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216-020
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3S-613 KUPARUK RIV UNIT 3S-613 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3S-613 50-103-20735-00-00 216-020-0 G SPT 5146 2160200 1500 2250 2250 2250 2250 90 93 93 93 4YRTST P Kam StJohn 8/13/2022 Good Test 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 3S-613 Inspection Date: Tubing OA Packer Depth 280 1750 1685 1675IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220813200218 BBL Pumped:2.1 BBL Returned:1.8 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:54:29 -08'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 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 was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 STATE OF ALASKA � �� � AL.OIL AND GAS CONSERVATION COMMI�N REPORT OF SUNDRY WELL OPERATIONS DEC 1 Z 2017 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing H io shutdown LI Performed: Suspend El Perforate ❑ Other Stimulate ❑ Alter Casing 111C a ge pproved Program ❑ Plug for Redrill ❑ ,erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: VJij./1 JAG. DA 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 216-020-0 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-103-20735-00 7.Property Designation(Lease Number): 8.Well Name and Number: MORTRO3 3S-613 ADL 25528,25544,380107 ll/ 4 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Torok Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,782 feet Plugs measured None feet true vertical 5,196 feet Junk measured None feet Effective Depth measured 15,782 feet Packer measured 10,909 feet true vertical 5 796 feet true vertical 5,146 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 120 120 Surface 2,862 15 2,901 2,571 Intermediate 11,044 8 11,082 5,163 Production Liner 4,740 7 15,650 5,219 Perforation depth Measured depth 11,491 -15,122 feet SCANNED •JAN 1 9 21118 True Vertical depth 5,191 -5,210 feet Tubing(size,grade,measured and true vertical depth) 4.5 L-80 10,914'MD 5,147'TVD Packers and SSSV(type,measured and true vertical depth) Baker HRD-E ZXP 10,909'MD/5,146'TVD No SSV 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: 450 600 1100 Subsequent to operation: 500 425 2185 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Service E Stratigraphic Q Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ :; }DSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317. —55'g Contact Name: Lynn Aleshire Authorized Name: Lynn Aleshire Contact Email: Lynn.Aleshire@conocophillips.com Authorized Title: Petroleum Engineer �o / . Authorized Signature: Cati.Vt/t, Date: 12-1L 1 10 Contact Phone: (907)265-6525 //7-/i Form 10-404 Revised 4/2017 . ' Ri6D� s L' i„ 1 201/ Submit Original Only 400 ��/ L Gov o / • ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 December 12, 2017 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3S-613 (PTD# 216-020-0). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, (ire. a44:4_, Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed Schematic 1 • 3S-613 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/07/17 Well SI for PFOT, WAG to gas injection to follow. Freeze protect flowline and tubing. 11/21/17 Well BOL on gas injection. First WAG cycle for Torok. KUP I 3S-613 ConocoPhillips a Well Attribut Max Angleilk TD Ada L IlIt:. Wellbore API/UWI Field Name Wellbore Statusmel 0 MD(ftKB) Act Btm(ftKB) igrp, 501032073500 TRACT OPERATION MORTR03 INJ J 92.37 12,863.09 15,782.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-3s-613,12/12/20176:27;00 AM SSSV: NONE Last WO: 39.77 5/24/2016 Vadaal srhemabc(WWaQ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;34.7 Last Tag' Rev Reason:MILLED OUT FRAC SLEEVE's pproven 8/9/2016 asing rings `i�I ,.II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 40.0 120.0 120.0 164.80 B-35 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 38.8 2,901.0 2,571.1 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;40.0-120.0 INTERMEDIATE 75/8 6.875 37.6 11,0820 5,163A 29.70 L80 H563 1I1'1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;2,716.3 L.it LINER 41/2 3.958 10,909.1 15,649.5 5,199.0 12.60 L-80 IBTM I I Liner Details SURFACE;38.8-2,901.0 To Nominal ID p(BKB) To p(TVD)(ftKB) Top Mel 0 Item Des Com (In) 10,909.1 a4.910 • (10.99' a GAS LIFT;8,805.3 al 1• 1 :1 Hyd 4.910 563 box x 10,931.7 5,149.2 83.09 HANGER Baker 5.5"rx 7.625"Flex-Lock Liner hanger L-80 4.840 Hyd 563 pin x pin GAUGE;10,791.1 -- 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 10,987.9 5,155.4 84.27 NIPPLE Nipple,Camco 3.75"DB-6,SN: 3656-2 1 NIPPLE,10,856.8 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer"-"H" SN:50494-001-24 3.900 PACKER Locator;10,913.6 9ti 11,491.3 5,190.5 86.27 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.650 4 1 350") PN:10495006 Seal Assembly;10,915.0 I (MILLED OUT 6/23/16) 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer"-"G" SN:50494-001-30 3.900 : ; PACKER 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.650 3.375") PN:10495002 �p (MILLED OUT 6/23/16) AffIli ?6 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer"-"F" SN:50494-001-26 3.900 PACKER INTERMEDIATE;37.6-11,082.0 12,699 0 5,219.3 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.650 3.25")PN:10495003 (MILLED OUT 6/23/16) IN 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-19 3.900 a PACKER Hydraulic Fracture,11,401.013,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 p� 3.125")PN:10495005 (MILLED OUT 8/8/2016) 13,593.4 5,197.1 9048 SWELL Baker-"Swell Packer"-"D" SN:50494-001-3 3.900 In PACKER 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 3.00")PN:10495008 (MILLED OUT 8/8/2016) Hydraulic Fracture,12,114.0 I I 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer"-"C" SN:50494-001-35 3.900 PACKER 14,497.4 5207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2937 2875")PN:10495004 (MILLED OUT 8/8/2016) 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer"-"B" SN:50494-001-45 1900 Hydrautc Fracture:126990 i;i PACKER 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Drift w/ 2.812 2.00")PN:10495007 (MILLED OUT 8/8/2016) MI 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN:50494-001-27 3.900 CD PACKER 15,595.4 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 Hydraulic Fracture;13,323.0 1 I 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1 25"Ball) 1.000 ,yam Tubing Strings u'=? Tubing Description Ma...ID Oct Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection • 4-1/2"TUBING 1String 41/2) 3.9581 34.71 10,964. 71 5,153.01 12.601 L-80 !Top 563 am Completion Details Nominal ID Hydraulic Fracture;13.911.0 I RITop INKS) Top(TVD)(ftKB) Top Inel CI Item Des Com 0.00 HANGER Hanger,FMC,TC-1A-EMS, (in) 34.7 34.7 11"x 4-1/2"IBT,4"H BPVG, 3.958 with 2 contorl line ports II 10,791.2 5,128.9 80.50 GAUGE Gauge Carrier,SLB,SGM with Sapphire tubing pressure 3.864 gauge,SN:C12GM-0194 Ill iv 10,856.6 5,139.2 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN: 3654-11 3.813 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22 192-47(bottom of the 3.870 Hydrawlc Fracture:14.497 0 I II locator spaced out 4.86') °k 10,915.1 5,147.1 82.75 Seal Seal Assembly,Baker,192-47 3.870 Assembly i • Stimulations&Treatments • Proppant Designed(Ib) Proppant In Formation(lb) 193,900.01 193,900.0 6/5/2016 6/5/2016 Stimulations&Treatments Hydraulic Fracture,15,122.0 I.'.I Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date SIim/Treat Fluid (bbl) Vol Slurry(bbl) 1 15,595.0 15,596.0 6/5/2016 Hybor G,Gelled Salt Water 4241.00 4432.00 2 15,122.0 15,123.0 6/5/2016 Hybor G,Gelled Salt Water 2979.00 3175.00 11. Proppant Designed(lb) Proppant In Formation(lb) I Date Ix 195,200.01 195,200.0 6/8/2016 II I Stimulations&Treatments Hydraulic Fracture;15,595.0 Vol Clean Pump Stg 0 Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) • 3' 14.497.0 14,498.0 6/8/2016 Hybor G,Gelled Salt Water 299300 3185.00 . 4 13,911.0 13,912.0 6/8/2016 Hybor G,Gelled Salt Water 2654.00 2846.00 LINER;10.909.1-15,649.5 T "ilk KUP 11, 3S-613 ConocoPhillips Phasic:;.It t; Conocat'hiuips ••• HORIZONTAL 3S-613,12112/2017627;01 AM VartcH ec tabc.jactlel) HANGER;34.7 1• ` Stimulations&Treatments a I,. :I1 Vol Clean Pump Stg# Top(ftKB) Btm(RKB) Data Stim/Treat Fluid (bbl) Vol Slurry(bbl) 5 13,323.0 13,324.0 6/8/2016 Hybor G,Gelled Salt Water 3016.00 3209.00 Proppant Designed(Ib) Proppant In Formation)lb) Date 193,900.0 193,900.0 6/11/2016 CONDUCTOR,400-120.0 g Stimulations&Treatments me GAS LIFT,2,716.3 t; Vol Clean Pump Stg if Top(RKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(PCI) I p 6 12,699.0 12,700.0 6/11/2016 Hybor G,Gelled Salt Water 2888.00 3080.00 SURFACE;38.8-2,901.0 fl 7 12,114.0 12,115.0 6/11/2016 Hybor G,Gelled Salt Water 2785.00 2977.00 8 11,491.0 11,492.0 6/11/2016 Hybor G,Gelled Salt Water 2904.00 3099.00 • Mt Mandrel Inserts GAS LIFT',8,605.3 1. St I ati Top(TVD) Valve Latch Port Size TRO Run Top(ttK8) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,716.3 2,456.7 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,742.0 6/30/2016 GAUGE;10,791.1 -- a 2 8,605.3 4,536.2 Camco KBMG 1 GAS LIFT OV BK 0.313 6/30/2016 gg NIPPLE;10856.6 _ Locator,10,913.6 AllE a Seal Assembly,10,915.0 1 a :a: I I i • INTERMEDIATE,376-11,082.0 MI •i Hydraulic Fracture 11,491.0 I!I ■ • L I Hydraulic Fracture,12,114.0 I , E- a a Hydraulic Fracture;12699.0 )•I ■ MI V Hydraulic Fracture;13,323.0 II)Y, I t I'fp Hydraulic Fracture;13911.0 I, r I II •• a Hydraulic Fracture,14,4970 I'_ IIII 1 1111 M I Hydraulic Fracture,15,122.0 MU WEI Hydraulic Fracture,15,595.0 131 iiii LINER,10,909.1-15,649.5 SOF 74 • 0w*\\\I%%'sA THE STATE Alaska Oil and Gas ofALAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF p. Main: 907.279.1433 4LA91 Fax: 907.276.7542 www.aogcc.alaska.gov Lynn Aleshire SCANNED DEC 1 5 2017 Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-613 Permit to Drill Number: 216-020 Sundry Number: 317-558 Dear Mr. Aleshire: 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, eCCLI Hollis S. French Chair DATED this 3. day of December, 2017. RBDMS 1-t_- EC 0 8 2017 0 0 RECEIVED • NOV 21 2017 STATE OF ALASKA Qtr.- (2(11 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC t 7 APPLICATION FOR SUNDRY APPROVALS C 20 AAC 25.280 1.Type of Request: Abandon LJ Plug Perforations H Fracture Stimulate H Repair Well H Operations shutdown H Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ WINJ TO WAG Other: Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.• Exploratory ❑ Development ❑ 216-020-0 " 3.Address: Stratigraphic ❑ Service Q, 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20735-00• 7.If perforating: T,►.9 8.Well Name and Number: .l1$ What Regulation or Conservation Order governs well spacing in this pool? 7 � ikx 6- A.40431031 • Will planned perforations require a spacing exception? Yes ❑ No IYI 3S-613 9.Property Designation(Lease Number): 110.Field/Pool(s): ADL 25528,25544,380107 ' Kuparuk River Field/Torok 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): 15,782' 5,196' 15,782' 5,796' 6,912 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 120' 120' Surface 2,862' 10.8" 2,901' 2,571' Intermediate 11,044' 7.625" 11,082' 5,163' Production Liner 4,740' 4.5" 15,650' 5,219' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,491-15,122 5,191 -5,210 4.500" L-80 10,914' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker HRD-E ZXP . 10,909'MD/5,146'TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic E '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0, 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/1/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 i GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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: Lynn Aleshire Contact Name: Lynn Aleshire Authorized Title: Petroleum Engineer Contact Email: Lynn.Aleshire@conocophillips.com / Contact Phone: (907)265-6525 Authorized Signature: ( A,L_j,, Date: I/2'4 ` COMMIMISSION{ION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:3 17 ✓ /7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ (�J( Other: Post Initial Injection MIT Req'd? Yes ❑ No [ RDD S u- DEC 0 2017 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /D 461 IL APPROVED BY 'Z ' Approved by: COMMISSIONER THE COMMISSION Date: CI- J A 4( Submit Form and ,I Form 10-403 Revised 4/2017 Approved application is valid for n islftMVV/�tielOtoval. Attachments in Duplicate `O (` ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 November 20, 2017 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding Service Well 3S-613 (PTD# 216-020-0). ConocoPhillips is seeking permission to change operation of this service well from water injection to WAG injection. ' The Proposal, AOR Detail and Event Summary were submitted with the previous Form 10-403 Sundry#316-501 which converted the well to water injection. There have been no new wells drilled in the area. If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, CatlitGue Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed 1 KUP 3S-613 ConocdP}11li1p5 Well Attribu Max Ant D TD Ata Inc ' Wellbore APUUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) Con0SWPhdl ps'3'''+ 501032073500 TRACT OPERATION MORTRO3 INJ 92.37 12,863.09 15,782.0 ... Comment H2S(ppm) Date Annotation End Date 1 KB-GM(ft) Rig Release Date HORIZONTAL 35813,11/21/20178:4220 AM SSSV: NONE Last WO: 11 39.77 5/24/2016 Vence/sdlemabc("'4) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;34.7 Last Tag: Rev Reason:MILLED OUT FRAC SLEEVE's pproven 8/9/2016 11 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen II...Grade Top Thread 1111 CONDUCTOR 16 15.250 40.0 120.0 120.0 164.80 B-35 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread SURFACE 103/4 9.950 38.8 2,901.0 2,571.1 45.50 L-80 TSH 563 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(L..Grade Top Thread CONDUCTOR;40.0-120.0 INTERMEDIATE 75/8 6.875 37.6 11,082.0 5,163.4 29.70 L80 H563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;2,716.3 t0 Mk LINER 4 1/2 3.958 10,909.1 15,649.5 5,199.0 1260 L-80 IBTM Liner Details Nominal ID SURFACE;38.&2,901.0 Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Cam (in) 10,909.1 5,146.4 82.64 PACKER Baker HRD-E ZXP 5.5"x 7 625"Liner Top Packer 4.910 IN (10.99'tie back sleeve;ID=5.75") GAS LIFT;8605.3 IP 10,928.9 5,148.9 83.03 NIPPLE Baker"RS".Packoff Seal Nipple,5.5",148, L-80,Hyd 4.910 563 box x box 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625"Flex-Lock Liner hanger L-80 4.840 2 Hyd 563 pin x pin GAUGE;10,791.1 -- MIR 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 it tog 10,987.9 5,155.4 8427 NIPPLE Nipple,Camco 3.75"DB-6,SN:3656-2 3.750 NIPPLE;10856.6 art 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer"-"H" SN:50494-001-24 1900 PACKER Locator,10,9136 INV 11,491.3 5,190.5 86.27 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Driftw/ 3.650 I 3.50")PN:10495006 Seal Assembly,m,9150 1t (MILLED OUT 6/23/16) s 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer"-"G" SN:50494-001-30 3.900 PACKER 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.650 3.375")PN:10495002 (MILLED OUT 6/23/16) ii( 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer"-"F" SN:50494-001-26 3.900 • PACKER INTERMEDIATE;37.6-11,092.[1 12,699.0 5,219.3' 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.650 3.25")PN:10495003 • (MILLED OUT 6/23/16) . s 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-19 3.900 is PACKER Hydraulic Fracture;11,491.0 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 r 3.125")PN:10495005 (MILLED OUT 8/8/2016) I y., 13,593.4 5,197.1 90.48 SWELL Baker-"Swell Packer"-"D" SN:50494-001-3 3.900 PACKER 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 3.00")PN:10495008 (MILLED OUT 8/8/2016) Hydraulic Fracture;12,114.0 I, I 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer"-"C" SN: 50494-001-35 3.900 PACKER • 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 • 2875")PN:10495004 • (MILLED OUT 8/8/2016) _ 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer"-"B" SN:50494-001-45 3.900 Hydraulic Fracture;12,699.0 (•I PACKER °F 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Drift w/ 2.812 I 2.00")PN:10495007 L (MILLED OUT 8/8/2016) 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN:50494-001-27 3.900 • L PACKER I 15,595.4 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 Hydra°"`Fracture 13 3:3 0 I' +I 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1.25"Ball) 1.000 u. ■ Tubing Strings k Tubing Description String Ma...ID(inl Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection i 4-1/2"TUBING 41/2 3.958 34.7 10,964.7 5,153.0 12.60 L-80 Hydril 563 • Completion Details Nominal ID I 7F Top(ftKB) Top(ND)(ftKB) Top Incl C) item Des Com (in) Hydraulic Proctors;13,911.0 *,I 34.7 34.7 0.00 HANGER Hanger,FMC,TC-1A-EMS,11"x 4-1/2"IBT,4"H BPVG, 3.958 Iwith 2 contorl line ports 8 10,791.2 5,128.9 80.50 GAUGE Gauge Carrier,SLB,SGM with Sapphire tubing pressure 3.864 • gauge,SN:C12GM-0194 • L 10,856.6 5,139.2 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN:3654-11 3.813 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22 192-47(bottom of the 3.870 Hydraulic Fracture;14,4970 I I locator spaced out 4.86') 10,915.1 5,147.1 82.75 Seal Seal Assembly,Baker,192-47 3.870 Assembly L • Stimulations&Treatments as Proppant Designed(lb) Proppant In Formation(lb) Date 8 193,900.0 193,900.0 6/5/2016 Hydraulic Fracture,15,12z.o Stimulations&Treatments H yI, I Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date StimlTreat Fluid WA Vol Slurry)bbl) 1 15,595.0 15,596.0 6/5/2016 Hybor G,Gelled Salt Water 4241.00 4432.00 • 2 15,1220 15,123.0 6/5/2016 Hybor G,Gelled Salt Water 2979.00 3175.00 Proppant Designed(lb) Proppant In Formation(Ib) Date . 195,200.0 195,200.0 6/8/2016 Stimulations&Treatments Hydraulic Fracture,15,595.0 I',; I Vol Clean Pump Stg it Top)ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) • 3 14,497.0 14,498.0 6/8/2016 Hybor G,Gelled Salt Water 2993.00 3185.00 . 4 13,911.0 13,912.0 6/8/2016 Hybor G,Gelled Salt Water 2654.00 2846.00 LINER,10,909.1-15,649.5- zori KUP 3S-613 ConocoPhillips , 8 Alaska,Inc. C.xaxoPhllhus •• HORIZONTAL-30-613,11/21/20178:42:21 AM verocal schemabc(actual) HANGER,34.7 Stimulations&Treatments • • ■ Vol Clean Pump Top(ftKB) Btm(ftKB( Date I Stim/Treat Fluid (bbl) Vol Slurry(bbl) 13,323.0 13,324.0 6/8/2016 It Hybor G,Gelled Salt Water 3016.00 3209.00 Proppant Designed(Ib) Proppant In Formation(Ib) Date 193,900.0 193,900.0 6/11/2016 CONDUCTOR;40.0-120.0 Stimulations&Treatments GAS LIFT;2,716.3 4 Vol Clean Pump Sig k Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) t l 6 12,699.0 12,700.0 6/11/2016 Hybor G,Gelled Salt Water 2888.00 3080.00 SURFACE;38.8-2,901.0 t 7 12,114.0 12,115.0 6/11/2016 Hybor G,Gelled Salt Water 2785.00 2977.00 8 11 491.0 11,492.0'6/11/2016 Hybor G,Gelled Salt Water 2904.00 3099.00 Mandrel Inserts GAS LIFT,8,605.3 0t ® atii ( N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (kKB) Make Model OD(in) Seer Type Type (in) (psi) Run Date Com 1i 1 2.716.3 2,456.7 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,742.0 6/30/2016 GAUGE;10,791.1 -- 2 8.605.3 4,536.2 Camco KBMG 1 GAS LIFT OV BK 0.313 6/30/2016 11111 NIPPLE;10,856.6 MB Locator;10,913.6 I Seal Assembly;10,915.0 fix INTERMEDIATE;37.6-11,082.0 U Hydraulic Fracture;11,491 0 IN I Hydraulic Fracture:12,1140 Hydraulic Fracture,12,699.0 11 QRp� LJ Hydraulic Fracture;13,323.0 MIN Hydraulic Fracture;13,911.0 I I U i Hydraulic Fracture,14,497.0 IMI' Hydraulic Fracture,15,122.0 II as Hydraulic Fracture;15,595.0 I I LINER;10,909.1-15,649.5 • • `'Tp2 -0Zv • Loepp, Victoria T (DOA) From: Aleshire, Lynn <Lynn.Aleshire@conocophillips.com> Sent: Tuesday, November 21,2017 4:52 PM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]Re:3S-613 WINJ to WAG Follow Up Flag: Follow up Flag Status: Flagged Thanks Victoria.The 10-403 was delivered this morning and we WAG'd to gas this afternoon. Happy Thanksgiving, Lynn From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, November 21,2017 10:30 AM To:Aleshire, Lynn<Lynn.Aleshire@conocophillips.com> Subject: [EXTERNAL]Re: 3S-613 WINJ to WAG Verbal approval is granted. Please deliver a sundry to our office by EOB Wednesday, November 22,2017. Thanx, Victoria Sent from my iPhone On Nov 20,2017,at 3:45 PM,Aleshire, Lynn<Lvnn.Aleshire@conocophillips.com>wrote: Victoria, Per our conversation,ConocoPhillips is requesting verbal permission to WAG Service Well 3S-613 (PTD 216-020-0)to gas injection.The current status in your system is WINJ.A Sundry Application Form 10-403 will follow tomorrow. Regards, Lynn Aleshire Lynn Aleshire I Petroleum Engr 3HGS&Subsidence I ConocoPhillips Alaska 1700 G St.ATO 1348,Anchorage,AK 99501 Office:(907)265-6525 I Mobile: (907)240-2583 SCANNED . ! Well BLANK CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis Top of 7"Otis I 0.0 ft 1111,7---71111--CDR2 Rig's dip Pan Distances from top of riser Excluding quick-test sub 7-1/16"5k Flange X 7"Otis Box Top of Annular ( 6.0 ft z.____24 Hydril 7 1/16" Top of Annular Element 6.7 ft Annular Bottom Annular 8.0 ft J Blind/Shear CL Blind/Shears I 9.3 ft I I 2-3/8'Pipe/Slips CL 2-3/8"Pipe/Slips 10.1 ft ► 0 B1 B2 B3 I 84 L.noxe tare Kill Line "a *: i PP in 6 ♦ 1' "" bra k.. 41.4'ft4 crossiMl Hta, B raa11MN1A1MMly 1 Ili 2-3/8"x 31'2"VBRs 4. CL 2-3/8"x 3-1/2"VBRs I 12.6 ft IMr► 2-3/8'PipelSlips ille Po Pir CL 2-3/8"Pipe/Slips I 13.4 ft I ► ..,-. N. ' Pr Pr L CL of Top Swab 16.0ft =—Swab Test Pump Hose • ai T1 ifT2 CL of Flow Cross 17.4 ft •� �• AI ` Master CL of Master 18.8 ft LDS „ „ ,. -. 1:1 . IA II, II tl II II MAL. III 11 II II II '41' I: OA II ii II ii II 41111111 LDS Ground Level I I STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON E 1 VE D REPORT OF SUNDRY WELL OPERATIONS Nt1 0 2017 1.Operations Abandon U Plug Perforations Li Fracture Stimulate U Pull Tubing ❑ ..- a'•n hutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate - = 'r ,'ro ram ❑ Alter Casing ❑ g ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ WINJ ❑., 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 216-020-0 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-103-20735-00 7.Property Designation(Lease Number): 8.Well Name and Number: MORTRO3 3S-613 ADL 25528,25544,380107 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Torok Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,782 feet Plugs measured None feet true vertical 5,196 feet Junk measured None feet Effective Depth measured 15,782 feet Packer measured 10,909 feet true vertical 6,796 feet true vertical 5,146 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 120 120 Surface 2,862 10.75 2,901 2571 Intermediate 11,044 7.625 11,082 5163 Production Liner 4,740 4.5 15,650 5219 Perforation depth Measured depth 11,491 feet True Vertical depth 5,190 feet Tubing(size,grade,measured and true vertical depth) 4.5 L-80 10914 5147 Packers and SSSV(type,measured and true vertical depth) Camco Nipple: 10,857'MD,5139'TVD Baker HRD-E ZXP: 10,909'MD,5146'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED DEC 1 5 2017 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: 400 540 100 800 340 Subsequent to operation: 1400 600 1000 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Service ❑✓ Stratigraphic Li Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL Li Printed and Electronic Fracture Stimulation Data ❑ GSTOR Li WINJ 0 WAG ❑ GINJ Li SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-501 Contact Name: Lynn Aleshire Authorized Name: Lynn Aleshire Contact Email: Lynn.Aleshire@conocophillips.com Authorized Title: Petroleum Engineer Authorized Signature: Date: 11/1,0`� Contact Phone: (907)265-6525 AAA: irri..-- JZ1 71/ Form 10-404 Revised 4/2017 ` �� �RECbVIS 1 .i € OV 2 2 2017 Submit Original Only ConocoPhillips ConocoPhillips Alaska, Inc. RECEIVED 700 G St. NOV 2 0 2017 Anchorage, AK 99501-3448 AOGCC November 20, 2017 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3S-613 (PTD# 216-020-0). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, (A4r OPht-1 Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachmei its. Sundry Report Description of Work Completed 1 • • 3S-613 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/20/16 Pulled OV © 8605' RKB. Pulled GLV @ 2716' RKB and set DV. Circ out w/diesel and freeze protect. 09/21/16 Set DV @ 8605' RKB. MIT-IA passed. 10/01/16 Placed on water injection, 950 BWPD. KUP PROD 3S-613 Conoc©Philtips1Well Attributes Max Angle&MD TD ' i'' Wellbore API/UWI Field Sante Wellbore Status Inc!(°) MD(ftKB) Act Btm MK B) RlaSka,lnC, : tT_wcanpa 501032073500 TRACT OPERATION MORTRO3 PROD 92.37 12,863.09 15,782.0 PlY ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-39-613,819/20164:07.05 PM SSSV:NONE Last WO: 39.77 5!24/2016 Vertical scnamatic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;34.7 -41Wou Last Tag: Rev Reason:MILLED OUT FRAC SLEEVE's pproven 8/9/2016 Casing Strings 111111.1M `.:': Cas'ng Description OD(!n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I Grade Top Thread ��. CONDUCTOR 16 15B)40 (ft120KB) VD)120.0 164.80 5-35 Top Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 10 3/4 9.950 38.8 2,901.0 2,571.1 45.50 L-80 TSH 563 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR,40.0.120.0 111 INTERMEDIATE 75/8 6.875 37.6 11,082.0 5,163.4 29.70 L80 H563 ME Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread GAS LIFT;2,716.3 ": 41/2"LINER 41/2 3.958 10,909.1 15,649.5 5,199.0 12.60 L-80 IBTM dit I r Liner Details SURFACE;38.8-2.901,0III Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com N(in)I ID 10,909.1 5,146.4 82.64 PACKER Baker HRD-E ZXP 5.5"x 7.625"Liner Top Packer 4.910 (10.99'tie back sleeve;ID=5.75") NI GAS LIFT;8,605.3 'iInt 10,928.9 5,148.9 83.03 NIPPLE Baker"RS"Packoff Seal Nipple,5.5",14#,L-80,Hyd 4.910 111 563 box x box 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625"Flex-Lock Liner hanger L-80 4.840 M Hyd 563 pin x pin GAUGE;10,791.1IR- 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 sm 10,987.9 5,155.4 84.27 NIPPLE Nipple,Camco 3.75"DB-6,SN:3656-2 3.750 NIPPLE;10,856.6 ." 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer"-"H" SN:50494-001-24 3.900 PACKER Locator;10,813.6 p>����+ 11,491.3 5,190.5 86.27 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.650 F1 3.50")PN:10495006 (MILLED OUT 6/23!16) Seal Assembly;10,915.0 F.01 11 gm, 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer"-"G" SN:50494-001-30 3.900 PACKER iii 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.650 3.375")PN:10495002 (MILLED OUT 6/23/16) 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer'-"F" SN:50494-001-26 3.900 HMI PACKER INTERMEDIATE;37.6-11062 0 ( 12,699.0 5,219.3 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Bali,Drift w! 3.650 3.25")PN:10495003 (MILLED OUT 6/23/16) • 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-19 3.900 Ire,, PACKER 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w! 3.187 Hydraulic Fracture:11,491.0 I I 3.125")PN:10495005 (MILLED OUT 8!8/2016) I tea 13,593.4 5,197.1 90.48 SWELL Baker-"Swell Packer'-"D" SN:50494-001-3 3.900 PACKER 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 xr 3.00")PN:10495008 (MILLED OUT 8/8/2016) Hydreuhc Fracture;12.114.0 I Fes.I 14,220,4 5,201.1 88.95 SWELL Baker-"Swell Packer'-"C" SN:50494-001-35 3.900 PACKER 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 2.875")PN:10495004 - (MILLED OUT 8/8/2016) Ir(i 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer"-"B" SN:50494-001-45 3.900 PACKER Hydraulic Fracture;12,699.0 13d���y 1 I 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1•(2.875"Ball,Drift w/ 2.812 2.00")PN:10495007 m (MILLED OUT 8/8/2016) 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN:50494-001-27 3.900 ralfi PACKER - 15,595.4 5,199.9 90.98 SLEEVE 4-1)2"Baker Alpha Pressure Sleeve 3.000 Hydraulic Fracture;13,323,0 I CI I I 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1.25"Ball) 1.000 III Tubing Strings ATubing Description Stnng Ma...ID(in) Top(ftKB) Set Depth(ft..tSet Depth(TVD)(...Wt(lb(ft) Grade Top Connection 4-1/2"TUBING 4 1/2 3.958 34.7 10,964.7 5,153.0 12.60 L-80 Hydril 563 XV Completion Details I . Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) Hydraulic Fracture;13,911.0 I 01 1 I 34.7 34.7 0.00 HANGER Hanger,FMC,TC-1A-EMS,11"x 4-1/2"18T,4"H BPVG, 3.958 with 2 contort line ports 10,791.2 5,128.9 80.50 GAUGE Gauge Carrier,SLB,SGM with Sapphire tubing pressure 3.864 gauge,SN:C12GM-0194 10,856.6 5,139.2' 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN:3654-11 3.813 I 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22 192-47(bottom of the 3.870 Hydraulic Fracture.14,497.0 plocator spaced out 4.86') `�!-'I 10,915.1 5,147.1 82.75 Seal Assembly Seal Assembly,Baker,192-47 3.870 1 Stimulations&Treatments Min Top Max Btm 1 Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (MB) (ftKB) Stg# Type Date Corn Hydraulic Fracture;15,122.0 I I 15,595.0 15,596.0 5,199.9 5,199.9 1 Hydraulic Fracture 6/5/2016 Day 1 Summary: Stages 1 and 2 complete,6 stages remain. • Total proppant pumped:392,000 lbs. 15,122.0 15,123.0 5,209.6 5,209.6 2 Hydraulic 6/5/2016 Day 1 Summary: Fracture Stages 1 and 2 complete,6 stages remain. • Total proppant pumped:392,000 lbs. Hydraulic Fracture;15,595.0 I ' 4 112"LINER;10.909.1-15,649.5 KUP PROD 3S-613 Con©coPhillips ' Alaska,Inc. O rmeal1MUtPu HORIZONTAL-30-613,8/9/2016 4:07:06 PM Vortical schematic(actual) HANGER;34.7 -2:t11k ee • Stimulations&Treatments . ,.. .+• ••,... i�l Min Top Max atm 14DRp9t7h0 14D,4ep9t8h.0 To5p,2(0TV7.D7) Btm2(0TV7) (KB (SOB) (ftKB) KB Stg Type Date Corn 3 Hydraulic 6/8/2016 Summary(June 8th,2016): Fracture Stages 3,4,5 pumped successfully;3 CONDUCTOR:40.0-120.0 111- stages remain Stages 6,7,8 will be pumped Friday GAS LIFT;2,716 3 • Total proppant pumped:583,500 lbs { • 100%of design placed into formation ( p 13,911.0 13,912.0 5,196.5 5,196.5 4 Hydraulic 6/8/2016 Summary(June 8th,2016): SURFACE;38.8-2,901.0 Il Fracture stages rams es 3,4,5 pumped successfully;3 • Stages 6,7,8 will be pumped Friday • Total proppant pumped;583,500 lbs GAS LIFT;8,605.3 • 100%of design placed into formation MI 13,323.0 13,324.0 5,200.3 5,200.2 5 Hydraulic 6/8/2016 Summary(June 8th,2016): 1' [ Fracture Stages 3,4,5 pumped successfully;3 stages remain • Stages 6,7,8 will be pumped Friday GAUGE;10,791 1 • Total proppant pumped;583,500 lbs • 100%of design placed into formation NIPPLE;10.8588 12,699.0 12,700.0 5,219.3 5,219.3 6 Hydraulic 6/11/2016 Summary(June 11th,2016): Fracture Stages 6,7,8 pumped successfully per design;job complete • Total proppant pumped:1.56 MMlbs Locator;10.913.6 I! • Total fluid pumped:24 Mbbls • 100%of design placed into formation Seal AssembN,10,915.0 12,114.0 12,115.0 5,214.6 5,214.6 7 Hydraulic 6/11/2016 Summary(June 11th,2016): Fracture Stages 6,7,8 pumped successfully per design;job complete Total proppant pumped:1.56 MMlbs • Total fluid pumped:24 Mbbls • 100%of design placed into formation 11,491.0 11,492.0 5,190.5 5,190.6 8 Hydraulic 6/11/2016 Summary(June 11th,2016): aa Fracture Stages 6,7,8 pumped successfully per design;job complete INTERMEDIATE;376-11,082.0 • Total proppant pumped:1.56 MMlbs • Total fluid pumped:24 Mbbls • 100%of design placed into formation Mandrel Inserts St ae Hydraulic Fracture,11,491 0 I I on Top(TVD) Valve Latch port Size TRO Run R Tap(RKB) (MKS) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,716.3 2,456.7 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,742.0 6/30/2016 2 8,605.3 4,536.2 Camco KBMG 1 GAS LIFT OV BK 0.313 6/30/2016 Hydraukc Fracture,12,114.0 I QI Hydraulic Fracture;12.6990 ) 0. I Hydraulic Fracture;13,323,0 I I Hydraulic Fracture',13,911 0 in I iJ Hydraulic Fracture;14,497.0 I a I Hydraulic Fracture 15,122.0 I *A9I Hydraulic Fracture;15,595.0 I I 4 1/2'LINER.10,909.1-15,649.5 61 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,November 16,2016 Jim Regg P.I.Supervisor 12ej q II I t '7416 SUBJECT: Mechanical Integrity Tests cc CONOCOPHILLIPS ALASKA INC 3S-613 FROM: Lou Grimaldi KUPARUK RIV UNIT 3S-613 Petroleum Inspector Src: Inspector Reviewed B,3,.._ P.I.Supry JPS NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3S-613 API Well Number 50-103-20735-00-00 Inspector Name: Lou Grimaldi Permit Number: 216-020-0 Inspection Date: 10/16/2016 Insp Num: mitLG161016055854 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 35-613 . Type Inj W TVD 1 5146 - JTubing 900 900 - 900 910 - PTD 2160200 . Type Test SPT Test psi I1500 - IA 1325 2000 -1 1980 - 1990- Interval "NITA"' '' P/F L P OA 652 699 i 697 704. 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UNa ) UCL N W 00Y a Z U m 0 2 it <c) ii<c) ii ii m12 owc1- c Q c nla c�la c nla c D Pr-I o W c W o W 0 Rin E Z fir/ W • IoUI� o0Lo vUl� OVIa No OQ to l OQ C } I— 'F', ' N' I aim I Nm 1 wcn0 °w a9m (ow C) Q 'iL Wm2 Wm2 Wmn: Nx towO Ni 0c . t • a d • cO cO cO m cO °� ° m m Om J 0 to 0 0 0 v._ EWE :m o LU N N N N N �p 3 0 N Cl) Z M O) ce 0 a N N N o m ao w co 00 I1 E W Zw V V Z Q. a) m o a • J m Z0 °' u, Qre rn co co N 0 O J n. c J d .2 a E 00. U U CL CO c a) c G N O O O N p E 1 N UV CJ ^ c w E o } ›- E 0 —I M t a ! a 1 M c E r ~ ON p Z N Z m – Z. 2 _ ▪ 76 m CO N d w E ic> c g a E I Y t m COE - I a v� m (n ° c p f1 c o o @ Esm I-- Y Q I cE O 0H QE Z ON f0 E U cc m co c 0 2 0 m U U Z l/) co I y6 .� :.9 @ N .0. N ' CO t0 M • O D 0 0 0 ai 0 ai c N N _O TO To To- y0 x To 2 . �i, ` N LO J a J E a a0 c co I-N ,10 in Lo 0 LO LO 0 C WE a p N N N N N N N N d W .0 O 0 I N_ G N w c `N' = N G co N U)N. d n3 p a H C) O N co 0 o Q c c0 < cZ D U : U U 0U U U U U p 2 U ° J N a C7 0 C. 3 0 0. Q N 0 o • o E O E 15 0 0 0 0 °� °1 - Oa a> O o m d d O. 2 w W W W J LU J 3 Z 0 a 0 0 0 a 0 0 0 0 0 0' N 9 o0 U, N co a)r. b O c N N T z E 3 z 41 c, z w Ci T. O a a J W = IX a O U W O Z C., c, Z 15,Qco J o O. coC 20 0 ON a op E V 0 0 J co rt0lb— 0. coM r i- . z o N > N Ili CO re in > > / a o Q Yo a) Q a Z_ E d 0 0 A H z d 3 0 I 7 I II o > m NH a 0 a> (0 ' 3 N d a) cc O U CcU ,- a) _ U E E O a 0 1 O 0 „' 41///;,/of 773, • THE STATE Alaska Oil and Gas o fLA S KA Conservation Commission 333 West Seventh Avenue Z"— Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 �F ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Kasper Kowalewski Senior Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit, Torok Oil Pool, KRU 3S-613 Permit to Drill Number: 216-020 Sundry Number: 316-501 Dear Mr. Kowalewski: 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, Cath . Foerster Chair DATED this 3day of September, 2016. RBDMS L 00 0 3 2016 • STATE OF ALASKA ; F� 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION k APPLICATION FOR SUNDRY APPROVALS , 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well E Operations shutdown 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 Other: PROD to WINJ l 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r . 216-020-0 3.Address. Stratigraphic r Service r 6.API Number. P. O. Box 100360,Anchorage,Alaska 99510 50-103-20735-00 , 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 r No p' f KRU 3S-613 A 9.Property Designation(Lease Number): 10.Field/Pool(s): 7143 ADL 25528,25544,380107 • KUPARUK RIVER FIELD/TOROK UNDETIN_4_, SIL 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): 15782 •5196 - 15782' . 5796' 6912 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 120' 120' - SURFACE 2862' 10 3/4 2901' 2571' INTERMEDIATE 11044' 7 5/8 11082' 5163' LINER 4740' 41/2 15650' 5219' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): FRAC SLEEVE 11491,12114,12699,13323,13911,14497, 15122 • 5,190,521,552,195,200,000,000,000,000 41/2 L-80 10914 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=NIPPLE,CAMCO MD=10857 TVD=5139 PACKER= BAKER HRD-E ZXP MD=10909 TVD=5146 SEAL ASSEMBLY=SEAL ASSEMBLY,BAKER MD=10915 TVD=5147 12.Attachments: Proposal Summary J7 WellBore Schematic 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service (zr ' 14.Estimated Date for 15. Well Status after proposed work: 09/30/16 OIL r WINJ r • wDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned E 17.I hereby certify that the foregoing is true Contact: Kasper Kowalewski Printed Name Kasper Kowalewski Phone:265-1363 Email: Kasper.Kowalewski(a�cop.com I. Title: Senior Petroleum Engineer Signature ,7Date: 4?)/ q1/(c , Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `6 — 5V \ Rug Integrity r BOP Test r Mechanical Integrity Test (t'` Location Clearance r Other: jc ctill,lit,,, Post Initial Injection MIT Req'd? Yes V No r-- Spacing Exception Required? Yes r No V Subsequent Form Required: ' 0 - 4 O I' RBDMS t-`UL,I 0 2016 APPROVED BY Approved by: • 4 COMMISSIONER THE COMMISSION Date:, 3646 ?A I/36P 1— 30 @ lb 0 '': Submit Form and Form 10-403 Revised 11/2015 p Ja p J to alid for 12 months from the date of approval. Attachments in Duplicate • • RECEIVED SEP 292016 Kasper Kowalewski A03CC Senior Petroleum Engineer ATO-1356 PO Box 196105 ConocoPh i I I i ps Anchorage,AK 99519-6105 Phone:(907)265-1363 Fax:659-7314 September 29, 2016 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 3S- 613 from Oil Production to Water Injection service. I Enclosed you will find 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3S-613 (PTD#216-020). If you have any questions regarding this matter, please contact me at 907-265-1363 Sincerely Kasper Kowalewski Attachments Sundry application AOR Detail Area Map Well schematic • • 3S-613 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Moraine 3S-613 (PTD#216-020) from Oil Production service to Water Injection service as the pre-production period has been completed. Area of Review: Moraine well 3S-613 was completed as an injector on 5/24/16 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producer 3S-620. The top of the Moraine sand was found at 10958' and/5152' 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 producer 3S-620, there are no additional production/injection wells located within a 1/4 mile radius of the 3S-613 penetrations of the Moraine interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3S-613 is good and is classified as a "Multi Stage Frac'd horizontal lined"well. The injection tubing/casing annulus is isolated via a Baker HRD-E ZXP packer located at 10909' and (5146' tvd). A State-witnessed MIT-IA will be performed once well 3S-613 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The CBL interpretation was completed on the PTD's. The 16" Conductor was driven. The 10-3/4" Surface casing was cemented with 1743sx bbls Class"G"followed by 290sx Class"G". The 7-5/8" Intermediate casing was cemented with 228sx Class "G" followed by 1210sx Class "G" 0 0 g. t \ _ { 2 \ \ [ 6c - - e = - ( \t ! \ _ ( \\2 { \\ (OA 1} ( \\ \ ` ) 6E a a 0 - § ) \ ) \ \ \\ \\ , _ _ L ,A' > §2 ce)_- � S! 9 Li. P1 n Q <Lill ''_ - rt« ' ( ) "6k \ LI I?i / « < ' .11 \\k ) ) ) 5 7'?'2 , , KUP PROD , 3S-613 Conoc Phillips r Well Attributes Max Angle&MD TD • Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Bab(ftKB) onrmc,,,,,,„„g,,,,44,0 501032073500 TRACT OPERATION MORTR03 PROD 92.37 12,863.09 15,782.0 • --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-3S-613,8/9/20184'07'.05 PM SSSV:NONE Last WO: 39.77 5/24/2016 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,34.7 41143 Last Tag: Rev Reason:MILLED OUT FRAC SLEEVE's pproven 8/9/2016 -Casing Stiings .. - •,. ;�• ,� '• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 75.250 40.0 120.0 120.0 164.80 B-35 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 38.8 2,901.0 2,571.1 45.50 L-80 TSH 563 Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;40.0-120.0 INTERMEDIATE 75/8 6.875 37.6 11,082.0 5,163.4 29.70 L80 H563 0. Casing Description OD(in) 'ID(in) Top(960) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread GAS LIFT;2,716.3 ir 41/2"LINER 41/2 3.958 10,909.1 15,649.5 5,199.0 12.60 L-80 IBTM Liner Details Nominal ID SURFACE;38.8-2,901.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 10,909.1 5,146.4 82.64 PACKER Baker HRD-E ZXP 5.5"x 7.625"Liner Top Packer 4.910 ., (10.99'tie back sleeve;ID=5.75") GAS LIFT;8,605.3 #K 10,928.9 5,148.9 83.03 NIPPLE Baker"RS'Packoff Seal Nipple,5.5",14#,L-80,Hyd 4.910 563 box z box ID 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625'Flex-Lock Liner hanger L-80 4.840 Hyd 563 pin x pin GAUGE;10791.1 -� 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 10,987.9 5,155.4 84.27 NIPPLE Nipple,Camco 3.75"DB-6,SN:3656-2 3.750 NIPPLE;10,856.6 _ 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer-"H" SN:50494-001-24 3.900 PACKER Locator;10,913.6 MN 11,491.3 5,190.5 86.27 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.650 1 1 3.50")PN:10495006 Seal Assembly;10,915.0 .; (MILLED OUT 6/23/16) I; 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer-"G" SN:50494-001-30 3.900 PACKER 'ti; 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.650 3.375")PN:10495002 (MILLED OUT 6/23/16) tt. 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer"-"F" SN:50494-001-26 3.900 NM PACKER INTERMEDIATE;37.6-11,082.0 12,699.0 5,219.3 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.650 3.25")PN:10495003 Z. (MILLED OUT 6/23/16) 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer-"E" SN:50494-001-19 3.900' Z PACKER 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 Hydraulic Fracture;11,491.0 I A (MILLED OUT 8/8/2016) ., 13,593.4 5,197.1 90.48 SWELL Baker-"Swell Packer-"D" SN:50494-001-3 3.900 PACKER 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 Z 3.00")PN:10495006 (MILLED OUT 8/8/2016) Hydraufc Fracture;12,114.0 I,,,I 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer"-"C" SN:50494-001-35 3.900 PACKER Z. 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 • 2.875")PN:10495004 (MILLED OUT 8/8/2016) 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer"-"B" SN:50494-001-45 3.900 Hydraulic Fracture;12,699.0 I I PACKER 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Drift w/ 2.812 2.00")PN:10495007 (MILLED OUT 8/8/2016) • 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN:50494-001-27 3.900 PACKER 15,595.4 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 Hydraulic Fracture;13,323.0 I, ,,I 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1.25"Ball) 1.000 I Tubing Strings x Tubing Description !String Ma...I ID(in) I Top(ftKB) I Set Depth(fx..I Set Depth(181))(...I Wt(Ib/(t) (Grade !Top Connection 4-1/2"TUBING 4 1/2 3.958 34.7 10.964.7 5,153.0 12.60 L-80 Hydril 563 x Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) Hydraulic Fracture;13,911.0 I, ,I 34.7 34.7 0.00 HANGER Hanger,FMC,TC-IA-EMS,11"x4-1/2"IBT,4"H BPVG, 3.958 - with 2 contorl line ports T.. 10,791.2 5,128.9 80.50 GAUGE Gauge Carder,SLB,SGM with Sapphire tubing pressure 3.864 gauge,SN:C12GM-0194 Z. 10,856.6 5,139.2 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN:3654-11 3.813 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22192-47(bottom of the 3.870 Hydraulic Fracture;14,4970 I ^- I locator spaced out 4.86') 4' 10,915.1 5,147.1 82.75 Seal Assembly Seal Assembly,Baker,192-47 3.870 Mi Stimulations&Treatments -- Min Top Max Btm S Depth Depth Top(TVD) Blot(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Stg# Type Date Com HytlrauFC Fracture;15,122.0 I I 15,595.0 15,596.0 5,199.9 5,199.9 1 Hydraulic 6/5/2016 Day 1 Summary: Fracture Stages 1 and 2 complete,6 stages remain. • Total proppant pumped:392,000 lbs. = 15,122.0 15,123.0 5,209.6 5,209.6 2 Hydraulic 6/5/2016 Day 1 Summary: Fracture Stages 1 and 2 complete,6 stages remain. I • Total proppant pumped:392,000 lbs. Hydraulic Fracture;15,595.0 It I 7-7 41/2'LINER;10,909.1-15,649.5 i KUP PROD • 3S-613 Conocoi'hillips ° Well Attributes Max Angle&MD TD • Alaska.Inc Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Blm(ftKB) crnocoPrvnps 501032073500 TRACT OPERATION MORTRO3 PROD 92.37 12,863.09 15,782.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-3S-613,8/9/20164'07'.05 PM SSSV:NONE Last WO: 39.77 5/24/2016 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;34.7 :i I/i Last Tag: Rev Reason:MILLED OUT FRAC SLEEVE's pproven 8/9/2016 'l 7 j D Casing Strings SURFACE O tion OD10 16 ID 9.950 Top(ftKB) 0 Set Depth(ftKB)0 Set Depth(TVD)...Wt/Len(0 Grade5p Thread s p (in) (in) ) ( ) CONDUCTOR 16 15.250 40.0 120.0 120.0 164.80 B-35 Welded^Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 2,571.1 45.50 L-80 TSH 563 I Casing Description OD(in) -ID(in) Top(ft)(B) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;45.0.120.0 INTERMEDIATE 75/8 6.875 37.6 11,082.0 5,163.4 29.70 L80 H563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...W6Len(I...Grade Top Thread GAS LIFT;2,716.3 3 41/2"LINER 41/2 3.958 10,909.1 15,649.5 5,199.0 12.60 L-80 IBTM t Liner Details Nominal ID SURFACE;38.8-2,901.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 10,909.1 5,146.4 82.64'PACKER Baker HRD-E ZXP 5.5"x 7.625"Liner Top Packer 4.910 (10.99'tie back sleeve;ID=5.75") GAS LIFT;8,605.3 1< 10,928.9 5,148.9 83.03 NIPPLE Baker"RS"Packoff Seal Nipple,5.5",146,L-80,Hyd ' 4.910 UR 563 box x box ( 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625"Flex-Lock Liner hanger L-80 4.840 Hyd 563 pin x pin GAUGE;10,791.1 11 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 10,987.9 5,155.4 84.27 NIPPLE Nipple,Camco 3.75"DB-6,SN:3656-2 3.750 NIPPLE;10,856.6 �:g lal 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packet'-"H" SN:50494-001-24 3.900 PACKER Locator,10,913.8 ®11,491.3 5,190.5 86.27 FRAC SLEEVE Baker4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.650 1 3.50")PN:10495006 F (MILLED OUT 6/23/16) Seal Assembly;10,915.0I J 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packet"-"G" SN:50494-001-30 3.900 PACKER ' 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.650 3.375")PN:10495002 (MILLED OUT 6/23/16) Int 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packet'-"F" SN:50494-001-26 3.900 HE PACKER INTERMEDIATE;37.6-11.0820 , 12,699.0 5,219.3 90.98 FRAC SLEEVE Baker4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.650 T 3.25")PN:10495003 • (MILLED OUT 6/23/16) • 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packet'-"E" SN:50494-001-19 3.900 M PACKER Hydraulic Fracture;11,491.0 ' 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 ,lT.f,I 3.125")PN:10495005 i1// (MILLED OUT 8/8/2016) 13,593.4 5,197.1 90.48 SWELL Baker-"Swell Packer"-"D" SN:50494-001-3 3.900 • PACKER - • 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 M 3.00")PN:10495008 (MILLED OUT 8/8/2016) Hydraulic Fracture;12,114.0 I,,,I 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer"-"C" SN:50494-001-35 3.900 Y PACKER 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 • 2.875")PN:10495004 (MILLED OUT 8/8/2016) M. 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer"-"B" SN:50494-001-45 3.900 Hydraulic Fracture;12,699.0 I I PACKER 15,122.3' 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Drift w/ 2.812 2.00")PN:10495007 (MILLED OUT 8/8/2016) • 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN:50494-001-27 3.900 M PACKER I} 15,595.4 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 Hydraulic Fracture;13,323.0 1 Ili I 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1.25"Ball) 1.000 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/fl) Grade Top Connection IN 4-1/2'TUBING 41/2 3.958 34.7 10,964.7 5,153.0 12.60 L-80 Hydril 563 Z Completion Details INominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) Hydraulic Fracture:13,911.0 I. I I 34.7 34.7 0.00 HANGER Hanger,FMC,TC-1A-EMS,11"x 4-1/2"IBT,4"H BPVG, 3.958 rwith 2 contod line ports M. 10,791.2 5,128.9 80.50 GAUGE -Gauge Cartier,SLB,SGM with Sapphire tubing pressure 3.864- • gauge,SN:C12GM-0194 • 10,856.6 5,139.2 81.60 NIPPLE Nipple,Cameo,3.813"DB-6 Profile,SN:3654-11 3.813 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22 192-47(bottom of the 3.870 Hydraulic Fracture;14,4970 I I locator spaced out 4.86') ,C14, 10,915.1 5,147.1 82.75 Seal Assembly Seal Assembly,Baker,192-47 3.870 m Stimulations&Treatments • Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Stg# Type Date Cent Hydraulic Fracture;15,122.0 II 15 ,595.0 15,596.0 5,199.9 5,199.9 1 Hydraulic 6/5/2016 Day 1 Summary: Fracture Stages 1 and 2 complete,6 stages remain. Total proppant pumped:392,000 lbs. all 15,122.0 15,123.0' 5,209.6 5,209.6 2 Hydraulic 6/5/2016 Day 1 Summary: Fracture Stages 1 and 2 complete,6 stages remain. Total proppant pumped:392,000 lbs. M. Hydraulic Fracture;15,595.0 I' ■ 4 12'LINER;10,909.1-15,649.5 ..m...t,. • t$' A®8;. ...C, \ - 3S=08 9 0 too ' _ •�� ..._ ^6 Q O ,170 G ;88888 O O.O C0 vinNi N ' V Q >> V1 w m m_o N J c. ����d t lb- 5.23 < - J UUUV0 Q 00000 �`sco B�.S£ 0 W tor m m m m O C7 NNNN O r CO U 0• • I m iiN Nil) N mm0002 o O ^. ,I� n12214 C .c h— SF ,'�P O S•22 a O CD r 0 (0 4-1N al LU 6L E O 4-1 co ^, ti w CO •Nom W i SY VI /� O V > M to■.... M E \F a' co L M LO M a 0O O N too N CO Ill M 0 O 0 0 0 CS In O LU ,�0 I!) N ti (fl (ul/[4sn (JS ,1,) (-F)upadl/(®)U;nos'— • ConocoPhillips9sep16 Alaska, Inc. 3S-613 10-403 Sundry 0 0.15 0.3 0.6 Miles 111111111 AT12DL025528R7E ADL380106 • • 3S-62o 3S-613 i ADL02544 ADL380107 T12N R8E 3S-613 Open Interval 1 j —Well Within Radius 1 3S-613 Trajectory --–-–•--–---–-–-– *Well Pad ❑1/4Mi. Radius 3S-613 ADL021551 3Q ADL3c•• Kuparuk PA i 4_Kuparuk River Unit • • cop 9 ✓ ayi = tiel r � � �. w fD z N N W W W W W W - N 1... =�� w 3 00 A pop r D 00 00 v A 7o C v, CC-' 3 K O -+ N -+ O _, N -� o N `D C CD w N O O co co C, --I O V Q� A - '" m co =r �` Z� I= ^ 3 C n `° 9t, i''' z CD v N CII CA N N N 01 N Cn 0 0 0 0 0 0 0 0 0 w 0 0 0 0 0 - 0 0 0 N N N N N 0 N N N CT C CO CO CO CO CO W 1D CO CD D CI -, j N N N N N N N N N O 7 3 -. w7 3 GI W co N oo W N O) W A A A O Co A ul A Oo V V rn O 0 O 0 0 0 0 0 0 Q) n ^ 0 0 0 0 0 0 0 0 0tu .. - m c re vov -4- P4O °o —I < t� 1 1 1 1 m N m —I —I w0 0 0 0 0 0 0 C /1 0 0 N 0 0 0 0 0 0 0 0 0 O; w o o CI \ ♦ — ^ CAO 00) v OAi 01 O (0 - 0 ". Q) v In x z. < T T. 7C w ci . . ccc c c o c it D D D D A C D D D T m C C C C C D C C C 3 f . T. x x x x m x x x z < < < < < < < < m on m m m m m m m m cr 7J73737373 73 73 XI Ir) 73 X 73 M 73 73 73 . ., W ZX $ 111 o ^T` d w N.. 3 R o < 00 Cow n td `m < v, w W (t.‘N 0 00 2 m D �_ � 0:, a v D D D 0 xi xi mO7 m r r r r 73 O w OO O K Gm m m mTm nn co O w c C O r ? O z 0 o On OI O (D w ll vA i. co c- co m T T T T M M M T ^ , a- 41 CD Z Z Z Z Z Z Z Z Z D CO z cu -' cr -a' D D D D D D D 1 D D - (-Ti co n CD „ r r r r r r r r r D 0 , . 3 CD i m m T Ti M T Ti TI T 1 o o w m m m m m m m m m L Q c- c- conw CC C o C C C D D C "' d w rt co C- 1 a iro'CD CD ^ • 1 D 3 o 0 y z Co w 1/1 CD -0 a �I w N a D) ul A m IZi, Q c c c c - -i CCL D D D D D D D D D D m _ Di o o c- v, c c c cc 0 0 0 0 0 D l/1 .-r v O rip CO CO ea CD f0 J J l r 0 m - 3 2_ o w rn rn rn 0) Cr 0 rn rn a m D O w w O S 10• -4 m w O 3 m o n mWO -< 1 -"' ao 0 '` o 0 0 !V IV O c- = rD 0 -, mem v O ro CT 37 O N O N D- (a °x D tri cn °c° (0 C re ' O tV O 0 8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS , REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown E Performed: Suspend E Perforate E Other Stimulate F Alter Casing E Change Approved Program F Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Pump 15%:HCL PosWFreac F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 216-020-0 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20735-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25528,ADL 25544,ADL 38107 KRU 3S-613 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Torok Undefined Oil Pool 11.Present Well Condition Summary: Total Depth measured 15782 feet Plugs(measured) None true vertical 5196 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 10909 true vertical 0 feet (true vertical) 5146 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 120 120 SURFACE 2862 10 3/4 2901 2571 INTERMEDIATE 11044 7 5/8 11082 5163 4 1/2"LINER 4740 4 1/2 15650 5199 RECEIVED ,JUL 25 2016 Perforation depth: Measured depth: 11491, 12114, 12699, 13323, 13910, 14497, 15122, 15595 ` True Vertical Depth: 5190,5215, 5219, 5200,5196, 5208,5210, 5200 (+o Tubing(size,grade,MD,and TVD) 4.5, L-80, 10964 MD,5153 TVD Packers&SSSV(type,MD,and ND) PACKER-Baker HRD-E ZXP Liner Top Packer @ 10909 MD and 5146 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE , 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 N/A N/A N/A N/A N/A Subsequent to operation 838 1173 57 904 241 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development r Service F Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL [— Printed Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ F WAG r GINJ r SUSP r SPLUG r- 17. 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: 316-351 Contact Marshall Brown @ 265-6218 Email H.Marshall.Brown(cD_conocophillips.com Printed Name shall Brown Title Wells Engineer Signature00 Phone:265-6218 4 Date .9 /Z Jz 0/6 Form 10-404 Revised 5/2015 Vr`� 11‘, RBDMS (/V ����_ 2 6 2016 Submit Original Only 3S-613 DTTMS JOBTYP SUMMARYOPS 6/26/16 FRACTURING BRUSH n' FLUSH TBG, RAN 3.60" MAGNET TO 10890' SLM. 3.81 DB-6 NIP © 10,856' RKB. RECOVER METAL SHAVINGS. IN PROGRESS. 6/27/16 FRACTURING UNABLE TO SET 3.81 DBP @ 10856' RKB IN 80 DEGREE DEVIATION, WHILE PUMPING, LOCATE GLM © 2716' RKB FOR CORRELATION, SET 4.5" EVO PLUG @ 2753' RKB, 2500 PSI TBG TEST PASSED, SET CATCHER ON PLUG @ SAME, PULLED DV ©2716' RKB, CMIT TO 2500 PSI PASSED, DRAW DOWN TEST PASSED. READY FOR BPV. 6/28/16 FRACTURING (MISC) T POT PASSED, T PPPOT PASSED, TEST BPV PASSED, BLEED T, IA, AND OA TO 0 PSI, IA DDT PASSED. 6/29/16 FRACTURING (MISC) : TREE SHELL TEST POST THA/TREE SWAP TO 5000 PSI (PASSED). T-PPPOT (PASSED). 6/30/16 FRACTURING ASSIST S/L AS DIRECTED 6/30/16 FRACTURING PULLED CATCHER & EVO TRIEVE PLUG @ 2753' RKB; DEPLOYED CATCHER & SET GLV©2716' RKB; PULLED DV (SEVER EROSION ON LATCH FROM FRAC) & SET OV @ 8605' RKB (GOOD DDT ON IA); PULLED CATCHER. READY FOR CTU. 7/3/16 FRACTURING RIH to spot 20 bbls of 15% HCI on four frac balls. No frac ball seen at frac sleeve#4 © 13,322' RKB. RIH to frac ball at sleeve#3 and tag up @ 13,910' RKB. Spot 5 bbls acid and wait 15 minutes for ball to dissolve. RIH to frac ball and pass through sleeve#3. Slowly able to push frac ball in sleeve 3 down to tag on sleeve#2 @ 14,497' RKB. Spot 5 bbls acid on frac ball 2. Wait 15 minutes. Tag on ball after 15 minutes. Spot 2 more barrels acid and wait 30 minutes. Eventually make way through sleeve#2. Push frac balls to tag on sleeve#1 at 15,122' RKB. Spot 7 barrels acid on final frac ball and wait 30 minutes. RIH to final frac ball and pass through final frac sleeve to 15,600' CTMD. POOH pumping to surface. LDFN. Job in progress. 7/4/16 FRACTURING RIH with SpectraScan logging tool to hard tag on frac sleeve#4 @ 13,322' RKB. Make multiple attempts to pass through frac sleeve using different pump rates and running speeds. Confer with town engineer and decision made to log from tag depth to requested top at 10,400' RKB. POOH. Rig down and hand over well to DSO to BOL. Job complete. KUP PR S-613 COnocoPhillip5 $.. Well Attributes Max Angle&MD D Alaska,Inc.. %i Wellbore API/UWI Field Name Wellbore Status ncl I) MD(kKB) Act Otm(ftKB) Conisselhyl)ps eRF 501032073500 TRACT OPERATION MORTR03 PROD 92.37 12,863.09 15,782.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-30-613,7/14/20168.12.30 AM SSSV: NONE Last WO: 39.77 5/24/2016 Vertiralsrhemahc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER.347 IrANIVN Last Tag: Rev Reason:GLV C/O pproven 7/13/2016 f''.-;I Casing Strings m04-,."'""'""®°"•"Pf� ' , o' ''`"'''Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 40.0 120.0 120.0 164.80 B-35 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • �.i.r SURFACE 10 3/4 9.950 38.8 2,901.0_ 2,571.1 45.50 L-80 TSH 563 Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread CONDUCTOR;40.6120.0 INTERMEDIATE 75/8 6.875 37.6 11,082.0 5,163.4 29.70 L80 H563 GAS LIFT;2,778.3 Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) 'Set Depth(TVD)...'Wt/Len(I...Grade 'Top Thread ir 41/2"LINER 41/2 3.958 10,909.1, 15,649.5 5,199.0 12.60 L-80 IBTM ( L Liner Details SURFACE;38.8-2,901.0 •1 Top(ftKB) Top(TVD((ftKB) Top Incl(°) Item Des Com No(in)I ID 10,909.1 5,146.4 82.64 PACKER Baker HRD-E ZXP 5.5"x 7.625"Liner Top Packer 4.910 (10.99'tie back sleeve;ID=5.75") GAS LIFT;8,605.3 ii • NI 10,928.9 5,148.9 83.03 NIPPLE Baker"RS"Packoff Seal Nipple,5.5",14#, L-80,Hyd 4.910 I 563 box x box 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625"Flex-Lock Liner hanger L-80 4.840 II Hyd 563 pin x pin GAUGE;10,791.1 IEN 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 Mt NIPPLE;10,8566 n; 10,987.9 5,155.4 84.27 NIPPLE Nipple,Camco 3.75"DB-6,SN:3656-2 3.750 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer"-"H" SN:50494-001-24 3.900 PACKER Locator;10,913.6 11,491.3 5,190.5 8627 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.562 ice. 3.50") PN:10495006 Seal Assembly;10,015.0 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer"-"G" SN:50494-001-30 3.900 MK PACKER i`{ 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.437 3.375")PN:10495002 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer"-"F" SN:50494-001-26 3.900 PACKER 12,699.0 5,219.3 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.312 INTERMEDIATE;37.6-11,082.0 • 3.25")PN:10495003 b 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer'-"E" SN:50494-001-19 3.900 PACKER NI 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 3.125")PN:10495005 M 13,593.4 5,197.1 90.48 SWELL Baker-"Swell Packer"-"D" SN:50494-001-3 3.900 PACKER Hydraulic Fracture:11,660.0 I I 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 Q 3.00")PN:10495008 NI 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer"-"C" SN:50494-001-35 3.900 ® PACKER 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 2.875") PN:10495004 „yarautc Fracture.122400 I I 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer-"B" SN:50494-001-05 3.900 PACKER 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Drift w/ 2.812 ® 2.00")PN:10495007 • 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN:50494-001-27 3.900 ® PACKER 15,5954 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 Hydraulic Fracture;12,820.0 I I 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(125"Ball) 1.000 cm ® Tubing Strings Tubing Description String Ma... ID(in) Top(ft613) Set Depth(ft..I Set Depth(TVD)(...Wt(Iblft) Grade Top Connection ® 4-1/2"TUBING 41/2 3.958 34.7 10,964.7 5,153.0 12.60 L-80 Hydril 563 Completion Details Nominal ID Hydraulic Fracture;13,400.0 I I Top(ftKB) Top(TVD((ftKB) Top Incl(•) Item Des Corn (in) 34.7 34.7 0.00 HANGER Hanger,FMC,TC-1A-EMS,11"x 4-1/2"IBT,4"H BPVG, 3.958 with 2 contort line ports IIIII 10,791.2 5,128.9 80.50 GAUGE Gauge Carrier,SLB,SGM with Sapphire tubing pressure 3.864' EP ))) gauge,SN:C12GM-0194 . 10,856.6 5,139.2 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN: 3654-11 3.813 SIS 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22 192-47(bottom of the 3.870 Hydraulic Fracture;13,000.0 I I locator spaced out 4.86') ® 10,915.1 5,147.1 82.75'Seal Seal Assembly,Baker,192-47 3.870 - Assembly Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) • (ftKB) (0KB) (11KB) (MB) Type Date Com Hydraulic Fracture;14,560.0 I PI 11,660.0 12,821.0 5,201.6 5,201.7 Hydraulic 6/11/2016 Summary(June 11th,2016): f£7 Fracture Stages 6,7,8 pumped successfully per design;job complete O Total proppant pumped:1.56 MMlbs • Total fluid pumped:24 Mbbls 100%of design placed into formation 11,660.0 12,821.0 5,213.3 5,213.4 Hydraulic 6/11/2016 Summary(June 11th,2016): Fracture Stages 6,7,8 pumped successfully per Hydraulic Fracture;15,140.0 I I design;job complete • Total proppant pumped:1.56 MMlbs i . • Totalfluid pumped: Mbbls 100%of design placed into formation rmation 11,660.0 12,821.0 5,216.4 5,216.3 Hydraulic 6/11/2016 Summary(June 11th,2016): Fracture • Stages 6,7,8 pumped successfully per design;job complete • Total proppant pumped:1.56 MMlbs • Total fluid pumped:24 Mbbls • 100%of design placed into formation 4 VT LINER;10,909.7-15.649.5 Hydraulic Fracture;15,720.0 I I .