"337 662937 49959 5,510.90 8,000,81751 5ZPI.m.35 364 5.510.90 MWD(4) 10,56D" 87.57 86.07 6,]03]6 6821.76 4,80662 5,549]] 6,000a1971 5340]9.21 4.03 5540]] MND(4) 10,59D65 6625 69.07 8,]05.38 6823.38 4,889.88 5,570W 6,000,8810 53416930 755 5,570.% MD (4) 10,62,30 86.10 WN 6]07.43 6625,43 4.090.03 5601.44 6.000.821.36 534139.0] B.09 5,071," MWD (4) 10,0511® a4>n 9371 6.709.07 0,627.83 4,88 .02 5,831.11 8,070.80136 534169.54 10.17 5,631.11 MWD (4) 10,680.41 8597 959 6,7139 5,63017 49a6A3 S,6FA.23 6,003.09.98 534198.6] 7.02 5%0.23 MWD (4) 10,710.07 8TM 95.31 6.713% 6,631% 4,83354 5,697.26 6,600,01521 534220.71 131 5,69026 MWD (4) 10,741.61 8059 95.53 6715.09 6633.07 4007.62 5.72108 6070012.40 531.25951 445 S,Y21.00 M4W(4) 10."0.63 89.00 94.01 671568 ..Ms. 4810.00 5,]4990 6000,80.90 534.295" 100 5.74907 MWD(4) 10,070.57 0951 92.75 6,716A5 6.631.% 4.87603 5]]985 saw ,It (PI 534.318.31 ]03 5,"985 MWD(4) t0,B30.41 90,99 91AS 6715.92 6833.92 4,87480 5,009.67 6,000,807.01 5 .M,13 6.15 5,80967 NMA) (4) 10.070.38 90.52 an'. 611553 693353 4,94.33 5.039.63 6.000.8%.55 SM.37&W 419 5,079.63 MIND (4) 10,89395 9015 89.07 6.715.31 6633.33 4,87423 5,073.20 6,000.005.59 534,01.66 2.15 5,07330 MND (4) 10.92623 W.0 ,49.20 6,715.66 6,63366 48]4]6 5804.4] 6,00999.24 534,44292 715 5,904.47 la D(4) 10,955.12 87.17 W50 6.718.75 66X75 4,875.62 592o$3M 6,070.80621 5344]277 5.05 5934.33 MD (4) 10.986.06 05.52 8615 6.710.8 66%]2 4.96.52 5965.19 6.00..808.23 53450363 SAS 5,%5.19 MD (4) 11,015.41 05.67 8701 6.M.9 8,630.97 4,97.76 5,994.42 6,m,81056 53453307 391 5,89442 MM (4) if A45.W 8604 95.97 8,]23.17 6,6419 4,87961 6,02473 6,000.012.56 534.563.15 3.62 6.@413 MM (4) 1194.59 87sl 83.20 6jN.69 6,64269 4902.32 6.053.30 6000.01537 53459171 11,52 8,05330 MWD(4) 11.110.80 9071 82.25 6.35.13 607313 4,006.92 600930 6OW'So, 11 531.68769 615 669930 MMD(4) 11.14091 9301 82.23 6,n4.16 6.64216 1090.83 6.11073 6.0Wr82423 534.657.10 774 6119.73 MWO(4) 11,1694] 95.16 91]3 6]22.11 6.64011 4,894.95 6,14].23 6AW.028.35 53460759 785 6,14733 MJN(4) 1/ 192:M 10FI81 Patio Annotation TIP KOP �� 4 1 UGXFS r, ConocoPhillips enll� 4 ConocoPhilli s DefinXive Survey Report 9 Dame ConocoPhillipz(Alazka) Inc. -,2 Project: Kupamk River Unit SW: Kupamk 30 Pad Well: 3C410 Weltme: 3C-0HAPB2 Dedi 3C-08,42788 Survey Local Co-ordinate Reference: TVD Reference'. MD Reference: North Reference'. Survey Calculation Method: Database. 036113"5 30430 @ 82.00us8 (30-08) 30430 ® 02,00uzM1 (3"8) Tone Minimum Curealum EDT 14 Alaska Production Annotation 1738019 2: 38'10PM Peps 4 COMPASS 5000.14 Budd 850 Map Map Vertical MD IM Av TVD TVD55 +WS +E/ -W Northing Eaatla9 OLS Section Survey Tool Name (.an) V) (°) time) lu9fll lusnl luznl IXI (hl I°nodl 1X1 11,200.85 97.90 81.18 671852 653552 4699.53 617803 6000831 1. 534711540 9.15 6,178.06 VWD 141 1133188 99.31 6036 5,713.89 6,631,89 4,904.46 6,21612 8,000.83810 534,746.43 5% 6.258.12 MWD (4) 11 Mall 99,60 7899 670319 6.627.18 4%9.50 6,235.)6 6000,84334 534774.05 092 6.235.76 MD (4) 11.29063 99.31 78.82 6 704, 16 6622.16 491528 6 2e 2. 6,00064814 534.803.53 133 .alSah MWD(4) 77,320.03 97.07 78.02 6,699,89 6,617.89 4,925.98 6,294.36 6,0331854.95 534.832.60 7,51 6,294.36 MAD (4) 11,356.25 93.50 7657 6,696.58 6,614.56 44927.57 6,329.20 6,000,86167 534.857.41 9.89 6,32830 MAD (4) 11.3116.40 9185 8019 6.685.22 6.61322 4.932,87 6,350.90 6,(CQW]03 534,097,08 6.90 6,358.90 MINI) (4) 11,415.83 81 82.23 6,894.92 6,612.92 4,037,36 6.387.98 61WO,B7t69 534,926.14 9.78 6,367.96 MWD(4) 1,445.15 08,40 81 6,69544 6,61544 494068 6.417.10 6,000,87512 534,85535 9.47 6.417.10 MWD (4) 1147514 8853 acted 6696,26 6,614.26 4.M17. 6,441.52 81000.070.34 534,98405 3.76 6,47.52 MWD (4) 11,90,1,67 89.32 03.43 6 69a 6614.80 4,94LOB 61 6.0001101.74 535014.50 217 6,476,46 MD(4) 11.536.61 92.67 Be 21 6b%25 661435 4,949.94 650806 6,003.81 535,046.16 1571 6508.06 MWD(4) 11,566.85 93.26 87,99 661 6,61230 4,951,46 6,537.96 6,000,885.35 535.076.05 825 6,53796 MND(4) 11609.00 e5M 8799 6,692.29 661028 405284 658037 8,000.888,00 535.118.36 000 6.58027 PRO TED 10 TD Annotation 1738019 2: 38'10PM Peps 4 COMPASS 5000.14 Budd 850 THE STATE Alaska Oil and Gas °fALASKA GOVERNOR MIKE DUNLEAVY Sandeep Pedam Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3C -08A Permit to Drill Number: 218-161 Sundry Number: 318-574 Dear Mr. Pedam: Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the 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, Hollis S. French Chair DATED this day of January, 2019. RBDMSJAN 0 9 2019 STATE OF i � I G I N A LLA` .A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Plug Perforations ❑ Fracture Stimulate ' Repair Well Operations shutdown LJ 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: ConocoPhilli s Alaska Inc. Exploratory ❑ Development p Stratigraphic ❑ Service ❑ 218-161 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21390-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this po N/A Will planned perforations require a spacing exception? Yes ❑ No ❑� KRU 3C -08A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL25629 / ADL25634 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft) Effective Depth MD: Effective Depth TVD MPSP (psi): Plugs (MD): Junk (MD): 10,234' 6,839' 10,137' 6,775' NONE 10068'/10084' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 116' 116' Surface 5,171' 9.625" 5,206' 3732' Intermediate Production 10,224' 7" 10,218' 6830' finer w/frac sleeve 3300' 2-3/8" 13,100' 6656' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9904-9921, 9938-9954, 6623-6634, 6645-6656, 3.500" L-80 9,962' 9976-10004 6670-6689 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - PACKER, BAKER, PREMIER MD= 9652 TVD= 6459 SSSV - NONE NONE 12. Attachments: Proposal Summar Wellbore schematic❑ 13. Well Class after proposed work: Detailed Operations Program R1 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 1/ 9 f/ `D Lt -7 Commencing Operations: 15. Well Status after proposed work: V OIL ❑Q 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. Authorized Name: Sandeep Pedam Sandee Pe Contact Name: P dam Authorized Title: Co letions eer Contact Email: Sandeep.pedam@conocophillips.com Authorized Signature ,, t n Contact Phone: ;907) 263-4724 10f Date: , d COMMI SIO USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test F] Mechanical Integrity Test❑ Location Clearance ❑ Other: WC /15 /K--31 and 3C -IDA to be Sht,f-/v P/ -"or io a. cl Gffit-i"Z Ft-acl't rC,s�,-1�m/rlafror.avrGj martna^c/ /vrc," for,' -I ri!Rtitl-�rj Post Initial Injection MIT Req', Yes ❑ No 2 Spacing Exception Required, Yes ❑ No Subsequent Form Required: O APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: orm 10 \•��\ hl »i 2,.1. espprvveu application is valla Tor 1Z monthsthe date of approval. Attachments in Duplicate JAN 0 9 2019 �� i 7• l`'i ConocoPhillips Alaska December 26, 2018 To: Operator and Owners (shown on Exhibit 2) Jason Lyons Staff Landman Land & Business Development ConocoPhillips Company 700 G Street Anchorage, AK 99501 Office: 907-265-6002 Fax 907-263-4966 jason.lyons@cop.com Re: Notice pursuant to 20 AAC 25.283 (1) 3C -08A Well Kuparuk River Unit, Alaska ADL 25634, KRU Tract 21; ADL 25629, KRU Tract 14; and ADL 25628, KRU Tract 15 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAP') as Operator and on behalf of the Kuparuk River Unit ("KRU") 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 3C -08A Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about December 26, 2018. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). 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 to you. If you require any additional information, please contact Paul Wharton at 907-263-4076 or paul.k.wharton@conocophillips.com. truly yours, Staff cc: Rebecca Swensen EXHIBIT 1 2 g ADL025628 ADL025629 o$ W 2 W O o z X11 z 12 o N N 7 zti D n O U t— a Gq 3C.10 Aww M �G p`bP 3�,0� 3G.10 P�1P�1 ^,G• -3 gG' 16 3C I ��. %GO .�, 3C'>6 3C-12 13 18 �9 Ci � w � n 'c 1R ADL025634 ADL025635 O Well Pad • Frac Points ConoeoPhillips 24 — Well Trajectory Alaska Open Interval [:31/2 Mile Frac Point Radius N 3C -08A Q 1/2 Mile Well Trajectory Radius Lease Plat mmmE::3mmm= Miles — Wells within Trajectory Radius 9/20/2018 0 0.1 0.2 0.3 0.4 0 CPAI Lease UoClm ll P7h. usonoa. 1a.ak sharadANULug', l GKAGeosciencegeDtechymjeclslGKAy;r fsIOPF_3_WO Vi!ell 3G_OM.All_3C_OBA fracsundry_20180905rrua 3C -08A Hydraulic Fracturing Notice Letter December 26, 2018 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non -Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Weston Nash Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 K Street, Suite 406 Attention: Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 P. O. Box 196601 (Zip for PO Box 99519) Anchorage, AK 99503 (Street zip) Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director I TO THE A,..SKA 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 KRU 3C -08A 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 . ollows: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 or about December 26, 2018, 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 261h day of December, 2018. C G E. Lyons STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 261h day of December, 2018, by Jason E. Lyons. 66tary � _ �Al Qk 1 Public, State of Alaska STAT ��T NOTARY PUBLIC j REBECCA SW ENSEN My Canmission Expires Aug. 27, 2020. STATE OF ALASKA ALA:..,, OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 2Rn 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 12d Repair Well LJ Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Aller Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 185-155 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-213 -00-00 7. If perforating: S. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N A Will planned perforations require a spacing exception? Yes ❑ No 0 , r KR 3C-08 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL25629 / ADL25634 I f Kuparuk River Field / Kuparuiy4r Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft) Effective Depth MD: Effective Depth ND MPSP (psi): lugs (MD): Junk (MD): 10,234' 6,839' 10,137' 6,775' V NONE 10068'/10084' Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16” 116' 11 Surface 5,171' 9.625" 5,206' 32' Intermediate Production 10,224' 7" 10,258' 6830' Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9904-9921, 9938-9954, 6623-6634, 6645-6656, 3.5cw' L-80 9,982' 9976-10004 6670-6689 Packers and SSSV Type: Pacyers and SSSV MD (ft) and ND (ft): PACKER- PACKER, BAKER, PREMIER =9652 TVD=6459 SSSV-NONE ONE 12. Attachments: Proposal Summar Wellbore sch mati 0 13. Well Class after proposed work: Detailed Operations Program ❑� 80P Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/4/2019 OIL g 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 t procedure approved herein will not be deviated from without prior wri n approval. Authorized Name: Sandeep Pedam Sandeep Pedam Contact Name: Authorized Title: �Eompleti24 Engipper Contact Email: Sandeep.pedam@conocophillips.com Contact Phone: ;907) 263-4724 Authorized Signature Date: I 20 Zb ( B _—�) COMMIS ION USE ONLY Conditions of approval: Notify Commissio so that a representative may witness Sundry Number: Plug Integrity ❑ BOP T to Mechanical Integrity Test❑ Location Clearance ❑ Other: Post Initial Injection MIT Req' Yes ❑ No ❑ Spacing Exception Required-, Yes ❑ No ❑ Subsequent Forth Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: orm 10403 Revised 4/2017 Approved appllc0ri�]IjGr114) from the date of approval. Attachments in Duplicate ConocoPhillips Alaska Paul K. Wharton Staff Landman P.O. Box 100360 —Suite ATO 1482 Anchorage, Alaska 99510-0360 Phone (907) 263-4076 Paul. K. Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 3C -08A Well Kuparuk River Unit, Alaska ADL 25634, KRU Tract 21; ADL 25629, KRU Tract Dear Sirs: 14; and ADL 25628, }KRU Tract 15 ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") 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 3C -08A Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about September 24, 2018. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). 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 to you. If you require any additional information, please contact the undersigned. Very truly yours, e K �)&'?/-f�✓ Paul Wharton Staff Landman cc: Rebecca Swensen ADL025629 c> ADL025634 v /,/ ConocoPhillips Alaska m a 3C -08A N Lease Plat 11111111111111=300K=Miles 9/20/2018 0 0.1 0.2 0.3 0.4 ADL025628 1R ADL025635 OO Well Pad Frac Points Well Trajectory Open Interval C31/2 Mile Frac Point Radius C31/2 Mile Well Trajectory Radius — Wells within Trajectory Radius CPAI Lease 3C -08A Hydraulic Fracturing Notice Letter September 24, 2018 Page 3 Exhibit 2 Mineral Owners Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non -Operators BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Weston Nash Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 K Street, Attention: Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 P. O. Box 196601 (Zip for PO Box 9 Anchorage, AK 99503 (Street zip) Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the Alaska Oil and Gas Conservation Commission in the Matter of the Request of ConocoPhillips Alaska, Inc. for Hydraulic fracturing for the KRU 3C-08 Well under the Provisions of 20 AAC 25.280 STATE OF ALASKA THIRD JUDICIAL DISTRICT ) AFFIDAVIT OF Paul K. Wharton �xv Paul K. Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton. I am over 19 years old and have personal know' ge of the matters set forth herein. 2. 1 am Staff Landman for the well operator, ConocoPhillips Alas , Inc. ("G I") 3. Pursuant to 20 AAC 25.283 (1) CPA[ prepared the attached No' of perations ("Notice"). 4. On or about September 24, 2018, CPAI sent a copy f t e oti by certified mail to the last known address of all other owners, landowners, surface owners, and operators of ord hin a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 24th day of September, Paul K. STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 24th day oSeptember, 2018, by Paul K. Wharton. Notary Public, State of Alaska ST ALASKA „m M(TCARY PUBLIC REBECCA SWENSEN MY Cot m{gion Ex nm Au . 27, 2020. 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) SECTION 3 - FRESHWATER AQUIFERS 20 AAC 25.283(A)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a % mile area beyond and lying directly below the Kuparuk River oil and gas producing field". 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 The 9-5/8" casing cement pump report on 7/17/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 543 bbls of Arctic Set III ' and 70 bbls of Class G Cement. The 7" casing cement pump report on 7/24/1985 shows the the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 450 Sx (92 bbls) of Class G Cement. 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 design limits. Section 7 — Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) 20 AAC 25.283. Hydraulic fracturing (a) Before hydraulic fracturing, the operation must submit and Application for Sundry Approvals (Form 10-403) under 20 AAC 25.280. Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (7) pressure test information if available and plans to pressure test the casings and tubing installed in the well; On 05/26/2018 the 9-5/8" casing passed a MIT -OA; was pressure tested to 1,800 psi. On 08/22/2018 the 7" casing passed pressure test to 2000 psi. On 11/23/2018 the tubing was pressure tested to 7000 psi after RWO On 11/24/2018 IA was pressure tested to 2750 psi with 1500 psi on tubing The tubing will be pressure tested to 6150 psi and IA to 2750 psi before frac. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,850 Annulus pressure during frac 2,500 Annulus PRV setpoint during frac 2,600 Annulus pressure test 2,750 Tubing pressure Test 6,150 Nitrogen PRV 8,550 Highest pump trip 8,050 Table 1: Required Pressures 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 9 & 5/8" 36 1-55 3,520 psi 26 J-55 4,890 psi j2,020 apsi 3 & %" 9.3 L-80 11560 psi 2 & 3/8" 4.6 L-80 11,200 psi able 2: Pressure Ratings Stimulation Surface Rig -Up Bleeo/Tattle \ Tela Tank L' d Y \ a e F d R {J L tl>al ownd V Pop -0M Teak Tree Saver With Wellhead ►SOIL STATES Energy Services (Canada) Inc. QUOTE#: DATE: Maximum Allowable Pumping Rates PROPOSAL: SIZE ID OD RATE mYrnin CSG 2.250 3 1/2" Big Bore 1.750 3.750 10 m3/min —2.750 6 in'linin 2-7/8" & 3112" 1.438 2.360 2 3/8" 1.000 2 ml/min 3 1116 & 4 1/16 with tapered mandrel 2.750 —1.-9-00 4.000 F 15 m'/min 4 1/16 X Tool Mandrel 3.610 4.750 1 24 rn-ImIn OPEN P051110N CLOSID POSITION USA) [i I4 41. Yi AI t. www.osescanada.com Tree Saver Rating: 15,000 psi — I Wellbore schematic J 3C-08 Proposed CTG Schematic td' d28 H40 shoe Lo a18'MO 9-f t 35#155 shoe Q 5255' MD Rsand perfs Sew'-ag21 Mo 9938'- 9954• MD 2875' - 19604• MD E2d* Jb5 shoe Q! 256' MD 11 9.3R L-80 EVE Tubng to surface 3-1:2'x 1-1.2 MMGCamra gaslmandrels @2459, 5271'. Je77. 8179', 9,71 89626'MD. Sake Prerrier packer Q 9859 MD 3-1. "X-NCTis Q 9584' MD {261'3' min ID) Top of Tandem Wedge 9/ Ass @ 9916' ND 3-1-C X -r: r, 9p3?'An'-'I:'mio Top of Tandem Wedge 92 Ass C 9934' MO 3 -VZ, X4. `Z't.`r2.SIS min ID: Tubing tail Q 9965 MD __. - ___j Rams 610 MUM Lenum0 8Y1 Co f?61 luDea,ea 32116 m m Lerre BOns, ABM[ id7, 0.5t , - Kaez e Nipm 1751 23rd' ®set llner, ABWit i-0, ttyal' 2: Ball IX: Fra::;reYe fnSS i.'ld 1 zff ecce Lsxr. a€.?m. id]. V 13C..u,eEYE 1.563 11.61-15 23 a"Dr ,, 4ii�i�7, 1F -vE 1:35 IM3 238 &stir una, l5Mt L-03. 