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215-166
P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, 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 Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ConocoPhillips Well Integrity Field Supervisor RBDMS JSB 081425 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:01-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off1C-15450-029-23559-00-00215-16670"51.810"7/31/20253.48/7/2025 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: Polymer Flood 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 12680'feet None feet true vertical 3849' feet None feet Effective Depth measured 12680'feet 5435'feet true vertical 3849' feet 3846' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 5482' MD 3850' TVD Packers and SSSV (type, measured and true vertical depth) 5435' MD N/A 3846' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: 323-588 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker HRD-E ZXP W/HD Packer SSSV: None Natalie Dye natalie.b.dye@conocophillips.com (907) 265-1027 Senior Production Engineer Slots: 5839-6767', 7049-10583', 10863-12631' Slots: 3871-3864', 3877-3872', 3867-3850' 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 122' ~ ~~ INJECTOR ~~ ~ measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-166 50-029-23559-00-00 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, ADL0025649 Kuparuk River Field/ West Sak Oil Pool KRU 1C-154 Plugs Junk measured Length Production Liner 5575' 7206' Casing 3858' 4-1/2" 5614' 12641' 3850' 2595' 122' Conductor Surface Intermediate 20" 10-3/4" 80' 2637' 2413' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov signed by Amy Conklin for Natalie Dye By Grace Christianson at 8:04 am, Nov 14, 2024 DTTMSTART JOBTYP SUMMARYOPS 9/8/2023 ACQUIRE DATA FREELY DRIFT TBG W/ 3.845 GAUGE RING TO DB NIPPLE @ 4927' RKB. SET 3.81 DB NO-GO SUB W/ FLOW THRU SUB & SOFT SET W/ TANDEM GAUGES IN DB NIPPLE @ 4927' RKB. JOB COMPLETE. (3.81 DB NO-GO SUB + FLOW THRU SUB + SOFT SET & TANDEM GAUGES = 78") 9/29/2023 ACQUIRE DATA PULL DB NO-GO SUB W/ FLOW THRU SUB & GAUGES. REPLACE SOFT-SET AND DUAL SPARTEK GAUGES, AND RE-SET IN DB NIPPLE @ 4927' RKB. JOB COMPLETE 11/26/2023 ACQUIRE DATA PULL 3.813" DB NO-GO SUB W/ FLOW THROUGH SUB & DUAL SPARTEK GUAGES FROM DB NIPPLE @ 4927' RKB. READY FOR CTU 12/11/2023 ACQUIRE DATA (WELL ON INJECTION AT 1350 BWPD, 1090 PSI WHP, 66 DEG F). FLUFF n' STUFF FROM 4800' TO LOCK UP @ 10,661' CTMD WHILE PUMPING SSW AT 1.8 BPM DOWN COIL, WITH ONLINE INJECTING; PULLED UP TO SAFETY & CALLED OUT FOR SSW W/ SAFE LUBE IN ATTEMPT TO GET DEEPER. 12/12/2023 ACQUIRE DATA CONTINUE FLUFF n' STUFF FROM 10,661 CTMD PUMPING SSW W/ SAFE LUBE DOWN BACKSIDE OF CT DOWN TO LOCK UP AT 11,392' CTMD (PAINTED ORANGE FLAG). IPROF LOG 5200' - 11,267' @ 100 FPM & 60 FPM @ 1555 BWPD INJECTION RATE. SI INJECTION, FREEZE PROTECT & WAIT 1 HOUR. REPEAT 60 12/13/2023 ACQUIRE DATA LAYDOWN IPROF TOOLS AND VERIFY DATA. SEND TO TOWN RESERVOIR ENGINEER. NO SPINNER DATA COLLECTED DURING INJECTION UP PASSES @ 100 & 60 FPM. REPEAT FNS & INJECTION PASSES. FLUFF & STUFF 4600' - 12090' PUMPING SSW W/ SAFELUBE DOWN CT BACKSIDE @ 1.0 BPM AND DOWN COIL 12/14/2023 ACQUIRE DATA IPROF LOG @ 5200' - 12020' MAKING DOWN/UP PASSES @ 100 & 60 FPM PUMPING 0.60 BPM SSW W/ SAFELUBE DOWN COIL BACKSIDE. DOWN LOAD LOGS. PARTIAL SPINNER DATA. CONFER W/ PE. RDMO TO NEXT WELL 1B-101. 12/15/2023 ACQUIRE DATA SET 3.813" DB NO-GO W/ FLOW THROUGH SUB AND DUAL SPARTEK GAUGES @ 4926' RKB. SET 4-1/2 SLIP-STOP ON TOP OF GAUGES @ 4925' RKB. JOB 3/22/2024 MAINTAIN WELL FREEZE PROTECTTUBING AND FLOWLINE PUMPED 40 BBLS DSL DOWN TBG AND 3 BBLS METH UP INJECTION LINE 4/5/2024 ACQUIRE DATA (PRE-SW) BLEED GAS FOR SW MITIA COMPLETE. 4/7/2024 ACQUIRE DATA (PRE-SW) LOADED IA FOR UPCOMING SW-MIT-IA (COMPLETE) 4/29/2024 ACQUIRE DATA PULLED 4.5'' SLIPSTOP @ 4925'RKB, PULLED 3.81'' NO-GO SUB W/ DUAL SPARTEK GAUGES @ 4927'RKB, SET 3.81'' NO-GO SUB & SOFT SET/ DUAL SPARTEK GAUGES(OAL 77'', BATTS START @ 1534) @ 4927'RKB, SET 4.5'' 8/26/2024 MAINTAIN WELL FREEZE PROTECT PUMPED 35 BBLS DSL DWN TBG PUMPED 2 BBLS METH DWN FL 10/14/2024 ACQUIRE DATA 1C-154 Polymer Flood Summary of Operations DRIFTED W/ 3.81" CENTRALIZER, 3.84" GAUGE RING TO SLIPSTOP @ 4,925' RKB, PULLED SLIPSTOP @ 4,925' RKB, PULLED FLOW THROUGH NOGO SUB W/ GAUGES @ 4,927' RKB ***JOB COMPLETE*** Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 1C-154 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled slipstop & gauges 1C-154 10/14/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Conductor 20 19.25 42.2 122.2 122.2 78.67 B Welded Surface 10 3/4 9.95 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 Intermediate 7 5/8 6.88 39.4 5,614.0 3,857.8 29.70 L-80 Hydril563 Liner 4 1/2 4.00 5,435.0 12,641.0 3,849.8 11.60 L-80 IBT-m Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.7 Set Depth 5,481.6 Set Depth 3,850.2 String Max No 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD563 ID (in) 3.96 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) 34.7 34.7 0.04 HANGER 10.750 Vetco Off Set Tubing Hanger W/ 13- 3/8" false bowel SN: IJ00040001- 0431-4 Vetco MB222A , PN# H36101 3-1R- NC, ser # 1J00040 001- 0431-4 3.875 2,509.4 2,323.9 43.29 GAS LIFT 6.440 CAMCO KBMG 3.860 3,695.2 3,099.4 54.12 GAS LIFT 6.440 CAMCO KBMG 3.860 4,926.7 3,728.3 71.78 NIPPLE 5.560 CAMCO 'DB' Nipple 4½" w/3.812" no-go profile CAMCO PN: 3357- 000- 25000, SN 10103-3 3.813 5,441.3 3,846.7 84.19 LOCATOR 4.500 Baker mechanical locator Comm N #H450-01-4785 Baker LTSA H450-01 -4785 3.860 5,464.2 3,848.8 85.12 SEAL ASSY 4.500 Baker Bonded Seal assy with full Mule Shoe, Comm N #H450-01- 4785 Baker 3.870 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) 2,509.4 2,323.9 43.29 1 GAS LIFT DMY BK 1 0.0 1/16/2016 Schlumb erger Camco KBMG 0.000 3,695.2 3,099.4 54.12 2 GAS LIFT DMY BK 1 0.0 2/22/2020 Schlumb erger Camco KBMG 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) 5,435.0 3,846.0 83.94 PACKER 6.540 Baker HRD-E ZXP W/HD's 5½" X 7.63", 5½" 17# Hydril 563 pin dn Baker ZXP, PN.: H296-45- 0131, control no.: QR1602 4.970 5,454.9 3,848.0 84.74 NIPPLE 6.070 RS Nipple 7.63" L-80 5.5" 15.5# HYD 563 Box x box Baker RS, PN.: H294-01- 0656, control no.: 105462589- 04 4.850 5,487.2 3,850.6 86.05 XO THREAD 6.060 Crossover Sub, 5½" H563 Box x 4½" IBT Pin CPAI CPAI MM# 10793825, PO# 451932127 1 3.940 5,829.3 3,870.9 86.82 SWELL PACKER 4.500 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "E" S/N -049169-001-2 Baker PN.: H301- 87-0397, ser # 049169-001 -2, reactive 92 3.960 6,772.7 3,864.4 88.57 SWELL PACKER 4.500 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "D" S/N -049169-001- 1 Baker PN.: H301- 87-0397, ser # 049169-001 -1, reactive 92 3.980 7,038.5 3,876.6 86.18 SWELL PACKER 6.390 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "C" S/N -049169-001- 9 Baker PN.: H301- 87-0397, ser # 049169-001 -9, reactive 92 3.970 1C-154, 11/13/2024 12:44:03 PM Vertical schematic (actual) Liner; 5,435.0-12,641.0 SHOE; 12,631.3-12,641.0 SLOTS; 10,863.0-12,631.0 SWELL PACKER; 10,853.5- 10,860.2 SWELL PACKER; 10,589.5- 10,596.2 SLOTS; 7,049.0-10,583.0 SWELL PACKER; 7,038.5- 7,045.3 SWELL PACKER; 6,772.7- 6,779.4 SLOTS; 5,839.0-6,767.0 SWELL PACKER; 5,829.3- 5,836.1 Intermediate; 39.4-5,614.0 Float Shoe; 5,610.5-5,614.0 Float Collar; 5,521.8-5,524.6 XO THREAD; 5,487.2-5,488.6 SBE; 5,467.5-5,487.2 SEAL ASSY; 5,464.2 NIPPLE; 5,454.9-5,457.7 PACKER; 5,435.0-5,454.9 LOCATOR; 5,441.3 XO THREAD; 4,928.5 NIPPLE; 4,926.7 XO THREAD; 4,916.9 XO THREAD; 3,702.4 GAS LIFT; 3,695.2 XO THREAD; 3,685.8 Surface; 42.2-2,636.9 Float Shoe; 2,632.9-2,636.9 Float Collar; 2,546.1-2,549.2 GAS LIFT; 2,509.4 Conductor; 42.2-122.2 CASING HANGER; 42.2-42.5 CASING HANGER; 39.4-40.0 HANGER; 34.7 KUP INJ KB-Grd (ft) 39.73 RR Date 11/8/2015 Other Elev 1C-154 ... TD Act Btm (ftKB) 12,680.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292355900 Wellbore Status INJ Max Angle & MD Incl (°) 94.57 MD (ftKB) 10,930.02 WELLNAME WELLBORE1C-154 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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) 10,589.5 3,872.2 89.36 SWELL PACKER 6.390 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "B" S/N -049169-001-8 Baker PN.: H301- 87-0397, ser # 049169-001 -8, reactive 92 3.980 10,853.5 3,867.5 94.13 SWELL PACKER 6.390 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "A" S/N -049169-001-4 Baker PN.: H301- 87-0397, ser # 049169-001 -4, reactive 92 3.980 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,839.0 6,767.0 3,871.4 3,864.2 WS D, 1C-154 11/3/2015 SLOTS 4 1/2" OD L-80, 11.6#, R3, IBTM slotted liner 7,049.0 10,583.0 3,877.3 3,872.2 WS D, 1C-154 11/3/2015 SLOTS 2 1/2" x 1/8" slots, 8 slots/row, 4 rows/ft. 10,863.0 12,631.0 3,866.8 3,849.9 WS D, 1C-154 11/3/2015 SLOTS 3' standoff each end, SMLS 1C-154, 11/13/2024 12:44:04 PM Vertical schematic (actual) Liner; 5,435.0-12,641.0 SHOE; 12,631.3-12,641.0 SLOTS; 10,863.0-12,631.0 SWELL PACKER; 10,853.5- 10,860.2 SWELL PACKER; 10,589.5- 10,596.2 SLOTS; 7,049.0-10,583.0 SWELL PACKER; 7,038.5- 7,045.3 SWELL PACKER; 6,772.7- 6,779.4 SLOTS; 5,839.0-6,767.0 SWELL PACKER; 5,829.3- 5,836.1 Intermediate; 39.4-5,614.0 Float Shoe; 5,610.5-5,614.0 Float Collar; 5,521.8-5,524.6 XO THREAD; 5,487.2-5,488.6 SBE; 5,467.5-5,487.2 SEAL ASSY; 5,464.2 NIPPLE; 5,454.9-5,457.7 PACKER; 5,435.0-5,454.9 LOCATOR; 5,441.3 XO THREAD; 4,928.5 NIPPLE; 4,926.7 XO THREAD; 4,916.9 XO THREAD; 3,702.4 GAS LIFT; 3,695.2 XO THREAD; 3,685.8 Surface; 42.2-2,636.9 Float Shoe; 2,632.9-2,636.9 Float Collar; 2,546.1-2,549.2 GAS LIFT; 2,509.4 Conductor; 42.2-122.2 CASING HANGER; 42.2-42.5 CASING HANGER; 39.4-40.0 HANGER; 34.7 KUP INJ 1C-154 ... WELLNAME WELLBORE1C-154 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 2, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-154 KUPARUK RIV U WSAK 1C-154 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/02/2024 1C-154 50-029-23559-00-00 215-166-0 W SPT 3848 2151660 3000 1002 1102 1102 1102 215 235 235 235 REQVAR P Kam StJohn 5/21/2024 MIT-IA to MAIP per AIO 2C.087 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 U WSAK 1C-154 Inspection Date: Tubing OA Packer Depth 370 3300 3220 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240522124502 BBL Pumped:2.1 BBL Returned:2.1 Tuesday, July 2, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 99 9 9 9AIO 2C.087 James B. Regg Digitally signed by James B. Regg Date: 2024.07.02 13:11:44 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-12-12_22140_KRU_1C-154_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22140 KRU 1C-154 50-029-23559-00 Injection Profile 12- Dec-23 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: 215-166 T38249 1/3/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.03 13:31:07 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Polymer Flood 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12680' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-4146 Senior Reservoir Engineer KRU 1C-154 3849' 12680' 3849' None N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: doug.k.valentine@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5435' MD and 3846' TVD N/A Doug Valentine STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025638, ADL0025649 215-166 P.O. Box 100360, Anchorage, AK 99510 50-029-23559-00-00 Kuparuk River Field West Sak Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst 5482' MD 122' 2413' 3858' 122' 2637' 20" 10-3/4" 80' 7-5/8"5575' 2595' 5614' Slotted Liner: 5839-6767', 7049- 10583', 10863-12631' 4-1/2" Slotted Liner: 3871-3864', 3877-3872', 3867-3850' Perforation Depth TVD (ft): 12/1/2023 12641'7206' 4-1/2" 3850' Packer: Baker HRD-E ZXP Packer SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov None Douglas Valentine Digitally signed by Douglas Valentine Date: 2023.10.31 10:45:08 -08'00' 323-588 By Grace Christianson at 11:30 am, Oct 31, 2023 SFD 11/1/2023VTL 11/14/2023 DSR-11/2/23 10-404 *&:JLC 11/15/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.15 14:30:17 -09'00'11/15/23 RBDMS JSB 111623 1C-154 Polymer Injection Trial Objecve The objec ve the polymer injec on is to iden fy long-term injec vity in 1C-154 while pumping 10 cP polymer for future economic modeling Procedure Set equipment on 1C pad following all COP standards o 4 Tanks and Manifold o Choke Trailer o Polymer slicing unit (PSU) o Waste tank o Chemical injec on skid (O2 scavenger) o Polymer storage Hook equipment up and check for func onality HSE and facility walkdowns Start-up PSU on water only Pump 10 cP polymer down injector monitoring pressure, .owrate, and viscosity o Pump polymer on pressure control staying at ~1100 psi at surface to stay below reservoir par ng pressure Pump 24 hours / 7 days a week for 14 weeks or un l long term injec vity iden 2ed Shut-in well for pressure fall o3 Rig down move out Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 1C-154 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Replaced gauges 1C-154 9/29/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE:lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Conductor 20 19.25 42.2 122.2 122.2 78.67 B Welded Surface 10 3/4 9.95 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 Intermediate 7 5/8 6.88 39.4 5,614.0 3,857.8 29.70 L-80 Hydril563 Liner 4 1/2 4.00 5,435.0 12,641.0 3,849.8 11.60 L-80 IBT-m Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 34.7 Set Depth … 5,481.6 Set Depth … 3,850.2 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD563 ID (in) 3.96 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) 34.7 34.7 0.04 HANGER 10.750 Vetco Off Set Tubing Hanger W/ 13- 3/8" false bowel SN: IJ00040001- 0431-4 Vetco MB222A , PN# H36101 3-1R- NC, ser # 1J00040 001- 0431-4 3.875 2,509.4 2,323.9 43.29 GAS LIFT 6.440 CAMCO KBMG 3.860 3,695.2 3,099.4 54.12 GAS LIFT 6.440 CAMCO KBMG 3.860 4,926.7 3,728.3 71.78 NIPPLE 5.560 CAMCO 'DB' Nipple 4½" w/3.812" no-go profile CAMCO PN: 3357- 000- 25000, SN 10103-3 3.813 5,441.3 3,846.7 84.19 LOCATOR 4.500 Baker mechanical locator Comm N #H450-01-4785 Baker LTSA H450-01 -4785 3.860 5,464.2 3,848.8 85.12 SEAL ASSY 4.500 Baker Bonded Seal assy with full Mule Shoe, Comm N #H450-01- 4785 Baker 3.870 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) 4,927.0 3,728.4 71.79 GAUGES Set dual spartec gauges on 4.5" bait sub, 3.84" DB No-Go sub. (OAL 78") 9/29/2023 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) 2,509.4 2,323.9 43.29 1 GAS LIFT DMY BK 1 0.0 1/16/2016 Schlumb erger Camco KBMG 0.000 3,695.2 3,099.4 54.12 2 GAS LIFT DMY BK 1 0.0 2/22/2020 Schlumb erger Camco KBMG 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) 5,435.0 3,846.0 83.94 PACKER 6.540 Baker HRD-E ZXP W/HD's 5½" X 7.63", 5½" 17# Hydril 563 pin dn Baker ZXP, PN.: H296-45- 0131, control no.: QR1602 4.970 5,454.9 3,848.0 84.74 NIPPLE 6.070 RS Nipple 7.63" L-80 5.5" 15.5# HYD 563 Box x box Baker RS, PN.: H294-01- 0656, control no.: 105462589- 04 4.850 5,487.2 3,850.6 86.05 XO THREAD 6.060 Crossover Sub, 5½" H563 Box x 4½" IBT Pin CPAI CPAI MM# 10793825, PO# 451932127 1 3.940 5,829.3 3,870.9 86.82 SWELL PACKER 4.500 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "E" S/N -049169-001-2 Baker PN.: H301- 87-0397, ser # 049169-001 -2, reactive 92 3.960 6,772.7 3,864.4 88.57 SWELL PACKER 4.500 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "D" S/N -049169-001- 1 Baker PN.: H301- 87-0397, ser # 049169-001 -1, reactive 92 3.980 1C-154, 10/26/2023 5:55:36 PM Vertical schematic (actual) Liner; 5,435.0-12,641.0 SLOTS; 10,863.0-12,631.0 SLOTS; 7,049.0-10,583.0 SLOTS; 5,839.0-6,767.0 Intermediate; 39.4-5,614.0 GAUGES; 4,927.0 GAS LIFT; 3,695.2 Surface; 42.2-2,636.9 GAS LIFT; 2,509.4 Conductor; 42.2-122.2 HANGER; 34.7 KUP INJ KB-Grd (ft) 39.73 RR Date 11/8/2015 Other Elev… 1C-154 ... TD Act Btm (ftKB) 12,680.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292355900 Wellbore Status INJ Max Angle & MD Incl (°) 94.57 MD (ftKB) 10,930.02 WELLNAME WELLBORE1C-154 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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) 7,038.5 3,876.6 86.18 SWELL PACKER 6.390 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "C" S/N -049169-001- 9 Baker PN.: H301- 87-0397, ser # 049169-001 -9, reactive 92 3.970 10,589.5 3,872.2 89.36 SWELL PACKER 6.390 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "B" S/N -049169-001-8 Baker PN.: H301- 87-0397, ser # 049169-001 -8, reactive 92 3.980 10,853.5 3,867.5 94.13 SWELL PACKER 6.390 Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "A" S/N -049169-001-4 Baker PN.: H301- 87-0397, ser # 049169-001 -4, reactive 92 3.980 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,839.0 6,767.0 3,871.4 3,864.2 WS D, 1C-154 11/3/2015 SLOTS 4 1/2" OD L-80, 11.6#, R3, IBTM slotted liner 7,049.0 10,583.0 3,877.3 3,872.2 WS D, 1C-154 11/3/2015 SLOTS 2 1/2" x 1/8" slots, 8 slots/row, 4 rows/ft. 10,863.0 12,631.0 3,866.8 3,849.9 WS D, 1C-154 11/3/2015 SLOTS 3' standoff each end, SMLS 1C-154, 10/26/2023 5:55:37 PM Vertical schematic (actual) Liner; 5,435.0-12,641.0 SLOTS; 10,863.0-12,631.0 SLOTS; 7,049.0-10,583.0 SLOTS; 5,839.0-6,767.0 Intermediate; 39.4-5,614.0 GAUGES; 4,927.0 GAS LIFT; 3,695.2 Surface; 42.2-2,636.9 GAS LIFT; 2,509.4 Conductor; 42.2-122.2 HANGER; 34.7 KUP INJ 1C-154 ... WELLNAME WELLBORE1C-154 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-07-10_22544_1C-154_10-Jul-23_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22544 KRU 50-029-23559-00 Injection Profile 10-Jul-23 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: 215-166 T37854 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.18 13:11:00 -08'00' 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1C-154 (PTD 215-166) Update and AA application Date:Wednesday, May 10, 2023 10:27:24 AM Attachments:KRU 1C-154 (PTD 215-166) AA application packet 2.16.23.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, February 16, 2023 1:08 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1C-154 (PTD 215-166) Update and AA application Chris KRU 1C-154 (PTD 215-166) is at the end of its 30 day monitor period while on water injection and although the IA continued to experience a slow pressure fall off the well did pass an MITIA and pack off tests proving that the well still maintains barriers from reservoir. With this information it is CPAI intent to apply for an AA to allow the well to remain on water injection only with suspect IA x FORM. The application has been submitted and the plan is for the well to remain on injection while the application is being processed. I have attached a copy of the application for your review. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 February 16, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2C, Rule 11, to apply for Administrative Approval to allow KRU injection well 1C-154 (PTD 215-166) to remain in water only injection service. The well has suspect IA x Formation communication. Please contact me at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Well Integrity Specialist 2/16/2023 1 ConocoPhillips Alaska, Inc. Kuparuk Well 1C-154 (PTD 215-166) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2C, Rule 11, to continue water only injection for Kuparuk injection well 1C-154 (PTD 215-166) with suspect IA x Formation communication. Well History and Status Kuparuk River Unit well 1C-154 (PTD 215-166) was drilled and completed in 2015 as an injection well. January 17, 2023, 1C-154 was reported to the Commission for slow IA pressure decrease. The well passed a diagnostics MITIA and pack off tests after which the well was placed on a 30 day monitor where the IA pressure continued to demonstrate an extremely slow decrease averaging a 51 psi per day loss. Reviewing TIO trends has shown the IA pressure will continue to drop below the OA pressure as such it is suspected to have IA x Formation communication. The pressure loss is too slow to locate with current technology, but ConocoPhillips intends to pursue repairs if the leak increases or additional leaks develop. Additionally, the well still passes an MITIA and maintains integrity from wellbore pressure, it is only over a long period of time that the IA pressure loss is recognizable. As such, ConocoPhillips requests an AA which will allow the well to remain online in water only injection service. Barrier and Hazard Evaluation Tubing: The 4.5”, 12.6 lb., L-80 tubing has integrity from surface to the packer at 5,435’ MD (3,846’ TVD) based on a passing a diagnostic MIT-IA on January 20, 2023, and TIO pressure trends. Production casing: The 7-5/8”, 29.7 lb., L-80 production casing has integrity from surface to the packer at 5,435’ MD (3,846’ TVD) based on a passing a diagnostic MIT-IA on January 20, 2023. It is only over an extended period of time th at the slow IA pressure fall off is recognizable. Surface casing: The 10-3/4”, 45.5 lb., L-80 surface casing has integrity from surface to TD at 2639’ based on a passing pressure test during construction and TIO pressure trends. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer at 5,435’ MD (3,846’ TVD). Secondary barrier: The secondary barrier to prevent a release from the well is the production casing. It is know to have a slow leak, but the integrity demonstrated by the MITIA should allow time to secure the wellbore as needed. Tertiary barrier: The tertiary barrier to prevent a release and provide zonal isolation is the surface casing in the extremely rare instance tha t the first two barriers fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should additional leaks develop in the well bore it will be noted during the daily monitoring process. Any pressure Well Integrity Specialist 2/16/2023 2 trends that indicate annular communication require investigation, Commission notification, and corrective action, up to and including a shut-in of the well. T/IO plots are compiled, reviewed, and submitted to the AOGCC monthly. Proposed Operating and Monitoring Plan 1. Well will be used for water only injection (no MI or gas injection allowed). 2. Perform a passing MITIA every 2-years to maximum anticipated injection pressure. 3. Allow operating IA pressure up to 2000 psi, operating OA pressure up to 100 psi. 4. Submit monthly reports of daily tubing , IA & OA pressures, injection volumes and pressure bleeds for all annuli. 5. Shut-in the well should diagnostic testing or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 6. Anniversary date to be set the month of May 2024 to align the AOGCC biennial AA witnessed testing with the UIC MIT permanent 4 -year scheduled pad testing. 1C-154 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1C-154 2022-11-20 307.0 418 111.0 IA 1C-154 2022-11-28 233.0 543 310.0 IA 1C-154 2023-01-06 223.0 640 417.0 OA 1C-154 2023-01-14 224.0 687 463.0 IA 1C-154 2023-01-20 675.0 515 -160.0 IA 1C-154 2023-02-12 292.0 460 168.0 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 1C-154 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set DV, Pulled Plug 2/22/2020 1C-154 fergusp Casing Strings Casing Description Conductor OD (in) 20 ID (in) 19.25 Top (ftKB) 42.2 Set Depth (ftKB) 122.2 Set Depth (TVD) … 122.2 Wt/Len (l… 78.67 Grade B Top Thread Welded Casing Description Surface OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 42.2 Set Depth (ftKB) 2,636.9 Set Depth (TVD) … 2,412.7 Wt/Len (l… 45.50 Grade L-80 Top Thread TSH 563 Casing Description Intermediate OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 39.4 Set Depth (ftKB) 5,614.0 Set Depth (TVD) … 3,857.8 Wt/Len (l… 29.70 Grade L-80 Top Thread Hydril563 Casing Description Liner OD (in) 4 1/2 ID (in) 4.00 Top (ftKB) 5,435.0 Set Depth (ftKB) 12,641.0 Set Depth (TVD) … 3,849.8 Wt/Len (l… 11.60 Grade L-80 Top Thread IBT-m Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP W/HD's 5½" X 7.63", 5½" 17# Hydril 563 pin dn 4.970 5,454.9 3,848.0 84.74 NIPPLE RS Nipple 7.63" L-80 5.5" 15.5# HYD 563 Box x box 4.850 5,457.7 3,848.2 84.86 HANGER Baker "DG" Flex-Lock liner hanger 5½" X 7.63" 5 1/2 Hyd 563 pin x pin 4.840 5,467.5 3,849.1 85.25 SBE Baker 4.75" ID Seal Bore Extension, 5 1/2" Hyd 563 Box x Pin 4.750 5,829.3 3,870.9 86.82 SWELL PACKER Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "E" S/N -049169-001-2 3.960 6,772.7 3,864.4 88.57 SWELL PACKER Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "D" S/N -049169-001-1 3.980 7,038.5 3,876.6 86.18 SWELL PACKER Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "C" S/N -049169-001-9 3.970 10,589.5 3,872.2 89.36 SWELL PACKER Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "B" S/N -049169-001-8 3.980 10,853.5 3,867.5 94.13 SWELL PACKER Baker swell packer , 4-1/2" x 6.38", 920 medium (Water activated) "A" S/N -049169-001-4 3.980 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 34.7 Set Depth (ft… 5,481.6 Set Depth (TVD) (… 3,850.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 34.7 34.7 0.04 HANGER Vetco Off Set Tubing Hanger W/ 13-3/8" false bowel SN: IJ00040001-0431-4 3.875 4,926.7 3,728.3 71.78 NIPPLE CAMCO 'DB' Nipple 4½" w/3.812" no-go profile 3.813 5,441.3 3,846.7 84.19 LOCATOR Baker mechanical locator Comm N #H450-01-4785 3.860 5,464.2 3,848.8 85.12 SEAL ASSY Baker Bonded Seal assy with full Mule Shoe, Comm N #H450-01- 4785 3.870 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,839.0 6,767.0 3,871.4 3,864.2 WS D, 1C-154 11/3/2015 SLOTS 4 1/2" OD L-80, 11.6#, R3, IBTM slotted liner 7,049.0 10,583.0 3,877.3 3,872.2 WS D, 1C-154 11/3/2015 SLOTS 2 1/2" x 1/8" slots, 8 slots/row, 4 rows/ft. 10,863.0 12,631.0 3,866.8 3,849.9 WS D, 1C-154 11/3/2015 SLOTS 3' standoff each end, SMLS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/16/2016 2 3,695.2 3,099.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/22/2020 Notes: General & Safety End Date Annotation NOTE: 1C-154, 2/23/2020 9:19:34 AM Vertical schematic (actual) Liner; 5,435.0-12,641.0 SLOTS; 10,863.0-12,631.0 SLOTS; 7,049.0-10,583.0 SLOTS; 5,839.0-6,767.0 Intermediate; 39.4-5,614.0 SEAL ASSY; 5,464.2 LOCATOR; 5,441.3 XO THREAD; 4,928.5 NIPPLE; 4,926.7 XO THREAD; 4,916.9 XO THREAD; 3,702.4 GAS LIFT; 3,695.2 XO THREAD; 3,685.8 Surface; 42.2-2,636.9 GAS LIFT; 2,509.4 Conductor; 42.2-122.2 HANGER; 34.7 KUP INJ KB-Grd (ft) 39.73 Rig Release Date 11/8/2015 1C-154 ... TD Act Btm (ftKB) 12,680.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292355900 Wellbore Status INJ Max Angle & MD Incl (°) 94.57 MD (ftKB) 10,930.02 WELLNAME WELLBORE1C-154 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2151660 Type Inj W Tubing 1081 1082 1076 1069 Type Test P Packer TVD 3846 BBL Pump 1.3 IA 675 2500 2445 2425 Interval O Test psi 1500 BBL Return OA 246 251 253 254 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Diagnostic MITIA Notes: 1C-154 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1C Pad Borge 01/30/23 Form 10-426 (Revised 01/2017)MIT KRU 1C-154 diagnostic MITIA 1-20-23.xlsx 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1C-154 (PTD 215-166) Report of suspect IA pressure fall off Date:Tuesday, January 17, 2023 11:34:07 AM Attachments:AnnComm Surveillance TIO for 1C-154.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Tuesday, January 17, 2023 11:16 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1C-154 (PTD 215-166) Report of suspect IA pressure fall off Chris, KRU 1C-154 (PTD 215-166) is exhibiting suspect IA pressure fall off. Operations has recently pressured the IA up a couple times, but the IA pressure has exhibited a slow fall off. DHD will be mobilized to perform initial testing to include an MITIA, pack off tests and adjust the IA pressure for a 30 day monitor. Any required paperwork for continued injection or corrective action will be submitted once a plan forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 ry N (d.6ap) a�n}e�aduna1 4 m �rymp� ryVm� ev OO d O pQp O .a loommommil ■-------,I MEEMEMSE (lSd) ainssa-ld (0d3sW IQ Od9) a;ea Si-iO-E ZOZ Zi -Z 0-E ZOZ 6Q -Z 0-E Z 0 Z 9O-i❑-E20- tr0 TD -i 0-E ZD Z �6Z-ZZ-ZZOZ 92-ri-r2O- £Z-Zi-ZZOZ QZ-Zi-ZZOZ LT-Zi-Z2O- bi-ZZ-ZZOz Ti-Zi-ZZOZ sc-ZZ-ZZOZ sO-Zi-ZZOZ, za-ei-era- o 6Z-ii-ZZOZ 9Z-ii-ZZOZ £Z-Zi-ZZOZ QZ-ZZ-ZZOZ Li-ii-ZZOZ bi-ii-rrOZ Tl-ii-ZZOZ SQ-tt-zzoz SQ-ii-ZZQZ zQ-ti-zzOz Qa-oz-ezaz LZ-OI-EZOZ trZ-Di-ZZOZ LZ-of-rZOz 6T-OZ-rZOZ 1C-154 90 -Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1C-154 2022-10-20 249.0 176 -73.0 OA 1C-154 2022-10-21 350.0 477 127.0 IA 1C-154 2022-11-20 307.0 418 111.0 IA 1C-154 2022-11-28 233.0 543 310.0 IA 1C-154 2023-01-06 223.0 640 417.0 OA 1C-154 2023-01-14 224.0 687 463.0 IA -\ KUP INJ WELLNAME 1C-154 WELLBORE 1C-154 LVI RJlVr11illIp$ Alaska, Inc. Well Attributes; Max AngleBh TD F,ela Name wE T AK Wdifi-MAPWWI Woumi atimn, Icl (°) Mn(nKRI MBrm (nKR) IN .5] 10,93002 12,6800 CammenL SSSV: NIPPLE X251ppm) Gale MroLvlbn Entl gNe 3933 I test WO: 39.]3 Rq Rekeae gale 11182015 1L-15<,1 -Prep g:19: al AM I Last Tag Veni®l echemeec(-IN AnroUtlon Depthm%B) EIM Dab Milbore Unit MW By HANGER.54.7- Last Tag: L. 16154 1pneven Last Rev Reason Annornu n Entl gate WNlhore 1 Lot Metl Ry ' - -Rev Reason: Set DV, PDIIed Plug 2.22.2020 "',e, RAgusp .....-.....-.....-.....-.....-.....-.....-.....-..... .. ... .... com„nmr; 4x arzz.2 GAS LIFT:25W.0 aunw:9zazexa- XO THREAD; SEEI GAS MrT'. 3.6N.2 xo THREAD; 3 7 4 xo THRPAD; ague wPPLe.4.em.] MTHREAD; a S2a.5 LOCATGa,5441] SEAL ASSY; 5,4Sn.2 o Im.rmealae: Se.w,au.° SLOTS; 5ERSS6.767.0 SLOTS;].Wg.0-104ta. sLors', m.eeuo-u.eel.o unar.a4SSp-12.E41D- Casing Strings CYIn9 Deanlptlon Og (in) Conductor 20 In lint To 1-(721 50 gePtM1 II1KR) set Del- flvD)... INTI -en ll... Grind, ToP rM1reatl 1925 42.2 1222 1222 78.67 B Welded Casing Deenip5cn OD (in) Surface 10314 ID (in) Top Ri Set DeptM1IflKBI Set Dench HID) WoUn g... Naas Tap Threat 9.95 42.2 2,6369 2,412.7 45.50 L40 TSH 563 Dail, Ducripsm OD (in) Intermediate ]518 ID (in) Top (MB) Set DepthlarKBl Srt Depth IND)... Wanton (I Naae Tap Thread 6.88 39.4 5,614.0 3,857.8 29.70 L40 Hydri1563 c asine Deenipacn End (in) 1. On) TopfM ) SN Depth MILE) Ent Dom, INDI... WBI.en(I Grade Tap Threes Liner 4112 4.00 5,435.0 12,641.0 3,849.8 11.60 1 LA0 IBT-m Liner Details Top (nKR) Top PRDI.nKB) Top awl P) Ibm Dee xamine ID Com him 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP WIHD'S 5'S' X].63", 5'G"17# 4.970 HyJdl 563 pin In 5,454.9 3,848.0 84.74 NIPPIE RS Nipple 7.63" LA0 5.5" 15.5# HYD 563 Box x box 4.850 5,45].] 3,848.2 84.86 HANGER Baker "DG' Flex -Lock liner hanger 51S' X].63' 512 4.840 Hyd 563 in x pin 5,467.5 3,849.1 85.25 SBE Baker 4.75" ID Seal Bore Extension, 5112"Hyd 563 4.750 Box x Pin 5,829.3 3,870.9 86.82 SWELL PACKER Baker Swell packer, 4-1l2' x 6.38', 920 medium 3.960 (Water activated) "E"SIN -D49169-001-2 6,772.7 3,864.4 88.57 SWELL PACKER Baker Swell packer ,4-il2'x 6.38", 920 medium 3.980 (Water activated) "D" SIN -049169-001-1 7,038.5 3,876.6 86.18 SWELL PACKER Bakerswellpacker, 4-1l2"x6.38", 920medium 3.970 (Water activated) "O' SIN -049169-001-9 10,589.5 3,872.2 89.36 SWELL PACKER Baker swell packer, 4-112"x6.38", 920 medium 3.980 (Water activated) "B" Sox -049169-001-8 10,853.5 3,867.5 94.13 SWELL PACKER Baker swell packer, 4-ill"x6.38", 920 medium 3.980 (Water activated) "A" SM -049169-001-0 Tubing Strings Tubing Deanlptlon 54ing Ma... ID'(m) Top (nKR) sn Depth M.. set Depth OVD) f... M phan Grade TIP Connection TUBING 4112 396 34J 5,481.6 3,8502 12.60 L-80 HYD563 Completion Details Top HID) Top mn TopiKKB) (nKB) H) xommm ii Com ID (in) 347 347 1 0.04 HANGER Vetca OR Set Tubing Hanger W113A.8'false bowel SN'. 3.675 IJ000400m-0431-0 4,926.7 3.726.3 71.78 NIPPLE CAMCO'DB'Nipple4'/a' I43.812"n"oproble 3.813 5,441.3 3,846.7 84.19 LOCATOR Baker mechanical locator Comm N#H45001-0785 3.860 5464.2 3,848.8 85.12 SEAL ASSY Baker Banded Seal ass, with full Mule Shoe, Comm N#H450-01- 3,870 785 rations & Slots Shot Den Top (ND) Wm (W(ahonx Top ffdab Mn Prol) IML.) (nKB) Llnkea Zone D. I Type Com 5,839.0 6,767.0 1 3,871.4 3,864.2 WS q 16154 11/312015 SLOTS 4112-1 On L-80,11.6#, R3, IBTM Slotted liner 7,1-9.0 10,563.0 3,877.3 3,872.2 WS q 16154 11/312015 SLOTS 2 112" x 118" Slope 8 slotemow, 4 rowsla. tg863.o 12,631.0 I 3,:566.8 1 3,849.9 WS D. 16154 111312015 SLOTS 3' shouted each end SMLS Mandrel Inserts at mi N Top (M E) Top(ND) MKS) Make Model ODlin) .ery Verye Lurch Pon Sim -Run Type Type lin) (Ai) Run OMe 1 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 D.0 V16I2016 2 3,695.2 3,099.4 CAMCO IKHMG I 1 GASLIFT DMY BK I 0.000 D.0 2.22.2020 Notes: General & Safety Ena Dae Annotation NOTE: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-154 KUPARUK RIV UNIT 1C-154 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-154 50-029-23559-00-00 215-166-0 W SPT 3848 2151660 1500 1311 1316 1316 1314 159 292 290 281 4YRTST P Austin McLeod 5/13/2022 MITIA 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 1C-154 Inspection Date: Tubing OA Packer Depth 10 2020 1910 1900IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220514075611 BBL Pumped:2.5 BBL Returned:1.9 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:29:01 -08'00' MEMORANDA • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Jim Regg Keil 51 6 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-154 FROM: Austin McLeod KUPARUK RIV UNIT 1C-154 Petroleum Inspector Src: Inspector Reviewed By:yd P.I.Supry 3 BP-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-154 API Well Number 50-029-23559-00-00 Inspector Name: Austin McLeod Permit Number: 215-166-0 Inspection Date: 5/13/2018 — Insp Num: mitSAM180514084106 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IC-154 TType Inj W TVD 3848 Tubing 971 974 961 960 PTD 2151660 Type Test SPT Test psi 1500 IA 345 1800 1740 - 1720 BBL Pumped: 13 BBL Returned: 1.1 - OA 231 367 - 358 ' 346 Interval 4YRTST P/F P Notes: MIT-IA SCANNED JUN 0 12018 Wednesday,May 16,2018 Page 1 of 1 • t • STATE •OF ALASKA • ` ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 1", Plug Perforations Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter r Change Approved Program Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Initial WAG Cycle p' 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Developments Explorator r 215-166-0 3.Address: Stratigraphic Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23559-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025649;ADL025638 KRU 1C-154 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 12680 feet Plugs(measured) None true vertical 3849 feet Junk(measured) None Effective Depth measured 12680 feet Packer(measured) 5435 true vertical 3849 feet (true vertical) 3846 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20 122' 122' SURFACE 2595' 10 3/4 2637' 2413' INTERMEDIATE 5575' 7 5/8 5614' 3858' LINER 7206' 41/2 12641' 3877' Perforation depth: Measured depth: 5839-6767, 7049-10583, 10863-12631 RECEIVED True Vertical Depth: 3871-3864, 3877-3872, 3867-3850 JUN 14 2017 Tubing(size,grade,MD,and ND) 4 1/2 ,L-80, 5482 MD, 3850 TVD AOGCC Packers&SSSV(type,MD,and TVD) SSSV=None Packer: Baker HRD-E ZXP, 5,435'MD, 3,846'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A NOV � Treatment descriptions including volumes used and final pressure: SCANNED OV 0 1 201y 7, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation _ 400 50 890 Subsequent to operation 1110 55 1800 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations j Exploratory r Development r Service p- Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil Gas WDSPL `', Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG 17 GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Marina Krysinski Email: marina.l.krvsinski ..cop.com Printed Name Marina Krvsinski Title: Drillsite Petroleum Engineer Signature 17.-N - , Kii.„:„.„:„ Phone:263-4906 Date to41^on tn Form 10-404 Revised 5/2015 Submit Original Only RBDMS JUN 1 4 2017 • • 1C-164 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/03/17ICommenced WAG Injection. KUP PROD • 1C-154 Conoco�'11lli ps 2 eli Atttr butes -<,„ • • t4 a Angle&IND •`.• {k18S1(c7 inc. Wellbore APIIUWI Field Name Wellbore Status ncl l°) MD(ftKB) Act Btm(ftKB) p co�adx�tmps 500292355900 WEST SAK PROD 94.57 10,930.02 12,680.0 ..• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Dale „1 0.154,1n0/20t623017 PM,. SSSV:NIPPLE Last WO: 39.73, 11/8/2015 Vertical sohernaho(aotuall Annotation Depth(ftKB) End Dale Annotation Last Mod By End Date Last Tag:SLM Rev Reason:GLV C/O pproven 1/20/2016 HANGER,34.7- f®te.77' 1 f�.l.;.I•N sing St1ngs' ,". Q .:',. -,;:s.,''.•','.'.. At_ • Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...WtlLen(1...Grade Top Thread Conductor 20 19.250 42.2 122.2 122.2 78.67 B Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread ............... ............ ................®... .. -..Surface 10 3/4 9.950 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Intermediate 7 5/8 6.875 39.4 5,614.0 3(7812572)....28. ,857.8 29.70 L-80 Hydri1563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth MKS) Set Depth(ND)...Wt/Len(I...Grade Top Thread Liner 41/2 4.000 5,435.0 12,641.0 3,849.8 11.60 L-80 IBT-m •Liner Details • Pte, . m k''-' .. ••�\•�� � Nominal ID Conductor,42.2-122.2 . Top(ftKB) Top(ND)(MB) Top not rt Item Des Com (In) 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP WHO's 5%"X 7.63",5%"17# 4.970 Hydril 563 pin do 5,454.9 3,848.0 84.74 NIPPLE RS Nipple 7.63"L-80 5.5"15.5#HYD 563 Box x box 4.850 GAS LIFT;2,000.4 5,457.7 3,848.2 84.86 HANGER Baker"DG"Flex-Lock liner hanger 5%"X 7.63"5 1/2 4.840 Hyd 563 pin x pin i I, 5,467.5 3,849.1 85.25 SBE Baker 4.75"ID Seal Bore Extension,5 1/2"Hyd 563 4.750 Baxx Pin 5,829.3 3,870.9 86.82 SWELL Baker swell packer 4-1/2"x 6.38",920 medium 3.960 PACKER (Water activated)"E"S/N-049169-001-2 Surface;42 2-2536 2,636.9 6,772.7 3,864.4 88.57 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 PACKER (Water activated)"D"S/N-049169-001-1 XO THREAD;3,6858 7,038.5 3,876.6 86.18 SWELL Baker swell packer,4-1/2"x6.38",920 medium 3.970 GAS LIFT;3,695.2 PACKER (Water activated)"C"S/N-049169-001-9 XO THREAD;3,702.4 10,589.5 3,872.2 89.36 SWELL Baker swell packer,4-1/2"x6.38",920 medium 3.980 PACKER (Water activated)"B"S/N-049169-001-8 XO THREAD;4,916.9 10,853.5 3,867.5 94.13 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 PACKER (Water activated)"A"S/N-049169-001-4 NIPPLE;4,926.7 y - '' X0 THREAD;4,928.5 Tubing Description String Ma...ID lit Top(ftKB)34 Set Depth IR..Set Depth(ND)(.. Wt p ) Grade T p Connection TUBING 4 1/2 3 958 34 7 5,481.6 3,850 2 2.60 L-80 HYD563 I Rom fetor!GetAlis ; Nominal lO Top(ftKB) Top(TVD)(MB) Top Incl rt Item Des Co lin) 34.7 34.7 0.04 HANGER Vetco Off Set Tubing Hanger W/13-3/8"false bowel SN. 3.875 LOCATOR;5,441.3 1J00040001-0431-4 4,926.7 3,728.3 71.78 NIPPLE CAMCO'DB'Nipple 4%"w/3.812"no-go profile w/RHC 3.813 plug SN#10103-3(PULLED CAT STANDING VALVE 11 I 12/20/2015) 5,441.3 3,846.7 84.19 LOCATOR Baker mechanical locator Comm N#H450-01-4785 3.860 I. :4705,4642 3,848.8 85.12 SEAL ASSY Baker Bonded Seal assy with full Mule Shoe,Comm N 3.870 SEAL ASSY;5,464.2 t) I Perloratlans&Slots w Shot Dens Top 1N0) Btm(TVD) (shots# Top MB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 5,839.0 6,767.0 3,871.4 3,864.2 11/3/2015 SLOTS 4 1/2"OD L-80,11.6#, R3,IBTM slotted liner 7,049.0 10,583.0 3,877.3 3,872.2 11/3/2015 SLOTS 2 1/2"x 1/8"slots,8 slots/row,4 rows/fi. Intermediate;39.4-5,614.0 Al l 10,863.0 12,631.0 3,866.8 3,849.9 11/3/2015 SLOTS 3'standoff each end, SMLS Mandrel Inserts lif st ati on Top(ND) Valve Latch Port Size TRO Run N Top(MB) (ftKB) Make Model OD lin) Sery Type Type (in) (psi) Run Date Com 1' 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/16/2016 SLOTS;5,039.0-6.767.0 2 3,695.2 3,099.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/17/2016 Notes:General&::Sa e�t i 414 End Date Annotation NOTE; Iiiir ''''llil'll' I-I SLOTS;7,0490-10,583.0 SLOTS;10,863.0-12,631.0-tom I 1---- I- Liner,5,435.0-12,641 0 Kirai 2-tc-l(c,c) Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, March 18, 2016 6:03 PM C.l t( To: NSK West Sak Prod Engr; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; Jensen, Marc D; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; Haakinson, David Subject: LPP/SSV on well 1C-154 was returned to service Jim: The low pressure pilot(LPP) on well 1C-154 (PTD#215-166)was returned to service and removed from the safety defeat log today, March 18th, 2016, after the wellhead injection pressure stabilized above the LPP trip point of 500 PSI. This notification is in accordance with "Administrative Approval No. CO 4066.001." The current wellhead injection pressure is 535 psi at an injection rate of 890 BWPD. Please let me know if you have any questions. Regards, Tyler Hall / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638(a?conocophillips.com SCANNED SEP 2 12016 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TOJim Regg ( DATE: Monday,March 14,2016 P.I.Supervisor ` > , 3I 1 71 1SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-154 FROM: Guy Cook KUPARUK RIV UNIT 1C-154 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .J8:42— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IC-154 API Well Number 50-029-23559-00-00 Inspector Name: Guy Cook Permit Number: 215-166-0 Inspection Date: 3/12/2016 Insp Num: mitGDC160312121024 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 'Well 1C-154 - Type Inj W'TVD 3848 Tubing 440 440 440 440 PTD 2151660 - Type Test SPT Test psi 1500 IA 1060 2000 1970 - 1965 - Interval INITAL P/F P OA 380 471 - 466 - 463 Notes: Suggested testing to 2000 psi after reviewing TIO's. Test went well. Pressured up to 2000 psi using 0.6 BBLS and bled back 0.55 BBLS after testing was completed. SCANNED SEP 2 j 2016 Monday,March 14,2016 Page 1 of I prb Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, February 25, 2016 2:18 PM To: Regg, James B (DOA) e71 Cc: Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; Jensen, Marc D; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Braden, John C; Stanley, Scott M; Hall, Tyler A; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on well 1C-154 Jim: The low pressure pilot (LPP) on well 1C-154 (PTD#215-166)was defeated today, February 25th, 2016 when the well was brought online following a long term shut in period. The well is currently building surface pressure from an initial wellhead injection pressure of 235 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Tyler Hall West Sak Production Engineers ConocoPhillips Alaska, Inc. SCANNED SEP 21201&; Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 S S o ] . o • • J O o • I N 9 () 0 N • I N p) co (4 (O a' O N o .-. N (O NI A N Z \ @ 00 U U5O 0 U 0)CAS U aNil r-,a �I T..,a - �I N �I m Z 0 0 a� o n o (o QJ QJ QJ Q m QL O n n n IE.- m a I a l a I Q CLCD cn o 0 0 OftE. g 2 I 0 �`o' >, 0 Ua Ua UQ c)0) U EI > in in in a C) o a) 0 J 0 J 0 J 0 J 0 0 . •o) . 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U a m Q a2 N o 0 o m Z U U J Ii C7 Q C1 I C1Q03 co } e } IX < as N (D N - LLOa a) d Eu)a Jco 3 -0-3' o 0W _ Cr) Z aS ce d0 ( V O ii E W zca ti J a) @ m O V o ' E J E as Z a) a ) w ce O NO N ill:C_ Cr) J 0. c _.I a). m z E Cl. 0 ... M 0 0 C ) G CO co 0LP 0 n V V Z w M 1 1 E i Q Cil) >-O tlr/1 o ®' V o N S E y 5 z O la co c G = N as > 00 a) — aNi E Ca c o H E I l w c H Cn as tq v m cI as CI 1 1 I Q ° c \ c ° m 0 SII Q z Eo af CI U 6 2 o 1 ' co Z ► N to 10 4 co � c ./ N N a0 O F4../ coco o E o c \BVI 5., CD > w > g > m I— WE a 0 aa) N a) W • t I N d c a a> o N =1) I ui > o O aNi 10 o ai c re co -is Z as a o o a_ o o w a w U J d m to U E V O a o 0. a 0 H E \ Q Uo o u. 0 E O o E d E �J E Q a 2 3 i 0 Q 0 0 o W ° v 0 • • RECEIVED STATE OF ALASKA MAR 2 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing 9 Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Prod to WAG 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (;i Exploratory r 215-1660 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23559-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025649;ADL025638 KRU 1C-154 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 12680' feet Plugs(measured) 1135 true vertical 3849' feet Junk(measured) None Effective Depth measured 12680' feet Packer(measured) 4927, 5464 true vertical 3849' feet (true vertical) 3728, 3849 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 122 122' SURFACE 2595 18.125 2637 2413' INTERMEDIATE 5575 12.75 5614 3858' LINER 7206 6.58 12641 3850' Perforation depth: Measured depth: 5839-6767; 7049-10583; 10863-12631 True Vertical Depth: 3871-3864; 3877-3872; 3867-3850 Tubing(size,grade,MD,and TVD) 4.5, L-80, 5482 MD,3850 TVD Packers&SSSV(type,MD,and TVD) SSSV= None NIPPLE-CAMCO'DB'NIPPLE 4W W/3.812"NO-GO PROFILE W/RHC PLUG SN#10103-3 @ 4927 MD and 3728 TVD SEAL ASSY-BAKER BONDED SEAL ASSY WITH FULL MULE SHOE,COMM N#H450-01-4785 @ 5464 MD and 3849 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 373 197 1 1350 250 Subsequent to operation 0 0 897 1013 530 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG 17 GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-119 Contact Bob Christensen/Darrell Humphrey Email: n1139conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature 1 Phone:659-7535 Date 3 r f9 14 vi-i_ 41 zik Form 10-404 Revised 5/2015 A q//04 RBDMS I,, MAR 2 2 2016 Submit Original Only • • 1C-154 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/12/16 STATE WITNESSED (GUY COOK) MITIA TO 2000 PSI (PASSED). 02/25/16 Open well to water injection service •UP PROD 111111 1C-154 ConocoPhillips 4 Well Attributes Max Angle&MD TD Alaska,InC. Wellbore APIIDWI Field Name Wellbore Status ncl(°l MD(ftKB) Act Btm(ftKB) ,_ yMp 500292355900 WEST SAK PROD 94.57 10,930.02 12,680.0 .," ,sem Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-154,1/20/20162:35;17 PM SSSV:NIPPLE Last WO: 39.73 11/8/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ` Last Tag:SLM Rev Reason:GLV C/O pproven 1/20/2016 HANGER 34.7- ''u i ag! 'Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Conductor 20 19.250 42.2 122.2 122.2 78.67 B Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread _..._..._�.____�......._.......__.._._ .... .... ....Surface 10 3/4 9.950 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread Intermediate 7 5/8 6.875 39.4 5,614.0 3,857.8 29.70 L-80 Hydril563 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...Wt/Len(I...Grade Top Thread Liner 41/2 4.000 5,435.0 12,641.0 3,849.8 11.60 L-80 IBT-m • Liner Details Nominal ID Conductor,422-122.2 Top(ftKB) Top(TVD)(ftKB) Top Incl 7 Item Des Com (in) 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP W/HD's 5W X 7.63",5W 17# 4.970 Hydril 563 pin do • 5,454.9 3,848.0 84.74 NIPPLE RS Nipple 7.63"L-80 5.5"15.5#HYD 563 Box x box 4.850 GAS LIFT;2,509.4 .III I. 5,457.7 3,848.2 84.86 HANGER Baker"DG"Flex-Lock liner hanger 5W X 7.63"5 1/2 4.840 Hyd 563 pin x pin (II 5,467.5 3,849.1 85.25 SBE Baker 4.75"ID Seal Bore Extension,5 1/2"Hyd 563 4.750 - Bak x Pin .. [ 5,829.3 3,870.9 86.82 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.960 PACKER (Water activated)"E"S/N-049169-001-2 Surface;42.2 2,636.9 6,772.7 3,864.4 88.57 SWELL Baker swell packer,4-1/2"x6.38",920 medium 3.980 PACKER (Water activated)"D"S/N-049169-001-1 XO THREAD;3,685.8 7,038.5 3,876.6 86.18 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.970 GAS LIFT;3,6952 PACKER (Water activated)"C"S/N-049169-001-9 XO THREAD;3,702.4 10,589.5 3,872.2 89.36 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 PACKER (Water activated)"B"S/N-049169-001-8 XO THREAD;4,916.9 10,853.5 3,867.5 94.13 SWELL Baker swell packer,4-1/2"x6.38",920 medium 3.980 PACKER (Water activated)"A"S/N-049169-001-4 NIPPLE;4,926.7 � Tubing Strings XO THREAD;4,928.5 Tubing Description String Ma...ID(in) Top(860) Set Depth(k..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection ITUBING 41/2 3.958 34.7 5,481.6 3,850.2 12.60 L-80 HYD563 I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 34.7 34.7 0.04 HANGER Vetco Off Set Tubing Hanger W/13-3/8"false bowel SN: 3.875 LOCATOR;5,441.3 ., )J00040001-0431-4 4,926.7 3,728.3 71.78 NIPPLE CAMCO'DB'Nipple 404"w/3.812"no-go profile w/RHC 3.813 • plug SN#10103-3(PULLED CAT STANDING VALVE ff 12/20/2015) 11 IE _ I. 5,441.3 3,846.7 84.19 LOCATOR Baker mechanical locator Comm N#H450-01-4785 3.860 lI ! 5,464.2 3,848.8 85.12 SEAL ASSY Baker Bonded Seal assy with full Mule Shoe,Comm N 3.870 SEAL ASSY;5,464.2I 464 2 , #H450-01-4785 I Perforations&Slots i Shot - Dena Top(TVD) Blm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 5,839.0' 6,767.0 3,871.4 3,864.2 11/3/2015 SLOTS 4 1/2"OD L-80,11.68, Il 1 R3,)BTM slotted liner 7,049.0 10,583.0 3,877.3 3,872.2 11/3/2015 SLOTS 2 1/2"x 1/8"slots,8 J slots/row,4 rows/ft. Intermediate;39.4-5,614.0-+ 10,863.0' 12, 631.0 3,866.8 3,849.9 11/3/2015 SLOTS 3'standoff each end, SMLS Mandrel Inserts SI St ei on Top(TVD) Valve Latch Port Size TRO Run - N Top(ftKB) _ (ftKB) Make Model OD(in)_ Sery Type Type (in) (psi) Run Date Com 'i 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/16/2016 SLOTS;5,039.0-6,787.0 j 2 3,695.2 3,099.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/17/2016 1_1 Notes:General&Safety End Date Annotation UrNOTE. w • SLOTS;7,049A-10,583.0 SLOTS;10.863.0-12,631.0 Liter;5,435.0-12,641.0 • OF Tit yi // 7 ex THE STATE Alaska Oil and Gas 0:,,-s_ `�4, of/\ j /�1Z S} /� Conservation Commission 11LAL1 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 995091-3572 509. 1572 Main: ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christensen NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-154 Permit to Drill Number: 215-166 Sundry Number: 316-119 Dear Mr. Christensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /0,14.,hz, Cathy '. Foerster Chair DATED this 2 day of February, 2016. RBDMS �-� F L� L 4 2016 . 0 RE k'oED RECEIVED STATE OF ALASKA 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION SFE•FEB 1 12 2 to APPLICATION FOR SUNDRY APPROVALS /�OGC> / 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations i- Fracture Stimulate r Repair Well r Operations shutdow n r Suspend r Perforate f Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool JW Re-enter Susp Well r Alter Casing r Other:Prod to WAG Id • - 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory J! Development 215-1660 3.Address: Stratigraphic Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23559-00^ 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will planned perforations require spacing exception? Yes 1 No 1-/ KRU 1C-154 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025649;ADL025638 • Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: 'Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): '12680' ^ 3849' " 12680' - 3849' 1135 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 122' 122' SURFACE 2595 10 3/4 2637' 2413' _ INTERMEDIATE 5575 7 5/8 5614' 3858' LINER 7206 41/2 12641' 3850' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5839-6767;7049-10583; 10863-12631' 3871-3864;3877-3872; 3867-3850 4 1/2 L-80 5482 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=NONE MD= TVD= PKR=Baker HRD-E ZXP MD=5435 TVD=3846 12.Attachments: Proposal Summary WellBore Schematic p 13. Well Class after proposed work: Detailed Operations Program r' BOP Sketch r Exploratory 1 Stratigraphic Jm Development r Service J`/' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/30/16 OIL rWIND J WDSPL J— Suspended J" 16.Verbal Approval: Date: GAS r WAG JV, GSTOR f SPLUG r Commission Representative: GINJ J'"` Op Shutdow n E Abandoned 1 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Bob Christensen/Darrell Humphrey Printed Name Robert D. Christensen Phone:659-7535 Email: n1139(aconocophillips.com `� Title: NSK Production Engineering Specialist �L.J Signaturedie, / 1ejt,„_va__9(1- Date: 2/9/l6 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Le. \\ck Rug Integrity r BOP Test J'Mechanical Integrity Test r Location Clearance r Other: Da-il y 04 wlur`► r'"'i"q o{ kRuJ wefts ie-OSS /C -U G ef k' � —o 7- Fo - edviFa,„.1,tavtcc ,,a,Mp/J'en hCe vrtchit ,2,e „Inc 1S, 40zy) / lot -c w, e-ssrd MGT—IA rG� - Post Initial Injection MIT Req'd? Yes JV No r Spacing Exception Required? Yes r No v Subsequent Form Required: /Q- 4 Q 4 APPROVED BY Approved by: L/PP � COMMISSIONER THE COMMISSION Date: 2. -2-3_7A — UTI- /18/« Ail 21/461 Qr I1 � A Submit Form and Form 10-403 Revised 11/2015 v c n/ id for 12 months from the date of approval. itenalirtsin`uuri,cahe 2��9pM ��� �6�-6 ,f GD WR1 • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 :onocoPhil I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 February 09, 2016 Victoria Loepp RECEIVED State of Alaska, Oil & Gas Conservation Commission FEB 12 2016 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 AOGCC Victoria, ConocoPhillips Alaska, Inc. is submitting revisions for sundry number 316-039 to convert Kuparuk River Unit well 1C-154 from Oil Production to Water Alternating Gas Injection service. Enclosed you will find 10-403 Sundry form for ConocoPhillips Alaska, Inc. regarding 1C-154 (PTD# 215-1660), with revised MPSP value, updated AOR spreadsheet, and updated Proposal Summary for 10-401, conditions for approval. If you have any questions regarding this matter, please contact myself or Darrell Humphrey Sin -rely, , Robert D. Christensen Attachments Sundry application Proposal Summary Area Map AOR Detail Well schematic • • 1C-154 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1C-154 (PTD# 215-1660) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: West Sak well 1C-154 was completed as an injector on 11/7/15 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 1 C-153 and 1 C- 155. The base of the Ugnu A sand was found at 4788' and /3680' tvd The top of the Wsak D sand was found at 5517' and /3852' tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset producers (1C-153 & 155), there are no additional production/injection wells located within a 1/4 mile radius of the 1C-154 penetrations of the Wsak interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1C-154 is good and is classified as a"Single Casing"well. The injection tubing/casing annulus is isolated via a Baker HRD-E ZXP packer located at 5435' and (3846' tvd). A State-witnessed MIT-IA will be performed once well 1C-154 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (4961' -5490' and /3739' - 3851' tvd) to insure injection zone conformance. The 20" Conductor was cemented with 200 cf ArcticCRETE. The 10-3/4" Surface casing was cemented with 460 bbls DeepCrete followed by 61.5 bbls DeepCrete. The 7-5/8" Intermediate casing was cemented with 43.6 bbls Class "G". Conditions for approval (if applicable): Daily OA pressure monitoring of KRU Wells 1C-05, 1C-06, & 1C-07 for conformance compliance under 20 AAC 25.402 (f). Injection operations to be in accordance with AIO 2C. • ...