# KUP PR S-613 Con Phillips r€ Ataska,Inc. GonocoPhillips't ...•• HORIZONTAL 30-613,7/17/2016 9:.1231 AM Verlaad arS»maataok 0 HANGER;34.7 1 Iffi Stimulations&Treatments jy Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (RKB) (ftKB) (ttKB) (RKB) Type Date Coin , w" 13,400.0 14,561.0 5,198.8 5,198.8 Hydraulic 6/8/2016 Summary(June 8th,2016): Fracture Stages 3,4,5 pumped successfully;3 stages CONDUCTOR;40.0-120.0 remain Stages 6,7,8 wit be pumped Friday GAS LIFT,2,716.3 Total proppant pumped:583,500 lbs • 100%of design placed into formation 13,400.0 14,561.0 5,197.3 5,197.3 Hydraulic 6/8/2016 Summary(June 8th,2016): SURFACE;388-2501 o- 7',, Fracture Stages 3,4,5 pumped successfully;3 stages remain • Stages 6,7,8 will be pumped Friday • Total proppant pumped:583,500 lbs GAS LIFT;8,605.3 ',.r • 100%of design placed into formation 13,400.0 14,561.0 5,209.2 5,209.2 Hydraulic 6/8/2016 Summary(June 8th,2016): .i Fracture Stages 3,4,5 pumped successfully;3 stages remain - • Stages 6,7,8 will be pumped Friday GAUGE,10,791 1 -ail • Total proppant pumped:583,500 lbs Ili • 100%of design placed into formation NIPPLE;10,856.6 15,140.0 15,721.0 5,209.1 5,209.1 Hydraulic 6/5/2016 Day 1 Summary: it Fracture Stages 1 and 2 complete,6 stages remain. • Total proppant pumped:392,000 lbs. Locator,10,913.6 - kw 15,140.0 15,721.0 5,197.7 5,197.6 Hydraulic 6/5/2016 Day 1 Summary: g Fracture Stages 1 and 2 complete,6 stages remain. Seal Assembly;10,9150 ,B • Total proppant pumped:392,000 lbs. N Mandrel Inserts . St eti N Top(TVD) Valve Latch Port Size TRO Run Top(ttKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com at 1011111 2,716.3 2,456.7 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,742.0 6/30/2016 Da 2 8,605.3 4,536.2 Camco KBMG 1 GAS LIFT OV BK 0.313 6/30/2016 INTERMEDIATE;376-11,082.0 M11k , i I $ Hydraulic Fracture;11,660.0 I ii I • 1.1 ii B'3.k Hydraulic Fracture,12,240.0 I IMI am ®° Hydraulic Fracture;12,820.0 I I I= MN ISO P'.0 Hydraulic Fracture,13,400.0 I I MEI I® l§:=3 Hydraulic Fracture;13,980 0 I I EU Mil PM Hydraulic Fracture;14,560 0 I I Hydraulic Fracture,15,140.0 I 1 I I • 41/2"LINER;10,909.1-15,649.5 (i d Hydraulic Fracture;15,720.0 I I ST•OF ALASKA MORTRO3 3S-613 ALASKA OIL AND GAS CONSERVATION COMMIS ON REPORT OF SUNDRY WELL OPERATIONS 2 7 5 4 7 1.Operations Abandon f- Plug Perforations ra Fracture Stimulate F Pull Tubing Operations Shutdown Performed: Suspend I- Perforate l Other Stimulate I- Alter Casing Change Approved Program f-•••••.. Plug for Redrill Perforate New Pool E Repair Well Re-enter Susp Well I. r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development la Exploratory 1- 216-020 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic h Service 50-103-20735-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25528,ADL 25544,ADL 38107 KRU 3S-613 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Torok Undefined Oil Pool 11.Present Well Condition Summary: . Total Depth measured 15782 feet Plugs(measured) None true vertical 5196 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 10909 true vertical 0 feet (true vertical) 5146 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 120 120 SURFACE 2862 10 3/4 2901 2571 INTERMEDIATE 11044 7 5/8 11082 5163 4 1/2"LINER 4740 4 1/2 15650 5199 RECE:1 V Perforation depth: Measured depth: 0 JUL 1 1 2016 True Vertical Depth: 0 {� W 4 �f Tubing(size,grade,MD,and TVD) 4.5, L-80, 10914 MD, 5147 TVD Packers&SSSV(type,MD,and ND) PACKER-Baker HRD-E ZXP Liner Top Packer @ 10909 MD and 5146 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11,660-12,821, 13,400-14,561, 15,140-15,721 Treatment descriptions including volumes used and final pressure: Total Well-8 stages 1.56 million lbs placed....See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory I.- Development Service F Stratigraphic Copies of Logs and Surveys Run I-. 16.Well Status after work: Oil E Gas E WDSPL I Printed and Electronic Fracture Stimulation Data I✓? GSTOR I- WINJ F7 WAG T GINJ T SUSP IT SPLUG T GP 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: 316-283 Contact Sandeep Pedam @ 263-4724 Email Sandeep.Pedamt conocophillips.com Printed Name • dee! •am Title Sr. Completions Engineer Signature / Phone:263-4724 Date 1 f is/i& -.001 ill l Vri.- g/'Z'/i�i 10 OW1/0.0/6 ' i �i�i34 Form 10-404 Revised 5/2015 Submit Original Only RBDMS IN JUL 1 2 2016 • • 3S-613 DTTMS JOBTYP SUMMARYOPS 6/2/16 FRACTURING DRIFT TBG W/3.80" BLR ASSEMBLY&TAG RHC BODY @ 10856' RKB; DEPLOY CATCHER; PULLED SOV& SET DV @ 8605' RKB (GOOD TBG TEST W/GAS); PULLED CATCHER & RHC PLUG BODY @ 10,856' RKB. READY FOR MIT'S. IN PROGRESS. 6/3/16 PUMPING MIT-T TO 5000 PSI PASS MIT-IA TO 4100 PSI PASS PUMPED 6.8 BBLS DIESEL DOWN TRACKING TBG TO ACHIEVE 5000 PSI MIT-T TEST PRESSURE. TBG LOST 100 PSI 1ST 15MIN AND ONLY 10 PSI 2ND 15 MIN FOR A TOTAL LOSS OF 110 PSI OVER THE 30 MIN TEST. BLED 6.8 BBLS BACK. PUMPED 4.9 BBLS DISEL DOWN IA TO ACHIEVE 4100 PSI MIT-IA TEST PRESSURE. IA LOST 50 PSI 1ST 15 MIN AND 0 PSI 2ND 15 MIN FOR A TOTAL LOSS OF 50 PSI OVER THE 30 MIN TEST. BLED 4.9 BBLS BACK. (JOB COMPLETE) 6/5/16 FRACTURING Pumped 2 stages of frac; placed 392,000 lbs of proppant in formation. Stages 3,4,5 to be frac'ed on Wednesday. 6/8/16 FRACTURING PUMPED STAGES 3, 4, & 5 PER DESIGN. PLACED 583,500 LBS OF PROPPANT AND 8,600 BBLS OF FLUID INTO FORMATION. STAGES 6, 7, & 8 TO BE PUMPED SATURDAY 6/11/16 FRACTURING PUMPED STAGES 6, 7, & 8 PER DESIGN. PLACED 588,570 LBS OF PROPPANT AND 8,400 BBLS OF FLUID INTO FORMATION. JOB TOTAL - 1,564,000 LBS OF PROPPANT PLACED. 6/21/16 FRACTURING B&C CTU #1: RIG UP FOR FILL CLEANOUT. HARD TAG AT TOP FRAC SLEEVE AT 11,491'. SUSPECT FRAC BALL NOT DISSOLVED. DISCUSS PLAN FORWARD AND RESTART IN THE MORNING. 6/22/16 FRACTURING B&C CTU #1: ATTEMPT TO MILL FRAC SLEEVES WITH STATEWIDE 2-7/8" TITAN MOTOR AND 3.65" MDX DIAMOND SPEED MILL AND NOT ABLE TO GET THROUGH TOP SLEEVE AT 11491'. NOT SEEING ANY MOTOR WORK STACKING 30K#, SUSPECT SPINNING ON BALL. NO MARKS ON MILL. PERFORM WEEKLY BOP TEST AND PREPARE TO GO TO WELL WITH 3.65" CARBIDE TWISTER MILL IN THE MORNING. 6/23/16 FRACTURING B&C CTU #1: MILL TOP 2 FRAC SLEEVES AT 11491' & 12114' WITH STATEWIDE 2-7/8" TITAN MOTOR AND 3.65" CARBIDE TWISTER MILL. START MILLING NEXT SLEEVE AT 12699', BUT UNABLE TO WORK THROUGH. FIND DING MARKS ON MOTOR BODY SHOULDER ABOVE SHAFT. WILL REATTEMPT IN THE MORNING WITH TAPERED MOTOR BODY AND AGITATOR. 6/24/16 FRACTURING B&C CTU #1: MILL THIRD OF SEVEN FRAC SLEEVES AT 12699' WITH STATEWIDE 2- 7/8" BEVELED TITAN MOTOR, XRV AGITATOR, AND 3.65" CARBIDE TWISTER MILL. UNABLE TO MAKE IT THROUGH FORTH SLEEVE AT 13322' WITH MILL, NO NEW MARKS ON MOTOR. ATTEMPT TO DRIFT SLEEVE WITH 2.4" JSN AND AGITATOR, UNABLE TO PASS. POSSIBLE DEBRIS ON TOP OF BALL SEAT. RIG BACK AND PLAN VENTURI RUN IN THE MORNING. 6/25/16 FRACTURING B&C CTU #1: RECOVER MINIMAL DEBRIS ON TOP OR FRAC SLEEVE#4 AT 13322' WITH STATEWIDE 2.88"VENTURI BASKET. ATTEMPT TO MILL FRAC SLEEVE#4 WITH 3.13" BAKER EXTREME MOTOR AND 3.65" FIVE BLADE GLYPHALLOY CONCAVE MILL. UNABLE TO GET MOTOR WORK. SPOT 100 BBLS OF 10% KCL IN LATERAL AND POOH. RIG BACK UNIT AND PLAN TO MOVE TO 3S-620 IN THE MORNING. • 6/26/16 FRACTURING BRUSH n' FLUSH TBG, RAN 3.60" MAGNET TO 10890' SLM. 3.81 DB-6 NIP @ 10,856' RKB. RECOVER METAL SHAVINGS. IN PROGRESS. 6/27/16 FRACTURING UNABLE TO SET 3.81 DBP @ 10856' RKB IN 80 DEGREE DEVIATION, WHILE PUMPING, LOCATE GLM © 2716' RKB FOR CORRELATION, SET 4.5" EVO PLUG ©2753' RKB, 2500 PSI TBG TEST PASSED, SET CATCHER ON PLUG © SAME, PULLED DV©2716' RKB, CMIT TO 2500 PSI PASSED, DRAW DOWN TEST PASSED. READY FOR BPV. 6/28/16 FRACTURING (MISC) T POT PASSED, T PPPOT PASSED, TEST BPV PASSED, BLEED T, IA, AND OA TO 0 PSI, IA DDT PASSED. 6/29/16 FRACTURING (MISC) : TREE SHELL TEST POST THA/TREE SWAP TO 5000 PSI (PASSED). T-PPPOT (PASSED). 6/30/16 FRACTURING ASSIST S/L AS DIRECTED 6/30/16 FRACTURING PULLED CATCHER & EVO TRIEVE PLUG ©2753' RKB; DEPLOYED CATCHER & SET GLV ©2716' RKB; PULLED DV(SEVER EROSION ON LATCH FROM FRAC) & SET OV @ 8605' RKB (GOOD DDT ON IA); PULLED CATCHER. READY FOR CTU. 7/3/16 FRACTURING RIH to spot 20 bbls of 15% HCI on four frac balls. No frac ball seen at frac sleeve#4 @ 13,322' RKB. RIH to frac ball at sleeve#3 and tag up © 13,910' RKB. Spot 5 bbls acid and wait 15 minutes for ball to dissolve. RIH to frac ball and pass through sleeve#3. Slowly able to push frac ball in sleeve 3 down to tag on sleeve#2 @ 14,497' RKB. Spot 5 bbls acid on frac ball 2. Wait 15 minutes. Tag on ball after 15 minutes. Spot 2 more barrels acid and wait 30 minutes. Eventually make way through sleeve#2. Push frac balls to tag on sleeve#1 at 15,122' RKB. Spot 7 barrels acid on final frac ball and wait 30 minutes. RIH to final frac ball and pass through final frac sleeve to 15,600' CTMD. POOH pumping to surface. LDFN. Job in progress. 7/4/16 FRACTURING RIH with SpectraScan logging tool to hard tag on frac sleeve#4 @ 13,322' RKB. Make multiple attempts to pass through frac sleeve using different pump rates and running speeds. Confer with town engineer and decision made to log from tag depth to requested top at 10,400' RKB. POOH. Rig down and hand over well to DSO to BOL. Job complete. 0 • Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 6/5/2016 Job End Date: 6/11/2016 State: Alaska County: Harrison Bay API Number: 50-103-20735-00-00 �C Operator Name: ConocoPhillips Company/Burlington FOCUS Resources Chemical Disclosure Registry Well Name and Number: 3S-613 Latitude: 70.39416400 Longitude: -150.19671500 CSM ` Datum_ NAD83 Federal Well: NO Y� Oil Se Gas Indian Well: NO True Vertical Depth. 1,027,319 7-,,,:,,,,,,.„ e Non Water Volume, 0 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Service Ingredient Ingredient de Name Supplier Purpose Ingredients Number Concentration in Concentration in Comments (CAS#) o Additive HF Fluid (/o by mass)" (%by.mass)" ea Water Operator Base Fluid ✓Vater 7732-18-5 100 00000 84.44521Jensity=8.540 CarboLite 16/20 CARBO Ceramics Inc.Proppant NA 56996-83-9 3E-6 MICROBIOCIDE,Halliburton Additive,Biocide, OL-22 UC,CL-31 3reaker,Crosslinker, CROSSLINKER, Gelling Agent, _OSURF-300D,MO- Microbiocide,Non- 37,OPTIFLO-II onic Surfactant,pH DELAYED RELEASE Control Additive, BREAKER,OPTIFLO- Proppant II DELAYED RELEASE BREAKER, SAND-COMMON WHITE-100 MESH, SSA-2,100 LB SACK (100002158),SP 3REAKER,WG-36 GELLING AGENT 2-Bromo-2-n itropropane-1,3-diol 52-51-7 Ingredients shown above are subject to 29 CFR 1910.1200(i)and appear on Material Safety Data Sheets(MSDS).Ingredients shown below are Non-MSDS. • • -lazardous and Non- Hazardous Ingredients Ceramic materials and wares, 66402-68-4 100.00000 14.4716C chemicals Crystalline silica,quartz 14808-60-7 100.00000 0.53637 Guar gum 9000-30-0 100.00000 0.30252 Water 7732-18-5 100.00000 0.07120 Borate salts Confidential 60.00000 0.06311 Potassium formate 590-29-4 60.00000 0.06311 Ethanol 64-17-5 60.00000 0.04430 Oxyalkylated phenolic resin Confidential 30.0000C 0.02952 Potassium metaborate 13709-94-9 60.0000C 0.02861 Heavy aromatic petroleum 64742-94-5 30.00000 0.02215 naphtha Bentonite,benzyl(hydrogenated 121888-68-4 5.00000 0.01512 tallow alkyl)dimethylammonium stearate complex Surfactant mixture Confidential 1.00000 0.0060E Ammonium persulfate 7727-54-0 100.00000 0.00594 Naphthalene 91-20-3 5.00000 0.00366 Poly(oxy-1,2-ethanediyl),alpha- 127087-87-0 5.00000 0.00360 (4-nonyl phenyl)-omega- hydroxy-,branched Sodium hydroxide 1310-73-2 30.0000C 0.00331 Silica gel 112926-00-8 1.00000 0.00303 Potassium hydroxide 1310-58-3 5.00000 0.00238 Cured acrylic resin Confidential 30.00000 0.00178 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00000 0.00171 Sodium chloride 7647-14-5 1.00000 0.00116 Sodium glycollate 2836-32-0 1.00000 0.00105 Acrylate polymer Confidential 1.00000 0.00105Denise Tuck,Halliburton, 3000 N.Sam Houston Pkwy E., Houston,TX 77032,281- 871-6226 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.00105 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00074 Sodium persulfate 7775-27-1 100.00000 0.00032 Crystalline Silica,Quartz 14808-60-7 0.10000 0.00030 Sodium sulfate 7757-82-6 0.10000 0.00000 Total Water Volume sources may include fresh water,produced water,and/or recycled water **Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) KUP Pill 3S-613 ConocoPhillips P Well Attributes Max Angle&III TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl r) MD(ftKB) Act Btm(ftKB) ConocaPhieipz-p` 501032073500 TRACT OPERATION MORTRO3 PROD 92.37 12,863.09 15,782.0 •A ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-30-613,7/11/20164:02:25 PM SSSV: NONE Last WO: 39.77 5/24/2016 • verocalsdiemaac.(aotual)....,... Annotation Depth(ftKB) End Date Annotation Last Mott By End Date HANGER;34.7 -'"r'- Last Tag: Rev Reason: Fracturing lehallf 7/11/2016 ' I= Casing Strings ,,.,.,.,.,,,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread II CONDUCTOR- 16 15.250 40.0 120.0 120.0 164.80 B-35 Welded _-,.."..."--...Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ft SURFACE 10 3/4 9.950 38.8 2,901.0 2,571.1 45.50 L-80 TSH 563 CONDUCTOR;40.0-120.0 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread INTERMEDIATE 75/8 6.875 37.6 11,082.0 5,163.4 29.70 L80 6(563 GAS LIFT;2,716.3 : Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g...Grade Top Thread 4 1/2"LINER 4 1/2, 3.958 10,909.1 15,649.5 5,199.0 12.60 L-80 IBTM f Liner Details SURFACE;38.8-2,901.0 ` Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Kern Des Com (In) GAS LIFT;8,805.3 10,909.1 5,146.4 82.64 PACKER Baker HRD-E ZXP 5.5"x 7.625"Liner Top Packer 4.910 (10.99'tie back sleeve;ID=5.75") I� 1 10,928.9 5,148.9 83.03 NIPPLE Baker"RS"Packoff Seal Nipple,5.5",14#, L-80,Hyd 4.910 GAUGE;10,791.1 ON 563 box x box 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625"Flex-Lock Liner hanger L-80 4.840 I: Hyd 563 pin x pin NIPPLE;10,856.6 EII - 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 III 10,987.9 5,155.4 84.27'NIPPLE Nipple,Camco 3.75"DB-6,SN:3656-2 3.750 Locator;10,913.6 !, 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer"-"H" SN:50494-001-24 3.900 111 PACKER Seal Assembly;10,915.0 Fry 11,491.3 5,190.5 86.27 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.562 try 3.50")PN:10495006 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer"-"G" SN:50494-001-30 3.900 PACKER • 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.437 ••-•-•=1 3.375")PN:10495002 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer"-"F" SN:50494-001-26 3.900 INTERMEDIATE;37.6-11,082.0 .1 PACKER Eta 12,699.0 5,219.3 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.312 3.25")PN:10495003I. , 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-19 3.900 1:151PACKER ED 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 3.125")PN:10495005 Hydraulic Fracture;11,660.0 I I 13,593.4 5,197.1 90.48'SWELL Baker-"Swell Packer-"D" SN:50494-001-3 3.900 ® PACKER mil 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 3.00")PN:10495008 1331 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer"-"C" SN: 50494-001-35 3.900 PACKER 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 „ydrauI:c Fracture;12,240.0 I I I 2.875")PN:10495004 (D 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer'-"B" SN:50494-001-45 3.900 ill PACKER IP 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Driftw/ 2.812 2.00")PN:10495007 Q° 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN: 50494-001-27 I 3.900 I PACKER Hydraulic Fracture;12,820.0 1 j 1 15,595.4 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 IO 15,606.6 5,199 7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1.25"Ball) 1.000 IEI Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 4-1/2"TUBING 41/2 3.958 34.7 10,964.7 5,153.0 12.60 L-80 Hydril 563 Completion Details Ilydraul,c Fracture;13,400.0 I l I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (In) 34.7 34.7 0.00 HANGER Hanger,FMC,TC-1A-EMS,11"x 4-1/2"IBT,4"H BPVG, 3.958 with 2 contort line ports 10,791.2 5,128.9 80.50 GAUGE Gauge Carrier,SLB,SGM with Sapphire tubing pressure 3.864 gauge,SN:C12GM-0194 10,856.6 5,139.2 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN: 3654-11 3.813 Hydraulic Fracture;13,980.0 I: I 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22192-47(bottom of the 3.870 locator spaced out 4.86') 10,915.1 5,147.1 82.75 Seal Seal Assembly,Baker,192-47 3.870 • Assembly Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Bier(TVD) Hydraulic Fracture;14,560.0 I I (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 11,660.0 12,821.0 5,201.6 5,201.7 Hydraulic 6/11/2016 Summary(June 11th,2016): P Fracture Stages 6,7,8 pumped successfully per design;job complete • Total proppant pumped:1.56 MMlbs Total fluid pumped:24 Mbbls • 100%of design placed into formation 01 11,660.0 12,821.0 5,213.3 5,213.4 Hydraulic 6/11/2016 Summary(June 11th,2016): Hydraulic Fracture,15,140.0 I I Fracture Stadesign;job completees pumped successfully per cm Total proppant pumped:1.56 MMlbs • Total fluid pumped:24 Mbbls IR • 100%of design placed into formation CS 11,660.0 12,821.0 5,216.4 5,216.3 Hydraulic 6/11/2016 Summary(June 11th,2016): Fracture Stages 6,7,8 pumped successfully per design;job complete _ Total proppant pumped:1.56 MMlbs • Total fluid pumped:24 Mbbls • 100%of design placed into formation 41/2"LINER;10,909.1-15,649.5 I K. Hydraulic Fracture;15,720.0 I I • KUP P. • 3S-613 ConocoPhillips ` ' r Alaska_Inc, e ConocePhdlips • HORIZONTAL-3S-613,7/11/20164:02:25 PM Vertical s:hematc.(actual) HANGER;34.7 q` 'p Stimulations&Treatments LWtn;ria Min Top Max Btm Depth Depth Top(ND) Btm(ND) (19KB) (MB) (ftKB) (ftKB) Type Date Com 11 13,400.0 14,561.0 5,198.8 5,198.8 Hydraulic 6/8/2016 Summary(June 8th,2016): CONDUCTOR;40.0-120.0 Fracture Stages 3,4,5 pumped successfully;3 stages remain GAS LIFT;2,716.3 Stages 6,7,8 will be pumped Friday • Total proppant pumped:583,500 lbs € • 100%of design placed into formation 13,400.0 14,561.0 5,197.3 5,197.3 Hydraulic 6/8/2016 Summary(June 8th,2016): SURFACE;38.8-2,901.01. 11 Fracture Stages 3,4,5 pumped successfully;3 stages remain GAS LIFT;8,605.3 [: Stages 6,7,8 will be pumped Friday ir ,� • Total proppant pumped:583,500 lbs I • 100%of design placed into formation 13,400.0 14,561.0 5,209.2 5,209.2 Hydraulic 6/8/2016 Summary(June 8th,2016): GAUGE;167911 - Fracture Stages 3,4,5 pumped successfully;3 stages remain �® Stages 6,7,8 will be pumped Friday NIPPLE;10,856.8 • Total proppant pumped:583,500 lbs • 100%of design placed into formation ii 15,140.0 15,721.0 5,209.1 5,209.1 Hydraulic 6/5/2016 Day 1 Summary: Locator;10,913.6 Fracture Stages 1 and 2 complete,6 stages remain. 121 • Total proppant pumped:392,000 lbs. Seal Acaemdy;10,915.0 Itlr. 15,140.0 15,721.0 5,197.7 5,197.6 Hydraulic 6/5/2016 Day 1 Summary: g Fracture Stages 1 and 2 complete,6 stages remain. M • Total proppant pumped:392,000 lbs. Mandrel Inserts St a5 rrr-�� r:.W, on Top(ND) Valve Latch Port size TRO Run N, Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,716.3 2,456.7 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/23/2016 INTERMEDIATE;37.6-11.0020 • 2 8,605.3 4,536.2 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0•6/2/2016 MO OE Ea Hydraulic Fracture.11 660.0 I '.. Hydraulic Fracture;12,240.0 I!I NI ON DI Hydraulic Facture:12,820 0 I I 1D ME CD Et Hydraulid Fracture.1:1.400 0 I 1 0 MI cm Et HydramLC Fracture;13,980.0 I I LEI III MI Hydraulic Fracture;14,560.0 I I PO H�1 nt Hydraulic Fracture,15,140.0 I I 1 NI t OX gal 4 1/2.LINER;10,909.1-15,649 5-.G* Hydraulic Fracture,15,720.0 I I • • -rtfrti Cj7 "k THE STATE Alaska Oil and Gas o fALASKA Conservation Commission sty= 333 West Seventh Avenue W" GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 M'• Main: 907.279.1433 ®44'ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Torok Undefined Oil Pool, KRU 3S-613 Permit to Drill Number: 216-020 Sundry Number: 316-351 Dear Mr. Brown: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster �� ,_ Chair DATED this /' day of July, 2016. RBDMS (V JUL 0 8 2016 SO RECEIVED • STATE OF ALASKA JUN 3 Q �' ALASKA OIL AND GAS CONSERVATION COMMISSION � 7/7 APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon r- Plug Perforations E Fracture Stimulate 17, Repair Well I- Operations Shutdown I^ Suspend Perforate r Other Stimulate JPull Tubing I-•••••. Change Approved Program F Plug for Redrill Ei Perforate New Pool I- E Re-enter Susp Well Alter Casing( ,, Other: Pump 15%HCL Post Fr _ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. , Exploratory I- Development fl 216-020 " 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service F " 50-103-20735-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ( No FKRU 3S-613 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25528,ADL 25544,ADL 38107 Kuparuk River Field/Torok Undefined 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): 15,782' 5,196' 6912 n/a n/a Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16" 120' 120' Surface 2,862' 10 3/4 2,901' 2,571' Intermediate 11,044' 7 5/8 11,082' 513' Liner 4,740' 5" 15,649' 5,199' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4.5 L-80 10,965' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER HRD-E ZXP Liner Top Packer 10909=MD and 5146=TVD SSSV: NONE 12.Attachments: Proposal Summary El Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory I- Stratigraphic Development E Service •F 14.Estimated Date for 5/30/2016 15.Well Status after proposed work: Commencing Operations: OIL I-•• WINJ F ' WDSPL fa Suspended I- 16.Verbal Approval: Date: 6/29/2016 GAS I- WAG I- GSTOR I SPLUG I- Commission Representative: Victoria Loepp GINJ Op Shutdown I-. Abandoned I- 17. 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Marshall Brown@ 265-6218 Email H.Marshall.Brown@conocophillips.com Printed Name Mar Br wn / Title Wells Engineer a4 /// V I ��3o z 0/6 Signature �P one 263-4724 Date / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test El Mechanical Integrity Test V Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes VNo ❑ d Spacing Exception Required? Yes ❑ No / Subsequent Form Required: !B—40-I (� RBDMS (/ JUL 0 8 2016 /n� APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 7 - 7..../‘ �� 10-T3 O7ale?, !ikj 0 �4II34 � � Submit Formane Form 10- t33 ed 11/2015 ii i is valid for 12 months from the date of approval. � Attachments in Duplicate KUP P 3S-613 ConocoPhilZips °„' '` ° Well Attributes Max Angle& u TD Alaska111G r Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(kKB) a CarrocoPthllips 501032073500 TRACT OPERATION MORTRO3 PROD 92.37 12,863.09 15,782.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-3S-613,6/30/20169:42:45 AM SSSV: NONE Last WO: 39.77 5/24/2016 - Vertical schemaLn.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;34.7 '6 r, Last Tag: Rev Reason: PULL PLUG,GLV C/O pproven 6/3/2016 1 -T Casing Stnngs ' * Casing Description OD(in) 11)(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ' CONDUCTOR 16 15.250 40.0 120.0 120.0 164.80 B-35 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread �� SURFACE 10 3/4 9.950 38.8 2,901.0 2,571.1 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread CONDUCTOR;40.o-120.0 INTERMEDIATE 7 5/8 6.875 37.6 11,082.0 5,163.4 29.70 L80 H563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread GAS LIFT;2,716.3 is 41/2"LINER 41/2 3.958 10,909.1 15,649.5 5,199.0 12.60 L-80 IBTM iLiner Details P Nominal ID €E Ll Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) SURFACE;38.8-2,901.0 10,909.1 5,146.4 82.64 PACKER Baker HRD-E ZXP 5.5"x 7.625"Liner Top Packer 4.910 GAS LIFT;8,6053 (10.99'tie back sleeve;ID=5 75") 10,928.9 5,148.9 83.03 NIPPLE Baker"RS"Packoff Seal Nipple,5.5",148, L-80,Hyd 4.910 563 box x box 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625"Flex-Lock Liner hanger L-80 4.840 GAUGE;10,791.1 - Hyd 563 pin x pin 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 NIPPLE;10,858.8 10,987.9 5,155.4 8427 NIPPLE Nipple,Camco 3.75"DB-6,SN:3656-2 3.750 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer"-"H" SN:50494-001-24 3.900 PACKER Locator;10,913.6 11,491.3 5,190.5 8627 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.562 111 3.50")PN:10495006 seal Assembly;1o,91s.o 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer"-"G" SN:50494-001-30 3.900 PACKER 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.437 fi 3.375")PN:10495002 I 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer'-"F" SN:50494-001-26 3.900 PACKER 12,699.0 5,219.3 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.312 3.25")PN:10495003 Mr, 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-19 3.900 INTERMEDIATE,37.6-11,0820 PACKER 1170 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 OM 3.125")PN:10495005 E 13,593.4 5,197.1 90.48 SWELL Baker-"Swell Packer"-"D" SN:50494-001-3 3.900 PACKER la 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 3.00")PN:10495008 Vi 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer'-"C" SN:50494-001-35 3.900 PACKER 111 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 8° 2.875") PN:10495004 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer"-"B" SN:50494-001-45 3.900 PACKER I 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Drift w/ 2.812 Ei 2.00")PN:10495007 MI 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN: 50494-001-27 3.900 d PACKER 15,595.4 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 9 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1 25"Ball) 1.000 0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection NI 4-1/2"TUBING 41/2 3.958 34.7 10,964.7 5,153.0 12.60 L-80 Hydril 563 El Completion Details Nominal ID Top(ftKB) Top(ND)(kKB) Top Incl(°) Item Des Com (in) 34.7 34.7 0.00 HANGER Hanger,FMC,TC-1A-EMS,11"x 4-1/2"IBT,4"H BPVG, 3.958 Ei with 2 contort line ports 10,791.2 5,128.9 80.50 GAUGE Gauge Carrier,SLB,SGM with Sapphire tubing pressure 3.864 lil gauge,SN: C12GM-0194 UN 10,856.6 5,1392 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN: 3654-11 3.813 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22 192-47(bottom of the 3.870 locator spaced out 4.86') 10,915.1 5,147.1 82.75 Seal Seal Assembly,Baker,192-47 3.870- Assembly Mandrel Inserts St aft 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 2,716.3 2,456.7 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/23/2016 2 8,605.3 4,536.2 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/2/2016 11■ a I I 41/7 LINER;10,909.1-15,649.5 Steps: 2" Coiled Tubing: FCO 1) Inspect pad and work area for hazards. Complete Pre-Job Safety Meeting. 2) MIRU 2" coiled tubing, pressure test surface equipment and lubricator as required. 3) Ensure there are no upsets/hard shoulders in the FCO BHA, as we will FCO to the Alpha Sleeve @ 15,595 ft., passing through multiple nipple and frac sleeve restrictions. a) CoilCade modeling predicts 2" coil can reach the Alpha Sleeve,with approx.450#WOB remaining 4) RIH w/a centralized 2" Down Jet Nozzle BHA to the 4th sleeve @ 13,322 ft.and tag ball. a) If Hard Tag: Spot 4 Bbl. of 15% HCI, pull up hole 100 ft., Pump down coil annulus @ .5 BPM for 30 seconds and shut down.Wait 10 minutes, Pump down coil annulus @ .5 BPM for 30 seconds then RIH and tag frac ball. b) If ball is not tagged at depth: Perform FCO to frac sleeve#3 @ 13,910ft. 5) RIH and tag frac ball @ sleeve#3 @ 13,910 ft. Spot 4 Bbl.of 15% HCI. Pull up hole 100 ft. Pump down coil annulus @ .5 BPM for 30 seconds and shut down. a) Note pressure while pumping. 6)Wait 10 minutes. Pump down coil annulus @ .5 BPM for 30 seconds and shut down. RIH and tag frac ball @ 13,910' a) Note pressure when pumping b) If ball unseats while pumping, a decease in pressure should be seen. c) Repeat steps 5 &6 until ball is pushed through sleeve NOTE: Only spot in more HCI if more than 4 bbl. of HCI is pumped away while trying to push ball thru per sleeve 7) RIH and tag frac ball @ sleeve#2 @ 14,497 ft. Repeat steps 5 &6 until ball is pushed through seat. 8) RIH and tag frac ball @ sleeve#1 @ 15,122 ft. Repeat steps 5 &6 until ball is pushed through seat. 9) Perform FCO to Alpha sleeve @ 15,595 ft. 10) POOH while performing FCO to surface ensuring a 2,000 ft.freeze proctect,Shut in well. a) 35 bbl. • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JU U 2 1 2016 1a.WellStatuWELOil❑L CO❑MPLETIOSPLUG❑N OR ROther ❑ECOdMePLETIONd E enR EPORIT1 b.Well IAN ass: C 20AAC 25.105 20AAC 25.110 Development❑ Exploratory❑ GINJ ❑ WINJ 2 WAG❑ WDSPL❑ No.of Completions: Service 2, Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 5/24/2016 216-020/316-254 ' 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 4/16/2016 50-103-20735-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2514'FNL, 1051'FEL,Sec 18,T12N, R8E•, UM 5/10/2016 KRU 3S-613' Top of Productive Interval: 9. Ref Elevations: KB:64.4 17. Field/Pool(s): Ilk-' 1557'FNL,4171'FEL,Sec 13,T12N,R7E, UM GL:24.7 BF: Kupurak River Field/Torok Lek Oil Poo Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2198'FNL, 155'FEL,Sec 11,T12N,R7E, UM N/A ADL 25528,ADL 25544,ADL 380107' 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 476208 y- 5993901 Zone- 4 15782/5196 4624,2639 TPI: x- 468287 y- 5994888 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 467040 y- 5999532 Zone- 4 n/a 1612/1576 5. Directional or Inclination Survey: Yes 2 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Mud Log,Peri/Micro/SonicScope 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 16 164.8 B-35 40 120 40 120 24 Driven 10 3/4 45.5 L-80 38.8 2901 38.8 2571 13 1/2 1743 sx 11.0ppg Class G Lead Cmt,290 sx 15.8 ppg Class G Tail Cmt 7 5/8 29.7 L-80 37.6 11082 37.6 5163 9 7/8 Stage 1:228 sx 15.8 ppg Class G Intermed CMT. Stage 2: 1210 sx 15.8 ppg Class G 4 1/2 12.6 L-80 10909 15649 5146 5199 6 3/4 24.Open to production or injection? Yes D 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): 4 1/2 10695 10909/5146 FRAC SLEEVE-11491-5190 FRAC SLEEVE-12114-5215 ^:IMi-'f_ET:ON 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. FRAC SLEEVE-12699-5219 req•;(- Was hydraulic fracturing used during completion? Yes❑ No ❑ FRAC SLEEVE-13323-5200 6./24 N FRAC SLEEVE-13911-5196 Per 20 AAC 25.283(i)(2)attach electronic and printed information FRAC SLEEVE-14497-5208 's `I'1};', DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED FRAC SLEEVE-15122-5210 `• 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting for 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 10-407 Revised 11/2015 VTL- "06//L CONTINUED ON PAGE 2 RBDMS 0/ JUN 2 2 2016 Submit ORIGINIAL ogle • • 28.CORE DATAConventional r i I r : Yes No Core(s): Yes ❑ No ❑ Sidewall Cores: ❑ ❑ 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 1611 1575 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 10964 5152 information, including reports, per 20 AAC 25.071. T-3 669 669 WSAK TOP 2140 2023 WSAK BASE 2710 2452 C-50 5013 3354 K-3 7267 4093 BASE COYOTE 7660 4223 TOP MORAINE 10958 5152 Formation at total depth: 1 MORAINE 31. List of Attachments: Daily Operations Summary,Definitive Survey,Cement Report,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results. Der + C 25.070. 32. I hereby certify that the foregoing is true and • -•f;• ••- best of my knowledge. Contact: Scott Brunswick A 263-4249 ' Email: Scott.A.Brunswickacop.com Printed Name: G.L.Alvord �+ /p Title: Alaska Drilling Manager C- Signature: _ _QA Phone: 265-6120 Date: C 41 (' 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 1 b: 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 P D 3S-613 ConocoPhiliips " & s Well Attribu Max AnglE ) J TD Alaska Inc. Wellbore APIIUWI Field Name Wellbore Status ncl 0) MD MKK Act Btm(ftKB) igips 501032073500 TRACT OPERATION MORTRO3 PROD ` 9237 12,863.09 15,782.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-35-613,6/21/20167'.22'.12 AM SSSV: NONE _Last WO: 39.77 5/24/2016 Verpcal schematic lactuap . Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,34.7 Last Tag: Rev Reason: PULL PLUG,GLV C/O pproven 6/3/2016 ll I Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ■II I ,, CONDUCTOR 16 15.250 40.0 120.0 120.0 164.80 B-35 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 38.8 2,901.0 2,571.1 45.50 L-80 TSH 563 Casing Description - OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread CONDUCTOR;40.0-120.0 INTERMEDIATE 7 5/8 6.875 37.6 11,082.0 5,163.4. 29.70 L80 H563 111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade 'Top Thread GAS LIFT;2,716.3 #: 41/2"LINER 41/2 3.958 10,909.1 15,649.5 5,199.0 12.60 L-80 IBTM SE I Liner Details Y Nominal ID SURFACE;38.8-2,801.0 3 L, Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 10,909.1 5,146.4 82.64 PACKER Baker HRD-E ZXP 5.5"x 7.625"Liner Top Packer 4.910 GAS LIFT;8,605.3 ;: (10.99'tie back sleeve;ID=5.75") 10,928.9 5,148.9 83.03 NIPPLE Baker"RS"Packoff Seal Nipple,5.5",146, L-80,Hyd 4.910 III I 563 box x box 10,931.7 5,149.2 83.09 HANGER Baker 5.5"x 7.625,Flex-Lock Liner hanger L-80 4.840 RI GAUGE;10,791.1-- -={ Hyd 563 pin x pin iii IRO 10,951.8 5,151.5 83.52 SBE Baker 190-47 Seal bore extension,5-1/2"Hyd 563 4.750 NIPPLE;10,856.6 ata10,987.9 5,155.4 8427 NIPPLE Nipple,Camco 3.75"DB-6,SN: 3656-2 3.750 I 11,215.1 5,172.5 86.17 SWELL Baker-"Swell Packer"-"H" SN:50494-001-24 3.900 PACKER Locator;10,913.6 i 11,491.3 5,190.5 86.27 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#7-(3.625"Ball,Drift w/ 3.562 3.50")PN:10495006 Illi 11,798.9 5,210.8 86.24 SWELL Baker-"Swell Packer"-"G" SN:50494-001-30 3.900 Seal Assembly;10,915.0 a) PACKER 12,114.1 5,214.6 91.03 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#6-(3.50"Ball,Drift w/ 3.437 Y3.375")PN:10495002 12,422.1 5,217.1 88.53 SWELL Baker-"Swell Packer"-"F" SN:50494-001-26 3.900 PACKER • 12,699.0 5,219.3 90.98 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#5-(3.375"Ball,Drift w/ 3.312 , 3.25")PN:10495003 aa 13,006.6 5,209.0 92.08 SWELL Baker-"Swell Packer"-"E" SN:50494-001-19 3.900 INTERMEDIATE;37.6-11,082.0 PACKER P. 13,322.8 5,200.3 91.34 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#4-(3.25"Ball,Drift w/ 3.187 ON 3.125")PN:10495005 n 13,593.4 5,197.1 90.48 SWELL Baker-"Swell Packer"-"D" SN:50494-001-3 3.900 PACKER 10 13,910.7 5,196.5 89.46 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#3-(3.125"Ball,Drift w/ 3.062 3.00")PN:10495008 W 14,220.4 5,201.1 88.95 SWELL Baker-"Swell Packer'-"C" SN: 50494-001-35 3.900 PACKER I. 14,497.4 5,207.7 88.64 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#2-(3.00"Ball,Drift w/ 2.937 PP., 2.875") PN:10495004 14,806.2 5,215.2 89.09 SWELL Baker-"Swell Packer"-"B" SN:50494-001-45 3.900 PACKER 15,122.3 5,209.6 91.69 FRAC SLEEVE Baker 4-1/2"Frac Sleeve#1-(2.875"Ball,Drift w/ 2.812 2.00")PN:10495007 • 15,399.1 5,203.6 91.03 SWELL Baker-"Swell Packer"-"A" SN: 50494-001-27 3.900 iii PACKER t l15,595.4 5,199.9 90.98 SLEEVE 4-1/2"Baker Alpha Pressure Sleeve 3.000 ilaii 15,606.6 5,199.7 90.96 VALVE 4-1/2"Baker Wellbore Isolation Valve(1.25"Ball) 1.000 d Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection OM 4-1/2"TUBING 41/2 3.958 34.7 10,964.7 5,153.0 12.60 L-80 Hydril 563 Completion Details t Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 34.7 34.7 0.00 HANGER Hanger,FMC,TC-1A-EMS,11"x 4-1/2"IBT,4"H BPVG, 3.958 with 2 contort line ports 10,791.2 5,128.9 80.50 GAUGE Gauge Carrier,SLB,SGM with Sapphire tubing pressure 3.864 gauge,SN: C12GM-0194 10,856.6 5,139.2 81.60 NIPPLE Nipple,Camco,3.813"DB-6 Profile,SN: 3654-11 3.813 10,913.6 5,147.0 82.72 Locator Locator Sub,Baker,GBH-22 192-47(bottom of the 3.870 locator spaced out 4.86') 10,915.1 5,147.1 82.75 Seal Seal Assembly,Baker,192-47 3.870 Assembly Mandrel Inserts St att on Top(TVD) Valve Latch Port Size TRO Run y N Top(ftKB) (ftKB) Make Model OD(in) Sew Typo Type (in) (psi) Run Date Com 1 2,716.3 2,456.7 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/23/2016 2 8,605.3 4,536.2 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/2/2016 2 7 0 41/2'LINER;10,909.1-15,649.5 .OLS., !'. I (I � xe r 110 Operations Summary (with Timelog Depths) y 4,10i? _ 3S-613 ConocoPtsillps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code lime P-T-X Operation (ftKB) End Depth(ftKB) 4/15/2016 4/15/2016 5.75 MIRU MOVE RURD P Setup landings and stairways and 0.0 0.0 16:00 21:45 install handi-berm around rockwasher and cuttings tank.Hook up interconnects,position/test skate,and load tanks with water. Rig accepted @ 16:00 hrs. 4/15/2016 4/15/2016 1.50 MIRU MOVE RURD P M/U fittings to annular,strap diverter 0.0 0.0 21:45 23:15 line,and prepare to nipple up riser. Note:64.47'RKB to MSL 4/15/2016 4/16/2016 0.75 MIRU MOVE SFTY P Hold pre-spud meeting with crew. 0.0 0.0 23:15 00:00 4/16/2016 4/16/2016 2.50 MIRU MOVE RURD P N/U diverter,install hydraulic hoses, 0.0 0.0 00:00 02:30 and energize accumulator. SIMOPS-Load/strap 5"DP in shed. 4/16/2016 4/16/2016 2.50 MIRU MOVE SLPC P Cut 85'of drill line and calibrate 0.0 0.0 02:30 05:00 blocks. 4/16/2016 4/16/2016 1.00 MIRU MOVE SEQP P Function test diverter w/5"DP double. 0.0 0.0 05:00 06:00 4/16/2016 4/16/2016 3.00 MIRU MOVE RURD P Change out saver sub for 5"DP. 0.0 0.0 06:00 09:00 4/16/2016 4/16/2016 1.25 MIRU MOVE BOPE P Test diverter system: knife valve 0.0 0.0 09:00 10:15 opened in 3 seconds and annular closed in 35 seconds,witnessed by AOGCC rep Brian Bixby.Check gas alarm calibration and inspect accumulator. 4/16/2016 4/16/2016 0.50 MIRU MOVE SFTY P Perform table-top diverter drill 0.0 0.0 10:15 10:45 4/16/2016 4/16/2016 4.75 MIRU MOVE PULD P P/U and rack back 33 x stands 5"DP. 0.0 0.0 10:45 15:30 Note:Tagged up at 71'MD. 4/16/2016 4/16/2016 0.50 MIRU MOVE SEQP .P Calbirate Totco system 0.0 0.0 15:30 16:00 4/16/2016 4/16/2016 1.25 MIRU MOVE PULD P P/U and rack back 6 x stands 5" 0.0 0.0 16:00 17:15 HWDP w/jar. 4/16/2016 4/16/2016 0.75 MIRU MOVE SVRG P Service top drive and blocks. 0.0 0.0 17:15 18:00 4/16/2016 4/16/2016 1.50 MIRU MOVE SEQP P Calibrate Quadco and Schlumberger 0.0 0.0 18:00 19:30 equipment 4/16/2016 4/16/2016 2.50 MIRU MOVE BHAH P Make up surface cleanout BHA#1 as 0.0 71.0 19:30 22:00 per DD, RIH and tag up at @ 71'MD w/4k WOB. 4/16/2016 4/16/2016 0.50 MIRU MOVE SEQP P Fill hole and surface lines w/fresh 71.0 71.0 22:00 22:30 water and pressure test high pressure mud lines to 3,500 psi. 4/16/2016 4/16/2016 0.50 MIRU MOVE DRLG P Stage up pumps to 400 GPM,250psi, 71.0 120.0 22:30 23:00 and cleanout conductor with fresh water from 71'MD to 120'MD w/0-5k WOB. 4/16/2016 4/17/2016 1.00 SURFAC DRILL DDRL P Swap over to spud mud and drill 13- 120.0 130.0 23:00 00:00 1/2"surface hole from 120'MD to 130' MD with 400 GPM,250psi,32%flow out,40 RPM, 1k TQ,and 0-5k WOB. Page 1/32 Report Printed: 6/1/2016 00 *rations Summary (with Timelog ths) 3S-613 conocoPhishps Rig: DOYON 142 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) 4/17/2016 4/17/2016 1.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 130'to 130.0 225.0 00:00 01:00 225'MD w/0-5k WOO, 1k TQ,40 RPM,400 GPM,250 PSI,32%F/O. 4/17/2016 4/17/2016 1.50 SURFAC DRILL TRIP P POOH from 225'to surface.Inspect 225.0 0.0 01:00 02:30 bit:0-0-WT-A-E-N-NO-BHA. 4/17/2016 4/17/2016 3.50 SURFAC DRILL SHAH P P/U and M/U 13-1/2"drilling BHA to 0.0 140.0 02:30 06:00 140'MD as per DD. 4/17/2016 4/17/2016 0.75 SURFAC DRILL DHEQ P Cycle pumps to test MWD/GYRO 140.0 140.0 06:00 06:45 tools w/600 GPM,596 PSI-good test. 4/17/2016 4/17/2016 1.00 SURFAC DRILL BHAH P Continue P/U and M/U BHAw/drill 140.0 225.0 06:45 07:45 collars from 140'to 225'MD. 4/17/2016 4/17/2016 0.50 SURFAC DRILL DHEQ P Cycle pumps to test MWD/GYRO 225.0 225.0 07:45 08:15 tools w/600 GPM,660 PSI-good test. 4/17/2016 4/17/2016 3.75 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 225'to 225.0 582.0 08:15 12:00 582'MD w/5k WOB,40 RPM,3k TQ, 600 GPM,950 PSI,39%F/O,PUW 82k,SOW 88k,ROT 88k KOP @ 302'MD 4/17/2016 4/17/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 582'to 582.0 1,200.0 12:00 18:00 1,200'MD w/15-20k WOB,60 RPM, 4k TQ,611 GPM, 1230 PSI,39%F/O, PUW 93k,SOW 97k,ROT 97k. Note:Swap to MWD surveys from 970'MD onward. 4/17/2016 4/18/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1,200' 1,200.0 1,623.0 18:00 00:00 to 1,623'MD w/25k WOB,50-90 RPM,4k TQ,663 GPM, 1560 PSI, 39%F/O,PUW 104k,SOW 101k, ROT 103k. Note:Observed 900 PSI increase in SPP @ 1,310'MD after cycling pumps -after troubleshooting,determined IBOP wasn't open fully.After manual functioning,SPP went back to normal. 4/18/2016 4/18/2016 6.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1,623' 1,623.0 1,999.0 00:00 06:00 to 1,999'MD w/25k WOB,80 RPM, 5k TQ,618 GPM, 1,510 PSI,39% F/O,POW 114k,SOW 105k,ROT 108k. 4/18/2016 4/18/2016 1.25 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 1,999' 1,999.0 2,015.0 06:00 07:15 to 2,015'MD w/15k WOB,50 RPM, 6k TO,657 GPM, 1,550 PSI,41% F/O.Observe 8.2°dogleg @ 2,013' MD. 4/18/2016 4/18/2016 2.75 SURFAC DRILL BKRM T Backream hole section between 2,015' 2,015.0 1,907.0 07:15 10:00 to 1,812'MD w/700 GPM,1,550 PSI, 43%F/0,50 RPM,5k TQ. 4/18/2016 4/18/2016 2.00 SURFAC DRILL REAM T Attempt to work through tight hole @ 1,907.0 1,998.0 10:00 12:00 1,906'MD.Orient high side and slide down from 1,906'to 1,998'MD w/10- 30k WOB,700 GPM, 1,750 PSI,42% F/O. 1 Page 2/32 Report Printed: 6/1/2016 0 III F , j' , Operations Summary (with Timelog Depths) y, 3S-613 C.ionocoPhillips P r hvka Rig: DOYON 142 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) 4/18/2016 4/18/2016 0.50 SURFAC DRILL BKRM T Backream hole section between 1,998' 1,998.0 1,900.0 12:00 12:30 to 1,900'MD w/700 GPM, 1,610 PSI, 42%F/O,60 RPM,5k TQ. 4/18/2016 4/18/2016 0.25 SURFAC DRILL REAM T Orient high side and slide through hole 1,900.0 2,015.0 12:30 12:45 section from 1,900'MD to 2,015'MD, rolling pumps to keep jets from plugging-no tight hole observed. Final check survey showed dogleg reduced to 7.6°@ 2,013'MD. 4/18/2016 4/18/2016 5.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2,015' 2,015.0 2,283.0 12:45 17:45 to 2,283'MD w/25k WOB,700 GPM, 1,780 PSI,42%F/O,60 RPM,6k TQ, PUW 115,SOW 105,ROT 108. 4/18/2016 4/18/2016 0.25 SURFAC DRILL OTHR P Blowdown topdrive and reciprocate 2,283.0 2,283.0 17:45 18:00 string. 4/18/2016 4/18/2016 1.00 SURFAC DRILL SFTY P Hold safety stand down with both 2,283.0 2,283.0 18:00 19:00 crews. 4/18/2016 4/19/2016 5.00 SURFAC DRILL DDRL P Drill 13-1/2"surface hole from 2,283' 2,283.0 2,570.0 19:00 00:00 to 2,570'MD w/25k WOB,711 GPM, 1,850 PSI,42%F/O,70 RPM,6k TQ, PUW 121k,SOW 105k,ROT 110k. 4/19/2016 4/19/2016 5.50 SURFAC DRILL DDRL P PJSM,DDrill f/2570'-2908'MD,2575' 2,570.0 2,908.0 00:00 05:30 TVD,AST 2.54,ADT 4.23,Bit 19.84, Jars 19.84,PU 124K,SO 108K,ROT 11OK,120 rpm,Tq on 7K,FO 29%, WOB 29K,707 gpm,2033 psi 4/19/2016 4/19/2016 0.25 SURFAC CASING SRVY P Take final TD survey @ 2908'MD, 2,908.0 2,908.0 05:30 05:45 2577'TVD. 4/19/2016 4/19/2016 0.25 SURFAC CASING OWFF P Monitor well,static 2,908.0 2,908.0 05:45 06:00 4/19/2016 4/19/2016 2.25 SURFAC CASING CIRC 'P PJSM-CBU 3X @ 700 gpm, 1800 psi, 2,908.0 2,665.0 06:00 08:15 70 rpm,Tq 4-6K,FO 40%,f/2908'- 2665'MD. 4/19/2016 4/19/2016 3.50 SURFAC CASING BKRM P PJSM-BROOH f/2665'-1808'MD @ 2,665.0 1,808.0 08:15 11:45 700 gpm, 1720-1570 psi,70 rpm,Tq 3 -5K,FO 40%,. 4/19/2016 4/19/2016 0.50 SURFAC CASING TRIP T PJSM-TIH f/1808'-2095'MD,PU 1,808.0 2,095.0 11:45 12:15 115K,SO 105K. 4/19/2016 4/19/2016 0.75 SURFAC CASING BKRM T PJSM-BROOH f/2095'-1808'MD @ 2,095.0 1,808.0 12:15 13:00 700 gpm, 1520 psi,70 rpm,Tq 2-6K, FO 41%,PU 103K,SO 98K. 4/19/2016 4/19/2016 1.75 SURFAC CASING BKRM P PJSM-BROOH f/1808'-1336'MD @ 1,808.0 1,336.0 13:00 14:45 700 gpm, 1520 psi,70 rpm,Tq 2-6K, FO 41%,PU 103K,SO 98K. 4/19/2016 4/19/2016 0.25 SURFAC CASING OWFF P Monitor well,static 1,336.0 1,336.0 14:45 15:00 4/19/2016 4/19/2016 0.50 SURFAC CASING TRIP P Make several attempts to TOH @ 1,336.0 1,336.0 15:00 15:30 1336'MD,observe 45K over pull at 1320'MD. 4/19/2016 4/19/2016 2.50 SURFAC CASING BKRM P PJSM-BROOH f/1336'-770'MD @ 1,336.0 770.0 15:30 18:00 500 gpm,960 psi,60 rpm,Tq 1K,FO 30%,PU 87K,SO 89K. 4/19/2016 4/19/2016 1.50 SURFAC CASING TRIP P PJSM-stand back HWDP in derrick 770.0 211.0 18:00 19:30 770'-211'MD. Page 3/32 Report Printed: 6/1/2016 •erations Summary (with Timelogths) 2 � i 3S-613 Gortoco0 pro hps Rig: DOYON 142 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) 4/19/2016 4/19/2016 3.50 SURFAC CASING BHAH P PJSM-lay down BHA 2 as per SLB 211.0 0.0 19:30 23:00 DD to surface. 4/19/2016 4/20/2016 1.00 SURFAC CASING BHAH P Clear BHA&clean rig floor. 0.0 0.0 23:00 00:00 4/20/2016 4/20/2016 2.00 SURFAC CASING RURD P Clean up rig floor,C/O and install 0.0 0.0 00:00 02:00 pony bails. 4/20/2016 4/20/2016 3.00 SURFAC CASING RURD P M/U Volant tool,install 350 Ton slips 0.0 0.0 02:00 05:00 and R/U power tongs 4/20/2016 4/20/2016 1.75 SURFAC CASING PUTB P P/U and M/U 10 3/4"shoe track total 0.0 164.0 05:00 06:45 length 164'. Pump 5 bpm @ 25 psi with 17%F/O. Good check on floats. 4/20/2016 4/20/2016 5.25 SURFAC CASING PUTB P P/U&TIH with 10 3/4",45.5#,L-80 164.0 1,249.0 06:45 12:00 Hydril 563 dopeless casing with bow spring centralizers on every joint from 164'to 1249'MD.M/U 19.4K ft/lbs,fill on the fly and top up every 10 joints. 4/20/2016 4/20/2016 1.50 SURFAC CASING PUTB T Begin working tight spot from 1249'- 1,249.0 1,261.0 12:00 13:30 1261'.Washing down at 3-7 bpm,90- 120 psi.Break through&continue to run in hole.Observe pieces of wood returning to surface. - 4/20/2016 4/20/2016 9.50 SURFAC CASING PUTB T Continue running in the hole f/1261'- 1,261.0 1,301.0 13:30 23:00 1301'.Work through another tight spot from 1281'-1301'.Washing down at 3 -7 bpm,90-120 psi, 15 rpm,Tq 7-14K. Spot high-vis lube pill on bottom. Continue varying parameters to break through&continue to run in hole. Observe pieces of wood returning to surface. 4/20/2016 4/21/2016 1.00 SURFAC CASING PUTB P P/U&TIH with 10 3/4",45.5#,L-80 1,301.0 1,423.0 23:00 00:00 Hydril 563 dopeless casing with bow spring centralizers on every joint from 1301'to 1423'MD.M/U 19.4K ft/lbs, fill on the fly and top up every 10 joints. PU 105K,SO 89K. 4/21/2016 4/21/2016 2.00 SURFAC CASING PUTB -P PJSM-P/U&TIH with 10 3/4",45.5#, 1,423.0 1,926.0 00:00 02:00 L-80 Hydril 563 dopeless casing with bow spring centralizers on every joint from 1423'to 1926'MD.M/U 19.4K ft/lbs,fill on the fly and top up every 10 joints. PU 130K,SO 107K. 4/21/2016 4/21/2016 4.00 SURFAC CASING PUTB -T Work through another tight spot from 1,926.0 1,985.0 02:00 06:00 1926'-1985'MD.Washing down at 3- 5 bpm,60-90 psi(wash& reciprocate).Continue varying parameters to break through& continue to run in hole. 4/21/2016 4/21/2016 4.25 SURFAC CASING PUTB P Continue to TIH with 10 3/4",45.5#,L- 1,985.0 2,859.0 06:00 10:15 80 Hydril 563 dopeless casing with bow spring centralizers on every joint from 1985'to 2859'MD.Washing each joint down at 3 bpm, 140 psi,PU _ 166K,SO 115K. 10-3/4"HYD 563 DPLS,0 Rejects,0 Remakes. Page 4/32 Report Printed: 6/1/2016 • • Operations Summary (with 1 � TimelogDepths) the p ) wA Y-.2,,C4, i, 74, Fi ii1n,t l 3S-613 ConocoPhillips Rig: DOYON 142 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) 4/21/2016 4/21/2016 0.75 SURFAC CASING HOSO P PJSM-make up hanger&landing joint 2,859.0 2,901.0 10:15 11:00 f/2859'-2901'MD,washing down at 3 bpm, 130 psi,PU 130K,SO 104K. 4/21/2016 4/21/2016 0.25 SURFAC CEMENT RURD P PJSM-blow down TD&rig up cement 2,901.0 2,901.0 11:00 11:15 line. 4/21/2016 4/21/2016 2.75 SURFAC CEMENT CIRC P Circulate&condition for cementing. 2,901.0 2,901.0 11:15 14:00 Pump nut plug sweep&chase with treated mud at 3 bpm, 155 psi.Stage pumps up to 8 bpm,335 psi,PU 170K,SO 126K. 4/21/2016 4/21/2016 5.00 SURFAC CEMENT CMNT P PJSM-flood cement lines with H20, 2,901.0 0.0 14:00 19:00 PT lines at 900&4000 psi.Pump 100 bbls of 10.5 ppg MP II w/red dye at 5 bpm,65 psi.Load bottom plug.Batch up&pump 593 bbls of 11.0 ppg lead cement at 6 bpm, 190 psi.Pump 60 bbls of 15.8 ppg tail cement at 4.5 bpm,200 psi.Load top plug&pump 10 bbls of fresh H20.Swap to rig pumps&chase with 9.3 ppg mud at 5 bpm,200-650 psi.Bump the plug with 2537 strokes,261 bbls. 11.0 ppg lead cement was observed at shakers @ 1170 strokes, 136.7 bbls retured to surface.Pressure up to 1100 psi& hold for 5 minutes.Bleed off pressure &check floats,good.CIP at 18:57 hrs. 4/21/2016 4/21/2016 2.00 SURFAC CEMENT RURD P PJSM-flush&blow down all surface 0.0 0.0 19:00 21:00 cement lines.Flush stack with black water pill.SIMOPS clean out&grease all 3"manifold valves. 4/21/2016 4/22/2016 3.00 SURFAC CEMENT RURD P PJSM-rig down&clean CRT,long 0.0 0.0 21:00 00:00 bails,bail extensions,power tongs. Install short bails.Clear all equipment from rig floor.SIMOPS load 5"DP in the pipe shed. 4/22/2016 4/22/2016 4.00 SURFAC CEMENT NUND P PJSM-flush&clean all diverter 0.0 0.0 00:00 04:00 equipment,pull risers,remove 4" valves from conductor,remove all lines.SIMOPS clean pits&break out studs on annular. 4/22/2016 4/22/2016 2.00 SURFAC CEMENT -NUND P PJSM-nipple down diverter system& 0.0 0.0 04:00 06:00 one section of diverter line to close cellar door. 4/22/2016 4/22/2016 2.00 SURFAC WHDBOP NUND P PJSM- nipple up well head per 0.0 0.0 06:00 08:00 schematic,FMC,&DSO.Test seals to 5000 for 10 min.Obtain RKB's,34.63' RKB to top of well head flange. 4/22/2016 4/22/2016 8.50 SURFAC WHDBOP NUND P PJSM-nipple up BOPE,install DSA,2' 0.0 0.0 08:00 16:30 spool&BOP stack.Torque all flanges. Install choke&kill hoses. Install air boot flange on top of annular.Install riser from BOPE to rig floor. 4/22/2016 4/22/2016 1.00 SURFAC CEMENT RURD P PJSM-rig up to pick up DP to stand 0.0 0.0 16:30 17:30 back in derrick.SIMOPS complete DP tally in pipe shed. Page 5/32 Report Printed: 6/1/2016 0 _ rations Summary (with Timelog Dhs) ' 3S-613 Cor ooM:Hhitlipis Atl Rig: DOYON 142 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) 4/22/2016 4/23/2016 6.50 SURFAC CEMENT PULD P PJSM-pick up 114 joints of 5"DP via 0.0 0.0 17:30 00:00 mouse hole&rack back in the derrick. 4/23/2016 4/23/2016 4.50 SURFAC CEMENT PULD P PJSM-pick up 75 joints of 5"DP via 0.0 0.0 00:00 04:30 mouse hole&rack back in the derrick. 4/23/2016 4/23/2016 0.50 SURFAC WHDBOP RURD P PJSM-set test plug&rig up test 0.0 0.0 04:30 05:00 equipment. 4/23/2016 4/23/2016 0.50 SURFAC WHDBOP BOPE P PJSM-fill lines&stack w/H2O. 0.0 0.0 05:00 05:30 Conduct BOP body test,for BWM, to 2500 psi(good). 4/23/2016 4/23/2016 5.00 SURFAC WHDBOP BOPE P PJSM-Test BOPE w/5"TJ,all tests 0.0 0.0 05:30 10:30 other than annular tested to 250/3000 PSI. 1)Annular to 250/2500 PSI;2) Upper 3%2"x 6"VBR's,CV#1,#12, #13,#14&4"Kill on Mud Line;3)CV #9,#11,Mezzanine Kill Line Valve& Dart Valve;4)CV#8,#10, HCR Kill, FOSV;5)CV#66)Super choke &manual choke to 2000 psi;7)CV#2, #5,Manual Kill;8)Upper IBOP(failed), HCR Choke;9)Lower IBOP,Manual Choke;10)Lower 3%2'x 6"VBR's; 11)Blinds,CV#3,#4,#6;12)Upper IBOP Retest.Perform Koomey draw down test initial system pressure 3000 psi,after closure 1900 psi,200 psi attained in 17 sec,full pressure attained in 82 sec, 6 nitrogen bottles with an average pressure of 2633 PSI. All H2S and Combustible gas alarms tested with audible and light alarms. Test waived by AOGCC Rep-Guy Cook • 4/23/2016 4/23/2016 1.00 SURFAC WHDBOP RURD P PJSM-pull test plug,install 10-1/8"ID 0.0 0.0 10:30 11:30 wear bushing,blow down all lines. 4/23/2016 4/23/2016 0.50 SURFAC WHDBOP SVRG P PJSM-service rig,grease crown. 0.0 0.0 11:30 12:00 4/23/2016 4/23/2016 4.00'SURFAC WHDBOP -RGRP T PJSM-change out upper IBOP,Tq 6- 0.0 0.0 12:00 16:00 5/8"reg connection to 44K ft/lbs.Tq ring bolts to 185 ft/lbs. 4/23/2016 4/23/2016 0.50 SURFAC WHDBOP SVRG P PJSM-service rig,grease top drive. 0.0 0.0 16:00 16:30 4/23/2016 4/23/2016 1.50 SURFAC -WHDBOP BOPE T Retest IBOP to 250/3500 psi,5 min 0.0 0.0 16:30 18:00 each.Blow down TD&test equipment. 4/23/2016 4/23/2016 4.50 SURFAC CEMENT BHAH P PJSM-mobilize BHA to rig floor,make 0.0 752.0 18:00 22:30 up BHA 3 as per SLB DD TO 752'MD. .4/23/2016 4/24/2016 1.50 SURFAC CEMENT PULD P PJSM-single in the hole f/752'-1895' 752.0 1,859.0 22:30 00:00 MD,PU 99K,SO 89K. 4/24/2016 4/24/2016 1.50 SURFAC CEMENT PULD P PJSM-single in the hole f/1895'-2653' 1,859.0 2,653.0 00:00 01:30 MD,PU 130K,SO 100K. 4/24/2016 4/24/2016 1.50 SURFAC CEMENT CIRC P Circulate&condition mud to 9.2 ppg 2,653.0 2,653.0 01:30 03:00 in&out. 4/24/2016 4/24/2016 0.50 SURFAC -CEMENT DHEA P Shallow hole test MWD @ 500 gpm, 2,653.0 2,653.0 03:00 03:30 1150 psi,good. Page 6/32 Report Printed: 6/1/2016 w • 1Operations Summary (with Timelog Depths) ' 0i 1;. L .' •' S p 745, 3S-613 ,K` ConocoPhilliprs Rig: DOYON 142 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) 4/24/2016 4/24/2016 1.00 SURFAC CEMENT PRTS P PJSM-rig up&test 10-3/4"surface 2,653.0 2,653.0 03:30 04:30 casing to 3000 psi for 30 minutes. Rig/blow down equipment. 4/24/2016 4/24/2016 2.00 SURFAC CEMENT SLPC P PJSM-cut&slip 38"of drill line. 2,653.0 2,653.0 04:30 06:30 Calibrate Totco&Amphion systems. 4/24/2016 4/24/2016 0.50 SURFAC CEMENT COCF P PJSM-wash to TOC f/2653'-2797' 2,653.0 2,797.0 06:30 07:00 MD.500 gpm, 1142 psi,FO 24%, setting down 5K, PU 130K,SO 105K, ROT 114K. 4/24/2016 4/24/2016 1.00 SURFAC CEMENT COCF P Drill out cement to float collar f/2797'- 2,797.0 2,816.0 07:00 08:00 2816'MD,450-550 gpm, 1200-1300 psi,FO 30%,60-70 rpm,Tq 7-8K, WOB 4-10K,PU 130K,SO 105K, ROT114K. 4/24/2016 4/24/2016 7.00 SURFAC CEMENT DRLG T Attempt to drill out float collar at 2816' 2,816.0 2,816.0 08:00 15:00 MD,w/varying parameters,450-550 gpm,1200-1300 psi,FO 30%,60-70 rpm,Tq 7-8K,WOB 4-10K, PU 130K, SO 105K, ROT114K. 4/24/2016 4/24/2016 0.50 SURFAC CEMENT OWFF T Monitor well,static.SIMOPS blow 2,816.0 2,816.0 15:00 15:30 down TD&prep to TOH. 4/24/2016 4/24/2016 2.00 SURFAC CEMENT TRIP T PJSM-TOH f/2816'to surface. 2,816.0 193.0 15:30 17:30 4/24/2016 4/24/2016 1.00 SURFAC CEMENT -BHAH T PJSM-stand back NMFC,remove 193.0 0.0 17:30 18:30 source,&break off bit. 4/24/2016 4/24/2016 0.50 SURFAC CEMENT PRTS P PJSM-rig up&test casing to 3000 psi 0.0 0.0 18:30 19:00 for 10 minutes,good.Blow down lines. 4/24/2016 4/24/2016 2.00 SURFAC CEMENT BHAH T PJSM-make up BHA 4,w/mill tooth 0.0 752.0 19:00 21:00 bit,f/0-752'MD. 4/24/2016 4/24/2016 1.00 SURFAC CEMENT TRIP T PJSM-TIH f/752'-2816'MD. 752.0 2,816.0 21:00 22:00 4/24/2016 4/25/2016 2.00 SURFAC CEMENT DRLG P Drill out float collar&shoe track f/ 2,816.0 2,833.0 22:00 00:00 2816'-2833'MD,200-500 gpm, 190- 1150 psi,40-70 rpm,Tq 5-10K,WOB 5-30K,PU 130K,SO 105K, ROT114K. Observed plug debris returns to surface after drilling through shoe track. 4/25/2016 4/25/2016 1.50 SURFAC CEMENT DRLG P Drill out shoe track f/2833'-2908'MD, 2,833.0 2,908.0 00:00 01:30 500 gpm, 1150 psi,60 rpm,Tq 8K, WOB 4K,PU 130K,SO 105K, ROT114K. 4/25/2016 4/25/2016 1.00 SURFAC CEMENT DDRL P DDrill intermediate hole section f/ 2,908.0 2,928.0 01:30 02:30 2908'-2928'MD,2586'TVD,Bit .46, Jars 19.95,PU 131K,SO 100K,ROT 115K,60 rpm,Tq on 8K,off 6K,FO 26%, WOB 5K,500 gpm, 1146 psi. Total footage 20'MD. 4/25/2016 4/25/2016 0.75 SURFAC CEMENT FIT T PJSM-rig up&perform FIT at 2902' 2,928.0 2,928.0 02:30 03:15 MD,2572'TVD,to an EMW of 16.0 ppg,with 9.5 ppg mud.Pressured up to 870 psi.Shut in&observe pressure decrease from 870 to 700 psi in 10 minutes. 4/25/2016 4/25/2016 0.25 INTRM1 DRILL OWFF T Monitor well,static.SIMOPS blow 2,928.0 2,928.0 03:15 03:30 down test equipment. 4/25/2016 4/25/2016 3.00 INTRM1 DRILL TRIP T PJSM-TOH f/2928'-91'MD. 2,928.0 91.0 03:30 06:30 Page 7132 Report Printed: 6/1/2016 02) •rations Summary (with Timelog ths) ` t I i 3S-613 cono iIlips Rig: DOYON 142 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) 4/25/2016 4/25/2016 0.50 INTRM1 DRILL BHAH T PJSM-change out milled tooth bit 91.0 91.0 06:30 07:00 (XR+)to Si519 PDC, 4/25/2016 4/25/2016 0.50 INTRM1 DRILL EQRP T PJSM-change out SLB pressure 91.0 91.0 07:00 07:30 transducer on stand pipe. 4/25/2016 4/25/2016 3.00 INTRM1 DRILL TRIP T PJSM-TIH f/91'-2840'MD,PU 130K, 91.0 2,840.0 07:30 10:30 SO 100K. 4/25/2016 4/25/2016 0.50 INTRM1 DRILL SVRG P PJSM-grease blocks. 2,840.0 2,840.0 10:30 11:00 4/25/2016 4/25/2016 1.00 INTRM1 DRILL RURD P PJSM-rig up to circulate w/head pin 2,840.0 2,840.0 11:00 12:00 &cement line. 4/25/2016 4/25/2016 0.75 INTRMI DRILL CIRC P CBU @ 338 gpm,720 psi,FO 17%. 2,840.0 2,840.0 12:00 12:45 4/25/2016 4/25/2016 0.50 INTRM1 DRILL FIT P PJSM-rig up&perform FIT at 2902' 2,840.0 2,840.0 12:45 13:15 MD,2572'TVD,to an EMW of 16.0 ppg,with 9.5 ppg mud.Pressured up to 880 psi.Shut in&observe pressure decrease from 880 to 750 psi in 10 minutes. 4/25/2016 4/25/2016 0.50 INTRM1 DRILL SVRG P Service rig,lube Back Saver hydraulic 2,840.0 2,840.0 13:15 13:45 slips. 4/25/2016 4/25/2016 2.00 INTRM1 DRILL RGRP T PJSM-trouble shoot&repair Top 2,840.0 2,840.0 13:45 15:45 Drive rotary.Change out damaged wire to rotary. 