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Home My WebLink About218-031MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, November 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-110 KUPARUK RIV UNIT 1H-110 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/26/2025 1H-110 50-029-23601-00-00 218-031-0 W SPT 3737 2180310 1500 718 730 727 720 220 340 340 340 4YRTST P Bob Noble 10/30/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1H-110 Inspection Date: Tubing OA Packer Depth 1360 2215 2180 2175IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN251103151423 BBL Pumped:0.8 BBL Returned:0.8 Wednesday, November 26, 2025 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:10-426 form from 1H PAD on 8-23-25 Date:Sunday, August 24, 2025 8:41:47 AM Attachments:image001.png MIT KRU 1H PAD SI TESTS 08-23-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s that were conducted on 8-23-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58+ 37' non witnessed shut in MITIA’s OPERATOR:FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1930200 Type Inj N Tubing 2300 2300 2300 2300 Type T 6334 BBL Pump 1.1 IA 460 1760 1730 1725 Interv 1584 BBL Return 1.0 OA 10 10 10 10 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1921290 Type Inj N Tubing 200 220 220 220 Type T 6489 BBL Pump 1.7 IA 170 1820 1780 1775 Interv 1622 BBL Return 1.6 OA 130 320 320 320 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2180310 Type Inj N Tubing 0 0 0 0 Type T 3737 BBL Pump 1.4 IA 250 1810 1770 1760 Interv 1500 BBL Return 1.4 OA 20 30 30 30 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu TYPE TEST Codes INTERVAL Codes Result Codes p, Kuparuk / KRU / 1H Pad Arend 08/23/25 1H-18 1H-20 1H-110 9 9 9 9 9 9 9 9 9 9 9 -5HJJ 1H-110 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: RPPG Treatment Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 105454'feet 8189'feet true vertical 3820' feet None feet Effective Depth measured 8189'feet 8052', 8254', 8580', 9113', 9200' feet true vertical 3793'feet 3737', 3819', 3950', 4105', 4117' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 9237' MD 4121' TVD Packers and SSSV (type, measured and true vertical depth) 8052' MD 8254' MD 8580' MD 9113' MD 9200' MD N/A 3737' TVD 3819' TVD 3950' TVD 4105' TVD 4117' TVD N/A N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 12. Stimulation or cement squeeze summary: Intervals treated (measured): RPPG pumped into Injector 1H-110. See Events for details. Treatment descriptions including volumes used and final pressure: Packer: HES Feed-Thru Packer Packer: HES Feed-Thru Packer Packer: HES Feed-Thru Packer Packer: HES TNT Packer Packer: Baker HRD-E ZXP LT Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 465-6471Staff Well interventions Engineer 3758-3804', 3834-3869', 4002-4023', 4092-4089', 4021-4017', 3977-3971', 3907-3901' 8102-8218', 8293-8379', 8712-9771', 9823-9837', 10077', 10091', 10200-10214', 10359-10373' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 120' ~~~ INJECTOR ~~ ~ measured TVD 7" 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-031 50-029-23601-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025638, ADL0025639 Kuparuk River Field/ West Sak Oil Pool KRU 1H-110 Plugs Junk measured Length Lower Completion Liner 9321' 1335' Casing 4128' 3825' 9359' 10535' 1822' 120'Conductor Surface Intermediate 20" 10-3/4" 80' 1862' 1773' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:16 pm, Aug 20, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.08.20 11:29:35-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne DSR-9/11/25J.Lau 11/4/25 RBDMS JSB 082525 DTTMSTJOBTYP SUMMARYOPS 7/22/2025 ACQUIRE DATA RIG UP FLOW CROSS, RUN HARDLINE AND REVERSE OUT SKID, SPOT SAND JET TANK. LAY LINER, SPOT BLENDER AND PUMP. SPOT CONTANER OF RPPG 7/23/2025 ACQUIRE DATA PUMP FULL BORE RPPG TO MBE IN D SAND LATERAL AT 8102' RKB. PUMPED 5908 LBS OF DAQING RPPG PRODUCT. RAPID INCREASE AS PRODUCT HIT MBE, FLUSH CALLED AT 2309 PSI @ 366 BBL JSV. CONTINUE TO SEE PSI INCREASE IN FLUSH, DROP RATE TO GET FLUSH VOLUME AWAY, MAX PSI 3029. JOB VOL 421 BBL WELL TO REMAIN SHUT IN FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 7/28/2025 DATA ACQUISITION (PRE SW) DEGAS IA (COMPLETE), LOAD IA (COMPLETE) PRE SW MIT-IA. 1H-110/ 1H-104 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By LAST TAG:1H-110 jennalt Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added RBP, catcher, sand, & swapped DMY to CV, 1H-110 1/25/2025 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE:jennalt Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR2019.2039.5 119.5 119.5 78.67 B SURFACE 10 3/4 9.95 40.5 1,862.2 1,772.9 45.50 L-80 Hydril 563 INTERMEDIATE 7 6.28 37.7 9,359.0 4,128.4 26.00 L-80 TXP BTC LOWER COMPLETION 3 1/2 2.92 9,199.6 10,534.5 3,825.4 9.30 L-80 Hyd 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.9 Set Depth… 9,237.2 Set Depth… 4,120.5 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.9 32.9 0.02 HANGER 10.813 Vetco MB228 4-1/2" Tubing hanger w/ parent bowl OD= 13.38" Vetco Grey MB228, PN: H38136 9-1, SN 5145448 -4 3.900 77.1 77.1 0.06 XO 4.500 XO 4-1/2" Hyd 563 box X 3-1/2" Hyd 563 pin CPAI MM# 1378409 5 2.992 2,507.22,232.9 59.06 GAS LIFT 5.968 3.5" X 1.5" MMG GLM w/DCR-1- SOV RKP latch, 2500 psi (SN: 257AG06) ( Assy #13) Camco MMG2.915 8,052.1 3,737.4 66.06 PACKER 5.996 HES Feed Through Packer #3 (SN: 0004010601-02 ) ( Assy #12) HES PN: 1027719 35, SN: SG 0004010 601-02 2.897 8,065.6 3,742.8 66.07 GAUGE 5.428 HES #3, EUE 8rd-m ROC-150 gauge, annulus pressure, (SN: 4513461411.018 ) HES PN: 1019189 25, gauge ser # ROC- 005482 2.973 8,083.3 3,750.0 66.08 NIPPLE 4.500 Camco 2.813 DS nipple EUE 8rd-m (SN: 5461-9 ) ( Assy #11) Camco 2.813 8,090.6 3,753.0 66.09 INJ 5.969 3.5" X 1.5" MMGW Mandrel w/ DV 8rd-m (SN: 730MZ01 ) Camco MMGW2.915 8,130.33,769.066.12 INJ 5.969 3.5" X 1.5" MMGW Mandrel w/ DV 8rd-m (SN: 769MZ01 ) ( Assy #10) Camco MMGW 2.915 8,254.2 3,818.8 66.50 PACKER 5.998 HES Feed Through Packer #2 (SN: 0004010601-03 ) ( Assy #9) HES PN: 1027719 35, SN: SG 0004010 601-03 2.897 8,267.9 3,824.3 66.48 GAUGE 5.430 HES #2, EUE 8rd-m, ROC-150 gauge, annulus pressure, (SN:4513461411.20) HES PN: 1019189 25, gauge ser # ROC- 005418 2.973 8,283.6 3,830.5 66.46 INJ 5.968 3.5" X 1.5" MMGW Mandrel w/ DV 8rd-m (SN: 733MZ01 ) ( Assy #8) Camco MMGW2.915 8,323.3 3,846.4 66.41 INJ 5.968 3.5" X 1.5" MMGW Mandrel w/ DV 8rd-m (SN: 747MZ01 ) ( Assy #7) Camco MMGW2.915 8,579.5 3,949.6 66.21 PACKER 6.000 HES feed through Packer #1 (SN:SG 3519029-04 ) ( Assy #6) HES PN: 1023123 78, SN: SG 3519029 -04 2.920 8,593.2 3,955.2 66.20 GAUGE 5.450 HES # 1, EUE 8rd-m, ROC-150, annulus pressure (SN: 4513461411.019) HES PN: 1019189 25, gauge ser # ROC- 005561 2.972 8,608.8 3,961.5 66.19 INJ 5.968 3.5" X 1.5" MMGW Mandrel w/ DV 8rd-m (SN: 734MZ01 ) ( Assy #5) Camco MMGW2.915 8,648.6 3,977.4 66.73 INJ 5.968 3.5" X 1.5" MMGW Mandrel w/ DV 8rd-m (SN: 725MZ01 ) ( Assy #4) Camco MMGW2.915 9,112.7 4,104.9 80.84 PACKER 5.875 HES TNT Packer (SN: SG 3369483-04 ) ( Assy #3) HES PN: 1017833 94, SN: SG 3369483 -04 2.949 1H-110, 8/11/2025 2:28:30 PM Vertical schematic (actual) LOWER COMPLETION ; 9,199.6-10,534.5 SLOTS; 10,358.9-10,373.1 SLOTS; 10,199.6-10,213.8 SLOTS; 10,076.7-10,090.9 SLOTS; 9,822.9-9,837.0 INTERMEDIATE; 37.7-9,359.0 NIPPLE; 9,166.5 PACKER; 9,112.7 IPERF; 8,712.0-8,771.0 INJ; 8,648.6 INJ; 8,608.8 PACKER; 8,579.5 IPERF; 8,293.0-8,379.0 INJ; 8,323.3 INJ; 8,283.6 PACKER; 8,254.2 RBP; 8,189.5 CATCHER; 8,184.2 SAND; 8,170.0 IPERF; 8,102.0-8,218.0 Hydraulic fracture; 8,102.0 INJ; 8,130.3 INJ; 8,090.6 NIPPLE; 8,083.3 PACKER; 8,052.1 GAS LIFT; 2,507.2 SURFACE; 40.5-1,862.2 CONDUCTOR; 39.5-119.5 HANGER; 32.9 KUP INJ KB-Grd (ft) 38.88 RR Date 6/3/2018 Other Elev… 1H-110 ... TD Act Btm (ftKB) 10,545.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292360100 Wellbore Status INJ Max Angle & MD Incl (°) 119.30 MD (ftKB) 10,545.00 WELLNAME WELLBORE Annotation LAST WO: End DateH2S (ppm)DateComment SSSV: NONE Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,166.5 4,112.7 82.57 NIPPLE 4.480 Camco 2.813" X nipple (2.813") (SN: 1 ) ( Assy 2) Camco PN: 218GX0 336, SN: 1 2.813 9,203.1 4,117.1 83.71 XO 3.500 XO 3-1/2" EUE 8rd-Mod Box X 12UN-2B Pin (Assy # 1) 3.013 9,234.2 4,120.2 84.63 SHOE 3.500 HES Self Align Muleshoe, 3-1/2" 12UN-2B Pin HES PN: 1027646 44, Ser # 4008029 .3 3.073 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,170.0 3,785.1 66.23 SAND 14' OF SAND ON TOP OF CATCHER 1/25/20250.000 8,184.2 3,790.8 66.29 CATCHER 2.72" CATCHER W/ RBP STINGER, OAL = 65" 1/24/20250.000 8,189.6 3,792.9 66.31 RBP 2.72" PIIP RBP W/ DEBRIS EXTENSION, MOE = 8192, OAL = 7.22' TTS PIIP 1/24/2025 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,507.2 2,232.9 59.06 1 INJ DMY RK 1 1/2 0.06/10/2018Schlumb erger MMG0.000 8,090.6 3,753.0 66.09 2 INJ DMY RK 1 1/2 0.0 11/11/2021 Schlumb erger 0.000 8,130.33,769.066.12 3 CVRK1 1/21/25/2025 CIRC ULATI NG VAVL E Schlumb erger 8,283.6 3,830.5 66.46 4 INJ DMY RK 1 1/2 0.0 1/3/2021 High Seal PKG Schlumb erger 0.000 8,323.3 3,846.4 66.41 5 INJ DMY RK 1 1/2 0.0 1/3/2021 High Seal PKG Schlumb erger 0.000 8,608.8 3,961.5 66.19 6 INJ DMY RK 1 1/2 0.06/3/2018Schlumb erger 0.000 8,648.6 3,977.4 66.73 7 INJ WFRV RK 1 1/2 0.08/26/2019500 BWP D Schlumb erger 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,199.6 4,116.7 83.61 PACKER 5.000 Baker HRD-E ZXP 5" x 7" ZXP Liner top packer L-80 Hyd 521 pin BakerPN: H296- 45- 0109ST1, Control # 104913215- 01 5.250 9,219.6 4,118.8 84.20 NIPPLE 5.000 Baker 5" "RS" Packoff Seal Nipple 15# L-80 Hyd 521 box x box BakerPN: H294- 01-0553, Control # 104357750 3 4.250 9,241.5 4,120.9 84.84 XO 5.000 Cross over Bushing, 5" Hyd 521 box X 3-1/2" Hyd 563 2.910 9,664.8 4,119.9 96.81 SLIDING SLEEVE 3.500 Baker CM Sliding sleeve, 3-1/2" 9.3# L-80 Hyd 563 SN: BakerPN: H810- 79-4439 2.810 9,719.2 4,112.4 99.20 XO-EXPANDING (3.5-3.85) 3.850 Cross over Bushing, 3-1/2" Hyd 563 box X 4-1/2" Hyd 563 pin 3.500 9,725.3 4,111.4 99.47 SWELL PACKER 5.760 TAM Swell Packer 5-3/4" OD, #4 ,SN# 50115961-5 TAM FreeCap SN# 50115961-5 3.890 9,735.7 4,109.6 99.95 XO 4.500 Cross over Bushing, 4-1/2" Hyd 563 box X 3-1/2" Hyd 563 pin 3.850 9,822.9 4,092.1 102.8 4 ICD 3.500 ICD # 4 HES Equiflow , 3-2-1 Nozzle Config, "A3 Sand" SN# LAF4014941A-01 HES ICD SN# LAF401494 1A-01 2.813 10,044.5 4,032.0 108.7 0 XO-EXPANDING (3.5-3.85) 3.850 Cross over Bushing, 3-1/2" Hyd 563 box X 4-1/2" Hyd 563 pin 3.500 10,050.7 4,030.0 108.8 6 SWELL PACKER 5.760 TAM Swell Packer 5-3/4" OD, #3 SN# 50115961-1 TAM FreeCap SN# 50115961-1 3.890 10,060.3 4,026.8109.0 7 XO 4.500 Cross over Bushing, 4-1/2" Hyd 563 box X 3-1/2" Hyd 563 pin 3.850 10,076.7 4,021.4 109.4 3 ICD 3.500 ICD # 3 HES Equiflow , 3-0-0 Nozzle Config "A4 Sand" SN# LAF2284A-01 HES ICD SN# LAF2284A- 01 2.813 10,117.0 4,007.7 110.3 2 XO-EXPANDING (3.5-3.85) 3.850 Cross over Bushing, 3-1/2" Hyd 563 box X 4-1/2" Hyd 563 pin 3.500 10,123.1 4,005.6 110.4 5 SWELL PACKER 5.760 TAM Swell Packer 5-3/4" OD, #2 ,SN# 50115961-4 TAM FreeCap SN# 50115961-4 3.890 10,132.8 4,002.2 110.6 7 XO4.500Cross over Bushing, 4-1/2" Hyd 563 box X 3-1/2" Hyd 563 pin 3.850 1H-110, 8/11/2025 2:28:33 PM Vertical schematic (actual) LOWER COMPLETION ; 9,199.6-10,534.5 SLOTS; 10,358.9-10,373.1 SLOTS; 10,199.6-10,213.8 SLOTS; 10,076.7-10,090.9 SLOTS; 9,822.9-9,837.0 INTERMEDIATE; 37.7-9,359.0 NIPPLE; 9,166.5 PACKER; 9,112.7 IPERF; 8,712.0-8,771.0 INJ; 8,648.6 INJ; 8,608.8 PACKER; 8,579.5 IPERF; 8,293.0-8,379.0 INJ; 8,323.3 INJ; 8,283.6 PACKER; 8,254.2 RBP; 8,189.5 CATCHER; 8,184.2 SAND; 8,170.0 IPERF; 8,102.0-8,218.0 Hydraulic fracture; 8,102.0 INJ; 8,130.3 INJ; 8,090.6 NIPPLE; 8,083.3 PACKER; 8,052.1 GAS LIFT; 2,507.2 SURFACE; 40.5-1,862.2 CONDUCTOR; 39.5-119.5 HANGER; 32.9 KUP INJ 1H-110 ... WELLNAME WELLBORE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,199.6 3,977.1 113.7 2 ICD 3.500 ICD # 2 HES Equiflow , 3-2-1 Nozzle Config " B Sand" SN# LAF4914940A-01 HES ICD SN# LAF491494 0A-01 2.813 10,263.3 3,950.0 116.0 9 XO REDUCING 3.850 Cross over Bushing, 3-1/2" Hyd 563 box X 4-1/2" Hyd 563 pin 3.500 10,269.8 3,947.1 116.1 6 SWELL PACKER 5.760 TAM Swell Packer 5-3/4" OD, #1 ,SN# 50115961-3 TAM FreeCap SN# 50115961-3 3.890 10,279.5 3,942.9 116.2 6 XO4.500Cross over Bushing, 4-1/2" Hyd 563 box X 3-1/2" Hyd 563 pin 3.850 10,358.9 3,907.2 116.9 4 ICD 3.500 ICD # 1 HES Equiflow , 3-1-0 Nozzle Config"D Sand" SN#LAF4014942A-01 HES ICD SN#LAF401 4942A-01 2.813 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,102.0 8,218.0 3,757.6 3,804.4 WS D, 1H-110 5/31/2018 6.0 IPERF 3.125" 6 SPF MILLENNIUM GUNS 60 DEG PHASE 8,293.0 8,379.0 3,834.3 3,868.7 WS B, 1H-110 5/31/2018 6.0 IPERF 3.125" 6 SPF MILLENNIUM GUNS 60 DEG PHASE 8,712.0 8,771.0 4,001.8 4,022.9 WS A2, 1H-110 5/31/2018 6.0 IPERF 3.125" 6 SPF MILLENNIUM GUNS 60 DEG PHASE 9,822.9 9,837.0 4,092.1 4,089.0 WS A3, 1H-110 5/22/2018 SLOTS HES Equiflow 3-2-1 NZL Config A3 sand SN# LAF4014941A-01 10,076.7 10,090.9 4,021.4 4,016.7 WS A4, 1H-110 5/22/2018 SLOTS HES Equiflow 3-1-2 NZL Config A4 sand SN# LAF2284A-01 10,199.6 10,213.8 3,977.1 3,971.3 WS B, 1H-110 5/22/2018 SLOTS HES Equiflow 3-2-1 NZL Config B sand SN# LAF4914940A-01 10,358.910,373.13,907.23,900.8 WS D, 1H-110 5/22/2018 SLOTS HES Equiflow 3-1-0 NZL Config D sand SN# LAF4014942A-01 1H-110, 8/11/2025 2:28:36 PM Vertical schematic (actual) LOWER COMPLETION ; 9,199.6-10,534.5 SLOTS; 10,358.9-10,373.1 SLOTS; 10,199.6-10,213.8 SLOTS; 10,076.7-10,090.9 SLOTS; 9,822.9-9,837.0 INTERMEDIATE; 37.7-9,359.0 NIPPLE; 9,166.5 PACKER; 9,112.7 IPERF; 8,712.0-8,771.0 INJ; 8,648.6 INJ; 8,608.8 PACKER; 8,579.5 IPERF; 8,293.0-8,379.0 INJ; 8,323.3 INJ; 8,283.6 PACKER; 8,254.2 RBP; 8,189.5 CATCHER; 8,184.2 SAND; 8,170.0 IPERF; 8,102.0-8,218.0 Hydraulic fracture; 8,102.0 INJ; 8,130.3 INJ; 8,090.6 NIPPLE; 8,083.3 PACKER; 8,052.1 GAS LIFT; 2,507.2 SURFACE; 40.5-1,862.2 CONDUCTOR; 39.5-119.5 HANGER; 32.9 KUP INJ 1H-110 ... WELLNAME WELLBORE ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 1H-110 50029236010000 2180310 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Originated: Delivered to:19-Feb-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-20 50-029-22112-00 909816966 Kuparuk River Leak Detect Log Field- Final 23-Jan-25 0 12 1A-20 50-029-22112-00 909816966 Kuparuk River Multi Finger Caliper Field & Processed 22-Jan-25 0 13 1A-20 50-029-22112-00 909816966 Kuparuk River Plug Setting Record Field- Final 22-Jan-25 0 14 1D-38 50-029-22961-00 909594223 Kuparuk River Multi Finger Caliper Field & Processed 16-Jan-25 0 15 1E-17 50-029-20793-00 909817737 Kuparuk River Plug Setting Record Field- Final 4-Feb-25 0 16 1E-22 50-029-20884-00 909817740 Kuparuk River Multi Finger Caliper Field & Processed 2-Feb-25 0 17 1E-22 50-029-20884-00 909817740 Kuparuk River Plug Setting Record Field- Final 3-Feb-25 0 18 1H-01 50-029-22330-00 909817089 Kuparuk River Multi Finger Caliper Field & Processed 7-Feb-25 0 19 1H-01 50-029-22330-00 909817089 Kuparuk River Plug Setting Record Field- Final 7-Feb-25 0 110 1H-110 50-029-23601-00 909817451 Kuparuk River Plug Setting Record Field- Final 24-Jan-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40111T40111T40111T40112T40113T40114T40114T40115T40115T40116190-162200-077182-116182-214193-006218-0312/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.02.20 11:39:57 -09'00'1H-11050-029-23601-00 909817451Kuparuk RiverPlugSetting RecordField- Final24-Jan-2501T4011606218-031 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2022-11-21_15889_KRU_1H-110_InjectionProfile_Rev_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15889 KRU 1H-110 50-029-23601-00 Injection Profile 21-Nov-22 Rev. Sep 2023 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 218-031 T37303Revision 10/5/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.05 09:08:06 -08'00' C:\Users\mdguhl\Desktop\2022-11-21_15889_KRU_1H-110_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15889 KRU 1H-110 50-029-23601-00 Injection Profile 21-Nov-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 218-031 T37303 By Meredith Guhl at 9:58 am, Nov 23, 2022 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.23 09:59:08 -09'00' MEMORANDUM To: Jim Reggj P.I. Supervisor �j 6(I Z1 Zfi'L FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1H-110 KUPARUK RIV UNIT 1H-110 Src: Inspector Reviewed By: P.I. Suprv� Comm Well Name KUPARUK RIV UNIT 1H-110 API Well Number 50-029-23601-00-00 Inspector Name: Bob Noble Permit Number: 218-031-0 Inspection Date: 8/1/2021 Insp Num: mitRCN210802093825 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-1100 Type In-' � W' TVD 3737 - TUbing 1038 1038 1038- 1038 PTD 2180310 Type Test: SPT Test psi YP BBL Pumped: 1.4- L Returned: 1500 - 1.2 IA OA 280 1790 - 1720 1715 - 495 _ 600 610 _ 610 - Interval 4YRTST IP/F _ P Notes: Wednesday, August 4, 2021 Page 1 of 1 ProActive Diagnostic Services, Inc. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Injection Profile RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Pr( 2) Signed Print Name: 2 18 03 1 3 13 10 ProActive Diagnostic Services, Inc. RECEIVE® Attn: Diane Williams OCTQ 130 West International Airport Road �+9 2919 Suite C /^t Anchorage, AK 99518 A` OGCC pdsanchoraaeOmemorvloa com 50-029-23601-00 Date :O " Yf O� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CDMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM https'readcasedhole-my. sharepoincwMpersoml/diene williams readcasedhole co Docum,,tsD DvivWAchi,e,UasterTemplateFilcsTemplateeDistnbutioN mr mittalSheets ConocoPhillips_Transmit,do� VS -11. ProActive Diagnostic Services, Inc. WELL LOG TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Profile 2) Signed Print Name: 2 1803 1 31139 ProActive Diagnostic Services, Inc. RECEIVED, Attn: Diane Williams AUG 2 9 2019 130 West International Airport Road Suite CAOGCC Anchorage, AK 99518 gdsanchoraseAmemorvloa.com 06 -Aug -19 1H-110 CD 50-029-23601-00 Date: J[q PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)246.8952 E-MAIL: PDSANCHORAGE(adMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM hnpv�/readcasedhole-my sharepvivuoMpersonal/diane_williams readcasedhole cvmTDcit s. Drive/Achives/MastelfemplateFiles TemplatesDisvibutioNTraysmittelSheets/ConocoPhillips_'Rer.s.iLdocs ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: 21F-031 C 11ED MAY 0 8 2019 AOGCC Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 5/6/2019 1J & 1H Well Name API If PTD# Initial top of cement Vol. of cement pum ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1J-180 50029233290000 2061500 20'9" 2.80 1'5" 5/4/2019 5 5/5/2019 11-1-101 50029235850000 2171380 2'10" 0.70 9" 5/4/2019 2.2 5/5/2019 1H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 50029235930000 2180030 2'2.5" 0.45 9" 5/4/2019 2.2 5/5/2019 1H-104 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 5/5/2019 1H-1088 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 11-1-109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 1H-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2 5/5/2019 IH -111 50029235810000 2171330 2' 0.35 9" 5/4/2019 2.2 5/5/2019 11-1-113 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 1.7 5/5/2019 1H-114 50029235840000 2171360 1'11" 0.25 7.5" 5/4/2019 1.8 5/5/2019 1H-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 2 5/5/2019 1H-116 50029235940000 2180120 17" 0.25 7" 5/4/2019 1.7 5/5/2019 1H-117 50029236020000 2180320 1'11" 0.35 7" 5/4/2019 1.7 5/5/2019 11-1-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 1 H-119 50029235910000 2171780 3' 0.80 8" 5/4/2019 1.8 5/5/2019 218U3'1 30 2 • •- TRANSMITTALDATE •Schlumbepger,TRANSMITTAL# • �' GCC PTS - PRINT CENTER •. 6411 A Street Alaska Anchorage, AK 99S18 333 W. 7th Ave, Suite rr r rr (907)273-4760 fax Anchorage, AK 99501 SERVICE ORDER SERVICE Color WELL NAME API # # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Prints CD's Tr nsmittal Recej t A Transmittal Receipt signature confirms that a package (box, II I envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The P in am Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy toJumberger and CPAI. point. Alaska PTSPrintCenter slb.com Tom,OsterkampPconoco hilli s.com JSLB Auditor- 'TL,ij Schlumberger -Private DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180310 Well Name/No. KUPARUK RIV UNIT 1H-110 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23601-00-00 MD 10545 TVD 3820 Completion Date 6/3/2018 REQUIRED INFORMATION / Mud Log No v/ DATA INFORMATION List of Logs Obtained: GR/Res/Den/Sonic LW D (Cement Evaluation) Well Log Information: Log/ Electr DD' Dataset Completion Status WAGIN Samples No ata igrtal Log Log Run Type Med/Frmt Number Name_ Scale Media No ED C 29448 Digital Data ED C 29448 Digital Data ED C 29448 Digital Data ED C 29448 Digital Data ED C 29448 Digital Data Log C 29448 Log Header Scans ED C 29499 Digital Data ED C 29499 Digital Data ED C 29499 Digital Data ED C 29499 Digital Data AOGCC Paas 1 of4 Current Status WAGIN UIC Yes Directional Survey Yes t/ (from Master Well Data/Logs) Interval OHI Start Stop CH Received Comments 2388 2616 7/2/2018 Electronic Data Set, Filename: CPAI_1 H- 110 TCP CORRELATION_31MAY18_UPCT_2606- 2406_UP_007_C.las 7896 8066 7/2/2018 Electronic Data Set, Filename: CPAI_1H- 110 TCP CORRELATION_ 31MAY18_UPCT_8040- 7913_UP_002O.las 7/2/2018 Electronic File CPAI_1H-110 TCP CORRELATION_ 31MAY18_UPCT_2606- 2406_UP_007 C.dlis 7/2/2018 Electronic File: CPAI_1H-110 TCP CORRELATION_ 31MAY18_UPCT_8040- 7913_UP_002C.dlis 7/2/2018 Electronic File CPAI_1H-110 TCP CORRELATION _31MAY18_UPCT.Pdf 0 0 2180310 KUPARUK RIV UNIT 11-1-110 LOG HEADERS 12 1872 7/9/2018 Electronic Data Set, Filename: CPAI_1H- 110_Scope_Gamma_Ray_LW D001_RM_LAS.las 9238 10544 7/9/2018 Electronic Data Set, Filename: CPAI_1 H- 110_VISION_Resistivity_LW D003_RM_LAS.las 1710 16825 7/9/2018 Electronic Data Set, Filename: CPAI_1H- 110_VISION_Service_LW D002_RM_LAS.las 601 9350 7/9/2018 Electronic Data Set, Filename: CPAI_1H- 110_VIS I ON_Resistivity_G R- MadPass_MD_RM_LAS.las Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11126/2018 Permit to Drill 2180310 Well Name/No. KUPARUK RIV UNIT 11-1-110 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23601-00-00 MD 10545 TVD 3820 Completion Date 6/3/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29499 Digital Data 12 10544 7/9/2018 Electronic Data Set, Filename: CPAI_1H- 110 VISION_Service_RM_LAS.Ias ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _1H- 110_Scope_Gamma_Ray_RM_DLIS_LW D001.diI s ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI_1H- 110_ Scope_Gamma_Ray_RM_DLIS_LW D001.ht ml ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _1H- 110_VISION_Service_RM_DLIS_LW D002.d1is ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _1H - 110_V ISION_Service_RM_DLIS_LW D002.html ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI 11-1- 110_VISION_Resistimtiy_RM_DLIS_LW D003.dlis ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI 1H- 110_ VISION_Resistivitiy_RM_DLIS_LW D003.ht ml ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI H- _111- 110—VISION—Service DLI 110_VISION_ServiceDLI S.dl is ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _11-1- H- 110—VISION—Service D 110_VISION_ServiceD L I S. htm I ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _1H - 110_V ISION_Service_2MD_RM.pdf ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI_1H- 110_VISION _Service_2T V D_Above90Degreel nc _RM.pdf ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _1H- 110—VISION — Service — 2TV D_RM.pdf ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _H - 110_V I S I ON_Service_5MD_RM.pdf ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _1H- 110_VISION— Service_5T V D_Above90Degreel nc _RM.pdf ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI _1H- 110_VIS ION_Service_5TV D_RM. pdf ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI 1H - 110_V I S I O N_Resi stivity_G R- MadPass_5MD_RM.pdf AOGCC Page 2 of Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180310 Well Name/No. KUPARUK RIV UNIT 1H-110 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23601-00-00 MD 10545 TVD 3820 Completion Date 6/3/2018 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI_11-1-110_Final Surveys.csv ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI 11-1-110 GWD005 EXCEL GYRO SURVEYS.xlsx ED C 29499 Digital Data 7/9/2018 Electronic File: CPAI 1H-110_GWD005 G y r o d ata Survey.docx ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD27 EOW Compass Surveys [Canvas].txt ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD27 EOW Compass Surveys [Macro].txt ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NA027 EOW Compass Surveys [Petrel].txt ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD27 EOW Compass Surveys [Surveys].bd ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD27 EOW Compass Surveys.pdf ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD83 EOW Compass Surveys [Canvas].txt ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD83 EOW Compass Surveys [Macro].bd ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD83 EOW Compass Surveys [Petrel].txt ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD83 EOW Compass Surveys [Surveys].txt ED C 29499 Digital Data 7/9/2018 Electronic File: 1H-110 NAD83 EOW Compass Surveys.pdf Log C 29499 Log Header Scans 0 0 2180310 KUPARUK RIV UNIT 1H-110 LOG HEADERS Well Cores/Samples Information: - -- Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED MH7(./ Pug,3 or-{ Monday. November 26. 2019 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180310 Well Name/No. KUPARUK RIV UNIT 1H-110 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23601-00-00 MD 10545 TVD 3820 Completion Date 6/3/2018 Completion Status WAGIN Current Status WAGIN UIC Yes Completion Report O Directional / Inclination Data DY Mud Logs, Image Files, Digital Data Y & Core Chips Y /6 Production Test Information Y A Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files 9 Core Photographs Y / A Geologic Markers/Tops V Daily Operations Summary YO Cuttings Samples Y /CV" Laboratory Analyses Y / If COMPLIANCE HISTORY Completion Date: 6/3/2018 Release Date: 4/23/2018 Description Date Comments Comments: Compliance Reviewed �v Date: ZC01 -- AOGCC Page 4 of Monday, November 26, 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION r'nRA REECEIVED JUN 2 6 208 IIVV �. WELL COMPLETION OR RECOMPLETION REPORT AWQMU ta. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ tb. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAGS WDSPL ❑ No. of Completions: Service R] Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 6/3/2018 218-031 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 6/16/2018 50-029-23601-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 139' FSL, 776' FEL, Sec 28, T12N, R10E, UM 5/27/2018 KRU 1H-110 Top of Productive interval: 9. Ref Elevations: KB:92.8i 17. Field / Pool(s): 1508' FNL, 78' FEL, Sec 34, T12N, R10E, UM GL: 64 BF: Kuparuk River Field/West Sak Oil Pool Total Depth: 10. Plug Back Depth MD/rVD: 18. Property Designation: 275' FNL, 3427' FEL, Sec 35, TI 2N, R1 OE, UM N/A ADL 26639,'A131_ 25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 549564 y- 5980842 Zone- 4 10546/3820 • 80-261, 931695000 TPI: x- 555556 y- 5979237 Zone- 4 12. SSSV Depth MD1TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 557476 y- 5980484 Zone- 4 N/A 1711/1641 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) NIA 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/Den/Sonic LAD (Cement Evaluation) 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD CASING GRADE AMOUNT FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 78.67 B 39 11939 119 42 Existing cement to surface 103/4 45.5 L-80 40 1862 40 1773 13 1/2 1054 sx 11.0ppg, Class G 189 7 26 7-80 38 9359 38 4128 8 3/4 805 sx 12.Oppg, Class G sx 15.8ppg, Class G 31/2 9.3 L-80 9200 10534 4117 3825 6 1/8 Uncemented Liner 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 31/2 9237 8052/3737, 8254/3819 PERFORATIONS @: ► 8579/3950, 9113/4105 8102-8218 MD and 3758-3804 TVD...5/31/2018 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8293-8379 MD and 3834-3869 TVD... 5/31/2018 COMPLETION Was hydraulic fracturing used during completion? y 9 9 P Yes ❑ No � 8712-8771 MD and 4002x1023 TVD...5/31/2018 DAT A ry i! Per 20 AAC 25.283 (i)(2) attach electronic and printed information SLOTS • VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 37 9823-9837 MD and 4092-4089 TVD... 5/22/2018 1 10077-10091 MD and 4021-4017 TVD... 5/22/2018 10200-10214 MD and 3977-3971 TVD... 5/22/2018 10359-10373 MD and 3907-3901 TVD... 5/22/2018 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A INJECTION ONLY - NOT PRE -PRODUCED Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Press. Casino Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (torr): 24 -Hour Rate V77- ql/ _l'8 Form 10-407 Revised 5/2017 /// CONTINUED ON PAGE 2 RBDMS.