\\,•i. KUP PROD 1C-154 ConocoPhillips O Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) crn«orr4u�`- 500292355900 WEST SAK PROD 94.57 10,930.02 12,680.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 1C-154,1/20/20162:35:17 PM SSSV:NIPPLE Last WO: 39.73 11/8/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM Rev Reason:GLV C/O pproven 1/20/2016 HANGER,34.7- 11.,_1:4 Casing Strings Casing Description i OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread ' '• Conductor 20 19250 422 122.2 122.2 78.67 6 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread .._...._.._...._..._................................_ I..........Surface 10 3/4 9.950 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Tap(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread Intermediate 75/8 6.875 39.4 5,614.0 3,857.8 29.70 L-80 Hydri1563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread Liner 41/2 4.000 5,435.0 12,641.0 3,849.8 11.60 L-80 IBT-m Liner Details Nominal ID Conductor,42.2.122.2 Top(fIKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP W/HD's 51A"X 7.63",5'/x"17# 4.970 Hydril 563 pin do 5,454.9' 3,848.0 84.74 NIPPLE RS Nipple 7.63"L-80 5.5"15.58 HYD 563 Box x box 4.850 GAS LIFT;26094 5,457.7 3,848.2 84.86 HANGER Baker"DG"Flex-Lock liner hanger 51/2"X 7.63"5 1/2 4.840 Hyd 563 pin x pin • I 5,467.5 3,849.1 85.25 SBE Baker4.75"ID Seal Bore Extension,5 1/2"Hyd 563 4.750 Box x Pin 5,829.3 3,870.9 86.82 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.960 PACKER (Water activated)"E"S/N-049169-001-2 Surface;42 2-2 636.9 6,772.7 3,864.4 88.57 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 • PACKER (Water activated)"D"S/N-049169-001-1 00 THREAD;3685.8 `. 7,038.5 3,876.6 86.18 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.970 GAS LIFT,3595.2 PACKER (Water activated)"C"S/N-049169-001-9 XO THREAD;3 702 4IIII 10,589.5 3,872.2 89.36 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 PACKER (Water activated)"B"S/N-049169-001-8 XO THREAD;4,916.9 10,853.5 3,867.5 94.13 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 PACKER (Water activated)"A"S/N-049169-001-4 NIPPLE;4,920.7 am- Tubing Tubing Strings 80 THREAD;4,928.511.1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 34.7 5,481.6 3,850.2 12.60 L-80 HYD563 Completion Details Nominal 10 Tap(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 34.7 34.7 0.04 HANGER Vetco Off Set Tubing Hanger W/13-3/8"false bowel SN: 3.875 LOCATOR;5,441.3Ili 1200040001-0431-4 4,926.7 3,728.3 71.78 NIPPLE CAMCO'DB'Nipple 4'/,"w/3.812"no-go profile w/RHC 3.813 plug SN#10103-3(PULLED CAT STANDING VALVE 12/20/2015) I 5,441.3 3,846.7' 84.19 LOCATOR Baker mechanical locator Comm N#H450-01-4785 3.860 "i" 5.4642 3,848.8' 85.12 SEAL ASSY Baker Bonded Seal assy with full Mule Shoe,Comm N 3.870 SEAL ASSY;5,464.2 #H450-01-4785 r r �+��f Perforations&Slots Aim Shot Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Typo Com 5,839.0 6,767.0 3,871.4 3,864.2 11/3/2015 SLOTS 4 1/2"OD L-80,11.66, R3,IBTM slotted liner 7,049.0 10,583.0 3,877.3' 3,872.2 '11/3/2015 SLOTS 2 1/2"x 1/8"slots,8 slots/row,4 rows/ft. Intermediate;394-5614.0 10,863.0 12,631.0 3,866.8 3,849.9 111312015 SLOTS 3'standoff each end, SMLS Mandrel Inserts Sir St 0/i I- N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/16/2016 SLOTS:5.039.0-6767.0 2: 3,695.2 3,099.4 CAMCO KBMG 1 GAS LIFT 'DMY BK 0.000 0.0 1/17/2016 _' Notes:General&Safety End Date Annotation lifNOTE. lif 1-I SLOTS;7049.0-10,583 0 1-I iiiir lir SLOTS;10063,0-12,631.0-1--. I-1 Liner;5,435.0-12,641.0 I I 0 • ` n -o /}} 2 , 8 77 !f8 ! )( \ \[ - o $\! 7 , . � g \// t Lt i. _Li j \)i4 � \�,\ ` L 7' :;.) ` :,;-2 `.2: = \222 CI /§+ . ~ §! t; \ \$\\ \\j\ k!!] \ E . �\ G'} rli �\ �\ �\ o ) ° \ �\ ° U 4 ){ ! ! ° ! _ ¢ ¢ - , f o §e - - , . ca Cll }\ K \ m < ! 'ak ,63 \ \ %a / _ 2 \7 : : �\ t - f - / /\ �\ ®( ®\ i7, ) k .. B § LI f $ § ` \ \ \ • i ConocoPhillips 17----- Alaska, Inc. 1C-154 10-403 Sundry 14Jan16 I i ADL047449 1 ADL025638 1 i i i t I i . I i I i i n • 1 w 1 I Q Kuparuk PA ADL025649 ADL028242 i i I West Sak PA ' 'Well Pad — 1C-153 Trajectory 1C-154 Trajectory References: 10-154 Open Section Well Data: ConocoPhillips Alaska Well Database(ATDB) — 1C-155 Trajectory 1/4 Mi. 1C-154 Open Section Radius N L West Sak PA Boundary ❑ Pad Outline 0 0.1 0.2 0.3 0.4 ❑CPAI Lease Miles R --17) LP RECEIVED STATE OF ALASKA JAN 2 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdow n r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Othery 33 -r 03 (d 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 215-166-0 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23559-00 ' 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No grocQ j \C'Rl.J 1C-154 - 9.Property Designation(Lease Number): 10.Field/Pool(s): / ADL 025649,025638 , Kuparuk River Field/West Sok I 11. PRESENT WELL CONDITION SUMM' R Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: S (psi): Plugs(MD): Junk(MD): 12680' ' 3849' • 12680' 3849' 1392 Casing Length Size MD a TVD Burst Collapse CONDUCTOR 80 20.00 122' 122' SURFACE 2595 10.75 2637' 'NO2413' INTERMEDIATE 5575 7.63 56443858' LINER 7206 4.50 1(71C1'1' 3850' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots 5839-12631 • 3874-3850 4.5 L-80 5481 Packers and SSSV Type: Pa and SSSV MD(ft)and TVD(ft) SSSV=Nipple ; MO= 27 TVD=3728 SEAL ASSY-BAKER BONDED SEAL ASSY WITH FULL MULE SHO /5464 TVD=3849 , 12.Attachments: Proposal Summary V WellBore Schematic r 1 . Well Class after proposed work: Detailed Operations Program r BOP Sketch r ' Exploratory r Stratigraphic r Development r Service 14.Estimated Date for /415. Well Status after proposed work: Commencing Operations: 1/30/16 / OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: / GAS r WAG GSTOR r SPLUG r Commission Representative: / GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true and the procure approved herein will not be deviated from without prior written app/•val. Contact: Bob Christensen/Darrell Humphrey Printed Name Darrell Humphrey Phone:659-7535 Email: n1139(ci)conocophillips.com Title: NSK Production Engineering Specialist Signature '--A..,,,.v.qL nip�.s.,I Date: / —2 7. / co Commission Use Only Conditions of approval: Notify Commission •o that a representative may witness Sundry Number: 77 \1iz - ® 77�1 Rug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: Post Initial Injection MIT Req'd? Yes r No r Spacing Exception Required? Yes r No v Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ?Ills // h1"• Submit Form and Form 10-403 Revised 11/2015 ApoRIGic}t sNa i t months from the date of approval. Attachments in Duplicate • • RECEIVED JAN 2 8 2016 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 �0��� PO Box 196105 ConocoPhillips Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 January 27, 2016 Victoria Loepp State of Alaska, Oil& Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Victoria, ConocoPhillips Alaska, Inc. is submitting revisions for sundry number 316-039 to convert Kuparuk River Unit well 1C-154 from Oil Production to Water Alternating Gas Injection service. Enclosed you will find 10-403 Sundry form for ConocoPhillips Alaska, Inc. regarding 1C-154 (PTD# 215-1660), with revised casing sizes,property designation lease numbers, MPSP value and AOR spreadsheet. If you have any questions regarding this matter,please contact myself or Bob Christensen Sincerely, \I=ia -4-44 Darrell Humphrey Attachments Sundry application Area Map AOR Spreadsheet Well schematic S"pERSaI7 ED • 1C-154 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 10-154 (PTD# 215-1660) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. i-v)e /VG( V1' ✓ ►/V-e J1 Area of Review: West Sak well 1C-154 was completed as an injector on 11/7/15 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 1C-153 and 1C- 155. The top of the Ugnu A sand was found at 4600' and/3598'tvd The base of the Ugnu N sand was found at 4961' and/3739' tvd The top of the Wsak D sand was found at 5517' and /3853' tvd Area Map with 1/4 mile radius around target injection zone (see attached): Tha map attached shows that, with the exception of the offset producers (1C-153 & 155), there are no additional production/injection wells located within a 1/4 mile radiurs of the 10-154 penetrations of the Wsak interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1C-154 is good and is classified as a "Single Casing"well. A State- witnessed MIT-IA will be performed once well 1C-154 is converted to water injection, online, and stabilized. The injection tubing/casing annulus is isolated via a Baker Bonded Seal Assembly located at 5464' and (3849' tvd). The 20" Conductor was cemented with 200 cf ArcticCRETE. The 10-3/4" Surface casing was cemented with 460 bbls DeepCrete followed by 61.5 bbls DeepCrete. The 7-5/8" Intermediate casing was cemented with 43.6 bbls Class "G". CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (4961' -5490' and/3739' - 3851' tvd) to insure injection zone conformance. SUpLJN-SC'DkD . __ . • 0 0 /(/� gE i oi §§( ; "i" ; \ §l-: 7 ;n7}i (( ( ! pg ,i§ N 7 F. , , E - ° k� \) )3 ( /( _ ]) ' ( \ \\ ® �§f , ©8 L §`f! | !!k{- 26 =» p! ! _ � u tg ; 4 §§ t% ( a] / �} ` } }3j )E % :9 V , \ i \ ° ; \ \ ®13 � \£ ®t 2 - §! 9. § ( = 2] ) i . - |} §\ \ / /E ti , / 0_ @ ƒ� }� { 2 Z ! , , , )} ;! 3 6 a ii w . $ > t � � '1,1' § - tt ~ r4 I } o ; @ . a) ` jk \ / \ !/ ) - - $ @ ! 'E /\ § ) \ 212 5 - - ) 2 ',3_ zti `41 3-1 | .S.uprgo , SED ) § , | \ , 4 § ,n § \ \ \ /11-- ConocoPhillips Alaska, Inc. 1C-154 10-403 Sundry 14Jan16 ADL047449 ADLO2 38 1 1 tri 1 � 1 � Kuparuk PA ADL025 9 ADL028242 West Sak PA Well Pad — 1C-153 Trajectory SQ RS 1C-154 Trajectory References: 1C-154 Open Section Well Data: ConocoPhillips Alaska Well Database (ATDB) — 1C-155 Trajectory 1/4 Mi. 1C-154 Open Section Radius N I_^West Sak PA Boundary Li Pad Outline 0 0.1 0.2 0.3 0.4 ❑ CPAI Lease Miles KUP PROD • 1C-154 ConoctPhiliips a g0 MaxAngle Attributes ax &MD TD Alaska,Inc. Wellbore API/UW I Field Name Wellbore Status Incl 7) MD(ftKB) Act Blm(ftKB) ,_ y01� 500292355900 WEST SAK PROD 94.57 10,930.02 12,680.0 -. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-154,1/20/20152:35:17 PM SSSV:NIPPLE Last WO: 39.73 11/8/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM Rev Reason:GLV C/O pproven 1120/2016 HANGER;34.7 �i:j Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Tap Thread ! LIM Conductor 20 19.250 42.2 122.2 122.2 78.67 B Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ........................................._...................o... .._o.....Surface 103/4 9.950 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(NOB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Intermediate 7 5/8 6.875 39.4 5,614.0 3,857.8 29.70'L-80 Hydr11563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Liner 41/2 4.000 5,435.0 12,641.0 3,849.8 11.60 L-80 1ST-m Liner Details Nominal ID Conductor;422-122.2 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Cam (in) 1 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP VV/HD's 5W X 7.63",5W 178 4.970 Hydril 563 pin do 5,454.9 3,848.0 84.74 NIPPLE RS Nipple 7.63"L-80 5.5"15.58 HYD 563 Box x box 4.850 GAS LIFT;2,509.4II 5,457.7 3,848.2 84.86 HANGER Baker"DG"Flex-Lock liner hanger 5W X 7.63"51/2 4.840 Hyd 563 pin x pin r ] 5,467.5 3,849.1 85.25 SBE Baker 4.75"ID Seal Bore Extension,5 1/2"Hyd 563 4.750 t .1 Box Pin 5,829.3 3,870.9 86.82 SWELL Baker swell packer,4-1/2"x6.38",920 medium 3.960 PACKER (Water activated)"E"S/N-049169-001-2 Surface;42.2-1636.9-• J l 6,772.7 3,864.4 88.57 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 PACKER (Water activated)"D"S/N-049169-001-1 Xo THREAD;3,685.8Iri 7,038.5 3,876.6 86.18 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.970 GAS LIFT;3,695.2 PACKER (Water activated)"C"S/N-049169-001-9 XO THREAD;3,702.4 10,589.5 3,872.2 89.36 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 F1PACKER (Water activated)"B"S/N-049169-001-8 XGTHREAD'40109 10,853.5 3,867.5 94.13 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 PACKER (Water activated)"A"S/N-049169-001-4 NIPPLE;4,926.7 El Tubing Strings XO THREAD;4,928.5 Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection aTUBING 41/2 3.958 34.7 5,481.6 3,850.2 12.60 L-80 HYD563 • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 34.7 34.7 0.04 HANGER Vetco Off Set Tubing Hanger W/13-3/8"false bowel SN: 3.875 LOCATOR;5,441.3 MI' U00040001-0431-4 I 4,926.7 3,728.3 71.78 NIPPLE CAMCO'DB'Nipple 4W w(3.812"no-go profile w/RHC 3.813 :H i plug SN#10103-3(PULLED CAT STANDING VALVE 12/20/2015) 5,441.3 3,846.7 84.19 LOCATOR Baker mechanical locator Comm N#H450-01-4785 3.860 5,464.2 3,848.8 85.12 SEAL ASSY Baker Bonded Seal assy with full Mule Shoe,Comm N 3.870 SEAL ASSY;5,464.21 E. #H450-01-4785 1) l 1 I Perforations&Slots I shat Den Top(ND) Btm(TVD) (shots/f Top(ftKB) Btrn(ftKB) (MB) (ftKB) Zone Date t) Type Com 5,839.0 6,767.0 3,871.4' 3,864.2' 11/3/2015 SLOTS 4 1/2"OD L-80,11.69, R3,IBTM slotted liner 7,049.0 10,583.0 3,877.3 3,872.2 11/3/2015 SLOTS 2 1/2"x 1/8"slots,8 510)5 0w,4 rows/ft. Intermediate;35.4-5,614.0- 10,863.0 12,631.0 3,866.8 3,849.9 11/3)2015 SLOTS 3'standoff each end, SMLS Mandrel Inserts sr St ati on Top(TVD) Valve Latch Port Size TRO Run - N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/16/2016 SLOTS;5,839.0-6,767.0 2' 3,695.2 3,099.4 CAMCO 'KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/17/2016 - _ Notes:General&Safety End Date Annotation lir NOTE: sir SLOTS;7,049.0-10,583.0 I-I Ifir sir SLOTS;10,863.0-12,631.0 --.� I-i 1 Liner;5,435.0-12,841.0 I • S Loepp, Victoria T (DOA) From: Loepp, Victoria T(DOA) Sent: Friday,January 29, 2016 8:13 AM To: Targac, Gary(Gary.Targac@conocophillips.com) Subject: KRU 1C-154(PTD 215-166, Sundry 316-039) Conversion to WI Draft Sundry Attachments: Wsak Sundry.pdf Gary, Here is the sundry we talked about that needs to be reviewed by the Petroleum Engineer. Please forward to Scott Stanley since I do not have his email. 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.Loepo a(�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov St-JPRSD 1 RECEIVED • STATE OF ALASKA • JAN 20.2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend [ Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r- Alter Casing r Other: PROD to WAG Ii 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: 7 ConocoPhillips Alaska, Inc. • Exploratory r Development F- 215-166-0 ' 3.Address: Stratigraphic J Service I- P.O. Box 100360,Anchorage,Alaska 99510 50-029-2 59-00 7. If perforating, �!Q 8.Well Name a Number: What Regulation or Conservation Order governs well spacing in this pool? lik ��a Will planned perforations require spacing exception? Yes r No Vlr'?) i412...l.1 1C-154 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025649;ADL025638 • Kuparuk River Field/West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY p Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP N. i):\\' 1, Plugs(MD): Junk(MD): 12680 - 3849 ' 12680' - 3849' * , Casing Length Size MD / Burst Collapse CONDUCTOR 80 20 122' \ \ ' SURFACE 2595 18.125 2637' (.-___.i..>'2413' INTERMEDIATE 5575 12.75 5614' ' 3857' LINER 7206 6.58 12641' i'' 3850' cif) Perforation Depth MD(ft): Perforation Depth TVD(ft): Q Tubing Size: Tubing Grade: Tubing MD(ft): Slots 5839-12631 % 3874-3850 / 4.5 L-80 5464 Packers and SSSV Type: Packers and,•S MD(ft)and TVD(ft) SSSV=Nipple MD=4.1y=3728 SEAL ASSY-BAKER BONDED SEAL ASSY WITH FULL MULE SHOE MD=54t. D=3849 12.Attachments: Proposal Summary r„— WellBore Schematic F 13. 1 s after proposed work: Detailed Operations Program r BOP Sketch r 1 76410,atory r Stratigraphic r Development r Service p. - 11 14.Estimated Date for 15. i ell Status after proposed work: Commencing Operations: 01/22/16 ©IL r WINJ E WDL r SPSuspended r 16.Verbal Approval: Date: /GAS r WAG r - GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17. I hereby certify that the foregoing is Contact: Bob Christensen/Darrell Humphrey Printed Name Robert D. Christensen Phone:659-7535 Email: n1139conocophillips.com Title: NSK Production Engineering Specialist / Signature �//11. Date: /� / Commission Use Only o�/ Conditions of approval: Notify Commission so th.t a representative may witness Sundry Number: / Rug Integrity r BOP Test fl'Mechanical Integrity Test r Location Clearance r Other: I i Post Initial Injection MIT Req'd? Yes r No r Spacing Exception Required?/ Yes r No IPIPIK Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: INA Submit Form and Form 10-403 Revised 11/2015 Ai o e i/� o the date months from the date of approval. Attachments in Duplicate • • RECEIVED JAN 20 2016 Robert Christensen/Darrell Humphrey Production Engineering Specialists. IppvAQG CC Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPh i Iii ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 January 18,2015 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 1 C- 154 from Oil Production to Water Alternating Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1C-154 (PTD#215-1660). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, 4Q4ch Robert D. Christensen Attachments Sundry application Area Map Well schematic CBL sup S 1C-154 S DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1C-154 (PTD# 215-1660) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: West Sak well 1C-154 was completed as an injector on 11/7/15 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 1C-153 and 1C- 155. The top of the Ugnu A sand was found at 4600' and /3598' tvd The base of the Ugnu N sand was found at 4961' and /3739' tvd The top of the Wsak D sand was found at 5517' and /3853' tvd Area Map with 1/4 mile radius around target injection zone (see attached): Tha map attached shows that, with the exception of the offset producers (1C-153 & 155), there are no additional production/injection wells located within a 1/4 mile radiurs of the 1C-154 penetrations of the Wsak interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1C-154 is good and is classified as a "Single Casing"well. A State- witnessed MIT-IA will be performed once well 10-154 is converted to water injection, online, and stabilized. The injection tubing/casing annulus is isolated via a Baker Bonded Seal Assembly located at 5464' and (3849' tvd). The 20" Conductor was cemented with 200 cf ArcticCRETE. The 10-3/4" Surface casing was cemented with 460 bbls DeepCrete followed by 61.5 bbls DeepCrete. The 7-5/8" Intermediate casing was cemented with 43.6 bbls Class "G". CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (4961' - 5490' and /3739' - 3851' tvd) to insure injection zone conformance. SuP�s�b • ConocoPhillips Alaska, Inc. 1C-154 --------_—__—__—__—__� 10-403 Sundry 14Jan16 ADL047449 ADL02- 38 Cl I � X> •aruk PA ADL025: 9 ADL028242 West SakP- i * Well Pad — 1C-153 Trajectory ,S — 1C-154 TrajectoryReferences: �p'S 1C-154 Open Section Well Data: ConocoPhillips laska Well DatabaseAB) — 1C-155 Trajectory In 1/4 Mi. 1C-154 Open Section Radius �� N 0 West Sak PA Boundary Pad Outline 0 0.1 0.2 0.3 0.4 ❑ CPAI Lease Miles �. KUP PROD • 1C-154 ConocoPhiilips Well Attributes Max Angle&MD TD Alaska,(no Wellbore APIIUWI Field Name Wellbore Status MD(flKB) Act Blm(ftKB) rronocow++Mpc 500292355900 WEST SAK PROD 94.57 10,930.02 12,680.0 ... Comment N2S(ppm) Date Annotation Entl Date KB-Grd(fl) Rig Release Dale 1C-154,121221201512'.46:47 PM SSSV:NIPPLE Last WO: 39.73 11/8/2015 Vertical schematic(061001) Annotation Depth(ftKe) End Dat¢ Annotation Last Mod ey Entl Date Last Tag: Rev Reason:ADD SLOTS lehallf 12/22/2015 HANGER;347- '," Casing Strings Cooin Descri tion OD ID in To ftKB Set Depth kKB Set De th TVD... WALen I...Grade To Thread Conductor 20 19.250 42.2 122.2 122.2 78.67 B Welded Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread _...._....___._..........._..._.................... - _ .....v....Surface 10 3/4 9.950 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...WVLen(I...Grade 'Top Threatl Intermediate 75/8 6.875 39.4 5,614.0 3,857.8 29.70 L-80 Hydril563 Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread Liner 41/2 4.000 5,435.0 12,641.0 3,849.8 11.60 L-80 IBT-m >n, v Liner Details Nominal ID Conductor;42.2-122.2 Top(kKB) Top(TVD)(11KB) Top Incl(°) Item Des Com (in) 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP W/HD's 51/2"X 7.63",514"17# 4.970 Hydril 563 pin do 5,454.9 3,848.0 84.74 NIPPLE RS Nipple 7.63"L-80 5.5"15.58 HYD 563 Box x box 4.850 GAS LIFT;2,509.4 5,457.7 3,848.2 84.86 HANGER Baker"DG"Flex-Lock liner hanger 514"X 7.63"51/2 4.840 Hyd 563 pin x pin I Ht 1 5,467.5 3,849.1 85.25 SBE Baker4.75"ID Seal Bore Extension,5 1/2"Hyd 563 4.750 J Box x Pin 5,829.3 3,870.9 86.82 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.960 Surface;42.2-2,636.9-- PACKER (Water activated)"E"S/N-049169-001-2 6,772.7 3,864.4 88.57 SWELL Baker swell packer,4-112"x 6.38",920 medium 3.980 PACKER (Water activated)"D"S/N-049169-001-1 XO THREAD;3,685 7,038.5 3,876.6 86.18 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.970 GAS LIFT;3,695.2 PACKER (Water activated)"C"S/N-049169-001-9 00 THREAD;3,702.4 10,589.5 3,872.2 89.36 SWELL Baker swell packer,4-1/2"x6.38",920 medium 3.980 PACKER (Water activated)"B"S/N-049169-001-8 10,853.5 3,867.5 94.13 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 00 THREAD;4,916.9 PACKER (Water activated)"A"S/N-049169-001-4 NIPPLE,4,920.7 11�.Strings XO THREAD;4,928.5 - - Tubing Description String Me,,,ID(in) Top(kKB) Set Depth(k..Set Depth(TVD)I...Wt(Ibkl) Grade Top Connection TUBING 41/2 3.958 34.7 5,481.6 3,850.2 12.60 L-80 HYD563 omption Details Nominal ID Top(kKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 34.7 34.7 0.04 HANGER Vetco Off Set Tubing Hanger W/13-3/8"false bowel SN: 3.875 LOCATOR;5 441 3 IJ00040991-0431-4 4,926.7 3,728.3 71.78 NIPPLE CAMCO'DB'Nipple 414"w)3.812"no-go profile w/RHC 3.813 plug SN#10103-3(PULLED CAT STANDING VALVE 12/20/2015) r 5,441.3 3,846.7 84.19 LOCATOR Baker mechanical locator Comm N#H450-01-4785 3.860 III 5,464.2 3,848.8 85.12 SEAL ASSY Baker Bonded Seal assy with full Mule Shoe,Comm N 3.870 SEAL ASSY;5,464.2 )s #H450-01-4785 i 1 I Perforations&Slots shot i Dens Top(TVD) Bim(TVD) (sholsk Top(kKB) Btm(kKB) (kKB) (kKB) Zone Date t) Type Corn 5,839.0 6,767.0 3,871.4 3,864.2 11/3/2015 SLOTS 4 1/2"OD L-80,11.68, R3,IBTM slotted liner 7,049.0 10,583.0 3,877.3 3,872.2 11/3/2015 SLOTS 2 1/2"x 1/8"slots,8 1 slots/row,4 rows/k. Intermediate;39.4-5,614.0 + 10,863.0 12,631.0 3,866.8 3,849.9 11/3/2015 SLOTS 3'standoff each end, SMLS Mandrel Inserts Tir st au on Top(TVD) Valve Latch Part Size TRO Run N Top(kKB) (kKB) Make Medol OD(in) Seen Type Typo (in) (psi) Run Date Com 1 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,288.0 12/19/2015 SLOTS;5,839.0-6,767.0 2 3,695.2 3,099.4 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 12/19/2015 Notes:General&Safety QEnd Date Annotation NOTE: SLOTS;7049 0-106810 _i SUAs. 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I tfitxtP7 ' Li ,ii,i-,,wie; ----t---, i 1 ;1:,;,,11:144,0 - , -,. 11„1„.„.,:, .. „,,, , ,.. ,,;-......, -, .. . . - il ,,„ A ,- = i A = 'iti'li'.1': Ill ''' 1 1 t;titi 1 0917g ..t....-Ai, ?, 1 1 1 1 it'll;liT .i -‘1 I. 1 1 1 , '41.i.r.;;I:(4) i)3 *1 A , :,--i:1 i- ,, . . , , ...1 '. , !Al 4- .f ' 1 ! 111 r, -I- ' , . 11 , , --1-- 1 T r , I , . I [ . - I 11( '‘.° '• OOPS 4. . i D I : , 1 ' 4 . 1 . , ; r . . . . - "--- , . . . i.. [ ' 1 ' „_ k' Ii' I ' ' . .= i •. , ' I, 1:• 1„ l'-lili ' .. 1 , 1 „ „ ' , ,. - 1 lSES 0 1. - ,,1143:1,ii;,,i 11:1 ! illflifi , Si)- .:.-,,,T1;,„ , ,,,._. .., • , „ 1, i • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday,January 20, 2016 3:16 PM To: NSK Prod Engr Specialist (n1139@conocophillips.com) Subject: KRU 1C-154(PTD 215-166, Sundry 316-039)Conversion to WI Bob, We are now requiring the completion of an AOR spreadsheet for injection conversions. I have attached a sample spreadsheet for you to use. The spreadsheet should include all wells in the AOR including the well that is to be converted. You may email it to me when it is completed. 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.Loepoaa laska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 Y-WCIPSW/U-n— Schlumberger ` Transmittal#: 17DEC15-SPO2 Drilling & Measurements �J�C ' � �I r MWD/LWD Log Product Delivery J l `� Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-154 "REVISION-1** Date Dispatched: 17-Dec-15 Job#: 15AKA0102 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A TVD MD TVD LAS Digital Data N/A Contents on CD N/A Directional Data 1 Contents on CD N/A Nad27 —REVISION-1" x x As-Built Survey N/A Contents on CD N/A Nad83 CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff _ x Surveys:pdf,txt **REV-1** x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elciarico(a�conocophillips.com ntCenter(a�slb.com Ricky Elgarico R EC Pacillo 1 .5-6580 JAN 2 0 2016 Received By: -A �r AOGCC S2 - Loll? 2Ca4(oI REVISED 12:47 pm, Dec 16, 2015 NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-154 Definitive Survey Report 25 November, 2015 NAD 27 Schlumberger IP S . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 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 1C-154 Well Position +N/-S 0.00 usft Northing: 5,968,757.31 usfl Latitude: 70°19'30.612 N +E/-W 0.00 usft Easting: 562,168.40 usfl Longitude: 149°29'45.181 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 57.60 usft Wellbore 1C-154 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 10/15/2015 18.92 80.99 57,505 Design 1C-154 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.73 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.73 0.00 0.00 345.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 86.95 1,296.61 1C-154 Srvy#1 -GWD(1C-154) GYD-GC-SS Gyrodata gyro single shots 10/23/2015 2:1 1,355.32 2,562.37 1C-154 Srvy#2-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8: 2,661.47 12,619.22 1C-154 Srvy#3-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.73 0.00 0.00 39.73 -57.60 0.00 0.00 5,968,757.31 562,168.40 0.00 0.00 UNDEFINED 86.95 0.07 102.10 86.95 -10.38 -0.01 0.03 5,968,757.31 562,168.43 0.15 -0.01 GYD-GC-SS(1) 122.20 0.11 61.68 122.20 24.87 0.01 0.08 5,968,757.32 562,168.48 0.21 -0.02 0 NOT an Actual Survey 20"x 42" 160.11 0.18 45.94 160.11 62.78 0.06 0.15 5,968,757.38 562,168.56 0.21 0.02 GYD-GC-SS(1) 206.24 1.56 49.19 206.23 108.90 0.53 0.68 5,968,757.84 562,169.08 2.99 0.33 GYD-GC-SS(1) 262.56 2.85 45.04 262.51 165.18 2.02 2.25 5,968,759.35 562,170.64 2.31 1.36 GYD-GC-SS(1) 358.25 5.81 37.39 357.92 260.59 7.55 6.88 5,968,764.91 562,175.22 3.14 5.51 GYD-GC-SS(1) 451.26 10.02 38.96 450.02 352.69 17.58 14.83 5,968,775.02 562,183.08 4.53 13.15 GYD-GC-SS(1) 506.54 11.51 39.23 504.33 407.00 25.60 21.34 5,968,783.08 562,189.53 2.70 19.20 GYD-GC-SS(1) 543.66 12.36 39.08 540.64 443.31 31.55 26.19 5,968,789.07 562,194.32 2.29 23.70 GYD-GC-SS(1) 635.92 13.19 35.63 630.62 533.29 47.77 38.54 5,968,805.39 562,206.55 1.22 36.17 GYD-GC-SS(1) 11/25/2015 8:45:27AM Page 2 COMPASS 5000.1 Build 74 Schlumberger IP S . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 0 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 728.05 12.36 43.19 720.48 623.15 63.50 51.42 5,968,821.23 562,219.29 2.02 48.03 GYD-GC-SS(1) 822.11 12.26 49.10 812.38 715.05 77.38 65.86 5,968,835.23 562,233.61 1.34 57.70 GYD-GC-SS(1) 914.71 13.18 49.30 902.70 805.37 90.70 81.29 5,968,848.68 562,248.93 0.99 66.57 GYD-GC-SS(1) 1,011.51 12.95 51.28 997.00 899.67 104.68 98.12 5,968,862.80 562,265.64 0.52 75.72 GYD-GC-SS(1) 1,105.83 11.53 57.57 1,089.18 991.85 116.35 114.32 5,968,874.60 562,281.75 2.06 82.80 GYD-GC-SS(1) 1,201.06 13.64 58.48 1,182.11 1,084.78 127.33 131.93 5,968,885.72 562,299.26 2.23 88.84 GYD-GC-SS(1) 1,296.61 14.24 60.97 1,274.85 1,177.52 138.92 151.81 5,968,897.47 562,319.04 0.89 94.89 GYD-GC-SS(1) 1,355.32 15.88 61.83 1,331.54 1,234.21 146.22 165.21 5,968,904.88 562,332.38 2.82 98.48 MWD+IFR-AK-CAZ-SC(2) 1,449.60 18.73 62.77 1,421.54 1,324.21 159.23 190.04 5,968,918.10 562,357.10 3.04 104.62 MWD+IFR-AK-CAZ-SC(2) 1,544.23 18.75 61.78 1,511.16 1,413.83 173.38 216.95 5,968,932.46 562,383.89 0.34 111.32 MWD+IFR-AK-CAZ-SC(2) 1,638.81 21.13 62.50 1,600.06 1,502.73 188.44 245.47 5,968,947.76 562,412.28 2.53 118.49 MWD+IFR-AK-CAZ-SC(2) 1,733.27 23.94 64.15 1,687.30 1,589.97 204.66 277.83 5,968,964.25 562,444.50 3.05 125.78 MWD+IFR-AK-CAZ-SC(2) 1,828.83 26.49 65.57 1,773.75 1,676.42 221.93 314.69 5,968,981.82 562,481.21 2.74 132.92 MWD+IFR-AK-CAZ-SC(2) 1,922.58 30.35 62.93 1,856.19 1,758.86 241.37 354.83 5,969,001.59 562,521.19 4.33 141.30 MWD+IFR-AK-CAZ-SC(2) 2,017.51 32.94 61.53 1,937.00 1,839.67 264.59 398.88 5,969,025.17 562,565.04 2.84 152.33 MWD+IFR-AK-CAZ-SC(2) 2,113.33 33.26 61.90 2,017.27 1,919.94 289.38 444.96 5,969,050.34 562,610.91 0.39 164.36 MWD+IFR-AK-CAZ-SC(2) 2,208.09 34.69 61.84 2,095.85 1,998.52 314.35 491.66 5,969,075.69 562,657.39 1.51 176.39 MWD+IFR-AK-CAZ-SC(2) 2,302.52 40.92 62.61 2,170.42 2,073.09 341.29 542.86 5,969,103.05 562,708.37 6.62 189.15 MWD+IFR-AK-CAZ-SC(2) 2,396.14 42.31 61.59 2,240.41 2,143.08 370.38 597.80 5,969,132.60 562,763.06 1.65 203.04 MWD+IFR-AK-CAZ-SC(2) 2,492.78 42.58 59.82 2,311.73 2,214.40 402.30 654.68 5,969,164.98 562,819.66 1.27 219.15 MWD+IFR-AK-CAZ-SC(2) 2,562.37 45.53 58.66 2,361.74 2,264.41 427.05 696.25 5,969,190.08 562,861.02 4.39 232.30 MWD+IFR-AK-CAZ-SC(2) 2,636.90 48.14 57.89 2,412.72 2,315.39 455.64 742.48 5,969,219.04 562,907.01 3.58 247.95 NOT an Actual Survey (3) 10 3/4"x 13-1/2 2,661.47 49.00 57.65 2,428.98 2,331.65 465.47 758.06 5,969,229.00 562,922.51 3.58 253.41 MWD+IFR-AK-CAZ-SC(3) 2,756.23 49.43 60.12 2,490.88 2,393.55 502.53 819.48 5,969,266.57 562,983.61 2.03 273.31 MWD+IFR-AK-CAZ-SC(3) 2,851.73 49.53 61.70 2,552.93 2,455.60 537.83 882.91 5,969,302.38 563,046.75 1.26 290.98 MWD+IFR-AK-CAZ-SC(3) 2,946.62 48.36 60.35 2,615.25 2,517.92 572.48 945.51 5,969,337.55 563,109.05 1.63 308.26 MWD+IFR-AK-CAZ-SC(3) 3,040.99 48.13 63.02 2,678.11 2,580.78 605.87 1,007.48 5,969,371.45 563,170.73 2.12 324.47 MWD+IFR-AK-CAZ-SC(3) 3,135.79 48.13 62.91 2,741.38 2,644.05 637.96 1,070.36 5,969,404.05 563,233.34 0.09 339.19 MWD+IFR-AK-CAZ-SC(3) 3,231.09 48.10 64.81 2,805.01 2,707.68 669.21 1,134.04 5,969,435.83 563,296.76 1.48 352.90 MWD+IFR-AK-CAZ-SC(3) 3,326.04 48.29 65.69 2,868.30 2,770.97 698.84 1,198.32 5,969,465.99 563,360.78 0.72 364.88 MWD+IFR-AK-CAZ-SC(3) 3,420.19 49.69 61.54 2,930.10 2,832.77 730.43 1,261.92 5,969,498.10 563,424.11 3.64 378.93 MWD+IFR-AK-CAZ-SC(3) 3,513.67 51.45 57.56 2,989.48 2,892.15 767.03 1,324.13 5,969,535.21 563,486.00 3.79 398.18 MWD+IFR-AK-CAZ-SC(3) 3,609.56 52.75 55.50 3,048.39 2,951.06 808.76 1,387.23 5,969,577.46 563,548.75 2.17 422.16 MWD+IFR-AK-CAZ-SC(3) 3,704.09 54.26 52.01 3,104.62 3,007.29 853.70 1,448.49 5,969,622.90 563,609.63 3.37 449.71 MWD+IFR-AK-CAZ-SC(3) 3,799.51 54.86 47.64 3,159.97 3,062.64 903.84 1,507.86 5,969,673.53 563,668.58 3.78 482.78 MWD+IFR-AK-CAZ-SC(3) 3,894.09 54.87 42.06 3,214.43 3,117.10 958.64 1,562.37 5,969,728.77 563,722.63 4.82 521.60 MWD+IFR-AK-CAZ-SC(3) 3,988.94 55.15 36.65 3,268.84 3,171.51 1,018.69 1,611.61 5,969,789.22 563,771.36 4.68 566.87 MWD+IFR-AK-CAZ-SC(3) 4,083.41 55.57 31.57 3,322.57 3,225.24 1,083.02 1,655.17 5,969,853.90 563,814.38 4.45 617.72 MWD+IFR-AK-CAZ-SC(3) 4,177.80 55.87 28.85 3,375.74 3,278.41 1,150.41 1,694.40 5,969,921.61 563,853.05 2.40 672.66 MWD+IFR-AK-CAZ-SC(3) 11/25/2015 8:45:27AM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,272.48 56.77 25.87 3,428.25 3,330.92 1,220.37 1,730.60 5,969,991.86 563,888.66 2.79 730.88 MWD+IFR-AK-CAZ-SC(3) 4,368.03 58.12 20.96 3,479.69 3,382.36 1,294.25 1,762.56 5,970,066.00 563,920.01 4.56 793.97 MWD+IFR-AK-CAZ-SC(3) 4,462.89 58.96 15.31 3,529.22 3,431.89 1,371.10 1,787.71 5,970,143.05 563,944.52 5.16 861.69 MWD+IFR-AK-CAZ-SC(3) 4,557.64 59.76 12.99 3,577.52 3,480.19 1,450.15 1,807.63 5,970,222.24 563,963.79 2.27 932.88 MWD+IFR-AK-CAZ-SC(3) 4,652.34 62.85 8.87 3,623.00 3,525.67 1,531.68 1,823.33 5,970,303.90 563,978.81 5.02 1,007.58 MWD+IFR-AK-CAZ-SC(3) 4,747.03 65.86 5.71 3,663.98 3,566.65 1,616.33 1,834.13 5,970,388.63 563,988.91 4.38 1,086.55 MWD+IFR-AK-CAZ-SC(3) 4,841.67 69.38 1.76 3,700.02 3,602.69 1,703.62 1,839.79 5,970,475.96 563,993.84 5.36 1,169.40 MWD+IFR-AK-CAZ-SC(3) 4,937.34 72.08 357.42 3,731.60 3,634.27 1,793.90 1,839.12 5,970,566.21 563,992.42 5.13 1,256.77 MWD+IFR-AK-CAZ-SC(3) 5,031.94 73.84 353.62 3,759.33 3,662.00 1,884.04 1,832.04 5,970,656.29 563,984.60 4.27 1,345.68 MWD+IFR-AK-CAZ-SC(3) 5,126.45 74.94 351.03 3,784.77 3,687.44 1,974.24 1,819.88 5,970,746.37 563,971.69 2.88 1,435.95 MWD+IFR-AK-CAZ-SC(3) 5,221.78 76.23 348.45 3,808.50 3,711.17 2,065.08 1,803.43 5,970,837.07 563,954.49 2.95 1,527.95 MWD+IFR-AK-CAZ-SC(3) 5,316.17 79.21 348.34 3,828.58 3,731.25 2,155.42 1,784.88 5,970,927.24 563,935.19 3.16 1,620.01 MWD+IFR-AK-CAZ-SC(3) 5,411.08 82.97 346.95 3,843.28 3,745.95 2,246.99 1,764.82 5,971,018.63 563,914.37 4.22 1,713.66 MWD+IFR-AK-CAZ-SC(3) 5,505.72 86.80 345.26 3,851.71 3,754.38 2,338.47 1,742.18 5,971,109.91 563,890.98 4.42 1,807.88 MWD+IFR-AK-CAZ-SC(3) 5,559.45 86.86 345.65 3,854.68 3,757.35 2,390.40 1,728.71 5,971,161.72 563,877.08 0.73 1,861.53 MWD+IFR-AK-CAZ-SC(3) 5,614.00 86.65 345.32 3,857.77 3,760.44 2,443.13 1,715.06 5,971,214.33 563,863.00 0.70 1,915.99 NOT an Actual Survey 7-5/8"x 9-7/8" 5,655.00 86.50 345.08 3,860.22 3,762.89 2,482.70 1,704.61 5,971,253.81 563,852.22 0.70 1,956.92 MWD+IFR-AK-CAZ-SC(3) 5,710.88 86.46 343.89 3,863.65 3,766.32 2,536.44 1,689.69 5,971,307.42 563,836.86 2.13 2,012.69 MWD+IFR-AK-CAZ-SC(3) 5,806.50 86.45 343.04 3,869.56 3,772.23 2,627.93 1,662.53 5,971,398.67 563,808.94 0.89 2,108.09 MWD+IFR-AK-CAZ-SC(3) 5,855.89 87.25 341.35 3,872.28 3,774.95 2,674.88 1,647.45 5,971,445.49 563,793.47 3.78 2,157.34 MWD+IFR-AK-CAZ-SC(3) 5,901.05 87.90 338.25 3,874.19 3,776.86 2,717.22 1,631.87 5,971,487.69 563,777.55 7.01 2,202.27 MWD+IFR-AK-CAZ-SC(3) 5,946.09 89.00 337.00 3,875.41 3,778.08 2,758.85 1,614.73 5,971,529.18 563,760.07 3.70 2,246.92 MWD+IFR-AK-CAZ-SC(3) 5,995.85 89.93 334.09 3,875.87 3,778.54 2,804.14 1,594.13 5,971,574.29 563,739.10 6.14 2,296.00 MWD+IFR-AK-CAZ-SC(3) 6,090.97 91.27 331.06 3,874.87 3,777.54 2,888.55 1,550.33 5,971,658.33 563,694.60 3.48 2,388.87 MWD+IFR-AK-CAZ-SC(3) 6,185.34 92.76 329.66 3,871.56 3,774.23 2,970.52 1,503.69 5,971,739.90 563,647.29 2.17 2,480.12 MWD+IFR-AK-CAZ-SC(3) 6,281.15 92.05 333.57 3,867.53 3,770.20 3,054.72 1,458.20 5,971,823.71 563,601.10 4.14 2,573.22 MWD+IFR-AK-CAZ-SC(3) 6,376.67 91.33 337.97 3,864.71 3,767.38 3,141.76 1,419.02 5,971,910.42 563,561.21 4.67 2,667.44 MWD+IFR-AK-CAZ-SC(3) 6,469.98 91.47 338.26 3,862.44 3,765.11 3,228.32 1,384.25 5,971,996.68 563,525.73 0.35 2,760.05 MWD+IFR-AK-CAZ-SC(3) 6,564.35 90.37 338.81 3,860.92 3,763.59 3,316.14 1,349.72 5,972,084.20 563,490.48 1.30 2,853.81 MWD+IFR-AK-CAZ-SC(3) 6,659.89 88.58 340.48 3,861.80 3,764.47 3,405.70 1,316.49 5,972,173.47 563,456.51 2.56 2,948.92 MWD+IFR-AK-CAZ-SC(3) 6,754.22 88.80 341.40 3,863.95 3,766.62 3,494.83 1,285.70 5,972,262.34 563,424.98 1.00 3,042.99 MWD+IFR-AK-CAZ-SC(3) 6,849.07 87.60 343.81 3,866.93 3,769.60 3,585.29 1,257.36 5,972,352.55 563,395.90 2.84 3,137.70 MWD+IFR-AK-CAZ-SC(3) 6,944.61 87.25 345.50 3,871.22 3,773.89 3,677.33 1,232.10 5,972,444.37 563,369.88 1.80 3,233.14 MWD+IFR-AK-CAZ-SC(3) 7,039.46 86.17 344.00 3,876.67 3,779.34 3,768.68 1,207.20 5,972,535.51 563,344.22 1.95 3,327.82 MWD+IFR-AK-CAZ-SC(3) 7,134.55 87.27 342.35 3,882.11 3,784.78 3,859.55 1,179.72 5,972,626.13 563,315.99 2.08 3,422.71 MWD+IFR-AK-CAZ-SC(3) 7,228.56 90.18 339.80 3,884.20 3,786.87 3,948.44 1,149.24 5,972,714.76 563,284.78 4.12 3,516.45 MWD+IFR-AK-CAZ-SC(3) 7,322.88 90.99 341.38 3,883.24 3,785.91 4,037.39 1,117.90 5,972,803.44 563,252.71 1.88 3,610.49 MW D+I FR-AK-CAZ-SC(3) 7,417.58 91.33 344.96 3,881.32 3,783.99 4,128.00 1,090.49 5,972,893.81 563,224.55 3.80 3,705.10 MWD+IFR-AK-CAZ-SC(3) 7,512.75 91.78 346.10 3,878.74 3,781.41 4,220.12 1,066.72 5,972,985.72 563,200.02 1.29 3,800.23 MWD+IFR-AK-CAZ-SC(3) 7,606.78 92.78 343.21 3,875.00 3,777.67 4,310.71 1,041.86 5,973,076.09 563,174.41 3.25 3,894.17 MWD+IFR-AK-CAZ-SC(3) 11/25/2015 8:45:27AM Page 4 COMPASS 5000.1 Build 74 1111 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,702.30 93.59 343.29 3,869.69 3,772.36 4,402.04 1,014.37 5,973,167.18 563,146.18 0.85 3,989.50 MWD+IFR-AK-CAZ-SC(3) 7,795.97 91.06 341.12 3,865.89 3,768.56 4,491.14 985.77 5,973,256.03 563,116.84 3.56 4,082.97 MWD+IFR-AK-CAZ-SC(3) 7,890.81 88.57 339.72 3,866.19 3,768.86 4,580.48 953.99 5,973,345.10 563,084.32 3.01 4,177.50 MWD+IFR-AK-CAZ-SC(3) 7,985.07 89.14 341.82 3,868.08 3,770.75 4,669.46 922.96 5,973,433.81 563,052.55 2.31 4,271.48 MWD+IFR-AK-CAZ-SC(3) 8,080.86 90.00 342.15 3,868.80 3,771.47 4,760.55 893.33 5,973,524.65 563,022.18 0.96 4,367.13 MWD+IFR-AK-CAZ-SC(3) 8,175.44 90.13 344.90 3,868.69 3,771.36 4,851.24 866.51 5,973,615.10 562,994.61 2.91 4,461.67 MWD+IFR-AK-CAZ-SC(3) 8,270.97 89.19 347.77 3,869.26 3,771.93 4,944.05 843.95 5,973,707.72 562,971.28 3.16 4,557.16 MWD+IFR-AK-CAZ-SC(3) 8,365.24 90.17 346.73 3,869.78 3,772.45 5,036.00 823.14 5,973,799.47 562,949.72 1.52 4,651.35 MWD+IFR-AK-CAZ-SC(3) 8,460.17 91.48 347.29 3,868.42 3,771.09 5,128.48 801.81 5,973,891.77 562,927.62 1.50 4,746.21 MWD+IFR-AK-CAZ-SC(3) 8,509.33 89.57 345.09 3,867.97 3,770.64 5,176.22 790.07 5,973,939.40 562,915.49 5.93 4,795.36 MWD+IFR-AK-CAZ-SC(3) 8,555.56 88.87 343.03 3,868.60 3,771.27 5,220.66 777.38 5,973,983.74 562,902.43 4.71 4,841.57 MWD+IFR-AK-CAZ-SC(3) 8,599.91 88.09 339.61 3,869.77 3,772.44 5,262.65 763.18 5,974,025.60 562,887.89 7.91 4,885.81 MWD+IFR-AK-CAZ-SC(3) 8,651.08 88.39 338.15 3,871.34 3,774.01 5,310.36 744.75 5,974,073.16 562,869.07 2.91 4,936.66 MWD+IFR-AK-CAZ-SC(3) 8,695.84 88.10 339.57 3,872.71 3,775.38 5,352.09 728.62 5,974,114.74 562,852.59 3.24 4,981.14 MWD+IFR-AK-CAZ-SC(3) 8,746.37 88.69 342.16 3,874.13 3,776.80 5,399.81 712.06 5,974,162.31 562,835.64 5.25 5,031.52 MWD+IFR-AK-CAZ-SC(3) 8,794.67 89.35 344.00 3,874.96 3,777.63 5,446.01 698.01 5,974,208.39 562,821.20 4.05 5,079.78 MWD+IFR-AK-CAZ-SC(3) 8,840.62 90.37 346.77 3,875.07 3,777.74 5,490.46 686.42 5,974,252.75 562,809.24 6.42 5,125.72 MWD+IFR-AK-CAZ-SC(3) 8,884.48 90.68 348.16 3,874.67 3,777.34 5,533.28 676.90 5,974,295.48 562,799.37 3.25 5,169.54 MWD+IFR-AK-CAZ-SC(3) 8,930.14 90.65 350.40 3,874.14 3,776.81 5,578.13 668.41 5,974,340.26 562,790.51 4.91 5,215.07 MWD+IFR-AK-CAZ-SC(3) 9,027.84 90.82 350.99 3,872.88 3,775.55 5,674.54 652.61 5,974,436.52 562,773.92 0.63 5,312.28 MWD+IFR-AK-CAZ-SC(3) 9,124.10 90.17 350.24 3,872.05 3,774.72 5,769.51 636.91 5,974,531.34 562,757.44 1.03 5,408.07 MWD+IFR-AK-CAZ-SC(3) 9,219.27 90.20 348.32 3,871.74 3,774.41 5,863.01 619.21 5,974,624.69 562,738.96 2.02 5,502.97 MWD+IFR-AK-CAZ-SC(3) 9,314.50 90.24 345.96 3,871.38 3,774.05 5,955.84 598.02 5,974,717.34 562,717.00 2.48 5,598.13 MWD+IFR-AK-CAZ-SC(3) 9,410.83 90.37 344.44 3,870.87 3,773.54 6,048.97 573.41 5,974,810.25 562,691.63 1.58 5,694.45 MWD+IFR-AK-CAZ-SC(3) 9,505.99 89.30 342.91 3,871.14 3,773.81 6,140.29 546.67 5,974,901.34 562,664.13 1.96 5,789.58 MWD+IFR-AK-CAZ-SC(3) 9,600.93 89.72 342.16 3,871.95 3,774.62 6,230.85 518.17 5,974,991.65 562,634.89 0.91 5,884.43 MWD+IFR-AK-CAZ-SC(3) 9,696.23 90.48 344.05 3,871.79 3,774.46 6,322.03 490.48 5,975,082.59 562,606.44 2.14 5,979.67 MWD+IFR-AK-CAZ-SC(3) 9,790.90 89.96 345.47 3,871.42 3,774.09 6,413.37 465.59 5,975,173.71 562,580.81 1.60 6,074.34 MWD+IFR-AK-CAZ-SC(3) 9,886.01 89.34 346.00 3,872.00 3,774.67 6,505.55 442.16 5,975,265.68 562,556.61 0.86 6,169.44 MWD+IFR-AK-CAZ-SC(3) 9,980.28 90.17 346.28 3,872.41 3,775.08 6,597.07 419.58 5,975,357.00 562,533.27 0.93 6,263.69 MWD+IFR-AK-CAZ-SC(3) 10,073.93 91.00 348.55 3,871.45 3,774.12 6,688.46 399.17 5,975,448.21 562,512.12 2.58 6,357.24 MWD+IFR-AK-CAZ-SC(3) 10,171.36 89.86 347.45 3,870.72 3,773.39 6,783.75 378.92 5,975,543.32 562,491.07 1.63 6,454.53 MWD+IFR-AK-CAZ-SC(3) 10,266.80 90.03 346.04 3,870.81 3,773.48 6,876.65 357.04 5,975,636.02 562,468.42 1.49 6,549.92 MWD+IFR-AK-CAZ-SC(3) 10,361.88 90.44 345.94 3,870.42 3,773.09 6,968.90 334.02 5,975,728.07 562,444.65 0.44 6,644.99 MWD+IFR-AK-CAZ-SC(3) 10,456.80 89.52 343.11 3,870.45 3,773.12 7,060.37 308.70 5,975,819.32 562,418.57 3.14 6,739.90 MWD+IFR-AK-CAZ-SC(3) 10,551.76 88.99 344.35 3,871.69 3,774.36 7,151.52 282.09 5,975,910.23 562,391.21 1.42 6,834.82 MWD+IFR-AK-CAZ-SC(3) 10,647.01 89.93 346.94 3,872.59 3,775.26 7,243.78 258.48 5,976,002.29 562,366.84 2.89 6,930.05 MWD+IFR-AK-CAZ-SC(3) 10,741.22 90.38 346.30 3,872.33 3,775.00 7,335.43 236.68 5,976,093.75 562,344.28 0.83 7,024.22 MWD+IFR-AK-CAZ-SC(3) 10,836.68 94.03 345.23 3,868.66 3,771.33 7,427.87 213.23 5,976,185.99 562,320.07 3.98 7,119.59 MWD+IFR-AK-CAZ-SC(3) 10,930.03 94.57 346.11 3,861.66 3,764.33 7,518.06 190.19 5,976,275.97 562,296.29 1.10 7,212.67 MWD+IFR-AK-CAZ-SC(3) 11/25/2015 8..45:27AM Page 5 COMPASS 5000.1 Build 74 Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,026.85 93.43 346.95 3,854.91 3,757.58 7,611.99 167.69 5,976,369.70 562,273.01 1.46 7,309.21 MWD+IFR-AK-CAZ-SC(3) 11,122.36 91.12 347.32 3,851.11 3,753.78 7,705.02 146.45 5,976,462.55 562,251.00 2.45 7,404.58 MWD+IFR-AK-CAZ-SC(3) 11,217.63 90.72 345.69 3,849.59 3,752.26 7,797.65 124.22 5,976,554.97 562,228.01 1.76 7,499.80 MWD+IFR-AK-CAZ-SC(3) 11,312.44 91.30 344.61 3,847.91 3,750.58 7,889.27 99.92 5,976,646.39 562,202.96 1.29 7,594.59 MWD+IFR-AK-CAZ-SC(3) 11,407.14 91.06 344.37 3,845.96 3,748.63 7,980.50 74.61 5,976,737.40 562,176.89 0.36 7,689.27 MWD+IFR-AK-CAZ-SC(3) 11,502.69 90.91 344.51 3,844.32 3,746.99 8,072.54 48.98 5,976,829.21 562,150.50 0.21 7,784.80 MWD+IFR-AK-CAZ-SC(3) 11,597.35 87.98 340.09 3,845.24 3,747.91 8,162.68 20.21 5,976,919.10 562,120.99 5.60 7,879.31 MWD+IFR-AK-CAZ-SC(3) 11,691.83 88.49 342.02 3,848.15 3,750.82 8,252.00 -10.45 5,977,008.15 562,089.60 2.11 7,973.52 MWD+IFR-AK-CAZ-SC(3) 11,786.05 88.97 344.43 3,850.24 3,752.91 8,342.18 -37.63 5,977,098.09 562,061.67 2.61 8,067.67 MWD+IFR-AK-CAZ-SC(3) 11,878.44 89.48 346.02 3,851.49 3,754.16 8,431.50 -61.19 5,977,187.21 562,037.37 1.81 8,160.04 MWD+IFR-AK-CAZ-SC(3) 11,971.67 90.10 347.44 3,851.83 3,754.50 8,522.24 -82.59 5,977,277.76 562,015.22 1.66 8,253.23 MWD+IFR-AK-CAZ-SC(3) 12,064.22 90.61 348.40 3,851.26 3,753.93 8,612.74 -101.96 5,977,368.09 561,995.11 1.17 8,345.65 MWD+IFR-AK-CAZ-SC(3) 12,155.62 91.59 348.54 3,849.50 3,752.17 8,702.28 -120.22 5,977,457.46 561,976.10 1.08 8,436.87 MWD+IFR-AK-CAZ-SC(3) 12,247.88 90.51 349.78 3,847.81 3,750.48 8,792.87 -137.57 5,977,547.90 561,958.01 1.78 8,528.87 MWD+IFR-AK-CAZ-SC(3) 12,340.10 88.39 347.50 3,848.70 3,751.37 8,883.27 -155.73 5,977,638.14 561,939.10 3.38 8,620.88 MWD+IFR-AK-CAZ-SC(3) 12,433.30 89.45 346.55 3,850.45 3,753.12 8,974.07 -176.65 5,977,728.75 561,917.43 1.53 8,714.01 MWD+IFR-AK-CAZ-SC(3) 12,525.84 90.24 346.34 3,850.70 3,753.37 9,064.03 -198.34 5,977,818.52 561,895.00 0.88 8,806.52 MWD+IFR-AK-CAZ-SC(3) 12,619.22 90.58 346.60 3,850.03 3,752.70 9,154.82 -220.19 5,977,909.12 561,872.40 0.46 8,899.86 MWD+IFR-AK-CAZ-SC(3) 12,680.00 90.58 346.60 3,849.42 3,752.09 9,213.94 -234.27 5,977,968.11 561,857.83 0.00 8,960.62 PROJECTED to TD NOT an ActualSurvy Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. E] Yes ❑ No 1 have checked to the best of my ability that the following data is correct: [I Surface Coordinates [J Declination & Convergence GRS Survey Corrections p Survey Tool Codes Vincent ptfnFT signed IN Wart than CtI, Cam, xfilndw+w.. a- SLB DE: Osara wwr...cmnrstb.l°r,c.ua Dais.]D9L110.1.1a55 DM Dgt:a0 sywder eau.Ha < Client Representative: Kelsey Hallford P `D-, Date: 04-Nov-2015 11/25/2015 8:45:27AM Page 6 COMPASS 5000.1 Build 74 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAc 25.105 2oaac 25.110 Development El Exploratory ❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Suspa or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 11/7/2015 s 215-166 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 .10/20/2015 50-029-23559-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1480'FNL,4118'FEL, Sec. 12,T11N, R10E, UM •11/2/2015 KRU 1C-154 Top of Productive Interval: 9. Ref Elevations: KB:97 17. Field/Pool(s): 4422.3 FNL,2375 FEL, Sec 1,T11N, R10E, UM GL: 58 BF: Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2827'FNL,4347'FEL, Sec. 36,T12N, R10E, UM n/a ADL 025649,ADL 025638 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 562168 y- 5968757 Zone-4 12680'/3849' 931695 TPI: x- 563891 y- 5971109.8 Zone-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 561858 y- 5977968 Zone-4 no SSSV 1854'MD/1793'TVD 5. Directional or Inclination Survey: Yes 7 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL)I n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary RECEIVED GR/Res/Sonic(TOC) DEC 0 4 2015 AoGrrt 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20 94 H40 42 122 42 122 42 200 cf of ArcticCRETE 10 3/4 45.5 L-80 42 2637 42 2413 13.5 460 bbl DeepCRETE Lead 61.5 bbl DeepCRETE Tail 7.625 29.7 L-80 39 5614 39 3857 9.87 43.6 bbl Class G • 4 1/2 11.6 L-80 5435 12641 3846 3850 6.75 Slotted 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): 3.5 9190 9183/6387 Slotted Liner from 5839'-6767'=MD 3871'-3864'=TVD Slotted liner from 10863'-12631'=MD 3867-3850'=TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Slotted Liner From 7048'-10583'=MD 3877'-3872'=TVD Was hydraulic fracturing used during completion? Yes❑ No 2 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - - Form Form 10-407 Revised 11/2015 v-7_ `j/J 2_4 i 1‘. OjVTI J N PAGE 2 RBDNISt6 DEC 0 9 2015 Submit ORIGINIAL onI6 • • 28. CORE DATA Conventional Core(s): Yes ❑ No RI Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1854 1793 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 5517 3853 information, including reports, per 20 AAC 25.071. Top Ugnu C 3963 3254 Top Ugnu B 4399 3497 Top Ugnu A 4600 3598 West Sak D 5517 3853 West Sak D Total Depth 12680 3849 Formation at total depth: West Sak D 31. List of Attachments:Summary of Operations, Definitive Survey,Schematic,Cement Reports Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelsey Hallford@265=4138 y ;> ? Email: Kelsey.hallford@cop.com t•- Printed Name: G. L.Alvord /n��,, Title: Alaska Drilling Manager Signature: C�- O. Phone: 265-6120 Date: l 2_( (Lt2 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 la: 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 lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection, Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only $ , KUP POD 1C-154 ConocoPhillips g Well Attribu Max AnglES TD r Alaska,Inc. IIU Wellbore APWI Field Name Wellbore Status ncl C) MD(ft Act Btm(ORB) Conocii Ftillips '' 500292355900 WEST SAK PROD 94.57 10,930.02 12,680.0 s ... y< Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-154 12/4/201510:43:10 AM SSSV:NIPPLE Last WO 39.73 11/8/2015 Vertical schemanc.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL lehallf 120/2015 HANGER,34.7 1-4 64) ��"�" Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtILen(I...Grade Top Thread ..- Conductor 20 19.250 42.2 122.2 122.2 78.67 B Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread Surface 10 3/4 9.950 42.2 2,636.9 2,412.7 45.50 L-80 TSH 563 '� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(1...Grade Top Thread Intermediate 7 5/8 6.875 39.4 5,614.0 3,857.8 29.70 L-80 Hydril563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread Liner 41/2 4.000 5,435.0 12,641.0 3,849.8 11.60 L-80 IBT-m Liner Details Nominal ID Top(ftKB) Top(ND)(ORB) Top Incl(°) Item Des Com (in) ce duem 42.2-122.2 5,435.0 3,846.0 83.94 PACKER Baker HRD-E ZXP W/HD's 5%"X 7.63",5Y."178 4.970 _ Hydril 563 pin do 5,454.9 3,848.0 84.74 NIPPLE RS Nipple 7.63"L-80 5.5"15.59 HYD 563 Box x box 4.850 GAS LIFT;2.509.4 5,457.7 3,848.2 84.86 HANGER Baker"DG"Flex-Lock liner hanger 5W X 7.63"5 1/2 4.840 Hyd 563 pin x pin 5,467.5 3,849.1 85.25 SBE Baker 4.75"ID Seal Bore Extension,5 1/2"Hyd 563 4.750 Box x Pin • 5,829.3 3,870.9 86.82 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.960 PACKER (Water activated)"E"S/N-049169-001-2 6,772.7 3,864.4 88.57 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 Surface,az.z-z,e3e9-ii PACKER (Water activated)"D"S/N-049169-001-1 7,038.5 3,876.6 86.18 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.970 PACKER (Water activated)"C"S/N-049169-001-9 XO THREAD,3,685.8 II 10,589.5 3,8722 89.36 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 GAS LIFT,3,605.2 - PACKER (Water activated)"B"SIN-049169-001-8 XO THREAD;3,702.4 10,853.5 3,867.5 94.13 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.980 ElPACKER (Water activated)"A"SIN-049169-001-4 Tubing Strings XO THREAD;4,918.9 Tubing DescriptionString Ma.. ID(in) Top(MOB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection NIPPLE;4,929.7 TUBING I 41/21 3.9581 34.71 5,481.61 3,850.21 12.60 L-80 I HYD563 Completion Details XO THREAD;4,928.5 Nominal ID �/ �� Top(ftKB) Top(TVD)(ftKB) Top Incl 5) Item Des Com (in) 34.7 34.7 0.04 HANGER Vetco Off Set Tubing Hanger W/13-3/8"false bowel SN: 3.875 1J00040001-0431-4 4,926.7 3,728.3 71.78'NIPPLE CAMCO'DB'Nipple 4'/:"w)3.812"no-go profile w/RHC 3.813 plug SN#10103-3 LOCATOR.5,441.3 _ 5,441.3 3,846.7 84.19 LOCATOR Baker mechanical locator Comm N#H450-01-4785 3.860 5,464.2 3,848.8 85.12 SEAL ASSY Baker Bonded Seal assy with full Mule Shoe,Comm N 3.870 #H450-01-4785 Mandrel Inserts St I. 1. ati SEAL ASSY,5,464.2 I.� on Top(ND) Valve Latch Pon Size TRO Run rl!: I N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1 F 1 2,509.4 2,323.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/4/2015 2 3,695.2 3,099.4 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0 11/4/2015 Notes:General&Safety End Date Annotation • NOTE I II Intermediate;39.4-5,614.0 I i I Iiii! a:tlirSu N Liner,5,435.0-12,641.0 I I 011ii operations Summary (with Timelog epths) RECEIVED 1C-154 DEC 18 2015 Gorxxxiktillips AOGCC hgr.A:. Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/18/2015 10/18/2015 8.50 MIRU MOVE MOB P Prep derrick.Raise and pin C-section 110.0 110.0 03:30 12:00 and disconnect innerconnects. PJSM. Prep and skid rig floor to move position.Pin mast cylinders and lower derrick. Prep cellar pinning lift cylinders,remove grating and cribbing. Unpin pipe shed. Walk out pipe shed away from sub,walk power, pump and pit mods. Hook truck to power complex. 10/18/2015 10/18/2015 2.00 MIRU MOVE MOB P Walk pipe shed while turning into 110.0 110.0 12:00 14:00 position for truck, Hook up truck and stage pipe shed at end of pad near casing. Concurrently: Change out valves on mix line suctions. 