19 3..irS reeve SMW IJrer, 41.t% L-0. WT ine4 [rte 5md [ 3 m4y+1.f6v412,107 rm 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 Kuparuk Interval is approximately 313' TVD thick, with the top and base picked at 9,543' MD/6,307' TVDSS and 10,024' MD/6,620' TVDSS, respectively. The Kuparuk Interval is composed of fine-grained sandstones, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 0.65ppg. The overlying confining zone consists of greater than 349' TVD of Kalubik and HRZ mudstones. The fracture gradient for each of these zones is estimated to be 15ppg and 16ppg respectively. The top of the overlying confining zone is picked at 8,987' MD/5,958' TVDSS. The underlying confinement zone consist of approximately 520' TVD of mudstones comprising the Miluveach Shale. The estimated fracture gradient for the Miluveach Shale is 15-18ppg with fracture gradient increasing with depth. 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 the 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 one-half mile radius of the proposed wellbore tractor. Casing & Cement assessments for all wells that transect the confining zone 113-31: The 7" casing cement report on 1/24/1995 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 60 bbls of 15.8 ppg cement. The plug bumped, and the floats were checked and held. A/'c CET ru h 1R-33: The 7" casing cement report on 12/29/1994 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 73 bbls of 15.8 ppg cement. The plug bumped, and the floats were checked and held. 3C-09L1-01PB1: The 7" casing cement report for 3C-09 on 7/12/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 90 bbls class "G", 15.8 ppg, cement. The plug bumped, and the floats were checked and held. 3C-10AL1 and 3C-10AL1PB1: The 7" casing cement report for 3C-10 on 7/3/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 77- bbls of 15.8 ppg cement. The plug bumped, and the floats were checked and held. CET n 4J Ca yzs poor 6rmt --I-- 3K-18: The 7" casing cement report on 9/10/1986 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 100 Sxs of 12.0 ppg cement followed by 300 Sx s of 15.8 ppg cement. The plug bumped, and the floats were checked and held. UGNU SWPT 1: The well has been plugged and abandoned as of March 1993. The abandonment operation began with 205 Sx G cement around the bottom of the casing, 450 Sxs G cement thru DV at 3583', squeezed 250 Sxs G cement at 3491-3521', squeezed 50 Sxs G cement at 3109-3111', and squeezed 125 Sxs G cement at 3004-3093'. API Well Name status UsinB5lze Top of Cement (MD) Top of mpui Tagof Cement Determined By Reservoir it°Nse Zonallmlatbn Cement Operanonz Summary MeahankallMegMy Top Kupemk Oil Tap Kuparuk OBl .1 pa Pool (MD) ( Estimated based on cement MR 06/12/2016. Packer biown wlumesand Baker packer M 12304' (1/24/1995) Pumped 6D this of downlwle, but passed OMIT 500292253800 SR-31 Prod--Shot In )" 10121• 5262 Macubout Open hole for production RKB 15.8 PPG cement as deslgntd against lower packer 12013 6330 Baker Packer 915036' (12/29/1994) Pumped 73 this 500292252900 1R-33 IW-OMlne )" 1 10260 4752 CBL Open hre for Injection RKB of 15.8 PPG cement as designed MRIA05/14/2015-Passed 14]5] 6337 Baker Packerat9562' (7/24/1985) pumped 92 bbl' of 500292339000 K'Ni Prod-Shut In )" 9180 070 CET Open hole for Production RKB 15.8 PPG cement as designed MITIA 08/2212018-passed 9543 6307 31-09: ] 1 1985)SO bbb Open hole stuck BNA. Open hole duck BNA. Class W-me'(111 ppg) as 31-0)-MITI 08/111201]- 5002921355]3 3C U9 CRPBl MEND 2 318' ))20 62)3 CET INat In produNon. Not in remittent production. Passed 7589 6181 Enameled baed on anent Dner, 3C-1..(]/3/1985) 500232135660 3C-3"L1 PROD 231W wlumesand Pumped]] bbb of 15.0 PPG 3G104-TIFL and MROA I 7034• 53403036washout Liner Liner cementasdeslgned 07/18/2017 Passed 8120 6251 Estlnate based on cement Abandoned, 3010:(7/3/1985) wlumezand Open hole out lined. Not Open hale not lined. vamped 77 bbb of 15.8 PPG 3G10A-TIFi and MROA 5002921356]1 3C-1pAL1P81 E%PENO 23/8" ]034• 5340308 wuhout In Production. Not in production. mentasdesigned W/18/201]Passed U20 62511 (9/1011986) tamped 100 Sx of Umw Packer at 9405' 12.0 ppg cement followed by 500292164100 3K-18 INI )' 7480 5235 CB1 Open holeforin)ection RKB 300 Sat of 15.8 PPG as designed MBIA 05/10/2017-Passed 9115 6337 roan m of PBA wkM1 Cement casing 500292093400 WNU SWPfl UPLOR 103/4' N/A'• N/A-- CBL PBA rtainesat3015'RKB 2")450 G tam DV at 3503' N/A NA NA ' Uloulated depths coroemed to TV011 baud oa estimated 3M washout NO Cement 4 for lR-31 and no Remarkable top of cement for 3C -SOA In the LET.PVor era e✓' aH 3C -/C. " UGNU SWPT1 TO 93991 MD in Wert S*Ngnifil.elf, Bove the Kupemk zone of Interest on corresponds to top kuparuk formation n parent wellbore -, op corresponds to tpp kupamk formation n parent wellbore op conespoMz to top kupamk formation n parent wellbore D @ 3991 MD In West Sat svo�z�:<: ,bcr, Jrc s y $DoyRZJ3S5�•fao gG�D`1�-f-ZJI V1o;L ctr�{{ccl Top of API Well Name Status Casing Size Top of Cement Resenroir Status Zonal Isolation Cement Operations Cement Determined Summary Mechanical Integrity By MIT 06/12/2016. Packer (1/24/1995) Pumped 60 blown downhole, but 500292253800 1R-31 prod-Shut 7" Uncertain Open hole for Baker Packer at bbls of 15.8 PPG cement as passed OMIT against lower L production 12104'RKB designed packer (12/29/1994) Pumped 73 500292252900 1R-33 INJ- Onlin 7" Open hole for Baker Packerat bbls of 15.8 PPG cement as 10260 L injection 15036' RKB designed MITIA 05/14/2015- Passed �— (7/24/1985) Pumped 92 500292139000 3C-08 Prod -Shut 7" O le for Baker Packerat 9662' bbls of 15.8 PPG cement as 9180 CET ducti RKB designed MITIA 08/22/2018-Passed 3C-09:(7/12/1985) 90 bbls 500292135571 3C-09L1-01PB1 EXPEND 23/8" 7720 CET p&q G Aban Class"G"cement(15.8 3C-09- MITIA 08/03/2017- ne ppg)as designed Passed 1500292135660 V • C Liner, 3C-10: (7/3/1985) 3C-30AL3 PROD 23/8" Unce Pumped 77 bbls of 15.8 PPG 3C-30A- TIFL and MITOA ain C Liner Liner cement as designed 07/18/2017 Passed ' �1 C_ Abandoned, 3C-10: •V, (7/3/1985) Pumped 77 bbls 500292135671 3C-SOAL1P81 EXPEND 23/8" Unbertain ET P&A cement as 3C-30A-71FLand MITOA Abandoned dess �dG 8 07/18/2017 Passed ' (9/10/198 u ped 100Sx of 12.0 ppg ce t 500292164100 3K-18 INJ 7" Open hole for Camco Packerat followed by300Sx 15.8 7480 CBL injection 9405' RKB PPG as designed MITIA 05/10/2017- Passed loGNU 1) 205 Sx G Around bottom P&A with Cement of casing 500292091400 SWPTI EXPLOR 103/4" Uncertain CBL P&A retainer at 3015'RKB 2)450Gthru DV at 3583' N/A svo�z�:<: ,bcr, Jrc s y $DoyRZJ3S5�•fao gG�D`1�-f-ZJI V1o;L ctr�{{ccl SECTION 11— LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFIING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well and other subsurface information currently available that there are six mapped faults that transect the Kuparuk Interval and enter the confining zone (Kalubik and HRZ) within one half mile radius of the wellbore trajectory of the planned 3C-08 CTD wellbore. The three northwest -southeast trending faults and the two north -south trending faults around 3C-08 terminate within shales of the confining zone, and fault throw ranges between 15-140' (see table below). One mapped fault intersects the wellbore within the Kuparuk B2 shale and has a throw of 5'. This fault is not visible within the seismic data and is mapped based on stratigraphic thickness and well log correlation with surrounding wells. Fracture gradients within the confining zone will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining zone is discussed in Section 9. 3C-08 Area Faults Orientation Throw in Feet Fault#1 Northwest -Southeast 130-140' Fault#2 Northwest -Southeast 20-30' Fault #3 Northwest -Southeast 15-20' Fault #4 North-South 35-55' Fault #5 North-South 15 -Oct Fault #6 Unknown 5' Section 12 — Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) 3C-08 was completed in 1985 as producer in the Kuparuk A sand formation. The well was completed with 7" production casing and 3.5" tubing. The well will be drilled as a CTD single lateral with three frac sleeves and a perf pup at the toe. A multi -single stage frac will be pumped through the A -sand (3 stages through sleeves and 1 stage through the pert pup) with 225,000MIbs 20/40 Carbolite proppant and 25,000 Mlbs 20/40 Carbo Scale Guard proppant. Proposed Procedure: Halliburton Pumping Services: (C Sand 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 12 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1009 F seawater (approx. 4810 bbls are required for the treatment with breakdown, maximum pad, and 420 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,500 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 238 bbl breakdown stage (25# Hybor) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 15 BPM as quick as possible, pressure permitting. Increase annulus pressure to 2,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain [SIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 7,850 psi. Section 13 — Post -Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) K R U 3C-08 Stage Job Size (Ib) Top MD (ft) Top TVD (ft) Propped Half- length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 62500 12,700 6,645 420 50 0.368 2 62500 11,900 6,670 430 50 0.280 3 62500 11,100 6,645 430 50 0.279 4 62500 10,350 6,645 440 50 0.263 Disclaimer Notice: • This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips 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 CUSTOMER ConccOPhillips Alaska, Im. LEASE KRU 3CO8 FORMAMIN API 50029-21390 FD 051go!) 8.54 -" 39991144 SALES ORDER 1234567690 BHSTM 165 HA"Ho UNt9N - _ )675604 Trertment Interval s Stage Number 1-1 1-2 13 14 Fluid Descriptlon 250 bore 25pH orG 250 Linear Shut -In - Stage Description Load Well Mini -Fran FIuA Shut -In Proppant Descn Tion rograrg rop Conc 9) urry Rale ( m) 5 15 15 vressurel N an an Volume Wu 'e (a1) bb11 1,000 24 10000 238 2,000 48 urry Volu (bbij 24 238 48 rop Toh (W) age n e'. Time Time lhh:mm:u) (hh:mmss 51 0:15:5206 0:03:1013 004:46k0:46:35 3 psudavam ( 0 1.00 1.00 3.00 uIM food 0.80 0.80 LingdAdditives onwl„BvSP mnlmker t) c( t) 1.20 0.45 1.21] OAS 200 eeer rre(9pt) ra _ Gd (pt 25.00 25.00 25.00 N.uee (PO) 0.15 0.15 OAS OryAddtlues p N..ke. t) 2a0 2.00 2.00 p o mke. I pt/ 025 035 o.8 amav Dow) 2 o w 1-5 25pN bore Pad 1 5.3 1 DOI 15 ii'6,200 262 262 0:17:223 1.00 1.6 25pH bore Proan[Laden Fluid Wan1120/40+Carbo 5G 20/40 1.00 15 0.80 1.20 0.45 15.00 0.15 2.00 0.25 8#N bore Pm an[laden Fluitl Wan1120/40+Carbo SG 20/40 200 k250 349 149 6,250 0:10:2235 1.00 0.80 1.20 0.45 25.00 0.15 2.00 0.25 15 )000 16J i6] 14,000 0:1):0)13 1.00 0.80 1.2025.00 8#HborG Maram laden Fluitl WanIi 2040+ Carbo SG 20/40 3.00 35 6)50 161 161 20,250 0:12:1]5 0.15 2.00 0.35 19 25pH bore Pro ant Laden Fluid WanIi 20/40+<arbo SG 20/40 4.00 1.00 0.80 120 0.45 25.00 0.15 2.00 0.25 25#HborG 15 5,500 131 131 22,0013 0:10:195 1.00 0.80 1.20 0.45 8.00 Spacer&Oro Ball 15 1,000 24 24 0:01:355 0.15 2.00 0.25 2-1 2-1 25pH 4G Pad 1.00 0.00 1.20 OAS 25.00 0.15 200 0.25 2-2 25#H 15 13000 686 686 037+28 1:04:03 100 0.80 1.20 0.45 25.00 r bore prop MLatlen Fluid WanIi 20/40+Carbo 5G 20/40 1.00 15 6,250 143 149 6250 p.ls zpD 00x5 tees 2-3 25NHborG pro it Laden Fluid WanIi 2040+Carbo SG 20/40 2.00 15 0:10:22 0:46:35 1.00 0.80 1.20 0.45 25.00 0.15 100 0.25 24 254H bore )000 143 155 14,000 0:12:0) 0:36:13 1.00 0.00 1.20 0.45 25.00 0.35 m Proant Laden Fluid WanIi 20/40 Karbo 5G 2040 3.00 15 6)50 167 180 20,250 01211 034:05 2.00 0.25 2-5 MEHborG Propant Wden Fluid! Wang 2040+Carbo SG 20/40 AM 15 5,500 2.0 0.80 1.20 0.45 25.00 0.15 2.00 0.8 2-6 25#H borG 190 223 22 ODD 0:10.19 0:11:55 1.00 0.80 1.20 0.45 25.00 Satter &Dro Ball 15 2.000 ]90 232 00135 0:15 2.00 0.25 as 3-1 250 bore Pad 0:01:35 1.00 0.80 1.20 DA5 25.00 0.15 2.00 0.25 3-2 259H bore Pro 15 111000 262 262 0:17:20 1:04:03 1.00 0.80 1.20 DA5 25.00 0.15 2.00 ,. an[latlen Fluid WanIi 20/40+Carbo5G 2040 1.00 15 6,250 149 149 6,250 0:10:22 0:46:35 0.25 2 e 3-3 25#H bore Pmp an[laden Fluty Wang 2040+Carbo SG 20/40 2.00 15 7,000 ].00 0.00 120 0.45 25.00 0.15 2.00 0.8 e 3d 25pH bore 167 16] 14000 0:12:00 0:36:13 3.00 0.80 1.20 045 25.00 L Pro nt Laden Fluid Wan1120/40+Carbo SG 20/40 3.00 IS 6,750 161 161 20,250 0:12:11 0.15 2.00 0.25 3-5 250 HyborG Pro ant Laden Fluid Wang 20/40+Carbo SG 20/40 4.00 35 0:24:05 1.00 0.80 1.20 0.45 8.00 0.15 2.00 025 36 25#N bore 5 aoer&DroBall 5500 131 131 22,000 0:10:19 0:1155 1000 0.80 1.20 Oq5 25.00 0.15 2.00 0.25 4-1 25CHorG Pad 15 1,000 24 24 0:01:35 0:01:35 1.00 0.80 1020 0 .45 25 0.15 2000 ' 35 13OD0 262 262 D:1):28 1:06:28 3.00 0.80 3.20 0.45 .00 0.25 4-2 8#H bore Prp aM laden Fluid Wan120/40+Carbo $G 20/40 1.00 15 680 349 149 6350 25.00 0:35 2.00 0.25 4-3 259H borG Pront Laden Fluid Wang 2040+ Carbo SG 20/40 200 0:30:22 0:49:00 1.00 0.80 1.20 0.45 25.00 0.15 2.00 US 0.25 2 0 4.4 25pH horG 15 7,Op0 167 167 14000. 0:12:0) 0:38:38 1.00 0.80 1.20 OA$ 25.00 Proppanl Laden Fluid Wang 2040+Carbo5G 20/40 3.00 IS 6,750 161 363 30250 0:12:11 0.15 2.00 on £ ^ q-5 SMH bore Pro an[Iatlen Fluid Wan1120/40+Urbo SG 2040 4.00 036:30 1.00 0.80 1.20 pA5 25.00 0.15 2000 0.25 4-6 25# Linear 15 5,500 131 131 22,000 0:10:19 0:14:19 ].00 0.80 1.20 0.45 25.00 0.15 4-) Freeu ProteR FImrh Freeze Protect 15 35 1663 BAD 40 20 40 20 0:02:40 0:01:20 0:04:00 00130 100 1000.00 25.00 0.15 x000 200 0.25 0.25 0.25 0.50 164521 6,810 4,926 250.000 gA2o25 Prpppant Type Ign Total(Ibs) Wanli20/40 225,000 Carbo SraleGuaM 25,000 / Initial Max Accift"e Rate Min Add it. Rate Lodurt3000 MO -6) CLQ2 UC CL -31 LVF -200 WG -36 BE6 OptiFio-ill OptliFlo-0 Sp I".(pm IOMn (pmf (mam) ppm ppm ppm pm m 0.6 0.5 0.8 0 3 630.0 18.9 0.1 1.3 0.2 0.3 0.2 0.2 D.2 0.1 1 210.0 1 5.3 1 DOI 0.4 1 0.10.1 Z X '� / Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 2019-12-19 State: Alaska County: BBIeM1e POiOt APINumber. 5002921390 NORTHSLOPE. Operator Name: ESUS Well Name and Number. KRU 3C-09 Lan9itude: -148.7] Latitude: 70.4 Long&.t ProjecBon: IndlanlPederel: none Production Ty,ba, True Vertical Depth (Ttn): 0 Total Water Volume (gal': 163,]38 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient ingredient Trade Name Supplier Purpose di Ingreents Service Concentration in Additive Concentration in Ingredibs ent Mash Number l Comments Company Flret Name Lest Name Email Phone (OAS (% by mass)`" HF Fluid (%by Sea Water O fetor Base Fluid Water ]]32-155 masa " BE6 96.00% 00.66019- 1342396 Density=8.540 MICROBIOCIDE Hallibunon eiocitle Listed Below Listetl Below 0 C622 UC Halliburron Crosslinker Usletl Below Listed Below NA C 0 NA LROSSLINNER Hallburion Cresslinker Listed Below Listed BNow g LOSURF-3001) HalliWnon Non-ionic Surfactant Listed Below Listed Below NA M067 Hallibudon H Control Additive -IT Below Listed Below 0 NA OPTIFLO-II 0 NA DELAYED RELEASE Halliburton Breaker Listed Below Listetl Below BREAKER 0 NA O-111 D EiLAY DELAYED RELEASE Hallibunon Breaker Listed Below Listed Below BREAKER g Kbk SP BREAKER Hellihunon Breaker Listed Below Listetl Below WG GELLING 0 NA AGENT Hallibudon Gelling Agent Listed! Below Listed Below ScaleGuard II CSrboCeam Additive Listetl at. Listed Below 0 NA 0 NA LVr-200 Penrew Additive Listetl Below Ustetl Below xinmi Wanli 0 NA 20/40 Wendt Industry Develepmen Additive Listed Below Listed Below t Co. Litl g NA In radiants Listed Above 1,$4 TnmdM1 Ibemene 9563£ 1.008 0.000]98 13 2-Bmmo-2-nitro-1,3- neanedici 52-51-] 100.00% 0.00074% 25 Denise Tuck, Hallibudon, 3000 Acrylate polymer Propdetury 1.008 0.00136% 23 N. Sam Houston Denise Tuck® Pk" E. Houston. Hallibunon Denise Tuck Hatlibulon.co 281-871-6226 Tx ]]032,281- m 8]1-6226 Amrronlum ersullafe 772]-54-0 0.022178 369 Borate salts Proprietary 0.00133% 1354 Oanise.Tuck@ Hallibunon Dart. Tuck HaNibuton.co 281-871-6226 Ceramc Materials end wares, m chemicals 66402154 1.276058 21250 Confidential buffer t Trade Sevet E 0.03004% 500 Larbo Iacamocaremi281- Ceramics Jason Genevan cs 921-6472 os.tvm Confidential buffer 2 TfOtle $etrof 0.003008 51 Carbo Ceramics Jason Goodwin Ocarg000tan 281-921-6472 ne--eeremi u.oam Corundu ial scale inM1ibiler Trade Serret 0.16.22& 2500 Carbo Iasonffoomn Ceramiu Jason Goodwin cswr booefami 281-921-6472 Corundum 1302-745 ].935]99 123]5106'com C sialine silica uar 14808.80-7 30.0Da 0.90629* 10] Cured acrylic issue Proprietary - 30.00* 0.00665% 112 Denise.Tuck® Halliburton Denise Tuck Halliburton.co 281-871.6226 Ethanol 64-17-5 60.00% 0.04446% ]40 m Guar um 9000.30-0 10D.D08 0.24600% 4095 Hea aromatic etrokumna htha 64742-94-5 30.00% 0.02223% 3]0 drobeated Distillate,O ht..C9-16 6474247-8 100.008 0.34047% 5605 Mullite 1302-93-8 45.00% 6.08383% 101250 No hthalene 91-20.3 5. DO% 0.003]1% 62 Oglared phenolic resin Proprietary 3o. ooa o.0296ge 494 Halliburton Denise Tuck HafliF-Trurlon w� 261-8710226 P.k(ory-1,2cihanedry0, alpha-(4 nonylphenyl)omega-hydroxy-, 12108]46]-0 brunched 5.OD% 0.003718 62 m Potassium formals 590-2&4 60.00% 0.08133% 1354 Potassium droxide 1310-58-3 5.0080.00236% 40 Potassium in 13]09.949 60.008 0.02832% 412 Semi-permeable waeng Trade Secret 5. CD8 0.07511% 1250 Carbo lason.gsodeen Cosmetics Jason Goodwin ®carboceami 261-B21-fi4]2 Sodium carbo in Icellulose 900432-4 Sodium chloride ]64]-145 1.00% 4.008 0.00136% 3.363018 23 55910 cs.cem Sodium collate 203632-0 1.00% 0.00136* 23 Sodiumhdroxide 1310.732 3D.DD% 0.02450% 408 Sodium ersulale17]5.2]-1 