�. JUN 2 6 2018 Submit ORIGINIAL onlai'_ 28. CORE DATA Conventional Core(s): Yes ❑ No ❑Z Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No El If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base • 1711 1641 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8103 3760 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Sak Ugnu 5829 3109 TD 10545 3620 Formation at total depth: West Salk 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, paleontolooical renort. production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Ben Tolman 4S. Authorized Title: Ile Alaska Drillin Manager Contact Email: ben.v.tolman co .com Authorized! Contact Phone: 265-6828 Signature: t 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 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 512017 Submit ORIGINAL Only Wellhead /Tubing Hanger/ Tree c 13-3/8"X4-'i'1BTM,5M 1H-110 Injector Well Design 01 S D EN Insulated Conductor: 20" Casing Crossover below TH : 4-1/2" x 3-1/2" Tubing 13-%2" HOLE & 'f— 10-3/4" 45.5#, L-80 HYD563 @ 1,862 ft MD / 1,740' TVD RA/PIP Tags 3-1/2", 9.3 #, L-80, EUE/ HYD563 3-1/2" MMG with SOV Feed Through Packer #3: 8,052' MD Multi Drop Gauge Mandrel 2.812" Cameo DS Nipple Upper MMG-W Lower MMG-W Feed Through Packer #2: 8,254' MD Multi Drop Gauge Mandrel Upper MMG-W Lower MMG-W Feed Through Packer #1: 8,579' MD Single Gauge Mandrel Upper MMG-W Lower MMG-W Lower packer (non feedthrough): 9,113' MD 2.813" Cameo X Nipple (Final — Post Rig) "D" Sand Perforations: 8102'-8218'MD "B" Sand Perforations: 8293'-8379'MD WLEG Liner Top Hanger/Packer — 8-%" HOLE & 7" 26#, L-80, HYD563/TXP @ 9,359' MD / 4,129' TVD A4 perfs: No perfs (wet) A3 perfs: No perfs (wet) A2 perfs: 8712'-8771'MD A3 Baker WIV D � 6-1/8" HOLE & 3-1/2", 9.2#, L-80, HYD563 Shiftable ICD @ 10,545' MD / 3,820' TVD 5.75" OD Swell Packer CMU Sleeve ConooN illips JUaeka. Ix. I.".. M1Ta11a 3m.31 PM Last Tag veraalvlsneN(K AnmYlrm DO Dale Cep, l#Kel iad, MW By LASTTAG'. pennant ............................................................ ...... .._.._..... .......................... WNGER; 32.8 .............. Last Rev Reason ,m- Access.End Date LailMW ay Rev Reason l05id11 WREV 'sA Pulled RHC plug assembly (Post Rig( 6111/2018 em Casing Strings .........__.___._.._......_........... Casing Description Coup) ID (in) I Fiesta Set DepM,Ke) sHDepinlT D1... WULent.-Grace TonThread CONDUCTOR 20 1920 39.5 1195 1195 7867 B Casing Description OD un) IDC.) lop lXKel Set Deptn,tta) SH Death Bet)... WULen(It-Go". Top Thread SURFACE 10314 995 40.5 1.8622 1]]29 4550 L-80 Hydnl563 Casing Description OO lin) ID)M) top MUd% Set Depth MKED W ospin(CUR. WULen(11-Sued. Top1h is INTERMEDIATE J 6.28 3].7 9.3590 4128.4 2600 L-80 TXP BTC CONDUCTOR, 39.E-1195 Casino Descnplion on lin) to (in) Top MKS) SN Depth Main Sat Depth (ND)... WNLen II... Golan Top Thread LOWER COMPLETION 3112 2.92 9.199.6 10,534.5 3,8254 9.30 L-80 Hyd 563 SURFACE; W5_1,8622� Tubing Strings Tubtng description Slnng Ma... ID ltn) Top,Ka) $IN DepM Int. Sat De Pe 1D)[..WIUrain Grace Top Conneclton TUBING- 3112 2.99 32.9 923)2 41205 930 L-60 Hytl 563 CASUFTiC.Rai PRODUCTION Completion Details Topp D) Topm=I Nombal Top MIKEd tnMHl r) lose on' c=m 10 (in) 32.9 32.9 002 HANGER Voice M32284-112" Tubing Clanger wl parent bowl OD= 1338" 3.900 PACKER:a..1 77.1 77.1 0.06 XO XO 4-112" Hyd 563 box X }112" Hyd 553 pin 2992 CAU..'11.061 8052.1 3,]37.4 66.06 PACKER HES Feed Through Padoer# (N: i ) 2.897 NIPPIE; 0,WR3 ( Any #121 .,.,a- 8.065.6 3,7428 6607 GAUGE RESk3, DUE 8W -as RO-150gauge, annulus pressure, N: 2.973 4513461411 018) wJ8ale.� PERF. 0.1mO0 I,il0. 8,083.3 37500 6608 NIPPLE am.. 2.813 D5 nipple EUE 8rbm(SN '. 5461- ) Any 2813 #it) 8,090.6 3,7530 6609 INN .5"X14 MM WMantlrel W/ DV Brbm(SN: 730MZ01( 2915 PACKER; 9.24.2 8.130.3 3769.0 012 INJ .5"XTV- MMGW Mandrel w/DV 8nEm( N: 769MZOI )(Any 2915 GAugeaire #10) wJ: e.2m.e 8,2542 31818.8 W50 PACKER HES reare Thmugh Packer#2 N: 000401060143) 2897 ( Assy #9) 8,267S 3824.3 WAR GAUGE H #2, UE RII ROC -15 gauge, annulus pressure, 2. ]3 (SNA513461411.20) a 3a3 8.2836 3,8305 66A61NJ 5" X 16' MMGW Mandrel w/DV 8rdEm N 73WZOI Any 2.15 IPEaF. e,2noa.rani #8) 8,323.3 3.6464 6641 IND 3 So X 16"MMGW Merged wl OVBrd-m 85,: 747MZ Assy 2915 Man 8MS- 07) GAUGeaem.x 1 INJ:9.000.9 8.579.5 3,9496 64521 PACKER e t tough Packer#1 (N: 351 9029-04 Assy 2920 #6) INJ:aegOs 8,5932 3,9552 BE 20 GAUGERES rbm,R -15, annulus pposesee(SN '. 2972 4513461411.019) IFERP.0.712INSTU ll 6,606.8 3,961.5 filo INJ - "M WMantlrel wl DV 6Mm (SN J MZ01(Any 2.915 #5) PACKER:9U27 8,KIM 6 3874 66.73 INJ 5'X I S"MM WMantlrel pal DV BpErD N'.J5MZ1 Assy 2.15 #4) NIPPIE;stme 9,1127 4,1049 8084 PACKER HES NTPmc r (SN: SG 336948304 ) (Any #3) 9,166.5 4.112.7 82.57 NIPPLE Camw 2.813' X nipple (2813')SKI 11 (Any 2) 2.813 9203.1 4,1171 8371 XO XO3-112"EUE 8d -Mod Box 12UN-2B Pin (Assy A 1) 3.013 9.234.2 4,120.2 84.63 SHOE HES Self Align Muleshoe, 3-112"12UN-2B Re ]DG, Perforations 6 Slots Snot Den Top IND) Man (WD) (an.m INTERMEDIATE; 37 N),aA.� Top MKO) Sam loan) MKD) (Nall LInMM Zona Dace I, Ty, Co. 8,102.0 8,218.0 3,757.6 3,8044 WS 01H-110 5/3112018 6.0 IPERF 3 125" 65PF MILLENNIUM GUNS 60 DEG PHASE 8,293.0 8,379.0 3,834.3 3,868.7 WS B. 111-110 5012018 SO PERF 77FTgFF ILLENNIUM GUNS 60 DEG PHASE 5,712.0 8,771.0 4,001.8 4,022.9 WE A2, IH -1 105012018 SO (PERF 3.12 " 6 LLENNIUM GUNS 60 DEG PHASE 9,822.9 9,837.0 4,092.1 4,009.0 WSA3, 1H-110 5222018 SLOTS HES gm0.w 3 -1 NZL Config A3 sand Spite SLOTaam2G UdC. LAF4014941A-01 10,0763 10,090.9 4.0214 4,016.7 WSA4, IH -110 51222016 SLOTS ES Equ,ow 3-1- NZL Config A4 salty SN# wl-zze4A-01 10,199.6 10,213.8 39]].1 3,971.3 WE B,111410 5122/2018 SLOTS H Equ,oW -IN L atoTs: ,.ma T -,,Oils IAF4914. Config B sand SN# 10,356.9 10373.1 3,907.2 3,9008 WE D, 111-110 72-92-018 SLOTSH 11 1 NZL 0al.nd Config D and SN# LAF4014942A-0i GkF40 Mandrel Inserts St s1 -01S; 10, 1. S -10.213a as H Top nVO) Valve Latin PortSw TRO Run Top IRKa) MKa) Make Madel Do (in) Ssry Type Type (in) ard) Run Oah Co. 1 2,507.2 amgo MMG 112 OODD 00 5,102 18 2 8090.6 3,]53.0 Camw MMGW 112 fi132 1 3 8,130.3 3,769.0 Camco MMGW 11/2 00 fi11112 118 500 BWP D JWFRV 4 8,2036 3.830.5 Camco MMGW 1112 602o18 5 8.3233 3,6464 Camw MM W 1112 K 00 61102018 BWP D fi 8,fi08.8 3,9615 amwMM W 1112 K 6/32016 LONER COMPLEUON: l W gino.s. Islas ConowPhillips Ales", Inc. KUP INJ 1H-110 1 1 N110. F1112m.9.32.92 PM va�Iewium(xrowl _.._.................................................... . ...... ............. XNiGER: 92B� .............................................. ............. .............................. L Mandrel Inserts s1 an on N T.P"ROB) TOP RVDI ryIXal Make Model OD(ln) Sery Valva Type faro —a Rod Bre so) TRO Run (Paq R.. Oak Co. 7 8,648.6 3.9])4 C.mcD MM W 1 V2 INJ WFRV RK 00 &112018 0 I BWP CONDUCTOR, 5B.S11R3 D Notes: General & Safety Ena Dale Annotation SURFACE..11,882.— NOTE GaS LIR;$AT.2 PACKER', BW21 GAU.R $.8 NIPPLE 8,0839 INJ',.,f .,.a - IW B1L9 IPERF; .,1L208,2180� PACKER,:] 2 WAGE', �B2.B IW', B,ffi1.8 IW',8933 IFERF:.,]H3.Od,3R0� GAUGE 8,B'12 IW:9,BYB IW: B,BIBS IPERF:B.T120BT110� PACKER;B112T NIPPUS%l99. NTERMED.;927d,9990— .LOTS:$sII.Ba.6910 u sLms: to.oTa.nm.aeaa�pl SLOT.: 1019961,2198 IfI#I` stmS.1035.9103n1 LOWER COMPLET. Operations Summary (with Timelog Depths) 1 H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime End Tme Dur(hr) F Phase Op Cotle A Wty Cotle Tme P -T -X operation Start Depth (WB) End Depth (WB) 5/15/2018 5/15/2018 0.50 MIRU MOVE MOB P Move from 1H-117 to 1H-110. Pull 0.0 0.0 18:00 18:30 pipe shed away from sub. 5/15/2018 5/15/2018 1.00 MIRU MOVE MOB P Pull out motor, pump, & pits modules. 0.0 0.0 18:30 19:30 5/15/2018 5/15/2018 0.50 MIRU MOVE MOB P Skid sub to move position. Install 0.0 0.0 19:30 20:00 tongue on front of sub base. 5/15/2018 5/15/2018 1.00 MIRU MOVE MOB P Move sub base off of 1 H-117. 0.0 0.0 20:00 21:00 5/15/2018 5/15/2018 2.00 MIRU MOVE MOB P Spot mats from lH-117 to 1H-110. 0.0 0.0 21:00 23:00 Spot sub base over 1 H-110. Skid sub to drill position. Remove tongue from sub base. 5/15/2018 5/16/2018 1.00 MIRU MOVE MOB P Back pits module into place & set. 0.0 0.0 23:00 00:00 5/16/2018 5/16/2018 0.50 MIRU MOVE MOB P Back in pump module & set. Hook up 0.0 0.0 00:00 00:30 lines between pump & pits modules. 5/16/2018 5/16/2018 0.50 MIRU MOVE MOB P Spot motor complex. 0.0 0.0 00:30 01:00 5/16/2018 5/16/2018 1.00 MIRU MOVE MOB P Spot pipe shed module. Hook up inner 0.0 0.0 01:00 02:00 connects on all modules. 5/16/2018 5/16/2018 3.00 MIRU MOVE RURD P Continue rig up between modules, 0.0 0.0 02:00 05:00 install skate ramp, start hooking up electrical. Berm up cellar; hook up steam, water, & air. Rig acceptance checklist completed. Rig accepted @ 05:00 hrs. 5/16/2018 5/16/2018 2.75 MIRU MOVE NUND P Install flow riser on annular; install 0.0 0.0 05:00 07:45 hydraulic hoses to annular & knife valve; take on spud mud; align & secure annular; air up boots; install mouse hole; check high pressure connections & safety cables; obtain RKB's; post diverter signs. 5/16/2018 5/16/2018 1.00 MIRU MOVE RURD P PU 4.5" elevators & slips; make up a 0.0 0.0 07:45 08:45 stand of 4.5" DP for diverter test; tag bottom of mouse hole at 89.88' MD. 5/16/2018 5/16/2018 1.25 MIRU MOVE BOPE P RIH w/ a stand of 4.5" OR Function 0.0 0.0 08:45 10:00 test diverter. Perform Diverter Test - Knife valve open in 7 sec; annular closed in 22 sec; initial system pressure 3075 psi; pressure after closure 1950 psi; 200 psi recharge time 7 sec; full recharge 44 sec; 6 nitrogen bottles avg pressure 2125 psi; test gas, flow, & pit level alarms. Test witnessed by AOGCC Rep Adam Earl. 5/16/2018 5/16/2018 0.25 MIRU MOVE PULD P PU 4 joint & RIH, tagging bottom of 0.0 0.0 10:00 10:15 conductor at 104.2', lay down single & rack back stand. 5/16/2018 5/16/2018 3.25 MIRU MOVE BHAH P Mobilize BHA, 4.5" subs & XO's to rig 0.0 - 0.0 10:15 13:30 floor. Load, strap & tally BHA & DP. Make up HWDP w/ jam & NMFC racking back in the derrick. Back on shore power @ 12:30 hm. 5/16/2018 5/16/2018 1.50 MIRU MOVE SHAH P Make up & scribe 13.5" BHA 1 as per 0.0 104.0 13:30 15:00 1 1 SLB DD to 104' MD. 5/16/2018 5/16/2018 0.75 MIRU MOVE SEQP P Flood lines & conductor to check for 104.0 104.0 15:00 15:45 I leaks, good. Test high pressure mud lines to top drive 3000 psi, SHT MWD & gyro. Page 1/17 Report Printed: 611912018 G,--rations Summary (with Timelog DeNihs) ft-'j 111-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (m) Phase - Op Code Activity Code .Time P -T -X - Operation Start Depth (MB) End Depth (111<13) 5116/2018 5/16/2018 1.25 SURFAC DRILL DDRL P Directional drill 13-112" surface hole f/ 104.0 203.0 15:45 17:00 104'-203' MD, 203' TVD, 450 gpm, 530 psi on, 480 psi off, FO 279%, 40 rpm, Tq on 2K, off 1K, WOB 8K, PU 62K, SO 69K, ROT 67K, ART .93, ADT.93, BIT.93, Jars 70.72. Total Footage 99' 5/16/2018 5/16/2018 1.00 SURFAC DRILL SHAH P Carry scribe to NMFC, make up 203.0 203.0 17:00 18:00 stabilizer above 1st NMFC in the stand & RIH. 5/16/2018 5/1712018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/7' surface hole f/ 203.0 592.0 18:00 00:00 203'-592' MD, 591' TVD, 450 gpm, 900 psi on, 560 psi off, FO 28%, 60 rpm, Tq on 5K, off 3K, WOB 25K, PU 70K, SO 78K, ROT 78K, ART 1.94, ADT 3.41, BIT 4.34, Jars 74.13. Total Footage 389' 5/17/2018 5/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 592.0 1,138.0 00:00 06:00 592'-1138' MD, 1120' TVD, 553 gpm, 1335 psi on, 1050 psi off, FO 32%, 60 rpm, Tq on 5K, off 3K, WOB 25-30K, PU 88K, SO 90K, ROT 89K, ART 2.76, ADT 3.91, BIT 8.25, Jars 78.04. Total Footage 546' 5/17/2018 5/17/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface hole f/ 1,138.0 1,872.0 05:00 12:00 1138'-1872' MD, 1782' TVD, 552 gpm, 1580 psi on, 1230 psi off, FO 31%, 50 rpm, Tq on 7K, off 2K, WOB 25-30K, PU 102K, SO 96K, ROT 97K, Max Gas 8295, ART 2.52, ADT 4.49, BIT 12.74, Jars 83.46. Total Footage 734' TO 1872' MD; 1782' TVD. 5/17/2018 5/17/2018 0.75 SURFAC CASING CIRC P CBU f/ 1872'-1800' MD, 552-698 gpm, 1,872.0 1,800.0 12:00 12:45 1290-1735 psi, FO 31-36%, 60 rpm, Tq 3K, PU 99K, SO 94K, obtain survey & final T/D. 5/17/2018 5/17/2018 3.75 SURFAC CASING BKRM P BROOH V 1800'-758' MD, 550 gpm, 1,800.0 758.0 12:45 16:30 1060 psi, FO 30%, 60 rpm, Tq 2K, PU 83K, SO 89K. 5/17/2018 5/17/2018 0.25 SURFAC CASING OWFF P Monitorwell, static. SIMOPS blow 758.0 758.0 16:30 16:45 doom TD. 5/17/2018 5/17/2018 1.00 SURFAC CASING SHAH P Rack back 4.5" HWDP in the derrick & 758.0 205.0 16:45 17:45 lay down 5" HWDP V 758'-205' MD. 5/17/2018 5/17/2018 2.00 SURFAC CASING SHAH P PJSM, rack back NMFC & lay down 205.0 0.0 17:45 19:45 BHA 1 as per SLB DD. 5/17/2018 5/17/2018 0.50 SURFAC CASING SHAH P Clear & clean rig floor. 0.0 0.0 19:45 20:15 5/17/2018 5/17/2018 1.75 SURFAC CASING RURD P Pick up rasing handling equipment, 0.0 0.0 20:15 22:00 make up CRT, mobilize pup joint & hanger to floor. Verity 46 joints in the shed. 5/17/2018 5/17/2018 0.50 SURFAC CASING PUTS P Make up shoe track for 10-3/4", 45.5#, 0.0 169.0 22:00 22:30 L-80, Hydril 563 surface casing. PU shoe joint installing 2 bow spring centralizers IVY either end, spacer joint w/ same centralizer configuration & float collar joint w/ a centralizer 10' up from FC & one on the collar. Check floats, good. 5/17/2018 5/18/2018 1.50 SURFAC CASING PUTB Run 10-3/4", 45.5#, L-80, Hydril 563 169.0 691.0 22:30 00:00 surface casing f/ 169'-691' MD, SO IP I 62K, bow spring centralizer on each collar, torque to 19,400 ff/Ibs. Page 2/17 Report Printed: 6 /1 912 01 8 Operations Summary (with Timelog Depths) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan note End Time Dur(hr) Phase Op Code Activity Code lime P-T-% Operation start Depth (fiKB) EM Depth (fiKB) 5/18/2018 5/18/2018 0.75 SURFAC CASING PUTS P Run 10-3/4", 45.5#, L-80, Hydril 563 691.0 950.0 00:00 0045 surface casing f/ 691' MD to 950' MD'. Pushing mud away, slowed running speed, losses cont. Lost 10 bbls on the last 10 joints. Slop RIH to condition hole. P/U= 85K, S/0= 77K. 5/18/2018 5/18/2018 1.00 SURFAC CASING CIRC P Circulate and condtion hole, stage 950.0 950.0 00:45 01:45 pumps up slowly f/ 1 bpm= 80 psi to 3.5 bpm= 70 psi. P/U=81 K, S/0= 80K., 5/18/2018 5/18/2018 3.25 SURFAC CASING PUTB P Cont to run 10-3/4", 45.5#, L-80, Hydril 950.0 1,862.0 01:45 05:00 563 surface casing f/ 950' MD to 1824' MY. M/U 10-3/4" Hyd 562 space out, hanger and landing joint. Wash casing down 1 bpm= 150 psi. Land on casing hanger @ 1862'.17' MD. P/U= 116K, S/0= 105K. 5/18/2018 5/18/2018 4.00 SURFAC CEMENT CIRC P Circulate and condtion mud for 1,862.0 1,862.0 05:00 09:00 cement job as per MI. Stage pumps up f/ 1 bpm=150 psi to 8 bpm= 294 psi. Mud weight of 9.5 ppg, YP=23. SIMOPS, hold PJSM for cementing surface casing. 5/18/2018 5/18/2018 3.25 SURFAC CEMENT CMNT P Cement 10-3/4" surface casing. Pump 1,862.0 0.0 09:00 12:15 5 bbis of CW-100 and test lines to 3,500 psi, good. Reciprocate pipe (PUW = 117k, SOW= 107k) and pump 35 bbls of CW-100 @ 5.5 bpm, 115 psi. Pump 77 bbls of Mud Push II W/ red dye @ 5.0 bpm, 127 psi. Drop bottom plug & pump 358 bbls of 11.0 ppg LiteCRETE lead slurry @ 5.5 bpm, 222 psi. followed by 55.6 bbls of 12.0 ppg DeepCRETE tail slurry @ 5.5 bpm, 272 psi. Drop top plug. Chase with 10 bbls of water. Rig displace with 9.5 ppg Spud Mud @ 7.5 bpm, 350 psi. Landed hanger after pumping all lead cement, POW=133K, SOW= 76K. Bumped plug @ 1595 strokes. 117 bbls of 11.0 ppg lead cement returned to surface. 5/18/2018 5/18/2018 0.75 SURFAC CEMENT PRTS P Pressure up to 830 psi ( 500 psi over 0.0 0.0 12:15 13:00 FCP) hold for 5 min, bleed to 0. I Pressure up to 3000 psi f/ 30 min to test 10-3/4" casing, good. Bleed off and check floats, good. 5/18/2018 5/18/2018 2.50 SURFAC CEMENT RURD P Rig down CRT, casing equipment, & 0.0 0.0 13:00 15:30 lay down landing joint. Flush diverter system w/ black H2O. SIMOPS clean cement from mud manifold. 5/18/2018 5/18/2018 2.50 SURFAC CEMENT NUND P Nipple down surface risers system & 0.0 0.0 15:30 18:00 lay down via BOP deck. NO diverter tee & knife valve, removing via BOP deck. Remove GE surface adapter. 5/18/2018 5/18/2018 1.25 SURFAC WHDBOP NUND P Nipple up GE wellhead per GE Rep. 0.0 0.0 18:00 19:15 Orient wellhead w/ 3-point laser to conductor & cellar punch marks. 5/18/2018 5/18/2018 0.25 SURFAC WHDBOP PRTS P Test seals between hanger & wellhead 0.0 0.0 19:15 19:30 to 2000 psi for 15 minutes, witnessed by CPAI Rep. 5/18/2018 5/19/2018 4.50 SURFAC WHDBOP NUND P Nipple up BOPE, Dutch riser adaptor, 0.0 0.0 19:30 00:00 flow nipple, choke &kill lines. Torque all connection to specs. Page 3117 Report Printed: 6119/2018 G,,orations Summary (with Timelog DeNchs) i 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log - StartTime End Tme Dor (hr) Phase Op cede A00y Code Tme P-T-X Opeaffon Start Depth (111K8) -. EM Depth(RKB) 5/19/2018 5/19/2018 0.50 SURFAC WHDBOP NUND P Finish torque flanges on ROPE & 0.0 0.0 00:00 00:30 secure BOP stack. SIMOPS rig up to test BOPE. 5/19/2018 5/19/2018 6.00 SURFAC WHDBOP BOPE P PJSM, Test BOPE with 7", 4-1/2" and 0.0 0.0 00:30 06:30 3-1/2" test joint to 250 psi/3500 psi for 5 min on chart.Test 1: 7" TJ Annular, CV # 1,12,13, 14, 4" kill line & XT39 dart. 2: 7" TJ Upper rams, CV # 9,11, Mezzanine kill valve & XT-39 FOSV. 3: CV # 8,10 & HCR kill 4: CV # 6 & 7, XT-43 dart valve. 5; Super choke & manual choke to 2500 psi. 6: CV #2,5.7: Super choke & manual choke to 2500 psi & showed bleed off. 8: Blind rams, CV #3,4. 9: 3- 1/2" TJ Annular, HCR choke & XT-43 FOSV(FP ann leaking by). 10: 3-1/7' TJ Annular, manual choke & upper IBOP. 11: 3-112 TJ, lower 3-1/2" X 6 VBRs & lower IBOP 12:4-1/2" TJ, 3- 1/2" X 6 VBRs. Koomey draw down test: System pressure= 3050 psi, after closing = 1750 psi Attained 200 psi after 8 seconds, Attained full pressure after 54 seconds. Six bottles nitrogen avg= 2200 psi Tested all pits level, flow, & gas alarms. 1 FP on test 9, annular leaking by. Functioned several times & retested good. Jeff Jones of AOGCC waived witness. 5/19/2018 5/19/2018 1.00 SURFAC WHDBOP RURD P Remove test plug, install 12-1/4" ID 0.0 0.0 06:30 07:30 wear bushing, RILDS X2. Blow down test equipment, choke & kill lines. 5/19/2018 5/19/2018 0.50 SURFAC CEMENT BHAH P Mobilize BHA 2 to the dg floor. 0.0 0.0 07:30 08:00 - 5/19/2018 5/19/2018 0.75 SURFAC CEMENT SVRG P Service TD. 0.0 0.0 08:00 08:45 5/19/2018 5/19/2018 2.00 SURFAC CEMENT SHAH P PJSM, pick up 8-3/4" BHA2 as per 0.0 390.0 08:45 10:45 SLB DD to 390' MD, PU 60K, SO 70K. 5/19/2018 5/19/2018 1.25 SURFAC CEMENT TRIP P TIH f/ 390'-1635' MD on 4-1/2" DP 390.0 1,635.0 10:45 1200 1from derrick. j 5/19/2018 5/19/2018 1.00 SURFAC CEMENT DHEQ T Attempt to shallow hole test MWD, 1,635.0 1,635.0 12:00 13:00 trouble shoot. SIMOPS test OA valve to 3000 psi for 5 minutes, good. 5/19/2018 5/19/2018 1.00 SURFAC CEMENT EQRP T Change out MWD transducer on 1,635.0 1,635.0 13:00 14:00 standpipe. 5/19/2018 5/19/2018 0.50 SURFAC CEMENT DHEQ P Shallow hole test MWD 518 gpm, 790 1,635.0 1,635.0 14:00 14:30 psi, FO 29%, test good. 5/19/2018 5/19/2018 0.25 SURFAC CEMENT COCF P Wash down f/ 1635-1762'10D, 518 1,635.0 1,762.0 14:30 14:45 gpm, 790 psi, FO 29%, tag TOC Cry 1762' with 5K. 5/19/2018 5/19/2018 2.50 SURFAC CEMENT DRLG P Drill up 9' of cement, plugs, float collar, 1,762.0 1,872.0 14:45 17:15 & shoe f11762'-1872' MD, 525 gpm, 830 psi, FO 29%, 70 rpm, Tq 3-5K, W08 5-15K, PU 88K, SO 83K, ROT 86K. Page 4/17 Report Printed: 6/1912018 Operations Summary (with Timelog Depths) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Op..Con Start Depth (8KB) End Depth mKa) 5/19/2018 5/19/2018 0.25 SURFAC CEMENT DDRL P DDrill 8-3/4" hole f/ 1872'-1892' MD, 1,872.0 1,892.0 17:15 17:30 1799' TVD, 528 gpm, on 858 psi, off 842 psi, FO 29%, 70 rpm, Tq on 3K, off 2K, WOB 2K, PU 88K, SO 83K, ROT 86K, Max gas 30. Total Footage 20' MD. SCR @ 1853' MD, 1763' TVD, MW 9.5 ppg, 17:00 hrs #1 @ 20=20 psi, @ 30=50 psi #2 @ 20=20 psi, @ 30=40 psi 5/19/2018 5/19/2018 1.00 SURFAC CEMENT CIRC P Circulate & condifion 9.5 ppg mud @ 1,892.0 1,825.0 17:30 18:30 1 600 gpm, 1062 psi, FO 29%, 70 rpm, Tq 2K. Rack back 1 stand. 5/19/2018 5/19/2018 1.00 SURFAC CEMENT FIT P Rig up & perform FIT -@ the shoe1862' 1,825.0 1,892.0 18:30 19:30 MD, 1790' TVD to EM W of 12.0 ppg with 9.5 ppg mud. Pump 6 strokes(.6 bbl), pressuring up to 235 psi. Record shut in pressure for 10 minutes, 235 psi initial, 118 psi final. Rig down test equipment & run in hole w/ partial stand to 1892' MD. 5/19/2018 5/20/2018 4.50 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/ 1892'-2300' MD, 1,892.0 2,300.0 19:30 00:00 2119' TVD, 600 gpm, on 798 psi, off 782 psi, FO 29%,150 rpm, Tq on 5K, off 3K, WOB 2-4K, PU 94K, SO 86K, ROT 89K, Max gas 533, Bit 2.71, jar 2.71, ADT 2.71. Total Footage 408' MD. Displaced well to 9.0 ppg LSND mud while drilling 1st stand of new formation. SCR @ 2015' MD, 1932' TVD, MW 9.0 ppg, 21:30 hrs #1 @ 30=60 psi, @ 40=80 psi #2 @ 30=60 psi, @ 40=80 psi 5/20/2018 5/20/2018 6.00 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/ 2300' MD to 3033' 2,300.0 3,033.0 00:00 06:00 MD, TVD= 2435'. Pump @ 590 gpm= 830 psi on. 820 psi off w/ 29% FO. Rotate @ 120-150 rpm's w/ 5-8K Tq on, 4K Tq off. WOB= 2-6K, ECD- 10.06 ppg. Mas gas= 286. P/U= 98K, S/O= 77K, ROT= 87K. ADT= 4.4, Total bit hours= 7.11, Total Jar hours= 7.11 5/20/2018 5/20/2018 6.00 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/ 3033' MD to 3500' 3,033.0 3,500.0 06:00 12:00 MD, TVD= 2541'. Pump @ 469 gpm= 570 psi on. 572 psi off w/ 25% FO. Rotate @ 100 rpm's w/ 3-5K Tq on, 4K Tq off. WOB= 3K, ECD= 10.16 ppg. Mas gas= 30. P/U= 102K, S/0= 75K, ROT= 87K. ADT= 4.49, Total bit hours= 11.60, Total Jar hours= 11.60. No issues observed when drilling coals sections f/ 2850' MD to 3100' MD and 3300' MD to 3500' MD. Slowed pump rate to 460 gpm and rotary to 100 rpm's while drilling coals. Kick w/ drilling drill @ 10:00 hrs, CRT 1:45 Obtained SPRs @ 3070' MD, TVD= 2446;, MW= 9.0 ppg, 6:30 hours MP#1: 20 spm= 80 psi, 30 spm= 120 psi MP#2: 20 spm= 80 psi, 30 spm= 120 psi Page 5117 Report Printed: 6/19/2018 Uperations Summary (with Timelog Depths) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SGATmre End Time our hr) Phase Op Code Acdvity Code Ti me P -T -X Operation Soal epth (RKB) End Depth(AKB) 5/20/2018 5/20/2018 6.00 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/ 3500' MD to 4102' 3,500.0 4,102.0 12:00 1800 MD, TVD= 2683'. Pump @ 500 gpm= 715 psi on. 705 psi off w/ 28% FO. Rotate @ 80=120 rpm's w/ 2-7K Tq on, 4K Tq off. WOB= 1-4K, ECD= 9.97 ppg. Max gas= 165. P/U= 104K, S/0= 78K, ROT= 89K. ADT= 4.22, Total bit hours= 15.82, Total Jar hours= 15.82. 5/20/2018 5/21/2018 6.00 PROD? DRILL DDRL P DDrill 8-314" hole f/ 4102'MD to 5162' 4,102.0 5,162.0 18:00 00:00 MD, TVD= 2941'. Pump @ 620 gpm= 1216 psi on. 1200 psi off w/ 29% FO. Rotate @ 110 rpm w/ 1 OK Tq on, 71K Tq off. WOB= 5K, ECD= 10.58 ppg. Max gas= 199. P/U= 115K, S/0= 74K, ROT= 92K. ADT= 4.26, Total bit hours= 20.08, Total Jar hours= 20.08. Obtained SPRs @ 4400' MD, TVD= 2941', MW= 9.0 ppg, 19:30 hours MP#1: 30 spm= 180 psi, 40 spm= 200 psi MP#2: 30 spm= 180 psi, 40 spm= 200 psi 5/21/2018 5/21/2018 6.00 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/5162-6310'MID, 5,162.0 6,310.0 00:00 06:00 3223' TVD, 600 gpm, 1353 psi on. 1342 psi off, 2S% FO, 120 rpm, 11 K Tq on, 81K off, WOB 10-15K, ECD 10.89, Max gas 50, PU 132K, SO 72K, ROT 96K. ADT 4.35, Bit Hrs 24.43, Jar Hrs 24.43. 5/21/2018 5/21/2018 6.00 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/ 6310'-7071' MD, 6,310.0 7,071.0 06:00 12:00 3409' TVD, 500 gpm, 1058 psi on. 1028 psi off, 29% FO, 100 rpm, 10K Tq on, 7K off, WOB 12K, ECD 10.54, Max gas 51, PU 130K, SO 70K, ROT 99K. ADT 3.96, Bit Hrs 28.39, Jar Hrs 28.39. Obtained SPRs @ 6400' MD, TVD= 3247', MW= 9.2 ppg, 06:30 hours MP#1: 30 spm= 250 psi, 40 spm= 300 psi MP#2: 30 spm= 250 psi, 40 spm= 300 psi 5/21/2018 5/21/2018 6.00 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/ 7071'-7737' MD, 7,071.0 7,737.0 12:00 18:00 3615' TVD, 565 gpm, 1353 psi on. 1340 psi off, 28% FO, 120 rpm, 9-12K Tq on, 91K off, WOB 9-11 K, ECD 10.72, Max gas 56, PU 144K, SO 75K, ROT 107K. ADT 4.32, Bit Hrs 32.71, Jar Hrs 32.71. 5/21/2018 5/22/2018 6.00 PROD1 DRILL DDRL P DDrill 8-3/4"holef/7737'-821 O'MD, 7,737.0 8,210.0 18:00 00:00 3802' TVD, 600 gpm, 1469 psi on. 1460 psi off, 28% FO, 120 rpm, 9-12K Tq on, 9K off, WOB 9-12K, ECD 10.47, Max gas 25, PU 149K, SO 78K, ROT 11 OK. ADT 4.72, Bit Hrs 37.43, Jar Hrs 37.43. Obtained SPRs @ 7830' MD, TVD - 3650', MW= 9.0+ ppg, 18:30 hours - MP#1: 30 spm= 220 psi, 40 spm= 280 psi MP#2: 30 spm= 220 psi, 40 spm= 280 psi Page 6117 ReportPrinted: 6119/2018 Operations Summary (with Timelog Depths) 111-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Time Ehd Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (flKB) End Dep1h(110) 5/22/2018 5/22/2018 6.00 PRODt DRILL DDRL P DDrill 8-3/4" hole f/8210'-8,950"MID, 8,210.0 8,950.0 00:00 06:00 4,073'' TVD, 600 gpm, 1,780 psi on. 1,720 psi off, 28% FO, 120 rpm, 9-12K Tq on, 9K off, WOB 9-12K, ECD 11.05, Max gas 33, PU 159K, SO 81K, ROT 112K. ADT 4.27, Bit Him 41.7, Jar Hrs 41.7. 5/22/2018 5/22/2018 4.00 PROD1 DRILL DDRL P DDrill 8-3/4" hole f/ 8,950" MD - 9,368' 8,950.0 9,368.0 06:00 10:00 MID, 4,131' TVD, 600 gpm, 1,871 psi on. 1,839 psi off, 29% FO, 120 rpm, 12K Tq on, 9K off, WOB 10-17K, ECD 11.17, Max gas 49, PU 162K, SO 74K, ROT 112K. ADT 2.82, Bit Hrs 44.52, Jar Him 44.52. 5/22/2018 5/22/2018 0.50 PRODt CASING CIRC P Rotate and reciprocate from 9,366'- 9,368.0 9,352.0 10:00 10:30 9,286' MD. with 700 GPM @ ICP - 2,443 PSI, FCP - 2,135 PSI DPP. 32% Flo, at 80 RPM. 10K TO. IECD - 11.32 / FECD - 11.15. UP WT= 148K DWN WT = 78K. ROT - 112K, Total strokes pumped = 6,106. 5/22/2018 5/22/2018 0.50 PRODi CASING OWFF P OWFF LD single and observe well for 9,352.0 9,352.0 10:30 11:00 flow. (STATIC) 5/22/2018 5/22/2018 7.00 PROD1 CASING BKRM P BKRM OOH from 9,352' MD -6,800' 9,352.0 6,800.0 11:00 18:00 MD. UP WT = 103K. 700 GPM @ 2,135 (NEW MUD), FCP-2,163 PSI. 32 % F/O. 140 RPM with 1 OK TQ, IECD - 11. 15, FWCD = 11.19. 5/22/2018 5/23/2018 6.00 PROD1 CASING BKRM P BKRM OOH from 6,800' MD -4,143' 6,800.0 4,143.0 18:00 00:00 MD. UP WT = 80K. 650 GPM @ 1,474 PSI , FCP - 1,437 PSI. 32 % F/O. 140 - 120 RPM with 6-8K TQ, IECD - 11.06 FWCD = 10.99. 5/23/2018 5/23/2018 6.00 PROD1 CASING BKRM P BKRM from 4,143'MD-2,000'MD 4,143.0 2,000.0 00:00 06:00 with 550 GPM @ 770 PSI DPP. 32 % F/0. 