4/25/2016 4/25/2016 0.75 INTRM1 DRILL DISP .P PJSM-displace to 9.2 ppg LSND mud 2,840.0 2,928.0 15:45 16:30 system f/2840'-2928'MD.Pump 35 bbl High-Vis spacer,then pump 9.2 ppg LSND @ 475 gpm,760 psi,FO 27%,70 rpm,Tq 7K. - 4/25/2016 4/26/2016 7.50 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 2,928.0 3,484.0 16:30 00:00 2928'-3484'MD,2855'TVD,Bit 5.24, Jars 25.54,PU 130K,SO 105K,ROT 120K,120 rpm,Tq on 8K,off 6K,ECD 9.8 ppg, FO 27%, WOB 5K,700 gpm,1600 psi.Total footage 556'MD. 4/26/2016 4/26/2016 6.00 INTRM1 DRILL DDRL P Drill from 3484'to 4072',TVD 3046', 3,484.0 4,072.0 00:00 06:00 4.24 ADT,9.48 Bit hrs.29.78 Jar Hrs, 113K P/U weight,102K down wt, 150 RPM,9K trq on bottom,7K free spin, 10.2 ECD,28%flow,8K WOB,700 GPM, 1775 psi,106 units gas. SPR @3677'MDMW=9.2 #1 MP 2/3 BPM=100/140 psi #2 MP 2/3 BPM=100/140 psi 4/26/2016 4/26/2016 6.00 INTRM1 DRILL DDRL P Drill 4072'-4670',TVD 3241',700 4,072.0 4,670.0 06:00 12:00 GPM, 1962 psi,30%flow,160 RPM, 11K TQ,8-10K WOB,ECD 10.52. Off bottom-1960 psi,P/U 157K,S/O 104K,ROT=119K,8K TQ,ART 4.11, ADT 4.11,total bit hours 13.59,jar hrs 33.89 SPR @ 4165'3079 TVD,MW=9.2 PPG #1 MP 2/3 BPM=100/140 psi #2 MP 2/3 BPM=100/140 psi. Page 8/32 Report Printed: 6/1/2016 • Operations Summary (with Timelog Depths) 3S-613 ConocoPhillips Rig: DOYON 142 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) 4/26/2016 4/26/2016 6.00 INTRMI DRILL DDRL P Drill 4670'-5210,TVD 3422',700 4,670.0 5,210.0 12:00 18:00 GPM, 1962 psi,30%flow,140 RPM, 10K TQ,8-10K WOB,ECD 10.52. Off bottom-2000 psi,P/U 155K,S/O 104K,ROT= 120K,8K TQ,ART 4.43, ADT 4.43,total bit hours 18.02,jar hrs 38.82 SPR @ 4644',3231 TVD,MW=9.4 PPG #1 MP 2/3 BPM=140/160 psi #2 MP 2/3 BPM=120/160 psi. 4/26/2016 4/27/2016 6.00 INTRM1 DRILL DDRL P 5390'-one abbreviated ECD spike to 5,210.0 5,682.0 18:00 00:00 11.2 from 10.6,slowed ROP from 125 to 100.Kept ROP from 100-115 most of the night due to ECD. Mud checks showed 10%solids,begin using mud cleaner @ 22:30 hrs.order dilution truck. Drill 5210-5682',TVD 3578',706 GPM,2264 psi,30%flow,140 RPM, 10K TQ,8-10K WOB,ECD 10.66. Off bottom-2266 psi,P/U 152K,S/O 104K,ROT=121K,8K TQ,ART 4.42, ADT 4.42,total bit hours 22.44,jar hrs 42.74 SPR @ 5210',3421 TVD,MW=9.3 PPG #1 MP 2/3 BPM=125/190 psi #2 MP 2/3 BPM=140/180 psi. 4/27/2016 4/27/2016 6.00 INTRMI DRILL DDRL P DDrill intermediate hole section f/ 5,682.0 6,200.0 00:00 06:00 5682'to 6200',TVD=3743',Bit hrs= 26.68,Jars hrs=46.98,PU 159K,SO 105K,ROT 125K, 130 rpm,Tq on 10K,off 8K,ECD 10.66 ppg, FO 30%, WOB 8K,700 gpm,2175 psi.Total footage=518' SPR @ 5966'MD MW=9.4 @ 03:00 hours #1 MP 20/30 SPM=130/190 psi #2 MP 20/30 SPM=140/190 psi 4/27/2016 4/27/2016 6.00 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 6,200.0 6,731.0 06:00 12:00 6200'to 6731',TVD=3916',Bit hrs= 31.07,Jars hrs=51.37,PU 182K,SO 116K, ROT 131K, 120 rpm,Tq on 11K,off 9K,ECD 10.78 ppg, FO 30%, WOB 8K,700 gpm,2380 psi.Total footage=531' SPR @ 6363'MD MW=9.4 @ 10:30 hours #1 MP 20/30 SPM=140/190 psi #2 MP 20/30 SPM=140/190 psi Page 9/32 Report Printed: 6/1/2016 *rations Summary (with Timelog D hs) 3S-613 Co€ a;Phitb s A Rig: DOYON 142 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) 4/27/2016 4/27/2016 6.00 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 6,731.0 7,206.0 12:00 18:00 6731'to 7206',TVD=4071',Bit hrs= 35.30,Jars hrs=55.60,PU 170K,SO 117K,ROT 135K, 130 rpm,Tq on 11K,off 10K,ECD 10.71 ppg, FO 28%, WOB 11K,700 gpm,2375 psi. Total footage=475' Spill Drill CRT 80 sec @ 14:20 hrs. SPR @ 7200'MD,4071'TVD,MW= 9.4©17:30 hours • #1 MP 20/30 SPM=160/2100 psi #2 MP 20/30 SPM=160/210 psi 4/27/2016 4/28/2016 6.00 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 7,206.0 7,840.0 18:00 00:00 7206'to 7840',TVD=4282',Bit hrs= 39.60,Jars hrs=59.9,PU 155K,SO 122K,ROT 136K, 140 rpm,Tq on 10K,off 8K,ECD 10.56 ppg, FO 29%, WOB 7K,700 gpm,2530 psi.Total footage=634' SPR @ 7676'MD,4227'TVD,MW= 9.3 @ 22:30 hours #1 MP 20/30 SPM=180/240 psi #2 MP 20/30 SPM=200/240 psi 4/28/2016 4/28/2016 6.00 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 7,840.0 8,456.0 00:00 06:00 7840'to 8456',TVD=4486',ADT 4.04,Bit hrs=44.13,Jars hrs=64.43, PU 166K,SO 128K, ROT 150K,165 rpm,Tq on 10-12K,off 11K,ECD 10.68 ppg, FO 29%, WOB 10K,700 gpm,2570 psi.Total footage=616' Table Top Kick w/Drilling @ 02:30 hrs SPR @ 8244'MD,4416'TVD,MW= 9.4©04:00 hours #1 MP 20/30 SPM=220/240 psi #2 MP 20/30 SPM=190/240 psi 4/28/2016 4/28/2016 6.00 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 8,456.0 9,162.0 06:00 12:00 8456'to 9162',TVD=4719',ADT 4,27,Bit hrs=48.4,Jars hrs=68.70, PU 183K,SO 134K, ROT 150K, 140 rpm,Tq on 13K,off 10K,ECD 10.77 ppg, FO 27%, WOB 12K,700 gpm, 2641 psi.Total footage=706' SPR @ 8719'MD,4573'TVD,MW= 9.6©08:00 hours #1 MP 20/30 SPM=200/280 psi #2 MP 20/30 SPM=220/300 psi 4/28/2016 4/28/2016 8.50 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 9,162.0 10,049.0 12:00 20:30 9162'to 10049',TVD=4975',ADT 5.29,Bit hrs=53.69,Jars hrs=74.01, PU 202K,SO 131K,ROT 147K, 140 rpm,Tq on 15K,off 12K,ECD 10.63 ppg, FO 27%, WOB 13K,700 gpm, 2463 psi.Total footage=887' Fire Drill CRT 60 sec©14:00 hrs. SPR @ 9194'MD,4731'TVD,MW= 9.6 @ 12:30 hours #1 MP 20/30 SPM=200/260 psi #2 MP 20/30 SPM=200/260 psi Page 10/32 Report Printed: 6/1/2016 Operations Summary (with Timelog Depths) _ �, !3si 3S-613 iConoc©Phillips Rig: DOYON 142 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) 4/28/2016 4/28/2016 0.75 INTRM1 DRILL SRVY T PJSM-pull up to 9955're shoot 10,049.0 10,049.0 20:30 21:15 survey.Run back in&resume drilling. 4/28/2016 4/29/2016 2.75 INTRM1 DRILL DDRL P DDrill intermediate hole section f/ 10,049.0 10,356.0 21:15 00:00 10049'to 10356',TVD=5043',ADT 1.76,Bit hrs=55.45,Jars hrs=75.75, PU 205K,SO 122K,ROT 151K, 140 rpm,Tq on 17K,off 16K,ECD 10.54 ppg, FO 28%, WOB 13K,708 gpm, 2448 psi.Total footage=307' SPR @ 10142'MD,4998'TVD,MW= 9.3©22:00 hours #1 MP 20/30 SPM=220/280 psi #2 MP 20/30 SPM=220/280 psi 4/29/2016 4/29/2016 5.00 INTRMI DRILL DDRL P DDrill intermediate hole section f/ 10,356.0 10,902.0 00:00 05:00 10356'to 10902',TVD=5147',ADT 3.21,Bit hrs=58.66,Jars hrs=78.96, PU 224K,SO 114K,ROT 152K, 140 rpm,Tq on 18K,off 16K,ECD 10.51 ppg, FO 29%, WOB 15K,711 gpm, 2550 psi.Total footage=546' SPR @ 10805'MD,5131'TVD,MW= 9.2 @ 04:00 hours #1 MP 20/30 SPM=210/260 psi #2 MP 20/30 SPM=210/250 psi 4/29/2016 4/29/2016 1.00 INTRMI DRILL RGRP T PJSM-change out swab&liner in#1 10,902.0 10,902.0 05:00 06:00 pump,#1 pod.Circulate at 480 gpm, 1430 psi, 120 rpm,Tq 14K,5665 strokes. Table Top Kick w/Drilling©05:00 hrs. 4/29/2016 4/29/2016 1.50 INTRM1 DRILL DDRL P DDrill intermediate hole section to TD, 10,902.0 11,090.0 06:00 07:30 10902'to 11090',TVD=5163',ADT 1.12,Bit hrs=59.78,Jars hrs=80.08, PU 241K,SO 121K,ROT 152K, 140 rpm,Tq on 19K,off 17K,ECD 10.44 ppg, FO 27%, WOB 15K,700 gpm, 2444 psi.Total footage=188' SPR @ 11086'MD,5163'TVD,MW= 9.3 @ 07:30 hours #1 MP 20/30 SPM=220/260 psi #2 MP 20/30 SPM=220/260 psi 4/29/2016 4/29/2016 4.00 INTRM1 CASING CIRC P Circulate hole clean f/11090'-10710' 11,090.0 10,710.0 07:30 11:30 MD,700 gpm,2423-2340 psi,FO 27%, 140 rpm,Tq 15K,PU 241,SO 120K,ROT 156K.Pumped 2 LCM pills @ 11090'&10995'MD. 4/29/2016 4/29/2016 0.50 INTRM1 CASING OWFF P Monitor well,static.Monitor w/10 rpm, 10,710.0 10,710.0 11:30 12:00 Tq 18-20K. 4/29/2016 4/29/2016 4.00 INTRM1 CASING TRIP P PJSM-TOH f/10710'-7660'MD, 10,710.0 7,660.0 12:00 16:00 calculated fill 22.4,actual 25.4 bbls. PU 260K,SO 115K,40K over pull @ 10425'&25K over pull at 10550',wipe both spots.Reshoot survey per SLB ©7985'MD. 4/29/2016 4/30/2016 8.00 INTRM1 CASING DLOG P PJSM-MAD pass f/7660'-7223'MD, 7,660.0 7,223.0 16:00 00:00 100 fph,700 gpm, 1970 psi,FO 27%, 100 rpm,Tq 12-13K,PU 193K,SO 115K,ROT 135K. Page 11/32 Report Printed: 6/1/2016 K .. Werations Summary(with Timelog ths) 3S-613 ConoccilphiIlaprs. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/30/2016 4/30/2016 0.50 INTRM1 CASING DLOG P PJSM-MAD pass f/7223'-7170'MD, 7,223.0 7,170.0 00:00 00:30 100 fph,700 gpm,1970 psi,FO 27%, 100 rpm,Tq 12-13K,PU 193K,SO 115K,ROT 141K. 4/30/2016 4/30/2016 0.50 INTRM1 CASING OWFF P Monitor well,static.SIMOPS blow 7,170.0 7,170.0 00:30 01:00 down TD. 4/30/2016 4/30/2016 5.00 INTRM1 CASING TRIP P PJSM-TOH f/7170'-2900'MD,PU 7,170.0 2,900.0 01:00 06:00 131K,SO 106K,wipe 20K-30K over pull spots between 6450'-5980',5205', 5150'. 4/30/2016 4/30/2016 1.25 INTRM1 CASING CIRC P Pump 25 bbl Hi-Vis Sweep,then CBU 2,900.0 2,900.0 06:00 07:15 6X,700 gpm, 1561 psi,80 rpm,Tq 8K,PU 135K,SO 105K,ROT 118K. 4/30/2016 4/30/2016 0.25 INTRM1 CASING 'OWFF P Monitor well,static.SIMOPS blow 2,900.0 2,900.0 07:15 07:30 down TD. 4/30/2016 4/30/2016 1.75 INTRM1 CASING TRIP P PJSM-TOH f/2900'-752'MD, 2,900.0 752.0 07:30 09:15 calculated fill 15.64,actual 20.5 bbls. 4/30/2016 4/30/2016 0.25 INTRM1 CASING 'OWFF P Monitor well,static. 752.0 752.0 09:15 09:30 4/30/2016 4/30/2016 2.50 INTRMI CASING BHAH P PJSM-lay down BHA 5 per SLB, 752.0 0.0 09:30 12:00 calculated fill 9.3,actual 14 bbls. 4/30/2016 4/30/2016 1.00 INTRMI CASING BHAH 'P PJSM-clear&clean rig floor. 0.0 0.0 12:00 13:00 4/30/2016 4/30/2016 1.00 INTRMI CASING WWWH P PJSM-make up stack washing tool& 0.0 0.0 13:00 14:00 flush stack at 828 gpm,FO 30%,87 psi,40 rpm,Tq 1K.Blow down top drive&lay down tool. 4/30/2016 4/30/2016 0.75 INTRM1 CASING RURD P PJSM-rig up to pull wear bushing. 0.0 0.0 14:00 14:45 Attempt to remove w/puller.No success. 4/30/2016 4/30/2016 1.25 INTRMI CASING RURD T PJSM-change out wear bushing 0.0 0.0 14:45 16:00 puller&attempt to remove bushing, unsuccessful. 4/30/2016 4/30/2016 2.00 INTRM1 CASING RURD P PJSM-close blind rams&change out 0.0 0.0 16:00 18:00 upper VBR's to 7-5/8"solid body rams. 4/30/2016 4/30/2016 1.00 INTRM1 CASING WWWH T PJSM-make up stack washing tool 0.0 0.0 18:00 19:00 &wash wear bushing at 730 gpm,FO 26%,78 psi, 15 rpm,Tq 1K.Blow down top drive&lay down tool. 4/30/2016 4/30/2016 0.50 INTRM1 CASING RURD T PJSM-make up wear bushing puller& 0.0 0.0 19:00 19:30 attempt to remove bushing, unsuccessful. 4/30/2016 4/30/2016 0.50 INTRM1 CASING SFTY P Perform H2S pad evacuation CRT 9 0.0 0.0 19:30 20:00 minutes 15 seconds.Identified need for another wind sock&evacuation • alarm. 4/30/2016 4/30/2016 1.50-INTRMI CASING FISH T PJSM-make up Baker fishing spear 0.0 0.0 20:00 21:30 w/9.90"grapple.Latch on to wear bushing,pull free w/3K over.Lay down wear bushing.Observe top edge of wear bushing rolled over. 4/30/2016 4/30/2016 1.00 INTRM1 CASING BOPE P PJSM-set test plug&rig up to test. 0.0 0.0 21:30 22:30 4/30/2016 4/30/2016 1.00 INTRM1 CASING BOPE P PJSM-Test w/7-5/8"joint,annular 0.0 0.0 22:30 23:30 250/2500 psi,upper 7-5/8"rams 250/3500 psi,each test 5 minutes.Rig down test equipment. Page 12/32 Report Printed: 6/1/2016 . x1 • • Operations Summary (with Timelog Depths) 7X- ''+44.'1,0400,, 4,4 3S-613 eonoeoPhiillips ;4 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code lime P-T-X Operation (ftKB) End Depth(ftKB) 4/30/2016 5/1/2016 0.50 INTRM1 CASING RURD P PJSM-rig up to run 7-5/8"casing. 0.0 0.0 23:30 00:00 5/1/2016 5/1/2016 1.00 INTRM1 CASING PUTB P PJSM-perform dummy run with 7-5/8" 0.0 0.0 00:00 01:00 hanger,make up hanger to landing joint(6.75 turns w/acme threads). Land out&scribe mark on landing joint.Lay down landing joint&leave hanger on the rig floor. 5/1/2016 5/1/2016 2.25 INTRM1 CASING RURD P PJSM-rig up casing handling 0.0 0.0 01:00 03:15 equipment,change out bails,make up CRT,rig up casing tongs,&fill up hose. 5/1/2016 5/1/2016 0.25 INTRMI CASING SFTY P PJSM for running 7-5/8"casing. 0.0 0.0 03:15 03:30 5/1/2016 5/1/2016 1.00 INTRM1 CASING PUTB P TIH w/7.625",29.7#,L-80,HYD 563, 0.0 134.0 03:30 04:30 shoe track to 134'MD.BakerLok shoe track to baffle collar,install bow spring centralizers on#1 10'up from pin 10'from box.Circulate through shoe track&check floats,good. 5/1/2016 5/1/2016 7.50 INTRM1 CASING PUTB P TIH w/7.625",29.7#,L-80,HYD 563, 134.0 2,869.0 04:30 12:00 f/134'-2869'MD,filling on the fly& topping off every 10 joints. 5/1/2016 5/1/2016 0.50 INTRM1 CASING CIRC P CBU establishing rates @ 64 gpm,92 2,869.0 2,869.0 12:00 12:30 psi,FO 6%,@ 232 gpm, 118 psi,FO 16%,PU 118K,SO 111K,ROT 113K, 15 RPM,Tq 4K,pumped 1691strokes. 5/1/2016 5/1/2016 3.00 INTRMI CASING PUTB P TIH w/7.625",29.7#,L-80,HYD 563, 2,869.0 4,710.0 12:30 15:30 f/2869'-4710'MD,filling on the fly& topping off every 10 joints.SO 110K. 5/1/2016 5/1/2016 1.50 INTRM1 CASING CIRC T Work through tight hole @ 4710'MD 4,710.0 4,710.0 15:30 17:00 w/30K SO.Establish circulation @ 2 bpm,220-208 psi, FO 10%,PU 140K, SO 114K,pumped 2562 strokes. 5/1/2016 5/1/2016 3.00 INTRMI CASING PUTB P TIH w/7.625",29.7#,L-80,HYD 563, 4,710.0 7,004.0 17:00 20:00 f/4710'-7004'MD,filling on the fly& topping off every 10 joints.PU 189K, SO 119K. 5/1/2016 5/1/2016 2.75 INTRMI CASING CIRC P Break circulation staging up the pump 7,004.0 7,004.0 20:00 22:45 f/1.5-4 bpm, ICP 230 psi,FCP 215psi, PU 203K,SO 120K,3920 strokes pumped,9.3+ppg mud in&out. 5/1/2016 5/2/2016 1.25 INTRM1 CASING PUTB P TIH w/7.625",29.7#,L-80,HYD 563, 7,004.0 8,038.0 22:45 00:00 f/7004'-8038'MD,filling on the fly& topping off every 10 joints.PU 200K, SO 128K. 5/2/2016 5/2/2016 4.25 INTRM1 CASING PUTB P PJSM-TIH w/7.625",29.7#,L-80, 8,038.0 10,670.0 00:00 04:15 HYD 563,f/8083'-10670'MD,filling on the fly&topping off every 10 joints. PU 215K,SO 110K. 5/2/2016 5/2/2016 1.75 INTRM1 CASING CIRC P Break circulation due to increased 10,670.0 10,706.0 04:15 06:00 drag.Stage pumps up in 1/2 bbl increments ICP.5 bpm=500 psi up to 2.5 bpm=590 psi FCP.Reciprocating 10670'-10706'MD.PU 222K,SO 115K. Page 13/32 Report Printed: 6/1/2016 •erations Summary (with Timelog LOths) 3S-613 oc h tops Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/2/2016 5/2/2016 2.50 INTRM1 CASING PUTB P TIH w/7.625",29.7#,L-80,HYD 563, 10,706.0 11,041.0 06:00 08:30 f/10706-11041'MD,washing down each joint at 2.5 bpm,520 psi, FO 10%,SO 120K. 5/2/2016 5/2/2016 0.50 INTRM1 CASING HOSO P PJSM-make up FMC hanger& 11,041.0 11,082.0 08:30 09:00 landing joint washing down at 2.5 bpm,520 psi,FO 10%,land casing on depth at 11082'MD, PU 245K,SO 120K. 5/2/2016 5/2/2016 0.50 INTRM1 CEMENT RURD P PJSM-rig up cement hose to CRT& 11,082.0 11,082.0 09:00 09:30 blow down TD. 5/2/2016 5/2/2016 3.50 INTRM1 CEMENT CIRC P Circulate&condition mud for cement 11,082.0 11,082.0 09:30 13:00 job.Stage up pumps from 2.5 bpm= 450 psi to 4.5 bpm=288 psi,total strokes pumped 14686.Reciprocate 10'strokes,PU 290K,SO 118K, 5/2/2016 5/2/2016 3.75 INTRMI CEMENT CMNT P PJSM-PT lines to 4000 psi.Pump 25 11,082.0 11,082.0 13:00 16:45 bbls of CW100 @ 4.5 bpm,236 psi, FO 12%.Pump 20 bbls of 12.5 ppg MPII @ 4.5 bpm,200 psi,FO 12%. Drop bottom plug.Chase w/47 bbls of 15.8 ppg cement @ 4.5 bpm,ICP 200 psi,FCP 130 psi,FO 18%.Drop top plug.Pump 10 bbls of H2O @ 4.5 bpm,21 psi,FO 3%.Swap to rig pump&chase with 9.3 ppg LSND mud @ 4.5 bpm,catching plugs @ 1300 strokes,97 psi, FO 14%,FCP 441 psi,FO 12%.Bump plug @ 4800 strokes pressuring up to 941 psi.Hold pressure for 5 min&check floats good.Reciprocated casing through out job to 4300 strokes displacement, landing hanger.PU 305K,SO 127K. CIP @16:15hrs. 5/2/2016 5/2/2016 0.25 INTRMI CEMENT CIRC P PJSM-line up&pressure up to open 11,082.0 11,082.0 16:45 17:00 stage tool,observe stage tool open at 2833 psi. 5/2/2016 5/2/2016 3.00 INTRM1 CEMENT CIRC P Stage pumps up to 7.5 bpm,ICP 285 11,082.0 11,082.0 17:00 20:00 psi,FO 18%.Reduce rate to 6 bpm, 256 psi,FO 15%,MPII at surface w/ 3300 strokes.Dump 370 bbls to rock washer @ 4 bpm,240 psi,FCP 165 psi,strokes pumped 9234. 5/2/2016 5/2/2016 3.50 INTRM1 CEMENT CMNT P PJSM-line up to cementer.SLB pump 11,082.0 0.0 20:00 23:30 30 bbls of CW100 @ 6 bpm,290 psi. Pump 30 bbls of 12.5 ppg MPII @ 4.5 bpm,180 psi.Pump 189 bbls of 15.8 ppg cement @ 5 bpm,200 psi,slow to 3 bpm,57 psi.Drop top closing plug.Pump 10 bbls of H2O at 3 bpm, 190 psi.Swap to rig&pump 9.3 ppg LSND @ 5 bpm,ICP 250 psi,FCP 870 psi.Reduce rate at 4470 strokes to 3 bpm,800 psi.Bump plug @ 4593 strokes.Pressure up&close stage collar @ 1800 psi,increase to 2100 psi&hold for 5 min.Bleed off pressure&check stage collar closed, good.CIP @ 23:11. 5/2/2016 5/3/2016 0.50 INTRM1 CEMENT RURD P PJSM-rig down CRT,lay down 0.0 0.0 23:30 00:00 landing joint per FMC. Page 14/32 Report Printed: 6/1/2016 � 1-,, ID � L Aerations Summary (with Timelog Depths) 3S-613 ` eY {Conoco Phillips P.trka Rig: DOYON 142 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) 5/3/2016 5/3/2016 0.50 INTRMI CEMENT RURD P PJSM-clear&clean rig floor of casing 0.0 0.0 00:00 00:30 equipment. Fire Drill CRT 180 sec @ 01:12 hrs. 5/3/2016 5/3/2016 3.00 INTRM1 CEMENT WWSP P PJSM-make up running tool&set 0.0 0.0 00:30 03:30 packoff per FMC Rep.RILDS&test void to 5000 psi for 10 minutes, witnessed.Lay down running tool. Make up wear bushing running tool& set 9"ID wear bushing. 5/3/2016 5/3/2016 1.00 INTRM1 CEMENT RURD P PJSM-pick up&set mouse hole in 0.0 0.0 03:30 04:30 the rotary table.Change to 122"bails &install 5"elevators. 5/3/2016 5/3/2016 11.00 INTRM1 CEMENT PULD P PJSM-lay down 90 stands of 5"DP 0.0 0.0 04:30 15:30 from derrick,via mouse hole. 5/3/2016 5/3/2016 0.50 INTRM1 CEMENT LOT P PJSM-perform 10.75"X 7.625" 0.0 0.0 15:30 16:00 annular LOT. 10.75"shoe at 2902' MD,2572'TVD,with 9.3 ppg mud in annulus.LOT EMW of 18.4 ppg. Pump 10.5 bbls @.5 bpm,Pressuring up to 1400 psi to observe break over. Final pump pressure at 10.5 bbls was 1250 psi.Shut in at 1250 psi& observe pressure decrease to 770 psi in 10 minutes.SIMOPS lay down 5 stands of 5"DP from derrick via mouse hole. 5/3/2016 5/3/2016 1.50 INTRM1 CEMENT PULD P PJSM-lay down 11 stands of 5"DP 0.0 0.0 16:00 17:30 from derrick,via mouse hole. Table Top H2S Rig Evacuation Drill 5/3/2016 5/3/2016 3.00 INTRMI CEMENT 'FRZP P PJSM-Isotherm freeze protect 10.75" 0.0 0.0 17:30 20:30 X 7.625"annulus to 2126'MD,2006' TVD.Pump 84.4 bbls at.5 bpm,ICP 800 psi,FCP 1300 psi,final shut in 1200 psi. SIMOPS lay down 10 stands of 5"DP from derrick via mouse hole.Lay down mouse hole&clear rig floor. 5/3/2016 5/3/2016 2.00 INTRMI CEMENT RURD P PJSM-change out saver sub on top 0.0 0.0 20:30 22:30 drive f/4-1/2"IF to 4"XT39. 5/3/2016 5/4/2016 1.50 INTRM1 CEMENT RURD P PJSM-Change out upper 7-5/8"rams 0.0 0.0 22:30 00:00 to 3-1/2"X 6"VBR's. OA 650 psi @ 24:00 hrs. 5/4/2016 5/4/2016 2.25 INTRM1 CEMENT SLPC P PJSM-Cut&slip 88'of drill line, 0.0 0.0 00:00 02:15 service top drive,blocks,crown,& drawworks. Man Down Drill Table Top @ 02:15 hrs. 5/4/2016 5/4/2016 9.75 INTRMI CEMENT PULD P PJSM-Make up stack washer&pick 0.0 6,340.0 02:15 12:00 up 4"DP TIH to 6340'MD.Picked up 67 stands.PU 123K,SO 80K Kick w/Tripping CRT 75 sec @ 08:00 hrs. 5/4/2016 5/4/2016 0.50 INTRM1 CEMENT CIRC P Circulate string volume @ 508 gpm, 6,340.0 6,340.0 12:00 12:30 1684 psi,FO 27%,30 rpm,Tq 5K,PU 123K,SO 80K,ROT 90K.Pumped 1684 strokes. 5/4/2016 5/4/2016 0.25 INTRMI CEMENT OWFF P Monitor well,static.SIMOPS blow 6,340.0 6,340.0 12:30 12:45 down TD. 5/4/2016 5/4/2016 3.25 INTRM1 CEMENT TRIP P PJSM-TOH f/6340'-0,lay down stack 6,340.0 0.0 12:45 16:00 washer. 5/4/2016 5/4/2016 0.50 INTRM1 CEMENT RURD P PJSM-Clear rig floor. 0.0 0.0 16:00 16:30 Page 15/32 Report Printed: 6/1/2016 10 Serations Summary (with Timelog ths) 3S-613 \conocoPhliiips • Mat, Rig: DOYON 142 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) 5/4/2016 5/4/2016 1.50 INTRM1 WHDBOP RURD P PJSM-Remove wear bushing&install 0.0 0.0 16:30 18:00 test plug.Flush and fill lines w/H2O. Rig up test equipment. 5/4/2016 5/4/2016 5.00 INTRM1 WHDBOP BOPE P PJSM-Test BOPE w14"TJ,all tests 0.0 0.0 18:00 23:00 other than annular,tested to 250/3500 PSI for 5 min each. 1) Annular to 250/2500 PSI;2)Upper 3 '/2"x 6"VBR's,CV#1,#12,#13,#14, 4"Kill on Mud Line&Dart Valve;3) CV#9,#11,Mezzanine Kill Line Valve,FOSV;4)CV#8,#10,HCR Kill, Upper IBOP;5)CV#6,Manual Kill,Lower IBOP;6)CV#2,#5;7) Lower 3'/z"x 6"VBR's;8)Blinds,CV #3,#4,#6;9)Hydraulic Super Choke 1500 psi;10)Manual Choke 1500 psi; 11)4.5"TJ w/Annular to 250/2500; 12)4.5"TJ w/Upper 3'/2"x 6"VBR's, HCR Choke; 13)4.5"TJ w/Upper 3 1/2"x 6"VBR's,Manual Choke; 14) Lower 3'/2"x 6"VBR's. Perform Koomey draw down test initial system pressure 3000 psi,after closure 1875 psi,200 psi attained in 7 sec,full pressure attained in 45 sec, 6 nitrogen bottles with an average pressure of 2216 psi.Test pit level& flow out alarms. All H2S and Combustible gas alarms tested with audible and light alarms. Test waived by AOGCC Rep—Chuck Scheve 5/4/2016 5/5/2016 1.00 INTRM1 WHDBOP RURD P PJSM-Rig down test equipment,blow 0.0 0.0 23:00 00:00 down all lines.Remove test plug& install 9"ID wear bushing. OA 400 psi @ 24:00 hrs. 5/5/2016 5/5/2016 2.25 INTRM1 CEMENT BHAH P PJSM-Make up BHA 6 per SLB to 0.0 157.0 00:00 02:15 157'MD. 5/5/2016 5/5/2016 0.25 INTRM1 CEMENT SHAH P PJSM-Load source in ADNVision. 157.0 157.0 02:15 02:30 5/5/2016 5/5/2016 1.00 INTRMI CEMENT BHAH P Continue picking up BHA 6 per SLB f/ 157.0 532.0 02:30 03:30 157'-532'MD,PU 55K,SO 61K. 5/5/2016 5/5/2016 1.75 INTRMI CEMENT PULD P PJSM-TIH picking up 4"DP from 532.0 1,475.0 03:30 05:15 shed f/532'-1475'MD(PU 30 joints f/ shed) 5/5/2016 5/5/2016 0.50 INTRM1 CEMENT DHEQ P Shallow test MWD @ 212 gpm, 1031 1,475.0 1,475.0 05:15 05:45 psi,FO 11%,test good.Blow down Top Drive. 5/5/2016 5/5/2016 6.75 INTRM1 CEMENT PULD P PJSM-TIH picking up 4"DP from 1,475.0 6,217.0 05:45 12:30 shed f/1475-6217'MD(PU 150 joints f/shed)fill pipe every 20 stands,PU 115K,SO 75K. Fire Drill CRT 45 sec @ 07:00 hrs. OA 480 psi©08:00 hrs. 5/5/2016 5/5/2016 0.50 INTRM1 CEMENT DLOG P Establish circulation @ 215 gpm,1381 6,217.0 6,217.0 12:30 13:00 psi,FO 11%.Send down link command per DD to switch tools on for logging. Page 16/32 Report Printed: 6/1/2016 • !erations Summary (with Timelog Depths) ,,A 3S-613 ConocoPhiilip^s Rig: DOYON 142 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) 5/5/2016 5/5/2016 9.00 INTRM1 CEMENT DLOG P PJSM-Log cement f/6217'-10199' 6,217.0 10,199.0 13:00 22:00 MD,900 fph,fill pipe every 20 stands, PU 182K,SO 170K. Kick w/Tripping Drill CRT 180 sec @ 19:15 hrs. 5/5/2016 5/5/2016 0.25 INTRM1 CEMENT COCF P Ream down f/10199'-10267'MD,tag 10,199.0 10,267.0 22:00 22:15 cement stringer,203 gpm, 1475 psi, FO 11%,40 rpm,Tq 14K. 5/5/2016 5/6/2016 1.75 INTRM1 CEMENT CIRC P Circulate surface to surface @ 200 10,267.0 10,267.0 22:15 00:00 gpm,1475 psi,40 rpm,Tq 13K,FO 11%,PU 182K,SO 70K,ROT 115K. Pump 4648 strokes. OA 550 psi @ 24:00 hrs. 5/6/2016 5/6/2016 0.50 INTRM1 CEMENT RURD P PJSM-Rig up to test casing above the 10,267.0 10,199.0 00:00 00:30 stage collar.Rack back 1 stand 10267'-10199'MD.Install bail extensions&elevators.Flood lines for test. 5/6/2016 5/6/2016 0.50 INTRM1 CEMENT PRTS P PJSM-Test casing to 3500 psi for 10 10,199.0 10,199.0 00:30 01:00 minutes,charted.Pumped 6.3 bbls, bled back 6.3 bbls. 5/6/2016 5/6/2016 0.50 INTRM1 CEMENT RURD P PJSM-Rig down bail extensions& 10,199.0 10,199.0 01:00 01:30 blow down lines.Run in the hole 10199'-10267'MD. 5/6/2016 5/6/2016 0.25 INTRM1 CEMENT COCF P PJSM-Wash&ream f/10199'-10287' 10,199.0 10,287.0 01:30 01:45 MD,40 rpm,Tq 14K 5/6/2016 5/6/2016 0.75 INTRMI CEMENT DRLG P PJSM-Drill out stage collar f/10287'- 10,287.0 10,290.0 01:45 02:30 10290'MD,203 gpm, 1130 psi,40 rpm,Tq 11-16K.Work through collar 3X. 5/6/2016 5/6/2016 4.25 INTRM1 CEMENT COCF P Wash&ream to top of baffle collar f/ 10,290.0 10,859.0 02:30 06:45 10290'-10859'MD,215 gpm, 1512 psi,WOB 6-10K,60 rpm,Tq 14K,PU 200K,SO 80K,ROT 117K. 5/6/2016 5/6/2016 2.00 INTRMI CEMENT CIRC P Circulate&condition for casing test @ 10,859.0 10,859.0 06:45 08:45 215 gpm, 1512 psi,60 rpm,Tq 14K, PU 200K,SO 80K,ROT 117K, pumped 5101 strokes,blow down top drive. 5/6/2016 5/6/2016 1.00 INTRM1 CEMENT RURD P PJSM-Rig up to test casing at 10859' 10,859.0 10,859.0 08:45 09:45 MD. Install bail extensions& elevators.Flood lines for test. 5/6/2016 5/6/2016 1.75 INTRM1 CEMENT PRTS P PJSM-Pressure test 7.625"casing to 10,859.0 10,859.0 09:45 11:30 3500 psi for 30 min.Pump 58 strokes =6 bbls.Bled back 6 bbls.Confer with town&decide to retest to 3750 psi for 30 minutes.Pump 62 strokes=6.4 bbls.Bled back 6.4 bbls.Both tests good. 5/6/2016 5/6/2016 0.50 INTRMI CEMENT RURD P PJSM-Rig down bail extensions& 10,859.0 10,859.0 11:30 12:00 blow down lines. OA 580 psi @ 12:00 hrs. Page 17/32 Report Printed: 6/1/2016 *rations Summary (with Timelog liths) 3S-613 Conocc Ptsiflups Rig: DOYON 142 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(EKB) 5/6/2016 5/6/2016 4.00 INTRM1 CEMENT DRLG P Drill out shoe track&part of rat hole f/ 10,859.0 11,087.0 12:00 16:00 10859'-11087'MD.Tag up on baffle collar at 10944'MD,float collar 10988' MD,&shoe at 11077'MD.Drill shoe track at varying parameters 200-215 gpm,1350-1540 psi,60 rpm,Tq 12- 16K,FO 11%,WOB 1-4K. SPR's @ 11046'MD,5161'TVD,MW 9.3 ppg, 14:30 hrs. #1 @ 20/30 spm=400/640 psi #2 @ 20/30 spm=400/640 psi 5/6/2016 5/6/2016 2.75 INTRM1 CEMENT OTHR T Encountered debris in hole w/reaming 11,087.0 11,087.0 16:00 18:45 down on 3rd pass thru shoe @ 11083' MD.Unable to work up or down.Rack back stand&pick up single.Continue to work pipe until able to rotate& reciprocate w/circulation,4 bpm,840 psi,40 rpm,Tq 14-16K,PU 224K,SO 60K,ROT 113K.Lay down single. 5/6/2016 5/6/2016 0.50 INTRM1 CEMENT DRLG P Continue to drill out rat hole f/11087'- 11,087.0 11,090.0 18:45 19:15 11090'MD,wiping debris up intermittently at 220 gpm, 1576 psi, FO 12%,60 rpm,Tq 13-14K,WOB 8K. 5/6/2016 5/6/2016 0.75 INTRM1 CEMENT DDRL P DDrill 6-3/4"production section f/ 11,090.0 11,110.0 19:15 20:00 11090'-11110'MD,5166'TVD, ADT.29,Bit.29,Jars.29,PU 220K, SO 60K,ROT 117K,Tq on 14k,off 12K,220 gpm, 1576 psi,FO 12%,60 rpm,Tq 13-14K,WOB 8K, ECD 10.08, Max Gas 0 5/6/2016 5/6/2016 1.50 INTRM1 CEMENT CIRC P CBU @ 213 gpm,1510 psi,60 rpm, 11,110.0 11,110.0 20:00 21:30 Tq 14K,FO 12%,total strokes pumped 3406. 5/6/2016 5/6/2016 0.50 INTRM1 CEMENT RURD P PJSM-Rig up to perform LOT. Rack 11,110.0 11,067.0 21:30 22:00 back one stand f/11110'-11067'MD. Install bail extensions&elevators. Flood lines for test. 5/6/2016 5/6/2016 0.50 INTRM1 CEMENT LOT P PJSM-Perform LOT at the shoe 11,067.0 11,067.0 22:00 22:30 11082'MD,5163'TVD,MW 9.3 ppg. Pump at 6 spm&observe pressure increase to 1020 psi at 19 strokes. Pressure broke over to 600 psi at 20 strokes.Continue test to 50 strokes, 5.4 bbls total.Shut down&shut in with 605 psi.Observe pressure decrease to 485 psi in 10 minutes. Bled back 2.2 bbls.Observe pressure deviate from plot @ 838 psi to show an EMW of 12.4 ppg LOT. 5/6/2016 5/6/2016 0.50 PROD1 DRILL RURD P PJSM-Rig down bail extensions,test 11,067.0 11,067.0 22:30 23:00 equipment&blow down lines. 5/6/2016 5/7/2016 - 1.00 PROD1 DRILL DISP P PJSM-Displace mud system to 8.6 11,067.0 11,110.0 23:00 00:00 ppg KlaSheild.Pump 50 bbl,9.3 ppg Hi-Vis spacer through both pumps to clean lines of LSND.Chase spacer at 212 gpm, 1540 psi,FO 11%,60 rpm, Tq 13-14K. Displace to bottom f/ 11067'-11110'MD. OA 560 psi @ 24:00 hrs. Page 18/32 Report Printed: 6/1/2016 p- {', 'I trations Summary (with Timelog Depths) 3S-613 ConocoPhiHips Rig: DOYON 142 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) 5/7/2016 5/7/2016 1.25 PROD1 DRILL DISP P Continue to displace well w/8.6 ppg 11,110.0 11,110.0 00:00 01:15 Klasheild @ 212 gpm,1485-1225 psi, FO 12-6%,60 rpm,Tq 12K,total strokes 5113, 5/7/2016 5/7/2016 0.50 PROD1 DRILL OWFF P Monitor well,static.SIMOPS clean 11,110.0 11,110.0 01:15 01:45 shakers&troughs. 5/7/2016 5/7/2016 4.25 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 11,110.0 11,406.0 01:45 06:00 hole section f/11110'-11406'MD, 5185'TVD,270 gpm, 1965 psi,FO 16%,100 rpm,Tq on 7.5,off 5.5K, WOB 6K,PU 150K,SO 88K,ROT 117K,ECD 9.95,ADT 3.36,Bit 3.36, Jars 3.36,Max gas 361.Total footage 296'MD. 5/7/2016 5/7/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 11,406.0 11,940.0 06:00 12:00 hole section f/11406'-11940'MD, 5220'TVD,270 gpm,2110 psi,FO 16%, 120 rpm,Tq on 8.5,off 5.5K, WOB 6.7K,PU 149K,SO 89K, ROT 116K,ECD 10.27,ADT 4.06,Bit 7.42, Jars 7.42,Max gas 625.Total footage 534'MD. SPR's @ 11712'MD,5205'TVD,MW 8.7 ppg,09:40 hrs. #1 @ 20/30 spm=480/680 psi #2 @ 20/30 spm=480/680 psi 5/7/2016 5/7/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 11,940.0 12,433.0 12:00 18:00 hole section f/11940'-12433'MD, 5216'TVD,270 gpm,2170 psi,FO 16%, 120 rpm,Tq on 9,off 7K,WOB 5 -11K,PU 149K,SO 89K,ROT 116K, ECD 10.4,ADT 4.34,Bit 11.76,Jars 11.76,Max gas 1035.Total footage 493'MD. 5/7/2016 5/8/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 12,433.0 12,858.0 18:00 00:00 hole section f/12433'-12858'MD, 5214'TVD,270 gpm,2215 psi,FO 16%, 120 rpm,Tq on 8,off 7K,WOB 4K,PU 153K,SO 89K,ROT 111K, ECD 10.48,ADT 4.57,Bit 16.33,Jars 16.33,Max gas 648.Total footage 425'MD. OA 740 psi @ 24:00 hrs. SPR's @ 12751'MD,5221'TVD,MW 9.0 ppg,22:25 hrs. #1 @ 20/30 spm=540/770 psi #2 @ 20/30 spm=540/760 psi 5/8/2016 5/8/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 12,858.0 13,321.0 00:00 06:00 hole section f/12858'-13321'MD, 5200'TVD,270 gpm,2285 psi, 120 rpm,Tq on 8,off 7K,WOB 5.5K,FO 16%,PU 162K,SO 87K,ROT 114K, ECD 10.62,MW 9.1 ppg,Max Gas 508, ADT 4.84,Bit 21.17,Jars 21.17. Total footage 463'MD. OA 780 psi @ 06:00 hrs. Kick w/Drilling CRT 120 sec @ 03:35 hrs. SPR's @ 12751'MD,5221'TVD,MW 9.0 ppg,06:00 hrs. #1 @ 20/30 spm=560/800 psi #2 @ 20/30 spm=570/800 psi Page 19/32 Report Printed: 6/1/2016 *rations Summary (with Timelog Iths) 3S-613 Conoco Phillips Ahs! Rig: DOYON 142 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) 5/8/2016 5/8/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 13,321.0 13,594.0 06:00 12:00 hole section f/13321'-13594'MD, 5196'TVD,270 gpm,2270 psi,120 rpm,Tq on 8.5,off 7.5K,WOB 2.5K, FO 17%,PU 167K,SO 74K, ROT 110K,ECD 10.71,MW 9.0 ppg,Max Gas 400, ADT 4.63,Bit 25.80,Jars 25.80.Total footage 273'MD. Kick w/Drilling CRT 93 sec @ 11:05 hrs. 5/8/2016 5/8/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 13,594.0 13,904.0 12:00 18:00 hole section f/13594'-13904'MD, 5195'TVD,270 gpm,2320 psi,120 rpm,Tq on 8.7,off 8K,WOB 4.5K,FO 16%,PU 164K,SO 78K,ROT 117K, ECD 10.71,MW 9.0 ppg,Max Gas 615, ADT 4.40,Bit 30.20,Jars 30.20. Total footage 310'MD. SPR's @ 13795'MD,5195'TVD, MW 9.0 ppg, 15:45 hrs. #1 @ 20/30 spm=540/780 psi #2 @ 20/30 spm=540/790 psi 5/8/2016 5/9/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 13,904.0 14,290.0 18:00 00:00 hole section f/13904'-14290'MD, 5202'TVD,270 gpm,2250 psi,120 rpm,Tq on 10.5,off 8.5K,WOB 3.6K, FO 16%,PU 192K,SO N/A,ROT 114K,ECD 10.71,MW 9.0 ppg,Max Gas 615, ADT 5.28,Bit 35.28,Jars 35.48.Total footage 386'MD. 5/9/2016 5/9/2016 1.50 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 14,290.0 14,364.0 00:00 01:30 hole section f/14296-14364'MD, 5202'TVD,270 gpm,2230 psi,150 rpm,Tq on 12,off 9K,WOB 3K,FO 16%,PU 188K,SO N/A, ROT 115K, ECD 10.38,MW 8.95 ppg,Max Gas 645, ADT 1.0,Bit 36.48,Jars 34.48. Total footage 74'MD. SPR's @ 14363'MD,5202'TVD,MW 8.9+ppg,01:15 hrs. #1 @ 20/30 spm=520/760 psi #2 @ 20/30 spm=520/740 psi 5/9/2016 5/9/2016 1.00 PROD1 DRILL OWFF P Monitor well,observe slight flow. 14,364.0 14,364.0 01:30 02:30 Monitor flow&perform well bore breathing test.Record flow rate decreasing over 40 minutes,total back.4 bbls. 5/9/2016 5/9/2016 9.50 PROD1 DRILL BKRM T Decision made to perform wiper trip to 14,364.0 13,395.0 02:30 12:00 shoe,due to increase in PU weight (30K)&lose of SO weight(30K)while drilling from 13986-14270'MD.PJSM- BROOH f/14364'13395'MD,270 gpm,2150-2300 psi, 150 rpm,Tq 9- 13K,ECD 10.62,PU 188K,SO N/A, ROT 109K.Shoot survey at 13559' MD. 5/9/2016 5/9/2016 4.00 PROD1 DRILL -BKRM T PJSM-BROOH ft 13395'-13130'MD, 13,395.0 13,130.0 12:00 16:00 270 gpm,2158 psi,FO 17%,120 rpm, Tq 8-12K,ROT 109K. Page 20/32 Report Printed: 6/1/2016 • 'aerations Summary (with Timelog Depths) '!444-4'4" 4-7s `� ��v,s; 3S-613 •CConocoPhillips Rig: DOYON 142 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) 5/9/2016 5/9/2016 2.00 PROD1 DRILL REAM T Attempt to TON on elevators pick up 13,130.0 13,221.0 16:00 18:00 35K over to 195K,slack off to block weight.Ream f/13130'-13221'MD, 211 gpm, 1470 psi,80 rpm,Tq 8K. Attempt to TIH with SO to block weight. 5/9/2016 5/9/2016 3.50 PROD1 DRILL REAM T Ream f/13221'-14272'MD, 126 gpm, 13,221.0 14,272.0 18:00 21:30 745 psi,FO 8%,25 rpm,Tq 8K 5/9/2016 5/9/2016 1.00 PROD1 DRILL CIRC T CBU @ 270 gpm,2240 psi, 120 rpm, 14,272.0 14,272.0 21:30 22:30 Tq 10K, ROT 115K. 5/9/2016 5/10/2016 1.50 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 14,272.0 14,458.0 22:30 00:00 hole section f/14364'-14458'MD, 5206'TVD,270 gpm,2240 psi, 150 rpm,Tq on 12K,off 9K,WOB 3K,FO 16%,PU 183K,SO N/A,ROT 115K, ECD 10.46,MW 9.05 ppg,Max Gas 239, ADT 1.29,Bit 37.77,Jars 37.77. Total footage 94'MD. SPR's @ 14458'MD,5206'TVD,MW 9.0+ppg,23:59 hrs. #1 @ 20/30 spm=540/760 psi #2 @ 20/30 spm=540/760 psi 5/10/2016 5/10/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 14,458.0 14,838.0 00:00 06:00 hole section f/14458'-14838'MD, 5216'TVD,270 gpm,2250 psi, 150 rpm,Tq on 11K,off 9K,WOB 4K,FO 17%,PU 172K,SO 76K,ROT 121K, ECD 10.41,MW 9.0 ppg,Max Gas 298, ADT 4.84,Bit 42.61,Jars 42.61. Total footage 380'MD. SPR's @ 14458'MD,5206'TVD, MW 9.0+ppg,00:20 hrs. #1 @ 20/30 spm=540/760 psi #2 @ 20/30 spm=540/760 psi 5/10/2016 5/10/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 14,838.0 15,267.0 06:00 12:00 hole section f/14838'-15267'MD, 5205'TVD,270 gpm,2340 psi, 150 rpm,Tq on 11K,off 9K,WOB 4K,FO 17%,PU 171K,SO 71 K,ROT 118K, ECD 10.63,MW 9.0 ppg,Max Gas 390, ADT 4.42,Bit 47.03,Jars 47.03. Total footage 429'MD. SPR's @ 15122'MD,5209'TVD,MW 8.9+ppg, 10:00 hrs. #1 @ 20/30 spm=510/740 psi #2 @ 20/30 spm=520/740 psi 5/10/2016 5/10/2016 6.00 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 15,267.0 15,580.0 12:00 18:00 hole section f/15267-15580'MD, 5200'TVD,270 gpm,2360 psi, 150 rpm,Tq on 10K,off 9K,WOB 2K,FO 17%,PU 170K,SO 65K, ROT 115K, ECD 10.70,MW 9.0+ppg,Max Gas 655, ADT 4.79,Bit 51.82,Jars 51.82. Total footage 313'MD. SPR's @ 15122'MD,5209'TVD,MW 8.9+ppg, 10:00 hrs. • #1 @ 20/30 spm=510/740 psi #2 @ 20/30 spm=520/740 psi Page 21/32 Report Printed: 6/1/2016 *rations Summary (with Timelog litths) 3S-613 ,cone Philips Arsat Rig: DOYON 142 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) 5/10/2016 5/10/2016 3.75 PROD1 DRILL DDRL P Directional drilling 6-3/4"production 15,580.0 15,782.0 18:00 21:45 hole section f/15580'to TD of 15782' MD,5196.43'TVD,268 gpm,2360 psi, 150 rpm,Tq on 11K,off 9K,WOB 5K,FO 17%,PU 185K,SO 48K,ROT 116K,ECD 10.74,MW 9.1+ppg,Max Gas 223, ADT 3.5,Bit 55.32,Jars 55.32.Total footage 202'MD. SPR's @ 15122'MD,5209'TVD,MW 8.9+ppg, 10:00 hrs. #1 @ 20/30 spm=510/740 psi #2 @ 20/30 spm=520/740 psi 5/10/2016 5/10/2016 0.25 PROD1 CASING SRW P Obtain final surveys and SPR's at TD. 15,782.0 15,782.0 21:45 22:00 SPR's @ 15782'MD,5196'TVD,MW 9.15 ppg,21:55 hrs. #1 @ 20/30 spm=550/790 psi #2 @ 20/30 spm=540/780 psi 5/10/2016 5/10/2016 0.75 PROD1 CASING OWFF P Monitor well on trip tank-perform 15,782.0 15,782.0 22:00 22:45 breathing test with initial flow back rate of 3.5 bbls/hr decreasing to 0.35 bbl/hr.Total volume bled back= 0.35bbls 5/10/2016 5/11/2016 1.25 PROD1 CASING BKRM P BROOH f/15782'-15598'MD,268 15,782.0 15,598.0 22:45 00:00 gpm,2390 psi,FO 16%, 150 rpm,Tq 10-11K, Note:Dump/dilute 290 bbls Kla-Shield WBM 5/11/2016 5/11/2016 6.00 PROD1 CASING BKRM P BROOH f/15598'-13988'MD,270 15,598.0 13,988.0 00:00 06:00 gpm,2275 psi,FO 16%, 150 rpm,Tq 10-11K,PU 170K,SO 69K,ROT 116K Note:Dump/dilute 290 bbls Kla-Shield WBM(total of 580bb1s of new mud added into system) 5/11/2016 5/11/2016 6.00 PROD1 CASING BKRM P BROOH f/13988'-13280'MD,270 13,988.0 13,280.0 06:00 12:00 gpm,2260 psi,FO 16%, 150 rpm,Tq 8-10K,ROT 109K.Work tight hole/ packoffs from 13,535'onwards. 5/11/2016 5/11/2016 6.00'PROD1 CASING BKRM P BROOH f/13280'-12685'MD,270 13,280.0 12,685.0 12:00 18:00 gpm,2150 psi,FO 17%,150 rpm,Tq 9K,ROT 111K. 5/11/2016 5/12/2016 6.00 PROD1 CASING BKRM P BROOH f/12685'-11052'MD,270 12,685.0 11,052.0 18:00 00:00 gpm,2060 psi,FO 17%,150 rpm,Tq 7-9K.PU 136K,SO 103K,ROT 117K 5/12/2016 5/12/2016 5.00 PROD1 CASING CIRC 'P Pump 25 bbl Hi-Vis Sweep,then CBU 11,052.0 10,862.0 00:00 05:00 x 4,216 gpm,1410-1300psi,65-80 rpm,Tq 5K,FO 14%. 5/12/2016 5/12/2016 0.75 PROD1 CASING OWFF T OWFF on trip tank.Perform breathing 10,862.0 10,862.0 05:00 05:45 test,with initial rate of 7.1 bbl/hr decreasing to 1.0 bbl/hr.Volume bled back=1.67bbls. 5/12/2016 5/12/2016 0.25 PROD1 CASING RURD P Blow down top drive. 10,862.0 10,862.0 05:45 06:00 Page 22/32 Report Printed: 6/1/2016 f • `• 3Aerations Summary (with Timelog Depths) � ¢ 3S-613 ConocoPhill ps 4',a Rig: DOYON 142 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) 5/12/2016 5/12/2016 4.00 PROD1 CASING OWFF T OWFF on trip tank.Observe flowback 10,862.0 10,862.0 06:00 10:00 on decreasing trend with final rate of 0.23 bbls/hr.Total volume bled back over the 4.75 hours=2.67bbls 5/12/2016 5/12/2016 1.25 PROD1 CASING CIRC P CBU x 1,270 gpm, 1890psi,60 rpm, 10,862.0 10,862.0 10:00 11:15 Tq 5K,FO 17%,ECD 9.83ppg. No increase in gas observed at bottoms up.Observe 2 bbl loss. 5/12/2016 5/12/2016 1.25 PROD1 CASING OWFF P Blow down top drive and OWFF on 10,862.0 10,862.0 11:15 12:30 trip tank.Observe flow back decreasing from 0.48 bbl/hr to 0.29bb1/hr 5/12/2016 5/12/2016 5.50 PROD1 CASING TRIP P POOH on elevators f/10862'-6123' 10,862.0 6,123.0 12:30 18:00 MD,racking back 4"DP stands. Monitor displacement on trip tank. 5/12/2016 5/12/2016 0.50 PROD1 CASING SVRG P Service crown,blocks,top drive,and 6,123.0 6,123.0 18:00 18:30 iron roughneck 5/12/2016 5/12/2016 4.00 PROD1 CASING TRIP P POOH on elevators f/6123'-532'MD, 6,123.0 532.0 18:30 22:30 racking back 4"DP stands.Monitor displacement on trip tank. 5/12/2016 5/12/2016 0.50 PROD1 CASING OWFF P OWFF-well static. Hold PJSM for 532.0 532.0 22:30 23:00 laying out BHA. 5/12/2016 5/13/2016 1.00 PROD1 CASING BHAH P POOH f/532'-379'MD,laying down 532.0 254.0 23:00 00:00 jars,P/U HWDP single,and racking back 4"HWDP stands. 5/13/2016 5/13/2016 2.50 PROD1 CASING BHAH P POOH and UD BHA f/254'to surface 254.0 0.0 00:00 02:30 as per DD,removing RA source from ADN.No signs of wear observed on BHA. Bit graded 0-0-NO-A-X-0-NO-TD 5/13/2016 5/13/2016 0.50 PROD1 CASING BHAH P Clean and clear rig floor 0.0 0.0 02:30 03:00 5/13/2016 5/13/2016 3.00 COMPZN CASING PULD P RIH w/54 x joints 4"HWDP and rack 0.0 0.0 03:00 06:00 back in derrick. 5/13/2016 5/13/2016 2.00 COMPZN CASING RURD P Rig up to run 4-1/2"liner.Hold PJSM 0.0 0.0 06:00 08:00 and confirm pipe count. 5/13/2016 5/13/2016 9.00 COMPZN CASING PUTB P RIH 4-1/2"12.6#L-80 IBT-m Liner as 0.0 4,823.0 08:00 17:00 per tally from surface to 4823'MD, allowing liner to self-fill through perforated pup.Intal)centralizers on every joint and on frac sleeves. Torque connections to 4500 ft-lbs. 5/13/2016 5/13/2016 1.00 COMPZN CASING OTHR P MU Baker Liner hanger/packer 4,823.0 4,972.0 17:00 18:00 assembly and pour in PAL mix. Make up first stand of 4"DP and RIH to 4972'MD. 5/13/2016 5/13/2016 1.50 COMPZN CASING CIRC P Circulate 1 x surface-to-surface 4,972.0 4,972.0 18:00 19:30 volume,3bpm,300psi,FO 8%,PUW 83k,SOW 77k 5/13/2016 5/13/2016 3.75 COMPZN CASING RUNL P RIH liner on 4"DP stands from derrick 4,972.0 11,054.0 19:30 23:15 f/4972'-11054'MD,allowing liner to self-fill through perforated pup. 5/13/2016 5/14/2016 0.75 COMPZN 'CASING CIRC P CBU x 1 prior to exiting shoe,4bpm, 11,054.0 11,054.0 23:15 00:00 676psi,FO 10%. 5/14/2016 5/14/2016 1.00 COMPZN CASING CIRC P CBU x 1 prior to exiting shoe,4bpm, 11,054.0 11,054.0 00:00 01:00 676psi,FO 10%,PUW 127k,SOW 96k,ROT 107k @ 10rpm w/5k TRQ. Page 23/32 Report Printed: 6/1/2016 0 1,' *rations Summary (with Timelog ths) t 3S-613 j.,Canccoptiifhps Ra,xr Rig: DOYON 142 Job: DRILLING ORIGINAL Tirne Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/14/2016 5/14/2016 4.75 COMPZN CASING RUNL P RIH liner on 4"DP stands f/11054'- 11,054.0 13,890.0 01:00 05:45 13890'MD,allowing liner to self-fill through perforated pup. 5/14/2016 5/14/2016 9.25 COMPZN CASING RUNL T Work tight hole f/13890'-13933'MD. 13,890.0 13,933.0 05:45 15:00 Stage pumps up to 2bpm,470psi,FO 7%and attempt to wash down.Unable to rotate string w/6500 ft-lbs at surface.PUW 155k,SOW 83k. 5/14/2016 5/14/2016 2.75 COMPZN CASING PMPO T Pump OOH f/13933'-12946'MD and 13,933.0 12,946.0 15:00 17:45 rack back 1 x stand 4"HWDP and 10 x stands 4"DP,2bpm,430psi,FO 6%, PUW 152k,SOW 80k. 5/14/2016 5/14/2016 1.25 COMPZN CASING RUNL T B/D topdrive and RIH w/4"HWDP 12,946.0 13,933.0 17:45 19:00 stands f/12946'-13933' 5/14/2016 5/14/2016 2.0,0 COMPZN CASING RUNL T Work tight hole f/13933'-13980'MD. 13,933.0 13,980.0 19:00 21:00 Stage pumps up to 3bpm,650psi,FO 9%,and attempt to wash down.PUW 175k,SOW 87k. 5/14/2016 5/15/2016 3.00 COMPZN CASING TRIP T POOH f/13980'-12132'MD,racking 13,980.0 12,132.0 21:00 00:00 back 4"HWDP and 4"DP stands in derrick. 5/15/2016 5/15/2016 6.50 COMPZN CASING TRIP T TOOH on elevators from 12000'- 12,132.0 4,895.0 00:00 06:30 4895'MD with max pull rate of 90'/minute. 5/15/2016 5/15/2016 0.75 COMPZN CASING RURD T R/U casing equipment for pulling liner. 4,895.0 4,895.0 06:30 07:15 5/15/2016 5/15/2016 0.25 COMPZN CASING -PULL T M/U 15'pup joint to liner 4,895.0 4,817.0 07:15 07:30 hanger/packer assembly and rack back in derrick 5/15/2016 5/15/2016 8.00 COMPZN CASING PULL T POOH and lay down 4-1/2"12.6#L-80 4,817.0 0.0 07:30 15:30 IBT-m Liner. Note:2 x gouges observed on Swell Packer"A"and element measured at 6-1/8"OD.Observed minimal damage to swells B-H and elements,with elements on Swell Packers"B-C" measuring at 6.3"OD,"E"measuring at 6-5/8"OD,and"F-H"measuring at 6-9/16"OD.Top 3 x swell packers had small amount of metal debris embedded in element.Joints 4,6,& 22 laid out due to slight damage to torque rings. 5/15/2016 5/15/2016 1.00 COMPZN CASING RURD T Rig down casing running equipment 0.0 0.0 15:30 16:30 and clean/clear rig floor 5/15/2016 5/15/2016 1.50 COMPZN CASING WWWH T Pull wear bushing,RIH and flush 0.0 0.0 16:30 18:00 stack,and re-install wear bushing 5/15/2016 5/15/2016 2.25 COMPZN CASING SLPC P Slip&cut drill line and calibrate 0.0 0.0 18:00 20:15 system. 5/15/2016 5/15/2016 2.25 COMPZN CASING BHAH T M/U 6-3/4"Cleanout BHA as per DD. 0.0 422.0 20:15 22:30 5/15/2016 5/16/2016 1.50 COMPZN CASING TRIP T RIH cleanout BHA on 94 x stands 4" 422.0 2,347.0 22:30 00:00 DP and 19 x stands 4"HWDP f/422'- 2347'. 5/16/2016 5/16/2016 4.50 COMPZN CASING TRIP -T Continue to TIH with cleanout BHA on 2,347.0 9,330.0 00:00 04:30 4"DP from 2347'to 9330'MD. 5/16/2016 5/16/2016 1.50'COMPZN CASING PULD T RIH with 30 joints of 4"HW DP from 9,330.0 10,250.0 04:30 06:00 the pipe shed from 9330'to 10250' MD. Page 24/32 Report Printed: 6/1/2016 • Aerations Summary (with Timelog Depths) ;09g 3S-613 ConocoPhillps Rig: DOYON 142 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(MB) 5/16/2016 5/16/2016 1.00 COMPZN CASING TRIP T TOOH standing back 10 stands of 4" 10,250.0 9,330.0 06:00 07:00 HW DP on the driller side. 5/16/2016 5/16/2016 1.00 COMPZN CASING TRIP T TIH with 18 stands of 4"HW DP from 9,330.0 10,897.0 07:00 08:00 the off drillers side. 5/16/2016 5/16/2016 1.50 COMPZN CASING TRIP T TOOH standing back 18 stands of4" 10,897.0 9,330.0 08:00 09:30 HW DP on the driller side. 5/16/2016 5/16/2016 0.75 COMPZN CASING TRIP T Continue to TIH with cleanout 9,330.0 11,032.0 09:30 10:15 assembly of 4"DP from 9330'to 11032'MD(PU=140K and SO= 104K). 5/16/2016 5/16/2016 1.75 COMPZN CASING CIRC T CBU at 7 BPM=1570 psi,80 RPM, 11,032.0 11,032.0 10:15 12:00 free torque=4.5K ft-lbs,PU=140K, SO=104K,and rotating weight= 117K. 5/16/2016 5/16/2016 2.25 COMPZN CASING REAM T Wash and ream with cleanout BHA 11,032.0 12,592.0 12:00 14:15 from 11032'to 12592'MD at 7 BPM= 1540 psi,20 RPM=7K ft-lbs,PU= 154K,and SO=84K. Stacked weight at the following depths: 11496'(15K), 11629'(30K), 11852'(20K), 12155'(10K), 12240'(35K),12290'(22K), 12418'(30K),12513'(20K), 12535'(20K),and 12592'(30K). 5/16/2016 5/16/2016 3.75 COMPZN CASING REAM T Continue to wash and ream with 12,592.0 12,840.0 14:15 18:00 cleanout BHA from 12592'to 12840' MD at 7 BPM=1540 psi,20 RPM= 7K ft-lbs. Packed off at 12840'MD. PU to 12800'MD and staged up the pumps 2 BPM=380 psi,3 BPM=490 psi,4 BPM=670 psi,5 BPM=1050 psi, 6 BPM=1245 psi,7 BPM=1440 psi and rotary at 80 RPM,free torque =6.4K ft-lbs. Wash and ream back to 12840'MD. 5/16/2016 5/17/2016 6.00 COMPZN CASING REAM T Continue to wash and ream with 12,840.0 13,676.0 18:00 00:00 cleanout BHA from 12840'to 13676' MD at 6 BPM=1450 psi,80 RPM= 7K ft-lbs. 5/17/2016 5/17/2016 6.00 COMPZN CASING REAM T Continue to wash and ream with 13,676.0 14,134.0 00:00 06:00 cleanout BHA from 13676'to 14134' MD at 6 BPM= 1450 psi,90 RPM=8- 7K ft-lbs. Working pipe and circulating to avoid packing off at 13090', 13500', 13820',and 14008'MD. 5/17/2016 5/17/2016 6.00 COMPZN CASING REAM T Continue to wash and ream with 14,134.0 14,495.0 06:00 12:00 cleanout BHA from 14134'to 14495' MD at 6 BPM=1580 psi, 100 RPM= 7K ft-lbs. Pump a 30 bbl hi vis sweep and started adding alpine beads to the active system at 14250'MD. 5/17/2016 5/17/2016 6.00 COMPZN CASING REAM T Continue to wash and ream with 14,495.0 15,180.0 12:00 18:00 cleanout BHA from 14495'to 15180' MD at 6 BPM= 1720 psi, 100 RPM= 8-14K ft-lbs,and rotating weight= 133K. Continued to add alpine beads to the active system. Page 25/32 Report Printed: 6/1/2016 `, I , *rations Summary (with Timelog ths) 0 3S-613 `..conoo411111ips re,,( Rig: DOYON 142 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) 5/17/2016 5/18/2016 6.00 COMPZN CASING REAM T Continue to wash and ream with 15,180.0 15,640.0 18:00 00:00 cleanout BHA from 15180'to 15640' MD at 6 BPM=1720 psi, 100 RPM= 8-14K ft-lbs,and rotating weight= 133K. Continued to add alpine beads to the active system. 5/18/2016 5/18/2016 4.50 COMPZN CASING REAM T Continue to wash and ream with 15,640.0 15,782.0 00:00 04:30 cleanout BHA from 15640'to 15782'(TD)MD at 6 BPM=1750 psi, 100 RPM=8-14K ft-lbs,and rotating weight=133K. Continued to add alpine beads to the active system. 5/18/2016 5/18/2016 1.50 COMPZN CASING BKRM T Pump a 30 bbl hi vis sweep and 15,782.0 15,553.0 04:30 06:00 BROOH from 15782'to 15553'MD at 6.5 BPM=1850 psi, 120 RPM=9K ft- . lbs,PU=190K,SO=103K,and rotating weight=137K. 5/18/2016 5/18/2016 3.75 COMPZN CASING BKRM T Continue to BROOH from 15553'to 15,553.0 15,185.0 06:00 09:45 15185'MD at 6 BPM=1850 psi, 120 RPM=9K ft-lbs working through packoffs in tight hole. 5/18/2016 5/18/2016 7.75 COMPZN CASING PMPO T Pump out of the hole standing back 4" 15,185.0 10,942.0 09:45 17:30 DP from 15185'to 10942'MD at 2 BPM=500 psi(PU=143K and SO= 88K). 5/18/2016 5/18/2016 2.50 COMPZN CASING CIRC T Pump a hi vis sweep and circulate the 10,942.0 10,942.0 17:30 20:00 well clean while rotating/reciprocating at 6.5 BPM=1455 psi,80 RPM= 4.5K ft-lbs,and rotating weight= 105K. 5/18/2016 5/18/2016 2.00 COMPZN CASING MPSP T PU,MU,and RIH with the storm 10,942.0 11,030.0 20:00 22:00 packer. Set the storm packer at 80' MD(center of element),release from the storm packer,and POOH. PT the storm packer to 1000 psi for 10 minutes(good test). 5/18/2016 5/18/2016 1.00 COMPZN WHDBOP RURD T RU BOPE testing equipment. Pull the 0.0 0.0 22:00 23:00 wear ring and install the test plug. 5/18/2016 5/19/2016 1.00 COMPZN WHDBOP BOPE T Conduct bi-weekly BOPE test to 0.0 0.0 23:00 00:00 250/3500 psi: test 3-1/2"x 6"VBR's (upper pipe rams and lower pipe rams)with 4"and 4-1/2"test joints; test annular to 250/2500 with 4"and 4- 1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The test was witnessed by AOGCC inspector Guy Cook. Tests: 1) Annular with 4"test joint,4"Demco kill line on the mud manifold,chokes 1,12, 13,&14(passed) 2) Upper pipe rams with 4"test joint, upper IBOP,4"Demco mezzanine kill line,chokes 9&11 (passed) 3) HCR kill,Lower IBOP,chokes 8& 10(passed) Page 26/32 Report Printed: 6/1/2016 y� `r1 • of, 'aerations Summary (with Timelog Depths) 3S-613 Conocon illips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End lime Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/19/2016 5/19/2016 4.00 COMPZN WHDBOP BOPE T Continue to conduct bi-weekly BOPE 0.0 0.0 00:00 04:00 test to 250/3500 psi: test 3-1/2"x 6" VBR's(upper pipe rams and lower pipe rams)with 4"and 4-1/2"test joints;test annular to 250/2500 with 4" and 4-1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The test was witnessed by AOGCC inspector Guy Cook. Tests: 4) Chokes 6&7(passed) 5) Hydraulic choke and manual choke (passed) 6) Manual kill,4"dart valve,chokes 2 &5(passed) 7) Lower pipe rams with 4"test joint, 4"TIW(passed) 8) Blind rams,chokes 3,4,&6 (passed) 9) Annular with 4-1/2"test joint,HCR choke(passed) 10)Upper pipe rams with 4-1/2"test joint,manual choke(passed) 11)Lower pipe rams with 4-1/2"test joint. Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure=2950 psi Accumulator Pressure After Closer= 1800 psi Pressure Gain of 200 psi= 14 seconds Full System=78 Seconds Average N2(6 Bottles)=2604 psi 5/19/2016 5/19/2016 1.00 COMPZN WHDBOP RURD T Blow down the choke,kill,and top 0.0 0.0 04:00 05:00 drive. Align the choke manifold. Break down the test joint,TIW,and dart valve. Drain the stack. Pull the test plug and install the wear ring. 5/19/2016 5/19/2016 1.75 COMPZN CASING SVRG T Change out the saver sub on the top 0.0 0.0 05:00 06:45 drive due to normal wear from use. 5/19/2016 5/19/2016 1.50 COMPZN CASING MPSP T MU retrieving tool,engage the storm 0.0 10,941.0 06:45 08:15 packer,open the equalizing valve(no pressure under the storm packer), release the storm packer,check well for flow,and lay down the storm packer assembly. 5/19/2016 5/19/2016 1.25 COMPZN CASING CIRC T Circulate BU prior to TOOH at 6.5 10,941.0 10,941.0 08:15 09:30 BPM=1470 psi while rotating/rociprocating at 80 RPM. . 5/19/2016 5/19/2016 0.75 COMPZN CASING OWFF T Observe the well for flow for 30 10,941.0 10,941.0 09:30 10:15 minutes.Well initial flowed at 1.6 BPH, down to 0.7 BPH.Pull 2 stands, monitored for 15 minutes,and no flow was observed. 5/19/2016 5/19/2016 9.00 COMPZN CASING TRIP T TOOH standing back DP. 10,941.0 422.0 10:15 19:15 5/19/2016 5/19/2016 2.25 COMPZN CASING BHAH T Lay down cleanout BHA. Clean and 422.0 0.0 19:15 21:30 clear the floor. Page 27/32 Report Printed: 6/1/2016 li *rations Summa ) " � ry (with Timelogthe 3S-613 ConoccpPhiII s Rig: DOYON 142 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(ftKS) 5/19/2016 5/20/2016 2.50 COMPZN CASING PUTB T PU,MU,and RIH with 4-1/2"liner to 0.0 348.0 21:30 00:00 348'MD at midnight. 5/20/2016 5/20/2016 6.75 COMPZN CASING PUTB T Continue to RIH with 4-1/2"liner from 348.0 4,671.0 00:00 06:45 348'to 4671'MD(PU=76K) 5/20/2016 5/20/2016 1.00 COMPZN CASING OTHR T Change elevators. PU and MU liner 4,671.0 4,884.0 06:45 07:45 top packer/liner hanger/SBE assembly. Break the connection between the SBE and the liner hanger,change out the ball seat to 1.5"(for backup ball seat),MU SBE/liner hanger connection,and RIH on a stand of DP. 5/20/2016 5/20/2016 0.50 COMPZN CASING CIRC T Circulate one liner volume at 3 BPM= 4,884.0 4,884.0 07:45 08:15 300 psi,PU=84K,SO=80K, 10 RPM=1.5K ft-lbs,and 20 RPM= 1.5K. 5/20/2016 5/20/2016 5.75 COMPZN CASING RUNL T TIH with 4-1/2"liner on 4"DP from 4,884.0 11,072.0 08:15 14:00 4884'to 11072'MD(PU=130K and SO=98K). 5/20/2016 5/20/2016 1.50 COMPZN CASING CIRC T Circulate BU at the shoe at 6 BPM= 11,072.0 11,072.0 14:00 15:30 917 psi,PU=124K,SO=95K,and rotating weight=109K at 20 RPM. 5/20/2016 5/20/2016 0.75 COMPZN CASING RUNL T Continue to TIH with 4-1/2"liner on 4" 11,072.0 11,762.0 15:30 16:15 DP from 11072'-11762'MD. 5/20/2016 5/20/2016 2.00 COMPZN CASING RUNL T Continue to TIH with 4-1/2"liner on 4" 11,762.0 13,980.0 16:15 18:15 HW DP from 11762'-13980'MD. 5/20/2016 5/20/2016 0.50 COMPZN CASING RUNL P Continue to TIH with 4-1/2"liner on 4" 13,980.0 14,617.0 18:15 18:45 HW DP from13980'-14617'MD. 5/20/2016 5/20/2016 0.75 COMPZN CASING RUNL P Continue to TIH with 4-1/2"liner on 4" 14,617.0 15,659.0 18:45 19:30 DP from14617'-15659'MD(PU= 195K and SO=70K). 5/20/2016 5/20/2016 0.25 COMPZN CASING HOSO P Position liner top packer at setting 15,659.0 15,649.0 19:30 19:45 depth 10909'MD with liner shoe at 15649'MD. 5/20/2016 5/20/2016 1.75 COMPZN CASING CIRC P Establish circulation, drop the 1.25" 15,649.0 15,649.0 19:45 21:30 ball,and circulate to Wellbore Isolation Valve(WIV)ball set(1556 strokes). 5/20/2016 5/20/2016 0.75 COMPZN CASING PACK P Pressure up to 2000 psi and hold for 5 15,649.0 10,909.0 21:30 22:15 minutes and continue to pressure up to 3800 psi to set the Flex-Lock liner hanger. SO to block weight to confirm liner hanger is set and to release the HRD-E liner running tool. PU 15'to get the rotating dog sub above the ZXP liner top packer and SO to block weight to set the ZXP liner top packer (good shear indication at surface). PU to string weight,rotate at 10 RPM,SO to block weight to confirm liner top packer is set,and PU to string weight. 5/20/2016 5/20/2016 0.25 COMPZN CASING PRTS P Purge the kill line,close the annular, 10,909.0 10,877.0 22:15 22:30 and pressure up on the IA to 1500 psi for 10 minutes to PT the ZXP liner top packer(good test). PU 20'for circulating the well over to 9.0 ppg NaCl brine. Page 28/32 Report Printed: 6/1/2016 ftlep,:04%._ Aerations Summary (with Timelog Depths) 3S-613 4. ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start lime End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/20/2016 5/21/2016 1.50 COMPZN WELLPR COND P Empty mud from pit#5 and clean pit 10,877.0 10,877.0 22:30 00:00 #5. Load pits 5,6,&7 with 290 bbls of 9.0 ppg NaCI brine for displaceing 9.0 ppg KLASHIELD mud. 5/21/2016 5/21/2016 3.00 COMPZN WELLPR WAIT T Wait second dirty truck to and for third 10,877.0 10,877.0 00:00 03:00 load of 9.0 ppg NaCI brine to arrive. SimOps: Clean the rig floor and general housekeeping. Prep for displacement and for laying down DP. 5/21/2016 5/21/2016 0.25 COMPZN WELLPR SFTY P PJSM for displacing the well to 9.0 10,877.0 10,877.0 03:00 03:15 ppg NaCI brine. 5/21/2016 5/21/2016 2.75 COMPZN WELLPR DISP P Displace the 9.1 ppg KlayShield mud 10,877.0 10,877.0 03:15 06:00 by pumping 60 bbl hi vis spaced followed by 9.0 ppg NaCI brine at 7 BPM until clean brine was at surface. 5/21/2016 5/21/2016 0.50 COMPZN WELLPR OWFF P Observe the well for flow for 30 10,877.0 10,877.0 06:00 06:30 minutes and the well is static. SimOps: Blow down the top drive and kill line. 5/21/2016 5/21/2016 5.00 COMPZN WELLPR PULD P POOH laying down 4"DP/HW DP to 10,877.0 6,538.0 06:30 11:30 6538'MD. 5/21/2016 5/21/2016 0.50 COMPZN WELLPR SFTY P H2S Drill: Secured the well and 6,538.0 6,538.0 11:30 12:00 evacuated to primary muster area. All personnel accounted for in 8 minuets 30 seconds. 5/21/2016 5/21/2016 4.50 COMPZN WELLPR PULD P Continue POOH laying down 4"DP 6,538.0 1,849.0 12:00 16:30 from 6538'-1849'MD. 5/21/2016 5/21/2016 4.00 COMPZN WELLPR TRIP P TIH with remaining 77 stands of DP in 1,849.0 9,049.0 16:30 20:30 the derrick from 1849'-9049'MD(PU =75K and SO=75K). 5/21/2016 5/22/2016 3.50 COMPZN WELLPR PULD P POOH laying down 4"DP 9049'- 9,049.0 6,615.0 20:30 00:00 6615'MD at midnight. 5/22/2016 5/22/2016 7.00 COMPZN WELLPR PULD P Continue POOH laying down 4"DP 6,615.0 64.0 00:00 07:00 6615'-64'MD. 5/22/2016 5/22/2016 0.50 COMPZN WELLPR BHAH P Lay down liner running tool. 64.0 0.0 07:00 07:30 5/22/2016 5/22/2016 0.50 COMPZN WELLPR PULD Lay down the two stands in the derrick 0.0 0.0 07:30 08:00 that had damaged threads and flagged the damaged joints. 5/22/2016 5/22/2016 0.75 COMPZN RPCOMP RURD Clean and clear the rig floor. PU/MU 0.0 0.0 08:00 08:45 wear ring pulling tool,pull the wear ring,and lay down the wear ring pulling tool. 5/22/2016 5/22/2016 3.25 COMPZN RPCOMP .RURD P Bring Doyon power tubing tongs,4- 0.0 0.0 08:45 12:00 1/2"slips,and 4-1/2"elevators to the rig floor. Bring SLB I-wire spooler unit to the rig floor,RU spooling unit,and hang the sheave. Stage 270 cross coupling cannon clamps and 10 mid joint cannon clamps on the rig floor. Confirm running order in the pipe shed. Page 29/32 Report Printed: 6/1/2016 t-,.0 ! *rations Summary (with Timelog ths) 3S-613 Conot4tkiLIips A Rig: DOYON 142 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) 5/22/2016 5/22/2016 0.25 COMPZN RPCOMP SFTY P PJSM. Disused PU 4-1/2"tubing, 0.0 0.0 12:00 12:15 make torque 3800 ft-lbs,hand placement,power tong safety,SLB to test I-wire every 1000ft,cover the hole,cannon clamp on every joint, TIW valve,and communication. 5/22/2016 5/22/2016 1.00 COMPZN RPCOMP PUTB P PU and MU Baker 192-47 seal 0.0 168.0 12:15 13:15 assembly, 1 joint 4-1/2"tubing,Camco 3.813"DB-6 nipple assembly,1 joint of 4-1/2"tubing,and SLB gauge carrier. 5/22/2016 5/22/2016 1.00 COMPZN RPCOMP PUTB P Install Sapphire tubing pressure gauge 168.0 168.0 13:15 14:15 and connect I-wire to the gauge. PT gauge connection to 5000 psi for 5 minutes(good test)and check I-wire continuity(20 psi at 52.65°F). 5/22/2016 5/23/2016 9.75 COMPZN RPCOMP PUTB P Continue to RIH with 4-1/2"tubing 168.0 8,345.0 14:15 00:00 completion per tally installing cross coupling cannon clamps on every connection and testing the I-wire continuity every 1000'to 8345'MD at midnight. 5/23/2016 5/23/2016 3.00 COMPZN RPCOMP PUTB P Continue to RIH with 4-1/2"tubing 8,345.0 10,968.0 00:00 03:00 completion per tally installing cross coupling cannon clamps on every connection and testing the I-wire continuity every 1000'from 8345'- 10968'MD. 5/23/2016 5/23/2016 0.25 COMPZN RPCOMP HOSO P MU head pin to joint#271 10,968.0 10,968.0 03:00 03:15 5/23/2016 5/23/2016 2.00 COMPZN RPCOMP HOSO P Pump at 1 BPM,engage the seal 10,968.0 10,926.0 03:15 05:15 assembly into the SBE,seen a pressure increase,shut down the pumps,bleed off the pressure,locate out,and mark the pipe for space out. Lay down joints#271,270,and 268. PU space out pups 9.8',7.75',7.87', 1.99',and 9.79'. MU space out pups and joint#268. ___ 5/23/2016 5/23/2016 2.00 COMPZN RPCOMP THGR P RU circulating equipment to the 10,926.0 10,926.0 05:15 07:15 landing joint,MU the landing joint to the tubing hanger,and MU FMC tubing hanger. Cut the I-wire and MU to the tubing hanger. PT to 5000 psi for 5 minutes and check continuity (good tests). Ran at total of 270 cross coupling cannon clamps and 6 mid joint cannon clamps. 5/23/2016 5/23/2016 2.00 COMPZN RPCOMP CRIH T Lined up to pump 9.0 ppg corrosion 10,926.0 10,926.0 07:15 09:15 inhibited brine down tubing. After 14 bbls away at 4 BPM the tubing pressured up to 1400 psi.Stop pumping, Bleed off tubing to 0 psi. Pump at 1/2 BPM and pressure increased to 500 psi. Shut down the pumps and bleed pressure to 0 psi. RD surface equipment to inspect. Pump around surface lines and to confirm lines are clear. Call town to discuss options. Page 30/32 Report Printed: 6/1/2016 • 9 Aerations Summary (with Timelog Depths) 3S-613 conocoPhitiips Rig: DOYON 142 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) 5/23/2016 5/23/2016 0.75 COMPZN RPCOMP WAIT T Discuss further plans with town. 10,926.0 10,926.0 09:15 10:00 5/23/2016 5/23/2016 2.00 COMPZN RPCOMP CIRC T Space out to reverse circulate.reduce 10,926.0 10,926.0 10:00 12:00 annular closing pressure to 500 psi, close the annular around first full tubing joint below hanger.Begin to reverse circulate,monitoring returns. Pump at 3 BPM=900 psi. Small cement debris chunks came out first in the first 3 minutes of pumping. After pumping 130 bbls pressure increased with sporadic flow out. Swell packer rubber shavings and small chunks caught over the shaker along with small pieces of old cement debris. After 166 bbls pumped recovered more rubber shavings and small chunks over the shaker. Pumped an additional 1.5 times tubing volume with no more debris over shakers. 5/23/2016 5/23/2016 1.25 COMPZN RPCOMP CIRC T Line up and pump one tubing volume 10,926.0 10,926.0 12:00 13:15 of brine down tubing to ensure tubing is free before pumping corrosion inhibitor.Pump 5 bpm=590 psi. 5/23/2016 5/23/2016 1.50 COMPZN RPCOMP CRIH P PU tubing hanger above rig floor, 10,926.0 10,926.0 13:15 14:45 Begin pumping 65 bbls of corrosion inhibited fluid down the tubing followed by 165 bbls of brine to spot around the seal assembly up to SOV.SLB re- tested the I-wire with a reading of 2716 psi at 121°F(good test). 5/23/2016 5/23/2016 0.75 COMPZN RPCOMP THGR P PJSM. Suck out the BOP stack,land 10,926.0 10,965.0 14:45 15:30 tubing hanger,and RILDS. 5/23/2016 5/23/2016 2.25 COMPZN RPCOMP PRTS P PJSM. PT the tubing to 4500 psi for 0.0 0.0 15:30 17:45 30 minutes(good test),bleed the tubing to 3000 psi,and PT the IA to 4000 psi for 30 minutes(good test). Quickly bleed the pressure off the tubing to shear the SOV. 5/23/2016 5/23/2016 0.75 COMPZN RPCOMP RURD -P Blow down circulating lines,pull the 0.0 0.0 17:45 18:30 landing joint,and RD circulating equipment. 5/23/2016 5/23/2016 1.00 COMPZN WHDBOP MPSP P Install 4"H BPV with dry rod. 0.0 0.0 18:30 19:30 Pressure up on the IA to 1000 psi for 10 minutes to test the BPV from below in the direction of flow(good test). 5/23/2016 5/23/2016 1.50 COMPZN WHDBOP WWWH P MU stack jetting tool on ajoint of DP, 0.0 0.0 19:30 21:00 jet the BOP stack,lay down stack jetting tool,and lay down the joint of DP. 5/23/2016 5/23/2016 1.50 COMPZN WHDBOP NUND P Blow down the choke,kill,hole fill,and 0.0 0.0 21:00 22:30 jet line to the BOP stack. Blow down the top drive. Clean out the drip pan and drain the BOP stack. 5/23/2016 5/24/2016 1.50 COMPZN WHDBOP NUND P Pull the riser. Remove the choke and 0.0 0.0 22:30 00:00 kill line from the BOP stack. ND the BOP stack and set back on the stump for transport. Page 31/32 Report Printed: 6/1/2016 *rations Summary (with Timelog hs) 3S-613 Coeo noftiiilips Rig: DOYON 142 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(5KB) 5/24/2016 5/24/2016 2.00 COMPZN WHDBOP NUND P ND BOPE 0.0 0.0 00:00 02:00 5/24/2016 5/24/2016 5.50'COMPZN WHDBOP NUND P N/U Tree-Clean hanger&BPV.Install 0.0 0.0 02:00 07:30 frac sleeve in hanger,set adapter spool in cellar,hang frac tree.Begin performing BWM on BOPE stump while SLB terminates the E-control line connection. 