100.00% 0.000108 3 Sodium sulfate 7757-82.8 0.loe O. Da 0008 1 Water ]]32-165 100.00* p. 150674 2509 • Total Water Volume sources may include fresh water, produced water, another 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 suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content ofthe MSDS should be directed to the supplierwho provitle0 it. The Occupational Safety and Health Administadon's (OSHA) regulations govern the criteria for the disclosure of this Information. Please note that Federal Law protects "proprietary", 'Veda secret", and "confidential business information" and the criteria for how this information is reparted! on an MSDS is sub'ect W 29 CFR 1910.1200 and A endix D. ADL025629 3C ADL025628 1R ADL025634 ADL025635 OO Cali Well Pad Frac Points Well Trajectory ConocoPhillips Open Interval Alaska Q 1/2 Mile Frac Point Radius N Q 112 Mile Well Trajectory Radius 3C -08A Faults within Frac Point Radius Fault Analysis MENEZZ31111100= Miles Wells within Frac Point Radius 9/20/2018 0 0.1 0.2 0.3 0.4 0 CPAI Lease 1, �J! di-� 177777777777—, 0 e-' ConocoPhillips Alaska 3C -08A Lease Plat ADL025629 9/20/2018 A a m' o z'z CIA -. N --- iMiles 0 0.1 0.2 0.3 0.4 Ci n ADL025628 1R ADL025635 OO CO,Well Pad • Frac Points — Well Trajectory Open Interval C31/2 Mile Frac Point Radius Q 1/2 Mile Well Trajectory Radius — Wells within Trajectory Radius CPAI Lease Loepp, Victoria T (DOA) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Victoria, Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Friday, January 4, 2019 3:27 PM Loepp, Victoria T (DOA) Davies, Stephen F (DOA); Wallace, Chris D (DOA); Buck, Brian R FW: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation KRU 1 R -31/3C-10 Cement Eval 1R-31 1-24-1995 Daily Drilling Report.pdf; 1001397029_3C-10.TIF Fallow up Flagged Thanks for your email. I've included a copy of drilling report for 113-31 and the log for 3C-10 per your request. There is no log available for 113-31 - the casing depth and bit size was used to calculate a theoretical TOC. SLB Log Analyst Comments for 3C-10: \ 1 • CET log is a predecessor to the current USIT, it is a circumferential ultra -sonic measurement. • Seems like there are some solids in the entire logged interval but not necessarily connected. • Looks like a wide channel across most of the logged interval, 8700'-8750'— shows fuller coverage. • At 8500'-8515' there is a mostly free zone which correlates with a drop in GR. Our plan is to have manned monitoring (IA and OA) for IR -31 and 3C-10 during frac operations. IR -31 is currently shut-in, 3C-10 will be shut-in 2 days prior to frac and monitored on the day of frac. F_, Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 4, 2019 2:37 PM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation KRU 1R -31/3C-10 Cement Eval Sandeep, Thank you for the additional information. Could you please provide a snapshot of the relevant section of the cement log and/or the cement job summary for KRU 3C-10 and 1R-31. Also, please provide the log analyst's comments. Please outline any risk mitigation measures that will taken during the frac job such as manned IA/OA monitoring of these wells. I understand the frac is tentatively planned for 1/10/19 so please expedite this information to me, 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 LoePP@alaska 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 You, contact Victoria Loepp of (907)793-1247 or Vicuna LOeD »(4alaska aov is aware of the mistaken sending it to From: Pedam, Sandeep <Sandeeo Pedam@conocoohillios com> Sent: Thursday, January 3, 2019 11:49 AM To: Loepp, Victoria T (DOA) <victoria I0epp@alaska F;ov> Subject: RE: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation Victoria, Happy New Year! Please find the requested information attached. I wanted to clarify that we didn't see high quality cement in the 3C-10 parent bore and 113-31's cement tops were calculated. However, we plan to monitor these wells and shut -down in the event we see communication. Please let me know if you need anything else. Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep Pedam@Conocoohillios com From: Loepp, Victoria T (DOA) <victoria loeoo@alaska eov> Sent: Monday, December 31, 2018 11:26 AM To: Pedam, Sandeep <Sandeep.Pedam(a@conocoohillios com> Subject: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation Sandeep, In Section 10, the casing and cementing assessments of wells within''/: mile radius of the fracturing interval, please update the table to provide the following: 1. TOC estimate(calculated) for the intermediate casing for wells that have the TOC listed as "uncertain" in both MD and TVDss. This calculation may include a 30% washout. 2. TOC estimate in TVDss for the intermediate casing for wells in which a cement evaluation log was run 3. Top of the oil pool in both MD and TVDss for all wells listed 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. Loeoo(a7alaska.00v CONFIDENTIAMY 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 of (907)7931247 or Victoria.Loeoo@alasko.gov IADC -API OFFICIAL DAILY DRILLING REPORT FORM 19T INrcImIANI AxuwNn p( wnliq ('emr.ur[IM1 FORM 2T-5 APPROVED APPROVED PRINTED IN U.S.A. DEQ OP A - COLYTRACTOR / 2 SIGNATURE OF-O-PEERRAAT 5 REPRESENTATIVE S ATTUUR OF CONTRACTOR' )OL PUSHER { `IP pP. Slif 4./Ft. 4q.NE TOOL JT o.6 TVPE TNREnO STRING N0. P MD. PUMP FACjPRESSUR.E TYPE �fTHE •�-3 co 1 aU la" I JWE DISTRIBUTION - HOURS NO. DRILLING ASSEMBLY PIT RECORD LSIID RECORD IM.d AAlrwl "MF-MERI.TION NIGHT DAY FIT FT. E I O I RIO UP AND -TEAR — -- DONN — --. - FT. SIZE GNT D, I DRILL AtiuLL OD IADC CODE DIE6 P�i� 1 REAWNO -- OO FT. MFG. VISCSEC u a WANG PV/YP OD FT. TYPESGRCULgE S CONpT10N MUD ( SEA NO. 6 TRIPS OD FT. GELS j YP NETS 1/12" /IFA u,2 L LUINNUTE RIG OD RT. 4L {C'S 1 •.E/ i RFPR PIG REPAIR q N� OUT OFF 9' DRILLING LINE DFslii O(n yj(IDS f J ID DEVIATION "VEY DEFITI IN N� It. YFRE LINE LOGS TOTAL M. STANDS CP FT. r41p 6 QIFYICYS ADDED L IL RIMCAMNG6CEMENT jIDTAL HAS TYPE T. TYPE 4R. LNGLES OF FT. CUTTING TRULTURE ISNAITONCEMENT INNER OUTER OULLO.Al LOCATION Il NIPLP 6QP. KELLY DONN FT. ' 3 J a BEARINGS/ OTHER REASON SEALS GAGE DULL GULLED M TEST 6MR. TOTAL FT. .NAR 1 ' 8 U. DRILL STEM TEST YIT. OF STRING LBS li PLUG &AIX REMARKS t u. LL SQUEEZE CEMENT 19. FISHING M MIL NORK 1 y 2T" _ DRILLER IIS 91 NO. DRILLING ASSEMBLY IAr nitl.l wul BIT RECORD - MUD RECORD - A PERF'q'TIN BIT FT.Rrr NO, TINE i 'D 6 TBG TRIPS O C TREATING SIZE HEIGHT DAR D. $MABBIW W IADC CODE PRESSURE LL.. O FT IIA GDIdT �V? E. TESTING MFG. (j O T --- U U F. ADgT'N'L TYPE FT PV/Y,, G O FT SER NO. GELS -7 (� FT TENS wr TOTALS ^L /IFA U12 RL PH pAY WORK TINE SUWNARY (OFFICE IbE OwDEFM DUI' MRS N/CONTR D.P. DEPI77 IN SOLIDS R 1 F MRS v/OPIL MP. STANDS W FT.7'O'['AL TOTAL FIG. HRS TYPE MW t EMICALS ADDED MET. TYPE IML MIS RD/OP HRS STANDBY SINGLES DP FL CUTTING STRUCTURE INNER OUTER DULL CHAR LOCATION ^ 1 'LJj 111 93 KELLY DORN FT 1 E D A BEARINGS/ OTHER REASON K 4 0 TOTAL FT SEAl6 GAGE DULL PULLED CHAR. S S & 44 q Mf. OF STRING LIST 3 _ P = P&I"P HPIOD RdARKDMD TOTAL DAY WORK a DF SIP UNIALATIOTATITATING Hill. WAL MIR, CRIT DR l IADC -API OFFICIAL DAILY DRILLING REPORT FORM 19T INrcImIANI AxuwNn p( wnliq ('emr.ur[IM1 FORM 2T-5 APPROVED APPROVED PRINTED IN U.S.A. i ,,,,,TION .RECORD CODE HD. DETAILS Of OPEgATIOP6IN SFpUMERS 1 FOOTAGE TO I olio REt on WR6 DEVIATION RECORD FORMATION DMD* CORE RECOVERY) Y E O fZIDE 110 DETAILS OF DPEMipM IR SEDUEMCE AIq RERWOLS SO U. I PRESS PUMP N0. PRP D LINER SP.M %a L11�R it --�i Son 1 E/Z 2 1 cT ba ztoa r 2 "/a J30P IADC- AN OFFICIAL DAILY DRIPLUNG REPORT FC APPROVED APPROVED No. 51.1J t • 1 • a RURF MIRE LINE RECORE Y Plo 3 L LLE RT.AtlS n0. MMS FEET 31Z --� QM IRS. 3E1 AT � � - LInES IT,YI FO ENT i L Q cAR� � nER �TTRIn RTS cVr - -- _ CUERAATIVE — --.— - - TCM MI. OR TRIPE FDD7AGESIR-, xRE FORMATION TD ODIIL. IEPIDPICORt RECOVER 91TR PUMP PIM PRS PUWPEE ,,SW qM 1000. PRESS RR S R� SP.N ,,,,,TION .RECORD CODE HD. DETAILS Of OPEgATIOP6IN SFpUMERS 1 FOOTAGE TO I olio REt on WR6 DEVIATION RECORD FORMATION DMD* CORE RECOVERY) Y E O fZIDE 110 DETAILS OF DPEMipM IR SEDUEMCE AIq RERWOLS SO U. I PRESS PUMP N0. PRP D LINER SP.M %a L11�R it --�i Son 1 E/Z 2 1 cT ba ztoa r 2 "/a J30P IADC- AN OFFICIAL DAILY DRIPLUNG REPORT FC APPROVED APPROVED No. Davies, Stephen F (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Monday, December 31, 2018 12:03 PM To: Davies, Stephen F (DOA) Cc: Herring, Keith E Subject: FW: Final tally for 3C -08A Steve, Please see final tally for 3C-08 listed below. Please let me know if you need anything else. Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Monday, December 31, 2018 6:17 AM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Subject: Final tally for 3C -08A Sandeep, Below is the final tally for 3C -08A. If you have questions please let me know. 12247.1 V/ X-08 Slotted Lifter Well: 3C -08A Enter Bo eOi mPhillips Kiserl Klein Date: 1213012016 Depth of E Aw", Ire. Rig: CDR3-AC Depth (the Set D Tallied Piping Jt Number Num of Jts Well Equipment Description and Comments Page 1 Length Tops Slotted Liner- i 'Casing' OF Slotted L 00 Nominal' ID Size 10' Seal Bore Deployment Sleeve 2.70" 00, 2.25" Polished Bore 10.29 9830.6 As72to72 1Jts _/S Blani, liner, � E#Jft, L -S0, Hyd E'11 30.93 9840.93 PoundsPe R Profile nipple (1.781'Bore, 2.70" OC) 1.08 9871.86 Jts 49 to 71 23Jts 2-2J5 Blank liner, 4.E#M. L -SO, Hyd N1 727.76 9872.94 Grad* 2-2!K' Frac Sleeve Pup, 4.6#fft, 1-40, Hyd 511 9.82 10600.70 #3. Ball drop fracsleeve, 1D 1.656" -Ball OD 1.718" 2.33 10610.52 Top Connectc 2-'-!S" Frac Sleeve Pup,4.6#!ft, L-80, Hyd 511 9.81 10612.85 2-318" Space out pup, 46#1ft, L-80, Hyd 511 -9.84" 9.84 10622.66 Top Connectc As 36 to 48 13 Jts 2-3;5" Blank liner, 4.6#1ft, L -SO, Hvd Ell 410.60 10632.50 2-318" Frac Sleeve Pup, 4.Mft, L-80, Hyd 511 9.88 11043.10 Bottom Connec #2: Ball drop frac sleeve, ID 1.563" - Ball OD 1.625" 2.33 11052.98 2-318" Free Sleeve Pup, 4.6#/ft, L-80, Hyd 511 9.81 11055.31 Bottom Connec 2-318" Space out pup, 4.6#1ft, L-80, Hyd 511 - 5.80' 5.80 11065.12 Jts29to35 7Jts 2--'_:8" Blank liner, 46t)fl, L -SO, Hyd E11 221.38 11070.92 Drift 2-315" Frac Sleeve Pup, 4.6Wft, L-80, Hyd 511 9.79 11292.30 #1: Ball drop fracsleeve, ID 1.438" -'Ball OD 1.500" 2.32 11302.09 Max OD Si; 2-318" Frac Sleeve Pup, 4.6#/ft, L-80, Hyd 511 9.83 11304.41 2-318" Space out pup, 4.P#/ft, L-80, Hyd 511 - 9.86'+8.04' 15.30 11314.24 ICON Jts7to 26 221,u 2--1?8 Blant. liner, <.c'»lft L -SSA. Hyd E11 697.15 11330.14 Liner -slc Perf Joint (0.281", 3 SP7 BC') 29.84 12027.29 Enter value! Jtst[o6 6Jts 2-'? Elanl:liner ,-.cd.: ft, L -S0. Hyd E11 183.43 12057.13 to match your SL Aluminum ported bull nose. 1,00" ID, 1.375" Ball OC .44 12246.56 12247.00 12247.00 See belc- Approved try Keith Herring 12/30/18 12247.00 Liner Bl: Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO - 664 Keith. E. Herring(n�cmxwoph i I I i ps.com ConocoPhillips Alaska Davies, Stephen F (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Thursday, December 27, 2018 12:17 PM To: Davies, Stephen F (DOA) Subject: Re: [EXTERNAL]RE: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Attachments: well_3C_08A_fault_analysis_20181227.pdf Steve, Please find the revised copy of the fault map attached. Expected fracture azimuth: "Between N25W and N30W". Please let me know if you need anything else. Regards, Sandeep Get Outlook for Android From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Wednesday, December 26, 2018 11:16:54 PM To: Pedam, Sandeep Subject: RE: [EXTERNAL]RE: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Sandeep, CPAI's application does not provide any means of linking the fault descriptions shown in the table within Section 11 with the fault traces shown on the Fault Analysis map. Could you please provide a revised copy of that map displaying each fault trace annotated with fault number, vertical displacement, and indicating the downthrown fault block? What is the likely azimuth of the induced fractures? Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesalaska.gov. From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Wednesday, December 26, 2018 9:22 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Steve, Thank you speaking with me this morning. Just wanted to let you know that we double checked and the 1 R-32 well doesn't fall under the '/� mile radius. Also, 3C-091-1-01 was not drilled and hence we don't have any data for this well. Hope you have a great day and Merry Christmas! Regards, Sandeep From: Davies, Stephen F (DOA) <steve.daviesCd alaska.00v> Sent: Friday, December 21, 2018 4:00 PM To: Pedam, Sandeep <Sandeep.Pedamoconocophillips.com> Subject: [EXTERNAL)RE: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Sandeep, For the''Y2-mile radius Area of Review surrounding the fracturing interval within KRU 3C -08A, shouldn't wells KRU 1 R-32 and KRU 3C-091-1-01 also be included? If so, please update the text and Zonal Isolation table in Section 10 of the supporting documentation. Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies(G-),alaska.00v. From: Davies, Stephen F (DOA) Sent: Friday, December 21, 2018 11:27 AM To: 'sandeep.pedam@conocophillips.com' <Sandeep.pedama-conocophillips.com> Subject: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Sandeep, I'm reviewing CPAI's application to fracture stimulate well KRU 3C-08, and I'm a bit confused. I notice that the application form and the Affidavit that CPAI submitted is for well 3C-08, but the lease map and application cover letter depict and reference 3C -08A. Has 3C -08A been drilled? If so, CPAI has not yet submitted a Well Completion Report and well log data for 3C -08A. Wasn't the completion for 3C -08A designed to isolate the few A -sand perforations that lie above the whipstock that was set in 3C-08? If all of the Kuparuk perforations within 3C-08 are isolated, 3C-08 is classified as abandoned, and Sundry Application form and the Affidavit should be changed and resubmitted as an application to fracture stimulate 3C -08A. Or have I overlooked something? Please provide additional information. Thank you, Steve Davies Senior Petroleum Geologist AOGCC 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 ur forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(a)alaska gov. 2 I Fault #1 ( ADL025629 Fault #4 11 3C 00( ADL025634 ConocoPhillips C- ADL025628 3�0� 32+ Fault #2 zs 30 �9� 36....E " 23 24� 20 44 ault #6 o 75 2 ault #3 7 z �� i5 EZ4 Fault#5 20 A 1 w W LLJ 9 N 13 Alaska 3C -08A N Fault Analysis Miles y 0 0.1 0.2 0.3 0.4 0.5 12/27/2018 oocsulsri Papa G GiS Fro S Cr,sp,,EuoPor o 1d ADL026635 �= Well Pad Frac Points — Well Trajectory Open Interval C31/2 Mile Frac Point Radius C31/2 Mile Well Trajectory Radius Faults within Frac Point Radius — Wells within Frac Point Radius i� CPAI Lease Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, December 26, 2018 3:07 PM To: sandeep.pedam@conocophillips.com' Subject: KRU 3C -08A (PTD 2181610) Sundry 318-574 Fracture Stimulation Additional Information Required Sandeep, We are reviewing the frac sundry request and it mentions a new frac chemical ScaleGuard II from Carbo Ceramics that I do not recall seeing before. It also looks like Carbo Ceramics is claiming the CAS number as Trade Secret. Please provide the MSDS and ensure that the full CAS number components are visible. If this is a proprietary (trade secret confidential) please let me know and get with the provider and submit the disclosure of the CAS numbers as per AOGCC regulation 20 AAC 25.283(k). Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7`^ Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallacernlalaska.eov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. Davies, Stephen F (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Wednesday, December 26, 2018 9:22 AM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]RE: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Steve, Thank you speaking with me this morning. Just wanted to let you know that we double checked and the 1R-32 well doesn't fall under the %: mile radius. Also, 3C-091-1-01 was not drilled and hence we don't have any data for this well. Hope you have a great day and Merry Christmas! Regards, Sandeep From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Friday, December 21, 2018 4:00 PM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Sandeep, For the %2 -mile radius Area of Review surrounding the fracturing interval within KRU 3C -08A, shouldn't wells KRU 111-32 and KRU 3C-091-1-01 also be included? If so, please update the text and Zonal Isolation table in Section 10 of the supporting documentation. Thank you, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesrvlalaska.gov. From: Davies, Stephen F (DOA) Sent: Friday, December 21, 2018 11:27 AM To: 'sandeep.pedam@conocophillips.com' <Sandeep.pedam@conocophillips.com> Subject: KRU 3C-08 (PTD 185-155; Sundry 318-574) - Question Sandeep, I'm reviewing CPAI's application to fracture stimulate well KRU 3C-08, and I'm a bit confused. I notice that the application form and the Affidavit that CPAI submitted is for well 3C-08, but the lease map and application cover letter depict and reference 3C -08A. Has 3C -08A been drilled? If so, CPAI has not yet submitted a Well Completion Report and well log data for 3C -08A. Wasn't the completion for 3C -08A designed to isolate the few A -sand perforations that lie above the whipstock that was set in 3C-08? If all of the Kuparuk perforations within 3C-08 are isolated, 3C-08 is classified as abandoned, and Sundry Application form and the Affidavit should be changed and resubmitted as an application to fracture stimulate 3C -08A. Or have I overlooked something? Please provide additional information. Thank you, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesCDalaska.gov. 20 AAC 25.283 Hydraulic Fracturing Application — Checklist KRU 3C -08A (PTD No. 218-161; Sundry No. 318-574) Paragraph Sub -Paragraph Section Complete? (a) Application for I(a)(1) Affidavit I Sundry Approval (a)(2) Plat (a)(2)(A) Well location (a)(2)(B) Each water well within M mile I (a)(2)(C) Identify all well types within I mile (a)(3) Freshwater aquifers: geological name; measured and true vertical depth Provided with application. Provided with application. SFD 12/21/2018 Provided on map accompanying application. Surface location lies in Section 14, T12N, R9E, UM. The well passes through Sections 11 and 12 of T12N, R9E, UM, and the SFD fracturing interval lies within Section 12 of T12N, R9E, UM 12/21/2018 and Section 7 of T12N, R10E. UM. TD of the well lies in Section 7 of T12N, R10E. UM. Provided with application: No wells are used for drinking water purposes are known to lie within %: mile of the surface location of KRU 3C -08A. According to the Water Estate map available through DNR's Alaska Mapper SFD application (accessed online December 21, 2018), there are 12/21/2018 no water rights within 4 miles of the surface location of, and fracturing interval within, KRU 3C -08A. There are currently 39 oil -related wells that lie within''/: mile of the KRU 3C -08A path. (See the 34C -08A Lease Plat accompanying the application.) There are 10 wells and wellbores within %: mile of the planned fracturing interval: five are P&A'd (Ugnu SWPT 1, 3C-09 L1-01, SFD 3C-09 1-1-01P131, 3C-10AL1PB1, and 3C-08), and the others 12/21/2018 are active producers or injectors (3C-10AL1, 3K-18, 111-31, 111-32, and 1R-33; see map accompanying application). Freshwater aquifers within the area % mile beyond and lying directly below the Kuparuk River Unit are exempt per Federal Regulation 40 CFR 147.102(b)(3). For an outline of SFD the Area, see the EPA's "Alaska Oil & Gas Aquifer 12/21/2018 Exemptions Interactive Man" available online under the AOGCC Page 1 January 8, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist KRU 3C -08A (PTD No. 218-161; Sundry No. 318-574) Paragraph Sub -Paragraph Section Complete? AOGCC Page 2 January 8, 2019 "Permits" section of EPA Region 10's web page at https://www.epa.gov/uic/underground-in*ection-control region-10-ak-id-or-a nd-wa. (a)(4) Baseline water sampling plan None required. SFD 12/21/2018 _ Provided with application. See the attached schematic for (a)(5) Casing and cementing information CDW As -Built casing and cementing_ information. The 9 5/8" surface casing was cemented with 543 bbls AS 12/26/2018 III and 70 bbl Class G. The 7" intermediate casing - CPAI (a)(6) Casing and cementing operation CDW indicates top of cement at 9180'MD with the sidetrack KOP assessment 12/26/2018 9941 ft. 3.5" uncemented tubing with frac sleeve and perf joint in production hole. (o)(6)(A) Casing cemented below No freshwater aquifers present (see Section (a)(3), above). lowermost freshwater aquifer and Surface casing set at 5,206' MD (3,732' TVD, -3,650' TVDSS) SFD conforms to 20 AAC 25.030 and cemented to surface. 12/21/2018 Yes. Surface casing is set and cemented to surface. Intermediate hole is cased with 7" pipe with the estimated (a)(6)(B) Each hydrocarbon zone is top of cement at 7,050 MD (about -4,758' TVDSS), which SFD isolated covers the K-3 sand (contains poor -quality hydrocarbon shows in nearby wells Moraine 1 and Colville Delta 3) and 12/21/2018 is about 1,300 true vertical feet above the top of the target Moraine sands. (a)(7) Pressure test. information and Provided with application. 9 5/8" tested to 1800 psi. 7" rig pressure -test plans for casing and tubing installed in well tested to 2000 psi, and 2750 psi. A 2750 psi plan to pre- frac test. tubing tested to 7000 psi, and planned to 6150 CDW 12/26/2018 psi. Provided with application. 15K psi treesaver, pump trips at CDW (a)(8) Pressure ratings and schematics: L wellbore wellhead, BOPE, treating head 8050 and PRV at 8550 psi. - 12/26/2018 AOGCC Page 2 January 8, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist KRU 3C -08A (PTD No. 218-161; Sundry No. 318-574) Paragraph Sub -Paragraph Section Complete? AOGCC Page 3 January 8, 2019 Upper confining zones: over 1,000' of mudstone and siltstorie assigned to the Kuparuk D, Kalubik, HRZ, Hue (a)(9)(A) Fracturing and confining zones: Shale, and the lower Colville. Fracture gradient expected to lithologic description for each zone be about 0.82 psi/ft. (o)(9)(8) Geological name of each zone Fracturing Zone: Kuparuk A -Sand reservoir from about 10,006' MD to the total depth of the well (12,246' MD), a (0)(9)(C) and (a)(9)(D) Measured and true true vertical thickness of about 25'. The vertical height of SFD vertical depths the induced fractures is expected to be about 50', and the 1/7/2019 fracture gradient is expected to be about 0.65 to 0.70 (a)(9)(E) Fracture pressure for each zone psi/ft. Lower confining zones: Miluveach and Kingak Shale totaling many hundreds of feet in thickness. Fracture gradient expected to be about 0.78 to 0.93 psi/ft. (a)(10) Location, orientation, report on Eight wells with wellbores are within''/: mile of the planned VTL mechanical condition of each well fracturing interval. 1/8/19 The wells are identified and cementing and TOC estimates (o)(10 cont) Sufficient information to are provided. Poor cement is indicated in 3C-10 based on determine wells will not interfere with CET run. The fracture half length is -420'. 3C-10 wellbore VTL TL containment within 3: mile is over 1500' from 3C-08. This well will be shut in during 1/ 8/19 the frac and monitored on the day of the frac. Operator -provided structure map indicates five faults are (a)(11) Faults and fractures, location, located within the Area of Review. The nearest fault lies orientation about 900' southwest of the westernmost fracture point in 3C -08A. This northwest trending fault has 10' to 50' of (oJ(11) Faults and fractures, Sufficient vertical displacement. The maximum modeled half-length SFD 1 information to determine no interference of the induced fractures is about 440', and the expected 1/7/2019 with containment within % mile direction of the induced fractures is along an azimuth of about N 30 W, which is subparallel to the nearest fault. Accordingly, it is highly unlikely that any of the known AOGCC Page 3 January 8, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist KRU 3C -08A (PTD No. 218-161; Sundry No. 318-574) Paragraph Sub -Paragraph section Complete? AOGCC Page 4 January 8, 2019 nearby faults will interfere with containment of the fracturing fluids. (a)(12) Proposed program for fracturing Provided with application. CDW operation 12/26/2018 Provided with application. 4909 bbl total dirty vol. CDW (a)(12)(A) Estimated volume excluding 15 bbl freeze protect, 250,000 pound proppant— 12/26/2018 4 intervals, 3 using frac sleeves, 1 through the perf pup. (a)(12)(B) Additives: names, purposes, Provided with application. CDW concentrations 12/26/2018 Provided with application. Halliburton /Carbo Ceramics CDW (a)(12)(C) Chemical name and CAS number chemical trade secret submission was received 1/2/2019. 1/7/2019 of each Halliburton proprietary products were previously provided to AOGCC under confidentiality provisions. (a)(12)(D) Inert substances, weight or Provided with application. CDW volume of each (a)(12)(E) Maximum treating pressure with Max. 7850 psi estimated treating pressure. Max pressure _1_2/26/2018 CDW supporting info to determine is 8550 psi to (Pump shutdown). With 2500 psi back 12/26/2018 appropriateness for program pressure on IA, max tubing differential should be 5350 psi. Provided with revised supporting documentation. The anticipated half -lengths of the induced fractures range from 420' to 440' according to the Operator's computer simulation. Computer simulation indicates the anticipated (a)(12)(F) Fractures — height length, MD heights of the induced fractures are about 50' for each of and ND to top, description of fracturing the planned fracture stages, so the induced fracture will SFD model likely penetrate nearly through Kuparuk A -Sand reservoir 12/26/2018 and into, but certainly not through, the overlying mudstone and siltstone confining layers. Similarly, the thick mudstone and siltstone intervals of the Lower Kuparuk, Miluveach Shale and Kingak Shale will prevent injected fluids from migrating out of the injection interval. AOGCC Page 4 January 8, 2019 Paragraph 20 AAC 25.283 Hydraulic Fracturing Application — Checklist KRU 3C -08A (PTD No. 218-161; Sundry No. 318-574) Sub -Paragraph Section Complete? AOGCC Page 5 January 8, 2019 (a)(13) Proposed program for post- Provided with application. Both Class 1 and II disposal CDW fracturing well cleanup and fluid recovery available in KRU. 12/26/2018 (b)Testing of casing or intermediate Tested >110% of max anticipated pressure 2500 psi back pressure, plan to test to 2750 psi with a PRV CDW 12/26/2018 casing set at 2600 psi. (c) Fracturing string (c)(1) Packer >I00' below TOC of 4.5" liner hanger set in 7 5/8" casing with packer set at production or intermediate casing 13569' and cement estimated at 8270 ft (3830' ND). tubing to be pressure tested to 6150 psi. 2500 psi CDW (c)(2) Tested >110% of max anticipated backpressure planned. Max treating pressure of 7850 psi 12/26/2018 pressure differential would require testing to 5885 psi. Max differential (pump trip 8050 psi) of 5550 psi would require testing to 6105 psi. (d) Pressure relief Line pressure test pressure, remotely 15K psi treesaver, pump knock out set 8050 and PRV set at CDW valve - controlled shut-in device 8550 psi plans. IA PRV set as 2600 psi. line test pressure of 12/26/2018 9500 psi. (eJ Confinement Frac fluids confined to approved Provided with application. CDW formations 12/26/2018 (f) Surface casing Monitored with gauge and pressure relief CDW pressures device IA PRV set at 2600 psi. Surface annulus open. 12/26/2018 (g) Annulus pressure 500 psi criteria monitoring & notification (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report (i) Reporting (i)(1) FrocFocus Reporting (i)(2) AOGCC Reporting: printed & electronic AOGCC Page 5 January 8, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist KRU 3C -08A (PTD No. 218-161; Sundry No. 318-574) Paragraph Sub -Paragraph Section Complete? (%J Post frac water sampling plan Not required (see Section (a)(3), above), (k) Confidential Clearly marked and specific facts information supporting nondisclosure (I) Variances Modifications of deadlines, requests for requested variances or waivers No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation. AOGCC Page 6 January 8, 2019 20 AAC 25.283 Hydraulic Fracturing Application — Checklist KRU 3C -08A (PTD No. 218-161; Sundry No. 318-574) Paragraph Seati-Paragraph ISection I Complete? West soomimm INIM KRU 3C-09 0.6.n s0o2WIMooa iestsso 0.9.M. KRU 3C-08 sareszzsosao .mass East KUPARUK RW UNIT 1R31 Est. Top Cement for 7" casing in 3C-08 - - primary well (-4,760' - TVDSS) _ qqq�} Al HRZ Sh le --- Up er s f '.. Co fining - T bso0 .- Fracturing Interval 2-3/g" slotted Mir in Vertical scale for cross-section is in _ 3C -08A (approx.) Lower - units of True Vertical Feet Subsea - - -- Confining AOGCC Page 7 January 8, 2019 Loepp, Victoria T (DOA) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Victoria, Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Friday, January 4, 2019 3:27 PM Loepp, Victoria T (DOA) Davies, Stephen F (DOA); Wallace, Chris D (DOA); Buck, Brian R FW: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation KRU 1 R -31/3C-10 Cement Eval 1 R-31 1-24-1995 Daily Drilling Report.pdf; 1001397029_3C-103IF Follow up Flagged Thanks for your email. I've included a copy of drilling report for 111-31 and the log for 3C-10 per your request. There is no log available for 1R-31- the casing depth and bit size was used to calculate a theoretical TOC. SLB Log Analyst Comments for 3C-10: • CET log is a predecessor to the current USIT, it is a circumferential ultra -sonic measurement. • Seems like there are some solids in the entire logged interval but not necessarily connected. • Looks like a wide channel across most of the logged interval, 8700'-8750' shows fuller coverage. • At 8500'-8515' there is a mostly free zone which correlates with a drop in GR. Our plan is to have manned monitoring (IA and OA) for IR -31 and 3C-10 during frac operations. IR -31 is currently shut-in, 3C-10 will be shut-in 2 days prior to frac and monitored on the day of frac. Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, January 4, 2019 2:37 PM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation KRU 1R -31/3C-10 Cement Eval Sandeep, Thank you for the additional information. Could you please provide a snapshot of the relevant section of the cement log and/or the cement job summary for KRU 3C-10 and 111-31. Also, please provide the log analyst's comments. Please outline any risk mitigation measures that will taken during the frac job such as manned IA/OA monitoring of these wells. I understand the frac is tentatively planned for 1/10/19 so please expedite this information to me. 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. LoeppOalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal low. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.loeoa@alasko.aov From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Thursday, January 3, 2019 11:49 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: RE: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation Victoria, Happy New Year! Please find the requested information attached. I wanted to clarify that we didn't see high quality cement in the 3C-10 parent bore and 111-31's cement tops were calculated. However, we plan to monitor these wells and shut -down in the event we see communication. Please let me know if you need anything else. Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Office: 907.263.4724 Cell: 512.507.9537 Email: Sandeep.Pedam@Conocophillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.Kov> Sent: Monday, December 31, 2018 11:26 AM To: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Subject: [EXTERNAL]KRU 3C-08A(PTD 218-161, Sundry 318-574) Fracture Stimulation Sandeep, In Section 10, the casing and cementing assessments of wells within %: mile radius of the fracturing interval, please update the table to provide the following: 1. TOC estimate(calculated) for the intermediate casing for wells that have the TOC listed as "uncertain" in both MD and TVDss. This calculation may include a 30% washout. 2. TOC estimate in TVDss for the intermediate casing for wells in which a cement evaluation log was run 3. Top of the oil pool in both MD and TVDss for all wells listed 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 Loepp0alas ka. 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)793-1247 or Victoria.Loepp®alaska.aov 1✓ ConocoPhillips Transmittal #1240 Detail Date: 1/7/2019 218161 30 20 5 Sent Via: Hand Delivery Justification: Compliance Transmittal Info Tracking #: Data Detail Quantity*: Description*: 3C -08A, 3C-08APB1, & 3C-08APB2 Final Well Log data including: CGM, LAS, PDF, Surveys, Tapescan, and TIFF Attachments: Received By: cJ Approver: Signat a _ ✓ gnature AOGCC Type*: CD DIt 0 1IT Date: To (External Party): From (CPAI Contact): Email*: meredith.guhl@alaska.gov Email*: Richard.E.Elgarico@conocophillips.com First Name*: Meredith First Name*: Ricky Last Name*: Guhl Last Name*: Elgarico Phone Number: (907) 793-1235 Phone Number: (907) 265-6580 Company: AOGCC Company: CPAI Address: 333 W. 7th Ave. Address: 700 G Street City: Anchorage City: Anchorage RECEIVED �✓C State: Alaska State: AK Zip Code: 99501 Zip Code: 99501 JAN 01 2019 Sent Via: Hand Delivery Justification: Compliance Transmittal Info Tracking #: Data Detail Quantity*: Description*: 3C -08A, 3C-08APB1, & 3C-08APB2 Final Well Log data including: CGM, LAS, PDF, Surveys, Tapescan, and TIFF Attachments: Received By: cJ Approver: Signat a _ ✓ gnature AOGCC Type*: CD DIt 0 1IT Date: BAS. q 1 PRINT DISTRIBUTION LIST UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3C -08A FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider_Qbakerhughes.com STATUS Final Replacement: COMPANY ADDRESS IFEDEX WILL NOT DELIVER TO P.O. 90X) PERSON ATTENTION V t BP North Slope. EOA, PROC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 v - 218161 1 u 2 0 5 se sign and return one copy of this transmittal form to: ocoPhillips Alaska, Inc. I Osterkamp (WINS Petroleum Technician) G Street. horaee.Alaska 99510 LOG TYPE GR -1 LOG DATE December 30, 2018 TODAYS DATE January 4, 2019 Revision Details: Rev. Requested by: --- FIELD I FINALCD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY I REPORT LOGS LOGS CGM, Final Surveys) (Compass) #OF PRINT 4 Ur rK11N #OF COPIES #OFCOPIES #OFCOPIES 4 9 9 d 4 4 2 ConocoPhillips Alaska Inc. 0 O O O 1 0 Atm: Ricky Elgarico 0 708 70 E1� C 700 G rare,[ ?C V {� Anchorage, AK 99510 3 ExxonMobil, Alaska 0 O O 0 Alto: Lynda M. Yaskell and/or Leonardo Elias (� 3201 C Street, Suite 505 r Anchorage, AK 99503 4lStat,of Alaska -AOGCC 0 i 'I O O Attu: Natural Resources Technician II 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 6 DNR - Division ofOil & Gas "* 0 0 1 0 0 AM: Resource Evaluation 1550 West 7th Avenue, Suite 1100 Anchorage, Alasks 99501 *** Stamp "confidential" on all material deliver to DNR —71 6IBP Exploration (Alaska) Inc. 0 0 0 0 Petrotechnical Data Center, LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 218161 �/ 30206 ConocoPhillips Transmittal #1240 Detail Date: 1/7/2019 To (External Party): From (CPAI Contact): Email*: meredith.guhl@alaska.gov Email*: Richard.E.Elgarico@conocophillips.com First Meredith Name*: First Name*: Ricky Last Name*: Guhl Last Name*: Elgarico Phone (907) 793-1235 Phone Number: (907) 265-6580 Number: Company: AOGCC Company: CPAI Address: 333 W 7th Ave. Address: 700 G Street City: Anchorage City: Anchorage RECEIVED State: Alaska State: AK Zip Code: 99501 Zip Code: 99501 JAN Q l 2019 Sent Via: Hand Delivery Justification: Compliance Transmittal Info Tracking #: Data Detail Quantity*: Description*: 3C -08A, 3C-08APB1, & 3C-08APB2 Final 1 Well Log data including: CGM, LAS, PDF, Surveys, Tapescan, and TIFF Attachments: Received By: U Approver: Signatufe:, Signature AOGCC Type*: CD D te: ) Date: BA ER PRINT DISTRIBUTION LIST F EIGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3C-08APBl FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com STATUS Final Replacement: No COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. 