120-140 RPM. 6K TQ. ECD = 10.15 UP WT with pumps on =85K. 5/23/2018 5/23/2018 0.50 PROD1 CASING BKRM P BKRM from 2,000' MD to 1,860' MD 2,000.0 1,860.0 06:00 06:30 with 550 GPM @ 770 PSI, 32% F/O. 140 RPM 6 TQ ECD = 9.98 PPG. UP WT with pumps = 83K. 5/23/2018 5/23/2018 1.00 PROD1 CASING CIRC P Rotate and recip at casing shoe from 1,860.0 1,860.0 06:30 07:30 1,860'- 1,780' MD while pumping at 750 GPM 1,185 PSI DPP. 80 RPM 1- 3K TQ. UP WT 83K. RWT = 82K. pump 15 BBP Hid Vis sweep. 5/23/2018 5/23/2018 0.25 PROD1 CASING OWFF P Observe well for flow while BD Top 1,860.0 1,860.0 07:30 07:45 Drive. 5/23/2018 5/23/2018 1.50 PROD1 CASING TRIP P Continue to POOH with 4 1/2" DP 1,860.0 -38 9-0 07:45 09:15 from 1,860'-389'MD. UP WT=64K, DW WT = 69K. Monitor disp via TT. 5/23/2018 5/23/2018 4.25 PROD1 CASING BHAH P PJSM / LD 8 3/4" BHA from 389' to 389.0 0.0 09:15 13:30 surface. Clean dg floor and flush flow lines. 5/23/2018 5/23/2018 0.50 PROD1 CASING RURD P Wash stack @ 900 GPM PD and rig 0.0 0.0 13:30 14:00 up GBR. 5/23/2018 5/23/2018 1.00 COMPZN CASING RURD P Continue to RU GBR handling tools. 0.0 0.0 14:00 15:00 5/23/2018 5/23/2018 1.00 COMPZN CASING PUTB P PJSM RIH with 7" 261E L-80 TXP CSG 0.0 0.0 15:00 16:00 1 shoe and JT 2. During MU crushed top of shoe JT. Page 7117 Report Printed: 6/19/2018 ONerations Summary (with Timelog DeNtns) •I_ 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log - SW Tune - Edd Time. Der(hr). Phase OP Code Activity Code .Time P -T -X Operation Start Depth (W) End Depth(KKB) 5/23/2018 5/23/2018 2.00 COMPZN CASING PUTB T LD crushed joint and PU second shoe 0.0 0.0 16:00 18:00 system and crushed again. Re- evaluate and inspect equipment. Nothing stands out on crushing of pipe. Install cent on new joint while awaiting for another shoe. 5/23/2018 5/23/2018 5.00 COMPZN CASING PUTB P MU shoe joint and RIH making up 0.0 1,854.0 18:00 23:00 shoe track. Baker Lok all connections as per program. Fill pipe and check floats (PASSED). TQ all conections to 17.5K FULbs. RIH to 1,854' MD. 5/23/2018 5/24/2018. 1.00 COMPZN CASING CIRC P Stage pumps up to 6 BPM 82 PSI 1,854.0 1,854.0 23:00 00:00 withle recip pipe from 1,854'- 1,810' MD. UP WT=84K DWN WT=86K. 2400 stks pumped. 5/24/2018 5/24/2018 7.75 COMPZN CASING PUTB P Continue to RIH with 7"26#TXP 1,854.0 6,110.0 00:00 07:45 casing as per tally to 6,110' MD. TQ all connections to 17.5 FT/LBS. Up WT=140K DWN WT=87K. Top off every ten. 5/24/2018 5/24/2018 0.75 COMPZN CASING CIRC P Circulate BU at 6,110' MD. Stage 6,110.0 6,110.0 07:45 08:30 pumps to 6 BPM @ 456 PSI ICP 1400 PSI FCR. 263 GPM 117% F/O 140K UP WT/DWN WT=88K. pump 1,972 STKS. 5/24/2018 5/24/2018 7.00 COMPZN CASING PUTB P Continue to RIH with 7" 26# TXP 6,110.0 9,277.0 08:30 15:30 casing from 6,110' MD - 9,277' MD TQ all connections to 17.5K FT/LB. UP WT=222k DWN WT=94K. Fill on fly and topping off every ten. 5/24/2018 5/24/2018 1.00 COMPZN CASING HOBO P MU Vetco 7" casing hanger and PU 9,277.0 9,321.0 15:30 16:30 landing joint. RU cement hose asym. Cycle pipe from 9,288' MD to 9,318' MD UP WT=222K. DWN WT=94K. Stage up SLB cementers. 5/24/2018 5/24/2018 3.00 COMPZN CEMENT CIRC P Circulate and condition mud while 9,321.0 9,321.0 16:30 19:30 recip 8,288' - 9,318' MD. Slowly stage up pumps to 7 BPM @ 308 GPM, 720 PSI, FIG 20%, up WT = 115K DNW WT=81 K. Simops by PU 103/4"x7" packoff. LD Spiders, Bail extensions, and unlad shed of 7" casing. Start loading 4" DP / clean rig floor. 5/24/2018 5/24/2018 2.50 COMPZN CEMENT CMNT P Line up SLB cementers and pump 5 9,321.0 9,360.0 19:30 22:00 BBL fresh water / Pt - 4K PSI. Drop BTM PLUG and pump 40 BBLS of 12.5# Mud push. Drop 2nd BTM Plug and pump 167.5 BBL of 15.8 PPG Class G cement @ 5.5 BPM at 308 PSI. Drop top plug pump 10 bbls fresh water and swap to rig pumps. Displace cement with drilling mud at 7 BPM with a peak pressure of 842 PSI. Reduce rate at 2,900 DTKS to 5 BPM with peak pressure at 885 PSI. Reduce rate again at 3,300 stks to 3 BPM And bump plug at 3,430 stks. Pressure up to 1,326 PSI for 5 min then bleed off. 5/24/2018 5/24/2018 1.00 COMPZN CEMENT PRTS P Pt 7" 26# casing to 3,500 PSI for 30 9,360.0 9,360.0 22:00 23:00 min. 54 stk pumped and 5.4 BBLS bled back. Casing test passed 40 PSI loss in 30 min. 5/24/2018 5/25/2018 1.00 COMPZN CEMENT W WSP P Rig dwon cement running tools and 9,360.0 9,360.0 23:00 00:00 install pack off / RILDS. Page 8117 ReportPrinted: 6/19/2018 Operations Summary (with Timelog Depths) g� -114 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTme End Tme our (hr) Phase Op code Activity Code Time P -T -X Operation Start Depth (flK8) End Depth(9Ka) 5/25/2018 5/25/2018 1.50 COMPZN WHDBOP W WSP P Test upper and lower seals on pack off 9,360.0 9,360.0 00:00 01:30 to 5,000 PSI. Witnessed by Rock. Install wear bushing and RILDS. 9" ID. Lay down running tools. 5/25/2018 5/25/2018 2.25 COMPZN CEMENT SLPC P Change out handling equipment on rig 0.0 0.0 01:30 03:45 floor. Change out savor sub, and guide on TD. LD running tools. SL/CT 59' Drill line. calibrate blocks. 5/25/2018 5/25/2018 1.00 COMPZN CEMENT BHAH P PJSM / MU 6 3/4" drilling BHA and 0.0 329.9 03:45 04:45 RIH to 329.86' MD. 5/25/2018 5/25/2018 2.75 COMPZN CEMENT TRIP P Trip 6 3/4" drilling BHA in hole with 4" 329.9 2,197.0 04:45 07:30 DP from 329.9' MD - 2,197' MD. UP WT=76K OWN WT=74K. Monitor Disp via TT. 5/25/2018 5/25/2018 1.00 COMPZN CEMENT OTHR P SHT MWD with 240 GPM, 1,170 PSI 2,197.0 2,197.0 07:30 08:30 FO = 17%. Good test. Sim OPs with removing ice plug from mouse hole. 5/25/2018 5/25/2018 2.75 COMPZN CEMENT DLOG P Mad Pass at 300 FPH. from 2,197'- 2,197.0 2,700.0 08:30 11:15 2,700' MD. 250 GPM @ 1,308 PSI DPP. 17%F/O. UP WT=78K. OWN wT = 76K. 5/25/2018 5/25/2018 0.75 COMPZN CEMENT TRIP P Continue to TIH with 6 3/4" BHA on 4" 2,700.0 3,497.0 11:15 12:00 OP. from 2,700' MD - 3,497' MD. Monitor disp via TT. 5/25/2018 5/25/2018 0.50 COMPZN CEMENT DLOG P Mad Pass to ensure no cement @ 3,497.0 3,554.0 12:00 12:30 3,500' MD- @ 300 FPH from 3,497' - 3,554' MD 220 GPM @ 1,103 PSI F/O-15%. UP WT=80K. OWN WT = 75K. 5/25/2018 5/25/2018 0.50 COMPZN CEMENT TRIP P Continue to Trip in hole with 6 3/4" 3,554.0 3,971.0 12:30 13:00 BHAon 4" DP from 3,554'- 3,971' MD monitoring disp via TT. UP WT = 81 K, OWN WT = 75K. 5/25/2018 5/25/2018 5.00 COMPZN CEMENT DLOG P Mad Pass @ 800 FPH from 3,971'- 3,971.0 5,455.0 13:00 18:00 5,455' MD. 225 GPM @ 1,285 PSI DPP. 18% F/O UP WT = 104K. OWN WT = 70K. building stands in mouse hole on the fly. 5/25/2018 5/26/2018 6.00 COMPZN CEMENT DLOG P Continue to RIH performing CBL 5,455.0 7,740.0 18:00 00:00 F/5,455' MD to 7,740' MD. 800 FPH at 225 GPM 1,470 PSI DPP. 16% F/O. UP WT=144K. DWN WT=64k 5/26/2018 5/26/2018 5.25 COMPZN CEMENT DLOG P Continue RIH while performing CBL 7,740.0 9,200.0 00:00 05:15 logging from 7,740' - 9,200' MD. Sim ops while freeze protect OA with 90 BELS fresh water/ 115 BBLS diesel with max pressure of 1,050 PSI. Max rate 2 BPM. 480 PSI SI pressure after 10 min Sl. 5/26/2018 5/26/2018 0.75 COMPZN CEMENT DRLG P Drill out cement and Float equipment 9,200.0 9,245.0 05:15 06:00 from 9,200' -9,245' MD DO plugs with 225 GPM 1,800 PSI DPP, 15%F/O. 40 RPM 10-12.5K To. 6-1 OK WOB. Top plugs at 9,232' MD. BTM landing collar 9,236' MD. 3K WOB, on LNDG collar. 5/26/2018 5/26/2018 5.00 COMPZN CEMENT DRLG P DO cement from 9,245'- 9,388' MD. 9,245.0 9,388.0 06:00 11:00 225 GPM @ 15% F/O. 1,800 PSI DPP. 10-12KTo. UPWT=172/ OWN WT=57K. Fighting high ECD's and appears we are pushing piece of float shoe. Page 9117 ReportPrinted: 61191-2018 L_ GI arations Summary (with Timelog DevLhs) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Steri Time End Time Dur(hr), Phase Op Cod. itY Code Time P7 -X O station start Dept (RKB) EM Depth (ftKB) 5/26!2018 5!26/2018 1.00 COMPZN CEMENT CIRC P Circulate and condition mud for FIT. 9,388.0 9,388.0 11:00 12:00 RECIP from 9,388 - 9,358' MD. 225 GPM Q 1,780 PSI. 15% F/O. 80 RPM with 9-11 K TQ. ECD = 11.57. UP WT=172K, DWN WT=57K ROT = 95K. 5/26/2018 5/26/2018 1.50 PROD2 DRILL RURD P RU head pin for FIT/LOT. 9,388.0 9,388.0 12:00 13:30 Troubleshoot circulation problems and find mud to be in clober state. 5/26/2018 5/26/2018 0.75 PROD2 DRILL FIT P Perform FIT/LOT circ at 8 SPM / 9,388.0 9,388.0 13:30 14:15 pumped 9 strokes to 820 PSI. EMW = 13 PPG. Volume bled back= 1BBL. RD test equipment. 5/26/2018 5/26/2018 1.25 PROD2 DRILL CIRC P Displace well over to 9.2 solids free 9,388.0 9,388.0 14:15 15:30 flow pro. 25 BBL spacer pill rot/rec from 9,388'to 9,358' MD. 235 GPM 1,700 PSI F/O 19%. 40 RPM 1 O TQ. RWT 95K. 11.1 ECD. 3,650 STKS pumped. 5/26/2018 5/26/2018 2.50 PROD2 DRILL DDRL P Drill 6 1/8" hole from 9,388' MD - 9,388.0 9,540.0 15:30 18:00 9,540' MD 4,135 TVD. 235 GPM @ 1,990 PSI DPP. 16% F/O 100 RPM9- 11KTQ10-12KWOB. ECD's=11.5 Off btm press = 1,950 PSI. UP WT = 155K. DWN WT=59K. ROT 96K. 1 OK TQ /// Max gas = 49 units. ADT 2.27 Bit him 2.27 Jarjrs 2.27 SPR's 9,370' MD 4,128 TVD MW=9.2 Time 15:35 hrs MP1 20 SPM - 540 PSI 30 SPM - 780 PSI MP220 SPM -540 PSI 30 SPM -780 PSI 5/26/2018 5/27/2018 6.00 PROD2 DRILL DDRL P Drill 6 1/8" hole from 9,540' MD 4,135 9,540.0 9,848.0 18:00 00:00 TVD - 9,848' MD 4,008' TVD. 220 GPM @ 1,970 PSI DPP. 15% F/O 140 RPM 9K TQ 9K WOB. ECD's = 11.6 Off btm press = 1,860 PSI. UP WT=158K. DWN WT=54K. ROT 93K. 9.51K TQ /// Max gas = 35 units. _ ADT 4.81 Bit hrs 7.08 Jar jrs 7.08 SPR's 9,540' MD 4,135 TVD MW=9.1+Time 18:11 hrs MP1 20 SPM - 680 PSI 30 SPM - 910 PSI MP2 20 SPM - 620 PSI 30 SPM - 880 PSI OA = 185 5/27/2018 5/27/2018 6.00 PROD2 DRILL DDRL P Drill 6 1/8" hole from 9,848' MD 4,008' 9,848.0 10,206.0 00:00 06:00 TVD - 10,206 MD 3,979' TVD. 235 GPM Q 2,110 PSI DPP. 15% F/O 180 RPM 11.5K TQ 15K WOB. ECD's = 11.96 Off btm press = 2,050 PSI. UP WT=165K. DWN WT=OK. ROT 94K. 10K TQ /// Max gas = 130 units. ADT4.73 Bit his 11.81 Jarjrs 11.81 Page 10/17 ReportPrinted: 611912018 Operations Summary (with Timelog Depths) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Se End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation Steri Oepth (MB) End Depth (W)5/27/2018/2018 5/27/2018 6.00 PROD2 DRILL DDRL P Drill 6 1/8" hole from10,206 MD 3,979' 10,206.0 10,431.0 06:00 12:00 TVD - 10,431' MD 3,875' TVD. 235 GPM @ 2,112 PSI DPP. 15% F/O 130 RPM 13K TQ 15K WOB. ECD's = 11.95 Off btm press = 2,000 PSI. UP WT=167K. DWN WT=OK. ROT 94K. 10K TQ /// Max gas = 64 units. ADT 4.98 Bit hrs 16.79 Jar jrs 16.79 SPR's 10,300' MD 3,942' TVD MW=9.35 Time 08:45 hrs MPI 20 SPM - 700 PSI 30 SPM - 950 PSI MP2 20 SPM - 700 PSI 30 SPM - 920 PSI 5/27/2018 5/27/2018 5.25 PROD2 DRILL DDRL P Drill 6 1/8" hole from 10,431' MD 3,875' 10,431.0 10,545.0 12:00 17:15 TVD - 10,545' MD 3,823' TVD. 235 GPM @ 2,340 PSI DPP. 15% F/O 120 RPM 14K TO 20K WOB. ECD's = 11.85 Off btm press = 2,300 PSI, UP WT=167K. DWN WT=OK. ROT 95K. 10K TQ /// Max gas = 56 units. ADT 4,47 Bit hrs 21.26 Jar jrs 21.26 5/27/2018 5/27/2018 1.25 PROD2 CASING CIRC P Circulate BU from 10,545'- 10-490' 10,545.0 10,545.0 17:15 18:30 MD. 235 GPM @ 2,032 PSI DPP. 120 RPM with 9- 11 K TO UP WT = 167K DWN WT=O. RWT=96K. ECD = 11.68 PPG Pumped 3,000 stks MW in/out 9.2. SPR's 10,545' MD 3,823' TVD MW=9.2 Time 18:20 hrs MP1 20 SPM - 630 PSI 30 SPM - 870 PSI MP2 20 SPM - 620 PSI 30 SPM - 850 PSI 5/27/2018 5/27/2018 0.50 PROD2 CASING OWFF P OWFF (static) 10,545.0 10,545.0 18:30 19:00 5/27/2018 5/27/2018 4.25 PROD2 CASING BKRM P BKRM OOH from 10,545' MD to 10,545.0 9,340.0 19:00 2315 9,340' MD. 235 GPM @ 1,800 PSI, 140 RPM 1 O TO. 11.18 ECD. 500 FPH Pull speed. UP WT = 180K. DWN WT = 47K. 5/27/2018 5/28/2018 0.75 PROD2 CASING CIRC P Circulate bottoms up while rotating 9,340.0 9,260.0 23:15 00:00 from 9,340'- 9,260' MD. 235 GPM @ 1,750 PSI DPP. 16% F/0 120 RPM, 1 O TQ with 10.99 ECD. 5/28/2018 5/28/2018 1.50 PROD2 CASING CIRC P Circulate BU while recip pipe from 9,260.0 9,340.0 00:00 01:30 9,260 - 9340' MD. 235 GPM @ 1,750 PSI. 16% F/O 120 RPM, 1 OKTQ, 10.99 ECD. UP WT= 162K. DWN WT = 60 K. pump 2,600 stks. 9.2 PPG inlout, Sim ops cleaning drip pan, rotary table , shakers / decks. 5/28/2018 5/28/2018 0.75 PROD2 CASINGTRIP P RIH from 9,340'- 10,215' MD. Unable 9,340.0 10,215.0 01:30 02:15 to work pipe past due to hole angle. No slack off weight. Monitor disp via Pit #5. Page 11117 Report Printed: 6119/2018 - GNerations Summary (with Timelog Det ths) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Tfine Log Stall Time End Time Dur (hr) Phase Op Code Activity Cede Eme P-T-X operation Start Depth (ftKB) End DepUh (ftKB) 5/28/2018 5/28/2018 1.75 PROD2 CASING REAM P Wash and ream to bottom due to lack 10,215.0 10,556.0 02:15 04:00 of weight. 220 GPM @ 1,680 PSI 15% F10. 50 RPM 10K TQ. Ream from 10,215 - 10,556' MD at 140 RPM 11 TQ. 11.44 ECD. total slks pumped = 3,200. 5/28/2018 5/28/2018 1.75 PROD2 CASING CIRC P Displace well to solids free 9.0 PPG 10,556.0 10,556.0 04:00 05:45 flo-pro. flush pumps with fresh water then pump 60 BBL hi vis spacer and chase with solids fee 9.0 PPG flo-pro. at 235 GPM 1,600 PSI, 17% F/O 140 RPM, IOK TQ. UP WT= 164K DWN WT= no go!!I 5/28/2018 5/28/2018 0.25 PROD2 CASING OTHR P Clean mud troughs and flow lines with 10,556.0 10,556.0 05:45 06:00 new clean mud in hole. 5/28/2018 5/28/2018 0.75 PROD2 CASING CIRC P Continue to displace well over to 10,556.0 10,556.0 06:00 06:45 solids free flo-pro. while recip pipe UP WT = 164K No go down. 216 GPM @ 1,488 5/28/2018 5/28/2018 0.25 PROD2 CASING PULL P POOH on elevators from 10,556- 10,556.0 10,460.0 06:45 07:00 10,460' MD. Well swabbing/ MYU top drive POOH with 66 GPM 496 PSI DPP 5% F/0. UP WT=164K. 5/28/2018 5/28/2018 0.50 PROD2 CASING OWFF P Observe Well for flow. Static. 10,460.0 10,460.0 07:00 07:30 5/28/2018 5/28/2018 3.50 PROD2 CASING PMPO P Pump OOH from 10,460'- 9,260' MD 10,460.0 - 9,260.0 07:30 11:00 laying DP down via mouse hole. 66 GPM @ 515 PSI DPP. UP WT = 172. 5/28/2018 5/28/2018 5.50 PROD2 CASING PULL P POOH on elevators after checking for 9,260.0 329.0 11:00 16:30 swabbing from 9,260'- 329' MD. Monitoring well via TT. Sim ops of cleaning pits and suction lines to remove chances of contaminating solids free Flo-pro. 5/28/2018 5/28/2018 1.50 PROD2 CASING BHAH P PJSM LD BHA as per DD. UP WT= 329.0 0.0 16:30 18:00 56K. DWN WT=52K. 5/2812018 5/26/2018 1.00 COMPZN CASING SHAH P PJSM RU GBR casing running 0.0 0.0 18:00 19:00 equipment and PU Shoe track. 5/28/2018 5/28/2018 4.00 COMPZN CASING RUNL P RIH with 3 1/2" 9.3# L-80 HYD 63 0.0 1,288.0 19:00 23:00 liner, MU TQ= 2,900#. to 1,288' Dilling pipe every 10 joints. Monitor disp via TT. 5/28/2018 5/29/2018 1.00 COMPZN CASING BHAH P PIU Liner hanger aas per Baker rep 1,288.0 1,377.0 23:00 00:00 and RIH on 4" DP. Max running speed 90 FPM. Break circulation and pump 29 BBLs 330 PSI @ 4 BPM 12% F/O, 445 PSI @ 5 BPM. 15% 1 UP WT =59K. DWN WT=54K. 5/29/2018 5/29/2018 8.25 PROD2 CASING RUNL P Continue to RIH with 3 112" L-80 9.3# 1,377.0 10,545.0 00:00 08:15 Hyd 563 liner on 4" DP from 1,377' - 9,043' MD. Monitor disp via TT. Fill pipe every 20 stds. Break circ on std 81 @ 4 DPM 756 PSI DPP 12% F/O. UP WT=156K. DWN WT=65K.H Pick up HWDP from 9.G43'- 10,545' MD for push pipe. no issues getting to bottom. UP WT= 179K DWN WT= 65K. 5/29/2018 5/29/2018 0.50 PROD2 CASING SFTY P Pre job safety meet for spotting 10,545.0 10,545.0 08:15 08:45 brakedown D as per well plan and schedules. Page 12/17 ReportPrinted: 6/19/2018 Operations Summary (with Timelog Depths) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Statl Time End Time Dur (hr) Phase Op Code Activity Cutle Time P -T -X Operation Start Depth (ftKB) EM Depth(flKB) 5/29/2018 5/29/2018 2.75 COMPZN CASING CIRC P Pump DP/ liner volume from 10,534' 10,545.0 10,545.0 08:45 11:30 MD then stage up brakedown D as per plan forward @ 6 BPM 1,440 PSI DPP. 18% F/O, 45 BBLS Brakedown D @ 6 BPM 1,815 PSI DPP. 18% F/O, Drop 1 1.2" ball, 45 BBLS Brakedown D at 5 BPM 1,390 PSI 15 % F/O. 34 BBLA brine @ 5 BPm 1,278 PSI Ball on seat @ 875 stks. pressured up to 3,00 PSI and hold for 3 min. Pressure up to set ZXP packer (ova 3,400 PSI. Hold for 3 min and bleed off. PU to UP WT of 180K. PT ZXP PKR to 3,000 PSI for 5 min (PASSED). UP WT = 186K. slack off to confirm set with dog sub. LD 2 jts HWDP. 5/29/2018 5/29/2018 1.00 COMPZN CASING CIRC P PU to 9,191' MD to displace well to 9 10,545.0 9,191.0 11:30 12:30 PPG Brine at 438 GPM 2,505 PSI, 27% F/O. 2,210 PSI 27% F/O total stks pumped 3,420. BD top drive. 5/29/2018 5/29/2018 0.50 COMPZN CASING OWFF P Observe well for flow. Static 9,191.0 9,191.0 12:30 13:00 5/29/2018 5/29/2018 0.75 COMPZN CASING TRIP P POOH LD 4" HWDP, from 9,161'- 9,191.0 8,852.0 13:00 13:45 8,852' MD UP WT= 160K. Monitor well via TT. 5/29/2018 5/29/2018 0.50 COMPZN RIGMNT RGRP P Service roughneck / service top drive / 8,852.0 8,852.0 13:45 14:15 1 1 clean floor. 5/29/2018 5/29/2018 3.25 COMPZN CASING TRIP P Continue to POOH R/B 4" DP. 8,852 - 8,852.0 50.0 14:15 17:30 50' MD UP WT = 52K, DNW WT Monitor well Via TT. 5/29/2018 5/29/2018 0.50 COMPZN CASING SHAH P LD BHA and running toos as per 50.0 0.0 17:30 18:00 Baker. Clean rig floor. 5/29/2018 5/30/2018 6.00 COMPZN WELLPR MPSP P MU Baker RBP and RIH with 4" DP to 0.0 9,020.0 18:00 00:00 8,822', Max speed at 75 FPM. PU HWDP to 9,020' MD UP WT = 161 K. DWN TW = 86K. 5/30/2018 5/30/2018 COMPZN 9,020.0 00:00 00:00 5/30/2018 5/30/2018 1.50 COMPZN WELLPR MPSP P RIH to 9,020' MD. PU WT= 161 K. 9,020.0 9,020.0 00:00 01:30 DWN WT = 86K. Set Bridge plug as per Baker rep. Rotate 15 RPM while RIH to dit down. 70K DWN WT. UP WT = 170K check sert bridge plug. Set depth= 8,990' MD. Swallow retrieval at 8,994.91' MD. BTM of plug at 9,002.06. PT plug to 2,000 PSI charted for 10 min. 22 stks to pressur eup..4 BBLS bled back. 5/30/2018 5/30/2018 0.50 COMPZN WELLPR SVRG P Service IBOP— Leaking. Will change 9,020.0 8,994.9 01:30 02:00 out when OOH. 5/30/2018 5/30/2018 4.00 COMPZN WELLPR TRIP P POOH standing back all stands. 8,994.9 0.0 02:00 06:00 5/30/2018 5/30/2018 1.25 COMPZN WELLPR BHAH P LD Baker Plug running tool. Clean rig 0.0 0.0 06:00 07:15 floor. 5/30/2018 5/30/2018 1.25 COMPZN WELLPR RGRP T Changeout upper IBOP. Sim ops with 0.0 0.0 07:15 08:30 flushing dart valves and cross overs. Drain BOP stack in prep for upcomming BOP test. R/u chart recorder for testing BOPE. Lineup choke manifold system. Begin calibrate of gas alarms. Page 13117 Report Printed: 6119/2018 Operations Summary (with Timelog Depths) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time Ertl Time Ow(hr) Phase Op Code A.tiry Cod. lime P -T -X Operation Start Depth (ft7 ) End Depth (MB) 5/30/2018 5/30/2018 7.50 COMPZN WHDBOP BOPE P Perform BOPE test. PU testjoint pull 0.0 0.0 08:30 16:00 wear bushing and set test plug. After filling stack re -drain and changeout test plug rubber. fill / shell] test. PJSM. Test HOPE with 4" & 3 1/2" test joints. Annular CV#1,12,13,14,4" kill line on mud monifold. 4" dart, 2) CV# 9.11. Mem kill valve, 4" FOSV, 3) CV 3 8,11, HCR, Kill 4) CV # 6,7 Manual Kill. Test BOPE with 4 $ 3 1/2" test joint. All tested to 250 low, 3,500 PSI high. 5 min ea. Super choke, man choke 6) 3,5,7) 4# Joint lower rams, 8) Blinds, CV # 3,4,6,9 )3 12" jnt, Annular Upper IBOP, HCR choke, 10) 3 1/2" joint Lower IBOP, Manual choke 11) 3 1/2" joint lower rams. Koomey test -acc PAI 3,075. Manifold PSI 1,500. Function rams, HCR's. ACC PSI -1,750. 9 sec for 200 PSI 57 sec for full charge with a 6 bottle average 2,060 PSI. Test all gas alarms and PVT sensors, AOGCC witness =Austin Mcleod Rig dawn testing equipment and pull test plug. Set wear bushing and RILDS. 5/30/2018 5/30/2018 0.50 COMPZN PERF SFTY P Prejob for MU of pert guns. 0.0 0.0 - 16:00 16:30 5/30/2018 5/30/2018 1.50 COMPZN PERF SHAH P MU and RIH with 3.125" TCP guns 6 0.0 754.0 16:30 18:00 SPF. to 754' MD. Monitor disp via TT. 5/30/2018 5/30/2018 5.50 COMPZN PERF TRIP P Continue to RIH with perf guns on 4" 754.0 8,880.0 18:00 23:30 DP from 754'-8,880'MD. UPWT= 130K DWNWT=76K. Monitordisp via TT fill pip from top with stand 66 being last fill leaving 1,735' Void. 5/30/2018 5/312018 0.50 COMPZN PERF PULD P PU stand 84 / single from pipe shed 8,880.0 8,817.0 23:30 00:00 tehn stand 85 and RIH to 8,880'then POOH to 8,817' leaving string in tension with 3' stub. 5/31/2018 5/31/2018 2.50 COMPZN PERF WAIT T Wait on SLB eline crew to arrive. 8,817.0 8,817.0 00:00 02:30 Houred out on 5/30 need six hours sleep. Perfrom general housekeeping task and maintenance on rig. 5/31/2018 5/31/2018 1.50 COMPZN PERF ELOG P RU schlumberger aline. 8,817.0 8,817.0 02:30 04:00 5/31/2018 5/31/2018 2.00 COMPZN PERF ELOG P RIH with sling for correlation log to 8,817.0 8,817.0 04:00 06:00 8,030' MD 5/31/2018 5/312018 2.75 COMPZN PERF ELOG P Continue to POOH with eline for 8,817.0 8,817.0 06:00 08:45 correlation log from 8,030' MD to surface at 0630 hrs. PJSM whle aline work for RD aline and clean / clear rig floor. Simops BD tank hardline with hose to confirm pathway. MU manifold for parting. Verify RA tag depth with aline to adjust depths. 5/31/2018 1.25 COMPZN PERF P Verify RA tag depths and adjust 8,817.0 8,817.0 15/31/2018 08:45 10:00 depths accordingly. PJSM for firring 1 1RURD guns. reverse out and make up surface pump lines. Page 14117 Report Printed: 611912018 Operations Summary (with Timelog Depths) IH -110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time EM Tme Dur (hoPhase Op Cotle Activity Cotle lime P -T -X Operation (flag) End DepN(ftKD) 5/31/2018 5/31/2018 0.50 COMPZN PERF PERF P PU to pert depth of eline corrected 8,817.0 8,775.0 10:00 10:30 depth at 8,102' - 8,218' top perf, Middle parts at 8,293 - 8379' MD, Bottom perfs at 8,712'- 8,771' MD. Set 7" Champ PKR with bypass set 20K. 56K DWN WT UP WT= 130K, DWN 76 K for check set. Close ann, and circulate down [A& test PKR to 1,000 PSI. Hold for 10 min. Good test. Take press up to 3,600 PSI and hold for 30 sec. Bleed off to 680 PSI. Wait 7 min for guns to fire. 10:20 AM aper to choke 820 PSI SIP. Good indicator. 5/31/2018 5/31/2018 2.75 COMPZN PERF CIRC P Reverse circulate taking returns to kill 8,775.0 8,788.0 10:30 13:15 tank at 5 BPM. 1,411 PSI. Holding 200-220 PSI on choke. Crude observed at 75 bbls away. pumped 100 total BBLS and then shut down pumped. wait 10 min then pump 227 BBLS reversing. 120 PSI on gauge after shut down. Call town and circulate the long way at 5 BPM 513 PSI DPP. total stks 3333 stks. Sent 100 BBLS out to kill tank due to crude. SD pump at 1250 PM monitor pressure. 20 PSI bleed pressure off and open choke kill lines and annular. Release packer at 13:11 hrs UP WT = 143K. Well on vac. 5/31/2018 5/31/2018 0.75 COMPZN PERF RURD P RD circulation equipment blow down 8,788.0 8,604.0 13:15 14:00 hard line / kill / choke line and manifold. R/B two stds to 8604' MD. monitor well (static). Simps clean BOPE stack and cellar. 5/31/2018 5/31/2018 3.50 COMPZN PERF TRIP P POOH from 8,605' MD - 714' MD LD 8,604.0 754.0 14:00 17:30 pup joint and RA marker. Monitor well via TT. 5/31/2018 5/31/2018 0.25 COMPZN PERF SFTY P PJSM for laying down perforation 754.0 79-0- 17:30 17:45 1 1 1 guns. 5/31/2018 5/31/2018 2.25 COMPZN PERF BHAH P LD perf guns and note all shots fired. 754.0 0.0 17:45 20:00 clean fig floor and LD all BHA msubs etc. PU / MU Baker BHA for bridge plug retrieval process with scrapper. 5/31/2018 5/31/2018 0.25 COMPZN WELLPR SFTY P PJSM for MU Baker scrapper cishing 0.0 0.0 20:00 20:15 BHA for bridge plug removal. 5/31/2018 6/1/2018 3.75 COMPZN WELLPR TRIP P Finish making up Baker BHA and RIH 0.0 5,995.0 20:15 00:00 for retrieal process. 6/1/2018 6/1/2018 4.00 COMPZN WELLPR TRIP P Continue to RIH with T' casing scraper 5,995.0 8,771.0 00:00 04:00 and bridge plug retrieval tool from 5,995' MD - 8,771' MD. Passing through all three sets of perforations with an down/up/down pass to clean all debris. spot 30 BBL hi vis pill for reversing. 6/1/2018 6/1/2018 1.75 COMPZN WELLPR CIRC P RIH to 8,995' MD and RU to reverse. 8,771.0 8,985.0 04:00 05:45 Pump 200 BBLS total taking 60 BBLS _ to outside tank to catch previously spotted nigh vis pill. 4 BPM Q 430 PSI DP and ANN press. Monitor well for 30 min. Page 16117 ReportPrinted: 6119/2018 01,orations Summary (with Timelog Deh,,hs) 1H-110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Dur(ho Phase Op Code Adwty Cotle Mine P -T -X Operation (flKB) End Depth(ftKe) 6/1/2018 6/1/2018 2.00 COMPZN WELLPR MPSP P Latch onto Baker retrievable packer. 8,985.0 8,989.0 0545 07:45 ROT at 5 RPM 7.5K tq DWN WT = 92K. UP WT- 153K to confirm latch. Release RBP and wait for 15 min to relax elements. 7K PU drag increase. 6/1/2018 6/1/2018 8.75 COMPZN WELLPR TRIP P POOH slowly through perfs. from 8,989.0 200.0 07:45 16:30 8,771'- 8,1-2' MD. then continue to 200' MD monitoring disp via TT. 6/1/2018 6/1/2018 2.50 COMPZN WELLPR BHAH P LD scraper asym and RBP as per 200.0 0.0 16:30 19:00 Baker rep. Monitor disp via TT Clean rig floor and pull wear bushing. Flush stack and LD subs + HW. BD top drive. 6/1/2018 6/1/2018 3.00 COMPZN RPCOMP RURD P PU and make up 3 1/2" handeling 0.0 0.0 19:00 22:00 equip. Bring HES spool to rig floor / GBR equipment to rig floor. Align shed for pipe right. Stack and count clamps accordingly. 6/1/2018 6/212018 2.00 COMPZN RPCOMP PUTS P RIH with 3.5" L-80 EUE 9.3# upper 0.0 680.0 22:00 00:00 completion to 680' MU TQ = 2,240 ft/lbs. Monitor returns via TT. 6/212018 6/2/2018 6.00 COMPZN RPCOMP PUTB P Continue to RIH with 3 1/2" L-80 563 680.0 1,190.0 00:00 06:00 Upper completion from 680'- 1,190' MD. MU HES TEC wire. 6/2/2018 6/2/2018 6.00 COMPZN RPCOMP PUTB P Continue to RIH with 3 1/2" L-80 563 1,190.0 4,389.0 06:00 12:00 Upper Completion from 1,190'- 4,389' MD. Monitor Disp via TT. UP WT = 70K. DWNWT=61K. 6/2/2018 6/2/2018 6.00 COMPZN RPCOMP PUTB P Continue to RIH with 3 1/2" L-80 563 4,389.0 8,498.0 12:00 18:00 completion as per tally from 4,389' MD - 8,498' MD monitoring disp via TT. UP WT=100K. DWN INT =60K. 6/2/2018 6/2/2018 3.00 COMPZN RPCOMP PUTB P Continue to RIH with upper completion 8,498.0 9,187.0 18:00 21:00 of 3 112" L-80 563 hyd pipe as per tally from 8,498'-9,095'MD. UP WT= 102K. SWN WT=61 K. Mu top drive to begin washing down as per plan forward from 9,096- 9,241' MD with 3 BPM @ 250 PSI DPP. 6% NO Locate on nogo @ 9,241.92' MD. Set 5K dwn wt. to verify. PUH to 9,187' MD set string in compression. 6/2/2018 6/3/2018 3.00 COMPZN RPCOMP CRIH P MU head pin and circulate 50 BELS 9,187.0 9,187.0 21:00 00:00 brine followed with 330 BBLS Cl bdne@ 3BPM 260 PSI8°% F/O. 5 BBLS loss to formation. Monitor well 10 min. 6/3/2018 6/3/2018 4.00 COMPZN RPCOMP ELOG P RU/ SLB eline to correlate upper 9,187.0 9,187.0 00:00 04:00 completion and send to town for approval. 6/3/2018 6/3/2018 1.00 COMPZN RPCOMP ELOG P Rig down aline system and prepare to 9,187.0 9,187.0 04:00 05:00 land upper completion. 6/3/2018 6/3/2018 3.00 COMPZN RPCOMP HOSO P M/U space out Wo pup / hanger, with 9,187.0 9,237.0 05:00 08:00 timed collar. Used all three collars in an attempt to gain correct alignment. End up tuning sring with rotary and working up/down to align haner to pin asym. Terminale tech wire / BO choke Kill drain stack. UP wt = 100K. DWN WT = 64K. Land completion at 0740. Confirm alignment through 2" port. RILDS. Page 161117 Report Printed: 6119/2018 Operations Summary (with Timelog Depths) IH -110 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code A4ivity Code Time P -T -X Operation Start Depth (RKB) EM Depth tftKB) 6/3/2018 6/3/2018 1.00 COMPZN RPCOMP THGR P Pressure test seals to 5,000 PSI 9,237.0 9,237.0 08:00 09:00 (Charted) and witnessed. Sim Os LD tbg handeling equip. tech spool and spooler. RU injection line. 6/3/2018 6/3/2018 2.00 COMPZN RPCOMP PRTS P PJSM drop ball and rod and circulate 9,237.0 9,237.0 09:00 11:00 down on seat. at 70 STKS witness ball and rod on seat. increase pressure to 4,200 PSI and chart for 30 min. H Bleed tubing down to 2,000 PSI and pump down IA to 3,600 PSI. Chart for 30 Min. Bleed IA and tubing. Pump down IA to Shear out @ 2,600 PSI. pump 3 BBLS to confirm sheared. Monitor well 10 min. 6/3/2018 6/3/2018 1.00 COMPZN WHDBOP MPSP P BD / RD circ equip and pull landing 9,237.0 9,237.0 11:00 12:00 hanger. set BPV and test BPV by pumping down IA to 2,500 PSI. Charted for 10 min. PASSES. BD. 6/3/2018 6/3/2018 6.00 COMPZN WHDBOP NUND P Pull mousehole and riser equipment. 