5/24/2016 5/24/2016 2.00 COMPZN WHDBOP NUND P Pressure test void on adapter flange 0.0 0.0 07:30 09:30 250/5000 psi for 15 min.visualy inspected by Co rep.pull BPV and install test plug.Double check all flanged connections,tighten up.R/U IA hoses and cement manifold in cellar for freeze protecting. 5/24/2016 5/24/2016 1.50 COMPZN WHDBOP PRTS P PJSM-Rig up 10K presure test pump. 0.0 0.0 09:30 11:00 Fill stack and test Frac tree 250/10,000 psi.Worked up pressure in stages 2000,5000,7500, 10,000 psi.IA open-tree and test plug test good. 5/24/2016 5/24/2016 3.00 COMPZN WHDBOP FRZP P R/U LRS and freeze protect using 90 0.0 0.0 11:00 14:00 bbls of SD.Start 3 bpm @ 800 psi. Final 1175 psi @ 3bpm.Shut in bleed of LRS rig down. 5/24/2016 5/24/2016 1.00 COMPZN WHDBOP FRZP P Let the well sawp-continue to rig 0.0 0.0 14:00 15:00 down and prep for rig move-lower skate and rack out. 5/24/2016 5/24/2016 0.50 COMPZN WHDBOP MPSP P Final well pressures=SITP 0/IA 0/ 0.0 0.0 15:00 15:30 OA 0 Set BPV 5/24/2016 5/24/2016 0.50 DEMOB MOVE -RURD P Clean up tree and rig release @ 16:00 0.0 15:30 16:00 hrs. • Page 32/32 Report Printed: 6/1/2016 • NADConversion Kuparuk River Unit Kuparuk 3S Pad 3S-613 3S-613 Definitive Survey Report 19 May, 2016 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit ND Reference: 3S-513 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-513 actual©64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 3S-613 Well Position +Ni-S 0.00 usft Northing: 5,993,901.19 usfl Latitude: 70°23'40.084 N +EI-W 0.00 usft Easting: 476,207.90 usfl Longitude: 150°11'36.889 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: 24.70 usft Wellbore 3S-613 Magnetics i2,, Model Name Sample Date Declination Dip Angle Field tt n BGGM2015 5/1/2016 18.23 80.97 57,482 Design 3S-613 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.77 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°)', 39.77 0.00 0.00 300.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.15 816.58 3S-613 Srvy 1 -SLB_GWD70(3S-613) GYD-GC-SS Gyrodata gyro single shots 4/17/2016 8:3. 876.24 2,827.88 3S-613 Srvy 2-SLB_MWD+GMAC(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/17/2016 8:2. 2,891.75 2,959.21 3S-613 Srvy 3-SLB_INC+FILLER(3S-6 INC+TREND Inclinometer+known azi trend 4/25/2016 8:5: 3,053.58 11,016.76 3S-613 Srvy 4-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/25/2016 8:51 11,109.82 15,702.97 3S-613 Srvy 5-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/7/2016 9:05. Survey • Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 39.77 0.00 0.00 39.77 -24.70 0.00 0.00 5,993,901.19 476,207.90 0.00 0.00 UNDEFINED 99.15 0.41 209.21 99.15 34.68 -0.19 -0.10 5,993,901.00 476,207.80 0.69 0.00 GYD-GC-SS(1) 162.63 0.24 235.92 162.63 98.16 -0.46 -0.32 5,993,900.73 476,207.57 0.35 0.05 GYD-GC-SS(1) 255.75 0.05 222.35 255.75 191.28 -0.60 -0.51 5,993,900.59 476,207.38 0.21 0.15 GYD-GC-SS(1) 349.00 1.96 176.79 348.98 284.51 -2.22 -0.45 5,993,898.97 476,207.44 2.06 -0.72 GYD-GC-SS(1) 442.13 3.71 182.06 441.99 377.52 -6.82 -0.47 5,993,894.37 476,207.41 1.90 -3.00 GYD-GC-SS(1) 535.28 3.02 185.21 534.98 470.51 -12.28 -0.80 5,993,888.92 476,207.06 0.77 -5.44 GYD-GC-SS(1) 628.64 4.77 200.47 628.12 563.65 -18.36 -2.38 5,993,882.84 476,205.46 2.16 -7.12 GYD-GC-SS(1) 722.05 6.58 212.06 721.08 656.61 -26.54 -6.58 5,993,874.68 476,201.23 2.28 -7.57 GYD-GC-SS(1) 816.58 7.30 223.45 814.92 750.45 -35.49 -13.59 5,993,865.75 476,194.20 1.64 -5.98 GYD-GC-SS(1) 5/19/2016 8:22.'23AM Page 2 COMPASS 5000.1 Build 74 Iii __ Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-513 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-513 actual @ 64.47usft(Doyon 142) Well: . 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Az; TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (') (°) (usft) (usft) (usft) (usft) (ft) (ft) (`°1100) (ft) Survey Tool Name 876.24 7.51 231.68 874.08 809.61 -40.66 -19.25 5,993,860.60 476,188.52 1.81 -3.66 MWD+IFR-AK-CAZ-SC(2) 970.62 9.25 242.41 967.46 902.99 -48.00 -30.82 5,993,853.30 476,176.93 2.47 2.69 MWD+IFR-AK-CAZ-SC(2) 1,065.29 13.12 251.04 1,060.32 995.85 -55.02 -47.73 5,993,846.33 476,160.00 4.44 13.83 MWD+IFR-AK-CAZ-SC(2) 1,161.53 15.39 254.03 1,153.59 1,089.12 -62.08 -70.34 5,993,839.34 476,137.37 2.48 29.88 MWD+IFR-AK-CAZ-SC(2) 1,254.28 16.71 249.78 1,242.72 1,178.25 -70.07 -94.69 5,993,831.42 476,113.00 1.90 46.96 MWD+IFR-AK-CAZ-SC(2) 1,349.55 19.21 241.42 1,333.36 1,268.89 -82.31 -121.31 5,993,819.27 476,086.34 3.76 63.90 MWD+I FR-AK-CAZ-SC(2) 1,444.30 21.66 237.49 1,422.14 1,357.67 -99.17 -149.75 5,993,802.51 476,057.85 2.96 80.11 MWD+I FR-AK-CAZ-SC(2) 1,539.42 24.51 238.37 1,509.64 1,445.17 -118.95 -181.36 5,993,782.83 476,026.18 3.02 97.59 MWD+IFR-AK-CAZ-SC(2) 1,633.94 26.61 238.54 1,594.90 1,530.43 -140.29 -216.12 5,993,761.61 475,991.36 2.22 117.02 MWD+I FR-AK-CAZ-SC(2) 1,728.07 26.12 237.27 1,679.24 1,614.77 -162.49 -251.53 5,993,739.52 475,955.88 0.79 136.59 MWD+IFR-AK-CAZ-SC(2) 1,822.57 26.91 238.35 1,763.80 1,699.33 -184.96 -287.23 5,993,717.16 475,920.11 0.98 156.27 MWD+IFR-AK-CAZ-SC(2) 1,918.99 31.36 239.84 1,848.00 1,783.53 -209.03 -327.52 5,993,693.23 475,879.75 4.68 179.13 MWD+IFR-AK-CAZ-SC(2) 2,013.65 38.98 240.11 1,925.33 1,860.86 -236.28 -374.70 5,993,666.13 475,832.49 8.05 206.36 MWD+IFR-AK-CAZ-SC(2) 2,107.91 39.29 241.09 1,998.44 1,933.97 -265.48 -426.53 5,993,637.09 475,780.57 0.73 236.64 MWD+IFR-AK-CAZ-SC(2) 2,202.58 38.25 244.46 2,072.26 2,007.79 -292.61 -479.22 5,993,610.13 475,727.80 2.48 268.71 MWD+IFR-AK-CAZ-SC(2) 2,297.95 38.95 245.96 2,146.79 2,082.32 -317.55 -533.23 5,993,585.37 475,673.71 1.23 303.02 MWD+IFR-AK-CAZ-SC(2) 2,391.94 39.59 247.81 2,219.56 2,155.09 -340.90 -587.95 5,993,562.20 475,618.93 1.42 338.73 MWD+IFR-AK-CAZ-SC(2) 2,486.90 41.04 251.44 2,291.98 2,227.51 -362.25 -645.53 5,993,541.03 475,561.28 2.91 377.92 MWD+IFR-AK-CAZ-SC(2) 2,580.56 42.35 256.35 2,361.93 2,297.46 -379.49 -705.35 5,993,523.98 475,501.41 3.76 421.11 MWD+IFR-AK-CAZ-SC(2) 2,676.54 47.30 256.71 2,429.98 2,365.51 -395.24 -771.13 5,993,508.45 475,435.59 5.16 470.20 MWD+IFR-AK-CAZ-SC(2) 2,771.34 49.38 258.28 2,493.00 2,428.53 -410.56 -840.27 5,993,493.35 475,366.41 2.52 522.42 MWD+IFR-AK-CAZ-SC(2) 2,827.88 52.52 257.66 2,528.61 2,464.14 -419.71 -883.21 5,993,484.33 475,323.44 5.62 555.03 MWD+IFR-AK-CAZ-SC(2) 2,891.75 56.00 257.76 2,565.91 2,501.44 -430.74 -933.86 5,993,473.46 475,272.77 5.45 593.37 INC+TREND(3) 2,901.00 56.06 257.77 2,571.08 2,506.61 -432.37 -941.36 5,993,471.86 475,265.27 0.66 599.05 INC+TREND(3) 10 314"x 13-112" *, 2,959.21 56.44 257.86 2,603.42 2,538.95 -442.58 -988.67 5,993,461.80 475,217.93 0.66 634.92 INC+TREND(3) 3,053.58 57.60 257.96 2,654.79 2,590.32 -459.16 -1,066.07 5,993,445.47 475,140.48 1.23 693.66 MWD+IFR-AK-CAZ-SC(4) 3,148.37 59.19 259.99 2,704.47 2,640.00 -474.59 -1,145.31 5,993,430.30 475,061.20 2.48 754.57 MWD+I FR-AK-CAZ-SC(4) 3,242.89 61.30 259.95 2,751.37 2,686.90 -488.88 -1,226.11 5,993,416.26 474,980.37 2.23 817.40 MWD+I FR-AK-CAZ-SC(4) 3,336.34 63.60 261.29 2,794.60 2,730.13 -502.37 -1,307.84 5,993,403.03 474,898.59 2.77 881.44 MWD+IFR-AK-CAZ-SC(4) 3,431.88 66.94 262.16 2,834.56 2,770.09 -514.85 -1,393.71 5,993,390.83 474,812.70 3.59 949.56 MWD+IFR-AK-CAZ-SC(4) 3,527.73 70.01 264.08 2,869.73 2,805.26 -525.51 -1,482.22 5,993,380.45 474,724.17 3.71 1,020.88 MWD+IFR-AK-CAZ-SC(4) 3,622.12 70.19 266.79 2,901.86 2,837.39 -532.58 -1,570.68 5,993,373.67 474,635.69 2.71 1,093.96 MWD+IFR-AK-CAZ-SC(4) 3,717.82 71.41 268.53 2,933.33 2,868.86 -536.26 -1,660.97 5,993,370.27 474,545.39 2.14 1,170.31 MWD+IFR-AK-CAZ-SC(4) 3,811.69 71.29 268.82 2,963.35 2,898.88 -538.32 -1,749.89 5,993,368.50 474,456.48 0.32 1,246.29 MWD+IFR-AK-CAZ-SC(4) 3,905.64 71.25 268.01 2,993.52 2,929.05 -540.78 -1,838.83 5,993,366.32 474,367.54 0.82 1,322.08 MWD+IFR-AK-CAZ-SC(4) 4,001.08 71.33 267.99 3,024.14 2,959.67 -543.93 -1,929.17 5,993,363.45 474,277.20 0.09 1,398.75 MWD+IFR-AK-CAZ-SC(4) 4,095.58 71.25 267.44 3,054.45 2,989.98 -547.50 -2,018.61 5,993,360.17 474,187.76 0.56 1,474.41 MWD+IFR-AK-CAZ-SC(4) 4,189.60 71.24 268.82 3,084.68 3,020.21 -550.41 -2,107.58 5,993,357.55 474,098.78 1.39 1,550.02 MWD+IFR-AK-CAZ-SC(4) 4,284.95 70.83 272.25 3,115.68 3,051.21 -549.57 -2,197.74 5,993,358.67 474,008.64 3.43 1,628.51 MWD+IFR-AK-CAZ-SC(4) 4,379.99 70.82 274.42 3,146.90 3,082.43 -544.35 -2,287.35 5,993,364.18 473,919.06 2.16 1,708.73 MWD+IFR-AK-CAZ-SC(4) 5/19/2016 8:22:23AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project Kuparuk River Unit TVD Reference: 3S-513 actual©64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-513 actual©64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (ustt) .r(tusft) (usft) (usft) (ft) (ft) 0100) (ft) Survey Tool Name 4,475.99 71.00 276.75 3,178.30 3,113.83 -535.52 -2,377.63 5,993,373.29 473,828.82 2.30 1,791.33 MWD+IFR-AK-CAZ-SC(4) 4,569.76 70.86 278.22 3,208.94 3,144.47 -523.97 -2,465.49 5,993,385.12 473,741.00 1.49 1,873.19 MWD+IFR-AK-CAZ-SC(4) 4,664.17 70.90 278.35 3,239.86 3,175.39 -511.12 -2,553.77 5,993,398.25 473,652.77 0.14 1,956.07 MWD+IFR-AK-CAZ-SC(4) 4,758.70 70.82 278.05 3,270.85 3,206.38 -498.38 -2,642.16 5,993,411.27 473,564.43 0.31 2,038.98 MWD+IFR-AK-CAZ-SC(4) 4,854.00 71.06 278.05 3,301.97 3,237.50 -485.77 -2,731.34 5,993,424.16 473,475.29 0.25 2,122.53 MWD+IFR-AK-CAZ-SC(4) 4,949.17 70.49 274.73 3,333.32 3,268.85 -475.76 -2,820.63 5,993,434.45 473,386.05 3.35 2,204.86 MWD+IFR-AK-CAZ-SC(4) 5,044.63 69.76 272.14 3,365.78 3,301.31 -470.38 -2,910.24 5,993,440.12 473,296.47 2.66 2,285.15 MWD+IFR-AK-CAZ-SC(4) 5,139.58 70.32 270.52 3,398.19 3,333.72 -468.31 -2,999.45 5,993,442.47 473,207.27 1.71 2,363.45 MWD+IFR-AK-CAZ-SC(4) 5,234.59 70.70 271.23 3,429.89 3,365.42 -466.94 -3,089.01 5,993,444.13 473,117.73 0.81 2,441.69 MWD+IFR-AK-CAZ-SC(4) 5,329.35 70.55 271.26 3,461.33 3,396.86 -465.00 -3,178.38 5,993,446.35 473,028.37 0.16 2,520.06 MWD+IFR-AK-CAZ-SC(4) 5,424.73 70.62 271.38 3,493.03 3,428.56 -462.93 -3,268.31 5,993,448.71 472,938.46 0.14 2,598.98 MWD+IFR-AK-CAZ-SC(4) 5,518.76 70.74 272.53 3,524.14 3,459.67 -459.90 -3,356.99 5,993,452.02 472,849.79 1.16 2,677.29 MWD+IFR-AK-CAZ-SC(4) 5,613.80 70.91 274.72 3,555.36 3,490.89 -454.23 -3,446.58 5,993,457.98 472,760.24 2.18 2,757.71 MWD+IFR-AK-CAZ-SC(4) 5,709.25 70.77 275.06 3,586.69 3,522.22 -446.54 -3,536.41 5,993,465.95 472,670.44 0.37 2,839.35 MWD+IFR-AK-CAZ-SC(4) 5,803.68 71.42 276.33 3,617.29 3,552.82 -437.67 -3,625.30 5,993,475.10 472,581.58 1.45 2,920.77 MWD+IFR-AK-CAZ-SC(4) 5,898.66 71.16 276.02 3,647.75 3,583.28 -428.00 -3,714.74 5,993,485.06 472,492.19 0.41 3,003.06 MWD+IFR-AK-CAZ-SC(4) 5,993.14 71.20 274.44 3,678.23 3,613.76 -419.85 -3,803.79 5,993,493.49 472,403.17 1.58 3,084.26 MWD+1FR-AK-CAZ-SC(4) 6,087.84 71.20 272.30 3,708.76 3,644.29 -414.58 -3,893.28 5,993,499.05 472,313.71 2.14 3,164.39 MWD+IFR-AK-CAZ-SC(4) 6,182.85 71.21 270.75 3,739.37 3,674.90 -412.18 -3,983.19 5,993,501.73 472,223.82 1.54 3,243.45 MWD+IFR-AK-CAZ-SC(4) 6,275.83 71.13 269.99 3,769.38 3,704.91 -411.61 -4,071.19 5,993,502.58 472,135.83 0.78 3,319.95 MWD+IFR-AK-CAZ-SC(4) 6,371.66 71.29 270.41 3,800.25 3,735.78 -411.30 -4,161.91 5,993,503.18 472,045.11 0.45 3,398.67 MWD+IFR-AK-CAZ-SC(4) 6,466.55 71.33 271.65 3,830.65 3,766.18 -409.68 -4,251.78 5,993,505.08 471,955.26 1.24 3,477.31 MWD+IFR-AK-CAZ-SC(4) 6,561.96 71.11 272.03 3,861.37 3,796.90 -406.78 -4,342.06 5,993,508.27 471,864.99 0.44 3,556.95 MWD+IFR-AK-CAZ-SC(4) 6,656.74 70.63 272.92 3,892.43 3,827.96 -402.92 -4,431.53 5,993,512.42 471,775.55 1.02 3,636.36 MWD+IFR-AK-CAZ-SC(4) 6,751.86 70.79 275.10 3,923.86 3,859.39 -396.64 -4,521.08 5,993,518.98 471,686.03 2.17 3,717.05 MWD+IFR-AK-CAZ-SC(4) 6,846.30 70.64 275.03 3,955.05 3,890.58 -388.77 -4,609.87 5,993,527.13 471,597.27 0.17 3,797.88 MWD+IFR-AK-CAZ-SC(4) 6,941.56 70.78 275.11 3,986.52 3,922.05 -380.82 -4,699.43 5,993,535.36 471,507.75 0.17 3,879.42 MWD+IFR-AK-CAZ-SC(4) 7,036.80 70.65 274.58 4,017.97 3,953.50 -373.23 -4,789.01 5,993,543.24 471,418.21 0.54 3,960.79 MWD+IFR-AK-CAZ-SC(4) 7,131.87 70.62 274.00 4,049.50 3,985.03 -366.52 -4,878.45 5,993,550.23 471,328.80 0.58 4,041.60 MWD+IFR-AK-CAZ-SC(4) 7,227.79 70.66 272.91 4,081.30 4,016.83 -361.07 -4,968.78 5,993,555.98 471,238.49 1.07 4,122.55 MWD+IFR-AK-CAZ-SC(4) 7,321.63 70.56 271.95 4,112.45 4,047.98 -357.31 -5,057.21 5,993,560.01 471,150.08 0.97 4,201.02 MWD+I F R-AK-CAZ-SC(4) 7,416.79 70.71 271.17 4,144.00 4,079.53 -354.87 -5,146.95 5,993,562.74 471,060.35 0.79 4,279.96 MWD+IFR-AK-CAZ-SC(4) 7,511.28 71.19 273.55 4,174.85 4,110.38 -351.19 -5,236.19 5,993,566.70 470,971.14 2.43 4,359.08 MWD+IFR-AK-CAZ-SC(4) 7,606.03 70.67 270.52 4,205.81 4,141.34 -348.01 -5,325.67 5,993,570.17 470,881.68 3.07 4,438.16 MWD+IFR-AK-CAZ-SC(4) 7,700.90 70.59 270.00 4,237.28 4,172.81 -347.60 -5,415.17 5,993,570.86 470,792.19 0.52 4,515.87 MWD+IFR-AK-CAZ-SC(4) 7,795.43 70.73 269.86 4,268.58 4,204.11 -347.71 -5,504.36 5,993,571.04 470,703.01 0.20 4,593.06 MWD+IFR-AK-CAZ-SC(4) 7,890.97 70.59 268.49 4,300.23 4,235.76 -349.01 -5,594.50 5,993,570.03 470,612.88 1.36 4,670.47 MWD+IFR-AK-CAZ-SC(4) 7,984.52 70.75 268.16 4,331.19 4,266.72 -351.59 -5,682.74 5,993,567.73 470,524.64 0.37 4,745.60 MWD+IFR-AK-CAZ-SC(4) 8,080.59 70.72 269.74 4,362.89 4,298.42 -353.25 -5,773.41 5,993,566.35 470,433.97 1.55 4,823.29 MWD+IFR-AK-CAZ-SC(4) 8,175.09 70.75 271.26 4,394.07 4,329.60 -352.47 -5,862.61 5,993,567.42 470,344.78 1.52 4,900.93 MWD+IFR-AK-CAZ-SC(4) 5/19/2016 8:22:23AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: " 3S-513 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-513 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True °Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 Database: OAKEDMP2 Suar Map Map Vertical MD Inc Azi TVD 1VDSS +NI-S 4.7+E/-W Northing Fasting DLS Section �^ (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100')', (ft) Survey Tool Name .. 8,270.04 70.71 272.08 4,425.41 4,360.94 -349.86 -5,952.20 5,993,570.31 470,255.21 0.82 4,979.83 MWD+IFR-AK-CAZ-SC(4) 8,364.63 70.81 272.09 4,456.58 4,392.11 -346.61 -6,041.45 5,993,573.84 470,165.98 0.11 5,058.74 MWD+IFR-AK-CAZ-SC(4) 8,459.74 70.65 271.45 4,487.97 4,423.50 -343.83 -6,131.19 5,993,576.90 470,076.26 0.66 5,137.85 MWD+IFR-AK-CAZ-SC(4) 8,555.14 70.66 271.45 4,519.57 4,455.10 -341.56 -6,221.17 5,993,579.47 469,986.29 0.01 5,216.91 MWD+IFR-AK-CAZ-SC(4) 8,649.44 70.59 271.53 4,550.85 4,486.38 -339.24 -6,310.10 5,993,582.06 469,897.38 0.11 5,295.09 MWD+IFR-AK-CAZ-SC(4) 8,744.05 70.70 276.35 4,582.22 4,517.75 -333.11 -6,399.12 5,993,588.48 469,808.39 4.81 5,375.25 MWD+IFR-AK-CAZ-SC(4) 8,839.16 70.61 278.37 4,613.73 4,549.26 -321.62 -6,488.12 5,993,600.26 469,719.44 2.01 5,458.06 MWD+IFR-AK-CAZ-SC(4) 8,932.66 70.17 281.43 4,645.12 4,580.65 -306.48 -6,574.87 5,993,615.67 469,632.74 3.12 5,540.76 MWD+IFR-AK-CAZ-SC(4) 9,027.50 70.33 283.65 4,677.17 4,612.70 -287.10 -6,661.99 5,993,635.32 469,545.69 2.21 5,625.91 MWD+IFR-AK-CAZ-SC(4) 9,122.23 71.49 287.78 4,708.16 4,643.69 -262.85 -6,748.14 5,993,659.84 469,459.63 4.30 5,712.64 MWD+IFR-AK-CAZ-SC(4) 9,217.00 71.59 290.87 4,738 18 4,673.71 -233.10 -6,832.96 5,993,689.86 469,374.91 3.09 5,800.96 MWD+IFR-AK-CAZ-SC(4) 9,311.55 71.83 292.95 4,767.85 4,703.38 -199.61 -6,916.24 5,993,723.62 469,291.75 2.10 5,889.84 MWD+IFR-AK-CAZ-SC(4) 9,406.26 72.11 295.12 4,797.17 4,732.70 -162.93 -6,998.48 5,993,760.55 469,209.63 2.20 5,979.40 MWD+IFR-AK-CAZ-SC(4) 9,500.93 72.19 296.80 4,826.19 4,761.72 -123.48 -7,079.50 5,993,800.25 469,128.75 1.69 6,069.29 MWD+IFR-AK-CAZ-SC(4) 9,596.30 72.38 298.95 4,855.21 4,790.74 -81.01 -7,159.80 5,993,842.98 469,048.59 2.16 6,160.07 MWD+IFR-AK-CAZ-SC(4) 9,690.94 73.21 300.98 4,883.21 4,818.74 -35.85 -7,238.12 5,993,888.37 468,970.43 2.23 6,250.46 MWD+IFR-AK-CAZ-SC(4) 9,787.00 74.40 304.74 4,910.01 4,845.54 14.19 -7,315.58 5,993,938.67 468,893.13 3.96 6,342.58 MWD+IFR-AK-CAZ-SC(4) 9,881.24 74.93 307.67 4,934.94 4,870.47 67.87 -7,388.91 5,993,992.57 468,819.98 3.05 6,432.92 MWD+IFR-AK-CAZ-SC(4) 9,975.99 75.70 312.50 4,958.97 4,894.50 126.88 -7,459.00 5,994,051.79 468,750.08 5.00 6,523.12 MWD+IFR-AK-CAZ-SC(4) 10,070.82 76.47 315.80 4,981.78 4,917.31 190.98 -7,525.03 5,994,116.10 468,684.26 3.47 6,612.36 MWD+IFR-AK-CAZ-SC(4) 10,165.41 77.27 321.75 5,003.29 4,938.82 260.24 -7,585.70 5,994,185.54 468,623.82 6.18 6,699.53 MWD+IFR-AK-CAZ-SC(4) 10,259.49 77.92 325.51 5,023.50 4,959.03 334.21 -7,640.18 5,994,259.68 468,569.59 3.96 6,783.69 MWD+IFR-AK-CAZ-SC(4) 10,355.16 78.25 327.70 5,043.26 4,978.79 412.36 -7,691.69 5,994,337.99 468,518.32 2.27 6,867.38 MWD+IFR-AK-CAZ-SC(4) 10,449.63 78.31 331.38 5,062.45 4,997.98 492.08 -7,738.58 5,994,417.85 468,471.70 3.81 6,947.84 MWD+IFR-AK-CAZ-SC(4) 10,544.42 78.00 333.79 5,081.91 5,017.44 574.43 -7,781.29 5,994,500.32 468,429.25 2.51 7,026.01 MWD+IFR-AK-CAZ-SC(4) 10,639.15 78.55 336.80 5,101.17 5,036.70 658.68 -7,820.05 5,994,584.69 468,390.76 3.16 7,101.70 MWD+IFR-AK-CAZ-SC(4) 10,732.50 79.64 339.93 5,118.83 5,054.36 743.87 -7,853.84 5,994,669.98 468,357.25 3.49 7,173.56 MWD+IFR-AK-CAZ-SC(4) 10,827.76 81.03 341.56 5,134.83 5,070.36 832.53 -7,884.80 5,994,758.72 468,326.57 2.23 7,244.70 MWD+IFR-AK-CAZ-SC(4) 10,922.04 82.89 343.19 5,148.01 5,083.54 921.49 -7,913.06 5,994,847.77 468,298.60 2.61 7,313.66 MWD+IFR-AK-CAZ-SC(4) 11,016.76 84.88 342.39 5,158.10 5,093.63 1,011.45 -7,940.93 5,994,937.80 468,271.02 2.26 7,382.77 MWD+IFR-AK-CAZ-SC(4) 11,082.00 85.74 341.68 5,163.44 5,098.97 1,073.30 -7,960.98 5,994,999.71 468,251.17 1.70 7,431.06 MWD+IFR-AK-CAZ-SC(5) 7-518"x 9-7/8" 11,109.82 86.10 341.38 5,165.42 5,100.95 1,099.62 -7,969.77 5,995,026.06 468,242.46 1.70 7,451.83 MWD+IFR-AK-CAZ-SC(5) 11,158.87 86.15 342.34 5,168.73 5,104.26 1,146.12 -7,985.01 5,995,072.61 468,227.37 1.96 7,488.28 MWD+IFR-AK-CAZ-SC(5) 11,253.42 86.19 341.69 5,175.05 5,110.58 1,235.85 -8,014.14 5,995,162.42 468,198.53 0.69 7,558.37 MWD+IFR-AK-CAZ-SC(5) 11,347.88 86.26 340.94 5,181.27 5,116.80 1,325.14 -8,044.33 5,995,251.79 468,168.63 0.80 7,629.17 MWD+IFR-AK-CAZ-SC(5) 11,442.17 86.33 341.57 5,187.36 5,122.89 1,414.24 -8,074.57 5,995,340.98 468,138.68 0.67 7,699.90 MWD+IFR-AK-CAZ-SC(5) 11,537.40 86.22 340.20 5,193.55 5,129.08 1,504.03 -8,105.69 5,995,430.86 468,107.85 1.44 7,771.74 MWD+IFR-AK-CAZ-SC(5) 11,632.35 86.26 340.85 5,199.78 5,135.31 1,593.35 -8,137.27 5,995,520.27 468,076.55 0.68 7,843.76 MWD+IFR-AK-CAZ-SC(5) 11,726.27 86.19 341.85 5,205.96 5,141.49 1,682.15 -8,167.24 5,995,609.15 468,046.86 1.07 7,914.11 MWD+IFR-AK-CAZ-SC(5) 11,821.12 86.25 344.44 5,212.21 5,147.74 1,772.72 -8,194.68 5,995,699.80 468,019.72 2.73 7,983.16 MWD+IFR-AK-CAZ-SC(5) 5/19/2016 8:22:23AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference; 3S-513 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reston,co: 3S-513 actual @ 64.47usft(Doyon 142) Well: 3S-613 North R;E nce: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 Database: OAKEDMP2 Survey Map Map Vertical MD Inc TVD TVDSS +N1-$ +E1-W Northing Easting DLS Section (usft) (°} (°) _ (usft) (usft) (usft) '"(usft) (ft)', (ft) (°1100•) (ft) ' Survey Tool Name 11,916.54 88.13 345.23 5,216.89 5,152.42 1,864.70 -8,219.61 5,995,791.85 467,995.08 2.14 8,050.74 MWD+IFR-AK-CAZ-SC(5) 12,009.59 91.66 346.35 5,217.06 5,152.59 1,954.89 -8,242.45 5,995,882.10 467,972.53 3.98 8,115.61 MWD+IFR-AK-CAZ-SC(5) 12,104.20 91.09 346.29 5,214.79 5,150.32 2,046.78 -8,264.82 5,995,974.06 467,950.46 0.61 8,180.94 MWD+IFR-AK-CAZ-SC(5) 12,199.28 90.51 345.97 5,213.46 5,148.99 2,139.08 -8,287.61 5,996,066.42 467,927.96 0.70 8,246.82 MWD+IFR-AK-CAZ-SC(5) 12,292.55 88.93 346.23 5,213.92 5,149.45 2,229.62 -8,310.01 5,996,157.02 467,905.85 1.72 8,311.49 MWD+IFR-AK-CAZ-SC(5) 12,387.28 88.35 345.95 5,216.17 5,151.70 2,321.54 -8,332.78 5,996,249.01 467,883.38 0.68 8,377.17 MWD+IFR-AK-CAZ-SC(5) 12,482.45 88.83 346.12 5,218.51 5,154.04 2,413.87 -8,355.74 5,996,341.40 467,860.71 0.54 8,443.22 MWD+IFR-AK-CAZ-SC(5) 12,576.92 89.45 345.45 5,219.93 5,155.46 2,505.44 -8,378.94 5,996,433.03 467,837.81 0.97 8,509.09 MWD+IFR-AK-CAZ-SC(5) 12,672.07 90.82 344.10 5,219.70 5,155.23 2,597.24 -8,403.92 5,996,524.91 467,813.12 2.02 8,576.63 MWD+IFR-AK-CAZ-SC(5) 12,767.60 91.37 343.45 5,217.88 5,153.41 2,688.95 -8,430.61 5,996,616.69 467,786.73 0.89 8,645.60 MWD+IFR-AK-CAZ-SC(5) 12,863.10 92.37 342.08 5,214.76 5,150.29 2,780.11 -8,458.89 5,996,707.93 467,758.74 1.78 8,715.67 MWD+IFR-AK-CAZ-SC(5) 12,957.94 92.33 340.82 5,210.87 5,146.40 2,869.95 -8,489.03 5,996,797.85 467,728.89 1.33 8,786.69 MWD+IFR-AK-CAZ-SC(5) 13,053.00 91.85 341.01 5,207.41 5,142.94 2,959.72 -8,520.09 5,996,887.72 467,698.11 0.54 8,858.48 MWD+IFR-AK-CAZ-SC(5) 13,147.27 91.44 344.01 5,204.70 5,140.23 3,049.59 -8,548.41 5,996,977.66 467,670.09 3.21 8,927.93 MWD+IFR-AK-CAZ-SC(5) 13,241.79 91.50 347.56 5,202.27 5,137.80 3,141.17 -8,571.61 5,997,069.31 467,647.18 3.76 8,993.82 MWD+IFR-AK-CAZ-SC(5) 13,335.69 91.31 352.69 5,199.97 5,135.50 3,233.62 -8,587.70 5,997,161.80 467,631.38 5.47 9,053.98 MWD+IFR-AK-CAZ-SC(5) 13,431.04 90.61 351.25 5,198.37 5,133.90 3,328.02 -8,601.02 5,997,256.23 467,618.37 1.68 9,112.71 MWD+IFR-AK-CAZ-SC(5) 13,480.88 90.27 347.86 5,197.99 5,133.52 3,377.02 -8,610.06 5,997,305.26 467,609.49 6.84 9,145.04 MWD+IFR-AK-CAZ-SC(5) 13,524.82 90.52 345.18 5,197.69 5,133.22 3,419.75 -8,620.30 5,997,348.01 467,599.39 6.13 9,175.27 MWD+IFR-AK-CAZ-SC(5) 13,571.44 90.44 345.00 5,197.30 5,132.83 3,464.80 -8,632.29 5,997,393.10 467,587.54 0.42 9,208.18 MWD+IFR-AK-CAZ-SC(5) 13,620.52 90.54 345.19 5,196.88 5,132.41 3,512.22 -8,644.92 5,997,440.56 467,575.06 0.44 9,242.83 MWD+IFR-AK-CAZ-SC(5) 13,715.71 90.37 345.10 5,196.12 5,131.65 3,604.23 -8,669.32 5,997,532.63 467,550.96 0.20 9,309.96 MWD+IFR-AK-CAZ-SC(5) 13,810.78 89.89 343.80 5,195.91 5,131.44 3,695.82 -8,694.80 5,997,624.29 467,525.77 1.46 9,377.83 MWD+IFR-AK-CAZ-SC(5) 13,905.45 89.48 344.74 5,196.43 5,131.96 3,786.94 -8,720.47 5,997,715.48 467,500.39 1.08 9,445.62 MWD+IFR-AK-CAZ-SC(5) 14,000.15 89.11 346.77 5,197.59 5,133.12 3,878.71 -8,743.77 5,997,807.33 467,477.39 2.18 9,511.68 MWD+IFR-AK-CAZ-SC(5) 14,094.72 89.11 347.51 5,199.06 5,134.59 3,970.90 -8,764.81 5,997,899.57 467,456.64 0.78 9,576.00 MWD+IFR-AK-CAZ-SC(5) 14,189.55 89.11 347.49 5,200.53 5,136.06 4,063.47 -8,785.34 5,997,992.20 467,436.41 0.02 9,640.06 MWD+IFR-AK-CAZ-SC(5) 14,282.53 88.63 346.56 5,202.37 5,137.90 4,154.06 -8,806.21 5,998,082.84 467,415.83 1.13 9,703.43 MWD+IFR-AK-CAZ-SC(5) 14,379.24 88.49 346.32 5,204.80 5,140.33 4,248.04 -8,828.88 5,998,176.89 467,393.46 0.29 9,770.05 MWD+IFR-AK-CAZ-SC(5) 14,474.34 88.66 346.16 5,207.16 5,142.69 4,340.38 -8,851.49 5,998,269.29 467,371.15 0.25 9,835.81 MWD+IFR-AK-CAZ-SC(5) 14,569.44 88.59 344.80 5,209.44 5,144.97 4,432.42 -8,875.33 5,998,361.39 467,347.61 1.43 9,902.47 MWD+IFR-AK-CAZ-SC(5) 14,664.18 88.56 343.28 5,211.80 5,147.33 4,523.48 -8,901.37 5,998,452.52 467,321.86 1.60 9,970.55 MWD+IFR-AK-CAZ-SC(5) 14,759.20 88.56 342.53 5,214.19 5,149.72 4,614.27 -8,929.29 5,998,543.39 467,294.23 0.79 10,040.13 MWD+IFR-AK-CAZ-SC(5) 14,852.90 89.62 341.39 5,215.68 5,151.21 4,703.35 -8,958.30 5,998,632.56 467,265.50 1.66 10,109.79 MWD+IFR-AK-CAZ-SC(5) 14,948.19 91.70 342.84 5,214.58 5,150.11 4,794.02 -8,987.56 5,998,723.31 467,236.53 2.66 10,180.47 MWD+IFR-AK-CAZ-SC(5) 15,041.66 91.57 344.04 5,211.91 5,147.44 4,883.57 -9,014.19 5,998,812.94 467,210.19 1.29 10,248.31 MWD+IFR-AK-CAZ-SC(5) 15,135.52 91.71 346.00 5,209.23 5,144.76 4,974.20 -9,038.44 5,998,903.64 467,186.23 2.09 10,314.62 MWD+IFR-AK-CAZ-SC(5) 15,231.50 91.23 349.03 5,206.76 5,142.29 5,067.87 -9,059.18 5,998,997.36 467,165.79 3.20 10,379.42 MWD+IFR-AK-CAZ-SC(5) 15,324.17 91.03 350.23 5,204.93 5,140.46 5,159.01 -9,075.86 5,999,088.54 467,149.41 1.31 10,439.43 MWD+IFR-AK-CAZ-SC(5) 15,419.06 91.03 348.35 5,203.23 5,138.76 5,252.23 -9,093.49 5,999,181.81 467,132.07 1.98 10,501.31 MWD+IFR-AK-CAZ-SC(5) 5/19/2016 8:22:23AM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-513 actual @ 64.47usft(Doyon 142) Site Kuparuk 3S Pad MD Reference: 3S-513 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 Database: OAKEDMP2 Survey • -p Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,513.24 91.13 347.06 5,201.45 5,136.98 5,344.23 -9,113.54 5,999,273.86 467,112.32 1.37 10,564.67 MWD+IFR-AK-CAZ-SC(5) 15,608.72 90.96 344.71 5,199.71 5,135.24 5,436.80 -9,136.82 5,999,366.50 467,089.34 2.47 10,631.12 MWD+IFR-AK-CAZ-SC(5) 15,702.97 91.13 342.62 5,197.99 5,133.52 5,527.23 -9,163.32 5,999,457.00 467,063.12 2.22 10,699.28 MWD+IFR-AK-CAZ-SC(5) 15,782.00 91.13 342.62 5,196.43 5,131.96 5,602.64 -9,186.92 5,999,532.48 467,039.76 0.00 10,757.43 PROJECTED to TD Projection to TO 5/19/2016 8:2223AM Page 7 COMPASS 5000.1 Build 74 • • 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: O Surface Coordinates O Declination & Convergence LJ GRS Survey Corrections • Survey Tool Codes SLB DE: Digitally signed by Scott Bncnswick Scott Brunswick DN cn=Scatt Brunswick,o,ou=D&W, Client Representative: mail= nn.a.brurewck@c o,o, <=D5 Date: 19-May-2016 , Manna Cement Detail Report `14 &Wells 3S-613 iHips ridxk:s String: Conductor Cement Job: DRILLING ORIGINAL,4/15/2016 16:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 1/30/2016 12:00 1/30/2016 23:30 3S-613 Comment Peak drilled 42"hole to 81'below ground level,set 16"62.58#Grade B Insulated Conductor.AFC mixer truck poured 500/3000 aggregate-ratio Type I/II cement in two stages,2.5 yards on first stage and 7.5 yards on second stage.Sealed Pan Cellar is 5'deep,6'wide. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement 93.0 120.0 No No No 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) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment AFC Mixer truck pour 2.5 yards(-12 bbls)of 500/3000 aggregate type I/II cement at 60 degree slurry temp in over 5 minute interval.Ambient temp was-8 deg. Cement supervisor was Russ Blaine. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(f/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement 40.0 93.0 No No No 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) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment AFC Mixer truck pour 7.5 yards(-36 bbls)of 500/3000 aggregate type I/II cement at 60 degree slurry temp over 10 minute interval.Ambient temp was-5 deg. Cement supervisor was Russ Blaine. 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: 6/17/2016 Cement Detail Report 0 3S-613 illlps. String: Surface Casing Cement Job: DRILLING ORIGINAL,4/15/2016 16:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 4/21/2016 15:54 4/21/2016 18:57 3S-613 Comment Flood cement lines with H2O, PT lines at 900&4000 psi. Pump 100 bbls of 10.5 ppg MP II w/red dye at 5 bpm,65 psi. Load bottom plug. Batch up&pump 593 bbls of 11.0 ppg lead cement at 6 bpm, 190 psi. Pump 60 bbls of 15.8 ppg tail cement at 4.5 bpm,200 psi. Load top plug&pump 10 bbls of fresh H2O.Swap to rig pumps&chase with 9.3 ppg mud at 5 bpm,200-650 psi. Bump the plug with 2537 strokes,261 bbls. Pressure up to 1100 psi&hold for 5 minutes. Bleed off pressure&check floats,good.CIP at 18:57 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement surface casing 42.3 2,908.0 No 136.7 Yes Yes 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) 7 3 5 559.0 1,100.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Flood cement lines with H2O, PT lines at 900&4000 psi. Pump 100 bbls of 10.5 ppg MP II w/red dye at 5 bpm,65 psi. Load bottom plug. Batch up&pump 593 bbls of 11.0 ppg lead cement at 6 bpm, 190 psi. Pump 60 bbls of 15.8 ppg tail cement at 4.5 bpm,200 psi.Load top plug&pump 10 bbls of fresh H2O.Swap to rig pumps&chase with 9.3 ppg mud at 5 bpm,200-650 psi. Bump the plug with 2537 strokes,261 bbls. Pressure up to 1100 psi&hold for 5 minutes. Bleed off pressure&check floats,good.CIP at 18:57 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push 60.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead 42.3 2,402.0 1,743 G 593.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.75 11.00 102.1 6.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Cement Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail 2,402.0 2,908.0 290 G 60.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.06 15.80 166.3 4.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.05 gal/sx Page 1/1 Report Printed: 6/17/2016 Cement Detail Report 3S-613 L.oirmocow 'taillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,4/15/2016 16:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 5/2/2016 14:00 5/2/2016 21:40 3S-613 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 10,292.0 11,090.0 Yes 0.0 Yes Yes Cement Q Pump Init(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) 8 4 8 492.0 408.0 Yes 10.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM-PT lines to 4000 psi.Pump 25 bbls of CW100 @ 4.5 bpm,236 psi, FO 12%.Pump 20 bbls of 12.5 ppg MPII @ 4.5 bpm,200 psi, FO 12%.Drop bottom plug.Chase w/47 bbls of 15.8 ppg cement @ 4.5 bpm, ICP 200 psi, FCP 130 psi, FO 18%. Drop top plug. Pump 10 bbls of H2O @ 4.5 bpm,21 psi,FO 3%. Swap to rig pump&chase with 9.3 ppg LSND mud @ 4.5 bpm,catching plugs @ 1300 strokes,97 psi, FO 14%,FCP 441 psi,FO 12%.Bump plug @ 4800 strokes pressuring up to 941 psi. Hold pressure for 5 min&check floats good. Reciprocated casing through out job to 4300 strokes displacement,landing hanger.PU 305K,SO 127K.CIP @ 16:15 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,292.0 11,090.0 228 G 47.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 4.87 15.80 185.4 10.25 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.03 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 6,752.0 10,292.0 Yes 0.0 No No Cement Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 8 8 228.0 817.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM-line up to cementer.SLB pump 30 bbls of CW100 @ 6 bpm,290 psi.Pump 30 bbls of 12.5 ppg MPII @ 4.5 bpm, 180 psi. Pump 189 bbls of 15.8 ppg cement @ 5 bpm,200 psi,slow to 3 bpm,57 psi. Drop top closing plug. Pump 10 bbls of H2O at 3 bpm, 190 psi.Swap to rig&pump 9.3 ppg LSND @ 5 bpm, ICP 250 psi,FCP 870 psi. Reduce rate at 4470 strokes to 3 bpm,800 psi.Bump plug @ 4593 strokes. Pressure up&close stage collar @ 1800 psi,increase to 2100 psi&hold for 5 min.Bleed off pressure&check stage collar closed,good.CIP @ 23:11. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 6,752.0 10,292.0 1,210 G 250.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 4.89 15.80 224.1 5.50 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Page 1/1 Report Printed: 6/17/2016 • • 216020 RECEIVED 27 3 06 JUN 15 2016 ConocoPhdli AOGCC TRANSMITTAL DATA LOGGED Co /t0/2016 ,.I. K.BENDER FROM: Sandra D. Lemke, ATO7-704 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3S-613 DATE: 06/14/2016 Transmitted: Kuparuk River Unit, Alaska 3S-613 1 CD of log images and 1 color mud log print each: Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.Lemke(&COP.com CC: 3S-613 transmittal folder, production well files, eSearch Receipt:fi)At#4U e: .... °" n, GIS-Technical Data Management I ConocoPhillips j Anchorage, Alaska I Ph: 90Z265,6947 • OF Tjy y/��s THE STATE Alaska Oil and Gas of/k L sKA. Conservation Commission coot333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Sandeep Pedam Sr. Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Torok Undefined Oil Pool, KRU 3S-613 Permit to Drill Number: 216-020 Sundry Number: 316-283 Dear Mr. Pedam: 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, eV-6 /371)2444../.. Cathy P. Foerster Chair DATED this s day of June, 2016. RBDMS V}- JUN 0 2 2016 r • STATE OF ALASKA • R, ALASKA OIL AND GAS CONSERVATION COMMISSION AY 2 4 2016 APPLICATION FOR SUNDRY APPROVALS S�4 1 i 1, 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations Fracture Stimulate F Repair Well Operations hu down Suspend rPerforate r Other Stimulate 1 ••••••. Pull Tubing IT Change Approved Program Plug for Redrill F; Perforate New Pool FT Re-enter Susp Well FT Alter Casing F, Other: I- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory I— Development FT 216-020 3.Address: 6.API Number: F P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic FT Service 50-103-20735-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes 1— No , I✓ KRU 3S-613 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25528,ADL 25544,ADL 38107 Kuparuk River Field/Torok Undefined 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): 15,782' 5,196' 4,al i 2 n/a n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 120' 120' Surface 2,862' 10 3/4 2,901' 2,571' Intermediate 11,044' 7 5/8 11,082' 513' Liner 4,740' 5" 15,649' 5,199' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): - 4.5 L-80 10,965' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER HRD-E ZXP Liner Top Packer 10909=MD and 5146=TVD SSSV: NONE 12.Attachments: Proposal Summary El Wellbore schematic (] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory FT Stratigraphic FT Development FT Service F 14.Estimated Date for 5/30/2016 15.Well Status after proposed work: Commencing Operations: OIL I— WINJ F WDSPL F Suspended F- 1 6. 16.Verbal Approval: Date: GAS r WAG FGSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned F- 1 7.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Sandeep Pedam@ 263-4724 Email Sandeep.Pedam@conocophillips.com Printed Name Sandeep Pedam Title Sr.Completions EngineerlAt n 41,1i� W /6 itSignature r Phone 263-4724 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ t-- 2-53 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 3 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes VNo ❑ RBDMS JUN 0 2 201f Spacing Exception Required? Yes ❑ No I/ Subsequent Form Required: /Q —4 0 1- U APPROVED BY Approved by: 5L-c` COMMISSIONER THE COMMISSION Date: L- //4p Form 10-403 Re sed 11/2 15 1 \AIea ll CA is valid for 12 months from the date of val. Attachments in Duplicate 611/16 ' ` v ' v Utio 611( i6 7t2 c./i/ic. TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Julie D. Little Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 3S-613 Well ) under the Provisions of 20 AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Julie D. Little, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Julie D. Little, and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI"). 3. Pursuant to 20 AAC 25.283(a)(1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On April 7, 2016, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. 5. On May 18, 2016, CPAI sent a corrected Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 18th day of May, 2016. Julie D. Little STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 18th day of May, 2016, by Julie D. Little. Nota Public, State of Alaska My Commission Expires: 14104// / 8 026/7 STATE OF.A.? &sBA NOTARY Pt.TL3LIC r> / LAURA E. MUTCH My Commission Expires Apr.18,2019 • Julie D.Little INV Staff Landman ConocoPhillips Alaska, Inc. ConocoPhillips P.O. Box 100360 Anchorage,Alaska 99510-360 Telephone:(907)265-6158 Facsimile: (907)265-1441 Julie.D.Little@conocophillips.com May 18, 2016 SENT VIA CERTIFIED MAIL To: Operator and Owners (see Distribution below) Re: Revised Notice pursuant to 20 MC 25.283 (1) 3S-613 Well Kuparuk River Unit, Alaska ADL 380107, KRU Tract 150; ADL 25544, KRU Tract 149; and ADL 25528, KRU Tract 147 Gentlemen: In letter mailed April 7, 2016 ConocoPhillips Alaska, Inc. ("CPAP') as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, provided notice of its intent to submit an Application for stimulation by hydraulic fracturing for the 2S-613 Well (the"Well") on or about April 7, 2016. A copy of the original notice letter is attached. Subsequent review of this communication confirmed that the notice cover letter contained a typographical error with respect to the well number. In the first paragraph, the original notice should have referred to the 3S-613 well, not the 2S-03 well. All other information in the original notice (including surface location, target location, and bottom hole location) is correct. Additionally, the Exhibits to the original notice were all correct and accurate. This letter is sent to correct the typographical error in the first paragraph of the original notice. Please replace the reference to 2S-03 with 3S-613. The Application for stimulation by hydraulic fracturing for the 3S-613 well will be filed with the AOGCC this week. Please contact me if you have questions or require additional information. Very truly yours, °. dt& Julie D. Little Staff Landman Distribution: BP Exploration (Alaska) Inc. Chevron U.S.A. Inc. ExxonMobil Alaska Production Inc. State of Alaska Department of Natural Resources Attachment: Original Notice Letter w/ attachments Cc: Sandeep Pedam Rebecca Swensen • • ConocoPhillips laska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2S-613 Well Kuparuk River Unit, Alaska ADL 380107, KRU Tract 150; ADL 25544, KRU Tract 149; and ADL 25528, KRU Tract 147 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2S-03 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about April 7, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on leases ADL 380107, KRU Tract 150; ADL 25544, KRU Tract 149; and ADL 25528, KRU Tract 147 as depicted on Exhibit 1 as follows: Surface Location: 2514' FNL, 1052' FEL Section 18, T12N, RO8E, UM Target Location: 1385' FNL, 4258' FEL Section 13, T12N, RO7E, UM Bottomhole Location: 2137' FNL, 158' FEL Section 11, T12N, RO7E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, et44.L - • Z Paul Wharton Staff Landman cc: Sandeep Pedam Rebecca Swensen TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2S-613 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton, and I have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations("Notice"). 4. On or about April 7, 2016, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners,surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 7th day of April, 2016. Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 7th day of April, 2016, by Paul K.Wharton. Notary Public, State of Alaska STATE OF ALASKA ;�, ' ,,' MraTSignEggIC : REBECCA SWENibtN ct.74, J My Commission Expires Aug.27,2O1d 0 0 `,Z6,,..,LI 5/5 ii/50 Moraine 3S-61:. Grass Roots Horizontal Multi-Stage Frac'd injector As Drilled Wellbore Schematic ConocoPhillips FMC 4-%"tree,top joint is 4-W 12.6#IBTM,crossed over(for frac equipint Existing Conductor: New SpudMud 16" 9.2 PPG with Dummy(2,493'TVD;54 deg incl) . L Surface Casing: 10-3/4"45.5#L-80 Hydril 563 2,901' MD/2,572'TVD @ 13-1/2"Surface Hole 4W,xl„KemG 56° _ Campanian Top 3,381'MD(2,75 . . . . . . . . . . . 9-7/8" Intermediate Tubing: Hole 4-1/2" 12.6#L-80 Hydril 563; Seal Assembly: 10,915' SND Planned top ot 2—stage cement ,2 PPG above 6,767MD (a minimum of 500'MD above the 'eep up with K-3) )ilution 4"A"x 1"KBMG TVD with SOV(4,500 TVD;70 deg i CI) - •" - .Kt- (Cotote)Tpp q2F 'tilDi 409P-R D - ,. . : n ., - . - ,... . . . . indi k.rm a C Int e mto th A4,r•in :- .. 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II 1 111 PALM 1 18 C� 17 . —"--..-17. --* 3S 16 3S-22 3S-08B 3S-08A/ A�.:0107 ADL025546 3S-23'4' ! �. .. 3S-0-37 j 3S-08 ADL025544 1 i I 1 24 3S-08C ._.._.'—.._.._..2� 21 23 3S-21 3S-23A Well Within Trajectory Radius — Fault Within Frac Point Radius 3S-24A I • Frac Point I —3S-613 Trajectory 3S-24 1 1 0 1/2 Mi. Frac Point Radius ADL025551 1 30 ,0 1/2 Mi. Trajectory Radius 26 25 1 AD 92374 -.. .._.._.._.._.._.._.._.._.._.._..� L1 Kuparuk PA i:Unit Boundary 1 ❑ CAELUS Lease 1 0 CPAI Lease 2S-613 Hydraulic Fracturing draulic Notice Lette• • April 7,2016 Page 2 Exhibit 1 / ;.s 5 T13N R7E ConOcOP,, ilhps A.CL'_5502a 35-613 Alas Ka:Inc. Aam:5750 Lease Pia' N 0553,9 Oooguruk 0r.2 *.4 ..5 01 A.ao: Unit '4.':t _ 5545 ' Kuparuk Rive ' Unit i 1 - i I I 147 46 ACL360424 1 Aa s _ ADLO� '1, w 0106 afe c1 Acs 25:0 - --- Act.' '-- ; 2, ,..,__, 1 i .._.._.. ._.,_ '/2 mile radius i from Well i i — 1 \1 T72 II ' e) T'12N - :E i 1 f 3S-613 i � ,� i/, � , 50 .ACL2635.57 • •,=DL5-"554' _ A .i 41107 Acro: EO 1 Aas 2560 ass:2448 • I 1 • I 1 1 1 1 Li / 1 1 • Frac Point ; —3S-613 Open Interval - Placer -.---•-•-----•-- —3S-613 Trajectory Unit . E Q 1/2 Mi.Trajectory Radius 1 'II-Unit Tract Number :I.cL351s1: F •.ate:7 30 1 152 ADLO 5551 -- E j=Kuparuk PA 1 ��1 Avss 2500 -- 1.7;Unit Boundary .. .._.._.._.._.. .. .. .. .. DASRC Lease DCAELUS Lease 1 t ; ❑CPAI Lease • • 2S-613 Hydraulic Fracturing Notice Letter April 7, 2016 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director 11, • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 3S-613 Landowners Iv- 11rtart6 is € _ T13N R7E ConocoPhillips 151 - -9t3 Alaska.Irc, ACL355036 Acres 8750 - ( Lease Plat N ACL 032 Oooguruk Acres: Unit R 6lrles c4 C6 0 8 'A i Kuparuk River i Unit ' 2 t 5 I I I ADL744 .c s: ADLIN2552: _ F-6 s Acre ..1I. ,. � I 21 I i i � I I i T12 ' R7E ' 12N •`.E i c ' €4 13 18 1( 3S-613 i 22 I 1 �' 50, AC ?.0?p, ! Al Ib.. A...,`1107 a. 2.80 I — 2580 s.,2448 i I ; 22a •••••m•mmmilliillMIIIMNIN•rleeeieiliiielMillienIMII I 1 1 i. ! • Frac Point i '--35-613 Open Interval — — --- —1 - .—.—._.—•—•-----3S-813 Trajectory Placer ' Uniti 01/2 Mi_Trajectory Radius 1§-1 Unit Tract Number ADL312 Acres 2480 I 259ii 4 AE Kuparuk PA 128 4012 'is Unit Boundary El ASRC Lease ❑CAELUS Lease i ; o CPAI Lease • • SLL bv � clu5/3 1)/(42 .1441 A Table 1: Wells within .5 miles WELL NAME STATUS WELL TYPE 3S-19 ACTIVE PROD 3S-620 ACTIVE PROD MORAINE 1 PA EXPLOR 1063-Lpi/A, 214p,iva. 3 n3 SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See conclusion of the Agifer Exception Order No. 2 — Milne Point Unit. Which states "Those portions of freshwateraquifers lying directly below Milne Point Unit qualify as exempt freshwater aquiferinder 10 AAC 25.440" // • • SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • S SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) 0 � ,-gm.? All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 4/21/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 10.5 bbls MPII and 11 ppg lead cement, this was followed by 15.8 ppg tail cement and displaced with 9.3 ppg mud. Full returns were seen throughout the job. The plug bumped at 1100 psi and the floats were checked and they held. The 7-5/8" casing cement report on 5/2/2016 shows that the job was pumped as designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before dropping bottom plug, this was then chased with 15.8 ppg cement and dropped top plug. This was chased with 9.3 ppg LSND mud. Full returns were seen throughout the job. The plug bumped at 941 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 4/24/2016 the 10 & 3/4" casing was pressure tested to 3125 psi for 30 mins. On 5/6/2016 the 7 & 5/8" casing was pressure tested to 3505 psi. The 7 & 5/8" casing will be pressure tested to 4,100 psi prior to frac'ing. The 4.5" tubing will be pressure tested to 5,000 psi prior to frac'ing. 0 • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 4.5" 12.6 L-80 8,430 psi 7,500 psi Table 2: Pressure Ratings • Stimulation Surface Rig-Up 1 � Bleed l Tattle Tale Tank 14.441 € � a .111111, v 11 o • Minimum pressure rating on all surface treating lines 10,000 psi 11,14111.41 • Main treating line PRV is set to 95/0 of max treating pressure -appP s k G • IA parallel PRV set to psi 3 ()Hit° = 11004:1 • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 N N ` „ N _ psi. a. j 11►I Y Q I W hprul dtund U Pop-Off Tank :•43 Pop-Off Tank _ Pump Truck G N Z} G1 Frac Pump 01 P►J Frac Pump Frac Pump r N Frac Pump Frac Pump r Frac Pump • S 10K Frac Tree 0111 h;I L.I-C t TR,f �: f I�1p�(I�3 =el 1 IA1,YY•163 It M' JL tly.l a`' .—. 4-114.64.3 Om*II tit MTh a_,III I27•.1 mu ne D.._7I !IBC, —i 1,111-5111.1.4-23 :rid >s3r DIT �.bti s'I9._ 'Air. --MIT:,TT —l., -.1= - —D L8:!} x4 }1+:: ; �i ■r II�.-a5 ets.3 ,7„ ,,...„N G.IT—.- IIIA IIIA —`I.1... ah-1”..z arcs , L Ill 111C~*�f+L1. ' 114"G L'1 am iv.i,. ”.1.I - AK SeTS�INS SIMS.irn __�■. r.......•;' —--S.M.ro.a 1.4.71144.3 f --—f l } _ if (t. 10.1 NM.i>MI OM TON o-Tar>DS*Ta x IW Ra. 6II5 . 1 'of- `'ll° 1x2.4 J.1 I'..17. +'` ,.� . ,. Is K urb.�18x = — _,���:tlUa NOM WNW UNDO 1taD, 1 1 —_— RJIQ.>311.RF RBTa*TL%LMS41 I. — — VOILA 141111.1136- LM.i :I:LIi I — Si J i— --Lambs MD mer I.WNs-1047 Di lls UM a bu;a.sx 4Bll X11 1is lee. IV MS DNS 191:F .a PPM;ATM •1i•i4 DOM .!SIN MIK PNIC SLAG , GEN 5 16 X If) 3/4 M. ' §f9 x 4 In MD#DATINT pxm .r.MMISSINSIS i5.12111.1D f^s iniE 341.724.11 ,r,I4. rum.. x'HTM rC IMMO,,FUI1EM 14JE4EL. �.16-1.-1-1 r,. L 1 ET19471N,C '.paL*SII �'- a ` 7.WDLICI.21-143 ® IING LATE 1NIIINN111-- ,�>.�>.........•�.I.MM. TL CYI OI?CSS • S SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) Get this from the geo. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that: The fracturing zone, the Upper Moraine reservoir, is approximately 220 ft. TVD thick at the heel, with the top Upper Moraine at -5,088 ft. TVDSS (10,962 ft. MD) and an estimated 230 ft. TVD thick at the toe of the well. The Upper Moraine Member is comprised of thinly bedded sandstone, siltstone, and mudstone layers. The sandstone and siltstone components are litharenites, moderately to well sorted, and very fine grained. The mudstones are composed of clay-rich, moderately to poorly sorted silt and mud grains. The estimated fracture pressure for the Moraine interval is —12.5-13.5 ppg. The overlaying confining interval of the Torok Formation consists of mudstone and siltstone ranging in total thickness from 1,060 ft. TVD at the heel to approximately 1,025 ft. TVD at the toe with the top of the Torok starting at -4,031 ft. TVDSS (7,269 ft. MD). The estimated fracture gradient for the overlaying Torok Formation is —0.82 psi/ft. • SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 3S-19: 7" casing cement pump report on 7/2/2003 shows that job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G Cement, displaced with seawater. The plug bumped at 2000psi, and the floats were checked and they held. CBL conducted on 12/22/2012 from 9170ft to surface. CBL log indicates good to fair cement from 9170ft to 7350ftMD. Moraine-1: The 9-5/8" casing cement pump report on 2/11/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 12ppg class G cement, displaced with 9.7 ppg brine. The plug bumped at 2031 psi and the floats were checked and they held. Well is currently Plugged &Abandoned. 3S-620: The 7 & 5/8 casing cement pump report on 2/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 9.7 ppg mud. The plug bumped at 1,000 psi and the floats were checked and they held. • S SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion,based on seismic,well,and other subsurface information currently available that there are three faults that transects the Moraine Oil Pool within one half mile radius of the wellbore trajectory for 3S-613.The faults do not intersect the 3S-613 wellbore and terminate within the proposed pool, in the Lower Moraine Member,roughly 350+ft. TVD below the 3S-613 wellbore. No losses were observed at any projected crossings above the faults during drilling of the 3S-613. Fracture gradients within the confining zone(Torok Formation)will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. 3S-613 Faults MD(feet) TVDSS Throw(feet) Fault#1 (WNW strike) 10,420(projected) -5,521 ft. 10(DTS) Fault#2(NNE strike) 7,800(projected) -5,501 ft. 10(DTNW) Fault#3 (NNE strike at toe) Past toe of well -5,520 ft. 26(DTSE) The three faults offset the HRZ, a thick marine mudstone unit below the Moraine Oil Pool and terminate into the Lower Moraine Member.The HRZ has an estimated fracture pressure of—16+ ppg. One fault (fault#3) is within one%2 mile radius of the toe of 3S-613, and the other two faults (faults#1 and #2) project up to the intermediate section of the wellbore.These features are noted on the included map, but they are much deeper than the wellbore, roughly 350+ft.TVD deeper than the deepest part of the 3S-613 wellbore.All the faults are more than 260 ft.TVD deeper than the deepest expected stimulated fractures.Additional smaller, sub-seismic scaled features were not encountered or inferred while drilling. CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the apparent faults will not interfere with containment. ' 11Mar16 • ADL355038 ConocoPhilli s ADL355039 35 ConocoPhillips Oooguruk !� 15 36 Alaska, Inc. 16 3S-613 Unjt Fault Analysis N Kuparuk River o o.z o.a o.s o.Mtes A I Unit t VV 4c-0 5/31/19- I 2 1 5 3 1 6 •1 1 1 CD • ADL380106 1 ADL390434 . 'DL025528 21 ; 1 1 1 10 1 1 1=.�..�..�.._.._., 8 7 1 1 1 1 13520 / 14 ��, 3S-19 .. r18.......„: 01k-4,3 1 � 17 1 3S-613 Kuparuk PA i ►, A �ii�r� ADL380107 ADL390697 . ADL04544 22 _--1 } 1 I I 1 G 1 22I 23 24 i I 1 Well Within Frac Point Radius i — Fault Within Frac Point Radius 1 } o Frac Point -•- •----1 t e—•---•-•-•-• Placer — 3S-613 Trajectory Unit i 0 1/2 Mi. Frac Point Radius O I a 1 0 1/2 Mi. Trajectory Radius I '"' 15 1 .81,)Unit Tract Number 27 1 ADL391912 1 26 ADL025551-�_--_..�. 25 30 0Kuparuk PA I i: Unit Boundary ❑ASRC Lease 1 ❑ CAELUS Lease El CPAI Lease • • • Plat 2: Fault Analysis ConocoPhillips 2x-01 Fault Art sishl.`SiSc. I'iC. 13Jan1fi 041:10258041117 DS2S pr ADC:02560E 11011) AC C2 BaaIrf • Nal • Frac Pain Active -II Within Confining Zone Aba -oned Weil Within Confining Zone Referer,cr Well Data Ccro a?hiHips Alaska Technical Database tATCe —W-:Trajectory i F=uI Within Confining Zone IR 1/2 Mi.Frac Point Radius 1/2 Mi.Trajectory Radius 1.KRiIHoun.ar}, _ __ 3a C 4 ❑ :CPA Lease •25.c:c ".!iter ff • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 3S-613 was completed in 2016 as horizontal injector in the Moraine formation. The well was completed with 4.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Moraine Formation Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 22 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 23,000 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the —300 bbl breakdown stage (30# Hybor G) according to the attached PDF HES pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure to 3,700 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 6912 psi. 12. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). • \,3* ZeAv WoSL ConocoPhillips discloses that it will be using the listed volumes of Radioactive Tracer, Chemical Frac Tracer, and Oil Frac Tracer for tracing purposes in the concentrations detailed in the attached Core lab Hydraulic Fracturing Fluid Product Component Information Disclosure. In support of this application, ConocoPhillips provides the front page of the Core Lab/Protechnics' MSDSs for each of the chemical additive, as well as the Hydraulic Fracturing Fluid Product Component Information Disclosure provided by Core Lab/Protechnics. Core Lab/Protechnics will supply the AOGCC with additional chemical disclosure information for the proprietary additives listed in the Hydraulic Fracturing Fluid Product Component Information Disclosure SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) • Akid r/3)//s. SAFETY DATA SHEET Date-Issued:05-2015 SDS Ref.No:ZW Date-Revised:5/31/15 Revision No:001 CareL �tnretr utuus�rlrr 1.PRODUCT AND COMPANY IDENTIFICATION 1.1 Product Identifiers Product name • Zero Wash Tracer Product number • NA Generic name IRZW,SCZW,SBZW,and low Density(LD) 1.2 Relevant identified used of the substance or mixture and uses advised against Identified uses Diagnostic Uses advised against • Not available 1.3 Details of the supplier of the safety data sheet Company ProTechnics Division of Core Laboratories 6510 W.Sam Houston Parkway N. Houston,Texas 77041 Telephone 713-328-2320 1.4 Emergency telephone number Emergency phone number 713-328-2320 Transportation emergency 1-800-535-5053(inside US) 1-352-323-3500 collect(outside US) 2.HAZARDS IDENTIFICATION 2.1 Classification of the substance or mixture GHS classification in accordance with 29 CFR 1910(OSHA HCS) Not Classified-Radioactive Material 2.2 GHS Label elements,including precautionary statements Pictogram Signal word None Associated Radioactive Material Hazard statement(s) No hazard statement associated-Radioactive Material.Zero Wash is a small bead that emits low gamma radiation in small quantities Precautionary statement(s) • • 2.3 Hazards not otherwise classified(IINOC)or not covered by GHS-Radioactive Material 3.COMPOSITION/INFORMATION ON INGREDIENTS 3.1 Substances Substance/mixture Mixture Ingredient , CAS/Exempt No , Percent, Hazardous Ceramic Proppant Proprietary 100 Yes 4.FIRST AID MEASURES 4.1 Description of first aid measures General advice Move away from source.Use ALARA-Time,Distance,Shielding If inhaled Not respirable In case of skin contact Remove from contact with skin.Keep distance In case of eye contact Immediately flush eyes with plenty of water for two to three minutes.Remove any contact lenses and continue flushing for 15 minutes.If irritation continues,consult a physician. If swallowed Consult a physician. 4.2 Most important symptoms and effects,both acute and delayed No side effects known with short teen,avoid long term exposure. 4.3 Indication of any immediate medical attention and special treatment needed Remove bead and place in shielding or create distance. 5.FIRE FIGHTING MEASURES 5.1 Extinguishing media Suitable extinguishing media Carbon Dioxide or Halon(This reduces the spread of Zero Wash material). 5.2 Special hazards arising from the substance or mixture NA 5.3 Advice for firefighters Low activity Gamma emitting radioactive material-low exposure S • 6.ACCIDENTAL RELEASE MEASURES 6.1 Personal precautions,protective equipment and emergency procedures 6.2 Environmental precautions .CONTROL THE AREA. Rubber gloves,boots and safety glasses should be worn when handling. 6.3 Methods and materials for containment and cleanup Clean up spill area by scooping up spilled material and transfer to a container. If clothing indicates the presence of Zero Wash material,remove the bead with adhesive tape,hold tape containing bead for decay in proper storage area.If numerous beads are found on clothing,remove clothing and place in a container for later cleaning or disposal. When any spill or release occurs,ProTechnics should be notified(713-328-2320)to supervise clean-up efforts. 7.HANDLING AND STORAGE 7.1 Precautions for safe handling Only ProTechnics Trained tracer supervisors should handle this material as they are trained in how to contain,remove and find the material. 7.2 Conditions for safe storage Normal 7.3 Specific end uses(s) Diagnostic. 8.EXPOSURE CONTROLS/PERSONAL PROTECTION 8.1 Control parameters Components with workplace control parameters Non radiation workers should avoid any contact with material.Restricted area for use should be set at 2mR/hr and prevent any unintentional exposure 8.2 Exposure controls Appropriate engineering controls Material stored in lead lined containers and used in restricted areas only.Only trained Tracing supervisors have access and control of the material Personal protective equipment Eye/face protection Safety glasses with side-shields conforming to EN 166. Use equipment for eye protection tested and approved under appropriate government standards such as NIOSH(US)or EN166(EU). Skin protection Handle with chemical-resistant gloves. Gloves must be inspected prior to use. Use proper glove removal technique(without touching glove's outer surface)to avoid skin contact with this product. Dispose of contaminated gloves after use in accordance with applicable laws and good laboratory practices. Wash and dry hands. Body protection Standard FRC should be adequate and use of proper surveying techniques used when material is being used. Control of environmental exposure All material should be captured and managed by ProTechnics,if material is noticed by survey please contact ProTechnics at 713-328-2320 • 9.PHYSICAL AND CHEMICAL PROPERTIES 9.1 Information on basic physical and chemical properties a) Appearance Form: Small grey colored ceramic bead Color: grey b) Odor Odorless c) Boiling point NA d) Freeze point NA e) Density/Specific Gravity 2.6 g/mL f) Flash point Not flammable g) pH Not available h) Evaporation factor Not determined i) Solubility not Soluble in water j) Vapor pressure Not determined k) Oxidizing properties Not determined 1) Vapor density Not determined m) Viscosity Not determined 9.2 Other safety information No data available. 10.STABILITY AND REACTIVITY 10.1 Reactivity NA 10.2 Chemical stability The product is stable under normal ambient conditions of temperature and pressure. 10.3 Possibility of hazardous reactions Will not polymerize. 10.4 Conditions to avoid Combination of material with more like material could increase exposure levels.The smaller the amount the lower the exposure rates should be. 10.5 Incompatible materials NA 10.6 Hazardous decomposition products None.All ZW material decay to stable state. 11.TOXICOLOGICAL INFORMATION 11.1 Information on toxicological effects Acute toxicity—oral • • May cause Eye and Mucous membrane irritation. Y . Ingestion is the only method of internal consumption. Acute toxicity—dermal Irritation or itching of the skin. Acute toxicity—inhalation ZERO WASH particle is too large to inhale. Skin corrosion/irritation NA. Serious eye damage/irritation NA Respiratory sensitization ZERO WASH particle is too large to inhale Skin sensitization Irritation or itching of the skin. Germ cell mutagenicity Genotoxicity—in vitro Based on available data the classification criteria are not met. Genotoxicity-in vivo Based on available data the classification criteria are not met. Carcinogenicity IARC: No component of this product present at levels greater than or equal to 0.1%is identified as probable,possible,or confirmed human carcinogen by IARC. ACGIH: No component of this product present at levels greater than or equal to 0.1%is identified as a carcinogen or potential carcinogen by ACGIH. NTP: No component of this product present at levels greater than or equal to 0.1%is identified as a known or anticipated carcinogen by NTP OSHA: No component of this product present at levels greater than or equal to 0.1%is identified as a carcinogen or potential carcinogen by OSHA. Reproductive toxicity Reproductive toxicity—fertility Based on available data the classification criteria are not met. Reproductive toxicity—development Based on available data the classification criteria are not met. Specific target organ toxicity—single exposure Low doses not applicable Specific target organ toxicity—repeated exposure Internal-possible gamma exposure Aspiration hazard Not anticipated to present an aspiration hazard,based on Physical structure. To the best of our knowledge,the chemical,physical,and toxicological properties have not been thoroughly investigated. • • 12.ECOLOGICAL INFORMATION 12.1 Toxicity NA. 12.2 Persistence and degradability Half life:IRZW-74 days,SCZW-84 days,SBZW-60 days 123 Bioaccumulative potential No data available. 12.4 Mobility in soil Zero Wash does not plate and will not breakdown in soil. 12.5 Results of PBT and vPvB assessment PBT/vPvB assessment are not available as chemical safety assessment not required/not conducted. 12.6 Other adverse effects No data available. 