60X) PERSON ATTENTION V I BP North Slope. EOA, PBOC, PR&20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 218161 30206 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE December 30, 2018 TODAYS DATE January 4, 2019 Revision Details: Rev. Requested by: --- FIELD/ FINAL CD/DVD FINAL 0 PRELIM LOGS las, dlis, PDF, META, I (CGM, SURVEY REPORT LOGS Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES 2 ConocoPhillips Alaska Inc. 0 0 0 0 0 Attn: Ricky Elgarico ATO 708 700 G Street v ++ Anchorage, AK 99510 v O 3 Exxon Mobil,Alasla 0 0 0 0 Atm: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 P Anchorage, AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 .Ann: Natural Resources Technician If 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division oron & Gas — 0 0 1 0 0 Ann: Resource Evaluation 550 West 71h Avenue, Suite 1100 Anchorage, Alaska 99501 e.. Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alasla) Inc. 0 0 1 0 0 Petrotechnical Data Center, IR2-1 900 E Benson Blvd. Anchorage, Alaslo 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 218161 30207 ConocoPhillips Transmittal #1240 Detail Date: 1/7/2019 To (External Party): From (CPAI Contact): Email*: meredith.guhl@alaska.gov Email*: Richard.E.Elgarico@conocophillips.com First Name*: Meredith First Name*: Ricky Last Name*: Guhl Phone Number: (907)793-1235 Company: AOGCC Address: 333 W. 7th Ave. City: Anchorage State: Alaska Zip Code: 99501 Sent Via: Hand Delivery Justification: Compliance Last Name*: Elgarico Phone Number: (907) 265-6580 Company: CPAI Address: 700 G Street City: Anchorage RECEIVE® State: AK Zip Code: 99501 JAN 0 i 2019 Transmittal Info Tracking #: Data Detail Quantity*: Description*: 3C -08A, 3C-08APB1, & 3C-08APB2 Final 1 Well Log data including: CGM, LAS, PDF, Surveys, Tapescan, and TIFF Attachments: Received By Approver: Signatu,�: JSignature: AOGVC Type*: CD Date Date: BA ER PRINT DISTRIBUTION LIST I UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME 3C-08APB2 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@bakerhughes.corn STATUS Final Replacement COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V ) BP North Slope. EOA. PBOC. PRW20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobik Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias '.3201 C Street, Suite 505 Anchorage, AK 99503 N1- 218161 30 20 7 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 to acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE December 30. 2018 TODAYS DATE January 4, 2019 Revision Details: Rev. Requested by: -- FIELD /FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRIN UF rKIN # OF COPIES # OF COPIES # OF COPIES !� 4 4 a I !1 0 0 0 0 0 P 41StaM of Alaska -AOGCC 0 1 1 0 0 IAun: Natural Resources Technician 11 1333 W. 7th Ave, Suite 100 I lAnchorage, Alaska 99501 5DNR - Division ofOil & Gas *** 0 0 (Attn: Resource Evaluation 1550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 Stamp "—fi&ntiaf' on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, IR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 3 0 0 BA(ER Q F�UGHES a GE company Date: January 4, 2019 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 218161 30201 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data for the following well(s): 3C-08APB1 3C-08APB2 3C -08A (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BakerHushes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C -08A 50-029-21390-01 Baker Hughes INTEQ Definitive Survey Report 03 January, 2019 BAT(ER UGHES aGE<ompany 218161 30201 ConocoPhillips BA ER ConocDefinitive Survey Report U�Gt ES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-08 Wellbore: 3C -08A Design: 3C -08A Project Kuparuk River Unit, North Slope Alaska, UnitedStates Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3C-08 11/1/2018 Design Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Elating: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3C -08A W Magnetics Model Name Sample Date (usft) 34.90 Well 3C-08 3C-08 @ 82.00usft (3C-08) 3C-08 @ 82.00usft(3C-08) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,995,910 44 usft 528,557.71 usft usft Declination V) 16 89 Latitude: 70' 23' 59.683 N 7 Longitude: 149'46'3.299 W j Ground Level: 47.10 usft i 7 Dip Angle Field Strength 1°) oT) 80.92 57,440 —1 Tie On Depth: 10,470.34 +N/ -S +E/ -W Direction (usft) (usft) C) 0.00 0.00 90.00 1/32019 2:38:44PM Page 2 COMPASS 5000.19 Build 85D BGGM2018 11/1/2018 Design 3C -08A Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 34.90 Well 3C-08 3C-08 @ 82.00usft (3C-08) 3C-08 @ 82.00usft(3C-08) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,995,910 44 usft 528,557.71 usft usft Declination V) 16 89 Latitude: 70' 23' 59.683 N 7 Longitude: 149'46'3.299 W j Ground Level: 47.10 usft i 7 Dip Angle Field Strength 1°) oT) 80.92 57,440 —1 Tie On Depth: 10,470.34 +N/ -S +E/ -W Direction (usft) (usft) C) 0.00 0.00 90.00 1/32019 2:38:44PM Page 2 COMPASS 5000.19 Build 85D ConocoPhillips DA�cER ConocoPhillips Definitive Survey Report ry M Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 3C Pad Well: 3C-08 Wellbore: 3C -08A Design: 3C -08A Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3C-08 3C-08 @ 82.00usft (3C-08) 3C-08 @ 82.00usR (3C-08) True Minimum Curvature EDT 14 Alaska Production Survey Program Date 1/3/2019 From To Vertical Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date 100.00 9,900.00 3C-08(3C-08)GCT-MS Schlumberger GCT multishot 1/12/2001 9,935.00 10,021.09 3C-08APB1 MWD-INC(3C-08APB1) MWD -INC -ONLY MWD-INCONLY_FILLER 12/24/2018 10,049.89 10,271.01 3C-08APB1 (3C-08APB1) MWD MWD -Standard 12/25/2018 10,290.00 10,470.34 3C-08APB2 MWD(3C-08APB2) MWD MWD -Standard 12/25/2018 10,490.00 12,246.00 3C -08A BHGE CTK MWD <10470.34-12 MWD MWD -Standard 12/30/2018 Survey MD (usft) 10,470.34 10,49060 10,521.07 10,550.83 10,581.93 10,611.41 10,641 ns 10,671.75 10,701.91 10,731.37 10,761.43 10,792.03 10,822.25 10,851.66 10,881.42 10,910.62 10,941.84 10,972.26 11,003.53 Survey End Date 12/24/2018 1 12/25/2018 12/25/2018 12/30/2018 I v t Annotation TIP KOP 1/32019 2:36:44PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical Inc Azi TVD TVDSS +N/ -S +E/ -W (usft) (usft) (usft) lusft) Northing Eastin9 °DOS ( ) Section Survey Tool Name (R) (ft) (ft) 87.91 84.40 6,699.87 6,617.87 4,881.08 5,451.03 6,000,811.83 533,989.51 17.73 5,451.03 MWD (4) 87.77 84.51 6,700.61 6,618.61 4,882.98 5,470.59 6,OOD,813.80 534,009.50 0.91 5,470.59 MWD (5) 85.05 83.04 6,702.55 6,620.55 4,886.34 5,50141 6,000,817.28 53,039.87 9.95 5,501.41 MWD (5) 82.12 81.96 6,705.88 6,623.88 4,890.20 5,530.73 6,000,821.25 534,069.16 10.48 5,530.73 MWD (5) 83.42 80.56 6,709.79 6,627.79 4,899.89 5,561.22 6,000,826.05 534,099.64 6.12 5,561.22 MWD (5) 83.94 78.83 6,713.04 6,631.04 4,900.13 5,590.05 6,000,831.41 534,128.44 6.09 5,590.05 MWO (5) 85.60 78.98 6,715.78 6,633.78 4,905.89 5,619.43 6,000,837.28 534,157.80 5.54 5,619.43 MWD (5) 87.39 78.01 6,717.63 6,63563 4,911,92 5,649.04 6,000,843.42 534,187.38 6.72 5,649.04 MWD (5) 87.76 76.99 6,718.91 6,636.91 4,918.44 5,678.46 6,500,850.05 534,216.77 3.59 5,67646 MWD (5) 85.78 75.27 6,720.31 6,638.31 4,925.49 5,707.02 6,000,857.21 534,245.31 6.71 5,70702 MWD (5) 87.82 76.65 6,721.72 6,639.72 4,932.72 5,736.16 6,000,864.56 534,274.42 6.29 5,73616 MWD(5) 8868 78.54 6,722.66 6,640.66 4,939.24 5,76605 6,000,871.19 539,30427 6.19 5)65.05 MWD (5) 89.35 80.64 6,723.18 6,641.18 4,944.70 5,795.76 6,000,876.76 53,333.96 7.30 5,795.76 MWD (5) 88.25 80.97 6,723.79 6,641.79 4,949.40 5,824.79 6,000,88157 53,362.97 3.94 5,824.79 MAD (5) 88.68 80.16 6,724.59 6,642.59 4,954.28 5,854.13 6,000,886.56 53,392.29 3.08 5,859.13 MWD (5) 89.51 80.12 6,725.05 6,643.05 4,959.28 5,882.90 6,000,891.67 534,421.03 2.85 5,882.90 MWD (5) 89.42 7]65 6,725.34 6,643.34 4,965.29 5,913.53 6,000,897.80 534,451.64 7.92 5,913.53 MWD (5) 91.01 79.42 6,72523 6,643.23 4,971.34 5,943.34 6,000,903.96 534,481.42 7.82 5,943.34 MWD (5) 91.75 82.67 6,724.47 6,642.47 4,97621 5,97422 6,000,908.94 534,51228 10.50 5,974.22 MWD(5) Survey End Date 12/24/2018 1 12/25/2018 12/25/2018 12/30/2018 I v t Annotation TIP KOP 1/32019 2:36:44PM Page 3 COMPASS 5000.14 Build 85D 10 ConocoPllllips ConocoPhillips Definitive Survey Report An Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Well 3C-08 Project: Kuparuk River Unit TVD Reference: 3C-08 @ 82.00usft (3C-08) Site: Kuparuk 3C Pad MD Reference: 3C-08 @ 82.00usft (3C-08) Well: 3C-08 North Reference: True Wellbore: 3C -08A Survey Calculation Method: Minimum Curvature Design: 3C -08A Database: EDT 14 Alaska Production Survey MD Inc An TVD TVDSS -NI-S +El -W Map Map Vertical (8 (usft) (usft) (usft) (usft) Northing Easting H00 Section Survey Tool Name (ft) (ft) (' ) (ft) 11031 11,031.21 91 91.]8 83.69 6,72362 6,64162 4,979.49 6,001.69 6,000,912.33 534,539.73 3.68 6,00169 MM (5) 11,06148 93.84 83.55 6,722.14 6,640.14 4,982.85 6,031.73 6,000,915.81 534,569.76 6.82 6,031.73 MWD(5) 11,090.23 95.35 83.65 6,719.83 6,637.83 4,986.04 6,06021 6,000,919.11 W598.22 5.26 6,050.21 MWD(5) 11,116.55 96.65 82.52 6,717.08 6,635.08 4,989.20 6,086.19 6,000,922.36 534,624.19 6.53 6,086.19 MWD (5) 11,149.58 100.54 81.45 6,712.15 6,630.15 4,993.75 6,118.53 6,000,927.04 534,656.50 12.20 6118.53 MM (5) 11,18029 100.19 82.37 6,706.62 6,624.62 4,998.00 6,148.43 6,000,931.40 534,686.39 3.16 6,14843 MWD(5) 11,211.24 9673 83.41 6,701.53 6,619.53 5,001.78 6,178.73 6,000,93529 534,716.67 5.77 6,178.73 MWD (5) 11,239.90 97.82 84.45 6,697.41 6,615.41 5,004.77 6,206.93 6,000,938.40 534,744.86 479 6,206.93 MWD (5) 11,271.78 95.19 85.42 6,693.80 8,611.80 5,007.57 6,238.48 6,000,941.32 534,776.39 8.79 6,238.48 MWD (5) 11,301.31 93.01 87.11 6,691.69 6609.69 5,00949 6,267.87 6,000,943.35 534,805.77 9.33 6,267.87 MWD (5) 11,332.26 90.95 88.36 6,690.62 6,608.62 5,010.71 6,298.77 6,000,944.69 534,836.67 7.78 6,298.77 MWD (5) 11,361.50 88.74 90.30 6,690.70 6,608.70 5,011.05 6,328.01 6,000,945.14 534,865.90 10.06 6,328.01 MM (5) 11,392.20 85.% 92.43 6,692.11 6,610.11 5,010.32 6,358.66 6,000,944.53 534,896.55 11.35 6,358.66 MWD (5) 11,420.75 87.08 92.00 6,693.84 6,611.84 5,009.22 6,387.14 6,000,943.53 534,925.03 4.14 6,387.14 MWD (5) 11,451.33 86.37 91.75 6,695.58 6,613.58 5,008.22 6,417.65 6,000,942.65 534,955.54 2.46 6,417.65 MWD(5) 11,481.88 86.44 90.97 6,697.50 6,615.50 5,007.50 6,448.13 6,000,942.04 534,98562 2.56 6,448.13 MM (5) 11,510.54 87.45 91.02 6,699.03 6,617.03 5,007.00 6,476.75 6,000,941.66 535,014.63 3.53 6,476.75 MWD (5) 11,54044 87.97 90.91 6,70022 6,61822 5,006.50 6,506.62 6,000,941.27 535,044.51 1.78 6,506.62 MWD (5) 11,570.32 87.30 88.99 6,701.46 6,619.46 5,006.52 6,536.47 6,000,941.41 535,074.36 6.80 6,536.47 MM (5) 11,600.47 88.40 87.48 6,702.59 6,620.59 5,007.45 6,56558 6,000,942.45 535,104.46 6.19 6,566.58 MWD (5) 11,630.89 89.91 86.58 6,703.03 6,621.04 5,009.03 6,596.96 6,000,944.14 535,134.83 5.78 6,596.96 MWD (5) 11,661.05 91.08 86.74 6702.77 6,62077 5,010.79 6,627.07 6,000,946.01 535,164.92 3.92 6,627.07 MWD (5) 11,690.85 90.74 85.57 6,702.30 6,620.30 5,012.78 6,656.79 6,000,948.13 535,194.64 4.09 6,655.79 MWD (5) 11,720.57 89.97 84.92 6,702.12 6,620.12 5,015.25 6,686.41 6,000,950.70 535,224.25 3.39 6,686.41 MWD(5) 11,750.77 90.40 83.39 6,702.02 6,620.02 5,018.32 6,716.45 6,000,953.89 535,254.27 5.26 6,716.45 MWD (5) 11,78066 91.17 84.23 6,701.61 6,619.61 5,021.54 6,746.16 6,000,957.23 535,283.97 3.81 6,746.16 MM (5) 11,810.57 92.18 82.74 6,700.74 6,618.74 5,024.94 6,775.87 6,000,960.73 535,313.66 6.02 6,775.87 MWD (5) 11,840.63 9258 83.85. 6,699.49 6,617.49 5,028.44 6,805.70 6,000,964.35 535,343.47 3.92 6,805.70 MWD (5) 11,870.57 93.63 83.40 6,697.87 6,61557 5,031.76 6,835.41 6,000,967.79 535,373.16 3.81 6,835.41 MWD(5) 11,901.17 92.60 8281 6,696.15 6614.15 5,035.43 6,865.74 6,000,971.57 535,403.48 3.33 6,865.74 MM (5) 11,931.09 92.95 80.28 6,69465 6,612.65 5,039.82 6,89529 6,000.97608 535,43301 846 6,895.29 MWD (5) Annotation 1/3/2019 2'36'44PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConxoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-08 Wellbore: 3C -08A Design: 3C -08A Survey ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3C-08 3C-08 @ 82.00usft (3C-08) 3C-08 @ 82.00usft (3C-08) True Minimum Curvature EDT 14 Alaska Production MD Inc Aid TVD TVDSS .147-S +E7 -W Map Map .34 ,044 5DLS Vertical (usat) (°) (0) (usR Northing Easting Section 11960.57 93.63 82.07 6692.96 6,61096 5 (6,610 ( ,0 (usft) (ft) (°/100') Survey Tool Name 6,92437 6,000,980.70 535462.07 6.49 6,924.37 MWD (5) 11,99140 93.32 7926 6,691.09 6,60969 5,049.33 6,954,74 6,000,985.81 535,492.41 9.15 6,954.74 MWD (5) 12,021.50 94,71 79.54 6,688.98 6,606.98 5,054.85 6,98425 6060,991.44 535,521.90 4.71 6,984.25 MWD (5) 12,050.59 95.78 80.52 6,686.32 6,604.32 5,059.87 7,012.78 6,000,996.57 536550.41 4.98 7,012.78 MWD (5) 12,080.46 96.07 81.35 6,683.24 6,601.24 5,064.55 7,042.12 6,001,001.36 535,579.73 2.93 7,042.12 MWD (5) 12,110.47 96.62 82.35 6,679.92 6,597.92 5,068.78 7,071.64 6,001,005.70 535,609.23 3.79 7,071.64 MWD (5) 12,140.55 97.21 83.64 6,676.30 6,594.30 5,072.42 7,101.29 6,001,009.46 535,638.86 4.69 7,101.29 MM (5) 12,170.03 97.14 85.86 6,67262 6,590.62 5,075.10 7,130.40 6,001,012.24 535,667.96 7.48 7,13040 MIND (5) 12,200.19 96A6 86.88 6,669.05 6,587.05 5,076.99 7,16029 6,001,01425 535,697.84 4.04 7,160.29 MWD (5) 12,212.29 95.72 87.03 6,667.76 6,585.76 5,077.63 7,172.31 6,001,014.94 535,709.85 6.24 7,172.31 MWD (5) 12,246.00 95.72 87.03 6,664.40 6,582.40 5,079.37 7,205.80 61001,016.80 535,743.34 0.00 7,205.80 PROJECTED to TD Annotation BA 1i UGHES 1/3/2019 2: 36 44P Page 5 COMPASS 5000.14 Build 85D BA ER I UGI ES a GE company Date: January 4, 2019 Abby Bell AOGCC 333 West 71h Ave, Suite 100 Anchorage, Alaska 99501 21 8161 30 20 2 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94th Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 3C-08APB1 3C-08APB2 3C -08A (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper@BakerHuehes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C-08APB1 50-029-21390-70 Baker Hughes INTEQ Definitive Survey Report 03 January, 2019 BA ER F�UGHES a GE company 218161 30202 1/312019 2: 29: 41PM Page 2 COMPASS 500014 Build 85D ConocoPhillips Hi ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3C-08 j Project: Kuparuk River Unit TVD Reference: 3C-08 @ 82,00usft (3C-08) h Site: Kuparuk 3C Pad MD Reference: 3C-08 @ 82.00usft (3C-08) Well: 3C-08 North Reference: True j Wellbore: 3C-08 Survey Calculation Method: Minimum Curvature Design: 3C-08 Database: EDT 14 Alaska Production Project Kuparuk River Unit, North Slope Alaska, United States N Map System: US Slate 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 3C -08 ->__.-v _...... __.. _-...__.... Well Position +N/ -S 0.00 usft Northing: 5, 995,910.44usft Latitude: 70° 23'59.683 N +E/ -W 0.00 usft Easting: 528,557.71 usft Longitude: 149" 46' 3.299 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 47.10 usft Wellbore 3C-08APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) (I (nT) BGGM2018 11/1/2018 16.89 80.92 57,440 Design 3C-08APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,900.