0.0 0.0 12:00 18:00 ND choke / and BOP stack Simops C/O savor sub. Clean well head and NU tree. Terminate tech wire and test tree void to 5,000 PSI. (Witnessed). ND all injection lines. Swap to gen power. 6/3/2018 6/3/2018 1.75 COMPZN WHDBOP PRTS P Fill tree with diesel an perform 0.0 0.0 18:00 19:45 250/5,000 PSI and chart same. (witnessed. 6/3/2018 6/3/2018 1.25 COMPZN WHDBOP FRZP P Pull test dart / BPV and pmp 95 BBLS 0.0 0.0 19:45 21:00 _ diesel to freeze protect IA and tubing @ 3.75 BPM. ICP= 500 PSI. FCP= 500 PSI. SIWHP = 110 PSI. 95 BBLS returned to tank. 6/3/2018 6/4/2018 3.00 COMPZN WHDBOP MPSP P RU lubricator and test to 1,500 PSI. 0.0 0.0 21:00 00:00 STE BPV / dg off and secure. Clean cellar, install valves, etc. Rig released at midnight. Page 17/17 ReportPrinted: 6119/2018 NADConversion Kuparuk River Unit Kuparuk 1H Pad 1H-110 1H-110 NAD 27 ConocoPhillips Definitive Survey Report 12 June, 2018 (Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Q yes ❑ No I have checked to the best of my ability that the following data is correct: O Surface Coordinates 0 Declination & Convergence CJ GRS Survey Corrections Survey Tool Codes Brandon TernYYl�e Digitally,,gnedbyBrandon Temple SLB DE' I' Date: 2018.06.1211:08:04-08'00' ... Digitally signed ey Ben Tolman Client Representative: Data 2018 06,12 13:11:27 -09'00' Date: 6112/18 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 11-1-110 Project: Kuparuk River Unit TVD Reference: 1H-110 actual @ 92.88usft (D142) Site: Kuparuk 1H Pad MD Reference: 1H-110 actual @ 92.88usft (13142) Well: 1H-110 North Reference: True Wellbore: 1H-110 Survey Calculation Method: Minimum Curvature Design: 1H-110 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 1 H-110 Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Welbom 11-1-110 Mognagcs Model Name BGGM2017 Northing: Easing: Wellhead Elevation: Sample Date 5/15/2018 5,980,842.21 usft Latitude: 70° 21'30.398 N 549,564.40 usft Longitude: 149° 35'50.770 W usft Ground Level: 54.00 usft Declination Dip Angle Field Strength P) Pl Inn 17.11 80.93 57,469 Design 1H-110 Dab Audit Notes: To Version: 1.0 Phase: ACTUAL Tie On Depth: 38.88 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction 759.59 (usft) (usft) (usft) 0 1,781.01 38.88 0.00 0.00 92.97 Survey Program Dab From To (usft) (ueft) Survey (Wellbore) Tool Name Description Survey Date 49.16 700.15 1 H-110 Srvy 1 - SLB _GWD70 (1 H-110) GYD-GC-SS Gymdata gyro single shots 5/16/2018 11:34: 759.59 1,709.881H-110 Srvy 2-SLB_MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/17/2018 11:45: 1,781.01 1,951.911H-110 Srvy 3- SLB _MWD-Inc-Only-Fille MWD -INC _ONLY MWD -INC _ONLY -FILLER 5/19/2018 9:39: 2,046.37 9,302.641H-110 Srvy 4 - SLB_MWD+GMAG (1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/19/2018 9:42:- 9,385.63 10,483.481H-110 Srvy 5-SLB_MWD+GMAG(11-1- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/26/2018 9:42: - Survey Map Map Vertical MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) 1°) (1) (usft) (usft) (usft) (usm (ft) (ft) C/1007 (K) Survey Tool Name 38.88 0.00 0.00 38.88 54.00 0.00 0.00 5,980,842.21 549,564.40 0.00 0.00 UNDEFINED 49.18 0.06 240.88 49.18 -03.70 0.00 0.00 5,980,842.21 549,564.40 0.58 0.00 GYD-GC-SS(1) 147.73 0.11 123.39 147.73 54.85 40B 0.03 5,980,842.13 549,564.43 0.15 0.03 GYD-GCSS (1) 242.48 0.75 114.47 242.48 149.60 -0.39 0.67 5,98.841.83 549,565.07 0.68 0.69 GYD-GCSS(1) 336.59 1.89 110.92 336.56 243.68 -1.2D 2.68 5,980,841.03 549,567.09 1.21 2.74 GYD-GCSS(1) 428.43 3.80 111.92 428.28 335.40 -2.87 6.92 5,980,839.38 549,571.34 2.08 7.06 GYD-GCSS(1) 519.57 5.55 112.26 519.12 426.24 5.67 13.8D 5,960,836.63 549,578.24 1.92 14.07 GYD-GCSS(1) 609.06 7.29 113.40 608.04 515.16 -9.56 23.02 5,980,832.80 549,587.48 1.95 23.48 GYD-GCSS(1) 700.15 8.92 100.97 698.22 605.34 -14.16 35.013 5,980,828.29 54.599.49 1.92 35.69 GYD-GCSS(1) 759.59 10.01 107.54 756.85 653.97 -17.21 44.28 5,980,825.29 549,608.79 1.88 45.11 MWD-IFR-AK-CAZ-SC (2) 6/12/2018 10:59:46AM Page 2 COMPASS 5000.14 Build 85 Survey ConocoPhillipis Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well 1H-110 Project: Kuparuk River Unit TVD Reference: 1 H-110 actual @ 92.88usft (D142) Site: Kuparuk 1 H Pad MD Reference: 1 H-110 actual @ 92.88usft (D142) Well: 1H-110 North Reference: True Wellbore: 1H-110 Survey Calculation Method: Minimum Curvature Design: 1 H-110 Database: OAKEDMP2 Survey 6/1202 0 18 10.59:46AM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AM TVD TVDSS +WS +E1 -W Northing Easting DLS Section (usft) (1) r) (usn) (usm (usft) ("M (ft) (ft) (°)1001 (ft) Survey Tool Name 854.57 12.75 109.66 849.95 757.07 -23.23 62.03 5,980,819.40 549,626.57 2.92 63.15 MWDAFR-AK-CAZSC(2) 949.48 14.07 112.46 942.27 849.39 31.16 82.55 5,98,811.60 549,647.15 1.55 84.06 MWD+IFR-AK-CAZSC(2) 1,045.20 15.04 110.55 1,034.92 942.04 39.96 104.94 5,980,80295 549,659.59 1.13 106.86 MWD+IFR-AK-CAZSC(2) 1,138.83 18.08 109.34 1,124.66 1,031.78 39.04 130.03 5,980,794.04 549,694.73 3.27 132.39 MWD+IFR-AK-CAZ-SC(2) 1,234.27 21.48 107.95 1,214.45 1,121.57 59.33 160.0 5,980,783.95 549,725.40 3.60 163.49 MWD+IFR-AK-CAZ-SC(2) 1329.13 23.57 107.08 1,302.07 1,209.19 -70.26 195.29 5,980,773.25 549,760.13 2.23 198.66 MWD+IFR-AK-CAZSC(2) 1,424.39 26.62 107.30 1,388.33 1,295.45 -82.20 233.88 5,980,761.57 549,798.79 3.20 23282 MWD+IFR-AK-CAZ-SC(2) 1,519.63 28.64 105.99 1,472.71 1,379.83 54.83 276.20 5,980,749.21 549,841.19 2.21 28034 10WD+1FR-AK-CAZ-SC(2) 1,614.83 28.44 106.53 1,556.34 1,463.46 -1 D7.57 319.86 5,98,736.77 549,884.93 0.34 325.00 MWD+IFR-AK-CAZSC(2) 1709.88 28.08 106.97 1,640.06 1,547.18 -120.54 362.95 5,980,724.09 549,928.11 0.44 368]1 MWD+IFR-AK-CAZSC(2) 1,781.01 28.90 106.41 1,702.58 1,6119.70 -130.28 395.45 5,980,714.56 549,960.67 1.21 401.67 MWD-INC_ONLY (3) 1,858.63 30.88 106.41 1,769.87 1,676.99 -141.21 432.55 5,980,703.88 549,997.84 2.55 439.29 MWD4NC ONLY(3) 1,951.91 32.8D 107.98 1,849.11 1,756.23 -155.77 479.56 5,980,689.63 550,044.93 2.24 186.98 MWD -INC -ONLY (3) 2,046.37 35.45 109.38 1,926.83 1,833.95 -172.99 530.38 5,980,672.75 550,095.86 3.95 538.63 MWDAFR-AK-W-SC(4) 2,140.88 41.32 112.14 2,000.38 1,907.50 -199.07 585.80 5,980,652.03 550,151.42 5.47 595.07 MWD+IFR-AK-CAZSC(4) 2,235.26 46.00 110.45 2,068.64 1,975.76 -217.69 646.51 5,980,628.82 550,212.27 5.11 656.91 MWD+IFR-AK-CAZSC (4) 2,331.26 50.55 108.72 2,132.52 2,039.64 -241.65 714.00 5,98,605.30 550,279.91 4.93 725.56 MWD+IFR-AK-CAZ-SC (4) 2,426.37 55.61 107.70 2,189.63 2,096.75 -265.40 786.21 5,980,582.05 55,352.27 5.39 798.90 MWD+IFR-AK-CAZ-SC(4) 2,457.96 57.62 107.49 2,207.02 2,114.14 -273.37 811.35 5,98,574.24 550,377.47 6.39 824.42 MWD+IFR-AK4;AZ-SC(4) 2,533.64 59.83 107.68 2,246.30 2,153.42 -292.91 873.01 5,98,555.11 550,439.24 2.93 88701 MWD+IFR-AK-CAZ-SC(4) 2,628.69 63.32 109.05 2,291.54 2,198.66 319.26 952.32 5,980,529.29 550,518.72 3.88 967.58 MWD+IFR-AK-CAZSC(4) 2,723.84 66.62 108.84 2,331.79 2,238.91 347.24 1,033.86 5,980,501.85 550,600.43 3.47 1,050.45 MWD+IFR-AK-CAZSC(4) 2,818.51 70.20 108.61 2,366.62 2,273.74 375.50 1,117.21 5,980,474.15 550,683.96 3.79 1,135.16 MWD+IFR-AK-CAZSC(4) 2,913.88 71.80 108.88 2,397.67 2,304.79 -404.47 1,202.60 5,980,445]4 550,769.53 1.70 1,221.93 MWD+IFR-AK-CAZSC(4) 3,008.04 75.58 109.48 2,424.11 2,331.23 -034.16 1,287.94 5,980,416.62 550,855.06 4.06 1,308.69 MWD+IFR-AK-CAZSC(4) 3,103.59 76.93 107.89 2,446.81 2,353.93 -463.89 1,375.86 5,980,387.48 550,943.16 2.15 1,398.03 MWD+IFR-AK-CAZSC (4) 3,198.38 76.32 108.09 2,468.74 2,375.86 -492.37 1,463.57 5,980,359.58 551,031.05 0.68 1487.10 MWD+IFR-AK-CAZSC(4) 3,293.65 76.15 107.53 2,491.41 2,398.53 520.68 1,551.66 5,980,331.86 551,119.32 0.60 1,576.55 MWDAFR-AK-CAZSC(4) 3,389.50 76.18 108.33 2,514.33 2,421.45 549.33 1,640.21 5,980,303.80 551,208.05 0.81 1,665.46 1AWD+IFR-AK-CAZ-13C(4) 3,484.53 76.40 107.54 2,535.85 2,443.97 577.76 1,728.05 5,980,275.96 551,296.06 0.84 1,755.65 MWD+IFR-AK-CAZ-SC(4) 3,579.57 76.29 108.09 2,559.29 2,466.41 -606.01 1,815.97 5,980,248.29 551,384.17 0.57 1,849.82 MWD+IFR-AK-CAZ-SC(4) 3,674.71 76.36 107.71 2,581.78 2,488.90 534.42 1,903.94 5,980,220.46 551,472.31 0.40 1,934.24 MWD+IFR-AK-CAZ-SC(4) 3,769.12 76.49 107.30 2,603.94 2,511.06 662.03 1,991.46 5,980,193.49 551,560.01 0.49 2,023.08 MWD+IFR-AK-CAZSC (4) 3,864.23 76.27 108.05 2.626.34 2,533.46 590.09 2,079.53 5,980,16596 551,648.25 0.80 2,112.8 MW0+IFR-AK-CAZSC(4) 3,959.61 76.30 107.53 2,648.95 2,566.07 -718.40 2,167.76 5,980,138.24 551,735.66 0.53 2,202.06 MWD+IFR-AK-CAZSC(4) 4,054.42 76.27 107.81 2,671.43 2,578.55 -746.36 2,255.52 5,98,11D.W 551,824.59 0.29 2,291.15 MWD+IFR.AK-CAZSC(4) 4,148.99 76.51 107.00 2,693.69 2,600.81 -773.85 2,343.23 5,980,083.95 551,912.47 0.87 2,380.16 MWD+IFR-AK-CAZSC(4) 4,243.89 76.49 107.68 2,715.84 2,622.96 -801.36 2,431.31 5,98,057.4 552,000.73 0.70 2,469.55 1OWD+1FR-AK-CAZSC(4) 4,339.45 75.79 107.09 2,738.73 2,645.85 529.08 2,519.85 5,980,029.90 552,089.4 0.95 2,559.41 MWD+IFR-AK-CAZSC(4) 4,434.36 75.67 107.43 2,762.13 2.669.25 655.37 2,607.69 5,980,003.20 552,177.45 0.37 2,648.54 MWD+IFR-AK-CAZSC (4) 6/1202 0 18 10.59:46AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-110 Project: Kuparuk River Unit TVD Reference: 1H-110 actual @ 92.88usft (D142) Site: Kuparuk 1H Pad MD Reference: 1 H-110 actual @ 92.88usft (D142) Well: 111-110 North Reference: True Wellbore: 111-110 Survey Calculation Method: Minimum Curvature Design: 111-110 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +wS +E1 -W Northing Seating DLS Section (usft) (1) 0 (usft) (usft) (usft) (uaR) (ft) (ft) (°1100') (ft) Survey Tool Name 4,529.46 76.07 108.15 2,7a5.34 2,692.46 -884.55 2,695.50 5,979,975.60 552,265.43 0.85 2,737.69 MWD+1FR-AK-CAZ-SC(4) 4,624.28 76.22 108.09 2,808.05 2,715.17 4313.18 2,783.00 5,979,947.56 552,353.11 0.17 2,826.55 MWD+IFR-AK-CAZ-SC(4) 4,719.54 76.07 108.46 2,830.86 2,737.98 542.18 2,870.82 5,979,919.14 552,441.11 0.41 2,915.76 1AWD+1FR-AK-CAZ-SC(4) 4,814.86 75.71 108.79 2,854.10 2,761.22 4371]0 2,958.42 5,979,890.20 552,528.90 0.51 3,00418 MWDHFR-AK-CAZ-SC(4) 4,910.28 75.69 109.19 2,877.67 2,784.79 -1,D01.79 3,045.86 5,979,860.69 552,616.52 0.41 3,093.65 MWD+IFR-AK-CAZSC(4) 5,004.74 75.62 109.55 2,901.07 2,808.19 -1,032.14 3,132.19 5,979,830.91 552,703.05 0.38 3,181.44 MWD+IFR-AK-CAZSC(4) 5,100.40 75.60 109.67 2,924.84 2,831.96 -1,063.24 3,219.47 5,979,800.40 552,790.53 0.12 3,270.22 MWD+1FR-AK-CAZSC(4) 5,196.36 75.35 110.11 2,948.91 2,856.03 -1,094.85 3,306.83 5,979,769.38 552,878.08 0.51 3,359.09 MWD+IFR-AKCAZSC(4) 5,291.61 75.54 109.84 2,972.85 2,879.97 4,126.34 3,393.47 5,979,738.46 552,964.92 0.34 3,44225 MW13+1FR-AK-C ZSC(4) 5,386.95 75.63 110.48 2,996.58 2,903.70 -1,158.16 3,480.15 5,979,707.21 553,051.80 0.66 3,535.46 MWD+IFR-AK-CAZSC(4) 5,481.81 75.57 110.25 3,020.17 2,927.29 -1,190.14 3,566.29 5,979,675.81 553,138.14 0.24 3,623.14 MWD+IFR-A.K-CAZ-SC (4) 5,576.90 75.02 109.71 3,044.31 2,951.43 -1,221.56 3,652.73 5,979,644.96 553,22418 0.80 3,711.09 MWDAFR-AK-CAZ-SC(4) 5,672.00 75.30 108.66 3,068.67 2,975.79 -1,251.92 3,739.50 5,979,615.18 553,311.74 0.91 3,799.31 MWD+IFR-AK-CAZ-SC (4) 5,767.01 7512 106.68 3,092.44 2,999.56 -1,280.00 3,827.09 5,979,587.69 553,399.50 2.27 3,888.24 MWD+IFR-AK-CAZSC(4) 5,862.55 76.01 105.27 3,115.78 3,022.90 -1,305.49 3,916.16 5,979,562.79 553,498.73 1.46 3,979.51 MWD+IFR-AK-CAZSC(4) 5,957.62 75.95 105.70 3,138.81 3,045.93 -1,330.12 4,005.05 5,979,538.75 553,577.77 0.44 4,068.56 MWD+IFR-AK-CAZ.SC(4) 6,052.61 76.09 106.40 3,161.76 3,068.88 -1,355.60 4,093.63 5,979,513.85 553.666.51 0.73 4,158.34 MWD+IFR-AK-CAZSC(4) 6,147.44 76.22 107.48 3,184.45 3,091.57 -1,382.43 4,181.71 5,979,487.61 553,754.76 1.11 4,247.69 MWD+IFR-AK-CAZSC(4) 6,242.91 75.97 108.57 3,207.39 3,114.51 -1,411.11 4,269.83 5,979,459.52 553,843.06 1.14 4,337.18 MND+IFR-AKXAZSC(4) 6,337.42 76.01 109.65 3,230.27 3,137.39 -1 4341.13 4,356.47 5,979,430.07 553,929.89 1.12 4,425.26 MND+IFR-AK-CAZSC(4) 6,432.32 75.94 109.31 3,253.27 3,160.39 -1,471.84 4,443.27 5,979,399.94 554,016.88 0.37 4,513.53 MND+1FR-AK-C Z.SC (4) 6,527.53 76.07 109.4 3,276.30 3,183.42 -1,502.49 4,530.42 5,979,369.87 554,104.22 0.19 4,602.15 MWD+1FR-AK-CAZSC(4) 6,621.93 75.98 109.72 3,299.09 3,206.21 -1,533.19 4,616.73 5,979,339.75 554,190.73 0.30 4.689.94 MND+IFR-AK-CA7-SC (4) 6,717.17 76.01 108.94 3,322.14 3,229.26 -1,563.78 4,703.93 5,979,309.74 554,278.12 0.80 4,778.60 1ANDAFR-AK-CAZ-SC (4) 6,812.41 76.02 110.13 3,345.16 3,252.28 -1,594.68 4,791.03 5,979,279.42 554,365.41 1.21 4,867.18 MWD+IFR-AK-CA -SC(4) 6,908.6 75.91 109.07 3,368.% 3,275.48 -1,625.81 4,878.44 5979,248.87 554,453.02 1.08 4,956.03 MWD+IFR-AK-CAZ-SC(4) 7,003.28 75.95 108.64 3,391.51 3,298.63 -1,655.66 4,965.85 5,979,219.61 554,540.61 0.44 5,044.93 MWD+1FR-AK-CAZ-SC(4) 7,098.53 75.73 105.73 3,414.81 3,321.93 -1,682.94 5,054.07 5,979,192.91 554,629.00 2.97 5,134.44 MWD+IFR-AK-CAZSC(4) 7,192.64 75.99 102.05 3,437.81 3,344.93 -1]04.85 5,142.64 5,979,171.59 554,717.71 3.80 5,224.03 MWD+IFR-AK-CAZSC(4) 7,288.57 74.25 98.33 3,462.45 3,369.57 -1,721.26 5,233.87 5,979,155.79 554,809.04 4.16 5,315.99 MNDAFR-AK-C ZSC(4) 7,383.61 71.74 94.61 3,490.25 3,397.37 -1,731.51 5,324.15 5,979,146.13 554,899.37 4.58 5,406.67 MND+IFR-AK-CAZSC (4) 7,478.48 70.09 92.58 3,521.28 3,428.40 -1,737.14 5,413.62 5,979,141.09 554,988.87 2.67 5,496.32 MWD+11FR-AK-CAZSC(4) 7,573.49 68.99 88.66 3,654.50 3,461.62 -1,738.12 5,502.61 5,979,14011 555,077.85 4.04 5,585.23 MWD+IFR-AK-CAZSC(4) 7,668.90 68.29 84.58 3,589.26 3,496.38 -1]32.89 5,591.28 5,979,146.53 555,166.48 4.05 5,673.52 MWD+1FR-AK-CAZSC(4) 7,763.67 67.90 80.94 3,624.63 3,531.75 -1,721.81 5,678.49 5,979,158.18 555,253.61 3.59 5,76D.04 MWD+IFR-AK-CAZSC(4) 7,859.49 67.61 78.42 3,660.91 3,568.03 -1,705.93 5,765.74 5,979,174.64 555,34014 2.45 5,846.35 MWD+IFR-AK-CAZ-SC(4) 7,954.64 66.43 75.09 3,698.6 3,605.18 -1,685.87 5,850.99 5,979,195.25 555,425.85 3.45 5,930.45 MWDAFR-AK-CAZ-SC(4) 8,049.73 66.06 71.38 3,736.38 3,643.50 -1,660.78 5,934.31 5,979,220.90 555,508.99 3.59 6,012.35 1AWD+IFR-AK-CAZ-SC(4) 8,144.49 66.13 69.54 3,774.78 3,681.90 -1,631.80 6,015.95 5,979,250.41 555,590.43 1.78 6,092.38 MWDAFR-AK-CAZ-SC(4) 8,240.22 66.52 68.07 3,813.22 3,720.34 -1,600.10 6,097.68 5,979,282.64 555,671.95 1.46 6,172.37 MWD+IFR-AK-CAZSC(4) 6112/2018 10.59:46AM Page 4 COMPASS 5000.14 Build 85 Survey f ConocoPhillips ( Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well IH -110 Project: Kuparuk River Unit TVD Reference: 1 H-110 actual @ 92.88usft (D142) Site: Kuparuk 1 H Pad MD Reference: 1 H-110 actual @ 92.88usft (D142) Well: IH -110 North Reference: True Wellbore: IH -110 Survey Calculation Method: Minimum Curvature Design: 1H-110 Database: OAKEDMP2 Survey 6/IZ2018 10:5g:46AM Page 5 COMPASS 5000.14 Build 85 Map Map vertical MD Inc AN TVD TVDSS +WS +E1 -W Northing Easting DLS Section (usft) (1) (°) (usft) (usft) (wft) (-it) (ft) (in (°1100') (it) Survey Tool Name 8,334.98 66.39 68.94 3,851.08 3,758.20 -1,568.27 6,178.51 5,979,315.00 555,752.55 0.85 6,251.44 MWD+IFR-AK-CAZ-SC (4) 8,430.06 66.13 69.44 3,889.35 3,796.47 -1,537.35 6,259.87 5,979,346.46 555,833.69 0.55 6,331.08 MWD+IFR-AK-CAZ-SC (4) 8,525.74 66.26 68.27 3,927.97 3,835.09 -1,505.77 6,341.51 5,979,378.57 555,915.12 1.13 6,410.98 MWD+IFR-AK-CAZ-SC (4) 8,621.09 66.18 66.49 3,966.42 3,873.54 -1,472.22 6,422.05 5,979,412.66 555,995.43 1.71 6,489.68 MWDAFR-AK-CAZ-SC (4) 8,716.14 68.07 65.21 4,003.37 3,910.49 -1,436.38 6,501.95 5,979,449.02 556,075.08 2.34 6,567.61 MWD+IFR-AK-CAZ-SC(4) 8,811.15 71.94 64.41 4,035.85 3,942.97 -1,398.38 6,582.73 5,979,487.55 556,155.59 4.15 6,646.31 MWD+IFR-AK-CAZ-SC(4) 8,905.76 75.38 63.69 4,062.47 3,969.59 -1,358.66 6,664.35 5,979,527.81 556,236.94 3.71 6,725.76 MWD+IFR-AK-CAZ-SC(4) 9,001.17 78.04 62.97 4,084.40 3,991.52 -1,316.98 6,747.31 5,979,570.03 556,319.62 2.88 6,806.46 MWD+1FR-AK-CAZ-SC(4) 9,096.27 80.31 61.90 4,102.26 4,009.38 -1,273.76 6,830.11 5,979,613.80 556,402.12 2.63 6,886.91 MWD+IFR-AK-CAZSC(4) 9,192.12 83.39 61.26 4,115.84 4,022.96 -1,228.60 6,913.54 5,979,659.50 556,485.25 3.28 6,96].89 MWDAFR-AK-CAZ-SC(4) 9,2B6.68 86.17 58.87 4,124.45 4,031.57 A.181.62 6,995.13 5,979,707.02 556,566.52 3.87 7,046.94 MWD+IFR-AK-CAZSC(4) 9,302.64 86.59 59.02 4,125.46 4,032.58 -1,173.40 7,008.78 5,979,715.32 556,580.11 2.79 7,060.14 MWD+1FR-AK-CAZSC(4) 9,385.63 87.06 56.6 4,129.47 4,036.59 -1,129.16 7,078.87 5,979,760.02 556,649.89 3.44 7,127.84 MWD+IFR-AK-CAZSC(5) 9,481.77 89.90 54.63 4,131.35. 4,038.47 -1,074.78 7,158.12 5,979,814.92 555,728.78 2.85 7,204.17 MWD+1FR-AK-CAZSC(5) 9,576.31 93.92 51.72 4,128.20 4,035.32 -1,018.17 7,233.73 5,979,872.03 556.804.01 5.25 7,276.75 MWD+IFR-AK-CAZSC(5) 9,671.55 97.03 49.81 4,119.12 4,026.24 -958.22 7,37.15 5,979,932.6 556,877.02 3.83 7,346.97 MWD+1FR-AK-CAZSC(5) 9,766.57 101.35 48.63 4,103.94 4,011.06 596.97 7,378.17 5,979,994.16 556,947.62 4.71 7,414.72 MWD+IFR-AK-CAZSC(5) 9,859.60 103.82 49.16 4,083.67 3,990.79 537.28 7,446.57 5,980,054.30 557,015.63 2.71 7,479.94 MWD+IFR-AK-CAZSC (5) 9,956.w 197.34 46.17 4,058.58 3,965.70 -774.60 7,515.40 5,980,117.43 557,084.03 3.97 7,545.43 MWD+IFR-AK-CAZSC(5) 10,051.04 108.87 47.03 4,029.85 3,936.97 -712.38 7,581.19 5,980,180.08 557,149.40 2.80 7,607.91 MWD+IFR-AK-CAZSC (5) 10,145.77 110.95 48.70 3,997.59 3,904.71 552.63 7,647.22 5,980,240.26 557,215.03 2.75 7,670.76 MWD+IFR-AK-CAZSC (5) 10,241.15 115.85 49.85 3,959.72 3,866.84 -595.52 7,713.53 5,980,297.80 557,280.95 5.26 7734.02 MWD+IFR-AK-CAZ-SC(5) 10,334.96 116.85 47.90 3,918.08 3,825.20 540.24 7,776.85 5,980,353.49 557,343.90 2.15 7,794.39 MWD+1FR-AK-CAZ-SC(5) 10,430.74 117.20 44.99 3,874.55 3,781.67 A81.46 7,838.68 5,980,412.67 557,405.33 2.73 7,853.97 MWD+IFR-AK-CAZ-SC(5) 10,483.48 118.64 44.83 3,849.86 3,756.98 -448.46 7,871.58 5,980,445.89 557,438.01 2.74 7,884.24 MWD+IFR-AK-CAZ-SC(5) 10,545.00 118.64 44.83 3,820.37 3,727.49 410.17 7,909.64 5,990484.43 557,475.82 0.00 7,920.27 PROJECTED to TO 6/IZ2018 10:5g:46AM Page 5 COMPASS 5000.14 Build 85 Cement Detail Report 11-1-110 String: Conductor Job: DRILLING ORIGINAL, 5/15/2018 18:00 Cement Details DescriptionCementing Conductor Start Date 11/3/2016 00:00 Cementing End Date 11/3/2016 00:00 Wellbore Name 1H-110 Comment 10 yards (5.5 sacks) of aggregate cement poured into backside by AFC. CMT/aggregate ratio of 564/3520 per yard Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) 39.0 Bottom Depth (ftKB) 119.0 Full Return? No Vol Cement... I Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Finat (bbl/... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Conductor Cement Fluid Description Estimated Top (ftKB) 39.0 Est Btm (RKB) 119.0 Amount (sacks) 6 Class AGGRAGATE Volume Pumped (bbl) Yield (R'/sack) Mix H2O Ratio (gal/sa... Free Water (Y) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 6/19/2016 Cement Detail Report 1H-110 String: Surface Casing Cement Job: DRILLING ORIGINAL, 51151201818:00 Cement Details Description Surface Casing Cement Cementing Start Date 5/18/2018 09:00 CementingEntl Date 5/18/2018 12 45 111-1-110 Wellbore Name Comment Pump 5 bbls of CW -100 and test lines to 3,500 psi, good. Reciprocate pipe (PUW = 117k, SOW = 107k) and pump 35 bbls of CW -100 @ 5.5 bpm, 115 psi. Pump 77 bbls of Mud Push II w/ red dye @ 5.0 bpm, 127 psi. Drop bottom plug & pump 358 bbls of 11.0 ppg LiteCRETE lead slurry @ 5.5 bpm, 222 psi. followed by 55.6 bbls of 12.0 ppg DeepCRETE tail slurry @ 5.5 bpm, 272 psit.Drop top plug. Chase with 10 bbls of water. Rig displace with 9.5 ppg Spud Mud @ 7.5 bpm, 350 psi. Landed hanger after pumping all lead cement, POW=133K, SOW= 76K. Bumped plug @ 1595 strokes. Hold 500 psi over FCP for 5 min, bleed off and pressure up to 3000 psi f/ 30 min to test casing, good. Bleed off and check floats, good. Cement Stages Stage It 1 Description Surface Casing Cement ObjectiveTop Depth (ftKB) 39.0 Bottom Depth (ftKB) 1,872.0 Full Return? Yes Vol Cement... 117.0 Top Plug? Yes son Plug? Yes Q Pump Init (bbUm... 4 Q Pump Final (bbl/... 3 Q Pump Avg (bbl/... 6 P Pump Final (psi) 300.0 P Plug Bump (psi) 800.0 Recip? Yes Stroke (ft) 15.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 40 bbls of CW 100 chem wash, 77 bbls of 10.5 ppg MP II, 358 bbls of 11.0 ppg lead cement and 55.6 bbls of 12.0 ppg tail cement. Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description I Estimated Top (ftKB) I Est Btm (ftKB) I Amount (sacks) I Class I Mud Push II Volume Pumped (bbl) 77.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (°k) Density (Ib/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 39.0 Est Btm (ftKB) 1,372.0 Amount (sacks) 1,054 Class G Volume Pumped (bbi) 358.0 Yield (ft /sack) 1.91 Mix H2O Ratio (gal/sa... 6.87 Free Water (%) Density (Ib/gap 11.00 Plastic Viscosity (cP) 62,000.0 Thickening Time (hr) 0.00 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,372.0 Est Btm (ftKB) 1,872.0 Amount (sacks) 189 Class Volume G 55.6 Pumped (bbl) Yield (ft'/sack) 1.65 Mix H2O Ratio (gullies... 5.73 Free Water (Ye) Density (lblgal) 12.00 Plastic Viscosity (cP) 94,000.0 Thickening Time (hr) CmprStr 0.00 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 6/19/2018 Cement Detail Report 11-1-1110 String: Production Casing Cement Job: DRILLING ORIGINAL, 5/15/201818:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 5/24/2018 16:00 5/24/2018 22:00 II H-110 Comment Circulate and condition mud while recip 9,288'- 9,318' MD. Slowly stage up pumps to 7 BPM @ 308 GPM, 720 PSI, F/020%, up WT = 115K DNW WT = 81 K. Lineup SLB cementers and pump 5 BBL fresh water / Pt - 4K PSI. Drop BTM PLUG and pump 40 BBLS of 12.5# Mud push. Drop 2nd BTM Plug and pump 167.5 BBI -of 15.8 PPG Class G cement @ 5.5 BPM at 308 PSI. Drop top plug pump 10 bbls freshwater and swap to dg pumps. Displace cement with drilling mud at 7 BPM with speak pressure of 842 PSI. Reduce rate at 2,900 DTKS to 5 BPM with peak pressure at 885 PSI. Reduce rate again at 3,300 stks to 3 BPM And bump plug at 3,430 stks. Take pressre to 1,326 PSI for 5 min then bleed off. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Production Casing Production casing cement 5,600.0 9,368.0 No 0.0 Yes I Yes Cement O Pump Init (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/...P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 7 6 720.0 1,235.0 1 Yes 24.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Circulate and condition mud while recip 9,288'- 9,318' MD. Slowly stage up pumps to 7 BPM @ 308 GPM, 720 PSI, F/O 20%, up WT = 115K DNW WT = 81K. Line up SLB cementers and pump 5 BBL fresh water / Pt - 4K PSI. Drop BTM PLUG and pump 40 BBLS of 12.5# Mud push. Drop 2nd BTM Plug and pump 167.5 BBL of 15.8 PPG Class G cement @ 5.5 BPM at 308 PSI. Drop top plug pump 10 bbls fresh water and swap to rig pumps. Displace cement with drilling mud at 7 BPM with a peak pressure of 842 PSI. Reduce rate at 2,900 DTKS to 5 BPM with peak pressure at 885 PSI. Reduce rate again at 3,300 silks to 3 BPM And bump plug at 3,430 stks. Take pressre to 1,326 PSI for 5 min then bleed off. Cement Fluids 8 Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) 1 Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud PUSH 4,106.0 15,600.0 1 1 40.0 Yield (ft' /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm IRKS) Amount (sacks) Class Volume Pumped (bbl) Production Cement 5,600.0 9,368.0 805 G 167.5 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.17 5.15 15.80 4.00 Additives Additive Type Concentration I Conc Unit label Page 1/1 Report Printed: 6119/2018 i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re '7 DATE: Monday, July 02, 2018 7 P.I. Supervisor y6f 1fo(I„ SUBJECT: Mechanical Integrity Tests (l CONOCOPHILLIPS ALASKA, INC. IH -110 FROM: Adam Earl KUPARUK RIV UNIT IH -110 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry Y!5( - NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IH -110 API Well Number 50-029-23601-00-00 Inspector Name: Adam Earl Permit Number: 218-031-0 Inspection Date: 6/26/2018 Insp Num: mitAGE180626154218 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I11-110 "'Type lnj W -'TVD 3737 Tubing 1041 - 1041 - 1041 1011 PTD 2180310 "Type TestS� PT Test psi,. — 1500 IA - 135 1810 - 1750 1740 BBL Pumped: j 1.6 - BBL Returned: s OA so 100 �u 1�u Interval ----- --- - - Notes: new injector MIT/IA Monday, July 02, 2018 Page I of I 2 18 03 1 29 49 9 chlumberger Transmittal#: 05JUL18-SP02 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: AOGCC: Natural Resources Tech Well Name: 1H-110 Date Dispatched: 5 -Jul -18 Logging Date Color Log Prints: Service Order #: 18AKA0011 Dispatched By: Stephanie Pacillo VISION Service Product Description Hardcopy Digital Copy Logging Date Color Log Prints: N/A Contents on CD 28 -May -18 VISION Service 2" MD / TVD x 5" MD / TVD x 2' TVD above 90deg incline x 5" TVD above 90deg incline x 5" MD GR -Mad Pass x RECEIVE D JUL 0 9 2018 AOGCC Digital Data N/A Contents on CD LAS/DLIS Data x Surveys N/A Contents on CD Directional Survey Nad27 x Directional Survey Nad83 x Gyrodata Survey x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom. Osterkamo conoco h' i s.com Alaska PTSPrintCenter(oslb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo (7) Received By: Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: j AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Com mision 333 W. 7th Ave, Suite 10D yJra Anchorage, AK 99501 TRANSMITTALDATE TRANSMITTAL# 218031 29 44 8 WELL NAME 1E-119 1H-110 1H-105 1Q-22 1C-10 2M -09A 2M -09A 2W-09 2W09 2M -09A 2M -09A 2M -09A .. # 50-029-23198.00 50-029-23601-00 50-029-20727-01 50-029.22595-00 50-029-20865.00 50-103-20177.01 50-103-20177.01 50-029.21235-00 50.029-21235-00 50-103.20177-01 50-103-20177.01 50-103-20177-01 ORDERSERVICE DV4X-00012 DV4X-00013 DV4X-00014 DSOS-00136 DV4X-00018 6V4X-00019 DV4X•00019 DV4X-00020 DV4X-00021 DV4X-00022 DV4X-00023 DV4X-00025 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER DELIVERABLE WL WL WL WL WL WL WL WL WL WL WL WL DESCRIPTIONDATA [PROF TCP Corr (PROF PPROF (PROF Perf CBL LDL Caliper Perf Perf Perf FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD r. TELOGGED Prints 30 -May -18 31 -May -18 1 -Jun -18 14Jun-18 21 -Jun -18 22 -Jun -18 22 -Jun -18 23 -Jun -18 23 -Jun -18 25 -Jun -18 26 -Jun -18 28 -Jun -18 CD's 1 1 1 1 1 1 1 1 1 1 1 1 12 Tr nsmittal Receipt �f//�y{ / (�-. A Transmittal Receipt signature confirms that a package (box, ly//A/6f'c/V/'/�///n, �/ U / /1 envelope, etc.) has been received and the contents of the X G 111 V package have been verified to match the media noted above. The Print Nam Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy Schlumberger and CPAI. point. Alaska PTSPri ntCenter slb.com Tom.Osterkam Conoco hilli s.mm SLB Auditor- �tJ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed Bry / P.I. 5uprv,l�� BOPE Test Report for: KUPARUK RIV UNIT IH -110 Comm Contractor/Rig No.: Doyon 142 - PTD#: 2180310 ' DATE: 5/30/2018 Inspector Austin McLeod Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Granville Rizek Rig Rep: Frank Carla Inspector Type Operation: DRILL Sundry No: Test Pressures: Rams: Annular: Valves: Type Test: BIWKLY MISC. INSPECTIONS: FLOOR SAFTY VALVES: P/F Location Gen.: _ P Housekeeping: _P-__ PTD On Location P ' Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P Misc NA FLOOR SAFTY VALVES: 250/3500 - 250/3500 - 250/3500 Quantity P/F Upper Kelly 1 P - Lower Kelly 1 P' Ball Type I P Inside BOP 1 P FSV Misc 0 NA 250/3500 - 250/3500 - 250/3500 TEST DATA 3075 - MUD SYSTEM: Pressure After Closure Visual Alarm P ' Trip Tank P P - Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P _ P H2S Gas Detector P P MS Mise NA NA BOP STACK: MASP: Inspection No: bopSAM180530194247 1386 - Related Insp No: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3075 - P Pressure After Closure _ 1750 P ' 200 PSI Attained 9 P " Full Pressure Attained 57 P " Blind Switch Covers: All stations - P Nitgn. Bottles (avg): 6 - ACC Mise 0 NA Quantity Size P/F Stripper 0 P/F NA Annular Preventer 1 - 13-5/8" P "- #1 Rams 1 " 7" Solid NT #2 Rams 1 ' Blinds P #3 Rams 1 ' 3-1/2"x6" P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8" _ P HCR Valves 2- 3-1/8" _ _ _P Kill Line Valves 3 - 3-1/8" P Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 0 Test Results Test Time 4.2 Remarks: 4" and 3-1/2" test joints. Annular and Lower VBR's were tested with both joints. TPR's were dressed with 7" solid bodies and ✓ were not tested. Gas/PVT's/Flow alarms tested. Annular called for 2500psi test, operator tested to 3500psi. All tests done against test plug. Quantity P/F No. Valves 14 P - Manual Chokes I P - Hydraulic Chokes 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 0 Test Results Test Time 4.2 Remarks: 4" and 3-1/2" test joints. Annular and Lower VBR's were tested with both joints. TPR's were dressed with 7" solid bodies and ✓ were not tested. Gas/PVT's/Flow alarms tested. Annular called for 2500psi test, operator tested to 3500psi. All tests done against test plug. F—L> v;?1c9-031 Loepp, Victoria T (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Saturday, May 26, 2018 3:25 PM To: Loepp, Victoria T (DOA) Subject: Re: [EXTERNAL]Re: KRU 11-1-110 (PTD #218-031) Cement Job Report Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria, have a good weekend. Hanna Get Outlook for iOS From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Saturday, May 26, 2018 3:20:27 PM To: Sylte, Hanna Subject: [EXTERNAL]Re: KRU 11-1-110 (PTD #218-031) Cement Job Report Hanna, Approval is granted to proceed with perforating. Thanx, Victoria Sent from my Whone On May 26, 2018, at 3:08 PM, Sylte, Hanna <Hanna Sylte@conocophillips.com> wrote: Victoria, Attached is the 1H-110 schematic, cement review, Cement Detail Report, and log from LWD sonic tool. A couple of highlights: • Cement job went well; crews maintained consistent density and good lift pressure was seen on displacement. • Schlumberger's sonic LWD tool was utilized for cement evaluation and SLB picked TOC @ 5,600' MD • 7" casing was successfully tested to 3,500 psi for 30 minutes. • Upon drilling out the 7" casing shoe track, a successful FIT of 13.0 ppg. Please let me know if we have approval to proceed with perforating or if you have any questions. Thank you, Hanna Sylte Completions Engineer ATO 1712 office: (907) 265-6342 Mobile: (713) 449-2197 <11-1-110 Cement Review.pdf> <Conoco Ph illi ps_1 H-110_Top_of_Cement.pdf> Cement Detail Report IH -110 String: Production Casing Cement Job: DRILLING ORIGINAL, 5/15/201818:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 5/24/2018 16:00 5/24/2018 22:00 11H-110 Comment Circulate and condition mud while recip 9,288'- 9,318' MD. Slowly stage up pumps to 7 BPM @ 308 GPM, 720 PSI, F/O 20%, up WT = 115K DNW WT = 81K. Lineup SLB cementers and pump 5 BBL fresh water / Pt - 4K PSI. Drop BTM PLUG and pump 40 BBLS of 12.5# Mud push. Drop 2nd BTM Plug and pump 167.5 BBI -of 15.8 PPG Class G cement @ 5.5 BPM at 308 PSI. Drop top plug pump 10 bbls freshwater and swap to rig pumps. Displace cement with drilling mud at 7 BPM with a peak pressure of 842 PSI. Reduce rate at 2,900 DTKS to 5 RPM with peak pressure at 885 PSI. Reduce rale again at 3,300 stks to 3 BPM And bump plug at 3,430 stks. Take pressre to 1,326 PSI for 5 min then bleed off. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? I Vol Cement... Top Plug? Btm Plug? Production Casing Production casing cement 5,600.0 9,368.0 No 0.0 Yes Yes Cement O Pump Init (bbNm.. O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 7 6 720.0 1,235.0 Yes 24.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out 70 (ftKB) Drill Out Diameter (in) Comment Circulate and condition mud while recip 9,288'- 9,318' MD. Slowly stage up pumps to 7 BPM @ 308 GPM, 720 PSI, F/O 20%, up WT = 115K DNW WT = 81K. Line up SLB cementers and pump 5 BBL fresh water / Pt - 4K PSI. Drop BTM PLUG and pump 40 BBLS of 12.5# Mud push. Drop 2nd BTM Plug and pump 167.5 BBL of 15.8 PPG Class G cement @ 5.5 BPM at 308 PSI. Drop top plug pump 10 bbls fresh water and swap to rig pumps. Displace cement with drilling mud at 7 BPM with a peak pressure of 842 PSI. Reduce rate at 2,900 DTKS to 5 BPM with peak pressure at 885 PSI. Reduce rate again at 3.300 stks to 3 BPM And bump plug at 3,430 stks. Take pressre to 1,326 PSI for 5 min then bleed off. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ClassVolume Pumped (bbq Mud PUSH 4,106.0 5,600.0 40.0 Yield (ft' /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 7 (psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 5,600.0 9,368.0 805 G 167.5 Yield (ft' /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density lib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.17 5.15 15.80 4.00 Additives Additive Type Concentration Conic Unit label Page 7/1 Report Printed: 5/26/2018 • Cement Slurry: s 805 sks 15.8 ppg tail a Job Comments: Maintained proper cement mixing density ® Returns throughout job Reciprocated pipe Saw good lift pressure Bumped plugs (displaced w/ rig pumps) TOC identified at 5,600' MD / 3,050' TVD 2,012' MD above pool top 520' TVD above pool top • Pressure tested 7" casing to 3,500 psi for 30 min FIT 13.0 ppg 1H-110 Pump Chart rime W:4sa_n:. —Pressure —Rate Density 7au97 :am:• � n:u:w NOS M:mm, 4wansoa 0.00 1107 R00 139 4401 55W —09 cz 1A 7.1 U 61 00 —6M 000 50 100 1! L&6 0 0 pImuLced 20" O Conductor. Q61 Casing S TJ - N Wellhead i Tubing Hanger � Tree 13.3rS' x 4-';:" IBTM, 5%1 1 H-110 Injector Well Design ,�Crossoverbelon TH: 4.12"x342 -Tubing (Pre -Completions) 13-1/17 HOLE & 10-3i4" 45.59. L-80 HYD563 @ 1,862 ft hID i 1,740' TLD 3-L2", 9.3 L -8Q ELE HID563 Feed Through Packer 3 8,052 \!D Multi Drop Grog. Mandrel 2.812' Camra DS Nipple Upper ASID -W I Loner 114iG-W V Feed Through Packer e2: 8,2561,E) Multi Drop Gauge Mandrel a' Upper 1LMG-3C Loner NUG -W Feed Through Packer $l: 8,5791M — Single Gauge Mandrel 2.813" Cameo X Nipple Upper NaIG-0.' _ Lower NMIG-W, RAPIP Tags 342" I.MiG nish SOC "D" Sand Perforations: 8102'-8218'MD e8" Sand Perforations: 8293'-8379'MD A4 perfs: No perfs (wet) A3 perfs: No perfs (wet) A2 perfs: 8712'E771'MD Lonw paeku (non feedthrough): 8,108' A1D 2.75" D nipple — WLEG Liner Top Hanger:Packer W - 8-34" HOLE & 7" 26d, L -SO, H1D563.+TXP u (d• 9,359' hID 4,129' TVD Baker NR' o a M J-Ir6i8" HOLE & 3-1i2", 9.2*, L-80, '— Shiftable ICD @ 10,682' h'ID i 3, 5.75" OD Sue11 Packer :i COMPANY WELL: FIELD: STATE.- COUNTRY TATE:COUNTRY TECHLOG PROCESSED INTERPRETATION 10 ConocoPhillips API No: 50-029-23601-00-00 Field: kuparik River Unit Localion: NAD83ASP, Zone4 ConocoPhillips Alaska, Inc 1H-110 Kuparik River Unit Alaska USA B ff- E E w Co `d E >, v E $ ¢ Y .59 Z5a LDN m � % E 3 ami 9 � C 3 E E m �� m y o Yo N ' U �3Eisro8a E g E > m Q E N N E 8 a 0 a 0 L Q W Z C6 J�u J Q o 0U J 5 LL W COMPANY WELL: FIELD: STATE.- COUNTRY TATE:COUNTRY TECHLOG PROCESSED INTERPRETATION 10 ConocoPhillips API No: 50-029-23601-00-00 Field: kuparik River Unit Localion: NAD83ASP, Zone4 ConocoPhillips Alaska, Inc 1H-110 Kuparik River Unit Alaska USA B ff- E E w Co `d E >, v E $ ¢ Y .59 Z5a LDN m � % E 3 ami 9 � C 3 E E m �� m y o Yo N ' U �3Eisro8a E g E > m Q E N N E 8 a 0 a 0 4erenc (ft) GR_MXW_RT OItv�t�LOLnLnL O r N M S In CD I-- M O 0 6 0 0 0 6 6 0 0 _ _S_T_Projection SPJ_MH_RT AMP1_CSG 0 100 AMP2_CSG 1:1000 0 gAPI 150 0 us/m 984 0 unitless 100 2200- 200 2300 2300 2400- 400 i i 2500 s �t —= - - Schlumberger Sonic To (TOC) Evaluation S It ATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION DIVERTER Test Report for: KUPARUK RIV UNIT IH -I 10 Reviewed By: P.I. SuprvS�L$f 1$ Comm Contractor/Rig No.: Doyon 142 PTD#: 2180310 " DATE: 5/16/2018 ' Inspector Adam Earl Insp Source Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Newman Rig Rep: Coates Inspector Well Class: DEV Inspection No: divAGE180518091343 MISC.INSPECTIONS: GAS DETECTORS: Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA TEST DATA P/F Location Gen.: P Housekeeping: P _ Warning Sign P " 24 hr Notice: P _ Well Sign: P__" Drlg. Rig. P ' Misc: NA GAS DETECTORS: Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA TEST DATA P/F MUD SYSTEM: P . Visual Alarm Trip Tank: P P_' Mud Pits: _P P ' Flow Monitor: P - P Mud System Misc: .0 NA ACCUMULATOR SYSTEM: Time/Pressure P/F Systems Pressure: 3075 P . Pressure After Closure: 1950 P 200 psi Recharge Time: 7 P Full Recharge Time: 44 - P Nitrogen Bottles (Number of). 6 _= P ' Avg. Pressure: 2125 P ' Accumulator Misc:_0 NA Related Insp No: DIVERTER SYSTEM: Size P/F Designed to Avoid Freeze-up? P Remote Operated Diverter? P No Threaded Connections? P Vent line Below Diverter? P Diverter Size: 21.25 P Hole Size: 13.5 - P Vent Line(s) Size: 16 P ' Vent Line(s) Length: 193 - P - Closest Ignition Source: 79 P Outlet from Rig Substructure: 184 P Vent Line(s) Anchored: P ' Turns Targeted / Long Radius: NA " Divert Valve(s) Full Opening: P Valve(s) Auto & Simultaneous: P - Annular Closed Time: 22 P Knife Valve Open Time: 7 P Diverter Misc: 0 NA Number of Failures: 0 ✓ Test Time: 1.5 Remarks: Tested W 4.5" DP p7'9 al8-63 / Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Friday, May 11, 2018 5:08 AM To: Loepp, Victoria T (DOA) Cc: Bearden, J Daniel Subject: RE: [EXTERNAL]KRU 1H-110 (PTD 218-031) LWD-Sonic Conditions of Approval Follow Up Flag: Follow up Flag Status: Flagged Victoria, The conditions of approval have been noted and will be documented with the original PTD. We will be sure to share the information as outlined when available. Hope you have a great weekend. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, May 10, 2018 1:41 PM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Cc: Bearden, J Daniel <J.Daniel. Bearden @conocophillips.com> Subject: [EXTERNAL]KRU 11-1-110 (PTD 218-031) LWD-Sonic Conditions of Approval KRU 1H-110(PTD 218-031) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well KRU 11-1-110 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Please update the approved PTD with this approval and conditions. 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. Loeppe-alaska.go 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 oryictoria.Loeoo@alaska.aov From: Tolman, Ben V <Ben.V.Tolman conocophillips.com> Sent: Thursday, May 30, 2018 11:00 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Subject: RE: [EXTERNAL]RE: PTD 218-031: KRU 1H-110 Clarification Good morning Victoria, We will be utilizing Schlumberger's 4-3/4" LWD sonic tool, the SonicScope. Just for a point of reference, this is the same sonic tool we have been utilizing in Kuparuk for LWD cement evaluations since 2014. A copy of the proposed BHA is attached. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(0)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp alaska.gov] Sent: Thursday, May 10, 2018 10:35 AM To: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Cc: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: RE: [EXTERNAL]RE: PTD 218-031: KRU 11-1-110 Clarification What tool and vendor are used for the CBL and for the LWD-sonic? From: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Thursday, May 10, 2018 10:13 AM To: Loepp, Victoria T (DOA) <victoria.loeop@alaska.eov>; Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: RE: [EXTERNAL]RE: PTD 218-031: KRU 11-1-110 Clarification Hi Victoria, Please let us know when is a good time to talk to you about the request for Sonic to log our 7" cement job. Since this injector will have a production lateral (we are calling this well a "fish hook" to capture similar sands in a graben across a fault), we propose that we add a SonicScope to our production lateral BHA to log our 7" cement job instead of running a traditional CBL on wireline prior to drilling our lateral. Sonic logging is similar to how we've performed our 3 -string injection well cement surveys in the past. As you stated, we would discuss Sonic results and the cement job with AOGCC prior to perforating the 7" injection zones. Thanks, Dan STNDrad I Tubing HaugerI Tt" _ 13-3+8•x4.`:'HYD563.S\t 1H-110 Injector Well Design Irtw. J I I1 1� Cr9saneabetaxTH 4•!^_•x3.1+2-nte�nc WP2ti Wellbore Schematic c9nalKt9t �o• —t C2=1 1;-':" HOLE & 10-3 4" 45.5=. L -SO HYD563 d I.S26 is XID PAPA Tap, :.56D'?41 &'.988 3.12". 9.3 =. L -SO. HYD563 EUE 3.112' NL1lG with 50\' `D" Sand Pods: 8138'43249'MD HEs }0T raedboupb Paekaa a5 8.130 }0) — }rola M, Gaore Mmtrel - 81. Cameo DS Nffle "B" Sand Porrs: 8304'4392'MD L'ppea Lo•.aaa.tLHG.W - HES }O -T Feeddaoopb Packe sf -. 8.'90' }m —� ♦ - }iE5 }0T Fee&eapb Pike aa. 8Y^ NO —/7 M.%1hep Gwpe}laabd-- r -A4" Sand Ports: 9450'45492'MD \(ate pop Gaope }label - 813' Cameo X \rp3de —� �• � HES }0T T.Iftoeln Packer s3 SAM' MD , }IulepopGmbe}Ised&d "A3• Sand Parrs: 8584'•8638'MD vppea Lar %516 aw —� ' 275•DmppkUUG HES }0T Teeddaoopb Parket ej- 8.5M MD Mote popGanpe)ko&d "A2•' Sand Pork: 8761'-8823'MO V, � A L&I S" HOLE & 3.1 2". 9.:e. L -SO. HY it 10.671' ?61D 376S' i I— Stul able ICD A57P ODAe11 Park. 1 �-- Faed L'ppe Lnwn }LMG.W --�J HES }O -T Feeddaoopb Packe sf -. 8.'90' }m —� ♦ - Sr{k Gnp - 813' Cameo X \rp3de —� uFF.L... }1114W HES T`.•r Permsomt Packer. 9.190}0 —� ' 275•DmppkUUG t L. Top HeereaPad, 9.16 --.NW - S-?:' HOLE & 7' 16=. L-90. HYD563 TSP a 9.362' btD 4.130' TVD V, � A L&I S" HOLE & 3.1 2". 9.:e. L -SO. HY it 10.671' ?61D 376S' i I— Stul able ICD A57P ODAe11 Park. 1 �-- Faed Daniel Bearden Supervising Drilling Engineer Conoco Phillips, Alaska 907-263-4864 work 907-602-7068 cell From: Loepp, Victoria T (DOA)[maiIto: victoria. loepp@alaska.aov] Sent: Tuesday, May 8, 2018 2:03 PM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Cc: Bearden, J Daniel <1.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]RE: PTD 218-031: KRU 11-1-110 Clarification Ben, We agreed that for the 1H West Sak injectors that CBLs would be run on the 7" when we were discussing FIT requirements for producer laterals. The following 1H injectors have had CBLs run: 1H-116(PTD 218-012), 1H-109(PTD 218-013), 1H-119(PTD 217-178) and 1H-113(PTD 217-168). CBLs are preferable. Maybe you were not present during those discussions. 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(a)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 is aware of the mistake in sending if to you, contact Victoria Loepp at (907(7931247 or Victoda.Loeipip@aloska.gov From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Tuesday, May 08, 2018 7:27 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Bearden, J Daniel <J.Dan ie1.Bea rden@conocophillips.com> Subject: RE: PTD 218-031: KRU 1H-110 Clarification Victoria, Good morning. We just wanted to send a quick note and make sure you had any follow-up questions. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(0)1(307) 231-3550(m) From: Tolman, Ben V Sent: Friday, April 27, 2018 12:28 PM To:'Loepp, Victoria T(DOA)' <victoria.loeppCu@alaska.gov> Cc: Bearden, J Daniel <J. Daniel. Bearden@conocophillips.com> Subject: PTD 218-031: KRU 1H-110 Clarification Victoria, Good afternoon. We received back the approved PTD 218-031 (11-1-110) this week. We have some questions/comments with the PTD's conditions of approval we would like to clarify; in particular the comments referencing the CBL results (see below for reference comments): Comments on Conditions of Approval: 4�MIA•ti' �Is7JeOtI.w�,�y KA b�v.•Ob•yNb-•M.sR•o m.s<'�',•�.0«,y�M,O�a m«r! dDP7�'tf 3scu//as'a ,�.�« +•�r«I11W� r""Vl iJ'nnrJwr pjY pts o f I e to 75Qy �.�., r«�( 0 1 oo. .rm ." I R resew r^r 3�lts .! � es 1- rol!dvame,•+.a +e.[1 �,hi +n«ae+ q.nel er.n[nf Jab P'i P, f3 Qr+'f•'wr'n� laltill}av, WT wit'+ N Ow 111F � u Y 21 rg Comments on Step 14 of Proposed Drilling Program: 11. IWAII 7-p Aaffmd Wb 7.500.'... 1i FMA 10.7}`x Tc :u wish wAW ad fo pokct I'1, pse. Ckslpmluctica aliag x+7500 psi(<iJNlofpxbl'ult�d k.:q nl X)Aw 10 MIM 14. $,U&I/i'bil xal 4 -VC dnt:iV&x b1y.Wid1 MWU/LWp()tw ,&y.mWiQy, md..dc(ody tOrterlml exxhu/im)J. Iwyl4pi o(amrn. Iklwndiny m :.m:xg ofcpeNim+.4p of crsml mx)' be de .'ibw GBL rf•1 ..'.-rA Re ✓iew ffyv/ S ! - C13L%iawirdiucw1rt Lima (Kw.O pfff.,W g) GBL w�. [/frmrn rJob F, f,Yf fs pf�f •••l•r.�. 15. (YI3w.*mwui vA2O*c( whnk Yrrkw ,hv tmbxni�mun of l2ppe L•l7W I.lII'.tll', rnanlind J nsilta our preferred method for performing our cement evaluation would be via Sonic LWD tools. This will allow us to obtain reliable cement evaluation results much sooner than performing a traditional CBL on wireline. As outlined in Step 14, our plan is to pick up a Sonic LWD tool as part of our 6-1/8" hole section BHA in order to log cement behind the 7" casing. Following similar format of our other 1H injectors, we will communicate the cement evaluation log along with cement job details to the state prior to perforating. We just wanted to verify that obtaining our cement evaluation results via sonic LWD tools would be acceptable in place of a traditional CBL wire log. In the unforeseen event, logistics, or tool issues impede us from obtaining those cement evaluation results via Sonic LWD tool, a CBL will be performed via wireline prior to perforating. Please let me know if you have any follow-up questions. Hope you have a great weekend. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907) 265-6828 (o) 1 (307) 231-3550 (m) Field Name Kuparux River Unit -1 gore a Name Plan: 11-1-110 Note Sin (in) 6.125 Sbuc[ure Name ,Uparul, 1H Pad SHAName lH-110&l251n Draft X6BHA_rev4 Plan: 111-110 Depth 1. Ut) 9370.00 Well Name Depth Out ft 10670.00 Desc. Manu Serial Numb at 60- MasOD (In) TTpe Gentler But FN OD LengthBM Oil Cum. Length (ft) Cum. Weight (lowWon) Lower Weight gomM) m Top Type Top Gender FN Length 1 6 LB" X516 PDC Bit Smith 4.500 6.125 0.000 0.72 0.72 0.1 82.46 1.500 3-12REG Pin 0.00 2 43/4"PowerOrive X6 w/5 7/8" Stabilized Conml Collar Srttlumbergar 4.980 5.875 3.IMMEG Box 13.33 14,06 0.7 50.60 3.640 14136 Box 3 PoverDrive Receiver Sub Scillumberger .950 5.000 NC39 Pin 4.650 8.451 22.50 1.2 51.71 2.250 NL35 Pin 1.77 4 4 WC PedScope Schlumberger 4.650 5.290 Ncta JBOX 4.650 23.51 46.01 2.4 51.6 2.250 Nc35 Pin 9.06 5 5 3/4" Inline Wearband Schlumberger 4.800 iBoe 5.750E 4.940 1.51 47.52 2.4 5190 22W Pin 0.95 6 43/4" Impulse Schlumberger 4.810 5280 1 G35 Boz 4.710 33.74 81.26 4.1 WOO 2.250 NC3e Pin 1.39 7 43W SonicSoope w/g' Stabilizers Schl er 4.820 6000 tC3e Box 31.50 11276 6.3 69.21 3.160 Nle Box 8 NM Float Sub (Ported Flapper float) Stlllumbe er 4.750 4.870 NC38 Pin 4.870 2.50 115.26 6.4 46.55 2.250 NC36 Box 1,47 9 43/4'Flex NMOC Schlumberger 3.500 5.200 NCB Pin 4.800 30,86 146.12 7.2 24.80 2.250 Nc38 Box 2.81 10 Steel Saver Sub [Corrosion Rin SrJYumber er 4.880 4.880 NC38 Pin 4.880 3.30 149.42 ].d 48.28 2.380 NC39 Box 2.04 11 XO Sub Steel Rig2.825 4]50 4.800 NC3a Pin 1.85 151.07 7.4 41.69 X139 Boz 12 4" HWDP (3jo nta) Rig2.563 4.1100 5.250 x139 Pin 92.88 243.95 10.2 29.92 x139 Boz 13 43/4" Jas Weatherford 4.750 4.800 me Pin 4.700 28.97 272.92 11.21 36.08 2250 x139 Box 1.64 144"HWDP(2 joints) Rig 4.000 5.250 me Pin 60.87 333.79 13.1 29.9 2.563 me Box 15 4.14.00 DPS, Prensun Rig 3.868 5.000 xT39 Pin 1 31.00 364.79 13.6 15.91 3.340 x739 Box 1 Total Larniff, M 384.79 BHAComenesols Total Wei htln Air IIOUU lbm 13.6 Total Buc ant Wei t00016m 11.9 Buo ant Wei ht Below Jar 1000 thin) 9.0 Wel hl in Air Below Jar (1000 IM) 10.2 Flow range: 220-240 gpm @ 9.2-9.dppg. Actual dimensions may vary slightly based on equipment Mud Pniparties availability. MudWei M IDM al 9.20 Mud T WBM PV cP YP IM/tO0R2 Senior Ogset MORM Stabilizer Summary BHA Nozzle Summa Gemma Ray 6.58 Blade ount x ID D+I 7 45 Blade Mid -Pt to Bit (11) Blade OD (in) Length Components IM in TFA (int) Resisevi 30.20 10.730 5.875 0.492 Bit 3x 122x 13 0.591 PWD 39.14 46940 5.750 0.380 Gamma R 39,92 65.930 6.000 0.510 Resistive 53.97 102.630 6.000 0.510 D+I 59.17 Gamna Ray 61.17 PD Flow Resiritlor 1/32 rd 18.00 nic 97.02 Rotor Bypass Noel¢ 1/32 in Send Summa Bend AnqWd Bend to Bit(ft)Dale O8Ma 2018 Desi reds it DIR\V Sara roved THE STATE °fALASKA GOVERNOR BILL WALKER Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-110 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-031 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Surface Location: 139' FSL, 776' FEL, SEC. 28, T12N, R10E, UM Bottomhole Location: 211.7' FNL, 3662.4' FEL, SEC. 35, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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 ,.d DATED thisZ�day of April, 2018. STATE OF ALASKA AL. -KA OIL AND GAS CONSERVATION COMMIbSION PERMIT TO DRILL �hL13eYbYrUL� RECEIVED 1a. Type of Work:1 b. Proposed Well Class: Exploratory - Gas Ll Service - WAG 0 ' Service - Disp 1 c. Specify if well is proposed for: Drill 0' Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑ Single Zane Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone 10 Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑i ' Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. l Bond No. 59-52-180- KRU iH-110 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10,427 • TVD: 3,769' • Kuparak River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 139' FSL & 776' FEL, Sec 28, T12N, R10E, UM ADL025639 & ADL025638 ' Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1526.9' FNL & 98.2' FEL, Sec 34, T12N, R10E, UM 80-261 & 931695000 5/17/2018 Total Depth: 9. Acres in Propertv: 14. Distance to Nearest Property: 211.7' FNL & 3662.4' FEL, Sec 35, T12N, R10E, UM 2560 acres & 2560 acres 5068'to ADL025649 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93.0" 15. Distance to Nearest Well Open Surface: x- 549564.4' y- 5980842.2' Zone- 4 GL / BF Elevation above MSL (ft): 54'.0 • to Same Pool: 847' to 1 H-113 16. Deviated wells: Kickoff depth:4 feet W5 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 119.22 degrees, Downhole: 1,785 psi • Surface: 1,386 psi ' 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) 42" 20" 94# H-40 Welded 80' Surf Surf 119' 119' Existing, cement to surface 13-1/2" 10-3/4" 45.5# L-80 HYD563 1787' Surf Surf 1826' 1743' 659 sx 11.0 ppg, 191 sx 12.0 ppg 8-3/4" 7" 26# L-80 HYD563lf 9279' Surf Surf 9318' 4086' 422 sx 15.8 ppg Class G 6-1/8" 3-1/2" 9.3# L-80 HYD563 1309' 9118' 4067' 10427' 3769' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD In Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes[] No 0 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program ❑ Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 20 AAC 25.050 requirementsg 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: Ben Tolman 4. Authorized Name: Chip Alvord Contact Email: bertm.tolman CO .COm Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6828 Authorized Signature: \ Date: Commission Use Only Permit to Drill API Number : Permit Approval See cover letter for other Number: " D3 50- Qo(, 3(0D1 - 00 -OD Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other.B,op � ¢o ,x$00 ISS / fit�j f AnZ Samples req'd: Yes ❑ NodMud I�S Yes Z No ' log req'd: Yes❑ t0 [jr ff y rr v/ R ✓ /J r.�✓7 �C J�O(]/9$-t measures: No❑ Directional svy req'd: Yes No❑ p rV% eW try i 3 or -L9 �- Spacing exception req'd: Yes ElNod Inclination -only svy mq'd: Yes E] NoRr Qh C� Ccrns t b r/'or D 'I�Cr 0rr4 i''LiA Post initial injection MIT req'd: YesEr No❑ APPROVED BY Li 122j I 1 Approved by: COMMISSIONER THE COMMISSION Date: m1 -permit Submit Form and Form 10401 Re 5/2017 Thisv lid "OR113ol"NdALProval per 20 AAC 25.005(9) Aachments in Duplicate Application for Permit to Drill, Well 1 H-110 Saved: 13 -Mar -18 March, 13 2018 Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 1H-110, a West Sak Sand Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots injector well from the 1 H pad. The expected spud date for this well is May 17, 2018. It is planned to use rig Doyon 142.✓ 1H-110 is planned to be a slant thru the West Sak sands. The surface section will be drilled with 13-1/2" bit and run 10- 3/4" casing to ±1,826' MD / 1,743' TVD. The I" production section will be drilled with 8-3/4" bit and run 7" casing to ±9,318'MD / 4,086' TVD. A 2"d production section will be drilled out the 7" casing shoe with 6-1/8" hole and be steered back up through the West Sak to +/- 10,427' MD / 3,769' TVD and lined with a 3-1/2" casing w/ ICDs. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ben Tolman at 265-6828 (ben.v.tolman@cop.com) or Chip Alvord at 265-6120. Sincerely, C. QJL hip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well M-110 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 1H-110 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Penni? to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's corners and showing (A) the coordinates of the proposed location of the yell at the surface. at the top of each objective fornnation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of Ute well at the sajace, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Sa%,ey in the National Oceanic and Atmospheric Administration: (C) the proposed depth of the well at the top ojeach objective formation and at total depth: Location at Surface 139' FSL & 776' FEL, Sec 28, T12N, R10E, UM NGS Coordinates Northings: 5,980,842.21' Eastings: 549,564.40' BKB Elevation 93.0' AMSL Pad Elevation 54.0'AMSL Location at Top of Productive Interval FNL & 98.2' FEL, Sec 34, T12N, R10E, UM NGS Coordinates Northings: 5,979,218.12' Eastings: 555536.27' Location at Total De th 211.7' FNL & 3662.4' FEL Sec 35, T12N, R10E UM NGS Coordinates Northings: 5,980,546.05' Eastings: 557240.26' Measured De th, RKB: 10,427' Total vertical De th, RKB: 3,769' Total Vertical De th, SS: 3,676' and (D) other information req ,h ed by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) !fa well is to be intentionally deviated. site application for a Permit to Drill (Form 10-001) ,last (1) include a plat, drown to a suitable scale, shoving the path of the proposed wellbore, including all adjacent twelba'es within 200 feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2) for all wells u'iti in 200 feet of the proposed wellba-e (A) list the nares of the operators of those wells, to the extent that those names are known ar' discoverable in public records. and show that each named operator has beers furnished a copy of Bre application by certified mail; or (B) stale that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill most be accompanied by each of the following items, except for an item already on file with the commission and idea! fed in the application: (3) a diagram and description of the blow l prevention equipment (BOPE) as required b1 20 AAC 25.035. 20 AAC 25.036. or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 and attachment. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill most be accompanied by each of the following items, except far an item already on file with the commission and identified in the application.: (4) info, nation on drilling hazards. including (A) the maxinnon donnho/e pressure that may be encountered, criteria used to determine it, and warinmm potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1H-110 is calculated using an estimated maximum reservoir pressure of 1,785 psi (based on I H-105 MDT pressure of 1749 psi, 8.6 ppg equivalent, and corrected to depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A2 sand at 3,990' TVD: A Sand Estimated. BHP = 1,785 psi A Sand estimated depth = 3,990' TVD Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 399 psi (3,990TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,386 psi (1,784 psi — 399 psi) (B) data on potential gas cones: The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation cores, and zones that hot e a propensily for differential sticking: See attached 1H-110 Drilling Hazards Summary Reauirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the follmring itmns. except for at, item ahead), on file frith the commission and identified in the application: (5) a description of dee procedure for conducting formation integrity tests. as required under 20 AAC 25.030(n: A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of thefollowing items. exceptJar an item already onfile it in) the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed Casing and Cement Program Casin and Cementin Pro ram Csg/Tbg OD Hole size e Grade Cann. Length ng Tap MD/TVD BBut,MD/TVD Cement Program (in) LlftJ (it) ft) 20 42 94 H-40 Welded 80 Surf 119/119 Existing Cement to Surface with 10-3/4 13-1/2 45.5 L-80 HYD563 1,787 Surf 1,826 /1,743 659 sx LiteCRETE Lead 11.0 ppg 191 sx Dee CRETE Tail 12.0Dug 7 8-3/4 26 L-80 HYD563 / 9,279 Surf 9,318 / 4,086 422 sx Class G at 15.8 ppg TXP w/ TOC at 6,992' MD 3-1/2 6-1/8 9.3 L-80 HYD563 1,309 9,118/4,067 10,427/3,769 N/A 10-3/4" Surface casine run to 1,826' MD / 1,743' TVD Cement from 1,826' MD to 1,326'(500' of tail) with 12.0 ppg DeepCRETE, and from 1,326' to surface with 11.0 ppg LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. Lead slurry from 1,326' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119'— 0') x 1.364 ft3/ft x 1.0 (0% excess) = 162 ft3 Bottom of Lead to Conductor (1,326'— 119') x 0.3637 ft3/ft x 2.50 (150% excess) = 1,097 ft3 Total Volume = 162 + 1,097 = 1,259 ft3=> 659 sx of 11.0 ppg LitcCRETE @ 1.91 ft3/sk Tail slurry from 1,826' MD to 1,326 MD with DeepCREET @ 12 ppg Shoe to Top of Tail (1,826' — 1,326') x 0.3637 ft3/ft x 1.50 (50% excess) = 273 113 Shoe Joint (80') x 0.5400 113/ft x 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 113 => 191 sx of 12.0 ppg DeepCRETE @ 1.65 ft3/sk 7" Production casine run to 9318' MD / 4,086' TVD Single stage slurry is designed to be placed from TD to 6,992' MD, which is 250' TVD above top of West Salk Pool (base of U. -nu); 35% excess annular volume. Slurry from 9,318 MD to 6,992' MD with 15.8 ppg Class G + additives Shoe to Top of Cement (9,318' —6,992') X 0.1503 ft3/ft X 1.35 (35%excess) =472 ft3 Shoe Joint (80') X 0.2148 ft3/ft X LO (0% excess) = 17 113 Total Volume = 472 + 17 = 489 ft3 => 422 sx of 15.8 ppg Class G @ 1.16 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applteation for a Permit to Duill must be accompanied by each of the following items. except for air item already on ale with lire commission and identified in the application: (7) a diagram and description ofthe diverier system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic attached. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must he accompanied by each of the folloii ing items, except for an item already on file with the commission and identified in the application: (3) a drilling fluid program, including a diagram and description ol'the drilling fluid ssslen. as required b3 20 AAC 25.033; Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Reauirements of 20 AAC 25.005 (c)(13) An application fora Permit to Drill musl be accompanied by each of the follmring /tens. except for an item already on frle irilli the commission and idem f ed in the apphcallo+c The proposed drilling program is included below. Please refer to attachment for proposed well schematic. Surface 13-1/2" Hole 10-3/4" Casing Production 1 8-3/4" Hole 7" Casing Production 2 6-1/8" Hole 3-1/2" Liner Mud System Spud WBM) LSND (WBM) FloPro NT (WBM -Density 8.8-9.5 9.0-10.0 9.0-9.5 a PV ALAP ALAP ALAP YP 30-80 20-30 15-20 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 9 - I 1 7-10 10 -minute Gel 30-50 < 20 8-16 API Filtrate NC <6 <6 HTHP Fluid Loss at 160° F N/A < 10 <10 H 10.8-11.2 9.5-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Reauirements of 20 AAC 25.005 (c)(13) An application fora Permit to Drill musl be accompanied by each of the follmring /tens. except for an item already on frle irilli the commission and idem f ed in the apphcallo+c The proposed drilling program is included below. Please refer to attachment for proposed well schematic. I . Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. Notify AOGCC 24 hrs before test. 2. Spud and directionally drill 13-1/2" hole to surface TD at+/- 1,826' MD / 1,743' TVD as per directional plan. Run MWD tools and required for directional monitoring [gamma ray]. ✓ 3. Run and cement 10-3/4", 45.5#, L80, HYD563 casing to surface. Displace cement with mud and check floats upon bumping plug. Notify AOGCC if top job is required. 4. Remove diverter system and install wellhead. Install and test 13-5/8" x 5,000 psi BOP'S to 250 psi low and 3,500 psi high (annular preventer to 3,500 psi). Notify AOGCC 24 hrs before test. ✓ 5. PU 8-3/4" bit and 6-3/4" drilling assembly, with MWD/LWD [gamma ray, resistivity, and density]. RIH, clean out cement to top of float equipment and test casing to 3,000 psi for 30 min. 6. Drill out shoe track and 20' of new hole. Perform shoe test to a minimum of I I.Sppg EMW LOT/FIT, recording �- results. 7. Displace to 9.0 - 9.2 ppg LSND water-based drilling fluid. 8. Directionally drill to production 1 TD at 9,318' MD / 4,086' TVD. 9. Circulate hole clean. BROOK 10. Run and cement 7", 26#, L80, HYD563/TXP casing to surface. (Top of cement to be 6,992' MD / 3,38 P TVD which corresponds to 250' TVD above top of the West Sak Pool.) 11. Install 7" packoff and test to 3,500 psi. 12. Flush 10.75" x 7" annulus with water and freeze protect. 13. Pressure test production casing to 3,500 psi (48.35% of published burst rating) for 30 min. 14. PU 6-1/8" bit and 4-3/4" drilling assembly, with MWD/LWD [gamma ray, resistivity, and sonic (only for cement evaluation)]. Log top of cement. Depending on timing of operations, top of cement mayybe determined with CBL via wireline at later time (prior to perforating). C ®L /.t eaL and Ccmc l job Prior io perf'orat hq. 15. Drill out shoe track and 20' of new hole. Perform shoe test to a minimum of 12ppg EMW LOT/FIT, recording �- ✓ results. 16. Directionally drill to production 2 TD at 10,427' MD / 3,769' TVD. 17. Circulate hole clean. BROOK 18. P/U and run 3-1/2", 9.3#, liner with ICD's, swell packers, and liner -top packer. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Circulate in breaker fluid. Pump down ball to close WIV. Set liner -top packer and pressure test for 10 minutes, chart results. POOH and lay down running tools. RIH and set plug in liner. RIH with TCPs and perforate zones. Close annular and reverse circulate perforations (circulate out gas from perf guns any potential hydrocarbons). Make clean out run if needed. Run 3-1/2" upper completions with packers and gauges. Land hanger, run in lock screws, and test seals to 5,000 psi. Set BPV and test in the direction of flow. 29. Nipple down BOPE, nipple up tree and test. Pull BPV. 30. Freeze protect 3.5' x 7" annulus (if the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 31. Set BPV and move off rig. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application jar a Permit to Drill must be accompanied by each of the following items, except for an item already on file with rhe commission and identified in the application: (1 4) a general description of holt the operalor plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request aulhori_ation lender 10 AAC 25.080 for an annular disposal operation in thea ell.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (DS 1B CRI), Milne Point, Prudhoe DS -4. 'All cuttings generated will be hauled to the DS 1B CRI, Milne Point, Prudhoe Bay Grind and Inject Facility (for temporary storage and eventual processing for injection down an approved disposal well), or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment I AOR Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Diverter Layout Diagram Attachment 6 BOP Configuration Attachment 1 AOR An Area of Review plot is shown below of the IH -1 10 planned wellpath and offset wells. The included table identifies any of the offset wellbores within the '/e -mile review. w>..-- 1 H-110wp26 Scotus Quarter Mile View H -n< _..'Antos- [[ �H-1o2L2 +H-1o3wyzs ____ Reservoir tRtawp23-. Cement Operations 1H -102L3 • ;tH-102L1 /� d0 iH-ll5wp21 (�/TVD) (MD/TVD) J 3 M-102 1X-116 Status Summary I Proposed 7,776' MD / Planned. 6,992' MD / 1H-12 Not Yet Drilled 1H-113 Well does not exist yet. Injector 3,63I'TVD ]50 f40 Y� TVD above pool top. k rr;1-7� Column of q IH -103 Proposed Not Yet Drilled N/A Not Yet cement to be Well does not exist yet IH -103 I � Producer � 250' TVD ] o 1I q m i I above pool top. ii Column of -1500 IH -104 Proposed Not Yet Drilled N/A [— O cement to be I IH -103 Producer 2250 _-1 250'TVD — �– 3750 0500 5250 6000 6]50 above pool top. ]SOD 9250 9000 9750 10500 Wn9-Wlsq.)(750�. ) Well Scotus Top of West Sak/ Sand TOC TOC Determined Reservoir Zonal Isolation Cement Operations Name (�/TVD) (MD/TVD) Ry Status Summary IH -110 Proposed 7,776' MD / Planned. 6,992' MD / Sonic LWD Not Yet Drilled Column of cement to be 250' Well does not exist yet. Injector 3,63I'TVD 3,381' TVD TVD above pool top. Column of IH -103 Proposed Not Yet Drilled N/A Not Yet cement to be Well does not exist yet IH -103 Producer Drilled 250' TVD above pool top. Column of IH -104 Proposed Not Yet Drilled N/A Not Yet cement to be Well does not exist yet IH -103 Producer Drilled 250'TVD above pool top. Column d IH -113 Active 9,704' MD / 5,395'MD / CBL Injecting in of cement to be,% 3,88 1' MD / 805' TVD above sks Class Good lift Injector 3,808' TVD 2,819' TVD Wes[ Sak.pressure. Pool to P.. prPlugsgs bumped. pr West Salk behind surface Activecasing 5'328 / Circ cement Producing cemented to surface. 1330 sks Permafrost •`D" & IH -13 Kuparuk 3,728' TTVVD Surface to surface. Kuparuk. Over 2,000' TVD separation 500 sks Class G. Circ Producer where wellbores cross in plan cement to surface. view. 9 35, M9/ch 07 2018 Depth To SurveyAlan 1 H-110wp26 3900 20" x 42' 10-3/4"z13-1/2' 1H-110) GVD-GOBS 7" �_ x 6-3/4' �-i 1625.00 iH-fl Mry26 (Plan: q MWD 1]00.00 -- - 1�- MWDIlFRAK-CAZ-SC 1825.00 2325.00 1H -it Owp2B (Plan: 1H-110) 4-1/2"x6-1/8' N y I I I 1H-110wp26 (Plop 1H-110) 17M - 9315.00 1U21+63 I I I iHA-10) MWD 9315.001012]63i110p26 I 0 H10) MWD+IFR-AK-CAZ-SC 2790- 3150 - 3150 3510 90 ' 0 2250 4500 6750 9000 11250 3070 - Measured Depth _off I N 20" x 42' 4240 - 4600 240 - 120 Doo 10-3/4"x13-1/2' Plan: 54+39 @ 93.00usft (Doyon 142) o • ��0_"" o 3/q' 4-112"x6-1/8' 6810 �� 1 � r 7540 3 - 150 75x0 - 8290 0 n 0 II f 190 T. ^ II � I 11l 9750 0 1500 3000 4500 6000 7500 97so - 104415 Horizontal Departure Measured Depth Depth From Depth To SurveyAlan 390 Tool 3900 1700.00 11+110.rp28 (Plan: 1H-110) GVD-GOBS 1]0000 1625.00 iH-fl Mry26 (Plan: 1H-110) MWD 1]00.00 1825.00 1H -fl DW6(PI»; 11-110) MWDIlFRAK-CAZ-SC 1825.00 2325.00 1H -it Owp2B (Plan: 1H-110) MWD MIND 1025.00 931500 1H-110wp26 (Plop 1H-110) 17M - 9315.00 1U21+63 - (Pann iHA-10) MWD 9315.001012]63i110p26 H-0p2Ple: H10) MWD+IFR-AK-CAZ-SC 4.50 11060 599.69 -4.03 12.00 110.00 896.38 -18.74 30.21 106.69 1574.00 -98.67 30.21 106.89 1674.00 -115.58 33.25 106.89 174300 -127.96 33.25 106.89 175973 -131.16 75.85 109.17 2404.12 415.96 75.85 109.17 337583 -1681.12 67.01 67.78 375500 -1663.35 67.01 67.78 3903 00 -1531.46 72.25 66.60 3949.65 -1482.74 72.25 66,60 3980,45 -1444.51 87.63 47,73 4086.13 -1123.82 87.63 47,73 4086.96-111038 119.22 37.27 3896.55 -52794 119.22 37.27 3769.00 -346A5 Pad Elevation: 54.00 DDI 6.645 plan Summa Q D 39 380 390 330 �- 30 570 - 570 760 E W j 780 - 950 Hold for 101.05' RN 1140 1140 1320 300 60 1320 1510 '4•°' Hold for 261.3' Ism - 1700 1 H-110 T05 TD 082417 FH TD: 10427.63' MD, 3769' TVD 17M - 2060 2430 2430 -neo 270 2790- 3150 - 3150 3510 90 ' 3510 - 3070 3070 - 4240 _off I N 4240 - 4600 240 - 120 4600 5340 - 5340 6070 6070 - 6810 beta - 7540 3 - 150 75x0 - 8290 11260 W20 190 T. 9020 9750 97so - 104415 Magnetic Model & Date: BGGM20195-Feb-18 Magnetic North is 17.25° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.94° 57476nT Annotation Lithology Column KDP: Stall 1.5°/100' DLS. 110° W. for 300' Start 315°/100' DLS, 0° TF, for 81.13' Hold for 20' Start 3.75°/100' DLS, 3.26° TF, for 1136.9' Hold for 3974.14' Base Perm T-3 Start 3.5-11017DLS, -109.03° TF, for 1144.94' 1H-110 T01 D 082417 FH Hold for 378.9' ,0 IH -110 T02 A3 082417 FH Start 4°/100' DL5, -12.17° TF, for 134.06' Hold for 101.05' Start 4°/100 DLS, -52.4' TF, for 601.6Z IH -110 7 Csg PI Hold for 20 Stan 4°/100' DLS, -16.85° TF, for 828.48' Hold for 261.3' 1 H-110 T05 TD 082417 FH TD: 10427.63' MD, 3769' TVD K-15 and I approve the scan and collision avoidance plan asset out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified 1 otherwise all targets have a 100 feel lateral tolerance. I CS DeLappj I V Osara I I Erik Stark Approved by: DE Name afna UG -C n:,�G_B UG A sxa - Na -Ai I 1 H-110wp26 Section View 0 •11 s CL 01800 �- 2700 L_ 20" x 42" 0° Base Perm 1uu� 10-3/4"x13-1/2" 0 T-3 --- --_ = 05 M o UG -C UGI B _UG_1!A WS D — S -B 0 o Na 3 WS_ WS_ W �a?s ----------------------- ---- o - \ I I a 'o ---------- ----------------------------------------------------- ----------------------------------------------------------------------------------------------------------- --_-_---_--_--_-------_--_--_-----_----_-----_----_----_-----_ --- --------------------------------- ----------------------- ---------_---- -_-_---_---_-__---_ _-_- O \ 7 T / XL I I 7" x 8-3/4' 1 4-1/2" x 6-1/8" 0 900 1800 2700 3600 4500 5400 6300 7200 Vertical Section at 90.000 1 H-110wP26 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 1800 900 20" x 42" 10-3/4"x13-1/2" ,o A26 �O Off, 0 O ;N Q) 4-1/2" x 6-1/8" � o M Y V 7 z 900 0 o7" x 8-3/4" 428 -- - O — 00- w 0 p O O. O n0 t9p _1800- 1800 -2700- -2700-36000 -3600- 0900 1800 2700 3600 4500 5400 6300 7200 West( -)/East(+) 9:32, March 07 2018 Easting (1500 usftlin) 7bH-20 1PB1 60 1H-1 1H -1,Q] #�C1� 1H-102 1-19AL1 1H-118 - 1H-05 40 1H-16 k 0 1H-103wp26 1H-19 50 H-119 1H -19A 0 1H-105 17 00 IH -114 1H-115wp21 O 60. 1H-104wp23 40 60 1d�fl16AL1PB1 0 2 1H -16A 1 7 8TH 40 0 5 40 z h0 1H -10A 0 1 7 B1 0 AR -03 Kuparuk 1H 16 50 Pa 0 l s 1 2� H 1H6 12 1H-113 0 1H-04 - 09 40 0 0 p 0 a° o o 1H-111 1H-110wp26 v ° 1H-21 —. H-04 ^' n 0 1H-1 0 0 0 0 ra0 o a p 0 v 1H-15 50 H-22 O6wp2 40 ^�° 1H- 074P22 0 0 60 PH -16 �° 0 m 1 H-0 1H-0 H -0S 1H-02 1H-11 1H-09 Easting (1500 usftlin) ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-110 50029xxxxx00 Plan: IH -110 Plan: 1 H-110wp26 Standard Proposal Report 07 March, 2018 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupawk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-110 Wellbore: Plan: IH -110 Design: 1H-110wp28 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: IH -110 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) MD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit North Slope Alaska, United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 1H Pad Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan: 11-1-110 Well Position +NIS 871.07 usft +E/ -W 372.96 usft Position Uncertainty 0.00 usft Ground Level: 54.00 usft Wellbore Plan: 1H-110 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) M wn BGGM2017 2/15/2018 17.25 80.94 57,476 Design 1H-110Wp26 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (ND) +N/S +E/ -W Direction (usft) (usft) (usft) (') 39.00 0.00 0.00 90.00 317/2018 10.25..56AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1H Pad North Reference: Well: Plan: 11-1-110 Survey Calculation Method: Wellbore: Plan: 1H-110 GYD-GC-SS Design: 11-1-110wp26 Plan Survey Tool Program Dasa 2!26/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,700.00 IH-110WP26(Plan: IH -110) GYD-GC-SS Build Tum Gyrodata gyro single shots 2 1,700.00 1,625.00 1H-110wp26(Plan: 1H-110) MWD Rate Rab Rate TFO MWD - Standard 3 1,700.00 1,825.00 IH-110WP26(Plan: 1H-110) MWD+IFR-AK-CAZ-SC (usft) (WousR) (1100ueft) rA00usft) MWD+IFR AK CAZ SCC 4 1,825.00 2,325.00 1H-110wp26(Plan: 11-1-110) MWD 0.00 0.00 0.00 0.00 MWD - Standard 5 1,825.00 9,315.00 1H-110wp26(Plan: 1H-110) MWD+IFR-AKSCC 300.00 0.00 0.00 0.00 MWD+IFR AK SCC Sperry 6 9,315.00 10,427.63 1H-110wp26(Plan: 111-110) MWD 110.00 599.69 -4.03 11.06 MWD - Standard 7 9,315.00 10,427.63 IH-110Wp26(Plan: 11-1-110) MWD+IFR-AK-CAZ-SC 12.00 110.00 896.38 -18.74 MWD+IFR AK CAZ SCC ConocoPhillips Standard Proposal Report Well Plan: 1H-110 Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Tum Depth inclination Azimuth Depth +NAS +E1 -W Rate Rab Rate TFO (usft) (1 r) (usft) Wait) (usft) (WousR) (1100ueft) rA00usft) P) Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0,00 0.00 600.00 4.50 110.00 599.69 -4.03 11.06 1.50 1.50 0.00 110.00 900,00 12.00 110.00 896.38 -18.74 51.49 2.50 2.50 0.00 0.00 1,629.38 30.21 106.89 1,574.00 -98.67 300.41 2.50 2.50 -0.43 5.00 1,745.09 30.21 106.89 1,674.00 -115.58 356.11 0.00 0.00 0.00 0.00 1,826.23 33.25 106.89 1,743.00 -127.98 396.93 3.75 3.75 0.00 0.00 1,846.23 33.25 106.89 1,759.73 -131.16 407.43 0.00 0.00 0.00 0.00 2,983.13 75.85 109.17 2,404.12 415.96 1,266.29 3.75 3.75 0.20 3.26 6,957.26 75.85 109.17 3,375.83 -1,681.12 4,906.19 0.00 0.00 0.00 0.00 8,102.21 67.01 67.78 3,755.00 -1,663.36 5,961.76 3.50 -0.77 -3.61 -109.03 1H -110T01 D082417 8,481.11 67.01 67.78 3,903.00 -1,531.46 6,284.67 0.00 0.00 0.00 0.001H-110 T02 A308241 8,615.17 72.25 68.60 3,949.65 -1,482.74 6,400.47 4.00 3.91 -0.88 -12.17 8,716.22 72.25 66.60 3,980.45 -1,444.51 6,488.79 0.00 0.00 0.00 0.00 9,317.85 87.63 47,73 4,086.13 -1,123.82 6,981.39 4.00 2.56 -3.14 -52.401H-1107 Csg Pt 9,337.85 87.63 47.73 4,086.96 -1,110.38 6,996.18 0.00 0.00 0.00 0.00 10,166.33 119.22 37.27 3,896.55 -527.94 7,536.52 4.00 3.81 -1.26 -16.85 10,427.63 119.22 37.27 3,769.00 -346.45 7,674.61 0.00 0.00 0.00 0.00 1H-110 T05 TD 08241 3/72018 10:25:56AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Coordinate Reference: Well Plan: 11-1-110 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Project: Kupawk River Unit MD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) Site: Kupawk 1H Pad North Reference: True Well: Plan: 1H-110 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 1H-110 Design: 1H-110wp26 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NIS +E/ -W Section Rate Rate Rate (usft) (_) (<) (usft) (usft) (usft) (usft) ('1100usft) ('1100uift) r1100us111) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 118.00 0.00 0.00 118.00 0.00 0.00 0.00 0.00 0.00 0.00 20" s 42" 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 110° TF, for 300' 400.00 1.50 110.00 399,99 -0.45 1.23 1.23 1.50 1.50 0.00 500.00 3.00 110.00 499.91 -1.79 4.92 4,92 1.50 1.50 0.00 600.00 4.50 110.00 599.69 -4,03 11.06 11,06 1.50 1.50 0.00 Start 2.5°/100' DLS, 0- TF, for 300- 700.00 7.00 110.00 699.18 -7.45 20.48 20.48 2.50 2.50 0.00 800,00 9.50 110.00 798,14 -12.36 33.96 33.96 2.50 2.50 0.00 900.00 12.00 110.00 896.38 -18.74 51.49 51.49 2.50 2.50 0.00 Adjust TF to -5-, for 729.38' 1,000.00 14.49 109.13 993.71 -26.40 73.08 73.08 2.50 2.49 -0.87 1,100.00 16.99 108.51 1,089.95 -35.14 98.76 98.76 2.50 2.49 -0.62 1,200.00 19.48 108.05 1,184.92 -44.94 128.47 128.47 2.50 2.50 -0.46 1,300.00 21.98 107.68 1,278.44 -55.79 162.16 162.16 2.50 2.50 -0.36 1,400.00 24.48 107.39 1,370.33 -67.67 199.76 199.76 2.50 2.50 -0.29 1,500.00 26.97 107.15 1,460.41 -80.55 241.21 241.21 2.50 2.50 -0.24 1,600.00 29.47 106.95 1,548.51 -94.41 286.42 286.42 2.50 2.50 -0.20 1,629.38 30.21 106.89 1,574.00 -98.67 300.41 300.41 2.50 2.50 -0.18 Hold for 115.71' 1,687.24 30.21 106.89 1,624.00 -107.12 328.26 328.26 0.00 0.00 0.00 Base Perm 1,700.00 30.21 106.89 1,635.03 -108.99 334.40 334.40 0.00 0.00 0.00 1,745.09 30.21 106.89 1,674.00 -115.58 356.11 356.11 0.00 0.00 0.00 Start 3.75°/100' DLS, 0° TF, for 81.13' 1,800.00 32.27 106.89 1,720.94 -123.85 383.35 383.35 3.75 3.75 0.00 1,826.23 33.25 106.89 1,743.00 -127.98 396.93 396.93 3.75 3.75 0.00 Hold for 20'. 110-314N13-1/2" 1,846.23 33.25 106,89 1,759.73 -131.16 407,43 407.43 0.00 0.00 0.00 Start 3.75°/100' DLS, 3.26• TF, for 1136.9' 1,890.02 34.89 107.06 1,796.00 -138.33 430.89 430.89 3,75 3.74 0.37 T3 1,900.00 35.26 107.09 1,804.17 -140.01 436.37 436.37 3.75 3.74 0.35 2,000.00 39.01 107.41 1,883.88 -157.92 494.01 494.01 3.75 3,74 0.32 2,100.00 42.75 107.69 1,959.47 -177.65 556.40 556.40 3.75 3.75 0.27 2,200.00 46.50 107.92 2,030.63 -199.13 623.27 623.27 3.75 3.75 0.24 2,203.45 46.63 107.93 2,033.00 -199.90 825.65 625.65 3.75 3.75 0.22 K-15 2,300.00 50.25 108.13 2,097.05 -222.27 694.33 694.33 3.75 3.75 0.21 2,400.00 53.99 108.32 2,158.44 -246.95 769.29 769.29 3.75 3.75 0.19 2,500.00 57.74 108.49 2,214.54 -273.08 847.81 847.81 3.75 3.75 0.17 2,600.00 61.49 108.65 2,265.11 -300.55 929.57 929.57 3.75 3.75 0.16 2,700.00 65.24 108.79 2,309.94 -329.23 1,014.21 1,014.21 3.75 3.75 0.15 2,800.00 68,98 108.93 2,348.83 -359.01 1,101.38 1,101.38 3.75 3.75 0.14 2,900.00 72,73 109.06 2,381.61 -389.76 1,190.69 1,190.69 3.75 3.75 0.13 2,983.13 75.85 109.17 2,404.12 -415.96 1,266.29 1,266.29 3.75 3.75 0.13 Hold for 3974.14' 3,000.00 75.85 109.17 2,408.25 -421.33 1,281.74 1,281.74 0.00 0.00 0.00 17/2018 10:25:56AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup1 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kupamk 1H Pad North Reference: Well: Plan: 1H-110 Survey Calculation Method: Wellbore: Plan: 1H-110 Dogleg Design: 1H-110wp26 Depth ConocoPhillips Standard Proposal Report Well Plan: 11-1-110 Plan: 54+39 Q 93.00usft(Doyon 142) Plan: 54+39 @ 93.00usft(Doyon 142) True Minimum Curvature Planned Survey _._._.___. Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NIS +EI -W Section Rate Rate Rate (usft) (q (°) (usft) (usft) (usft) (usft) ('1100usft) ('1100usft) (°I100usft) 3,100.00 75.85 109.17 2,432.70 453.16 1,373.33 1,373.33 0.00 0.00 0.00 3,200.00 75.85 109.17 2,457.15 -485.00 1,464.92 1,464.92 0.00 0.00 0.00 3,300.00 75.85 109.17 2,481.60 -516.83 1,556.51 1,556.51 0.00 0.00 0.00 3,400.00 75.85 109.17 2,506.05 -548.67 1,648.10 1,648.10 0.00 0.00 0.00 3,500.00 75.85 109.17 2,530.50 -580.50 1,739.69 1,739.69 0.00 0.00 0.00 3,600.00 75.85 109.17 2,554.95 -612.34 1,831.28 1,831.28 0.00 0.00 0.00 3,700.00 75.85 109.17 2,579.40 -644.17 1,922.87 1,922.87 0.00 0.00 0.00 3,800.00 75.85 109.17 2,603.85 -676.01 2,014.46 2,014.46 0.00 0.00 0.00 3,900.00 75.85 109.17 2,628.30 -707.84 2,106.05 2,106.05 0.00 0.00 0.00 4,000.00 75.85 109.17 2,652.76 -739.68 2,197.64 2,197.64 0.00 0.00 0.00 4,100.00 75.85 109.17 2,677.21 -771.51 2,289.23 2,289.23 0.00 0.00 0.00 4,200.00 75.85 109.17 2,701.66 -803.35 2,380.82 2,380.82 0.00 0.00 0.00 4,300.00 75.85 109.17 2,726.11 -835.18 2,472.41 2,472.41 0.00 0.00 0.00 4,400.00 75.85 109.17 2,750.56 -867.02 2,564.00 2,564.00 0.00 0.00 0.00 4,500.00 75.85 109.17 2,775.01 -898.85 2,655.59 2,655.59 0.00 0.00 0.00 4,600.00 75.85 109.17 2,799.46 -930.69 2,747.18 2,747.18 0.00 0.00 0.00 4,700.00 75.85 109.17 2,823.91 -962.52 2,838.77 2,838.77 0.00 0.00 0.00 4,800.00 75.85 109.17 2,848.36 -994.36 2,930.36 2,930.36 0.00 0.00 0.00 4,900.00 75.85 109.17 2,872.81 -1,026.19 3,021.95 3,021.95 0.00 0.00 0.00 5,000.00 75.85 109.17 2,897.26 -1,058.03 3,113.54 3,113.54 0.00 0.00 0.00 5,100.00 75.85 109.17 2,921.72 -1,089.86 3,205.13 3,205.13 0.00 0.00 0.00 5,200.00 75.85 109.17 2,946.17 -1,121.70 3,296.72 3,296.72 0.00 0.00 0.00 5,300.00 75.85 109.17 2,970.62 -1,153.53 3,388.30 3,388.30 0.00 0.00 0.00 5,400.00 75.85 109.17 2,995.07 -1,185.37 3,479.89 3,479.89 0.00 0.00 0.00 5,500.00 75.85 109.17 3,019.52 -1,217.20 3,571.48 3,571.48 0.00 0.00 0.00 5,600.00 75.85 109.17 3,043.97 -1,249.04 3,663.07 3,663.07 0.00 0.00 0.00 5,700.00 75.85 109.17 3,068.42 -1,280.87 3,754.66 3,754.66 0.00 0.00 0.00 5,800.00 75.85 109.17 3,092.87 -1,312.71 3,84625 3,846.25 0.00 0.00 0.00 5,900.00 75.85 109.17 3,117.32 -1,344.54 3,937.84 3,937.84 0.00 0.00 0.00 6,000.00 75.85 109.17 3,141.77 -1,376.38 4,029.43 4,029.43 0.00 0.00 0.00 6,045.91 75.85 109.17 3,153.00 -1,390.99 4,071.49 4,071.49 0.00 0.00 0.00 UG_C 6,100.00 75.85 109.17 3,166.22 -1,408.21 4,121.02 4,121.02 0.00 0.00 0.00 6,200.00 75.85 109.17 3,190.68 -1,440.05 4,212.61 4,212.61 0.00 0.00 0.00 6,300.00 75.85 109.17 3,215.13 -1,471.88 4,304.20 4,304.20 0.00 0.00 0.00 6,400.00 75.85 109.17 3,239.58 -1,503.72 4,395.79 4,395.79 0.00 0.00 0.00 6,500.00 75.85 109.17 3,264.03 -1,535.55 4,487.38 4,487.38 0.00 0.00 0.00 6,600.00 75.85 109.17 3,288.48 -1,567.39 4,578.97 4,578.97 0.00 0.00 0.00 6,700.00 75.85 109.17 3,312.93 -1,599.22 4,670.56 4,670.56 0.00 0.00 0.00 6,800.00 75.85 109.17 3,337.38 -1,631.08 4,762.15 4,762.15 0.00 0.00 0.00 6,900.00 75.85 109.17 3,361.83 -1,662.89 4,853.74 4,853.74 0.00 0.00 0.00 6,957.26 75.85 109.17 3,375.83 -1,681.12 4,906.19 4,906.19 0.00 0.00 0.00 Start 3.6°1100' DLS, -109.03° TF, for 1144.94' 7,000.00 75.36 107.70 3,386.46 -1,694.21 4,945.46 4,945.46 3.50 -1.13 -3.42 7,100.00 74.27 104.26 3,412.66 -1,720.79 5,038.22 5,038.22 3.50 -1.09 -3.44 7,108.62 74.18 103.96 3,415.00 -1,722.81 5,046.27 5,046.27 3.50 -1.07 -3.46 UG_B 7,200.00 73.23 100.78 3,440.65 -1,741.60 5,131.92 5,131.92 3.50 -1.04 -3.48 7,300.00 72.25 97.26 3,470.32 -1,756.58 5,226.22 5,226.22 3.50 -0.98 -3.52 7,400.00 71.33 93.70 3,501.58 -1,765.66 5,320.75 5,320.75 3.50 -0.92 -3.56 7,429.23 71.08 92.66 3,511.00 -1,767.20 5,348.38 5,348.38 3.50 -0.87 -3.58 UG_A 7,500.00 70.48 90.11 3,534.30 -1,768.81 5,415.18 5,415.18 3.50 -0.84 -3.60 7600.00 69.71 86.48 3568.36 -1,766.03 5,509.15 5509.15 3.50 -0.78 -3.63 3/7/2018 10:25:56AM Page 5 COMPASS 5000.14 Butts 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 1H-110 Company: ConocoPhillips (Alaska) Inc. -Kupl TVD Reference: Plan: 54+39 (Kil 93.00usft (Doyon 142) Project: Kupamk River Unit MD Reference: Plan: 54+39 a 93.00usft (Doyon 142) Site: Kupawk 1H Pad North Reference: True Well: Plan: 111-110 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 111-110 Design: 1H-110wp26 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth -NI-S +El -W Section Rate Rate Rata (usft) (^) (_) (usft) (usft) (usft) (usft) ('Mo0usft) ri100usft) (°1100usft) 7,700.00 69.00 82.82 3,603.63 -1,757.31 5,602.30 5,602.30 3.50 •0.70 -3.66 7,775.56 68.52 80.03 3,631.00 -1,746.81 5,671.93 5,671.93 3.50 -0.63 -3.69 No 7,800.00 68.38 79.12 3,639.98 -1,742.70 5,694.28 5,694.28 3.50 -0.59 -3.71 7,900.00 67.84 75.39 3,677.27 -1,722.24 5,784.77 5,784.77 3.50 -0.54 -3.73 8,000.00 67.38 71.64 3,715.37 -1,696.02 5,873.41 5,873.41 3.50 -0.46 -3.75 8,100.00 67.02 67.87 3,754.14 -1,664.13 5,959.88 5,959.88 3.50 -0.37 -3.78 8,102.21 67.01 67.78 3,755.00 -1,663.36 5,961.76 5,961.76 3.50 -0.32 -3.79 Hold for 378.9' 8,145.73 67.01 67.78 3,772.00 -1,648.21 5,998.85 5,998.85 0.00 0.00 0.00 INS -1) 8,200.00 67.01 67.78 3,793.20 -1,629.32 6,045.10 6,045.10 0.00 0.00 0.00 8,263.50 67.01 67.78 3,818.00 -1,607.22 6,099.22 6,099.22 0.00 0.00 0.00 WS -C 8,300.00 67.01 87.78 3,832.26 -1,594.51 6,130.33 6,130.33 0.00 0.00 0.00 8,314.70 67.01 67.78 3,838.00 -1,589.39 6,142.85 6,142.85 0.00 0.00 0.00 MIA -B 8,322.38 67.01 67.78 3,841.00 -1,586.72 6,149.40 6,149.40 0.00 0.00 0.00 WS A4 8,400.00 67.01 67.78 3,871.32 -1,559.70 6,215.55 6,215.55 0.00 0.00 0.00 8,481.11 67.01 67.78 3,903.00 -1,531.46 6,284.67 6,284.67 0.00 0.00 0.00 Start 4"1100' OLS, 42.17° TF, for 130.06' 8,499.30 67.72 67.62 3,910.00 -1,525.09 6,300.20 6,300.20 4.00 3.91 -0.91 WS -A3 8,500.00 67.75 67.61 3,910.27 -1,524.85 6,300.80 6,300.80 4.00 3.91 -0.91 8,600.00 71.66 66.73 3,944.95 -1,488.45 6,387.22 6,387.22 4.00 3.91 -0.88 8,615.17 72.25 66.60 3,949.65 -1,482.74 6,400.47 6,400.47 4.00 3.92 -0.86 Hold for 101.06' 8,700.00 72.25 66.60 3,975.50 -1,450.65 6,474.61 6,474.61 0.00 0.00 0.00 8,716.22 72.25 66.60 3,980.45 -1,444.51 6,488.79 6,488.79 0.00 0.00 0.00 Start 4°1100' DLS, 52A° TF, for 601.62' 8,748.25 73.04 65.54 3,990.00 -1,432.11 6,516.73 6,516.73 4.00 2.45 -3.31 WS_A2 8,800.00 