10/18/2015 10/18/2015 3.00 MIRU MOVE MOB P Walk sub out and away from 1C-153, 110.0 110.0 14:00 17:00 positioning for truck.Attach jeep and trucks to sub and stage near 1C-154. Remove trucks and jeep. 10/18/2015 10/18/2015 3.00 MIRU MOVE MOB P Walk sub into 1C-154.Spot sub,level 110.0 110.0 17:00 20:00 and shim. Sub spotted at 20:00 10/18/2015 10/18/2015 1.25 MIRU MOVE MOB P Move pipe shed via trucks and align 110.0 110.0 20:00 21:15 adjacent to sub. Remove truck from pipe shed,walk pits forward for turck hook up.Berm cellar. 10/18/2015 10/19/2015 2.75 MIRU MOVE MOB P Walk pipe shed under and into sub 110.0 110.0 21:15 00:00 and position for pinning.Stage pits, pump and power modules forward via trucks. 10/19/2015 10/19/2015 2.00 MIRU MOVE MOB P Spot and shim pipe shed.Spot power 110.0 110.0 00:00 02:00 module with Peak sow and store suspension. 10/19/2015 10/19/2015 1.00 MIRU MOVE MOB P PJSM for raising derrick.Raise 110.0 110.0 02:00 03:00 derrick,set rig mats for casing shed. Spot casing shed with Peak sow. 10/19/2015 10/19/2015 1.00 MIRU MOVE MOB P PJSM for skidding rig floor.Skid rig 110.0 110.0 03:00 04:00 floor.Release Peak Sow at 03:30hrs. 10/19/2015 10/19/2015 2.00 MIRU MOVE MOB P PJSM for raising cattle chute,raise 110.0 110.0 04:00 06:00 cattle chute and prep to lower C- section.Continue to spot casing shed and store suspension.Spot pit,pump and power modules.Plug in electrical interconnects. 10/19/2015 10/19/2015 4.00 MIRU MOVE RURD P Shim casing shed.Lower C-section. 110.0 110.0 06:00 10:00 Plug in electrical interconnects. RU fluid interconnects,test generator emergency stops.Swap ower from cold starts to 3516 generatrors.Lower and berm cellar walls. 10/19/2015 10/19/2015 0.50 MIRU MOVE RURD P PJSM,spool 10 wraps of drilling line 110.0 110.0 10:00 10:30 back onto drawworks drum. Un-pin blocks and top drive. Bridal up scoping lines. 10/19/2015 10/19/2015 1.50 MIRU MOVE RURD P Scope derrick up,bridal down scoping 110.0 110.0 10:30 12:00 lines,remove bridal line yokes,hook up kelly hose to top drive. Page 1/29 Report Printed: 12/18/2015 -" operations Summary (with Timelog�pths) of ells 1C-154 Con000`Philtips Ate., Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ttKB) 10/19/2015 10/19/2015 1.00 MIRU MOVE RURD P Remove kelly hose and re-align man 110.0 110.0 12:00 13:00 rider cable.Re-position top drive service landing. MU kelly hose and sling.Pull master bushings. 10/19/2015 10/19/2015 4.50 MIRU MOVE NUND P PU surface riser. Lower to cellar and 110.0 110.0 13:00 17:30 nipple up same. Nipple up surface annular,flow box,flow line,4" conductor valves and risers,koomey lines to bag and knife valve,and flow jet lines. Concurrently, MU choke line @ interconnect,swap from rig generator power to high line power @ 15:00. 10/19/2015 10/19/2015 1.00 MIRU MOVE RURD P Verify pipe count in pipe shed. Install 110.0 110.0 17:30 18:30 hole fill hose to annular,accumulator PM's,and mobilize mouse hole to pipe shed.Obtain RKB measurements(Rig Floor to Ground Level=39.28'). 10/19/2015 10/20/2015 5.50 MIRU MOVE PULD P RIH with 4"HWDP tagging bottom of 110.0 110.0 18:30 00:00 conductor @ 110.8'MD. Install mouse hole in rotary. Pick up/Make up and rack back 11 stands of 4"HWDP singles 11 std's of 4"HWDP by using mouse hole.PU/rack back 35 std's of 4"DP with super sliders. Concurrently, Replace Strip-O-Matic door seal in flow box. 10/20/2015 10/20/2015 3.50 MIRU MOVE PULD P PJSM for PU 4"DP. PU 39stds of 4" 110.0 110.0 00:00 03:30 DP without super sliders in mouse hole and rack back in derrick. 10/20/2015 10/20/2015 2.50 MIRU MOVE PULD P Change out elevators to 5"DP. PU 110.0 110.0 03:30 06:00 23stds of 5"DP in mouse hole and rack back in derrick. Pull mouse hole. 10/20/2015 10/20/2015 1.00 MIRU MOVE BOPE P PU std of 5"DP and RIH to 60'MD. 110.0 110.0 06:00 07:00 Perform diverter test(Witnessed by Louis Grimaldi with AOGCC). 10/20/2015 10/20/2015 2.00 MIRU MOVE PULD P Install mouse hole and continue to PU 110.0 110.0 07:00 09:00 and rack back 23stds of 5"DP, 17jts of 5"HWDP,6-1/4"mechanical jars. Construct barricade outside of 100' diverter exclusion zone(front of Well Houses: 1C-131 and 1C-133 as per Louis Grimaldi of AOGCC). Calibrate Pit PVT sensors and Gas Watch system(Quadco Rep:Ricky Castro). 10/20/2015 10/20/2015 2.50 MIRU MOVE BHAH P PJSM for PU 13-1/2"Motor Assembly. 110.0 110.0 09:00 11:30 PU 13-1/2"Motor Assembly to 106' MD.PU wt=56k,SO wt=62k,Rot wt= 60k,TQ=1k Page 2/29 Report Printed: 12/18/2015 to Iperations Summary (with Timeloglpths) 0.: 1C-154 Conocc>hillaps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/20/2015 10/20/2015 1.00 MIRU MOVE SEQP P Fill lines with H2O to test mud lines. 110.0 110.0 11:30 12:30 Function hole fill and jet lines,check cellar and BOP deck for leaks. Replace 0-ring on mud line @ interconnect.Pressure test surface lines to 3500psi for 5mins. Concurrent Operations, Load 10-3/4"casing into casing shed. 10/20/2015 10/20/2015 1.25 MIRU MOVE DRLG P Tag and drill cement at 108.5'MD to 110.0 110.0 12:30 13:45 120'MD(shoe of conductor) 10/20/2015 10/20/2015 3.25 SURFAC DRILL DDRL P Spud well at 13:45 10/20/2015. Drill 110.0 290.0 13:45 17:00 and Gyro survey 13-1/2"surface hole from 110'MD to 290'MD/290'TVD with Flow=500 GPM,SPP=675psi, F/O=44%, RPM=40,TQ=6k,and WOB=23k.Off bottom pressure= 580psi. PU wt=65k,SO wt=72k, ROT=70k,and Off bottom TQ=1k. 10/20/2015 10/20/2015 1.75 SURFAC DRILL BHAH P POOH from 290'MD to 112'MD 290.0 290.0 17:00 18:45 racking back HWDP.MU stabilizer, X/O,7-1/4"DC's and saver sub as per DD to 216'MD.Wash down to 290' MD. 10/20/2015 10/20/2015 1.00 SURFAC DRILL DDRL P Directional Drill 13-1/2"surface hole 290.0 399.0 18:45 19:45 from 290'MD to 399'MD/397'TVD with Flow=502 GPM,SPP=800psi, F/O=43%,RPM=40,TQ=6k,WOB= 27k.Off bottom pressure=580psi, Pu wt=65k,SO wt=72k, Rot wt=70k,and Off bottom TQ=1 k. 10/20/2015 10/20/2015 0.50 SURFAC DRILL TRIP P POOH from 399'MD to 309'MD 399.0 399.0 19:45 20:15 racking back lstd HWDP, MU Jart std, RIH to 398'MD. 10/20/2015 10/21/2015 3.75 SURFAC DRILL DDRL P Directional Drill 13-1/2"surface hole 399.0 750.0 20:15 00:00 from 399'MD to 750'MD/742'TVD with Flow=500 GPM,SPP=900psi, F/O=43%,RPM=50,TQ=6k,WOB= 25k.Off bottom pressure=655psi, Pu wt=79k,SO wt=84k, Rot wt=79k,and Off bottom TQ=2k AST=2.7,ART=1.3,ADT=4.0. Concurrently, Change out derrick assist cable. 10/21/2015 10/21/2015 0.25 SURFAC DRILL DDRL P Directional drill 13-1/2"surface hole 750.0 772.0 00:00 00:15 from 750'to 772'MD,752'TVD with Flow=500 GPM,SPP=955psi,F/O= 41%,RPM=50,TQ=6k,and WOB= 25k. Off bottom pressure=630psi, PU wt=80k,SO wt=85k, Rot wt=85k and off bottom TQ=2k. 10/21/2015 10/21/2015 0.50 SURFAC DRILL SVRG P Grease top drive and inspect top drive 772.0 772.0 00:15 00:45 and blocks. Reciprocate pipe from 772'MD to 697'MD with Flow=250 GPM,SPP=312psi,FO=34%,PU wt=80k.SO wt=85k,and Rot wt=80k. Page 3/29 Report Printed: 12/18/2015 operations Summary (with Timelog epths) 0a ells 1C-154 conoaPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/21/2015 10/21/2015 0.25 SURFAC DRILL RGRP T Change out swabs and liners in MP#1. 772.0 772.0 00:45 01:00 (Cylinders#1 and#3).Continue to reciprocate from 772'MD to 697'MD with Flow=250 GPM,SPP=315psi, FO=34%,PU wt=80k.SO wt=85k, and Rot wt=80k. 10/21/2015 10/21/2015 5.00 SURFAC DRILL DDRL P Directional drill 13-1/2"surface hole 772.0 1,150.0 01:00 06:00 from 772'to 1150'MD, 1132'TVD with Flow=500 GPM,SPP= 1040psi, F/0= 41%, RPM=60,TQ=5k,and WOB= 25k. Off bottom pressure=975psi,PU wt=91k,SO wt=92k, Rot wt=89k and off bottom TQ=2k. 10/21/2015 10/21/2015 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2"surface hole 1,150.0 1,670.0 06:00 12:00 from 1150'to 1670'MD, 1628'TVD with Flow=625 GPM,SPP=1565psi, F/O=44%,RPM=60,TQ=5k,and WOB=40k. Off bottom pressure= 1200psi,PU wt=110k,SO wt=98k, Rot wt=101k and off bottom TQ=3k. (AST=2.79,ART=3.96,ADT=6.75) 10/21/2015 10/21/2015 3.00 SURFAC DRILL -DDRL P Directional drill 13-1/2"surface hole 1,670.0 2,004.0 12:00 15:00 from 1670'to 2004'MD, 1924'TVD with Flow=653 GPM,SPP=1500psi, F/O=43%, RPM=70,TQ=7k,and WOB=24k. Off bottom pressure= 1240psi,PU wt= 108k,SO wt=103k, Rot wt=104k and off bottom T0=3k. 10/21/2015 10/21/2015 0.50 SURFAC DRILL RGRP T Backream from 2004'MD to 1906'MD 2,004.0 2,004.0 15:00 15:30 with Flow=420 GPM,SPP=780psi, F/O=36%,RPM=70,and TQ=4k. Concurrently, Change swab and liner on MP#1 (Cylinder#2). 10/21/2015 10/21/2015 6.50 SURFAC DRILL DDRL P Directional drill 13-1/2"surface hole 2,004.0 2,643.0 15:30 22:00 from 2004'to 2643'MD,2418'TVD with Flow=700 GPM,SPP= 1820psi, F/O=44%,RPM=70,TQ=6k,and WOB=24k. Off bottom pressure= 1620psi,PU wt=120k,SO wt=109k, Rot wt=112k and off bottom TQ=4k. (AST=3.1,ART=2.05,ADT=5.25) Concurrently, Install 7-5/8"UPR's,PU and secure well head in BOP deck,Torque 18" riser extension on top of same. 10/21/2015 10/21/2015 1.25 SURFAC CASING CIRC P Obtain survey,CBU(x3: 12330 total 2,643.0 2,643.0 22:00 23:15 strokes)while rotating and reciprocating drill pipe from 2643'MD to 2571'MD with Flow=700 GPM, SPP=1560psi,F/O=44%,RPM=70, TQ=4k 10/21/2015 10/21/2015 0.25 SURFAC CASING OWFF P Monitor well for 10min.(Well Static) 2,643.0 2,643.0 23:15 23:30 10/21/2015 10/22/2015 0.50 SURFAC CASING BKRM P {BROOH from 2643'MD to 2386'MD 2,643.0 2,386.0 23:30 00:00 with Flow=700 GPM,SPP=1575psi, F/0=45%,RPM=70 and TQ=5. Page 4/29 Report Printed: 12/18/2015 0I Iperations Summary (with Timeloglepths) r� AZ1 1C-154 ConocathiIGps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 5.25 SURFAC CASING BKRM P Backream out of hole from 2386'MD 2,386.0 776.0 00:00 05:15 to 776'MD with Flow=700 GPM, SPP=1496psi, F/O=44%,PU wt= 103k,SO wt= 100k 10/22/2015 10/22/2015 1.75 SURFAC CASING TRIP P Pull out of hole on elevators from 776' 776.0 152.0 05:15 07:00 MD to 152'MD while monitoring hole fill on trip tank. PU wt=83k,SO wt= 86k. 10/22/2015 10/22/2015 2.00 SURFAC CASING BHAH P PJSM for laying down BHA. Lay down 152.0 0.0 07:00 09:00 BHA from 152'MD to 0'MD while monitoring displacement via trip tank. 10/22/2015 10/22/2015 1.00 SURFAC CASING BHAH P Clean and clear rig floor. 0.0 0.0 09:00 10:00 Concurrently, Open Schaffer BOP doors and inspect rams. 10/22/2015 10/22/2015 1.50 SURFAC CASING RURD P RU to run 10-3/4"casing:remove 0.0 0.0 10:00 11:30 master bushings,install PS-21 slips with 10-3/4"inserts,remove 5"DP elevators,install 6'bail extensions, install 10-3/4"side door elevators,RU volant casing running tool. PJSM for running 10-3/4"casing with volant CRT and power tongs. 10/22/2015 10/22/2015 1.50 SURFAC CASING PUTB P MU 10-3/4"shoe track(Baker loc first 0.0 167.0 11:30 13:00 3 jts). Continue running 10-3/4" casing to 167'MD.Check floats (holding). (MU TQ=22,400ft/lbs) 10/22/2015 10/22/2015 4.50 SURFAC CASING PUTB P RIH with 10-3/4"45.5#L-80 Hydril 563 167.0 1,938.0 13:00 17:30 dopeless casing from 167'MD to 1938'MD filling casing on the fly and topping off every 10 jts. 10/22/2015 10/22/2015 2.25 SURFAC CASING CIRC P Circulate and condition while 1,938.0 1,938.0 17:30 19:45 reciprocating from 1897'MD to 1938' MD.Stage pumps to 1 BPM,SPP= 130psi,FO=18%;6 BPM, SPP=185psi,FO=27%. PU wt=114k,SO wt=116k 10/22/2015 10/22/2015 2.00 SURFAC CASING PUTB P Continue to RIH with 10-3/4"casing 1,938.0 2,591.0 19:45 21:45 from 1938'MD to 2591'MD filling on the fly and topping off every 10 jts. PU wt= 138k,SO wt=116k. 10/22/2015 10/22/2015 0.25 SURFAC CASING HOSO T MU Vetco Grey hanger,PU 10-3/4" 2,591.0 2,591.0 21:45 22:00 landing joint and found large amounts of scale inside. Attempt to drift unsuccessfully from rig floor with 9.875"OD drift. 10/22/2015 10/22/2015 1.25 SURFAC CASING HOSO T LD landing joint in pipe shed and work 2,591.0 2,591.0 22:00 23:15 to clean out and get it drifted with 9.875"OD drift. Concurrently, Circulate and reciprocate from 2591' MD to 2581'MD @ 3 BPM, SPP=115psi,FO= 12%,PU wt=136k, SO wt= 116k. Page 5/29 Report Printed: 12/18/2015 Iperations Summary (with Timelogepths) 1C-154 conoc hilIps AExka Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 0.50 SURFAC CASING HOSO P PU 10-3/4"landing joint to floor and re 2,591.0 2,637.0 23:15 23:45 -drift landing jt at rig floor. MU to 10- 3/4"casing hanger and land casing at 2637'MD. 10/22/2015 10/23/2015 0.25 SURFAC CEMENT CIRC P Circulate while reciprocating pipe and 2,637.0 2,637.0 23:45 00:00 conditioning mud from 2637'MD to 2607'MD staging pumps to 4 BPM, SPP=120 psi, FO=22%. 10/23/2015 10/23/2015 2.00 SURFAC CEMENT CIRC P Blow down top drive.Rig up cement 2,637.0 2,637.0 00:00 02:00 hose and break circulation by staging pump up from 2 BPM,SPP=100psi,FO=12%; 3 BPM,SPP=130psi,FO=13%; 4 BPM,SPP=150psi,FO=13%; 5 BPM,SPP=178psi, FO=15%; 6 BPM,SPP=218psi, FO=17%; 7 BPM,SPP=265psi, FO=19%; 8 BPM, ICP=330psi FCP=305psi, FO= 20%. PU wt= 142k,SO wt= 120k. 10/23/2015 10/23/2015 1.00 SURFAC CEMENT CIRC P Continue to reciprocate from 2636'MD 2,637.0 2,637.0 02:00 03:00 to 2606'MD with Flow=8 BPM, SPP=307psi,FO=22%.Circulate for 8510stks. Concurrently, Have PJSM for pumping cement with Dowell cementers,MI Swaco Mud Engineers,Vac Truck Drivers and crews. 10/23/2015 10/23/2015 3.75 SURFAC CEMENT CMNT P Pump 5bbl CW 100 and test cement 2,637.0 2,637.0 03:00 06:45 lines to 3500psi(Good Test).Dowell continue to pump 70bbl of CW100 at 6.1BPM,320psi, FO=12%. Pump 70.5bbl of 10.59ppg Mud Push II with 2 gal of Red Dye at 5BPM,280psi, and FO=11%. Drop bottom plug, pump 460bb1 of Lead Deep Crete 11.0ppg at 6.6BPM,245psi, FO=18%. Pump 12ppg Tail cement at 5BPM, 228psi,FO=12%.Drop top plug and chase with 10bb1 of water prior to swapping to rig pumps. Continue pumping 234.4bbls of 9.5ppg Drilplex mud at 8 BPM,437%,FO=20%using rig pumps. Divert to cellar box at 1113stks,slow pumps to 3BPM at 1400stks,220psi. Bump plug with 2330stks,265psi. Increase to 800psi and shut in.Bled back to Opsi.Pump back up to 800psi and shut in.Bled back to Opsi.Check Floats(Held). 10/23/2015 10/23/2015 5.25 SURFAC CEMENT RURD P Blow down cement line and rig down 2,637.0 2,637.0 06:45 12:00 Volant casing running tool(CRT). Break off landing joint and drain stack. Pump 100bb1 black H2O pill into stack. Remove hoses for knife valve, function annular 3x,Lay down Volant CRT,remove PS-21 slips,Nipple down Low psi riser,21-1/4"annular, 21-1/"riser,and Nipple down diverter. Page 6/29 Report Printed: 12/18/2015 •perations Summary (with Timelogepths) 1C-154 conocoPhillips hgr.A.7 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/23/2015 10/23/2015 6.75 SURFAC WHDBOP NUND P NU Vetco well head and 1.47"and 14" 2,637.0 2,637.0 12:00 18:45 spools and 0.67'offset DSA. NU BOP stack,choke and kill lines.Slide in Joe's Box and chink. Install Strip-O- Matic and flow line. TOC @ 15:00hrs=14',run in with PVC pipe to 25'.Flush conductor with fresh water.Suck out conductor with rig vack to 25'. 10/23/2015 10/23/2015 1.50 SURFAC WHDBOP CMNT T Mix Class G cement with 60:40 ratio 2,637.0 2,637.0 18:45 20:15 and pour down conductor. Concurrently, Change out saver sub to XT-39.MU floor valves and prep for BOP equipment test. 10/23/2015 10/24/2015 3.75 SURFAC WHDBOP PULD P Change out elevators,install 9-5/8" 2,637.0 2,637.0 20:15 00:00 slip inserts and PU mousehole.Lay down 5"DP 2x1 storing 23 doubles in pipe shed.Lay down 6stds of HWDP. Concurrently, Continue to add Class G cement with 60:40 ratio.Total cement poured= 5bbls.(In place by 21:30) 10/24/2015 10/24/2015 1.25 SURFAC WHDBOP RURD P Set test plug as per Vetco 0.0 0.0 00:00 01:15 representative. Rig up BOPE test equipment and fill with fresh water. Perform body test to 3500psi and check for leaks. 10/24/2015 10/24/2015 4.75 SURFAC WHDBOP BOPE P Test BOPE all tests to 250psi Low and 0.0 0.0 01:15 06:00 3500psi High for 5min charted,except manual operated and super choke (250/2000psi)with 4",4-1/2",and 7- 5/8"test jts.Witness waived by AOGCC Rep Louis Grimaldi. Test Annular with 4",4-1/2"and 7-5/8" test jts,Test 7-5/8"UPR with 7-5/8" test jt,2-7/8"x5-1/2"LPR with 4"and 4 -1/2"test jt.Jest 2-7/8"x-5-1/2",choke valves 1-15, Manual Operated and super choke,choke and kill manuls and HCR's,4"valve on kill line,4" TIW,4"DArt,4-1/2"TIW and 4-1/2" Dart,Upper and Lower IBOP. Perform Koomey drawdown, Accumulator=3000psi. Manifold=1500psi,Annular=1325psi, Air=135psi. Function choke,kill, annular,and lower pipe ramsx2. After cycle,Accumulator=1325psi, Manifold=1250psi,and Annular=1300psi. 24sec to build st 200psi and 162sec to get back to full charge with 2 electric and 2 air pumps. 6 bottle Nitrogen Avg=1916psi. Closing times:Annular-23sec, UPR=18sec,Blind/shears=16sec, LPR=17sec,Choke HCR=2sec,Kill HCR=2sec. Page 7/29 Report Printed: 12/18/2015 operations Summary (with Timelog epths) 1C-154 ConocoFhillps AF.r.Aa Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/24/2015 10/24/2015 1.00 SURFAC WHDBOP RURD P Rig down test equipment.Pull test 0.0 0.0 06:00 07:00 plug,Set13-1/2"OD x 12-1/8"ID wear bushing.Blow down choke,kill line and top drive. 10/24/2015 10/24/2015 3.00 SURFAC CEMENT BHAH P PJSM for MU 9-7/8"BHA. MU BHA to 0.0 275.0 07:00 10:00 181'MD, Install 4"PS-21 slip inserts and continue to MU 9-7/8"BHA from 181'MD to 275'MD.Monitor displacement via Trip Tank. 10/24/2015 10/24/2015 0.50 SURFAC CEMENT SVRG P Service and inspect top drive and 275.0 275.0 10:00 10:30 traveling blocks. 10/24/2015 10/24/2015 0.50 SURFAC CEMENT TRIP P Continue to RIH from 275'MD to 275.0 734.0 10:30 11:00 733.93'MD while monitoring displacement via Trip Tank. 10/24/2015 10/24/2015 0.75 SURFAC CEMENT TRIP P RIH from 733.93'MD to 1492'MD.PU 734.0 1,492.0 11:00 11:45 1 single of 4"DP, 12 DBL 4"DP TOC from wellhead:26" 10/24/2015 10/24/2015 0.25 SURFAC CEMENT DHEQ P Shallow test MWD with Flow= 1,492.0 1,492.0 11:45 12:00 500GPM,SPP=1150psi,FO=28%,PU wt=77k,SO wt=76k.(No communication with Exceed Tool). 10/24/2015 10/24/2015 0.50 SURFAC CEMENT DHEQ T Continue to shallow test MWD: 1,492.0 1,492.0 12:00 12:30 Increase Flow to 600GPM, SPP=1905psi,FO=31%. (No communication with Exceed Tool). Decision made to continue in the hole and perform FIT/LOT. 10/24/2015 10/24/2015 0.50 SURFAC CEMENT TRIP P RIH from 1492'MD 2441'MD while 1,492.0 2,441.0 12:30 13:00 monitoring displacement via Trip Tank.PU wt=87k SO wt=82k. 10/24/2015 10/24/2015 0.25 SURFAC CEMENT COCF P Wash and ream from 2441'MD to 2,441.0 2,538.0 13:00 13:15 2538'MD @ 5 BPM,SPP=320psi, FO=13%,RPM=30,TQ=3.5k.Tag TOC©2538'MD.Confirm tag without Rotary and 15k down. Rack back stand. 10/24/2015 10/24/2015 0.75 SURFAC CEMENT CIRC P Circulate while rotating and 2,533.0 2,440.0 13:15 14:00 reciprocating from 2533'MD to 2440' MD with Flow=500GPM,SPP= 1500psi,FO=26%,RPM=40,and TQ=3.2k.Total stks=2500.MWin and MWout=9.6ppg.PU wt=92k,SO=81k, and Rot=87k.Blow down top drive. 10/24/2015 10/24/2015 1.00 SURFAC CEMENT PRTS P Rig and test 10-3/4"casing to 3000psi 2,440.0 2,440.0 14:00 15:00 for 30 min charted.(Good Test). 50stks to pressure up,4.2bbl bleed back.Rig down test equipment. 10/24/2015 10/24/2015 5.25 SURFAC CEMENT DRLG P Drill out float equipment and drill 2,440.0 2,546.0 15:00 20:15 cement with Flow=550GPM, SPP=1750psi,FO=38%, RPM=50, TQ=4-5k,and WOB=2k. Tag plugs at 2546.4'MD,Tag shoe @ 2633.9 MD and bottom of shoe at 2638.5'MD. Drill out plugs with WOB=2-15k, RPM=50-80.Drill out shoe with 2-13k WOB and RPM=50-80." Page 8/29 Report Printed: 12/18/2015 or Iperations Summary (with Timeloglepths) 1C-154 Conoco`Phillips hF.r.Aa Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/24/2015 10/24/2015 0.25 SURFAC CEMENT DDRL P Drill 9-7/8—intermediate hole from 2,643.0 2,663.0 20:15 20:30 2643'MD to 2663'MD/2430'TVD with Flow=650 GPM,SPP=2220psi, FO=31%, RPM=80,WOB=3-4k, ECD=9.86ppg," 10/24/2015 10/24/2015 0.50 SURFAC CEMENT CIRC P CBU while rotating and reciprocating 2,663.0 2,635.0 20:30 21:00 from 2662'MD to 2635'MD with Flow=650GPM,SPP=2210psi, F0=31%, RPM=80,TQ=3.2k. MW=9.6 in an out after 4128stks(-2x CBU). 10/24/2015 10/24/2015 1.25 SURFAC CEMENT LOT P Rig up and perform LOT to 13.8ppg 2,635.0 2,635.0 21:00 22:15 EMW with a leak of pressure of 530psi with a 9.6ppg MW.Total strokes pumped=42, 1.2bbls bled back.Rig down and blow down testing equipment. Talk with town to confirm that it is ok to continue operations. 10/24/2015 10/24/2015 0.75 INTRM1 DRILL DISP P Displace well to 9.2ppg LSND drilling 2,635.0 2,663.0 22:15 23:00 fluid @ 550 GPM,SPP=1250psi, FO=29%,RPM=80,TQ=2.9k 10/24/2015 10/25/2015 1.00 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole from 2,663.0 2,722.0 23:00 00:00 2663'MD to 2722'MD/2470'TVD with Flow=600GPM,SPP=1290psi, FO=31%,RPM=80,TQ=2.5k,and WOB= 1k. ECD=9.69ppg,Off bottom pressure= 1280psi, PU wt=91k,SO=86k,Rot wt=88k,Off bottom TQ=3k. AST/ART/ADT=0.97hr. 10/25/2015 10/25/2015 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole from 2,722.0 3,419.0 00:00 06:00 2722'MD to 3419'MD/2930'TVD with Flow=650 GPM, 1664psi, FO=32%, RPM=130,TQ=5k,WOB=6k, ECD= 9.83ppg. Off bottom pressure= 1690psi, PU wt=99k,SO wt=88k,Rot wt=93k,Off bottom TQ=3k. AST/ART=3.62,ADT=3.62 10/25/2015 10/25/2015 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole from 3,419.0 4,365.0 06:00 12:00 3419'MD to 4365'MD/3483'TVD with Flow=650 GPM, 1664psi, FO=32%, RPM=140,TQ=5k,WOB=9k, ECD= 10.02ppg. Off bottom pressure= 2040psi,PU wt= 104k,SO wt=90k, Rot wt=96k,Off bottom TQ=3k. AST/ART=3.61,ADT=3.61 10/25/2015 10/25/2015 6.00 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole from 4,365.0 5,378.0 12:00 18:00 4365'MD to 5378'MD/3846'TVD with Flow=700 GPM,2765psi,FO=34%, RPM=180,TQ=6-8k,WOB=9k, ECD= 10.49ppg. Off bottom pressure= 2750psi, PU wt= 117k,SO wt=99k, Rot wt=90k,Off bottom TQ=3.5k. AST/ART=3.98,ADT=3.98 Page 9/29 Report Printed: 12/18/2015 •perations Summary (with Timelog�epths) 1C-154 C.on000`Philhps arxw., Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/25/2015 10/25/2015 3.25 INTRM1 DRILL DDRL P Drill 9-7/8"intermediate hole from 5,378.0 5,621.0 18:00 21:15 5378'MD to 5621'MD/3858'TVD with Flow=700 GPM,2820psi,FO=34%, RPM=180,TQ=6-7k,WOB=7k, ECD= 10.37ppg. Off bottom pressure= 2830psi,PU wt=117k,SO wt=90k, Rot wt=99k,Off bottom TQ=3.5k. AST/ART= 1.42,ADT=1.42 10/25/2015 10/25/2015 0.75 INTRM1 CASING CIRC P Circulate bottoms up while rotating 5,621.0 5,621.0 21:15 22:00 and reciprocating from 5621'MD to 5565'MD/3858'TVD with Flow=690 GPM,SPP=2760psi,FO=32%,RPM= 180,PU wt=110k,SO wt=86k,Rot wt=98k,TQ=4.5k. MW in/out= 9.4ppg. 10/25/2015 10/25/2015 0.25 INTRM1 CASING OWFF P Slow pump rates and prior to 5,621.0 5,621.0 22:00 22:15 backreaming out of the hole,observe will for flow for 5 min(Static) 10/25/2015 10/26/2015 1.75 INTRM1 CASING BKRM P Backream out of hole from 5621'MD 5,621.0 4,808.0 22:15 00:00 to 4808'MD with Flow=700 GPM, SPP=2750psi,FO=33%,RPM=180, and TQ=4.5k. 10/26/2015 10/26/2015 6.00 INTRM1 CASING BKRM P Backream out of hole from 4808'MD 4,808.0 2,631.0 00:00 06:00 to 2631'MD with Flow=7000PM, SPP=2695psi,FO=32%,RPM=180, and TQ=5-6k 10/26/2015 10/26/2015 0.75 INTRM1 CASING CIRC P Rotate and reciprocate from 2631'MD 2,631.0 2,536.0 06:00 06:45 to 2536'MD with Flow=700, SPP=2080psi,FO=33%, RPM=60, TQ=2.5.PU wt=94k,SO wt=81k,Rot wt=86k. 10/26/2015 10/26/2015 0.25 INTRM1 CASING OWFF P Monitor well(static)and blow down 2,536.0 2,536.0 06:45 07:00 top drive 10/26/2015 10/26/2015 1.50 INTRM1 CASING TRIP P Pull out of hole on elevators from 2,536.0 733.0 07:00 08:30 2631'MD to 733'MD while monitoring well on trip tank.PU wt=65k,SO wt=68k. 10/26/2015 10/26/2015 1.25 INTRM1 CASING BHAH P PJSM,lay down HWDP,lay down 733.0 175.0 08:30 09:45 BHA from 733'MD to 266'MD.Rack 1 std of 4"HWDP and contin ue to lay down BHA from 266'MD to 175'MD. Monitor wellbore displacement via trip tank. 10/26/2015 10/26/2015 0.50 INTRM1 CASING SVRG P Service and inspect top drive,blocks 175.0 175.0 09:45 10:15 and power slips 10/26/2015 10/26/2015 1.25 INTRM1 CASING BHAH P Continue to lay down BHA from 175' 175.0 114.0 10:15 11:30 MD to 114'MD while monitoring wellbore displacement via trip tank. 10/26/2015 10/26/2015 0.25 INTRM1 CASING RGRP T 114'MD,trouble shoot pipe skate, 114.0 114.0 11:30 11:45 continue to monitor displacement via trip tank.Clean and clear rig floor. 10/26/2015 10/26/2015 1.00 INTRM1 CASING BHAH P Lay down BHA from 114'MD to 0'MD. 114.0 0.0 11:45 12:45 Break out bit(Grade: 1-2-CT-A-X-I- WT-TD) 10/26/2015 10/26/2015 0.50 INTRM1 CASING BHAH P Clear and clean floor 0.0 0.0 12:45 13:15 10/26/2015 10/26/2015 0.25 INTRM1 CASING RURD P Pull wear bushing 0.0 0.0 13:15 13:30 Page 10/29 Report Printed: 12/18/2015 0 Iterations Summary (with Timelogl pths) 01 1C-154 ConocoPhillps R Enka Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2015 10/26/2015 1.00 INTRM1 CASING RURD P Rig up to run casing and hold PJSM 0.0 0.0 13:30 14:30 for running casing. 10/26/2015 10/26/2015 0.75 INTRM1 CASING PUTB P Run in hole with float equipment to 0.0 177.0 14:30 15:15 177'MD.Check floats and obtain parameters @ 3 BPM with FO=13- 14%.4 BPM with FO=13-14%,5 BPM with FO=42%,6 BPM with 52%,7 BPM with 64%,and 8 BPM with FO=21%. 10/26/2015 10/26/2015 2.50 INTRM1 CASING PUTB P Continue to run in hole with 7-5/8" 177.0 2,430.0 15:15 17:45 29.7ppf L-80 Hydril 563 dopeless casing to 2430'MD.Fill on the fly and top off every 10 joints. Monitor displacement via Pit#2 and Pit#3. 10/26/2015 10/26/2015 2.50 INTRM1 CASING PUTB T Encounter obstruction @ 2430'MD, 2,430.0 2,636.0 17:45 20:15 set 30k down.Wash down from 2430' MD to 2450'MD. Pull up 30k over. Establish circuation at 6 BPM, SPP=220psi, FO=19%.Overpull and set down appears in 40'intervals. Continue to RIH to 2634'MD with 10- 30k drag.Encounter obstruction at 2634'MD.Work through obstruction stacking—55k with up to TQ=8k, RPM=10.Attempt with pumps on and off up to Flow=8 BPM,SPP=280psi. Parameters in shoe=RPM=10,TQ=2- 4k.Pu wt=99k,SO wt=95k 10/26/2015 10/26/2015 3.25 INTRM1 CASING PUTB P Continue to RIH with 7-5/8"29.7ppf, L- 2,636.0 5,570.0 20:15 23:30 80 Hydril 563 Dopeless casing from 2636'MD to 5570'MD.Fill on the fly and top off every 10 joints. Monitor displacement via Pit#2 and Pit#3. 10/26/2015 10/27/2015 0.50 INTRM1 CASING HOSO P Make up 7-5/8"casing hanger and 5,570.0 5,614.0 23:30 00:00 landing joint. Wash to bottom with Flow=3BPM,SPP=270psi, FO=19%. Land on depth at 5613.96'MD.Pu wt=154k,SO wt= 109k. 10/27/2015 10/27/2015 1.00 INTRM1 CEMENT CIRC P Continue circulating @ 6 bpm,295 5,614.0 5,614.0 00:00 01:00 psi, 19%flow out, P/U=154k, S/0=112k,reciprocate pipe from 5613' MD to 5595'MD.Pump total strokes= 2369.Shut down to R/U cement hose. 10/27/2015 10/27/2015 2.00 INTRM1 CEMENT CIRC P Establish circulation via cement hose, 5,614.0 5,614.0 01:00 03:00 continue circulating @ 6 bpm,295 psi, 18%flow out,P/U=154k,S/0=107k, reciprocate pipe from 5613'MD to 5595'MD.Pump 8167 total strokes, condition mud for cement job. SIMOPS-PJSM with SLB and DDI on cementing intermadiate casing. Page 11/29 Report Printed: 12/18/2015 of operations Summary (with Timelog epths) kz 1C-154 Conoo*Phi!hips Aka Aa Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/27/2015 10/27/2015 2.50 INTRM1 CEMENT CMNT P SLB pumped 5 bbl CW100,PT lines to 5,614.0 0.0 03:00 05:30 4000 psi.Continue pumping 15 bbl CW100 @ 5 bpm,370 psi, 15%flow out.SLB pumped 43.3 bbl 11.5 ppg Mud Push @ 5 bpm,320 psi, 15% flow out. Drop bottom Davis Lynch non-rotating plug,pump 43.6 bbl 15.8 ppg lead cement(with retarder)@ 2.1 bpm, 119 psi 16%flow out.Drop top Davis Lynch non-rotating plug,kick out with 10 bbl water.Swap to rig pumps and displace with 240 bbl 9.3 ppg LSND @ 6 bpm,790 psi, 16% flow out.Bump plug @ 2403 stks, pressure up 500 psi to 1290 psi and hold for 5 minutes.Bleed pressure to 0 psi,bled back 1.3 bbl.Check floats- good.Final P/U=154k,S/0=107k. CIP:05:12 hrs 10-27-15 10/27/2015 10/27/2015 0.75 INTRM1 CEMENT PRTS P Test casing to 3500 psi,pumped 1 0.0 0.0 05:30 06:15 bpm,39 stks to 3500 psi.Shut in and chart for 30 minuites,3.9 bbl bled back. 10/27/2015 10/27/2015 0.75 INTRM1 CEMENT RURD P Blow down cement line, Lay down 7- 0.0 0.0 06:15 07:00 5/8"landing joint, R/D and L/D Volant CRT. 10/27/2015 10/27/2015 2.50 INTRM1 CEMENT WWSP P Install 4"elevators,M/U 7-5/8"Vetco 0.0 0.0 07:00 09:30 casing packoff.Drain BOP stack,set 7 -5/8"packoff.Test to 5000 psi for 10 minutes.Clean cement valves. Perform weekly BOP ram function. 10/27/2015 10/27/2015 1.00 INTRM1 CEMENT RURD P PJSM and R/U to perform LOT on OA. 0.0 0.0 09:30 10:30 Install 13-1/2"OD, 12-1/4"ID 3.13' long wear bushing,install 4"bell guides and 4"backup dies on top drive. 10/27/2015 10/27/2015 1.50 INTRM1 CEMENT BHAH P PJSM,M/U 6-3/4"BHA#3 to 177'MD 0.0 177.0 10:30 12:00 10/27/2015 10/27/2015 1.00 INTRM1 CEMENT BHAH P Continue M/U BHA#3 from 177'MD 177.0 397.0 12:00 13:00 to 397'MD,change out PS-21 inserts. 10/27/2015 10/27/2015 0.75 INTRM1 CEMENT PULD P Trip in hole with doubles from pipe 397.0 1,345.0 13:00 13:45 shed from 397'MD to 1345'MD 10/27/2015 10/27/2015 1.00 INTRM1 CEMENT LOT P Perform 10-3/4"x 7-5/8"annular LOT 1,345.0 2,704.0 13:45 14:45 to 500 psi(13.3 ppg EMW).Pump on @ 13:48 hrs,off @ 14:07 hrs. Pressure up @.7 bpm, 11 bbl pumped,bled back 1.1 bbl.Continue to pump additional 13.4 bbl for 20 bbl total injected down OA.Bled off 3.5 bbl and shut in OA. 1 bpm=410 psi 1.5 bpm=380 psi 2 bpm=520 psi SIMOPS-Continue TIH with doubles form pipe shed from 1345'MD top 2704'MD. 10/27/2015 10/27/2015 1.00 INTRM1 CEMENT DHEQ P Shallow hole test MWD tools @ 220 2,704.0 2,704.0 14:45 15:45 gpm,920 psi, 14%flow out,40 rpm, 1.8k TQ.MWD not responding. 10/27/2015 10/27/2015 0.75 INTRM1 CEMENT PULD P Continue TIH with doubles from pipe 2,704.0 3,243.0 15:45 16:30 shed from 2704'MD to 3243'MD. Page 12/29 Report Printed: 12/18/2015 •perations Summary (with Timelogitpths) 0.:. 1C-154 o corwco`PhilIps At.Aa Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/27/2015 10/27/2015 2.00 INTRM1 CEMENT FRZP P R/U Little Red Services, PT lines to 3,243.0 5,425.0 16:30 18:30 2300 psi-good.Pump on @ 16:30 hrs,pumped 115 bbl water flush ICP @ 2.1 bpm=510 psi, FCP @ 2.1 bpm=750 psi.Start pumping ISOTHERM @ 17:38 hrs ICP @ 2 bpm=880 psi,FCP @ 2 bpm= 1310 psi. Pump off @ 18:23 hrs,total ISOTHERM pumped=96 bbl. SIMOPS-Continue TIH from 3243' MD to 5425'MD from derrick. 10/27/2015 10/27/2015 1.00 INTRM1 CEMENT SLPC P Slip and cut 63'of 6 x 19 Extra Imp 5,425.0 5,425.0 18:30 19:30 plow steel drill line. SIMOPS-Circulate @ 4 bpm,695 psi, 16%flow out. 10/27/2015 10/27/2015 0.50 INTRM1 CEMENT SVRG P Service top drive,calibrate Totco, 5,425.0 5,425.0 19:30 20:00 Amphion and SLB block height. SIMOPS-Circulate @ 4 bpm,685 psi, 16%flow out.Total strokes pumped 4533,Mud weight in/out 9.3 ppg. 10/27/2015 10/28/2015 4.00 INTRM1 CEMENT DRLG P Drill out float equipment to 5616,tag 5,425.0 5,616.0 20:00 00:00 cement stringer @ 5458'MD,top of cement @ 5469'MD.Drill cement @ 210 gpm, 1140 psi, 15%flow out,50 rpm,6-6.5K Tq,3K WOB,Tag top of plugs @ 5523'MD,tag top of shoe @ 5610'MD.Drill plugs with 230 gpm, 1670 psi,70-90 rpm,6.5-7K Tq.(45 min to drill plugs)Drill on shoe with 210 gpm, 1500 psi,70 rpm,6K Tq. P/U=121k,S/O=77k. SPR's @ 5605'MD,3850'TVD, 9.35 ppg,22:50 hrs #1-20 spm=540 psi,30 spm=710 psi #2-20 spm=580 psi,30 spm=720 psi 10/28/2015 10/28/2015 6.00 INTRM1 CEMENT DRLG T Attempt to continue to drill rathole and 5,616.0 5,619.0 00:00 06:00 open hole from 5616'MD.After drilling through the shoe @ 5614'MD,ROP stopped and would not drill ahead. Vary pump rates from 230 gpm-290 gpm,rotary from 35 rpm to 75 rpm, 10k WOB,occasionally stalling @ 10k Tq.5.5k off bottom torque. P/U=121k, 5/0=77k, ROT=93k. Pumped 23 bbl 11 ppg weighted sweep with nut plug to clean BHA and add some lubricity no affect. 10/28/2015 10/28/2015 0.50 INTRM1 CEMENT PMPO T Pump out of hole from 5619'MD to 5,619.0 5,619.0 06:00 06:30 5330'MD,230 gpm, 1445 psi, 16% flow out.RBIH from 5330'to 5619'in attempt to remove debris from bit/drill string. Page 13/29 Report Printed: 12/18/2015 01;' operations Summary (with Timelog epths) S ells 1 C-154 ill ConOCo`F'hiiiips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/28/2015 10/28/2015 0.50 INTRMI CEMENT DRLG T Continue to attempt drilling from 5619' 5,619.0 5,619.0 06:30 07:00 MD 230 gpm, 1520 psi,25%flow out, 70 rpm,7k Tq, 10k WOB,P/U=121k, S/O=77k, ROT=93k. No success moving forward. 10/28/2015 10/28/2015 0.50 INTRM1 CEMENT OWFF T Shut down,monitor well static 30 min 5,619.0 5,619.0 07:00 07:30 10/28/2015 10/28/2015 2.25 INTRM1 CEMENT TRIP T Pump 23 bbl dry job, POOH on 5,619.0 397.0 07:30 09:45 elevators from 5619'MD to 397'MD. 10/28/2015 10/28/2015 1.75 INTRM1 CEMENT BHAH T Continue POOH from 397'MD,stand 397.0 0.0 09:45 11:30 back 4"HWDP and 4%d'NMDC. PJSM and L/D BHA per SLB rep.Observe visible wear on power drive stab,bit looked good. 10/28/2015 10/28/2015 0.50 INTRM1 CEMENT BHAH T Clean and clear rig floor,drain stack, 0.0 0.0 11:30 12:00 function BOP rams. Mobilize BHA#4 OA pressure= 100 psi. 10%28/2015 10/28/2015 1.00 INTRM1 CEMENT SVRG T WOO for cleanout BHA,service 0.0 0.0 12:00 13:00 topdrive,perform PM's. 10/28/2015 10/28/2015 1.25 INTRM1 CEMENT BHAH T Program Sonicscope for BHA#4. 0.0 0.0 13:00 14:15 SIMOPS-Calibrate H2S and LEL gas sensors. 10/28/2015 10/28/2015 0.75 INTRM1 CEMENT BHAH T P/U cleanout BHA#4 to 313'MD. 0.0 313.0 14:15 15:00 Monitor displacement via pit#3.C/O PS-21 slip inserts. 10/28/2015 10/28/2015 1.50 INTRM1 CEMENT TRIP T Trip in hole with BHA#4 from 313'MD 313.0 2,656.0 15:00 16:30 to 2656'MD,fill pipe every 20 stands, monitor displacement via pit#3. 10/28/2015 10/28/2015 4.00 INTRM1 CEMENT DLOG P Trip in hole performing cement bond 2,656.0 5,562.0 16:30 20:30 log @ 900 fph form 2656'MD to 5562' MD.P/U= 110k,S/O=81k. 10/28/2015 10/28/2015 0.25 INTRM1 CEMENT REAM T Ream from 5562'MD to bottom @ 5,562.0 5,618.0 20:30 20:45 210 gpm,625 psi, 16%flow out,50 rpm,5k Tq.Tag bottom @ 5618'MD. 10/28/2015 10/28/2015 0.25 INTRM1 CEMENT DRLG T Drill junk from 5619'MD to 5621'MD 5,618.0 5,621.0 20:45 21:00 @ 210 gpm,625 psi, 16%flow out,70 rpm,7.5k Tq,put 15k WOB @ 5619' and observe torque and weight fall off @ 5620'MD-5621'MD. 10/28/2015 10/28/2015 0.50 INTRM1 CEMENT DDRL P Drill 63/a"production hole from 5621' 5,621.0 5,641.0 21:00 21:30 MD to 5641'MD,5858'TVD @ 250 gpm,775 psi, 16%flow out,90 rpm, 6.5k Tq, 19k WOB.ADT/ART=.6 hrs, Total Jar Hrs=148.1 hrs. 10/28/2015 10/28/2015 0.75 INTRM1CEMENT CIRC P CBU while Rotate and reciprocate 5,641.0 5,641.0 21:30 22:15 from 5640'MD to 5561'MD @ 350 gpm, 1270 psi,20%flow out,90 rpm, 5k Tq mud weight in/out 9.4 ppg.Total strokes pumped=2440.Observe shakers for drilled junk returns, nothing abnormal observed,Small aluminum chips,some small plastic chips and cement. 10/28/2015 10/28/2015 0.75 INTRM1 CEMENT RURD P Rack back stand to 5560', blow down 5,641.0 5,560.0 22:15 23:00 top drive and rig up for FIT. Flush lines. Page 14/29 Report Printed: 12/18/2015 operations Summary (with Timelog epths) 1C-154 Gon000`PhiIIips ms.Aw Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/28/2015 10/28/2015 0.50 INTRM1 CEMENT FIT P Perform FIT to 13.0 ppg EMW, 5,560.0 5,560.0 23:00 23:30 pumped 8 strokes to 722 psi,chart for 10 minutes and observe bleed down to 475 psi. Bled back.5 bbl. Blow down and rig down lines. 10/28/2015 10/29/2015 0.50 PROD1 DRILL DISP P Displace well to 9.4 ppg Flo Pro while 5,560.0 5,640.0 23:30 00:00 rotating and reciprocating from 5640' MD to 5561'MD @ 330 gpm, 1200 psio,20%flow out,70 rpm,5k Tq. OA pressure=125 psi 10/29/2015 10/29/2015 0.50 PROD1 DRILL DISP P Continue displacing well to 9.4 ppg Flo 5,640.0 5,640.0 00:00 00:30 Pro @ 330 gpm, 1160 psi,23%flow out,70 rpm,5k Tq.P/U=115k,S/0- , 82k, ROT=97k,Tq=3k after displacement. 10/29/2015 10/29/2015 0.50 PROD1 DRILL OWFF T Monitor well for flow-static. Pump 18 5,640.0 5,640.0 00:30 01:00 bbl 11.4 ppg Dry job @ 200 gpm,528 psi.Blow down top drive. 10/29/2015 10/29/2015 0.75 PROD1 DRILL TRIP T PJSM, POOH from 5531'MD to 4772' 5,640.0 4,772.0 01:00 01:45 MD. Pulled 15k over(130k)@ 5100' MD,SIO=83k.Continued pulling to 4772'MD,intermittantly seeing 10-15k overpull.Consult with drilling engineer. 10/29/2015 10/29/2015 1.25 PROD1 DRILL CIRC T Circulate 2 bottoms up @ 350 gpm, 4,772.0 4,772.0 01:45 03:00 1007 psi,20%flow out,70 rpm,4k Tq. P/U=112k,S/O=83k, ROT=87k. Total strokes pumped 3381 attempting to clean up obstruction.Observe nothing out of ordinary at shakers. 10/29/2015 10/29/2015 2.00 PROD1 DRILL TRIP T Continue POOH from 4772'MD to 4,772.0 313.0 03:00 05:00 313'MD.Observed 10k overpull @ 4020'MD,and again at 3300'MD. P/U=110k,S/O=84k, ROT=92k. 10/29/2015 10/29/2015 1.50 PROD1 DRILL BHAH T Monitor well @ BHA-static.C/O PS- 313.0 66.0 05:00 06:30 21 inserts to hand slips.Drain BOP stack and POOH from 313'MD, looking for debris or junk on BHA. Pulled up to 41',with bit at casing hanger and pulled 30k over.Could not work bit through 7-5/8"hanger.RIH to 66'MD,L/D 2 jts 4%"NMDC, P/U XO from 3%"IF to XT39 and 10'4"XT-39 DP pup joint.M/U to top drive. 10/29/2015 10/29/2015 1.00 PROD1 DRILL PMPO T Circulate @ 400 gpm to wash junk 66.0 0.0 06:30 07:30 uphole,422 psi,24%flow out,rotate 20 rpm,5k Tq.Circulate for 10 minutes to wash junk up stack to flowline.Slowly pull out of hole to surface while pumping and rotating, saw nothing as bit came throught the casing hanger or up stack.Observed no junk returns on shakers. 10/29/2015 10/29/2015 0.50 PROD1 DRILL BHAH T Break bit, P/U 2 jts 43/4'NMDC,stand 0.0 0.0 07:30 08:00 1 back stand. L/D Sonic tool. Page 15/29 Report Printed: 12/18/2015 operations Summary (with Timelog epths) Olt 1C-154 CorKxx Phillips A&xha Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/29/2015 10/29/2015 1.00 PROD1 DRILL WWWH T Suck out stack and inspect for junk- 0.0 0.0 08:00 09:00 nothing.RIH with 4"DP to 90', function test rams,circulate 840 gpm 150 psi,40%flow out 20 rpm to flush junbk from stack,observed nothing at shakers. Rack back DP,Flush flowline. 10/29/2015 10/29/2015 1.00 PROD1 DRILL BHAH T PJSM,M/U 6-%"drilling BHA#5 to 0.0 368.0 09:00 10:00 367.86'MD. Install 4"inserts in PS- 21's. 10/29/2015 10/29/2015 1.25 PROD1 DRILL TRIP T RIH from 368'MD to 2264'MD, 368.0 2,264.0 10:00 11:15 monitor displacement via TT. 10/29/2015 10/29/2015 0.50 PROD1 DRILL DHEQ T Shallow test MWD,210 gpm,878 psi, 2,264.0 2,264.0 11:15 11:45 17%flow out.Good detection.Shut down and blow down top drive. 10/29/2015 10/29/2015 0.25 PROD1 DRILL TRIP T Continue RIH from 2264'MD to 3118' 2,264.0 3,118.0 11:45 12:00 MD,P/U=86k,5/0=76k OA pressure=220 psi Losses for tour=0 bbl 10/29/2015 10/29/2015 1.50 PROD1 DRILL TRIP T Continue tripping in hole from 3118' 3,118.0 5,585.0 12:00 13:30 MD to 5585'MD,fill pipe every 20 stands,monitor displacement via trip tank. P/U=122k,S/0=78k. 10/29/2015 10/29/2015 0.25 PROD1 DRILL REAM T Obtain SPR's,ream to bottom @ 270 5,585.0 5,640.0 13:30 13:45 gpm, 1550 psi, 18%flow out,50 rpm, 6k Tq, 10.51 ppg ECD,tag bottom @ 5640.4'MD. SPR's @ 5600'MD,3857'TVD,9.4 ppg, 13:30 hrs. #1-20 spm=440 psi,30 spm=550 psi #2-20 spm=400 psi,30 spm=540 psi 10/29/2015 10/29/2015 4.25 PROD1 DRILL DDRL P Directional drill 6-3/4"production hole 5,640.0 5,726.0 13:45 18:00 from 5641'MD to 5726'MD,3865' TVD @ 270 gpm, 1960 psi, 19%flow out, 120 rpm,Tq on/off=6.5k/5k,2- 15k WOB, ECD=10.71 ppg, P/U=118k,5/0=79k, ROT=92k.Slow drilling due formation out top of West Sak. 10/29/2015 10/30/2015 6.00 PROD1 DRILL DDRL P Directional drill 6-%"production hole 5,726.0 6,246.0 18:00 00:00 from 5726'MD to 6246'MD,3871' TVD @ 280 gpm,2030 psi,21%flow out, 170 rpm,Tq on/off=6.5k/6k,2.5k WOB,ECD=11.12 ppg,P/U=121k, 5/0=76k,ROT=97k.ADT/ART=7.16 hrs,Total Bit hrs=7.16 hrs,Total Jar hrs=155.26 hrs.ROP increased to 225 fph,in West Sak D. OA pressure=140 psi Losses for tour=0 bbl. Page 16/29 Report Printed: 12/18/2015 •perations Summary (with Timelog epths) 03:5 1C-154 Conoov`PfiiIhps ALxL, Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/30/2015 10/30/2015 6.00 PROD1 DRILL DDRL P Directional drill 6-°A"production hole 6,246.0 6,920.0 00:00 06:00 from 6246'MD to 6920'MD,3870' TVD @ 280 gpm,2100 psi,20%flow out, 170 rpm,Tq on/off=6k/5.5k,3- 15k WOB, ECD=11.12 ppg, P/U=124k,S/O=70k,ROT=98k.Drill concretions w/15k WOB, 120 rpm @ 6493',6851'MD. SPR's @ 6625'MD,3858'TVD,9.4 ppg,02:30 hrs. #1-20 spm=520 psi,30 spm=740 psi #2-20 spm=460 psi,30 spm=640 psi 10/30/2015 10/30/2015 6.00 PROD1 DRILL DDRL P Directional drill 6-%"production hole 6,920.0 7,478.0 06:00 12:00 from 6920'MD to 7478'MD,3880' TVD @ 280 gpm,2260 psi,21%flow out, 160 rpm,Tq on/off=7.5k/6.5k,3k WOB, ECD=11.41 ppg,P/U=130k, S/O=69k,ROT=97k.ADT/ART=8.14 hrs,Total Bit hrs=15.3 hrs,Total Jar hrs=163.4 hrs. Drill out of zone @ 6880'MD at a down fault,re-entered at 6958'for 107'out of zone. SPR's @ 7093'MD,3878'TVD,9.4 ppg,08:30 hrs. #1-.20 spm=560 psi,30 spm=700 psi #2-20 spm=560 psi,30 spm=700 psi OA pressure=240 psi,losses for tour=0 bbl. 10/30/2015 10/30/2015 6.00 PROD1 DRILL DDRL P Directional drill 6'%"production hole 7,478.0 8,140.0 12:00 18:00 from 7478'MD to 8140'MD,3870' TVD @ 280 gpm,2245 psi,20%flow out, 160 rpm,Tq on/off=6-8k/8k, 1k WOB, ECD=11.55 ppg, P/U=140k, S/O=60k, ROT=96k.ADT/ART=4.2 hrs,Total Bit hrs=19.5 hrs,Total Jar hrs= 167.6 hrs. Drill concretions @ 7672',7718',7734',7750',7765', 7812',7828',7846',7862',7873', 7892',8114'MD. SPR's @ 7478'MD,3880'TVD,9.4 ppg, 12:00 hrs. #1-20 spm=620 psi,30 spm=780 psi #2-20 spm=520 psi,30 spm=720 psi Page 17/29 Report Printed: 12/18/2015 Iperations Summary (with Timeloglpths) 0;', a 1C-154 ConnmPhil lips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) ',End Depth(ftKB) 10/30/2015 10/31/2015 6.00 PROD1 DRILL DDRL P Directional drill 6-V4'production hole 8,140.0 9,001.0 18:00 00:00 from 8140'MD to 9001'MD,3872' TVD @ 280 gpm,2408 psi,22%flow out, 180 rpm,Tq on/off=9k/8k,2k WOB,ECD=11.78 ppg,P/U=144k, S/O=53k,ROT=102k.ADT/ART=3.95 hrs,Total Bit hrs=24.3 hrs,Total Jar hrs= 171.5 hrs.Drill concretions© 8143',8452',8486',8521',8570', 8669',8675'MD. SPR's @ 8234'MD,3868'TVD,9.45 ppg, 18:30 hrs. #1-20 spm=590 psi,30 spm=740 psi #2-20 spm=540 psi,30 spm=740 psi Losses for tour/day=0 bbl. 10/31/2015 10/31/2015 6.00 PROD1 DRILL DDRL P Directional drill 6-3/4'production hole 9,001.0 9,934.0 00:00 06:00 from 9001'MD to 9934'MD,3870' TVD @ 280 gpm,2420 psi,21%flow out, 180 rpm,Tq on/off=10k/8k,2k WOB, ECD=11.78 ppg, P/U=142k, S/O=45k, ROT=101k. Drill concretions @ 9399',9423',9468',9781',9793', 9803'MD. ROP 250-300 fph. 10/31/2015 10/31/2015 6.00 PROD1 DRILL DDRL P Directional drill 6'3/4'production hole 9,934.0 10,707.0 06:00 12:00 from 9934'MD to 10707'MD,3872' TVD @ 280 gpm,2582 psi,21%flow out,200 rpm,Tq on/off= 10k/8.6k,2k WOB,ECD=11.9 ppg, P/U=146k, S/O=40k, ROT=100k.ADT/ART=6.83 hrs,Total Bit hrs=31.13 hrs,Total Jar hrs= 178.33 hrs. Drill concretions @ 10110', 10139', 10386', 10394', 10456', 10627'MD. ROP 250-300 fph SPR's @ 10707'MD,3872'TVD,9.4 ppg, 12:00 hrs. #1-20 spm=690 psi,30 spm=880 psi #2-20 spm=740 psi,30 spm=890 psi Losses for tour=0 bbl OA pressure=175 psi. 10/31/2015 10/31/2015 7.75 PROD1 DRILL DDRL P Directional drill 6'/4"production hole 10,707.0 11,183.0 12:00 19:45 from 10707'MD to 11183'MD,3850' TVD @ 265 gpm,2600 psi, 19%flow out, 160 rpm,Tq on/off=9.5k/9.5k, 1.5k WOB,ECD=12.31 ppg, P/U=137k,S/O=40k,ROT=97k. ADT/ART=4.32 hrs,Total Bit hrs=35.45 hrs,Total Jar hrs= 182.65 hrs.Experiencing losses @ 40 bph @ 12.3 ppg ECD,observe well breathing back on connections. ROP reduced to 90-100 fph, monitoring losses. Drilled out of zone© 10697'-10820' MD. Page 18/29 Report Printed: 12/18/2015 Iperations Summary (with Timelog•pths) 0 1C-154 ConocoPhillips A Imk. Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/31/2015 10/31/2015 2.50 PROD1 DRILL CIRC T Circulate while rotate and reciprocate, 11,183.0 11,183.0 19:45 22:15 ream 3 stands from 11183'to 10900' MD @ 280 gpm,2615 psi, 19%flow out, 140-180 rpm,9k Tq.Circulate to clean hole and reduce ECD due to wellbore breathing @ 12.2-12.3 ppg ECD. Initial ECD 12.31 ppg @ 250 gpm,final ECD 11.8 ppg @ 250 gpm, 11.9 ppg @ 280 gpm.Total stokes pumped 9300-2.8 bottoms up, shakers cleaned up. Perform 100 bbl mud dilution while ciculating. Mud weight in=9.4 ppg, out 9.5 ppg. 10/31/2015 11/1/2015 1.75 PROD1 DRILL DDRL P Directional drill 6-%"production hole 11,183.0 11,278.0 22:15 00:00 from 11183'MD to 11278'MD,3846' TVD @ 280 gpm,2640 psi,20%flow out, 160 rpm,Tq on/off=9.5k/9k,3k WOB,ECD=12.07 ppg, P/U=135k, S/O=<40k,ROT=96k.ADT/ART=1.3 hrs,Total Bit hrs=37.75 hrs,Total Jar hrs=184.95 hrs. Losses @ 15 bph @ 12.0 ppg ECD,still observing well breathing back on connections briefly. Drill concretions @ 11217', 11225', 11256'MD. ROP reduced to 110 fph to maintain ECD below 12.2 ppg. Losses for tour=78 bbl OA pressure=175 psi. 11/1/2015 11/1/2015 5.00 PROD1 DRILL DDRL P Directional drill 6-%"production hole 11,278.0 11,698.0 00:00 05:00 from 11278'MD to 11698'MD,3860' TVD @ 280 gpm,2716 psi,20%flow out, 150-180 rpm,Tq on/off=9.5k/9k, 2-3k WOB,ECD=12.13 ppg, P/U=148k,S/O=<40k,ROT=103k. Losses @<10 bph,observe well breathing back slightly on connections. Drill concretions @ 11411', 11520', 11544', 11556'11564', 11571', 11595', 11649', 11652'MD. SPR's @ 11467'MD,3842'TVD,9.4 ppg,01:45 hrs #1-20 spm=740 psi,30 spm=890 psi #2-20 spm=640 psi,30 spm=860 psi 11/1/2015 11/1/2015 0.25 PROD1 DRILL SVRG P Service rig 11,698.0 11,698.0 05:00 05:15 11/1/2015 11/1/2015 6.75 PROD1 DRILL DDRL P Directional drill 6-%"production hole 11,698.0 11,967.0 05:15 12:00 from 11698'MD to 11967'MD,3850' TVD @ 280 gpm,2870 psi,20%flow out, 150 rpm,Tq on/off=9k/9k,2k WOB, ECD=12.31 ppg,P/U=148k, S/O=<40k,ROT=103k.ADT/ART= 9.95 hrs,Total Bit hrs=47.7 hrs,Total Jar hrs=195.75 hrs.Losses @<15 bph.Observing well breathing back on connections briefly.No concretions. Losses for tour=80 bbl OA pressure=200 psi. Page 19/29 Report Printed: 12/18/2015 V 0 Sperations Summary (with Timeloglipths) 0 1C-154 conoca`Philbps AGxAn Rig: DOYON 25 Job: DRILLING ORIGINAL,, Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/1/2015 11/1/2015 6.00 PROD1 DRILL DDRL P Directional drill 6-%"production hole 11,967.0 12,277.0 12:00 18:00 from 11967'MD to 12277'MD,3844' TVD @ 280 gpm,3060 psi,21%flow out, 140 rpm,Tq on/off= 10k/9.5k,3k WOB,ECD=12.73 ppg, P/U=153k, S/O=<40k,ROT=101k.ADT/ART=4.8 hrs,Total Bit hrs=52.5 hrs,Total Jar hrs=200.55 hrs. Losses @+-15 bph. Observing well breathing back on connections.No concretions. SPR's @ 12031'MD,3851'TVD,9.4 ppg, 13:20 hrs #1-20 spm=850 psi,30 spm=1040 psi #2-20 spm=810 psi,30 spm=1020 psi 11/1/2015 11/2/2015 6.00 PROD1 DRILL DDRL P Directional drill 6-%"production hole 12,277.0 12,616.0 18:00 00:00 from 12277'MD to 12616'MD,3848' TVD @ 280 gpm,2980 psi, 19%flow out, 140 rpm,Tq on/off=10.5k/10k,3k WOB,ECD=12.44 ppg,P/U=163k, S/O=<40k, ROT=99k.ADT/ART=4.19 hrs,Total Bit hrs=56.69 hrs,Total Jar hrs=204.74 hrs.ECD reduced via mud dilution,losses @<15 bph. Observing well breathing back slightly on connections. Drill concretions @ 12323', 12570'MD. Losses for tour=78 bbl OA pressure=210 psi. 11/2/2015 11/2/2015 0.50 PROD1 DRILL DDRL P Directional drill 6-%"production hole 12,616.0 12,680.0 00:00 00:30 from 12616'MD to section TD, 12680' MD,3848'TVD @ 280 gpm,2995 psi, 20%flow out, 140 rpm,Tq on/off= 10.5k/10k,2k WOB,ECD=12.5 ppg, P/U=167k,S/O=<40k, ROT=107k. ADT/ART=.6 hrs,Total Bit hrs=57.29 hrs,Total Jar hrs=205.34 hrs. 11/2/2015 11/2/2015 2.00 PROD1 CASING CIRC P Circulate until shakers cleaned up 1.5 12,680.0 12,585.0 00:30 02:30 bottoms up,290 gpm @ 3154 psi, 140 -180 rpm, 10-11k Tq. Rack back a stand after 1 bottom up. SPR's @ 12680'MD,3848'TVD,9.45 ppg,01:28 hrs #1-20 spm=760 psi,30 spm=940 psi #2-20 spm=660 psi,30 spm=940 psi 11/2/2015 11/2/2015 3.50 PROD1 CASING BKRM P Backream out of hole from 12585'MD 12,585.0 10,707.0 02:30 06:00 to 10707'MD,280 gpm,2640 psi, 19%flow out, 140 rpm,8-9k Tq. Page 20/29 Report Printed: 12/18/2015 .:! 01 •perations Summary (with Timelog'ffepths) 1C-154 Conoco`Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/2/2015 11/2/2015 4.00 PROD1 CASING JAR T Backream from 10707'to 10634'MD, 10,707.0 10,634.0 06:00 10:00 torqued up and stalled out at 16k. Observed no pressure increase,ECD spike or flow restriction.Let torque out of pipe,attempt to move down or up without success.Slack off to block weight,no movement,pulled 50k over, no movement.Reduce pump rate to 5 spm,work pipe up and down attempting to cock jars.never saw movement of jars. 11/2/2015 11/2/2015 2.00 PROD1 CASING JAR T Pump at 280 gpm,2560 psi,rotate 10,634.0 10,634.0 10:00 12:00 pipe up to 19k and hold,work string up and down to get get torque down to suspected stuck spot.Suspect stuck at the shoe.Work pipe up and down, torquing up and letting out attempting to move without success. Mud loss to formation=59 bbl OA pressure= 180 psi 11/2/2015 11/2/2015 5.00 PROD1 CASING JAR T Continue to work pipe,torque string 10,634.0 10,635.0 12:00 17:00 up to 22k,26 turns total.Work torque down,work pipe between 40k-99k hookload attempting to cock jars.Let out torque and attempt same,with and without pumps @ 22 gpm,240 psi up to 280 gpm,2520 psi.Gained 1'down while working pipe. 11/2/2015 11/2/2015 4.00 PROD1 CASING JAR T Jar down,cock jars with 150k 10,635.0 10,707.0 17:00 21:00 hookload,set down to 40k with rotary ©25 rpm to stall @ 22k to transfer wt. Jar down with and without rotary, gained another 1'while jarring. Stopped making any headway. Increase torque to 24k and work pipe between 40-99k,increase pump rate to 215 gpm for MWD detection of toolface.Observe string break free @ 20:55 hrs,run stand in the hole with 215 gpm, 1775 psi 17%flow out. Increase rotary to 50 rpm,7.5k Tq. 11/2/2015 11/2/2015 2.00 PROD1 CASING CIRC T CBU while rotate and reciprocate from 10,707.0 10,707.0 21:00 23:00 10,707'MD to 10687'MD,RIH 1 stand and continue CBU while R&R from 10707'MD to 10800'MD @ 280 gpm, 2670 psi, 19%flow out, 180 rpm,8k Tq, ECD=11.84 ppg,Total strokes pumped=8184,mud weight in/out 9.5 ppg.String in additional 1% SAFELUBE while circulating. 11/2/2015 11/3/2015 1.00 PROD1 CASING BKRM P Continue backreaming out of hole 10,707.0 10,520.0 23:00 00:00 from 10707'@ 280 gpm,2470 psi, 18%flow out, 140 rpm,8k Tq, ECD=11.55 ppg,500 fph pulling speed to 10520'MD. Ream through section 10695'-10610'twice,observe no obstruction at all on either pass. Losses for tour=42 bbl OA pressure= 140 psi Page 21/29 Report Printed: 12/18/2015 •perations Summary (with Timelog•pths) 0.111114 1C-154 Conoco`ehilliips AI:r.Aa Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/3/2015 11/3/2015 6.00 PROD1 CASING BKRM P Backream out of hole form 10520'MD 10,520.0 8,103.0 00:00 06:00 to 8103'MD,280 gpm,2200 psi, 18% flow out, 140 rpm,7k Tq,Calc Disp=13.5 bbl Actual Disp=41.7 bbl. Average loss rate=5 bph.Start backreaming @ 500 fph,increase to 900 fph using caution. 11/3/2015 11/3/2015 6.00 PROD1 CASING BKRM P Continue backreaming out of hole 8,103.0 5,678.0 06:00 12:00 from 8103'MD to 5678'MD,280 gpm, 1894 psi, 18%flow out, 140 rpm,6k Tq,pulling speed 900 fph.Average loss rate=5 bph. Total fluid lost for tour=55 bbl OA pressure=160 psi 11/3/2015 11/3/2015 0.50 PROD1 CASING BKRM P Continue backreaming out of hole 5,678.0 5,585.0 12:00 12:30 from 5678'MD to 5585'MD,280 gpm, 1870 psi, 18%flow out, 140 rpm,6-7k Tq.Backream inside shoe,shut down pump and rotary,work BHA thru shoe with no obstruction.P/U=124k, S/O=74k. 11/3/2015 11/3/2015 1.00 PROD1 CASING CIRC P Circulate 2 bottoms up while rotate 5,585.0 5,585.0 12:30 13:30 and reciprocating from 5580'to 5485' MD,285 gpm, 1950 psi, 19%flow out, 90 rpm,5.5k Tq.Total strokes pumped 4370,Mud wt in/out=9.4 ppg. P/U=121 k,5/0=81k.Shakers cleaned up good. 11/3/2015 11/3/2015 0.75 PROD1 CASING OWFF P Monitor well for 30 minutes-static with 5,585.0 5,585.0 13:30 14:15 slight drop-3". 11/3/2015 11/3/2015 0.25 PROD1 CASING CIRC P Pump 30 bbl 11 ppg dry job,blow 5,585.0 5,585.0 14:15 14:30 down top drive. 11/3/2015 11/3/2015 2.25 PROD1 CASING TRIP P POOH on elevators from 5585'MD to 5,585.0 367.0 14:30 16:45 367'MD,monitor displacement via trip tank. P/U=48k,S/O=54k. 11/3/2015 11/3/2015 0.25 PROD1 CASING OWFF P Monitor well for 10 min @ BHA,2" 367.0 367.0 16:45 17:00 drop.C/O PS-21 inserts. 11/3/2015 11/3/2015 1.50 PROD1 CASING BHAH P Lay down HWDP,Jars and BHA#5 as 367.0 0.0 17:00 18:30 per DD from 367'MD to surface. No abnormal wear observed on BHA. Observed excessive torque to break out bit(16-18k),indicating BHA was stuck @ the bit. 11/3/2015 11/3/2015 0.75 PROD1 CASING BHAH P Clean and clear rig floor,perform 0.0 0.0 18:30 19:15 derrick inspection. 