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 34.90 0.00 0.00 90.00 Survey Program Date 1/3/2019 From TO Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 100.00 9,900.00 3C-08 (3C-08) GCT -MS Schlumberger GCT multishot 1/12/2001 9,935.00 10,021.09 3C-08APB1 MWD -INC (3C-08APB1) MWD-INC_ONLY MWD-INC—ONLY—FILLER 12/24/2018 12/24/2018 10,049.89 11,181.39 3C-08APB1 (3C-08APB1) MWD MWD - Standard 12/25/2018 12/25/2018 1/312019 2: 29: 41PM Page 2 COMPASS 500014 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3C-08 Project: Kuparuk River Unit TVD Reference: 3C-08 Q 82.00usft (3C-08) Site: Kuparuk 3C Pad MD Reference: 3C-08 @ 82.00usft (3C-08) Well: 3C-08 North Reference: True Wellbore: 3C-0BAPB1 Survey Calculation Method: Minimum Curvature Design: 3C-08APB1 Database: EDT 14 Alaska Production Survey BA (ER UGHES Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 1/32019 2:29:41PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +N7 -S +E/ -W DLS (usft) (°) (°) (us@) (usft) (usft) (usft) Northing Easting (°1100') Section Survey Tool Nam[ (ft) (ft) (ft) 9,900.00 49.18 54.07 6,620.23 6,538.23 4,623.77 4,976.14 6,000,55274 533,515.65 0.40 4,976.14 MWO-INC_ONLY (2) 9,935.00 48.95 54.04 6,643.16 6,561.16 4,639.30 4,997.54 6,000568.34 533,536.99 0.66 4,997.54 MWD -INC ONLY(2) 9,960.17 54.10 54.00 6,658.82 6,576.82 4,650.87 5,01348 6,000,579.97 533,552.89 20.46 5,013.48 MM -INC _ONLY (2) 9,990.63 63.57 52.00 6,674.56 6,592.56 4,666.55 5,034.26 6,000,595.73 533,573.60 31.59 5,034.26 MWD -INC -ONLY (2) 10,021.09 72.27 50.00 6,686.00 6,604.00 4,684.31 5,056.16 6,000,613.57 533,595.44 29.20 5,056.16 MWD-INC_ONLY (2) 10,049.89 80.63 47.91 6,692.75 6,610.75 4,702.68 5,077.25 6,000,632.03 533,616.45 29.87 5,077.25 MWD (3) 10,070.54 89.63 48.16 6,694.50 6,612.50 4,716.43 5,09254 6,000,645.83 533,631.68 4380 5,092.54 MWD (3) 10,100.43 91.50 50.31 6,694.20 6,612.20 4,735.94 5,115.17 6,000,665.42 533,65424 9.53 5,115.17 MAD (3) 10,130.36 90.89 53.84 6,693.58 6,611.58 4,754.33 5,138.77 6,000,683.90 533,677.77 11.97 5,138.77 MWD (3) 10,180.08 90.55 5946 6,692.95 6,610.95 4,781.65 5,180.29 6,000,711.38 533,719.17 1132 5,180.29 MAD(3) 10,210.23 90.58 61.69 6,692.65 6,610.66 4,796.46 5,206.54 6,000,726.29 533,745.37 7.40 5,206.54 MWD(3) 10,240.61 90.77 64.89 6,692.30 6,610.30 4,810.11 5,233.68 6,000,740.04 533,772.45 10.55 5,233.68 MWD (3) 10,271.01 91.01 68.77 6,691.82 6,609.82 4,822.07 5,261.61 6,000,752.10 533,800.34 12.79 5,261,61 MWD (3) 10,299.98 90.40 72.06 6,69147 6,60947 4,831.78 5,288.90 6,000,761.92 533,827.59 11.55 5,288.90 MWD (3) 10,329.32 90.71 74,19 6,691.18 6,609.18 4,840.30 5,31698 6,000,770.54 533,855.63 7.34 5,316.98 MWD (3) 10,358.89 9141 76.73 6,690.64 6,608.64 4,847.72 5,345.59 6,000,778.07 533,884.21 8.91 5,345.59 MWD (3) 10,390.19 90.77 77.82 6,690.04 6,WB.04 4,854.61 5,376.12 6,000,785.08 533,914.71 4.04 5,376.12 MWD (3) 10,420.51 8606 77.36 6,690.35 6,608.35 4,861.13 5,405,72 6,000,791.71 533,944.28 9.07 5,405.72 MWD(3) 10,450.66 85.21 75.84 6,692.12 6,610.12 4,868.10 5,435.00 6,000,798.79 533,973.53 10.71 5,43500 MWD (3) 10,480.50 83.97 77.02 6,694.93 6,612.93 4,875.07 5,46388 6,000,80587 534,002.38 5.72 5,463.88 MWD (3) 10,500.84 84.65 78.71 6,696.95 6,614.95 4,879.33 5,48366 6,000,81020 534,022.15 8.92 5,483.66 MM (3) 10,526.49 84.92 81.51 6,699.28 6,617.28 4,683.71 5,50682 6,000,814.68 534,04729 10.92 5,508.82 MWD (3) 10,553.74 86.13 85.93 6,701.41 6,619.41 4,886.68 5,535.82 6,000,81276 534,07427 16.77 5,535.82 MWD (3) 10,580.70 88.68 90.50 6,702.63 6,620.63 4,887.52 5,562.73 6,000,818.70 534,101.17 19.39 5,562.73 MWD (3) 10,610.37 87.94 93.85 6,703.51 6,621.51 4,886.39 5,592.36 6,000,817.68 534,130.81 11.56 5,592.36 MWD(3) 10,641.01 87.85 98.88 6,704.63 6,622.63 4,883.00 5,622.78 6,000,814.41 53,161.24 16.41 5,622.78 MM (3) 10,670.75 88.56 105.13 6,705.56 6,623.56 4,876.82 5,651.84 6,000,808.34 534,190.32 21.14 5,651.84 MWD (3) 10,690.17 88.16 107.99 6,706.12 6,624.12 4,871.29 5,670.45 6,000,802.88 534,208.94 14.86 5,670.45 MAD (3) 10,721.78 88.65 106.88 6,707.00 6,625.00 4,861.82 5,700.59 6,000,793.53 534,239.12 3.84 5,700.59 MWD(3) ..�.. 10,751.77 88.00 108.03 6,707.88 6,625.88 4,852.83 5,729.19 6,000,784.65 534,267.75 440 5,729.19 Mi (3) BA (ER UGHES Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth 1/32019 2:29:41PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillIps Definitive Survey Report Company: Protect: Site: Well: Wellbore: Design: Surveyp� MD (usR) 10780.45 10,811.12 10,841.26 10,871.69 10,901.56 10,932.40 10,980.67 10,991.29 11,032.33 11,061 04 11,091.10 11,125.13 11,151.57 11,181.39 11,215.00 ConocoPhlilips(Alaska) Inc.-Kup2 Kupamk River Unit Kuparuk 3C Pad 3C-08 3C-08APB1 3C-08APB1 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3C -OB 3C-08 @ 82.00usft (3C-08) 3C-08 @ 82.00usft (3C-08) True Minimum Curvature EDT 14 Alaska Production Inc Azi TVD TVDSS .N/S +E/ -W Map Map Vertical (`) (1 (usft) (usft) (usft) (usft) Northing Easting ('D O) Section Survey Tool Name 89.29 106.62 6,706.56 6,626.56 4,843.82 5,75641 6,00,775.74 (it) (ft) W295.00 4.95 (ft) 5,756.41 MWD(3) 88.03 11087 6,709.27 6,627.27 4,833.46 5,785.26 6,000,765.49 534,323.89 8.41 5,785.26 MWO (3) 88.96 113.14 6,710.06 6,628.06 4,822.17 5,813.20 6,000,754.31 534,351.86 8.14 5,813.20 MWD (3) 87.11 115.67 6,711.11 6,629.11 4,809.52 5,841.07 6,000,74177 534,379.78 10.23 5,841.07 MWD (3) 89.45 11993 6,712.01 6,630.01 4,795.70 5,867.30 6,000,728.04 534,406.06 16.37 5,867.30 MWD(3) 87.54 116.43 6,712.82 6,630.82 4,781.14 5,894.46 6,000,713.59 534,433.28 12.92 5,894.46 MWD (3) 86.37 114.26 6,714.32 6,632.32 4,769.06 5,91998 6,000,70161 534,458.83 8.71 5,919.98 MWD (3) 87.94 112.58 6,715.84 6,633.84 4,756.90 5,948.04 6,000,689.56 534,486.94 T50 5,948.04 MWD (3) 89.97 114.34 6,716.59 6,634.59 4,740.57 5,985.67 6,ODD,673.37 534,524.63 6.55 5,985.67 MWD (3) 86.03 111.40 6,717.59 6,635.59 4,729.42 6,012.10 6,000.66233 534,551.10 17.12 6,012.10 MWD(3) 85.94 111.44 6,719.69 6,637.69 4,718.47 6,040.02 6,000,651.48 534,579.06 0.33 6,040.02 MWD (3) 86.53 108.19 6,721.93 6,639.93 4,706.96 6,071.96 6,000,640.10 534,611.04 9.69 6,071.96 MWD (3) 87.32 106.29 6,723.35 6,641.35 4,699.13 6,097.17 6,000,63237 534,63628 7.77 6,097.17 MWD (3) 88.25 10524 6,724.50 6,642.50 4,691.04 6,125.85 6,00,624.39 534,664.98 4.70 6,125.85 MWD (3) 88.25 105.24 6,725.53 6,643.53 4,682.21 6,158.26 6,000,615.68 534,697.43 0.00 6,158.26 PROJECTED to TO Annotation i 1/3/2019 2:29:41PM Page 4 COMPASS 5000.14 Build 85D BATBA ER I IGHES GE company E Date: January 4, 2019 Abby Bell AOGCC 333 West 7" Ave, Suite 100 Anchorage, Alaska 99501 21816 30 20 3 Letter of Transmittal Michael Soper Baker Hughes, a GE Company 795 East 94`^ Avenue Anchorage, Alaska 99515 lease find enclosed the directional survey data for the following well(s): 3C-08APB1 3C-08APB2 3C -08A (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Applications Engineer Michael.Soper(@BakerHughes.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C-08APB2 Baker Hughes INTEQ Definitive Survey Report 03 January, 2019 BA, TR UGHES a GE company 218161 50203 ConocoPhillipsE ConocoPhillips Definitive Survey Report B%HES Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3C Pad Well: 3C-08 Wellbore: 3C-08APB2 Design: 3C-08APB2 Project - Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum. Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 S Well 3C-08 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: I Well Position +N/3 0.00 usft Northing: ' +E/ -W 0.00 usft Easting: '. Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 3C-08AP82 3C-08 (3C-08) Magnetics Model Name Sample Date 10,021.09 BGGM2018 11/1/2018 Design 3C-08APB2 10,271.01 Audit Notes: Version: 1.0 Vertical Section: Survey Program From (usft) 100.00 9,935.00 10,049.89 10,290.00 Phase: ACTUAL Depth From (TVD) (usft) 34.90 Date 1/3/2019 Well 3C-08 3C-08 @ 82.00usft (3C-08) 3C-08 @ 82.00usft (3C-08) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,995,910.44 usft 528,557.71 usft usft Declination V) 16.89 Latitude: Longitude: Ground Level: Dip Angle (°) 80.92 70° 23'59.683 N 149° 463Z99 W 47.10 usft Field Strength K) 57,440 Tie On Depth: 10.271.01 +N/ -S +E/ -W Direction (usft) (usft) (°) 000 0.00 90.00 { To (usft) Survey (Wellbore)Tool ) Tool Name Description Survey Start Date 9,900.00 3C-08 (3C-08) GCT -MS Schlumberger GCT multishot 1/12/2001 10,021.09 3C-08APB1 MWD -INC (3C-08APB1) MWD -INC ONLY MWD-INC_ONLY FILLER 12/24/2018 10,271.01 3C-08APB1 (3C-08APB1) MWD MWD -Standard 12/25/2018 11,566.59 3C-08APB2 MWD(3O.OBAPB2) MWD MWD -Standard 12/25/2018 Survey End Date 12/24/2018 12/25/2018 12/25/2018 1/3/2019 2:33: fOPM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 3C-08 Project: Kuparuk River Unit TVD Reference: 313-08 @ 82.00usft (3C-08) Site: Kuparuk 3C Pad MD Reference: 3C-08 @ 82.00usft (3C-08) Well: 3C-08 North Reference: True Wellbore: 3C-OSAPB2 Survey Calculation Method: Minimum Curvature Design: 3C-08APB2 Database: EDT 14 Alaska Production Survey MD Inc Azi TVD TVDSS +Nl-S +EI -W Map Map Vertical (usft) (1) (_) (usft (ssft) (usk) (usk) Northing Easting OLS Section on Survey Tool Name (ft). (ft) (Y700.) (ft) 10,27101 91.01 68.]] 6,691.82 6,609.82 4,822.07 5,261.61 6,000,752.10 533,800.34 12.79 526161 MWD(3) 10,290.00 90.61 70.93 6,691.56 6,609.56 4,828.61 5,279A4 6,000,758.71 533,818.14 11.57 5,279.44 MWD(4) 10,320.06 88.28 68.39 6,691.85 6,609.85 4,839.06 5,30.62 6,000,769.27 533,846.28 11.47 5,307.62 MWD (4) 10,352.16 86.55 68.09 6,693.29 6,611.30 4,850.95 5,337.40 6,000,78127 533,876.01 5.47 5,337.40 MWD(4) 10.38226 85.54 70.47 6,695.37 6,613.37 4,861.57 5,365.48 6,00,792.00 533,90465 8.57 5,365.48 MWD (4) 10,440.69 87.82 79.14 6,698.76 6,616.76 4,876.84 5,421.72 6,000,807.48 533,960.22 15.32 5,421.72 MWD (4) 10,470.34 87.91 84.40 6,699.87 6,617.87 4,881.08 5,451.03 6,000,811.83 533,989.51 17.73 5,451.03 MWD (4) 10,500.47 87.70 84.57 6,701.02 6,619.02 4,883.97 5,481.00 6,000,814.84 534,019.47 0.90 5,481.00 MWD (4) 10,530.51 87.14 85.51 6,702.37 6,620.37 4,886.57 5,510.90 6,00,817.54 534,049.35 3.64 5,510.90 MWD (4) 10,560.48 87.57 86.64 6,703.76 6,621.76 4,888.62 5,540.77 6,000,819.71 534,079.21 4.03 5,540.77 MM (4) 10,590.65 86.25 88.50 6,705.38 6,623.38 4,889.89 5,570.86 6,000,821.10 534,109.30 7.55 5,570.86 MWD (4) 10,621.30 86.10 90,98 6,70743 6,625.43 4,890.03 5,601.44 6,000,821.36 534,139.87 8.09 5,601.44 MWD (4) 10,651.09 84.77 93.71 6,709.80 6,627.80 4,886.82 5,631.11 6,000,820.26 534,169.54 10.17 5,631.11 MWD (4) 10,680.41 85.97 9567 6,712.17 6,630.17 4,886.43 5,660.23 6,000,817.98 534,198.67 7.82 5,660.23 MWD(4) 10,71063 87.23 95.31 6,713.96 6,631.96 4,883.54 5,690.26 6,000,815.21 534,228.71 4.34 5,690.26 MWD(4) 10,741.61 88.59 95.53 6,715.09 6,633.09 4,880.62 5,721.08 6,000,81240 534,259.54 4.45 5,721.08 MWD (4) 10,770.63 89.08 94.81 6,715.68 6,633.68 4,878.00 5,749.98 6,000,809.90 534,288.44 3.00 5,749.98 MWD (4) 10,800.57 89.51 92.75 6,716.05 6,634.05 4,876.03 5,779.85 6,000,80864 534,318.31 7.03 5,779.85 10,830.41 90.98 91.65 6,715.92 6,633.92 4,874.88 5,809.67 6,000,807,01 534,348.13 6.15 MWD(4) 10,860.38 90.52 90.48 6,715.53 6,633.53 4,874.33 5,839.63 6,000,806.56 534,378.09 4.19 5,809.67 5,839.63 MWD (4) MWD (4) 10,893.95 90.15 89.86 6,715.33 6,633.33 4,874.23 5,873.20 6,000,806.59 534,41166 2.15 5,873.20 MV (4) 10,925.23 88.65 88.20 6,715.66 6,633.66 4,874.76 5,904.47 6,000,807.24 534,442.92 7.15 5,904.47 MWD (4) 10,955.12 87.17 88.50 6,716.75 6,63475 4,875.62 5,93433 6,000,806.21 534,472.77 5.05 5,934.33 MWD (4) 10,986.06 85.52 88.15 6,718.72 6,636.72 4,876.52 5,965.19 6,000,809.23 534,503.63 5.45 5,965.19 MWD (4) 11015.41 85.67 87.01 6,720.97 6,638.97 4,877.76 5,994.42 6,000,810.58 534,532.86 3.91 5,994.42 MWD(4) 11,045.85 86.04 85.97 6,723.17 6,641.17 4,879.61 6,024.73 6,000,812.56 534,563.15 362 6,024.73 MM (4) 11,074.59 87.91 83.20 6,72469 6,642.69 4,882.32 6,053.30 6,000,815.37 534,591.71 11.62 6,053.30 MWD (4) 11,110.89 90.71 82.25 6,725.13 6,643.13 4,886.92 6,089.30 6,000,820.11 534,627.69 8.15 6,089.30 MWD (4) 11,140.61 93.01 82.23 6,724.16 6,642.16 4,890.93 6,11873 6,000,824.23 534,657.10 7.74 6,118.73 MWD (4) 11,169.47 95.16 81.73 6,722.11 6,640.11 4,894.95 6,147.23 6,000,828.35 534,665.58 7.65 6,147.23 MM (4) Annotation TIP KOP �ERW F HES 1/3/2019 233: fOPM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupawk 3C Pad Well: 3C-08 Wellbore: 3C-08APB2 Design: 3C-08APB2 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3C-08 3C-08 @ 82.00usft (3C-08) 3C-08 Cot 82.00usft (3C-08) True Minimum Curvature EDT 14 Alaska Production MD Inc Azl TVD TVDSS +Nl-S +E/ -W Map Map Vertical (usft) V) (°) (usft) (usft) (usft) (usft) Northing Easting DLS Section 77,200(ft) (ft) (°7100') (ft) .86 97.98 87.78 6,718.52 6,636.52 4,899.58 6,178.06 6,000,833.10 534,716.40 9.15 6,17866 11,231.66 99.31 80.36 6,713.89 6,631.89 4,904.46 6,208.12 6,000,838.10 534,746.43 5.06 6,208.12 11,260.15 99.68 78.99 6,709.19 6,627.19 4,909.50 6,235.76 6,000,843.24 534,774.05 4.92 6,235.76 11,290.63 99.31 78.82 6,704.16 6,622.16 4,915.28 6,26526 6,000,849.14 534,803.53 1.33 6,265.26 11,320.59 97.07 79.02 6,699.89 6,617.89 4,920.98 6,294.36 6,000,854.95 534,832.60 7.51 6,294.36 11,356.20 93.59 79.57 6,696.58 6,614.58 4,927.571 1 6,329.20 6,000,861.67 534,867.41 9.89 6,32920 MWD(4) 11,386.40 91.60 80.19 6,695.22 6,613.22 4,932.87 6,358.90 6,000,867.9 534,89.08 6.90 6,369.90 MWD (4) 11,415.83 89.57 82.23 6,694.92 6,612.92 4,937.36 6,387.98 6,000,871.69 534,926.14 9.78 6,387.98 MWD(4) 11,445.15 88.40 84.75 6,695.44 6,613.44 4,940.69 6,417.10 6,000,875.12 534,955.25 947 6,417.10 MWD (4) 11,475.74 88.53 8360 6,69626 6,61426 4,943.79 6,447.52 6,000,878.34 534,985.65 3.78 6,447.52 MWD (4) 11,504.87 89.32 83.3 6,696.80 6,614.80 4,947.08 6,47646 6,000,881.74 535,014.58 2.77 6,476.46 MWD(4) 11,536.61 92.67 86.21 6,696.25 6,614.25 4,949.94 6,508.9 6,000,884.73 535,046.16 13.71 6,508.06 MWo(4) 11,566.59 9326 87.99 6,694.70 6,612.70 4,951.46 6,537.96 6,000,886.35 535, 076A5 625 6,537.96 MWD (4) 11,609.00 93.26 87.% 6,692.29 6610.29 4.95294 6580.27 6,000,88800 535,118.36 0.00 6,580.27 PROJECTED IC TD BAKER ft gUGHES 1/3/2019 2:33: 10PM Page 4 COMPASS 5000.14 Build 85D THE STATE °f11. - - - GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3C -08A ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-161 Surface Location: 522' FNL, 1013' FEL, SEC. 14, T12N, R9E, UM Bottomhole Location: 954' FNL, 3008' FEL, SEC. 7, T12N, R10E, UM Dear Mr. Ohlinger: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W ww.aogcc.olaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair DATED this day of December, 2018. STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM( ON PERMIT TO DRILL 20 AAC 25.005 IF EECEIVED ,...,_ . 4 20118 1a. Type of Work: Drill ❑ Lateral ❑ Retlrill ' Reentry ❑ tb. Proposed Well Class: Exploratory - Gas ❑ Service - WAG Service - Disp ❑ Stratigraphic Test ElDevelopment - Oil ❑✓ Service- Wini ❑ Single Zone ❑� Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 1 c. Specify if well is proposed'for: Coalbed Gas ❑ Gas Hydrates El0 Geothermal ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: Blanket Q • Single Well ❑ Bond No. 5952180 • 11. Well Name and Number: KRU 3C -08A 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13100' TVD: 6656' 12. Field/Pool(s): Kuparuk River Pool / Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): Surface: 522' FNL, 1013' FEL, Sec 14, T12N, R9E, UM Top of Productive Horizon: 1161' FNL, 1288' FEL, Sec 12, T12N, R9E, UM Total Depth: 954' FNL, 3008' FEL, Sec 7, T12N, R10E, UM 7. Property Designation: rJpZ_ ADL 25629, ADL 25634 8. DNR Approval Number: 12,4, ff LONS 83-131 13. Approximate Spud Date:f2/' e� 12117,1'018 "Y 9. Acres in Property: 2560 14. Distance to Nearest Property: 6965' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 528558 y- 5995910 Zone- 4 10. KB Elevation above MSL (ft): 82' GL / BF Elevation above MSL (ft): 47' 15. Distance to Nearest Well Open to Same Pool: 14' (1R-31) 116. Deviated wells: Kickoff depth: 9941 , feet Maximum Hole Angle: 98 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 4844 • Surface: 4180 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8" 4.7# L-80 HYD511 3300' 9800' . 6555' 13100' - 6656' Uncemented liner w/ frac sleeves 19. PRESENT WELL CONDITION SUMMARY (To be completed for Retlrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 10234' 6839' N/A 10137' 6775' 10068' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 213 sx CS II 116' 116' Surface 5171' 9-5/8" 1580 sx AS III, 340 sx Class G 5206' 3732' Production 10185' 7" 450 sx Class G, 250 sx AS 1 10219' 6830' 11 Perforation Depth MD (ft): 9904' - 9921', 9938' - 9954', Perforation Depth TVD (ft): 6622' - 6634', 6645' - 6656', 9976'- 10004' 66716689' 6689' Hydraulic Fracture planned? YesO No ❑ 20. Attachments: Property Plat BOP SketchDrilling Diverter Sketch a Program Seabed Report Time v. Depth Plot Shallow Hazard Analysis 8 Drilling Fluid Program e 20 AAC 25.050 requirementse 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: James Ohlinger Contact Email: Klaith.E.Hefrin COP.Com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: 11131611145 Commission Use Only Permit to Drill Number: �(�—/ API Number: _�CJ1 50-�JL 2/ �/V ''C� Permit Approval Date: 1 1 See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: BOOP Ac -57t -1a 4500y�p_ S-/ -Samples req'd: Yes ❑,/WoFr Mud log req'd: Yes El o2 J`rf 1Y1L/6j/ �/YVCv777r / Z ✓�J Z�Orp�easures: Yes Lrj No❑,�r/ Directional svy req'd: Yes NoEl Spacing exception req'd: Yes ❑ Nov Inclination -only svy req'd: Yes ❑ No rLiv)� Post initial injection MIT req'd: Yes ❑ No Cr APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 'OnRit ^ t� A 1 Submit Form and m 10-401 Revised 512017 Th' s permit's valitl fo r t f pprpial per 20 AA/C �25.005(9) Attachments in Duplicate SS�rcorVT)...12 l 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 30, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill one lateral out of the KRU 3C-08 (PTD# 185-155) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in December 2018. The objective will be to drill one lateral KRU 3C -08A targeting the Kuparuk A -sand interval. The CTD completion is planned to isolate the 3C-08 perforations with solid liner. ConocoPhillips requests a lc - variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method to isolate/abandon 3C-08 with an expandable liner top packer and blank liner in the CTD completion. Hydraulic fracture stimulation is planned for this lateral after CTD operations are complete. A separate application for sundry approvals will be submitted prior to the fracture stimulation. Attached to the sundry application are the following documents: - 10-403 Sundry Application for KRU 3C-08 - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Wellbore Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 3C -08A - Detailed Summary of Operations - Directional Plans for 3C -08A - Proposed CTD schematic - Current Wellbore Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, *Y Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 3C -08A Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))...................................................................................................................2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5))................