74.32 63.84 4,004.54 -1,410.87 6,561.62 6,561.62 4.00 2.47 -3.28 8,900.00 76.82 60.62 4,029.47 -1,365.74 6,647.29 6,647.29 4.00 2.51 -3.22 9,000.00 79.37 57.47 4,050.09 -1,315.41 6,731.17 6,731.17 4.00 2.55 -3.15 9,100.00 81.95 54.37 4,066.33 -1,260.12 6,812.88 6,812.88 4.00 2.58 -3.10 9,200.00 84.55 51.30 4,078.09 -1,200.13 6,891.99 6,891.99 4.00 2.60 -3.06 9,300.00 87.16 48.27 4,085.32 -1,135.75 6,968.14 6,968.14 4.00 2.62 -3.03 9,317.85 87.63 47.73 4,086.13 -1,123.82 6,961.39 6,981.39 4.00 2.62 -3.02 Hold for 20'- 7" x 8414" 9,337.85 87.63 47.73 4,086.96 -1,110.38 6,996.18 6,996.18 0.00 0.00 0.00 Start 4°1100' DLS, -18.85° TF, for 828.48' 9,400.00 90.01 47.01 4,088.24 -1,068.30 7,041.89 7,041.89 4.00 3.83 -1.16 9,500.00 93.84 45.85 4,084.88 -999.43 7,114.29 7,114.29 4.00 3.83 -1.16 9,600.00 97.66 44.68 4,074.86 -929.41 7,184.95 7,184.95 4.00 3.83 -1.17 9,700.00 101.49 43.49 4,058.23 -858.60 7,253.54 7,253.54 4.00 3.82 -1.19 9,800.00 105.31 42.26 4,035.06 -787.33 7,319.72 7,319.72 4.00 3.82 -1.22 9,900.00 109.12 40.99 4,005.48 -715.95 7,383.17 7,383.17 4.00 3.61 -1.27 10,000.00 112.92 39.66 3,969.61 -644.80 7,443.57 7,443.57 4.00 3.80 -1.33 10,100.00 116.71 38.25 3,927.85 -574.25 7,500.64 7,500.64 4.00 3.79 -1.41 10 166.33 119.22 37.27 3,696.55 -527.94 7,536.52 7,536.52 4.00 3.78 -1.49 3172018 10:25.56AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 TVD Reference: Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Plan: 54+39 @ 93.00usft (Doyon 142) Site: Kuparuk 1 H Pad True Well: Plan: 1H-110 +NIS Wellbore: Plan: 11-1-110 +N1 -S +E/ -W Design: 1H-110wp26 (usft) (usft) Planned Survey (°1100usft) (°1100usft) (°1100usft) -504.55 7,554.31 Measured 0.00 0.00 0.00 Vertical Depth Inclination Azimuth Depth (usft) 0 (1 (usft) Hold for 2613' 0.00 0.00 0.00 6-3/4 10,200.00 119.22 37.27 3,880.11 10,300.00 119.22 37.27 3,831.30 10,400.00 119.22 37.27 3,782.49 10,427.63 119.22 37.27 3,769.00 TD: 10427.63' MD, 3769' TVD - 4-1/2" x 6.118" ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 11-1-110 TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) MD Reference: Vertical Plan: 54+39 @ 93.00usft (Doyon 142) North Reference: Hole True Survey Calculation Method: Minimum Curvature +NIS Vertical Dogleg Build Tum +N1 -S +E/ -W Section Rate Rate Rate (usft) (usft) (usft) (°1100usft) (°1100usft) (°1100usft) -504.55 7,554.31 7,554.31 0.00 0.00 0.00 -435.10 7,607.16 7,607.16 0.00 0.00 0.00 -365.64 7,660.01 7,660.01 0.00 0.00 0.00 -346.45 7,674.61 7,674.61 0.00 0.00 0.00 Design Targafs Target Name Vertical Casing Hole -hitimiss target Dip Angle Dip Dir. TVD +NIS +E/.W -Shape (°) (°) (usft) (usft) (usft) 1 H-110 Tot D 082417 F 0.00 0.00 3,755.00 -1,663.36 5,961.76 - plan hits target center 1,743.00 10-3/4"x13-1/2" 10-3/4 13.1/2 - Circle (radius 100.00) 4,086.13 7'x"4" 7 6-3/4 1 H-110 T05 TD 082417 0.00 0.00 3,769.00 -346.45 7,674.61 - plan hits target center - Circle (radius 100.00) 1H-110 T04 D20824171 0.00 0.00 3,869.00 483.84 7,579.70 - plan misses target center by 9.64usft at 10233.23usft MD (3863.89 TVD, -481.48 N, 7571.87 E) - Circle (radius 100.00) 1H-110 T02 A3 082417 1 0.00 0.00 3,903.00 -1,531.46 6,284.67 - plan hits target center - Circle (radius 100.00) 1H-1107 Csg Pt 0.00 0.00 4,086.13 -1,123.82 6,981.39 - plan hits target center - Circle (radius 100.00) 1H-110 T03 AS 0824171 0.00 0.00 4,088.00 -1,061.41 7,046.85 - plan misses target center by 1.66usft at 9408.34usft MD (4088.21 TVD, -1062.60 N, 7047.99 E) -Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 118.00 118.00 20" x 4Y' 20 42 1,826.23 1,743.00 10-3/4"x13-1/2" 10-3/4 13.1/2 9,317.85 4,086.13 7'x"4" 7 6-3/4 10,427.63 3,769.00 4-1/2"X6-1/8" 4-1/2 6-1/8 3172018 10.25.'56AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kuparuk I Pad Well: Plan: 1H-110 Wellbore: Plan: 11-1-110 Design: 1H-110wp26 Formations Measured Vertical Depth Depth Measured (usft) (usft) 1,687.24 1,624.00 Base Perm 1,890.02 1,796.00 T-3 2,203.45 2,033.00 K-15 6,045.91 3,153.00 UG -C 7,108.62 3,415.00 UG_B 7,429.23 3,511.00 UG_A 7,775.56 3,631.00 Na 8,145.73 3,772.00 WS_D 8,263.50 3,818.00 WS_C 8,314.70 3,838.00 WS_B 8,322.38 3,841.00 WS -A4 8,499.30 3,910.00 WS_A3 6,748.25 3,990.00 WS -A2 Name Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Lithology ConocoPhillips Standard Proposal Report Well Plan: IH -110 Plan: 54+39,@ 93.00usft(Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature Dip 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip Direction r) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -s +E1 -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5'1100' DLS, 110° TF, for 300' 600.00 599.69 -4.03 11.06 Start 2.5°1100' DLS, 0' TF, for 300' 900.00 896.38 -18.74 51.49 Adjust TF to -5', for 729.38' 1,629.38 1,574.00 -98.67 300.41 Hold for 115.71' 1,745.09 1,674.00 -115.58 356.11 Start 3.75°/100' DLS, 0* TF, for 81.13' 1,826.23 1,743.00 -127.98 396.93 Hold for 20' 1,846.23 1,759.73 -131.16 407.43 Start 3.75°/100' DLS, 3.26* TF, for 1136.9' 2,963.13 2,404.12 415.96 1,286.29 Hold for 3974.14' 6,957.26 3,375.83 -1,681.12 4,906.19 Start 3.5°/100' DLS, -109.03°TF, for 1144.94' 8,102.21 3,755.00 -1,663.36 5,961.76 Hold for 378.9' 8,481.11 3,903.00 -1,531.46 6,284.67 Start 4°/100' DLS, -12.17° TF, for 134.06' 8,615.17 3,949.65 -1,482.74 6,400.47 Hold for 101.05' 8,716.22 3,980.45 -1,444.51 6,488.79 Start 4°/100' DLS, -52.4° TF, for 601.62' 9,317.85 4,086.13 -1,123.82 6,981.39 Hold for 20' 9,337.85 4,086.96 -1,110.38 6,996.18 Start 4°/100' DLS, -16.85°TF, for 826.48' 10,166.33 3,896.55 -527.94 7,536.52 Hold for 261.3' 10,427.63 3,769.00 -346.45 7,674.61 TD: 10427.63' MD, 3769' TVD 3/72018 10:25:56AM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 11-1-110 Plan: IH -110 50029xxxxx00 1 H-110wp26 ConocoPhillips Clearance Summary Anticollision Report 07 March, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 1H Pad - Plan: 1H -110 -Plan: 1H-110-1H-110wp26 Datum Height: Plan: 54+39 @ 93.00usft (Doyon 142) Scan Range: 0.00 to 10,428.25 usft. Measured Depth. Scan Radius is 1,238.92 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 6000.14 Build: 86 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 1H-110 -I H-110wp26 Tray. Cylinder North Proximity Scan on Current Survey Data Worth Reference) Reference Design: Kuparukllf Pad -Plan: 1H -110 -Plan: 1H-110.11,1410wp26 Scan Range: 0.00 to 10,426.25 usft. Measured Depth. Scan Radius is 1,238.92 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Measured Minimum @Measured Ellipse @,Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name -Design (usft) (usft) (usft) (usR) usft Kuparuk 1H Pad 1H -05 -1H -05-1H-05 2,033.16 212.76 2,033.16 162.56 2,150.00 4.238 Centre Distance Pass -Major Risk iH-05-1H-05-1H-05 2,050.64 212.91 2,050.64 162.55 2,175.00 4.228 Clearance Factor Pass -Major Risk 1H -05 -1H -105-1H-105 2,031.54 212.78 2,031.54 162.60 2,150.00 4.240 Centre Distance Pass - Major Risk 1H -05 -1H -105-1H-105 2,049.05 212.87 2,049.05 162.52 2,175.00 4.228 Clearance Factor Pass - Major Risk 1H -102 -1H -102-1H-102 100.38 180.08 100.38 176.99 100.00 58.377 Centre Distance Pass - Major Risk 1 H-102 -1 H-102 - 1 H-102 275.37 161.32 275.37 176.43 275.00 37.080 Clearance Factor Pass - Major Risk 1H-102-1H-102L1.1H-1021_1 100.38 180.08 100.38 176.99 100.00 58.377 Centre Distance Pass - Major Risk 1H -102 -1H -1021-1-1H-1021_1 275.37 181.32 275.37 176.43 275.00 37.060 Clearance Factor Pass -Major Risk IH -102 -1H -1021.2-1H-1021-2 100.38 180.08 100.38 176.99 100.00 58.377 Centre Distance Pass - Major Risk IH -102 -1H -1021-2-1H-10212 275.37 181.32 275.37 176.43 275.00 37.080 Clearance Factor Pass - Major Risk 1H-102-iH-102L3-1H-102L3 100.38 180.08 100.38 176,99 100.00 58.377 Centre Distance Pass - Major Risk 1H -102 -1H -10213-1H-1021-3 275.37 181.32 275.37 176.43 275.00 37.080 Clearance Factor Pass - Major Risk 1H -102 -1H -102L4 -1H -102L4 100.38 180.08 100.38 176.99 100.00 58.377 Centre Distance Pass - Major Risk 1 H-102 - 1 H-1021-4 - 1 H-10214 275.37 181.32 275.37 176.43 275.00 37.080 Clearance Factor Pass - Major Risk 1H -109 -1H -109-1H-109 39.00 30.09 39.00 27.89 39.00 13.666 Centre Distance Pass - Major Risk IH-109-1H-109-iH-109 550.89 33.43 550.89 22.25 550.00 2.992 Clearance Factor Pass - Major Risk 1 H-111 -1 H-111 - 1 H-111 300.28 29.14 300.28 23.90 300.00 5.562 Centre Distance Pass - Major Risk 1H-111-1H-111-iH-111 1,564.99 44.75 1,564.99 17.84 1,575.00 1.663 Clearance Factor Pass - Major Risk 1H-113-1H-113-iH-113 622.32 67.12 622.32 76.71 625.00 8.368 Centre Distance Pass - Major Risk 1H-113. 1H -113-1H-113 696.67 87.73 696.67 76.28 700.00 7.664 Clearance Factor Pass - Major Risk 1 H-114 - 1 H-114 - 1 H-114 39.10 119.99 39.10 117.60 38.84 54.553 Centre Distance Pass - Major Risk 1 H-114 - 1 H-114 - 1 H-114 349.42 122.24 349.42 116.14 350.00 20.043 Clearance Factor Pass - Major Risk 1H-116. 1H -116-1H-116 373.47 178.35 373.47 170.71 375.00 23.335 Centre Distance Pass - Major Risk 1 H-116 - 1 H-116 - 1 H-116 496.23 179.57 496.23 169.52 500.00 17.866 Clearance Factor Pass - Major Risk 1 H-118 - 1 H-118 - 1 H-118 39.00 239,67 39.00 237.09 38.85 92.759 Centre Distance Pass - Major Risk 1H -118 -1H -118-1H-118 348.90 241.74 346.90 235.59 350.00 39.316 Clearance Factor Pass - Major Risk iH-12-iH-12-1H-12 2,516.35 446.83 2,516.35 379.54 2,600.00 6.641 Centre Distance Pass - Major Risk 1H -12 -1H -12-1H-12 2,534.35 447.04 2,534.35 379.51 2,625.00 6.620 Clearance Factor Pass - Major Risk 07 March, 2018 - 10.27 Page 2 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 11-1-110-1H-11Owp26 Trav, Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk lH Pad - Plan: 1N -110 -Plan: 1H-110-1H-110Wp26 Scan Range: 0.00 to 10,428.25 usft. Measured Depth. Scan Radius is 1,238.92 uaft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 07 March, 2018 - 10:27 Page 3 of 6 COMPASS Measured Minimum @@Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft iH-13-1H-13-1H-13 4,141.03 395.69 4,141.03 258.81 3,900.00 2.891 Clearance Factor Pass - Major Risk iH-401(UGNU)-1H-401-1H-401 1,386.15 152.91 1,386.15 117.39 1,550.00 4.304 Centre Distance Pass - Major Risk 1H-401(UGNU)-iH-401.1H-401 1,401.62 154.07 1,401.62 117.32 1,575.00 4.193 Clearance Factor Pass - Major Risk Plan: 1H -103 -Plan: 1 H-1 03 - 1 H-1 03wp26 299.90 120.00 299.90 114.73 300.00 22.772 Centre Distance Pass - Major Risk Plan: 1H -103 -Plan: 1 H-103 - 1 H-1 03wp26 477.14 121.14 477.14 113.35 475.00 15.561 Clearance Factor Pass - Major Risk Plan: 1H -104 -Plan: 1H-104-iH-104Wp23 299.90 59.94 299.90 54.60 300.00 11.223 Centre Distance Pass - Major Risk Plan: 1H -104 -Plan: 1H-104-1H-104wp23 500.71 60.74 500.71 52.42 500.00 7.302 Clearance Factor Pass - Major Risk Plan: 1H -106 -Plan: 1H-106-1H-106Wp22 275.00 209.95 275.00 205.04 275.00 42.796 Centre Distance Pass - Major Risk Plan: 1H -106 -Plan: 1H-106-1H-106wp22 427.77 210.91 427.77 203.70 425.00 29.249 Clearance Factor Pass - Major Risk Plan: 1H -107 -Plan: 1 H-107 - 1 H-107wp22 250.00 150.33 250.00 145.86 250.00 33.638 Centre Distance Pass - Major Risk Plan: 1H -107 -Plan: 1H-107-1H-107wp22 325.40 150.94 325.40 145.32 325.00 26.836 Clearance Factor Pass - Major Risk Plan: IH -108 -Plan: IH-108-1H-108wp21 678.19 86.71 678.19 75.52 675.00 7.749 Centre Distance Pass - Major Risk Plan: IH -108 -Plan: 1H-108-1H-108wp21 854.50 88.10 854.50 74.07 850.00 6.279 Clearance Factor Pass - Major Risk Plan: 1H -112 -Plan: 1H-112-iH-112wp21 300.00 60.04 300.00 54.70 300.00 11.239 Centre Distance Pass - Major Risk Plan: 1H -112 -Plan: 1H-112-iH-112wp21 448.98 61.29 448.98 53.51 450.00 7.884 Clearance Factor Pass - Major Risk Plan: 1H -115 -Plan: 1H-115-1H-115wp21 299.90 149.89 299.90 144.55 300.00 28.063 Centre Distance Pass - Major Risk Plan: 1 H-115 - Plan: 1 H-115 - 1 H-115wp21 765.77 152.79 765.77 140.01 775.00 11.958 Clearance Factor Pass - Major Risk Plan: IH -117 -Plan: 1H-117.1H-117wp26 300.00 210.13 300.00 204.78 300.00 39.330 Centre Distance Pass - Major Risk Plan: iH-117-PIan:1H-117-1H-117wp26 446.66 211.31 446.66 203.56 450.00 27.285 Clearance Factor Pass - Major Risk 07 March, 2018 - 10:27 Page 3 of 6 COMPASS ConocoPhillips Anticollision Report for Plan: 11-1-110 - 1H-110wp26 Survey tool orouram From Neal 39.00 1,700.00 1,700.00 1,825.00 1,825.00 9,315.00 9,315.00 To (usft) 1,700.00 1H-110wp26 1,625.00 1H-110wp26 1,825.00 1H-110wp26 2,325.00 1H-110wp26 9,315.00 1H-11 Owp26 10,427.63 1H-110wp26 10,427.63 1H-110wp26 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool GYD-GC-SS MWD MWD,IFR-AK-CAZSC MWD MWD+IFR-AK-SCC MWD MWD+IFR-AK-CAZSC ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 07 March, 2018 - 10:27 Page 4 of 6 COMPASS Ladder View 1 H-110wp26 The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors � � 3 S S i II S S TIf 130— � 1 1 I' p I i �1 N CO) 11111 1111111 II �i 'i ! U65 _ _....__. v Equiv 1 M Mai Dislanc - - O 0 0 1500 3000 4500 6000 7500 9000 10500 Displayed interval could be less than entire well:Measured Depth 39.00 To 10428.25 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 1700.00 1H-110wp26 (Plan: 11-1-110) GYD-GC-SS 118.00 118.00 20"x42" 1700.00 1825.00 1H-110wp26 (Plan: 11-1-110) MWD 1743.OKB26.23 10-3/4"1 1700.00 1825.00 1H-110wp26(Plan:11-1-110) MWD+IFR-AK-CAZ-SC 4086.1GB317.85 7'x8-3/4" 1825.00 2325.00 1H-110wp26(Plan:11-1-110) MWD 3769.11927.63 4-1/2"x6-1/8" 1825.00 9315.00 11-1-110wp26 (Plan: 11-1-110) MWD+IFR-AK-SCC 9315.0010427.63 1H-110wp26 (Plan: 11-1-110) MWD 9315.0010427.63 1H-110wp26 (Plan: 11-1-110) MWD+IFR-AK-CAZ-SC i s 60 11 C III a Me tic Dianne 9ne �_Equivalent d 1 d I I N 30 U 0 0 c m U 0- 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth C r 0 t Northing (1500 usk/in) D a Y (uifysn oogL) E r I Northing (250 usft/in) (u.44sn OSZ) 6ui4NON O = _ _ ♦- r N _ t0 N 2 4 x 0 N 3 = o I _ I (u.44sn OSZ) 6ui4NON 9,50, March 07 2018 I 1 H-110wp26 TC View SURVEY PROGRAM bLUTION DI, I AILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 39,001700.00 GYD-GC-SS 39.00 0.00 0.00 39.00 0.00 0.00 1700.00 1825.00 MWD 300.00 0.00 0.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 110° TF, for 30V 1700.00 1825.00 MWD+IFR-AK-CAZ-SC 600.00 4.50 110.00 599.69 1.50 110.00 Start 2.5°1100' OILS, 0" TF, for 300' 1825.00 2325.00 MWD 900.00 12.00 110.00 896.38 2.50 0.00 Adjust TF to -5°, for 729.38' 1825.00 9315.00 MWD+IFR-AK-SCC 1629.38 30.21 106.89 1574.00 2.50 -5.00 Hold for 115.71' 9315.00 10427.63 MWD 1745.09 30.21 106.89 1674.00 0.00 0.00 Start 3.75'1100' DLS, 0° TF, for 81.13' 9315.00 10427.63 MWD+IFR-AK-CAZ-SC 1826.23 33.25 106.89 1743.00 3.75 0.00 Hold for 20' 1846.23 33.25 106.89 1759.73 0.00 0.00 Stan 3.75°1100' DLS, 3.26° TF, for 1136.9' 2983.13 75.85 109.17 2404.12 3.75 3.26 Hold for 3974.14' 6957.26 75.85 109.17 3375.83 0.00 0.00 Start 3.5'/100' OILS, -109.03° TF, for 1144.94' 8102.21 67.01 67.78 3755.00 3.50 -109.03 1 H-110 T01 D 082417 FH Hold for 378.9' 8481.11 67.01 67.78 3903.00 0.00 0.00 IH -110 T02 A3 082417 FH Start 4°/100' DLS, -12.17° TF, for 134.06' 8615.17 72.25 66.60 3949.65 4.00 -12.17 Hold for 101.05' 8716.22 72.25 66.60 3980.45 0.00 0.00 Start 4°/100' DLS, -52.4° TF, for 601.62' 9317.85 87.63 47.73 4086.13 4.00 -52.40 1H-110 7 Cs9 Pt Hold for 20' 9337.85 87.63 47.73 4086.96 0.00 0.00 Start 4"/100' DI -S, -16.85- TF, for 828.48' 10166.33 119.22 37.27 3896.55 4.00 -16.85 Hold for 261.3' 10427.63 119.22 37.27 3769.00 0.00 0.00 1H-110 T05 TO 082417 FH TD: 10427.63' MD, 3769' TVD CASING DETAILS TVD MD Name 118.00 118.00 20" x 42" 1743.00 1826.23 10-3/4"x13-1/2" 4086.13 9317.85 7" x 8-3/4" 3769.00 10427.63 4-1/2"x6-1/8" 1 H-114 H-115wp21 _ 0 i H-111 1 H-113 330 ,�30 ,I. 39 380 ��tr„ew 380 570 570-760 300 60 760 -950 H-112wp21 -�� tp 950 - 1140 ,iii 1140 - 1320 1320 - 1510 r Bio �s1 1510 1700 �o 1700 - 2060 2060 2430 90 2430 - 2790 - 2790 3150 270 3150 - 3510 n� 3510 - 3870 M, 3870 - 4240 4240 - 4600 1 H-104wp2 1 z - 4600 - 5340 5340 - 6070 240 120 6070 - 6810 6810 - 7540 1 7540 - 8280 1H-109 8280 9020 9020 9750 21 150 9750 - 10489 H-108wp21 1H-107wp2 180 -- - - -1 H-103wp2 m O C 3 O O O O O O O O 0 0 0 0 0 0 0 00 O O O O N - O M M M Ln r � J IT I` r 'q 00 N M V 00 I- M Ln r M M I- O V r LO 00 N (O M O M Ln N O I- O �. 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00000000 mo O � � vi vi ❑�M(Om m v m ro M(Om(p f�o�op Ol Q]��(O I�MMa-� ��'-r-N (OWaDW COT000 o. morn ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad Plan: 1H-110 50029xxxxx00 Plan: 1H-110 Plan: 1 H-110wp26 Error Ellipse Survey Report 07 March, 2018 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1 Pad Well: Plan: 1H-110 Wellbore: Plan: 1H-110 Design: 1H-110wp26 ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Output errors are at Database: Well Plan: IH -110 Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 Q 93.00usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Project Kuparuk River Una, North Slope Alaska, United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk I Pad Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan: 1H-110 Well Position +NIS 0.00 Usti +E/4N 0.00 Usti Position Uncertainty 0.00 usft Ground Level: 54.00 usft Wallbore Plan: 1H-110 Magnetics Model Name Sample Data Declination Dip Angle Field Strength (9 (1 0T) BGGM2017 2/15/2018 17.25 80.94 57,476 Design 1H-110wp26 Date 2/2 612 01 8 From Audit Notes: (usft) (usft) Survey (Wellbore) Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) -N/-S +E/ -W Direction 1,700.00 (usft) (usft) (usft) (11 2,325.00 1 H-110wp26 (Plan: 1 H-110) 39.00 0.00 0.00 90.00 Survey Tool Program Date 2/2 612 01 8 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,700.00 1H-110wp26 (Plan: 1H-110) GYD-GCSS Gyrodata gyro single shots 1,700.00 1,825.00 1H-110WP26(Plan: 1 H-110) MWD MWD -Standard 1,700.00 1,825.00 1H-110wp26(Plan: 1 H-110) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,825.00 2,325.00 1 H-110wp26 (Plan: 1 H-110) MWD MWD -Standard 1,825.00 9,315.00 1H-110wp26(Plan: 1 H-110) MWD+IFR-AKSCC MWD+IFR AK SCC Sperry 9,315.00 10,427.63 1H-110WP26(Plan: 1 H-110) MWD MWD -Standard 9,315.00 10,427.63 1H-110wp26(Plan: 1 H-110) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/7/2018 10.24:17AM Page 2 COMPASS $000.14 Build 85 6 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well Plan: 1H-110 Project: Kuparuk River Unit TVD Reference: Plan: 54+39 Q 93.00usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: Plan: 54+39 Q 93-00usft (Doyon 142) Well: Plan: 1H-110 North Reference: True Wellbore: Plan: 111-110 Survey Calculation Method: Minimum Curvature Design: 1H-110wp26 Output errors are at 1.00 sigma sepia Database: OAKEDMP2 Plan Survey Tool Program Date 2/26/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,700.00 1H-110wp26 (Plan: 1 H-110) GYD-GC-SS Gymdata gyro single shots 2 1,700.00 1,825.001H-110wp26(Plan:111-110) MWD MWD - Standard 3 1,700.00 1,825.001H-110wp26(Plan;111-110) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 1,825.00 2,325.001H-110wp26(Plan: 1H-110) MWD MWD - Standard 5 1,625.00 9,315.00 1H-110wp26 (Plan: 11-1-110) MWD+IFR-AK-SCC MWD+IFR AK SCC Sperry 6 9,315.00 10,427.631H-110wp26(Plan: 1H-110) MWD MWD - Standard 7 9,315.00 10,427.63 1H-110wp26 (Plan: 11-1-110) MWD+IFR-AK-CAZ-SC MWD+IFRAK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Arauth Vertical NighsMe Uw.1 wr8w1 Magnitude Swi,siNor fiemV+ninor sepia Depth Error Bias EBor Bias Error Bus of Bias Error Enor Arhnuth Tod (aaa) (% M lean) (am) lush) Nan) (aslp (ush) tush) (asnl (asnl (assn) M 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 100.03 0.00 ew 100.00 0.04 0.00 0.04 0.00 1.15 0.00 0.00 0.04 0.04 0.00 GYDGGSS (1, 1) 118D0 0.00 0.00 118.00 0.19 see 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD W (1, 1) 200.00 0.00 0.00 200.00 0.19 Bee 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GY0.G6B8 (1, 1) 300.00 0.00 0.00 300.00 0.33 0.00 0.33 0.00 1.15 0.01 0.01 0.33 0.33 0.00 GYDGGBs(1, 1) 400.00 1.50 11000 399.99 0.44 0.00 0.44 ew 1.15 0.01 0.01 0.41 0.44 45.00 GY GCSs(1, 1) 500.00 3.00 110.00 499.91 0.53 9.00 0.53 0.00 1.15 0.02 0.02 0.53 0.53 20.67 0Y0.GG8s (1, 1) 600.00 4.50 110.00 599.69 e64 0.00 0.04 0.00 1.15 0.03 0.03 0.81 0.64 21.42 GY c -ss (1, 1) 700.00 7.00 liew 899.18 026 0.00 0.77 ew 1.15 0.05 0.05 0.71 0.77 25.29 GY c-ss(1, 1) 800.00 9.50 110.00 798.14 0.09 -0.01 0.91 0.00 1.15 0.07 Ban 0.91 0.91 10S68 GY GG55(1,1) 900.00 12.00 110.00 896.38 1.03 4.01 1.07 0.00 1.15 BOB 0.09 1.07 1.05 108, 2 GYD-GCSS(1. 1) 1,000.00 14.49 109.13 993.71 1.9 4.01 1.25 0.00 1.14 0.11 0.11 1.25 1.20 109.20 GYD-GGSs(1, 1) 1,100.00 16.99 108.51 1,089.95 1.32 4.02 1,44 0.00 1.14 0.13 0.13 1.44 1.36 109.28 GYDGD-ss(1, 1) 1,200.00 19.40 108.05 1,184.92 1.47 -0.02 t.fi6 Bw 1.14 0.16 0.16 I'M 1.52 109.07 GYD-GGSS o. 1) 1,300.00 21.90 107.68 1278.44 1.63 -0.03 1.90 0.00 1.15 0.19 0.19 1.90 1.69 tBan GYc.GOBs(1. 1) 1.400.00 24.48 107.39 1.370.33 1.79 -0.01 2.16 0.00 1.16 022 0.22 2.16 1.86 108.52 GYDGOSS (1, 1) 1,500.00 26.97 107.15 1.180.41 1.98 -0.05 2.44 000 1.18 025 0.26 2.44 2.04 108.27 GY6G0W(1, 1) 1,600.00 29.47 108.95 1,548.51 2.14 -0.06 225 0.00 121 0.28 0.29 2.75 2.22 108.04 GYDGO-W(1. 1) 1,829.38 30.21 106.89 1,94.40 2.19 -0.07 2.85 0.00 1.21 029 0.30 2.85 228 108.00 GY6GC-SS(1. 1) 1,69.24 30.21 105.89 1,624.00 2.34 4.07 3.08 Bee 1.25 0.31 0.33 3.08 2.40 107.85 GYDG (1, 1) i.7w.00 30.21 106.69 1,63503 2.34 -0.07 3.08 0.00 125 0.31 0.33 3.08 2.40 107.85 GYDGC-5311,1) 1,745.09 30.21 106.89 1,9100 2.39 -0.07 3.16 0.03 126 0.33 0.35 3.16 2.45 107.02 KIM (1. 2) 1,800.00 32.27 105.89 1,720.94 2.37 AM 3.23 0.12 126 0.35 0.39 323 2.45 107.79 MMM. 2) 1,828.23 33.25 106.89 1,743.00 235 -0.09 3.18 0.02 1.24 0.36 0.38 3.16 2.46 107.89 MWD(2,3) 3!72018 1024: 17AM Page 3 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk I Pad Well: Plan: 1H-110 Wellbore: Plan: 1H-110 Design: 1H-110wp26 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: survey Calculation Method: Output errors are at Database: Well Plan: 1H-110 Plan: 54+39 @ 93.00usR (Doyon 142) Plan: 54+39 @ 93.00usR (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Neuuletl I Ml n AanaM WNW HpOaMe Lateral Verna wvitu6e semimUor Semi+ninor papal aep111 E. aas Error BWs Error pipe of Blas E., Enar AvmuN Tod (un) M P) (ualb ('am (usn) (uea) (usn) Iusn) (usa) (usn) (--ft) 4 -aa) V) 1,84613 33.25 106.09 1)59.73 2.% -0.09 3.20 0.06 1.24 0.36 0.38 3.20 28 107.7 MM (2.3) 11890.02 34.89 107.05 1798.00 2.34 -0.10 3.31 0.16 1.2r 0,38 0.44 161 2.48 107.00 MWD (2,3) 11900.00 3516 17.09 1,804.17 2.34 4.10 3.31 0.16 1.24 0.36 0.44 3.31 2.48 107.80 MWD (2.3) 2,000.00 39.01 107.41 1.883.88 2.31 -0.13 374 0.37 1.24 0.42 0.58 3.74 2.51 107.72 MWD Q. 3) 8,100.00 42.75 107.89 1.959.47 2.31 445 4.45 0.61 118 OA5 0.79 4.45 2.56 107.74 MWD C2,3) 2,200.00 48.50 107.92 2,030.63 2.34 4.18 5.40 0.89 1.31 0.48 1.04 SAO 2.63 17.82 MWD (2, 3) 2,203.45 4883 107.93 2,033.00 2.39 -0.21 8.51 112 1A0 0.51 1.35 6.51 2.71 107.93 MWD(2, 3) 2,300.00 W.M 100.13 2.007.05 2.39 4.21 6.51 1.22 1.40 0.51 1.35 6.51 2.71 17.93 MWD (2, 3) 2,400.00 53.99 108.12 2,158.44 2.14 4.26 5.63 0.00 1.25 0.54 0.62 5.00 2.84 108.39 MW IFR-M(WC(3,3) 2,500.00 57.74 100.49 2,214.54 2.12 -0.30 6.42 0.00 1.29 0.57 0.66 6.42 2.68 108.49 MWSNIFR-AK-WC(3.3) 2,000.00 61.49 108.65 2,265.11 2.11 -0.33 7.25 -0.01 1.38 0.59 0.70 7.25 272 108.57 MV WR -W( -=C(3,3) 2,700.00 6514 108.79 2,309.94 2.10 4.38 8.10 -0.01 1M 0.61 0.74 8.10 2.76 108.64 MW Wlt-AKSCC(3,3) 2,800.00 68.90 108.93 2,348.83 2.11 .0.42 8.88 4.01 1.54 0.63 070 8.88 2.W 108.70 MWSa6R-AK-SCC(3,3) 2,900.00 72.73 109A6 2,381.81 2.12 -0.46 9.81 4.01 1.85 0.00 0.81 9.01 200 108.76 MW WR-AK-SCC(3,3) 2.983.13 75.85 109.17 2.404.12 2.14 -0.60 lo.W 4.01 175 0.65 0.84 10.7 285 10880 MW WR-AK-WC(3,3) 3,00.0 75.85 109.17 2,400.25 2.17 4.50 10.64 4.01 177 0.65 085 10.64 2.00 108.81 MW IFR-M-WC(3. 3) 3,100.00 7585 109.17 2,432.70 2.30 -0.50 11.8 -0.01 1.92 O.W 0.88 11.0 2.00 10888 MW WR-AK-WC(3,3) 310.00 75.85 109.17 2,457.15 2.45 -0.60 12.32 4.01 2.07 0.67 0.91 12.32 2.90 108.90 MM IFR -AK -GCC (3.3) 3,30.00 75.85 10.17 2,481.80 2.59 -0.W ilia -0.01 212 0.68 0.95 13.18 2.7 108.93 MW IFR -AK -WC (3,3) 3,400.00 75.85 109.17 2506.05 2.74 4.60 14.05 -0.01 2.37 0.69 0.99 14.05 2.94 108.26 MW IFR-AK-SCC(3,3) 3,500.W 75.85 109.17 2,530.50 2.90 4.00 14.92 -0.01 253 0]0 1.02 14.92 296 108.98 MW9HFR-AKSCC(3,3) 3,60.00 75.85 10.17 2554.95 3.05 -0.50 15.80 -0.01 269 0.71 1.00 15.80 2.0 10.02 MW IFR -A C(3,E) 3,7W.00 75.86 100.17 2.579.40 3.21 -0.60 16.88 -0.01 2.85 0.72 1.10 18.88 3.01 109.04 Mb IFR -AK -SCC (3.3) 3.80.00 7585 109.17 2603.05 3.37 4.50 17.57 -0.01 3.01 0.73 1.14 17.57 3.03 109.05 MW IFR -W( -SGC (3,3) 3,900.00 75.85 109.17 2,628.30 3.53 490 18.48 -801 3.17 0.75 1.19 18.46 3.05 10.7 MWDHFR-A CC (3.3) 4.00080 75.85 109.17 2,652]6 310 4.50 19.38 -0.01 3.34 076 1.23 19.38 3.00 10.0 MWMIFR-AKSCC(3.3) 4,100.00 75.85 109.17 2,6.4.21 9.86 -090 20.28 -0.01 150 0]7 1.27 20.26 3.10 10.10 MWDeIFR-AK-SCC(3,3) 4,27.00 75.05 109.17 270198 4.00 4.W 21.16 4.01 3.67 078 1.92 21.16 3.13 109.11 MWD+1FR-W(4CC(3,3) 4,30.0 75.85 109.17 2728.11 4.19 -0.50 22.05 -0.01 183 079 1.36 22.06 3.16 109.12 MW0+IFR-AK-SGCRa) 4,40.00 75.65 109.17 2,750.7 4.30 -0.50 2298 4.01 400 0.00 1.41 22.96 3.10 109.13 MM -IFR -AK -SCC (l 3) 4,600.00 75.05 10.17 2775.01 4.53 -0.50 23.87 -0.01 4.17 0.82 1.46 23.7 3.21 109.14 MM-IFR-AK-SCC(3,3) 4,600.0 75.85 10.17 2,799.46 4.70 -0.50 24.70 4.01 4.33 0.83 1.50 24.78 3.24 109.15 M%V11FR-W(-SCC(3.3) 4,700.W 75.85 109.17 2,823.91 4.08 -Ua 25.69 4.01 4.00 0.84 1.55 2589 3.27 109.16 MWD-IFR-WASCC(3,3) 4,800.0 75.05 109.17 2,848.36 5.03 .0.50 26.60 -0.01 4.67 0.05 1.60 26.60 3.30 109.17 MW IFR-AKSCC(3.3) 4,900.00 75.05 10.17 2,872.81 5.20 .0.50 27.51 4.01 4.04 0.87 1.65 27.51 3.33 100.10 MW IFR-A(-SCC(3,3) 5.00.0 75.85 109.17 2.897.26 5.30 -O.W 28.42 4.01 5.W 0.88 130 28.42 in 109.48 MW IFR-AK-SCC(3, 3) 511010 75.85 10.17 2.921.72 5.55 -0.60 29.33 -0.01 5.17 0.89 1.75 29.33 3.39 109.19 MW IFR-W-WC(3,3) 5,20.00 75.85 10.17 2,94fi.17 5.72 460 30.25 4.01 5.34 0.91 1.01 30.25 3.42 100.19 MW IFR-AK-WC(3,3) 5,30.00 75.85 109.17 2,970.62 5.89 -0.W 31.16 4.01 5.51 0.92 1.86 31.16 3.45 109.20 MW IFR-AKSCC(3,3) 5,400.00 75.85 109.17 2995.7 6.06 -0.60 32.07 4.01 5.80 0.93 1.91 32.07 3.0 10.20 MWDNFR-AKSCC (3,3) 5,57.00 75.85 10.17 3,019.52 813 -0.W 32.9 -0.01 5.85 0.95 1.7 32.0 3.51 10.21 MW IFR-AKSCC(3,3) 5.60.00 75.85 108.17 3,04997 6.41 4.50 33.91 4.07 6.02 0.56 2.02 33.91 3.54 109.21 64WDHFR-AKSCC(3,3) 5700.0 75.85 109.17 3,060.42 6.58 4.60 34.82 -0.01 6.18 Gm 2.0 34.7 3.50 17.22 MWDHFR-AKSCC (3,3) 5,000.00 75.85 109.17 3,092.07 6.75 -0.50 35.74 -0.01 6.35 099 2.14 35.74 3.61 10.22 MWDHFR-AR-SCC(3, 3) 5.9W.W 75.85 109.17 3.117.32 6.92 -0.50 38.68 -0.01 6.52 1.01 219 W.W 864 109.22 MWDdFR-W(-S0C(3,3) 6,OW.00 75.85 109.17 3,141]7 7.10 4.50 37.57 .0.01 6.69 1.02 2.25 37.57 3.68 10013 MWWIFR-W(-SCC(3,3) 6,045.91 75.85 109.17 3,153.00 7.27 -0.50 38.49 -0.01 am 1.0 2.31 38.49 3.71 109.23 MW IFR -A3( -SCC (3.3) 6,100.00 75.05 10.17 3,166M 7.27 -0.50 38A9 .0.01 6.00 1.03 2.31 38.49 3.71 10913 MWSAIFR-AK-WC(3, 3) 6,2780 75.85 10.17 3,17.80 7.44 4.50 39.41 .0.01 7.03 1.05 2.37 39.41 175 109.24 MW IFR-AWBCC(3, 3) 8,300.0 75.85 109.17 3.215.13 Tat -0.50 40.33 -0.01 710 1.07 2.43 40.33 3.78 109.24 MW VR -AI( -SCC (3.3) 6.400.00 75.05 109.17 3,239.50 7.79 -0.00 41.25 4.01 787 1.08 2.49 41.25 lag 10914 MP IFR -AK -WC (3.3) 8,50.00 75.85 17.17 3,264.03 7.97 -0.60 42.17 4.01 7.54 1.10 2.58 42.17 lW 109.24 MWWIFR-AK-WC(3,3) 6,600.00 75.85 10.17 3,280.40 8.14 .0.50 4109 4.01 731 1.11 2.62 43.09 3.89 109.25 M IFR-AI(SCC(3.3) 8,700.00 75.85 10.17 3.312.93 8.31 4.00 44.01 4.01 7.88 1.13 2.68 44.01 3.92 10.25 MWDNFR-AKSCC (3.3) 317201810.24: 17AM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-110 Wellbore: Plan: 1H-110 Design: 1H-110Wp26 ConocoPhillips Error Ellipse Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 11-1-110 Plan: 54+39 Q 93.00usft (Doyon 142) Plan: 54+39 Q 93.00usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station M wni wauean R auM V41aw1 th inM Iamn1 Verlkel Mari sealk"or SnnimMar Minh ppm Eoer Bide Ertor Blae E. Bles oraMa Emw Eno, Axinuni 1691 IasM 0 PI (panl (vert) (wM lusts (um) (vanl (use) Nor) (esn) IusM 0 5,800.00 75.05 IWA7 3337.36 8.49 -040 44.93 -0.01 8.05 1.14 2.75 44.93 3.90 109.25 MW IFR -AH -SCC (3,3) 8900,00 75.85 109.17 3,361.83 8.66 am 4585 -0.01 8.22 1.16 2.81 45.85 4.0D 109.25 MY IFR -MK SCC (3.3) 6,957.26 75.85 109.17 3.375.63 0]6 4.00 46.38 .0.01 8.32 1.17 2.85 46.38 4.02 109.25 MW I`R-M-SCC (3. 