11/3/2015 11/3/2015 0.50 COMPZN CASING OTHR P M/U liner hanger,ZXP,seal bore and 0.0 0.0 19:15 19:45 rack back in derrick with single of DP on top. 11/3/2015 11/3/2015 0.75 COMPZN CASING RURD P R/U for P/U and run liner,verify count 0.0 0.0 19:45 20:30 in pipe/casing shed.Hold PJSM for running liner with DDI rig crew,CPAI rep,BOT completion rep,GBR casing. Page 22/29 Report Printed: 12/18/2015 Iperations Summary (with Timelog9e pths) 0 tz 1C-154 Cono `P aohilhps Akr.ka Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/3/2015 11/4/2015 3.50 COMPZN CASING PUTB P P/U and RIH with 4V2'11.6#L-80 IBT- 0.0 4,248.0 20:30 00:00 M slotted liner with 6.38"Baker water activated swell packers and 4'/z' blanks per running order to 4248'MD. Monitor displacement via trip tank, losses<2 bph.Swell A in the hole @ 22:15, B @ 22:35 hrs. OA pressure=140 psi Total lost for tour=5 bbl 11/4/2015 11/4/2015 2.75 COMPZN CASING PUTB P Continue P/U and RIH with 4W 11.6# 4,248.0 7,118.0 00:00 02:45 L-80 IBT-M slotted liner with 6.38" Baker water activated swell packers and 4'/2'blanks per running order from 4248'MD to 7118'MD. Monitor displacement via trip tank,losses<2 bph.Swell'C'in the hole @ 01:05,'D' @ 01:25,'E'@ 02:15 hrs.Calculated Disp=30.4 bbl,Actual Disp=24.3 bbl. 11/4/2015 11/4/2015 0.75 COMPZN CASING OTHR P P/U ZXP,liner hanger and seal bore 7,118.0 7,278.0 02:45 03:30 assy from derrick, M/U to liner. Mix up Pal Mix and fill liner top. RIH,P/U single out of shed.M/U to top drive and stage up to 2 bpm to verify flow path.Obtain P/U=99k and S/O=68k weights.2 bpm @ 90 psi. 11/4/2015 11/4/2015 3.50 COMPZN CASING RUNL P RIH with liner on 4"DP with super 7,278.0 12,567.0 03:30 07:00 sliders,4"DP and HWDP from 7278' MD to 12567'MD. P/U=155k, S/O=65k,Calc Disp=33.3 bbl,Actual Disp=31.7 bbl. 11/4/2015 11/4/2015 1.00 COMPZN CASING PACK P Wash down last stand @ 2 bpm,370 12,567.0 12,639.0 07:00 08:00 psi,drop 1.25"hanger setting ball and pump down @ 2 bpm,slack off 5'past set depth and P/U to setting depth @ 12639'MD,placing string in tension. Ball on seat,pressure up to 3500 psi, slack off 100k to block wt setting liner hanger. Bleed pressure off to 0,P/U and observe breakover @ 120k.P/U 4'to expose setting dogs,set down 50k while rotating 10 rpm 3.5k Tq, setting ZXP packer. Liner shoe @ 12641'MD,3849.8'TVD.Top of liner @ 5435.03'MD,3845.8'TVD 11/4/2015 11/4/2015 1.00 COMPZN CASING PRTS P R/U and pressure test Packer/ 12,639.0 5,426.0 08:00 09:00 annulus to 3500 psi for 30 minutes charted.Bleed pressure to 0 psi,blow down top drive and kill line,rig down test equipment. 11/4/2015 11/4/2015 1.25 COMPZN WELLPR PULD P POOH laying down 33 jts 4"HWDP 5,426.0 4,335.0 09:00 10:15 from 5426'MD to 4335'MD, P/U=96k, 5/0=72k,monitor fill with trip tank. Losses @ 2 bph. 11/4/2015 11/4/2015 1.75 COMPZN WELLPR PULD P Continue POOH laying down 4"DP 4,335.0 3,197.0 10:15 12:00 (35 jts) from 4335'MD to 3197'MD, P/U=85k,S/O=70k. Monitor hole fill with trip tank,losses @ 2 bph. OA pressure= 140 psi Losses for tour=14 bbl Page 23/29 Report Printed: 12/18/2015 v iterations Summary (with Timeloggepths) 0 ng gells 1C-154 Conoao`Phiilliips ALr.An Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/4/2015 11/4/2015 5.00 COMPZN WELLPR PULD P Continue POOH laying down 4"DP 1 3,197.0 0.0 12:00 17:00 x 1 (100 jts)from 3197'MD to surface, removing super sliders.Monitor hole fill with trip tank,losses @ 2 bph. 11/4/2015 11/4/2015 0.50 COMPZN WELLPR BHAH P Lay down liner running epuipment as 0.0 0.0 17:00 17:30 per Baker completions rep. 11/4/2015 11/4/2015 0.50 COMPZN WELLPR RURD P Clean and clear rig floor,prep to RIH 0.0 0.0 17:30 18:00 with 4"DP. 11/4/2015 11/4/2015 2.00 COMPZN WELLPR TRIP P M/U mule shoe and RIH to 55 stands 0.0 5,218.0 18:00 20:00 5218'MD,monitor well via trip tank. 11/4/2015 11/4/2015 2.00 COMPZN WELLPR PULD P POOH,laying down 20 each doubles 5,218.0 3,510.0 20:00 22:00 and singles,breaking,inspect and re- torque all connections before laying down doubles. 11/4/2015 11/4/2015 1.00 COMPZN WELLPR TRIP P RIH from 3510'MD to 5410'MD with 3,510.0 5,410.0 22:00 23:00 remaining 20 stands. 11/4/2015 11/5/2015 1.00 COMPZN WELLPR SLPC P Cut and slip 94'drilling line.Monitor 5,410.0 5,410.0 23:00 00:00 well via trip tank,<2 bph static loss. Total losses for tour=8.2 bbl. 11/5/2015 11/5/2015 0.50 COMPZN WELLPR SLPC P Continue and finish up slip and cut 5,410.0 5,410.0 00:00 00:30 operation.Calibrate block height on Totco and Amphion systems 11/5/2015 11/5/2015 0.50 COMPZN WELLPR SVRG P Lubricate rig,perform PM's and DW's 5,410.0 5,410.0 00:30 01:00 on deadman.Check hydraulic oil on topdrive. 11/5/2015 11/5/2015 1.00 COMPZN WELLPR DISP P PJSM,displace well to 9.4 ppg brine. 5,410.0 5,410.0 01:00 02:00 Pump 41 bbl DeepClean pill,69 bbp HiVis HEC pill,chased with 9.4 ppg brine until cleaned up at shakers. Displaced at 420 gpm, 1030 psi.Shut down. 11/5/2015 11/5/2015 0.50 COMPZN WELLPR OWFF 'P Blow down top drive and observe well 5,410.0 5,410.0 02:00 02:30 static for 30 minutes,very slight-2" drop. 11/5/2015 11/5/2015 5.50 COMPZN WELLPR PULD P POOH laying down 4"drill pipe in 5,410.0 0.0 02:30 08:00 singles and doubles. Breaking, inspecting and re-torquing connections on doubles,culling 4"drill pipe that needs new hardbanding. Total 49 doubles in pipe shed tubs. 11/5/2015 11/5/2015 0.50 COMPZN RPCOMP RURD P Make up wear ring puller,J in to wear 0.0 0.0 08:00 08:30 ring,back out lock down screws and pull wear ring. 11/5/2015 11/5/2015 0.75 COMPZN RPCOMP WWWH P Make up stack washer on bottom of 0.0 0.0 08:30 09:15 double,wash stack @ 8 bpm 40 psi. Blow down top drive and lay down tools. 11/5/2015 11/5/2015 0.75 COMPZN RPCOMP RURD P Rig up to run 4W Hydril 563 tubing 0.0 0.0 09:15 10:00 completion.Make up well control XO to TIW valve,bring space out pups to rig floor,verify pipe count and jewelry in correct order. 11/5/2015 11/5/2015 0.25 COMPZN RPCOMP SFTY P PJSM on running tubing completion 0.0 0.0 10:00 10:15 with DDI rig crew,CPAI rep,GBR casing crew and Baker completions rep. Page 24/29 Report Printed: 12/18/2015 iterations Summary (with Timelog�epths) 1C-154 Cono0 aco Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/5/2015 11/5/2015 1.25 COMPZN RPCOMP PUTB P Run 4'W L-80 12.6#Hydril 563 orange 0.0 1,312.0 10:15 11:30 peel shoe and tubing to 1312'MD as per running order. P/U=45k,S/O=52k. Torquing all connections to 3800 ft/lbs. OA pressure=140 psi. Losses for tour= 10 bbl 11/5/2015 11/5/2015 2.75 COMPZN RPCOMP PUTB P Continue running 4'W Hydril 563 1,312.0 4,791.0 11:30 14:15 upper completionwith 2 GLM's and 1 nipple as per detail from 1312'MD to 4791'MD,torquing all connections to 3800 ft/lbs. 11/5/2015 11/5/2015 1.00 COMPZN RPCOMP SFTY P Hold Safety stand up with rig crew, 4,791.0 4,791.0 14:15 15:15 service hands and 3rd party hands on location. 11/5/2015 11/5/2015 1.25 COMPZN RPCOMP PUTB P Continue RIH with 4W completion per 4,791.0 5,460.0 15:15 16:30 detail from 4791'MD to 5460'MD, torque all connections to 3800 ft/lbs, monitor displacement via trip tank. 11/5/2015 11/5/2015 1.00 COMPZN RPCOMP HOSO P Pump down joint 131 @ 2 bpm, 100 5,460.0 5,380.0 16:30 17:30 psi 9%flow out.Observe pressure increase to 130 psi @ 8W down as seals enter seal bore.Shut down pump and continue down to fully locate on no-go @ 5484.14'MD'.Lay down jts 131, 130 and 129.Blow down top drive.P/U 2 space out pups,(9.83' and 9.84'). P/U tubing hanger with full joint below,M/U landing joint. P/U=92k,S/O=76k. 11/5/2015 11/5/2015 1.00 COMPZN RPCOMP CRIH P Reverse circulate in 55 bbl corrosion 5,380.0 5,380.0 17:30 18:30 inhibited brine,chase with 95 bbl straight 9.4 ppg brine @ 4 bpm,260 psi. 11/5/2015 11/5/2015 1.25 COMPZN RPCOMP THGR P Drain stack,sting into seal bore,land 5,464.0 5,464.0 18:30 19:45 hanger and run in lock down screws. Slack off prior to landing 76k.Tubing landed @ 19:20 hrs,seal assy mule shoe @ 5464.20'MD,4.52'off fully located. 11/5/2015 11/5/2015 0.75 COMPZN RPCOMP THGR P Test upper and lower hanger seal to 5,464.0 5,464.0 19:45 20:30 5000 psi for 10 minutes each. 11/5/2015 11/5/2015 0.25 COMPZN RPCOMP PRTS P Pressure test IA to 1000 psi for 10 5,464.0 5,464.0 20:30 20:45 minutes to verify seals engaged. 11/5/2015 11/5/2015 1.25 COMPZN RPCOMP PRTS T Drop 1-5/16"ball and rod w/rollers and 5,464.0 5,464.0 20:45 22:00 let fall for 10 minutes.Attempt to pressure up on tubing. Pressure up to 650 psi(9 stks)and observe pressure fall off,continuie to pump 3.3 bbl @ 1.5 bpm,pressure slowly rise to 430 psi.Bleed off and wait 10 more minutes for ball/rod to fall.Pump additional 5 bbl @ 1.5 bpm,530 psi no pressure build.Shut down and bleed again.Third attempt ramped pump up to 4.5 bpm briefly,keeping pressure below 650 psi,slowed pump to 3 bpm, pumped total 10 bbl without observing ball on seat. Page 25/29 Report Printed: 12/18/2015 of ex Iperations Summary (with Timelog•pths) 1C-154 Conodihilhps *mak. Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/5/2015 11/6/2015 2.00 COMPZN RPCOMP WAIT T Wait on slickline,prep tools for nipple 5,464.0 5,464.0 22:00 00:00 down.Prep rig for rig move.Complete PM's,misc housekeeping projects. OA pressure=80 psi 11/6/2015 11/6/2015 2.50 COMPZN RPCOMP WAIT T Wait on Slickline,complete PM's,misc 5,464.0 5,464.0 00:00 02:30 housekeeping on rig.Clean pits,lay mats and prep pad for move. 11/6/2015 11/6/2015 1.00 COMPZN RPCOMP • SFTY P Safety stand up with oncoming rig 5,464.0 5,464.0 02:30 03:30 crew,reviewing recent incidents, seasonal changes,review of PREP Alaska and success triangle. 11/6/2015 11/6/2015 2.50 COMPZN RPCOMP WAIT T Continue waiting on Slickline, 5,464.0 5,464.0 03:30 06:00 complete PM's,misc housekeeping on rig.Clean pits,lay mats and prep pad for move.Slickline arrive on location 04:00 hrs,return to Y pad for tooling to fish ball/rod. 11/6/2015 11/6/2015 3.75 COMPZN RPCOMP SLKL T R/U Slickline,attempt to find ball and 5,464.0 5,464.0 06:00 09:45 rod to put on seat and pressure test. Did not tag up where expected @ 4922'MD,RIH to—5199'wireline depth,latch on and retrieve ball/rod. 11/6/2015 11/6/2015 2.25 COMPZN RPCOMP SLKL T Order XO for slickline to run in and 5,464.0 5,464.0 09:45 12:00 pull RHC plug body,could not locate XO.Rig down line wiper with side entry sub,re-install on XO's 4'W IBTM to 3'W EUE 8rd to 4%'Otis.M/U RHC retrieval tool and RIH with slickline to fish RHC plug body. 11/6/2015 11/6/2015 3.25 COMPZN RPCOMP SLKL T Continue RIH with slickline to fish 5,464.0 5,464.0 12:00 15:15 RHC,successful on second attempt.Retrieved RHC plug body, observe body does not have DB-6 no- go lock,only collet lock. 11/6/2015 11/6/2015 1.25 COMPZN RPCOMP SLKL T RIH with slickline,set CAT standing 5,464.0 5,464.0 15:15 16:30 valve to test tubing.POOH with slickline. Rig down slickline XO's. 11/6/2015 11/6/2015 0.50 COMPZN RPCOMP PRTS T Rig up head pin and cement hose, 5,464.0 5,464.0 16:30 17:00 pressure test standing valve to 1000 psi for 5 minutes.Blow down cement lines. 11/6/2015 11/6/2015 0.50 COMPZN RPCOMP SLKL T . down HES tools and sheaves, 5,464.0 5,464.0 17:00 17:30 release slickline. 11/6/2015 11/6/2015 0.75 COMPZN RPCOMP SFTY P Safety stand up with oncoming rig 5,464.0 5,464.0 17:30 18:15 crew,reviewing recent incidents, seasonal changes,review of PREP Alaska and success triangle. 11/6/22015 11/6/2015 3.75 COMPZN RPCOMP PRTS T Rig up to test tubing to 3500 psi for 30 5,464.0 5,464.0 18:15 22:00 minutes charted. Pressure gradually falling.Troubleshoot all surface equipment.Change o-ring on landing joint,still bleeding off.Monitor IA pressure no significant change,no surface leaks detected. Isolate rig pump system,line up only to test pump.Break off head pin and observe brine falling in the tubing,determine the CAT standing valve is leaking. Fluid loss to formation.3 bph. Page 26/29 Report Printed: 12/18/2015 4110 Of; iterations Summary (with TimelogSepths) a 1C-154 conoc&hilh"ps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/6/2015 11/7/2015 2.00 COMPZN RPCOMP WAIT T Wait on Slickline to pull CAT standing 5,464.0 5,464.0 22:00 00:00 valve and replace with positive seal plug.Continue working on MP-2's, housekeeping and ensure rig is ready to move.Prep/plan for surface hole drilling. OA pressure=80 psi 11/7/2015 11/7/2015 5.50 COMPZN RPCOMP WAIT T Wait on Slickline to pull standing valve 5,464.0 5,464.0 00:00 05:30 and replace. Perform equipment PM's, change saver sub from XT39 to 41,4 IF for surface hole on 155. 11/7/2015 11/7/2015 2.75 COMPZN 'RPCOMP SLKL T Rig up HES Slickline equipment.M/U 5,464.0 5,464.0 05:30 08:15 retrieval tool,RIH with Slickline and pull standing valve from 4926',replace with new valve. 11/7/2015 11/7/2015 1.50 COMPZN RPCOMP PRTS P Line up to pump down tubing,top off 5,464.0 5,464.0 08:15 09:45 landing joint with 9.4 ppg brine,bleed air from surface lines.Pressure up tubing to 3500 psi,hold for 30 minutes on chart,good test.Bleed tubing to 2000 psi and shut in,pressure test 7- 5/8"x 4-1/2"IA to 3000 psi for 30 minutes charted.Good test. 11/7/2015 11/7/2015 1.00 COMPZN RPCOMP SLKL T HES slickline release from standing 5,464.0 5,464.0 09:45 10:45 valve and POOH. Rig down slickline equipment. 11/7/2015 11/7/2015 0.50 COMPZN RPCOMP CIRC P Rig up on tubing and pressure up to 5,464.0 5,464.0 10:45 11:15 2000 psi 10 minutes to verify standing valve still holding,good test. Line up to take returns from tubing,pump down IA,pressure up to 2950 psi and shear out SOV,witness and chart shear out.Pump in both direction to verify shear, 1 bpm 130 psi. 11/7/2015 11/7/2015 0.50 COMPZN RPCOMP RURD P Blow down injection line and squeeze 5,464.0 5,464.0 11:15 11:45 manifold,rig down test equipment. 11/7/2015 11/7/2015 0.25 COMPZN WHDBOP MPSP P Pull landing joint and lay down. Install 5,464.0 0.0 11:45 12:00 Type H back pressure valve as per GE Vetco rep. OA pressure=50 psi 11/7/2015 11/7/2015 0.75 COMPZN WHDBOP MPSP P Finish installing BPV,flush circ lines. 0.0 0.0 12:00 12:45 Test BPV from below,pump into IA to 2000 psi for 5 minutes charted. 11/7/2015 11/7/2015 0.50 COMPZN WHDBOP OWFF P Monitor well for 30 minutes-static. 0.0 0.0 12:45 13:15 Blow down injection line. 11/7/2015 11/7/2015 1.50 COMPZN WHDBOP NUND P Blow down choke and kill lines,pull 0.0 0.0 13:15 14:45 PS-21 slips,clean and remove Strip-O -Matic,clean out flow box,nipple down riser,nipple down flow box, flowline,N/D BOPE. 11/7/2015 11/7/2015 1.25 COMPZN WHDBOP NUND P Pick riser to rig floor,clean wellhead 0.0 0.0 14:45 16:00 profile,lower tree to cellar and nipple up tree. Page 27/29 Report Printed: 12/18/2015 ..� Aerations Summary (with Timelog epths) 0 eat 1C-154 ConocolPhil lips AkmAn Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/7/2015 11/7/2015 2.00 COMPZN WHDBOP NUND P Continue nippling up tree,pressure 0.0 0.0 16:00 18:00 test tree seals and void to 5000 psi for 10 minuites witnessed by CPAI rep. SIMOPS-Remove BOP annular cap, remove element,clean and inspect cavity,replace annular element and replace cap. Rig up bridle yokes and lines. 11/7/2015 11/7/2015 2.00 COMPZN WHDBOP MPSP P Lower and rig up lubricator,test to 0.0 0.0 18:00 20:00 1000 psi for 5 minutes. Pull BPV, install TWC. SIMOPS-Raise top drive,secure bridle lines in upper sheaves. 11/7/2015 '11/7/2015 0.75 COMPZN WHDBOP PRTS P Rig up and test tree to 5000 psi for 10 0.0 0.0 20:00 20:45 minutes charted. Bleed off pressure. SIMOPS-PJSM and scope down derrick. Remove block valve from top drive,blow down steam and water, clean pits. 11/7/2015 11/7/2015 0.50 COMPZN WHDBOP MPSP P Pull two way check. 0.0 0.0 20:45 21:15 SIMOPS-PJSM and scope down derrick.Remove block valve from top drive,blow down steam and water, clean pits. 11/7/2015 11/7/2015 1.75 COMPZN WHDBOP FRZP P Rig up to manifold/tree/injection line 0.0 0.0 21:15 23:00 for freeze protect. SIMOPS-PJSM and scope down derrick. Remove block valve from top drive,blow down steam and water, clean pits. 11/7/2015 11/8/2015 1.00 COMPZN WHDBOP FRZP P Freeze protect well pumping 87 bbl 0.0 0.0 23:00 00:00 diesel down IA taking returns out the tubing. ICP=460 psi,FCP=670 psi. SIMOPS-Lower cattle chute. 11/8/2015 11/8/2015 1.00 COMPZN WHDBOP FRZP P Line up and put tubing and IA in 0.0 0.0 00:00 01:00 communication via squeeze manifold and allow well to U-tube. SIMOPS-Lowering cattle chute 11/8/2015 11/8/2015 1.50 COMPZN WHDBOP FRZP P Blow down injection lines and squeeze 0.0 0.0 01:00 02:30 manifold,secure well. Install valves and guages.Tubing=100 psi,IA=100 psi,OA=50 psi. SIMOPS-Pin topdrive in place,secure energy track, Kelly and cement hoses. Unspool drilling line off drawworks and deadman.Raise C-Section and pin in place. Blow down remaining water and steam,disconnect remaining innerconnects. Page 28/29 Report Printed: 12/18/2015 •perations Summary (with Timelog�epths) 0 1C-154 conoca`Philkps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/8/2015 11/8/2015 1.50 COMPZN WHDBOP MPSP P Rig up GE Vetco lubricator and install 0.0 0.0 02:30 04:00 BPV in tree. SIMOPS-Prepping to skid rig floor, swap power in complexes to cold start power.Start un-plugging complexes and stomping casing shed away. 11/8/2015 11/8/2015 1.50 DEMOB MOVE RURD P Secure lubricator in BOP deck.Skid 0.0 0.0 04:00 05:30 rig floor over,lay derrick over and secure same. 11/8/2015 11/8/2015 0.50 DEMOB MOVE RURD P Secure cellar area.Continue 0.0 0.0 05:30 06:00 unplugging complexes and stomping casing shed away. Rig released @ 06:00 hrs Page 29/29 Report Printed: 12/18/2015 • Daily Operations Summary — i &We�; 1C-154 Cc nocat hi ps Rig: DOYON 25 Job: DRILLING ORIGINAL Daily Operations Start Date Last 24hr Sum 10/18/2015 Move rig off of 1C-153, move onto 1C-153 using trucks. Mate up pipe mod. 10/19/2015 Continue to MIRU on 1C-154 location. PU surface riser. Lower to cellar and nipple up same. Nipple up surface annular,flow box,flow line,4" conductor valves and risers,koomey lines to bag and knife valve,and flow jet lines. Rig accepted at 12:00, 10/19/2015. Pick up 4"DP and 4" HWDP. 10/20/2015 PU drillpipe. Perform Diverter Test. PU 13-1/2"BHA, Perform leak test.Spud well at 13:45, 10/20/2015. Directionally drill ahead with 13-1/2" directional assembly from 120'MD to 750'MD/742'TVD. 10/21/2015 Drill from 750'MD to 2643'MD/2416.9'TVD.Circulated bottoms up.Observe well for flow(Static). Begin back reaming out of hole from 2643'MD to 2386'MD. 10/22/2015 Pump out of hole with 13-1/2"motor assembly. LD BHA. RU to run 10-3/4"casing. MU shoe track,fill and check floats(Holding). RIH with 10- 3/4"45.5#L-80 Hydril 563 casing. 10/23/2015 RU for 10-3/4"surface cement job. Pump cement.Rig down surface cement equipment. Nipple down diverter. Nipple up wellhead.Lay down 5" DP while topping up cement at wellhead.Nipple up BOP and prepare for testing BOPE. 10/24/2015 Set BOPE test plug, RU to test BOPE,test BOPE. PU/MU 9-7/8"BHA and RIH to 2440'MD RU and test 10-3/4"Casing. Drill float equipment, cement and 20'of new hole(2643'MD to 2663'MD).Perform LOT. Displace well to 9.2ppg LSND and drill ahead to 2722'MD/2470'TVD. 10/25/2015 Drill ahead from 2722'MD to 5621'MD/3858'TVD. Circulate bottoms up. Flow check(Static). Backream from 5621'MD to 4808'MD. 10/26/2015 Pull out of hole with 9-7/8"rotary steerable assembly. Lay down BHA. Rig up to run 7-5/8"casing. Run in hole with 7-5/8"casing and space out with hanger. 10/27/2015 Circulate prior to cement job. Rig up to pump intermediate cement job.Test cement lines. Pump cement and displace. Pressure test casing to 3500psi.Set and test packoff. M/U BHA#3 and RIH with doubles and stands. Rig up to perform LOT and freeze protect. RIH with 6-3/4" production drilling assembly,drill float equipment,shoe track and shoe to 5616'MD. 10/28/2015 Attempt to drill rathole and 20'new hole with PDC. POOH for Milled Tooth bit cleanout BHA. P/U sonicscope and perform CBL while RIH to TD. Drill up junk on bottom from 5618'to 5620',drill new formation to 5641'MD. Perform FIT to 13.0 ppg EMW. Begin displacement to 9.4 ppg Flo Pro. 10/29/2015 Complete Flo Pro displacement, POOH, L/D BHA#4, P/U Periscope/Powerdrive BHA#5. M/U same and RBIH. Drill 6-3A"production section from 5641'MD to 6246'MD,3871'TVD. 10/30/2015 Drill 6-3/4"production section from 6246'MD to 9001'MD,3872'TVD. Drilled out of zone 107'from 6880'to 6958' MD due fault. Drilled total of 22 concretions. 10/31/2015 Drill 6-3A"production section from 9001'MD to 11278'MD,3846'TVD. Drilled out of zone 123'from 10697'to 10820'MD due fault. Drilled 17 concretions,41 total since shoe. 11/1/2015 Drill 6-3A"production section from 11278'MD to 12616'MD,3848'TVD. Drilled 14 concretions, 55 total since shoe. Monitor wellbore breathing, manage ECD with reduced ROP and whole mud dilution. 11/2/2015 Continue drilling 63/4"production to TD(12680'MD),circulate bottoms up, backream out of hole to 10630'MD,torque up to 16k,stall out and stuck pipe,full circulation.Work pipe attempt to free for 15 hrs. Free pipe,circulate and condition hole,work through area 2x observing no obstruction, continue backreaming out of hole. 11/3/2015 Continue backreaming out of hole with caution to casing shoe.Circulate casing clean at shoe, POOH standing back 4"DP. R/U and run 4%" 11.6# L-80 IBTM slotted and blank liner with Baker swell packers to 4248'MD. 11/4/2015 Continue P/U and RIH with slotted and blank liner, P/U liner hanger/packer assy.XO to 4"XT39 DP.Verify flow path,establish parameters and run liner on 4"DP with Super sliders,4"DP and HWDP.Set liner hanger,ZXP,release and test to 3500 psi. POOH laying down DP, HWDP and super sliders. 11/5/2015 Continue laying down 4"DP, RIH with remaining pipe and displace to 9.4 ppg brine.POOH laying down 4"DP,break and re-torque doubles,cull 4"pipe that needs re-hard banded. R/U and run 4'%"Hydril 563 completion.Safety Stand up with both crews. Pump inhibited brine,space out and land completion,drop ball and rod,failed to fall on seat,re-attempt x 3.Waiting on Slickline. 11/6/2015 Rig up slickline to push down ball/rod to seat. Fish ball/rod,fished RHC plug body from 5199',slipped past DB nipple due no no-go.Run and set CAT standing valve,test to 1000 psi good. Release slickline.Attempt to test tubing, bleeding off.Troubleshoot,valve is leaking, losing fluid static down tubing.Wait on slickline.Safety Stand up with both crews,review recent incidents,discuss seasonal changes, PREP and Success Triangle. 11/7/2015 Rig up slickline, pull standing valve,set 2nd standing valve and test-good.Test tubing and IA,shear out SOV.Set BPV and test,N/D BOPE, N/U tree and test. Freeze protect well with 87 bbl diesel.SIMOPS-scope derrick,swap annular on BOP, blow down steam and water,raise stairs, prep for move. 11/8/2015 Allow diesel to U-tube. Install BPV and secure well.RDMO to 1C-155. Page 1/1 Report Printed: 11/24/2015 • • NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-154 Definitive Survey Report 04 November, 2015 • Schlumberger • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 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 1C-154 Well Position +N/-S 0.00 usft Northing: 5,968,757.31 usfl Latitude: 70°19'30.612 N +E/-W 0.00 usft Easting: 562,168.40 usfl Longitude: 149°29'45.181 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 57.60 usft Wellb ' 1C-154 Mag: 4, Model Name Sample Date Declination Dip Angle F'ieid/yy ,, a: () (°) ' .fl {,F% BGGM2015 10/15/2015 18.92 80.99 57,505 Design ..-5--;,--,:-,. s 1C-154 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.73 �tical Section: Depth From(TVD) +N/-S +El-W Direction _ /� %, (usft) (usft} (usfl) (° ,.., ,,,,,,,,,k 39.73 0.00 0.00 344.53 Survey Program Date ,', 1: From To ,r;:', (usft) (usft) Survey(Wellbore) Tocol; ptien Survey Date',': 86.95 1,296.61 1C-154 Srvy#1 -GWD(1C-154) GYD-GC-SS Gyrodata gyro single shots 10/23/2015 2:1 1,355.32 2,562.37 1C-154 Srvy#2-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8:. 2,661.47 12,619.22 1C-154 Srvy#3-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 39.73 0.00 0.00 39.73 -57.60 0.00 0.00 5,968,757.31 562,168.40 0.00 0.00 UNDEFINED 86.95 0.07 101.63 86.95 -10.38 -0.01 0.03 5,968,757.31 562,168.43 0.15 -0.01 GYD-GC-SS(1) 122.20 0.11 61.20 122.20 24.87 0.01 0.08 5,968,757.32 562,168.48 0.21 -0.02 GYD-GC-SS(1) 20"x 42" ... r,� -ft'4, 160.11 0.18 45.47 160.11 62.78 0.07 0.15 5,968,757.38 562,168.56 0.21 0.02 GYD-GC-SS(1) 206.24 1.56 48.72 206.23 108.90 0.53 0.68 5,968,757.84 562,169.08 2.99 0.33 GYD-GC-SS(1) 262.56 2.85 44.57 262.51 165.18 2.03 2.24 5,968,759.35 562,170.64 2.31 1.36 GYD-GC-SS(1) 358.25 5.81 36.92 357.92 260.59 7.60 6.82 5,968,764.91 562,175.22 3.14 5.51 GYD-GC-SS(1) 451.26 10.02 38.49 450.02 352.69 17.70 14.68 5,968,775.01 562,183.08 4.53 13.15 GYD-GC-SS(1) 506.54 11.51 38.76 504.33 407.00 25.77 21.13 5,968,783.08 562,189.53 2.70 19.20 GYD-GC-SS(1) 543.66 12.36 38.61 540.64 443.31 31.76 25.93 5,968,789.07 562,194.33 2.29 23.70 GYD-GC-SS(1) 635.92 13.19 35.16 630.62 533.29 48.08 38.15 5,968,805.39 562,206.55 1.22 36.17 GYD-GC-SS(1) 11/4/2015 2:16:04PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit IVO/Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MIR8ference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North'Reference: Grid Wellbore: 1C-154 SuryQalculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map ..,s Vel'ti&al MD Inc Azi TVD TVDSS +N/S Northing Ewing DLS Section.. (usft) (°) (°) (usft); (usft) (usft) (use. (ft)', (ft) (°1100') (ft} " Survey Tool Name 728.05 12.36 42.72 720.48 623.15 63.92 50.89 5,968,821.23 562,219.29 2.02 48.03 GYD-GC-SS(1) 822.11 12.26 48.63 812.38 715.05 77.92 65.22 5,968,835.23 562,233.61 1.34 57.70 GYD-GC-SS(1) 914.71 13.18 48.83 902.70 805.37 91.37 80.54 5,968,848.67 562,248.94 0.99 66.57 GYD-GC-SS(1) 1,011.51 12.95 50.81 997.00 899.67 105.49 97.26 5,968,862.79 562,265.65 0.52 75.72 GYD-GC-SS(1) 1,105.83 11.53 57.10 1,089.18 991.85 117.29 113.36 5,968,874.59 562,281.75 2.06 82.80 GYD-GC-SS(1) 1,201.06 13.64 58.01 1,182.11 1,084.78 128.41 130.88 5,968,885.71 562,299.27 2.23 88.84 GYD-GC-SS(1) 1,296.61 14.24 60.50 1,274.85 1,177.52 140.17 150.66 5,968,897.46 562,319.05 0.89 94.89 GYD-GC-SS(1) 1,355.32 15.88 61.36 1,331.54 1,234.21 147.57 164.00 5,968,904.87 562,332.38 2.82 98.48 MWD+IFR-AK-CAZ-SC(2) 1,449.60 18.73 62.30 1,421.54 1,324.21 160.79 188.72 5,968,918.09 562,357.11 3.04 104.62 MWD+IFR-AK-CAZ-SC(2) 1,544.23 18.75 61.31 1,511.16 1,413.83 175.16 215.52 5,968,932.45 562,383.90 0.34 111.32 MWD+IFR-AK-CAZ-SC(2) 1,638.81 21.13 62.03 1,600.06 1,502.73 190.45 243.91 5,968,947.75 562,412.29 2.53 118.49 MWD+IFR-AK-CAZ-SC(2) 1,733.27 23.94 63.68 1,687.30 1,589.97 206.94 276.13 5,968,964.23 562,444.51 3.05 125.78 MWD+IFR-AK-CAZ-SC(2) 1,828.83 26.49 65.10 1,773.75 1,676.42 224.52 312.85 5,968,981.81 562,481.22 2.74 132.92 MWD+IFR-AK-CAZ-SC(2) 1,922.58 30.35 62.46 1,856.19 1,758.86 244.28 352.83 5,969,001.57 562,521.20 4.33 141.30 MWD+IFR-AK-CAZ-SC(2) 2,017.51 32.94 61.06 1,937.00 1,839.67 267.86 396.69 5,969,025.15 562,565.05 2.84 152.33 MWD+IFR-AK-CAZ-SC(2) 2,113.33 33.26 61.43 2,017.27 1,919.94 293.04 442.56 5,969,050.32 562,610.92 0.39 164.36 MWD+IFR-AK-CAZ-SC(2) 2,208.09 34.69 61.37 2,095.85 1,998.52 318.39 489.06 5,969,075.67 562,657.41 1.51 176.39 MWD+IFR-AK-CAZ-SC(2) 2,302.52 40.92 62.14 2,170.42 2,073.09 345.74 540.03 5,969,103.02 562,708.38 6.62 189.15 MWD+IFR-AK-CAZ-SC(2) 2,396.14 42.31 61.12 2,240.41 2,143.08 375.29 594.73 5,969,132.57 562,763.08 1.65 203.04 MWD+IFR-AK-CAZ-SC(2) 2,492.78 42.58 59.35 2,311.73 2,214.40 407.67 651.34 5,969,164.95 562,819.68 1.27 219.15 MWD+IFR-AK-CAZ-SC(2) 2,562.37 45.53 58.19 2,361.74 2,264.41 432.77 692.71 5,969,190.04 562,861.04 4.39 232.30 MWD+IFR-AK-CAZ-SC(2) 2,636.90 48.14 57.42 2,412.72 2,315.39 461.74 738.70 5,969,219.01 562,907.03 3.58 247.95 MWD+IFR-AK-CAZ-SC(3) 10314"x13-112 2,661.47 49.00 57.18 2,428.98 2,331.65 471.69 754.20 5,969,228.96 562,922.53 3.58 253.41 MWD+IFR-AK-CAZ-SC(3) 2,756.23 49.43 59.65 2,490.88 2,393.55 509.26 815.31 5,969,266.53 562,983.64 2.03 273.31 MWD+IFR-AK-CAZ-SC(3) 2,851.73 49.53 61.23 2,552.93 2,455.60 545.08 878.46 5,969,302.34 563,046.77 1.26 290.98 MWD+IFR-AK-CAZ-SC(3) 2,946.62 48.36 59.88 2,615.25 2,517.92 580.25 940.77 5,969,337.50 563,109.08 1.63 308.26 MWD+IFR-AK-CAZ-SC(3) 3,040.99 48.13 62.55 2,678.11 2,580.78 614.14 1,002.45 5,969,371.40 563,170.76 2.12 324.47 MWD+IFR-AK-CAZ-SC(3) 3,135.79 48.13 62.44 2,741.38 2,644.05 646.75 1,065.07 5,969,404.00 563,233.37 0.09 339.19 MWD+IFR-AK-CAZ-SC(3) 3,231.09 48.10 64.34 2,805.01 2,707.68 678.53 1,128.50 5,969,435.77 563,296.79 1.48 352.90 MWD+IFR-AK-CAZ-SC(3) 3,326.04 48.29 65.22 2,868.30 2,770.97 708.69 1,192.53 5,969,465.93 563,360.81 0.72 364.88 MWD+IFR-AK-CAZ-SC(3) 3,420.19 49.69 61.07 2,930.10 2,832.77 740.79 1,255.87 5,969,498.03 563,424.15 3.64 378.93 MWD+IFR-AK-CAZ-SC(3) 3,513.67 51.45 57.09 2,989.48 2,892.15 777.91 1,317.77 5,969,535.14 563,486.04 3.79 398.18 MWD+IFR-AK-CAZ-SC(3) 3,609.56 52.75 55.03 3,048.39 2,951.06 820.16 1,380.53 5,969,577.39 563,548.80 2.17 422.16 MWD+IFR-AK-CAZ-SC(3) 3,704.09 54.26 51.54 3,104.62 3,007.29 865.60 1,441.41 5,969,622.83 563,609.68 3.37 449.71 MWD+IFR-AK-CAZ-SC(3) 3,799.51 54.86 47.17 3,159.97 3,062.64 916.23 1,500.37 5,969,673.45 563,668.62 3.78 482.78 MWD+IFR-AK-CAZ-SC(3) 3,894.09 54.87 41.59 3,214.43 3,117.10 971.47 1,554.43 5,969,728.69 563,722.68 4.82 521.60 MWD+IFR-AK-CAZ-SC(3) 3,988.94 55.15 36.18 3,268.84 3,171.51 1,031.93 1,603.17 5,969,789.14 563,771.42 4.68 566.87 MWD+IFR-AK-CAZ-SC(3) 4,083.41 55.57 31.10 3,322.57 3,225.24 1,096.61 1,646.19 5,969,853.81 563,814.44 4.45 617.72 MWD+IFR-AK-CAZ-SC(3) 4,177.80 55.87 28.38 3,375.74 3,278.41 1,164.32 1,684.87 5,969,921.52 563,853.11 2.40 672.66 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 2:16:04PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD -A Inc Azi TVD TV +NI-S +E!-W = Northing Easting PLS Section (usft) , °� (°) (usft) (usft)' (usft) (usft) (ft) (ft) (°11o01 ' (ft) Survey Tool Name 4,272.48 56.77 25.40 3,428.25 3,330.92 1,234.58 1,720.49 5,969,991.78 563,888.73 2.79 730.88 MWD+IFR-AK-CAZ-SC(3) 4,368.03 58.12 20.49 3,479.69 3,382.36 1,308.72 1,751.84 5,970,065.91 563,920.08 4.56 793.97 MWD+IFR-AK-CAZ-SC(3) 4,462.89 58.96 14.84 3,529.22 3,431.89 1,385.78 1,776.36 5,970,142.96 563,944.59 5.16 861.69 MWD+IFR-AK-CAZ-SC(3) 4,557.64 59.76 12.52 3,577.52 3,480.19 1,464.98 1,795.63 5,970,222.15 563,963.86 2.27 932.88 MWD+IFR-AK-CAZ-SC(3) 4,652.34 62.85 8.40 3,623.00 3,525.67 1,546.64 1,810.66 5,970,303.81 563,978.89 5.02 1,007.58 MWD+IFR-AK-CAZ-SC(3) 4,747.03 65.86 5.24 3,663.98 3,566.65 1,631.38 1,820.76 5,970,388.54 563,988.99 4.38 1,086.55 MWD+IFR-AK-CAZ-SC(3) 4,841.67 69.38 1.29 3,700.02 3,602.69 1,718.72 1,825.70 5,970,475.86 563,993.93 5.36 1,169.40 MWD+IFR-AK-CAZ-SC(3) 4,937.34 72.08 356.95 3,731.60 3,634.27 1,808.98 1,824.29 5,970,566.12 563,992.51 5.13 1,256.77 MWD+IFR-AK-CAZ-SC(3) 5,031.94 73.84 353.15 3,759.33 3,662.00 1,899.07 1,816.47 5,970,656.20 563,984.69 4.27 1,345.68 MWD+IFR-AK-CAZ-SC(3) 5,126.45 74.94 350.56 3,784.77 3,687.44 1,989.16 1,803.56 5,970,746.28 563,971.79 2.88 1,435.95 MWD+IFR-AK-CAZ-SC(3) 5,221.78 76.23 347.98 3,808.50 3,711.17 2,079.86 1,786.37 5,970,836.97 563,954.60 2.95 1,527.95 MWD+IFR-AK-CAZ-SC(3) 5,316.17 79.21 347.87 3,828.58 3,731.25 2,170.04 1,767.07 5,970,927.15 563,935.30 3.16 1,620.01 MWD+IFR-AK-CAZ-SC(3) 5,411.08 82.97 346.48 3,843.28 3,745.95 2,261.45 1,746.25 5,971,018.54 563,914.49 4.22 1,713.66 MWD+IFR-AK-CAZ-SC(3) 5,505.72 86.80 344.79 3,851.71 3,754.38 2,352.74 1,722.87 5,971,109.83 563,891.10 4.42 1,807.88 MWD+IFR-AK-CAZ-SC(3) 5,559.45 86.86 345.18 3,854.68 3,757.35 2,404.55 1,708.97 5,971,161.64 563,877.20 0.73 1,861.53 MWD+IFR-AK-CAZ-SC(3) 5,614.00 86.65 344.85 3,857.77 3,760.44 2,457.17 1,694.88 5,971,214.24 563,863.12 0.70 1,915.99 MWD+IFR-AK-CAZ-SC(3) 7-5/8"x 9-718" 5,655.00 86.50 344.61 3,860.22 3,762.89 2,496.65 1,684.11 5,971,253.72 563,852.35 0.70 1,956.92 MWD+IFR-AK-CAZ-SC(3) 5,710.88 86.46 343.42 3,863.65 3,766.32 2,550.26 1,668.74 5,971,307.33 563,836.99 2.13 2,012.69 MWD+IFR-AK-CAZ-SC(3) 5,806.50 86.45 342.57 3,869.56 3,772.23 2,641.53 1,640.83 5,971,398.59 563,809.08 0.89 2,108.09 MWD+IFR-AK-CAZ-SC(3) 5,855.89 87.25 340.88 3,872.28 3,774.95 2,688.35 1,625.37 5,971,445.41 563,793.61 3.78 2,157.34 MWD+IFR-AK-CAZ-SC(3) 5,901.05 87.90 337.78 3,874.19 3,776.86 2,730.56 1,609.44 5,971,487.61 563,777.69 7.01 2,202.27 MWD+IFR-AK-CAZ-SC(3) 5,946.09 89.00 336.53 3,875.41 3,778.08 2,772.05 1,591.96 5,971,529.10 563,760.21 3.70 2,246.92 MWD+IFR-AK-CAZ-SC(3) 5,995.85 89.93 333.62 3,875.87 3,778.54 2,817.17 1,570.99 5,971,574.21 563,739.24 6.14 2,296.00 MWD+IFR-AK-CAZ-SC(3) 6,090.97 91.27 330.59 3,874.87 3,777.54 2,901.22 1,526.49 5,971,658.25 563,694.75 3.48 2,388.87 MWD+IFR-AK-CAZ-SC(3) 6,185.34 92.76 329.19 3,871.56 3,774.23 2,982.80 1,479.18 5,971,739.83 563,647.44 2.17 2,480.12 MWD+IFR-AK-CAZ-SC(3) 6,281.15 92.05 333.10 3,867.53 3,770.20 3,066.62 1,432.99 5,971,823.64 563,601.26 4.14 2,573.22 MWD+IFR-AK-CAZ-SC(3) 6,376.67 91.33 337.50 3,864.71 3,767.38 3,153.34 1,393.10 5,971,910.35 563,561.37 4.67 2,667.44 MWD+IFR-AK-CAZ-SC(3) 6,469.98 91.47 337.79 3,862.44 3,765.11 3,239.61 1,357.62 5,971,996.61 563,525.89 0.35 2,760.05 MWD+IFR-AK-CAZ-SC(3) 6,564.35 90.37 338.34 3,860.92 3,763.59 3,327.14 1,322.37 5,972,084.13 563,490.65 1.30 2,853.81 MWD+IFR-AK-CAZ-SC(3) 6,659.89 88.58 340.01 3,861.80 3,764.47 3,416.42 1,288.41 5,972,173.41 563,456.69 2.56 2,948.92 MWD+IFR-AK-CAZ-SC(3) 6,754.22 88.80 340.93 3,863.95 3,766.62 3,505.30 1,256.88 5,972,262.28 563,425.16 1.00 3,042.99 MWD+IFR-AK-CAZ-SC(3) 6,849.07 87.60 343.34 3,866.93 3,769.60 3,595.52 1,227.80 5,972,352.49 563,396.08 2.84 3,137.70 MWD+IFR-AK-CAZ-SC(3) 6,944.61 87.25 345.03 3,871.22 3,773.89 3,687.35 1,201.78 5,972,444.31 563,370.07 1.80 3,233.14 MWD+IFR-AK-CAZ-SC(3) 7,039.46 86.17 343.53 3,876.67 3,779.34 3,778.50 1,176.12 5,972,535.45 563,344.41 1.95 3,327.82 MWD+IFR-AK-CAZ-SC(3) 7,134.55 87.27 341.88 3,882.11 3,784.78 3,869.13 1,147.90 5,972,626.08 563,316.19 2.08 3,422.71 MWD+IFR-AK-CAZ-SC(3) 7,228.56 90.18 339.33 3,884.20 3,786.87 3,957.77 1,116.69 5,972,714.70 563,284.99 4.12 3,516.45 MWD+IFR-AK-CAZ-SC(3) 7,322.88 90.99 340.91 3,883.24 3,785.91 4,046.46 1,084.62 5,972,803.38 563,252.91 1.88 3,610.49 MWD+IFR-AK-CAZ-SC(3) 7,417.58 91.33 344.49 3,881.32 3,783.99 4,136.84 1,056.46 5,972,893.76 563,224.76 3.80 3,705.10 MWD+IFR-AK-CAZ-SC(3) 7,512.75 91.78 345.63 3,878.74 3,781.41 4,228.76 1,031.93 5,972,985.66 563,200.24 1.29 3,800.23 MWD+IFR-AK-CAZ-SC(3) 7,606.78 92.78 342.74 3,875.00 3,777.67 4,319.14 1,006.33 5,973,076.04 563,174.63 3.25 3,894.17 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 2:16:04PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore ; ,':?',1C-154 Survey Calculation Method: Minimum Curvature Design: ;1 C-154 Database: OAKEDMP2 Survey • '„ Map Map vertf ai MD Inc Azi TVD TOSS +NI-S +E(-W Northing Listing DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (01100') (ft) Survey Tool'Name 7,702.30 93.59 342.82 3,869.69 3,772.36 4,410.24 978.09 5,973,167.13 563,146.40 0.85 3,989.50 MWD+IFR-AK-CAZ-SC(3) 7,795.97 91.06 340.65 3,865.89 3,768.56 4,499.10 948.76 5,973,255.98 563,117.07 3.56 4,082.97 MWD+IFR-AK-CAZ-SC(3) 7,890.81 88.57 339.25 3,866.19 3,768.86 4,588.18 916.25 5,973,345.06 563,084.56 3.01 4,177.50 MWD+IFR-AK-CAZ-SC(3) 7,985.07 89.14 341.35 3,868.08 3,770.75 4,676.90 884.48 5,973,433.77 563,052.79 2.31 4,271.48 MWD+IFR-AK-CAZ-SC(3) 8,080.86 90.00 341.68 3,868.80 3,771.47 4,767.75 854.10 5,973,524.60 563,022.42 0.96 4,367.13 MWD+IFR-AK-CAZ-SC(3) 8,175.44 90.13 344.43 3,868.69 3,771.36 4,858.21 826.54 5,973,615.06 562,994.86 2.91 4,461.67 MWD+IFR-AK-CAZ-SC(3) 8,270.97 89.19 347.30 3,869.26 3,771.93 4,950.84 803.21 5,973,707.67 562,971.53 3.16 4,557.16 MWD+IFR-AK-CAZ-SC(3) 8,365.24 90.17 346.26 3,869.78 3,772.45 5,042.60 781.65 5,973,799.43 562,949.97 1.52 4,651.35 MWD+IFR-AK-CAZ-SC(3) 8,460.17 91.48 346.82 3,868.42 3,771.09 5,134.91 759.55 5,973,891.73 562,927.88 1.50 4,746.21 MWD+IFR-AK-CAZ-SC(3) 8,509.33 89.57 344.62 3,867.97 3,770.64 5,182.55 747.43 5,973,939.36 562,915.76 5.93 4,795.36 MWD+IFR-AK-CAZ-SC(3) 8,555.56 88.87 342.56 3,868.60 3,771.27 5,226.89 734.37 5,973,983.70 562,902.70 4.71 4,841.57 MWD+IFR-AK-CAZ-SC(3) 8,599.91 88.09 339.14 3,869.77 3,772.44 5,268.76 719.82 5,974,025.57 562,888.16 7.91 4,885.81 MWD+IFR-AK-CAZ-SC(3) 8,651.08 88.39 337.68 3,871.34 3,774.01 5,316.32 701.00 5,974,073.12 562,869.34 2.91 4,936.66 MWD+IFR-AK-CAZ-SC(3) 8,695.84 88.10 339.10 3,872.71 3,775.38 5,357.91 684.53 5,974,114.71 562,852.86 3.24 4,981.14 MWD+IFR-AK-CAZ-SC(3) 8,746.37 88.69 341.69 3,874.13 3,776.80 5,405.49 667.58 5,974,162.28 562,835.92 5.25 5,031.52 MWD+IFR-AK-CAZ-SC(3) 8,794.67 89.35 343.53 3,874.96 3,777.63 5,451.57 653.14 5,974,208.36 562,821.48 4.05 5,079.78 MWD+IFR-AK-CAZ-SC(3) 8,840.62 90.37 346.30 3,875.07 3,777.74 5,495.93 641.19 5,974,252.72 562,809.53 6.42 5,125.72 MWD+IFR-AK-CAZ-SC(3) 8,884.48 90.68 347.69 3,874.67 3,777.34 5,538.66 631.31 5,974,295.44 562,799.66 3.25 5,169.54 MWD+IFR-AK-CAZ-SC(3) 8,930.14 90.65 349.93 3,874.14 3,776.81 5,583.45 622.45 5,974,340.23 562,790.80 4.91 5,215.07 MWD+IFR-AK-CAZ-SC(3) 9,027.84 90.82 350.52 3,872.88 3,775.55 5,679.72 605.86 5,974,436.49 562,774.21 0.63 5,312.28 MWD+IFR-AK-CAZ-SC(3) 9,124.10 90.17 349.77 3,872.05 3,774.72 5,774.55 589.39 5,974,531.31 562,757.73 1.03 5,408.07 MWD+IFR-AK-CAZ-SC(3) 9,219.27 90.20 347.85 3,871.74 3,774.41 5,867.91 570.92 5,974,624.66 562,739.26 2.02 5,502.97 MWD+IFR-AK-CAZ-SC(3) 9,314.50 90.24 345.49 3,871.38 3,774.05 5,960.57 548.96 5,974,717.31 562,717.31 2.48 5,598.13 MWD+IFR-AK-CAZ-SC(3) 9,410.83 90.37 343.97 3,870.87 3,773.54 6,053.49 523.59 5,974,810.22 562,691.94 1.58 5,694.45 MWD+IFR-AK-CAZ-SC(3) 9,505.99 89.30 342.44 3,871.14 3,773.81 6,144.59 496.09 5,974,901.31 562,664.44 1.96 5,789.58 MWD+IFR-AK-CAZ-SC(3) 9,600.93 89.72 341.69 3,871.95 3,774.62 6,234.91 466.85 5,974,991.62 562,635.21 0.91 5,884.43 MWD+IFR-AK-CAZ-SC(3) 9,696.23 90.48 343.58 3,871.79 3,774.46 6,325.86 438.41 5,975,082.57 562,606.77 2.14 5,979.67 MWD+IFR-AK-CAZ-SC(3) 9,790.90 89.96 345.00 3,871.42 3,774.09 6,416.99 412.77 5,975,173.69 562,581.13 1.60 6,074.34 MWD+IFR-AK-CAZ-SC(3) 9,886.01 89.34 345.53 3,872.00 3,774.67 6,508.97 388.58 5,975,265.66 562,556.94 0.86 6,169.44 MWD+IFR-AK-CAZ-SC(3) 9,980.28 90.17 345.81 3,872.41 3,775.08 6,600.30 365.24 5,975,356.98 562,533.61 0.93 6,263.69 MWD+IFR-AK-CAZ-SC(3) 10,073.93 91.00 348.08 3,871.45 3,774.12 6,691.52 344.09 5,975,448.19 562,512.46 2.58 6,357.24 MWD+IFR-AK-CAZ-SC(3) 10,171.36 89.86 346.98 3,870.72 3,773.39 6,786.64 323.05 5,975,543.31 562,491.42 1.63 6,454.53 MWD+IFR-AK-CAZ-SC(3) 10,266.80 90.03 345.57 3,870.81 3,773.48 6,879.36 300.40 5,975,636.01 562,468.78 1.49 6,549.92 MWD+IFR-AK-CAZ-SC(3) 10,361.88 90.44 345.47 3,870.42 3,773.09 6,971.41 276.63 5,975,728.06 562,445.00 0.44 6,644.99 MWD+IFR-AK-CAZ-SC(3) 10,456.80 89.52 342.64 3,870.45 3,773.12 7,062.67 250.55 5,975,819.31 562,418.93 3.14 6,739.90 MWD+IFR-AK-CAZ-SC(3) 10,551.76 88.99 343.88 3,871.69 3,774.36 7,153.60 223.20 5,975,910.22 562,391.58 1.42 6,834.82 MWD+IFR-AK-CAZ-SC(3) 10,647.01 89.93 346.47 3,872.59 3,775.26 7,245 66 198.83 5,976,002.28 562,367.21 2.89 6,930.05 MWD+IFR-AK-CAZ-SC(3) 10,741.22 90.38 345.83 3,872.33 3,775.00 7,337.13 176.27 5,976,093.74 562,344.66 0.83 7,024.22 MWD+IFR-AK-CAZ-SC(3) 10,836.68 94.03 344.76 3,868.66 3,771.33 7,429.38 152.06 5,976,185 98 562,320.45 3.98 7,119.59 MWD+IFR-AK-CAZ-SC(3) 10,930.03 94.57 345.64 3,861.66 3,764.33 7,519.37 128.28 5,976,275.97 562,296.67 1.10 7,212.67 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 2:16:04PM Page 5 COMPASS 5000.1 Build 74 •• Schlumberger Definitive Survey Report NADConversion Local Co-ordinate Reference: Well 1C-154 Project Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73©97.33usft(Doyon25) ;Well: 1C-154 "North Reference: Grid 1C-154 Survey Calculation Method: Minimum Curvature 1C-154 Database: OAKEDMP2 y /..,, 5 ® /... v 6 E z;lnc ' ' a TYD TVDSS +N1-S +EI-W Elaine (usft) 'TY(*) (°) Gift} (usft) (usft) (usft) TOM „t•:;,, 11,026.85 93.43 346.48 3,854.91 3,757.58 7,613.11 105.01 5,976,369.70 562,273.40 1.46 7,309.21 MWD+IFR-AK-CAZ-SC(3) 11,122.36 91.12 346.85 3,851.11 3,753.78 7,705.97 83.00 5,976,462.54 562,251.39 2.45 7,404.58 MWD+IFR-AK-CAZ-SC(3) 11,217.63 90.72 345.22 3,849.59 3,752.26 7,798.40 60.01 5,976,554.97 562,228.40 1.76 7,499.80 MWD+IFR-AK-CAZ-SC(3) 11,312.44 91.30 344.14 3,847.91 3,750.58 7,889.83 34.96 5,976,646.39 562,203.36 1.29 7,594.59 MWD+IFR-AK-CAZ-SC(3) 11,407.14 91.06 343.90 3,845.96 3,748.63 7,980.85 8.89 5,976,737.40 562,177.29 0.36 7,689.27 MWD+IFR-AK-CAZ-SC(3) 11,502.69 90.91 344.04 3,844.32 3,746.99 8,072.67 -17.49 5,976,829.21 562,150.91 0.21 7,784.80 MWD+IFR-AK-CAZ-SC(3) 11,597.35 87.98 339.62 3,845.24 3,747.91 8,162.57 -47.00 5,976,919.10 562,121.41 5.60 7,879.31 MWD+IFR-AK-CAZ-SC(3) 11,691.83 88.49 341.55 3,848.15 3,750.82 8,251.63 -78.39 5,977,008.15 562,090.02 2.11 7,973.52 MWD+IFR-AK-CAZ-SC(3) 11,786.05 88.97 343.96 3,850.24 3,752.91 8,341.59 -106.32 5,977,098.10 562,062.09 2.61 8,067.67 MWD+IFR-AK-CAZ-SC(3) 11,878.44 89.48 345.55 3,851.49 3,754.16 8,430.71 -130.61 5,977,187.22 562,037.80 1.81 8,160.04 MWD+IFR-AK-CAZ-SC(3) 11,971.67 90.10 346.97 3,851.83 3,754.50 8,521.27 -152.76 5,977,277.77 562,015.66 1.66 8,253.23 MWD+IFR-AK-CAZ-SC(3) 12,064.22 90.61 347.93 3,851.26 3,753.93 8,611.61 -172.87 5,977,368.09 561,995.55 1.17 8,345.65 MWD+IFR-AK-CAZ-SC(3) 12,155.62 91.59 348.07 3,849.50 3,752.17 8,700.99 -191.87 5,977,457.47 561,976.55 1.08 8,436.87 MWD+IFR-AK-CAZ-SC(3) 12,247.88 90.51 349.31 3,847.81 3,750.48 8,791.44 -209.96 5,977,547.91 561,958.46 1.78 8,528.87 MWD+IFR-AK-CAZ-SC(3) 12,340.10 88.39 347.03 3,848.70 3,751.37 8,881.69 -228.87 5,977,638.15 561,939.55 3.38 8,620.88 MWD+IFR-AK-CAZ-SC(3) 12,433.30 89.45 346.08 3,850.45 3,753.12 8,972.31 -250.54 5,977,728.77 561,917.89 1.53 8,714.01 MWD+IFR-AK-CAZ-SC(3) 12,525.84 90.24 345.87 3,850.70 3,753.37 9,062.09 -272.97 5,977,818.54 561,895.46 0.88 8,806.52 MWD+IFR-AK-CAZ-SC(3) 12,619.22 90.58 346.13 3,850.03 3,752.70 9,152.69 -295.56 5,977,909.13 561,872.87 0.46 8,899.86 MWD+IFR-AK-CAZ-SC(3) 12,680.00 90.58 346.13 3,849.42 3,752.09 9,211.70 -310.13 5,977,968.13 561,858.30 0.00 8,960.62 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ❑ Yes ❑ No I have checked to the best of my ability that the following data is correct: U Surface Coordinates pi Declination & Convergence 1J GRS Survey Corrections I] Survey Tool Codes p Itv,=a“M Out Vincent �� < � xh6mtrilgx, SLB DE: Osara _yhw1 /feta:20'3.1,,H14105.5 Client Representative: Kelsey Hallford w" ,a Date: 04-Nov-2015 11/42015 2:16:04PM Page 6 COMPASS 5000.1 Build 74 • iso Dri -rog Cement Detail Report ,ejL. 1C-154 / v ConocoPhillips y _J String: Co uct r Job: DRILLING ORIGINAL, 10/18/201( 03:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor 9/2/2015 06:40 10/23/2015 07:30 1C-154 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Suface Casing: 10-3/4" Set 10-3/4"Surface 42.2 2,636.9 Yes 78.0 Yes Yes Casing Q Pump lnit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 1 6 800.0 323.0 Yes 30.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5bbl CW 100 and test cement lines to 3500psi(Good Test).Dowell continue to pump 70bbl of CW100 at 6.1 BPM,320psi, FO=12%. Pump 70.5bbl of 10.59ppg Mud Push II with 2 gal of Red Dye at 5BPM,280psi,and F0=11%. Drop bottom plug,pump 460bb1 of Lead Deep Crete 11.Oppg at 6.6BPM,245psi, FO=18%. Pump 12ppg Tail cement at 5BPM,228psi, FO= 12%. Drop top plug and chase with 1 Obbl of water prior to swapping to rig pumps. Continue pumping 234.4bbls of 9.5ppg Drilplex mud at 8 BPM,437%, FO=20%using rig pumps. Divert to cellar box at 1113stks,slow pumps to 3BPM at 1400stks,220psi. Bump plug with 2330stks,265psi. Increase to 800psi and shut in. Bled back to Opsi. Pump back up to 800psi and shut in. Bled back to Opsi.Check Floats(Held). Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush 75.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.35 5.0 Additives Additive Type Concentration Conc Unit label Chemical Wash co D122A 0.5 gal/bbl Additive Type Concentration Conc Unit label Fluid Loss J237A 0.25 gal/bbl Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush 70.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Extender D020 0.0 lb/bbl Additive Type Concentration Conc Unit label Turb.Spacer D182 7.0 lb/bbl Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 42.2 2,136.9 1,318 G 460.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.83 11.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Additive Type Concentration Conc Unit label Dispersant LT D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,136.9 2,136.9 239 G 61.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1 (psi) 1.66 5.82 12.00 4.58 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOB Additive Type Concentration Conc Unit label Dispersant LT D185 0.06 gal/sx Additive Type Concentration Conc Unit label Accelerator D186 0.03 gal/sx Page 1/1 Report Printed: 12/4/2015 • • iUngCement Detail Report estiattW 1C-154 Conoco'hillips String: 10-3/4" Surface Casing Job: DRILLING ORIGINAL, 10/18/2015 03:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 10-3/4"Surface Casing 10/23/2015 02:25 10/23/2015 06:46 1C-154 Comment Pump 5bbl CW 100 and test cement lines to 3500psi(Good Test).Dowell continue to pump 70bbl of CW100 at 6.1 BPM,320psi, FO=12%. Pump 70.5bb1 of 10.59ppg Mud Push II with 2 gal of Red Dye at 5BPM,280psi,and F0=11%. Drop bottom plug,pump 460bb1 of Lead Deep Crete 11.0ppg at 6.6BPM,245psi, FO=18%. Pump 12ppg Tail cement at 5BPM,228psi, FO= 12%. Drop top plug and chase with 10bb1 of water prior to swapping to rig pumps. Continue pumping 234.4bbls of 9.5ppg Drilplex mud at 8 BPM,437%, FO=20%using rig pumps. Divert to cellar box at 1113stks,slow pumps to 3BPM at 1400stks,220psi. Bump plug with 2330stks,265psi. Increase to 800psi and shut in. Bled back to Opsi. Pump back up to 800psi and shut in. Bled back to Opsi.Check Floats(Held). Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? 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 Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/4/2015 • • Drillffortg Cement Detail Report &Wt th 1C-154 LonocoPhillips String: 7.625" Intermediate cement Job: DRILLING ORIGINAL, 10/18/2015 03:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 7.625"Intermediate cement 10/27/2015 02:55 10/27/2015 05:12 1C-154 Comment SLB pumped 5 bbl CW100, PT lines to 4000 psi.Continue pumping 15 bbl CW100 @ 5 bpm, 370 psi, 15%flow out.SLB pumped 43.3 bbl 11.5 ppg Mud Push ©5 bpm,320 psi, 15%flow out. Drop bottom Davis Lynch non-rotating plug, pump 43.6 bbl 15.8 ppg lead cement(with retarder)@ 2.1 bpm, 119 psi 16%flow out. Drop top Davis Lynch non-rotating plug,kick out with 10 bbl water.Swap to rig pumps and displace with 240 bbl 9.3ppg LSND©6 bpm,790 psi, 16%flow out. Bump plug©2403 stks,pressure up 500 psi to 1290 psi and hold for 5 minutes. Bleed pressure to 0 psi, bled back 1.3 bbl.Check floats-good. Final P/U=154k,S/0=107k.CIP:05:12 hrs 10-27-15 Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 7.625"Intermediate 3,463.0 5,621.0 Yes 0.0 Yes Yes cement Q Pump nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 5 740.0 1,240.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement bond Sonic log located top of cement @ 3040'MD Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 2,133.0 2,501.0 20.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push 2,501.0 3,463.0 43.3 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1 (psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Retarded lead 3,463.0 4,370.0 211 G 43.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 15.80 12.80 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.4 %BWOC Additive Type Concentration Conc Unit label D177 Retarder 0.05 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail(no retarder) 4,370.0 5,621.0 300 G 62.