_.................................................,.................._............_.............................................2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 7. Diverter System Information ..........................................................................................................3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8))..................................................................................................................................................3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 3C -08A lateral .................................................... -................................................... 6 Attachment 2: Current Well Schematic for 3C-08............................................................................................................6 Attachment 3: Proposed Well Schematic for 3C -08A lateral...........................................................................................6 Page 1 of 6 November 28, 2018 PTD Application: 3C -08A Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed lateral described in this document is 3C -08A. The lateral will be classified as "Development -Oil' well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The lateral will target the A sand package in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 3C -08A. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,500 psi. Using the maximum formation pressure in the area of 4,844 psi in 3K-18 (i.e. 13.9 ppg E , the maximum f potential surface pressure in 3C-08, assuming a gas gradient of 0.1 psi/ft, would be 4,180 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 3C-08 was measured to be 4,241 psi (12.3 ppg EMW) on 10/26/2018. The maximum downhole pressure in the 3C-08 vicinity is the 3K-18 at 4,844 psi (13.9 ppg EMW) measured on 6/18/2018. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 3C-08 have injected gas, so there is a possibility of encountering free gas while drilling the 3C-08 lateral. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 3C-08 lateral will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3C-08 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 November 28, 2018 PTD Application: 3C -08A 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 16" 62.5 H-40 WELDED 36' 2-3/8", 4.7#, L-80, HYD511 blank 3C -08A 9800' 13,100'. 6473' 6574' liner; with frac sleeves and seal bore 36 J-55 BTC 35' 5206' • deployment sleeve Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 WELDED 36' 116' 36' 116' 1640 670 Surface 9-5/8" 36 J-55 BTC 35' 5206' • 35' 3732' 3520 2020 Production 7" 26 J-55 BTC 34' 10219' 34' 6830' 4980 4320 Tubing 3-1/2" 9.3 L-80 ELIE 8rd MOD 34' 9965' 34' 6663' 10160 10540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 12.4 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 3C -08A lateral we will target a constant BHP of 12.3 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 6 November 28, 2018 PTD Application: 3C -08A Pressure at the 3C-08 Window 9941' MD, 6647' TVD Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 3C-08 is a Kuparuk A sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize a single lateral to target the A -sands to the east of 3C-08. The laterals will improve recovery and capture lost resource associated with the KRU 1 R-31 long term shut in well. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge in the tandem wedge. CDR3-AC will mill a window in the tubing and production casing using the tandem wedge like a whipstock. CTD Drill and Complete 3C-08 Lateral: Pre -CTD Work 1. RU Slickline: Conduct dummy whipstock drift, set lock mandrel and check -set for inner wedge. 2. RUE -line: Set inner wedge. 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3C -08A Sidetrack a. Mill 2.80" window at 9941' MD. b. Drill 3" bi-center lateral to TD of 13000' MD. Page 4 of 6 November 28, 2018 Pumps On 1.8 bpm) Pumps Off A -sand Formation Pressure 12.3 4241 psi 4241 psi Mud Hydrostatic 8.6 2972 psi 2972 psi Annular friction i.e. ECD, 0.08psi/ft) 795 psi 0 psi Mud + ECD Combined no chokepressure) 3767 psi Underbalanced —474psi) 2972 psi Underbalanced —1269psi) Target BHP at Window 12.3 4251 psi 4251 psi Choke Pressure Required to Maintain Target BHP 484 psi 1279 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 3C-08 is a Kuparuk A sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize a single lateral to target the A -sands to the east of 3C-08. The laterals will improve recovery and capture lost resource associated with the KRU 1 R-31 long term shut in well. A recent rig workover installed tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge in the tandem wedge. CDR3-AC will mill a window in the tubing and production casing using the tandem wedge like a whipstock. CTD Drill and Complete 3C-08 Lateral: Pre -CTD Work 1. RU Slickline: Conduct dummy whipstock drift, set lock mandrel and check -set for inner wedge. 2. RUE -line: Set inner wedge. 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3C -08A Sidetrack a. Mill 2.80" window at 9941' MD. b. Drill 3" bi-center lateral to TD of 13000' MD. Page 4 of 6 November 28, 2018 PTD Application: 3C -08A c. Run 2-3/8" blank liner with frac sleeves and seal bore deployment sleeve back into the 3-1/2" tubing. 3. Freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. RU Slickline: Record SBHP, and dummy gas lift valves. 2. RU E -line: Set expandable liner top packer 3. Frac 3C -08A sidetrack. 4. RU Slickline: Install new gas lift design. 5. Return to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA un -deployment, the steps listed above are observed, only in reverse. Liner Running - The 3C-08 lateral will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. - While running 2-3/8" liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 5 of 6 November 28, 2018 PTD Application: 3C -08A 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plans - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name I Distance 3C -08A 1 6965' - - Distance to Nearest Well within Pool Lateral Name Distance I Well _ 1 3C -08A 14' 1R-31 1 16. Attachments Attachment 1: Directional Plans for 3C -08A lateral Attachment 2: Current Well Schematic for 3C-08 Attachment 3: Proposed Well Schematic for 3C -08A lateral Page 6 of 6 November 28, 2018 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C -O8 3C -08A Plan: 3C-08A_wp02 Standard Planning Report 02 August, 2018 BA UGHES a GE company ConocoPhillips BA ER ConoCO4iillIp5 Planning Report F IGHES BAT GE company Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-08 Wellbore: 3C -08A Design: 3C-08A_wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3C-08 Mean Sea Level 3C-08 @ 82.00usft (3C-08) True Minimum Curvature - Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) - System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3C Pad Site Position: From: Map Northing: Easting: 5,995,835.15usft 528,205.68usft Latitude: Longitude: 70° 23'58.955 N 149° 46' 13.622 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.22 ` Well 3C-08 Well Position +NIS 0.00 usft Northing: 5,995,910.44 usft Latitude: 70° 23' 59.683 N +E/ -W 0.00 usft Easting: 528,557.71 usft • Longitude: 149° 46'3.299 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 47.10 usft Wellbore 3C -08A Magnetics Model Name Sample Date Declination Dip Angle Field Strength ren BGGM2018 11/1/2018 16.89 80.92 57,440 Design 3C-08A_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,900.00 Vertical Section: Depth From (TVD) +N1S +E/ -W Direction (usft) (usft) (usft) (1) 47.10 0.00 0.00 90.00 Plan Sections Measured TVD Below Dogleg Build Tum Depth Inclination Azimuth System +NIS +EI -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (-1100ft) (°1100@) (-1100ftj (°) Target 9,900.00 49.18 54.07 6,538.23 4,623.77 4,976.14 0.00 0.00 0.00 0.00 9,941.00 48.91 54.03 6,565.10 4,641.95 5,001.20 0.66 -0.66 -0.10 -173.63 9,962.00 53.11 54.03 6,578.31 4,651.54 5,014.41 20.00 20.00 0.00 0.00 10,067.40 90.00 54.03 6,611.09 4,709.26 5,093.94 35.00 35.00 0.00 0.00 10,476.58 90.48 82.67 6,609.34 4,858.65 5,470.30 7.00 0.12 7.00 89.00 10,675.00 90.47 68.78 6,607.70 4,907.46 5,662.12 7.00 -0.01 -7.00 270.00 11,075.00 90.41 96.78 6,604.58 4,957.24 6,055.00 7.00 -0.01 7.00 90.00 11,325.00 90.39 79.28 6,602.61 4,965.80 6,303.87 7.00 -0.01 -7.00 270.00 11,475.00 97.79 86.75 6,592.10 4,984.01 6,452.16 7.00 4.93 4.98 45.00 11,625.00 90.32 94.16 6,581.48 4,982.78 6,601.57 7.00 -4.98 4.94 135.00 11,725.00 90.32 101.16 6,580.92 4,969.47 6,700.62 7.00 0.00 7.00 90.00 12,025.00 90.30 80.16 6,579.27 4,966.05 6,998.92 7.00 4.01 -7.00 270.00 12,450.00 90.26 109.91 6,577.15 4,929.19 7,417.53 7.00 -0.01 7.00 90.00 12,800.00 90.24 85.41 6,575.61 4,882.92 7,761.77 7.00 -0.01 -7.00 270.00 13,100.00 90.22 106.41 6,574.40 4,852.22 8,058.51 7.00 -0.01 7.00 90.00 822018 2.44:31PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips R ConocoPhillips Planning Report FLIGHES aGEcompany Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well X-08 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level Project: Kupamk River Unit MD Reference: 3C-08 @ 82.00usft (3C-08) Site: Kuparuk 3C Pad North Reference: True Well: 3C-08 Survey Calculation Method: Minimum Curvature Wellbore: 3C -08A MeasuredT Design: 3C-08A_wp02 Planned Survey MeasuredT Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth S tem +NIS +EI -W Section Rate Azimuth Northing Easting (usft) (_) (o) (usft) (usft) (usft) (usft) (`1100ft) (') (usft) (usft) 9,900.00 49.18 54.07 6,538.23 4,623.77 4,976.14 4,976.14 0.00 0.00 6000,552.74 533,515.65 TIP 9,941.00 - 48.91 54.03 6,565.10 4,641.95 5,001.20 5,001.20 0.66 -173.63 6,000,571.01 533,540.64 KOP 9,962.00 53.11 54.03 6,578.31 4,651.54 5,014.41 5,014.41 20.00 0.00 6,000,580.64 533,553.81 End 20 dls, Start 35 dls 10,000.00 66.41 54.03 6,597.41 4,670.78 5,040.92 5,040.92 35.00 0.00 6,000,599.98 533,580.25 10,067.40 90.00 54.03 6,611.09 4,709.26 5,093.94 5,093.94 35.00 0.00 6,000,638.66 533,633.11 End 35 dls, Start 7 dls 10,100.00 90.04 56.31 6,611.08 4,727.87 5,120.70 5,120.70 7.00 89.00 6,000,657.38 533,659.80 10,200.00 90.16 63.31 6,610.90 4,778.13 5,207.08 5,207.08 7.00 89.00 6,000,707.96 533,745.98 10,300.00 90.28 70.31 6,610.52 4,817.48 5,298.94 5,298.94 7.00 89.01 6,000,747.66 533,837.68 10,400.00 90.40 77.31 6,609.93 4,845.35 5,394.92 5,394.92 7.00 89.04 6,000,775.89 533,933.54 10,476.58 90.48 82.67 6,609.34 4,858.65 5,470.30 5,470.30 7.00 89.08 6,000,789.48 534,008.86 5 10,500.00 90.48 81.03 6,609.14 4,861.97 5,493.48 5,493.48 7.00 -90.00 6,000,792.89 534,032.03 10,600.00 90.47 74.03 6,608.31 4,883.55 5,591.06 5,591.06 7.00 -90.01 6,000,814.84 534,129.52 10,675.00 90.47 68.78 6,607.70 4,907.46 5,662.12 5,662.12 7.00 -90.07 6,000,839.02 534,200.47 6 10,700.00 90.47 70.53 6,607.49 4,916.15 5,685.56 5,685.56 7.00 90.00 6,000,847.80 534,223.88 10,800.00 90.46 77.53 6,606.69 4,943.65 5,781.63 5,781.63 7.00 90.01 6,000,875.66 534,319.84 10,900.00 90.45 84.53 6,605.89 4,959.23 5,880.35 5,860.35 7.00 90.07 6,000,891.61 534,418.48 11,000.00 90.43 91.53 6,605.13 4,962.67 5,980.22 5,980.22 7.00 90.13 6,000,895.43 534,518.33 11,075.00 90.41 96.78 6,604.58 4,957.24 6,055.00 6,055.00 7.00 90.18 6,000,890.29 534,593.12 7 11,100.00 90.41 95.03 6,604.40 4,954.66 6,079.86 6,079.86 7.00 -90.00 6,000,887.81 534,617.99 11,200.00 90.41 88.03 6,603.68 4,952.00 6,179.76 6,179.76 7.00 -90.01 6,000,885.52 534,717.89 11,300.00 90.40 81.03 6,602.98 4,961.52 6,279.24 6,279.24 7.00 -90.06 6,000,895.43 534,817.33 11,325.00 90.39 79.28 6,602.81 4,965.80 6,303.87 6,303.87 7.00 -90.11 6,000,899.80 534,641.94 a 11,400.00 94.10 83.00 6,599.87 4,977.34 6,377.89 6,377.89 7.00 45.00 6,000,911.62 534,915.91 11,475.00 97.79 86.75 6,592.10 4,984.01 6,452.16 6,452.16 7.00 45.15 6,000,918.57 534,990.14 9 11,500.00 96.55 88.00 6,588.98 4,985.15 6,476.94 6,476.94 7.00 135.00 6,000,919.80 535,014.91 11,600.00 91.57 92.93 6,581.89 4,984.33 6,576.62 6,576.62 7.00 135.16 6,000,919.37 535,114.59 11,625.00 90.32 94.16 6,581.48 4,982.78 6,601.57 6,601.57 7.00 135.51 6,000,917.92 535,139.54 10 11,700.00 90.32 99.41 6,581.06 4,973.93 6,676.02 6,676.02 7.00 90.00 6,000,909.35 535,214.01 11,725.00 90.32 101.16 6,580.92 4,969.47 6,700.62 6,700.62 7.00 90.03 6,000,904.98 535,238.63 11 11,800.00 90.32 95.91 6,580.50 4,958.34 6,774.76 6,774.76 7.00 -90.00 6,000,894.14 535,312.80 11,900.00 90.31 88.91 6,579.94 4,954.15 6,874.61 6,874.61 7.00 -90.03 6,000,890.33 535,412.66 12,000.00 90.30 81.91 6,579.41 4,962.15 6,974.22 6,974.22 7.00 -90.07 6,000,898.71 535,512.23 12,025.00 90.30 80.16 6,579.27 4,966.05 6,998.92 6,998.92 7.00 -90.11 6,000,902.70 535,536.91 12 12,100.00 90.30 85.41 6,578.88 4,975.47 7,073.30 7,073.30 7.00 90.00 6,000,912.41 535,611.24 12,200.00 90.29 92.41 6,578.37 4,977.38 7,173.21 7,173.21 7.00 90.03 6,000,914.70 535,711.14 12,300.00 90.28 99.41 6,577.86 4,967.09 7,272.62 7,272.62 7.00 90.06 6,000,904.79 535,810.58 12,400.00 90.27 106.41 6,577.38 4,944.77 7,370.03 7,370.03 7.00 90.10 6,000,882.85 535,908.06 12,450.00 90.26 109.91 6,577.15 4,929.19 7,417.53 7,417.53 7.00 90.13 6,000,867.45 535,955.62 13 12,500.00 90.26 106.41 6,576.92 4,913.62 7,465.04 7,465.04 7.00 -90.00 6,000852.06 536,003.18 822018 2.44.31PM Page 3 COMPASS 5000.14 Build 85 �. ConocoPhillips BA ER ConocoPhillips Planning Report BAT a 6E ,.,neon, Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3C Pad Well: 3C-08 Wellbore: 3C -08A Design: 3C-08A_wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 3C-08 Mean Sea Level 3C-08 @ 82.00usft (3C-08) True Minimum Curvature Planned Survey 140° 30' 44.680 W Target Name Diameter Diameter -hitimiss target Dip Angie Dip Dir. TVD +N/ -S +E/ -W Northing -Shape (°) (°) (usft) (usft) (usft) (usft) 3C -08A T04 0.00 0.00 6,574.00 246.241,148,194.37 6,000,544.00 - plan misses target center by 1140145.16usft at 13100.00usft MD (6574.40 TVD, 4852.22 N, 8056.51 E) - Point Measured 3C -08A T02 0.00 0.00 TVD Below 359.961,146,439.62 6,000,651.00 - plan misses target center by 1138389.97usft at 13100.00usft Vertical Dogleg Toolface Map Map Depth Inclination Azimuth Stem +N/ -S +El -W -Polygon Section Rate Azimuth Northing Fasting (usft) (') (°) (usft) (usft) (usft) Point Will (°llooft) (I (usft) (usft) 12,600.00 90.26 9941 6,576.47 4,891.29 7,562.45 Point 7,562.45 7.00 -90.02 6,000,830.11 536,10066 12,700.00 90.25 92.41 6,576.03 4,881.01 7,661.86 3C -08A T01 0.00 0.00 7,661.86 7.00 -90.05 6,000,820.21 536,200.10 12,600.00 90.24 85.41 6,575.61 4,882.92 7,761.77 376.831,146,736.71 7,761.77 7.00 -90.06 6,000,822.50 536,300.00 14 Casing Points Measured Vertical Depth Depth 12,900.00 90.23 92.41 6,575.20 4,884.82 7,861.69 13,100.00 61574.40 7,861.69 7.00 90.00 6,000,824.79 536,399.90 13,000.00 90.23 99.41 6,574.79 4,874.54 7,961.10 7,961.10 7.00 90.03 6,000,814.88 536,499.34 13,100.00 90.22 106.41 6,574.40 - 4,852.22 8,058.51 8,058.51 7.00 90.06 6,000,792.93 536,596.82 Planned TD at 13100.00 Targets 140° 30' 44.680 W Target Name Diameter Diameter -hitimiss target Dip Angie Dip Dir. TVD +N/ -S +E/ -W Northing -Shape (°) (°) (usft) (usft) (usft) (usft) 3C -08A T04 0.00 0.00 6,574.00 246.241,148,194.37 6,000,544.00 - plan misses target center by 1140145.16usft at 13100.00usft MD (6574.40 TVD, 4852.22 N, 8056.51 E) - Point 3C -08A T02 0.00 0.00 6,603.00 359.961,146,439.62 6,000,651.00 - plan misses target center by 1138389.97usft at 13100.00usft MD (6574.40 TVD, 4852.22 N, 8058.51 E) - Point 3608 CTD Polygon 0.00 0.00 0.00 239.561,144,972.00 6,000,525.00 - plan misses target center by 1136941.86usft at 13100.00usft MD (6574.40 TVD, 4852.22 N, 8058.51 E) -Polygon Point 0.00 0.00 0.00 6,000,525.00 Point 0.00 -412.11 282.48 6,000,114.01 Point 0.00 -112.62 1,488.73 6,000,418.08 Point 0.00 -255.91 3,152.37 6,000,281.16 Point 0.00 281.55 3,311.41 6,000,819.17 Point 0.00 376.61 1,441.57 6,000,907.08 Point 7 0.00 262.62 638.06 6,000,790.03 Point 8 0.00 0.00 0.00 6,000,525.00 3C -08A T01 0.00 0.00 6,611.00 103.561,145,229.51 6,000,390.00 - plan misses target center by 1137180.91 usft at 13100.00usft MD (6574.40 TVD, 4852.22 N, 8058.51 E) - Point 3C-08A_T03 0.00 0.00 6,581.00 376.831,146,736.71 6,000,669.00 - plan misses target center by 1138687.00usft