13.DISPOSAL CONSIDERATIONS 13.1 Waste treatment methods Product DISPOSAL METHOD:Dispose of waste at an appropriate waste disposal facility according to current applicable laws and regulations. PRODUCT DISPOSAL:Dispose of at a supervised appropriate waste disposal facility according to current applicable laws and regulations and product characteristics at time of disposal. EMPTY CONTAINER:Contaminated containers should be cleaned and disposed of in the same manner as the product in accordance with applicable regulations. GENERAL COMMENTS:Refer to Section 6,Accidental Release Measures for additional information. Contaminated packaging Contaminated containers should be cleaned and disposed of in the same manner as the product in accordance with applicable regulations.Please contact ProTechnics for Disposal guidance at 713-328-2320 14.TRANSPORT INFORMATION DOT(US) DOT(DEPARTMENT OF TRANSPORTATION) PROPER SHIPPING NAME:Radioactive material,type A package TECHNICAL NAME:Zero Wash Tracer LABEL:Diamond. Hazard Class/Division:7 United Nations number:2915 IMDG VESSEL(IMO/IMDG) PROPER SHIPPING NAME: Radioactive material,type A package TECHNICAL NAME: Zero Wash Tracer • • LABEL: Diamond. United Nations number:2915 IATA AIR-Forbidden on Passenger carrying aircraft. PROPER SHIPPING NAME: Radioactive material,type A package TECHNICAL NAME: Zero Wash Tracer LABEL: Diamond Hazard Class/Division:7 United Nations number:2915 15.REGULATORY INFORMATION SARA 302 Components SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title III, Section 302. SARA 313 Components SARA 313: This material does not contain any chemical components with known CAS numbers that exceed the threshold(De Minimis)reporting levels established by SARA Title III,Section 313. SARA 311/312 Hazards SAR 311/312: No chemicals in this material are subject to the reporting requirements of SARA Title III, Section 311/312. CERCLA(Comprehensive Response,Compensation,and Liability Act) Not Applicable. TSCA(Toxic Substance Control Act) Not Applicable. 16.OTHER INFORMATION HMIS Rating Health Hazard: 1 Chronic Health Hazard: 1 Flammability: 0 Physical Hazard: 0 NFPA Rating Health Hazard: 1 Fire Hazard: 0 Reactivity Hazard: 0 MANUFACTURER DISCLAIMER:Information given herein is offered in good faith as accurate,but without guarantee.Conditions of use and suitability of the product for particular uses are beyond our control; all risks of use of the product are therefore assumed by the user.Nothing is intended as a recommendation for uses which infringe valid patents or as extending license under valid patents.Appropriate warnings and safe handling procedures should be provided to handlers and users. Prepared by: ProTechnics Environmental Compliance Department Date of revision:05/31/2015 Contact information:713-328-2320 • • N C aA U N Q ± •o X � U -C 00 Q ro Q IL N 4- Q 2 0_ Q CO p Q = OD N p_ Q N LD N CC) m 0 H '427 O v O 0 N O N CU aA CO%LI c� I. Hydraulic Fracturing Fluid Product Component Disclosure Fracture Date 2016-04-15 • State: Alaska County: Harrison Bay API Number: 5010320735 CONOCO PHILLIPS Operator Name: NORTH SLOPE EBUS Well Name and Number: Kuparuk River 3S-613 Longitude: -150.19 Latitude: 70.39 Long/Lat Projection: Production Type: True Vertical Depth(TVD): 0 Total Water Volume(gal)': 959,531 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Ingredient Mass Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in lbs Comments Number(CAS (%by mass)** HF Fluid(%by #) mass)** Sea Water Operator Base Fluid NA NA 100.00% 83.21157% 8213559 Density=8.560 BA-20 BUFFERING AGENT,BE-8 MICROBIOCIDE, CL-22 UC,CL-31 CROSSLINKER, LOSURF-300D, Additive,Biocide, MO-67,OPTIFLO- Breaker,Buffer, II DELAYED Crosslinker,Gelling RELEASE Halliburton Agent,Microbiocide, NA NA 0 NA BREAKER, Non-ionic Surfactant, OPTIFLO-III DELAYED pH Control Additive, RELEASE Proppant BREAKER,SAND- COMMON WHITE- 100 MESH,3307 LB BAG,SP BREAKER,WG-36 GELLING AGENT GarboLite 16/20 CaProppant NA NA 0 NA - LVT-200 Penreco Additive NA NA 0 NA 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00073% 73 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00201% 198 Acetic acid 64-19-7 30.00% 0.00669% 656 Denise Tuck, Halliburton,3000 Acrylate polymer Confidential 1.00% 0.00099% 98 N.Sam Houston Pkwy E., Houston, TX 77032,281- 871-8226 Ammonium acetate 631-61-8 100.00% 0.02213% 2185 Ammonium persulfate 7727-54-0 100.00% 0.02188% 2162 Bentonite,benzyl(hydrogenated tallow alkyl)dimethylammonium 121888-68-4 5.00% 0.01458% 1440 stearate complex Borate salts Confidential 60.00% 0.05942% 5866 Ceramic materials and wares, 66402-68-4 100.00% 15.19650% 1500000 chemicals , Crystalline silica,quartz 14808-60-7 100.00% 0.58972% 58211 Crystalline Silica,Quartz 14808-60-7 0.10% 0.00029% 29 Cured acrylic resin Confidential 30.00% 0.00656% 648 Ethanol 64-17-5 60.00% 0.09388% 4332 Guar gum 9000-30-0 100.00% 0.29163% 28786 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02199% 2166 Hydrotreated Distillate,Light..C9-16 64742-47-8 100.00% 0.35283% 34827 Naphthalene 91-20-3 5.00% 0.00366% 361 Oxyalkylated phenolic resin Confidential 30.00% 0.02926% 2888 Poly(oxy-1,2-ethanediyl),alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 5.00% 0.00366% 361 branched Potassium formate 590-29-4 60.00% 0.05992% 5866 Potassium hydroxide 1310-58-3 5.00% 0.00230% 227 Potassium metaborate 13709-94-9 60.00% 0.02759% 2724 Silica gel 112926-00-8 1.00% 0.00292% 288 Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00099% 98 Sodium chloride 7647-14-5 1.00% 0.00198% 197 Sodium glycollate 2836-32-0 1.00% 0.00099% 98 Sodium hydroxide 1310-73-2 30.00% 0.02982% 2944 Sodium persulfate 7775-27-1 100.00% 0.00032% 32 Sodium sulfate 7757-82-6 0.10% 0.00000% 1 Surfactant mixture Confidential 1.00% 0.00583% 576 Water 7732-18-5 100.00% 0.16336% 16128 *Total Water Volume sources may include fresh water,produced water,and/or recycled water _ **Information is based on the maximumotential for concentration and thus the total maybe over 100% P Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. .z All component information listed was obtained from the supplier's Material Safety Data Sheets(MSDS).As such,the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's(OSHA)regulations govern the criteria for the disclosure of this information.Please note that Federal Law protects"proprietary","trade secret",and"confidential business information"and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i)and Appendix D. • • n Interval 5 Interval 4 Interval 3 Interval 2 Interval t _ o Moraine Moraine Moraine Moraine Moraine Wt 2 7 @13250-132511[165°F e13866-1366711165'F @14482-14483 ft 165°F (A 15096-1509759165°F @15712-1571311165°F 2 m 7 Tracer E Tracer D Tracer C Tracer B Tracer A "d W Lo m w o w J ,Ao m m w A W r., ,. o m w a w N w " w o 3 w in X. Dt o yc w ' _ z w w ct w c1 o n c, w m m m o w atcl w n w w w w w w m ct n w cr o ct w w w n w n n, w w atct w c1 6tcci A o N C 73 -' o` o` > > > o v 3 0 a a a a a n - a a a a o. 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Houston,Texas 77041 Telephone 713-328-2320 1.4 Emergency telephone number Emergency phone number 713-328-2320 Transportation emergency 1-800-535-5053(inside US) 1-352-323-3500 collect(outside US) 2.HAZARDS IDENTIFICATION 2.1 Classification of the substance or mixture GHS classification in accordance with 29 CFR 1910(OSHA HCS) Flammable liquids(Category 4-Combustible),H227 Skin irritation(Category 2),H315 Eye irritation(Category 2A),H319 Specific target organ toxicity-single exposure(Category 3),Respiratory system,H335 • • 2.2 GHS Label elements,including precautionary statements Pictogram Signal word Warning Hazard statement(s) H227 Combustible liquid. H315 Causes skin irritation. H319 Causes serious eye irritation. 11335 May cause respiratory irritation. Precautionary statement(s) P210 Keep away from heat/sparks/open flames/hot surfaces. No smoking. P261 Avoid breathing dust/fume/gas/mist/vapours/spray. P264 Wash skin thoroughly after handling. P280 Wear protective gloves. P280 Wear eye protection/face protection. P302+P352 IF ON SKIN: Wash with plenty of soap and water. P304+P340 IF INHALED: Remove affected person into fresh air and keep at rest in a position comfortable for breathing. P305+P351+P338 IF IN EYES: Rinse cautiously with water for several minutes. Remove contact lenses,if present and easy to do. Continue rinsing. P332+P313 If skin irritation occurs: Get medical advice/attention. P337+P313 If eye irritation persists: Get medical advice/attention. P362 Take off contaminated clothing and wash before reuse. P370+P378 In case of fire: Use dry sand,dry chemical or alcohol-resistant foam for extinction. P403+P233 Store in a well-ventilated place. Keep container tightly closed. P403+P235 Store in a well-ventilated place. Keep cool. P501 Dispose of contents/container to an approved waste disposal plant. 2.3 Hazards not otherwise classified(HNOC)or not covered by GHS-none 3.COMPOSITION/INFORMATION ON INGREDIENTS 3.1 Substances Substance/mixture Mixture Ingredient , CAS/Exempt No ,Percent, Hazardous Proprietary Ingredient Proprietary 0-30 No Proprietary Ingredient Proprietary 70-100 No 4.FIRST AID MEASURES 4.1 Description of first aid measures General advice Consult a physician. Show this safety data sheet to the doctor in attendance. Move out of dangerous area. If inhaled Move person into fresh air. If cough or other symptoms develop,consult a physician. • S In case of skin contact Remove contaminated clothing including shoes and immediately wash affected area with plenty of soap and water.If irritation continues,consult a physician.Wash contaminated clothing and shoes before reuse. In case of eye contact Immediately flush eyes with plenty of water for two to three minutes.Remove any contact lenses and continue flushing for 15 minutes.If irritation continues,consult a physician. If swallowed Do NOT induce vomiting. Wash out mouth with water and keep at rest.Consult a physician. 4.2 Most important symptoms and effects,both acute and delayed The most important known symptoms and effects are described in the labeling(see Section 2.2)and/or in Section 11. 4.3 Indication of any immediate medical attention and special treatment needed No data available. 5.FIRE FIGHTING MEASURES 5.1 Extinguishing media Suitable extinguishing media Use dry chemical,alcohol-resistant foam,water spray,or carbon dioxide. 5.2 Special hazards arising from the substance or mixture Carbon oxides,Halogenated hydrogen gas. 5.3 Advice for firefighters As in any fire,wear full protective clothing and equipment. 5.4 Further information Use water spray to cool unopened containers. 6.ACCIDENTAL RELEASE MEASURES 6.1 Personal precautions,protective equipment and emergency procedures Use personal protective equipment. Avoid breathing vapors,mist,or gas. Ensure adequate ventilation. Remove all sources of ignition. Evacuate personnel to safe areas. Beware of vapors accumulating to form explosive concentrations. Vapors can accumulate in low areas. 6.2 Environmental precautions Prevent further leakage or spillage if safe to do so. Do not let product enter drains. 6.3 Methods and materials for containment and cleanup Construct temporary dikes of dirt or any appropriate readily available material to prevent spreading of the material. Cover with absorbent and collect spillage with an electrically powered vacuum cleaner or by wet brushing. Place in container for disposal according to local regulations. Keep in suitable,closed containers for disposal. 6.4 Reference to other sections For protective clothing,see Section 8. For disposal,see Section 13. • • 7. HANDLING AND STORAGE 7.1 Precautions for safe handling Avoid contact with skin and eyes. Avoid inhalation of vapors or mist. Keep away from sources of ignition. No smoking. Take measure to prevent the buildup of electrostatic charge. Provide adequate exhaust ventilation at places where aerosols are formed. For precautions,see Section 2.2. Handle and use in a manner consistent with good industrial/manufacturing techniques and practices. 7.2 Conditions for safe storage Keep container tightly closed in a dry,cool,and well-ventilated place. 7.3 Specific end uses(s) Apart from the uses mentioned in Section 1.2,no other specific uses are stipulated. 8. EXPOSURE CONTROLS/PERSONAL PROTECTION 8.1 Control parameters Components with workplace control parameters No PELs,TLVs,or OELs for this product or its ingredients are listed in the current issue of ACGIH's Guide to Occupational Exposure Values nor have they been determined by the manufacturer. 8.2 Exposure controls Appropriate engineering controls Handle in accordance with good industrial hygiene and safety practice. Wash hands before breaks and at the end of the workday. Personal protective equipment Eye/face protection Safety glasses with side-shields conforming to EN166. Use equipment for eye protection tested and approved under appropriate government standards such as MUSH(US)or EN166(EU). Skin protection Handle with chemical-resistant nitrile gloves. Gloves must be inspected prior to use. Use proper glove removal technique(without touching glove's outer surface)to avoid skin contact with this product.Dispose of contaminated gloves after use in accordance with applicable laws and good laboratory practices. Wash and dry hands. Body protection Impervious clothing. The type of protective equipment must be selected according to the amount of dangerous substance at the specific workplace. Control of environmental exposure Prevent further leakage or spillage if safe to do so. Do not let product enter drains. 9.PHYSICAL AND CHEMICAL PROPERTIES 9.1 Information on basic physical and chemical properties a) Appearance Form: liquid Color: colorless b) Odor Mild. Resembling mothballs. c) Boiling point Approximately 175°C d) Freeze point Not determined. e) Density Not determined. S • f) Flash point Approximately 65°C—closed cup g) pH Not determined. h) Evaporation factor Not determined. i) Solubility Not soluble in water. j) Vapor pressure Not determined. k) Oxidizing properties Not determined. I) Vapor density Not determined. m) Viscosity Not determined. n) Auto-ignition temperature Not determined. o) Explosive properties Not determined. 9.2 Other safety information No data available. 10.STABILITY AND REACTIVITY 10.1 Reactivity No data available. 10.2 Chemical stability Stable under recommended storage conditions. 10.3 Possibility of hazardous reactions Will not polymerize. 10.4 Conditions to avoid Heat,flames,and sparks. 10.5 Incompatible materials Strong oxidizing agents. 10.6 Hazardous decomposition products Other decomposition products—No data available. In the event of a fire: see Section 5. 11.TOXICOLOGICAL INFORMATION 11.1 Information on toxicological effects Acute toxicity—oral Based on available data the classification criteria are not met. Acute toxicity—dermal Based on available data the classification criteria are not met. Acute toxicity—inhalation Based on available data the classification criteria are not met. Skin corrosion/irritation Skin irritant 2—H315 Causes skin irritation. • • Serious eye damage/irritation Eye irritant 2—H319 May cause severe eye irritation. Respiratory sensitization Based on available data the classification criteria are not met. Skin sensitization Based on available data the classification criteria are not met. Germ cell mutagenicity Genotoxicity—in vitro Based on available data the classification criteria are not met. Genotoxicity-in vivo Based on available data the classification criteria are not met. Carcinogenicity IARC: No component of this product present at levels greater than or equal to 0.1%is identified as probable,possible,or confirmed human carcinogen by IARC. ACGIH: No component of this product present at levels greater than or equal to 0.1%is identified as a carcinogen or potential carcinogen by ACGIH. NTP: No component of this product present at levels greater than or equal to 0.1%is identified as a known or anticipated carcinogen by NTP. OSHA: No component of this product present at levels greater than or equal to 0.1%is identified as a carcinogen or potential carcinogen by OSHA. Reproductive toxicity Reproductive toxicity—fertility Based on available data the classification criteria are not met. Reproductive toxicity—development Based on available data the classification criteria are not met. Specific target organ toxicity—single exposure STOT SE 3—H335 May cause respiratory irritation. Specific target organ toxicity—repeated exposure Based on available data the classification criteria are not met. Aspiration hazard Not anticipated to present an aspiration hazard,based on chemical structure. Additional information RTECS: Not available. Prolonged or repeated single exposure without adequate ventilation can cause: Nausea,headache,vomiting. To the best of our knowledge,the chemical,physical,and toxicological properties have not been thoroughly investigated. 12.ECOLOGICAL INFORMATION 12.1 Toxicity No data available. • • 12.2 Persistence and degradability Presumed to be persistent. 12.3 Bioaccumulative potential No data available. 12.4 Mobility in soil No data available. 12.5 Results of PBT and vPvB assessment PBT/vPvB assessment are not available as chemical safety assessment not required/not conducted. 12.6 Other adverse effects No data available. 13.DISPOSAL CONSIDERATIONS 13.1 Waste treatment methods Product This combustible material may be burned in a chemical incinerator equipped with an afterburner and scrubber. Offer surplus and non-recyclable solutions to a licensed disposal company. Contact a licensed professional waste disposal service to dispose of this material. Contaminated packaging Dispose of as unused product. 14.TRANSPORT INFORMATION DOT(US) Not dangerous goods. IMDG Not dangerous goods. IATA Not dangerous goods. 15.REGULATORY INFORMATION SARA 302 Components SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title III, Section 302. SARA 313 Components SARA 313: This material does not contain any chemical components with known CAS numbers that exceed the threshold(De Minimis)reporting levels established by SARA Title III,Section 313. SARA 311/312 Hazards Fire hazard—Combustible. CERCLA(Comprehensive Response,Compensation,and Liability Act) Not Applicable. • • TSCA(Toxic Substance Control Act) The components of this product are in compliance with the chemical notification requirements of TSCA. 16.OTHER INFORMATION HMIS Rating Health Hazard: 2 Chronic Health Hazard: Flammability: 2 Physical Hazard: 0 NFPA Rating Health Hazard: 2 Fire Hazard: 2 Reactivity Hazard: 0 MANUFACTURER DISCLAIMER:Information given herein is offered in good faith as accurate,but without guarantee.Conditions of use and suitability of the product for particular uses are beyond our control; all risks of use of the product are therefore assumed by the user.Nothing is intended as a recommendation for uses which infringe valid patents or as extending license under valid patents.Appropriate warnings and safe handling procedures should be provided to handlers and users. Prepared by: ProTechnics Environmental Compliance Department Date of revision:05/05/2016 Contact information:713-328-2320 • • 13.DISPOSAL CONSIDERATIONS 13.1 Waste treatment methods Product Dispose of at a supervised appropriate waste disposal facility according to current applicable laws and regulations and product characteristics at time of disposal. Contaminated packaging Contaminated containers should be cleaned and disposed of in the same manner as the product in accordance with applicable regulations. 14.TRANSPORT INFORMATII N DOT(US) Not dangerous goods. IMDG Not dangerous goods. IATA Not dangerous goods. 15.REGULATORY INFORMATION SARA 302 Components SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title III, Section 302. SARA 313 Components SARA 313: This material does not contain any chemical components with known CAS numbers that exceed the threshold(De Minimis)reporting levels established by SARA Title III,Section 313. SARA 311/312 Hazards SAR 311/312: No chemicals in this material are subject to the reporting requirements of SARA Title III, Section 311/312. CERCLA(Comprehensive Response,Compensation,and Liability Act) Not Applicable. TSCA(Toxic Substance Control Act) The components of this product are in compliance with the chemical notification requirements of TSCA. 16.OTHER INFORMATION HMIS Rating Health Hazard: 1 Chronic Health Hazard: Flammability: 0 Physical Hazard: 0 NFPA Rating Health Hazard: 1 Fire Hazard: 0 Reactivity Hazard: 0 • • MANUFACTURER DISCLAIMER:Information given herein is offered in good faith as accurate,but without guarantee.Conditions of use and suitability of the product for particular uses are beyond our control; all risks of use of the product are therefore assumed by the user.Nothing is intended as a recommendation for uses which infringe valid patents or as extending license under valid patents.Appropriate warnings and safe handling procedures should be provided to handlers and users. Prepared by: ProTechnics Environmental Compliance Department Date of revision:02/04/2016 Contact information:713-328-2320 • • SAFETY DATA SHEET Date-Issued:05-2015 % SDS Ref.No:CFT Date-Revised:2/04/15 Revision No:004 illikk011iOwe A 1 NESLBYOI3 OPSL'UZATION 1.PRODUCT AND COMPANY IDENTIFICATION 1.1 Product Identifiers Product name Chemical Frac Tracer Product number 1000,1100,1200,1300,1400, 1500,1600,1700,1900,2000,2100, 2200,2300,2400,2500,2800,2900,3000,3700,3900,4000,4800, 10100, 10200,10250,10300,10350,10400,10450,10500,10550, 10600,10650,10700,10750,10800,10850 Generic name CFT-1000,CFT-1100,CFT-1200,CFT-1300,CFT-1400,CFT-1500, CFT-1600,CFT-1700,CFT-1900,CFT-2000,CFT-2100,CFT-2200, CFT-2300,CFT-2400,CFT-2500,CFT-2800,CFT-2900,CFT-3000, CFT-3700,CFT-3900,CFT-4000,CFT-4800,CFT-10100, CFT-10200,CFT10250,CFT-10300,CFT-10350,CFT-10400, CFT-10450,CFT-10500,CFT-10550,CFT-10600,CFT-10650, CFT-10700,CFT-10750,CFT-10800,CFT-10850 1.2 Relevant identified used of the substance or mixture and uses advised against Identified uses Diagnostic Uses advised against Not available 1.3 Details of the supplier of the safety data sheet Company ProTechnics Division of Core Laboratories 6510 W.Sam Houston Parkway N. Houston,Texas 77041 Telephone 713-328-2320 1.4 Emergency telephone number Emergency phone number 713-328-2320 Transportation emergency 1-800-535-5053(inside US) 1-352-323-3500 collect(outside US) 2.HAZARDS IDENTIFICATION 2.1 Classification of the substance or mixture GHS classification in accordance with 29 CFR 1910(OSHA HCS) Skin irritation(Category 2),H315 Eye irritation(Category 2),H319 Specific target organ toxicity-single exposure(Category 3),Respiratory system,H335 • • 2.2 GHS Label elements,including precautionary statements Pictogram Signal word Warning Hazard statement(s) H315 Causes skin irritation. H319 Causes serious eye irritation. H335 May cause respiratory irritation. Precautionary statement(s) P261 Avoid breathing dust/fume/gas/mist/vapours/spray. P264 Wash skin thoroughly after handling. P280 Wear protective gloves. P302+P352 IF ON SKIN: Wash with plenty of soap and water. P304+P340 IF INHALED: Remove affected person into fresh air and keep at rest in a position comfortable for breathing. P332+P313 If skin irritation occurs: Get medical advice/attention. 2.3 Hazards not otherwise classified(IINOC)or not covered by GHS-none 3.COMPOSITION/INFORMATION ON INGREDIENTS 3.1 Substances Substance/mixture Mixture Ingredient , CAS/Exempt No ,Percent, Hazardous Proprietary Ingredient supplied as 10% w/v Aqueous Solution Proprietary 10 No Water 7732-18-5 90 No 4.FIRST AID MEASURES 4.1 Description of first aid measures General advice Consult a physician. Show this safety data sheet to the doctor in attendance. Move out of dangerous area. If inhaled Move person into fresh air. If cough or other symptoms develop,consult a physician. In case of skin contact Remove contaminated clothing including shoes and immediately wash affected area with plenty of soap and water.If irritation continues,consult a physician.Wash contaminated clothing and shoes before reuse. In case of eye contact Immediately flush eyes with plenty of water for two to three minutes.Remove any contact lenses and continue flushing for 15 minutes.If irritation continues,consult a physician. If swallowed Wash out mouth with water and keep at rest.Consult a physician. 4.2 Most important symptoms and effects,both acute and delayed The most important known symptoms and effects are described in the labeling(see Section 2.2)and/or in Section 11. 11) S 4.3 Indication of any immediate medical attention and special treatment needed No data available. 5.FIRE FIGHTING MEASURES 5.1 Extinguishing media Suitable extinguishing media Use fire-extinguishing media appropriate for surrounding materials. 5.2 Special hazards arising from the substance or mixture Carbon oxides,halogenated hydrogen gas. 5.3 Advice for firefighters As in any fire,wear full protective clothing and equipment. 5.4 Further information No data available. 6.ACCIDENTAL RELEASE MEASURES 6.1 Personal precautions,protective equipment and emergency procedures Use personal protective equipment. Avoid breathing vapours or mist. Evacuate personnel to safe areas. 6.2 Environmental precautions Do not let product enter drains,if safe to do so. 6.3 Methods and materials for containment and cleanup Construct temporary dikes of dirt or any appropriate readily available material to prevent spreading of the material. Cover with appropriate absorbent and sweep or shovel into an appropriate container. 6.4 Reference to other sections For protective clothing,see Section 8. For disposal,see Section 13. 7.HANDLING AND STORAGE 7.1 Precautions for safe handling Avoid contact with skin and eyes. Avoid formation of aerosols. Provide adequate exhaust ventilation at places where aerosols are formed. For precautions,see Section 2.2. Handle and use in a manner consistent with good industrial/manufacturing techniques and practices. 7.2 Conditions for safe storage Keep container tightly closed in a dry,cool,and well-ventilated place. Do not store with,or close to,strong acids. 7.3 Specific end uses(s) Apart from the uses mentioned in Section 1.2,no other specific uses are stipulated. S • 8. EXPOSURE CONTROLS/PERSONAL PROTECTION 8.1 Control parameters Components with workplace control parameters No PELs,TLVs,or OELs for this product or its ingredients are listed in the current issue of ACGIH's Guide to Occupational Exposure Values,nor have they been determined by the manufacturer. 8.2 Exposure controls Appropriate engineering controls Handle in accordance with good industrial hygiene and safety practice. Wash hands before breaks and at the end of the workday. Personal protective equipment Eye/face protection Safety glasses with side-shields conforming to EN166. Use equipment for eye protection tested and approved under appropriate government standards such as NIOSH(US)or EN166(EU). Skin protection Handle with chemical-resistant gloves. Gloves must be inspected prior to use. Use proper glove removal technique(without touching glove's outer surface)to avoid skin contact with this product. Dispose of contaminated gloves after use in accordance with applicable laws and good laboratory practices. Wash and dry hands. Body protection Impervious clothing. The type of protective equipment must be selected according to the amount of dangerous substance at the specific workplace. Control of environmental exposure Do not let product enter drains. 9.PHYSICAL AND CHEMICAL PROPERTIES 9.1 Information on basic physical and chemical properties a) Appearance Form: aqueous liquid Color: translucent b) Odor Odorless c) Boiling point Approximately 100°C d) Freeze point 0°C e) Density 1.05 g/mL fl Flash point Not flammable g) pH Approximately 9 h) Evaporation factor Not determined i) Solubility Soluble in water j) Vapor pressure Not determined k) Oxidizing properties Not determined 1) Vapor density Not determined m) Viscosity Not determined 9.2 Other safety information No data available. • • 10.STABILITY AND REACTIVITY 10.1 Reactivity Strong acids. Oxidizing materials. 10.2 Chemical stability The product is stable under normal ambient conditions of temperature and pressure. 10.3 Possibility of hazardous reactions Will not polymerize. 10.4 Conditions to avoid Extreme cold. 10.5 Incompatible materials Strong acids. Oxidizing materials. 10.6 Hazardous decomposition products None. 11.TOXICOLOGICAL INFORMATION 11.1 Information on toxicological effects Acute toxicity—oral Based on available data the classification criteria are not met. Acute toxicity—dermal Based on available data the classification criteria are not met. Acute toxicity—inhalation Based on available data the classification criteria are not met. Skin corrosion/irritation Skin irritant 2—H315 Causes skin irritation. Serious eye damage/irritation Eye irritant 2—H319 May cause severe eye irritation. Respiratory sensitization Based on available data the classification criteria are not met. Skin sensitization Based on available data the classification criteria are not met. Germ cell mutagenicity Genotoxicity—in vitro Based on available data the classification criteria are not met. Genotoxicity-in vivo Based on available data the classification criteria are not met. Carcinogenicity IARC: No component of this product present at levels greater than or equal to 0.1%is identified as probable,possible,or confirmed human carcinogen by IARC. i • ACGIH: No component of this product present at levels greater than or equal to 0.1%is identified as a carcinogen or potential carcinogen by ACGIH. NTP: No component of this product present at levels greater than or equal to 0.1%is identified as a known or anticipated carcinogen by NTP OSHA: No component of this product present at levels greater than or equal to 0.1%is identified as a carcinogen or potential carcinogen by OSHA. Reproductive toxicity Reproductive toxicity—fertility Based on available data the classification criteria are not met. Reproductive toxicity—development Based on available data the classification criteria are not met. Specific target organ toxicity—single exposure STOT SE 3—H335 May cause respiratory irritation. Specific target organ toxicity—repeated exposure Based on available data the classification criteria are not met. Aspiration hazard Not anticipated to present an aspiration hazard,based on chemical structure. Additional information RTECS: Not available. To the best of our knowledge,the chemical,physical,and toxicological properties have not been thoroughly investigated. 12.ECOLOGICAL INFORMATION 12.1 Toxicity No data available. 12.2 Persistence and degradability Presumed to be persistent. 12.3 Bioaccumulative potential No data available. 12.4 Mobility in soil No data available. 12.5 Results of PBT and vPvB assessment PBT/vPvB assessment are not available as chemical safety assessment not required/not conducted. 12.6 Other adverse effects No data available. • • TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2S-613 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton, and I have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283(1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about April 7, 2016, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners,surface owners,and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 7th day of April, 2016. gaddie, X •GQ --7 Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 7th day of April,2016, by Paul K.Wharton. Notary Public, State of Alaska STATE OF ALASKA MPRTIM&R eS: REBECCA SWENSEN + �' My Commission Expires Aug.2,7:201,6, • • Bettis, Patricia K (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, May 31, 2016 2:24 PM To: Bettis, Patricia K (DOA) Subject: FW: KRU 3S-613 PTD 216020 Sundry 316-283 Hydraulic Fracturing Questions Attachments: 3S-613 Fault Analysis Plat llmarl6.pdf;Zerowash products SDS.PDF;Visio-3S-613 Schematic Rev#4 - 2 stage cement.pdf; 3S-613 Fault Analysis Plat 31may16.pdf Not sure why they would be bouncing back?? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Pedam, Sandeep [mailto:Sandeep.Pedam@conocophillips.com] Sent: Tuesday, May 31, 2016 12:54 PM To: Wallace, Chris D (DOA) Subject: FW: KRU 3S-613 PTD 216020 Sundry 316-283 Hydraulic Fracturing Questions Chris, Looks like my email bounced back since the attachment sizes were too large. I will break them up in different emails. My apologies for sending this twice. Regards, Sandeep From: Pedam,Sandeep Sent:Tuesday, May 31, 2016 12:51 PM To: 'Wallace, Chris D (DOA)'<chris.wallace@alaska.gov> Subject: RE: KRU 3S-613 PTD 216020 Sundry 316-283 Hydraulic Fracturing Questions Chris, Good speaking on the phone with you this morning, I appreciate you taking the time to review the sundry. Please see my comments in blue font below. Please provide the following information for the KRU 3S-613 fracture stimulate sundry application: 1 1. A plat showing each well penetration within one-half mile of the KRU 3S•wellbore trajectory. Exhibit 1 provided in the application only shows KRU 3S-613. The exhibit does not show the wellbore trajectories of any other wells in the one-half mile trajectory radius. This would include all wells that may lie within the one-half mile trajectory radius of KRU 3S-613 at its surface location. The plat should show all wellbore trajectories within Y2-mile radius, which identifies well names and zones open to production or injection. This plat must include all abandoned or plugged-back wells. This information is attached to the email (3S-613 Fault Analysis Plat 31 May 16), please let me know if you need anything else. 2. Table 1 must list all wells within the KRU 3S-613 one-half mile wellbore trajectory radius and include the well status and well type. Please see below.Also, please note this information is available in Page 9 of the 35-620 frac sundry application (attached): WELL NAME STATUS WELL TYPE 3S-07 ACTIVE PROD 3S-09 ACTIVE INJ 3S-18 ACTIVE PROD 3S-14 ACTIVE INJ 3S-10 ACTIVE PROD 3S-15 ACTIVE PROD 3S-16 ACTIVE INJ 3S-22 ACTIVE INJ 3S-17 PA INJ 3S-17A ACTIVE INJ 35-08 PA PROD 3S-08A PA PROD 3S-08B PA PROD 3S-08C ACTIVE PROD 3S-21 ACTIVE INJ 3S-23 PA PROD 3S-23A ACTIVE PROD 3S-06 PA INJ 3S-06A ACTIVE INJ 3S-24 PA PROD PALM 1 PA EXPLOR 3S-26 ACTIVE INJ 3S-24A ACTIVE PROD 3S-03 ACTIVE PROD 3S-19 ACTIVE PROD 3S-620 ACTIVE PROD MORAINE 1 PA EXPLOR 3. Section 3-Freshwater Aquifers 20 AAC 25.383(a)(3) erroneously states "See conclusion of the Aquifer Exception Order No. 2—Milne Point Unit". The KRU 3S-613 well is not within the Milne Point Unit. Please address 20 AAC 25.283(a)(3) as it pertains to the Kuparuk River Unit. My apologies for this typo, 2 • See conclusion of the Aquifer Exemption Title 40 CFR 147.102() "The portions of aquifers on the North Slope described by a '/4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field" as exempt freshwater aquifers under 10 AAC 25.440" 4. Section 11, Plat 2: Fault Analysis. Plat 2: Fault Analysis provided with the application pertains to the KRU 2S-01 well not KRU 3-613 well. Please provide the correct fault analysis plat, again showing all well within the 1/2 mile frac point radius. Please see attachment(3S-613 Fault Analysis Plat). Please let me know if you need anything else. 5. Section 9, Data For Fracturing Zone and Confining Zones AAC 25.283(a)(9). Please provide a discussion of the underlying/bottom confining zone. Provide the top of the underlying confining interval is TVDss and MD, and the estimated fracture gradient for that confining zone. The underlying confining zone is the HRZ and has an overall thickness of 150'M. Top HRZ is estimated at- 5,493'TVDSS as it was not penetrated in the 35-613 well. The estimated fracture pressure for the underlying confining layer is 16 ppg. 6. Provide a list of fault-cuts (MD,TVDss and vertical displacement)that have been observed within wells and well branches within the area-of-review. No faults were encountered during the drilling portion of the well.CPAI has formed the opinion, based on seismic,well,and other subsurface information currently available that there are three faults that transects the Moraine Oil Pool within one half mile radius of the wellbore trajectory for 3S-613.The faults do not intersect the 35-613 wellbore and terminate within the proposed pool,in the Lower Moraine Member, roughly 350+ft.TVD below the 35-613 wellbore. No losses were observed at any projected crossings above the faults during drilling of the 3S-613. 7. Discuss any occurrences of lost circulation in those wells and wells branches that occurred while drilling. There were no losses due to faulting. 8. Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. These features are noted on the included map, but they are deeper than the wellbore, roughly 350+ft.TVD deeper than the deepest part of the 3S-613 wellbore.All the faults are 260+ft.TVD deeper than the deepest expected stimulated fractures.CPAI has formed the opinion, based on seismic,well,and other subsurface information currently available that the apparent faults will not interfere with containment. 9. Please discuss any mitigation plans CPAI may have should any of the fracture wings appear to intersect a fault during fracturing operations. What would be the fracture length, height and orientation compared to wellbore and faults within the area-of-review. Please note that should CPAI's mitigation plans for the above include shutting down the stage,going to flush, and dropping the ball to isolate said stage and move on to stimulate the stage ahead. 10. Please provide a copy of the digital well log data (specifically gamma ray, caliper, resistivity, and porosity) recorded in KRU 3S-613. Please note that a preliminary field print can be included since we are currently waiting on the final data. File size is 85MB,so I am unable to attach it to this email.Would you happen to have a different way for me to send this across?Please let me know and I am happy to get it across to you. 11. IA backpressure stated as 3700 psi in program. On "Stimulation Surface Rig-Up" it states IA parallel PRV set to 3500 psi. Please correct. My apologies,the IA backpressure will be held at 3700 psi. 3 12. Section 12 says Core Lab radioactive tracer, chemical frac tracer(CFT)and II Frac Tracer(OFT) in the concentrations attached. No concentrations are attached, and I only have records for CFT and OFT and not "radioactive tracer" chemicals? Am Ito receive "radioactive tracer"from Core-Lab or are these the same core lab chemicals used in 3S-620 for which I have the information? Thank you for your note, I have included the MSDS sheet from Protechnics for their radioactive tracer. Also, I've included a copy of the as drilled wellbore schematic. I believe there was a CBL run that might be in your possession. File size is 37MB, so I am unable to attach it to this email. I can also make a copy of this if you'd like along with the digital well log data request(10). Thanks again and hope you have a nice day. Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Cell: 512-507-9537 Office: 907-263-4724 From:Wallace, Chris D (DOA) [mailto:chris.wallace Walaska.gov] Sent:Wednesday, May 25, 2016 3:02 PM To: Pedam,Sandeep<Sandeep.Pedam@conocophillips.com> Subject: [EXTERNAL]KRU 35-613 PTD 216020 Sundry 316-283 Hydraulic Fracturing Questions Sandeep, We are in the process of reviewing the Sundry Application. Please provide the following information for the KRU 3S-613 fracture stimulate sundry application: 1. A plat showing each well penetration within one-half mile of the KRU 3S-613 wellbore trajectory. Exhibit 1 provided in the application only shows KRU 35-613. The exhibit does not show the wellbore trajectories of any other wells in the one-half mile trajectory radius. This would include all wells that may lie within the one-half mile trajectory radius of KRU 3S-613 at its surface location. The plat should show all wellbore trajectories within 1/2-mile radius,which identifies well names and zones open to production or injection. This plat must include all abandoned or plugged-back wells. 2. Table 1 must list all wells within the KRU 3S-613 one-half mile wellbore trajectory radius and include the well status and well type. 3. Section 3-Freshwater Aquifers 20 AAC 25.383(a)(3) erroneously states"See conclusion of the Aquifer Exception Order No. 2—Milne Point Unit". The KRU 3S-613 well is not within the Milne Point Unit. Please address 20 AAC 25.283(a)(3) as it pertains to the Kuparuk River Unit. 4. Section 11, Plat 2: Fault Analysis. Plat 2: Fault Analysis provided with the application pertains to the KRU 25-01 well not KRU 3-613 well. Please provide the correct fault analysis plat, again showing all well within the 1/2 mile frac point radius. 5. Section 9, Data For Fracturing Zone and Confining Zones AAC 25.283(a)(9). Please provide a discussion of the underlying/bottom confining zone. Provide the top of the underlying confining interval is TVDss and MD, and the estimated fracture gradient for that confining zone. 6. Provide a list of fault-cuts (MD,TVDss and vertical displacement)that have been observed within wells and well branches within the area-of-review. 7. Discuss any occurrences of lost circulation in those wells and wells branches that occurred while drilling. 4 • • 8. Pleaserovide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. 9. Please discuss any mitigation plans CPAI may have should any of the fracture wings appear to intersect a fault during fracturing operations.What would be the fracture length, height and orientation compared to wellbore and faults within the area-of-review. 10. Please provide a copy of the digital well log data (specifically gamma ray,caliper, resistivity, and porosity) recorded in KRU 3S-613. 11. IA backpressure stated as 3700 psi in program. On "Stimulation Surface Rig-Up" it states IA parallel PRV set to 3500 psi. Please correct. 12. Section 12 says Core Lab radioactive tracer, chemical frac tracer(CFT) and Oil Frac Tracer(OFT) in the concentrations attached. No concentrations are attached, and I only have records for CFT and OFT and not "radioactive tracer" chemicals? Am Ito receive "radioactive tracer" from Core-Lab or are these the same core lab chemicals used in 3S-620 for which I have the information? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Bettis, Patricia K(DOA) Sent: Wednesday, May 25, 2016 11:29 AM To: Wallace, Chris D (DOA) Subject: KRU 3S-613: My Questions Chris, do you want to send the email? Thanks, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 5 • • 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. 6 • • Bettis, Patricia K (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Wednesday,June 01, 2016 9:34 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3S-613 (PTD No. 216-020): Fracture Stimulate Sundry Application Patricia, Thank you for your email.We don't have any data for the Lower Moraine Member, Upper Moraine DFIT shows an estimated frac gradient of 0.6 psi/ft. Regards, Sandeep Pedam Completions Engineer ConocoPhillips Alaska Cell: 512-507-9537 Office: 907-263-4724 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday,June 01, 2016 9:05 AM To: Pedam, Sandeep<Sandeep.Pedam@conocophillips.com> Subject: [EXTERNAL]KRU 3S-613 (PTD No. 216-020): Fracture Stimulate Sundry Application Good morning Sandeep, Please break out the estimated fracture pressure gradient for the Upper Moraine Member and the Lower Moraine Member. 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 Dalaska.gov. 1 • • Bettis, Patricia K (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, May 26, 2016 2:53 PM To: sandeep.pedam@conocophillips.com Cc: Bettis, Patricia K (DOA) Subject: FW: KRU 3S-613 PTD 216020 Sundry 316-283 Hydraulic Fracturing Questions Sandeep, I would also request a final wellbore schematic rather than the proposed. Also a confirmation of the proposed cement tops/ isolation with the 2 stage cement pumped etc and how that was determined -Was there a CBL run at all? If so do we have a copy as Victoria will likely request that when she does her final review. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542 (fax) chris.wallacePalaska.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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wallace, Chris D (DOA) Sent: Wednesday, May 25, 2016 3:02 PM To: 'sandeep.pedam@conocophillips.com' Subject: KRU 3S-613 PTD 216020 Sundry 316-283 Hydraulic Fracturing Questions Sandeep, We are in the process of reviewing the Sundry Application. Please provide the following information for the KRU 3S-613 fracture stimulate sundry application: 1. A plat showing each well penetration within one-half mile of the KRU 3S-613 wellbore trajectory. Exhibit 1 provided in the application only shows KRU 3S-613. The exhibit does not show the wellbore trajectories of any other wells in the one-half mile trajectory radius. This would include all wells that may lie within the one-half mile trajectory radius of KRU 3S-613 at its surface location. The plat should show all wellbore trajectories within %-mile radius, which identifies well names and zones open to production or injection. This plat must include all abandoned or plugged-back wells. 2. Table 1 must list all wells within the KRU 3S-613 one-half mile wellbore trajectory radius and include the well status and well type. 3. Section 3-Freshwater Aquifers 20 AAC 25.383(a)(3) erroneously states "See conclusion of the Aquifer Exception Order No. 2—Milne Point Unit". The KRU 3S-613 well is not within the Milne Point Unit. Please address 20 AAC 25.283(a)(3) as it pertains to the Kuparuk River Unit. 1 • • 4. Section 11, Plat 2: Fault Analysis. Plat 2: Fault Analysis provided with the application pertains to the KRU 2S-01 well not KRU 3-613 well. Please provide the correct fault analysis plat, again showing all well within the 1/2 mile frac point radius. 5. Section 9, Data For Fracturing Zone and Confining Zones AAC 25.283(a)(9). Please provide a discussion of the underlying/bottom confining zone. Provide the top of the underlying confining interval is TVDss and MD, and the estimated fracture gradient for that confining zone. 6. Provide a list of fault-cuts (MD,TVDss and vertical displacement)that have been observed within wells and well branches within the area-of-review. 7. Discuss any occurrences of lost circulation in those wells and wells branches that occurred while drilling. 8. Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. 9. Please discuss any mitigation plans CPAI may have should any of the fracture wings appear to intersect a fault during fracturing operations. What would be the fracture length, height and orientation compared to wellbore and faults within the area-of-review. 10. Please provide a copy of the digital well log data (specifically gamma ray, caliper, resistivity, and porosity) recorded in KRU 35-613. 11. IA backpressure stated as 3700 psi in program. On "Stimulation Surface Rig-Up" it states IA parallel PRV set to 3500 psi. Please correct. 12. Section 12 says Core Lab radioactive tracer, chemical frac tracer(CFT) and Oil Frac Tracer(OFT) in the concentrations attached. No concentrations are attached, and I only have records for CFT and OFT and not "radioactive tracer" chemicals? Am Ito receive "radioactive tracer" from Core-Lab or are these the same core lab chemicals used in 3S-620 for which I have the information? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Bettis, Patricia K (DOA) Sent: Wednesday, May 25, 2016 11:29 AM To: Wallace, Chris D (DOA) Subject: KRU 3S-613: My Questions Chris, do you want to send the email? Thanks, Patricia 2 • • • • 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. 3 i • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, May 25, 2016 3:02 PM To: 'sandeep.pedam@conocophillips.com' Subject: KRU 3S-613 PTD 216020 Sundry 316-283 Hydraulic Fracturing Questions Sandeep, We are in the process of reviewing the Sundry Application. Please provide the following information for the KRU 3S-613 fracture stimulate sundry application: 1. A plat showing each well penetration within one-half mile of the KRU 3S-613 wellbore trajectory. Exhibit 1 provided in the application only shows KRU 3S-613. The exhibit does not show the wellbore trajectories of any other wells in the one-half mile trajectory radius. This would include all wells that may lie within the one-half mile trajectory radius of KRU 3S-613 at its surface location. The plat should show all wellbore trajectories within %2-mile radius,which identifies well names and zones open to production or injection. This plat must include all abandoned or plugged-back wells. 2. Table 1 must list all wells within the KRU 3S-613 one-half mile wellbore trajectory radius and include the well status and well type. 3. Section 3-Freshwater Aquifers 20 AAC 25.383(a)(3)erroneously states"See conclusion of the Aquifer Exception Order No.2—Milne Point Unit". The KRU 3S-613 well is not within the Milne Point Unit. Please address 20 AAC 25.283(a)(3)as it pertains to the Kuparuk River Unit. 4. Section 11, Plat 2: Fault Analysis. Plat 2: Fault Analysis provided with the application pertains to the KRU 2S-01 well not KRU 3-613 well. Please provide the correct fault analysis plat, again showing all well within theY2 mile frac point radius. 5. Section 9, Data For Fracturing Zone and Confining Zones AAC 25.283(a)(9). Please provide a discussion of the underlying/bottom confining zone. Provide the top of the underlying confining interval is TVDss and MD,and the estimated fracture gradient for that confining zone. 6. Provide a list of fault-cuts(MD,TVDss and vertical displacement)that have been observed within wells and well branches within the area-of-review. 7. Discuss any occurrences of lost circulation in those wells and wells branches that occurred while drilling. 8. Please provide estimates of the horizontal distances from the ends of the projected fracture wings to any nearby faults. If any of these fracture wings are likely to intersect or even closely approach a fault, please discuss why that fault will not provide a pathway for injected fluids to migrate out of the pool. 9. Please discuss any mitigation plans CPAI may have should any of the fracture wings appear to intersect a fault during fracturing operations. What would be the fracture length, height and orientation compared to wellbore and faults within the area-of-review. 10. Please provide a copy of the digital well log data (specifically gamma ray,caliper, resistivity,and porosity) recorded in KRU 3S-613. 11. IA backpressure stated as 3700 psi in program. On "Stimulation Surface Rig-Up" it states IA parallel PRV set to 3500 psi. Please correct. 12. Section 12 says Core Lab radioactive tracer,chemical frac tracer(CFT)and Oil Frac Tracer(OFT) in the concentrations attached. No concentrations are attached, and I only have records for CFT and OFT and not "radioactive tracer" chemicals? Am Ito receive "radioactive tracer"from Core-Lab or are these the same core lab chemicals used in 3S-620 for which I have the information? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer 1 • • Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Bettis, Patricia K(DOA) Sent: Wednesday, May 25, 2016 11:29 AM To: Wallace, Chris D (DOA) Subject: KRU 3S-613: My Questions Chris, do you want to send the email? 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O REC*VED 21 6020 MAY 31 2016 • 27 224 AOGCC SchlumbergerDrilling & Measurements Transmittal#: 31MAY16-SPO1 DATA LOGGED MWD/LWD Log Product Delivery (ai t i2oi6 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 3S-613 Date Dispatched: 31-May-16 Job#: 14AKA0119 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A Scope Services 2" MD x x Scope Services 2"TVD x x Scope Services 5"MD x x Scope Services 5'TVD x x Scope Services 2" MD MicroScope Image 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: Tom.Osterkamp(a�conocophillips.com AlaskaPTSPrintCenterslb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 Ti/),,,Li..-0,44.) 6���`A Received By: 4110 • 216020 27224 RECEWED MAY 31 2016 FINAL AOGCC J NADConversion Kuparuk River Unit Kuparuk 3S Pad 3S-613 3S-613 Definitive Survey Report 19 May, 2016 NAD 27 • r Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 3S-613 Well Position +N/-S 0.00 usft Northing: 5,993,901.19 usfi Latitude: 70°23'40.084 N +E/-W 0.00 usft Easting: 476,207.90 usfi Longitude: 150°11'36.889 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfi Ground Level: 24.70 usft Wellbore 3S-613 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 5/1/2016 18.23 80.97 57,482 Design 3S-613 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.77 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) (°) 39.77 0.00 0.00 300.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.15 816.58 3S-613 Srvy 1 -SLB_GWD70(3S-613) GYD-GC-SS Gyrodata gyro single shots 4/17/2016 8:3 876.24 2,827.88 3S-613 Srvy 2-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/17/2016 8:2• 2,891.75 2,959.21 3S-613 Srvy 3-SLB_INC+FILLER(3S-6 INC+TREND Inclinometer+known azi trend 4/25/2016 8:5. 