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 15.80 3.73 Additives Additive Type Concentration Conc Unit label Additive Type Concentration Conc Unit label D167 0.4 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 1/1 Report Printed: 12/4/2015 • 215166 26461 SchlumbergerDrilling & Measurements Transmittal#: 16N0V15-SPO1 DATA LOGGEDr� MWD/LWD Log Product Delivery M K/�BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-154 Date Dispatched: 16-Nov-15 Job#: 15AKA0102 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2" MD x x Scope Resistivity 2'TVD x x Scope Resistivity 5"MD x x Scope Resistivity 5'TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico(c�conocophillips.com AlaskaPTSPrintCenter0,slb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: jaA(f?.24'uLr -` / ' .1/ - 215166 26461 FINAL NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-154 Definitive Survey Report 04 November, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 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 1C-154 Well Position +N/-S 0.00 usft Northing: 5,968,757.31 usfl Latitude: 70°19'30.612 N +E/-W 0.00 usft Easting: 562,168.40 usfl Longitude: 149°29'45.181 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 57.60 usft Wellbore 1C-154 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 10/15/2015 18.92 80.99 57,505 Design 1C-154 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.73 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.73 0.00 0.00 344.53 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 86.95 1,296.61 1C-154 Srvy#1 -GWD(1C-154) GYD-GC-SS Gyrodata gyro single shots 10/23/2015 2:1 1,355.32 2,562.37 1C-154 Srvy#2-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8: 2,661.47 12,619.22 1C-154 Srvy#3-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8:: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.73 0.00 0.00 39.73 -57.60 0.00 0.00 5,968,757.31 562,168.40 0.00 0.00 UNDEFINED 86.95 0.07 101.63 86.95 -10.38 -0.01 0.03 5,968,757.31 562,168.43 0.15 -0.01 GYD-GC-SS(1) 122.20 0.11 61.20 122.20 24.87 0.01 0.08 5,968,757.32 562,168.48 0.21 -0.02 G' NOT an Actual Survey 20"x 42" 160.11 0.18 45.47 160.11 62.78 0.07 0.15 5,968,757.38 562,168.56 0.21 0.02 GYD-GC-SS(1) 206.24 1.56 48.72 206.23 108.90 0.53 0.68 5,968,757.84 562,169.08 2.99 0.33 GYD-GC-SS(1) 262.56 2.85 44.57 262.51 165.18 2.03 2.24 5,968,759.35 562,170.64 2.31 1.36 GYD-GC-SS(1) 358.25 5.81 36.92 357.92 260.59 7.60 6.82 5,968,764.91 562,175.22 3.14 5.51 GYD-GC-SS(1) 451.26 10.02 38.49 450.02 352.69 17.70 14.68 5,968,775.01 562,183.08 4.53 13.15 GYD-GC-SS(1) 506.54 11.51 38.76 504.33 407.00 25.77 21.13 5,968,783.08 562,189.53 2.70 19.20 GYD-GC-SS(1) 543.66 12.36 38.61 540.64 443.31 31.76 25.93 5,968,789.07 562,194.33 2.29 23.70 GYD-GC-SS(1) 635.92 13.19 35.16 630.62 533.29 48.08 38.15 5,968,805.39 562,206.55 1.22 36.17 GYD-GC-SS(1) 11/4/2015 2:16:04PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 728.05 12.36 42.72 720.48 623.15 63.92 50.89 5,968,821.23 562,219.29 2.02 48.03 GYD-GC-SS(1) 822.11 12.26 48.63 812.38 715.05 77.92 65.22 5,968,835.23 562,233.61 1.34 57.70 GYD-GC-SS(1) 914.71 13.18 48.83 902.70 805.37 91.37 80.54 5,968,848.67 562,248.94 0.99 66.57 GYD-GC-SS(1) 1,011.51 12.95 50.81 997.00 899.67 105.49 97.26 5,968,862.79 562,265.65 0.52 75.72 GYD-GC-SS(1) 1,105.83 11.53 57.10 1,089.18 991.85 117.29 113.36 5,968,874.59 562,281.75 2.06 82.80 GYD-GC-SS(1) 1,201.06 13.64 58.01 1,182.11 1,084.78 128.41 130.88 5,968,885.71 562,299.27 2.23 88.84 GYD-GC-SS(1) 1,296.61 14.24 60.50 1,274.85 1,177.52 140.17 150.66 5,968,897.46 562,319.05 0.89 94.89 GYD-GC-SS(1) 1,355.32 15.88 61.36 1,331.54 1,234.21 147.57 164.00 5,968,904.87 562,332.38 2.82 98.48 MWD+IFR-AK-CAZ-SC(2) 1,449.60 18.73 62.30 1,421.54 1,324.21 160.79 188.72 5,968,918.09 562,357.11 3.04 104.62 MWD+IFR-AK-CAZ-SC(2) 1,544.23 18.75 61.31 1,511.16 1,413.83 175.16 215.52 5,968,932.45 562,383.90 0.34 111.32 MWD+IFR-AK-CAZ-SC(2) 1,638.81 21.13 62.03 1,600.06 1,502.73 190.45 243.91 5,968,947.75 562,412.29 2.53 118.49 MWD+IFR-AK-CAZ-SC(2) 1,733.27 23.94 63.68 1,687.30 1,589.97 206.94 276.13 5,968,964.23 562,444.51 3.05 125.78 MWD+IFR-AK-CAZ-SC(2) 1,828.83 26.49 65.10 1,773.75 1,676.42 224.52 312.85 5,968,981.81 562,481.22 2.74 132.92 MWD+IFR-AK-CAZ-SC(2) 1,922.58 30.35 62.46 1,856.19 1,758.86 244.28 352.83 5,969,001.57 562,521.20 4.33 141.30 MWD+IFR-AK-CAZ-SC(2) 2,017.51 32.94 61.06 1,937.00 1,839.67 267.86 396.69 5,969,025.15 562,565.05 2.84 152.33 MWD+IFR-AK-CAZ-SC(2) 2,113.33 33.26 61.43 2,017.27 1,919.94 293.04 442.56 5,969,050.32 562,610.92 0.39 164.36 MWD+IFR-AK-CAZ-SC(2) 2,208.09 34.69 61.37 2,095.85 1,998.52 318.39 489.06 5,969,075.67 562,657.41 1.51 176.39 MWD+IFR-AK-CAZ-SC(2) 2,302.52 40.92 62.14 2,170.42 2,073.09 345.74 540.03 5,969,103.02 562,708.38 6.62 189.15 MWD+IFR-AK-CAZ-SC(2) 2,396.14 42.31 61.12 2,240.41 2,143.08 375.29 594.73 5,969,132.57 562,763.08 1.65 203.04 MWD+IFR-AK-CAZ-SC(2) 2,492.78 42.58 59.35 2,311.73 2,214.40 407.67 651.34 5,969,164.95 562,819.68 1.27 219.15 MWD+IFR-AK-CAZ-SC(2) 2,562.37 45.53 58.19 2,361.74 2,264.41 432.77 692.71 5,969,190.04 562,861.04 4.39 232.30 MWD+IFR-AK-CAZ-SC(2) 2,636.90 48.14 57.42 2,412.72 2,315.39 461.74 738.70 5,969,219.01 562,907.03 3.58 247.95 MV1 NOT an Actual Survey 3) 10314"x13-112 2,661.47 49.00 57.18 2,428.98 2,331.65 471.69 754.20 5,969,228.96 562,922.53 3.58 253.41 MWD+IFR-AK-CAZ-SC(3) 2,756.23 49.43 59.65 2,490.88 2,393.55 509.26 815.31 5,969,266.53 562,983.64 2.03 273.31 MWD+IFR-AK-CAZ-SC(3) 2,851.73 49.53 61.23 2,552.93 2,455.60 545.08 878.46 5,969,302.34 563,046.77 1.26 290.98 MWD+IFR-AK-CAZ-SC(3) 2,946.62 48.36 59.88 2,615.25 2,517.92 580.25 940.77 5,969,337.50 563,109.08 1.63 308.26 MWD+IFR-AK-CAZ-SC(3) 3,040.99 48.13 62.55 2,678.11 2,580.78 614.14 1,002.45 5,969,371.40 563,170.76 2.12 324.47 MWD+IFR-AK-CAZ-SC(3) 3,135.79 48.13 62.44 2,741.38 2,644.05 646.75 1,065.07 5,969,404.00 563,233.37 0.09 339.19 MWD+IFR-AK-CAZ-SC(3) 3,231.09 48.10 64.34 2,805.01 2,707.68 678.53 1,128.50 5,969,435.77 563,296.79 1.48 352.90 MWD+IFR-AK-CAZ-SC(3) 3,326.04 48.29 65.22 2,868.30 2,770.97 708.69 1,192.53 5,969,465.93 563,360.81 0.72 364.88 MWD+IFR-AK-CAZ-SC(3) 3,420.19 49.69 61.07 2,930.10 2,832.77 740.79 1,255.87 5,969,498.03 563,424.15 3.64 378.93 MWD+IFR-AK-CAZ-SC(3) 3,513.67 51.45 57.09 2,989.48 2,892.15 777.91 1,317.77 5,969,535.14 563,486.04 3.79 398.18 MWD+IFR-AK-CAZ-SC(3) 3,609.56 52.75 55.03 3,048.39 2,951.06 820.16 1,380.53 5,969,577.39 563,548.80 2.17 422.16 MWD+IFR-AK-CAZ-SC(3) 3,704.09 54.26 51.54 3,104.62 3,007.29 865.60 1,441.41 5,969,622.83 563,609.68 3.37 449.71 MWD+IFR-AK-CAZ-SC(3) 3,799.51 54.86 47.17 3,159.97 3,062.64 916.23 1,500.37 5,969,673.45 563,668.62 3.78 482.78 MWD+IFR-AK-CAZ-SC(3) 3,894.09 54.87 41.59 3,214.43 3,117.10 971.47 1,554.43 5,969,728.69 563,722.68 4.82 521.60 MWD+IFR-AK-CAZ-SC(3) 3,988.94 55.15 36.18 3,268.84 3,171.51 1,031.93 1,603.17 5,969,789.14 563,771.42 4.68 566.87 MWD+IFR-AK-CAZ-SC(3) 4,083.41 55.57 31.10 3,322.57 3,225.24 1,096.61 1,646.19 5,969,853.81 563,814.44 4.45 617.72 MWD+IFR-AK-CAZ-SC(3) 4,177.80 55.87 28.38 3,375.74 3,278.41 1,164.32 1,684.87 5,969,921.52 563,853.11 2.40 672.66 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 2:16:04PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,272.48 56.77 25.40 3,428.25 3,330.92 1,234.58 1,720.49 5,969,991.78 563,888.73 2.79 730.88 MWD+IFR-AK-CAZ-SC(3) 4,368.03 58.12 20.49 3,479.69 3,382.36 1,308.72 1,751.84 5,970,065.91 563,920.08 4.56 793.97 MWD+IFR-AK-CAZ-SC(3) 4,462.89 58.96 14.84 3,529.22 3,431.89 1,385.78 1,776.36 5,970,142.96 563,944.59 5.16 861.69 MW D+I FR-AK-CAZ-SC(3) 4,557.64 59.76 12.52 3,577.52 3,480.19 1,464.98 1,795.63 5,970,222.15 563,963.86 2.27 932.88 MW D+I FR-AK-CAZ-SC(3) 4,652.34 62.85 8.40 3,623.00 3,525.67 1,546.64 1,810.66 5,970,303.81 563,978.89 5.02 1,007.58 MW D+I FR-AK-CAZ-SC(3) 4,747.03 65.86 5.24 3,663.98 3,566.65 1,631.38 1,820.76 5,970,388.54 563,988.99 4.38 1,086.55 MWD+IFR-AK-CAZ-SC(3) 4,841.67 69.38 1.29 3,700.02 3,602.69 1,718.72 1,825.70 5,970,475.86 563,993.93 5.36 1,169.40 MWD+IFR-AK-CAZ-SC(3) 4,937.34 72.08 356.95 3,731.60 3,634.27 1,808.98 1,824.29 5,970,566.12 563,992.51 5.13 1,256.77 MWD+IFR-AK-CAZ-SC(3) 5,031.94 73.84 353.15 3,759.33 3,662.00 1,899.07 1,816.47 5,970,656.20 563,984.69 4.27 1,345.68 MW D+I FR-AK-CAZ-SC(3) 5,126.45 74.94 350.56 3,784.77 3,687.44 1,989.16 1,803.56 5,970,746.28 563,971.79 2.88 1,435.95 MW D+I FR-AK-CAZ-SC(3) 5,221.78 76.23 347.98 3,808.50 3,711.17 2,079.86 1,786.37 5,970,836.97 563,954.60 2.95 1,527.95 MW D+I FR-AK-CAZ-SC(3) 5,316.17 79.21 347.87 3,828.58 3,731.25 2,170.04 1,767.07 5,970,927.15 563,935.30 3.16 1,620.01 MW D+I FR-AK-CAZ-SC(3) 5,411.08 82.97 346.48 3,843.28 3,745.95 2,261.45 1,746.25 5,971,018.54 563,914.49 4.22 1,713.66 MW D+I FR-AK-CAZ-SC(3) 5,505.72 86.80 344.79 3,851.71 3,754.38 2,352.74 1,722.87 5,971,109.83 563,891.10 4.42 1,807.88 MWD+IFR-AK-CAZSC(3) 5,559.45 86.86 345.18 3,854.68 3,757.35 2,404.55 1,708.97 5,971,161.64 563,877.20 0.73 1,861.53 MWD+IFR-AK-CAZ-SC(3) 5,614.00 86.65 344.85 3,857.77 3,760.44 2,457.17 1,694.88 5,971,214.24 563,863.12 0.70 1,915.99 MV'NOT an Actual Survey 3) 7-5/8"x 9-7/8" 5,655.00 86.50 344.61 3,860.22 3,762.89 2,496.65 1,684.11 5,971,253.72 563,852.35 0.70 1,956.92 MWD+IFR-AK-CAZ-SC(3) 5,710.88 86.46 343.42 3,863.65 3,766.32 2,550.26 1,668.74 5,971,307.33 563,836.99 2.13 2,012.69 MWD+IFR-AK-CAZ-SC(3) 5,806.50 86.45 342.57 3,869.56 3,772.23 2,641.53 1,640.83 5,971,398.59 563,809.08 0.89 2,108.09 MWD+IFR-AK-CAZ-SC(3) 5,855.89 87.25 340.88 3,872.28 3,774.95 2,688.35 1,625.37 5,971,445.41 563,793.61 3.78 2,157.34 MWD+IFR-AK-CAZ-SC(3) 5,901.05 87.90 337.78 3,874.19 3,776.86 2,730.56 1,609.44 5,971,487.61 563,777.69 7.01 2,202.27 MWD+IFR-AK-CAZ-SC(3) 5,946.09 89.00 336.53 3,875.41 3,778.08 2,772.05 1,591.96 5,971,529.10 563,760.21 3.70 2,246.92 MWD+IFR-AK-CAZ-SC(3) 5,995.85 89.93 333.62 3,875.87 3,778.54 2,817.17 1,570.99 5,971,574.21 563,739.24 6.14 2,296.00 MWD+IFR-AK-CAZ-SC(3) 6,090.97 91.27 330.59 3,874.87 3,777.54 2,901.22 1,526.49 5,971,658.25 563,694.75 3.48 2,388.87 MWD+IFR-AK-CAZ-SC(3) 6,185.34 92.76 329.19 3,871.56 3,774.23 2,982.80 1,479.18 5,971,739.83 563,647.44 2.17 2,480.12 MWD+IFR-AK-CAZ-SC(3) 6,281.15 92.05 333.10 3,867.53 3,770.20 3,066.62 1,432.99 5,971,823.64 563,601.26 4.14 2,573.22 MWD+I FR-AK-CAZ-SC(3) 6,376.67 91.33 337.50 3,864.71 3,767.38 3,153.34 1,393.10 5,971,910.35 563,561.37 4.67 2,667.44 MW D+I FR-AK-CAZ-SC(3) 6,469.98 91.47 337.79 3,862.44 3,765.11 3,239.61 1,357.62 5,971,996.61 563,525.89 0.35 2,760.05 MW D+I FR-AK-CAZ-SC(3) 6,564.35 90.37 338.34 3,860.92 3,763.59 3,327.14 1,322.37 5,972,084.13 563,490.65 1.30 2,853.81 MWD+IFR-AK-CAZ-SC(3) 6,659.89 88.58 340.01 3,861.80 3,764.47 3,416.42 1,288.41 5,972,173.41 563,456.69 2.56 2,948.92 MWD+IFR-AK-CAZ-SC(3) 6,754.22 88.80 340.93 3,863.95 3,766.62 3,505.30 1,256.88 5,972,262.28 563,425.16 1.00 3,042.99 MWD+IFR-AK-CAZ-SC(3) 6,849.07 87.60 343.34 3,866.93 3,769.60 3,595.52 1,227.80 5,972,352.49 563,396.08 2.84 3,137.70 MWD+IFR-AK-CAZ-SC(3) 6,944.61 87.25 345.03 3,871.22 3,773.89 3,687.35 1,201.78 5,972,444.31 563,370.07 1.80 3,233.14 MWD+IFR-AK-CAZ-SC(3) 7,039.46 86.17 343.53 3,876.67 3,779.34 3,778.50 1,176.12 5,972,535.45 563,344.41 1.95 3,327.82 MWD+1FR-AK-CAZ-SC(3) 7,134.55 87.27 341.88 3,882.11 3,784.78 3,869.13 1,147.90 5,972,626.08 563,316.19 2.08 3,422.71 MWD+IFR-AK-CAZ-SC(3) 7,228.56 90.18 339.33 3,884.20 3,786.87 3,957.77 1,116.69 5,972,714.70 563,284.99 4.12 3,516.45 MWD+IFR-AK-CAZ-SC(3) 7,322.88 90.99 340.91 3,883.24 3,785.91 4,046.46 1,084.62 5,972,803.38 563,252.91 1.88 3,610.49 MWD+IFR-AK-CAZ-SC(3) 7,417.58 91.33 344.49 3,881.32 3,783.99 4,136.84 1,056.46 5,972,893.76 563,224.76 3.80 3,705.10 MWD+I FR-AK-CAZ-SC(3) 7,512.75 91.78 345.63 3,878.74 3,781.41 4,228.76 1,031.93 5,972,985.66 563,200.24 1.29 3,800.23 MWD+IFR-AK-CAZ-SC(3) 7,606.78 92.78 342.74 3,875.00 3,777.67 4,319.14 1,006.33 5,973,076.04 563,174.63 3.25 3,894.17 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 2.:16:04PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,702.30 93.59 342.82 3,869.69 3,772.36 4,410.24 978.09 5,973,167.13 563,146.40 0.85 3,989.50 MWD+IFR-AK-CAZ-SC(3) 7,795.97 91.06 340.65 3,865.89 3,768.56 4,499.10 948.76 5,973,255.98 563,117.07 3.56 4,082.97 MWD+IFR-AK-CAZ-SC(3) 7,890.81 88.57 339.25 3,866.19 3,768.86 4,588.18 916.25 5,973,345.06 563,084.56 3.01 4,177.50 MWD+IFR-AK-CAZ-SC(3) 7,985.07 89.14 341.35 3,868.08 3,770.75 4,676.90 884.48 5,973,433.77 563,052.79 2.31 4,271.48 MWD+IFR-AK-CAZ-SC(3) 8,080.86 90.00 341.68 3,868.80 3,771.47 4,767.75 854.10 5,973,524.60 563,022.42 0.96 4,367.13 MWD+IFR-AK-CAZ-SC(3) 8,175.44 90.13 344.43 3,868.69 3,771.36 4,858.21 826.54 5,973,615.06 562,994.86 2.91 4,461.67 MWD+IFR-AK-CAZ-SC(3) 8,270.97 89.19 347.30 3,869.26 3,771.93 4,950.84 803.21 5,973,707.67 562,971.53 3.16 4,557.16 MWD+IFR-AK-CAZ-SC(3) 8,365.24 90.17 346.26 3,869.78 3,772.45 5,042.60 781.65 5,973,799.43 562,949.97 1.52 4,651.35 MWD+IFR-AK-CAZ-SC(3) 8,460.17 91.48 346.82 3,868.42 3,771.09 5,134.91 759.55 5,973,891.73 562,927.88 1.50 4,746.21 MWD+IFR-AK-CAZ-SC(3) 8,509.33 89.57 344.62 3,867.97 3,770.64 5,182.55 747.43 5,973,939.36 562,915.76 5.93 4,795.36 MWD+IFR-AK-CAZ-SC(3) 8,555.56 88.87 342.56 3,868.60 3,771.27 5,226.89 734.37 5,973,983.70 562,902.70 4.71 4,841.57 MWD+IFR-AK-CAZ-SC(3) 8,599.91 88.09 339.14 3,869.77 3,772.44 5,268.76 719.82 5,974,025.57 562,888.16 7.91 4,885.81 MWD+IFR-AK-CAZ-SC(3) 8,651.08 88.39 337.68 3,871.34 3,774.01 5,316.32 701.00 5,974,073.12 562,869.34 2.91 4,936.66 MWD+IFR-AK-CAZ-SC(3) 8,695.84 88.10 339.10 3,872.71 3,775.38 5,357.91 684.53 5,974,114.71 562,852.86 3.24 4,981.14 MWD+IFR-AK-CAZ-SC(3) 8,746.37 88.69 341.69 3,874.13 3,776.80 5,405.49 667.58 5,974,162.28 562,835.92 5.25 5,031.52 MWD+IFR-AK-CAZ-SC(3) 8,794.67 89.35 343.53 3,874.96 3,777.63 5,451.57 653.14 5,974,208.36 562,821.48 4.05 5,079.78 MWD+IFR-AK-CAZ-SC(3) 8,840.62 90.37 346.30 3,875.07 3,777.74 5,495.93 641.19 5,974,252.72 562,809.53 6.42 5,125.72 MWD+IFR-AK-CAZ-SC(3) 8,884.48 90.68 347.69 3,874.67 3,777.34 5,538.66 631.31 5,974,295.44 562,799.66 3.25 5,169.54 MWD+IFR-AK-CAZ-SC(3) 8,930.14 90.65 349.93 3,874.14 3,776.81 5,583.45 622.45 5,974,340.23 562,790.80 4.91 5,215.07 MWD+IFR-AK-CAZ-SC(3) 9,027.84 90.82 350.52 3,872.88 3,775.55 5,679.72 605.86 5,974,436.49 562,774.21 0.63 5,312.28 MWD+IFR-AK-CAZ-SC(3) 9,124.10 90.17 349.77 3,872.05 3,774.72 5,774.55 589.39 5,974,531.31 562,757.73 1.03 5,408.07 MWD+IFR-AK-CAZ-SC(3) 9,219.27 90.20 347.85 3,871.74 3,774.41 5,867.91 570.92 5,974,624.66 562,739.26 2.02 5,502.97 MWD+IFR-AK-CAZ-SC(3) 9,314.50 90.24 345.49 3,871.38 3,774.05 5,960.57 548.96 5,974,717.31 562,717.31 2.48 5,598.13 MWD+IFR-AK-CAZ-SC(3) 9,410.83 90.37 343.97 3,870.87 3,773.54 6,053.49 523.59 5,974,810.22 562,691.94 1.58 5,694.45 MWD+IFR-AK-CAZ-SC(3) 9,505.99 89.30 342.44 3,871.14 3,773.81 6,144.59 496.09 5,974,901.31 562,664.44 1.96 5,789.58 MWD+IFR-AK-CAZ-SC(3) 9,600.93 89.72 341.69 3,871.95 3,774.62 6,234.91 466.85 5,974,991.62 562,635.21 0.91 5,884.43 MWD+IFR-AK-CAZ-SC(3) 9,696.23 90.48 343.58 3,871.79 3,774.46 6,325.86 438.41 5,975,082.57 562,606.77 2.14 5,979.67 MWD+IFR-AK-CAZ-SC(3) 9,790.90 89.96 345.00 3,871.42 3,774.09 6,416.99 412.77 5,975,173.69 562,581.13 1.60 6,074.34 MWD+IFR-AK-CAZ-SC(3) 9,886.01 89.34 345.53 3,872.00 3,774.67 6,508.97 388.58 5,975,265.66 562,556.94 0.86 6,169.44 MWD+IFR-AK-CAZ-SC(3) 9,980.28 90.17 345.81 3,872.41 3,775.08 6,600.30 365.24 5,975,356.98 562,533.61 0.93 6,263.69 MWD+IFR-AK-CAZ-SC(3) 10,073.93 91.00 348.08 3,871.45 3,774.12 6,691.52 344.09 5,975,448.19 562,512.46 2.58 6,357.24 MWD+IFR-AK-CAZ-SC(3) 10,171.36 89.86 346.98 3,870.72 3,773.39 6,786.64 323.05 5,975,543.31 562,491.42 1.63 6,454.53 MWD+IFR-AK-CAZ-SC(3) 10,266.80 90.03 345.57 3,870.81 3,773.48 6,879.36 300.40 5,975,636.01 562,468.78 1.49 6,549.92 MWD+IFR-AK-CAZ-SC(3) 10,361.88 90.44 345.47 3,870.42 3,773.09 6,971.41 276.63 5,975,728.06 562,445.00 0.44 6,644.99 MWD+IFR-AK-CAZ-SC(3) 10,456.80 89.52 342.64 3,870.45 3,773.12 7,062.67 250.55 5,975,819.31 562,418.93 3.14 6,739.90 MWD+IFR-AK-CAZ-SC(3) 10,551.76 88.99 343.88 3,871.69 3,774.36 7,153.60 223.20 5,975,910.22 562,391.58 1.42 6,834.82 MWD+IFR-AK-CAZ-SC(3) 10,647.01 89.93 346.47 3,872.59 3,775.26 7,245.66 198.83 5,976,002.28 562,367.21 2.89 6,930.05 MWD+IFR-AK-CAZ-SC(3) 10,741.22 90.38 345.83 3,872.33 3,775.00 7,337.13 176.27 5,976,093.74 562,344.66 0.83 7,024.22 MWD+IFR-AK-CAZ-SC(3) 10,836.68 94.03 344.76 3,868.66 3,771.33 7,429.38 152.06 5,976,185.98 562,320.45 3.98 7,119.59 MWD+IFR-AK-CAZ-SC(3) 10,930.03 94.57 345.64 3,861.66 3,764.33 7,519.37 128.28 5,976,275.97 562,296.67 1.10 7,212.67 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 2:16:04PM Page 5 COMPASS 5000.1 Build 74 • • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: Grid Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 11,026.85 93.43 346.48 3,854.91 3,757.58 7,613.11 105.01 5,976,369.70 562,273.40 1.46 7,309.21 MWD+IFR-AK-CAZ-SC(3) 11,122.36 91.12 346.85 3,851.11 3,753.78 7,705.97 83.00 5,976,462.54 562,251.39 2.45 7,404.58 MWD+IFR-AK-CAZ-SC(3) 11,217.63 90.72 345.22 3,849.59 3,752.26 7,798.40 60.01 5,976,554.97 562,228.40 1.76 7,499.80 MWD+IFR-AK-CAZ-SC(3) 11,312.44 91.30 344.14 3,847.91 3,750.58 7,889.83 34.96 5,976,646.39 562,203.36 1.29 7,594.59 MWD+IFR-AK-CAZ-SC(3) 11,407.14 91.06 343.90 3,845.96 3,748.63 7,980.85 8.89 5,976,737.40 562,177.29 0.36 7,689.27 MWD+IFR-AK-CAZ-SC(3) 11,502.69 90.91 344.04 3,844.32 3,746.99 8,072.67 -17.49 5,976,829.21 562,150.91 0.21 7,784.80 MWD+IFR-AK-CAZ-SC(3) 11,597.35 87.98 339.62 3,845.24 3,747.91 8,162.57 -47.00 5,976,919.10 562,121.41 5.60 7,879.31 MWD+IFR-AK-CAZ-SC(3) 11,691.83 88.49 341.55 3,848.15 3,750.82 8,251.63 -78.39 5,977,008.15 562,090.02 2.11 7,973.52 MWD+IFR-AK-CAZ-SC(3) 11,786.05 88.97 343.96 3,850.24 3,752.91 8,341.59 -106.32 5,977,098.10 562,062.09 2.61 8,067.67 MWD+IFR-AK-CAZ-SC(3) 11,878.44 89.48 345.55 3,851.49 3,754.16 8,430.71 -130.61 5,977,187.22 562,037.80 1.81 8,160.04 MWD+IFR-AK-CAZ-SC(3) 11,971.67 90.10 346.97 3,851.83 3,754.50 8,521.27 -152.76 5,977,277.77 562,015.66 1.66 8,253.23 MWD+IFR-AK-CAZ-SC(3) 12,064.22 90.61 347.93 3,851.26 3,753.93 8,611.61 -172.87 5,977,368.09 561,995.55 1.17 8,345.65 MWD+IFR-AK-CAZ-SC(3) 12,155.62 91.59 348.07 3,849.50 3,752.17 8,700.99 -191.87 5,977,457.47 561,976.55 1.08 8,436.87 MWD+IFR-AK-CAZ-SC(3) 12,247.88 90.51 349.31 3,847.81 3,750.48 8,791.44 -209.96 5,977,547.91 561,958.46 1.78 8,528.87 MWD+IFR-AK-CAZ-SC(3) 12,340.10 88.39 347.03 3,848.70 3,751.37 8,881.69 -228.87 5,977,638.15 561,939.55 3.38 8,620.88 MWD+IFR-AK-CAZ-SC(3) 12,433.30 89.45 346.08 3,850.45 3,753.12 8,972.31 -250.54 5,977,728.77 561,917.89 1.53 8,714.01 MWD+IFR-AK-CAZ-SC(3) 12,525.84 90.24 345.87 3,850.70 3,753.37 9,062.09 -272.97 5,977,818.54 561,895.46 0.88 8,806.52 MWD+IFR-AK-CAZ-SC(3) 12,619.22 90.58 346.13 3,850.03 3,752.70 9,152.69 -295.56 5,977,909.13 561,872.87 0.46 8,899.86 MWD+IFR-AK-CAZ-SC(3) 12,680.00 90.58 346.13 3,849.42 3,752.09 9,211.70 -310.13 5,977,968.13 561,858.30 0.00 8,960.62 PROJECTED to TD NOT an Actual Surrey Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. [ Yes ❑ No i have checked to the best of my ability that the following data is correct: Surface Coordinates n Declination & Convergence LJ GRS Survey Corrections p Survey Tool Codes Vincent .gang Swat by NncWR OSera Mcn-1.1riart Cann o-xukrnbagm. SLB DE_ Osara onor..vos,.,,-at.rtr•,c.vs cmc.2V1.1-D.1418 SI MD Dg0.,Cncat+u-.c.w ,t KelseyHallford V0 rtrs '"In0 Client Representative: Date: 04-Nov-2015 11/4/2015 2:16:04PM Page 6 COMPASS 5000.1 Build 74 • 0 215166 26461 r FINAL 2 ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1C-154 Definitive Survey Report 04 November, 2015 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1C-154 Well Position +N/-S 0.00 usft Northing: 5,968,509.07 usfl Latitude: 70° 19'29.567 N +E/-W 0.00 usft Easting: 1,702,200.32 usfl Longitude: 149°29'56.359 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 57.60 usft Wellbore 1C-154 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 10/15/2015 18.92 80.99 57,505 Design 1C-154 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.73 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.73 0.00 0.00 345.00 Survey Program Date 11/4/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 86.95 1,296.61 1C-154 Srvy#1 -GWD(1C-154) GYD-GC-SS Gyrodata gyro single shots 10/23/2015 2:1 1,355.32 2,562.37 1C-154 Srvy#2-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8: 2,661.47 12,619.22 1C-154 Srvy#3-GMAG(1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/26/2015 8: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.73 0.00 0.00 39.73 -57.60 0.00 0.00 5,968,509.07 1,702,200.32 0.00 0.00 UNDEFINED 86.95 0.07 102.10 86.95 -10.38 -0.01 0.03 5,968,509.06 1,702,200.35 0.15 -0.01 GYD-GC-SS(1) 122.20 0.11 61.68 122.20 24.87 0.01 0.08 5,968,509.08 1,702,200.40 0.21 -0.02 C NOT an Actual Survey 20"x 42" 160.11 0.18 45.94 160.11 62.78 0.06 0.15 5,968,509.14 1,702,200.47 0.21 0.02 GYD-GC-SS(1) 206.24 1.56 49.19 206.23 108.90 0.53 0.68 5,968,509.60 1,702,201.00 2.99 0.33 GYD-GC-SS(1) 262.56 2.85 45.04 262.51 165.18 2.02 2.25 5,968,511.10 1,702,202.56 2.31 1.36 GYD-GC-SS(1) 358.25 5.81 37.39 357.92 260.59 7.55 6.88 5,968,516.67 1,702,207.14 3.14 5.51 GYD-GC-SS(1) 451.26 10.02 38.96 450.02 352.69 17.58 14.83 5,968,526.77 1,702,215.00 4.53 13.15 GYD-GC-SS(1) 506.54 11.51 39.23 504.33 407.00 25.60 21.34 5,968,534.84 1,702,221.45 2.70 19.20 GYD-GC-SS(1) 543.66 12.36 39.08 540.64 443.31 31.55 26.19 5,968,540.83 1,702,226.24 2.29 23.70 GYD-GC-SS(1) 635.92 13.19 35.63 630.62 533.29 47.77 38.54 5,968,557.15 1,702,238.47 1.22 36.17 GYD-GC-SS(1) 11/4/2015 1:35:07PM Page 2 COMPASS 5000.1 Build 74 0 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 728.05 12.36 43.19 720.48 623.15 63.50 51.42 5,968,572.99 1,702,251.21 2.02 48.03 GYD-GC-SS(1) 822.11 12.26 49.10 812.38 715.05 77.38 65.86 5,968,586.98 1,702,265.53 1.34 57.70 GYD-GC-SS(1) 914.71 13.18 49.30 902.70 805.37 90.70 81.29 5,968,600.43 1,702,280.85 0.99 66.57 GYD-GC-SS(1) 1,011.51 12.95 51.28 997.00 899.67 104.68 98.12 5,968,614.55 1,702,297.57 0.52 75.72 GYD-GC-SS(1) 1,105.83 11.53 57.57 1,089.18 991.85 116.35 114.32 5,968,626.35 1,702,313.67 2.06 82.80 GYD-GC-SS(1) 1,201.06 13.64 58.48 1,182.11 1,084.78 127.33 131.93 5,968,637.47 1,702,331.19 2.23 88.84 GYD-GC-SS(1) 1,296.61 14.24 60.97 1,274.85 1,177.52 138.92 151.81 5,968,649.22 1,702,350.97 0.89 94.89 GYD-GC-SS(1) 1,355.32 15.88 61.83 1,331.54 1,234.21 146.22 165.21 5,968,656.63 1,702,364.30 2.82 98.48 MWD+IFR-AK-CAZ-SC(2) 1,449.60 18.73 62.77 1,421.54 1,324.21 159.23 190.04 5,968,669.85 1,702,389.03 3.04 104.62 MWD+IFR-AK-CAZ-SC(2) 1,544.23 18.75 61.78 1,511.16 1,413.83 173.38 216.95 5,968,684.21 1,702,415.82 0.34 111.32 MWD+IFR-AK-CAZ-SC(2) 1,638.81 21.13 62.50 1,600.06 1,502.73 188.44 245.47 5,968,699.51 1,702,444.21 2.53 118.49 MWD+IFR-AK-CAZ-SC(2) 1,733.27 23.94 64.15 1,687.30 1,589.97 204.66 277.83 5,968,715.99 1,702,476.43 3.05 125.78 MWD+IFR-AK-CAZ-SC(2) 1,828.83 26.49 65.57 1,773.75 1,676.42 221.93 314.69 5,968,733.56 1,702,513.14 2.74 132.92 MWD+IFR-AK-CAZ-SC(2) 1,922.58 30.35 62.93 1,856.19 1,758.86 241.37 354.83 5,968,753.33 1,702,553.12 4.33 141.30 MWD+IFR-AK-CAZ-SC(2) 2,017.51 32.94 61.53 1,937.00 1,839.67 264.59 398.88 5,968,776.91 1,702,596.97 2.84 152.33 MWD+IFR-AK-CAZ-SC(2) 2,113.33 33.26 61.90 2,017.27 1,919.94 289.38 444.96 5,968,802.08 1,702,642.84 0.39 164.36 MWD+IFR-AK-CAZ-SC(2) 2,208.09 34.69 61.84 2,095.85 1,998.52 314.35 491.66 5,968,827.43 1,702,689.33 1.51 176.39 MWD+IFR-AK-CAZ-SC(2) 2,302.52 40.92 62.61 2,170.42 2,073.09 341.29 542.86 5,968,854.78 1,702,740.30 6.62 189.15 MWD+IFR-AK-CAZ-SC(2) 2,396.14 42.31 61.59 2,240.41 2,143.08 370.38 597.80 5,968,884.33 1,702,795.00 1.65 203.04 MWD+IFR-AK-CAZ-SC(2) 2,492.78 42.58 59.82 2,311.73 2,214.40 402.30 654.68 5,968,916.70 1,702,851.60 1.27 219.15 MWD+IFR-AK-CAZ-SC(2) 2,562.37 45.53 58.66 2,361.74 2,264.41 427.05 696.25 5,968,941.80 1,702,892.96 4.39 232.30 MWD+IFR-AK-CAZ-SC(2) 2,636.90 48.14 57.89 2,412.72 2,315.39 455.64 742.48 5,968,970.76 1,702,938.95 3.58 247.95 NOT an Actual Survey (3) 10 3/4"x 13-1/2 2,661.47 49.00 57.65 2,428.98 2,331.65 465.47 758.06 5,968,980.72 1,702,954.45 3.58 253.41 MWD+IFR-AK-CAZ-SC(3) 2,756.23 49.43 60.12 2,490.88 2,393.55 502.53 819.48 5,969,018.28 1,703,015.56 2.03 273.31 MWD+IFR-AK-CAZ-SC(3) 2,851.73 49.53 61.70 2,552.93 2,455.60 537.83 882.91 5,969,054.10 1,703,078.69 1.26 290.98 MWD+IFR-AK-CAZ-SC(3) 2,946.62 48.36 60.35 2,615.25 2,517.92 572.48 945.51 5,969,089.26 1,703,141.00 1.63 308.26 MWD+IFR-AK-CAZ-SC(3) 3,040.99 48.13 63.02 2,678.11 2,580.78 605.87 1,007.48 5,969,123.16 1,703,202.68 2.12 324.47 MWD+IFR-AK-CAZ-SC(3) 3,135.79 48.13 62.91 2,741.38 2,644.05 637.96 1,070.36 5,969,155.76 1,703,265.29 0.09 339.19 MWD+IFR-AK-CAZ-SC(3) 3,231.09 48.10 64.81 2,805.01 2,707.68 669.21 1,134.04 5,969,187.53 1,703,328.71 1.48 352.90 MWD+IFR-AK-CAZ-SC(3) 3,326.04 48.29 65.69 2,868.30 2,770.97 698.84 1,198.32 5,969,217.69 1,703,392.73 0.72 364.88 MWD+IFR-AK-CAZ-SC(3) 3,420.19 49.69 61.54 2,930.10 2,832.77 730.43 1,261.92 5,969,249.79 1,703,456.07 3.64 378.93 MWD+IFR-AK-CAZ-SC(3) 3,513.67 51.45 57.56 2,989.48 2,892.15 767.03 1,324.13 5,969,286.90 1,703,517.96 3.79 398.18 MWD+IFR-AK-CAZ-SC(3) 3,609.56 52.75 55.50 3,048.39 2,951.06 808.76 1,387.23 5,969,329.15 1,703,580.71 2.17 422.16 MWD+IFR-AK-CAZ-SC(3) 3,704.09 54.26 52.01 3,104.62 3,007.29 853.70 1,448.49 5,969,374.59 1,703,641.59 3.37 449.71 MWD+IFR-AK-CAZ-SC(3) 3,799.51 54.86 47.64 3,159.97 3,062.64 903.84 1,507.86 5,969,425.21 1,703,700.54 3.78 482.78 MWD+IFR-AK-CAZ-SC(3) 3,894.09 54.87 42.06 3,214.43 3,117.10 958.64 1,562.37 5,969,480.45 1,703,754.60 4.82 521.60 MWD+IFR-AK-CAZ-SC(3) 3,988.94 55.15 36.65 3,268.84 3,171.51 1,018.69 1,611.61 5,969,540.90 1,703,803.34 4.68 566.87 MWD+IFR-AK-CAZ-SC(3) 4,083.41 55.57 31.57 3,322.57 3,225.24 1,083.02 1,655.17 5,969,605.57 1,703,846.36 4.45 617.72 MWD+IFR-AK-CAZ-SC(3) 4,177.80 55.87 28.85 3,375.74 3,278.41 1,150.41 1,694.40 5,969,673.28 1,703,885.03 2.40 672.66 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 1:35:07PM Page 3 COMPASS 5000.1 Build 74 r i Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,272.48 56.77 25.87 3,428.25 3,330.92 1,220.37 1,730.60 5,969,743.53 1,703,920.64 2.79 730.88 MWD+IFR-AK-CAZ-SC(3) 4,368.03 58.12 20.96 3,479.69 3,382.36 1,294.25 1,762.56 5,969,817.66 1,703,952.00 4.56 793.97 MWD+IFR-AK-CAZ-SC(3) 4,462.89 58.96 15.31 3,529.22 3,431.89 1,371.10 1,787.71 5,969,894.71 1,703,976.51 5.16 861.69 MWD+IFR-AK-CAZ-SC(3) 4,557.64 59.76 12.99 3,577.52 3,480.19 1,450.15 1,807.63 5,969,973.91 1,703,995.78 2.27 932.88 MWD+IFR-AK-CAZ-SC(3) 4,652.34 62.85 8.87 3,623.00 3,525.67 1,531.68 1,823.33 5,970,055.56 1,704,010.81 5.02 1,007.58 MWD+IFR-AK-CAZ-SC(3) 4,747.03 65.86 5.71 3,663.98 3,566.65 1,616.33 1,834.13 5,970,140.29 1,704,020.91 4.38 1,086.55 MWD+IFR-AK-CAZ-SC(3) 4,841.67 69.38 1.76 3,700.02 3,602.69 1,703.62 1,839.79 5,970,227.62 1,704,025.85 5.36 1,169.40 MWD+IFR-AK-CAZ-SC(3) 4,937.34 72.08 357.42 3,731.60 3,634.27 1,793.90 1,839.12 5,970,317.88 1,704,024.43 5.13 1,256.77 MWD+IFR-AK-CAZ-SC(3) 5,031.94 73.84 353.62 3,759.33 3,662.00 1,884.04 1,832.04 5,970,407.95 1,704,016.61 4.27 1,345.68 MWD+IFR-AK-CAZ-SC(3) 5,126.45 74.94 351.03 3,784.77 3,687.44 1,974.24 1,819.88 5,970,498.04 1,704,003.71 2.88 1,435.95 MWD+IFR-AK-CAZ-SC(3) 5,221.78 76.23 348.45 3,808.50 3,711.17 2,065.08 1,803.43 5,970,588.73 1,703,986.52 2.95 1,527.95 MWD+IFR-AK-CAZ-SC(3) 5,316.17 79.21 348.34 3,828.58 3,731.25 2,155.42 1,784.88 5,970,678.90 1,703,967.22 3.16 1,620.01 MW D+I FR-AK-CAZ-SC(3) 5,411.08 82.97 346.95 3,843.28 3,745.95 2,246.99 1,764.82 5,970,770.30 1,703,946.41 4.22 1,713.66 MWD+IFR-AK-CAZ-SC(3) 5,505.72 86.80 345.26 3,851.71 3,754.38 2,338.47 1,742.18 5,970,861.58 1,703,923.02 4.42 1,807.88 MWD+IFR-AK-CAZ-SC(3) 5,559.45 86.86 345.65 3,854.68 3,757.35 2,390.40 1,728.71 5,970,913.39 1,703,909.12 0.73 1,861.53 MWD+IFR-AK-CAZ-SC(3) 5,614.00 86.65 345.32 3,857.77 3,760.44 2,443.13 1,715.06 5,970,966.00 1,703,895.04 0.70 1,915.99 PNOT an Actual Survey (3) 7-5/8"x 9-7/8" 5,655.00 86.50 345.08 3,860.22 3,762.89 2,482.70 1,704.61 5,971,005.48 1,703,884.26 0.70 1,956.92 MWD+IFR-AK-CAZ-SC(3) 5,710.88 86.46 343.89 3,863.65 3,766.32 2,536.44 1,689.69 5,971,059.09 1,703,868.91 2.13 2,012.69 MWD+I FR-AK-CAZ-SC(3) 5,806.50 86.45 343.04 3,869.56 3,772.23 2,627.93 1,662.53 5,971,150.34 1,703,840.99 0.89 2,108.09 MW D+I FR-AK-CAZ-SC(3) 5,855.89 87.25 341.35 3,872.28 3,774.95 2,674.88 1,647.45 5,971,197.17 1,703,825.53 3.78 2,157.34 MW D+I FR-AK-CAZ-SC(3) 5,901.05 87.90 338.25 3,874.19 3,776.86 2,717.22 1,631.87 5,971,239.37 1,703,809.61 7.01 2,202.27 MWD+I FR-AK-CAZ-SC(3) 5,946.09 89.00 337.00 3,875.41 3,778.08 2,758.85 1,614.73 5,971,280.86 1,703,792.13 3.70 2,246.92 MWD+IFR-AK-CAZ-SC(3) 5,995.85 89.93 334.09 3,875.87 3,778.54 2,804.14 1,594.13 5,971,325.97 1,703,771.16 6.14 2,296.00 MWD+I FR-AK-CAZ-SC(3) 6,090.97 91.27 331.06 3,874.87 3,777.54 2,888.55 1,550.33 5,971,410.01 1,703,726.67 3.48 2,388.87 MWD+I FR-AK-CAZ-SC(3) 6,185.34 92.76 329.66 3,871.56 3,774.23 2,970.52 1,503.69 5,971,491.58 1,703,679.36 2.17 2,480.12 MWD+IFR-AK-CAZ-SC(3) 6,281.15 92.05 333.57 3,867.53 3,770.20 3,054.72 1,458.20 5,971,575.40 1,703,633.18 4.14 2,573.22 MWD+IFR-AK-CAZ-SC(3) 6,376.67 91.33 337.97 3,864.71 3,767.38 3,141.76 1,419.02 5,971,662.11 1,703,593.29 4.67 2,667.44 MWD+IFR-AK-CAZ-SC(3) 6,469.98 91.47 338.26 3,862.44 3,765.11 3,228.32 1,384.25 5,971,748.37 1,703,557.81 0.35 2,760.05 MWD+IFR-AK-CAZ-SC(3) 6,564.35 90.37 338.81 3,860.92 3,763.59 3,316.14 1,349.72 5,971,835.89 1,703,522.57 1.30 2,853.81 MWD+IFR-AK-CAZ-SC(3) 6,659.89 88.58 340.48 3,861.80 3,764.47 3,405.70 1,316.49 5,971,925.17 1,703,488.60 2.56 2,948.92 MWD+IFR-AK-CAZ-SC(3) 6,754.22 88.80 341.40 3,863.95 3,766.62 3,494.83 1,285.70 5,972,014.04 1,703,457.08 1.00 3,042.99 MWD+1FR-AK-CAZ-SC(3) 6,849.07 87.60 343.81 3,866.93 3,769.60 3,585.29 1,257.36 5,972,104.25 1,703,428.00 2.84 3,137.70 MWD+IFR-AK-CAZ-SC(3) 6,944.61 87.25 345.50 3,871.22 3,773.89 3,677.33 1,232.10 5,972,196.07 1,703,401.99 1.80 3,233.14 MWD+IFR-AK-CAZ-SC(3) 7,039.46 86.17 344.00 3,876.67 3,779.34 3,768.68 1,207.20 5,972,287.21 1,703,376.33 1.95 3,327.82 MWD+IFR-AK-CAZ-SC(3) 7,134.55 87.27 342.35 3,882.11 3,784.78 3,859.55 1,179.72 5,972,377.83 1,703,348.11 2.08 3,422.71 MW D+I FR-AK-CAZ-SC(3) 7,228.56 90.18 339.80 3,884.20 3,786.87 3,948.44 1,149.24 5,972,466.46 1,703,316.90 4.12 3,516.45 MWD+1FR-AK-CAZ-SC(3) 7,322.88 90.99 341.38 3,883.24 3,785.91 4,037.39 1,117.90 5,972,555.14 1,703,284.83 1.88 3,610.49 MWD+I FR-AK-CAZ-SC(3) 7,417.58 91.33 344.96 3,881.32 3,783.99 4,128.00 1,090.49 5,972,645.51 1,703,256.68 3.80 3,705.10 MW D+I FR-AK-CAZ-SC(3) 7,512.75 91.78 346.10 3,878.74 3,781.41 4,220.12 1,066.72 5,972,737.42 1,703,232.16 1.29 3,800.23 MWD+IFR-AK-CAZ-SC(3) 7,606.78 92.78 343.21 3,875.00 3,777.67 4,310.71 1,041.86 5,972,827.80 1,703,206.55 3.25 3,894.17 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 1:35:07PM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,702.30 93.59 343.29 3,869.69 3,772.36 4,402.04 1,014.37 5,972,918.89 1,703,178.32 0.85 3,989.50 MWD+IFR-AK-CAZ-SC(3) 7,795.97 91.06 341.12 3,865.89 3,768.56 4,491.14 985.77 5,973,007.74 1,703,148.99 3.56 4,082.97 MWD+IFR-AK-CAZ-SC(3) 7,890.81 88.57 339.72 3,866.19 3,768.86 4,580.48 953.99 5,973,096.82 1,703,116.48 3.01 4,177.50 MWD+IFR-AK-CAZ-SC(3) 7,985.07 89.14 341.82 3,868.08 3,770.75 4,669.46 922.96 5,973,185.53 1,703,084.71 2.31 4,271.48 MWD+IFR-AK-CAZ-SC(3) 8,080.86 90.00 342.15 3,868.80 3,771.47 4,760.55 893.33 5,973,276.36 1,703,054.34 0.96 4,367.13 MWD+IFR-AK-CAZ-SC(3) 8,175.44 90.13 344.90 3,868.69 3,771.36 4,851.24 866.51 5,973,366.82 1,703,026.78 2.91 4,461.67 MWD+IFR-AK-CAZ-SC(3) 8,270.97 89.19 347.77 3,869.26 3,771.93 4,944.05 843.95 5,973,459.43 1,703,003.45 3.16 4,557.16 MWD+IFR-AK-CAZ-SC(3) 8,365.24 90.17 346.73 3,869.78 3,772.45 5,036.00 823.14 5,973,551.19 1,702,981.89 1.52 4,651.35 MWD+IFR-AK-CAZ-SC(3) 8,460.17 91.48 347.29 3,868.42 3,771.09 5,128.48 801.81 5,973,643.49 1,702,959.80 1.50 4,746.21 MWD+IFR-AK-CAZ-SC(3) 8,509.33 89.57 345.09 3,867.97 3,770.64 5,176.22 790.07 5,973,691.12 1,702,947.67 5.93 4,795.36 MWD+IFR-AK-CAZ-SC(3) 8,555.56 88.87 343.03 3,868.60 3,771.27 5,220.66 777.38 5,973,735.46 1,702,934.62 4.71 4,841.57 MWD+IFR-AK-CAZ-SC(3) 8,599.91 88.09 339.61 3,869.77 3,772.44 5,262.65 763.18 5,973,777.33 1,702,920.08 7.91 4,885.81 MWD+IFR-AK-CAZ-SC(3) 8,651.08 88.39 338.15 3,871.34 3,774.01 5,310.36 744.75 5,973,824.88 1,702,901.26 2.91 4,936.66 MWD+IFR-AK-CAZ-SC(3) 8,695.84 88.10 339.57 3,872.71 3,775.38 5,352.09 728.62 5,973,866.47 1,702,884.78 3.24 4,981.14 MWD+IFR-AK-CAZ-SC(3) 8,746.37 88.69 342.16 3,874.13 3,776.80 5,399.81 712.06 5,973,914.04 1,702,867.83 5.25 5,031.52 MWD+IFR-AK-CAZ-SC(3) 8,794.67 89.35 344.00 3,874.96 3,777.63 5,446.01 698.01 5,973,960.12 1,702,853.40 4.05 5,079.78 MWD+IFR-AK-CAZ-SC(3) 8,840.62 90.37 346.77 3,875.07 3,777.74 5,490.46 686.42 5,974,004.47 1,702,841.44 6.42 5,125.72 MWD+IFR-AK-CAZ-SC(3) 8,884.48 90.68 348.16 3,874.67 3,777.34 5,533.28 676.90 5,974,047.20 1,702,831.57 3.25 5,169.54 MWD+IFR-AK-CAZ-SC(3) 8,930.14 90.65 350.40 3,874.14 3,776.81 5,578.13 668.41 5,974,091.98 1,702,822.71 4.91 5,215.07 MWD+IFR-AK-CAZ-SC(3) 9,027.84 90.82 350.99 3,872.88 3,775.55 5,674.54 652.61 5,974,188.25 1,702,806.13 0.63 5,312.28 MWD+IFR-AK-CAZ-SC(3) 9,124.10 90.17 350.24 3,872.05 3,774.72 5,769.51 636.91 5,974,283.07 1,702,789.65 1.03 5,408.07 MWD+IFR-AK-CAZ-SC(3) 9,219.27 90.20 348.32 3,871.74 3,774.41 5,863.01 619.21 5,974,376.42 1,702,771.18 2.02 5,502.97 MWD+IFR-AK-CAZ-SC(3) 9,314.50 90.24 345.96 3,871.38 3,774.05 5,955.84 598.02 5,974,469.07 1,702,749.23 2.48 5,598.13 MWD+IFR-AK-CAZ-SC(3) 9,410.83 90.37 344.44 3,870.87 3,773.54 6,048.97 573.41 5,974,561.98 1,702,723.86 1.58 5,694.45 MWD+IFR-AK-CAZ-SC(3) 9,505.99 89.30 342.91 3,871.14 3,773.81 6,140.29 546.67 5,974,653.07 1,702,696.36 1.96 5,789.58 MWD+IFR-AK-CAZ-SC(3) 9,600.93 89.72 342.16 3,871.95 3,774.62 6,230.85 518.17 5,974,743.38 1,702,667.13 0.91 5,884.43 MWD+IFR-AK-CAZ-SC(3) 9,696.23 90.48 344.05 3,871.79 3,774.46 6,322.03 490.48 5,974,834.32 1,702,638.69 2.14 5,979.67 MWD+IFR-AK-CAZ-SC(3) 9,790.90 89.96 345.47 3,871.42 3,774.09 6,413.37 465.59 5,974,925.44 1,702,613.05 1.60 6,074.34 MWD+IFR-AK-CAZ-SC(3) 9,886.01 89.34 346.00 3,872.00 3,774.67 6,505.55 442.16 5,975,017.41 1,702,588.86 0.86 6,169.44 MWD+IFR-AK-CAZ-SC(3) 9,980.28 90.17 346.28 3,872.41 3,775.08 6,597.07 419.58 5,975,108.74 1,702,565.53 0.93 6,263.69 MWD+IFR-AK-CAZ-SC(3) 10,073.93 91.00 348.55 3,871.45 3,774.12 6,688.46 399.17 5,975,199.95 1,702,544.38 2.58 6,357.24 MWD+IFR-AK-CAZ-SC(3) 10,171.36 89.86 347.45 3,870.72 3,773.39 6,783.75 378.92 5,975,295.06 1,702,523.34 1.63 6,454.53 MWD+IFR-AK-CAZ-SC(3) 10,266.80 90.03 346.04 3,870.81 3,773.48 6,876.65 357.04 5,975,387.77 1,702,500.69 1.49 6,549.92 MWD+IFR-AK-CAZ-SC(3) 10,361.88 90.44 345.94 3,870.42 3,773.09 6,968.90 334.02 5,975,479.82 1,702,476.92 0.44 6,644.99 MWD+IFR-AK-CAZ-SC(3) 10,456.80 89.52 343.11 3,870.45 3,773.12 7,060.37 308.70 5,975,571.06 1,702,450.85 3.14 6,739.90 MWD+IFR-AK-CAZ-SC(3) 10,551.76 88.99 344.35 3,871.69 3,774.36 7,151.52 282.09 5,975,661.98 1,702,423.50 1.42 6,834.82 MWD+IFR-AK-CAZ-SC(3) 10,647.01 89.93 346.94 3,872.59 3,775.26 7,243.78 258.48 5,975,754.04 1,702,399.13 2.89 6,930.05 MWD+IFR-AK-CAZ-SC(3) 10,741.22 90.38 346.30 3,872.33 3,775.00 7,335.43 236.68 5,975,845.50 1,702,376.58 0.83 7,024.22 MWD+IFR-AK-CAZ-SC(3) 10,836.68 94.03 345.23 3,868.66 3,771.33 7,427.87 213.23 5,975,937.74 1,702,352.37 3.98 7,119.59 MWD+IFR-AK-CAZ-SC(3) 10,930.03 94.57 346.11 3,861.66 3,764.33 7,518.06 190.19 5,976,027.73 1,702,328.59 1.10 7,212.67 MWD+IFR-AK-CAZ-SC(3) 11/4/2015 1:35:07PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-154 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.73 @ 97.33usft(Doyon25) Well: 1C-154 North Reference: True Wellbore: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,026.85 93.43 346.95 3,854.91 3,757.58 7,611.99 167.69 5,976,121.45 1,702,305.32 1.46 7,309.21 MWD+IFR-AK-CAZ-SC(3) 11,122.36 91.12 347.32 3,851.11 3,753.78 7,705.02 146.45 5,976,214.30 1,702,283.31 2.45 7,404.58 MWD+IFR-AK-CAZ-SC(3) 11,217.63 90.72 345.69 3,849.59 3,752.26 7,797.65 124.22 5,976,306.73 1,702,260.32 1.76 7,499.80 MWD+IFR-AK-CAZ-SC(3) 11,312.44 91.30 344.61 3,847.91 3,750.58 7,889.27 99.92 5,976,398.14 1,702,235.28 1.29 7,594.59 MWD+IFR-AK-CAZ-SC(3) 11,407.14 91.06 344.37 3,845.96 3,748.63 7,980.50 74.61 5,976,489.16 1,702,209.21 0.36 7,689.27 MWD+IFR-AK-CAZ-SC(3) 11,502.69 90.91 344.51 3,844.32 3,746.99 8,072.54 48.98 5,976,580.97 1,702,182.83 0.21 7,784.80 MWD+IFR-AK-CAZ-SC(3) 11,597.35 87.98 340.09 3,845.24 3,747.91 8,162.68 20.21 5,976,670.86 1,702,153.32 5.60 7,879.31 MWD+IFR-AK-CAZ-SC(3) 11,691.83 88.49 342.02 3,848.15 3,750.82 8,252.00 -10.45 5,976,759.91 1,702,121.94 2.11 7,973.52 MWD+IFR-AK-CAZ-SC(3) 11,786.05 88.97 344.43 3,850.24 3,752.91 8,342.18 -37.63 5,976,849.86 1,702,094.01 2.61 8,067.67 MWD+IFR-AK-CAZ-SC(3) 11,878.44 89.48 346.02 3,851.49 3,754.16 8,431.50 -61.19 5,976,938.98 1,702,069.72 1.81 8,160.04 MWD+IFR-AK-CAZ-SC(3) 11,971.67 90.10 347.44 3,851.83 3,754.50 8,522.24 -82.59 5,977,029.53 1,702,047.58 1.66 8,253.23 MWD+IFR-AK-CAZ-SC(3) 12,064.22 90.61 348.40 3,851.26 3,753.93 8,612.74 -101.96 5,977,119.85 1,702,027.47 1.17 8,345.65 MWD+IFR-AK-CAZ-SC(3) 12,155.62 91.59 348.54 3,849.50 3,752.17 8,702.28 -120.22 5,977,209.23 1,702,008.47 1.08 8,436.87 MWD+IFR-AK-CAZ-SC(3) 12,247.88 90.51 349.78 3,847.81 3,750.48 8,792.87 -137.57 5,977,299.67 1,701,990.38 1.78 8,528.87 MWD+IFR-AK-CAZ-SC(3) 12,340.10 88.39 347.50 3,848.70 3,751.37 8,883.27 -155.73 5,977,389.91 1,701,971.47 3.38 8,620.88 MWD+IFR-AK-CAZ-SC(3) 12,433.30 89.45 346.55 3,850.45 3,753.12 8,974.07 -176.65 5,977,480.52 1,701,949.81 1.53 8,714.01 MWD+IFR-AK-CAZ-SC(3) 12,525.84 90.24 346.34 3,850.70 3,753.37 9,064.03 -198.34 5,977,570.29 1,701,927.38 0.88 8,806.52 MWD+IFR-AK-CAZ-SC(3) 12,619.22 90.58 346.60 3,850.03 3,752.70 9,154.82 -220.19 5,977,660.89 1,701,904.79 0.46 8,899.86 MWD+IFR-AK-CAZ-SC(3) 12,680.00 90.58 346.60 3,849.42 3,752.09 9,213.94 -234.27 5,977,719.89 1,701,890.22 0.00 8,960.62 PROJECTED to TD NOT an Actual Survey Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes ❑ No have checked to the best of my ability that the following data is cornett: U Surface Coordinates (] Declination & Convergence IJ GRS Survey Corrections p Survey Tool Codes Vincent [MAIN onO ` o-SchUntborga �" SLB DE: Osara ` `"�"'`"' Dam7015.1 oa ie pass09 OD ••• D 19.a.1gm:t. tt.t KelseyHallford ▪ :nd("Sw W lbc a7,IV. Client Representative: Date: 04-Nov-2015 11/4/2015 1:35:07PM Page 6 COMPASS 5000.1 Build 74 21516 0 0 26462 SchlumbergerTransmittal#: 16N0V15-SPO2 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery t\ n1izo1S M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-154 Top of Cement Date Dispatched: 16-Nov-15 Job#: 15AKA0102 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement x x 2650' -5620' MD -.1 VC O u'V 17 Zu i • cc LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elqaricoconocophillips.com AlaskaPTSPrintCenter(Nsib.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: /���� 6...zitteet • • Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Friday, October 16, 2015 10:36 AM To: Loepp,Victoria T (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: PTD 215-166 Surface Casing PointA Attachments: 1C-154 10.75in Surface CADE v3 10.15.2015.pdf; 1C-154wp06 PlanSummary.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached you will find the revised cement program and updated directional plan representing the shallower surface casing point. Thank you, Kelsey From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: 13 October 2015 11:33 To: Hallford, Kelsey Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]RE: PTD 215-166 Surface Casing Point Kelsey, This change is approved. Please send revised cement calculations, casing program. Thanx, Victoria From: Hallford, Kelsey [mailto:Kelsey.HallfordOconocophillips.com] Sent: Tuesday, October 13, 2015 9:39 AM To: Loepp, Victoria T(DOA) Subject: PTD 215-166 Surface Casing Point Good morning Victoria, Our geologists for the upcoming West Sak well, 1C-154, would like to shorten the surface interval by—200'to set surface casing in a thicker mud stone with the goal of achieving a higher FIT.The proposed surface casing point would be at 2653' MD/2403'TVD; this depth corresponds to 375'TVD deeper than the T3 geological marker to put us in a thick mudstone to set the surface shoe. Background: Previous wells, 1C-150 and 1C-151, set surface casing in this shallower,thick, mudstone with competent FIT results.The reason behind deepening the casing point for the most recent 2015 1C wells(1C-152 and 1C-153)were a result of a sand present on the 1D pad that we saw earlier this year that we needed to set our shoe below, resulting in setting in a thinner mudstone with sands above and below that could cause lower FIT results. • • Please let me know if you approve and if there is additional information/sundry required by the state for this change. Kelsey Haiiford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsev.hallford(ccop.com 2 D. IC-I 5 wp06 6 . 801 Plan Summary >,5 T3K15 TopT � 4 D -5 ��41� Pfrost III 1 I � ��� £IUIII II � ► ► I \� !/�/ 0"x 42'1 ���('i'It., 0 3000 6000 9000 12000 F�/4. x 42' Measured Depth I. o---°s0~ Geodetic Datum: North American Datum 1983 " `, Depth Reference. Plan:57.6+39.5 0 97.1 ousft(Doyon 25) Rig: Doyon 25N. e !6y x 13-121' o_ 2e ; o 0 0p O h O Z'2 1 8 N OI, N (h _ Nn 4] O� rp CO, ///� 1 I I I ' •° I 13 r l 3 l 1 "" I 2 I I I dr O'" 0 I" 40 300 0 1500 3000 4500 6000 7500 9000 10500 o Horizontal Departure 300 490 \tt 490 670 330 ! 670 - 860 860 - 1040 0 +`-�.I. I ' i i. a'2 ��� F 1040• -- 1230 60 300 so 1230 - 1410 a - pp p °q - f . - 1410 1600 to _ I 'k I1 1� , 4�ic. _a,s 1600 -2060 41 ` II :. \.y 1.52.1',Y ye5$14:. :� 2060 2530 c , I O�i�i�:d:4t�� «�3�k' 1C-174 2530 - 2990 30- 3„ - • ♦*tall\ • . ? 2990 - 3450 yG1J4a L1(wp01)C-178 ¢ 1 3450 - 3910 -2 `1 -178L1s�1C-174a(wp01) roje�jr� N `�,> 3910 - 4370 8 - ‘,s1 -150 ` •A♦ ,,,,''.°0,'.4..v.,,, r H U 10 178.1P82 1C-15�wp01 F 1 +�` ,Yy 4,�� 4 4370 - 4840 4840 - 5300 0" 1 1 1C 170It1r P1 1 ( I 1 1 1 I I 1 I I I I i i i 1 i I r •; A' ��1 1Nih r,4,,i.�rs�irfatt�,0y944pt1C "4f` 5300 - 6230 0 2000 4000 6000 8000 10000 12000 240 •.'''''• 2/'7/"3:-° qdt" ,tF fg ' + -+20 ;t,y1j`�'�C70,' ,"0 6230 7150 SURVEY PROGRAM ` v4 1 �6; , yssv� 7150 8080 Surface Location A �� 8080 - 9010 Depth From Depth To Survey/Plan Tool North/Y: 596850a07 ��� 39.50 1150.00 1C-154wp06(Plan 10-154) GYD-GC-SS East/X: 1702200.32 210180 9010 9940 1150.00 2150.00 1C-154wp06(Plan 1C-154) MWD Pad Elevation: 57.60 - s • 9940 10860 1150.00 2628.07 1C-154wp06(Plan 1C-154) MWD+IFR-AK-CAZ-SC ;a„ 10860 11790 2628.07 4128.07 1C-154wp06(Plan 1C-154) MWD CASING DETAILS 11790 12719 2628.07 5854.71 1C-154wp06(Plan 1C-154) MWD+IFR-AK-CAZ-SC 5854.71 7354.71 1C-154wp06(Plan 1C-154) MWD TVD MD Name " 5854.71 12718.90 1C-154wp06(Plan 1C-154) MWD+IFR-AK-CAZ-SC 119.50 119.50 20"x42" Magnetic Model BGGM2015 T 2403.20 2628.07 10-3/4"x 13-1/2" Magnetic Model Date 25-Oct-15 3867.10 5854.71 7-5/8"x 9-7/8" Magnetic Declination: 18.90° 3832.10 12718.90 4-12"x 6-3/4" To convert a Magnetic Direction to a True Direction,Add 18.90°East SECTION DETAILS =1793.0 Sec MD Inc Azl TVD ON/-S +E/-W Oleg TFace VSect Target Annotation Pfrost 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 000 0.00 2 300.00 0.00 0.00 30000 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5"/100'DLS,35°TF,for 300.31' -2028.2 3 600.31 4.50 35.00 600.00 9.67 6.77 1,50 35.00 7.58 Start 2°/100'DLS,20"TF,for 302.67' 4 902.98 10.40 46.52 900.00 38.23 33.44 2.00 20.00 28.27 Adjust TF to 25°,for 902.51' 5 1805.49 27.81 62.82 1750.00 191.72 281.92 2.00 25.00 112.22 Hold for 11306' T3 6 1918.55 27.81 62.82 1850.00 215.82 328.86 000 0.00 123.35 Start 3°/100'DLS,-9.13°TF,for 701.79' 7 2620.34 48.71 58.47 2398.10 430.89 703.45 3.00 -9.13 234.14 Hold for 6.93' -2310.8 8 2627.27 48.71 58.47 2402.67 433.61 707.88 0.00 0.00 235.62 Start 3°7100'DLS,0.53°TF,for 0.81' 9 2628.07 48.73 58.47 2403.20 433.93 708.40 3.00 0.53 235.80 Start 3°/100'DLS,0.53°TF,for 0.81' 10 2648.07 48.73 58.47 2416.39 441.79 721.21 0.00 0.00 240.07 Start 3.75°7100'DLS,91.69°TF,for 109.63' 11 2757.70 48.74 63.94 2488.73 481.45 793.38 3.75 91.69 259.71 Hold for 656.57' 12 3414.28 48.74 63.94 2921.74 698.28 1236.75 0.00 0.00 354.39 Start 3.75-1100'DLS,-86-46°TF,for 2090.58' 13 5504.86 85.00 345.00 3852.10 2308.76 1756.92 3.75 -86.46 1775.37 1C-154 1.Top WSD 092515 DH Start 4°/100 DLS,64.34°TF,for 65.78' 14 5570.64 86.14 347.38 3857.18 2372.45 1741.26 4.00 64.34 1840.94 Hold for 10.06' 15 5580.70 86.14 347.38 3857.86 2382.24 1739.07 0.00 0.00 1850.96 Start 4°7100'DLS,-69.63°TF,for 274.01' 16 5854.71 90.00 337.11 3867,10 2642.64 1655.65 4.00 -69.63 2124.08 1C-154 2.T1 Landing 092515 OH Hold for 30' K15 17 588471 9000 337.11 3867.10 2670.28 1643.98 0.00 0.00 2153.80 Start 3°/100'DLS,-87.9°TF,for 41.08' 18 5925.79 90.05 335.88 3867.08 2707.95 162760 3.00 -87.90 2194.42 Hold for 941.57' 19 6867.35 90.05 335.88 3866.34 3567.30 1242.81 0.00 0.00 3124.08 Start 37100'DLS,90.03°TF,for 325.33' 20 7192.68 90.04 345.64 3866.10 3874.08 1135.72 3.00 90.03 3448.13 1C-154 3.T2 092515 DH Start 2°/100 DLS,0°TF,for 4.1' 21 7196.79 90.12 345.64 3866.09 3878.06 1134.71 2.00 0.00 3452.23 Hold for 933.72' 22 8130.50 90.12 34564 3864.11 4782.59 903.11 0.00 000 4385.89 Start 2°/100'DLS,178.72"TF,for 3.65' 23 8134-15 90.05 345.64 3864.10 4786.12 902.20 2.00 178.72 4389.53 1C-154 4.73 092515 DH Adjust TF to-90",for 1.34' 24 8135.49 90.05 345.61 3864.10 4787.42 901.87 2.00 -90.00 4390.88 Hold for 1164.76' -3214.7 25 9300.25 90.05 345.61 3863.10 5915.65 612.46 0.00 0.00 5555.57 1C-154 5.T4 092515 OH Start 2°/100'DLS,79.04°TF,for 10.09' 26 9310.34 90.09 345.81 3863.09 5925.43 809.97 2.00 79.04 5585.65 Hold for 1301.75' Top Ugnu C 27 10612.09 90.09 345.81 3861.10 7187.47 290.89 0.00 0.00 6867.27 1C-154 6.15 092515 DH Start 2°/100'DLS,-10.87°TF,for 99.98' 28 10712.06 92.05 345.43 3859.23 7284,29 266.07 2.00 -10.87 696722 Hold for 963.02' _3447.0 29 11675.08 92.05 345.43 3824.77 8215.76 24.03 0.00 0.00 7929.60 Start 2°7100'DLS,90.05°TF,for 46.57 Top Ugnu B 30 11721.65 92.05 346.37 3823.10 8260.90 12.69 2.00 90.05 7976.13 1C-154 7.16 092515 DH Adjust TF to 180°,for 137.89' 3584.0 31 11859.54 89.29 346.37 3821.49 8394.88 -19.80 2.00 180.00 8113.95 Hold for 859.36' - Top Ugnu A 32 12718-90 89.29 346.37 3832.10 9229.96 -222.36 0.00 0.00 8973.00 1C-154 8,TD 092515 OH TD'12718.9'MD,3832.1'TVD _3863.9 Top N -384p4D E signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings,I also aCknowledoe that,unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vinent Osara Nate Beck ' lfeanyi Ifesie • • Easting(3500 usPoln) 1H-19 ;ll.Pe '0010041•'0"- 41 .. ., _ �6wp07 P 1H-114wp09 WiP - I , i IV ��,t7 115wp09 WiP218 -r Kuparuk 1H Pad B: o9wpl0 iP1H-12 1H-113wp09 WiP : Kuparuk' 1 h ra= H-111wp10 1 ._ _-..!...-1,14111/ 1 C-152wp051 C-153wp06 112 1 '411 ` \\=: IRi-10: FI-�ftlit�ipPz WiP; 1c-154wpd6 �.� 1C-155wp03 �q 1H-08 11H0 ' ;7w.:' '•1C+71.0�O, 1C 11 1,-29 .t' ''g1tY1I 01 - - 1H-02 1 11t;- : 17At - 11 0 1 -17 at •B1 - 1B-10 1B- 19 1C-1s - ` 1B-09 ' ' "e fA • _ I/ 1C-14A _ O� 'B2 1C-22 1B- 4 11iti: 1t 3g • • 0g�g�g1t �� 6t1B• ,•. ,701k 1 , �� _ m N �1, es _ruzi i B t: :�1 Tf6 10-0:` �K 4$14 1 C-i 5L1 14 ui N 1;�`i. 1 —ot=r Kuparuk 1B Pa .�'P62 L'( � ,. 011 1C-15 = c u. ✓ - ♦+ rat 1! =7.',,,;#M l''� \\ !1� �/' 1 C-23 - Z- .fit* '�.4.11fS' ,t._:AA4i� � `� '.,// r4r4r-.::r:1 -7 It'''''' 6,1::4'.' ,t 17 • �, j: t v l ,�'���' i__ 10-27i � !f , fi• , 1.. O1 t - 1 E 08AL2 Ail Elit 1 ' : t <- 18-0402 B'-.t�O . Su111 C 0 j 1C-t 1C- vi 2 x`21 Mainbore 1h -104 '� V �``` �(' 1 i iel-e6244054111=BP 1' I t -.- _ ?.j.• !'r I r� 1 D 1 11 ; �n r l i t, 10 1D-02 = /j 1D- �. Kuparuk 1 C Pa 26 L2 : _<.:•, 0 Utes t•• 1C-12 - •• u .ruk 28243 1 - -.y4 Kuparuk 1 E Pa. . t .(wp,.'.m Kuparuk 1 D Pa. aw-- � �� _-isi - . . a -- --f-- (w ) / ooY �i .,..-. A•8L2PB1 • .. i�r 1 D-28 f�.1�P10 .. 11Bigal _..........--- Ilia. . 1D-42.1PB1 Easting(3500 ustt/in) • • IC-1 54wp06 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4-1/2"x 6-3/4"- ;: 632 9000 C-154 8.TD 092515 DH C-154 7.16 092515 DH 7500— icA54wP06 C-154 6.T5 092515 DH 8000- .. o C-154 5.14 092515 DH 0 A5 00 C-154 4.T3 092515 DH 154 3.12 092515 DH (2000— 7-5/8"x 9-7/8"- ,'.. __ =1C-154 2.T1 Landing 092515 DH 1500- 1C-154 1.Top WSD 092515 DH 10-314"x 13-1/2A,,, '°° 20"x 42" ` 0- i ` 0 i - -6000 -4500 -3000 -1500 0 °° 1500 3000 4500 6000 7500 West(-)/East(+) (1500 usft/in) • 0 1 C-154wp06 Section View -1000 i 0 20"x 42" 0° c Pfrost 1000 1000 /T3 o K15 0 0 L -- 2000 3000, 10-3/4"x 13-1/2" 0 " __ - Top Ugnu C �v— 0 ' TonUgruB . > w� 8 ogopgRu Top D S 3000 -4) '"z o o> co co a 4000 Tr 7-5/8"x 9-7/8" o § o ° o 0 0 ° 4-1/2 "x 6-3/4" in O O V 5000 l I I 7- I I 1 - 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Vertical Section at 345.00°(1000 usft/in) • • ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-154 Plan: 1C-154 Plan: 1C-154wp06 Report - Map Coordinates 14 October, 2015 0 Schlumberger • Comments apply to Report-Map Coordinates the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 1C Pad 11 Site Position: Northing: 5,968,274.22 usft Latitude: 70°19'27.241 NI From: Map Easting: 1,702,403.98usft Longitude: 149°29'50.471 WI Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.47° Well Plan: 1C-154 Well Position +N/-S 0.00 usft Northing: 5,968,509.07 usfi Latitude: 70°19'29.567 N +El-W 0.00 usft Easting: 1,702,200.32 usft Longitude: 149°29'56.359 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore Plan: 1C-154 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 10/25/2015 18.90 80.99 57,505 Design 1C-154wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) L 39.50 0.00 0.00 345.00 Survey Tool Program Date 10/14/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,150.00 1C-154wp06(Plan: 1C-154) GYD-GC-SS Gyrodata gyro single shots 1,150.00 2,150.00 1C-154wp06(Plan:1C-154) MWD MWD-Standard 1,150.00 2,628.07 1C-154wp06(Plan:1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,628.07 4,128.07 1C-154wp06(Plan:1C-154) MWD MWD-Standard 2,628.07 5,854.71 1C-154wp06(Plan: 1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,854.71 7,354.71 1C-154wp06(Plan: 1C-154) MWD MWD-Standard 5,854.71 12,718.90 1C-154wp06(Plan: 1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 39.50 0.00 0.00 39.50 -57.60 0.00 0.00 0.00 100.00 0.00 0.00 100.00 2.90 0.00 0.00 0.04 119.50 0.00 0.00 119.50 22.40 0.00 0.00 0.19 20"x 42" 200.00 0.00 0.00 200.00 102.90 0.00 0.00 0.19 300.00 0.00 0.00 300.00 202.90 0.00 0.00 0.33 KOP:Start 1.5°1100'DLS,35°TF,for 300.31' 10/14/2015 3:56:27PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger 0 Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) "ND TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 400.00 1.50 35.00 399.99 302.89 1.50 35.00 0.47 500.00 3.00 35.00 499.91 402.81 1.50 0.00 0.61 600.00 4.50 35.00 599.69 502.59 1.50 0.00 0.75 600.31 4.50 35.00 600.00 502.90 1.50 0.00 0.75 Start 2°/100'DLS,20°TF,for 302.67' 700.00 6.41 41.11 699.23 602.13 2.00 20.00 0.90 800.00 8.37 44.42 798.40 701.30 2.00 13.91 1.05 900.00 10.34 46.48 897.06 799.96 2.00 10.63 1.21 902.98 10.40 46.52 900.00 802.90 2.00 8.61 1.22 Adjust TF to 25°,for 902.51' 1,000.00 12.19 50.41 995.13 898.03 2.00 25.00 1.38 1,100.00 14.07 53.39 1,092.52 995.42 2.00 21.19 1.56 1,200.00 15.98 55.67 1,189.10 1,092.00 2.00 18.29 1.66 1,300.00 17.91 57.47 1,284.75 1,187.65 2.00 16.09 1.78 1,400.00 19.85 58.93 1,379.36 1,282.26 2.00 14.36 2.02 1,500.00 21.81 60.14 1,472.82 1,375.72 2.00 12.98 2.37 1,600.00 23.77 61.16 1,565.01 1,467.91 2.00 11.85 2.84 1,700.00 25.73 62.03 1,655.82 1,558.72 2.00 10.91 3.39 1,800.00 27.71 62.78 1,745.14 1,648.04 2.00 10.12 4.02 1,805.49 27.81 62.82 1,750.00 1,652.90 2.00 9.45 4.05 Hold for 113.06' 1,854.11 27.81 62.82 1,793.00 1,695.90 0.00 0.00 4.69 Pfrost 1,900.00 27.81 62.82 1,833.59 1,736.49 0.00 0.00 4.69 1,918.55 27.81 62.82 1,850.00 1,752.90 0.00 0.00 4.82 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,000.00 30.23 62.05 1,921.21 1,824.11 3.00 -9.13 5.40 2,100.00 33.20 61.25 2,006.27 1,909.17 3.00 -8.46 6.18 2,126.32 33.98 61.06 2,028.20 1,931.10 3.00 -7.78 3.26 T3 2,200.00 36.17 60.56 2,088.49 1,991.39 3.00 -7.62 3.26 2,300.00 39.15 59.96 2,167.65 2,070.55 3.00 -7.21 3.59 2,400.00 42.13 59.44 2,243.52 2,146.42 3.00 -6.74 3.96 2,492.79 44.90 59.00 2,310.80 2,213.70 3.00 -6.34 4.35 K15 2,500.00 45.11 58.97 2,315.90 2,218.80 3.00 -6.02 4.35 2,600.00 48.10 58.55 2,384.59 2,287.49 3.00 -6.00 4.76 2,620.34 48.71 58.47 2,398.10 2,301.00 3.00 -5.71 4.85 Hold for 6.93' 2,627.27 48.71 58.47 2,402.67 2,305.57 0.00 0.00 4.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 48.73 58.47 2,403.20 2,306.10 2.98 0.53 4.88 Hold for 20'-10-3/4"x 13-1/2" 2,648.07 48.73 58.47 2,416.39 2,319.29 0.00 0.00 4.98 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,700.00 48.70 61.06 2,450.66 2,353.56 3.75 91.69 5.27 10/14/2015 3:56:27PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger S Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Planned Survey 1 MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 2,757.70 48.74 63.94 2,488.73 2,391.63 3.75 89.98 5.64 Hold for 656.57' 2,800.00 48.74 63.94 2,516.62 2,419.52 0.00 0.00 5.94 2,900.00 48.74 63.94 2,582.57 2,485.47 0.00 0.00 6.76 3,000.00 48.74 63.94 2,648.52 2,551.42 0.00 0.00 7.70 3,100.00 48.74 63.94 2,714.47 2,617.37 0.00 0.00 8.71 3,200.00 48.74 63.94 2,780.42 2,683.32 0.00 0.00 9.77 3,300.00 48.74 63.94 2,846.37 2,749.27 0.00 0.00 10.87 3,400.00 48.74 63.94 2,912.32 2,815.22 0.00 0.00 11.99 3,414.28 48.74 63.94 2,921.74 2,824.64 0.00 0.00 12.15 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 3,500.00 49.02 59.69 2,978.13 2,881.03 3.75 -86.46 13.03 3,600.00 49.53 54.79 3,043.40 2,946.30 3.75 -83.66 13.90 3,700.00 50.26 49.98 3,107.84 3,010.74 3.75 -80.46 14.69 3,800.00 51.17 45.28 3,171.18 3,074.08 3.75 -77.36 15.42 3,869.97 51.92 42.07 3,214.70 3,117.60 3.75 -74.38 16.07 Top Ugnu C 3,900.00 52.27 40.71 3,233.15 3,136.05 3.75 -72.39 16.07 4,000.00 53.54 36.28 3,293.48 3,196.38 3.75 -71.55 16.67 4,100.00 54.97 32.01 3,351.91 3,254.81 3.75 -68.88 17.22 4,200.00 56.54 27.89 3,408.20 3,311.10 3.75 -66.39 8.08 4,271.50 57.75 25.04 3,447.00 3,349.90 3.75 -64.07 8.15 Top Ugnu B 4,300.00 58.24 23.93 3,462.11 3,365.01 3.75 -62.52 8.15 4,400.00 60.06 20.11 3,513.39 3,416.29 3.75 -61.93 8.23 4,500.00 61.99 16.43 3,561.84 3,464.74 3.75 -59.97 8.31 4,504.61 62.08 16.26 3,564.00 3,466.90 3.75 -58.19 8.41 Top Ugnu A 4,600.00 64.01 12.88 3,607.24 3,510.14 3.75 -58.11 8.41 4,700.00 66.12 9.46 3,649.40 3,552.30 3.75 -56.58 8.52 4,736.37 66.90 8.25 3,663.90 3,566.80 3.75 -55.14 8.66 Top N 4,800.00 68.30 6.15 3,688.15 3,591.05 3.75 -54.65 8.66 4,900.00 70.54 2.94 3,723.31 3,626.21 3.75 -53.85 8.81 5,000.00 72.84 359.82 3,754.73 3,657.63 3.75 -52.72 8.99 5,100.00 75.18 356.77 3,782.28 3,685.18 3.75 -51.74 9.19 5,200.00 77.57 353.79 3,805.84 3,708.74 3.75 -50.90 9.40 5,300.00 79.98 350.87 3,825.31 3,728.21 3.75 -50.20 9.63 5,400.00 82.42 347.99 3,840.61 3,743.51 3.75 -49.63 9.87 5,426.86 83.08 347.22 3,844.00 3,746.90 3.75 -49.19 10.11 Top D 5,500.00 84.88 345.14 3,851.67 3,754.57 3.75 -49.09 10.11 5,504.86 85.00 345.00 3,852.10 3,755.00 3.75 -48.88 10.12 Start 4°/100'DLS,64.34°TF,for 65.78' 10/14/2015 3:56:27PM Page 4 COMPASS 5000.1 Build 74 iSchlumberger 1111 Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (0) (usft) 5,570.64 86.14 347.38 3,857.18 3,760.08 4.00 64.34 10.63 Hold for 10.06' 5,580.70 86.14 347.38 3,857.86 3,760.76 0.00 0.00 10.651' Start 4°/100'DLS,-69.63°TF,for 274.01' 5,600.00 86.41 346.65 3,859.11 3,762.01 4.00 -69.63 10.65 5,700.00 87.81 342.90 3,864.15 3,767.05 4.00 -69.58 10.73 5,800.00 89.23 339.16 3,866.73 3,769.63 4.00 -69.39 10.80 5,854.71 90.00 337.11 3,867.10 3,770.00 4.00 -69.30 10.83 Hold for 30'-7-5/8"x 9-7/8" 5,884.71 90.00 337.11 3,867.10 3,770.00 0.00 0.00 11.01 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,900.00 90.02 336.65 3,867.10 3,770.00 3.00 -87.90 11.05 5,925.79 90.05 335.88 3,867.08 3,769.98 3.00 -87.90 11.12 Hold for 941.57' 6,000.00 90.05 335.88 3,867.03 3,769.93 0.00 0.00 11.70 6,100.00 90.05 335.88 3,866.95 3,769.85 0.00 0.00 12.61 6,200.00 90.05 335.88 3,866.87 3,769.77 0.00 0.00 13.66 6,300.00 90.05 335.88 3,866.79 3,769.69 0.00 0.00 14.80 6,400.00 90.05 335.88 3,866.71 3,769.61 0.00 0.00 16.02 6,500.00 90.05 335.88 3,866.63 3,769.53 0.00 0.00 17.30 6,600.00 90.05 335.88 3,866.55 3,769.45 0.00 0.00 18.63 6,700.00 90.05 335.88 3,866.47 3,769.37 0.00 0.00 20.01 6,800.00 90.05 335.88 3,866.40 3,769.30 0.00 0.00 21.41 6,867.35 90.05 335.88 3,866.34 3,769.24 0.00 0.00 22.37 Start 3°/100'DLS,90.03°TF,for 325.33' 6,900.00 90.04 336.86 3,866.32 3,769.22 3.00 90.03 22.95 7,000.00 90.04 339.86 3,866.24 3,769.14 3.00 90.03 24.62 7,100.00 90.04 342.86 3,866.17 3,769.07 3.00 90.03 26.25 7,192.68 90.04 345.64 3,866.10 3,769.00 3.00 90.03 27.70 Start 2°I100'DLS,0°TF,for 4.1' 7,196.79 90.12 345.64 3,866.09 3,768.99 2.00 0.00 27.75 Hold for 933.72' 7,200.00 90.12 345.64 3,866.09 3,768.99 0.00 0.00 27.80 7,300.00 90.12 345.64 3,865.87 3,768.77 0.00 0.00 29.22 7,400.00 90.12 345.64 3,865.66 3,768.56 0.00 0.00 16.92 7,500.00 90.12 345.64 3,865.45 3,768.35 0.00 0.00 17.34 7,600.00 90.12 345.64 3,865.24 3,768.14 0.00 0.00 17.78 7,700.00 90.12 345.64 3,865.02 3,767.92 0.00 0.00 18.22 7,800.00 90.12 345.64 3,864.81 3,767.71 0.00 0.00 18.67 7,900.00 90.12 345.64 3,864.60 3,767.50 0.00 0.00 19.13 8,000.00 90.12 345.64 3,864.38 3,767.28 0.00 0.00 19.59 8,100.00 90.12 345.64 3,864.17 3,767.07 0.00 0.00 20.07 8,130.50 90.12 345.64 3,864.11 3,767.01 0.00 0.00 20.21 Start 2°/100'DLS,178.72°TF,for 3.65' , 10/142015 3:56:27PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°1100usft) (0) (usft) 8,134.15 90.05 345.64 3,864.10 3,767.00 2.00 178.72 20.22 Adjust TF to-90°,for 1.34' 8,135.49 90.05 345.61 3,864.10 3,767.00 2.00 -90.00 20.23 Hold for 1164.76' 8,200.00 90.05 345.61 3,864.04 3,766.94 0.00 0.00 20.49 8,300.00 90.05 345.61 3,863.96 3,766.86 0.00 0.00 20.97 8,400.00 90.05 345.61 3,863.87 3,766.77 0.00 0.00 21.45 8,500.00 90.05 345.61 3,863.79 3,766.69 0.00 0.00 21.95 8,600.00 90.05 345.61 3,863.70 3,766.60 0.00 0.00 22.44 8,700.00 90.05 345.61 3,863.61 3,766.51 0.00 0.00 22.94 8,800.00 90.05 345.61 3,863.53 3,766.43 0.00 0.00 23.45 8,900.00 90.05 345.61 3,863.44 3,766.34 0.00 0.00 23.96 9,000.00 90.05 345.61 3,863.36 3,766.26 0.00 0.00 24.47 9,100.00 90.05 345.61 3,863.27 3,766.17 0.00 0.00 24.99 9,200.00 90.05 345.61 3,863.19 3,766.09 0.00 0.00 25.51 9,300.00 90.05 345.61 3,863.10 3,766.00 0.00 0.00 26.03 9,300.25 90.05 345.61 3,863.10 3,766.00 0.00 0.00 26.03 Start 2°l100'DLS,79.04°TF,for 10.0W 9,310.34 90.09 345.81 3,863.09 3,765.99 2.00 79.04 26.10 Hold for 1301.75' 9,400.00 90.09 345.81 3,862.95 3,765.85 0.00 121.83 26.51 9,500.00 90.09 345.81 3,862.80 3,765.70 0.00 0.00 27.04 9,600.00 90.09 345.81 3,862.65 3,765.55 0.00 0.00 27.57 9,700.00 90.09 345.81 3,862.49 3,765.39 0.00 0.00 28.10 9,800.00 90.09 345.81 3,862.34 3,765.24 0.00 0.00 28.63 9,900.00 90.09 345.81 3,862.19 3,765.09 0.00 0.00 29.16 10,000.00 90.09 345.81 3,862.03 3,764.93 0.00 0.00 29.70 10,100.00 90.09 345.81 3,861.88 3,764.78 0.00 0.00 30.24 10,200.00 90.09 345.81 3,861.73 3,764.63 0.00 0.00 30.78 10,300.00 90.09 345.81 3,861.58 3,764.48 0.00 0.00 31.32 10,400.00 90.09 345.81 3,861.42 3,764.32 0.00 0.00 31.87 10,500.00 90.09 345.81 3,861.27 3,764.17 0.00 0.00 32.41 10,600.00 90.09 345.81 3,861.12 3,764.02 0.00 0.00 32.96 10,612.09 90.09 345.81 3,861.10 3,764.00 0.00 0.00 33.03 Start 201100'DLS,-10.87°TF,for 99.98' 10,700.00 91.81 345.48 3,859.64 3,762.54 2.00 -10.87 33.48 10,712.06 92.05 345.43 3,859.23 3,762.13 2.00 -10.88 33.54 Hold for 963.02' 10,800.00 92.05 345.43 3,856.09 3,758.99 0.00 -10.00 34.02 10,900.00 92.05 345.43 3,852.51 3,755.41 0.00 0.00 34.57 11,000.00 92.05 345.43 3,848.93 3,751.83 0.00 0.00 35.12 11,100.00 92.05 345.43 3,845.35 3,748.25 0.00 0.00 35.67 11,200.00 92.05 345.43 3,841.77 3,744.67 0.00 0.00 36.23 11,300.00 92.05 345.43 3,838.19 3,741.09 0.00 0.00 36.78 11,400.00 92.05 345.43 3,834.61 3,737.51 0.00 0.00 37.34 10/14/2015 3:56:27PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger I Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kupl Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD 1VDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 11,500.00 92.05 345.43 3,831.03 3,733.93 0.00 0.00 37.90 11,600.00 92.05 345.43 3,827.45 3,730.35 0.00 0.00 38.46 11,675.08 92.05 345.43 3,824.77 3,727.67 0.00 0.00 38.88 Start 2°1100'DLS,90.05°TF,for 46.57' 11,700.00 92.05 345.93 3,823.87 3,726.77 2.00 90.05 39.03 11,721.65 92.05 346.37 3,823.10 3,726.00 2.00 90.07 39.15 Adjust TF to 180°,for 137.89' 11,800.00 90.48 346.37 3,821.37 3,724.27 2.00 180.00 39.35 11,859.54 89.29 346.37 3,821.49 3,724.39 2.00 180.00 39.44 Hold for 859.36' 11,900.00 89.29 346.37 3,821.98 3,724.88 0.00 0.00 39.58 12,000.00 89.29 346.37 3,823.22 3,726.12 0.00 0.00 40.14 12,100.00 89.29 346.37 3,824.46 3,727.36 0.00 0.00 40.70 12,200.00 89.29 346.37 3,825.69 3,728.59 0.00 0.00 41.26 12,300.00 89.29 346.37 3,826.93 3,729.83 0.00 0.00 41.82 12,400.00 89.29 346.37 3,828.16 3,731.06 0.00 0.00 42.38 12,500.00 89.29 346.37 3,829.40 3,732.30 0.00 0.00 42.94 12,600.00 89.29 346.37 3,830.63 3,733.53 0.00 0.00 43.51 12,700.00 89.29 346.37 3,831.87 3,734.77 0.00 0.00 44.07 12,718.90 89.29 346.37 3,832.10 3,735.00 0.00 0.00 44.18 TD:12718.9'MD,3832.1'TVD 10/14/2015 3:56:27PM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 , Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C') 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/142015 3:56:27PM Page 8 COMPASS 5000.1 Build 74 fSchlumberger 0 Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C') 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 1 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations +` Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/142015 3:56:27PM Page 9 COMPASS 5000.1 Build 74 • Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 20/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°1100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'TVD 10/142015 3:56:27PM Page 10 COMPASS 5000.1 Build 74 . Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 1 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction 0 (usft) (usft) Name Lithology (1 ( 1 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations I Measured Vertical Local Coordinates Depth Depth +N/-S +E./-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'TVD 10/142015 3:56:27PM Page 11 COMPASS 5000.1 Build 74 0 Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter _ (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.50/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'OLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'TVD r 10/142015 3:56:27PM Page 12 COMPASS 5000.1 Build 74 • Schlumberger 0 Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 1 (usft) (usft) Name C') C') 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'ND i 10/14/2015 3:56:27PM Page 13 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter '4 (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (°) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.50/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/14/2015 3:56:27PM Page 14 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'ND I A 10/142015 3.'56:27PM Page 15 COMPASS 5000.1 Build 74 • Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 I Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/14/2015 3:56:27PM Page 16 COMPASS 5000.1 Build 74 • Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5©97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5©97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C7 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology C) (°) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +FJ-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF.for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/14/2015 3:56:27PM Page 17 COMPASS 5000.1 Build 74 • • MD Q he 6z /40 T41359 ,6 E:� 191933 Eastirg Do4k9 T.Face Sector Type 29991 1 (aft) I 1-99 17 I 69E0I (404) ..3ft) '.aft) .s9) ,raft; (/100.56-1 ;1 39.50 0.00 0.00 3.50 -57.60 0.00 0.00 `5966509.07 170226.32 0.00 0.00 De lire i2 300.00 260.50 0.00 0.00 300700: 232.90 0.00-: 0.00 5968509.0. 1702203.32 0.00 Q.00 086490050 -� 13 600.31 300.11: 4.50 35.00 690.00 50290 9,67 6.77'. 5968518.79 1702207.01 1.50 35.00 50215.0 I4 902.96 302.6]-: 10.40 46.52 900.00. 602.90 30.29 33.44: 5960547.57^ 1702233.49 2.00 20.00 052339 5 1805.90 902.50-. 27.81 6282 1750.00 1652.90 191.72 28192 936870109 002460.63 200 25.00 012790 6 1958.55 11306 27.81: 6202 18 .00 174290 115702 328.86 4%86-].57: (00252]36: 0.00 0.00�e1�5TU .._...__..�..�. '5 262434 .701.70 0.]i 58.47 2398.10 ... 2355.57 430709 703.95 5%8946.70 170200.13 300 9.13 Off Al 80.5 8) B 2627.27 6.93 +5.is 58.47 20267 2305.57 433.61 707,07 5%6998.96 170700559 0.00 053- (k0) 1'10 .628.0]_ 0.81 58.47 2403.2. 2306.10 411.93 708.00 596690 74 1702905.08 3.00 0.53. (540) -, �. 10 ... 757.07^ 20_ 4873 5842 2116_39 __. 7319.29- HI.49 723.33 5%8956.74 102917.80 0.06 900 9608+110 111 2752.10 109.63 48.74 6394 2480.13 239163 981.45 233.1 5%893699 120343053 3.75 91,69.OPT K18) it.. 3414.28 656.57 0.74 6394 232074 2814.64 60.23 1236,'5 5969217.44 10343116 0.00 0.00 (066) 13 5504.86 290.58 85.00 34500 3852.10 375500 2306.76 1756.5. 597083200100393800 375 86.46 (000) 10-159 1.Top W50 092515 011- 5580.84 06 36 342.38 3857.18 3%0.08 238225 1733 6 5920995 32 1703923.55 4.00 64.34 011 01015 10 5580.70 6106 eo 342.38 3657.86 3160.76 2382.24 1]39.(' 59709015 32 170391355 0.00 0.00 (.8107 5859.71 27901 90Y 33711 3967.10 377575 254269 1655.65 5971165.00 170383400 4.00 44.63 (910) 1C-1692 T11sr6560325151:81 117 5684.73 _07 _ 90.00 13711 3867.10 3770.00 280.28 164316 5971192.54,_ 0.00 000StrettPO 00 592379... 41.08 90.05 33586 3867.08 3769.96 2707.95 1637.60 59712300. 170.3805.4c 300 87.90 10F1-H.015 19 6867.35' 941.57 90.05 335.88 3866.34 3769.21... 350.30 124281 597288.14.... 1703413.60 0.00 0.00 (0600) _.. ...... 719268 325.33 37.7 34564 386610 3769.00 3874.08 1135,52 5972392.00 1703304.00 3.00 90.03 (354) 1C-1543.T1 0925150i .1 5.64- ._..__ ,._..8__-..._. .___.0__._.W.W...._.2.00 .�..`0.00._ 122°1 7130.70 3.72 90.02 34564 3664.01 3767.09 409.59 1103.7. 5973395.96 170306293 0.00 :OPT 61015 21 8130.10 933.65 99.05 345.64. .3864.10 3%7.00 478259 902.2: 5973298.06 1703063.00 0.00 8.72. (Ot0) 23 8134.15 3.85 90.05 345.6+ 3964.10 3%7.00 4766.t2 902 Z� 93]3302.00 1709063.00 2.00 1%.R (Otte) 1C-1544.73092515011 29 8135.41 1.31 90.05 3 . 386410 3767.00 4%7.12 901 2' 5973373.30 1703062.66 2.00 +90.00 OT50100) .,_ 25 9300.25. 1164.% ....90.05 3404561 03 366310 3266.00 691,5.65_ 632.- 597442900 170276400 000... 000. (Ikb) .. K-1345.14092513011 _. % 9910.31 10.09�-_ 90.09 NS ei 3663.09 3%5.99 5925.13 609,`" 5974430.75 102%1,43 200 79.04 05CM Tag _... 27 10612.09 1301.% 90.09 395.81 3861.10 3%1.00 7187.47 700,35 5975690.00 1702452.00: 0.00 0.00: (0600) 1C.1546.16082915011 071206 ._ ..___,.. 2 10675.06 93.08: 92.05 395.93 3824.13 3%267 7284.79 224.03 ....-5975723.61 1702106.71 _ 0.00 -10.00 011 81.01.5 D 11675.08 % V 217 .OB 3.02 92.05 395 38 . 3727.67 8215.% 54%8 24.03 3.96 1702156.71 0.00 0.00 (60d) 30 11721.65 96.57 92.05 346.37 3823.10 37%.00 8260.90 12.69 59%X6.00 _ 1002145.00 2.00 90.05: (.8600) 92515 10.1547.160 .81 - 31 11859.54 ......-_ 137.89 �� 3%37 302149 3714.39 8391.88: -19.80_-_�-59%702.69 1702111.90 ...i 1,00 180.00:07501 ierp. 32 12218.90 ..__893.36 89.29'- 396.37... 3031.10 3735.00... 9729.96 232.36 0977736.00 110190100. 0.00 0.00 (O40o) 1C-1548.132092919014 • • ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-154 Plan: 1C-154 1 C-154wp06 Clearance Summary Anticollision Report 14 October,2015 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1C Pad-Plan:1C-154-Plan:1C-154-1C-154wp06 Well Coordinates: 5,968,509.07 N,1,702,200.32 E (70°19'29.57"N,149°29'56.36"W) Datum Height: Plan:57.6+39.5 97.10usft(Doyon 25) Scan Range: 0.00 to 12,718.90 usft Measured Depth. Scan Radius Is 1,467.94 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1C-154- 1 C-154wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1C Pad-Plan:1C-154-Plan:1C-154-1C-154wp06 Scan Range: 0.00 to 12,718.90 usft.Measured Depth. Scan Radius is 1,467.94 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited 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 *Kuparuk 1C Pad Plan 1C-20(wp 10)-1 C-20(wp10)-1 C-20(wp10) 46.50 145.57 46.50 142.88 50.00 54.181 Centre Distance Pass-Major Risk Plan 1C-20(wp 10)-1 C-20(wp10)-1 C-20(wp10) 271.49 146.88 271.49 142.14 275.00 31.010 Clearance Factor Pass-Major Risk Plan 1C-20(wp 10)-1C-20(wp10)-1C-20(Rig Proj) 46.50 145.57 46.50 143.27 50.00 63.255 Centre Distance Pass-Major Risk Plan 1C-20(wp 10)-1 C-20(wp10)-1 C-20(Rig Proj) 271.49 146.88 271.49 142.14 275.00 31.010 Clearance Factor Pass-Major Risk Plan 1C-20(wp 10)-1C-20(Rig)-1C-20(Rig) 46.50 145.57 46.50 142.88 50.00 54.181 Centre Distance Pass-Major Risk Plan 1C-20(wp 10)-1C-20(Rig)-10-20(Rig) 271.49 146.88 271.49 142.14 275.00 31.010 Clearance Factor Pass-Major Risk Plan 1C-21-1C-21 Mainbore-1C-21(wp11) 97.10 123.21 97.10 119.95 0.00 37.716 Centre Distance Pass-Major Risk Plan 1C-21-1 C-21 Mainbore-1 C-21(wp11) 346.11 124.62 346.11 119.01 250.00 22.240 Clearance Factor Pass-Major Risk Plan 1C-21-1 C-21 Mainbore-1 C-21 Mainbore 45.30 123.22 45.30 120.55 50.00 46.236 Centre Distance Pass-Major Risk Plan 1C-21-1 C21 Mainbore-1 C-21 Mainbore 344.34 125.18 344.34 119.39 350.00 21.610 Clearance Fades Pass-Major Risk Plan 1C-21-1 C-21 PB1-1 C-21 PB1 45.30 123.22 45.30 120.55 50.00 46.236 Centre Distance Pass-Major Risk Plan 1C-21-1 C-21 PB1-1 C21 PB1 344.34 125.18 344.34 119.39 350.00 21.610 Clearance Factor Pass-Major Risk Plan 1C-21-1 C-21 PB2-1 C-21 PB2 45.30 123.22 45.30 120.55 50.00 46.236 Centre Distance Pass-Major Risk Plan 1C-21-1 C-21 PB2-1 C-21 PB2 344.34 125.18 344.34 119.39 350.00 21.610 Clearance Factor Pass-Major Risk Plan 1C-28-Plan 1C-28-1 C-28(Actual)-wp14 326.71 83.32 326.71 76.75 450.00 12.679 Centre Distance Pass-Major Risk Plan 1C-28-Plan 1C-28-1 C-28(Actual)-wp14 400.00 84.05 400.00 76.03 525.00 10.478 Clearance Factor Pass-Major Risk Plan 1C-28-Plan 1C-28-1 C-28(Rig) 97.10 83.76 97.10 80.49 97.10 25.639 Clearance Factor Pass-Major Risk Plan 1C-28-Plan 1C-28(Rig)-1C-28(wp Rig) 97.10 83.76 97.10 81.01 100.60 30.441 Centre Distance Pass-Major Risk Plan 1C-28-Plan 1C-28(Rig)-1 C-28(wp Rig) 394.30 84.82 394.30 78.10 400,00 12.626 Clearance Factor Pass-Major Risk Kuparuk 1C Pad 1C-02-IC-02-IC-02 278.10 196.29 278.10 191.40 275.00 40.158 Centre Distance Pass-Major Risk IC-02-1C-02-IC-02 449.89 197.53 449.89 189.70 450.00 25.241 Clearance Factor Pass-Major Risk 1C-03-1C-03-1C-03 278.10 101.99 278.10 97.10 275.00 20.866 Centre Distance Pass-Major Risk 1C-03-1 C-03-1 C-03 376.46 102.62 376.46 96.04 375.00 15.615 Clearance Factor Pass-Major Risk 1C-03-1C-03A-1C-03A 278.10 101.99 278.10 97.10 275.00 20.866 Centre Distance Pass-Major Risk 1C-03-1C-03A-1C-03A 376.46 102.62 376.46 96.04 375.00 15.615 Clearance Factor Pass-Major Risk 10-04-10-04-1 C-04 303.03 107.38 303.03 101.50 300.00 18.255 Centre Distance Pass-Major Risk 14 October,2015- 15:53 Page 2 of 8 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1C-154- 1C-154wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1C Pad-Plan:1C-154-Plan:1C-154-1C-154wp06 Scan Range: 0.00 to 14718.90 usft.Measured Depth. Scan Radius is 1,487.94 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum 40Meaaured 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 1C-04-1 C-04-1 C-04 400.00 108.15 400.00 100.36 400.00 13.889 Clearance Factor Pass-Major Risk IC-05-1C-05-IC-05 351.91 205,38 351.91 199.51 350.00 35.000 Centre Distance Pass-Major Risk 1C-05-IC-05-IC-05 449.63 206.14 449.63 198.71 450.00 27.738 Clearance Factor Pass-Major Risk 1C-06-1C-06-1C-06 6,791.43 276.44 6,791.43 145.25 5,725.00 2.107 Clearance Factor Pass-Major Risk 1C-06-1C-06-1C-06 6,816.00 273.31 6,816.00 150.74 5,775.00 2.230 Centre Distance Pass-Major Risk 1C-12-1C-12-1C-12 2,184.37 233.28 2,184.37 184.10 2,475.00 4.742 Centre Distance Pass-Major Risk IC-12-IC-12-IC-12 2,217.17 236.64 2,217.17 182.90 2,525.00 4.403 Clearance Factor Pass-Major Risk 1C-14-1C-14-1C-14 611.77 75.03 611.77 63.63 625.00 6.581 Centre Distance Pass-Major Risk 1C-14-1C-14-1 C-14 635.95 75.53 635.95 63.52 650.00 6.291 Clearance Factor Pass-Major Risk 1C-14-1C-14A-IC-14A 611.10 75.02 611.10 63.62 625.00 6.582 Centre Distance Pass-Major Risk 1C-14-1C-14A-1C-14A 635.27 75.51 635.27 63.50 650.00 6.290 Clearance Factor Pass-Major Risk 1C-15-1C-15-1C-15 442.73 170.16 442.73 162.65 450.00 22.645 Centre Distance Pass-Major Risk IC-15-1C-15-1C-15 491.66 170.69 491.66 162.29 500.00 20.322 Clearance Factor Pass-Major Risk 1C-15-1 C-15L1-1 C-15L1 442.54 170.16 442.54 162.65 450.00 22.654 Centre Distance Pass-Major Risk 1C-1S-1C-15L1-1C-15L1 491.46 170.69 491.46 162.29 500.00 20.327 Clearance Factor Pass-Major Risk 1C-150-1C-150-1C-150 1,057.57 28.00 1,057.57 11.12 1,050.00 1.659 Clearance Factor Pass-Magor Risk 1C-153-1C-153-IC-153 199.16 327.80 199.16 324.13 200.00 89.459 Centre Distance Pass-Major Risk IC-153-1C-153-IC-153 399.07 328.88 399.07 321.79 400.00 46.360 Clearance Factor Pass-Major Risk 1C-153-1 C-153-1 C-153wp07 199.16 327.80 199.16 324.13 200.00 89.459 Centre Distance Pass-Major Risk 1C-153-1C-153-1C-153wp07 399.07 328.88 399.07 321.79 400.00 46.360 Clearance Factor Pass-Major Risk 1C-16-1C-16-1C-16 1,177.92 203.72 1,177.92 177.13 1,225.00 7.663 Centre Distance Pass-Major Risk 1 C-16-1 C-16-1 C-16 1,248.02 205.16 1,248.02 176.12 1,300.00 7.063 Clearance Factor Pass-Major Risk 1C-170-1C-170-IC-170 584.54 114.42 584.54 104.56 575.00 11.606 Centre Distance Pass-Major Risk IC-170-1C-170-IC-170 633.85 114.75 633.85 104.08 625.00 10.757 Clearance Factor Pass-Major Risk 1C-170-1 C-170P81-1C-170PB1 584.54 114.42 584.54 104.67 575.00 11.737 Centre Distance Pass-Major Risk 1C-170-1 C-170PB1-1 C-170PB1 633.85 114.75 633.85 104.19 625.00 10.869 Clearance Factor Pass-Major Risk 1C-172-1C-172-1C-172 59.90 79.77 59.90 76.88 50.00 27.603 Centre Distance Pass-Major Risk 1C-172-1C--172-IC-172 609.98 81.56 609.98 71.24 600.00 7.904 Clearance Factor Pass-Major Risk 1C-172-1C-172A-1C-172A 46.60 79.77 46.60 77.07 50.00 29.617 Centre Distance Pass-Major Risk 1C-172-1C-172A-IC-172A 621.57 81.74 621.57 71.24 625.00 7.788 Clearance Factor Pass-Major Risk 14 October,2015-15:53 Page 3 of 8 COMPASS III • ConocoPhillips(Alaska)Inc.-Kupi Kuparuk River Unit Anticollision Report for Plan: 1C-164- 1C-154wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1C Pad-Plan:1C-154-Plan:1C-154-1C-154wp06 Scan Range: 0.00 to 12,718.90 usft.Measured Depth. Scan Radius Is 1,457.94 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 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 1C-172-1 C-172AL1-1 C-172AL1 46.60 79.77 46.60 77.07 50.00 29.617 Centre Distance Pass-Major Risk 1C-172-1 C-172AL1-1 C-172AL1 621.57 81.74 621.57 71.24 625.00 7.788 Clearance Factor Pass-Major Risk 1C-172-1 C-172At2-1 C-172AL2 46.60 79.77 46.60 77.50 50.00 35.280 Centre Distance Pass-Major Risk 1C-172-1C-172Al2-1C-172AL2 621.57 81.74 621.57 71.29 625.00 7.823 Clearance Factor Pass-Major Risk 1C-172-1 C-172AL2PB1-1 C-172AL2PB1 46.60 79.77 46.60 77.07 50.00 29.617 Centre Distance Pass-Major Risk 1C-172-1 C-172AL2PB1-1 C-172AL2PB1 621.57 81.74 621.57 71.24 625.00 7.788 Clearance Factor Pass-Major Risk 1C-172-1 C-172AL2PB2-1 C-172AL2PB2 46.60 79.77 46.60 77.07 50.00 29.617 Centre Distance Pass-Major Risk 1C-172-1C-172AL2PB2-1C-172AL2PB2 621.57 81.74 621.57 71.24 625.00 7.788 Clearance Factor Pass-Major Risk IC-174-IC-174-IC-174 109.90 40.00 109.90 36.51 100.00 11.441 Clearance Factor Pass-Major Risk 1C-174-Plan 1C-174a-1C-174a(wp01) 109.90 40.00 109.90 36.51 100.00 11.441 Clearance Factor Pass-Major Risk 1C-174-Plan 1C-174a L7(wp01)-1C-174a L1(wp01 109.90 40.00 109.90 36.51 100.00 11.441 Clearance Factor Pass-Major Risk 1C-178-1 C-178-1 C-178 533.73 34.20 533,73 25.27 525.00 3.829 Clearance Factor Pass-Major Risk 1C-178-1C-178L1-1C-178L1 533.73 34.20 533.73 25.27 525.00 3.829 Clearance Factor Pass-Major Risk 1C-178-1 C-178L1 PB1-1 C-178L1 PB1 533.73 34.20 533.73 2527 525.00 3.829 Clearance Factor Pass-Major Risk 1C-178-1 C-178L1 PB2-1 C-178L1 PB2 533.73 34.20 533.73 25.27 525.00 3.829 Clearance Factor Pass-Major Risk 1C-18-1 C-18-1 C-18 95.60 152.21 95.60 148.87 100.00 45.645 Centre Distance Pass-Major Risk 1C-18-1C-18-1 C-18 393.48 153,99 393.48 147.37 400.00 23.270 Clearance Factor Pass-Major Risk IC-i84-1C-184-IC-184 109.90 160.11 109.90 156.65 100.00 46.326 Centre Distance Pass-Major Risk 1C-184-1C-184-1 C-184 409.90 162.54 409.90 155.76 400.00 23.988 Clearance Factor Pass-Major Risk 1C-19-1 C-19-1 C-19 2,341.46 109.62 2,341.46 65.20 2300.00 2.468 Clearance Factor Pass-Major Risk 1C-19-1 C-19-1 C-19 2,366.45 109.39 2,366.45 65.69 2,325.00 2.504 Centre Distance Pass-Major Risk 1C-20-1C-20-Plan 1C-20(wp10) 295.90 145.57 295.90 140.48 300.00 28.625 Centre Distance Pass-Major Risk 1C-20-1 C-20-Plan 1C-20(wp10) 320.46 145.75 320.46 140.27 325.00 26.568 Clearance Factor Pass-Major Risk 1C-20-1 C-20-1 C-20 45.90 145.57 45.90 142.88 50.00 54.169 Centre Distance Pass-Major Risk 1C-20-IC-20-1C-20 270.89 146,88 270.89 141.84 275.00 29.160 Clearance Factor Pass-Major Risk 1C-20-1 C-20PB1-1 C-20PB1 45.90 145.57 45.90 142.88 50.00 54.169 Centre Distance Pass-Major Risk 1C-20-1C-20PB1-1C-20PB1 270.89 146.88 270.89 141.84 275.00 29.160 Clearance Factor Pass-Major Risk 1C-21-1 C-21-1 C-21 45.30 123.22 45.30 120.94 50.00 54.053 Centre Distance Pass-Major Risk 1C-21-1 C-21-1C-21 344.34 125.18 344.34 119.39 350.00 21.610 Clearance Factor Pass-Major Risk 1C-21-1C-21L1-1C-21L1 45.30 123.22 45.30 120.55 50.00 46.238 Centre Distance Pass-Major Risk 14 October,2015- 15:53 Page 4 of 8 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1C-154- 1C-154wp06 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 1C Pad-Plan:1C-154-Plan:1C-154-1C-154wp06 Scan Range: 0.00 to 12,718.90 usft.Measured Depth. Scan Radius is 1,467.94 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 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 1C-21-1C-21L1-1C-21L1 344.34 125.18 344.34 119.39 350.00 21.610 Clearance Factor Pass-Major Risk 1C-21-10-2112-1C-21L2 45.30 123.22 45.30 120.55 50.00 46.236 Centre Distance Pass-Major Risk 1C-21-1C 2112-1C-21 L2 344.34 125.18 344.34 119.39 350.00 21.610 Clearance Factor Pass-Major Risk 1C-21-1C-2113-1C-2113 45.30 123.22 45.30 120.55 50.00 46.236 Centre Distance Pass-Major Risk 10-21-1C-21L3-1C-21 L3 344.34 125.18 344.34 119.39 350.00 21.610 Clearance Factor Pass-Major Risk 10-22-1C-22-1C-22 285.00 199.83 285.00 195.08 275.00 42,058 Centre Distance Pass-Major Risk 1C-22-1C-22-10-22 385.05 200.49 385.05 194.10 375.00 31.385 Clearance Factor Pass-Major Risk 1C-23-1C-23-1C-23 473.26 212.81 473.26 204.91 475.00 26.962 Centre Distance Pass-Major Risk 1C-23-1C-23-1023 497.76 213.02 497.76 204.70 500.00 25.599 Clearance Factor Pass-Major Risk IC-23PB1-1C-23P81-1C-23PB1 473.26 212.81 473.26 204.87 475.00 26.802 Centre Distance Pass-Major Risk 1C-23P81-1C-23P81-1C-23P81 497.76 213.02 497.76 204.65 500.00 25.454 Clearance Factor Pass-Major Risk 1C-24-1 C-24-1C 24 56.80 226.58 56.80 223.80 81.30 81.240 Centre Distance Pass-Major Risk 1C-24-1C-24-1C-24 320.07 227.76 320.07 221.53 325.00 36.565 Clearance Factor Pass-Major Risk 1C-28-10-28-1C-28 46.20 82.69 46.20 80.64 50.00 40.416 Centre Distance Pass-Major Risk 1C-28-1 C-28-1 C-28 394.03 83.85 394.03 76.47 400.00 11.364 Clearance Factor Pass-Major Risk 1C-28-1C-28L1-1C-28L1 46.20 82.69 46.20 79.99 50.00 30.719 Centre Distance Pass-Major Risk 1C-28-1C-28L1-1C-2811 394.03 83.85 39403 76.21 400.00 10.976 Clearance Factor Pass-Major Risk 1C-28-1 C-28PB1-1C28PB1 46.20 82.69 46.20 79.99 50.00 30.719 Centre Distance Pass-Major Risk 1C-28-1 C-28PB1-1C-28PB1 394.03 83.85 394.03 76.21 400.00 10.976 Clearance Factor Pass-Major Risk Plan 1C-155-Plart1C-155-1C-155wp05 425.01 120.12 425.01 112.50 425.00 15.781 Centre Distance Pass-Major Risk Plan 1C-155-PIen1C-155-1C-155wp05 599.53 120.69 599.53 110.08 600.00 11.374 Clearance Factor Pass-Major Risk Plan 10-156-Plan 1C-156-1C-156wp01 2,118.54 51.90 2,118,54 11.71 2,175.00 1.291 Clearance Factor Pass-Major Risk Plan 1C-156-Plan 10-156-1 C-156wp01 2,142.83 51.69 2,142.83 11.80 2,200.00 1.296 Centre Distance Pass-Major Risk Plan 1C-157-Plan 1 C-157-1C-157wp01 259.10 179.49 259.10 174.77 250.00 38.043 Centre Distance Pass-Major Risk Plan:1C-157-Plan 1C-157-1C-157wp01 357.78 179.90 357.78 173.63 350.00 28.705 Clearance Factor Pass-Major Risk Plan 1C-158-Plart1C-158-1C-158wp01 297.60 129.30 297.60 123.99 300.00 24.383 Centre Distance Pass-Major Risk Plan 1C-158-PlarrlC-158-1C-158wp01 639.00 132.59 639.00 121.45 650.00 11.898 Clearance Factor Pass-Major Risk 14 October,2015-15:53 Page 5 of 8 COMPASS • • ConocoPhillips(Alaska)Inc.-Kupl Kuparuk River Unit Anticollision Report for Plan: 1C-154- 1C-154wp06 Survey tool arQgram From To Survey/Plan Survey Tool (usft) (usft) 39.50 1,150.00 1 C-154wp06 GYD-GC-SS 1,150.00 2,150.00 1C-154wp06 MWD 1,150.00 2,628.07 1C-154wp06 MWD+IFR-AK-CAZ-SC 2,628.07 4,128.07 1C-154wp06 MWD 2,628.07 5,854.71 1C-154wp06 MWD+IFR-AK-CAZ-SC 5,854.71 7,354.71 1 C-154wp06 MWD 5,854.71 12,718.90 1C-154wp06 MWD+IFR-AK-CAZ-SC 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. 14 October,2015- 15:53 Page 6 of 8 COMPASS • 15,59, October 14 2(15 1C-154wU06 Later View r The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors c .in n n 3 3 3 qyt QZ.n 300— V tI I � 'l it i I ' / c t I1I III I1I�l� I I 'I;III•i� I1i ii i co �il j ,I 1 11 IId iliw 11, N 150 '° P dirtiliII' I o N _ 0,tI1.,1 n II N U _ O Equivelan. netic Distar, I 1 I 1 I I 1 I I 1 I I I I I I I I I I I I I I I I I I I 0 2000 4000 6000 8000 10000 12000 Displayed interval could be less than entire well:Measured Depth 39.50 To 12718.90 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 1150.00 1C-154wp06 (Plan: 1C-154) GYD-GC-SS 119.50 119.50 20"x 42" 1150.00 2150.00 1C-154wp06 (Plan: 1C-154) MWD 2403.28628.07 10-3/4"x 13-1/2" 1150.00 2628.07 1C-154wp06 (Plan: 1C-154) MWD+IFR-AK-CAZ-SC 3867.154.71 7-5/8"x 9-7/8" 2628.07 4128.07 1C-154wp06(Plan: 1C-154) MWD 3832111Y18.90 4-1/2"x 6-3/4" 2628.07 5854.71 1C-154wp06 (Plan: 1C-154) MWD+IFR-AK-CAZ-SC 5854.71 7354.71 1C-154wp06 (Plan: 1C-154) MWD 5854.71 12718.90 1C-154wp06 (Plan: 1C-154) MWD+IFR-AK-CAZ-SC . A N S ti U _U 60— I El, - 0 I�� i y IS !r n I U 111 2 - I // c co U 0 1 ( 1 1 IIIIIIIIIIIIIIIIITIII I I I I I 1 1 1 1 I I C-quiv8laM Magnetic oiatancP0 1000 1500 2000 2500 3000 3500 Partial Measured Depth ,, .. .4,4 ''- 4U 3UU 1 C-1 54wp06 . Inc Azi TVD Dleg TFace get 300 490 39.50 0.00 0.00 39.50 0.00 0.00 39.50 To 12718.90 300.00 0.00 0.00 300.00 0.00 0.00 490 670 600.31 4.50 35.00 600.00 1.50 35.00 670 860 2.98 10.40 46.52 900.00 2.00 20.00 15:59,October 14 2015 05.49 27.81 62.82 1750.00 2.00 25.00 860 1040 18.55 27.81 62.82 1850.00 0.00 0.00 CASING DETAILS 2620.34 48.71 58.47 2398.10 3.00 -9.13 1040 1230 l627.27 48.71 58.47 2402.67 0.00 0.00 TVD MD Na1230 1410 228.07 48.73 58.47 2403.20 3.00 0.53 119.50 119.50 20" x 4 48.07 48.73 58.47 2416.39 0.00 0.00 2403.20 2628.07 10-3/4" x 13-1/ 3867.10 5854.71 7-5/8" x 9-7/ 57.70 48.74 63.94 2488.73 3.75 91.69 1410 1600 3832.10 12718.90 4-1/2" x 6-3/i414.28 48.74 63.94 2921.74 0.00 0.00 1600 2060 5504.86 85.00 345.00 3852.10 3.75 -86.46 1C-154 1. Top WSD 092515 DH ate,.:FRO.PAN /0.64 86.14 347.38 3857.18 4.00 64.34 2060 2530 ...w rm...,.n 1e Survey/Plan r..a 80.70 86.14 347.38 3857.86 0.00 0.00 2530 2990 1110:3 113:0°e u-154..66 is u.11da.i o'6-" 54.71 90.00 337.11 3867.10 4.00 -69.63 1C-154 2. Ti Landing 092515 IDH a0.0o iui:0i 1ic�15a1Ny0.w0 C"" e-1n0i 0""*"*-"-c"-"8 4.71 90.00 337.11 3867.10 0.00 0.00 'ss 0:n i M I' i`ca i vl 1e-1") r*o R`-"'`-"25.79 90.05 335.88 3867.08 3.00 -87.90 2990 3450 ,.M., vn.,. 1c-1a.np.a P1.�: '-"" """"-"-"'"67.35 90.05 335.88 3866.34 0.00 0.00 3450 3910 92.68 90.04 345.64 3866.10 3.00 90.03 1C-154 3. T2 092515 DH 96.79 90.12 345.64 3866.09 2.00 0.00 3910 4370 30.50 90.12 345.64 3864.11 0.00 0.00 4370 4840 8134.15 90.05 345.64 3864.10 2.00 178.72 1C-154 4. T3 092515 DH 8135.49 90.05 345.61 3864.10 2.00 -90.00 4840 5300 9300.25 90.05 345.61 3863.10 0.00 0.00 1C-154 5. T4 092515 DH 9310.34 90.09 345.81 3863.09 2.00 79.04 5300 6230 10612.09 90.09 345.81 3861,4pp 0.00 0.00 1C-154 6. 15 092515 DH 10712.06 92.05 345.43 385933802.0. C-19 87 6230 7150 11675.08 92.05 11,` :l.pr•�f ' ; 00 +lw '�4:•- 7150 8080 11721.65 92.05 `' �l`' c 6'vrr+� yam♦ s 5 1C-154 7. T6 092515 DH 11859.54 89_ !� lkial 1 2��tii`ini 12A/.330 - l vim+ yr ii sE .• M ,' -Vr,° ; 8080 9010 y�'�{ ®i1,g►rl �t21C' .ate j '0 0*• 8k 092515 DH IMPAIL �� w s ' h . 4-`-- ♦`0��1 9010 9940 Pl..``_ �� .1���� 9940 10860 I���!' .�� �1��i$1� 0 11111,111011 \ ��s-� :vo.4 abbe./� 10860 11790 . *•." 1 1"si .\�.�`.-,a0 �•-1,4`1iM�► 11790 12719 1406. '♦r r wr►• .4044'1 � 15 0 V.WZi��., iii.sA 401.�`1L =OTC*, E r i, �: 113 x1 AperA�" fzrl gb.0- ►AAI �► 60/300 •: azo.\r'r • ..41.-.. % %N �y�_! o. si t, _alp 60 121 �.,�� � '74!4i, VW,4110 . 4.,t4iiiipr- -'.144,4161 '-' ..* tWellLWIRA gl" -‘1,04, - A0111 9° _ \Ivs IfamloON k I I • ,#.'•'','44-;:'%411;j:l••%.:•'7111. /Z ' 1 0 \ .81 W.#74"111IN illika1 1C-1748 aud.i l r,.I I � I i� I 1` . 11 NIllikup _90 i itz,i __,:.4;1-''' :r,41 I t\-44,14. rib ro,re ail ill 1 allik , .Am.. ` 'dam. y.;. \w ► :;11*,, Wv.,t a Fl♦ ry a :�• , ,i'4j►1r Y h�rks i "r� s iS : « v i f r r t'6: a e14i `,"01 �` �" �v \,�• ' r !9 �\ h ��� ��O►+,,i aD•' ♦a�1101 w r P t►. 04,��i �i. . d r,i�® . ��1 e r.A l aV T tArrgr 1e a/��IfV ( ��i,Q11 ,', �',.� ./���%�Y �� ���0 AIN � '::131/011►r SII ., gP, ,rb •� 41:44101�'`��� I 11C-1 11 I �;a�t, r „ 1111, ,v '' yl.� 2N`U�71 + 1.�Il9./ 1"11 ►i`\Ot t . ,N1 v. -• 1... , \• •••r•w• -120/ �,r.-, > .( �r.�! �!%� \ A l.Q���edi ; / muil‘ W \ .ice .tep i T -150/2101 "*It � 1 "s. .Aj •'1. ry, 1\ , Iligial°; .ear• - 80/180 '---r' • • 16:00,October14201E Easting(3000 us>tfn) „ II „ 11111 . , I . IL . 1 , . 11111 „ I , . „ I , 1111111 1I11 , 1I1111I1si , I „ i 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I i 1 1 1 I 1 1 1 1 1 1 1 1 1 - ,�' (NOT a Spider) - io-imwp07 ppgg _ — 1C-150 1 C-1 14C�R55wp05 — 1C- 4C- 70 1C-158.w.p0., r - 1C 78C 174a ., .61) - 1 V'P58wp01 _ - 1C- 8 C idC-19 1C-16 1C-14A 1C-22 1 1C-VIL1R:2 — 1C- 70P61 1#00 ` _ 1C-15L1 c - 1C-178L1 �a� ` c2— 104. '' 1C-15 _ �j� _- 1C-23 m co— La Ito -1111-&_"1-1-111miPP-Air - c 41,1 ai@®t C-03 1C-02 `�.`1 Mainbore !'117- L2PB221L3 _ - - L 1ffi2WR/'�igbl)-wp14 _ Kuparuk 10 Pad = = 1C-12 —• -- 1C-184 — Kuparuk 1D Pad 1r/non1 1cp awe cooiJ ploy - 111111111111111111 , 111111111111111111111111111111111111111111111111111111111111111111111111111111 - Easting(3000 tall/in) i • Casi„g Detans Survey Program TVD MD Name Depth From Depth TO Survey/Plan Tool 1C-154wp06 nq.5o „9.50 ao"x4" 39-So n5o.00 ,[,59 po6(Plan, ,54) CVD CC 55 40 300 z9o3za 58547, ,0-314"x97/8" n5o.00 n5o,00 ,C-,54�'Po6(Plarcff,59) MWD 3831.to 5854J, ]118"x4]/8" „50.00 2628.0] tC-t54�Po6(Plarc,C-,54) MWDaIFR-AK CAZ-SC To 3831 10 07x8 9° 492"x6314" 2628 07 m28 o7 ,Ca54�+po6(Nam 1c 154) MWD 39.50 1000.00 2628 07 5854„ ,C+549,6.6(Pla +6'64) MWD,12 AK CAZ 56- 39.50 C 300 490 5854], =97.; ,C-,54006 PI [54) MWD 5859.T tzTe.go ,C-,5gwpo6 Plaro,C-t59) MWDNFRAK-CAI-SC 490 670 MD Azi 0 / 360 67o 860 39.50 0.00 9 0 86o 1040 300.00 0.00 -30 / 33Q 0 600.31 35.00 1040 1230 902.98 46.52 1230_ 1410 1805.49 62.82 1C-172' 'B2 60 1410231600 1918.55 62.82 =- 60 1600 2060 2620.34 58.47 -60 / 300 - 2627.27 58.47 1C-174a 1 ( t e e• 2060 2530 A iNii i'►� 2628.07 58.47 - a., ;-441ir. 30 2530 2990 2648.07 58.47 �`1i�i*` . Pli, 2757.70 63.94 2990 3450 3414.28 63.94 / 7 3450 _. 3910 5504.86 345.090 2 0 _ -- 90 - 5570.64 347.38 3910 4370 5580.70 347.38 �- a'�_ 4370 4840 5854 71 337.11 rp1P'W'ili i°g'.II*414;; 4840 5300 ,�lr I` i 1 ^a - 5884.71 337.11 �i4�� '':���i;a�� �,��I� ���� -'� �. ���.; ' ` JI 5300 6230 5925.79 335.88 �I ������ � t ty� sF�,, 6867.35 335.88 -120 / 240 ei `� - -- ° ,r120 6230 7150 _` n 7192.68 345.641 /,� `��-%� 0 '`I������,� 4q ! 7150 8080 7196 79 345.64 /I �.' `►i -4 '1,1 Air r ��/ ,,;,� SW" 8080 9010 8130.50 345 64 �,,, •.•,,,,, .i. ,:.-40.41‘/ 1 01 994 8134.15 345.64 -1 1C-17: �� . .� f �� �,,,��1w '15 0 9 0 0 8135.49 345.61 '.41;107), )...P 9940 10860 9300.25 345.61 -180 / 180 10860 11790 rclin -,A At Ri 11790 12719 16:02,October 14 2015 IIJ/IG.6JU )9.)•�0 • • Casing Detaes Survey Program TVD MD Name Depth iron, Depth To Survey/Plan Tool 1C-154wpo6 9bo 9.50 0'x42" 39.50 ,,5000 tCg4 W6(Pan+C+59) GYDLCSS 40 300 2463.x0 5854.7, t0-314"x9-7/8" ,C454wpo6(PlantC-+54) MWD 3867.+0 5854.]1 7118"x4778" ,,50.00 26x8.0] tC-t54wp06(Plan+C+Sq))) MWD.IFR-AK-CAZ-SC 383x.+0 +z]+8.90 4'+!z"x6-314" x628.0] 5854.7] +C-t59`vpo6(PllantC-t5q) INVID MWDNFRAKLAZ-SC 300 490 1000.00 To 2000.00 5854.7, 7354.7+ tC t54wpo6(Plan+C454) MWD 5854-71 1418.90 +C-,59wpo6 Mare tC-t54) MWD.IFR-AKUZ-5C 490 67o MD Azi 0 / 360 67o 86o 39.5o o.00 90 860 1040 300.0o o.00 -30 / 339 0 600.31 35.00 1040 1230 902.98 46.52 1230 1410 1805.49 62.82 / 11160 1918.55 62.82 1410 1600 2620.34 58.47 -6o / 300 60 1600 _ 2060 2627.27 58.47 2060 253o 2628.07 58.47 3o 2530 2990 2648.07 58.47 2757.7o 63.94 2990 3450 3414.28 63.94 • ,.�Z..---",..v.„ 3450 - 3910 5504.86 345.00 I - 90 3910 4370 5570.64 347.381211400___ ___„.. ....__Huir- A� ��i 80 0347.38 rS41, 4 Nal 4370 4840 55 •7 , �: _;�:�.�►.� 5854.71 337.11 AMR* ��( ;1' ,`-10 4840 5300 5884.71 7.11 ��� �:c� : C� ���� ��` `, 5300 6230 5925.79 335.88 E:-... 6867.35 335.88 - \\VA.vilitis.4.."4 \\\\�t120 / 240 M11 1 120 62307150 7192.68 345.64 ��,J1014�� V "I '' 7150 8080 7196.79 345.64 y1�q/44 4•!�,G,� r 8080 9010 8130.5o 345.64 8134.15 345-64 -150 / 210A 150 9010 9940 8135.49 345.61 99____________ 0�� 9940 10860 9300.25 345.61 -180 / 180 10860 11790 !1'1 4/1 ')A "A L R 1 I 16:02,October 14 2015 11790 12719 IIJ/IL•vv )9',•9'3 \ • • Casing Detniis Survey Program TVO MD Name Depth From Depth To Survey/Plan Tool 1 C-15 4 w p o 6 „9.50 „9.50 o"x 43" 39.50 ”50.00 ,C-,54wpo6(Pim 10.,54) CYDLC SS 40 300 zoo;.zo z6z8.07 „50.00 2,50.00 1C454wpo6(Plare,C454) MWD 0 5854.], 71)8"x9-])8" ”50.00 x6z8.07 ,C-,54wp06(Plan:,U54) MWD.IFRAK-CAZSC A To3830.0 14718.90 4-,lz"z 6-3I4" z6ze.o7 4,x8.0] ,C-,54wp06(Plart,C4544 MWD 20\/0 00 3000 0® 638.07 5854.7, +4,54wpo6(Pa ,C+q) MWDHFRAK CAZ SC 300 490 5854.7, 73547, ,C-,54wp06(Plan:,C,54) MWD 5859J, 17718.90 tC-154wp06(Pian 1C-154) MWD.IFRAK-CAZ-SC 490 67o M D Azi 0 136o 67o 86o 39.5o o.o0 90 8601040 300.00 0.00 -30 / 33 - 0 600.31 35.00 1040 1230 902.98 46.52 1230 1410 1805.49 62.82 60 1410 1600\ 1918.55 62.82 2620.34 58.47 -60 / 300 / 60 1600 2060 2627.27 58.47 2060 2530 2628.07 58.47 ( 30 2530 2990 2648.07 58.47 2757.70 63.94 2990 3450 3414.28 63.94 3450 3910 5504.86 345.00 / 270 90 5570.64 347.38 - \ 3910 4370 5580 70 347.38 4370 484o 5854.71 337.11 ! 0 _ 4840 5300 5884.71 337.11 �_ z 5300 623o 5925.79 335.88 \ / X120 6230 7150 6867.35 335.88 -120 I 240 7192.68 345.64 L.y i 715o 8080 7196.79 345.64 III8080 9010 8130.50 345.64 1 4 -6wpo1 8134.15 345.64 -150 / 210 j 150 9010 9940 8135.49 345.61 9940 10860 9300.25 345.61 10860 11790 -180 / 180 (-Inlet 7A 7 A Q1 16:03,October 14 2015 11790 12719 Il.,/IG.1/V 34}0.9•3 • • Casing Derails Survey Program TVD MD Name pept Fran Depth To Survey/13m Tod 1C-154wpo6 9•So „9.So 70" 4z" 3950 50.00 C-154wpo6(PIarc1C-154) GVDLG55 40 300 0403.x0 06x8.0] 10-314"xg,/z" 1,50 00 x150.00 ,C-,54wp06(Phrc,C-154) MWD 3867.10 5854.7, 7518"x47/8" 1150.00 06x8.07 06-154wpo6 raw,C-,54) MWD.IFRAK-A1( -5C 383x.,0 a708.4o 1-,h"x6914" 06x8.0] 9n8.07 ,C-,54wpo6(Plan 06-059 MWD 00 Q 3000.00 To 12718.90 i6x8.o7 5854.70 ,C-154wp06(Pbu1C-154 MWD.1FRAKCAZSC 3 49 / 58547, 7354 7, ,C-,54wW6(Pbrc,C,54) MWD 5854.]1 1,7,8.9. IC 154wpo6(PIarc IC-154) MWDNFRAK-CAZ-5C 490 67o M D Azi 0 / 360 67o 86o 39.5o o.o09 0 __- 300.00 0.00 -30 / 33 0 86o 1040 600.31 35.00 1040 1230 902.98 46.521230 1410 1805.49 62.82 // 601410 1600 1918.55 62.82 -6o I 300 /60 1600 2060 2620.34 58.47 2627.27 58.47 2060 2530 2628.07 58.47 30 zS3o -- 2990 3450 2990 2648.07 58.47 2757.7o 63.94 7-3414.28 63.94 / 3450 3910 5504.86 345.00 270 90 3910 4370 5570.64 347.38 5580.70 347.38 4370 484o 5854.71 337.11 30 4840 5300 5884.71 337.11 530o 6230 5925.79 335.88 120 6230 7150 6867.35 335.88 -120 / 240 7192.68 345.64 60 7150 8o8o 7196.79 345.64 8130.50 345.64 \ 8080 9010 9010 9940 8134.15 345.64 -150 / 210 150 8135.49 345.61 90 9940 10860 9300.25 345.61 10860 11790 1,»n 7A ' Ar u4 -180 /180 16:04,October 14 2015 11790 12719 1.,i SI•D•1•3 • • ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-154 Plan: 1C-154 Plan: 1C-154wp06 Report - Errors To ltiptual errors: 14 October, 2015 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5©97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 1C Pad Site Position: Northing: 5,968,274.22 usft Latitude: 70°19'27.241 N From: Map Easting: 1,702,403,98usft Longitude: 149°29'50.471 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.47° Well Plan:1C-154 Well Position +NI-S 0.00 usft Northing: 5,968,509.07 usft Latitude: 70°19'29.567 N +E/-W 0.00 usft Easting: 1,702,200.32 usft Longitude: 149°29'56.359 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 57.60 usft Wellbore Plan: 1C-154 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 10/25/2015 18.90 80.99 57,505 Design 1 C-154wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(ND) +N/-S +EI-W Direction (usft) (usft) (usft) r) 39.50 0.00 0.00 345.00 Survey Tool Program Date 10/14/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,150.00 1C-154wp06(Plan: 1C-154) GYD-GC-SS Gyrodata gyro single shots 1,150.00 2,150.00 1C-154wp06(Plan: 1C-154) MWD MWD-Standard 1,150.00 2,628.07 1C-154wp06(Plan: 1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,628.07 4,128.07 1C-154wp06(Plan: 1C-154) MWD MWD-Standard 2,628.07 5,854.71 1C-154wp06(Plan: 1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,854.71 7,354.71 1C-154wp06(Plan: 1C-154) MWD MWD-Standard 5,854.71 12,718.90 1C-154wp06(Plan: 1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 39.50 0.00 0.00 0.00 -57.60 0.00 0.00 0.00 100.00 1.15 0.00 0.00 2.90 1.15 0.04 0.04 119.50 1.15 0.00 0.00 22.40 1.15 0.19 0.19 20"x 42" 200.00 1.15 0.00 0.00 102.90 1.15 0.19 0.19 300.00 1.15 0.00 0.00 202.90 1.15 0.33 0.33 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 10/14/2015 4:00:01PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger S Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (°) (usft) (usft) (usft) (usft) 400.00 1.15 1.50 135.00 302.89 1.15 0.47 0.47 500.00 1.15 3.00 135.00 402.81 1.15 0.61 0.61 600.00 1.16 4.50 125.93 502.59 1.15 0.75 0.75 600.31 1.16 4.50 125.93 502.90 1.15 0.75 0.75 Start 2°/100'DLS,20°TF,for 302.6T 700.00 1.16 6.41 155.54 602.13 1.15 0.90 0.89 800.00 1.16 8.37 27.40 701.30 1.15 1.05 1.03 900.00 1.17 10.34 35.74 799.96 1.15 1.21 1.18 902.98 1.17 10.40 35.86 802.90 1.15 1.22 1.18 Adjust TF to 25°,for 902.51' 1,000.00 1.18 12.19 39.41 898.03 1.15 1.38 1.32 1,100.00 1.19 14.07 42.40 995.42 1.15 1.56 1.47 1,200.00 1.21 15.98 44.34 1,092.00 1.15 1.66 1.54 1,300.00 1.23 17.91 50.92 1,187.65 1.15 1.78 1.55 1,400.00 1.25 19.85 54.97 1,282.26 1.15 2.02 1.57 1,500.00 1.28 21.81 57.06 1,375.72 1.15 2.37 1.60 1,600.00 1.30 23.77 58.37 1,467.91 1.15 2.84 1.66 1,700.00 1.33 25.73 59.33 1,558.72 1.16 3.39 1.74 1,800.00 1.36 27.71 60.12 1,648.04 1.18 4.02 1.83 1,805.49 1.36 27.81 60.15 1,652.90 1.18 4.05 1.84 Hold for 113.06' 1,854.11 1.37 27.81 60.70 1,695.90 1.22 4.69 1.95 Pfrost 1,900.00 1.37 27.81 60.70 1,736.49 1.22 4.69 1.95 1,918.55 1.37 27.81 60.79 1,752.90 1.23 4.82 1.98 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,000.00 1.41 30.23 61.08 1,824.11 1.26 5.40 2.07 2,100.00 1.46 33.20 61.24 1,909.17 1.30 6.18 2.20 2,126.32 1.50 33.98 63.77 1,931.10 1.21 3.26 1.90 T3 2,200.00 1.50 36.17 63.77 1,991.39 1.21 3.26 1.90 2,300.00 1.56 39.15 63.72 2,070.55 1.24 3.59 1.96 2,400.00 1.62 42.13 63.54 2,146.42 1.27 3.96 2.03 2,492.79 1.69 44.90 63.29 2,213.70 1.32 4.35 2.11 K15 2,500.00 1.69 45.11 63.29 2,218.80 1.32 4.35 2.11 2,600.00 1.76 48.10 63.00 2,287.49 1.37 4.76 2.18 2,620.34 1.77 48.71 62.95 2,301.00 1.38 4.85 2.20 Hold for 6.93' 2,627.27 1.77 48.71 62.93 2,305.57 1.38 4.88 2.21 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 1.77 48.73 62.93 2,306.10 1.38 4.88 2.21 Hold for 20'-10-3/4"x 13-1/2" 2,648.07 1.80 48.73 62.79 2,319.29 1.34 4.98 2.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,700.00 1.80 48.70 62.37 2,353.56 1.35 5.27 2.20 10/14/2015 4:00:01PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger II Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (0) (usft) (usft) (usft) (usft) 2,757.70 1.81 48.74 62.16 2,391.63 1.37 5.64 2.22 Hold for 656.57' 2,800.00 1.82 48.74 62.15 2,419.52 1.40 5.94 2.24 2,900.00 1.83 48.74 62.31 2,485.47 1.47 6.76 2.32 3,000.00 1.84 48.74 62.50 2,551.42 1.58 7.70 2.43 3,100.00 1.84 48.74 62.69 2,617.37 1.70 8.71 2.57 3,200.00 1.85 48.74 62.85 2,683.32 1.84 9.77 2.73 3,300.00 1.86 48.74 62.98 2,749.27 2.00 10.87 2.91 3,400.00 1.87 48.74 63.10 2,815.22 2.16 11.99 3.11 3,414.28 1.88 48.74 63.11 2,824.64 2.19 12.15 3.14 Start 3.75°1100'DLS,-86.46°TF,for 2090.58' 3,500.00 1.95 49.02 63.05 2,881.03 2.34 13.03 3.36 3,600.00 2.35 49.53 62.65 2,946.30 2.52 13.90 3.75 3,700.00 3.01 50.26 61.95 3,010.74 2.70 14.69 4.25 3,800.00 3.83 51.17 61.00 3,074.08 2.90 15.42 4.81 3,869.97 4.76 51.92 59.85 3,117.60 3.10 16.07 5.40 Top Ugnu C 3,900.00 4.76 52.27 59.85 3,136.05 3.10 16.07 5.40 4,000.00 5.77 53.54 58.55 3,196.38 3.32 16.67 5.98 4,100.00 6.84 54.97 57.10 3,254.81 3.54 17.22 6.54 4,200.00 4.22 56.54 58.19 3,311.10 2.34 8.08 4.04 4,271.50 4.70 57.75 56.79 3,349.90 2.44 8.15 4.21 Top Ugnu B 4,300.00 4.70 58.24 56.79 3,365.01 2.44 8.15 4.21 4,400.00 5.19 60.06 55.26 3,416.29 2.56 8.23 4.35 4,500.00 5.68 61.99 53.60 3,464.74 2.68 8.31 4.45 4,504.61 6.18 62.08 51.82 3,466.90 2.80 8.41 4.53 Top Ugnu A 4,600.00 6.18 64.01 51.82 3,510.14 2.80 8.41 4.53 4,700.00 6.68 66.12 49.92 3,552.30 2.93 8.52 4.57 4,736.37 7.17 66.90 47.91 3,566.80 3.06 8.66 '4.58 TopN 4,800.00 7.17 68.30 47.91 3,591.05 3.06 8.66 4.58 4,900.00 7.66 70.54 45.80 3,626.21 3.20 8.81 4.57 5,000.00 8.15 72.84 43.59 3,657.63 3.35 8.99 4.54 5,100.00 8.62 75.18 41.31 3,685.18 3.49 9.19 4.50 5,200.00 9.09 77.57 38.96 3,708.74 3.64 9.40 4.45 5,300.00 9.54 79.98 36.56 3,728.21 3.80 9.63 4.41 5,400.00 9.98 82.42 34.13 3,743.51 3.96 9.87 4.37 5,426.86 10.40 83.08 31.69 3,746.90 4.12 10.11 4.36 Top D 5,500.00 10.40 84.88 31.69 3,754.57 4.12 10.11 4.36 5,504.86 10.42 85.00 31.57 3,755.00 4.12 10.12 4.36 Start 4°1100'DLS,64.34°TF,for 65.78' 10/14/2015 4:00:01PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Hon.Error (usft) (usft) (°) (0) (usft) (usft) (usft) (usft) 5,570.64 10.15 86.14 30.75 3,760.08 4.23 10.63 4.40 Hold for 10.06' 5,580.70 10.15 86.14 30.67 3,760.76 4.25 10.65 4.42 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,600.00 10.25 86.41 30.32 3,762.01 4.28 10.65 4.43 5,700.00 10.77 87.81 28.17 3,767.05 4.44 10.73 4.52 5,800.00 11.28 89.23 26.01 3,769.63 4.60 10.80 4.63 5,854.71 11.56 90.00 24.83 3,770.00 4.69 10.83 4.69 Hold for 30'-7-5/8"x 9-718" 5,884.71 11.67 90.00 24.50 3,770.00 4.72 11.01 4.72 Start 3°l100'DLS,-87.9°TF,for 41.08' 1 5,900.00 11.73 90.02 24.10 3,770.00 4.72 11.05 4.72 5,925.79 11.83 90.05 23.41 3,769.98 4.72 11.12 4.72 Hold for 941.57' 6,000.00 11.84 90.05 21.33 3,769.93 4.74 11.70 4.74 6,100.00 11.84 90.05 18.40 3,769.85 4.79 12.61 4.79 6,200.00 11.84 90.05 15.39 3,769.77 4.87 13.66 4.87 6,300.00 11.85 90.05 12.41 3,769.69 4.98 14.80 4.97 6,400.00 11.85 90.05 9.52 3,769.61 5.10 16.02 5.10 6,500.00 11.85 90.05 6.81 3,769.53 5.25 17.30 5.25 6,600.00 11.85 90.05 4.31 3,769.45 5.43 18.63 5.43 6,700.00 11.86 90.05 2.04 3,769.37 5.62 20.01 5.62 6,800.00 11.86 90.05 179.99 3,769.30 5.82 21.41 5.82 6,867.35 11.86 90.05 178.74 3,769.24 5.97 22.37 5.97 Start 3°/100'DLS,90.03°TF,for 325.33' 6,900.00 11.60 90.04 178.22 3,769.22 6.05 22.95 6.04 7,000.00 10.79 90.04 176.96 3,769.14 6.28 24.62 6.28 7,100.00 10.00 90.04 175.97 3,769.07 6.53 26.25 6.53 7,192.68 9.34 90.04 175.29 3,769.00 6.77 27.70 6.77 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 9.34 90.12 175.25 3,768.99 6.78 27.75 6.78 Hold for 933.72' 7,200.00 9.34 90.12 175.23 3,768.99 6.79 27.80 6.78 7,300.00 9.35 90.12 174.54 3,768.77 7.06 29.22 7.05 7,400.00 10.13 90.12 10.72 3,768.56 5.46 16.92 5.45 7,500.00 10.14 90.12 9.89 3,768.35 5.55 17.34 5.55 7,600.00 10.14 90.12 9.07 3,768.14 5.65 17.78 5.64 7,700.00 10.15 90.12 8.28 3,767.92 5.75 18.22 5.74 7,800.00 10.15 90.12 7.51 3,767.71 5.85 18.67 5.85 7,900.00 10.16 90.12 6.77 3,767.50 5.96 19.13 5.96 8,000.00 10.16 90.12 6.05 3,767.28 6.07 19.59 6.07 8,100.00 10.17 90.12 5.36 3,767.07 6.18 20.07 6.18 8,130.50 10.17 90.12 5.15 3,767.01 6.22 20.21 6.22 Start 2°/100'DLS,178.72°TF,for 3.65' 10/142015 4:00:01PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (°) (usft) (usft) (usft) (usft) 8,134.15 10.16 90.05 5.14 3,767.00 6.22 20.22 6.22 Adjust TF to-90°,for 1.34' 8,135.49 10.17 90.05 5.14 3,767.00 6.23 20.23 6.22 Hold for 1164.76' 8,200.00 10.17 90.05 4.81 3,766.94 6.30 20.49 6.30 8,300.00 10.18 90.05 4.17 3,766.86 6.42 20.97 6.42 8,400.00 10.18 90.05 3.55 3,766.77 6.55 21.45 6.54 8,500.00 10.19 90.05 2.97 3,766.69 6.67 21.95 6.67 8,600.00 10.19 90.05 2.41 3,766.60 6.80 22.44 6.80 8,700.00 10.20 90.05 1.87 3,766.51 6.93 22.94 6.93 8,800.00 10.20 90.05 1.35 3,766.43 7.06 23.45 7.06 8,900.00 10.21 90.05 0.86 3,766.34 7.20 23.96 7.19 9,000.00 10.21 90.05 0.39 3,766.26 7.33 24.47 7.33 9,100.00 10.22 90.05 179.95 3,766.17 7.47 24.99 7.47 9,200.00 10.22 90.05 179.52 3,766.09 7.61 25.51 7.61 9,300.00 10.23 90.05 179.11 3,766.00 7.75 26.03 7.75 9,300.25 10.23 90.05 179.11 3,766.00 7.75 26.03 7.75 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 10.18 90.09 179.08 3,765.99 7.77 26.10 7.76 Hold for 1301.75' 9,400.00 10.18 90.09 178.79 3,765.85 7.89 26.51 7.89 9,500.00 10.19 90.09 178.42 3,765.70 8.04 27.04 8.04 9,600.00 10.19 90.09 178.06 3,765.55 8.18 27.57 8.18 9,700.00 10.20 90.09 177.72 3,765.39 8.33 28.10 8.33 9,800.00 10.20 90.09 177.40 3,765.24 8.48 28.63 8.48 9,900.00 10.21 90.09 177.09 3,765.09 8.63 29.16 8.63 10,000.00 10.22 90.09 176.79 3,764.93 8.78 29.70 8.78 10,100.00 10.22 90.09 176.51 3,764.78 8.93 30.24 8.93 10,200.00 10.23 90.09 176.23 3,764.63 9.08 30.78 9.08 10,300.00 10.23 90.09 175.97 3,764.48 9.24 31.32 9.24 10,400.00 10.24 90.09 175.72 3,764.32 9.39 31.87 9.39 10,500.00 10.24 90.09 175.48 3,764.17 9.55 32.41 9.55 10,600.00 10.25 90.09 175.25 3,764.02 9.70 32.96 9.70 10,612.09 10.25 90.09 175.22 3,764.00 9.72 33.03 9.72 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,700.00 10.38 91.81 175.03 3,762.54 9.86 33.48 9.83 10,712.06 10.40 92.05 175.00 3,762.13 9.88 33.54 9.84 Hold for 963.02' 10,800.00 10.40 92.05 174.81 3,758.99 10.02 34.02 9.98 10,900.00 10.41 92.05 174.60 3,755.41 10.18 34.57 10.14 11,000.00 10.42 92.05 174.40 3,751.83 10.34 35.12 10.30 11,100.00 10.42 92.05 174.21 3,748.25 10.49 35.67 10.46 11,200.00 10.43 92.05 174.02 3,744.67 10.65 36.23 10.62 11,300.00 10.43 92.05 173.84 3,741.09 10.82 36.78 10.78 11,400.00 10.44 92.05 173.67 3,737.51 10.98 37.34 10.94 I 10/14/2015 4:00:01PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 11,500.00 10.45 92.05 173.50 3,733.93 11.14 37.90 11.11 11,600.00 10.45 92.05 173.34 3,730.35 11.30 38.46 11.27 11,675.08 10.46 92.05 173.22 3,727.67 11.42 38.88 11.39 Start 2°/100'DLS,90.05°TF,for 46.57' 11,700.00 10.30 92.05 173.19 3,726.77 11.46 39.03 11.43 11,721.65 10.17 92.05 173.18 3,726.00 11.50 39.15 11.47 Adjust TF to 180°,for 137.89' 11,800.00 10.15 90.48 173.17 3,724.27 11.63 39.35 11.62 11,859.54 10.13 89.29 173.19 3,724.39 11.73 39.44 11.74 Hold for 859.36' 11,900.00 10.13 89.29 173.16 3,724.88 11.79 39.58 11.80 12,000.00 10.14 89.29 173.03 3,726.12 11.96 40.14 11.97 12,100.00 10.15 89.29 172.90 3,727.36 12.12 40.70 12.13 12,200.00 10.15 89.29 172.77 3,728.59 12.29 41.26 12.30 12,300.00 10.16 89.29 172.65 3,729.83 12.45 41.82 12.46 12,400.00 10.17 89.29 172.53 3,731.06 12.62 42.38 12.63 12,500.00 10.18 89.29 172.42 3,732.30 12.78 42.94 12.79 12,600.00 10.18 89.29 172.31 3,733.53 12.95 43.51 12.96 12,700.00 10.19 89.29 172.20 3,734.77 13.12 44.07 13.13 12,718.90 10.19 89.29 172.18 3,735.00 13.15 44.18 13.16 TD:12718.9'MD,3832.1'ND 10/14/2015 4:00:01PM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/14/2015 4:00:01 PM Page 8 COMPASS 5000.1 Build 74 • Schlumberger 0 Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 1 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") .4:':,`,^ .'' 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (`) (1 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/14/2015 4:00:01 PM Page 9 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') (") ' 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/14/2015 4:00:01PM Page 10 COMPASS 5000.1 Build 74 • Schlumberger S Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C') 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (') . ,, 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +FJ-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'TVD r 10/142015 4:00:01 PM Page 11 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top 0 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'ND '10/142015 4:00:01PM Page 12 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan:1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C.) 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'TVD 10/142015 4:00:01PM Page 13 COMPASS 5000.1 Build 74 iSchlumberger III Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit ND Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 ri"lan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.50/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 30/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD: 12718.9'MD,3832.1'ND 4.r 10/142015 4:00:01PM Page 14 COMPASS 5000.1 Build 74 • Schlumberger i Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C') 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) a ,u. 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'TVD 10/14/2015 4:00:01 PM Page 15 COMPASS 5000.1 Build 74 • Schlumberger i Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction �y (usft) (usft) Name Lithology (0) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS,178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TD:12718.9'MD,3832.1'TVD r 10/142015 4:00:01PM Page 16 COMPASS 5000.1 Build 74 • Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan: 1C-154 North Reference: True Wellbore: Plan: 1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter _v'4 (usft) (usft) Name (") (") 119.50 119.50 20"x 42" 20 42 2,628.07 2,403.20 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,854.71 3,867.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,718.90 3,832.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (0) 2,126.32 2,028.20 T3 0.00 5,426.86 3,844.00 Top D 0.00 4,504.61 3,564.00 Top Ugnu A 0.00 3,869.97 3,214.70 Top Ugnu C 0.00 1,854.11 1,793.00 Pfrost 0.00 4,271.50 3,447.00 Top Ugnu B 0.00 2,492.79 2,310.80 K15 0.00 4,736.37 3,663.90 Top N 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,35°TF,for 300.31' 600.31 600.00 9.67 6.77 Start 2°/100'DLS,20°TF,for 302.67' 902.98 900.00 38.23 33.44 Adjust TF to 25°,for 902.51' 1,805.49 1,750.00 191.72 281.92 Hold for 113.06' 1,918.55 1,850.00 215.82 328.86 Start 3°/100'DLS,-9.13°TF,for 701.79' 2,620.34 2,398.10 430.89 703.45 Hold for 6.93' 2,627.27 2,402.67 433.61 707.88 Start 3°/100'DLS,0.53°TF,for 0.81' 2,628.07 2,403.20 433.93 708.40 Hold for 20' 2,648.07 2,416.39 441.79 721.21 Start 3.75°/100'DLS,91.69°TF,for 109.63' 2,757.70 2,488.73 481.45 793.38 Hold for 656.57' 3,414.28 2,921.74 698.28 1,236.75 Start 3.75°/100'DLS,-86.46°TF,for 2090.58' 5,504.86 3,852.10 2,308.76 1,756.92 Start 4°/100'DLS,64.34°TF,for 65.78' 5,570.64 3,857.18 2,372.45 1,741.26 Hold for 10.06' 5,580.70 3,857.86 2,382.24 1,739.07 Start 4°/100'DLS,-69.63°TF,for 274.01' 5,854.71 3,867.10 2,642.64 1,655.65 Hold for 30' 5,884.71 3,867.10 2,670.28 1,643.98 Start 3°/100'DLS,-87.9°TF,for 41.08' 5,925.79 3,867.08 2,707.95 1,627.60 Hold for 941.57' 6,867.35 3,866.34 3,567.30 1,242.81 Start 3°/100'DLS,90.03°TF,for 325.33' 7,192.68 3,866.10 3,874.08 1,135.72 Start 2°/100'DLS,0°TF,for 4.1' 7,196.79 3,866.09 3,878.06 1,134.71 Hold for 933.72' 8,130.50 3,864.11 4,782.59 903.11 Start 2°/100'DLS, 178.72°TF,for 3.65' 8,134.15 3,864.10 4,786.12 902.20 Adjust TF to-90°,for 1.34' 8,135.49 3,864.10 4,787.42 901.87 Hold for 1164.76' 9,300.25 3,863.10 5,915.65 612.46 Start 2°/100'DLS,79.04°TF,for 10.09' 9,310.34 3,863.09 5,925.43 609.97 Hold for 1301.75' 10,612.09 3,861.10 7,187.47 290.89 Start 2°/100'DLS,-10.87°TF,for 99.98' 10,712.06 3,859.23 7,284.29 266.07 Hold for 963.02' 11,675.08 3,824.77 8,215.76 24.03 Start 2°/100'DLS,90.05°TF,for 46.57' 11,721.65 3,823.10 8,260.90 12.69 Adjust TF to 180°,for 137.89' 11,859.54 3,821.49 8,394.88 -19.80 Hold for 859.36' 12,718.90 3,832.10 9,229.96 -222.36 TO:12718.9'MD,3832.1'WD r 10/14/2015 4:00:01PM Page 17 COMPASS 5000.1 Build 74 REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRBgJAH Rev. Per K150013ACS LEGEND I - \HIC 2 4: • EXISTING CONDUCTOR -ARUK p1161R�1 Lip TI 1 ON O AS-BUILT CONDUCTOR THIS SURVEY K,- SWPT axial B y GRAPHIC SCALES CPF1 = C 0 100 200 400 9`� S;CI Id \ 12 • PITiiiiii A%iF, 11 1 inch = 200 ft. C 11+12 V rAO7. 10 16 15 14 13 f ,, ,_ iD�� ‹---. ... N ry • .CO "� .S • Ary Dk • ,gyp o� • \� • �4" • � �' • • 0 ,�� ry 40' • • •Nry^3 • • •rya • •\ 2 • ryC '''�83' ' 30' SEE SHEETS 2 & 3 FOR NOTES AND 0,c, LOCATION INFORMATION. 6/ 70 voimiiiiiiiii. ' OFq/ '�,`i `'<P�� S'♦1.1 SURVEYOR'S CERTIFICATE i �' .' a ' a 9th "N * • I HEREBY CERTIFY THAT I AM PROPERLY REGISTERD AND LICENSED $ ,- j.1 TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND 0 • THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER �JEREMIAH F. CORNELL.� o• MY DIRECT SUPERVISION AND THAT ALL NEW DIMENSIONS AND #1 s =. LS-12663 :' �`,o OTHER DETAILS PER THIS REVISION .e'Fp'••.,, :'���Ai ARE CORRECT AS OF JULY 16, 2015. LOUNSBURY ♦ b v- /...G(.�.-PO�♦` SURVEYORS& ASSOCIATis INC.PLANNERS `.i AREA:1C MODULE: XXXX UNIT: Dl ConocoPhilli sDS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. I PART: REV: LK6103d31 6/30/01 CEA-D1 CX-6103D31 1 OF 3 I 13 REV DATE BY CK APP • DESCRIPTION REV DATE BY K APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12, T11N, R1OE NAD27 NAD27 Section WELLASP Coordinates Geographic Coordinates Offset Elev. No. 