at 13100.00usft MD (6574.40 TVD, 4852.22 N, 8058.51 E) - Point Casing Points Measured Vertical Depth Depth (usft) (usft) Name 13,100.00 61574.40 23/8" Fasting (usft) Latitude Longitude 1,676,629.00 70' 9' 40.821 N 140' 30'3.595 W 1,674,874.00 70° 9'44.537 N 140' 30'53.245 W 1,673,407.00 70' 9'45.550 N 140' 31'35.71 1,673,407.00 1,673,691.02 1,674,896.00 1,676,560.01 1,676,716.98 1,674,846.98 1,674,043.99 1,673,407.00 1,673,665.00 70' 9'43.847 N 140' 31'28.952 W 1,675,171.00 70° 9'44.259 N 140° 30' 44.680 W Casing Hole Diameter Diameter uU (in) 2375 3 Ono J 8/2/2018 2:44:31PM Page 4 COMPASS 5000.14 Build 85 - ConocoPhillips Local Coordinates B*ER Depth ConocoPhillips Planning Report +E/ -W UGHES (usft) (usft) (usft) a GE..pany Database: EDT Alaska Sandbox Local Co-ordinate Reference: Well 3C-08 4.976.14 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Mean Sea Level 4,641.95 Project: Kupawk River Unit MD Reference: 3C-08 @ 82.00usft (3C-08) 6,578.31 Site: Kuparuk 3C Pad North Reference: True 10,067.40 Well: 30-08 Survey Calculation Method: Minimum Curvature End 35 dls, Start 7 die Wellbore: 3C -08A 6,609.34 4,858.65 5,470.30 Design: 3C-08A_wP02 10,675.00 6,607.70 4,907.46 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NAS +E/ -W (usft) (usft) (usft) (usft) Comment 9,900.00 6,538.23 4,623.77 4.976.14 TIP 9,941.00 6,565.10 4,641.95 5,001.20 KOP 9,962.00 6,578.31 4,651.54 5,014.41 End 20 dls, Start 35 dls 10,067.40 6,611.09 4,709.26 5,093.94 End 35 dls, Start 7 die 10,476.58 6,609.34 4,858.65 5,470.30 5 10,675.00 6,607.70 4,907.46 5,662.12 6 11,075.00 6,604.58 4,957.24 6,055.00 7 11,325.00 6,602.81 4,965.80 6,303.87 8 11,475.00 6,592.10 4,984.01 6,452.16 9 11,625.00 6,581.48 4,982.78 6,601.57 10 11,725.00 6,580.92 4,969.47 6,700.62 11 12,025.00 6,579.27 4,966.05 6,998.92 12 12,450.00 6,577.15 4,929.19 7,417.53 13 12,800.00 6,575.61 4,882.92 7,761.77 14 13,100.00 6,574.40 4,852.22 8,058.51 Planned TO at 13100.00 aW018 2.44:31PM Page 5 COMPASS 5000.14 Build 85 e,- Baker Hughes INTEQ ConoeoPhillips Travelling Cylinder Report JUGHES a GE..,, Company: ConomPhillips (Alaska) Ina -Kup2 Project: Kuparuk River Unit Reference Site: Kuparuk 3C Pad Site Error: 0.00 usft Reference Well: 3C48 Well Error: 0.00 usft Reference Wellbore 3C -08A Reference Design: 3C-08A_wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 3C-08 3C-08 @ 82.00usft (3C-08) 3C-08 @ 82.00usft (3C-08) True Minimum Curvature 1.00 sigma OAKEDNI Offset Datum Reference 3C-08A_wp02 1R Pad- Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 256 -MIND Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,900.00 to 13,100.00usft Scan Method: Tmv. Cylinder North Results Limited by: Maximum center -center distance of 1,506.51 usft Error Surface: Pedal Curve Summary Kuparuk 1R Pad- Survey Tool Program Date 8/2/2018 Survey Program: 256 -MIND From To eNS Reference (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 9,900.00 3C-08 (3C-08) GCT -MS Schlumberger GCT multishot 9,900.00 13,100.00 30-08A_wri(3C-08A) MWD MWD - Standard Distance Deviation Warning Casing Points Depth Depth Measured Vertical (usft) Casing Hole ISI Depth Depth Offset Well - Wellbore - Design Diameter Diameter (usft) (usft) Name r) C) 13,100.00 6,656.40 23/8" 12.647.00 2-3/8 3 Summary Kuparuk 1R Pad- 1R-31 - 1R-31 - 1R-31 Survey Program: 256 -MIND AzimutM1 eNS Reference Offset Centre to No -Go Allowable r) Measured Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan loan) Offset Well - Wellbore - Design (usft) (usft) (usft) 12970.80 (usft) 12.647.00 Kuparuk 1R Pad 7621 143.64 12,975.57 8856.89 12.625.00 6,881.29 1R -31 -1R -31-1R-31 13,055.96 12,325.00 14.05 0.98 13.80 Pass - Minor 1/10 1R -33 -1R -33-1R-33 13,100.00 12,525.00 1,462.13 423.69 1,102.31 Pass - Major Risk Kupamk 3C Pad s6i 12.55190 6.022.47 76.39 142.80 12998.88 3C-08 - 3C-08 - 3C-08 12.52580 6,802.86 7844 142.58 13,005.15 Out of range Offset Design Kuparuk 1R Pad- 1R-31 - 1R-31 - 1R-31 Survey Program: 256 -MIND AzimutM1 eNS +EI -W Reference Gasel Distance Semi Major Axis r) Measured Vertical Measured vertical Reference Onset Depth Depth Depth Di 298.43 5.01 (usnl loan) (usft) Nsn) Nan) Nan) 12970.80 6,656.91 12.647.00 6,898.55 7621 143.64 12,975.57 8856.89 12.625.00 6,881.29 76.25 143.45 12991.14 6.656.07 12.600.00 6,81 76.29 143.23 12,906.07 6,656.05 12,57500 6,942.07 76.34 143.02 12,992.77 s6i 12.55190 6.022.47 76.39 142.80 12998.88 8656.80 12.52580 6,802.86 7844 142.58 13,005.15 6,656.77 12,500.00 6,783.28 76.49 142.36 13,011.67 6,655]5 12,475.00 6.763.72 76.55 142.14 13,018.41 6.856.72 12.450.00 6.744.18 76.60 144.91 13,025.40 6.6%.69 12,425.00 6,724.68 76.69 141.59 13.032.63 6,61 12,400.00 8,705.16 76]2 141.47 Offset side Enof: 0.00 gall Rule Assigned: Minor 1110 Cnad WellEnor: 0.00 use Thoraco, Onset wellbore Centra Casing- Cemre to No Go Allowa0le Wamin9 AzimutM1 eNS +EI -W Hole Size Contra Distance Deviation r) loan) lush) 1"1 Juan) Nan) lush) -45.42 5,057.70 7,956.30 3 298.43 5.01 298.18 Pass - Minor 1110 -44.97 5,044.07 7,969.34 3 277.21 476 27896 Pass - Minor 1110 -44.41 5,029.86 7.966.93 3 253.12 448 252.87 Pass -Minor 1110 -43.81 5,015.05 7,969.53 3 229.07 4.19 228.82 Pass -Minor 1110 .43.13 5,00023 7,974.12 3 205.05 3.89 20480 Pass. Minor 1110 42.36 4,905.42 7,978.73 3 181.07 3.59 180.82 Pass - Minor 1/10 41.46 4,970.58 7,983.36 3 157.14 3.27 156.89 Pas, - Minor 1/10 10.30 4,95572 7,988.01 3 133.26 2.95 13301 Pass - Minor 1/10 -38.99 4,940.85 7,992.70 3 109.46 2.82 109.21 Pass - Minor 1110 -37.07 4,925.96 7,997.41 3 6574 2.29 85.49 Pass - Minor 1110 -34.01 4,911.05 a.m.15 3 62.7 1.94 61.92 Pass - Minor 1110 13,040.13 6.6%.63 12.375.00 6,605.60 76.78 141.25 -27.03 4,898.12 8,097.92 3 38.93 1160 38.68 Pass -1 inorin0 13,047.90 6,6511.60 12.350.00 6,886.23 70.85 141.03 -6.33 4,881.17 8,011.71 3 17.19 1.27 16.94 Pi Minor 1110 13,055.96 6,61 12,325,00 6.646.79 7691 140.81 9203 4,868.21 81016.53 3 14.05 0.98 13.80 Pau.Mgp,r1na CC,ES,SF 13,064.31 6.81 12.300.00 6.627.37 76.98 140.58 12175 4,051.22 8,021.30 3 34.84 0.83 34.59 Pass -Minor VII CC - Min Comp, to renter h,mrrre nr rnvmmpnf mint SF- min acro rafier etHnr FR - min a9inan •enarealinn 82/1018 8:37:56AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Project. Kupamk Rlver Unit Site: Kuparuk SC Pad x.�amromie xo,m ueamw Non6 to nleee.0o neu WELLBORE DETAILS: 3C-OBA REFERENCE INFORMATION Parent Wellbore. comd�ie lNhl Reterenm: weliacae, ime wnn Well: 3C -OB 61eeyY�'S743B.1nn Wl0 Te MD: 9800.00 vSKWn(/ol Relgerce: Mee -sex Wellbere:3C-09A pPMgk: W.93• On smmn N8) Retaeire: aM N.O Plan: SC-0BA_wp02 (SC -08/3C -08A) MNm' Longitude @82..0eM 6enueea DePu Relmerce: 3Cae® ez.aoum11ca1 J:F� fi3l IR -33 5995910.44 cetageooP Menea: w.aaaa eumave Mean 7 6 O 660[ 6300 6000 5701 c x5401 0 51 Or 0 _4801 045M 0 42ot s 539M O N 3601 33K 3001 2T% BA%ES 09 WELL DETAILS: 3C-08 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 J:F� fi3l IR -33 5995910.44 528557.71 70° 23' 59.683 N 149° 46'3.299 W Sec MD Inc Azi TOSS +N/ -S +E/ -W Dleg TFace vSect Annotation 1 9900.00 49.18 54.07 6538.23 4623.77 4976.14 0.00 0.00 4976.14 TIP 2 9941.00 48.91 54.03 6565.10 4641.95 5001.20 0.66 -173.63 5001.20 KOP 3 9962.00 53.11 54.03 6578.31 4651.54 5014,41 20.00 0.00 5014.41 nd 20 End 20 cls, Start 35 dls 4 10067.40 90.00 54.03 6611.09 4709.26 5093.94 35.00 0.00 5093.94 End 35 cls, Start 7 dls 510476.58 90.48 82.67 6609.34 4858.65 5470.30 7.00 89.00 5470.30 5 610675.00 90.47 68.78 6607.70 4907.46 5662.12 7.00 270.00 5662.12 6 711075.00 90.41 96.78 6604.58 4957.24 6055.00 7.00 90.00 6055.00 7 811325.00 90.39 79.28 6602.81 4965.80 6303.87 7.00 270.00 6303.87 8 9 11475.00 97.79 86.75 6592.10 4984.01 6452.16 7.00 45.00 6452.16 9 1011625A0 90.32 94.16 6581.48 4982.78 6601.57 7.00 135.00 6601.57 10 11 11725.00 90.32 101.16 6580.92 4969.47 6700.62 7,00 90.00 6700.62 11 12 12025.00 90.30 80.16 6579.27 4966.05 6998.92 7.00 270.00 6998.92 12 13 12450.00 90.26 109.91 6577.15 4929.19 7417,53 7.00 90.00 7417.53 13 1412800A0 90.24 85.41 6575.61 4882.92 7761.77 7.00 270.00 7761.77 14 15 13100.00 90.22 106.41 6574.40 4852.22 8058.51 7.00 90.00 8058.51 Planned TD at 13100.00 Mean 7 6 O 660[ 6300 6000 5701 c x5401 0 51 Or 0 _4801 045M 0 42ot s 539M O N 3601 33K 3001 2T% BA%ES 09 West( -)/East(+) (300 usft/in) 6030 J:F� fi3l IR -33 6120 31 I I nd 20 d 35d Is, Ste TIP 3.Stan 35 dl6 4d[ I -31/I 13 10 -ll I Pla d C-0 at 13 3C-0 00.00 A 6210 I 41 a ~I West( -)/East(+) (300 usft/in) 6030 6120 6210 41 ~I I aa 6300 a 4 n 6390 6480 PI edT 3.113100 .0( 6570 3C. SI3C-0 A KOP: 6660' d 20 Is, Sm, 35 dls 57 8 9 6750 /111 6840 3111B 31 Enda dls.$ rt7ds '1R-3 /IR -3. 6930 ea L Vertical Section at 90.00" (90 ustVin) ConocoPhillips Pro)ect: Kuparuk River Untt SH.: Kuparuk 3C Ped N;'N,.1 2e e rMB WELLBORE DETAILS: 3C-0BA NEESBEMCE wfoBMAnory Parent Wellbore: 3C -0B CoaIie. IBI Re I,: IW- 4B, T1. Whh Well: 3C-08Mq..a. sv,I sr43aix.r Te on MD: 9900.00 Vid.11 RM. 3ca @62.00�sn(3caB) B.gkn NS)Refe . Slot -p.WM, o.aeS) Wellbore: 3C -0M Plan: 3C -08A 02 3C -0813C -08A ( ( Gm+rero. eoaz• O.M. Ifnrnf W. Meaurm nakelx Wa —WP aGG1.Wf _ M a@81w..Wre(3C08) UGHES aGEmmow 3K-Il/lK lipp � p � I lK-INW-16ALMI 0000 19500 ny yll'K 11 9000... yuM ops I '. W471 .11 aol 6ota � 8000 7500 7009.681[ II G �A IM �K IN J fYlk !K,11 .K I/ + vrt 6500 I 2 -1113 b 4] I i ISI]K IS I I 60005500 I< ui I 1 5000 0 4500 s 7Nsr iL I xbc Ix 1, ;; my L 4000 - smrl - 0 3500 N 3000 31C45/iC 11 .111, 91, 4 lc u,Can _roll ..n — Yit Mm 2500 a Ilt ll 4 I< i4l Iz-3: 2000ow . - It 6, 1500 µ nuuo v, 3CNAC- 10 1000 r}( C 1011C -1,11'O, 500 -. c -v' Ibis-I:P r,J• y II v II S n oo ( 1 I n x I n lcoTo% •__. _. 00 Icon c+,� I _Doo I250o 13000 13500 14000 14500 1500 3�Ct1{�1p3n/3rC�0$l�I-0I BIItIJlla-IJ l iC'39R'IiA�� -1 soo -A 000 500 0 100 1000 1500 200 b01P 1000 3s00 4000 4500 5000 '$500 6000 6500 7000 7500 5000 asoo 9000 9500 IOODU 10500 1100011500 h 19iC i 3C-nnF-np131 1: iC-IN3C-19 3C.)WIC- West(-)/East(+) (500 usft/in) 30-08 Q 82.OWSK(3C-08) 3c-0lnc I ac /m IJ 3C-f4nC-14B SC'-11MC-11AL1 l IC'-W.0-14A )GlIII 3C-15AC-Is 3C-08 Proposed CTD Schematic 16" 62# H-40 shoe @ 116' MD 9-5/8" 36# J-55 shoe @ 5206' MD A -sand perfs 9904'- 9921' MD 9938'- 9954' MD 9976'- 10004' MD 7" 26# J-55 shoe @ 10,258' MD 3-1/2" 9.3# L-80 EUE Tubing to surface 3-1/2" x 1-1/2" MMG Carrico gas lift mandrels @ 2955', 5271', 6972', 8179', 9071 & 9626'MD. Baker Premier packer @ 9655' MD 3-1/2" X -Nipple @ 9684' MD (2.813" min ID) Top of Tandem Wedge #1 Ass @ 9914' MD 3-1/2" X -Nipple @ 9933' MD (2.813" min ID) Top of Tandem Wedge #2 Ass @ 9934' MD 3-1/2" X -Nipple @ 9953' MD (2.813" min ID) Tubing tail @ 9965' MD Pro osed CTD Completion Run Length Description Depth ID Ball OD SST -SPAN Liner Top 1.877 2 PTSA Tie -Back Seals 1.781 10' Seal Bore Deployment Sleeve 2.250 2-3/8" Blank Liner, 4.6#/1t, L-80, Hyd511 R Profile Nipple 1.781 2-318" Blank Liner, 4.64/1t, L-80, Hyd511 Stg 4. Ball Dro Frac Sleeve 1.656 1.718 2-3/8" Blank Liner, 4.6#111, L-80, Hyd511 1 St 3: Ball Drop Free Sleeve 1.563 1.625 2-3/8' an Liner, 4.6#/ft, L-80, Hyd511 St 2: Ball DropFrac Sleeve 2-3/8" Blank Liner, 4.6#/R, L-80, Hyd511 Stg 1: Perf Joint (0.281". 3 SPF, 60"I Aluminum Ported Bull Nose dAsRe2-318" IM Sho De enl Sleeve o conurgt"sy Slatted Liner, 4.6#/ft, L-80, ST -L Solid Bull Nose rvtn e: aieeveaep'ns wn oe upaarea oasea on as onnea reseworr svaivaaon ano—nnrHurls— rnuueuny. Liner MUST be set on bosom. Bakerl-ok ported bull nose and 31oiMs if liner is split II► 3C -08A wp02 TD @ 13AW IAD 16" 62# H-40 shoe @ 116' MD 9-5/8" 36# J-55 shoe @ 5206' MD A -sand perfs - 9904' - 9921' MD 9938' - 9954' MD 9976' - 10004' MD 0,258' MD 3C-08 Final RWO Schematic 3-1/2" 9.3# L-80 EUE Tubing to surface 3-1/2" x 1-1/2" MMG Camco gas lift mandrels @ 2955', 5271', 6972', 8179', 9071 & 9626'MD. Baker Premier packer @ 9655' MD 3-1/2" X -Nipple @ 9684' MD (2.813" min ID) Top of Tandem Wedge #1 Ass @ 9914' MD 3-1/2" X -Nipple @ 9933' MD (2.813" min ID) Top of Tandem Wedge #2 Ass @ 9934' MD 3-1/2" X -Nipple @ 9953' MD (2.813" min ID) Tubing tail @ 9965' MD TRANSMITTAL LETTER CHECKLIST WELL NAME:�� (�y� PTD: Z-Z/R _A0 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: k4l( 4-E V -Cl �;yi✓yi POOL: 4ee,70 G. I� iC/Y �(n,� Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50 - (If last two digits , Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements er Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPARUK RIV UNIT 3C -0$A Program DEV Well bore seg PTD#:2181610 Company COLIOCOPHILLIPS ALASKA INC Initial Class/rype DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal n Geologic Commissioner: Date: Permit fee attached ............................. -...-. NA ... ..__ �i s 2 Lease number appropriate - - - - - - - --- - - - - - - - - Yes ... Surface Location lies within ADL0025634; Top Productive Interval lies ADL0.025629;. 3 Unique well name and number . . . .... . . . . .. . . . Yes - -in - - TO lies in ADL0025628.- 4 Welllocated in a -defined pool- - - - - - - - - - - - - - - - - - - _ - _ - Yes _ . _ KUPARUK RIVER,-KUPARUK RIV OIL --490100 5 .WellJocated proper distance from drilling unit.boundary_ - - - - - - Yes - Kuparuk River Oil Pool, governed by Conservation Order No. 432D 6 Well Jocated proper distance from other wells - - - - - - - - - - .. - _ - - _ _ Yes - - - - - Conservation Order No. 432D has no interwell. spacing -restrictions, Welibore.will be more than 500' 7 Sufficient acreage available in drilling unit- - _ - - - . _ - - _ _ _ _ - - - Yes - from an external property line. where, ownership or. landownership changes. As proposed, will 8 Jf deviated, is wellbore platincluded- - - - - - - - - - _ - _ - _ _ Yes - -well - - conform to. spacing requirements. - - - - 9 Operator only affected Darty- - .. - _ - _ . - - - - - - - _ - - .Yes - - - - - - - - - 10 Operator has appropriate bond in force - _ - - - - - - - . - - _ - _ - - Yes - Appr Date 11 Permit can be issued without conservation order. . . . . . . . . ...... . . . . . - Yes SFD 12/6/2018 12 Permit can be issued without administrative.approval - - .. - - - - - ... _ - - Yes - 13 Can permit be approved before 15 -day. waif _ - - - _ - - - - Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in. comments) (For. NA - - - - - - --- - - - - 15 All wells within 114 -mile area of review identified (For service well only). - - - - _ _ - _ - NA - _ - _ . 16 Pre -produced injector; duration of pre production less than 3 months(For service well only) . - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ 18 Conductor stringprovided... . . . . ... . . . . . . . . . . . . .. . . . ... . . . . .. . . . NA.. _ _ - _ Conductor set for.KRU_ 3C -0S Engineering 19 Surface casing. protects all known USDWs - - - -- - - - - - - - - - - - - - - - - - - - - - NA. - _ . _ . - _ Surface casing set in KRU 3C-08 - 20 CMTvol 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 CM.T.will cover all known productive horizons - . ... . . . . . .... . No... - - _ Productiveintervalwill be completed with -uncemented liner and fracked 23 Casing designs adequate for C, T, B $permafrost - - - - - - - - - -- - - - - - - - - - - Yes 24 Adequate tankage or reserve pit - - - - - - .. _ - - - - - Yes - .. - Rig has steel tanks; all waste to approved disposal wells. 25 Jf a -re -drill, has_a 107403 for abandonment been approved - - - - - - - -- - - - --- Yes .. - PTD 185-155,.Sundry 318-535- - 26 Adequate wellbore separation proposed - .. - _ - _ - - - .... - - .. - - Yes .. - - - _ Anti-colfiskm analysis complete; major risk failure KRU.1R-31. in reservoir 27 if diverter required, does it meet regulations- - - - --- - - - --- - - - - - - - - NA.- Appr Date 28 Drilling fluid program schematic & equip list adequate- - - - - - - - - - - --- - - - -- Yes - - _ Max formation pressure is 4844 psig(13.9 ppg EMW ); wil drill wl 6.6 ppg EMW and maintain overbal wl MPD VTL 12/17/2018 29 BOPEs, do they meet regulation _ - . _ - - .. - - - - - - - - .. Yes 30 BOPE Press rating appropriate; test to _(put psig in comments)- - - - .... - - - - - Yes .. - MPSP is 4180 psig; will test BOPs to 4500-psig. - 31 Choke manifold come -lies w/API RP -53 (May $4)- - - - - - - - - - - - - - - - - - - - - - -Yes 32 .Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes 33 Is presence of H2S gas probable - - - - - - - - - - - - - - - Yes ... _ H2$ measures required 34 Mechanical condition of wells within AOR verified (Forservicewell only) . - - - .. - ... NA _ _ _ _ _ ____ _ _ _ __ _ _ _ Geology 35 Permit can be issued w/o hydrogen sulfide measures ... - _ _ - .. ... - No - _ - 3C -Pad wells are H2S7bearing. H2S-measures are required. - - - 36 Datapresentedon potential overpressure zones . . . . . . ...... . . . _ - _ Yes - - Maximum potential. reservoir pressureJ$ 13.9 ppg.EMW;-expected reservoir pressure -is 12.3 ppg-EMW... Appr Date 137 Seismic analysis of shallow gas zones _ - - - - - - - - NA - - - _ . - Well will be drilled using.8,6 ppg mud, a coiled -tubing rig, and -managed -pressure drilling SFD 12/6/2018 38 Seabed condition survey.(if off -shore) .... - - - - - - - - NA - - _ .. technique to control formation pressures and stabilize shale.sections. NOTE; Chance of 39 Contact name/phone for weekly progress reports [exploratory only[ - .. NA - _ - - . - - encountering gas while drilling this.wellbore due.to gas.injection performed in this area.. Geologic Commissioner: Date: Engineering Commissioner: Date ommi loner Date �i s 1z4IB(1� (/z�ai� 1-t� tz�,�,l,