3,053.58 11,016.76 3S-613 Srvy 4-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/25/2016 8:51 11,109.82 15,702.97 3S-613 Srvy 5-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/7/2016 9:05 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 39.77 0.00 0.00 39.77 -24.70 0.00 0.00 5,993,901.19 476,207.90 0.00 0.00 UNDEFINED 99.15 0.41 209.21 99.15 34.68 -0.19 -0.10 5,993,901.00 476,207.80 0.69 0.00 GYD-GC-SS(1) 162.63 0.24 235.92 162.63 98.16 -0.46 -0.32 5,993,900.73 476,207.57 0.35 0.05 GYD-GC-SS(1) 255.75 0.05 222.35 255.75 191.28 -0.60 -0.51 5,993,900.59 476,207.38 0.21 0.15 GYD-GC-SS(1) 349.00 1.96 176.79 348.98 284.51 -2.22 -0.45 5,993,898.97 476,207.44 2.06 -0.72 GYD-GC-SS(1) 442.13 3.71 182.06 441.99 377.52 -6.82 -0.47 5,993,894.37 476,207.41 1.90 -3.00 GYD-GC-SS(1) 535.28 3.02 185.21 534.98 470.51 -12.28 -0.80 5,993,888.92 476,207.06 0.77 -5.44 GYD-GC-SS(1) 628.64 4.77 200.47 628.12 563.65 -18.36 -2.38 5,993,882.84 476,205.46 2.16 -7.12 GYD-GC-SS(1) 722.05 6.58 212.06 721.08 656.61 -26.54 -6.58 5,993,874.68 476,201.23 2.28 -7.57 GYD-GC-SS(1) 816.58 7.30 223.45 814.92 750.45 -35.49 -13.59 5,993,865.75 476,194.20 1.64 -5.98 GYD-GC-SS(1) 5/19/2016 8:22:23AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 876.24 7.51 231.68 874.08 809.61 -40.66 -19.25 5,993,860.60 476,188.52 1.81 -3.66 MWD+IFR-AK-CAZ-SC(2) 970.62 9.25 242.41 967.46 902.99 -48.00 -30.82 5,993,853.30 476,176.93 2.47 2.69 MWD+IFR-AK-CAZ-SC(2) 1,065.29 13.12 251.04 1,060.32 995.85 -55.02 -47.73 5,993,846.33 476,160.00 4.44 13.83 MWD+IFR-AK-CAZ-SC(2) 1,161.53 15.39 254.03 1,153.59 1,089.12 -62.08 -70.34 5,993,839.34 476,137.37 2.48 29.88 MWD+IFR-AK-CAZ-SC(2) 1,254.28 16.71 249.78 1,242.72 1,178.25 -70.07 -94.69 5,993,831.42 476,113.00 1.90 46.96 MWD+IFR-AK-CAZ-SC(2) 1,349.55 19.21 241.42 1,333.36 1,268.89 -82.31 -121.31 5,993,819.27 476,086.34 3.76 63.90 MWD+IFR-AK-CAZ-SC(2) 1,444.30 21.66 237.49 1,422.14 1,357.67 -99.17 -149.75 5,993,802.51 476,057.85 2.96 80.11 MWD+IFR-AK-CAZ-SC(2) 1,539.42 24.51 238.37 1,509.64 1,445.17 -118.95 -181.36 5,993,782.83 476,026.18 3.02 97.59 MWD+IFR-AK-CAZ-SC(2) 1,633.94 26.61 238.54 1,594.90 1,530.43 -140.29 -216.12 5,993,761.61 475,991.36 2.22 117.02 MWD+IFR-AK-CAZ-SC(2) 1,728.07 26.12 237.27 1,679.24 1,614.77 -162.49 -251.53 5,993,739.52 475,955.88 0.79 136.59 MWD+IFR-AK-CAZ-SC(2) 1,822.57 26.91 238.35 1,763.80 1,699.33 -184.96 -287.23 5,993,717.16 475,920.11 0.98 156.27 MWD+IFR-AK-CAZ-SC(2) 1,918.99 31.36 239.84 1,848.00 1,783.53 -209.03 -327.52 5,993,693.23 475,879.75 4.68 179.13 MWD+IFR-AK-CAZ-SC(2) 2,013.65 38.98 240.11 1,925.33 1,860.86 -236.28 -374.70 5,993,666.13 475,832.49 8.05 206.36 MWD+IFR-AK-CAZ-SC(2) 2,107.91 39.29 241.09 1,998.44 1,933.97 -265.48 -426.53 5,993,637.09 475,780.57 0.73 236.64 MWD+IFR-AK-CAZ-SC(2) 2,202.58 38.25 244.46 2,072.26 2,007.79 -292.61 -479.22 5,993,610.13 475,727.80 2.48 268.71 MWD+IFR-AK-CAZ-SC(2) 2,297.95 38.95 245.96 2,146.79 2,082.32 -317.55 -533.23 5,993,585.37 475,673.71 1.23 303.02 MWD+IFR-AK-CAZ-SC(2) 2,391.94 39.59 247.81 2,219.56 2,155.09 -340.90 -587.95 5,993,562.20 475,618.93 1.42 338.73 MWD+IFR-AK-CAZ-SC(2) 2,486.90 41.04 251.44 2,291.98 2,227.51 -362.25 -645.53 5,993,541.03 475,561.28 2.91 377.92 MWD+IFR-AK-CAZ-SC(2) 2,580.56 42.35 256.35 2,361.93 2,297.46 -379.49 -705.35 5,993,523.98 475,501.41 3.76 421.11 MWD+IFR-AK-CAZ-SC(2) 2,676.54 47.30 256.71 2,429.98 2,365.51 -395.24 -771.13 5,993,508.45 475,435.59 5.16 470.20 MWD+IFR-AK-CAZ-SC(2) 2,771.34 49.38 258.28 2,493.00 2,428.53 -410.56 -840.27 5,993,493.35 475,366.41 2.52 522.42 MWD+IFR-AK-CAZ-SC(2) 2,827.88 52.52 257.66 2,528.61 2,464.14 -419.71 -883.21 5,993,484.33 475,323.44 5.62 555.03 MWD+IFR-AK-CAZ-SC(2) 2,891.75 56.00 257.76 2,565.91 2,501.44 -430.74 -933.86 5,993,473.46 475,272.77 5.45 593.37 INC+TREND(3) 2,901.00 56.06 257.77 2,571.08 2,506.61 -432.37 -941.36 5,993,471.86 475,265.27 0.66 599.05 NOT an Actual Survey 10 3/4"x 13-1/2" 2,959.21 56.44 257.86 2,603.42 2,538.95 -442.58 -988.67 5,993,461.80 475,217.93 0.66 634.92 INC+TREND(3) 3,053.58 57.60 257.96 2,654.79 2,590.32 -459.16 -1,066.07 5,993,445.47 475,140.48 1.23 693.66 MWD+IFR-AK-CAZ-SC(4) 3,148.37 59.19 259.99 2,704.47 2,640.00 -474.59 -1,145.31 5,993,430.30 475,061.20 2.48 754.57 MWD+IFR-AK-CAZ-SC(4) 3,242.89 61.30 259.95 2,751.37 2,686.90 -488.88 -1,226.11 5,993,416.26 474,980.37 2.23 817.40 MWD+IFR-AK-CAZ-SC(4) 3,336.34 63.60 261.29 2,794.60 2,730.13 -502.37 -1,307.84 5,993,403.03 474,898.59 2.77 881.44 MWD+IFR-AK-CAZ-SC(4) 3,431.88 66.94 262.16 2,834.56 2,770.09 -514.85 -1,393.71 5,993,390.83 474,812.70 3.59 949.56 MWD+IFR-AK-CAZ-SC(4) 3,527.73 70.01 264.08 2,869.73 2,805.26 -525.51 -1,482.22 5,993,380.45 474,724.17 3.71 1,020.88 MWD+IFR-AK-CAZ-SC(4) 3,622.12 70.19 266.79 2,901.86 2,837.39 -532.58 -1,570.68 5,993,373.67 474,635.69 2.71 1,093.96 MWD+IFR-AK-CAZ-SC(4) 3,717.82 71.41 268.53 2,933.33 2,868.86 -536.26 -1,660.97 5,993,370.27 474,545.39 2.14 1,170.31 MWD+IFR-AK-CAZ-SC(4) 3,811.69 71.29 268.82 2,963.35 2,898.88 -538.32 -1,749.89 5,993,368.50 474,456.48 0.32 1,246.29 MWD+IFR-AK-CAZ-SC(4) 3,905.64 71.25 268.01 2,993.52 2,929.05 -540.78 -1,838.83 5,993,366.32 474,367.54 0.82 1,322.08 MWD+IFR-AK-CAZ-SC(4) 4,001.08 71.33 267.99 3,024.14 2,959.67 -543.93 -1,929.17 5,993,363.45 474,277.20 0.09 1,398.75 MWD+IFR-AK-CAZ-SC(4) 4,095.58 71.25 267.44 3,054.45 2,989.98 -547.50 -2,018.61 5,993,360.17 474,187.76 0.56 1,474.41 MWD+IFR-AK-CAZ-SC(4) 4,189.60 71.24 268.82 3,084.68 3,020.21 -550.41 -2,107.58 5,993,357.55 474,098.78 1.39 1,550.02 MWD+IFR-AK-CAZ-SC(4) 4,284.95 70.83 272.25 3,115.68 3,051.21 -549.57 -2,197.74 5,993,358.67 474,008.64 3.43 1,628.51 MWD+IFR-AK-CAZ-SC(4) 4,379.99 70.82 274.42 3,146.90 3,082.43 -544.35 -2,287.35 5,993,364.18 473,919.06 2.16 1,708.73 MWD+IFR-AK-CAZ-SC(4) 5/19/2016 8:22:23AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 4,475.99 71.00 276.75 3,178.30 3,113.83 -535.52 -2,377.63 5,993,373.29 473,828.82 2.30 1,791.33 MWD+IFR-AK-CAZ-SC(4) 4,569.76 70.86 278.22 3,208.94 3,144.47 -523.97 -2,465.49 5,993,385.12 473,741.00 1.49 1,873.19 MWD+IFR-AK-CAZ-SC(4) 4,664.17 70.90 278.35 3,239.86 3,175.39 -511.12 -2,553.77 5,993,398.25 473,652.77 0.14 1,956.07 MWD+IFR-AK-CAZ-SC(4) 4,758.70 70.82 278.05 3,270.85 3,206.38 -498.38 -2,642.16 5,993,411.27 473,564.43 0.31 2,038.98 MWD+IFR-AK-CAZ-SC(4) 4,854.00 71.06 278.05 3,301.97 3,237.50 -485.77 -2,731.34 5,993,424.16 473,475.29 0.25 2,122.53 MWD+IFR-AK-CAZ-SC(4) 4,949.17 70.49 274.73 3,333.32 3,268.85 -475.76 -2,820.63 5,993,434.45 473,386.05 3.35 2,204.86 MWD+IFR-AK-CAZ-SC(4) 5,044.63 69.76 272.14 3,365.78 3,301.31 -470.38 -2,910.24 5,993,440.12 473,296.47 2.66 2,285.15 MWD+IFR-AK-CAZ-SC(4) 5,139.58 70.32 270.52 3,398.19 3,333.72 -468.31 -2,999.45 5,993,442.47 473,207.27 1.71 2,363.45 MWD+IFR-AK-CAZ-SC(4) 5,234.59 70.70 271.23 3,429.89 3,365.42 -466.94 -3,089.01 5,993,444.13 473,117.73 0.81 2,441.69 MWD+IFR-AK-CAZ-SC(4) 5,329.35 70.55 271.26 3,461.33 3,396.86 -465.00 -3,178.38 5,993,446.35 473,028.37 0.16 2,520.06 MWD+IFR-AK-CAZ-SC(4) 5,424.73 70.62 271.38 3,493.03 3,428.56 -462.93 -3,268.31 5,993,448.71 472,938.46 0.14 2,598.98 MWD+I FR-AK-CAZ-SC(4) 5,518.76 70.74 272.53 3,524.14 3,459.67 -459.90 -3,356.99 5,993,452.02 472,849.79 1.16 2,677.29 MWD+IFR-AK-CAZ-SC(4) 5,613.80 70.91 274.72 3,555.36 3,490.89 -454.23 -3,446.58 5,993,457.98 472,760.24 2.18 2,757.71 MWD+IFR-AK-CAZ-SC(4) 5,709.25 70.77 275.06 3,586.69 3,522.22 -446.54 -3,536.41 5,993,465.95 472,670.44 0.37 2,839.35 MWD+IFR-AK-CAZ-SC(4) 5,803.68 71.42 276.33 3,617.29 3,552.82 -437.67 -3,625.30 5,993,475.10 472,581.58 1.45 2,920.77 MWD+IFR-AK-CAZ-SC(4) 5,898.66 71.16 276.02 3,647.75 3,583.28 -428.00 -3,714.74 5,993,485.06 472,492.19 0.41 3,003.06 MWD+IFR-AK-CAZ-SC(4) 5,993.14 71.20 274.44 3,678.23 3,613.76 -419.85 -3,803.79 5,993,493.49 472,403.17 1.58 3,084.26 MWD+IFR-AK-CAZ-SC(4) 6,087.84 71.20 272.30 3,708.76 3,644.29 -414.58 -3,893.28 5,993,499.05 472,313.71 2.14 3,164.39 MWD+IFR-AK-CAZ-SC(4) 6,182.85 71.21 270.75 3,739.37 3,674.90 -412.18 -3,983.19 5,993,501.73 472,223.82 1.54 3,243.45 MWD+IFR-AK-CAZ-SC(4) 6,275.83 71.13 269.99 3,769.38 3,704.91 -411.61 -4,071.19 5,993,502.58 472,135.83 0.78 3,319.95 MWD+IFR-AK-CAZ-SC(4) 6,371.66 71.29 270.41 3,800.25 3,735.78 -411.30 -4,161.91 5,993,503.18 472,045.11 0.45 3,398.67 MWD+I FR-AK-CAZ-SC(4) 6,466.55 71.33 271.65 3,830.65 3,766.18 -409.68 -4,251.78 5,993,505.08 471,955.26 1.24 3,477.31 MWD+IFR-AK-CAZ-SC(4) 6,561.96 71.11 272.03 3,861.37 3,796.90 -406.78 -4,342.06 5,993,508.27 471,864.99 0.44 3,556.95 MWD+IFR-AK-CAZ-SC(4) 6,656.74 70.63 272.92 3,892.43 3,827.96 -402.92 -4,431.53 5,993,512.42 471,775.55 1.02 3,636.36 MWD+IFR-AK-CAZ-SC(4) 6,751.86 70.79 275.10 3,923.86 3,859.39 -396.64 -4,521.08 5,993,518.98 471,686.03 2.17 3,717.05 MWD+IFR-AK-CAZ-SC(4) 6,846.30 70.64 275.03 3,955.05 3,890.58 -388.77 -4,609.87 5,993,527.13 471,597.27 0.17 3,797.88 MWD+IFR-AK-CAZ-SC(4) 6,941.56 70.78 275.11 3,986.52 3,922.05 -380.82 -4,699.43 5,993,535.36 471,507.75 0.17 3,879.42 MWD+IFR-AK-CAZ-SC(4) 7,036.80 70.65 274.58 4,017.97 3,953.50 -373.23 -4,789.01 5,993,543.24 471,418.21 0.54 3,960.79 MWD+IFR-AK-CAZ-SC(4) 7,131.87 70.62 274.00 4,049.50 3,985.03 -366.52 -4,878.45 5,993,550.23 471,328.80 0.58 4,041.60 MWD+IFR-AK-CAZ-SC(4) 7,227.79 70.66 272.91 4,081.30 4,016.83 -361.07 -4,968.78 5,993,555.98 471,238.49 1.07 4,122.55 MWD+IFR-AK-CAZ-SC(4) 7,321.63 70.56 271.95 4,112.45 4,047.98 -357.31 -5,057.21 5,993,560.01 471,150.08 0.97 4,201.02 MWD+IFR-AK-CAZ-SC(4) 7,416.79 70.71 271.17 4,144.00 4,079.53 -354.87 -5,146.95 5,993,562.74 471,060.35 0.79 4,279.96 MWD+IFR-AK-CAZ-SC(4) 7,511.28 71.19 273.55 4,174.85 4,110.38 -351.19 -5,236.19 5,993,566.70 470,971.14 2.43 4,359.08 MWD+IFR-AK-CAZ-SC(4) 7,606.03 70.67 270.52 4,205.81 4,141.34 -348.01 -5,325.67 5,993,570.17 470,881.68 3.07 4,438.16 MWD+IFR-AK-CAZ-SC(4) 7,700.90 70.59 270.00 4,237.28 4,172.81 -347.60 -5,415.17 5,993,570.86 470,792.19 0.52 4,515.87 MWD+IFR-AK-CAZ-SC(4) 7,795.43 70.73 269.86 4,268.58 4,204.11 -347.71 -5,504.36 5,993,571.04 470,703.01 0.20 4,593.06 MWD+IFR-AK-CAZ-SC(4) 7,890.97 70.59 268.49 4,300.23 4,235.76 -349.01 -5,594.50 5,993,570.03 470,612.88 1.36 4,670.47 MWD+IFR-AK-CAZ-SC(4) 7,984.52 70.75 268.16 4,331.19 4,266.72 -351.59 -5,682.74 5,993,567.73 470,524.64 0.37 4,745.60 MWD+IFR-AK-CAZ-SC(4) 8,080.59 70.72 269.74 4,362.89 4,298.42 -353.25 -5,773.41 5,993,566.35 470,433.97 1.55 4,823.29 MWD+IFR-AK-CAZ-SC(4) 8,175.09 70.75 271.26 4,394.07 4,329.60 -352.47 -5,862.61 5,993,567.42 470,344.78 1.52 4,900.93 MWD+IFR-AK-CAZ-SC(4) 5/19/2016 8:22:23AM Page 4 COMPASS 5000.1 Build 74 S • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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) (°l100') (ft) Survey Tool Name 8,270.04 70.71 272.08 4,425.41 4,360.94 -349.86 -5,952.20 5,993,570.31 470,255.21 0.82 4,979.83 MWD+IFR-AK-CAZ-SC(4) 8,364.63 70.81 272.09 4,456.58 4,392.11 -346.61 -6,041.45 5,993,573.84 470,165.98 0.11 5,058.74 MWD+IFR-AK-CAZ-SC(4) 8,459.74 70.65 271.45 4,487.97 4,423.50 -343.83 -6,131.19 5,993,576.90 470,076.26 0.66 5,137.85 MWD+IFR-AK-CAZ-SC(4) 8,555.14 70.66 271.45 4,519.57 4,455.10 -341.56 -6,221.17 5,993,579.47 469,986.29 0.01 5,216.91 MWD+IFR-AK-CAZ-SC(4) 8,649.44 70.59 271.53 4,550.85 4,486.38 -339.24 -6,310.10 5,993,582.06 469,897.38 0.11 5,295.09 MWD+IFR-AK-CAZ-SC(4) 8,744.05 70.70 276.35 4,582.22 4,517.75 -333.11 -6,399.12 5,993,588.48 469,808.39 4.81 5,375.25 MWD+IFR-AK-CAZ-SC(4) 8,839.16 70.61 278.37 4,613.73 4,549.26 -321.62 -6,488.12 5,993,600.26 469,719.44 2.01 5,458.06 MWD+IFR-AK-CAZ-SC(4) 8,932.66 70.17 281.43 4,645.12 4,580.65 -306.48 -6,574.87 5,993,615.67 469,632.74 3.12 5,540.76 MWD+IFR-AK-CAZ-SC(4) 9,027.50 70.33 283.65 4,677.17 4,612.70 -287.10 -6,661.99 5,993,635.32 469,545.69 2.21 5,625.91 MWD+IFR-AK-CAZ-SC(4) 9,122.23 71.49 287.78 4,708.16 4,643.69 -262.85 -6,748.14 5,993,659.84 469,459.63 4.30 5,712.64 MWD+IFR-AK-CAZ-SC(4) 9,217.00 71.59 290.87 4,738.18 4,673.71 -233.10 -6,832.96 5,993,689.86 469,374.91 3.09 5,800.96 MWD+IFR-AK-CAZ-SC(4) 9,311.55 71.83 292.95 4,767.85 4,703.38 -199.61 -6,916.24 5,993,723.62 469,291.75 2.10 5,889.84 MWD+IFR-AK-CAZ-SC(4) 9,406.26 72.11 295.12 4,797.17 4,732.70 -162.93 -6,998.48 5,993,760.55 469,209.63 2.20 5,979.40 MWD+IFR-AK-CAZ-SC(4) 9,500.93 72.19 296.80 4,826.19 4,761.72 -123.48 -7,079.50 5,993,800.25 469,128.75 1.69 6,069.29 MWD+IFR-AK-CAZ-SC(4) 9,596.30 72.38 298.95 4,855.21 4,790.74 -81.01 -7,159.80 5,993,842.98 469,048.59 2.16 6,160.07 MWD+IFR-AK-CAZ-SC(4) 9,690.94 73.21 300.98 4,883.21 4,818.74 -35.85 -7,238.12 5,993,888.37 468,970.43 2.23 6,250.46 MWD+IFR-AK-CAZ-SC(4) 9,787.00 74.40 304.74 4,910.01 4,845.54 14.19 -7,315.58 5,993,938.67 468,893.13 3.96 6,342.58 MWD+IFR-AK-CAZ-SC(4) 9,881.24 74.93 307.67 4,934.94 4,870.47 67.87 -7,388.91 5,993,992.57 468,819.98 3.05 6,432.92 MWD+IFR-AK-CAZ-SC(4) 9,975.99 75.70 312.50 4,958.97 4,894.50 126.88 -7,459.00 5,994,051.79 468,750.08 5.00 6,523.12 MWD+IFR-AK-CAZ-SC(4) 10,070.82 76.47 315.80 4,981.78 4,917.31 190.98 -7,525.03 5,994,116.10 468,684.26 3.47 6,612.36 MWD+IFR-AK-CAZ-SC(4) 10,165.41 77.27 321.75 5,003.29 4,938.82 260.24 -7,585.70 5,994,185.54 468,623.82 6.18 6,699.53 MWD+IFR-AK-CAZ-SC(4) 10,259.49 77.92 325.51 5,023.50 4,959.03 334.21 -7,640.18 5,994,259.68 468,569.59 3.96 6,783.69 MWD+IFR-AK-CAZ-SC(4) 10,355.16 78.25 327.70 5,043.26 4,978.79 412.36 -7,691.69 5,994,337.99 468,518.32 2.27 6,867.38 MWD+IFR-AK-CAZ-SC(4) 10,449.63 78.31 331.38 5,062.45 4,997.98 492.08 -7,738.58 5,994,417.85 468,471.70 3.81 6,947.84 MWD+IFR-AK-CAZ-SC(4) 10,544.42 78.00 333.79 5,081.91 5,017.44 574.43 -7,781.29 5,994,500.32 468,429.25 2.51 7,026.01 MWD+IFR-AK-CAZSC(4) 10,639.15 78.55 336.80 5,101.17 5,036.70 658.68 -7,820.05 5,994,584.69 468,390.76 3.16 7,101.70 MWD+IFR-AK-CAZ-SC(4) 10,732.50 79.64 339.93 5,118.83 5,054.36 743.87 -7,853.84 5,994,669.98 468,357.25 3.49 7,173.56 MWD+IFR-AK-CAZ-SC(4) 10,827.76 81.03 341.56 5,134.83 5,070.36 832.53 -7,884.80 5,994,758.72 468,326.57 2.23 7,244.70 MWD+IFR-AK-CAZ-SC(4) 10,922.04 82.89 343.19 5,148.01 5,083.54 921.49 -7,913.06 5,994,847.77 468,298.60 2.61 7,313.66 MWD+IFR-AK-CAZ-SC(4) 11,016.76 84.88 342.39 5,158.10 5,093.63 1,011.45 -7,940.93 5,994,937.80 468,271.02 2.26 7,382.77 MWD+IFR-AK-CAZ-SC(4) 11,082.00 85.74 341.68 5,163.44 5,098.97 1,073.30 -7,960.98 5,994,999.71 468,251.17 1.70 7,431.06 I NOT an Actual Survey ) 7-5/8"x 9-7/8" 11,109.82 86.10 341.38 5,165.42 5,100.95 1,099.62 -7,969.77 5,995,026.06 468,242.46 1.70 7,451.83 MWD+IFR-AK-CAZ-SC(5) 11,158.87 86.15 342.34 5,168.73 5,104.26 1,146.12 -7,985.01 5,995,072.61 468,227.37 1.96 7,488.28 MWD+IFR-AK-CAZ-SC(5) 11,253.42 86.19 341.69 5,175.05 5,110.58 1,235.85 -8,014.14 5,995,162.42 468,198.53 0.69 7,558.37 MWD+IFR-AK-CAZ-SC(5) 11,347.88 86.26 340.94 5,181.27 5,116.80 1,325.14 -8,044.33 5,995,251.79 468,168.63 0.80 7,629.17 MWD+IFR-AK-CAZ-SC(5) 11,442.17 86.33 341.57 5,187.36 5,122.89 1,414.24 -8,074.57 5,995,340.98 468,138.68 0.67 7,699.90 MWD+IFR-AK-CAZ-SC(5) 11,537.40 86.22 340.20 5,193.55 5,129.08 1,504.03 -8,105.69 5,995,430.86 468,107.85 1.44 7,771.74 MWD+IFR-AK-CAZ-SC(5) 11,632.35 86.26 340.85 5,199.78 5,135.31 1,593.35 -8,137.27 5,995,520.27 468,076.55 0.68 7,843.76 MWD+IFR-AK-CAZ-SC(5) 11,726.27 86.19 341.85 5,205.96 5,141.49 1,682.15 -8,167.24 5,995,609.15 468,046.86 1.07 7,914.11 MWD+IFR-AK-CAZ-SC(5) 11,821.12 86.25 344.44 5,212.21 5,147.74 1,772.72 -8,194.68 5,995,699.80 468,019.72 2.73 7,983.16 MWD+IFR-AK-CAZ-SC(5) 5/19/2016 8:22:23AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 11,916.54 88.13 345.23 5,216.89 5,152.42 1,864.70 -8,219.61 5,995,791.85 467,995.08 2.14 8,050.74 MWD+IFR-AK-CAZ-SC(5) 12,009.59 91.66 346.35 5,217.06 5,152.59 1,954.89 -8,242.45 5,995,882.10 467,972.53 3.98 8,115.61 MW D+I FR-AK-CAZ-SC(5) 12,104.20 91.09 346.29 5,214.79 5,150.32 2,046.78 -8,264.82 5,995,974.06 467,950.46 0.61 8,180.94 MWD+IFR-AK-CAZ-SC(5) 12,199.28 90.51 345.97 5,213.46 5,148.99 2,139.08 -8,287.61 5,996,066.42 467,927.96 0.70 8,246.82 MWD+IFR-AK-CAZ-SC(5) 12,292.55 88.93 346.23 5,213.92 5,149.45 2,229.62 -8,310.01 5,996,157.02 467,905.85 1.72 8,311.49 MWD+IFR-AK-CAZ-SC(5) 12,387.28 88.35 345.95 5,216.17 5,151.70 2,321.54 -8,332.78 5,996,249.01 467,883.38 0.68 8,377.17 MW D+I FR-AK-CAZ-SC(5) 12,482.45 88.83 346.12 5,218.51 5,154.04 2,413.87 -8,355.74 5,996,341.40 467,860.71 0.54 8,443.22 MWD+1FR-AK-CAZ-SC(5) 12,576.92 89.45 345.45 5,219.93 5,155.46 2,505.44 -8,378.94 5,996,433.03 467,837.81 0.97 8,509.09 MWD+IFR-AK-CAZ-SC(5) 12,672.07 90.82 344.10 5,219.70 5,155.23 2,597.24 -8,403.92 5,996,524.91 467,813.12 2.02 8,576.63 MWD+IFR-AK-CAZ-SC(5) 12,767.60 91.37 343.45 5,217.88 5,153.41 2,688.95 -8,430.61 5,996,616.69 467,786.73 0.89 8,645.60 MWD+IFR-AK-CAZ-SC(5) 12,863.10 92.37 342.08 5,214.76 5,150.29 2,780.11 -8,458.89 5,996,707.93 467,758.74 1.78 8,715.67 MWD+1FR-AK-CAZ-SC(5) 12,957.94 92.33 340.82 5,210.87 5,146.40 2,869.95 -8,489.03 5,996,797.85 467,728.89 1.33 8,786.69 MWD+IFR-AK-CAZ-SC(5) 13,053.00 91.85 341.01 5,207.41 5,142.94 2,959.72 -8,520.09 5,996,887.72 467,698.11 0.54 8,858.48 MWD+IFR-AK-CAZ-SC(5) 13,147.27 91.44 344.01 5,204.70 5,140.23 3,049.59 -8,548.41 5,996,977.66 467,670.09 3.21 8,927.93 MWD+IFR-AK-CAZ-SC(5) 13,241.79 91.50 347.56 5,202.27 5,137.80 3,141.17 -8,571.61 5,997,069.31 467,647.18 3.76 8,993.82 MWD+1FR-AK-CAZ-SC(5) 13,335.69 91.31 352.69 5,199.97 5,135.50 3,233.62 -8,587.70 5,997,161.80 467,631.38 5.47 9,053.98 MWD+IFR-AK-CAZ-SC(5) 13,431.04 90.61 351.25 5,198.37 5,133.90 3,328.02 -8,601.02 5,997,256.23 467,618.37 1.68 9,112.71 MWD+IFR-AK-CAZ-SC(5) 13,480.88 90.27 347.86 5,197.99 5,133.52 3,377.02 -8,610.06 5,997,305.26 467,609.49 6.84 9,145.04 MWD+IFR-AK-CAZ-SC(5) 13,524.82 90.52 345.18 5,197.69 5,133.22 3,419.75 -8,620.30 5,997,348.01 467,599.39 6.13 9,175.27 MWD+IFR-AK-CAZ-SC(5) 13,571.44 90.44 345.00 5,197.30 5,132.83 3,464.80 -8,632.29 5,997,393.10 467,587.54 0.42 9,208.18 MWD+1FR-AK-CAZ-SC(5) 13,620.52 90.54 345.19 5,196.88 5,132.41 3,512.22 -8,644.92 5,997,440.56 467,575.06 0.44 9,242.83 MWD+IFR-AK-CAZ-SC(5) 13,715.71 90.37 345.10 5,196.12 5,131.65 3,604.23 -8,669.32 5,997,532.63 467,550.96 0.20 9,309.96 MW D+I FR-AK-CAZ-SC(5) 13,810.78 89.89 343.80 5,195.91 5,131.44 3,695.82 -8,694.80 5,997,624.29 467,525.77 1.46 9,377.83 MWD+IFR-AK-CAZ-SC(5) 13,905.45 89.48 344.74 5,196.43 5,131.96 3,786.94 -8,720.47 5,997,715.48 467,500.39 1.08 9,445.62 MWD+IFR-AK-CAZ-SC(5) 14,000.15 89.11 346.77 5,197.59 5,133.12 3,878.71 -8,743.77 5,997,807.33 467,477.39 2.18 9,511.68 MWD+IFR-AK-CAZ-SC(5) 14,094.72 89.11 347.51 5,199.06 5,134.59 3,970.90 -8,764.81 5,997,899.57 467,456.64 0.78 9,576.00 MWD+IFR-AK-CAZ-SC(5) 14,189.55 89.11 347.49 5,200.53 5,136.06 4,063.47 -8,785.34 5,997,992.20 467,436.41 0.02 9,640.06 MWD+IFR-AK-CAZ-SC(5) 14,282.53 88.63 346.56 5,202.37 5,137.90 4,154.06 -8,806.21 5,998,082.84 467,415.83 1.13 9,703.43 MWD+IFR-AK-CAZ-SC(5) 14,379.24 88.49 346.32 5,204.80 5,140.33 4,248.04 -8,828.88 5,998,176.89 467,393.46 0.29 9,770.05 MWD+IFR-AK-CAZ-SC(5) 14,474.34 88.66 346.16 5,207.16 5,142.69 4,340.38 -8,851.49 5,998,269.29 467,371.15 0.25 9,835.81 MWD+IFR-AK-CAZ-SC(5) 14,569.44 88.59 344.80 5,209.44 5,144.97 4,432.42 -8,875.33 5,998,361.39 467,347.61 1.43 9,902.47 MWD+IFR-AK-CAZ-SC(5) 14,664.18 88.56 343.28 5,211.80 5,147.33 4,523.48 -8,901.37 5,998,452.52 467,321.86 1.60 9,970.55 MWD+IFR-AK-CAZ-SC(5) 14,759.20 88.56 342.53 5,214.19 5,149.72 4,614.27 -8,929.29 5,998,543.39 467,294.23 0.79 10,040.13 MWD+IFR-AK-CAZ-SC(5) 14,852.90 89.62 341.39 5,215.68 5,151.21 4,703.35 -8,958.30 5,998,632.56 467,265.50 1.66 10,109.79 MWD+IFR-AK-CAZ-SC(5) 14,948.19 91.70 342.84 5,214.58 5,150.11 4,794.02 -8,987.56 5,998,723.31 467,236.53 2.66 10,180.47 MW D+I FR-AK-CAZ-SC(5) 15,041.66 91.57 344.04 5,211.91 5,147.44 4,883.57 -9,014.19 5,998,812.94 467,210.19 1.29 10,248.31 MW D+I FR-AK-CAZ-SC(5) 15,135.52 91.71 346.00 5,209.23 5,144.76 4,974.20 -9,038.44 5,998,903.64 467,186.23 2.09 10,314.62 MWD+IFR-AK-CAZ-SC(5) 15,231.50 91.23 349.03 5,206.76 5,142.29 5,067.87 -9,059.18 5,998,997.36 467,165.79 3.20 10,379.42 MWD+IFR-AK-CAZ-SC(5) 15,324.17 91.03 350.23 5,204.93 5,140.46 5,159.01 -9,075.86 5,999,088.54 467,149.41 1.31 10,439.43 MW D+I FR-AK-CAZ-SC(5) 15,419.06 91.03 348.35 5,203.23 5,138.76 5,252.23 -9,093.49 5,999,181.81 467,132.07 1.98 10,501.31 MWD+IFR-AK-CAZ-SC(5) 5/19/2016 8:22:23AM Page 6 COMPASS 5000.1 Build 74 s i . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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) (°/100') (ft) Survey Tool Name 15,513.24 91.13 347.06 5,201.45 5,136.98 5,344.23 -9,113.54 5,999,273.86 467,112.32 1.37 10,564.67 MWD+IFR-AK-CAZ-SC(5) 15,608.72 90.96 344.71 5,199.71 5,135.24 5,436.80 -9,136.82 5,999,366.50 467,089.34 2.47 10,631.12 MWD+IFR-AK-CAZ-SC(5) 15,702.97 91.13 342.62 5,197.99 5,133.52 5,527.23 -9,163.32 5,999,457.00 467,063.12 2.22 10,699.28 MWD+IFR-AK-CAZ-SC(5) 15,782.00 91.13 342.62 5,196.43 5,131.96 5,602.64 -9,186.92 5,999,532.48 467,039.76 0.00 10,757.43 PROJECTED to TD Projection to TD NOT an Actual Survey Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Li Yes ❑ No /have checked to the best of my ability that the following data is correct: 0 Surface Coordinates D Declination & Convergence p GRS Survey Corrections JJ Survey Tool Codes _ SLB DE: ' +, Scott Brunswick „�°Ktr ,',M°m".US Client Representative: __,._.._..._._ Date: 19-May-2016 5/19/2016 8:22:23AM Page 7 COMPASS 5000.1 Build 74 • 21 6020 27224 RECEIVED MAY 31 20111 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad 3S-613 3S-613 Definitive Survey Report 18 May, 2016 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 3S-613 Well Position +N/-S 0.00 usft Northing: 5,993,651.72 usfi Latitude: 70°23'38.993 N +E/-W 0.00 usft Easting: 1,616,239.97 usfi Longitude: 150° 11'48.175 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfi Ground Level: 24.70 usft Wellbore 3S-613 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 5/1/2016 18.23 80.97 57,482 Design 3S-613 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.77 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.77 0.00 0.00 300.00 Survey Program Date 5/18/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.15 816.58 3S-613 Srvy 1 -SLB_GWD70(3S-613) GYD-GC-SS Gyrodata gyro single shots 4/17/2016 8:3. 876.24 2,827.88 3S-613 Srvy 2-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/17/2016 8:2' 2,891.75 2,959.21 3S-613 Srvy 3-SLB_INC+FILLER(3S-6 INC+TREND Inclinometer+known azi trend 4/25/2016 8:5: 3,053.58 11,016.76 3S-613 Srvy 4-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/25/2016 8:51 11,109.82 15,702.97 3S-613 Srvy 5-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/7/2016 9:05 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 39.77 0.00 0.00 39.77 -24.70 0.00 0.00 5,993,651.72 1,616,239.97 0.00 0.00 UNDEFINED 99.15 0.41 209.21 99.15 34.68 -0.19 -0.10 5,993,651.54 1,616,239.87 0.69 0.00 GYD-GC-SS(1) 162.63 0.24 235.92 162.63 98.16 -0.46 -0.32 5,993,651.27 1,616,239.64 0.35 0.05 GYD-GC-SS(1) 255.75 0.05 222.35 255.75 191.28 -0.60 -0.51 5,993,651.13 1,616,239.46 0.21 0.15 GYD-GC-SS(1) 349.00 1.96 176.79 348.98 284.51 -2.22 -0.45 5,993,649.51 1,616,239.51 2.06 -0.72 GYD-GC-SS(1) 442.13 3.71 182.06 441.99 377.52 -6.82 -0.47 5,993,644.91 1,616,239.48 1.90 -3.00 GYD-GC-SS(1) 535.28 3.02 185.21 534.98 470.51 -12.28 -0.80 5,993,639.45 1,616,239.13 0.77 -5.44 GYD-GC-SS(1) 628.64 4.77 200.47 628.12 563.65 -18.36 -2.38 5,993,633.37 1,616,237.53 2.16 -7.12 GYD-GC-SS(1) 722.05 6.58 212.06 721.08 656.61 -26.54 -6.58 5,993,625.21 1,616,233.30 2.28 -7.57 GYD-GC-SS(1) 816.58 7.30 223.45 814.92 750.45 -35.49 -13.59 5,993,616.28 1,616,226.27 1.64 -5.98 GYD-GC-SS(1) 5/18/2016 2:25:49PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 876.24 7.51 231.68 874.08 809.61 -40.66 -19.25 5,993,611.13 1,616,220.59 1.81 -3.66 MWD+IFR-AK-CAZ-SC(2) 970.62 9.25 242.41 967.46 902.99 -48.00 -30.82 5,993,603.83 1,616,209.00 2.47 2.69 MWD+IFR-AK-CAZ-SC(2) 1,065.29 13.12 251.04 1,060.32 995.85 -55.02 -47.73 5,993,596.87 1,616,192.07 4.44 13.83 MWD+IFR-AK-CAZ-SC(2) 1,161.53 15.39 254.03 1,153.59 1,089.12 -62.08 -70.34 5,993,589.88 1,616,169.44 2.48 29.88 MWD+IFR-AK-CAZ-SC(2) 1,254.28 16.71 249.78 1,242.72 1,178.25 -70.07 -94.69 5,993,581.96 1,616,145.07 1.90 46.96 MWD+IFR-AK-CAZ-SC(2) 1,349.55 19.21 241.42 1,333.36 1,268.89 -82.31 -121.31 5,993,569.82 1,616,118.41 3.76 63.90 MWD+IFR-AK-CAZ-SC(2) 1,444.30 21.66 237.49 1,422.14 1,357.67 -99.17 -149.75 5,993,553.05 1,616,089.91 2.96 80.11 MWD+IFR-AK-CAZ-SC(2) 1,539.42 24.51 238.37 1,509.64 1,445.17 -118.95 -181.36 5,993,533.37 1,616,058.24 3.02 97.59 MWD+IFR-AK-CAZ-SC(2) 1,633.94 26.61 238.54 1,594.90 1,530.43 -140.29 -216.12 5,993,512.15 1,616,023.42 2.22 117.02 MWD+IFR-AK-CAZ-SC(2) 1,728.07 26.12 237.27 1,679.24 1,614.77 -162.49 -251.53 5,993,490.06 1,615,987.94 0.79 136.59 MWD+IFR-AK-CAZ-SC(2) 1,822.57 26.91 238.35 1,763.80 1,699.33 -184.96 -287.23 5,993,467.71 1,615,952.17 0.98 156.27 MWD+IFR-AK-CAZ-SC(2) 1,918.99 31.36 239.84 1,848.00 1,783.53 -209.03 -327.52 5,993,443.78 1,615,911.81 4.68 179.13 MWD+IFR-AK-CAZ-SC(2) 2,013.65 38.98 240.11 1,925.33 1,860.86 -236.28 -374.70 5,993,416.68 1,615,864.55 8.05 206.36 MWD+IFR-AK-CAZ-SC(2) 2,107.91 39.29 241.09 1,998.44 1,933.97 -265.48 -426.53 5,993,387.65 1,615,812.63 0.73 236.64 MWD+IFR-AK-CAZ-SC(2) 2,202.58 38.25 244.46 2,072.26 2,007.79 -292.61 -479.22 5,993,360.69 1,615,759.86 2.48 268.71 MWD+IFR-AK-CAZ-SC(2) 2,297.95 38.95 245.96 2,146.79 2,082.32 -317.55 -533.23 5,993,335.93 1,615,705.77 1.23 303.02 MWD+IFR-AK-CAZ-SC(2) 2,391.94 39.59 247.81 2,219.56 2,155.09 -340.90 -587.95 5,993,312.76 1,615,650.98 1.42 338.73 MWD+IFR-AK-CAZ-SC(2) 2,486.90 41.04 251.44 2,291.98 2,227.51 -362.25 -645.53 5,993,291.60 1,615,593.34 2.91 377.92 MWD+IFR-AK-CAZ-SC(2) 2,580.56 42.35 256.35 2,361.93 2,297.46 -379.49 -705.35 5,993,274.55 1,615,533.46 3.76 421.11 MWD+IFR-AK-CAZ-SC(2) 2,676.54 47.30 256.71 2,429.98 2,365.51 -395.24 -771.13 5,993,259.02 1,615,467.64 5.16 470.20 MWD+IFR-AK-CAZ-SC(2) 2,771.34 49.38 258.28 2,493.00 2,428.53 -410.56 -840.27 5,993,243.93 1,615,398.46 2.52 522.42 MWD+IFR-AK-CAZ-SC(2) 2,827.88 52.52 257.66 2,528.61 2,464.14 -419.71 -883.21 5,993,234.91 1,615,355.49 5.62 555.03 MWD+IFR-AK-CAZ-SC(2) 2,891.75 56.00 257.76 2,565.91 2,501.44 -430.74 -933.86 5,993,224.05 1,615,304.82 5.45 593.37 INC+TREND(3) 2,901.00 56.06 257.77 2,571.08 2,506.61 -432.37 -941.36 5,993,222.44 1,615,297.32 0.66 599.05 NOT an Actual Survey 10 3/4"x 13-1/2" 2,959.21 56.44 257.86 2,603.42 2,538.95 -442.58 -988.67 5,993,212.38 1,615,249.98 0.66 634.92 INC+TREND(3) 3,053.58 57.60 257.96 2,654.79 2,590.32 -459.16 -1,066.07 5,993,196.06 1,615,172.53 1.23 693.66 MWD+IFR-AK-CAZ-SC(4) 3,148.37 59.19 259.99 2,704.47 2,640.00 -474.59 -1,145.31 5,993,180.89 1,615,093.25 2.48 754.57 MWD+IFR-AK-CAZ-SC(4) 3,242.89 61.30 259.95 2,751.37 2,686.90 -488.88 -1,226.11 5,993,166.86 1,615,012.41 2.23 817.40 MWD+IFR-AK-CAZ-SC(4) 3,336.34 63.60 261.29 2,794.60 2,730.13 -502.37 -1,307.84 5,993,153.63 1,614,930.64 2.77 881.44 MWD+IFR-AK-CAZ-SC(4) 3,431.88 66.94 262.16 2,834.56 2,770.09 -514.85 -1,393.71 5,993,141.43 1,614,844.74 3.59 949.56 MWD+IFR-AK-CAZ-SC(4) 3,527.73 70.01 264.08 2,869.73 2,805.26 -525.51 -1,482.22 5,993,131.06 1,614,756.21 3.71 1,020.88 MWD+IFR-AK-CAZ-SC(4) 3,622.12 70.19 266.79 2,901.86 2,837.39 -532.58 -1,570.68 5,993,124.28 1,614,667.73 2.71 1,093.96 MWD+IFR-AK-CAZ-SC(4) 3,717.82 71.41 268.53 2,933.33 2,868.86 -536.26 -1,660.97 5,993,120.89 1,614,577.44 2.14 1,170.31 MWD+IFR-AK-CAZ-SC(4) 3,811.69 71.29 268.82 2,963.35 2,898.88 -538.32 -1,749.89 5,993,119.12 1,614,488.52 0.32 1,246.29 MWD+IFR-AK-CAZ-SC(4) 3,905.64 71.25 268.01 2,993.52 2,929.05 -540.78 -1,838.83 5,993,116.95 1,614,399.58 0.82 1,322.08 MWD+IFR-AK-CAZ-SC(4) 4,001.08 71.33 267.99 3,024.14 2,959.67 -543.93 -1,929.17 5,993,114.09 1,614,309.24 0.09 1,398.75 MWD+IFR-AK-CAZ-SC(4) 4,095.58 71.25 267.44 3,054.45 2,989.98 -547.50 -2,018.61 5,993,110.81 1,614,219.81 0.56 1,474.41 MWD+IFR-AK-CAZ-SC(4) 4,189.60 71.24 268.82 3,084.68 3,020.21 -550.41 -2,107.58 5,993,108.19 1,614,130.83 1.39 1,550.02 MWD+IFR-AK-CAZ-SC(4) 4,284.95 70.83 272.25 3,115.68 3,051.21 -549.57 -2,197.74 5,993,109.32 1,614,040.69 3.43 1,628.51 MWD+IFR-AK-CAZ-SC(4) 4,379.99 70.82 274.42 3,146.90 3,082.43 -544.35 -2,287.35 5,993,114.83 1,613,951.10 2.16 1,708.73 MWD+IFR-AK-CAZ-SC(4) 5/18/2016 2:25:49PM Page 3 COMPASS 5000.1 Build 74 • S Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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 4,475.99 71.00 276.75 3,178.30 3,113.83 -535.52 -2,377.63 5,993,123.95 1,613,860.86 2.30 1,791.33 MWD+IFR-AK-CAZ-SC(4) 4,569.76 70.86 278.22 3,208.94 3,144.47 -523.97 -2,465.49 5,993,135.78 1,613,773.04 1.49 1,873.19 MWD+IFR-AK-CAZ-SC(4) 4,664.17 70.90 278.35 3,239.86 3,175.39 -511.12 -2,553.77 5,993,148.92 1,613,684.82 0.14 1,956.07 MWD+IFR-AK-CAZ-SC(4) 4,758.70 70.82 278.05 3,270.85 3,206.38 -498.38 -2,642.16 5,993,161.94 1,613,596.48 0.31 2,038.98 MWD+IFR-AK-CAZ-SC(4) 4,854.00 71.06 278.05 3,301.97 3,237.50 -485.77 -2,731.34 5,993,174.84 1,613,507.34 0.25 2,122.53 MWD+IFR-AK-CAZ-SC(4) 4,949.17 70.49 274.73 3,333.32 3,268.85 -475.76 -2,820.63 5,993,185.13 1,613,418.09 3.35 2,204.86 MWD+IFR-AK-CAZ-SC(4) 5,044.63 69.76 272.14 3,365.78 3,301.31 -470.38 -2,910.24 5,993,190.80 1,613,328.52 2.66 2,285.15 MWD+IFR-AK-CAZ-SC(4) 5,139.58 70.32 270.52 3,398.19 3,333.72 -468.31 -2,999.45 5,993,193.16 1,613,239.32 1.71 2,363.45 MWD+IFR-AK-CAZ-SC(4) 5,234.59 70.70 271.23 3,429.89 3,365.42 -466.94 -3,089.01 5,993,194.82 1,613,149.78 0.81 2,441.69 MWD+IFR-AK-CAZ-SC(4) 5,329.35 70.55 271.26 3,461.33 3,396.86 -465.00 -3,178.38 5,993,197.05 1,613,060.42 0.16 2,520.06 MWD+IFR-AK-CAZ-SC(4) 5,424.73 70.62 271.38 3,493.03 3,428.56 -462.93 -3,268.31 5,993,199.41 1,612,970.50 0.14 2,598.98 MWD+IFR-AK-CAZ-SC(4) 5,518.76 70.74 272.53 3,524.14 3,459.67 -459.90 -3,356.99 5,993,202.73 1,612,881.84 1.16 2,677.29 MWD+IFR-AK-CAZ-SC(4) 5,613.80 70.91 274.72 3,555.36 3,490.89 -454.23 -3,446.58 5,993,208.69 1,612,792.29 2.18 2,757.71 MWD+IFR-AK-CAZ-SC(4) 5,709.25 70.77 275.06 3,586.69 3,522.22 -446.54 -3,536.41 5,993,216.67 1,612,702.49 0.37 2,839.35 MWD+IFR-AK-CAZ-SC(4) 5,803.68 71.42 276.33 3,617.29 3,552.82 -437.67 -3,625.30 5,993,225.82 1,612,613.63 1.45 2,920.77 MWD+IFR-AK-CAZ-SC(4) 5,898.66 71.16 276.02 3,647.75 3,583.28 -428.00 -3,714.74 5,993,235.79 1,612,524.24 0.41 3,003.06 MWD+IFR-AK-CAZ-SC(4) 5,993.14 71.20 274.44 3,678.23 3,613.76 -419.85 -3,803.79 5,993,244.22 1,612,435.22 1.58 3,084.26 MWD+IFR-AK-CAZ-SC(4) 6,087.84 71.20 272.30 3,708.76 3,644.29 -414.58 -3,893.28 5,993,249.78 1,612,345.76 2.14 3,164.39 MWD+IFR-AK-CAZ-SC(4) 6,182.85 71.21 270.75 3,739.37 3,674.90 -412.18 -3,983.19 5,993,252.47 1,612,255.87 1.54 3,243.45 MWD+IFR-AK-CAZ-SC(4) 6,275.83 71.13 269.99 3,769.38 3,704.91 -411.61 -4,071.19 5,993,253.32 1,612,167.88 0.78 3,319.95 MWD+IFR-AK-CAZ-SC(4) 6,371.66 71.29 270.41 3,800.25 3,735.78 -411.30 -4,161.91 5,993,253.93 1,612,077.16 0.45 3,398.67 MWD+IFR-AK-CAZ-SC(4) 6,466.55 71.33 271.65 3,830.65 3,766.18 -409.68 -4,251.78 5,993,255.84 1,611,987.31 1.24 3,477.31 MWD+IFR-AK-CAZ-SC(4) 6,561.96 71.11 272.03 3,861.37 3,796.90 -406.78 -4,342.06 5,993,259.03 1,611,897.04 0.44 3,556.95 MWD+IFR-AK-CAZ-SC(4) 6,656.74 70.63 272.92 3,892.43 3,827.96 -402.92 -4,431.53 5,993,263.18 1,611,807.61 1.02 3,636.36 MWD+IFR-AK-CAZ-SC(4) 6,751.86 70.79 275.10 3,923.86 3,859.39 -396.64 -4,521.08 5,993,269.75 1,611,718.08 2.17 3,717.05 MWD+IFR-AK-CAZ-SC(4) 6,846.30 70.64 275.03 3,955.05 3,890.58 -388.77 -4,609.87 5,993,277.91 1,611,629.32 0.17 3,797.88 MWD+IFR-AK-CAZ-SC(4) 6,941.56 70.78 275.11 3,986.52 3,922.05 -380.82 -4,699.43 5,993,286.14 1,611,539.80 0.17 3,879.42 MWD+IFR-AK-CAZ-SC(4) 7,036.80 70.65 274.58 4,017.97 3,953.50 -373.23 -4,789.01 5,993,294.02 1,611,450.26 0.54 3,960.79 MWD+IFR-AK-CAZ-SC(4) 7,131.87 70.62 274.00 4,049.50 3,985.03 -366.52 -4,878.45 5,993,301.02 1,611,360.85 0.58 4,041.60 MWD+IFR-AK-CAZ-SC(4) 7,227.79 70.66 272.91 4,081.30 4,016.83 -361.07 -4,968.78 5,993,306.77 1,611,270.55 1.07 4,122.55 MWD+IFR-AK-CAZ-SC(4) 7,321.63 70.56 271.95 4,112.45 4,047.98 -357.31 -5,057.21 5,993,310.80 1,611,182.13 0.97 4,201.02 MWD+IFR-AK-CAZ-SC(4) 7,416.79 70.71 271.17 4,144.00 4,079.53 -354.87 -5,146.95 5,993,313.54 1,611,092.41 0.79 4,279.96 MWD+IFR-AK-CAZ-SC(4) 7,511.28 71.19 273.55 4,174.85 4,110.38 -351.19 -5,236.19 5,993,317.51 1,611,003.20 2.43 4,359.08 MWD+IFR-AK-CAZ-SC(4) 7,606.03 70.67 270.52 4,205.81 4,141.34 -348.01 -5,325.67 5,993,320.98 1,610,913.74 3.07 4,438.16 MWD+IFR-AK-CAZ-SC(4) 7,700.90 70.59 270.00 4,237.28 4,172.81 -347.60 -5,415.17 5,993,321.67 1,610,824.25 0.52 4,515.87 MWD+IFR-AK-CAZ-SC(4) 7,795.43 70.73 269.86 4,268.58 4,204.11 -347.71 -5,504.36 5,993,321.85 1,610,735.06 0.20 4,593.06 MWD+IFR-AK-CAZ-SC(4) 7,890.97 70.59 268.49 4,300.23 4,235.76 -349.01 -5,594.50 5,993,320.85 1,610,644.93 1.36 4,670.47 MWD+IFR-AK-CAZ-SC(4) 7,984.52 70.75 268.16 4,331.19 4,266.72 -351.59 -5,682.74 5,993,318.55 1,610,556.69 0.37 4,745.60 MWD+IFR-AK-CAZ-SC(4) 8,080.59 70.72 269.74 4,362.89 4,298.42 -353.25 -5,773.41 5,993,317.18 1,610,466.02 1.55 4,823.29 MWD+IFR-AK-CAZ-SC(4) 8,175.09 70.75 271.26 4,394.07 4,329.60 -352.47 -5,862.61 5,993,318.25 1,610,376.84 1.52 4,900.93 MWD+IFR-AK-CAZ-SC(4) 5/18/2016 2:25:49PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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) (°/100') (ft) Survey Tool Name 8,270.04 70.71 272.08 4,425.41 4,360.94 -349.86 -5,952.20 5,993,321.15 1,610,287.26 0.82 4,979.83 MWD+IFR-AK-CAZ-SC(4) 8,364.63 70.81 272.09 4,456.58 4,392.11 -346.61 -6,041.45 5,993,324.69 1,610,198.03 0.11 5,058.74 MWD+IFR-AK-CAZ-SC(4) 8,459.74 70.65 271.45 4,487.97 4,423.50 -343.83 -6,131.19 5,993,327.75 1,610,108.31 0.66 5,137.85 MWD+IFR-AK-CAZ-SC(4) 8,555.14 70.66 271.45 4,519.57 4,455.10 -341.56 -6,221.17 5,993,330.32 1,610,018.35 0.01 5,216.91 MWD+IFR-AK-CAZ-SC(4) 8,649.44 70.59 271.53 4,550.85 4,486.38 -339.24 -6,310.10 5,993,332.92 1,609,929.43 0.11 5,295.09 MWD+IFR-AK-CAZ-SC(4) 8,744.05 70.70 276.35 4,582.22 4,517.75 -333.11 -6,399.12 5,993,339.34 1,609,840.44 4.81 5,375.25 MWD+IFR-AK-CAZ-SC(4) 8,839.16 70.61 278.37 4,613.73 4,549.26 -321.62 -6,488.12 5,993,351.12 1,609,751.49 2.01 5,458.06 MWD+IFR-AK-CAZ-SC(4) 8,932.66 70.17 281.43 4,645.12 4,580.65 -306.48 -6,574.87 5,993,366.54 1,609,664.80 3.12 5,540.76 MWD+IFR-AK-CAZ-SC(4) 9,027.50 70.33 283.65 4,677.17 4,612.70 -287.10 -6,661.99 5,993,386.20 1,609,577.75 2.21 5,625.91 MWD+IFR-AK-CAZ-SC(4) 9,122.23 71.49 287.78 4,708.16 4,643.69 -262.85 -6,748.14 5,993,410.73 1,609,491.69 4.30 5,712.64 MWD+IFR-AK-CAZ-SC(4) 9,217.00 71.59 290.87 4,738.18 4,673.71 -233.10 -6,832.96 5,993,440.74 1,609,406.97 3.09 5,800.96 MWD+IFR-AK-CAZ-SC(4) 9,311.55 71.83 292.95 4,767.85 4,703.38 -199.61 -6,916.24 5,993,474.51 1,609,323.81 2.10 5,889.84 MWD+IFR-AK-CAZ-SC(4) 9,406.26 72.11 295.12 4,797.17 4,732.70 -162.93 -6,998.48 5,993,511.45 1,609,241.69 2.20 5,979.40 MWD+IFR-AK-CAZ-SC(4) 9,500.93 72.19 296.80 4,826.19 4,761.72 -123.48 -7,079.50 5,993,551.15 1,609,160.81 1.69 6,069.29 MWD+IFR-AK-CAZ-SC(4) 9,596.30 72.38 298.95 4,855.21 4,790.74 -81.01 -7,159.80 5,993,593.88 1,609,080.66 2.16 6,160.07 MWD+IFR-AK-CAZ-SC(4) 9,690.94 73.21 300.98 4,883.21 4,818.74 -35.85 -7,238.12 5,993,639.28 1,609,002.50 2.23 6,250.46 MWD+IFR-AK-CAZ-SC(4) 9,787.00 74.40 304.74 4,910.01 4,845.54 14.19 -7,315.58 5,993,689.58 1,608,925.20 3.96 6,342.58 MWD+IFR-AK-CAZ-SC(4) 9,881.24 74.93 307.67 4,934.94 4,870.47 67.87 -7,388.91 5,993,743.49 1,608,852.06 3.05 6,432.92 MWD+IFR-AK-CAZ-SC(4) 9,975.99 75.70 312.50 4,958.97 4,894.50 126.88 -7,459.00 5,993,802.71 1,608,782.16 5.00 6,523.12 MWD+IFR-AK-CAZ-SC(4) 10,070.82 76.47 315.80 4,981.78 4,917.31 190.98 -7,525.03 5,993,867.03 1,608,716.34 3.47 6,612.36 MWD+IFR-AK-CAZ-SC(4) 10,165.41 77.27 321.75 5,003.29 4,938.82 260.24 -7,585.70 5,993,936.47 1,608,655.90 6.18 6,699.53 MWD+IFR-AK-CAZ-SC(4) 10,259.49 77.92 325.51 5,023.50 4,959.03 334.21 -7,640.18 5,994,010.61 1,608,601.67 3.96 6,783.69 MWD+IFR-AK-CAZ-SC(4) 10,355.16 78.25 327.70 5,043.26 4,978.79 412.36 -7,691.69 5,994,088.92 1,608,550.41 2.27 6,867.38 MWD+IFR-AK-CAZ-SC(4) 10,449.63 78.31 331.38 5,062.45 4,997.98 492.08 -7,738.58 5,994,168.78 1,608,503.79 3.81 6,947.84 MWD+IFR-AK-CAZSC(4) 10,544.42 78.00 333.79 5,081.91 5,017.44 574.43 -7,781.29 5,994,251.25 1,608,461.35 2.51 7,026.01 MWD+IFR-AK-CAZ-SC(4) 10,639.15 78.55 336.80 5,101.17 5,036.70 658.68 -7,820.05 5,994,335.63 1,608,422.87 3.16 7,101.70 MWD+IFR-AK-CAZ-SC(4) 10,732.50 79.64 339.93 5,118.83 5,054.36 743.87 -7,853.84 5,994,420.92 1,608,389.36 3.49 7,173.56 MWD+IFR-AK-CAZ-SC(4) 10,827.76 81.03 341.56 5,134.83 5,070.36 832.53 -7,884.80 5,994,509.66 1,608,358.69 2.23 7,244.70 MWD+IFR-AK-CAZ-SC(4) 10,922.04 82.89 343.19 5,148.01 5,083.54 921.49 -7,913.06 5,994,598.71 1,608,330.72 2.61 7,313.66 MWD+IFR-AK-CAZ-SC(4) 11,016.76 84.88 342.39 5,158.10 5,093.63 1,011.45 -7,940.93 5,994,688.75 1,608,303.15 2.26 7,382.77 MWD+IFR-AK-CAZ-SC(4) 11,082.00 85.74 341.68 5,163.44 5,098.97 1,073.30 -7,960.98 5,994,750.66 1,608,283.29 1.70 7,431.06 NOT an Actual Survey•(5) 7-5/8"x 9-7/8" 11,109.82 86.10 341.38 5,165.42 5,100.95 1,099.62 -7,969.77 5,994,777.00 1,608,274.59 1.70 7,451.83 MWD+IFR-AK-CAZ-SC(5) 11,158.87 86.15 342.34 5,168.73 5,104.26 1,146.12 -7,985.01 5,994,823.55 1,608,259.51 1.96 7,488.28 MWD+IFR-AK-CAZ-SC(5) 11,253.42 86.19 341.69 5,175.05 5,110.58 1,235.85 -8,014.14 5,994,913.37 1,608,230.67 0.69 7,558.37 MWD+IFR-AK-CAZ-SC(5) 11,347.88 86.26 340.94 5,181.27 5,116.80 1,325.14 -8,044.33 5,995,002.74 1,608,200.77 0.80 7,629.17 MWD+IFR-AK-CAZSC(5) 11,442.17 86.33 341.57 5,187.36 5,122.89 1,414.24 -8,074.57 5,995,091.93 1,608,170.82 0.67 7,699.90 MWD+IFR-AK-CAZ-SC(5) 11,537.40 86.22 340.20 5,193.55 5,129.08 1,504.03 -8,105.69 5,995,181.81 1,608,140.00 1.44 7,771.74 MWD+IFR-AK-CAZ-SC(5) 11,632.35 86.26 340.85 5,199.78 5,135.31 1,593.35 -8,137.27 5,995,271.23 1,608,108.70 0.68 7,843.76 MWD+IFR-AK-CAZ-SC(5) 11,726.27 86.19 341.85 5,205.96 5,141.49 1,682.15 -8,167.24 5,995,360.11 1,608,079.02 1.07 7,914.11 MWD+IFR-AK-CAZ-SC(5) 11,821.12 86.25 344.44 5,212.21 5,147.74 1,772.72 -8,194.68 5,995,450.76 1,608,051.88 2.73 7,983.16 MWD+IFR-AK-CAZ-SC(5) 5/18/2016 2:25:49PM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 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) (°l100') (ft) Survey Tool Name 11,916.54 88.13 345.23 5,216.89 5,152.42 1,864.70 -8,219.61 5,995,542.81 1,608,027.25 2.14 8,050.74 MWD+IFR-AK-CAZ-SC(5) 12,009.59 91.66 346.35 5,217.06 5,152.59 1,954.89 -8,242.45 5,995,633.06 1,608,004.71 3.98 8,115.61 MWD+IFR-AK-CAZ-SC(5) 12,104.20 91.09 346.29 5,214.79 5,150.32 2,046.78 -8,264.82 5,995,725.02 1,607,982.64 0.61 8,180.94 MWD+IFR-AK-CAZSC(5) 12,199.28 90.51 345.97 5,213.46 5,148.99 2,139.08 -8,287.61 5,995,817.39 1,607,960.15 0.70 8,246.82 MWD+IFR-AK-CAZ-SC(5) 12,292.55 88.93 346.23 5,213.92 5,149.45 2,229.62 -8,310.01 5,995,907.98 1,607,938.04 1.72 8,311.49 MWD+I FR-AK-CAZ-SC(5) 12,387.28 88.35 345.95 5,216.17 5,151.70 2,321.54 -8,332.78 5,995,999.97 1,607,915.57 0.68 8,377.17 MWD+I F R-AK-CAZ-SC(5) 12,482.45 88.83 346.12 5,218.51 5,154.04 2,413.87 -8,355.74 5,996,092.37 1,607,892.91 0.54 8,443.22 MWD+IFR-AK-CAZ-SC(5) 12,576.92 89.45 345.45 5,219.93 5,155.46 2,505.44 -8,378.94 5,996,184.00 1,607,870.01 0.97 8,509.09 MWD+IFR-AK-CAZ-SC(5) 12,672.07 90.82 344.10 5,219.70 5,155.23 2,597.24 -8,403.92 5,996,275.88 1,607,845.33 2.02 8,576.63 MWD+1FR-AK-CAZ-SC(5) 12,767.60 91.37 343.45 5,217.88 5,153.41 2,688.95 -8,430.61 5,996,367.66 1,607,818.94 0.89 8,645.60 MWD+1FR-AK-CAZ-SC(5) 12,863.10 92.37 342.08 5,214.76 5,150.29 2,780.11 -8,458.89 5,996,458.90 1,607,790.96 1.78 8,715.67 MWD+IFR-AK-CAZ-SC(5) 12,957.94 92.33 340.82 5,210.87 5,146.40 2,869.95 -8,489.03 5,996,548.83 1,607,761.11 1.33 8,786.69 MWD+1FR-AK-CAZ-SC(5) 13,053.00 91.85 341.01 5,207.41 5,142.94 2,959.72 -8,520.09 5,996,638.69 1,607,730.34 0.54 8,858.48 MWD+IFR-AK-CAZ-SC(5) 13,147.27 91.44 344.01 5,204.70 5,140.23 3,049.59 -8,548.41 5,996,728.64 1,607,702.32 3.21 8,927.93 MWD+1FR-AK-CAZ-SC(5) 13,241.79 91.50 347.56 5,202.27 5,137.80 3,141.17 -8,571.61 5,996,820.28 1,607,679.42 3.76 8,993.82 MWD+IFR-AK-CAZ-SC(5) 13,335.69 91.31 352.69 5,199.97 5,135.50 3,233.62 -8,587.70 5,996,912.78 1,607,663.62 5.47 9,053.98 MWD+IFR-AK-CAZ-SC(5) 13,431.04 90.61 351.25 5,198.37 5,133.90 3,328.02 -8,601.02 5,997,007.21 1,607,650.61 1.68 9,112.71 MWD+IFR-AK-CAZ-SC(5) 13,480.88 90.27 347.86 5,197.99 5,133.52 3,377.02 -8,610.06 5,997,056.24 1,607,641.74 6.84 9,145.04 MWD+IFR-AK-CAZ-SC(5) 13,524.82 90.52 345.18 5,197.69 5,133.22 3,419.75 -8,620.30 5,997,098.99 1,607,631.64 6.13 9,175.27 MWD+IFR-AK-CAZ-SC(5) 13,571.44 90.44 345.00 5,197.30 5,132.83 3,464.80 -8,632.29 5,997,144.07 1,607,619.79 0.42 9,208.18 MWD+IFR-AK-CAZ-SC(5) 13,620.52 90.54 345.19 5,196.88 5,132.41 3,512.22 -8,644.92 5,997,191.54 1,607,607.32 0.44 9,242.83 MWD+IFR-AK-CAZ-SC(5) 13,715.71 90.37 345.10 5,196.12 5,131.65 3,604.23 -8,669.32 5,997,283.61 1,607,583.21 0.20 9,309.96 MWD+I FR-AK-CAZ-SC(5) 13,810.78 89.89 343.80 5,195.91 5,131.44 3,695.82 -8,694.80 5,997,375.27 1,607,558.03 1.46 9,377.83 MW D+I FR-AK-CAZ-SC(5) 13,905.45 89.48 344.74 5,196.43 5,131.96 3,786.94 -8,720.47 5,997,466.47 1,607,532.66 1.08 9,445.62 MW D+I FR-AK-CAZ-SC(5) 14,000.15 89.11 346.77 5,197.59 5,133.12 3,878.71 -8,743.77 5,997,558.31 1,607,509.66 2.18 9,511.68 MW D+I FR-AK-CAZ-SC(5) 14,094.72 89.11 347.51 5,199.06 5,134.59 3,970.90 -8,764.81 5,997,650.55 1,607,488.91 0.78 9,576.00 MWD+IFR-AK-CAZ-SC(5) 14,189.55 89.11 347.49 5,200.53 5,136.06 4,063.47 -8,785.34 5,997,743.18 1,607,468.69 0.02 9,640.06 MWD+1FR-AK-CAZ-SC(5) 14,282.53 88.63 346.56 5,202.37 5,137.90 4,154.06 -8,806.21 5,997,833.83 1,607,448.12 1.13 9,703.43 MWD+IFR-AK-CAZ-SC(5) 14,379.24 88.49 346.32 5,204.80 5,140.33 4,248.04 -8,828.88 5,997,927.88 1,607,425.76 0.29 9,770.05 MWD+IFR-AK-CAZ-SC(5) 14,474.34 88.66 346.16 5,207.16 5,142.69 4,340.38 -8,851.49 5,998,020.28 1,607,403.44 0.25 9,835.81 MWD+IFR-AK-CAZ-SC(5) 14,569.44 88.59 344.80 5,209.44 5,144.97 4,432.42 -8,875.33 5,998,112.38 1,607,379.91 1.43 9,902.47 MW D+I FR-AK-CAZ-SC(5) 14,664.18 88.56 343.28 5,211.80 5,147.33 4,523.48 -8,901.37 5,998,203.51 1,607,354.16 1.60 9,970.55 MWD+IFR-AK-CAZ-SC(5) 14,759.20 88.56 342.53 5,214.19 5,149.72 4,614.27 -8,929.29 5,998,294.39 1,607,326.54 0.79 10,040.13 MWD+IFR-AK-CAZ-SC(5) 14,852.90 89.62 341.39 5,215.68 5,151.21 4,703.35 -8,958.30 5,998,383.55 1,607,297.82 1.66 10,109.79 MWD+1FR-AK-CAZ-SC(5) 14,948.19 91.70 342.84 5,214.58 5,150.11 4,794.02 -8,987.56 5,998,474.31 1,607,268.85 2.66 10,180.47 MWD+1FR-AK-CAZ-SC(5) 15,041.66 91.57 344.04 5,211.91 5,147.44 4,883.57 -9,014.19 5,998,563.94 1,607,242.51 1.29 10,248.31 MW D+I FR-AK-CAZ-SC(5) 15,135.52 91.71 346.00 5,209.23 5,144.76 4,974.20 -9,038.44 5,998,654.64 1,607,218.56 2.09 10,314.62 MW D+I FR-AK-CAZ-SC(5) 15,231.50 91.23 349.03 5,206.76 5,142.29 5,067.87 -9,059.18 5,998,748.36 1,607,198.13 3.20 10,379.42 MWD+IFR-AK-CAZ-SC(5) 15,324.17 91.03 350.23 5,204.93 5,140.46 5,159.01 -9,075.86 5,998,839.54 1,607,181.74 1.31 10,439.43 MWD+IFR-AK-CAZ-SC(5) 15,419.06 91.03 348.35 5,203.23 5,138.76 5,252.23 -9,093.49 5,998,932.81 1,607,164.42 1.98 10,501.31 MWD+IFR-AK-CAZ-SC(5) 5/18/2016 2:25:49PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-613 Project: Kuparuk River Unit TVD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-613 actual @ 64.47usft(Doyon 142) Well: 3S-613 North Reference: True Wellbore: 3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 15,513.24 91.13 347.06 5,201.45 5,136.98 5,344.23 -9,113.54 5,999,024.87 1,607,144.67 1.37 10,564.67 MWD+IFR-AK-CAZ-SC(5) 15,608.72 90.96 344.71 5,199.71 5,135.24 5,436.80 -9,136.82 5,999,117.51 1,607,121.69 2.47 10,631.12 MWD+IFR-AK-CAZ-SC(5) 15,702.97 91.13 342.62 5,197.99 5,133.52 5,527.23 -9,163.32 5,999,208.01 1,607,095.48 2.22 10,699.28 MWD+IFR-AK-CAZ-SC(5) 15,782.00 91.13 342.62 5,196.43 5,131.96 5,602.64 -9,186.92 5,999,283.48 1,607,072.13 0.00 10,757.43 PROJECTED to TD Projection to TD NOT an Actual Survey Final Definitive Survey Verified and Signed-off AN targets and/or well position objectives have been achieved. 0 Yes ❑ No f have checked to the best of my ability that the following data is correct: 0 Surface Coordinates O Dec inatiion & Convergence Q GRS Survey Corrections L] Survey Tool Codes SLB DE: G9tsty59000 o Scott u0'0 Client Representative. Scott Brunswick Date 19-May-2016 5/18/2016 2:25:49PM Page 7 COMPASS 5000.1 Build 74 Z1 6020 Rif"LIVED 0 27 223 MAY 31 201Ei S cblomherer OGCC Transmittal#: 31 MAY16-SP02 g Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery GM. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 3S-613 T.O.C. Date Dispatched: 31-May-16 Job#: 14AKA0119 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 6095' - 11300' MD x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A Nad27 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 Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(c�conocophillips.com AlaskaPTSPrintCenter(W,slb.com Tom Osterkamp Attn:Stephanie Pacillo 907-263-4795 p„),,,,Aasz.a..7/7) '`/Received By: Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Friday, May 13,2016 1:00 PM To: Loepp,Victoria T(DOA) Cc: Quick, Michael J (DOA); Bettis, Patricia K(DOA); Kanady, Randall B Subject: RE: [EXTERNAL]RE:35-613 Sundry 316-254(CBL) (PTD 216-020) Follow Up Flag: Follow up Flag Status: Flagged The K-3 top is correct on the schematic provided with the Sundry. The proposed TOC on the schematic in the sundry is also accurate to what we were targeting. Problem is with the excess we pumped on the job,the hole must have been more in gauge,therefore,based on logging from the calculated TOC with 40%excess,the cement has been pushed even higher than the calculated depth. We started logging at calculated TOC. From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, May 13,2016 10:01 AM To: Brunswick,Scott A<Scott.A.Brunswick@conocophillips.com> Cc:Quick, Michael J (DOA)<michael.quick@alaska.gov>; Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: [EXTERNAL]RE: 3S-613 Sundry 316-254(CBL) (PTD 216-020) Scott, Please provide an interpretation of this log including TOC, feet of cement summary by depth. Location of K-3; feet of cement above K-3. Thanx in advance, 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.LoepoAalaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov From: Loepp, Victoria T(DOA) Sent: Friday, May 13, 2016 9:38 AM To: 'Brunswick, Scott A' Cc: Quick, Michael 3 (DOA) Subject: RE: [EXTERNAL]RE: 3S-613 Sundry 316-254(CBL) (PTD 216-020) 1 • • Scott, I received the log. Do you have a summary of the cement job? An updated schematic? Thanx, Victoria From: Brunswick, Scott A [mailto:Scott.A.Bru nswick@conocophillips.com] Sent: Friday, May 13, 2016 9:21 AM To: Loepp, Victoria T(DOA) Subject: FW: [EXTERNAL]RE: 3S-613 Sundry 316-254(CBL) (PTD 216-020) Sent with Good(www.good.com) From: Brunswick,Scott A Sent: Friday, May 13,2016 12:19:13 PM To:Victoria L Ferguson Subject: FW: [EXTERNAL]RE:3S-613 Sundry 316-254(CBL) (PTD 216-020) Let me know if this gets through. Sent with Good(www.good.com) From: Erik Sterk<ESterk@slb.com> Sent:Friday, May 13,2016 12:13:22 PM To: Brunswick,Scott A Subject: RE: [EXTERNAL]RE: 3S-613 Sundry 316-254(CBL) (PTD 216-020) Try this file....we just might make it with 10mb Erik Sterk—Dual Services Manager Schlumberger North America Offshore AKA Drilling& Measurements Office: 907-273-1789 Mob: 617-417-8069 From: Brunswick,Scott A[mailto:Scott.A.Brunswick@conocophillips.com] Sent: Friday, May 13,2016 9:08 AM To: Erik Sterk<ESterk@slb.com> Subject: [Ext] FW: [EXTERNAL]RE:3S-613 Sundry 316-254(CBL) (PTD 216-020) Sent with Good(www.good.com) 2 • . From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Friday, May 13,2016 11:25:27 AM To: Brunswick,Scott A Subject: [EXTERNAL]RE:35-613 Sundry 316-254(CBL) (PTD 216-020) Yes, please send it over- From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Friday, May 13, 2016 7:24 AM To: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Subject: RE: 3S-613 Sundry 316-254 (CBL) (PTD 216-020) This is not working right,the original file is too large to e-mail. I tried printing to pdf again, but it made the graphics terrible. I don't have a log printer,so I'll probably print to normal paper and have Ann bring it over this morning. Is that oK? From: Brunswick,Scott A Sent: Friday, May 13, 2016 7:22 AM To: Loepp,Victoria T(DOA)(victoria.loepp@alaska.gov)<victoria.loepp@alaska.gov>; 'Schwartz,Guy L(DOA)' <guy.schwartz@alaska.gov> Subject:3S-613 Sundry 316-254(CBL)(PTD 216-020) Victoria Please find attached the cement bond log of 3S-613 intermediate casing. The sundry notes stated to send this before running liner,we are ready to run liner this morning, may we proceed? Thanks Scott 3 AAvs-mil r. usLU.rTIIIIrAMAW,11a. 0 Cn m * nCn Vial: 13 ODmm8 F �I1012 C __1 r r- STATE Alaska -z-ImDrDurm ccum _ 0 ■ r ,.--, d Laa, m ■�� z , cn a a ri 7,C D- g -I Ccwomil (D � � o� O CD ycn � � = n4.,::' th Ci' = wo V t 0 (0 Min CID ail _...,, rri Al win cn INO1( :)' ei) 'xi cn 7 o c -o -. `� -h cno mom 0 et n .13 m o CD Z0 = 2 o F.__. p Vf N „:, e mx � i— :n o 3 n � Aga CA ZCA .. CD CA v grog. FOLD HERE: the well ria re,locaticn ad baehde reference data were finished by the asters. Any ice,research,aelysis,data,resits,estimates,a recarmendaticn finished with the say ices a clhe mise axrrnnicated by Schkrrtergiar b the astcrner at any time in connection with the services ae opines based on inferences from neasuerrsrt,emitted rdatiarships,au/cr asstrrpfiais;which,inferences,errpirica) rddicnships attar assurpials ae rbt infallible aid with respect b which bcfessiaxis in the industry may direr.AccadrxcJy,Schkrrberger rand axi does not warant the aoaaacy,carectress,or completeness day such iriarpetaticn,research,analysis,data,resits,estirrates,a necornrrerxlaticn the c starer advrarvl edges that it is accepting the services"as is,"that ScHurterger makes no representation a warranty,express a irrdie ,cf any kind a desaiption in respect the aid that such services ae delivered with the explicit inderstrxirg axt agreerreri that any action taken based an the services received std beat its oNn risk aid responsibility,ad ro dam shah be made against ScHurt ager as a corsepace thereof. vc.Order#: OP Vers: Processed by: Process Date: May. 13 2016 ocation: Techlog Vers: 2015.3 e-mai:jburt2@slb.com Remarks: Pro,sing parameters summar ii Casing Amplitude#1 Casing shoe depth:11082 ft Casing inner diameter:6.875 in Casing outer diameter:7.625 in Filter length:17 Filter band high:16000.0 Hz Filter band low:10000.0 Hz Peak detection mode:Peak-to-Peak Time window start:400.0 us Time window stop:600.0 us Waveform monopole high frequency:WFA_MHTDepth sampling rate:0.166667 ft Source frequency:Monopole wideband Waveform step:20 us Waveform start:0.0 us OCDd. 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H . 1 ' it 1 j '. t 111111— 1 " 4 4 4 I i 4. 4 li 4 .or - - IIIIIR Ili I 1 I,c I I I , 1 IIP ! 11050 II , , 11075 ill , MEI ' ; , - gig, .I? 1 , i , t , , , , .., , •' / it,,• in 1 ,, , f`fi I 1 ' 1 ' IIIII 1 1 1 j j 41;44 ; 1 I 41 11100 A 44":' 4. , • i kki . . A '1„.1t,44.%, I, 1„,,,,,i ,., ' S' , ' I) i , I , , , I(' 1 imt . 1 i 1(f', i i;.J.t tt ' 111.1. Isk, I 1 tk.‘,1,1 , ill 1 11125 , ; 1 ! 4 i , , 1 ; ! , . ; 1 , ; 1 ; 1 / I I PI ,11 1 ,. 114' I I I 1 1 1 t 4 11150 i 11 I I MUNI 41 - 1 ' , 1 , MEIN ' 11175 it i I • i 1 . 1 1 I I i , • , , !ai 1 I I 0 1 4 1 1 il ; 1 I I 1 ? , i , Company: ConocoPhillips Alaska, Inc: Field: Kuparuk FWell ield:3S-613 Schiumberger State: Alaska API: 50-103-88212-00-00 • e �w\�\\I yy's . THE STATE Alaska Oil and Gas p`9 9 ofALAs Conservation Commission jtritt=7,74:5. l 333 West Seventh Avenue "1Anchorage,GOVERNOR BILL WALKER Alaska 99501-3572 Wim .\n4 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kupark River Field, Torok Undefined Oil Pool, KRU 3S-613 Permit to Drill Number: 216-020 Sundry Number: 316-254 Dear Mr. Alvord: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster {�,, Chair DATED this (o day of May, 2016. RBDMS uu MAY 1 0 2016 • 0 'RECEIVED STATE OF ALASKA MAY 0 2 2016 . ALASKA OIL AND GAS CONSERVATION COMMISSION 5/i, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate El Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Q Plug for Redrill El Perforate New Pool El Re-enter Susp Well El Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 216-020 3.Address: 6.API Number: Stratigraphic ❑ Service 2 P.O.Box 100360 Anchorage,AK 99510-0360 50-103-20735-00-00 • 7. If perforating: ,�.(1) 8.Well Name and Number: KRU 3S-613 What Regulation or Conservation Order governs well spacing in this pool? N k Will planned perforations require a spacing exception? Yes El No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): Kuparuk River Field, Torok Undefined Oil Pool + ADL 25528, 25544, 380107 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): Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 120 120 Surface 2862 10.75 2901 2572 Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Proposal Summary Li Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., 14.Estimated Date for 5/2/2016 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ E WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 4/29/2016 GAS El WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Victoria Loepp GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved Scott Brunswick 263-4249 ��� herein will not be deviated from without prior written approval. Contact �'2 Email scott.a.brunswickcop.com Printed Name Graham(Chip)Alvord Title Alaska Drilling Manager =t: _ C4 a-r� 570—(t t t Signature / Phone 265-6120 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: kLt— 2 .q Plug Integrity ❑ BOP Test ❑---- Mechanical Integrity Test ❑ Location Clearance ❑ Other: $UP tf 5 t vj--t /y 3S-G!> 51 CVrYw . -4,-)-11`c Cfstil w1 oCzCG /�re-55 fa y 1)v-lb r-fv rvvi n j vt, N briA.,v)tell.oma, A4Lj2vlaV pYrvz- r te5-f LSGt p 51 Af o 11,- /C C t'd o ft. GVH 'hi g✓-f /t,-1 II'C C/f pj o a^ci r fop �-. Post Initial Injection MIT Req'd? Yes [5---No ❑ 4 Wa Wet- J3 9rq" favi R/ta w pCGIc *J be pI4Grd � ( 7. o Do LtD Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0— 4 d aha Vd p cf (2c 4...4.c 2S,4rzr ) APPROVED BY RBDMS 0- MAY 1 0 2016 Approved by: P j /� COMMISSIONER THE COMMISSION Date: ,5- 6, / FR4 r ( A' A Submit Fa and Form 10-403 evised 11/2015 c a�p fc�rti�n lid for 12 mons fro tate of approval. Attachments in Duplicate V'TL </51<6 17 ''GAJ IY(7o 76- • • Post Office Box 100360 Conoc l'i Anchorage,Alaska 99510-0360 Phone(907)263-4297 Email: steve.shultz(&contractor.conocophillips.com May 2,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for change to approved Permit to Drill 3S-613(PTD 216-020) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a change to the approved Permit to Drill 216-020 of the onshore production well slot 3S-613 from the 3S drill site. This well is intended to be an injection well in the Moraine horizon in support for the 3S-620 well drilled last year. The Moraine formation was penetrated on April 29,2016 on 3S-613(PTD 216-020). While drilling with a 9.2 ppg mud due to predicted low formation pressure,with 10.5 ppg ECD at 11020' MD, dynamic losses of 40 bbl/hr were encountered. A LCM pill was pumped reducing the losses to 20 bbl/hr. TD was called at 11090' MD to set casing into the Moraine formation. While circulating the hole clean for the trip out of the hole,the dynamic losses went to zero with wall cake&LCM treatments. The purpose of this sundry is to change from a single stage cement job to a two stage job to ensure good cement in the 7-5/8"OA as per the original plan. The initial plan was a single 4300'column of cement to place cement top at least 500'above the K-3 formation. After seeing the losses, and based on updated cement modelling using what has been observed,the best path forward is to pump a two stage job covering the loss zone,followed by the second stage placing cement from the top of the first stage to the original proposed cement top. The 1st stage would be+/-790' in length,followed by+/-3500'ft, basically not changing the coverage from the original PTD,just how the cement is placed and do the best to make sure the lift needed to achieve proper top of cement. No changes to the completions design will be needed. Please find attached the information required by 20 ACC 25.005(a)and(c)for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 Sundry APPLICATION FOR change to approved drilling program 2. A proposed cement program 3. Proposed Completion Diagram Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Steve Shultz at 263-4297. Sincerely, cott Brunswick Drilling Engineer Nikon for Permit to Drill,Well 3S-613 Saved: 2-May-16 1. Updated Proposed Intermediate Cement Program The proposed cement program is listed below. 1. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe, change out one set of pipe rams on the BOPE to rams for 7 5/8" casing. 2. RU and run 7-5/8", 29.7#, L-80 Hydril 563 connections on the intermediate casing to 11,082.25' MD (with WTF 2nd stage cement tool +/-790' from shoe) and cement in place with a minimum of 500' of cement above the K-3 formation (TOC @ >6767'MD). K-3 top at 7267' MD. a. Due to observed losses encountered when drilling into the Moraine, change the plan to perform a 2 stage cement job. b. Pump 1st stage cement from shoe to stage tool (-793' column of cement) c. Pressure up to 3000 psi & open stage cement tool d. Circulate cement in OA from stage tool to surface e. Pump 2nd stage cement from stage tool to 500' above the K-3 formation f. Close stage tool 3. MU 63/" bit and RIH on 4" drill pipe 4. Pressure test 7 5/8" casing above stage tool to 3000 psi for 10 minutes 5. Drill out stage tool 6. Pressure test 7 5/8" casing to 3000 psi for 30 minutes, drill out and perform FIT to 16.0 ppg MWE with a minimum of 10.2 ppf MWE. 7. Return to original approved PTD 216-020 A-U&-e CvvI 6 Re /r 1- 5 `7S of Sdn cC/ p 41"-- 1.1 4 41 7 3S-613 APD Page 1 of 14 Printed:2-May-16 • 0 Grass Roots Horizontal Multi-Stage Frac'd injector ConocoPhillips Proposed Wellbore Schematic FMC 4-%"tree,top joint is 4-W 12.6#IBTM,crossed over(for fracequip nt I l New Existing Conductor: 16"62.6#HW@ 120 Spud Mud 2 PPG 5111, 13-1/2"Surface Hole F 4'/,"x1"KBMG : J . with Dummy(-2,500'TVD;54 deg inch . Surface Casing: 10-3/4"45.5#L-80 Hydril 563 2,901'MD/2,572'TVD @ ll 56° Campanian:Top.3;381 MD(2,7 t,; 9-7/8"Intermediate Tubing 'sole . 4-%" 12.6#L-80 Hydriol 563 ;ND Planned top o;.. ;A,.ya..en,o- cr PPG above 6,767'MD ep up with (a minimum of 500'MD above the K-3) 4Wx1"KBMG TVD with SOV(-4,500 ND;70 deg 001 el K-3(Coyote)Top 7267'MD/4093' D Intcmiadiate C st na ,, ..: ttilbt Cameo DB Nipple 3.812"nogo 1 M 7-5/8"29.7#L-80-all Hydril 563 connections SLB GaugeCarrier - 11,082.25 MD/5,16T TVD @ 90° Cameo DB Nipple 3.75"nogo WTF 2n°stage cea1er16ei 10288' HRD-E ZXP WitD's 5/,"x7%"480 for 29.79 csg 5-112"178 MD Hyctil 563 pin down(Baker);RS Nipple 7.63"L-80 5-112"179 1"Stage Cement top-10291'MD Hyd 563(Baker,;Flex-Lock 57:"x 7G"L-80,Flex Lock Hanger r 7 HYD 563 pin by pin(Baker);Baker 8047 Sealbore Extension 20ft,5/,"178 HYD 563 box x pin;(DEPTH:Approx.10,900'MD) s'. . i'+Si4" SFclritOEi jiiiiurhioraaie'11:Q�zA":00. ia2. 1.i:: : i :] : kxtFrac#!Oit. . . . :� :A�pebi�:FiopZ11::: :�-:i::=::::Hr�fe.; : : i:: =;i : : i:i::= : :: :::::::::::: ..::::.tir: ooD S::;:::Sev4n 4;7±.:8w69:F'*0kNiEi 4 i i31!Iu B t. : : ::: : • 0 Grass Roots Horizontal Multi-Stage Frac'd injector Proposed Wellbore Schematic ConocoPhillips FMC 4-%"tree,top joint is 4-W 12.6#IBTM,crossed over(for frac equip nt New Existing Conductor: Spud4 Mud 16"62.6#HW @ 120 1„KamG --:. 9.2 PPG with Dummy(-2,500'TVD;54 deg incl) 1 j a-I ' Surface Casino: 10-3/4"45.5#L-80 Hydril 56a13 "Surface Hole - 2,901' MD/2,572'TVD, 'gf 56° I- -1/2 6 ,_)-- 0' 6'\C2 ....„. .. ..• •. _. .. 'CampaniarrTop 338.1'MD J2,746 . . . . NE • • a • AR 0 . . . . 9-7/8" Intermediate Hole Tubina: 4-Y2" 12.6#L-80 Hydriol 563 LSND Planned top of 2"sta e cement 9.2 PPG above 6,767 MD (a minimum of 5007M0 above the Keep up with K-3) Dilution 4W'x 1"KBMG TVD with SOV(-4,500 ND;70 deg ncl ... _ _ _ , ... K-3(€oyote)Top.72674v16/4093 p ? • - - - - 1 interMcdite Ca'sinu Set'in the-Moraine.- - Camco DB Nipple 3.812"nogo mg 7-5/8"29.7#L-80-all Hydril 563 connections SLB Gauge Carrier -Ka 11,082.25' MD/5,167'TVD @ 90° Camco DB Nipple 3.75"nogo ail . 1-1111,24D-E ZiXPW/HD's.5 A"x7%"L-80 for 29.7#csg 5- WTF 2"'stage ceNin@ 10288' '17 Hydril 663 pm down(Baker);RS Nipple g 7.63"L-80 5-1/2 17#Hyd 563(Baker);Flex-Lock MD " /102-° X 5'/"x 7%"L-80,Flex Lock Hanger HYD 563 iii .1'Stage Cement top-10291'MD ,-,••z1 F,F.1 ,- , ,,•, - ,,• . i i' x ension 20ft, 1 —,,,,,,, , 01, s„,",7#HYD 563 box x pin; ',' 1 '' liq - ,7 eip-tvl - e l,r(2A ''''/:).7 i ' -: ,•• .,:: ":: :::i:,-ii :,: ::,. :: ]':iH ; iiH::',.'' iHJ :.:•' I i ' L, 4oi4i'l P00400197ri,,i iOt.::niti' 1 '°2;r!16 .1116 m'.ii,b*•:4:ki:.!ii,o;*v::i::!:-:i.i::,j.]-],.-.7.1.,,.iii•:e.:::.•••:••:...i•.:•.ii:.:i ik ,: ti4i * v?:0ii:Oi0io: 1!:::..]•Wi:.::]•:i::i•.::,i *.::i:H.H:.i:.8:i.tri•:A.•..0 . iStages. i:•,,...,,i•;',.ii:;'.:Hi:i..:.i.Hi.i.i,.;.i:.H.H,i, ... • •....... 1i11 NI 1111 1111_4 . •11. pp.G:::::::::::::::::::::::::::::::::.:::::::.:.:.:.:.: Form)---ii:iiii::::::::.:. o o o o o : •;iii HH!HH;10::i*iii:':•:iiiiii.30t :,-- .''•-':••'••• •''-• ::....... . l-:.:18.6..o.f.i. : ..: : : : '....,...,040. iwi• ,:@ 9o94-1:Hi2'H!1-:26-::#fErtvi ......-----i , '' .::''':''''''''':•:•:•.:-'•••••••••-•:**'''.---------:•:::—.:::-.-..":-. 1-0$9.:MD!:5 WD 15,7B2':TCYMD! ,217'217:: :i .. •••••.•• ..•••••••••••••••••••.•••••••••••••••••••••••••••••••••••••••••••••••••-••••• . • •• . .,174' - ..--••..•.•••••• •.:.:.:..........••••••:.„. ::t:: ii: ::H :,.'i]: :• ii;;iii.i.iiiii:iii .,.:.:.iii:::•ii:,i1:::•:.i:.:.:.]iii] iiHiii.] : ::::H:]:::::::::::::::::::::::.:::::.:::.]. .. . ••.- .. . .•• • .............. .. ...... .:: - • • Schlumberger CemCAD Ewell cementing recommendation for 7 5/8" Intermediate STAGE 1 Operator : CPAI Well : 3S-613,injector Country : USA Field : Moraine State : Alaska Prepared for : Brunswick,Scott Location : Doyon 142 Proposal No. : initial-6 Service Point : Prudhoe Bay,AK Date Prepared : 4.29.16 Business Phone : 907.659.2434 Prepared by : Britton Schlotz Phone : 907.265.1463 E-Mail Address : bschlotz©slb.com 44, C7 fi 1610 4GATE Disclaimer Notice: Schlumberger submits this document with the benefit of its Judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates bawd en provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTNENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. *Mark of Schlumberger Page 1 3s-613 cement vt.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector $chlumhergOr String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Section 1 : Well Description Configuration : Casing Stage : 1st of 2 Rig Type : Land Mud Line : 0.0 ft Total MD : 11090.0 ft BHST : 129degF Bit Size : 9 7/8 in ft !big al < - - > ,, . . . . 8 12 16 — r'=c I I . . . . . ——.Pore _ • • • • • uer-afrost I_ O r I .=- - . . . . . lila Cc.' - •`1- I . . . • • T I . . . . . Ca'�,zanian 1 .= - C_3�� I p =- I .J - ions zone ' J _ • • • • • I '_ . 4 Q 4,1 'a'','ell Litliolog_,,• 0I r71dtion cress Page 2 3s-613 cement vi.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schlu her cr String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2897.0 10 3/4 45.5 9.950 1st Stage Collar : 10292.0 ft Landing Collar MD : 10992.0 ft Casing/liner Shoe MD : 11082.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 11082.0 7 5/8 40.0 29.7 6.875 L-80 4310 5900 Hydril 563 Mean OH Diameter : 9.875 in Mean Annular Excess : 40.0 % Mean OH Equivalent Diameter: 10.642 in Total OH Volume : 901.3 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diem. (ft) (in) (%) (in) 10292.0 9.875 40.0 10.643 11082.0 9.875 40.0 10.643 11090.0 9.875 0.0 9.875 Max. Deviation Angle : 85 deg Max. DLS : 6.7076 deg/100ft Refer to Appendix 9 for complete directional survey Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1612.0 13.50 8.60 permafrost Sandstone 3072.0 13.50 8.60 n/a Sandstone 5100.0 13.50 8.60 Campanian Sandstone 7267.0 13.50 8.60 C-50 Sandstone 7632.0 13.50 8.60 K-3 Sandstone 11020.0 13.50 8.60 loss zone Sandstone 11090.0 10.20 8.60 TD Sandstone Page 3 3s-613 cement v1.cfw;04-29-2016; LaadCase int stage 1;Version wcs-cem476_02 • 0 Client : CPAI Well : 3S-613,injector SChillm holler String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1612.0 1576.1 32 0.8 11090.0 5172.1 129 2.1 ft dera= (x 10001 ft co_ 0 nrl 100 150 a 2. 6 9 -—Ge:,,-.=--- e I I -i-: .c=_='t. l ; L § 71.11. cp_,t arc° € , 1,-..) r 44 _.1 t '._,. s . ..... N +=— 1 i CI 0 CI Cri ti +— m ,. ... ma [II ,y ._ ... . E r ' - 7W_ _ €,_ , O .-, - in.€ 6 + I I 1 Temperature Hori- Departure Page 4 3s-613 cement vi.cfw:04-29-2016; LoadCase int stage 1:Version wcs-cem476_02 • S Client : CPAI Well : 3S-613,injector Schlumberger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Section 2: Fluid Descriptions LSND mud DESIGN Fluid No: 1 Density : 9.20 lb/gal Rheo. Model : HERSCHEL_B. k : 1.44E-2 Ibf.s^n/ft2 At temp. : 80 degF n : 0.446 Tv : 4.36 lbf/100ft2 Gel Strength : 8.54 Ibf/100ft2 MUD Mud Type :WBM Job volume :494.7 bbl Water Type : Fresh VOLUME FRACTION Solids : 10.0% Oil : 3.0% Water : 87.0% Rheometric Measurements Rheometer type : 35 (rpm) At 80 degF Geometry : R1B1 (deg) Spring No : 1.0 600 35.0 300 27.0 200 23.0 100 18.0 6 8.0 3 7.0 Viscosity: (cP) 10 sec Gel Strength 7.47 Ibf/100ft2 10 min Gel Strength 8.54 Ibf/100ft2 Anticipated mud properties. MUDPUSH II DESIGN Fluid No:2 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.81E-2 Ibf.s^n/ft2 At temp. : 65 degF n : 0.485 Tv : 12.86 lbf/100ft2 Gel Strength :22.63 Ibf/100ft2 SPACER Spacer Type : MUDPUSH II Porosity : 84.0% Solid Fraction : 16.0% Mud Type :WBM Mix Water/Spacer(vol.): 84.013/0 Job volume :20.0 bbl BASE FLUID Type : Fresh water Density : 8.32 lb/gal Weighting Agent(s) Code Conc. Density D031 226.47 lb/bbl of spacer 36.14 lb/gal Additives Code Conc. Function D182 6.000 lb/bbl of base fluid Turb. Spacer Page 5 3s-613 cement vt.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 41110 S Client : CPAI Well : 3S-613,injector S hlu der er String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 CW100 DESIGN 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 : 30.0 bbl Mud Type :WBM BASE FLUID Type : CW100 Density : 8.32 lb/gal Additives Code Conc. Function D122A .500 gal/bbl of wash Chem wash co J237A .250 gal/bbl of wash Fluid loss Fresh Water DESIGN Fluid No: 5 Density : 8.32 lb/gal Rheo. Model : NEWTONIAN At temp. : (degF) Viscosity : 5.000 cP Gel Strength : (Ibf/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 6 3s-613 cement vt.