'Y' 'X' LATITUDE LONGITUDE F.N.L F.W.L PAD 0.G. 1 5,968,523.00 562,372.00 N 70'19'28.291" W 14929'39.295" 1,717' 1,363' N/A N/A 2 5,968,590.00 562,271.00 N 7019'28.958" W 149'29'42.227" 1,649' 1,263' N/A N/A 3 5,968,656.00 562,172.00 N 70'19'29.615" W 149'29'45.100" 1,582' 1,164' N/A N/A 4 5,968,727.00 562,065.00 N 70'19'30.322" W 149'29'48.207" 1,510' 1,058' N/A N/A 5 5,968,793.00 561,965.00 N 70'19'30.979" W 14929'51.110" 1,442' 958' N/A N/A 6 5,968,860.00 561,864.00 N 7019'31.647" W 149'29'54.042" 1,375' 859' N/A N/A 7 5,968,926.00 561,765.00 N 7019'32.304" W 149'29'56.916" 1,308' 760' N/A N/A 8 5,968,993.00 561,664.00 N 7019'32.971" W 149'29'59.848" 1,240' 660' N/A N/A 9 5,968,851.99 561,548.05 N 70°19'31.593" W 149'30'03.267" 1,381' 542' N/A N/A 10 5,968,763.33 561,680.92 N 70'19'30.711" W 149'29'59.409" 1,471' 674' N/A N/A 11 5,969,008.74 561,641.06 N 70'19'33.128" W 149'30'00.514" 1,225' 637' 60.4' 55.0' 12 5,969,000.20 561,653.40 N 70'19'33.043" W 149'30'00.156" 1,234' 649' 60.4' 55.1' 13 5,968,842.13 561,891.29 N 70'19'31.469" W 149'29'53.250" 1,394' 885' 60.4' 55.0' 14 5,968,672.21 562,146.39 N 70'19'29.777" W 14929'45.844" 1,566' 1,139' 60.4' 55.0' 15 5,968,605.15 562,247.15 N 70°19'29.109" W 14929'42.919" 1,634' 1239' 60.3' 55.0' 16 5,968,825.37 561,916.31 N 7019'31.302" W 149'29'52.523" 1,411' 910' 60.3' 55.0' 17 5,968,838.00 561,568.78 N 7019'31.454" W 149'30'02.665" 1,395' 563' 60.5' 56.2' 18 5,968,758.80 562,016.22 N 70'19'30.639" W 14929'49.623" 1,478' 1,010' 60.4' 55.0' 19 5,968,624.28 562,368.18 N 7019'29.287" W 149'29'39.382" 1,616' 1,360' 59.1' 52.3' 20 5,968,622.03 562,222.10 N 70'19'29.277" W 149'29'43.646" 1,601' 1,191' 60.3' 55.0' 21 5,968,637.75 562,198.12 N 70'19'29.434" W 149'29'44.342" 1,617' 1,214' 60.6' 55.0' 22 5,968,646.48 562,334.93 N 7019'29.508" W 149'29'40.347" 1,593' 1,327' 59.1' 51.6' 23 5,968,579.61 562,285.45 N 70'19'28.855" W 149'29'41.807" 1,660' 1,277' 60.3' 55.2' 24 5,968,571.44 562,297.94 N 70'19'28.773" W 149'29'41.445" 1,668' 1,290' 60.3' 55.2' 25 5,968,546.47 562,335.47 N 70'19'28.525" W 149°29'40.355" 1,693' 1,327' 60.2' 55.0' 26 5,968,538.05 562,347.93 N 70'19'28.441" W 149'29'39.994" 1,702' 1,339' 60.2' 55.0' 27 5,968,529.79 562,360.58 N 70'19'28.358" W 149°29'39.626" 1,710' 1,352' 60.2' 55.0' 28 5,968,689.43 562,121.21 N 7019'29.948" W 149'29'46.575" 1,548' 1,114' 60.6' 55.0' 101 5,968,821.46 561,593.72 N 70'19'31.289" W 149'30'01.941" 1,412' 588' 60.6' 56.7' NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS1C MONUMENTATION LOUNSBURY PER LOUNSBURY & ASSOCIATES. & ASSOCIATES, INC. 2. COORDINATES SHOWN ARE ASP, ZONE 4, NAD27 SURVEYORS ENGINEERS PLANNERS 3. ELEVATIONS ARE BPMSL 1PV • AREA:1C MODULE: XXXX UNIT: D1 ConocoPhiIlipsDS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6103d31 6/30/01 CEA-D1 CX-6103D31 2 OF 3 13 REV DATE BY CK APP • DESCRIPTION REV, DATE BY CK APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12, T11N, R1OE NAD27 NAD27 Section WELLASP Coordinates Geographic Coordinates Offset Elev. No. 'Y' 'X' LATITUDE LONGITUDE F.N.L F.W.L PAD O.G. 102 5,968,813.50 561,606.18 N 70'19'31.210" W 149'30'01.579" 1,420' 600' 60.6' 56.7' 1045,968,796.65 561,631.04 N 70'19'31.042" W 149'30'00.857" 1,437' 625' 60.6' 56.7' 106 !ItCPA!Coordinate Converter I c:' ( 2`' 16.7' 109 From: _ To: 16.6' 111 Datum: NAD27 . Region: ,alaska .! Datum: jNAD83 ., Region: alaska 16 .5' 113 �� 16.5' I Latitude/Longitude 'Decimal Degrees L 1 C Latitude/Longitude 'Decimal Degrees • 115 6.4' 117 r UTM Zone: 1 f-' South r UTM Zone: True E South 6.3' 119 - State Plane Zone: 14 Units: 1us_ft A f: State Plane Zone:F4c-.i Units: Ius_ft „I 6.2' 121Legal Description(NAD27 only) 1 C Legal Description(NAD27 only) 6.1' 123 J 5.9' 125 Starting Coordinates: _ Ending Coordinates: 5.8' X: 1562168.4 X: 1 1702200.31862528 127 5.7' Y: 15968757.31 Y: 15968509.06820361 129 5.6' 131 5.5' 133 5.4' 135 5.5' 1 150 Transform Quit I Help 1 12.5 151 ` ,5.0' *152* 5,968,956.10 561,869.93 N 70'19'32.591" W 149'29'53.846" 1,279' 865' 57.6' 55.0' *153* 5,968,939.48 561,894.98 N 7019'32.426" W 149'29'53.118" 1,296' 890' 57.6' 55.0' *154* 5,968,757.31 562,168.40 N 70'19'30.612" W 14929'45.181" 1,481' 1,162' 57.6' 53.2' *155* 5,968,690.68 562,268.34 N 70'19'29.948" W 149'29'42.280" 1,548' 1,261' 57.6' 52.2' 170 5,968,823.66 562,068.55 N 7019'31.273" W 14929'48.080" 1,414' 1,063' 59.1' 54.1' 172 5,968,801.43 562,101.96 N 70'19'31.051" W 149'29'47.110" 1,436' 1,096' 59.1' 53.8' 174 5,968,779.41 562,135.06 N 70'19'30.832" W 149'29'46.149" 1,458' 1,129' 59.2' 53.5' 178 5,968,735.16 562,201.72 N 7019'30.391" W 149'29'44.214" 1,503' 1,195' 59.2' 52.9' 184 5,968,668.66 562,301.70 N 70'19'29.729" W 149'29'41.311" 1,571' 1,294' 59.1' 51.8' 190 5,968,602.07 562,401.26 N 70'19'29.066" W 149'29'38.421" 1,638' 1,393' 59.1' 51.5' ** ASBUILT CONDUCTOR THIS SURVEY 0. LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS no `V AREA:1C MODULE: XXXX UNIT: D1 ConocoPhillipsDS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6103d31 6/30/01 CEA-D1 CX-6103D31 3 OF 3 13 • • Schlumberger ce ADG well cementing recommendation for 10 314"Surface Operator : CPA! Well : 1CG154 Country : USA Held : Kuparuk State :Alaska Prepared for : Kelsey Hallford Location : Kuparuk Proposal Na : v3 Service Point : Prudhoe Bay Date Prepared : 10.15.15 Business Phone : (907)659-2434 FAX Na Prepared by : Eric Hanrin Phone : (812)243-0650 E-Mail Address : ehannum&l b can Q 0ATE Disclaimer Notice: Schlurbergersr6ritsthis docuretwith the benefit a itsird4rert,eperieroe,and good of fieldpaceces. This informabmispmided in accordance with generally accertedircFatry practice,relying onfacts or irfanation praidedby others,(irritations,carpternodels,neasteeirects,assume award interencesthatare nd infallible. ailculatiors are estinntes based m provided htanation All proposals,iecarnrendatims,cc predctiorsare opinions only. NOYWISRAMy1SGIVEN CCNCERINGACCURACYCRCCMRE7BJBSCF DATA,INFOFMA71CN PRESENTED,EPFECIIVBit5SCFMA1BIAl,WZOUCBQiSIFRIES,'WMMENDAIKNS MADE,ORF6rU7SOFWESBM($ Reednnharninfringement Barty irtellechal property rights CSdiurberger or others is not to be keened and no intellectual property dgltsare grated hereby. *Mart of Schlurterger Page 1 1c-154 cement v cfw;1415-2)15; lnedC:meSmfacewitrete;Versionwcs•cern175 01 01111 • LL Client : CPAI Well : 10-154 � i11iieri�jer String : 10314 District : Prudhoe Bay �i� Country : USA Loadcase : Surface w/crete Section 1: Well Description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2633.0 ft BHST : 51 degF Bit Size : 13 1/2 in ft (x 1000) psi J I 0 Frac 1 2 • 1---Pore ti Base , er'atrost • • • • • • . • • TD • • Well LithoIog_; Formation Press_ Page 2 1x154 remelt v1.dw;1615-2015; Lead(ase Mace wl crete;Version wcs-cemt75 01 III • Client : CPAI Well : 1C-154 Schlumberger be ger String : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 119.5 20 106.5 19.000 Landing Collar MD : 2548.0 ft Casing/liner Shoe MD : 2628.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2628.0 10 3/4 40.0 45.5 9.950 L-80 2090 3580 Hydril 563 Mean OH Diameter : 13.500 in Mean Annular Excess : 188.3 % Mean OH Equivalent Diameter: 17.538 in Total OH Volume : 751.0 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 1854.0 13.500 250.0 18.681 2628.0 13.500 50.0 14.683 2633.0 13.500 0.0 13.500 Max. Deviation Angle : 44 deg Max. DLS : 3.605 deg/100ft Hetet' to Appendix 1 for complete chtectloria/survey Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1874.0 12.50 8.30 Base permafrost Sandstone 2981.0 12.50 8.30 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1874.0 1791.1 32 0.7 2981.0 2615.0 60 1.5 Page 3 1c-154 cement vl.dw;10.15-M5; L oadCase 9.face wl crate;Version wcs-cenr1/5 01 • • Oient : CPA Well : 1C-154 Schimberg!' String : 103+4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Section 2: Fluid Descriptions Mud DESIGN Fluid No: 1 Density : 9.30 lb/gal Rheo. Model : HERSCHEL_B. k :4.64E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.732 Tr : 1.72lbf/100ft2 Gel Strength : 7.47 lbf/100ft2 Mt) Mud Type :WBM Job volume :235.1 bbl Water Type : Fresh VOLUME FRACTION Solids : 8.5% Oil : 2.0% Water : 89.5 Rheometric Measurements Rheometer type : 35 (rpm) At 80 degF Geometry : R1 B1 (deg) Spring No : 1.0 600 72.0 300 44.0 200 33.0 100 21.0 6 4.0 3 3.0 Viscosity: (cP) 10 sec Gel Strength 4.27 Ibf/100ft2 10 min Gel Strength 7.47 Ibf/100ft2 Page 4 1c-154cenert ric w;10.15,1015; Lcerrase 9lrface w/crete;Version wcscen475 01 • S cent : mai Well : 1C-154 �icrlllumb�i�g i� string : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete MUDPUSH II DESIGN Fluid No: 2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :2.22E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.431 Tv : 10.20 lbf/100ft2 Gel Strength : 17.08 Ibf/100ft2 SPACER Spacer Type : MUDPUSH II Porosity : 90.9% Solid Fraction :9.1 % Mud Type :WBM Mix Water/Spacer(vol.): 90.9% Job volume : 75.0 bbl BASE FLUID Type : Fresh water Density : 8.32 lb/gal Weighting Agent(s) Code Conc. Density D031 116.93 lb/bbl of spacer 270.31 lb/ft3 () (Ib/ft3) Additives Code Conc. Function D020 0.000 lb/bbl of base fluid Extender D182 7.000 lb/bbl of base fluid Turb. Spacer Rheometric Measirements Rheometer type : 35 (rpm) At 65 degF Geometry : R1 B1 (deg) Spring No : 1.0 300 42.0 200 36.5 100 29.5 60 26.5 30 23.0 6 16.5 3 13.9 Viscosity: (cP) 10 sec Gel Strength 14.94 Ibf/100ft2 10 min Gel Strength 17.08 Ibf/100ft2 Page 5 1c-154cenertvtcfw;10-154315; L adCasesafacew+crete;Versionwcscem 75 of • S aient : CPAI Well : 1G154 Sotto boiler String : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete CW100 DEIGN Fluid No: 3 Density :8.33 lb/gal Rheo. Model : NEWTONIAN At temp. : (degF) Viscosity : 5.000 cP Gel Strength : (Ibf/100ft2) WASH Wash Type : CW100 Water/Wash(vol.): 98.2% Job volume : 75.0 bbl Mud Type :WBM BASE FLUID Type : CW100 Density : 8.32 lb/gal Additives Code Conc. Function D122A 0.500 gal/bbl of wash Chem wash co J237A 0.250 gal/bbl of wash Fluid loss Pages 1c-154 cement vl.ciw;10.15.2015; toads se Suface wl trete;Version wcscen 475 01 • i A Client : CPAI Well : 1C-154 Sahi{11111�'ber eh String : 103/4 District : Prudhoe Bay Y(f {� Country : USA Loadcase : Surface w/crete Surface Tail DeepCRETESIt.rry DESIGN Fluid No:4 Density : 12.00 lb/gal Rheo. Model : HERSCHEL_B. k : 1.25E-2 Ibf.s^n/ft2 At temp. : 76 degF n : 0.798 Tr : 10.93Ibf/100ft2 Gel Strength : 21.38 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.0(0.80) Mix Fluid : 5.482 gal/sk Job volume : 56.3 bbl Dry Density : 112.29 lb/ft3 Yield : 1.63 ft3/sk Quantity : 194.40 sk Sack Weight : 100 lb Solid Fraction : 54.9% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.392 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D185 0.060 gal/sk blend Dispers. LT D186 0.030 gal/sk blend Accelerator Rheorr etric Measurements Rheometer type : 35 (rpm) At 76 degF Geometry : R1B5 (deg) Spring No : 1.0 300 101.0 200 75.0 100 49.0 60 35.0 30 25.5 6 14.5 3 10.0 Viscosity: (cP) 10 sec Gel Strength 16.63 Ibf/100ft2 10 min Gel Strength 21.38 Ibf/100ft2 Page 7 1c-154cenert vt.cfw;10.15.7015; LoadCase 9rface w/crete;Version wcs-cemt75 Q1 • • Client : CPAI Well : 1C-154 Schlumberger String : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Fresh Water DESIGN Fluid No: 6 Density : 8.32 lb/gal Rheo. Model : NEWTONIAN At temp. : (degF) Viscosity :5.000 cP Gel Strength : (lbf/100ft2) WASH Wash Type :Water Water/Wash(vol.): 100.0% Job volume : 10.0 bbl Mud Type :WBM BASE FLUID Type : Fresh water Density : 8.32 lb/gal Page 8 1c-154 caned vtcfw;1015.4315; Loadcase Surface w/crete;Version wcs-cen475 01 • S Client : CPAI Well : 1C-154 Schlumberger String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete llppg DeepCRETE Lead DESIGN Fluid No: 7 Density : 11.00 lb/gal Rheo. Model : HERSCHEL_B. k : 1.65E-3lbf.sAn/ft2 At temp. : 76 degF n : 1.049 Ty :21.51 lbf/100ft2 Gel Strength :22.57 lbf/100ft2 DESIGN BLEND SLURRY Name : 11.0 B439-54 Mix Fluid : 6.827 gal/sk Job volume : 448.4 bbl Dry Density : 100.63 lb/ft3 Yield : 1.91 ft3/sk Quantity : 1319.12 sk Sack Weight : 100 lb Solid Fraction : 52.2% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :6.737 gal/sk Additives Code Conc. Function D046 0.200%BWOB Antifoam D185 0.070 gal/sk blend Dispers. LT D177 0.020 gal/sk blend Retarder Rheumatic Measurements Rheometer type : 35 (rpm) At 76 degF Geometry : R1B5 (deg) Spring No : 1.0 300 68.0 200 48.5 100 36.5 60 29.0 30 25.0 6 17.5 3 13.5 Viscosity: (cP) 10 sec Gel Strength 17.81 lbf/100ft2 10 min Gel Strength 22.57 lbf/100ft2 Page 9 1c-154cemera vl.dw;1615-7D15; toad(ase Surface w/crete;Version wcscen#75 01 III 411 client : (PAI Well : 1C154 Schlumberger String : 1034 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Section 3: Ruid Sequence Original fluid Mud 9.30 lb/gal k:4.64E-3 Ibf.s^n/ft2 n :0.732 Ty: 1.72 Ibf/100ft2 Displacement Volume 245.1 bbl Total Volume 899.7 bbl TOC 0.0 ft Ruid Sequence Name Volume Ann.Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) CW100 75.0 0.0 8.33 viscosity:5.000 cP MUDPUSH II 75.0 0.0 10.50 k:2.22E-2 Ibf.s^n/ft2 n:0.431 Ty:10.20 lbf/100ft2 11ppg DeepCRETE 448.4 2128.0 0.0 11.00 k:1.65E-3 Ibf.s^n/ft2 n:1.049 Ty:21.51 Ibf/100ft2 Lead Surface Tail 56.3 500.0 2128.0 12.00 k:1.25E-2 Ibf.s^n/t2 n:0.798 Ty:10.93 Ibf/100ft2 DeepCRETE Slurry Fresh Water 10.0 2444.0 8.32 viscosity:5.000 cP Mud 235.1 0.0 9.30 k:4.64E-3lbf.s^n/ft2 n:0.732 Ty:1.72 lbf/100ft2 Static Security Checks: Frac 9 psi at 119.5 ft Pore 17 psi at 119.5 ft Collapse 1784 psi at 2548.0 ft Burst 3580 psi at 0.0 ft Csg.Pump out 36 ton Check Valve Diff Press 223 psi ft (x 1000)psi i i1 2 1 rv-:,,,5ta1c Fray -Pore - • •O O O- O O J O O O C.,- Fluid Sequence Static Well Security Page 10 1c-154cerrert vl.crw;10.15.7015; loadcase Surface wi crete;version wcscern$75 01 • Client : (PAI Well : 1C-154 Schlumberger String : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface WI crete Section 4: Pumping Schedule Jou ogecuve:bang cement to surrace. i o mitigate potential cement fallback,please slow puffy rate to-3 bpm when lead cement is seen at surface and slow rate to 1 bpm for the last 10 bbl of displacement to bump the plug.This pump schedule shcw'c r.,l.,1(!) t 7 hrlttl,but this ran ir,rrn/cp rer ti rroacc,=. ,:,,r,in the field. Pimping Schedule Name Flow Volume Stage Cum.Vol lnj. Comments Rate (bbl) Time (bbl). Temp. (bbl/min) (min) (degF) CW100 7.0 75.0 10.7 75.0 80 Pump CW100 MUDPUSH II 7.0 75.0 10.7 75.0 80 Pump MUDPUSH II Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug 11ppg 7.0 448.4 64.1 448.4 80 Pump lead slurry DeepCRETE Lead Surface Tail 7.0 56.3 8.0 56.3 80 Pump tail slurry DeepCRETE Slurry Pause 0.0 0.0 5.0 0.0 80 Drop top plug Fresh Water 7.0 10.0 1.4 10.0 80 Kick out plug Pause 0.0 0.0 5.0 0.0 80 Swap to rig Mud 8.0 225.1 28.1 225.1 80 Displacement Mud 3.0 10.0 3.3 235.1 80 Displacement Total 02:21 899.7 bbl hr:mn Dyna117c Security Checks: Frac 8 psi at 119.5 ft Pore 0 psi at 119.5 ft Collapse 1783 psi at 2548.0 ft Burst 3314 psi at 0.0 ft Temperature Restdts BHCT 65 degF Simulated Max HCT 74 degF Simulated BHCT 73 degF Max HCT Depth 2628.0 ft CT at TOC 69 degF Max HCT Time 02:10:29 hr:mn:sc Static temperatures: At Time (hr:mn) 50:00 hr:mn Geo.Temp. Top of Cement (degF) 34 degF 20 degF Bottom Hole (degF) 52 degF 51 degF Page 11 1c-154 cement v1.cfw;1015.2015; lnedeem SUtace w/Crete;Version wcs.cem475 01 S S y aient : CPAI Well : 1C- 4 b154 ef String : 103'4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Simulated pressures and Rates duri ng Pl acenlent 0 o Calc.Cerci-ii= 'yCala.Pump Press. aAcquired Pressure N H O. I I .__. iLfo....„...00..1..„ 0 25 50 75 100 125 150 Time (min) _ Fluids at 2628 ft o ------- C•- —Acquired Q Out 1 E —Acquired Op i _ i ,, 1.--- Q Out J .1 0 QIn ea F f cal 14 7 Ij Z. 50 75 100 1'25 1-:0 Time (min) 0- 0 —CaIC.Cent-P CO r-Cele.Pune Ress. Acquired Pressure `n▪0 a0- w f 2 CL ‘gF4-/...‘`......... 7 CO O 1 0 100 200 300 400 500 600 700 800 900 1000 Pumped Volume(bbl) O Fluids at 2628 ft Q out I �. �Qh Acquired aINA I I N O Al CL I W I 1 0 100 200 300 400 500 600 700 800 900 1000 Pumped Volume(bbl) Page 12 1c-154 cement v l.cfw;10.152015; LnedCese Surface w!trete;Version wcscemt75 01 • • aient : CPAI Well : 1C-154 Schlumberger String : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Simulated ECD at shoe during Placement Depth= 2628 ft ri Frac Pore Hydrostatic Dynamic O � N' r f6 p C • r -Q r N to cn re7"°°°°°°°"......"..../S"""14..."1"711 ^L LL O- C ct 0 25 50 75 100 125 150 Time(min) Page 13 1c-154 camera vtcfw;10.15- 15; LoadCaseSlrfacew/crate;Version wcscerr147501 • S aient : CPAI Well : 1C-154 Schlumberger String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w!crete Simulated ECD at previous casing shoe during placement Depth= 119 ft oo rac Pore Hydrostatic r- Dynamic N ti- c) N CO- 7 a o LM 0 m :1, 0 25 50 75 100 125 150 Time(min) Page 14 10-154 cement vl.cfw;1615-7015; Loadcase Surface wI crete;version wcscern175 of • • Client : CPAI Well : 1C-154 Schlumberger String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Simulated slurry temperature during and up to 24 hours after placement o °O 1 Last Sack Terrp. First Sack Temp. co -N d M O ..... \I/o 2 4= 0) U 0) 43 Q Ct-M -co co 0 co -o r` La N 0 500 1000 1500 2000 2500 3000 3500 Time(min) Page 15 lc-154 cement vl.crw;1615-2015; Loadcase Surace w/crete;version wcs-cem175 01 • • 4 Client : CPAI Well : 1G154 Schlumberger String : 103/4 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Section 5: Centralizer Placement Top of centralization :0.0 ft Bottom Cent. MD :2618.0 ft Casing Shoe :2628.0 ft NB of Cent. Used :67 NB of Floating Cent. :67 Centralizer Placement Bottom MD Nbr. Cent./ Cent.Name Code Min.STO @ Depth (ft) Joint (%) (ft) 2548.0 63 1/1 S1103610-10 3/4-6-36(3/16") 27.9 1868.0 2628.0 4 2/1 S1103610-10 3/4-6-36(3/16") 84.8 2558.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) S1103610-10 3/4-6- 10 3/4 14.500 11.874 No Houma 13.500 447.37 1548.93 36(3/16") (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Centralizer performance data is based on information provided by BP ft 2r 1 75 100 -1At Cart. rt: ri c: T„JIa MA, Cement SOR Page 16 1c-154cement vl.cfw;1415-3115; lnadC.ase&+face w/crete;Version wcscem475 01 III • aient : CPAI Well : 1C-154 Schlumberger String : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface vv/Crete Section 6: WA N II Simulator % ft 25 50 75 100 0 50 100 o— -Std Betw Cent. Mud Contamnaton -Cement Coverage Uncontaminated Slurry `- O O O- 1 O 0 o- N O o 0-• Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall aJ 0 4 -a 500- 500 500- -500' 1D00- 1 000 : = 00 1D06- -16 r • r s - - r a 1500- 1SOD i s 1566- -1500 i ca CI 0 0 1006- 2000 1000- -2000 rsa6 250D 25a0- -2500 4 a 43 a o -.0 0 4 3 4 En Mud I I High I 1 Low Fresh Water I-1 Medium I I None Mill Surface Tail DeepCRETE Slurry I J 11 ppg DeepCRETE Lead I I MUDPUSH II I I CW100 Page 17 to154 cement vt.cfw;10-15.3115; LoadCase Suface wl crete;von wcscemg75 01 i i Client : CPAI Well : 1C-154 Schi 111 merger String : 10314 District : Prudhoe Bay u]�� Country : USA Loadcase : Surface w/Crete Tolerances - Spacer Max Rate is 7 BPM - Cement rate 6-7 BPM (remain within +/-0.2ppg Density Range, to be checked periodically with a mud balance) - Max displacement Rate is 8 BPM - Min Displacement Rate to be determined based on remaining Thickening Time from field blend testing - Maximum shut down time is 20 mins - Mud to be conditioned 2 BU prior to cementing Contingencies In the event that a problem occurs during mixing, pumping, or displacement, contingency plans should be systematically followed. If a shutdown occurs during the job, make note in the CemCAT report of when the stoppage occurred and how much time is available to remedy an issue before the thickening time becomes a problem. 1) If losses are encountered prior to cementing a) Utilize CemNET(1-2 lb/bbl; 2 lb MAX) b) Slow rate until full circulation is regained c) Determine max rate with full circulation and pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at minimum rate b) Attempt to remedy issue c) If issue with mixing system—switch to back-up mixing system d) If issue with triplex pump—continue with secondary triplex on unit 3) Mud Pump failure during displacement a) Discuss rig up in the event of cement unit displacement in PJSM b) Attempt to continue displacement with secondary rig pump c) Attempt to remedy issue d) Note displacement volume pumped by mud pumps:verify with well site leader e) Subtract pumped volume from total volume, which will be the volume pumped by the cement unit f) Rig up hoses to get mud to Cement Unit and begin displacement with cement unit (verify volume with well site leader) 4) Cement does not return to surface a) Commence top out operations using top out DeepCRETE on location 5) Floats do not hold a) Shut in and WOC until the tail has gained 500 psi compressive strength as per the UCA test Page 18 lc-154 cement vt.cfw;1415-315; road se srrace wi crete;Ver9on wcs-cemns 01 0 • aient : CPAI Well : 1C-154 Schlumberger String : 10314 District : Prudhoe Bay Country : USA Loadcase : Surface w/crete Apperxdx 1: Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 110.4 110.4 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 290.9 290.9 0.0 0.0 0.000 300.0 300.0 0.1 20.0 1.538 400.0 400.0 1.6 20.0 1.500 500.0 499.9 3.1 20.0 1.500 591.2 590.9 4.5 20.0 1.491 600.0 599.7 4.7 21.0 2.122 700.0 699.2 6.7 28.4 2.107 800.0 798.3 8.7 32.4 2.097 894.0 890.9 10.6 34.7 2.096 900.0 896.8 10.8 35.1 2.542 1000.0 994.7 13.1 39.7 2.497 1100.0 1091.6 15.4 42.9 2.500 1200.0 1187.4 17.8 45.3 2.505 1300.0 1281.9 20.3 47.1 2.502 1400.0 1375.0 22.7 48.6 2.497 1500.0 1466.4 25.2 49.8 2.497 1600.0 1555.9 27.6 50.8 2.499 1700.0 1643.5 30.1 51.6 2.502 1800.0 1728.9 32.6 52.3 2.498 1814.2 1740.9 32.9 52.4 2.489 1873.8 1790.9 32.9 52.4 0.000 1900.0 1812.9 32.9 52.4 0.000 1933.4 1840.9 32.9 52.4 0.000 2000.0 1896.1 35.2 51.3 3.602 2100.0 1976.0 38.7 49.9 3.604 2200.0 2052.0 42.2 48.7 3.600 2247.9 2087.0 43.9 48.1 3.605 2300.0 2124.5 43.9 48.1 0.000 2400.0 2196.5 43.9 48.1 0.000 2500.0 2268.6 43.9 48.1 0.000 2600.0 2340.6 43.9 48.1 0.000 2700.0 2412.6 43.9 48.1 0.000 2800.0 2484.6 43.9 48.1 0.000 2900.0 2556.6 43.9 48.1 0.000 2981.0 2615.0 43.9 48.1 0.000 Page 19 10-154cement vi.cfw;10-16.2015; LnadCaseSrfacew/crete;Version wcscend75 01 ANN •oFT� I% , s THE STATE Alaska Oil and Gas of L /t sKA Conservation Commission *lift uit 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O�ALASIk Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-154 ConocoPhillips Alaska, Inc. Permit No: 215-166 Surface Location: 1480' FNL, 4118' FEL, SEC. 12, T11N, R10E, UM Bottomhole Location: 2811' FNL, 4334.9' FEL, SEC. 36, 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, Cath P. Foerster Chair DATED this C day of October, 2015. F° : ' L STATE OF ALASKA ALIA OIL AND GAS CONSERVATION COMMON SEP 1 1 2015 PERMIT TO DRILL ^ 20 AAC 25.005 A()GCC la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj Q. Single Zone 0 • lc.Specify if well is proposed for: Drill Q . Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ • Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc , Bond No. 59-52-180 • KRU 1C-154 , 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12,376'. TVD: 3,846', Kuparuk River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1480'FNL,4118'FEL, T 11N,R 10E,S 12,U ' ADL 025649,ADL 025638 - West Sak Oil Pool , Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4476.23'FNL,2575.12'FEL, T 11N,R 10E,Si,U 931695 15/10/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2811'FNL,4334.9'FEL, T 12N,R 10E,S 36,U - 2560,2560 r 5170 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 97.1 feet , 15.Distance to Nearest Well Open Surface: x- 562168 y- 5968757 Zone-4 - GL Elevation above MSL: 57.6 feet , to Same Pool: 750 ft 16.Deviated wells: Kickoff depth: 300 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.12 degrees • Downhole: 1729 psi Surface: 1304 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H40 Welded 80 40 40 120 120 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 2950 40 40 2990 2624 1438 sx DeepCRETE Lead,205 sx DeepCRETE Tail 9.875" 7.625" 29.7# L-80 Hydril 563 5470 40 40 5510 3856 518 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 7066 5310 3833 12376 3846 Slotted Liner Completion(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat BOP Sketch Drilling Program X Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program )( 20 AAC 25.050 requirements K 21. Verbal Approval: Commission Representative: Date 910/09!2015 22. I hereby certify that the foregoing is true and correct. Contact Kelsey Hallford @ 265-1577 Email kelsey.hallford@cop.com Printed Name G.Alvord Title Alaska Drilling Manager Signature ,4.C. "(�" `1 Phone 265-6120 Date (19( _Dr / Commission Use Only Permit to Drillf�/ /! / API Number: Permit Approval I See cover letter for other Number: U.''5- `b b 50-'kq_o�3Ss9_p�-„ Date: 1 �1 119 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: r8Op rc-5 f a-o 3.5-00/�S Samples req'd: Yes ❑ NOV( Mud log req'd:Yes�o 2/ yq-nrivIe r;p re✓cel ter- to 2S' pfr''°J H2S measures: Yes d Non/ Directional svy req'd:Yes No a__ , 7`a to 14/it.F-�r5SC'ol rvtt7---t,+ rccLt.r1PGG1 ftY Spacing exception req'd: Yes❑ No[ Inclination-only svy req'd:Yes❑ No iler et a�✓t'!)3 .cd r •'"t�rGtrcv] lc-07A. t ict7 GGr-rJL WCII$ IC-c 1 I C-O(�/1m /-uS- hcw-c OA rv,on ,*orrcj 'jai 11 L YCI vnVSf Cvvr orvV, With 2astr}-cZ5--40a(cr) �TNJCc o crcc�,'onS �o br /•h atC66r6lan<c t,vr)th 410 ZG APPROVED BY / Approved by / -(--1 COMMISSIONER THE COMMISSION Date:0Q-6-- ('•S / Cubmit Form and Form 10-401 evised 10/2012) t i a d fo 24/�m the from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Aviv s ConocoPhillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Kelsey Hallford Phone (907) 265-1577 September 10th, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1C-154 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore injector well, a horizontal well in the West Sak"D"sand. / The expected spud date for 1C-154 is, October 15st, 2015. The West Sak in the 1C area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1C-154 well will be drilled in the D Sand, down structure to the North with a planned lateral length of approximately 6866'. 2 fault crossings have been identified along the planned well path. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 9.2 ppg equivalent during the drilling of this well. A FIT test to a minimum of 11.0 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 11.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1C-154. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 3500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for the wellbore. Sincerely, Kelsey Hallford ConocoPhillips Drilling Engineer • . Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 Permit - West Sak Well #1C-154 �ss, F., Application for Permit to Drill Document MaxWell Mpxirriiz � Well Value Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(1) 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 AAC 25.005(c)(4) 4 4. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 5. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 6. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 7. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (DrilPlex) 5 Intermediate Hole Mud Program (LSND) 6 Lateral Mud Program (MI Flo-Pro WBM) 6 8. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 9. Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 10.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 12.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 1C-154 PERMIT.doc Page 1 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved.10-Sep-15 13.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 14.Plat of All Wells Within 1/4 Mile Radius of Injection Well 8 Requirements of 20 AAC 25.402(c) (1) 8 15.List of Operators /Surface Owners 8 Requirements of 20 AAC 25.402(c) (2) 8 16.Affidavit to Operators /Surface Owners Proving Notice of Injection 8 Requirements of 20 AAC 25.402(c) (3) 8 17.Description of Operation 8 Requirements of 20 AAC 25.402(c) (4) 8 18.Name and Descroption of Affected Pools 8 Requirements of 20 AAC 25.402(c) (5) 8 19.Name and Description of Affected Formations 9 Requirements of 20 AAC 25.402(c) (6) 9 20.Logs of Off-Set Injection Wells 9 Requirements of 20 AAC 25.402(c) (7) 9 21.Casing Design and Mechanical Integrity 9 Requirements of 20 AAC 25.402(c) (8) 9 22.Fluid Injection Data 10 Requirements of 20 AAC 25.402(c) (9) 10 23.Injection Pressure 10 Requirements of 20 AAC 25.402(c) (10) 10 24.Reservoir Containment 10 Requirements of 20 AAC 25.402(c) (11) 10 25.Formation Water Analysis 11 Requirements of 20 AAC 25.402(c) (12) 11 26.Freshwater Exemptions 12 Requirements of 20 AAC 25.402(c) (13) 12 27.Increase in Hydrocarbon Recovery 12 Requirements of 20 AAC 25.402(c) (14) 12 28.Offset Wells Mechanical Conditions 12 Requirements of 20 AAC 25.402(c) (15) 12 29.Attachments 13 Attachment 1 Directional Plan 13 Attachment 2 Drilling Hazards Summary 13 Attachment 3 Cement Program Summary 13 1C-154 PERMIT.doc Page 2 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 Attachment 4 Well Schematic 13 Attachment 5 Quarter Mile Plat 13 Attachment 6 Doyon 25 BOP Stack Configuration 13 Attachment 7 Doyon 25 on 1C-154 13 1. Well Name Requirements of 20 AA C 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-154. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (2)a p/at identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total death; I, ation at Surface 1480.46' FNL, 4118.16' FEL, T 11N, R 10E, S 12, U • ASP Zone 4 NAD 27 Coordinates RKB Elevation 99.5'AMSL Northings 5,968,757.3 Eastings:562,168.4 Pad Elevation 60.0'AMSL Location at Top of Productive 4476.23'FNL 2575.12' FEL T 11N R 10E S 1 U Interval (West Sak"D"Sand) ' ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 5209' Northings: 5,971,054.16 Eastings:563,691.06 Total Vertical Depth, RKB: 3844' Total Vertical Depth, SS: 3747' Location at Total Depth 2810.7' FNL, 4334.89' FEL, T 12N, R 10E, S 36, U ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12376' Northings: 5,977,984.03 Eastings: 561,870.16 Total Vertical Depth, RKB: 3846' Total Vertical Depth, SS:: 3749' and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a p/at,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1C-154 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail,or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit 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: 1C-154 PERMIT.doc Page 3 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1C-154. Please see information on the Doyon Rig 25 blowout prevention equipment placed on file with the Commission. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1C area are 0.447 psi/ft, or 8.6 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure(MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,304 psi, calculated thusly: MPSP = (3868 ft TVD)(0.447- 0.11 psi/ft) = 1,304 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-154 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit 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: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(0; 1C-154 will be completed with a 7-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 1C-154 PERMIT.doc Page 4 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 5. 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 the following items,except for an item a/ready on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Lengt Top Btm Csg/Tbg Size Weight MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (f) (C) (ft) Cement Program 20 42 62.5 H40 Welded 80 40/40 120/ 120 Cemented to surface 200 cf ArcticCRETE Cemented to Surface 1438 sx 11 ppg 10.75 13.5 45.5 L-80 Hydril 563 2950 40/40 2990/ 2624 DeepCRETE Lead, 205 sx 12 ppg DeepCRETE Tail Cement Top planned @ 7.625 9.875 29.7 L-80 Hydril 563 5470 40/40 5510/3856 3300'MD/2845'TVD Cemented w/518 sx 15.8 ppg Class'G' 4.5 6.75 11.6 L-80 Hydril 563 7066 5310/ 3849 12376/3846 Slotted Liner-no cement 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit 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: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1C-154 surface hole. Please see diagrams of the Doyon 25 diverter system on file with the Commission. 7. Drilling Fluid Program Requirements of 20 AA C 25.005(c)(8) An application for a Permit 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: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program(DrilPlex) Spud to Surface 10-3/4"Csg Point Density(ppg) 8.5 - 9.4 LSYP(cP) 30- 50 API Fluid Loss No Control (mL/30 min) Chlorides(mg/L) <1000 pH 10.8— 11.2 1C-154 PERMITdoc Page 5 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 Intermediate Hole Mud Program (LSND) Lateral Mud Program(MI Flo-Pro WBM) 10-3/4"Csg Shoe to 7-5/8'Csg Point 7-5/8"Csg Shoe to TD Density(ppg) 9.2 / Density(ppg) 9.2 Fann 35 6 RPM Fann 35 6 RPM (lb/100 ft2) 10- 12 (Ib/100 ft2) 5-8 API Filtrate HTHP Fluid Loss <10 (cc/30 min) <6 (ml/30min) pH 9.5— 10.0 Kla-Stop 2-3% Drill Solids <7 pH 9.5- 10.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 25. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit 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: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(0; Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit 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: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application fora Permit 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: (11)fora well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating di-filing vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit 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: (12)evidence showing that the requirements of 20 AAC 25025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit 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: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 42"insulated conductor to ± 120'RKB. Install landing ring on conductor. 2. Move in/ rig up Doyon Rig 25. Install 21-1/4"Annular with 16"diverter line and function test. 1C-154 PERMIT.doc Page 6 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 3. Spud and directionally drill 13.5"hole to casing point at±2,990'MD/2624'TVD as per directional plan. Run MWD tools as required for directional monitoring (gamma ray, resistivity, GWD).✓ 4. Run and cement 10.75",45.5#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. / 6. PU 9.875"bit and 6.75"drilling assembly,with MWD(gamma ray, resistivity). RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and, between 20'and 50'of new hole. Perform formation integrity test to 11.0ppg EMW, recording results. 8. Displace to LSND water based drilling fluid. 9. Directionally drill to 7-5/8"casing point at 5510'MD/ 3856'TVD. Backream out of hole to the surface casing shoe. 10. Run 7.625", 29.7# L80, Hydril 563 casing to surface. (top of cement to be 3300'MD/ 2845'TVD which corresponds to 500'above the Ugnu C formation). 11. Install wellhead x 7.625"packoff and test to 3500 psi. 12. Flush 10.75"x 7.625"annulus with water, followed by diesel. 13. PU 6.75"PDC Bit and 4.5"drilling assembly,with MWD and LWD logging tools(gamma ray, resistivity, periscope, sonic)/RIH, clean out cement to top of float equipment. Test casing to 3500 psi for 30 minutes. 14. A sonic tool will be in the BHA so after casing test perform MAD pass with sonic tool in memory mode to ensure cement quality. 15. Drill out cement and 20'-50'of new hole. Displace hole to lateral drilling Flo-Pro WBM system. Perform formation integrity test to 11.0ppg EMW, recording results. 16. Directionally drill 6.75"hole to West Sak D Sand to TD at± 12376'MD/3846'TVD as per directional plan. 17. Back ream out of hole to 7.625"shoe. Circulate to clean up casing and POOH on elevators. 18. PU and run 4-1/2"slotted liner. 19. Make up liner hanger running tool. 20. Finish running liner to TD to land liner. 21. Set liner hanger @ ± 5310'MD/ 3849'TVD, set liner top packer. POOH. 22. PU 4.5"tubing as required and RIH to depth. Land tubing. Set BPV 23. Nipple down BOPS, nipple up tree and test. Pull BPV. 24. Freeze protect well with diesel by pumping into 4.5"x 7.625"annulus,taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows,the Wells Group will freeze protect the well post rig). 25. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit 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: (14)a genera/description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; 1C-154 PERMIT.doc Page 7 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class / II disposal well. All cuttings generated will be disposed of by hauling to the 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Plat of All Wells Within 1/4 Mile Radius of Injection Well Requirements of 20 AAC 25.402(c) (1) An application for injection must include:(1)a p/at showing the location of each proposed injection well,abandoned or other unused well,production well,dry hole,and other well within one-quarter mile of each proposed injection well; The plot for 1C-154 quarter-mile injection review can be found in attachment#5 15.List of Operators /Surface Owners Requirements of 20 AAC 25.402(c) (2) An application for injection must include:(2)a list of all operators and surface owners within a one-quarter mile radius of each proposed injection well; N/A since we are in the existing Kuparuk unit. 16.Affidavit to Operators/ Surface Owners Proving Notice of Injection Requirements of 20 AAC 25.402(c) (3) An application for injection must include:(3)an affidavit showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for injection; N/A since we are in the existing Kuparuk unit. 17.Description of Operation Requirements of 20 AAC 25.402(c)(4) An application for injection must include:(4)a full description of the particular operation for which approval is requested; Enhanced recovery injection well 1C-154 will be used for the introduction of additional fluids into the reservoir to increase the ultimate recovery of oil. This well will support existing producer at the time of drilling 1C-153 and planned producer 1C-155. As of December 31, 2014,there were 108 active wells in the West Sak Pool—54 producers, 49 water injectors, and 5 water alternating gas injectors(1E-117, 1E- 119, 13-122, 13-164 and 13-170). Produced water from the Kuparuk Central Processing Facilities(CPFs) and treated seawater from the Saltwater Treatment Plant(STP)were used for the West Sak waterflood. 1C-154 will inject produced water and/or treated seawater into the West Sak Pool. 18.Name and Descroption of Affected Pools Requirements of 20 AAC 25.402(c)(5) An application for injection must include:(5) the names,descriptions,and depths of the pools to be affected; The D Sand interval of the West Sak Formation, within the Kuparuk Unit,will be affected by the 1C-154 injection well. The West Sak Pool is defined by Rule 2 of Conservation Order No.406 as the strata that are common to, and correlated with,the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 3,552 and 4,156 feet, measured depth. 1C-154 PERMIT.doc Page 8 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved: 10-Sep-15 19.Name and Description of Affected Formations Requirements of 20 AAC 25.402(c) (6) An application for injection must include:(6) the name,description,depth,and thickness of the formation into which fluids are to be injected,and appropriate geological data on the injection zone and confining zone,including lithologic descriptions and geologic names; The West Sak Formation is overlain by a 100-140 thick mudstone and clay formation (Ugnu A). The West Sak Pool is defined by Rule 2 of Conservation Order No. 406 as the strata that are common to, and correlated with,the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 3,552 and 4,156 feet, measured depth. The West Sak Formation is underlain by the Colville Group, a sequence of impermeable inter-bedded mudstones and shales over 1000 feet in thickness. The Colville Group lithologies have similar confining properties as the overlaying Ugnu sequence, and no injection or fraction propagation below the West Sak is anticipated. 20.Logs of Off-Set Injection Wells Requirements of 20 AAC 25.402(c)(7) An application for injection must include:(7) logs of the injection wells if not already on file with the commission; All injection wells previously drilled will have the logs on file with the commission. 21.Casing Design and Mechanical Integrity Requirements of 20 AAC 25.402(c) (8) An application for injection must include:(8) a description of the proposed method for demonstrating mechanical integrity of the casing and tubing under 20 AAC 25412 and for demonstrating that no fluids will move behind casing beyond the approved injection zone,and a description of In order to ensure that no fluids will move behind the casing and beyond the approved injection zone the 147. intermediate casing will be set into the West Sak D and cemented. To demonstrate the integrity of the cement job a sonic cement bond log has been run in order to prove the top of cement is covering all the required zones. To demonstrate the mechanical integrity of the intermediate casing and tubing strings, both strings will be pressured tested. The intermediate casing will be pressure tested to 3500 psi for 30 minutes and the tubing will be pressure tested to 3500 psi for 30 minutes. Also pressure test tubing x intermediate casing annulus to 1000 psi for 30 minutes. (A) the casing of the injection wells if the wells are existing;or N/A as 1C-154 is a new well. 1C-154 PERMIT.doc Page 9 of 13 Printed:10-Sep-/55 • . Application for Permit to Drill,Well 1C-154 Revision No.0 Saved: 10-Sep-15 (B) the proposed casing program,if the injection wells are new; Casing and cementing program for the new 1C-154 well. Casing and Cementing Program See also Attachment 3: Cement Summary Hole Lengt Top Btm Csg/Tbg Size Weight MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 42 62.5 H40 Welded 80 40/40 120/ 120 Cemented to surface 200 cf ArcticCRETE Cemented to Surface 1438 sx 11 ppg 10.75 13.5 45.5 L-80 Hydril 563 2950 40/40 2990/ 2624 DeepCRETE Lead, 205 sx 12 ppg DeepCRETE Tail Cement Top planned @ 7.625 9.875 29.7 L-80 Hydril 563 5470 40/40 5510/3856 3300'MD/2845'TVD Cemented w/518 sx 15.8 ppg Class'G' 4.5 6.75 11.6 L-80 Hydril 563 7066 5310/ 3849 12376/ 3846 Slotted Liner—no cement 22.Fluid Injection Data Requirements of 20 AAC 25.402(c)(9) An application for injection must include:(9) a statement of the type of fluid to be injected,the fluid's composition,the fluid's source,the estimated maximum amounts to be injected daily,and the fluid's compatibility with the injection zone; Produced water from the Kuparuk Central Processing Facilities(CPFs)and treated seawater from the Saltwater Treatment Plant(STP)were used for the West Sak waterflood. 1C-154 will inject produced water and/or treated seawater into the West Sak Pool. Compositions of the injection water from the CPF, and SPT were submitted previously as part of the AIO 2B application. — The estimate maximum amount to be injected daily is 1500 bbl/day. 23.Injection Pressure Requirements of 20 AAC 25.402(c) (10) An application for injection must include:(10) the estimated average and maximum injection pressure; West Sak Water Injection: Estimated Bottomhole Pressure: 2600 psi (average) and 3000 psi (maximum) Estimated Wellhead Pressure: 955 psi (average) and 1355 psi (maximum) (Based on a well depth of 3771'TVDSS,Average injection gradient is 0.7 psi/ft and maximum injection gradient is 0.8 psi/ft) 24.Reservoir Containment Requirements of 20 AAC 25.402(c) (11) An application for injection must include:(11) evidence to support a commission finding that each proposed injection well will not initiate or propagate fractures through the confining zones that might enable the injection fluid or formation fluid to enter freshwater strata; The estimated maximum injection rates for the 1C-154 injection well will not initiate or propagate fractures through the confining strata and,therefore,will not allow injection or formation fluid to enter 1C-154 PERMITdoc Page 10 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved: 10-Sep-15 any freshwater strata. There are no indications of injection out of zone for the current water injectors at West Sak. Existing water injection operations in the West Sak Oil Pool have been at or above formation parting pressure to improve oil recovery of oil. In no instance have such injection pressures breached the integrity of the confining zone. The West Sak Formation is overlain by a 100-140'thick mudstone and • clay formation (Ugnu). This confining sequence tends to behave as a plastic medium and can be expected to contain significantly higher pressures than the West Sak formation sandstones. Extensive fracture testing confirmed that even at the bottom hole pressure significantly above the initial parting pressure,the fluids continued to be confined by a relative thin (" 15-20 ft) shale/mudstone interval, provided that an adequate casing cement bond is present. All injectors that are currently online have had a cement bond log to confirm adequate cement isolation between the West Sak formation and the above strata prior to commencing water injection service. Fracture stimulation data from the West Sak Formation indicate a fracture gradient between 0.6 and 0.7 psi/ft under initial conditions. Proppant injection pressures as high as 7,000 psi (about 2.0 psi/ft injection gradient) showed to fracture growth across any confining shale zones. In addition, long-term water injection above 0.9 psi/ft in the West Sak sands tend to part the formation horizontally, rather than fracture vertically,thus keeping all injection fluids within the intended interval. The West Sak Formation is underlain by the Colville Group, a sequence of impermeable inter-bedded • mudstones and shales over 1000 feet in thickness. The Colville Group lithologies have similar confining properties as the overlaying Ugnu sequence, and no injection or fraction propagation below the West Sak is anticipated. 25.Formation Water Analysis Requirements of 20 AAC 25.402(c) (12) An application for injection must include:(12) a standard laboratory water analysis,or the results of another method acceptable to the commission,to determine the quality of the water within the formation into which fluid injection is proposed; Compositions of the injection water from the CPF, and SPT were submitted previously as part of the AIO 2B application. The West Sak Oil Pool connate water composition is provided below. West Sak Oil Pool Connate Water Composition Kuparuk Lab Analytical Report Date: June 4th, 1998 DS 1D Water Sample(#AA43724) Component Concentration (ppm) Chloride 1290 Fluoride <10 Iodide 4.8 Sulfate 18 1 C-154 PERMIT doc Page 11 of 13 Printed:10-Sep-155 • . Application for Permit to Drill,Well 1C-154 Revision No.0 Saved: 10-Sep-15 Calcium 9.8 Iron <1.0 Magnesium 19 Sodium 3480 Barium 3 Strontium 1.4 Silicon 8 Potassium 62 Aluminum 0.3 Chromium <.1 Manganese <.1 Lithium 1 Boron 15 Phosphorus 1 PH 7.7 Bicarbonate 6538 26.Freshwater Exemptions Requirements of 20 AAC 25.402(c) (13) An application for injection must include:(13) a reference to any applicable freshwater exemption issued under 20 AAC 25.440; All aquifers or portions of aquifers lying below and within one-quarter mile tithe Kuparuk River Unit are exempted aquifers. (ref. 40 CFR 147.1092(b)(3)and 20 ACC 25.440(c).) 27.Increase in Hydrocarbon Recovery Requirements of 20 AAC 25.402(c) (14) An application for injection must include:(14) the expected incremental increase in ultimate hydrocarbon recovery;and The 1C-154 VRWAG pattern is expected to yield oil recovery of 18.2%OOIP in the West Sak Oil Pool by / 2040. This includes approximately 16.4%OOIP recovery due to waterflooding and 1.8%OOIP of incremental VRWAG benefits over waterflood. 28.Offset Wells Mechanical Conditions Requirements of 20 AAC 25.402(c) (15) An application for injection must include:(15) a report on the mechanical condition of each well that has penetrated the injection Zone within a one-quarter mile radius of a proposed injection well. 1C-154 PERMIT.doc Page 12 of 13 Printed:10-Sep-155 • • Application for Permit to Drill,Well 1C-154 Revision No.0 Saved:10-Sep-15 1C-05 is permitted as a Kuparuk C Injector. 10 3/4"surface casing set at 2782'MD(2695'TVD). 7"casing set at 7723'MD(7024'TVD)and 115 bbls of lead followed by 60 bbls of Class G tail cement was pumped. Top of West Sak sands logged at 4024'MD(3770'TVD).Total of 175 bbls of cement pumped w 5 covering 6424'to 1299'MD. Cement job went to plan. 1C-06 is permitted as a Kuparuk C Injector. 10 3/4"surface casing set at 3287 MD (2685'TVD). 7"liner 5 e- set at 10226'MD(7090'TVD)and 143 bbls of lead followed by 59 bbls of Class G tail cement was a 10lc v t pumped. Top of West Sak sands logged at 5332'MD(3834'ND). Total of 202 bbls of cement pumped t•s" covering 7544'to 2682'MD. Cement job went to plan. 1C-07A is Kuparuk C producer.The original 7"Production casing was set at 9766'MD/6566'TVD and h,LA 207 bbls of Class G lead followed by 62 bbls of Class G tail was pumped. Top of West Sak sands logged ,og s r, at 4751'MD.Total of 269 bbls of cement pumped covering 8010'to 1756'(inside 10 3/4"surface casing). Se,fi P Cement job went to plan.A CBL was ran from 9643'MD to 2000'MD showing a good bond. 28 years 1 p3'v` later the well was sidetracked in the C-sand with 2 laterals.The window was milled at 8934'MD/6542' S j ? TVD and the liner top packer was set at 8646'MD/6364'TVD. 1C-13 is permitted as a Kuparuk C Producer. 9 5/8"surface casing set at 5705'MD(4446'TVD), which is set deeper than the West Sak sands; we have cement across the West Sak interval, and all the way to surface. 1C-16 has 9-5/8"casing set below the West Sak interval at 4,520'ND,and is cemented to surface. v 1C-19 has 9-5/8"casing set below the West Sak interval at 4,484'ND,and is cemented to surface. V 29.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Quarter Mile Plat Attachment 6 Doyon 25 BOP Stack Configuration Attachment 7 Doyon 25 on 1C-154 1C-154 PERMITdoc Page 13 of 13 Printed:10-Sep-155 S • Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Monday, September 28, 2015 10:27 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 1C-154(PTD 215-166) Mechanical Condition of Wells in AOR Victoria, As discussed on the phone at the time of the submission of the permit,there were no West Sak wells within the 1/4 mile radius of the planned 1C-154 trajectory. 1C-153 (PTD#215-116)will be a West Sak D sand producer and it is currently being drilled; at the time of its completion the laterals of 1C-153 and 1C-154 will be 750' apart. Currently 1C-153 has 13-1/2"Surface Casing set at 2831.5' MD and 9-5/8" Intermediate casing set in the West Sak reservoir at 5129' MD/3856'TVD and cemented to minimum of 500' above the Ugnu C(shallowest possible hydrocarbon bearing zone). Both surface and intermediate cement jobs went to plan with full pipe reciprocation throughout job and with full returns. We will be monitoring annulus pressures on 1C-153 while drilling 1C-154. 1C-16 is permitted as a Kuparuk Producer. 9-5/8" Surface Casing is set below the West Sak interval at 4,520'TVD and is cemented to surface. 1C-19 is permitted as a Kuparuk Producer. 9-5/8" Surface Casing is set below the West Sak interval at 4,484'TVD and is cemented to surface. Please let me know if there is additional information you require. Kelsey Hallford From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: 28 September 2015 08:53 To: Hallford, Kelsey Subject: [EXTERNAL]RE: KRU 1C-154(PTD 215-166) Mechanical Condition of Wells in AOR Same thing as you did for the Kuparuk wells in the AOR- From: Hallford, Kelsey [mailto:Kelsey.Hallford@conocophillips.com] Sent: Monday, September 28, 2015 8:51 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 1C-154(PTD 215-166) Mechanical Condition of Wells in AOR Good morning, The surface casing shoe for 1C-07A is located at 3,107 MD/2,615 TVD. What information is needed to satisfy detailing the mechanical condition of the well? Kelsey Hallford ; §dd° 157s Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hallford(a�cop.com 1 • , From: Loepp, Victoria T(DOA) [rnailto:victoria.loepp@alaska.gov] Sent: 25 September 2015 11:00 To: Hallford, Kelsey Subject: [EXTERNAL]KRU 1C-154(PTD 215-166) Mechanical Condition of Wells in AOR Kelsey, Please provide the mechanical condition of the West Sak wells in the AOR. For Kuparuk well 1C-07A,what depth is the surface casing set? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeoo aC�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 1208.August 25 21 • 1 c-i 54wp04 6D737 Plan Summary >.5- -5 173 17-5/8"x 9-7/8" ,, %,, _.,..-----\ �� _---I bil,„ , Pfrost - ,.. ,, i - ( ' .. 