3) 7,000.00 75.36 107.70 338646 0.87 -0.47 46.72 0.06 8.39 1.18 248 46.74 4.03 109125 MN IFR- -SCC (3,3) 7,100.00 74.27 104.26 3.41246 9.17 4.42 0.35 0.22 8.56 1.19 2.94 47.53 4.00 10920 VW IFR-M-SCC(3,3) 7,10.62 74.10 103.95 3.415.00 9.55 4.37 47.60 0.38 073 1.21 3.01 48.31 4.11 ursio MW IFR-Aa-SM(3.3) 7,200.00 73.23 100.78 3,44045 a55 -0.37 47.80 0.30 8.73 1.21 3.01 48.31 4.11 109.10 MW IFR -A3( -SCC (3.3) 7,300.00 72.25 9716 3,470.32 10.03 4.33 49.07 0.55 8.99 1.24 3.09 49.08 4.15 106.94 MW Wlr-ARSCC (3,3) 7,400.00 7113 93.70 3501.58 10.63 419 48.14 072 9.06 116 3.16 49.83 4.20 10a74 MN IFR-AK-SCC(3,3) 7.429.23 71.08 92.88 351140 11.35 -0.27 4840 0.90 9.22 1.28 3.24 50.56 4.25 106.49 MV IFR -M -SCC (3,3) 7,500.00 70.48 90.11 3.534.30 1195 427 48.00 0.90 912 1.28 3.24 50.56 4.25 108.49 MY IFR-AK-SCC(3,3) 7,600.00 6931 86.46 3.568.36 12.17 -024 47.65 1.08 9.38 1,31 3.31 51.27 4.31 108.20 MW IFR-AKSCC(3,3) 7]0100 69.00 82.82 3,60363 13.09 -0.23 47.09 116 9.54 1,34 3.39 51.94 4.39 107.87 Mb IFR-MSCC(33) 7,775.56 66.52 80.03 3,631.00 14.09 4.23 4830 1.45 9.70 1.37 3A7 52.57 4.50 107.52 MW IFR -MK 0(3,3) 7,800.00 68.9 79.12 3.839.98 ilea 423 46.30 1,45 9.70 1.37 3.47 52.57 4.50 107.52 MWWIFR-N(SCC 0, 3) 7,900.00 87.64 75.39 3,677.27 15.15 -0.24 45.29 1.83 9.86 140 354 53.9 4.62 107.13 MWD -IFR -AK -BCC (3, 3) steam 67.38 71.64 3,715.37 15.23 -0.26 44.05 1.81 10.02 1.34 3.82 53.73 420 10823 MMIFR-A(SC0(3,3) 810040 67102 67.67 3]54.14 17.32 -0.28 42.59 2.00 10.17 147 3.70 5424 4.90 108.31 VMOFR- SCC (3,3) 0,10221 67.01 67.78 3,755.00 17.35 -0.29 42.56 2.00 10.13 1.47 3.70 5425 4.99 106.30 MWDIFR-MSCC(3,3) 8,14533 67.01 67.78 3.772.00 17.46 -0.29 43.25 2.00 10.33 1.51 3.78 54.79 5.13 105.95 MWDNFR-M-$CC(1,3) 0,200.00 67.01 67.78 3,79320 17.46 429 43.25 2.00 10.33 1.51 3.78 54]9 5.13 10885 MWD+IFR-M-6CC(3,3) 8183.50 67.01 67.78 3,81840 17.57 -0.29 41.03 2.00 10.49 1.54 385 5540 5.22 105.35 MWDNFR-M-50C(3,3) 830040 67.01 67.78 3.832.26 17.57 -0.29 44.03 2.00 10.49 1.54 3.85 55.40 5.22 105.35 MW IFR-AWSCC(3,3) 8,314.70 67.01 67.78 3.83800 17.69 4.29 44.81 2.00 10.64 1.58 3.93 56.112 5.31 104.86 MM+IFR-AK-SCC (3.3) 8.322.38 67.01 67.78 3841.00 17.68 -0.29 44.81 2.00 10.64 1.58 3.93 56.02 5.33 104.68 MW IFR -AK -500 (3.3) 8.400.00 67.01 67.78 3.971.32 17.69 4.29 44.61 2.00 10.61 1.58 3.93 5842 5.33 104.86 MV IFR- -SCC (3,3) 8.401.11 67.01 67.78 3,903.00 17.70 419 45.45 2.00 10]7 1.61 4.00 56.53 5.42 104.47 MV IFR-M-SCC(3,3) 6,499.30 6712 67+62 3,910.00 17.54 4.33 45.49 2.01 10.80 1.62 4.02 66.65 5.45 104.38 MV IFR -M -SCC (3, 3) irtoew 0.75 67.61 1,91017 17.54 4.33 45.49 2.01 1040 1,62 442 5865 5.45 104.38 Ab IFR-MSCC (3,3) 8800.00 71.66 ears 3,944.95 18.25 -0.58 45]2 2.08 10.96 1.65 4.09 57.24 5.62 103.92 MNI10+1FR-M( 0(3,3) 8,615.17 72.25 66.60 3,94945 16.05 4A2 45.76 2.06 10.98 1.65 4.10 57.33 5.65 103.85 MV IFR- SCC (3, 3) 8,700.00 72.25 66.60 3,975.50 16.18 -0.82 46.41 2.08 11.12 1.68 4.17 57.84 5.79 103.45 MWD+IFR-AKSCC(3,3) -871612 72.25 66,60 3960A5 16.18 -0a2 46.54 2.06 1115 1.68 4.18 67.95 5.82 103.37 MWD+IFR-N(SCC(3,3) 8,74825 73.04 65.54 3,990.00 15.87 -0.78 45.44 2.22 1129 170 4.24 58.40 641 103.01 MWDNFR- SCC (3,3) amaeo 74.32 63.84 4,004,54 15.87 .0.78 45.44 2.12 11.29 1.70 4.24 58.40 6.01 103.01 MWDNFR-MSCC (3,3) 9,90040 76.02 60.62 4,029.47 15.32 -0.96 43.95 2A0 11148 172 441 50.01 6.34 10260 1AVA+11FR-A(-SCC (3.31 %000.00 79.37 57,47 4.050.09 14.65 -1.14 4295 257 11.63 1.74 497 5914 6.74 10220 MW IFR-A&SCC (3.3) 9.10000 81.95 5637 4,066.33 13.92 -1.31 40.67 273 11.80 1.75 4.42 59.60 7.19 101.79 Ml IFR -M -SCC (3. 3) 0200.00 84.55 arm 4,078.09 13.21 -1.47 38.89 2.89 11.97 1.76 4A7 59.91 771 101.40 MW IFR -MK C(3,3) 8300 00 87.16 40.27 4,085,32 12.64 -1+62 37.03 3.04 12.15 1.76 651 60.19 8.30 101.01 10AAN1`R-MSCC (3,3) 9,31285 87.63 47.73 4,006.13 12.55 -1.64 36.69 3.09 12.16 1.76 4.54 60.28 8.28 loom MWD(3,4) 0337.85 07.63 47.73 4.086.96 12.55 -1.64 36.78 3.15 12.16 1.76 4.50 60.33 8.31 100.89 MM (3.4) %400.00 90.01 Val 4,088.24 1216 .1]6 36.49 3.37 12.16 1.76 473 60.50 8.43 100.67 MWD(3.4) 050000 93.64 45.85 4,011 12.21 -1.94 36.07 3.70 1216 1.76 4.96 Son 8.77 100.27 MAA (3.4) 9,600.00 97.66 44.68 4,074.06 13.13 -2.11 35.69 4.03 12.20 1.76 5.19 61.05 9.27 99.84 MAA (3.4) 9,700.00 101,49 43.49 4,058.23 14.82 -225 35.35 4.34 1224 175 5.40 61.34 9.89 9908 MWD(3,Q 9,800.00 105.31 42.26 4.035.06 9.06 -2.38 35.03 CW 12.29 175 5.60 61+62 10.60 9890 MM (3.4) 9,900.00 109.12 4049 4,005.49 1970 .2.48 31.71 690 12.34 1.74 5.79 61.91 11.39 98.39 MWD(3,4) 10,00000 112.92 39.66 3.959.61 22.59 -2.55 mas 5.16 12.410 1.74 5.96 62.19 12.23 97.66 MWD(3, 4) 10,10000 116.71 %.25 3,927.85 25.65 -2.58 34.02 5.39 12.47 1.74 6.11 62.47 13.10 97.32 MWD(3,4) 10,166.33 119.22 3727 3,896.55 27.74 -2.59 3375 5.54 12.62 175 6.20 62.66 1389 96.96 FAM (3,4) la' ID.aa 119.22 3717 3,680.11 2775 -2.59 34.06 5.59 12.54 1.75 6.25 62.75 1300 96]0 FAM (3,4) 10.300.00 119.22 3727 3,831.30 2779 -249 alas 5.74 12.61 1.76 6.38 63.02 14.81 96.23 MM (3.4) 10,400.00 119.22 37.27 3782.49 27.63 -249 35.75 5.89 12.69 1.A 6.51 W31 15.65 95.87 MWD(3,4) 3,7/2018 10:24:17AM Page 5 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Ina -Kupt Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 11-1-110 Wellbore: Plan: 1H-110 Design: 1H-110wP26 ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: IH -110 Plan: 54+39 @ 93.00usft (Doyon 142) Plan: 54+39 @ 93.00usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and blas at survey station Target Name Meesu.d Ndi,unon R ..h Vemwl Hi,haide lateral Vertlul Magnant saml wn semiminm aamn omni E., Sus Emor Bias Emir Blas of Bus Emar Eno, %inlmh TOW (usft) (1 (°i (usft) iusnl (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usrl) (1 10,427,63 119M 37.27 3,769.00 27.53 -2.70 2977 3.56 1281 1.77 4.62 61.05 1030 99.59 MWD+IFR.MKC ZSn(4,4) Design Targets Target Name Vertical Casing Hole - hitimiss target Dip Angle Dip Dir. TVD +N/S +EI -W -Shape V) (') (usft) (usft) (usft) 1H-110 T01 D 082417 F 0.00 0.00 3,755.00 -1,663.36 5,961.76 - plan hits target center 1,743.00 10-3/4"x13-112" 10-3/4 13-1/2 - Circle (radius 100.00) 4,086.13 7" x 8-3/4" 7 8-3/4 1 H-110 T05 TD 082417 0.00 0.00 3,769.00 -346.45 7,674.61 - plan hits target center - Circle (radius 100.00) 1 H-110 T04 D2 082417 1 0.00 0.00 3,869.00 -483.84 7,579.70 - plan misses target center by 9.64usft at 10233.23usft MD (3863.89 TVD, -481.48 N, 7571.87 E) - Circle (radius 100.00) 1H-110 T02 A3 082417 1 0.00 0.00 3,903.00 -1,531.46 6,284,67 - plan hits target center -Circle (radius 100.00) 1H-1107 Csg Pt 0.00 0.00 4,086.13 -1,123.82 6,981.39 - plan hits target center - Circle (radius 100.00) 1H-110 T03 A3 082417 1 0.00 0.00 4,088.00 -1,061.41 7,046.85 - plan misses target center by 1.66usft at 9408.34usft MD (4088.21 TVD, -1062.60 N, 7047.99 E) -Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") () 118.00 118.00 20" x 42" 20 42 1,826.23 1,743.00 10-3/4"x13-112" 10-3/4 13-1/2 9,317.85 4,086.13 7" x 8-3/4" 7 8-3/4 10,427.63 3,769.00 4-112"x6-1/8" 4-112 6-1/8 3172018 Io24.'17AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well Plan: 1H-110 Project Kuparuk River Unit TVD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) SRe: Kuparuk 1H Pad MD Reference: Plan: 54+39 @ 93.00usft (Doyon 142) Well: Plan: 11-1-110 North Reference: True Wellbore: Plan: 1H-110 Survey Calculation Method: Minimum Curvature Design: 1H-110wp26 Output errore are at 1.00 sigma 2,203.45 2,033.00 Database: OAKEDMP2 Formations Measured Vertical Vertical Dip Depth Depth Depth Dip Direction (usft) (usft) Name Lithology (1) (�) 1,687.24 1,624.00 Base Perm 0.00 1,890.02 1,796.00 T-3 0.00 2,203.45 2,033.00 K-15 0.00 6,045.91 3,153.00 UG_C 0.00 7,108.62 3,415.00 UG_B 0.00 7,429.23 3,511.00 UG_A 0.00 7,775.56 3,631.00 Na 0.00 8,145.73 3,772.00 WS_D 0.00 8,263.50 3,818.00 WS_C 0.00 8,314.70 3,838.00 WS_B 0.00 8,322.38 3,841.00 WS -A4 0.00 8,499.30 3,910.00 WS_A3 0.00 8,748.25 3,990.00 WS_A2 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NIS +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 110° TF, for 300' 600.00 599.69 -4.03 11.06 Start 2.5°/100' DLS, 0' TF, for 300' 900.00 896.38 -18.74 51.49 Adjust TF to -5°, for 729.38' 1,629.38 1,574.00 -98.67 300.41 Hold for 115.71' 1,745.09 1,674.00 -115.58 356.11 Start 3.75°/100' DLS, 0' TF, for 81.13' 1,826.23 1,743.00 -127.98 396.93 Hold for 20' 1,846.23 1,759.73 -131.16 407.43 Start 3.75°/100' DLS, 3.26° TF, for 1136.9' 2,983.13 2,404.12 -415.96 1,266.29 Hold for 3974.14' 6,957.26 3,375.83 -1,681.12 4,906.19 Start 3.5°/100' DLS, -109.03° TF, for 1144.94' 8,102.21 3,755.00 -1,663.36 5,961.76 Hold for 378.9' 8,481.11 3,903.00 -1,531.46 8,284.67 Start 4°/l00'DLS, .12.17 -TF, for 134.06' 8,615.17 3,949.65 -1,482.74 6,400.47 Hold for 101.05' 8,716.22 3,980.45 -1,444.51 6,488.79 Start 4°/100' DLS, -52.4" TF, for 601.62' 9,317.85 4,086.13 -1,123.82 6,981.39 Hold for 20' 9,337.85 4,086.96 -1,110.38 6,996.18 Start 4°/1DO- DLS,-16.85-TF, for 828.48' 10,166.33 3,896.55 -527.94 7,536.52 Hold for 261.3' 10,427.63 3,769.00 -346.45 7,674.61 TD: 10427.63' MD, 3769' TVD Checked By: Approved By: Date: 3/7)2018 10:24.17AM Page 7 COMPASS 5000.14 Build 85 M N1 89 d0 = 9 L9 9 66-- C14 99 3 0 = 9 O 09 8 6S, 39 o 89 LS 39 � 99 -- 2 SS` 3f ,0 6 0 4S 9 9 £9_ Ob, g 5 g 40 Z9, _ � 7 0 9 4 6 3 8ti 2 9b, 8 Sb, a M tib a 3 9 £b, 1 0 a zt, r 7 Lb, 6 OV o rn 6£ 8 ge 0 0 0 0 0 0 0 r N (ui/gsn 09L) (+)4LoNA-)4lnos 0 0 0 0 ■ i r FiH-77 103wp26 Fl H-105 I LlH-13 1H-110wp26 Surface Location CPAI Coordinate Converter SIJ From: To: ----- Datum:NAD83 Region: alaska - Datum: NAD27 Region: alaska C Latitude/Longitude recimal Degrees r Latitude/Longitude Decimal Degrees * UTM Zone:— r South f UTM Zone: True r South * State Plane Zone: F____-3 Units: uslt r State Plane Zone: F___-1 Units: us-ft r Legal Description (NAD27 only) r Legal Description (NAD27 only] Starting Coordinates: X 11689596.02 Ending Coordinates: X: 549564.396931004 Y: 15900594.02 Y: 5980842.20953662 Transform Quit Help 1H-110wp26 Surface Location ift. CPAI Coordinate Converter From. -- To: Datum: NAD83 Region: alaska Datum: NAD27 Region:alaska * LatitudelLongitude f pecimal Degrees 71 r Latitude/Longitude IDecimalDegtees * UTM Zone: r South r UTM Zone: True r South G State Plane Zone: F_-] Units: Fus-57 D r State Plane Zone: I' J Units: us-f r Legal Description (NA.D27 only) (C Legal Description (NAD27 only) Starting Coordinates: X: 11689596.02 Legal Description Township: 012 [WD, Range: 010 E Y: 15900594.02 Meridian: U Section:28 FNL - 5140.7453 FEL - 776.12561 ........_...._..............._T..r.a...n...sform_.._.........._....!. Quit Help ._... ... IIH-110wp26 Surface Casing a CPAI Coordinate Converter Datum: NAD83 . Region: alaska r Latitude/Longitude recimalDegrees r UTM Zone: 1 — r South G State Plane Zone:q Units: us -ft r Legal Description (NAD27 only) Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees, C UTM Zone True r South C State Plane Zone:q - Units: us -ft r Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11689993.75 x: 549962.120075705 Y: 15980468.66 Y: 5980716.84496781 .Transform _) Quit Help H1H-110wp26 Surface Casing % CPAI Coordinate Converter I- From: - --- i r- To: Datum:NAD 63 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: [— r South C• State Plane Zone: F--] Units: us -ft C' Legal Description (NAD27 only) Starting Coordinates: X: 11689993.75 Y: 5980468.66 INWAI 0 Datum: NAD27 Region: fala7ka r Latitude/Longitude IDecimal Degrees —� r UTM Zone: True r South r State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) Township: 012 N , Range: 010 Meridian: U Section: 2S FNL 5268.7626FEL - 379.48323 ...............................................3 t Transform Quit Help 1H-110wp26 Top of Production CPAI Coordinate Converter JJ J From: To: -- ---- Datum: NAD83 � Region: alaska - Datum: NAp27 Region: alaska r Latitude/Longitude IDecimalDegrees C Latitude/Longitude IDecimalDegrees * UTM Zone: [_ r South [' UTM Zone: True r South * State Plane Zone: F----] Units: us-ft _ State Plane Zone: F-3- Units: usft r Legal Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates. X: 11695568 Ending Coordinates: X: 555536.274696894 Y: 15978970 Y: 5979218.11513632 ( Transform Quit Help 1H-110wp26 Top of Production CPAI Coordinate Converter From: To: — --- — --- Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees C Latitude/Longitude IDecimaiDegrees C UTM Zone: F— r South r UTM Zone: True r South �" State Plane Zone: I'-7E Units: us-ft-E r State Plane Zone: F7EUnits: us-ft r Legal Description (NAD27 only) G Legal Description (NAD27 only) Starting Coordinates: X: 1695568 Legal Description Township: 012 Range: 010 E Y: 15978970 Meridian: U wl Section: 3q FNL -1 1526.8807 F7 Dw 98.242646 ( Transform Quit Help 1H-110wp26 Intermediate Casing I CPA] Coordinate Converter -1111 X1 From: To: ---- - Datum: NAD83 Region: alaska . Daturrc NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees C LatitudelLongitude IDecimal Degrees * UTM Zone: r— r South r UTM Zone: True r South * State Plane Zone: F7-3 Units: us -ft + (-- State Plane Zone: q - Units: us -ft C Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: X: 11696583.96 Ending Coordinates: X; 556552.223214524 Y: 15979516.17 Y: 5979764.25294258 (.................Transfor mQuit Help 1H-110wp26 Intermediate Casing I ,ft CPAI Coordinate Converter 7, i . 117112(1 From: To: -- Datum: Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska r Latitude/Longitude IDecimalDegrees— r LatitudelLongitude IDecimalDegrees, C UTM Zane: F— r- South r UTM Zone: True r South F State Plane Zone: I' D Units: us -ft f State Plane Zone: q Units: us -ft C Legal Description (NAD27 only) G Legal Description (NAD27 only) Starting Coordinates: X: 1696583.96 Legal Description Township: 012 N , Range: 010 E Y: 5979516.17 Meridian: U D_ Secticn: 35 FNL 988.30068 FEL 4357.4085 ( .Transform _ _ Quit Help 1 H-110wp26 TD _113!X1 From: ---- To: Datum: NAD83 Region: alaska Datum: NAD27 Region: falaska C Latitude/Longitude IDecimalDegrees r Latitude/Longitude IDecimalDegrees r UTM Zone: r— r South C UTM Zone: True r South G State Plane Zone: F---:-] Units: us -ft - State Plane Zone: F-----3 Units: usft r Legal Description (NAD27 only) {' Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11697272 X: 557240.258619437 Y: 15980298 Y: 5980546.05128747 sform Quit Help 1 H-110wp26 TD -(111X) From:-- To: Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska C Latitude/Longitude IDecimaiDegtees r Latitude/Longitude IDecimalDegiees i7E I • UTM Zone: — r South r UTM Zone: True r South C•' State Plane Zone: I' Units: us -ft f State Plane Zone: q Units: us -ft r Legal. Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates: X: 1697272 Legal Description --,l Township: 012 FN Range: 010 E Y: 5980298 r' Meridian: IV � Section:35 FNL 211.67809 FEL - 3662.4301 Transform Quit Help REVI DATE IBYI CK IAPPI DESCRIPTION I REV I DATE BY U( I APP DESCRIPTION 1 2/05/0 MRT I CC I IRev. Per K05014ACS 12 02/01/11 JAH I LGM I Rev. Per K170005ACS N 25 30 29 28 27 I 125 1G 36 31 1H KCS 32 33 34 35 36 T12NA 1NR OE 6 5 4 3 2 *120 1A ASP GRID NORTH 0011 9 CPFI C 1G , 2 710 s 0118 9 tiF n 00117 12 40 0116 0115 1E n 16 15 14 13 0114 1E LEGEND 0113 IF 1° 24 011224 19 20 21 2 23 0 AS-BUILT CONDUCTOR Riji ZO-1 VICINITY MAP • EXISTING CONDUCTOR —1-0-D 0109 SCALE: I" = 2 MILES 0104 0108 _. _. _.- 0103 28 27 01-07 33+ 34 0102 0106 0101 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. eUGNU 01 4. ALL CONDUCTORS ARE LOCATED WITHIN 914 PROTRACTED SECTIONS 28 AND 33, *5 TOWNSHIP 12 NORTH, RANGE 10 EAST, *20 912 UMIAT MERIDIAN, ALASKA. 019 *22 e11 5. DATES OF SURVEY: 12-26-16 THRU •17 010 1-31-17 FIELD BOOKS L16-35, L16-40, 96 L17-02 & L17-03. •16 •21 •15 *13 6. ALL DISTANCES SHOWN ARE GROUND. •1 09 •2 *7 •3 *18 GRAPHIC SCALE 0 1D0 200 400 �g 04 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLELOUNSBURY k ASSOCIATES, INC. s R TORS ENGINEERS PLANNERS AREA:IH MODULE: XXXX UNIT: 51 ConocoPhilli S DS1H WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6108d31 2/05/05 CEA—DIHX-6108D31 1 OF 3 2 1 1 102/01AA JAH I LGM I (Create Per K170005ACS I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N., R. 10 E., UMIAT MERIDIAN Well I NAD 27 1 NAD 27 1 Sectia *110 5,980,842.21' 1 549,564.40' 1 N 70' 21' 30.398" W 149' 35' 50.770-1139' 776' 48.0' 54.0' *111 Y I X Lot. Long. F.S.L F.E.L. O.G. I PAD *103 5,980.722.55' 549,573.20' N 70' 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.0' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.0' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.1' *109 5.980.812.20' 549.566.50' ti '7n• 01' in ins" w Ido• zF' Rn 71 A" 109' 774' 48.0' 54.1' *110 5,980,842.21' 1 549,564.40' 1 N 70' 21' 30.398" W 149' 35' 50.770-1139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' 1 N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY �..•.L .4 1 .' 49th W 'c-.JEREMIAH•F. CORNELL / LS -12663 �fk'A AV SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF JANUARY 31, 2017. ConocoPhillips Alaska. Inc. LOUNSBURY k ASSOCIATES, INC. !VEYOR9 ENGINEERS PUNNERS 1H MODULE: XXXX UNIT: D1 DS1H WELL CONDUCTOR uNAIMNU NU. PART: REV: 12/27/16 CEA-D1HX-6108D31 3 OF 3 ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 30°of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of SO' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges 6 _' ConocoPhillips --:_:i,_:::eeveeieee_ ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations 1H-110 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casin¢ Interval Hazard Risk Level Mitigation Strategy Broach of conductor Low Monitor cellar continuously during interval. Gas hydrates Moderate Control drill, reduced pump rates, reduced drilling fluid Abnormal reservoir pressure Low temperatures, additions of ScreenKlen. Running sands and gravels Low Maintain planned mud parameters, increase mud weight, use Differential sticking Moderate weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping Hole swabbing on trips Moderate out Washouts / hole sloughing Low Cool mud temperatures, minimize circulating times when Fault crossings and concretions Moderate I possible. 8-3/4" Open Hole / 7" Casinrr Interval Hazard Risk Level Mitigation Strategy Running sands and gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal reservoir pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, add LCM. Differential sticking Moderate Follow mud program, keep pipe moving when able. Anti -collision Moderate Follow real time surveys very closely. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or back reaming. Getting casing to bottom Moderate Utilize proper drilling and hole cleaning practices, follow mud program. Fault crossings and concretions Moderate I Use developed best practices for concretion drilling. 6-1/8" Open Hole / 3-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Stuck pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal reservoir pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, add LCM. Differential sticking Moderate Follow mud program, keep pipe moving when able. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or back reaming. Getting casing to bottom Moderate Utilize proper drilling and hole cleaning practices, follow mud program. Fault crossings and concretions Moderate Use developed best practices for concretion drilling. 1H-110 Drilling Hazards. docx 3/13/2018 M Q Q x b . r O M r� a � n 7 00 00 N O •y w \\ �M� _ \ Y y ) 3 \ m U) \ m \ A ?^ O i \ O \ Q d \ C N D D \ O ^ M \ D v r m \ r H m N m C? 1 , m o a CL Q C N (� > m 0- 0 m ° c IN x xo s y m N oo F 3 a L V c .. H % Attachment G BOP Configuration The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can be found with the Doyon 142 documentation on file with the State. (Well: me: KRU IH -110 CPAI Mud Weight (ppg) Weak point or LOT - Measured depth (ft) Weak point or LOT True vertical depth (ft) Weak point or LOT - Hole angle (deg) Weak point or LOT - Hole size (in) Weak point Pressure or LOT - EMW (ooa) aVne m miefesa- measureu uepuI pq Zone of interest - True vertical depth (ft) Zone of interest - Hole angle (deg) Zone of interest - Hole size (in) Zone of interest - Pore Pressure EMW (PI <_= Data Input <_= Data Input 10.00 _= Data — Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input — Data Input <== Data Input <_= Data Input <_= Data Input <_= Data Input ouuum cute assemuiy uu tin) Bottom hole assembly length (ft) Drill pipe OD (in) u.ti - <== Uata Input <== Data Input <== Data Input 151' 5.000" BHA annular vol. @ zone of interest (bbllft) DP annular vol. @ zone of interest (bbl/ft) DP annular vol. IM weak point (bbllft) 0.0122 0.0501 0.1528 <== Data Weak point pressure (psi): Plo 1,042 psi Weak point pressure - Safety margin: Pmax Pmax EMW 1,042 psi 11.50 pp Max anticipated formation pressure (psi): Weak Pt to Zone of Interest distance (TVD ft): Pf OH (ND) 1,696 psi 2,050' Weak Pt to Zone of Interest distance (MD ft): OH {MD) 6,374' Maximum influx height at the bit (TVD ft): H (ND) 981' Maximum influx height at the bit (MD ft): H (MD) 2,511' Calc. volume of (H) around BHA: Calc. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: Vlbha V1 dp V1 1.8 bbl 118.2 bbl 120.1 bbl Calc. vol. that H equals @ weak point (MD ft): VWp 178.7 bbl Calc. volume ofVwp @ initial shut in: V2 109.8 bbl Kick Tolerance: TE: V2 V Loepp 4123118 109.8 bbl Bettis, Patricia K (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Tuesday, March 27, 2018 9:33 AM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 1 H-110 (PTD 218-031): Permit to Drill Application Good morning. No ma'am. Due to the wellbore design, the KRU 1H-110 will not be pre -produced Please let me know if you have nay more questions. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, March 27, 2018 8:39 AM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: [EXTERNAL]KRU 1H-110 (PTD 218-031): Permit to Drill Application Good morning Ben, Does ConocoPhillips plan to pre -produce KRU 11-1-110; and if so, for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7" Ave., Ste 100 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettisOalaska.zov. TRANSMITTAL LETTER CHECKLIST WELL NAME: Pau- 14-J/0 PTD:I1 '� J —Q- / Development ✓ Service Exploratory _ Stratigraphic Test —Non -Conventional FIELD: POOL: 44404fuK 'Z1kg-. w ° �� O�✓� 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(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: / Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 WELL PERMIT CHECKLISTField &Pool KUPARUK RIVER, WEST SAK OIL - 490150 PTD#:2180310 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type Well Name: JSUPARUK RIV UNIT 1H-110 Program SER Well bore seg ❑ SER/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31,05,030(j.1.A),(j,2.A-D) __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA Commissioner: Date ommi ' er Date L( 1 Permitfee attached _ _ _ _ _ _ _ . . . . . . . . . . . . ................ - . NA _ _ _ _ 2 Lease number appropriate_ _ _ _ ______________ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ADL0025639, Surf & Top Prod trite"; ADL0025638, TD._ 3 Unique well name and number . . . . . . . . ..... _ _ - _ Yes _ KRU 1 H-110 _ _ _ _ _ _ 4 Well located in defined pool ___ _ _ _ _ _ ____ _ _ ________ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ KUPARUK RIVER,WEST SAK O(L.- 490150,. governed by Conservation. Order No, 406C....... 5 Well located proper distance from drilling unit boundary . . . . . ........... . ...... . Yes _ _ . CO 406C contains no spacing restrictions with respect to drilling unit boundaries. .......... 6 Well located proper distance from other wells Yes _ CO 4060 has no interwell spacing restrictions, 7 Sufficient acreage available in. drilling unit... _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 8 If deviated, is. wellbore plat included _ _ _ _ _ _ _ _ . Yes 9 Operator only affected party _ _ _ _ _ _ _ _ _ _ _ _ ________ ... Yes Wellbore. will be more than 500' from an external property line where ownership or landownership. changes. 10 Operator has appropriatebond in force _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order_ ....... _ Yes 12 Permit can be issued without administrative. approval _ ... _ ... Yes PKB 3/27/2018 13 Can permit be approved before 15 -day wait_ . _ _ _ _ _ _ _ _ _ _ Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For. Yes AID 2C 15 All wells.. within 1/4. mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ KRU 1H-103, 111-11)4,111,113, 1H-13 16 Pre -produced injector duration of pre production less than 3 months (For service well only) ...No........ 8en.Tolman.(3/27/18)..... . ....... 18 Conductor string .provided_______ ........... _______________________ Yes....__. 89 conductor set______.____ Engineering 19 Surface casing protects all known USDWs .. _ _ _ _ _ _ _ _ Yes Surface casing set to 1826' MD 20 CMT vol adequate to circulate. on conductor & surf csg _ _ _ _ _ _ Yes _ _ _ 137% excess cement 21 CMT. vol adequate to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ No. 22 CMT will cover all known productive horizons _ _ Yes productive interval will be completed with. uncemented swell packers and sleeves 23 Casing designs adequate for C, T, B 8. permafrost _ _ _ _ _ _ _ _ _ _ Yes 24 Adequate tankage. or reserve pit _ _ _ _ _ _ Yes _ Rig has steel tanks; all waste. to approved disposal wells 25 If a. re -drill, has a 10-403 for abandonment been approved _ _ _ _ _ NA _ .. _ _ _ _ ............ 26 Adequate wellbore separation proposed... _ _ _ _ _ _ _ ... .. - Yes Anti-eotlision analysis complete; no major risk failures 27 If dverter required, does it meet regulations.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Diverter meets regulations Appr Date 28 Drilling fluid_ program schematic & equip list adequate_ _ _ _ _ _ _ Yes Max formation pressure is 1765 psig(8.6 ppg EMW); will drill w/ 6.8-10.0 ppg.EMW VTL 4/19/2018 29 BOPEs, do they meet regulation _ _ _ .... _ _ _ _ _ _ _ _ Yes 30 BOPE.press rating appropriate; test to (put psig in comments)_ _ _ Yes MPSP is.1386 psig; will test BOPS to 3500 psig ...... ... ... . 31 Choke. manifold complies w/API RP -53 (May 84)_ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown___ _ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 33 Is presence of 112S gas probable _ _ _ _ _ _ _ _ _ _ _____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ 112S measures required..... 34 Mechanical condition of wells within AOR verified (For service well only) _ _ _ ... _ _ _ _ _ Yes _ _ _ _ _ AOR complete; mectraniealconclition verified 35 Permit can be issued w/o hydrogen sulfide measures . . . ...... . . .. . .. . . _ No _ . _ _ _ H2S measures required, Geology 36 Data presented on potential overpressure zones . . . . . . . .................. Yes ..... Maximum potential. reservoir pressure. is 8.6 ppg EMW; will be drilled using.8,$ to 10.0 ppg mud. Appr Date Seismic analysis of shallow gas zones. _ _ _ _ _ NA PKB 3/27/2018 �37 38 Seabed oondition survey (if off -shore) _ _ _ _ _ _ _ NA 39 Contact name/phone for weekly progress reports. [exploratory only] _ _ _ NA _ Onshore service well to be drilled. Geologic Engineering Commissioner: Date: �I 4Ig Commissioner: Date ommi ' er Date L( �(s �5