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • Client : CPAI Wet : 3S-613,injector Schlumberger String : 7 5/8 District : Prudhoe Bay,AK �p t Country : USA Loadcase : int stage 1 UniSLURRY* DESIGN Fluid No: 7 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 5.54E-3 Ibf.s^n/ft2 At temp. : 80 degF n : 0.829 Ty : 5.63Ibf/100ft2 Gel Strength : 17.08 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.119 gal/sk Job volume :46.4 bbl Dry Density : 3.20 SG Yield : 1.16 ft3/sk Quantity : 224.06 sk Sack Weight : 94 lb Solid Fraction :41.2 BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 3.919 gal/sk Additives Code Conc. Function D047 .200 gal/sk cement Antifoam D065 .300%BWOC Dispersant D167 .400%BWOC Fluid loss Min TT= [155 mn(pump time)+20 mn(open tool)+190 mn (circ out)]x 1.5=9 hr,8 mn Page 7 35-613 cement vl.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • Client : CPAI Well : 3S-613,injector SWIM rger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Section 3: Fluid Sequence Job Objectives: Pump designed cement to isolate losses. If well experiences loss, add CemNET"to mitigate losses(max 2 ppb). Do not put CemNET*in first or last 5 bbl. Confirm min restriction of TFA is greater than 0.8 in2 and/or 12/32 in. Original fluid LSND mud 9.20 lb/gal k: 1.44E-2 Ibf.s^n/ft2 n : 0.446 To :4.36 lbf/100ft2 Displacement Volume 504.7 bbl Total Volume 601.1 bbl TOC 10292.0 ft 1st stage collar 10292.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) CW100 30.0 560.2 9358.3 8.33 viscosity:5.000 cP MUDPUSH II 20.0 373.5 9918.5 12.50 k:1.81E-2 lbf.s^n/ft2 n:0.485 TY:12.86 lbf/100ft2 GASBLOK" 46.4 790.0 10292.0 15.80 k:5.54E-3 lbf.s^n/ft2 n:0.829 TY:5.63 lbf/100ft2 Fresh Water 10.0 10774.2 8.32 viscosity:5.000 cP LSND mud 494.7 0.0 9.20 k:1.44E-2 Ibf.s^n/ft2 n:0.446 TY:4.36 lbf/100ft2 Static Security Checks: Frac 216 psi at 11090.0 ft Pore 80 psi at 2897.0 ft Collapse 4016 psi at 10992.0 ft Burst 5893 psi at 9918.5 ft Csg.Pump out 65 ton Check Valve Diff Press 51 psi ft (x 1000)psi 0 4 -Hydrostatic -Frac - -Pore cv - tn - _ - ii Fluid Sequence Static Well Security Page 8 3s-613 cement v1.cfw;04-29-2016; LoadCase int stage 1:Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schlmihrger String : 75/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Section 4: Pumping Schedule - Minimize time spent outside of+1-0.2 ppg Density Range for fly mixing.(No more than 10%slurry volume pumped at more than 0.2 ppg below target density) - Mud to be thinned prior to cementing(expected conditioned mud properties provided and included in the cement program.)Circulate at least 1.5 times hole volume at maximum rate,without inducing losses.Check circulation pressures.Mud in and mud out densities to be the same. - Maintain returns during cement job if possible(note returns,losses in job report) - Follow indicated flow rates as closely as possible,noting any variance from below rates in job report. - Contingency minimum displacement rate to be determined based on thickening time from field blend testing - Plug must be bumped at or below 3 bpm. Rates in the table below are the MAXIMUM rate for each stage.This rate must not be exceeded. Pumping Schedule Name Flow Volume Stage Cum.Vol lnj. Comments Rate (bbl) Time (bbl). Temp. (bbl/min) (min) (degF) CW100 4.5 30.0 6.7 30.0 80 mix&pump chem wash MUDPUSH II 4.5 20.0 4.4 20.0 80 mix&pump MUDPUSH II" Pause 0.0 0.0 10.0 0.0 80 drop bottom plug UniSLURRY* 4.5 46.4 10.3 46.4 80 mix&pump GASBLOK* Pause 0.0 0.0 10.0 0.0 80 , drop top plug II Fresh Water 4.5 10.0 2.2 10.0 80 kick out plug Pause _ 0.0 _ 0.0 10.0 0.0 80 swap to rig I LSND mud 4.5 474.7 105.5 474.7 80 displacement LSND mud 3.0 20.0 6.7 494.7 80 displacement Total 02:45 601.1 bbl hr:mn Dynamic Security Checks: Frac 8 psi at 11090.0 ft Pore 80 psi at 2897.1 ft Collapse 3937 psi at 918.2 ft Burst 5578 psi at 443.8 ft Temperature Results BHCT 107 degF Simulated Max HCT 107 degF Simulated BHCT 105 degF Max HCT Depth 10403.5 ft CT at TOC 106 degF Max HCT Time 00:56:21 hr:mn:sc Static temperatures: At Time 25:00 hr:mn 50:00 hr:mn Geo.Temp. Top of Cement 121 degF 124 degF 125 degF Bottom Hole 127 degF 128 degF 129 degF Page 9 3s-613 cement vl.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schlumberger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Contingencies Any issue that occurs during cement mixing,pumping,and displacement must be approached in a step by step method. Any time a stoppage in the job occurs,follow checklist to determine maximum shutdown time and contingencies. Report any issues in job report. 1) If well has losses prior to cementing a) Use CemNET(1-2 lb/bbl;2 lb MAX).Discuss with town engineer b) Attempt to establish max.rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time<20 min c) If issue is with mixing system,switch to back-up mixing system d) If issue is with triplex pump,continue job with secondary triplex pump on unit. 3) Mud pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue:time<10 min c) Note displacement volume pumped by mud pumps:verify with co.rep/WSL d) Subtract pumped volume from total volume=volume to be pumped by cement unit e) Rig up hoses to get mud to cement unit i) Begin displacement with cement unit remaining displacement volume verified by co.rep/WSL 4) Plug does not bump a) If plug does not bump after calculated volume of displacement is pumped,pump an additional half shoe track volume.DO NOT OVERDISPLACE 5) If floats do not hold a) Pump back the volume and close cement head until 50 psi compressive strength on the tail cement is reached Page 10 3s-613 cement vi.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector schillmherger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Simulated Surface Pressures and Flow Rates during Placement 0 0 —4:Ic.CemHPUp _.. 4.c Punp Press. Q.7-7; MI&i redRessure mo N 7cn O , 0 100 200 300 400 500 600 700 Pumped Volume(bbl) N- Acquired Q Out --- - I ®Acquiredt1 In - - - .S �- Q Out il tO_�QIn II a In I 1 -CD _— O i O , , , I , 0 100 200 300 400 500 600 700 Pumped Volume(bbl) Simulated Dynamic Security during Placement ft lb/gal 8 1n '2 14 -—Hytrestatic l _ • —Vin.Hy r rustatic - _TMS ,� - J_ —Min.Dynan-4Z _ ' -Frac. * t t -*_-rt- •J - J - I , Fluid Sequence Dynamic Well Security Page 11 3s-613 cement vt.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_22 • • Client : CPAI Well : 3S-613,injector SANDI biller String : 75/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Simulated Differential Pressure at Landing Collar during Placement o Depth=10992 ft 1 Pseudo Hydrostatic 0 0 N a o_ 0 0 O o - 0 100 200 300 400 500 600 700 Pumped Volume(bbl) Annular Velocity at Shoe during Placement Depth=11082 ft Annular Velocity -- -. lam- .... ....... .... 0 100 200 300 400 500 600 700 Pumped Volume(bbl) Page 12 3s-613 cement vt.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schhookrger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Simulated ECD at Shoe during Placement Depth=11082 ft N —Lsao. Pore A / dros c o c o mo . o; oc;, 0 100 200 300 400 500 600 700 Pumped Volume(bbl) Simulated ECD at Previous Casing Shoe during Placement Depth=10292 ft Frac -Pore '.. -r,y. ti -D7nanic N N U, m 0 C I co 0 100 200 300 400 500 600 700 Pumped Volume(bbl) Page 13 3s-613 cement vt.cfw;04-29-2016; LoadCase int stage 1:Version wcs-cem476_02 i • Client : CPAI Well : 3S-613,injector Salem krger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Simulated Slurry Temperature during and up to 24 hours after Placement CD v (*) —Last Sack Temp. r a .First Sack Temp. ccom� 1 l rW a = I� s 1 i ocp -ac cm L-. 1 li i t T— fg 1 1 1 4Y 1 : : ,,,,,_ d a , F CI F s li . its - -4. 1-4--- I _-1 t_ r— co 0 500 1000 1500 2000 2500 3000 3500 Time (min) Page 14 3s-613 cement v1.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_32 • • Client : CPAI Well : 3S-613,injector Schimmrger String : 75/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Section 5: Centralizer Placement Top of centralization :3983.0 ft Bottom Cent. MD :10992.0 ft Casing Shoe :11082.0 ft Tension at 1st stage :1381.58 lbf NB of Cent. Used :107 NB of Floating Cent. :107 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 6762.0 0 0/0 0.0 6775.4 10962.0 105 1/1 1732075-7 5/8-0-RIGID W121 48.6 10682.0 11002.0 2 2/1 1732075-7 5/8-0-RIGID W121 65.5 10982.0 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) (Ibf) 1732075-7 5/8-0- W121 7 5/8 9.626 9.626 Yes Houma N.A. N.A. N.A. RIGID Centralizer performance data is based on information provided by CPAI. ft 0 70 0 60 80 100 a Ar cent. cis �- _...�.. I I CD 0 [ C} ' 3 .�,.,. t C1 Pipe Standoff As per CPAI Program Page 15 3s-613 cement vi.cfw:04-29-2016; LoadCase int stage 1:Version wcs-cem476_02 • • String : 7 5/8 District : PrudhoenBay,AK Sc l r r Country : USA Loadcase : int stage 1 Section 6: WELLCLEAN II Simulator The below simulation is done assuming 40%annular excess over gauged 9-5/8"hole. Yoft 25 50 75 100 0 50 100 Std Betw.Cent —Mud Contamination '.. Cement Coverage Uncontaminated Slurry O O N O O O— O O O O O co O - '.. O O- O Ms O N Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall 5 5 10500 j -10500 10500 10500 1 0600- -10800 10600 10600 1 0700- -10700 10700 10700 10500 -10800 .c . 10800 10800 z o n W n m a m d O O 17 O 10900- -10900 10900 10900 11000- -11000 11000 11000 11 100- -11 100 11100 IMMI 11 100 G 3r G `0 0 z z ▪ LSND mud 1111 MUDPUSH II 1111 High Low IIIIIII� Fresh Water Owl 00 WS Medium None • GASBLOK" Channeling can be seen in the simulation with the existing centralization pattern. Actual results would vary based on actual hole size. Fluid rheologies at BHCT have been considered in the simulation; fluid properties downhole would change based on temperature at different depths. ANNULUS- ONLY SIMULATION. DOES NOT CONSIDER POSSIBLE IN-PIPE CONTAMINATION. Page 16 3s-613 cement vt.cfw;04-232016; LoadCase int stage 1;Version wcs-cem476_02 0 • Schlumberger Appendix 1: Directional Survey Appendix 1: Directional Survey Data Data MD TVD Deviation Azimuth Dogleg MD TVD Deviation Azimuth Dogleg (ft) (ft) (deg) (deg) Sev. (ft) (ft) (deg) (deg) Sev. (deg/100ft) (deg/100ft) 0.0 0.0 0.0 0.0 0.000 4100.0 3047.5 70.6 272.9 0.000 39.0 39.0 0.0 0.0 0.000 4200.0 3080.6 70.6 272.9 0.000 89.0 89.0 0.0 0.0 0.000 4300.0 3113.8 70.6 272.9 0.000 100.0 100.0 0.0 0.0 0.000 4400.0 3146.9 70.6 272.9 0.000 200.0 200.0 0.0 0.0 0.000 4500.0 3180.1 70.6 272.9 0.000 300.0 300.0 0.0 0.0 0.000 4600.0 3213.2 70.6 272.9 0.000 360.0 360.0 0.0 0.0 0.000 4700.0 3246.4 70.6 272.9 0.000 400.0 400.0 0.6 220.0 -1.500 4800.0 3279.5 70.6 272.9 0.000 500.0 500.0 2.1 220.0 1.500 4900.0 3312.7 70.6 272.9 0.000 500.0 500.0 2.1 220.0 0.000 5000.0 3345.8 70.6 272.9 0.000 600.0 599.8 4.1 228.8 2.001 5065.6 3367.6 70.6 272.9 0.000 700.0 699.4 6.0 231.8 1.997 5100.0 3379.0 70.6 272.9 0.000 800.0 798.7 8.0 233.4 1.999 5200.0 3412.1 70.6 272.9 0.000 900.0 897.4 10.0 234.3 2.005 5300.0 3445.3 70.6 272.9 0.000 1000.0 995.6 12.0 234.9 1.994 5400.0 3478.4 70.6 272.9 0.000 1100.0 1093.0 14.0 235.4 2.003 5500.0 3511.6 70.6 272.9 0.000 1200.0 1189.6 16.0 235.7 2.002 5600.0 3544.7 70.6 272.9 0.000 1300.0 1285.2 18.0 236.0 2.001 5700.0 3577.9 70.6 272.9 0.000 1400.0 1379.8 20.0 236.2 2.001 5800.0 3611.0 70.6 272.9 0.000 1500.0 1473.1 22.0 236.4 2.001 5900.0 3644.2 70.6 272.9 0.000 1600.0 1565.1 24.0 236.5 2.001 6000.0 3677.3 70.6 272.9 0.000 1611.6 1575.7 24.2 236.6 1.991 6100.0 3710.5 70.6 272.9 0.000 1700.0 1655.8 26.0 236.7 1.991 6200.0 3743.6 70.6 272.9 0.000 1706.6 1661.7 26.1 236.7 2.122 6300.0 3776.8 70.6 272.9 0.000 1800.0 1745.5 26.1 236.7 0.000 6400.0 3809.9 70.6 272.9 0.000 1818.0 1761.7 26.1 236.7 0.000 6500.0 3843.1 70.6 272.9 0.000 1900.0 1834.6 28.5 238.4 2.995 6600.0 3876.2 70.6 272.9 0.000 1988.0 1911.0 31.0 240.1 3.005 6700.0 3909.4 70.6 272.9 0.000 2000.0 1921.3 31.3 240.4 2.994 6800.0 3942.5 70.6 272.9 0.000 2100.0 2005.5 33.9 243.1 2.995 6900.0 3975.7 70.6 272.9 0.000 2115.9 2018.7 34.3 243.4 3.027 7000.0 4008.8 70.6 272.9 0.000 2200.0 2087.1 36.6 245.4 3.000 7100.0 4042.0 70.6 272.9 0.000 2300.0 2166.0 39.3 247.4 2.995 7200.0 4075.1 70.6 272.9 0.000 2400.0 2241.7 42.1 249.2 3.004 7252.4 4092.5 70.6 272.9 0.000 2500.0 2314.3 44.9 250.9 2.998 7300.0 4108.3 70.6 272.9 0.000 2600.0 2383.4 47.7 252.4 2.997 7400.0 4141.4 70.6 272.9 0.000 2700.0 2448.9 50.5 253.7 3.001 7500.0 4174.6 70.6 272.9 0.000 2715.4 2458.7 50.9 253.9 3.011 7600.0 4207.7 70.6 272.9 0.000 2800.0 2510.6 53.3 255.0 3.002 7632.4 4218.5 70.6 272.9 0.000 2897.1 2566.7 56.1 256.1 2.998 7700.0 4240.9 70.6 272.9 0.000 2900.0 2568.3 56.2 256.2 3.055 7800.0 4274.0 70.6 272.9 0.000 3000.0 2622.6 58.1 258.9 2.997 7852.6 4291.5 70.6 272.9 0.000 3075.6 2661.7 59.6 260.8 3.002 7900.0 4307.2 70.6 272.9 0.000 3100.0 2673.9 60.1 261.5 3.006 8000.0 4340.3 70.6 272.9 0.000 3200.0 2722.1 62.2 263.9 3.000 8100.0 4373.5 70.6 272.9 0.000 3300.0 2767.1 64.3 266.3 3.001 8200.0 4406.6 70.6 272.9 0.000 3400.0 2808.8 66.4 268.6 2.998 8300.0 4439.8 70.6 272.9 0.000 3500.0 2847.0 68.6 270.9 3.000 8400.0 4472.9 70.6 272.9 0.000 3591.5 2878.9 70.6 272.9 3.004 8500.0 4506.1 70.6 272.9 0.000 3600.0 2881.7 70.6 272.9 0.000 8600.0 4539.2 70.6 272.9 0.000 3700.0 2914.9 70.6 272.9 0.000 8700.0 4572.4 70.6 272.9 0.000 3800.0 2948.0 70.6 272.9 0.000 8709.0 4575.4 70.6 272.9 0.000 3900.0 2981.2 70.6 272.9 0.000 8800.0 4605.5 70.7 275.8 2.997 4000.0 3014.3 70.6 272.9 0.000 8900.0 4638.5 70.8 278.9 3.002 Page 17 3s-613 cement vt.cfw;04-29-2016; LoadCase int stage 1;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Sc Iu 6erger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : int stage 1 Appendix 1: Directional Survey Appendix 1: Directional Survey Data Data MD TVD Deviation Azimuth Dogleg MD TVD Deviation Azimuth Dogleg (ft) (ft) (deg) (deg) Sev. (ft) (ft) (deg) (deg) Sev. (deg/100ft) (deg/100ft) 9000.0 4671.4 70.9 282.1 2.997 10291.5 5040.3 77.2 322.0 3.000 9100.0 4704.0 71.1 285.3 3.004 10300.0 5042.2 77.2 322.2 2.937 9200.0 4736.2 71.3 288.4 2.993 10400.0 5063.7 78.0 325.2 3.004 9300.0 4767.9 71.6 291.6 3.002 10500.0 5083.8 78.8 328.1 3.001 9400.0 4799.1 72.0 294.7 3.004 10600.0 5102.5 79.6 331.1 2.996 9500.0 4829.7 72.4 297.8 2.997 10700.0 5119.7 80.5 334.0 3.005 9600.0 4859.6 72.8 300.9 3.002 10800.0 5135.5 81.4 336.9 2.996 9700.0 4888.7 73.3 304.0 2.998 10805.3 5136.2 81.4 337.0 2.976 9737.5 4899.4 73.5 305.2 3.009 10900.0 5149.6 82.3 339.8 3.003 9800.0 4916.9 73.9 307.1 3.004 11000.0 5162.2 83.2 342.6 2.995 9900.0 4944.1 74.5 310.2 2.993 11035.6 5166.3 83.6 343.7 3.016 10000.0 4970.4 75.1 313.2 3.000 11081.8 5171.3 84.0 345.0 2.998 10100.0 4995.5 75.8 316.2 2.997 11090.0 5172.1 84.6 345.0 6.708 10200.0 5019.5 76.5 319.2 3.007 Page 18 3s-613 cement v1.cfw;04-29-2016; LaadCase int stage 1;Version wcs-cem476_92 • • Schlumberger CemCAD Ewell cementing recommendation for 7 5/811 Intermediate STAGE 2 Operator : CPAI Well : 3S-613,injector Country : USA Field : Moraine State : Alaska Prepared for : Brunswick,Scott Location : Doyon 142 Proposal No. : initial-6 Service Point : Prudhoe Bay,AK Date Prepared : 4.29.16 Business Phone : 907.659.2434 Prepared by : Britton Schlotz Phone : 907.265.1463 E-Mail Address : bschlotz©slb.com .414 Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts w information provided by others,limitations,computer models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTNENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom frau infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. Mark of Schlumberger Page 1 3s-613 cement vi.cfw;04-29-2016; leadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schlumberger String : 7 5/8 District : Prudhoe Bay,AK illll Country : USA Loadcase : stage 2 Section 1 : Well Description Configuration : Casing Stage : 2nd of 2 Rig Type : Land Mud Line : 0.0 ft Total MD : 11090.0 ft BHST : 125 degF Bit Size : 9 7/8 in ft lb./gal < _ _ > 8 12 16 _ . . . . . permafrost _ 1 I 11 2 r .1 CD . . . . . . . . • C-50 1 o �? o- m '. T 1 _ loss zone o _ _ 0 o- cv k�,�ell Lithology Formation Press. Page 2 3s-613 cement v1.cfw;04-29-2016: LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schlu har er String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2897.0 10 3/4 45.5 9.950 1st Stage Collar : 10292.0 ft Landing Collar MD : 10992.0 ft Casing/liner Shoe MD : 11082.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 11082.0 7 5/8 40.0 29.7 6.875 L-80 4310 5900 Hydril 563 Mean OH Diameter : 9.875 in Mean Annular Excess : 40.0 % Mean OH Equivalent Diameter: 10.642 in Total OH Volume : 901.3 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 10292.0 9.875 40.0 10.643 11082.0 9.875 40.0 10.643 11090.0 9.875 0.0 9.875 Max. Deviation Angle : 85 deg Max. DLS : 6.7076 deg/100ft Refer to Appendix 9 for complete directional survey Formation Data I MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1612.0 13.50 8.60 permafrost Sandstone 3072.0 13.50 8.60 n/a Sandstone 5100.0 13.50 8.60 Campanian Sandstone 7267.0 13.50 8.60 C-50 Sandstone 7632.0 13.50 8.60 K-3 Sandstone 11020.0 13.50 8.60 loss zone Sandstone 11090.0 10.20 8.60 TD Sandstone Page 3 3s-613 cement v1.cfw:04-29-2016; LoadCase stage 2:Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector 11!lbuger String : 7 5/8 District : Prudhoe Bay,AK it Country : USA Loadcase : stage 2 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1612.0 1576.1 32 0.8 11090.0 5172.1 129 2.1 ft degF (x 1000)ft 0 I 100 150 f '; 6 9 c tr.F. =;.e _I- cep=-rt. I I _ , 1 1 — I . I_w. r t 1 1 -1 �' .* qq c, ___ 0 t : -- Lf) } o p O Tr 1O O7 O 1 j to ._ cD I 1-4-1 7m. ..a i 1 t 4 EJ Temperature Hari- Depatttie Page 4 3s-613 cement vt.cfw;04-29-2016; LoadCase stage 2:Version wcs-cem476_02 • Client : CPAI Well : 3S-613,injector Scirger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Section 2: Fluid Descriptions LSND mud DESIGN Fluid No: 1 Density : 9.20 lb/gal Rheo. Model : HERSCHEL_B. k : 1.44E-2 Ibf.s^n/ft2 At temp. : 80 degF n : 0.446 Ty : 4.361bf/100ft2 Gel Strength : 8.54 lbf/100ft2 MUD Mud Type :WBM Job volume :462.6 bbl Water Type : Fresh VOLUME FRACTION Solids : 10.0% Oil : 3.0% Water : 87.0% Rheometric Measurements Rheometer type : 35 (rpm) At 80 degF Geometry : R1 B1 (deg) Spring No : 1.0 600 35.0 300 27.0 200 23.0 100 18.0 6 8.0 3 7.0 Viscosity : (cP) 10 sec Gel Strength 7.47 Ibf/100ft2 10 min Gel Strength 8.54 Ibf/100ft2 Anticipated mud properties. MUDPUSH II DESIGN Fluid No:2 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.81E-2 Ibf.s^n/ft2 At temp. : 65 degF n : 0.485 Ty : 12.86 lbf/100ft2 Gel Strength : 22.63 Ibf/100ft2 SPACER Spacer Type : MUDPUSH II Porosity : 84.0% Solid Fraction : 16.0% Mud Type :WBM Mix Water/Spacer(vol.): 84.0% Job volume : 30.0 bbl BASE FLUID Type : Fresh water Density : 8.32 lb/gal Weighting Agent(s) Code Conc. Density D031 226.47 lb/bbl of spacer 36.14 lb/gal Additives Code Conc. Function D182 6.000 lb/bbl of base fluid Turb. Spacer Page 5 3s-613 cement vl.cfw;04-29-2016; LoadCasestage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schlumberger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 CW100 DESIGN Fluid No: 3 Density : 8.33 lb/gal Rheo. Model : NEWTONIAN At temp. : (degF) Viscosity : 5.000 cP Gel Strength : (lbf/100ft2) WASH Wash Type : CW100 Water/Wash (vol.): 98.2% Job volume : 30.0 bbl Mud Type :WBM BASE FLUID Type : CW100 Density : 8.32 lb/gal Additives Code Conc. Function D122A .500 gal/bbl of wash Chem wash co J237A .250 gal/bbl of wash Fluid loss Fresh Water DESIGN Fluid No: 5 Density : 8.32 lb/gal Rheo. Model : NEWTONIAN At temp. : (degF) Viscosity : 5.000 cP Gel Strength : (Ibf/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 6 3s-613 cement v1.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • Client : CPAI Well : 3S-613,injector Schlumberger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 UniSLURRY* DESIGN Fluid No: 7 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 5.54E-3 Ibf.sAn/ft2 At temp. : 80 degF n : 0.829 Tv : 5.63 lbf/100ft2 Gel Strength : 17.08 Ibf/100ft2 DESIGN BLEND SLURRY Name : G Mix Fluid : 5.119 gal/sk Job volume : 188.8 bbl Dry Density : 3.20 SG Yield : 1.16 ft3/sk Quantity : 910.78 sk Sack Weight : 94 lb Solid Fraction :41.2% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 3.919 gal/sk Additives Code Conc. Function D047 .200 gal/sk cement Antifoam D065 .300%BWOC Dispersant D167 .400%BWOC Fluid loss Min TT=127 mn+ 120 mn=4 hr,7 mn Page 7 3s-613 cement vt.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schirger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Section 3: Fluid Sequence Job Objectives: pump designed cement volume for a planned TOC a minimum of 500'MD above K-3. Original fluid LSND mud 9.20 lb/gal k: 1.44E-2 Ibf.s^n/ft2 n : 0.446 Ty: 4.36 lbf/100ft2 Dead end fluid LSND mud 9.20 lb/gal Displacement Volume 472.6 bbl Total Volume 721.3 bbl TOC 6767.0 ft Previous TOC 10292.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) CW100 30.0 560.2 5646.5 8.33 viscosity:5.000 cP MUDPUSH II 30.0 560.2 6206.8 12.50 k:1.81 E-2 Ibf.s^n/ft2 n:0.485 Ty:12.86 lbf/100ft2 GASBLOK* 188.8 3525.0 6767.0 15.80 k:5.54E-3 lbf.s^n/ft2 n:0.829 Ty:5.63Ibf/100ft2 Fresh Water 10.0 10074.2 8.32 viscosity:5.000 cP LSND mud 462.6 0.0 9.20 k:1.44E-2 Ibf.s^n/ft2 n:0.446 Ty:4.36 lbf/100ft2 Static Security Checks: Frac 573 psi at 2897.0 ft Pore 80 psi at 2897.0 ft Collapse 3667 psi at 10292.0 ft Burst 5892 psi at 6206.8 ft Check Valve Diff Press 406 psi ft (x 1000)psi o- 0 4 -Hydrostatic - -Frac o - o -Pore o- cv - o o- o {. . o - o - a l _, o- o " 0 o- i Fluid Sequence Static Well Security Page 8 3s-613 cement vl.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 II • Client : CPAI Well : 3S-613,injector Schi�1 he ger String : 7 5/8 District : Prudhoe Bay,AK {R Country : USA Loadcase : stage 2 Section 4: Pumping Schedule - Minimize time spent outside of+/-0.2 ppg Density Range for fly mixing.(No more than 10%slurry volume pumped at more than 0.2 ppg below target density) - Mud to be thinned prior to cementing(expected conditioned mud properties provided and included in the cement program.)Circulate at least 1.5 times hole volume at maximum rate,without inducing losses.Check circulation pressures.Mud in and mud out densities to be the same. - Maintain returns during cement job if possible(note returns,losses in job report) - Follow indicated flow rates as closely as possible,noting any variance from below rates in job report. - Contingency minimum displacement rate to be determined based on thickening time from field blend testing - Plug must be bumped at or below 3 bpm. Rates in the table below are the MAXIMUM rate for each stage.This rate must not be exceeded. Pumping Schedule Name Flow Volume Stage Cum.Vol Inj. Comments Rate (bbl) Time (bbl). Temp. (bbl/min) (min) (degF) CW100 7.0 30.0 4.3 30.0 80 mix&pump chem wash FA- MUDPUSH Il 7.0 30.0 4.3 30.0 80 mix&pump MUDPUSH II* Pause 0.0 0.0 10.0 0.0 80 drop bottom plug UniSLURRY* 7.0 188.8 27.0 188.8 80 mix&pump GASBLOK* Pause 0.0 0.0 10.0 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 10.0 0.0 80 swap to rig I LSND mud 7.0 452.6 64.7 452.6 80 displacement LSND mud 3.0 10.0 3.3 462.6 80 displacement Total 02:14 721.3 bbl hr:mn Dynamic Security Checks: Frac 432 psi at 10292.0 ft Pore 80 psi at 2897.1 ft Collapse 3508 psi at 1048.7 ft Burst 5155 psi at 0.0 ft Temperature Results BHCT 106 degF Simulated Max HCT 99 degF Simulated BHCT 98 degF Max HCT Depth 9661.9 ft CT at TOC 93 degF Max HCT Time 01:08:42 hr:mn:sc Static temperatures: At Time 25:00 hr:mn 50:00 hr:mn Geo.Temp. Top of Cement 95 degF 95 degF 95 degF Bottom Hole 121 degF 124 degF 125 degF Page 9 3s-613 cement vl.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schiu her er String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Contingencies Any issue that occurs during cement mixing,pumping,and displacement must be approached in a step by step method. Any time a stoppage in the job occurs,follow checklist to determine maximum shutdown time and contingencies. Report any issues in job report. 1) If well has losses prior to cementing a) Use CemNET(1-2 lb/bbl;2 lb MAX).Discuss with town engineer b) Attempt to establish max.rate at which full circulation is achieved c) Pump job at this rate if possible 2) Cement unit failure while mixing a) Attempt to continue pumping cement at 0.5 bpm b) Attempt to remedy issue:time<20 min c) If issue is with mixing system,switch to back-up mixing system d) If issue is with triplex pump,continue job with secondary triplex pump on unit. 3) Mud pump failure during displacement a) Attempt to continue displacement with secondary pump b) Attempt to repair issue:time<10 min c) Note displacement volume pumped by mud pumps:verify with co.rep/WSL d) Subtract pumped volume from total volume=volume to be pumped by cement unit e) Rig up hoses to get mud to cement unit i) Begin displacement with cement unit:remaining displacement volume verified by co.rep/WSL 4) Plug does not bump a) If plug does not bump after calculated volume of displacement is pumped,pump an additional half shoe track volume.DO NOT OVERDISPLACE 5) If floats do not hold a) Pump back the volume and close cement head until 50 psi compressive strength on the tail cement is reached Page 10 3s- 4-2-201 LoadCase stage 2;Version wcs-cem476 02 613 cement vi.cfw,0 9 6; g _ • • Client : CPAI Well : 3S-613,injector Sthiifill String 75/8 District Prudhoe Bay,AK Country : USA Loadcase : stage 2 Simulated Surface Pressures and Flow Rates during Placement 0 p —Calc.CemHP '.. '.... Calc.Rirrp Press Acquired Pressure //0 I in p 1 a.c) 0 0 100 200 300 400 500 600 700 800 Pumped Volume(bbl) N `- Acquired(_,Out —Acquired/C)In'% —— Q Out / —Qln / / 1 III �- • Cts_ 3 o i t_ rr p 0 100 200 300 400 500 600 700 800 Pumped Volume(bbl) Simulated Dynamic Security during Placement ft lb/gal 8 il 2 14 —Hydrostatic —Min. Hydrostatic O _ —Max.Dynamo O_ —Min.Dy°rra niC "'..". ... —Frac }.' —Fars - r- o v _ o o- co _ k CD - ®- co _ 0 o_ E]� yy _1 ..a_..1...l_CA ._._. Fluid Sequence Dynamic Well Security Page 11 3s-613 cement vi.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Sc Irger String : 75/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Simulated Differential Pressure at Landing Collar during Placement O Depth=10292 ft 0 Pseudo Hydrostatic O O- O au)co N a) US o in 0N O i O 0 100 200 300 400 500 600 700 800 Pumped Volume(bbl) Annular Velocity at Shoe during Placement o Depth=10292 ft O —Annular Velocity OD O Ln._.a.,Nr\ .___ N _____. z... C O in 0 100 200 300 400 500 600 700 800 Pumped Volume(bbl) Page 12 3s-613 cement vi.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector SCWrger String : 75/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Simulated ECD at Shoe during Placement Depth=10292 ft i Frac m Pore —Dynamic M N Til Co 927 cea` ¢o rn_ co 0 100 200 300 400 500 600 700 800 Pumped Volume(bbl) Simulated Slurry Temperature during and up to 24 hours after Placement 0 0 rri -Last Sack Temp. r First Sack Temp. j l& � -r ¢j Pte. S co iCU £ E. o o� i € i t x ©— ' «_ __.17 7 4 _.,_:..1-._ g._._ ....... _...._,_... },,... _,_..a.., _.__..._-_. - " l r— co 0 a- -v -in 0 u; r-- ri 0 500 1000 1500 2000 2500 3000 3500 Time ( tin) Page 13 3s-613 cement vi.cfw:04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injectorhlaerer String : 75/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Section 5: Centralizer Placement Top of centralization :3983.0 ft Bottom Cent. MD :10262.0 ft Casing Shoe :11082.0 ft NB of Cent. Used :88 NB of Floating Cent. :88 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 6762.0 0 0/0 0.0 6775.4 10322.0 89 1/1 1732075-7 5/8-0-RIGID W121 49.4 9682.0 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) (Ibf) (lbf) 1732075-7 5/8-0- W121 7 5/8 9.626 9.626 Yes Houma N.A. N.A. N.A. RIGID Centralizer performance data is based on information provided by CPAI. ft % G_ 0 i '0 60 80 100 _ —Eet.,aer Cert. - i At Cart.o z- k - . .. m € _ _ 0 1 0 o— 1 i .._,L, s t .t o i r = i _ . an o co - o o CJ Pipe Standoff As per CPAI Program Page 14 3s-613 cement vtcfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Scam huger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Section 6: WELLCLEAN II Simulator The below simulation is done assuming 40%annular excess over gauged 9-5/8"hole. % % ft 25 50 75 100 0 50 100 o_ 1 i 1 Std Betw.Cent. i—tvhid Contamination Cement Coverage Uncontaminated Slurry 0 0 o_ N 0 0 O— V O O O— O ltd O O O— co O - O O O O N Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall 2° g g 2 g _ 7000- 7000 7000 7000 7500- 7500 7500 7500 ,Z 8000- 8000 ,... 8000 8000 5500- 8500 .e 8500 8500 .e If a. a n 9000- 9000 0 9000 9000 9500- 9500 9500 9500 10000- 10000 10000 10000 o `o $ 2 2 IIIIII LSND mud Mi MUDPUSH II = High NM Low MI Fresh Water = CW100 Medium = None El GASBLOK' Actual results would vary based on actual hole size. Fluid rheologies at BHCT have been considered in the simulation;fluid properties downhole would change based on temperature at different depths. ANNULUS- ONLY SIMULATION. DOES NOT CONSIDER POSSIBLE IN-PIPE CONTAMINATION. Page 15 3s-613 cement v1.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Schlumberger Appendix 1: Directional Survey Data Appendix 1: Directional Survey Data MD TVD Deviation Azimuth Dogleg MD TVD Deviation Azimuth Dogleg (ft) (ft) (deg) (deg) Sev. (ft) (ft) (deg) (deg) Sev. (deg/100ft) (deg/100ft) 0.0 0.0 0.0 0.0 0.000 4200.0 3080.6 70.6 272.9 0.000 39.0 39.0 0.0 0.0 0.000 4300.0 3113.8 70.6 272.9 0.000 89.0 89.0 0.0 0.0 0.000 4400.0 3146.9 70.6 272.9 0.000 100.0 100.0 0.0 0.0 0.000 4500.0 3180.1 70.6 272.9 0.000 200.0 200.0 0.0 0.0 0.000 4600.0 3213.2 70.6 272.9 0.000 300.0 300.0 0.0 0.0 0.000 4700.0 3246.4 70.6 272.9 0.000 360.0 360.0 0.0 0.0 0.000 4800.0 3279.5 70.6 272.9 0.000 400.0 400.0 0.6 220.0 -1.500 4900.0 3312.7 70.6 272.9 0.000 500.0 500.0 2.1 220.0 1.500 5000.0 3345.8 70.6 272.9 0.000 500.0 500.0 2.1 220.0 0.000 5065.6 3367.6 70.6 272.9 0.000 600.0 599.8 4.1 228.8 2.001 5100.0 3379.0 70.6 272.9 0.000 700.0 699.4 6.0 231.8 1.997 5200.0 3412.1 70.6 272.9 0.000 800.0 798.7 8.0 233.4 1.999 5300.0 3445.3 70.6 272.9 0.000 900.0 897.4 10.0 234.3 2.005 5400.0 3478.4 70.6 272.9 0.000 1000.0 995.6 12.0 234.9 1.994 5500.0 3511.6 70.6 272.9 0.000 1100.0 1093.0 14.0 235.4 2.003 5600.0 3544.7 70.6 272.9 0.000 1200.0 1189.6 16.0 235.7 2.002 5700.0 3577.9 70.6 272.9 0.000 1300.0 1285.2 18.0 236.0 2.001 5800.0 3611.0 70.6 272.9 0.000 1400.0 1379.8 20.0 236.2 2.001 5900.0 3644.2 70.6 272.9 0.000 1500.0 1473.1 22.0 236.4 2.001 6000.0 3677.3 70.6 272.9 0.000 1600.0 1565.1 24.0 236.5 2.001 6100.0 3710.5 70.6 272.9 0.000 1611.6 1575.7 24.2 236.6 1.991 6200.0 3743.6 70.6 272.9 0.000 1700.0 1655.8 26.0 236.7 1.991 6300.0 3776.8 70.6 272.9 0.000 1706.6 1661.7 26.1 236.7 2.122 6400.0 3809.9 70.6 272.9 0.000 1800.0 1745.5 26.1 236.7 0.000 6500.0 3843.1 70.6 272.9 0.000 1818.0 1761.7 26.1 236.7 0.000 6600.0 3876.2 70.6 272.9 0.000 1900.0 1834.6 28.5 238.4 2.995 6700.0 3909.4 70.6 272.9 0.000 1988.0 1911.0 31.0 240.1 3.005 6800.0 3942.5 70.6 272.9 0.000 2000.0 1921.3 31.3 240.4 2.994 6900.0 3975.7 70.6 272.9 0.000 2100.0 2005.5 33.9 243.1 2.995 7000.0 4008.8 70.6 272.9 0.000 2115.9 2018.7 34.3 243.4 3.027 7100.0 4042.0 70.6 272.9 0.000 2200.0 2087.1 36.6 245.4 3.000 7200.0 4075.1 70.6 272.9 0.000 2300.0 2166.0 39.3 247.4 2.995 7252.4 4092.5 70.6 272.9 0.000 2400.0 2241.7 42.1 249.2 3.004 7300.0 4108.3 70.6 272.9 0.000 2500.0 2314.3 44.9 250.9 2.998 7400.0 4141.4 70.6 272.9 0.000 2600.0 2383.4 47.7 252.4 2.997 7500.0 4174.6 70.6 272.9 0.000 2700.0 2448.9 50.5 253.7 3.001 7600.0 4207.7 70.6 272.9 0.000 2715.4 2458.7 50.9 253.9 3.011 7632.4 4218.5 70.6 272.9 0.000 2800.0 2510.6 53.3 255.0 3.002 7700.0 4240.9 70.6 272.9 0.000 2897.1 2566.7 56.1 256.1 2.998 7800.0 4274.0 70.6 272.9 0.000 2900.0 2568.3 56.2 256.2 3.055 7852.6 4291.5 70.6 272.9 0.000 3000.0 2622.6 58.1 258.9 2.997 7900.0 4307.2 70.6 272.9 0.000 3075.6 2661.7 59.6 260.8 3.002 8000.0 4340.3 70.6 272.9 0.000 3100.0 2673.9 60.1 261.5 3.006 8100.0 4373.5 70.6 272.9 0.000 3200.0 2722.1 62.2 263.9 3.000 8200.0 4406.6 70.6 272.9 0.000 3300.0 2767.1 64.3 266.3 3.001 8300.0 4439.8 70.6 272.9 0.000 3400.0 2808.8 66.4 268.6 2.998 8400.0 4472.9 70.6 272.9 0.000 3500.0 2847.0 68.6 270.9 3.000 8500.0 4506.1 70.6 272.9 0.000 3591.5 2878.9 70.6 272.9 3.004 8600.0 4539.2 70.6 272.9 0.000 3600.0 2881.7 70.6 272.9 0.000 8700.0 4572.4 70.6 272.9 0.000 3700.0 2914.9 70.6 272.9 0.000 8709.0 4575.4 70.6 272.9 0.000 3800.0 2948.0 70.6 272.9 0.000 8800.0 4605.5 70.7 275.8 2.997 3900.0 2981.2 70.6 272.9 0.000 8900.0 4638.5 70.8 278.9 3.002 4000.0 3014.3 70.6 272.9 0.000 9000.0 4671.4 70.9 282.1 2.997 4100.0 3047.5 70.6 272.9 0.000 9100.0 4704.0 71.1 285.3 3.004 Page 16 3s-613 cement vt.cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Client : CPAI Well : 3S-613,injector Schlumberger String : 7 5/8 District : Prudhoe Bay,AK Country : USA Loadcase : stage 2 Appendix 1: Directional Survey Data Appendix 1: Directional Survey Data MD TVD Deviation Azimuth Dogleg MD TVD Deviation Azimuth Dogleg (ft) (ft) (deg) (deg) Sev. (ft) (ft) (deg) (deg) Sev. (deg/100ft) (deg/100ft) 9200.0 4736.2 71.3 288.4 2.993 10300.0 5042.2 77.2 322.2 2.937 9300.0 4767,9 71.6 291.6 3.002 10400.0 5063.7 78.0 325.2 3.004 9400.0 4799,1 72.0 294.7 3.004 10500.0 5083.8 78.8 328.1 3.001 9500.0 4829.7 72.4 297.8 2.997 10600.0 5102.5 79.6 331.1 2.996 9600.0 4859.6 72.8 300.9 3.002 10700.0 5119.7 80.5 334.0 3.005 9700.0 4888.7 73.3 304.0 2.998 10800.0 5135.5 81.4 336.9 2.996 9737.5 4899.4 73.5 305.2 3.009 10805.3 5136.2 81.4 337.0 2.976 9800.0 4916.9 73.9 307.1 3.004 10900.0 5149.6 82.3 339.8 3.003 9900.0 4944.1 74.5 310.2 2.993 11000.0 5162.2 83.2 342.6 2.995 10000.0 4970.4 75.1 313.2 3.000 11035.6 5166.3 83.6 343.7 3.016 10100.0 4995.5 75.8 316.2 2.997 11081.8 5171.3 84.0 345.0 2.998 10200.0 5019.5 76.5 319.2 3.007 11090.0 5172.1 84.6 345.0 6.708 10291.5 5040.3 77.2 322.0 3.000 Page 17 3s-613 cement v1 cfw;04-29-2016; LoadCase stage 2;Version wcs-cem476_02 • • Brunswick, Scott A From: Loepp, Victoria T(DOA) <victoria.loepp@alaska.gov> Sent: Friday, April 29, 2016 1:18 PM To: Brunswick, Scott A Cc: Bettis, Patricia K(DOA); Schwartz, Guy L(DOA) Subject: [EXTERNAL]FW: 3S-613 PTD 216-020 Attachments: 3S-613 Schematic Rev#4 - 2 stage cement proposal.pdf Scott, Approval is granted for the two stage cement job proposed below. Please submit a 10-403, Change of Approved Program as soon as possible outlining the proposed change. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(cilalaska.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.Loeoo@alaska.gov From: Bettis, Patricia K(DOA) Sent: Friday, April 29, 2016 12:40 PM To: Loepp, Victoria T(DOA) Subject: FW: 3S-613 PTD 216-020 From: Brunswick,Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Friday,April 29, 2016 11:36 AM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Cc:Schwartz, Guy L(DOA)<guy.schwartz(Walaska.gov>; Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com>; Alvord, Chip<Chip.Alvord@conocophillips.com> Subject: 3S-613 PTD 216-020 Patricia We entered the Moraine formation on 3S-613 (PTD 216-020)this morning. We were drilling with a 9.2 ppg mud due to predicted low formation pressure. After entering the Moraine with 10.5 ppg ECD at 11020' MD,we encountered dynamic losses of 40 bbl/hr. We pumped a LCM pill reducing the losses to 20 bbl/hr. We called TD at 11090' MD to set 1 casinginto the Moraine formation. ale we have been circulatingthe hole clean for the tripout of the hole,the dynamic losses have gone to zero with wall cake & LCM treatments. I would like to check to make sure the AOGCC is OK with my plan forward to change from a single stage cement job to a two stage job so I can make sure we get good cement in the 7-5/8" OA. The initial plan was a single 4300'column of cement to place cement top at least 500' above the K-3 formation. After seeing the losses this morning, and based on updated cement modelling using what we have seen,the best path forward is to pump a two stage job covering the loss zone,followed by the second stage placing cement from the top of the first stage to the original proposed cement top. The 15t stage would be+/-800' in length,followed by 3500'ft, basically we're not changing the coverage from the PTD, just how we get the cement in there and do our best to make sure we get the lift needed to achieve proper top of cement. If there are objections to this plan, or additional documents you may require please let me know. Thanks Scott 2 • 0 Loepp. Victoria T (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Wednesday, May 04, 2016 4:36 PM To: Loepp,Victoria T(DOA) Subject: Packer and Frac Port Depths Attachments: 3S-613 Schematic Rev#4- 2 stage cement.pdf Victoria, Hope you're doing well. It was good chatting with you today. I have attached the latest schematic. Please let me know if you have any questions. Approximate depths: Packer depth=10,900'MD First Frac port= 11,500' MD Distance between them=600' Sandeep Pedam Completions Engineer ConocoPhillips Alaska Cell:512-507-9537 Office:907-263-4724 1 • Loepp, Victoria T (DOA) From: Bettis, Patricia K(DOA) Sent: Friday,April 29,2016 12:40 PM To: Loepp,Victoria T(DOA) Subject: FW:3S-613 PTD 216-020 Attachments: 3S-613 Schematic Rev#4-2 stage cement proposal.pdf Follow Up Flag: Follow up Flag Status: Flagged From: Brunswick,Scott A[mailto:Scott.A.Brunswick@conocophillips.com) Sent: Friday,April 29,2016 11:36 AM To: Bettis,Patricia K(DOA)<patricia.bettis@alaska.gov> Cc:Schwartz,Guy L(DOA)<guv.schwartz@alaska.gov>; Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com>; Alvord,Chip<Chip.Alvord@conocophillips.com> Subject:3S-613 PTD 216-020 Patricia We entered the Moraine formation on 3S-613(PTD 216-020)this morning. We were drilling with a 9.2 ppg mud due to predicted low formation pressure. After entering the Moraine with 10.5 ppg ECD at 11020' MD,we encountered dynamic losses of 40 bbl/hr. We pumped a LCM pill reducing the losses to 20 bbl/hr. We called TD at 11090' MD to set casing into the Moraine formation. While we have been circulating the hole clean for the trip out of the hole,the dynamic losses have gone to zero with wall cake&LCM treatments. I would like to check to make sure the AOGCC is OK with my plan forward to change from a single stage cement job to a two stage job so I can make sure we get good cement in the 7-5/8"OA. The initial plan was a single 4300'column of cement to place cement top at least 500'above the K-3 formation. After seeing the losses this morning,and based on updated cement modelling using what we have seen,the best path forward is to pump a two stage job covering the loss zone,followed by the second stage placing cement from the top of the first stage to the original proposed cement top. The 1St stage would be+/-800' in length,followed by 3500'ft, basically we're not changing the coverage from the PTD, just how we get the cement in there and do our best to make sure we get the lift needed to achieve proper top of cement. If there are objections to this plan,or additional documents you may require please let me know. Thanks Scott 1 • • PrZ Q162. -oa. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue Anchorage,Alaska 99501 Re: THE APPLICATION OF ) Docket CO-16-004 ConocoPhillips Alaska, Inc. for an ) Conservation Order No. 722 exception to the spacing requirements ) Kuparuk River Field of 20 AAC 25.055(a)(3) to drill and ) Kuparuk River Unit complete a water injection well within ) Torok Undefined Oil Pool the same governmental quarter section ) Kuparuk River Unit 3S-613 as wells that are, or may be capable of, ) Water Injection Well producing from the same pool ) North Slope Borough, Alaska ) March 14, 2016 IT APPEARING THAT: 1. By letter received February 10, 2016, ConocoPhillips Alaska, Inc. (CPA!) requested an exception to the spacing provisions of 20 AAC 25.055(a)(3) to drill and complete water injection well Kuparuk River Unit (KRU) 3S-613 within the same governmental quarter section as wells that are, or may be capable of, producing from the same pool. 2. Pursuant to 20 AAC 25.540, the Alaska Oil and Gas Conservation Commission (AOGCC) tentatively scheduled a public hearing for March 17, 2016. On February 12, 2016. the AOGCC published notice of the opportunity for that hearing on the State of Alaska's Online Public Notice website and on the AOGCC's website, electronically transmitted the notice to all persons on the AOGCC's email distribution list, mailed printed copies of the notice to all persons on the AOGCC's mailing distribution list, and published the notice in the ALASKA DISPATCH NEWS. 3. Pursuant to 20 AAC 25.055(d)(1), CPAI sent by certified mail notice of the application to all owners, landowners, and operators of all properties within 1,000 feet of the KRU 3S-613 injection well, i.e., CPAI, BP Exploration (Alaska) Inc., Chevron USA Inc., ExxonMobil Alaska Production Inc., and the State of Alaska. CPAI provided the AOGCC the notice, date of mailing, addresses to which the notice was sent, and copies of the certified mail return receipts. 4. No comments on the application nor request for hearing were received. 5. Because CPAI provided sufficient information upon which to make an informed decision, the request can be resolved without a hearing. 6. The tentatively scheduled public hearing was vacated on March 8, 2016. • CO 722 March 14, 2016 Page 2 of 3 FINDINGS: 1. CPAI is a working interest, owner in, and operator of, the KRU that is located in the North Slope Borough, Alaska. 2. KRU 3S-613 is a proposed water injection well with an onshore surface location of 2,514 feet from the north line and 1,051 feet from the east line of Section 18, Township 12 North, Range 8 East, Umiat Meridian (U.M). The onshore bottom-hole location is 2,136 feet from the north line and 158 feet from the east line of Section 11, Township 12 North, Range 7 East, U.M. 3. The surface location of KRU 3S-613 will lie within State of Alaska oil and gas lease ADL 380107, and the horizontal productive portion of the well will lie within State of Alaska oil and gas leases ADL 25544 and ADL 25528. 4. KRU 3S-613 will target the oil-bearing Moraine sandstone within the Torok Undefined Oil Pool. 5. Development oil well KRU 3S-19 is capable of producing from the Torok Undefined Oil Pool within the same governmental quarter section as planned water injection well KRU 3S- 613. The well is completed in the Torok Undefined Oil Pool, but currently a selective sleeve is closed, preventing production from the interval. 6. Development oil well KRU 3S-620 currently produces from the Torok Undefined Oil Pool within the same governmental quarter section as planned water injection well KRU 3S-613. 7. KRU 3S-613 will provide injection support to oil producer KRU 3S-620 for enhanced oil recovery. 8. The AOGCC received no comments, objections or protests in response to the public notice regarding the proposed exception to the spacing requirements of 20 AAC 25.055 for KRU 3S-613 or to the notification sent by CPAI to all known owners, landowners, and operators within 1,000 feet of KRU 3S-613. CONCLUSIONS: 1. An exception to the well spacing provisions of 20 AAC 25.055(a)(3) is necessary to allow the drilling and completion of KRU 3S-613 in the Torok Undefined Oil Pool. 2. KRU 3S-613 will provide injection support to oil producer KRU 3S-620. 3. Drilling KRU 3S-613 in conformance with statewide spacing requirements would reduce the effectiveness of the well performance and enhanced oil recovery for the Torok Undefined Oil Pool. 4. Granting a spacing exception to the well spacing provisions of 20 AAC 25.055(a)(3) for the KRU 3S-613 is consistent with sound engineering and geoscience principles and will not result in waste or jeopardize correlative rights of adjoining or nearby owners. • CO 722 March 14,2016 Page 3 of 3 NOW THEREFORE IT IS ORDERED: AOGCC grants CPAI's February 10, 2016 application for an exception to the well spacing provisions of 20 AAC 25.055(a)(3) to allow the drilling and completion of the KRU 3S-613 water injection well within the Torok Undefined Oil Pool. CPAI may proceed as long as it complies with the terms of all lease agreements, applicable Alaska laws, and all other legal requirements. DONE at Anchorage, Alaska and dated March 14, 2016. tI t'- //signature on file// //signature on file// . Cathy P. Foerster Daniel T. Seamount, Jr. Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of'this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. ih AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and die denial of reconsideration are FINAL and may he appealed to superior court. The appeal MUST be tiled within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 41)days atter the date on which the application for reconsideration was filed, If die AOGCC grants an application for reconsideration, this order or decision does not become final, Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails. OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration As provided in AS 31.05.080(h),"Nhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default atter which the designated period begins to nm is not included in the period; the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • PrD OZO Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, March 01,2016 3:36 PM To: Loepp,Victoria T (DOA); Quick, Michael J (DOA) Subject: RE: 3S-613 Moraine: New Completion Follow Up Flag: Follow up Flag Status: Flagged No problem... stabbing into a seal bore is same function as a packer. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Loepp, Victoria T(DOA) Sent:Tuesday, March 01, 2016 2:48 PM To: Schwartz, Guy L(DOA); Quick, Michael J (DOA) Subject: FW: 3S-613 Moraine: New Completion Guy, Mike, Any comments on this completion?We have approved this type of completion at Alpine. Thanx, Victoria From: Bettis, Patricia K(DOA) Sent: Tuesday, March 01, 2016 2:23 PM To: Loepp, Victoria T(DOA) Subject: FW: 3S-613 Moraine From:Shultz,Steve(Orbis Engineering, Inc.) [mailto:Steve.Shultz@contractor.conocophillips.com] Sent:Tuesday, March 01,2016 2:22 PM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Cc:Pedam,Sandeep<Sandeep.Pedam@conocophillips.com> Subject:3S-613 Moraine Patricia, 1 My completions engineer would like to change the design for Moraine 3S-613 to a packerless completion. The present plan calls for a 41/2" horizontal liner with frac sleeves through the Moraine and a liner hanger with a ZXP for isolation. The permit I submitted has a packer on the 4'A" production tubing which was to be set right above the liner top. We would now like to forego the packer and run a seal assembly which would stab into an SBE integrated into the liner hanger. The Alpine and the Sharks Tooth developments have changed to a packerless completion design with no adverse effects,and therefore we would like to follow suit. I have included a schematic. Thanks you, Steve Shultz Drilling 263-4297 2 .vOF Tit Ork THE STATE Alaska Oil and Gas �, of Conservation Commission s ALASKA f }£: 1� 333 West Seventh Avenue k,, r►,� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Ol ALASY'14. Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-613 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-020 Surface Location: 2514.3' FNL, 1051.7' FEL, Sec. 18, T12N, R008E, UM Bottomhole Location: 2136.7' FNL, 158.3' FEL, Sec. 11, T12N, R008E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Conservation Order 722 issued March 14, 2016 granting spacing exception to well spacing provisions of 20 AAC 25.055(a)(3). 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this 1 day of March, 2016. TRECEIVED STATE OF ALASKA A A OIL AND GAS CONSERVATION COMM ON JAN 2 8 2015 PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Drill Li- Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj L • Single Zone 0. Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil LI Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket D. Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180' KRU 3S-613 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 15782', TVD: 5217'• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 2514.3 FNL,1051.7 FEL,Sec 18,T12N,R8E,UM • ADL 25528,ADL 25544,ADL 380107 • Kuparuk River Field/Torok Undefined Oi Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1238.9 FNL,4297.2 FEL,Sec 13,T12,R7E,UM ' 4624,2639' 3/1/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2136.7 FNL,158.3 FEL,Sec 11,T12N,R7E,Urn • 7568 >1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): . 66.7 15.Distance to Nearest Well Open Surface: x- 476208 y- 5993901 Zone-4 . GL Elevation above MSL(ft): . 27.7 to Same Pool: 1450 16.Deviated wells: Kickoff depth: , 360 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 90 degrees Downhole:Wei 10 psig Surface: 10 psig /US 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) 24 16 164.8 B-35 welded 81 surface surface I 120 120 Driven 13 1/2 10 3/4 45.5 L-80 Hydril 563 2858 surface surface 2897 2567 1310 sx 11.0 ppg LiteCRETE Lead, 195 sx 12.0 ppg LiteCRETE tail 9 7/8 7 5/8 29.7 L-80 Hydril 563 11212 surface surface 11251 5187 1190 sx GasBLOK 15.8 ppgClass G 6 3/4 4 1/2 12.6 L-80 IBTM 4681 11101 15782 5217 Uncemented Liner 6 3/4 4 1/2 12.6 L-80 IBTM 11100 surface surface 11100 5174 Production Tubing 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 D Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch 1=1 Seabed Report ❑ Drilling Fluid Program LJ 20 AAC 25.050 reequirements0 21. Verbal Approval: Commission Representative: Date %/.26/016 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Steve Shultz @ 263-4297 ._5711,.5 Email Steve.Shultz@contractor.cop.com Printed Name G.L.Alvord Title Alaska Drilling Manager Signature , } -ot,&_ Phone 265-6120 Date i(' (2o(Co Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other t� Number: 'c- o o 50-)03 O 3L -O0-O( Date: 7,- k6-kl.t. requirements. ,\ Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan ,gas hydrates,or gas contained in shales: L✓J Other: d a p fie5/ pr-i'S5 vre Is_ 3 TOO n5 t\ Samples req'd: Yes El Nog' Mud log req'd:Yes❑ No01 4 - i)m V'P pre. vt-F s 1-e-51- fo 2 f zS neasures: Yes iNo❑ Directional svy req'd:Yes No❑ No t'll j ems'On Elle 1• 91 yv it T 0 V qn Spacing exception req'd: Yes V No❑ Inclination-only svy req'd:Yes❑ Nog :A u ec1-l'(� Q/-t CLQ C: Post initial injection MIT req'd:Yes No❑ APPROVED BY Approved by: -3//5//j COMMISSIONER THE COMMISSION Date:3-1 5' 4, P&6 -. 1i4-1/° .04 ,4oj,.6 OiI31rIGI1vftf4Ionths Subs in Form ane Form 10-401(Revised 1112015) from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • S Post Office Box 100360 1"1OcC i1iiii Anchorage,Alaska 99510-0360 Phone(907)263-4297 Email: steve.shultz(&contractor.conocophillips.com January 20,2016 RECEIVED IVE Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 JAN 2 8 2015 Anchorage,Alaska 99501 Re: Application for Permit to Drill 3S-613 CC Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 3S-613 from the 3S drill site. This well is intended to be an injection wellin the Moraine horizon in support for the 3S-620 well drilled last year. The intended spud date for this well is March 1st ,2016 using Doyon 141. / When the Doyon 141 moves onto 3S-613,the proposed plan is to nipple up and test the diverter system utilizing the existing 16"conductor, spud the well with a 13'W'bit, drill to the surface casing point,then run and cement the 103/4"45.5#L-80 Hydril 563 surface casing in place. A 9%" bit will be made up and the surface casing drilled out. The well will be drilled down to the intermediate casing point where a string of 7%"29.7#L-80 Hydril 563 casing will be run and cemented in place.A 63/4" bit will be made up and the intermediate casing drilled out and a horizontal lateral will be drilled to TD. Once the drill string is pulled, a 4'/2" production liner with swell packers and frac sleeves will be slid in position for future frac operations.The final upper completion will consist of 41/2"tubing complete with gas lift equipment. Please find attached the information required by 20 ACC 25.005 (a) and (c)for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. Cementing Program 8. Diverter placement and orientation Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Steve Shultz at 263-4297. Sincere) , ////i Sikpy Shultz Drilling Engineer Attachments • Alation for Permit to Drill,Well 3S-613 Saved: 25-Jan-16 3S-613 Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 3 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 (Requirements of 20 AAC 25.005 (c)(14)) 8 3S-613 APD Page 1 of 14 Printed:25-Jan-16 • A�ation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Position and Orientation 3S-613 APD Page 2 of 14 Printed:25-Jan-16 • Aation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 3S-613. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3S-613 is planned as a horizontal grass roots injector to support the offset well 3S-620. The rig will drill a 13W surface hole which will be cased off with 103/" casing with premium connections. The 9%" intermediate section will be drilled into the top of the Moraine Sand where a string of 7%" casing will be run and cemented in place. A 63/4" bit will then be run to drill the horizontal portion of the well followed up with a 4W production liner(uncemented), equipped with swell packers and frac sleeves. Finally, a 4W gaslift tubing assembly will be run for the upper completion. Location at Surface 2514.3' FNL, 1051.7' FEL, Sec 18, T12N/R8E, UM NAD 1927 RKB Elevation 66.7'AMSL Northings: 5,993,901.19 Eastings: 476,207.90 Pad Elevation 27.7'AMSL Location at the 7%" Shoe 1238.9' FNL, 4297.2' FEL, Sec 13, T12N, R7E, UM NAD 1927 Measured Depth, RKB: 11,251' Northings: 5,995,206.4 Eastings:468,161.8 Total Vertical Depth, RKB: 5,187' Total Vertical Depth, SS: 5,120' Location at Total Depth 2,136.7' FNL, 158.3' FEL, Sec 11, T12N, R7E, UM _(Toe) NAD 1927 Measured Depth, RKB: 15,782' Northings: 5,9999593.1 Eastings: 467037.0 Total Vertical Depth, RKB: 5,217' Total Vertical Depth, SS: 5,150' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) Represents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Csg Setting Fracture Pore ASP Size Marker Depth Gradient pressure Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 Surface 120/ 120 10.9 54 68 103/4 100' TVD 2,897/2,567 13.9 1,143 1;2-76" 15-1 over C-80 7% Moraine 11,251 /5,187 13.5 2,350 2>-65Y®" 23 4% Moraine 15,782/ 5,217 13.5 2,350 ,660-' !826 • Pore pressures above the Moraine calculated with a seawater gradient of 8.6 ppg • NOTE: The Doyon 141, 5000 psi BOP equipment is adequate. Testing BOPE to 3500 psi. v" 3S-613 APD Page 3 of 14 Printed:25-Jan-16 Ap-ation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A)ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)-0.1]D Where: ASP =Anticipated Maximum Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP = [(FG x 0.052) -0.1] D = [(10.9 x 0.052)-0.1] x 120' = 68 psi z, OR ASP = FPP-(0.1 x D) =1,143-(0.1 x 2,567') = 886 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052)-0.1] D = [(13.9 x 0.052)-0.1] x 2,567' = 1,599 psi. OR ASP = FPP-(0.1 x D) =2,350- (0.1 x 5,187') = 1,831 psi 3. Drilling below intermediate casing (7-5/8") ASP = [(FG x 0.052)-0.1] D _ [(13.5 x 0.052)-0.1] x 5,187' = 3,140 psi OR ASP = FPP-(0.1 x D) =2,350-(0.1 x 5,217') = 1,828 psi / (B) Data on potential gas zones; The well bore is not expected to penetrate any gas zones. (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; Only 3S-620 has produced from the Moraine formation, as such the formation pressure is expected to be virgin pressure of approximately 2,350 psi or 8.7 ppg MWE. ✓ The majority of wells drilled in the 3S region were in search of hydrocarbons in the Kuparuk sands below. Only two wells have been drilled and completed in the Moraine (3S-19 and 3S-620). 3S-19 was drilled as a vertical producer in December of 2012 and 3S-620 was drilled as a horizontal producer last year. Since no injection has been initiate into the Moraine, the formation pressure should still be in virgin territory at 23 .0 psi or -8.7 ppg MWE.'Looking at these wells and all the other wells drilled from the 3S pad, there appears that no substantial problems occurred while drilling to and through the Moraine. Any well problems in this area occurred below the Moraine in the HRZ and Miluveach formations. / 3S-613 APD Page 4 of 14 Printed:25-Jan-16 • Ap 'ation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 164.8 B-35 Welded 81' Surf 120'/120' Driven Hydril Cemented to Surface with 10/4 13% 45.5 L-80 563 2,858' Surf 2,897'/2,567' 1310 sx 11.0 ppg LiteCRETE Lead 195 sx 12.0 ppg LiteCRETE tail Hydril Cement Top planned @ 6,750'MD/ 7% 9% 29.7 L-80 563 11,212' Surf 11,251'/5,187' 3,908'TVD. Cemented w/ 1190 sx GasBLOK 15.8 ppgClass"G" 4% 6% 12.6 L-80 IBTM 4,681' 11,101' 15,78275,217' 41/2 12.6 L-80 IBTM 11,100' Surf 11,100'/5,174' Production Tubing Casing / Liner Design: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 103/" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7%" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 4%" 12.6 C-110 3 Hyd521 9,200 psi 7,820 psi 11,590 psi 9,852 psi 4W 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 7,700 psi 6,545 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Doyon 141. 3S-613 APD Page 5 of 14 Printed:25-Jan-16 Ap _ation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: Surface Intermediate Production 131/2" hole 9'/8" hole 61/2" hole 103/4" Casing 75/8" Casing 41/2" Liner Spud Mud LSND KIa-Sheild Density 9.6 - 10 ppg 9.6— 10.0 ppg 9.6-10.0 ppg YP 60 - 80 18—28 18 -28 Funnel Viscosity (sec) 75—250 40 - 55 45 -55 PV 20 -60 20 -25 20 -25 Initial Gels 10 -35 4—8 5 - 9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160°F 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.6 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. Maintain mud weight above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: LSND/KLASHIELD water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. Maintain minimum mud weight of at least 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 141 Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 3S-613 APD Page 6 of 14 Printed:25-Jan-16 • *tion for Permit to Saved:Drill,Well15-M3Sar-16-613 1. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 2. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 141 on 3S-613 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs out on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor(-250')to get 13W bit and BHA below ground level. 5. Spud and directionally drill 13%' hole to the 10-3/4" surface casing point(2,897' MD/2,567' TVD) according to the directional plan. Run MWD/ LWD logging tools in drill string (GR/RES/PWD/Gyro while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10%' 45.5# L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in BOP's and pressure test surface casing to 3,000 psi as per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT to a minimum of 12.5 ppg MWE. 10. Directionally drill 9%" intermediate hole to 11,251' MD/5,187' TVD into the Moraine formation. Run MWD/LWD logging tools (GRIRES/NEUT/DENS/PWD)with on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe, .flange out one set of pipe rams on the BOPE to rams for 7 5/8" casing. 