0 7 I 1 I I l ,„,„ 1,,,, ....: , . „ . I i i ,-------- \ . ,,..,-- 1 y l 0 1 0 3000 6000 9000 12000 `®� 120"x/0 10-3/4"x 13-1/21 Measured Depth 412 x 6-3/4"� ' i \ \I o-•-- 20"x 42" Geodetic Datum: North American Datum 1983 *7041 0° Depth Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Ali,Rig: Doyon 25 �.`o , r. �00 O 110-3/4"x 13 1/21 ,` .® T OI7-5/8"x 9-7/81 *IlMr. x 6-3/41 -„ 0 -....,.... , . p O / 0 0 n O ' CO^o� ' (00m m W m m m 0 I N 1 . 0 40 "'-' 300 0 1500 3000 4,I0 6000 7500 0 9000 10500 0 300 - 490 Horizontal Departure I,C-,]2Y]P931 p ,c-,vzusPa,I, 330 _..12+. ,•` 30 490 - 670 io-nzxs( , _ y��b�► 670 - 860 •-1N0♦ tc nfutl� �EAON 860 - 1040 I:: Fii, 44 5 270 ••������\�r�.,�J 0990 - 3440 1 178L1 ••Q;1'� �C� j- 3400 - 3850 _1 tt 198 imai „ ,..... .., ;•4,)bsN7���'�Or rii��;ArA•4111gt i v;4 •-41.- ,��b� 70 3850 4300 U 1C-74a L1 (wp01) -_ I,G150I- fl AT-j iii/��ialrp: • 1 1(,fif a 4300 - 4750 11"4/'_ .:---- twL*IV 4.41;'a< ,.1,9,4 ,ray\ ,G,< 4750 - 5200 06 �O_O.Ob 0": 9•a - t1.4yk\ -_ ' 5200 - 6100 0 2000 4000 6000 8000 10000 12000 zao �'h7•®� •'0 1; ��i4�,� 35.2011014a( 6100 - 6990 SURVEY PROGRAM of..- ��, • 7990 - 7790 Surface Location Itc-,55,031 7890 - 8790 lepth From Depth To Survey/Plan Tool hc-178L1Pam1-_ ...t' 39.50 1150.00 1C-154wp04(Plan:1G0. Pad Elevation:57.60 -.154) GYD-GC-SS hG1)BL1PatJi'21� ;... 150 8790 - 9690 1150.00 2150.00 1C-154wp04(Plan:10-154) MWD iia-neLl9690 10580 - ---I,c-as fxwaiw,sl 1150.00 2990.10 1C-154wp04(Plan:1C-154) MWD+IFR-AK-CAZ-SC 11C-080811 , 160-,--_ 10580 11480 2990.10 4490.10 1C-154wp04(Plan:1G154) MWD CASING DETAILS c-a0l,c-.1Itc-o3al ioze f<a 7711 11480 - 12376 2990.10 5509.62 1C-154wp04(Plan:10-154) MWD+IFR-AK-CAZ-SC TVD MD Name M 5509.62 7009.62 1C-154wp04(Plan:1G154) MWD 119.50 119.50 20"x42" Magnetic Model: BGGM2015 T 5509.62 12376.43 1C-154wp04(Plan:10-154) MWD+IFR-AK-CAZ-SC 2624.10 2990.10 10-3/4"x 13-1/2" Magnetic Model Date: 25-Oct-15 - 3856.10 5509.62 7-5/8"x 9-7/8" Magnetic Declination: 18.90° 3846.10 12376.43 4-1/2"0 6-3/4" To convert a Magnetic Direction to a True Direction,Add 18.90°East SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5%100'DLS,20°TF,for 300.31' 3 600.31 4.50 20.00 600.00 11.09 4.04 1.50 20.00 9.67 Start 2.1%100'DLS,25°TF,for 302.75' 4 903.06 10.61 34.72 900.00 45.21 24.00 2.10 25.00 37.45 Start 2.5%100'DLS,25°TF,for 920.28' 5 1823.33 32.91 52.42 1750.00 270.38 273.78 2.50 25.00 190.31 Hold for 119.12' 6 1942.46 32.91 52.42 1850.00 309.85 325.08 0.00 0.00 215.16 Start 3.6%100'DLS,-15.32°TF,for 314.58' 7 2257.04 43.93 48.13 2096.13 435.22 474.55 3.60 -15.32 297.57 Hold for 1575.29' 8 3832.33 43.93 48.13 3230.69 1164.64 1288.35 0.00 0.00 791.50 Start 4.85100'DLS,-69.49°TF,for 1376.84' 9 5209.17 86.00 349.00 3844.10 2284.53 1541.69 4.80 -69.49 1807.67 1C-153 D-Top 09Sep14 DL Start 3.37%100'DLS,-64.14°TF,for 150.6' 10 5359.78 88.23 344.43 3851.69 2430.87 1507.12 3.37 -64.14 1957.96 Hold for 116.65' 11 5476.43 88.23 344.43 3855.30 2543.18 1475.82 0.00 0.00 2074.56 Start 2.95100'DLS,36.63°TF,for 33.19' 12 5509.62 89.00 345.00 3856.10 2575.19 1467.07 2.90 36.63 2107.73 1C-153 T1 09Sep14 DL Hold for 20' 13 5529.62 89.00 345.00 3856.45 2594.50 1461.90 0.00 0.00 2127.73 Start 3"/100'DLS,55.35°TF,for 28.98' 14 5558.59 89.49 345.72 3856.83 2622.54 1454.57 3.00 55.35 2156.70 Hold for 1262.38' 15 6820.97 89.49 345.72 3867.97 3845.83 1143.10 0.00 0.00 3418.93 Start 35100'DLS,-54.74°TF,for 29.2' 16 6850.17 90.00 345.00 3868.10 3874.08 1135.72 3.00 -54.74 3448.13 1C-153 T2 09Sep14 DL Start 2"/100'DLS,59.69°TF,for 37.43' 17 6887.60 90.38 345.65 3867.98 3910.29 1126.24 2.00 59.69 3485.56 Hold for 878.17' . Pfrost 18 7765.77 90.38 345.65 3862.19 4761.03 908.54 0.00 0.00 4363.66 Start 2"/100'DLS,136.89°TF,for 25.88' 19 7791.65 90.00 346.00 3862.10 4786.12 902.20 2.00 136.89 4389.53 1C-153 T3 09Sep14 DL Adjust TF to-90°,for 19.6T 20 7811.32 90.00 345.61 3862.10 4805.20 897.38 2.00 -90.00 4409.20 Hold for 1126.75' 21 8938.08 90.00 345.61 3862.10 5896.58 617.29 0.00 0.00 5535.89 Start 25100'DLS,90°TF,for 19.67' 22 8957.75 90.00 346.00 3862.10 5915.65 612.46 2.00 90.00 5555.57 1C-153 T4 09Sep14 DL Adjust TF to-144.12°,for 16.3T 23 8974.13 89.73 345.81 3862.14 5931.54 608.48 200 -14412 5571.94 Hold for 1279.1' 24 10253.23 89.73 345.81 3868.06 7171.58 294.88 0.00 0.00 6850.90 Start 25100'DLS,35.88°TF,for 16.37 25 10269.60 90.00 346.00 3868.10 7187.47 290.89 2.00 35.88 6867.27 10-153 T5 09Sep14 DL Adjust TF to-15.48°,for 110.0T 26 10379.67 92.12 345.41 3866.06 7294.10 263.72 2.00 -15.48 6977.31 Hold for 889.42' 27 11269.09 92.12 345.41 3833.14 8154.26 39.86 0.00 0.00 7866.09 Start 25100'DLS,164.51°TF,for 110.0T 28 11379.16 90.00 346.00 3831.10 8260.90 12.69 2.00 164.51 7976.13 1C-153 T6 09Sep14 DL Adjust TF to 157°,for 47.97' 29 11427.12 89.12 346.37 3831.47 8307.47 1.24 2.00 157.00 8024.08 Hold for 949.31' 30 12376.43 89.12 346.37 3846.10 9229.96 -222.36 0.00 0.00 8973.00 10-153 TD 09Sep14 DL TD:12376.43'MD,3846.1'ND L By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance olan as set nid in the audit pack aoorove it as the basis for the final well plan and wellsi e drawings I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Ifeanyi Ifesie Kelsey Hallford m . • o N in Northing (3500 usft/in) a a I ,� , 1 , IL_ iIiiiIi „ iIL _ IiiiiIiiilI iilI , , , _I I , II , , , , I iiI N II • •I• = I :a N CO �a — N U N U h U _ ^ U Q T N .i N p _ U �� U r _ N ' - ..d. aM\ U N/ . /1 F U CO F/ CN0 ' - in •• N �i� Y m J .0 a rn r o Q.. .3 U 6_41, Cr AO ;/U N .• i r Ii p _� l ' / T ••. 7 / , _ Q CD CL c - U r N m ` V T Y ` c0 '.��.�N— O ,- v+ 1Ttr Co -,`\ r r m -1:,‘°',' ' a 6T �0.04 al :T' ' ..: .. . d d �� � /�i f i...`\_ - �. 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OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 1C Pad Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan:1C-154 Well Position +N/-S 0.00 usft +E/-W 0.00 usft Position Uncertainty 0.00 usft Wellbore Plan:1C-154 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 10/25/2015 18.90 80.99 57,505 Design 1C-154wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.50 0.00 0.00 345.00 Survey Tool Program Date 8/25/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,150.00 1C-154wp04(Plan:1C-154) GYD-GC-SS Gyrodata gyro single shots 1,150.00 2,150.00 1C-154wp04(Plan:1C-154) MWD MWD-Standard 1,150.00 2,990.10 1C-154wp04(Plan'1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,990.10 4,490.10 1C-154wp04(Plan:1C-154) MWD MWD-Standard 2,990.10 5,509.62 1C-154wp04(Plan:1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,509.62 7,009.62 1C-154wp04(Plan:1C-154) MWD MWD-Standard 5,509.62 12,376.43 1C-154wp04(Plan:1C-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (°) (usft) 39.50 0.00 0.00 39.50 -57.60 0.00 0.00 0.00 100.00 0.00 0.00 100.00 2.90 0.00 0.00 0.04 119.50 0.00 0.00 119.50 22.40 0.00 0.00 0.19 20"x 42" 200.00 0.00 0.00 200.00 102.90 0.00 0.00 0.19 300.00 0.00 0.00 300.00 202.90 0.00 0.00 0.33 KOP:Start 1.5°/100'DLS,20°TF,for 300.31' 9/8/2015 2:04:00PM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan:1C-154 North Reference: True Wellbore: Plan:1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp04 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 400.00 1.50 20.00 399.99 302.89 1.50 20.00 0.48 500.00 3.00 20.00 499.91 402.81 1.50 0.00 0.62 600.00 4.50 20.00 599.69 502.59 1.50 0.00 0.77 600.31 4.50 20.00 600.00 502.90 1.50 0.00 0.77 Start 2.1°/100'DLS,25°TF,for 302.75' 700.00 6.46 27.88 699.23 602.13 2.10 25.00 0.91 800.00 8.49 32.08 798.38 701.28 2.10 17.15 1.07 900.00 10.55 34.66 896.99 799.89 2.10 12.99 1.23 903.06 10.61 34.72 900.00 802.90 2.10 10.45 1.23 Start 2.5°/100'DLS,25°TF,for 920.28' 1,000.00 12.85 39.33 994.91 897.81 2.50 25.00 1.40 1,100.00 15.22 42.67 1,091.92 994.82 2.50 20.49 1.58 1,200.00 17.62 45.12 1,187.84 1,090.74 2.50 17.25 1.69 1,300.00 20.04 46.99 1,282.48 1,185.38 2.50 14.90 1.82 1,400.00 22.49 48.47 1,375.67 1,278.57 2.50 13.12 2.10 1,500.00 24.94 49.68 1,467.22 1,370.12 2.50 11.74 2.52 1,600.00 27.40 50.68 1,556.96 1,459.86 2.50 10.64 3.06 1,700.00 29.87 51.53 1,644.73 1,547.63 2.50 9.74 3.70 1,800.00 32.34 52.26 1,730.35 1,633.25 2.50 8.99 4.42 1,823.33 32.91 52.42 1,750.00 1,652.90 2.50 8.37 4.60 Hold for 119.12' 1,882.90 32.91 52.42 1,800.00 1,702.90 0.00 0.00 5.21 Pfrost 1,900.00 32.91 52.42 1,814.36 1,717.26 0.00 0.00 5.21 1,942.46 32.91 52.42 1,850.00 1,752.90 0.00 0.00 5.55 Start 3.6°/100'DLS,-15.32°TF,for 314.58' 2,000.00 34.92 51.46 1,897.75 1,800.65 3.60 -15.32 6.02 2,100.00 38.41 50.01 1,977.96 1,880.86 3.60 -14.53 6.89 2,200.00 41.92 48.77 2,054.37 1,957.27 3.60 -13.36 3.50 2,257.04 43.93 48.13 2,096.13 1,999.03 3.60 -12.41 3.70 Hold for 1575.29' 2,300.00 43.93 48.13 2,127.07 2,029.97 0.00 0.00 3.86 2,400.00 43.93 48.13 2,199.09 2,101.99 0.00 0.00 4.25 2,500.00 43.93 48.13 2,271.12 2,174.02 0.00 0.00 4.64 2,600.00 43.93 48.13 2,343.14 2,246.04 0.00 0.00 5.04 2,700.00 43.93 48.13 2,415.16 2,318.06 0.00 0.00 5.44 2,800.00 43.93 48.13 2,487.18 2,390.08 0.00 0.00 5.85 2,900.00 43.93 48.13 2,559.21 2,462.11 0.00 0.00 6.26 2,990.10 43.93 48.13 2,624.10 2,527.00 0.00 0.00 6.70 10-314"x 13-1/2" 3,000.00 43.93 48.13 2,631.23 2,534.13 0.00 0.00 6.70 3,100.00 43.93 48.13 2,703.25 2,606.15 0.00 0.00 7.26 3,200.00 43.93 48.13 2,775.27 2,678.17 0.00 0.00 7.93 3,300.00 43.93 48.13 2,847.30 2,750.20 0.00 0.00 8.69 3,400.00 43.93 48.13 2,919.32 2,822.22 0.00 0.00 9.51 9/8/2015 2:04:00PM Page 3 COMPASS 5000.1 Build 74 ConocoPhillips • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan:1C-154 North Reference: True Wellbore: Plan:1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp04 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 3,500.00 43.93 48.13 2,991.34 2,894.24 0.00 0.00 10.37 3,600.00 43.93 48.13 3,063.36 2,966.26 0.00 0.00 11.28 3,700.00 43.93 48.13 3,135.38 3,038.28 0.00 0.00 12.21 3,800.00 43.93 48.13 3,207.41 3,110.31 0.00 0.00 13.16 3,832.33 43.93 48.13 3,230.69 3,133.59 0.00 0.00 13.48 Start 4.8°/100'DLS,-69.49°TF,for 1376.84' 3,900.00 45.15 43.84 3,278.94 3,181.84 4.80 -69.49 14.04 4,000.00 47.23 37.84 3,348.20 3,251.10 4.80 -66.43 14.73 4,100.00 49.60 32.26 3,414.60 3,317.50 4.80 -62.28 15.33 4,200.00 52.22 27.07 3,477.68 3,380.58 4.80 -58.57 15.89 1C-V14 D-Top 09-17-07 4,300.00 55.05 22.26 3,536.99 3,439.89 4.80 -55.30 16.43 4,400.00 58.06 17.78 3,592.11 3,495.01 4.80 -52.44 16.95 4,500.00 61.22 13.58 3,642.67 3,545.57 4.80 -49.97 8.83 1C-V14 MB CP1 09-17-07 4,600.00 64.49 9.64 3,688.30 3,591.20 4.80 -47.85 8.88 4,660.35 66.52 7.37 3,713.32 3,616.22 4.80 -46.05 8.95 1C-V14 MB_CP2 09-17-07 4,700.00 67.87 5.91 3,728.69 3,631.59 4.80 -45.11 8.95 4,800.00 71.33 2.36 3,763.55 3,666.45 4.80 -44.54 9.06 4,900.00 74.85 358.95 3,792.64 3,695.54 4.80 -43.30 9.19 4,993.56 78.19 355.87 3,814.44 3,717.34 4.80 -42.31 9.34 1C-V14 MB_CP3 09-17-07 5,000.00 78.43 355.66 3,815.75 3,718.65 4.80 -41.59 9.34 5,100.00 82.03 352.44 3,832.72 3,735.62 4.80 -41.55 9.52 5,200.00 85.67 349.29 3,843.43 3,746.33 4.80 -41.00 9.70 5,209.17 86.00 349.00 3,844.10 3,747.00 4.80 -40.67 9.72 Start 3.37°/100'DLS,-64.14°TF,for 150.6'-1C-153 D-Top 09Sep14 DL 5,300.00 87.34 346.24 3,849.38 3,752.28 3.37 -64.14 9.88 5,359.78 88.23 344.43 3,851.69 3,754.59 3.37 -63.98 9.97 Hold for 116.65' 5,400.00 88.23 344.43 3,852.93 3,755.83 0.00 0.00 10.16 5,476.43 88.23 344.43 3,855.30 3,758.20 0.00 0.00 10.48 Start 2.9°/100'DLS,36.63°TF,for 33.19' 5,500.00 88.78 344.83 3,855.91 3,758.81 2.90 36.63 10.61 5,509.62 89.00 345.00 3,856.10 3,759.00 2.90 36.62 10.67 Hold for 20'-7-5/8"x 9-7/8"-1C-153 T1 09Sep14 DL-1C-153 T1 09Sep14 DL Circle 5,529.62 89.00 345.00 3,856.45 3,759.35 0.00 36.61 10.76 Start 3°/100'DLS,55.35°TF,for 28.98' 5,558.59 89.49 345.72 3,856.83 3,759.73 3.00 55.35 11.09 Hold for 1262.38' 5,600.00 89.49 345.72 3,857.20 3,760.10 0.00 0.00 11.44 5,700.00 89.49 345.72 3,858.08 3,760.98 0.00 0.00 12.38 5,800.00 89.49 345.72 3,858.96 3,761.86 0.00 0.00 13.44 5,900.00 89.49 345.72 3,859.84 3,762.74 0.00 0.00 14.59 6,000.00 89.49 345.72 3,860.73 3,763.63 0.00 0.00 15.81 9/8/2015 2:04:00PM Page 4 COMPASS 5000.1 Build 74 • ConocoPhillips • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan:1C-154 North Reference: True Wellbore: Plan:1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp04 Database: OAKE D M P2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 6,100.00 89.49 345.72 3,861.61 3,764.51 0.00 0.00 17.09 6,140.66 89.49 345.72 3,861.97 3,764.87 0.00 0.00 18.41 1C-V14 MB_CP4 09-17-07 6,200.00 89.49 345.72 3,862.49 3,765.39 0.00 0.00 18.41 6,300.00 89.49 345.72 3,863.37 3,766.27 0.00 0.00 19.77 6,400.00 89.49 345.72 3,864.26 3,767.16 0.00 0.00 21.15 6,500.00 89.49 345.72 3,865.14 3,768.04 0.00 0.00 22.56 6,600.00 89.49 345.72 3,866.02 3,768.92 0.00 0.00 23.99 6,700.00 89.49 345.72 3,866.90 3,769.80 0.00 0.00 25.43 6,800.00 89.49 345.72 3,867.79 3,770.69 0.00 0.00 26.89 6,820.97 89.49 345.72 3,867.97 3,770.87 0.00 0.00 27.20 Start 3°/100'DLS,-54.74°TF,for 29.2' 6,850.17 90.00 345.00 3,868.10 3,771.00 3.00 -54.74 27.53 Start 2°/100'DLS,59.69°TF,for 37.43'-1 C-153 T2 09Sep14 DL 6,887.60 90.38 345.65 3,867.98 3,770.88 2.00 59.69 28.11 Hold for 878.17' 6,900.00 90.38 345.65 3,867.89 3,770.79 0.00 0.00 28.29 7,000.00 90.38 345.65 3,867.24 3,770.14 0.00 0.00 29.77 7,039.72 90.38 345.65 3,866.97 3,769.87 0.00 0.00 16.62 1C-V14 MB_CP6 09-17-07 7,100.00 90.38 345.65 3,866.58 3,769.48 0.00 0.00 16.62 7,200.00 90.38 345.65 3,865.92 3,768.82 0.00 0.00 17.09 7,300.00 90.38 345.65 3,865.26 3,768.16 0.00 0.00 17.57 7,400.00 90.38 345.65 3,864.60 3,767.50 0.00 0.00 18.06 7,500.00 90.38 345.65 3,863.94 3,766.84 0.00 0.00 18.55 7,600.00 90.38 345.65 3,863.28 3,766.18 0.00 0.00 19.05 7,700.00 90.38 345.65 3,862.62 3,765.52 0.00 0.00 19.55 7,765.77 90.38 345.65 3,862.19 3,765.09 0.00 0.00 19.88 Start 2°/100'DLS,136.89°TF,for 25.88' 7,791.65 90.00 346.00 3,862.10 3,765.00 2.00 136.89 20.01 Adjust TF to-90°,for 19.67'-1C-153 T3 09Sep14 DL 7,800.00 90.00 345.83 3,862.10 3,765.00 2.00 -90.00 20.02 7,811.32 90.00 345.61 3,862.10 3,765.00 2.00 -90.00 20.03 Hold for 1126.75' 7,900.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 20.41 8,000.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 20.92 8,100.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 21.44 8,200.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 21.96 8,238.74 90.00 345.61 3,862.10 3,765.00 0.00 0.00 22.48 1C-V14 MB_CP7 09-17-07 8,300.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 22.48 8,400.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 23.01 8,500.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 23.54 8,600.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 24.07 8,700.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 24.60 9/8/2015 2:04:00PM Page 5 COMPASS 5000.1 Build 74 ConocoPhillips • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan:1C-154 North Reference: True Wellbore: Plan:1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp04 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,800.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 25.14 8,900.00 90.00 345.61 3,862.10 3,765.00 0.00 0.00 25.68 8,938.08 90.00 345.61 3,862.10 3,765.00 0.00 0.00 25.89 Start 2°/100'DLS,90°TF,for 19.67' 8,957.75 90.00 346.00 3,862.10 3,765.00 2.00 90.00 26.01 Adjust TF to-144.12°,for 16.37'-1C-153 T4 09Sep14 DL 8,974.13 89.73 345.81 3,862.14 3,765.04 2.00 -144.12 26.04 Hold for 1279.1' 9,000.00 89.73 345.81 3,862.26 3,765.16 0.00 0.00 26.14 9,100.00 89.73 345.81 3,862.72 3,765.62 0.00 0.00 26.68 9,200.00 89.73 345.81 3,863.18 3,766.08 0.00 0.00 27.22 9,300.00 89.73 345.81 3,863.65 3,766.55 0.00 0.00 27.77 9,400.00 89.73 345.81 3,864.11 3,767.01 0.00 0.00 28.32 9,500.00 89.73 345.81 3,864.57 3,767.47 0.00 0.00 28.87 9,600.00 89.73 345.81 3,865.04 3,767.94 0.00 0.00 29.42 9,700.00 89.73 345.81 3,865.50 3,768.40 0.00 0.00 29.97 9,800.00 89.73 345.81 3,865.96 3,768.86 0.00 0.00 30.52 9,842.78 89.73 345.81 3,866.16 3,769.06 0.00 0.00 31.08 1C-V14 MB_CP8 09-17-07 9,900.00 89.73 345.81 3,866.43 3,769.33 0.00 0.00 31.08 10,000.00 89.73 345.81 3,866.89 3,769.79 0.00 0.00 31.63 10,100.00 89.73 345.81 3,867.35 3,770.25 0.00 0.00 32.19 10,200.00 89.73 345.81 3,867.82 3,770.72 0.00 0.00 32.75 10,253.23 89.73 345.81 3,868.06 3,770.96 0.00 0.00 33.05 Start 2°/100'DLS,35.88°TF,for 16.37' 10,269.60 90.00 346.00 3,868.10 3,771.00 2.00 35.88 33.15 Adjust TF to-15.48°,for 110.07'-1C-153 T5 09Sep14 DL 10,300.00 90.59 345.84 3,867.94 3,770.84 2.00 -15.48 33.30 10,379.67 92.12 345.41 3,866.06 3,768.96 2.00 -15.48 33.70 Hold for 889.42' 10,400.00 92.12 345.41 3,865.31 3,768.21 0.00 0.00 33.81 10,500.00 92.12 345.41 3,861.61 3,764.51 0.00 0.00 34.37 10,600.00 92.12 345.41 3,857.91 3,760.81 0.00 0.00 34.93 10,700.00 92.12 345.41 3,854.20 3,757.10 0.00 0.00 35.49 10,800.00 92.12 345.41 3,850.50 3,753.40 0.00 0.00 36.06 10,900.00 92.12 345.41 3,846.80 3,749.70 0.00 0.00 36.62 11,000.00 92.12 345.41 3,843.10 3,746.00 0.00 0.00 37.19 11,100.00 92.12 345.41 3,839.40 3,742.30 0.00 0.00 37.75 11,200.00 92.12 345.41 3,835.70 3,738.60 0.00 0.00 38.32 11,269.09 92.12 345.41 3,833.14 3,736.04 0.00 0.00 38.71 Start 2°/100'DLS,164.51°TF,for 110.07' 11,300.00 91.53 345.58 3,832.15 3,735.05 2.00 164.51 38.83 11,379.16 90.00 346.00 3,831.10 3,734.00 2.00 164.51 38.98 Adjust TF to 157°,for 47.97'-1C-153 T6 09Sep14 DL 11,400.00 89.62 346.16 3,831.17 3,734.07 2.00 157.00 39.03 9/8/2015 2:04:00PM Page 6 COMPASS 5000.1 Build 74 ConocoPhillips • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan:1C-154 North Reference: True Wellbore: Plan:1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp04 Database: OAKE DM P2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 11,427.12 89.12 346.37 3,831.47 3,734.37 2.00 157.00 39.08 Hold for 949.31' 11,500.00 89.12 346.37 3,832.59 3,735.49 0.00 0.00 39.35 11,600.00 89.12 346.37 3,834.13 3,737.03 0.00 0.00 39.91 11,700.00 89.12 346.37 3,835.68 3,738.58 0.00 0.00 40.48 11,800.00 89.12 346.37 3,837.22 3,740.12 0.00 0.00 41.05 11,835.62 89.12 346.37 3,837.77 3,740.67 0.00 0.00 41.61 1C-V14 MB_Toe 09-17-07 11,900.00 89.12 346.37 3,838.76 3,741.66 0.00 0.00 41.61 12,000.00 89.12 346.37 3,840.30 3,743.20 0.00 0.00 42.18 12,100.00 89.12 346.37 3,841.84 3,744.74 0.00 0.00 42.75 12,200.00 89.12 346.37 3,843.38 3,746.28 0.00 0.00 43.32 12,300.00 89.12 346.37 3,844.92 3,747.82 0.00 0.00 43.89 12,376.43 89.12 346.37 3,846.10 3,749.00 0.00 0.00 44.32 TD:12376.43'MD,3846.1'TVD-4-1/2"x 6-3/4"-1C-153 TD 09Sep14 DL Circle-1C-163 TD 09Sep14 DL 9/8/2015 2:04:00PM Page 7 COMPASS 5000.1 Build 74 ConocoPhillips • Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:57.6+39.5 @ 97.10usft(Doyon 25) Well: Plan:1C-154 North Reference: True Wellbore: Plan:1C-154 Survey Calculation Method: Minimum Curvature Design: 1C-154wp04 Database: OAKE D M P2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") f7 119.50 119.50 20"x 42" 20 42 2,990.10 2,624.10 10-3/4"x 13-1/2" 10-3/4 13-1/2 5,509.62 3,856.10 7-5/8"x 9-7/8" 7-5/8 9-7/8 12,376.43 3,846.10 4-1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (*) 1,882.90 1,800.00 Pfrost 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,20°TF,for 300.31' 600.31 600.00 11.09 4.04 Start 2.V/100'DLS,25°TF,for 302.75' 903.06 900.00 45.21 24.00 Start 2.57100'DLS,25°TF,for 920.28' 1,823.33 1,750.00 270.38 273.78 Hold for 119.12' 1,942.46 1,850.00 309.85 325.08 Start 3.67100'DLS,-15.32°TF,for 314.58' 2,257.04 2,096.13 435.22 474.55 Hold for 1575.29' 3,832.33 3,230.69 1,164.64 1,288.35 Start 4.8°/100'DLS,-69.49°TF,for 1376.84' 5,209.17 3,844.10 2,284.53 1,541.69 Start 3.37°/100'DLS,-64.14°TF,for 150.6' 5,359.78 3,851.69 2,430.87 1,507.12 Hold for 116.65' 5,476.43 3,855.30 2,543.18 1,475.82 Start 2.9°/100'DLS,36.63°TF,for 33.19' 5,509.62 3,856.10 2,575.19 1,467.07 Hold for 20' 5,529.62 3,856.45 2,594.50 1,461.90 Start 3°/100'DLS,55.35°TF,for 28.98' 5,558.59 3,856.83 2,622.54 1,454.57 Hold for 1262.38' 6,820.97 3,867.97 3,845.83 1,143.10 Start 37100'DLS,-54.74°TF,for 29.2' 6,850.17 3,868.10 3,874.08 1,135.72 Start 27100'DLS,59.69°TF,for 37.43' 6,887.60 3,867.98 3,910.29 1,126.24 Hold for 878.17' 7,765.77 3,862.19 4,761.03 908.54 Start 27100'DLS,136.89°TF,for 25.88' 7,791.65 3,862.10 4,786.12 902.20 Adjust TF to-90°,for 19.67' 7,811.32 3,862.10 4,805.20 897.38 Hold for 1126.75' 8,938.08 3,862.10 5,896.58 617.29 Start 27100'DLS,90°TF,for 19.67' 8,957.75 3,862.10 5,915.65 612.46 Adjust TF to-144.12°,for 16.37' 8,974.13 3,862.14 5,931.54 608.48 Hold for 1279.1' 10,253.23 3,868.06 7,171.58 294.88 Start 27100'DLS,35.88°TF,for 16.37' 10,269.60 3,868.10 7,187.47 290.89 Adjust TF to-15.48°,for 110.07' 10,379.67 3,866.06 7,294.10 263.72 Hold for 889.42' 11,269.09 3,833.14 8,154.26 39.86 Start 27100'DLS,164.51°TF,for 110.07' 11,379.16 3,831.10 8,260.90 12.69 Adjust TF to 157°,for 47.97' 11,427.12 3,831.47 8,307.47 1.24 Hold for 949.31' 12,376.43 3,846.10 9,229.96 -222.36 TD:12376.43'MD,3846.1'TVD Checked By: Approved By: Date: 9/8/2015 2:04:00PM Page 8 COMPASS 5000.1 Build 74 • • Schlumberger Report-Basic Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-154 Project: Kuparuk River Unit TVD Reference: Plan:60+28 @ 88.00usft(Doyon 141) Site: Kuparuk 10 Pad MD Reference: Plan:60+28 @ 88.00usft(Doyon 141) Well: Plan:1C-154 North Reference: True Wellbore: Plan:1C-154 Survey Calculation Method: Minimum Curvature Design: 1 C-154wp04 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 12,367.33 89.12 346.37 3,837.00 3,749.00 0 00 0.00 44.32 TD:12376.43'MD,3846.1'TVD-4-1/2"x 6-3/4" 8/25/2015 4:31:14PM Page 7 COMPASS 5000.1 Build 74 • S r ijC a� d E "C.- =7 N I c ° • 2 CU L' Cs) N NN CN - d N O C. a 0 — m w oo CU w Lo x m 0 o s v + o o N Cti �+ ♦, C 7 S Q CU 0 ❑ L yda 3 6 y a N ° (0 A+ (n C° Si VTD W ° a Cl) ° V+ ° Ci '0 0 Q .� = 0• R 3 A 0 ca 0 0 0 01 Nemo ° a aOaeu = w s = •_ u., v w ii I's v/ J • i + nN a LT cc, 0 0 d CI eF "1" = — 2 a 1- a a Q a 3 n a mo U Lo in o L C Y .2 M .2 7 0 o LL T T T �Y 0 N C a N m J N a-� Z a o ,- u_ s_ 0 T ICO NM aN ILO 0 ) s O Em CO OC.O aa U = U I Q 0 y £ r) G F� F� V Y Y a a T 0 In= -2, ° 12 2 2 N Fce 0 (n Cr)i0 > Co in 110 • d o 0 co �. xY Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y CI c N N N N N N N N N N N N N N O N N W N C) N N .S.A. 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C — y C.y M V VV CN) M Cl) 4 Cl) r nM V0M V0) V0M () M CN (N N) N NN O 0 CC 1 ` u N 43 7 N N V w u, A I L d' o °' LC) z , E .5 .c U 0 _ w • CL C o a) (q (VO Ca) V co 03 c ^. ) O 0 4 O 0 o. d o o O O O 0 O O O o p O L. c LL E Q. Q. 3 3 3 3 3 3 3 3 L U N o 2 M M (0 C) N. N. c a 0 c m 7 ,- ,- r r r r u°Di (O7n 14— O m m 6 6 6 t R m $ m a M 0 r U U 000066 u a N o d N N /� 7 U a s tO O co co 0. p. - 01 , J J J J J ,- 0 co co N N C) C) u7 C) (OO (OO _ N N O n N N •N N N N N M M ' ' V V C C) N N 0 0 0 V U 000066 ) Ce GN M 7 N 0 0 U 0 U N N N N CO 03 N N N N O O ( O d N V Z a s . C C C C CCCCCC O a 7 a- n — i ( ( ( ( U U U U co M U U U U ( i o N N N co co N co co (0 Cu G E S v 3 J J J co O) ' ' ' N N „ J J d a a a a a a a a a a a ui • O N N M CO U U V V C) CO CO C) CO CO 3 O C O C N N N N N N N N N N N N N N N N N M M C) 2 C) fli r N- C) <0 a . 'CC O N N N 00000 0666 — — U U U U U U U U _ O U U UC UC U U U UC Cl)Oa o N CoC NU Ci i ( ( ( ZO. ( ( 0 ( ( ( ( ( ( NN CO 01 CO CO CO 03 03 CO 03 CO N a o NNNNN NNNNNNNNNNN C C T 10m U ` K K al UUUUUU UUUUUU UU ° mmm m m m COU o o a a a a a a a a a a cc < 03 d 0 0 1- ct 0 CO • • Q . Co'a= Co m et CA a 0 0 0 0 0 0 O U) U) CO F N N N m U 0 0 Y Y Y N U) Q Q Q tr tY tr Cj tL u- LT CT- + T 0 0 0 0 0 0 0 } co 0 co a) c c C) a ff.. T a) ) • y. C " z p 0 ca Q. m a) a) ,,"tt^^ Ua) ) Y/ O_ a d o_ d d Q _a. T... 3 3 3 3 3 3 3 m w 1V V V V V V V a V � LOLOLOLOLO � co oU I, L r 0000000 m N• 2 E d, 2 UL a) LO O O O O N N co V) 3 (1) N O O O co V c c 3 I O O O O m 0 CO ',-5 a) Q) p U Cf) )f) O W O O m 03 0p O GO CON cr O c ^ - m C m pv) C N ca p O N o Q. a m w i d N w v 0 O L LO O O .— ,— CO (D a73) tz O 0 0 0 0 0 rn rn GO c '= 2 NEwMlO LO O) m 0 0 u! m a) r o4. o _ _ a) rn . v1m U • 0 4.4U. r •- CN u) L0 o 3 a) im. 0 17) a N v) m m m UQ a) a) UmN , W U LL Np Na N a )p0U Om y N_ c O ( (QC U U . N NN ii (6 GO y E p co Q Ua Q aup O pcm a c CN LO Va) a) U p C U Z N a W Na 0 U) 0 < • 0 I226, August 25 2O5 Ladder View 1C-1 54w p04 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. iG 8 a a - 3 3 ,-• ,- .- .- ' If' 300 "'"NH', 1 ,' WO kl if )11111111111111P' !.111U 111 ill, ,,v ,, , 0, It ,i1 411)1 1 r IIIIII i , ,.it ill i ii if lilt I i,,1 . 0 Nil,41 41:, ,l 1 ir,i II I 11 II I/ A II' 1 0 t .....,,,ik i fl,ii I i i I 1 CD —•••..•4...., 4/ 0_ :!!1,', iilir i ,' illi I 2 "'"'""410',411"1111 d,III Fo 150 ...rt.,4110,, x 1 1 A 4111 111, 46' lir "Pr" 1 F ii 1 1 0 Ili' 01 1111 dr ,t ilill,1111 '4 t I 4 il illii, 1 111111111 '*'' 11111111110 -.......000.1 il A 1,o (7) -.., o t...lopp 1 1 1 ..,... e ., IN 0 , i I , 1 I I I I I I I 1 I I I I I I I , I Equivelant Magnetic Distance 0 2000 4000 6000 8000 10000 12000 Displayed interval could be less than entire well:Measured Depth 39.50 To 12376.91 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 1150.00 1C-154wp04 (Plan: 1C-154) GYD-GC-SS 119.50 119.50 20"x 42" 1150.00 2150.00 1C-154wp04 (Plan: 1C-154) MWD 2624.10 2990.10 10-3/4" x 13-1/2" 1150.00 2990.10 1C-154wp04 (Plan: 1C-154) MWD+IFR-AK-CAZ-SC 3856.10 5509.62 7-5/8"x 9-7/8" 2990.10 4490.10 1C-154wp04 (Plan: 1C-154) MWD 3846.10 12376.43 4-1/2"x 6-3/4" 2990.10 5509.62 1C-154wp04 (Plan: 1C-154) MWD+IFR-AK-CAZ-SC 5509.62 7009.62 1C-154wp04 (Plan: 1C-154) MWD 5509.62 12376.43 1C-154wp04 (Plan: 1C-154) MWD+IFR-AK-CAZ-SC .-= P. 60 , 1 , i Ji ! I \ / c - ca a) t' 2 30 --. w 4 0 o 2 (1) c.) , i + i o 11 i i 1 I I I I 1 I I I I I I I i I I I I I I I I I I I I I I i 0 s 500 1000 1500 2000 2500 3000 3500 Equivelant Magnetic Distance Partial Measured Depth II 1C-154wp04 1 Inc Azi TVD Dleg TFace Target 300 490 39.50 0.00 0.00 39.50 0.00 0.00 39.50 To 12376.91 300.00 0.00 0.00 300.00 0.00 0.00 490 670 600.31 4.50 20.00 600.00 1.50 20.00 903.06 10.61 34.72 900.00 2.10 25.00 670 860 1823.33 32.91 52.42 1750.00 2.50 25.00 12:24,August 25 2015 1942.46 32.91 52.42 1850.00 0.00 0.00 860 - 1040 2257.04 43.93 48.13 2096.13 3.60 -15.32 CASING DETAILS 1040 1230 3832.33 43.93 48.13 3238.69 0.00 0.00 TVD MD Name 5209.17 86.00 349.00 3844.10 4.80 -69.49 1C-153 0-Top 09Sep14 DL 1230 1410 119.50 119.50 20" x 42" 5359.78 88.23 344.43 3851.69 3.37 -64.14 2624.10 2990.10 10-3/4" x 13-1/2" 5476.43 88.23 344.43 3855.30 0.00 0.00 1410 1600 3856.10 5509.62 7-5/8" x9-7/8" 5509.62 89.00 345.00 3856.10 2.90 36.63 1C-153 Ti 09Sep14 DL 3846.10 12376.43 4-1/2" x 6-3/4" 5529.62 89.00 345.00 3856.45 0.00 0.00 1600 2050 5558.59 89.49 345.72 3856.83 3.00 55.35 M11.111.===2: 6820.97 89.49 345.72 3867.97 0.00 0.00 2050 2500 oth From Depth To Survey/Plan 7001 6850.17 90.00 345.00 3868.10 3.00 -54.74 1C-153 T2 09Sep14 DL 39 56 1150 GO 1C-154.64 (Plan 1C-154) 811)-GC-55 6887.60 90.38 345.65 3867.98 2.00 59.69 2500 2950 1158 00 2150 81) 1C-1548$)04(Plan 1C-154) MAI 1159 00 2990 16 1C-154m(4/14(Plan 1C-154) 1114041F11-8K-CA7-5C 7765.77 90.38 345.65 3862.19 0.00 0.00 2999. 4490 10 1C-154)064(Plan 1C-154) MA 2950 3400 2990. 5509 62 1C-164)404(6790 1C-154) 111404I60-AK-C42-5C 7791.65 90.00 346.00 3862.10 2.00 136.89 1C-153 T3 09Sep14 DL 5589 62 7089.62 1C-1541404(Plan:1C-154) 150 6799.62 12376 43 1C-1544m04(Plan 1C4154) 11.41FP-8114C42-5C 7811.32 90.00 345.61 3862.10 2.00 -90.00 3400 3850 8938.08 90.00 345.61 3862.10 0.00 0.00 8957.75 90.00 346.00 3862.10 2.00 90.00 1C-153 T4 09Sep14 DL 3850 4300 8974.13 89.73 345.81 3862.14 2.00 -144.12 10253.23 89.73 345.81 3868.06 0.00 0.00 4300 4750 10269.60 90.00 346.00 3868.10 2.00 35.88 1C-153 15 09Sep14 DL 10379.67 92.12 345.41 3866.06 2.00 -15.48 4750 5200 11269.09 92.12 345.41 3833.14 0.00 0.00 • • •0 op ,. cio ; 0 00 -, 5200 6100 11427.12 89.12 346.37 oeggc47 2.00 1C-16 6100 6990 1C-172AL2PB2 12376.43 89.12 346. 7 :-S 0 -8.00 - 1C-153 TO 09Sep14 DL 1C-172AL2PB1 ,...„ ,,,,,gax.w --r• ,•leo.,,,v dr 011110"- ‘01°04,91"-q'IAIM00,44. --'• 1C-19 6990 7890 la 111, ,rvit, 040 40 30 " 1111404,,,,,UNIV4Iviaelt,04,410%.41,/z 7890 - 8790 1C-172AL2, -30/330 ,- low wok,t,sklk at•Vci,ei; 4111„tistiWN ' , , , 40,,,#, mg ','•,ifts 'IV--.ex 8790 9690 1C-172AL1,,\, 1C-172'•,',, 0, ______, . 00 titalikih‘li‘ -7- - •Nill'It,-400114014.- . lakottI,N,:::: ='.4aliTW -44.-alk444 4401;1% -.1011MW-4;w.,;•! e ,./144,*4411"*.%` ,N016214171tt":410110.10'..vartiaV;„,,'14,,1‘41k, 141144144.:(N-Iew .,...--41,4 itios- _•.,‘,kiv * J1641111W"Akz,ksr, • , Itt Is-....,--,„401mv,L.•,",,,olt.,,,'• 9690 10580 11480 10580 11480 12376 -- s•\ss"\\ ." 111104P Ikr;ICVY.141 ) ---- 150 -,,. 0070,-...,",..,,,,,,1 ,/,- Raw 4,. •'VG!.%Al i it t?4, \- "'%NW. \ e 1. -,-,,,,.•••• •4..• ii A is. 1,12s. _.,4&• xiik„.••••••. sw.,„v,- .,z41064" 60 60/ 1;14,:=---fi ."---- .;AV,;..r.. 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'ii:.•V ---!=,' • r-ret:.;,-:-.:"..-Totoidiiits:ilit• 120 1C-15L1 1C-157wp01 ',mr,iii'.0•-Y:,1*4. 14r01101':Wir ‘.41. :, '?.la Mit,s-i.4."%.- •-.---, ,itIlk •-•46,4,‘,.....'WO,.liAti,11 ONO 40 ,:„ ..... .. ___ ....„....„-.. ,..„..-_..., _--- ---,---gr..--„.„.- . -..e-,,-- „.---, . . ,.....,...„,, .,„ ,,-,. ..,. .s,....,, ,,, __ --.....fver.,..:-.,:4•4 AO. * :_Jew,',,,,"--_7.-- ,s ,, 4t,t.44:40. -...,..A:-.1-._„..• -,-,,, , , 1C-15 1C-18 ,' ass•-•;•,:v-,!•-,•,,,-.1;smi 4 ..ok 1 -, .-----_:.__:::-_-., 4.;• 4.•ti.,„," zs.,s' -,' •---,• ,.: 140 4PAR 01,.',4 It bWOF Aftir . 4,./-fr,- --.,, :---;- •,. ...r,„v.,.,.......-- 1C 04 / ' , '.".67.4,7410411111,1A1,1or0.---..rw.4.p10.m0,dw„4r'iz.-r4ol.'-;-,i.,'V.,.7;•7,,:f"/,,--"-----A,Ar T-A:11:-;;;,1• :..,4.s.••,,„ , ..,..... ,.-,. 1C-23P B1 1 -178L1pBi , 7 . a . : 1C-23 1=r • t , ,...!---,- ..!; • ,, , '41110...10.---•:"v,,!!,,,-.41,,,,. -••,,,wie,"4;0„../iie• -•iv,4'0.0.-.,:,---,'-.' - '----_ 1C-178L1PB2 , mor.-..-04.40,04,4r- %mart',4- , 0,,' .\ \\:',&•e\•=:: - 150•. - 1C-184 , -150/210 4- -evrpr.:mrioakv, ,4,..\i'ilreh4e,,,, .4 "'` ' '‘: 0' ,012:0,7rAwoitapAkku,•s-b'141., 11.-,-•• ' . - ". . 1C-178L1 1C-158wp01 ...„;,--....t±-.1,-•;,,c,„_ _ • • ,1 ,-, ,r,res.,4,..,,,-;=-kxtz-ro--- .. ' - _ - , -t - _,."17'•-•,;ciot ti\,,, ,:r---,- , • ,,,,--','-•::.--==.7.---- =, _1C-24 1C-156wp01 ,• .' 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Lr L(\ Ln Q V wil O N M in in d' d- d- d- d.' d-' d- - d- d.. d- d- .7r- 'd- ,,..Ln d- d_' d. d- d- ., O M rr1 rr1 M M M M M rr� M M m M M en M M rn r V o 0 0 'D m ' d- m N CO N1 N N a- N f\ 0 N. N N 00 Ln M M O f� r O Ln 0 (Yl 0 rr\ d- 0 in `: N. d- '0 Ln a\ 7 o t\ M 0 r `-: N r- T O a\ 0 O rn rn ry f� r1 O Ln ' • l d- rn r 01 00 O .- •00 a� r CO M 0 O 0 N Ln O Ln O N Ln N oO q) M L a1 Ln N L N N M Cr\ cc d1 N 00 M d- Ln Ln Ln CO 00 N. a1 N rYl c" N M Ln in in Ln N. 0 • • 0 ko 0 O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o0 o 0 0 0 d- M 0 0 Ln 0 Ln 0 Ln 0 Ln 0 O O' a 01 a Ln 0 M O N. O N d• kO 0 in d1 CO M N N CO N O ,- N M Cr 'O 00 c- c- c- e- N N N M M d- d- Ln \O D f CO a\ ,- e-- c- I O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d- 0 (5' N. k.0 d' M ' 0 in 0 Ln 0 in O in O O_ .01 a1 0\ 01 00 00 M d' 'D 00 0 N d q) 0 111 � M 00 rn N. N �O a 00 N 'O Ln d- r' " c- N N N LO ^ 00 Ql 0 ,- 0 O ON N 2LLEE lJ 7 - 7 .,6 MM' X _ / 0 a .1--7-1-,v v v a E 0 l N\ / / \ / \ ..\ ^_._.__.....____-_._._.. � u , a �d.��� /aiggggg i u, u, , `� av`.°n a°mmd,�6 y H n l n 0 au0 O O (---- 0 Oa66mN0 , CO r- c 1, O 0 _._ r E v��pn n z x b 5 x x b A.& 0 m ' 0 0 V4 q 000 M N ,9 �A r 1 70, O / O ON 71- • 0 N V) rrl _ ii,C 0 N 0 N N _ N Lr Cli 1 N 0 14,.O = N o 0 o N N N rn rn o rn rn O N N O 111 Ln O r• r• 0 r' 0 In1:11r d' f— < o 0 0 d- d- 7 o d- d- o o q) o o ° oO o ter- = r O O O d- N N 00 00 p, d' d' Ln u.: In Ln Ln Ln Qp Ln Li, 3 Ln 111 q3 111 Q Q r O N rn 111 Ln d' d- .1- d' d- d' d' ren 5: d' d' d' d' M M d' rn M d- M 00 r i ' O m M rrl M m M rn rn m m rn d. V 0 0 0 r � rn \D d- rn N CO rn N N Q, f. N- 0 N. L \ N pO Ln r rn 0 ^ N r 0 in 0 rr1 O M d- 0 rn N. d .O q..) in 0-\ .0 n rn 0 N. N k.0 k.0 O • O O M M N f\ N O-\ 00 O 0 Ln c- r\ rr1 LA M 0 0 0 00 p, N CO rrl d- Ln Ln Ln o0 00 co N. N a0 M 0, 0� N .O M M M r' N rr\ Ln Ln Lf1 Lr\ Ln Lf\ \. ^ - 00 co co 0 6 0 Errors Report Pool Report 1 .-0:41 C-23 le. 0a O O ID ;u peeeeseesoo ; taio°oouaooRR z 6 222np2222,uN N\ z...0 ryq�qy 6 R¢K i i Z i R C C Ili liurititititittt 42, ;� aoaao oo 000 ` . 410♦.gi/�,4�n ani.UF iY :;0 W 4 1sul is u M x 1 r. Ala, la la e t) ��' ��11, Ps CD R(100000.0. , . . N MNN NOtat NU! I /�/ 11 h F F I-F F P T-p 4R a✓f .moimmommmwm .03 , 4.1 lek $�dbr�;ubbbb �L` .. § a..a% t't- _N,' 'k(NI E., _ __ s ,,,,. ,_:,.. „,,,i,,,, , ii. .. or '-iill ,4411 .''::.[FV..4 0 co u �. b4-.j - wY!!} b • 0 ___..............-7.; _ e„ft., #4 1,, ej- r, o! 1 L 44 1,gt': _ .!•7-- ..‘dlifolril, , , 8 \#,4:�,' t Ksi ‘It. 22, st-ht 1� v CO "34, .. 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LLE?1 0 C 00086 1' r, \\ C O • :51-L- .— •\ M 4.0 ' X tel/ O 11000 N -, 4 r 00001 t 006 _ o p 0 0 o '-U 0006 bZ0- / o 0 0j v o a 1- o 006 _ 6 7r co 0008 _ rn o I ---- v IT e L 0 -r 0'6 U).10� c.0e ( 9 J p 0 O 0009 1 OM II• sO in _ ems o Oma ig SV i rn x 14 O O __ Nr-1-•1 T _ o -a co \ II � T X T '71- x c i o o N O LU T o o o p o p o o C 0 0 1 � 1^ ,Y o o L! co (ui/llsn 0051) i doa IeoweA anal • Y kI • . . .., • .. . 11=NO r,, li ,, . ,, , , „ ... , , ,,, . „ , , ,.,. , , ... : , .., . , . . . , . . .. . .: . .. , • . . .. . . . . . .. 0 -;,1.- ... �.. , - • I , ..,„ , , , , , . • . . . . . . , , . : . . . . . . . .. . . . . . . 3 . • . . • . . . . •..... : : : • . .„ .. ,. , • ,, , , . „.. . : : : : : , ..: N .,:„..... „.: . , .._ .. :, ._ _., , . „ , : ..... _,_ , . U , . • . . . 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CPAI Coordinate Converter l '1 _X j From: To. 4 �NAD27 Region: alaska Datum NAD83 7 Region: alaska Datum: C Latitude/Longitude 'Decimal Degreesr Latitude/Longitude �Dea'rmal Degrees • C' UTM Zone: E South C' UTM Zone: !True r South 4` State Plane Zone: R---":„,3 Units: Wit— C State Plane Zone: 4 f Units: us-ft r `` C Legal E ni.Dli t t D2. .�3 4` Legal Description(NAD27 only) Starting Coordinates: _. _ . Legal Description _,..... . . ... X: 1702200.32 Township: r 1011 N . Range: I010 EFTA Y: 1596850907 Meridian: lu Section:112 FNL • 11480.4639 FEL 14118.1558 Transform Quit I Het) l 1C-154wp04 Intermediate Casing I ffn. CPA!Coordinate Converter " ::D ' k 2,S From:._ __ i To: Datum: jNAD83 • Region: Ialaska '! Datum: INAD27 ,, Region: lalaska zi C Latitude/Longitude IDecimal Degrees C Latitude/Longitude Decimal Degrees .:J C' UT M Zone: I-- (— South C UTM Zone: True t South (' State Plane Zone q z Units: t.ft . C State Plane Zone: 1------ ,---1 Units: us•ft • r Leal Descriptlan(NAD27 only) ' Legal Description(NAD27 only) Starting Coordinates: x... Legal Description _ X: 11703646.00 Township: Range:011 N . 9 • r010 E • Y: 15971096.00 I Meridian: lu j Section:11 FNL 14185.5710 FEL 12649.5593 Transform Quit I Help I 0 0 1C-1 54wp04 TD rQ CPAI Coordinate Converter JJ " From: To Datum: 1NAD83 .I Region: alaska . Datum: f NAD27 Region: Ialaska .► 1 C Latitude/Longitude 'Decimal Degrees C Latitude/Longitude 'Decimal Degrees .'.l C UTM Zone: 1 r South C UTM Zone: ITrue I— South a State Plane Zone: 4 Units: us•ft . C State Plane Zone: 4 Units: us-ft C Legal D e s rrprirarr INAD27 r nl J 4` Legal Description(NAD27 only) Starting Coordinates: Legal Description . s X: 11701902.00 Township: 012 fr.4- . Range: 1010 1 E Y: 5977736,00 Meridian: U „ Section:-36 FNL 12810.6670 FEL-7,1 14334.8912 Transform i Quit I Help • • Tollerable Collision Risk Worksheet As - built REV' DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS LEGEND 4': . \HIO, 2 • EXISTING CONDUCTOR PROJECT _s.,,, 1 ARUK pWRSWP� 'LOCATION Q AS—BUILT CONDUCTOR THIS SURVEY �� lrGRAPHIC SCALE CPF1 4 C 0 103 200 403 k 10 PIT So�� 11 . 12 1 inch = 200 ft. . C , • 2+1 • ' �0 11 12 -TO 16 15 14 13 I. L .i 1D x .. rir i o D4 • oco A. IIIIII • N. ® .. ^O •• ,\O co 0 • ,,/ �q, O^ • O O O • g • N. ,pc • cb s ® ^�,�,_ • o,. 0 •� h0ti/ • °� 0• . ti 40' • N.®®N ci-,' � • • •.cep • •� 40 / ( ti:o 883' 30 SEE SHEETS 2 & 3 FOR NOTES AND oz., LOCATION INFORMATION. S:,1. '0 ®®`�®®\\\\®®Ra If • �?: ( ® SURVEYOR'S CERTIFICATE N.i' Ae- 0 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERD AND LICENSED ' '9th ' •••••: •® TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND 0 THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER =JEREMIAH F. CORNELL;' o� MY DIRECT SUPERVISION AND THAT ALL NEW DIMENSIONS AND ®®s LS-12663 :'��o OTHER DETAILS PER THIS REVISION . ,P,,, -... 44.%...r� • f/ ` c;„ ARE CORRECT AS OF JULY 16, 2015. LOUNSBURY ee0 pP\_ .7 SURVEYORS yASSOCIATES INC.ERS )111•,i AREA:1C MODULE: XXXX UNIT: D1 ConocoPhillipsDS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6103d31 6/30/01 CEA—D1 CX-6103D31 1 OF 3 13 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIP110N 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12, T11N, R1OE NAD27 NAD27 Section WELLASP Coordinates Geographic Coordinates Offset Elev. No. 'Y' 'X' LATITUDE LONGITUDE F.N.L F.W.L PAD 0.G. 1 5,968,523.00 562,372.00 N 70'19'28.291" W 149'29'39.295" 1,717' 1,363' N/A N/A 2 5,968,590.00 562,271.00 N 70'19'28.958" W 149'29'42.227" 1,649' 1,263' N/A N/A 3 5,968,656.00 562,172.00 N 7019'29.615" W 149'29'45.100" 1,582' 1,164' N/A N/A 4 5,968,727.00 562,065.00 N 70'19'30.322" W 149'29'48.207" 1,510' 1,058' N/A N/A 5 5,968,793.00 561,965.00 N 70'19'30.979" W 149'29'51.110" 1,442' 958' N/A N/A 6 5,968,860.00 561,864.00 N 70'19'31.647" W 149'29'54.042" 1,375' 859' N/A N/A 7 5,968,926.00 561,765.00 N 70'19'32.304" W 149'29'56.916" 1,308' 760' N/A N/A 8 5,968,993.00 561,664.00 N 70'19'32.971" W 149'29'59.848" 1,240' 660' N/A N/A 9 5,968,851.99 561,548.05 N 70'19'31.593" W 149'30'03.267" 1,381' 542' N/A N/A 10 5,968,763.33 561,680.92 N 70'19'30.711" W 149'29'59.409" 1,471' 674' N/A N/A 11 5,969,008.74 561,641.06 N 70'19'33.128" W 149'30'00.514" 1,225' 637' 60.4' 55.0' 12 5,969,000.20 561,653.40 N 70'19'33.043" W 149'30'00.156" 1,234' 649' 60.4' 55.1' 13 5,968,842.13 561,891.29 N 70'19'31.469" W 149'29'53.250" 1,394' 885' 60.4' 55.0' 14 5,968,672.21 562,146.39 N 7019'29.777" W 149'29'45.844" 1,566' 1,139' 60.4' 55.0' 15 5,968,605.15 562,247.15 N 70'19'29.109" W 149'29'42.919" 1,634' 1239' 60.3' 55.0' 16 5,968,825.37 561,916.31 N 70'19'31.302" W 149'29'52.523" 1,411' 910' 60.3' 55.0' 17 5,968,838.00 561,568.78 N 70'19'31.454" W 149'30'02.665" 1,395' 563' 60.5' 56.2' 18 5,968,758.80 562,016.22 N 70'19'30.639" W 149'29'49.623" 1,478' 1,010' 60.4' 55.0' 19 5,968,624.28 562,368.18 N 70'19'29.287" W 149'29'39.382" 1,616' 1,360' 59.1' 52.3' 20 5,968,622.03 562,222.10 N 70'19'29.277" W 149'29'43.646" 1,601' 1,191' 60.3' 55.0' 21 5,968,637.75 562,198.12 N 70'19'29.434" W 149'29'44.342" 1,617' 1,214' 60.6' 55.0' 22 5,968,646.48 562,334.93 N 70'19'29.508" W 149'29'40.347" 1,593' 1,327' 59.1' 51.6' 23 5,968,579.61 562,285.45 N 70'19'28.855" W 149'29'41.807" 1,660' 1,277' 60.3' 55.2' 24 5,968,571.44 562,297.94 N 70'19'28.773" W 149'29'41.445" 1,668' 1,290' 60.3' 55.2' 25 5,968,546.47 562,335.47 N 70'19'28.525" W 149'29'40.355" 1,693' 1,327' 60.2' 55.0' 26 5,968,538.05 562,347.93 N 70'19'28.441" W 149'29'39.994" 1,702' 1,339' 60.2' 55.0' 27 5,968,529.79 562,360.58 N 70'19'28.358" W 149'29'39.626" 1,710' 1,352' 60.2' 55.0' 28 5,968,689.43 562,121.21 N 70'19'29.948" W 149'29'46.575" 1,548' 1,114' 60.6' 55.0' 101 5,968,821.46 561,593.72 N 70'19'31.289" W 149'30'01.941" 1,412' 588' 60.6' 56.7' NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS1C MONUMENTATION LOUNSBURY PER LOUNSBURY & ASSOCIATES. & AssoCIATEs, INC. 2. COORDINATES SHOWN ARE ASP, ZONE 4, NAD27 SURVEYORS ENGINEERS PLANNERS 3. ELEVATIONS ARE BPMSL AREA:1C MODULE: XXXX UNIT: D1 ConocoPhillipsDS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6103d31 6/30/01 CEA-D1 CX-6103D31 2 OF 3 13 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 12 7/17/15 JAH SZ Rev. Per K150013ACS 13 8/21/15 NRB JAH Rev. Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 12, T11N, R1OE NAD27 NAD27 Section WELL ASP Coordinates Geographic Coordinates Offset Elev. No. 'Y' 'X' LATITUDE LONGITUDE F.N.L F.W.L PAD O.G. 102 5,968,813.50 561,606.18 N 70'19'31.210" W 149'30'01.579" 1,420' 600' 60.6' 56.7' 104 5,968,796.65 561,631.04 N 70'19'31.042" W 149'30'00.857" 1,437' 625' 60.6' 56.7' 106 5,968,779.74 561,656.61 N 70'19'30.874" W 149'30'00.115" 1,454' 650' 60.7' 56.7' 109 5,968,746.59 561,706.13 N 70'19'30.544" W 149'29'58.678" 1,487' 699' 60.7' 56.6' 111 5,968,730.13 561,731.01 N 70'19'30.380" W 149'29'57.955" 1,504' 724' 60.7' 56.5' 113 5,968,713.56 561,755.87 N 70'19'30.215" W 149'29'57.234" 1,521' 749' 60.7' 56.5' 115 5,968,696.96 561,780.86 N 70'19'30.050" W 149'29'56.508" 1,538' 774' 60.7' 56.4' 117 5,968,680.39 561,805.95 N 70'19'29.885" W 149'29'55.780" 1,555' 799' 60.8' 56.3' 119 5,968,664.02 561,830.61 N 70'19'29.722" W 149'29'55.064" 1,571' 823' 60.8' 56.2' 121 5,968,646.80 561,856.20 N 70'19'29.550" W 149'29'54.321" 1,589' 849' 60.8' 56.1' 123 5,968,630.35 561,880.54 N 70'19'29.387" W 149'29'53.614" 1,605' 873' 60.8' 55.9' 125 5,968,613.75 561,905.78 N 7019'29.221" W 14929'52.882" 1,622' 898' 60.8' 55.8' 127 5,968,597.14 561,930.71 N 70'19'29.056" W 149'29'52.158" 1,639' 923' 60.8' 55.7' 129 5,968,580.60 561,955.57 N 70'19'28.891" W 149'29'51.436" 1,656' 947' 60.8' 55.6' 131 5,968,563.88 561,980.83 N 70'19'28.725" W 149'29'50.703" 1,673' 973' 60.8' 55.5' 133 5,968,547.28 562,005.48 N 70'19'28.559" W 149'29'49.987" 1,690' 997' 60.8' 55.4' 135 5,968,530.55 562,030.50 N 70'19'28.393" W 149'29'49.261" 1,707' 1,022' 60.8' 55.5' 150 5,968,712.22 562,235.32 N 7019'30.163" W 14929'43.239" 1,527' 1,228' 58.2' 52.5 151 5,968,922.96 561,919.46 N 70'19'32.261" W 149'29'52.408" 1,313' 914' 58.4' 55.0' *152* 5,968,956.10 561,869.93 N 70'19'32.591" W 14929'53.846" 1,279' 865' 57.6' 55.0' *153* 5,968,939.48 561,894.98 N 7019'32.426" W 149'29'53.118" 1,296' 890' 57.6' 55.0' *154* 5,968,757.31 562,168.40 N 70'19'30.612" W 149'29'45.181" 1,481' 1,162' 57.6' 53.2' *155* 5,968,690.68 562,268.34 N 7019'29.948" W 14929'42.280" 1,548' 1,261' 57.6' 52.2' 170 5,968,823.66 562,068.55 N 70'19'31.273" W 149'29'48.080" 1,414' 1,063' 59.1' 54.1' 172 5,968,801.43 562,101.96 N 70'19'31.051" W 149'29'47.110" 1,436' 1,096' 59.1' 53.8' 174 5,968,779.41 562,135.06 N 70'19'30.832" W 149'29'46.149" 1,458' 1,129' 59.2' 53.5' 178 5,968,735.16 562,201.72 N 70'19'30.391" W 149'29'44.214" 1,503' 1,195' 59.2' 52.9' 184 5,968,668.66 562,301.70 N 7019'29.729" W 14929'41.311" 1,571' 1,294' 59.1' 51.8' 190 5,968,602.07 562,401.26 N 7019'29.066" W 149'29'38.421" 1,638' 1,393' 59.1' 51.5' ** ASBUILT CONDUCTOR THIS SURVEY LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS `V AREA:1C MODULE: XXXX UNIT: D1 ConocoPhillips DS1C WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: LK6103d31 6/30/01 CEA-D1 CX-6103D31 3 OF 3 13 • • Häagen Dazs Necessary Plan Request (NPR) r i Initiated by: Kelsey Hallford Date: 10/20/2014 Contact Information: 907-440-0004 Need by: 10/27/2014 for Event: FEL3 Well Name:1C-154 Placeholder Well Name: 1C-154 As-built available?No Planned Slot/Surface Location: Y/N: X/E: Z: a! -_•"qt NAD: 83 Rig:Other Doyon 25 Air Gap: 39.5 Inclination Profile:Horizontal Pilot Hole?: No Laterals?: Single New Hole from:Surface Number of Hole Sections: 3 Strings C C 20 x 42 80.00 TVD Formations Depths M-Motor , Base Permafrost 1800.00 Tvo Max Dogleg: 4.0 Limit Steering in this Hole Section?: No/Yes SI S iU u r' r f' a a e c e e 10 3/4 x 13 1/2 2400 TVD M-Motor Pump Tangent: No Max Dogleg: 5.o Limit Steering in this Hole Section?: No Top of Pool/Production Interval: • Name MD/TVD Depth Type Bottom of Pool/Production Interval: • Name MD/TVD Depth Type 7 5/8 x 9 7/8 MD/TVD Depth Type 88° Targets Y/North _ X/Eest Z/Depth Inclination° BHA Top WSD 5970806.00 1703723.00 ## TVDSS 85 I Max Dogleg: T1 Landing 5971096.00 1703646.00 #4 TVDSS 90 Dogleg T2 5972392.00 1703304.00 ## TVDSS 90 ° 13 5973302.00 1703063.00 ## TVDSS 90 ° i Horizontal By: MD/TVD Depth Type 90 14 5974429.00 1702764.00 ## TVDSS 90 ° Lineup with Toe at Heel? Yes 15 5975698.00 1702432.00 #4 TVDSS 90 ° 16 5976769.00 1702145.00 ## TVDSS 90 ° TD 5977736.00 1701902.00 ## TVDSS 90 ° Bottom Hardline: Name MD/TVD Depth Type 90° 41/2 x 63/4 Geology/Reservoir Comments: Drilling/Completion Comments: David Lee Well Plannin.Notes:For Official Use ONLY Surface Coordinates will still have to be dialed in,facilities has provided 7 surface locations to optimize directional planning for the future wells of this program(4 to be drilled this year).See attachement that contains visual of surface locations to use as reference. 1C-154(previously 1C-153)is an injector Hit Top D target at-85 degrees and land intermediate casing using same build rates at-88 degrees. TD intermediate casing-15 feet below D top Approved by: First&Last Name Date: mm/dd/yy Contact Information: ###-###-#### • 1C-154 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing 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 temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 9-7/8" Open Hole / 7-5/8" Casing 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, LCM 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 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. 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 backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. 1C-154 Drilling Hazards Summary.doc 9/9/20159:53:05 AM 1C-154 4111, Schlumberger CemCADE* Preliminary Job Design 10 3/4" Surface Casin• (V1) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 25 Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2481'MD. Client:CPAI Revision Date:September 9,2015 Prepared by:Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time:-240 min.(pump time plus 120 min.) Phone:(907)263-4207 DeepCRETE @ 11.00 ppg-1.91 ft3/100 lb sk Mobile:(907)223-8916 email:jhouston2@s1b.com 1.339 ft3/ft x 110 x 1.0(0%excess)= 148 ft3 0.3637 ft3/ft x(1874-120)x 3.50(250%excess)= 2246 ft3 < TOC at Surface 0.3637 ft3/ft x(2481-1874)x 1.50(50%excess)= 332 ft3 2246 ft3+ 148 ft3+332 ft3= 2726 ft3 2726 ft3/1.91 ft3/sk= 1428 sks(--1438 sks) Have additional 11#on location for Top Out stage,if necessary. Tail Slurry Minimum pump time:-190 min.(pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x(2981-2481)x 1.50(50%excess)= 273 ft3 0.54000 ft3/ft x 80'(Shoe Joint)= 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/1.63 ft3/sk= 195 sks Round up to 205 sks BHST=60°F,Estimated BHCT=72°F.(Based on 2.1°F/100 ft.from surface) PUMP SCHEDULE < Base of Permafrost at Stage Cumulative 1,874'MD Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW100 7.00 75.0 10.7 10.7 MUDPUSH II 7.00 75.0 10.7 21.4 Pause 0.00 0.0 5.0 26.4 < Top of Tail at 11ppg DeepCRETE 7.00 485.2 69.3 95.7 Lead 2,481'MD Surface Tail 7.00 56.3 8.0 103.7 DeepCRETE Slurry Pause 0.00 0.0 5.0 108.7 Fresh Water 7.00 10.0 1.4 110.1 Pause 0.00 0.0 5.0 115.1 Mud 8.00 159.0 19.9 135.0 Mud 3.00 100.0 33.3 168.3 Mud 1.00 10.0 10.0 178,3 < 10 3/4",45.5#casing 1 in 13.5"OH MUD REMOVAL Expected Mud Properties:9.4 ppg, Pv<20,Tv<20 TO at 2,981 MD (2,615'TVD) Spacer Properties:10.5 ppg MudPUSH`II,Pv,17-21,Ty,20-25 Centralizers: As per CPAi program. 'Mark of Schlumberger 1 C-154r CemCADE* Preliminary Job Design Schlumberger 7 5/8" Intermediate (V1 Preliminary Job Design based on limited input data.For estimate purposes only. Rig:Doyon 25 Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date:August 5,2015 Volumes are based on 20%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time:-200 min.(pump time plus 120 min.).The first Phone:(907)263-4207 49.7 bbl of slurry will be retarded to 720 min(12 hours)as per COP request. Mobile:(907)223-8916 15.8 ppg Class G+adds-1.16 ft3/sk email:jhouston2@slb.com 0.2148 ft3/ft x(5,501'-3,300')x 1.2(20%excess)= 568 ft3 Shoe Volume: 0.2578 ft3/ft x 80'x 1.00(no excess)= 21 ft3 Totals: 568 ft3+21 ft3= 589 ft3 589 ft3/1.16 ft3/sk= 508 sks(518 sks) BHST=101 °F,Estimated BHCT=79°F. (BHST calculated using a gradient of 2.1 °F/100 ft.from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) 10 3,/4",45.5#casing MUDPUSH II 6.00 40.0 6.7 ii.,_ 6.7 at 2981'MD Pause 0.00 0.0 5.0 11.7 Tail slurry+extra 6.00 49.7 8.3 20.0 retarder Tail Slurry 6.00 55.0 9.2 29.2 Pause 0.00 0.0 5.0 34.2 Fresh Water 6.00 10.0 1.7 35.9 Top of Tail at Pause 0.00 0.0 5.0 40.9 end of pumping Mud 6.00 228.9 38.2 79.1 < 3,300'MD Mud 3.00 10.0 3.3 82.4 MUD REMOVAL 7 5/8",29.7# Recommended Mud Properties:9.2 ppg,Pv<20,Tv<20. As thin and light as in 9 7/8"hole possible to aid in mud removal during cementing. Spacer Properties:11.5 ppg MudPUSH°II, Pv=25-30,Tv,30-40 Centralizers: As per CPAi program TD at-5,501'MD (3847 TVD) •Mark of Schlumberger • • >, N l C 6) r•, N 1111 -o to 'oil ,b 'o a 1111 N II11 a, N 0,.;..9 a,pip 4) Q V\C . i 1 OnC V II edC M .;O 111 1.0 N r-- 111 N^ III 4 III 4 @l III I1 III FH ill II II II II II II Il IN 11 U II 0 _ II � b T I1 0 �"Tr. b tin II . • IW l 7L-.) ^©^ bo o i 00 FSI6. U - O f � Q� _ O 11 M ��....�� •--� N E) q II Jur X .4 Ti X C O `VA • P a "Fi r4 6 y0 00 O fii ."Z Q cA F 11111 1O1 .. VN 1 11111 b 111X lilkin t] a — . 11111.. M ' liv Q - lilt] o 11 l x -" co C o 3 c7 @ ei in ^ + L '", vi a N X6.0 a.�O E- 7 C Gibo A E-+ b)' O, U O b Zo cn Q IIPP" so M �Q� I: ,f 00 - �' F-+ ' t x 7 N - co op p --, E-. M gH a X x � 1111111' tec D oo s� L V 5 M M a N 9 t` ct M G V E~ bE� a xNb 'n N cri p �p M y0 7 -' ,4 . N c•-) N z M ra0, 'r1�-\E•-i O O O 00 N V U 4M +V rn X -"N . v M U E Z O '111:' 1C-154 Plan Schematic WP04 i±,.;I:UI'III:NI::I:;11'`Il'11Ili'Ili,11.1 Well Schematic 1C-154(Injector) 10/09/2015 K.Hallford • • Prudhoe Bay Unit It Kuparuk PAS ADL025638 ADL047449 CP• CPAI, A, BPXA, EVRON, CHEVRON, XON MOBIL EXXON MOBIL 3/27/1984 9/30/1979 ■rr■■■■rrr■■■r■i 2560 2459 ■ ✓ ■ ■ I ■ ■ Q■ ■ s_�xawnr� + vuxawxa ■ c� LYt#dsaa ak!N1'fdtlaRiRP2a+�.-�www- ^:^" u�t�ssa_ aae a+ff/p. - '.i 7§77?��^x er. ■ n w ■ 01 Cl)' -07q NI ■ ■ .1111111111•MEN co • a ■ ■ ■ i` ■ a , a o R▪4DL025649 V ADL028242 a CPAI, 6 NCI CPAI, a a BPXA, BPXA, +DMIIEGRI�q�■■ a i CHEVRON, EXXON MOBILEXXON MOBIL 3/27/1984 a KuparukI3/27/1984 2560 River Unit 2469 1 : 0 : • • Doyon 25 BOP Configuration Well* Top of R(Italy Table a a# a a V 1 1315/8,.5hsllrt SM Annular e 13-5/B ShaBer 5M 9-S g" Casing Rams I 1 13-5,/8 Shaffer SM Bind Rains 11 NCR MANUAL, MANUAL NCR A �.�,.�.. Mud�Cro u•IEDII : Kill line CFic3se Line I-g ® 33-5/4° Shaffer (V ♦. I--- . 2-7(S°x S'V6R Rine Rama 1 I • • I °❑ --`-- --� 1 1 73 rm rf o • < x U m i d � L I �I it \ _ LLJn O D o L7 0 12 11 Emu ■ o ; C1178 ■ — —101 .--- o =102 ^ o ❑104 — r I ❑106 7 ❑ ❑10 - 01 09 — 152 0 ❑111 v 111113 -153 0 6 ❑ ❑115 -151 0 13 ❑ F 011 16 1= - rim O ❑119 / /� i 1711210 5 0123 II) ■I 1r] i m z MI I ❑125 18■i Ili M A 0127 I) i x < A 111129 �;\IIl ■ m N ❑131 1qj� • r N ❑133 ila r7 ❑135 `qi►:���� n , \ 'w‘I'lli '-u. D = 21 ❑ 150 0 _ 20❑ 155 0 15 III- 11184 1=12 ■ 1 m2234711_ .1122 ❑ D F, 19 ❑ g 251 _. o — 2617 111 z — 27M1— 1 ■ N 1 ■ N - 0 1 i . Z o N r O N y M M C, 5 • Bettis, Patricia K (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Thursday, September 17, 2015 2:06 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1C-154: Permit to Drill Application (PTD 215-166) Hello Patricia, We are not planning on pre-producing the well. We will flow it back to clean up the solids in the lateral which we expect to take 1-2 days. Let me know if you have further questions, Kelsey Hallford ATO Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsey.hallfordcop.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: 16 September 2015 13:56 To: Hallford, Kelsey Subject: [EXTERNAL]KRU 1C-154: Permit to Drill Application (PTD 215-166) Good afternoon Kelsey, Does ConocoPhillips plan to pre-produce KRU 1C-154; and if so,for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, September 16, 2015 1:56 PM To: Kelsey.Hallford@conocophillips.com Subject: KRU 1C-154: Permit to Drill Application (PTD 215-166) Good afternoon Kelsey, Does ConocoPhillips plan to pre-produce KRU 1C-154; and if so,for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: a/S- _Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: / Je POOL: Xvley.44 P Jr W k,s, `moi (Jr 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 V Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 ! 0 El co 0, p a) a y y o , ° rn ' TD E Q L a�,a a c =� as� w. °Ni o CD 3N of L m CD 0 c _ y 3 CO ` U a y a). 3. N. 1:' a). of d c a v_i 3 (ten Q 10; 3 0, , , U N ° , �, .- co w O M: (j Z w e a)' m' w o ,0 o. w, J, m °' a 0, _ m , o: CO D � o� O 8 c o � m a) � C. aai °�°l d' , y' , c9' a > ' a' ' Y' ' •V� O , O' .0, , p: ' 0 ' 4Y U' O) ' 0' .°, as 04, a c ° Q, p. N a �0 4 y •o X ' 0, �, V ar L Y 2 � 3 EO. @ N' TA � 'O� U v C3, O a c �, ° 3ifiy p, 'y 3 4 E, 'c a) a) >, w C, 30 y. y. 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