12. RU and run 7-5/8", 29.7#, L-80 Hydril 563 connections on the intermediate casing to 11,251' MD/ 5,187' TVD and cement in place with a minimum of 500' of cement above the K-3 formation (TOC @ >6750'MD). 13. MU 6%" bit and RIH on 4" drill pipe, test 7 5/8" casing to 3000 psi, drill out and perform FIT to 16.0 ppg MWE with a minimum of 13.5 ppf MWE.. 14. Directionally drill a 6%" hole to 15,782' MD/5,217' TVD. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Microscope/ iinic tool)for navigational monitoring and formation data gathering ,Sonic tool to be used to evaluate the 7 5/8" cement) 15. POOH and RU casing crew. 16. MU and run a 4'/" liner as follows: a. 4'/2" shoe (orange peel) b. 4'/2", 12.6#, L-80, BTCM liner(+1-4,582') with swell packers and frac sleeves c. Liner hanger 17. Once on bottom, circulate, then drop ball in drill pipe, circulate, land ball in seat. 18. Pressure up and set liner hanger, continue to pressure up and release the running tool from the liner hanger. 3S-613 APD Page 1 of 14 Printed: 15-Mar-16 • *ration for Permit to Saved:Drill,Well15-Ma3S-613r-16 19. Pick up 30 feet to expose setting dogs, slack off on drill string until setting dogs engage liner top, set down to set the ZXP liner top packer on top of the liner hanger. 20. PU 10 feet on drill pipe without pulling the seals out of the RS nipple and pressure test liner top packer, change over well to brine, POOH and LD 4" drill pipe 21. Run 4W completion tubing with gas lift mandrels, TEC gauge, DB nipple and seal assembly. RIH with 4 1/2" completion tubing and stab seal assembly into PBR located in the liner hanger at-11,100'MD 22. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out. 3. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AA C 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled 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. 4. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Position and Orientation 3S-613 APD Page 2 of 14 Printed: 15-Mar-16 • Ation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 141 on 3S-613 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs out on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor(-250') to get 13W bit and BHA below ground level. 5. Spud and directionally drill 13W hole to the 10-3/4" surface casing point (2,897' MD/2,567' TVD) according to the directional plan. Run MWD/ LWD logging tools in drill string (GR/RES/PWD/Gyro while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10%' 45.5# L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in BOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9'/8" intermediate hole to 11,251' MD/5,187' TVD into the Moraine formation. Run MWD/LWD logging tools (GR/RES/NEUT/DENS/PWD)Kwith on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#, L-80 Hydril 563 connections on the intermediate casing to 11,251' MD/ 5,187' TVD and cement in place with a minimum of 500' of cement above the K-3 formation (TOC @ >6750'MD). 13. MU 6%" bit and RIH on 4" drill pipe. 14. Directionally drill a 6%" hole to 15,782' MD /5,217'TVD. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Microscope) for navigational monitoring and formation data gathering. 15. POOH and RU casing crew. 16. MU and run a 4'/2" liner as follows: a. 4'/2" shoe (orange peel) b. 4'/", 12.6#, L-80, BTCM liner(+/-4,582')with swell packers and frac sleeves c. Liner hanger 17. Once on bottom, circulate, then drop ball in drill pipe, circulate, land ball in seat. 18. Pressure up and set liner hanger, continue to pressure up and release the running tool from the liner hanger. 19. Pick up 30 feet to expose setting dogs, slack off on drill string until setting dogs engage liner top, set down to set the ZXP liner top packer on top of the liner hanger. 20. PU 10 feet on drill pipe without pulling the seals out of the RS nipple and pressure test liner top packer, change over well to brine, POOH and LD 4" drill pipe 3S-613 APD Page 7 of 14 Printed:25-Jan-16 1 A tion for Permit to Drill,Well 3S-613 Saved:25-Jan-16 21. Run 4W completion tubing with gas lift mandrels, premier packer and seals. Set packer at+/- 11,090' MD/ 5,174' TVD. 22. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 1' (Requirements of 20 AAC 25.005 (c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1 B).✓All cuttings generated will be hauled 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. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Position and Orientation 3S-613 APD Page 8 of 14 Printed:25-Jan-16 Action for Permit to Drill,Well 3S-613 Saved:25-Jan-16 Attachment 2— Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 3S-613 Drilling Hazards Summary 131/2" Hole 1103/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Gravel /Sand Sloughing Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 9'/8" Hole / 7%" Casing Interval Event Risk Mitigation Strategy Level Campanian Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 63/4" Hole / 41/2" Horizontal Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 3S-613 APD Page 9 of 14 Printed:25-Jan-16 • Action for Permit to Drill,Well 3S-613 Saved:25-Jan-16 Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. A separation factor(or proximity ratio) using the ratio of center-to-center distance divided by the combined ellipses of uncertainty between two wellpaths is used to determine wellbore collision risk. A ratio of greater than 1.0 indicates two different well path ellipses of uncertainty do not touch. The traveling cylinder plot is used on the rig to keep track of the wellpath position relative to close approaches to offset existing wellbores. In the event that the wellpath falls behind the curve, drilling is stopped and the motor bend can be increased or the survey frequency can be increased. In general, no significant clearance issues exist with the 3S-613 well plan. Drilling Area Risks: Reservoir Pressure: The Moraine formation has not been exploited as of yet and therefore no injection of any kind has been implemented for secondary recovery. The formation pressure is still at virgin pressures and should not pose a problem for the drilling of this well. Lower Shale Stability: Unstable shale and ash in the intermediate could require higher mud weights to stabilize due to the high hole angle required to drill the well. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of surging or swabbing the formation. 3S-613 APD Page 10 of 14 Printed:25-Jan-16 . . ! 1 - ) \\) 2 !f ✓ - ° ! ® g E )�\o !$ | ) §.%�\j\\ • )); |+f# # A = 2!{7 ■ ! ) !I ƒ) §f ) k:7"' 27. // • H a) - 7 % } \ 2 {( \ 7 *1 a) El 4- BE �r k a) k � ) � k k El 2]\ Ja !T3 02 &! § \ B • 2 ) J • Loepp, Victoria T (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Thursday, February 11, 2016 9:54 AM To: Loepp,Victoria T (DOA) Subject: Emailing: 1.7.16 AOR Spreadsheet.xlsx Attachments: Moraine#1 Permanent Abandonment Schematic_Final.pdf; 1.7.16 AOR Spreadsheet.xlsx Follow Up Flag: Follow up Flag Status: Flagged Morning Victoria, I have filled out the spreadsheet for Moraine#1. This well had surface casing set to 2485'MD and cemented to surface. We drilled out and then cored from 5100'MD to 5306'MD. The well was then permanently abandoned with a series of cement plugs,a retainer and a bridge plug. See attached. Steve 1 Moraine #41ermanent Abandonment • ConocoPhillips Kup Tarn Gen V Brunswick 3/20/15 16"Conductor: RKB 28 ft N9E ' 16"62.6#H-40 Cement Laid on Top of Bridge Plug w/11 ppg ALC to Surface 114'MD .1 , Cap must be a minimum of 150 ft-laid in cement to surface Bridge Plug Set @-508' Build to 15.97°@ 29.22°drop back to 0°by surface casing point •,a Cement Laid on Top of Retainer w/15.8 Class G f/2,400'to 2,300' 96°y4 Cap above retainer must be @ least 50' Must be tested to 1500 psi minimum&24 hours notice to AOGCC Total of 3.5 bbl above retainer Surface Casing: Cement Retainer Set @-2,362'(no less than 50'&no more than 9-5/8"40#L-80 HYD563 100'above casing shoe) 2,485.21'MD/2,441'TVD @ 0° A L. Squeezed P&A Plug w/15.8 Class G fi 2,600'to 2,400' Volume of cement must be able to fill @ least 100'below the casing shoe Total of 31 bbl squeezed below retainer 4 a g690 P&A Plug#3 w/15.8 Class G fl 4,410'to 3,687'(tag depth) K-3/Top Coyote 4128'MD/4084'SSTVD Top plug must be at minimum 100'above all hydrocarbon bearing formations,&tagged with AOGCC 24 hour notice to • -. witness K-3/Coyote Hydrocarbon Possible P&A Plug#2 wi 15.8 Class G f/5,010'to 4,410' Moraine Top 5150'MD 5107'SSTVD P&A Plug#1 w/15.8 Class G f/TD @ 5,610'to 5,010' 7777 :.:...........Moraine Predicted Pore Pressure:8.7 ppg Moraine Bottom 5387'MD 5302'SSTVD Total Death 5.610'MD @ 0° i- z" open Noir • • Loepp, Victoria T (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday, March 01, 2016 2:23 PM To: Loepp,Victoria T(DOA) Subject: FW: 3S-613 Moraine Attachments: 3S-613 Schematic Rev#3.pdf Follow Up Flag: Follow up Flag Status: Flagged From:Shultz,Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz@contractor.conocophillips.com] Sent:Tuesday, March 01,2016 2:22 PM To: Bettis,Patricia K(DOA)<patricia.bettis@alaska.gov> Cc: Pedam,Sandeep<Sandeep.Pedam@conocophillips.com> Subject:3S-613 Moraine Patricia, My completions engineer would like to change the design for Moraine 3S-613 to a packerless completion. The present plan calls for a 41/2" horizontal liner with frac sleeves through the Moraine and a liner hanger with a ZXP for isolation. The permit I submitted has a packer on the 4 36" production tubing which was to be set right above the liner top. We would now like to forego the packer and run a seal assembly which would stab into an SBE integrated into the liner hanger. The Alpine and the Sharks Tooth developments have changed to a packerless completion design with no adverse effects,and therefore we would like to follow suit. I have included a schematic. Thanks you, Steve Shultz Drilling 263-4297 1 Grass Root�'Iorizontal Multi-Stage Frac'd Producer • Final Wellbore Schematic ConocoPhillips LFMC 4-1/2"tree,top joint is 4-W 12.6#IBTM,crossed over(for frac equipment) l New Existing Conductor: 16"62.6#HW© 120' pud Mud ).2 PPG 13-1/2"Surface Hole 4'h"x 1"KBMG with Dummy(-2,500'TVD;54 deg incl) J11 Surface Casing; L..._.. iir.' 10 3/4"45.5#L 80 Hydril 563 2,897'MD/2,567'TVD @ 46° Campanian Top 3,381'MD(2,752'-Ric 9-7/8"Intermediate Hole Tubing; 4-1/3"12.6#L-80 IBTM SND 2 PPG Top of cement above 6,750'MD (a minimum of 500'MD above the K-3) :eep up with Dilution 4%"x1"KBMG TVD 111-1 with SOV(-4,500 TVD;70 deg incl) SLB Gauge Carrier Camco 06 Nipple 3.812"nogo HRD-E ZXP W/HD's 5'/>"x7%"L-80 for 29.70 cog 5-112" 170 Hydril 563 ph down(Baker);RS Nipple 7.63"L-80 5-1/ 2"170 Hyd 563(Baker);Flex-Lock 51/:"x 7%"L-80,Fhx Lock Hanger HYD 563 ph by pin(Baker);Baker 80-47 Sealbore Extension 20ft,51/2"17#HYD 563 box x pin; Intermediate Casing Set into the Moraine; 7-5/fj"?9 7#4-80-all Hyr�ry'1 563 rpnnPrti9r.W. . : :11 .1 : .•.7r : . .. . • ,25. .MOit:6, ar:....Q 9E1i::: , ..:::PIt:4?dl!Ct• :..P:R...... 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E5:7 MI] iT Tip • Apation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 Attachment 3— Proposed Well Schematic Grass Roots Horizontal Mutti-Staqe Frac'd Producer Final Wellbore Schematic `OI'lOC(3�` lrf i1fl' J FMC 4-W tree,tap joint c4-',4'12.t4 IQThI,crossed e•.=s if,.fra:: I — equipments I LNew stiur 16"62.6Exiak HWng Conductor cto Spud Mud 2 PPG 3!4"Cameo De Nipple 1275' 1111 eOeuD 13-112"Surface Hole I� A 4!S"11'1421MG wen tummy Surface Casing: 10-314"45.5#L-80 Hydril 563 — 2,897'MD/2,567+TVD @ 46' 4K'=1'=FAG !fill Cummr gil 4!,,,"Y 1'KBMG Wth Dummy 9-718" Intermediate Hole Tubing: 4-'.�i" 12.6#L-601STM 4y;•a1"r[HMG ej watt,Dummy br cement above 4,750'MD '111!Imum of 50t'MD above the K-3) .hI s .441.'sarly"KOMG TO D MA GtUell*Wen 'r 7.51'.fere P-e-nr Picker 4':r'Cameo DB 4114444 181Z'n• —T .... -TS°a 4.1,V Bayer Roc Lata Liner hanger i __ Z}F Ih4 Fad e 1n?Mole Intermediate Casing Set into the Moraine; 4 7-518"29.7*t-80-al)Hydril 563 connections . ?t1; s'I'MD f 5,987':1VD: 0D° Fa4 4": .t0t.:(ja ietRo1& Tepotfw•raiiela:i7'MDS,18 ?JD : : : : :: ;. ::::::::::: ::::::: ::: ' k .N'O..::.:•:.::::•iii :• :*•.::.:... ..... ...:•. :. . . . . .0 . Hi M 1111 • A...... : iaastiiA35b •:.:1 action. er: in o:. is O:::: • : :::::::::: : : : : ::::::::::::::: : :.14,10fpA?ti .... .....'i1 .,....::::::................................ : ::T i::::::::::::::::::::: : : :: ::.i:•::.:.: : ::::::: .;. .:. . . .:. .: .•. :::.:15;78 `rNDt:5421.7..T1fQ... . . . . . . . .,.-. . 3S-613 APD Page 11 of 14 Printed:25-Jan-16 • Aation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 Attachment 4—Cement Summary 103/4" Surface Casing Cement Job Cement 10%"casing from shoe @ 2,897' MD to 1,612' MD with 12 PPG LiteCrete,and from 1,762'to surface with 11 PPG Arctic LiteCRETE. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(Base Perm is 1,751'MD),zero excess in 16"conductor. Lead Slurry: 1.339 ft3/ft X 110=148 ft3 0.3637 ft3/ft X(1612-110)X 3.50(250%excess)= 1,912 ft3 0.3637 ft3/ft X(2,397-1,612)X 1.50(50%excess)=428 ft3 Total volume=148 ft3+ 1.,912 ft3+428 ft3=2,488 ft3=>1303 Sx @ 1.91 ft3/sk System: "'1310 Sx Arctic LiteCRETE @ 11 PPG (443 bbls) Tail Slurry: 0.3637 ft3/ft X 2897-2397)X 1.5 (50%excess)=273 ft3 0.540 ft3/ft X 80ft(Shoe)=44ft3 Total volume=273 ft3+43.2 ft3=317 ft3=> 195 Sx @ 1.63 ft3/sk System: 195 Sx LiteCRETE @ 12 PPG (56 bbls) 75/8" Intermediate Casing Cement Job Cement 7%" casing from shoe @ 11,251' MD to 6,750' MD(minimum of 500' above the top of the K-3 with 15.8 PPG Class G w/GasBLOK.Assume 40%excess in the open hole volume. Slurry: 0.2148 X(11,251'—6,750')x 1.40(40%excess) =1354 ft3 in open hole 80'shoe track x 0.258 ft3/ft x 1.0(0%excess)=20.6 ft3 Total volume=1354 ft3+20.6 ft3= 1374 ft3=>1184Sx @ 1.16 ft3/sk System: 1190 Sx Class G @ 15.8 PPG (245 bbls) 3S-613 APD Page 12 of 14 Printed:25-Jan-16 • AAation for Permit to Drill,Well 3S-613 Saved:25-Jan-16 Attachment 5 - Diverter Orientation ConocoPhillips Q t''?'' t c... r I. • .a 7 3S-61 ` . r n--.'CY) x Y w • a ,:),T-'3't��S d,S' y� 0 a 10 e 4y. } k Ufa a sk' t ' A .,,.,..-.._.. . .,,,., 051-t g.11 50$ ., _ aR* c , ti•p' .i!....:, L. Og5515512b i S4 4 • r X4,1` 3S-613 APD Page 13 of 14 Printed:25-Jan-16 II- • II 3S-613wp06 Permit Pack Plan Summary -WS_TOP kku_possible_fault_crossing_2 a 5_ �WS_BASE -5 • ` CAMP_SST \ kku_possible_fault_crossing ati Erase Permahost`\ .' II _ � � TOP_MORAINE ice. . K-3(Top CGYgte) N 1 o, _ .� 1 BAS�_COYOT° in i C-50 `\ I kku_possible_fault crossing 1 l v 0 I I I ,1 I I I I ' I 1 I i 1 -1 I I 1 I 1 I 0 ' 1 1 \SII!• '0 350 7000 105001 14000 16"x 42' 110 3/4"x 13-1/ Measured Depthl- 7 5/8"x 9-7/8' All.....- p 0_'0a-16"x 421 Depth Reference: Plan:39+27.7 @ 66.70usft(Doyon142) 1®QORig: Doyon142 2O I10 3/4'x 13-14 w a o 0 1775/8"x 9-7/81 14 1/2"x 6-3/41 0 0 0 o 4�°vpo I o en renal 1 ci 1 1 I I I I 1 f ii i i i I i I i a, i I v 1 I ` 39 360 0 1500 3000 45001 6000 7500 90000 1000 01200 1500 0 380 - 550 Horizontal Departure 330 "� 1 0„ 0 550 - 740 01111r11°'. 740 - 930 ri Irl r I �� �• 4� ..p��,'� 930 - 1120 o �� 111 x�,.` �`,�w E� 1120 - 1320 It]60 ' \\s \ -- 300 :r D� �< a't11 4 i`0 ,1 60 1320 - 1510 n \ y'., 38-1' __� �7.e%9 ,k,=.1 pa: 2,'1,6 �4yi;ate 1510 - 1700 1700 - 2290 i2 1 E. \ ` \•36-..,, �a,ln�Y 1 `\�'° @ °�4 2290 2880 U 30 CI. \ .__ IIIII v-.06"4$1,6/f ' °`„,..::,11` :: ,4 5 '=' i MMt1 2880 - 3460 O ' ` • • 270'11.41X,7*, , ® .Iii 90 3460 - 4050 m ® 1.. . -� s ��t ••� 4050 - 4640 35-2° • s 'v 4640 - 5220 5220 - 5810 Q _ ° I 5810 - 6400 6400 - 7570 0 2500 5000 7500 10000 12500 15000 240 120 7570 - 8750 SURVEY PROGRAM - 8750 - 9920 _ Surface Location 9920 - 11090 Depth From Depth To Survey/Plan Tool 39.00 1100.00 3S-613wp06(Plan 3S-613) GYD-GC-SS Pad Elevation:27.70 210 ...--i---- 160 11090 - 12270 1100.00 2100.00 3S-613wp06(Plan.3S-613) MWD • 12" 12270 13440 1100.00 2897.07 3S-613wp06(Plan 3S-613) MWD+IFR-AK-CAZ-SC 180 13440 ` - 14610 2897.07 4397.07 3S-613wp06(Plan 3S-613) MWD CASING DETAILS 2897.07 11251.37 3S-613wp06(Plan 3S-613) MWD+IFR-AK-CAZ-SC 14610 - 15782 11251.37 12751.37 3S-613wp06(Plan 3S-613) MWD TVD MD Name -M' 11251.37 15781.68 35-613wp06(Plan 3S-613MWD+IFR-AK-CAZ-SC 89.00 89.00 16"x 42" Magnetic Model: BGGM2015 T 2566.70 2897.07 10 3/4"x 13-1/2 Magnetic Model Date: 01-May-16 A 5186.70 11251.37 7-5/8"x 9-7/8" Magnetic Declination: 18.23° 5216.70 15781.68 4 1/2"x 63/4" To convert a Magnetic Direction to a True Direction,Add 18.23°East SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 360.00 0.00 0.00 360.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,220°TF,for 140.03' - 1575.7 3 500.03 2.10 220.00 500.00 -1.97 -1.65 1.50 220.00 0.45 Start 2°/100'DLS,18°TF,for 1206.57' 4 1706.60 26.14 236.67 1681.70 -187.39 -241.45 2.00 18.00 125.41 Hold for 111.39' Base Permafrost 5 1817.99 26.14 236.67 1761.70 -194.36 -282.45 0.00 0.00 147.43 Start 3°/100'DLS,20°TF,for 170.02' 6 1988.01 30.98 240.05 1911.00 -236.81 -351.69 3.00 20.00 186.17 Adjust TF to 30°,for 909.07' -2018.7 7 2897.07 56.09 256.08 2566.70 -448.36 -931.53 3.00 30.00 582.55 Adjust TF to 49.98°,for 694.46' 8 3591.54 70.64 272.86 2878.97 -501.96 -1545.21 3.00 49.98 1087.21 Hold for 5117.47' WS_TOP 9 8709.01 70.64 272.86 4575.63 -261.34 -6387.24 0.00 0.00 5383.52 Start 3°/100'DLS,89.85°TF,for 2372.79' -2458.7 10 11081.80 84.00 344.99 5171.70 1115.97 -8007.34 3.00 89.85 7492.54 3S-813 0.Top Moraine 100915 VO Adjust TF to-0.01°,for 34.31' WS BASE 11 11116.11 85.03 344.99 5174.98 1148.95 -8018.18 3.00 -0.01 7516.69 Hold for 398.58' -2661.7" 12 11514.68 85.03 344.99 5209.52 1532.48 -8119.03 0.00 0.00 7797.52 Start 3°/100'DLS,0.01°TF,for 165.69' 13 11680.38 90.00 344.99 5216.70 1692.32 -8161.89 3.00 0.01 7914.56 3S-613 1.Heel 100915 VO2 Start 0.02°/100'DLS,90°TF,for 4101.3' 14 15781.68 90.00 345.97 5216.70 5662.55 -9190.24 0.02 90.00 10790.26 3S-613 2.Toe 100815 SS TD:15781.68'MD,5216.7'TVD CAMP_SST -3367.7 C-50 y TE) y-40 42 V°88,O - 99k99ku_possible_fau8_rossin -481SK7 71rpossible_fautt rossin - 51 p-possible_fautt_rossin TOP_MORAINE P 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 app-rove the scan and collision 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 acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by Vinent Osara Nate Beck Ifeanyi Ifesie 0 N N � CO• r0 N _ IC' , co' , Northing (3500 usft/in) �Mj m (c{�) I I V 1 I'` I I Q I I f`�I I I rt 1 L I 1_L i 1 1 1 1 1 1 1 1 1 I I I I I I 11 1 I I 11 I I I I v I 1 I �! � 11 I 1 1 l 1 I _ ✓ N Ir VVV V c;, , - co (QRI N Q •i CO _ \ co _ N = N M m m ,— a d m Q N TI N d M M Q _3 Q=om r) NMN y — _ CO _ W _ 0 — (n co O co O N ch d) M co - O \-0 M — co •• ^La. Oi�, 7 7 el 0 M CO Mcn ` c Q i w_ Z : w _ it u) cy . M _ N Ch - r-- N.Q N CO _ Ch N co co V N (n _ — co O N co N , N V CO CO Csl (n - CO N CO _ 1 (n — \ CO - CO / O 0. - — M - CO _ U) - M tD — a- O - N _ CO — ia _ (4 7 — C ea — 7 I I I I I I I I I I I I I I I I I I I I I I I I I I I I 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 I I I I I I I I I I I I I c (u!rsn 005£) 6u!Lg.JoN N N r O---....-----.........,—. ai o ,t) o Ln Q) S 0 a) 02,- % —o �� Z.: e x -o O 0g£ 0_ Q y, I. 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M 0 U , t 6 —o V"' a �: a)o x Q. = CO M ' CO N- M — CN O a) S i T — T I 0 0 0 0 0 0 o 0 0 0 0n in co v (ui/T4sn 000 (+)L11aoN/(-)T noS • • 0 0 - o 3S-613wp06 N 782 0 Lo z 0 - Q 15830 0 0 co x al 140• 0 O 0 o .MINI "r • 1000 °' V • X56 - 000 COI- 0 I c 0 � 6 n o UI Pp00/ o ', w ox x o n Q bo 0 m 006 Ln a o s m o 0 _ , o c • r O o o p0a` d ca) 0 Co Lu F- 00 U L EL CI) (n O N L0m CSO > E 1 (AI I 0 co O E \ QO °0s d 0 c� 0 0 CO ` OO�y _ 0 M O T • • tO O O o O , I ; N O T \ \ M 1 X , co N o 1- x T 1 - I o O O O O O O o , O O O O Lo Ln O Ln O ,- , co O (uiI lsn 0090 uldea Ieo!Pan anal 0 le ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-613 Plan: 3S-613 Plan: 3S-613wp06 Report Permit Pack 18 January, 2016 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.18 ° Well Plan:3S-613 Well Position +N/-S 0.00 usft Northing: usfi Latitude: +El-W 0.00 usft Easting: usfl Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: 0.00 usft Wellbore Plan:3S-613 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 5/1/2016 18.23 80.97 57,482 Design 35-613wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.00 0.00 0.00 300.00 Survey Tool Program Date 1/18/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 1,100.00 35-613wp06(Plan:3S-613) GYD-GC-SS Gyrodata gyro single shots 1,100.00 2,100.00 35-613wp06(Plan:3S-613) MWD MWD-Standard 1,100.00 2,897.07 3S-613wp06(Plan:3S-613) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,897.07 4,397.07 35-613wp06(Plan:3S-613) MWD MWD-Standard 2,897.07 11,251.37 3S-613wp06(Plan:3S-613) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,251.37 12,751.37 3S-613wp06(Plan:3S-613) MWD MWD-Standard 11,251.37 15,781.68 3S-613wp06(Plan:3S-613) 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) (0) (usft) 39.00 0.00 0.00 39.00 -27.70 0.00 0.00 0.00 89.00 0.00 0.00 89.00 22.30 0.00 0.00 0.04 16"x42" 100.00 0.00 0.00 100.00 33.30 0.00 0.00 0.04 200.00 0.00 0.00 200.00 133.30 0.00 0.00 0.19 300.00 0.00 0.00 300.00 233.30 0.00 0.00 0.33 1/18/2016 2:58:02PM Page 2 COMPASS 5000.1 Build 74 0 Schlumberger 0 Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 360.00 0.00 0.00 360.00 293.30 0.00 0.00 0.42 KOP:Start 1.5°/100'DLS,220°TF,for 140.03' 400.00 0.60 220.00 400.00 333.30 1.50 220.00 0.46 500.00 2.10 220.00 499.97 433.27 1.50 0.00 0.51 500.03 2.10 220.00 500.00 433.30 1.50 0.00 0.51 Start 2°/100'DLS,18°TF,for 1206.57' 600.00 4.05 228.78 599.82 533.12 2.00 18.00 0.60 700.00 6.03 231.84 699.43 632.73 2.00 9.23 0.71 800.00 8.02 233.38 798.67 731.97 2.00 6.19 0.84 900.00 10.02 234.31 897.43 830.73 2.00 4.65 0.99 1,000.00 12.01 234.94 995.58 928.88 2.00 3.73 1.15 1,100.00 14.01 235.39 1,093.01 1,026.31 2.00 3.12 1.33 1,200.00 16.01 235.73 1,189.59 1,122.89 2.00 2.68 1.44 1,300.00 18.01 235.99 1,285.21 1,218.51 2.00 2.35 1.58 1,400.00 20.01 236.21 1,379.76 1,313.06 2.00 2.10 1.86 1,500.00 22.01 236.38 1,473.11 1,406.41 2.00 1.90 2.27 1,600.00 24.01 236.53 1,565.15 1,498.45 2.00 1.73 2.78 1,611.56 24.24 236.55 1,575.70 1,509.00 2.00 1.60 3.37 Base Permafrost 1,700.00 26.00 236.66 1,655.77 1,589.07 2.00 1.58 3.37 1,706.60 26.14 236.67 1,661.70 1,595.00 2.00 1.48 3.41 Hold for 111.39' 1,800.00 26.14 236.67 1,745.55 1,678.85 0.00 0.00 4.01 1,817.99 26.14 236.67 1,761.70 1,695.00 0.00 0.00 4.13 Start 3°/100'DLS,20°TF,for 170.02' 1,900.00 28.46 238.43 1,834.57 1,767.87 3.00 20.00 4.69 1,988.01 30.98 240.05 1,911.00 1,844.30 3.00 18.43 5.35 Adjust TF to 30°,for 909.07' 2,000.00 31.29 240.40 1,921.26 1,854.56 3.00 30.00 5.44 2,100.00 33.92 243.06 2,005.50 1,938.80 3.00 29.70 6.25 2,115.94 34.35 243.45 2,018.70 1,952.00 3.00 27.46 3.37 WS_TOP 2,200.00 36.61 245.38 2,087.15 2,020.45 3.00 27.14 3.37 2,300.00 39.33 247.42 2,165.98 2,099.28 3.00 25.56 3.74 2,400.00 42.09 249.24 2,241.77 2,175.07 3.00 23.95 4.13 2,500.00 44.87 250.87 2,314.33 2,247.63 3.00 22.58 4.56 2,600.00 47.67 252.35 2,383.45 2,316.75 3.00 21.39 5.01 2,700.00 50.49 253.71 2,448.94 2,382.24 3.00 20.37 5.49 2,715.41 50.93 253.90 2,458.70 2,392.00 3.00 19.48 5.99 WS BASE 2,800.00 53.33 254.95 2,510.62 2,443.92 3.00 19.36 5.99 2,897.07 56.09 256.08 2,566.70 2,500.00 3.00 18.71 6.48 Adjust TF to 49.98°,for 694.46'-10 3/4"x 13-1/2 2,900.00 56.15 256.16 2,568.33 2,501.63 3.00 49.98 6.50 3,000.00 58.11 258.86 2,622.61 2,555.91 3.00 49.93 7.15 1/18/2016 2:58:02PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 3,075.61 59.63 260.83 2,661.70 2,595.00 3.00 48.46 8.01 CAMP SST 3,100.00 60.13 261.45 2,673.94 2,607.24 3.00 47.44 8.01 3,200.00 62.19 263.94 2,722.18 2,655.48 3.00 47.13 9.04 3,300.00 64.30 266.33 2,767.21 2,700.51 3.00 45.93 10.18 3,400.00 66.44 268.64 2,808.89 2,742.19 3.00 44.86 11.42 3,500.00 68.62 270.87 2,847.11 2,780.41 3.00 43.89 12.73 3,591.54 70.64 272.86 2,878.97 2,812.27 3.00 43.04 13.96 Hold for 5117.47' 3,600.00 70.64 272.86 2,881.78 2,815.08 0.00 0.00 14.09 3,700.00 70.64 272.86 2,914.93 2,848.23 0.00 0.00 15.59 3,800.00 70.64 272.86 2,948.09 2,881.39 0.00 0.00 17.12 3,900.00 70.64 272.86 2,981.24 2,914.54 0.00 0.00 18.67 4,000.00 70.64 272.86 3,014.40 2,947.70 0.00 0.00 20.23 4,100.00 70.64 272.86 3,047.55 2,980.85 0.00 0.00 21.81 4,200.00 70.64 272.86 3,080.70 3,014.00 0.00 0.00 23.39 4,300.00 70.64 272.86 3,113.86 3,047.16 0.00 0.00 24.98 4,400.00 70.64 272.86 3,147.01 3,080.31 0.00 0.00 11.76 4,500.00 70.64 272.86 3,180.17 3,113.47 0.00 0.00 12.29 4,600.00 70.64 272.86 3,213.32 3,146.62 0.00 0.00 12.83 4,700.00 70.64 272.86 3,246.48 3,179.78 0.00 0.00 13.37 4,800.00 70.64 272.86 3,279.63 3,212.93 0.00 0.00 13.92 4,900.00 70.64 272.86 3,312.78 3,246.08 0.00 0.00 14.47 5,000.00 70.64 272.86 3,345.94 3,279.24 0.00 0.00 15.03 5,065.64 70.64 272.86 3,367.70 3,301.00 0.00 0.00 15.59 C-50 5,100.00 70.64 272.86 3,379.09 3,312.39 0.00 0.00 15.59 5,200.00 70.64 272.86 3,412.25 3,345.55 0.00 0.00 16.15 5,300.00 70.64 272.86 3,445.40 3,378.70 0.00 0.00 16.72 5,400.00 70.64 272.86 3,478.55 3,411.85 0.00 0.00 17.28 5,500.00 70.64 272.86 3,511.71 3,445.01 0.00 0.00 17.85 5,600.00 70.64 272.86 3,544.86 3,478.16 0.00 0.00 18.42 5,700.00 70.64 272.86 3,578.02 3,511.32 0.00 0.00 19.00 5,800.00 70.64 272.86 3,611.17 3,544.47 0.00 0.00 19.57 5,900.00 70.64 272.86 3,644.33 3,577.63 0.00 0.00 20.15 6,000.00 70.64 272.86 3,677.48 3,610.78 0.00 0.00 20.72 6,100.00 70.64 272.86 3,710.63 3,643.93 0.00 0.00 21.30 6,200.00 70.64 272.86 3,743.79 3,677.09 0.00 0.00 21.88 6,300.00 70.64 272.86 3,776.94 3,710.24 0.00 0.00 22.47 6,400.00 70.64 272.86 3,810.10 3,743.40 0.00 0.00 23.05 6,500.00 70.64 272.86 3,843.25 3,776.55 0.00 0.00 23.63 6,600.00 70.64 272.86 3,876.40 3,809.70 0.00 0.00 24.21 6,700.00 70.64 272.86 3,909.56 3,842.86 0.00 0.00 24.80 6,800.00 70.64 272.86 3,942.71 3,876.01 0.00 0.00 25.38 6,900.00 70.64 272.86 3,975.87 3,909.17 0.00 0.00 25.97 1/182016 2:58:02PM Page 4 COMPASS 5000.1 Build 74 0 Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 7,000.00 70.64 272.86 4,009.02 3,942.32 0.00 0.00 26.56 7,100.00 70.64 272.86 4,042.18 3,975.48 0.00 0.00 27.14 7,200.00 70.64 272.86 4,075.33 4,008.63 0.00 0.00 27.73 7,252.39 70.64 272.86 4,092.70 4,026.00 0.00 0.00 28.32 K-3(Top Coyote) 7,300.00 70.64 272.86 4,108.48 4,041.78 0.00 0.00 28.32 7,400.00 70.64 272.86 4,141.64 4,074.94 0.00 0.00 28.91 7,500.00 70.64 272.86 4,174.79 4,108.09 0.00 0.00 29.50 7,600.00 70.64 272.86 4,207.95 4,141.25 0.00 0.00 30.09 7,632.44 70.64 272.86 4,218.70 4,152.00 0.00 0.00 30.68 BASE COYOTE 7,700.00 70.64 272.86 4,241.10 4,174.40 0.00 0.00 30.68 7,800.00 70.64 272.86 4,274.25 4,207.55 0.00 0.00 31.27 7,852.62 70.64 272.86 4,291.70 4,225.00 0.00 0.00 31.86 kku_possible_fault_crossing 7,900.00 70.64 272.86 4,307.41 4,240.71 0.00 0.00 31.86 8,000.00 70.64 272.86 4,340.56 4,273.86 0.00 0.00 32.45 8,100.00 70.64 272.86 4,373.72 4,307.02 0.00 0.00 33.05 8,200.00 70.64 272.86 4,406.87 4,340.17 0.00 0.00 33.64 8,300.00 70.64 272.86 4,440.03 4,373.33 0.00 0.00 34.23 8,400.00 70.64 272.86 4,473.18 4,406.48 0.00 0.00 34.82 8,500.00 70.64 272.86 4,506.33 4,439.63 0.00 0.00 35.42 8,600.00 70.64 272.86 4,539.49 4,472.79 0.00 0.00 36.01 8,700.00 70.64 272.86 4,572.64 4,505.94 0.00 0.00 36.60 8,709.01 70.64 272.86 4,575.63 4,508.93 0.00 0.00 36.66 Start 30/100'DLS,89.85°TF,for 2372.79' 8,800.00 70.67 275.75 4,605.78 4,539.08 3.00 89.85 37.00 8,900.00 70.75 278.93 4,638.82 4,572.12 3.00 88.89 37.21 9,000.00 70.89 282.10 4,671.68 4,604.98 3.00 87.84 37.32 9,100.00 71.09 285.27 4,704.25 4,637.55 3.00 86.79 37.32 9,200.00 71.34 288.42 4,736.47 4,669.77 3.00 85.76 37.21 9,300.00 71.64 291.57 4,768.22 4,701.52 3.00 84.75 37.00 9,400.00 71.99 294.71 4,799.44 4,732.74 3.00 83.75 36.67 9,500.00 72.39 297.83 4,830.03 4,763.33 3.00 82.77 36.24 9,600.00 72.84 300.94 4,859.91 4,793.21 3.00 81.81 35.71 9,700.00 73.34 304.03 4,889.00 4,822.30 3.00 80.88 35.08 9,737.55 73.54 305.19 4,899.70 4,833.00 3.00 79.98 34.36 kku_possible_fault_crossing_2 9,800.00 73.89 307.11 4,917.21 4,850.51 3.00 79.65 34.36 9,900.00 74.48 310.16 4,944.48 4,877.78 3.00 79.12 33.54 10,000.00 75.11 313.20 4,970.72 4,904.02 3.00 78.28 32.63 10,100.00 75.77 316.22 4,995.87 4,929.17 3.00 77.49 31.65 10,200.00 76.48 319.23 5,019.85 4,953.15 3.00 76.73 30.58 10,291.45 77.16 321.96 5,040.70 4,974.00 3.00 76.01 29.45 kku_possible_fault_crossing 1/18/2016 2:58:02PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger 0 Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 10,300.00 77.22 322.21 5,042.59 4,975.89 3.00 75.38 29.45 10,400.00 78.00 325.18 5,064.05 4,997.35 3.00 75.33 28.24 10,500.00 78.81 328.13 5,084.15 5,017.45 3.00 74.69 26.98 10,600.00 79.64 331.06 5,102.85 5,036.15 3.00 74.10 25.67 10,700.00 80.51 333.98 5,120.09 5,053.39 3.00 73.55 24.31 10,800.00 81.39 336.88 5,135.82 5,069.12 3.00 73.05 22.92 10,805.26 81.44 337.03 5,136.61 5,069.91 3.00 72.59 21.51 3S-613 1.Heel 071015 KU 10,900.00 82.30 339.77 5,150.00 5,083.30 3.00 72.57 21.51 11,000.00 83.23 342.64 5,162.60 5,095.90 3.00 72.18 20.09 11,035.64 83.56 343.67 5,166.70 5,100.00 3.00 71.82 18.93 TOP MORAINE 11,081.80 84.00 344.99 5,171.70 5,105.00 3.00 71.70 18.93 Adjust TF to-0.01°,for 34.31'-3S-613 0.Top Moraine 100915 VO 11,100.00 84.55 344.99 5,173.52 5,106.82 3.00 -0.01 19.00 11,116.11 85.03 344.99 5,174.98 5,108.28 3.00 -0.01 19.07 Hold for 398.58' 11,193.86 85.03 344.99 5,181.72 5,115.02 0.00 0.00 19.43 3S-613 0.Top Moraine 100815 SS 11,200.00 85.03 344.99 5,182.25 5,115.55 0.00 0.00 19.43 11,251.37 85.03 344.99 5,186.70 5,120.00 0.00 0.00 19.99 7-5/8"x 9-7/8" 11,300.00 85.03 344.99 5,190.91 5,124.21 0.00 0.00 19.99 11,400.00 85.03 344.99 5,199.58 5,132.88 0.00 0.00 20.75 11,500.00 85.03 344.99 5,208.24 5,141.54 0.00 0.00 21.59 11,514.68 85.03 344.99 5,209.52 5,142.82 0.00 0.00 21.72 Start 3°/100'DLS,0.01°TF,for 165.69' 11,600.00 87.59 344.99 5,215.01 5,148.31 3.00 0.01 22.51 11,680.38 90.00 344.99 5,216.70 5,150.00 3.00 0.01 23.31 Start 0.02°/100'DLS,90°TF,for 4101.3'-3S-613 1.Heel 100915 VO2-3S-613 1.Heel 100915 VO2_Cirlce 11,700.00 90.00 344.99 5,216.70 5,150.00 0.02 90.00 23.49 11,800.00 90.00 345.02 5,216.70 5,150.00 0.02 90.00 24.44 11,900.00 90.00 345.04 5,216.70 5,150.00 0.02 90.00 25.45 12,000.00 90.00 345.07 5,216.70 5,150.00 0.02 90.00 26.51 12,100.00 90.00 345.09 5,216.70 5,150.00 0.02 90.00 27.62 12,200.00 90.00 345.11 5,216.70 5,150.00 0.02 90.00 28.77 12,257.65 90.00 345.13 5,216.70 5,150.00 0.02 90.00 29.95 3S-613 1.Heel 100915 VO 12,300.00 90.00 345.14 5,216.70 5,150.00 0.02 90.00 29.95 12,400.00 90.00 345.16 5,216.70 5,150.00 0.02 90.00 31.17 12,500.00 90.00 345.19 5,216.70 5,150.00 0.02 90.00 32.42 12,600.00 90.00 345.21 5,216.70 5,150.00 0.02 90.00 33.69 12,700.00 90.00 345.23 5,216.70 5,150.00 0.02 90.00 34.98 12,800.00 90.00 345.26 5,216.70 5,150.00 0.02 90.00 23.76 12,900.00 90.00 345.28 5,216.70 5,150.00 0.02 90.00 24.11 1/18/2016 2:58:02PM Page 6 COMPASS 5000.1 Build 74 0 Schlumberger 411 Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 13,000.00 90.00 345.30 5,216.70 5,150.00 0.02 90.00 24.46 13,100.00 90.00 345.33 5,216.70 5,150.00 0.02 90.00 24.83 13,200.00 90.00 345.35 5,216.70 5,150.00 0.02 90.00 25.20 13,300.00 90.00 345.38 5,216.70 5,150.00 0.02 90.00 25.58 13,400.00 90.00 345.40 5,216.70 5,150.00 0.02 90.00 25.96 13,500.00 90.00 345.42 5,216.70 5,150.00 0.02 90.00 26.36 13,600.00 90.00 345.45 5,216.70 5,150.00 0.02 90.00 26.76 13,700.00 90.00 345.47 5,216.70 5,150.00 0.02 90.00 27.16 13,800.00 90.00 345.49 5,216.70 5,150.00 0.02 90.00 27.58 13,900.00 90.00 345.52 5,216.70 5,150.00 0.02 90.00 28.00 14,000.00 90.00 345.54 5,216.70 5,150.00 0.02 90.00 28.42 14,100.00 90.00 345.57 5,216.70 5,150.00 0.02 90.00 28.85 14,200.00 90.00 345.59 5,216.70 5,150.00 0.02 90.00 29.29 14,300.00 90.00 345.61 5,216.70 5,150.00 0.02 90.00 29.73 14,400.00 90.00 345.64 5,216.70 5,150.00 0.02 90.00 30.17 14,500.00 90.00 345.66 5,216.70 5,150.00 0.02 90.00 30.62 14,600.00 90.00 345.69 5,216.70 5,150.00 0.02 90.00 31.08 14,700.00 90.00 345.71 5,216.70 5,150.00 0.02 90.00 31.53 14,790.68 90.00 345.73 5,216.70 5,150.00 0.02 90.00 32.00 3S-613 02.Toe 081815 SS 14,800.00 90.00 345.73 5,216.70 5,150.00 0.02 90.00 32.00 14,900.00 90.00 345.76 5,216.70 5,150.00 0.02 90.00 32.46 15,000.00 90.00 345.78 5,216.70 5,150.00 0.02 90.00 32.93 15,100.00 90.00 345.80 5,216.70 5,150.00 0.02 90.00 33.41 15,200.00 90.00 345.83 5,216.70 5,150.00 0.02 90.00 33.88 15,300.00 90.00 345.85 5,216.70 5,150.00 0.02 90.00 34.36 15,400.00 90.00 345.88 5,216.70 5,150.00 0.02 90.00 34.85 15,500.00 90.00 345.90 5,216.70 5,150.00 0.02 90.00 35.33 15,600.00 90.00 345.92 5,216.70 5,150.00 0.02 90.00 35.82 15,700.00 90.00 345.95 5,216.70 5,150.00 0.02 90.00 36.31 15,781.68 90.00 345.97 5,216.70 5,150.00 0.02 90.00 36.71 TD:15781.68'MD,5216.7'TVD-3S-613 2.Toe 100815 SS-3S-613 2.Toe 100815 SS_Cirlce 1/18/2016 2:58:02PM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 89.00 89.00 16"x 42" 16 42 15,781.68 5,216.70 4 1/2"x 6-3/4" 4-1/2 6-3/4 11,251.37 5,186.70 7-5/8"x 9-7/8" 7-5/8 9-7/8 2,897.07 2,566.70 10 3/4"x 13-1/2 10-3/4 13-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (`) 11,035.64 5,166.70 TOP_MORAINE 0.00 2,715.41 2,458.70 WS_BASE 0.00 7,852.62 4,291.70 kku_possible_fault_crossing 0.00 7,252.39 4,092.70 K-3(Top Coyote) 0.00 2,115.94 2,018.70 WS_TOP 0.00 3,075.61 2,661.70 CAMP_SST 0.00 10,291.45 5,040.70 kku_possible_fault_crossing 0.00 9,737.55 4,899.70 kku_possible_fault_crossing_2 0.00 1,611.56 1,575.70 Base Permafrost 0.00 5,065.64 3,367.70 C-50 0.00 7,632.44 4,218.70 BASE_COYOTE 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 360.00 360.00 0.00 0.00 KOP:Start 1.5°/100'DLS,220°TF,for 140.03' 500.03 500.00 -1.97 -1.65 Start 2°/100'DLS, 18°TF,for 1206.57' 1,706.60 1,661.70 -167.39 -241.45 Hold for 111.39' 1,817.99 1,761.70 -194.36 -282.45 Start 3°/100'DLS,20°TF,for 170.02' 1,988.01 1,911.00 -236.81 -351.69 Adjust TF to 30°,for 909.07' 2,897.07 2,566.70 -448.36 -931.53 Adjust TF to 49.98°,for 694.46' 3,591.54 2,878.97 -501.96 -1,545.21 Hold for 5117.47' 8,709.01 4,575.63 -261.34 -6,367.24 Start 3°/100'DLS,89.85°TF,for 2372.79' 11,081.80 5,171.70 1,115.97 -8,007.34 Adjust TF to-0.01°,for 34.31' 11,116.11 5,174.98 1,148.95 -8,016.18 Hold for 398.58' 11,514.68 5,209.52 1,532.48 -8,119.03 Start 3°/100'DLS,0.01°TF,for 165.69' 11,680.38 5,216.70 1,692.32 -8,161.89 Start 0.02°/100'DLS,90°TF,for 4101.3' 15,781.68 5,216.70 5,662.55 -9,190.24 TD: 15781.68'MD,5216.7'TVD Checked By: Approved By: Date: 1/18/2016 2.58:02PM Page 8 COMPASS 5000.1 Build 74 0 • N w Q .£ M .2 N C O I .2 Q U ON N d a) CD O U) ° 2 • a — ` M W O Olio Mil X O ce MO .. 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E. cfl C COC c6 C 03 C CO C (U (O R C R E. c6 3 a) O O 0 N a) a) 0 O d O N CU a) O N O a) O a) O CU a) d O N a) a) co550505 050505 050505 00055 505 0 U a) 0) CO co o0 CO o0 0 — LO (O N (O ti CA N LO 6) 0 N 0 0) 0 0 CA (O r- V M LO N0 N 0 CA N CO CA O CO 0 0 N M LO CO LO (0 LO (O CO N N CO (O (O (O (O CO. r 0 0 0 O CA V CO C) CO ,- O CO O co N- I,- 0 6) N N N W ,— 6) MCA M .— LU CO N.: ,— 6) 6) .— 0 Lf) M CO ,— O .— O N N (O LO LO LO U a- a- a- .- V N co (N1 LO N 4 CO 4 CO CA r 6) r CO 03 CU LL U "00 0 0 0 0 0 x 0 0 0 0 0 0 0 0 0 0 0 CO 0 0 0 0 0 0 0 0 0 y . . . . . .0 0 0 0 LO O O O 0 0 0 0 0 O O O CO0 4 0 0 O 0 O O O . . . t O LO O O O O LO (O ((') LO (n O LO co; LO (O LO W LO N tO LO lO (O O (O O U) (O N 0 0 0 0 N N I� N C� (N 0 N 0 N- N N- N r N h N N I� 0 N LO CO 4-E, N N CA N CO N M N N N O CA N N N N LO (O ,. N N N y Q 3 CO ` r LO LO E a C M CO 4 N- V N- CO CO CO N CO N CO CO N M C- CO I- CO 0 LO CO N r CO r CO V CO V CO 0 CA CO (0 CA (� N N N- N CO 0 CO 0 (0 CO CO CO 0 0 d CV CA LO ' Ln V N I: (D (O (D L() I� V C7 C`'J C) I� r N N O (6 O O O O y CU= M n r r C� 6) 6) ,- ,- LO LO V CO 6) 6) 6) CA V V 0 0 LO LO CL y .- N N N N .- LO LO 03 w a"" N CO • E -a N CO v V O N C- 0 LO CO CO 6) 00 V' CO 0 N 0 0 N CO V V 001 y O C- N O N 0 0 C' CO CO r M O co X 7 0 0 O (0 O co 6) 6) — N 7 V C 3 O00 O 0 O O O CA LO LO LO V V V .s- (O O CA CA ( V V 6) LO 6) LO CA 6) a ^ co W CO CO CO CO CO 00 CO V 60 N CO CO CO CO CO CO LO (O V CO co N y CO l y N CA N CO N CO N N N O N N N N LO LO N N CO coQ. (1) 0 7 ,- V' C E O a co N O^ CU V CO CO CO M M LO CO N Cr) N- N.. N CO N <- N I- CO V CO V 0 0 M ,- (O c- Yf. E a) LO LO r V r V 0 6) 0 00 CA c- V 0 co co co r O — co <— co M <-- LO N M N 3 0 6) v 6) O 6) O O O O O C) V V 00 W 00 00 0 0 0 0 C) C) co; O O O C w CO N N- W N- W 0 0 N N LO M O Cc)N 6) C) CA CA N N N N n r N N co 00 — CD o a a L.. E p CC CD (3 w N x 0) (O R N M V' O N CO CO LO CO CO CA 00 0 0 0 N 0 (C N co V 7 M Ce cn d co t` N 0 N 0 O O V CO (fl r CO 0 CO V V 0 0 0 CO 0 CO CA CA .-- N V V t 000000 6) LO LO LU V NI' V r CO 4 V CA LO C) (O CA 6) (O CA CA L L M •p 3 fl. 0 CO CO CO CO CO N CO 'Q 6) CO M CO CO CO CO 00 LO LO '� CO CO �' Y y 0 y N 67 N CO N CO N N N 0 ,- N N N N (0 LO N N CO CO M zM y❑ � � v V'' co E E co (n to ..- M N ci E 0) R M sato C Z a) C 0 °' a) (3) aa)) T D riD 0 d M `1 C.) a) 3 E 3 (L E L 0 as @ y Z CO d 5 C a) R `o R o CI) 0) C c_ (n 3 R R 01 CI. TM ; . _ .,c-f' a 41) E i co 7 E r N- M M V - CNC CNC C rt X R — R LO 0 I� f� coW W 6) 6) N N M COM N N 4- 4- N N CO J Q a` N Z r a- r co — N N N N N N N co N N co Cn N a (`') M O O (O C' d `d' = Cn U) U) U) M C�') 666666 (n U) U) U) M M U) U) M M U) d i i C C O L n GI M CO M CO CO CO CO CO CO CO co M co co CO CO M 0 0 . 'R N O p r: C (O CO I- r N r 00 00 6) 6) ' ' N N CO CO M M V '0' V V CO 2 coNCCC O O •N_ Z ,y c y 0 N- ,- <- <- N N N N N N N N N N N N N J (n d 2 2 m d d y U) U) U) U) (n (n CO CI) U) CO CO CO CO CO (n CO CO CO U) CO CO U) CO it t III iiiiii 11111 Q co M a) ' ._ y E co co M co M M co co co co co co co CO CO CO CO CO M co co co co LL O 0.) C VO C d C •O Z a LO CO N. N- r n CO (b CA W N N CO CO CO CO 'R V V V co Co N N •� •C C j • • a I 0 u> 0 0 Il ca c C4 0. al 0 GA 0.1il 1.0 PI 0 U 0 CJ 0 0 0 U I- o > Y Y � < < < co a d eL Li_ LL LL CDT T T 000000 0 c a) m a) a m a T a) i ,^ = C 0^ N 2 0. co n M a) a N W CO co co co CO CO O (0 C Cl 00C) 0000 a) -C n n n n n w a) I 3hMMM 8 d �M C) M L CM) cocococo omco c Y coCD co co co co co M C 3 2 1 CO n 3 m U (4) O C) N- N- r N- CO C a) 2 C) O O O CO M (0 O a) 0 O O i� I� a) fu C E = 0v o c) ) O) L() LC co +J U N • F y r CO M N N- N- O "NO C C N N Lt) O @ ❑ O. 70_ co > N a) N n a) w L E z n 2 a) c CO c c o y.. i o0oNN- N- N- N a`) a) d m O O O O O CO CO Q U Q) a1 C a Q £ O O O I� t` U@ O L r CO O O o) O Lo Ln -a-, a) @ 0 3 N- CI M M N N t6 7 9 17). ii N 2 2 (i @ N m U e�- d `p Q, a N @ a) _ U O N N 3 to 0 = o 0ci) C 3 `) o c O .`L) ns o a) a3 C 0] N �_ o _V N a) _ N U _0 co ++ a) `—° ,_ m m = a V O_ - @ N Q — m a) o o _ W Ci oD 0 0 0 • 15:02, January 18 2C16 3S-613w 06 Lad er View pThe Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors .�.�... th0, 300 �4 di, . I � I Ill1;! / / JJ� I� Q fl211lk�ll i,, Filiviiihri . 150 1 1f l ci li 2J�,Ir IIS 4E' " o Equivelant Magnetic Distance t r — / 1 d 0 I 1 1 1 1 I I 1 1 I I I I I I I I I I I I I I I I I I I I 1 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well:Measured Depth 39.00 To 15781.68 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 1100.00 3S-613wp06 (Plan: 3S-613) GYD-GC-SS 89.00 89.00 16" x 42" 1100.00 2100.00 35-613wp06 (Plan: 3S-613) MWD 2566.78897.07 10 3/4"x 13-1/2 1100.00 2897.07 35-613wp06 (Plan: 3S-613) MWD+IFR-AK-CAZ-SC 518617251.37 7-5/8"x 9-7/8" 2897.07 4397.07 35-613wp06 (Plan: 3S-613) MWD 5216:M781.68 4 1/2"x 6-3/4" 2897.0711251.37 3S-613wp06 (Plan: 3S-613) MWD+IFR-AK-CAZ-SC 11251.3712751.37 3S-613wp06 (Plan: 3S-613) MWD 11251.3715781.68 3S-613wp06 (Plan: 3S-613) MWD+IFR-AK-CAZ-SC 0, M 60— i �..— ``-, / 1 \ \ ''-i' C — 0 CO I a_ _ 1 r 30— + U U 0 I I I 1 I I l I I I I I I I I I I I 1 1 I I I I 1 1 1 1 1 I I 1 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth SU sbu 3S-613wp06 MD ec Azi TVD Dleg TFace Tar., 360 550 _9.00 0.00 0.00 39.00 0.00 0.00 39.00 To 15781.68 360.00 0.00 0.00 360.00 0.00 0.00 550 740 500.03 2.10 220.00 500.00 1.50 220.00 740 930 6.60 26.14 236.67 1661.70 2.00 18.00 15:03,January 18 2016 7.99 26.14 236.67 1761.70 0.00 0.00 930 1120 _., 8.01 30.98 240.05 1911.00 3.00 20.00 CASING DETAILS 2897.07 56.09 256.08 2566.70 3.00 30.00 1120 1320 .55 1.54 70.64 272.86 2878.97 3.00 49.98 1320 1510 TVD MD N `F99.01 70.64 272.86 4575.63 0.00 0.00 89.00 89.00 16" x1 1.80 84.00 344.99 5171.70 3.00 89.85 38-613 0. Top Moraine 100915 ✓ 2566.70 2897.07 10 3/4" x 13- G 1510 1700 5186.70 11251.37 7-5/8" x 9-"). '. 6.11 85.03 344.99 5174.98 3.00 -0.01 5216.70 15781.68 4 1/2" x 6-1/145.:4.68 85.03 344.99 5209.52 0.00 0.00 1700 - 2290 11680.38 90.00 344.99 5216.70 3.00 0.01 38-613 1. Heel 100915 VO2 D63p.e63.„ 1.68 90.00 345.97 5216.70 0.02 90.00 3S-613 2. Toe 100815 SS 2290 2880 Depth Free 39 00°1100 00 5"613,05 55 (Plan 3.613, -33 2880 3460 1100 613.06 (Plan 3-613, 1100 0 9,:0, 35 61306 (Plan 3=613, -66-062-3C 2897 07 4397 07 33-613.606 (Plan 3-613) 3460 4050 .07 11251.31 3S-613x506 (elm:33-613) -AK cel-Sc .97 12751.31 35-6136506 (elm: 35-813) Ma 11251 97 15181.68 38-6136506 (A113: 38-613) 10mr16R-Art-c62-SC 4050 4640 4640 5220 5220 5810 5810 6400 3S-15 3S-14 6400 7570 0/360 i 7570 8750 ' 8750 9920 3S-620 4P0 �c�'{, 7.11��fj � � � 9 41' PALM 1 9920 11090 su/'ssu � i �tA` ii t, 30 3S-17A 40AdeliftiglararafirWillrifiKtairgiOlft,00Si ; -� �) • ,Nk4**,4,, " 3S-26 11090 12270 c.4!.! �reORP�Mf .., T� 0a1t1�-1 441 1)%774A 3 .1 y �/ /''per �i.4 �$ l,tp. ,, i .....„` li��:F 12270 13440 3S-17 .*411,0i�/ ., ' 11 rgs •,r•4441 P' z>. - S-10 �,`,,,,,� :4t, '-t/���s! ��`►i 46- / 1,0,5,4 4' ; its •��a 3 13440 14610 ':wtj►: <'a► ' �t �7. � ss,l:A .�dJ 4i ty�! t:>! r ; 14610 - 15782 3S-18 � t:-,��`� �• ��!�����ob'!,� .1•.y�,�ii1• �,'$d , �0'1�.A��:���^ �0'�'la , 3S-16 e4 *a ♦ K s •.� T` ) �' R� � a � Ca wv a ,a Px ,� 4e., c 4,00;:••••,,it,,,‘-::-.4-gs.:11"4,1�►0sbl7i/•e1/0.`®1l�:l i��l+ �//�>,� . �����y'r�$�1"�f 35-09 60/300,1/: i..,�! ®'<*...i 1 ,6 �F '}♦ . d'tO►s 'tr.ao ���ti ii(If1•i�` r�r�,, `�°�i�►' 6lt � .e 641 s.,, 6• eQ 4t ®9'a`t / (�� ��'1► ,Ai {�®�i'_,410,7.m.4-1.*i./. i`S ir I sP f 'A '0417-.v :R�,4�1� 1.___', -L.<1 • %N/ :44.. !ttltva�% ' �` �V i0. 3S-19 . ...� . t, tI �� .rte .moi />s® tit �f��'Ufa e�c.; .�4 04.A r� .,,,...,,,,,,„,.„„..„,..4,,,,..,,,,2c A_ -,'�, %,C.cs,,,,, �iw,r-.11M-49,40-k.-4, �` ` /%a/" ..:...i;,:-A1 �z 1 k 't_ sem. e we 4� 1,40.♦lop', .��i� l ,�I , . «� . ♦ r{, '...;:z!,.,, ..-1•;:,'4#i0/-74,y i. '..4.-- \-, v,--.44+sriLi AAft, ,,,ar t --.II l�erl'-..1��1. .3S-06A ..,,,,,,,i„.,.....,...__,.,..,.., ,� / , 1 1 ,♦O y , y�'0`e%6 _.... 1�a�i}f i� }✓I/as�R�i,Qi \ e 6S e )�. 6t. _ r A A 1'1 f ,. ,,,..N 4'.4'::74.11W.4.WIP'' r lls , A Y ♦ ®� ! to 1 dl /� f �) t ;w4, ��st apt;•i ., t.1 �'�...< 6.> ��� ,�A; •�. 1 1'/ t�r 35-07 - ® `1 Z1.�e' a�. , '4►.� E J Y '110!•-:::: • i .i ���. :- Z mop: k.r,6ir' .I4 ,:1,.._,;t..--..,._;, int 38-23 ;%.6 p ' '^r , ; ri ��y, ;.41::::":' ' ` ���=®� �. � f@Et., .� r. lw 0. its , '• ' O! ,� •f ,a♦i�hr• • • 1 -90)-z70 -: , 1. . 6,kt c, i� 'i 90 IiiIc3S-23 s :'C �;�� �� aav'. %- ' i ,�., i� trait. '' , ra/L��'-.>•i� I ,ii As*.. .7140 a;70 s L x i, 4;i2,it 6 I-�Iir;A:4 38-08 .fie r' ' �3S-08A 3S-24A-- -t4 75 `'1 "-"'-' Illiiiimmi.. 90 / od`►o?'". 35-086 4 c 3S-24 `ff.`A� 10 .r�'`44iy'e��„'1" l: / 1i����►.•�.s,• 3S-08C 120 ►` �., ' gym_ -120/240 `,�a, 135 " 4.a.�;R 120 4"Arit'�%♦, it vs, !:4�,-vi+ 150 �iira .' s +s��10• 165 ��'����, �1 rF1P15 180 iAlo NOLt ilL�� `,��,• 3S-21 ttr 195 �� i`�`,3Ai� 210 i/soar •\ -150/210 �. �. 150 y%ice® 031 -180/180 3S-03 • 0 Northing (2500 usftlin) I I ( I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I — co — 0 _ u) _ co _ O M - co N _ - (n Ch - co co O f� / - O _ OS th m _ co M\ T — Q c N o .. y 7 c0 U7 V = • M • M - 7 O - O co - 0 In t________ — in i"----------- = V NI c 1 ) — 0 w t w co • — - co - N co (` Q N \iii,, N coco M Q — V N M _ Oco N N V _ N C N _ cD co co co co O 2 N — M L — C1) I, — co _ co _ - I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I (umsn oosz) 6ui4DoN AC Flipbook e • O 0 0 0 N O 0 0 0 0 NO 0 00 c 00 Ln d' ON O 0 t- in NN N d" ..0 00 in d- rn eN- rn L!1 N. N 00 d" 0 .O N CO - v1 N. G' O� N rn d' L/ M L(1 N. 0 ,- ,- r- N N rn d" d- LIQ V1 .o N. CO O'N ,- c- , a\ O O O O O O O O 0 0 O O 0 O 0 O O 0 0 O O 0 0 M o V1 d- M N N — 0 O, CO .O L(1 d- N ',- 0 N. in N O1 N. d" rn V1 N. Ol rn i- N 00 d- 0 .o N co V1 N. O, O N d- .O N- T- r- N N M Ti- dLIN u' ' � \ ko N. co a' - N rn d" r l ON O O U V V O ' O 4 tai ��I;`\ " Sp V.10 !ilk � -�k �J �� , ' 0 mmmmmm� ` a-,°_--9-....a.-.°_--9_,E,.- /Or Aftt -1g,nrit et "I 1 AMA k \ Mak o �*/l�'� sAIv iN 1 i t /AV it\ ,?,-. ,"9 VI* 0R :,.., .,.,., r,...,,,,,,,..at,,.„,10 40. lik irn qD 00" ,.....v „. 1 *iv i rglIttlioli-n:Iik 44/0111\ 00 WRIPitlilleittekt41ttk- ,-. .-•...*747.4._elothittilpitl, %Ilk mug t d TIPA31)4I414.---;;, .-,,,,_\IAlsof-.41:14fit. aitla .;®tic- t kt .I 10 G_A . 0 klip°f*iljtaitOtirriall 0 "Ir - 10'"""frA\ ! .„ , AIL,V� ii,� M 1/40 O _ M I\ o O O o N O N 0. I I T- to M •R-, O O O N. N. Lr CO .o ON O'N O'N� N. o Q O O O �O �O O O o0 00 m0.. cr. O, C VD r 0 0 0 qD qO 0 ' d N N d - 7r 7F' L as N rn N N N N N N d' d' d- d' 1 _1 1 O N M M rn M M VI O0 M O O O .O O� O O Ln 0 00 • 00 q:1 UN M rn .0 0 0 00 O C' 0 CO — — 0o 00 M V1 N. co 0' ONO m 0 N- L .p • • O 0 0 0 N 0 0 0 0 0 0 0 0 0 0 0 0 0 O1 N. d' 000 0 0 0 O n lfl Ild' M M 111 N, 00 d" 0 N CO CF" Lf1 N. C\ ONIYld' Lfl M 11 1,, M i- c- ,- e- N N M d" d' Ll iiLO N. 00 O1 r0 - al 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M LO Ln d" ('rl N N ' 0 01 CO 1/40 LI' d- N r- 0 r- in N d'1 r- d- M Lfl N 01 r � N CO d" 0 NI CO d- n N a1 0 N M N N M d- d- 10 N 0 0 "< `;t' "g N V Q ¢ ¢ r- HISISIS I* - o"ir/ l,` 97 W-T,,'`:,','`,'44,'",' ifrii i \--- ,3333333 // I� 1l- Y a__�r��� �, / � / 0 0vO ,pv �, o 0 0 0 0 M� _ ;glr�1/AI�L rn m r elli ,t, ,, Qi 0 ....-4- \ oo ;,T,,--,-,-, , /00 wa \ , , -,--,-,92_2-_, f Ni totirAVAlk .,\ v."Al bi- ' 0110 m / 0 „Is, 1 O o 0 M N VD O o .0 ZS O O 0 N 0 N 0 T- 0 'N0 0 0 N. N. in CO 61 dl O.1`?1, n M rI. < O O O O O CO CO 01 61 dl C1 al c VD 0 0 0 0 N N d- d- d- d" Lr\ RIO N M M d- Ln N. r- d- d- d- d- d" _' i 0VI N N N N N N N M O M M M M • Q O O M O O `- n d' ' O ' CO CO Co 1� M O 0 0 0 rn O Lfl O 00 M 0 m � 0 0 ' rn � Ooo - COr I l M in N M CO 0 1.- in N . T. e- , 0 • O 0 O 0 N 0 0 0 O O O 0 0 O O 0 0 d1 d' ,- 00 0 o O 0 0 N 0 0 a, 00 .o in d' N — O n In N .O in tet- M N rrI Lin I� N 00 7r' 0 \O N OO t• Ln r aN O) N r�r1 O LNn M Ln N. 0\ N N N M Ct d- Ln LIN .O N CO O1 r , i a\ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M ,0 Ln d' M N N 0 a1 CO .O Ln d- N r' 0 I\ En N a1 n d- rr Ln N a1 r ,_ r N CO d- 0 Nn CO d' I� COC 0 N d' .O N N M d d .O 1- ‘-' M d" r 0 CaN0 V V V `On N Q Q Q W r- K K K V m m ' �0 � 0/� r- Z ECEEEEE x,3333333 O o o,NA 0 0 O O 0T.'- O 0 °° _ 0 O oo E v z x j u ° 0 grn o • M N O M in 00 O O 1/40 O ct' • rrN N N. 0 N O 0 N 10 1 `0 'N 0 O 0 N. N. Ln .O CO00 . 0\ al 0-NT11 N. t° Q O O O k.0 k.0 O p DD CO a1 a1 M C .0 .a N Nd- d' d' d' in O o 0 N O M r1\ d-Ln N. N. d- d- d- d- 7r . i 0 N N N N N N N en M M M m O r, • 0 0 0 M 0 M `-' I. 't' `-' 0 '— CO CO CO M O o 0 0 .o a, o 0 in 0 a0 7 .o M .o in 0 •M o o .o •N 00 • •' a; O fn VD 0 0 � CO cr.‘ C" o co - - co olo M Ln , ON ONO MOD N. o r- 1- L^n r- • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-613 Plan: 3S-613 Plan: 3S-613wp06 To • -. • yrs: Report - Errors Multiply by 2.5 :' 18 January, 2016 0 Schlumberger S Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.18 ° Well Plan:3S-613 Well Position +N/-S 0.00 usft Northing: usft Latitude: +El-W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 0.00 usft Wellbore Plan:3S-613 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 5/1/2016 18.23 80.97 57,482 Design 35-613wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 300.00 Survey Tool Program Date 1/18/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 1,100.00 35-613wp06(Plan:3S-613) GYD-GC-SS Gyrodata gyro single shots 1,100.00 2,100.00 35-613wp06(Plan:3S-613) MWD MWD-Standard 1,100.00 2,897.07 3S-613wp06(Plan:3S-613) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,897.07 4,397.07 3S-613wp06(Plan:3S-613) MWD MWD-Standard 2,897.07 11,251.37 3S-613wp06(Plan:3S-613) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,251.37 12,751.37 3S-613wp06(Plan:3S-613) MWD MWD-Standard 11,251.37 15,781.68 3S-613wp06(Plan:3S-613) 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) (°) (°) (usft) (usft) (usft) (usft) 39.00 0.00 0.00 0.00 -27.70 0.00 0.00 0.00 89.00 1.15 0.00 0.00 22.30 1.15 0.04 0.04 16"x 42" 100.00 1.15 0.00 0.00 33.30 1.15 0.04 0.04 200.00 1.15 0.00 0.00 133.30 1.15 0.19 0.19 300.00 1.15 0.00 0.00 233.30 1.15 0.33 0.33 1/18/2016 2:58:28PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 360.00 1.15 0.00 0.00 293.30 1.15 0.42 0.42 KOP:Start 1.5°/100'DLS,220°TF,for 140.03' 400.00 1.15 0.60 135.00 333.30 1.15 0.46 0.46 500.00 1.15 2.10 135.00 433.27 1.15 0.51 0.51 500.03 1.15 2.10 135.00 433.30 1.15 0.51 0.51 Start 2°/100'DLS,18°TF,for 1206.57' 600.00 1.16 4.05 135.00 533.12 1.15 0.60 0.59 700.00 1.16 6.03 145.53 632.73 1.15 0.71 0.70 800.00 1.16 8.02 17.91 731.97 1.15 0.84 0.83 900.00 1.17 10.02 47.77 830.73 1.15 0.99 0.96 1,000.00 1.18 12.01 51.07 928.88 1.15 1.15 1.10 1,100.00 1.19 14.01 52.54 1,026.31 1.15 1.33 1.24 1,200.00 1.20 16.01 53.08 1,122.89 1.15 1.44 1.31 1,300.00 1.22 18.01 54.25 1,218.51 1.15 1.58 1.32 1,400.00 1.23 20.01 54.88 1,313.06 1.15 1.86 1.35 1,500.00 1.25 22.01 55.21 1,406.41 1.15 2.27 1.40 1,600.00 1.27 24.01 55.43 1,498.45 1.15 2.78 1.47 1,611.56 1.29 24.24 55.60 1,509.00 1.16 3.37 1.56 Base Permafrost 1,700.00 1.29 26.00 55.60 1,589.07 1.16 3.37 1.56 1,706.60 1.30 26.14 55.60 1,595.00 1.17 3.41 1.56 Hold for 111.39' 1,800.00 1.30 26.14 55.72 1,678.85 1.19 4.01 1.68 1,817.99 1.31 26.14 55.74 1,695.00 1.20 4.13 1.70 Start 3°/100'DLS,20°TF,for 170.02' 1,900.00 1.33 28.46 55.91 1,767.87 1.22 4.69 1.80 1,988.01 1.37 30.98 56.29 1,844.30 1.25 5.35 1.93 Adjust TF to 30°,for 909.07' 2,000.00 1.38 31.29 56.34 1,854.56 1.24 5.44 1.95 2,100.00 1.45 33.92 57.04 1,938.80 1.30 6.25 2.14 2,115.94 1.46 34.35 55.02 1,952.00 1.21 3.37 1.80 WS_TOP 2,200.00 1.46 36.61 55.02 2,020.45 1.21 3.37 1.80 2,300.00 1.52 39.33 56.10 2,099.28 1.24 3.74 1.90 2,400.00 1.60 42.09 57.27 2,175.07 1.28 4.13 2.00 2,500.00 1.68 44.87 58.48 2,247.63 1.32 4.56 2.10 2,600.00 1.78 47.67 59.70 2,316.75 1.38 5.01 2.20 2,700.00 1.88 50.49 60.88 2,382.24 1.45 5.49 2.30 2,715.41 2.00 50.93 62.04 2,392.00 1.52 5.99 2.40 WS BASE 2,800.00 2.00 53.33 62.04 2,443.92 1.52 5.99 2.40 2,897.07 2.16 56.09 63.14 2,500.00 1.51 6.48 2.43 Adjust TF to 49.98°,for 694.46'-10 3/4"x 13-1/2 2,900.00 2.17 56.15 63.17 2,501.63 1.50 6.50 2.43 3,000.00 2.37 58.11 65.27 2,555.91 1.54 7.15 2.47 1/18/2016 2:58:28PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (0) (usft) (usft) (usft) (usft) 3,075.61 2.60 59.63 67.73 2,595.00 1.63 8.01 2.55 CAMP SST 3,100.00 2.60 60.13 67.73 2,607.24 1.63 8.01 2.55 3,200.00 2.86 62.19 70.24 2,655.48 1.76 9.04 2.67 3,300.00 3.16 64.30 72.62 2,700.51 1.93 10.18 2.82 3,400.00 3.50 66.44 74.81 2,742.19 2.13 11.42 2.99 3,500.00 3.88 68.62 76.84 2,780.41 2.37 12.73 3.18 3,591.54 4.28 70.64 78.55 2,812.27 2.61 13.96 3.37 Hold for 5117.47' 3,600.00 4.28 70.64 78.69 2,815.08 2.63 14.09 3.39 3,700.00 4.28 70.64 80.30 2,848.23 2.91 15.59 3.65 3,800.00 4.28 70.64 81.63 2,881.39 3.20 17.12 3.92 3,900.00 4.29 70.64 82.72 2,914.54 3.50 18.67 4.21 4,000.00 4.29 70.64 83.64 2,947.70 3.80 20.23 4.50 4,100.00 4.30 70.64 84.41 2,980.85 4.11 21.81 4.80 4,200.00 4.30 70.64 85.08 3,014.00 4.42 23.39 5.11 4,300.00 4.31 70.64 85.65 3,047.16 4.73 24.98 5.42 4,400.00 3.82 70.64 79.77 3,080.31 2.84 11.76 3.47 4,500.00 3.82 70.64 80.54 3,113.47 2.98 12.29 3.61 4,600.00 3.83 70.64 81.23 3,146.62 3.13 12.83 3.74 4,700.00 3.84 70.64 81.86 3,179.78 3.27 13.37 3.89 4,800.00 3.84 70.64 82.43 3,212.93 3.42 13.92 4.03 4,900.00 3.85 70.64 82.95 3,246.08 3.57 14.47 4.18 5,000.00 3.86 70.64 83.43 3,279.24 3.73 15.03 4.33 5,065.64 3.86 70.64 83.87 3,301.00 3.88 15.59 4.48 C-50 5,100.00 3.86 70.64 83.87 3,312.39 3.88 15.59 4.48 5,200.00 3.87 70.64 84.27 3,345.55 4.03 16.15 4.63 5,300.00 3.88 70.64 84.64 3,378.70 4.19 16.72 4.78 5,400.00 3.89 70.64 84.98 3,411.85 4.34 17.28 4.94 5,500.00 3.89 70.64 85.30 3,445.01 4.50 17.85 5.09 5,600.00 3.90 70.64 85.59 3,478.16 4.66 18.42 5.25 5,700.00 3.91 70.64 85.86 3,511.32 4.81 19.00 5.41 5,800.00 3.92 70.64 86.11 3,544.47 4.97 19.57 5.57 5,900.00 3.93 70.64 86.35 3,577.63 5.13 20.15 5.73 6,000.00 3.93 70.64 86.57 3,610.78 5.29 20.72 5.89 6,100.00 3.94 70.64 86.77 3,643.93 5.45 21.30 6.05 6,200.00 3.95 70.64 86.96 3,677.09 5.61 21.88 6.21 6,300.00 3.96 70.64 87.14 3,710.24 5.77 22.47 6.38 6,400.00 3.97 70.64 87.31 3,743.40 5.93 23.05 6.54 6,500.00 3.98 70.64 87.47 3,776.55 6.09 23.63 6.71 6,600.00 3.99 70.64 87.62 3,809.70 6.25 24.21 6.87 6,700.00 4.00 70.64 87.76 3,842.86 6.41 24.80 7.04 6,800.00 4.00 70.64 87.89 3,876.01 6.57 25.38 7.20 6,900.00 4.01 70.64 88.02 3,909.17 6.73 25.97 7.37 1/18/2016 2:58:28PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 7,000.00 4.02 70.64 88.13 3,942.32 6.89 26.56 7.54 7,100.00 4.03 70.64 88.25 3,975.48 7.05 27.14 7.70 7,200.00 4.04 70.64 88.36 4,008.63 7.21 27.73 7.87 7,252.39 4.05 70.64 88.46 4,026.00 7.37 28.32 8.04 K-3(Top Coyote) 7,300.00 4.05 70.64 88.46 4,041.78 7.37 28.32 8.04 7,400.00 4.06 70.64 88.55 4,074.94 7.54 28.91 8.20 7,500.00 4.07 70.64 88.65 4,108.09 7.70 29.50 8.37 7,600.00 4.08 70.64 88.73 4,141.25 7.86 30.09 8.54 7,632.44 4.09 70.64 88.82 4,152.00 8.02 30.68 8.71 BASE COYOTE 7,700.00 4.09 70.64 88.82 4,174.40 8.02 30.68 8.71 7,800.00 4.10 70.64 88.90 4,207.55 8.19 31.27 8.88 7,852.62 4.11 70.64 88.98 4,225.00 8.35 31.86 9.05 kku_possible_fault_crossing 7,900.00 4.11 70.64 88.98 4,240.71 8.35 31.86 9.05 8,000.00 4.13 70.64 89.05 4,273.86 8.51 32.45 9.22 8,100.00 4.14 70.64 89.12 4,307.02 8.67 33.05 9.39 8,200.00 4.15 70.64 89.19 4,340.17 8.84 33.64 9.56 8,300.00 4.16 70.64 89.25 4,373.33 9.00 34.23 9.73 8,400.00 4.17 70.64 89.31 4,406.48 9.16 34.82 9.90 8,500.00 4.18 70.64 89.37 4,439.63 9.32 35.42 10.07 8,600.00 4.19 70.64 89.43 4,472.79 9.49 36.01 10.24 8,700.00 4.20 70.64 89.49 4,505.94 9.65 36.60 10.41 8,709.01 4.20 70.64 89.49 4,508.93 9.66 36.66 10.42 Start 3°/100'DLS,89.85°TF,for 2372.79' 8,800.00 5.16 70.67 89.55 4,539.08 9.81 37.00 10.69 8,900.00 6.61 70.75 89.64 4,572.12 9.97 37.21 11.02 9,000.00 8.26 70.89 89.78 4,604.98 10.14 37.32 11.37 9,100.00 10.03 71.09 89.95 4,637.55 10.30 37.32 11.74 9,200.00 11.86 71.34 90.16 4,669.77 10.46 37.21 12.12 9,300.00 13.72 71.64 90.41 4,701.52 10.62 37.00 12.51 9,400.00 15.59 71.99 90.68 4,732.74 10.78 36.67 12.89 9,500.00 17.46 72.39 90.98 4,763.33 10.95 36.24 13.26 9,600.00 19.31 72.84 91.31 4,793.21 11.11 35.71 13.62 9,700.00 21.15 73.34 91.67 4,822.30 11.28 35.08 13.94 9,737.55 22.97 73.54 92.04 4,833.00 11.44 34.36 14.23 kku_possible_fault_crossing_2 9,800.00 22.97 73.89 92.04 4,850.51 11.44 34.36 14.23 9,900.00 24.75 74.48 92.43 4,877.78 11.61 33.54 14.49 10,000.00 26.49 75.11 92.84 4,904.02 11.77 32.63 14.71 10,100.00 28.19 75.77 93.27 4,929.17 11.94 31.65 14.89 10,200.00 29.83 76.48 93.70 4,953.15 12.11 30.58 15.02 10,291.45 31.42 77.16 94.14 4,974.00 12.28 29.45 15.12 kku_possible_fault_crossing 1/18/2016 2:58:28PM Page 5 COMPASS 5000.1 Build 74 0 Schlumberger • Report-Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit ND Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (0) (°) (usft) (usft) (usft) (usft) 10,300.00 31.42 77.22 94.14 4,975.89 12.28 29.45 15.12 10,400.00 32.95 78.00 94.59 4,997.35 12.45 28.24 15.17 10,500.00 34.41 78.81 95.04 5,017.45 12.62 26.98 15.19 10,600.00 35.79 79.64 95.49 5,036.15 12.79 25.67 15.17 10,700.00 37.10 80.51 95.94 5,053.39 12.96 24.31 15.13 10,800.00 38.34 81.39 96.38 5,069.12 13.13 22.92 15.06 10,805.26 39.48 81.44 96.82 5,069.91 13.30 21.51 14.98 3S-613 1.Heel 071015 KU 10,900.00 39.48 82.30 96.82 5,083.30 13.30 21.51 14.98 11,000.00 40.54 83.23 97.25 5,095.90 13.47 20.09 14.89 11,035.64 41.33 83.56 97.60 5,100.00 13.61 18.93 14.81 TOP MORAINE 11,081.80 41.33 84.00 97.60 5,105.00 13.61 18.93 14.81 Adjust TF to-0.01°,for 34.31'-3S-613 0.Top Moraine 100915 VO 11,100.00 41.39 84.55 97.68 5,106.82 13.65 19.00 14.69 11,116.11 41.43 85.03 97.76 5,108.28 13.67 19.07 14.59 Hold for 398.58' 11,193.86 41.43 85.03 98.16 5,115.02 13.82 19.43 14.73 3S-613 0.Top Moraine 100815 SS 11,200.00 41.43 85.03 98.16 5,115.55 13.82 19.43 14.73 11,251.37 41.55 85.03 98.83 5,120.00 13.89 19.99 14.82 7-5/8"x 9-7/8" 11,300.00 41.55 85.03 98.83 5,124.21 13.89 19.99 14.82 11,400.00 41.55 85.03 99.69 5,132.88 13.90 20.75 14.83 11,500.00 41.55 85.03 100.59 5,141.54 13.92 21.59 14.85 11,514.68 41.55 85.03 100.72 5,142.82 13.93 21.72 14.85 Start 30/100'DLS,0.01°TF,for 165.69' 11,600.00 41.75 87.59 101.52 5,148.31 13.95 22.51 14.31 11,680.38 41.87 90.00 102.30 5,150.00 13.98 23.31 13.98 Start 0.02°/100'DLS,90°TF,for 4101.3'-3S-613 1.Heel 100915 VO2-3S-613 1.Heel 100915 VO2_Cirlce 11,700.00 41.88 90.00 102.49 5,150.00 13.99 23.49 13.99 11,800.00 41.89 90.00 103.44 5,150.00 14.04 24.44 14.04 11,900.00 41.90 90.00 104.43 5,150.00 14.09 25.45 14.09 12,000.00 41.91 90.00 105.46 5,150.00 14.16 26.51 14.16 12,100.00 41.92 90.00 106.53 5,150.00 14.24 27.62 14.24 12,200.00 41.93 90.00 107.63 5,150.00 14.32 28.77 14.32 12,257.65 41.94 90.00 108.76 5,150.00 14.41 29.95 14.41 3S-613 1.Heel 100915 VO 12,300.00 41.94 90.00 108.76 5,150.00 14.41 29.95 14.41 12,400.00 41.95 90.00 109.92 5,150.00 14.52 31.17 14.52 12,500.00 41.97 90.00 111.12 5,150.00 14.63 32.42 14.63 12,600.00 41.98 90.00 112.34 5,150.00 14.75 33.69 14.75 12,700.00 41.99 90.00 113.58 5,150.00 14.87 34.98 14.87 12,800.00 41.98 90.00 102.73 5,150.00 14.17 23.76 14.17 12,900.00 41.99 90.00 103.05 5,150.00 14.20 24.11 14.20 1/18/2016 2:58:28PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit ND Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 13,000.00 42.00 90.00 103.39 5,150.00 14.24 24.46 14.24 13,100.00 42.01 90.00 103.72 5,150.00 14.28 24.83 14.28 13,200.00 42.02 90.00 104.07 5,150.00 14.33 25.20 14.33 13,300.00 42.03 90.00 104.42 5,150.00 14.37 25.58 14.37 13,400.00 42.05 90.00 104.78 5,150.00 14.42 25.96 14.42 13,500.00 42.06 90.00 105.14 5,150.00 14.47 26.36 14.47 13,600.00 42.07 90.00 105.52 5,150.00 14.52 26.76 14.52 13,700.00 42.08 90.00 105.89 5,150.00 14.57 27.16 14.57 13,800.00 42.09 90.00 106.28 5,150.00 14.62 27.58 14.62 13,900.00 42.10 90.00 106.67 5,150.00 14.68 28.00 14.68 14,000.00 42.11 90.00 107.07 5,150.00 14.74 28.42 14.74 14,100.00 42.12 90.00 107.48 5,150.00 14.80 28.85 14.80 14,200.00 42.13 90.00 107.89 5,150.00 14.86 29.29 14.86 14,300.00 42.15 90.00 108.31 5,150.00 14.93 29.73 14.93 14,400.00 42.16 90.00 108.74 5,150.00 15.00 30.17 15.00 14,500.00 42.17 90.00 109.17 5,150.00 15.06 30.62 15.06 14,600.00 42.18 90.00 109.61 5,150.00 15.13 31.08 15.13 14,700.00 42.19 90.00 110.05 5,150.00 15.21 31.53 15.21 14,790.68 42.20 90.00 110.51 5,150.00 15.28 32.00 15.28 3S-613 02.Toe 081815 SS 14,800.00 42.20 90.00 110.51 5,150.00 15.28 32.00 15.28 14,900.00 42.22 90.00 110.96 5,150.00 15.35 32.46 15.35 15,000.00 42.23 90.00 111.43 5,150.00 15.43 32.93 15.43 15,100.00 42.24 90.00 111.90 5,150.00 15.51 33.41 15.51 15,200.00 42.25 90.00 112.38 5,150.00 15.59 33.88 15.59 15,300.00 42.27 90.00 112.86 5,150.00 15.67 34.36 15.67 15,400.00 42.28 90.00 113.35 5,150.00 15.76 34.85 15.76 15,500.00 42.29 90.00 113.84 5,150.00 15.84 35.33 15.84 15,600.00 42.30 90.00 114.34 5,150.00 15.93 35.82 15.93 15,700.00 42.32 90.00 114.84 5,150.00 16.02 36.31 16.02 15,781.68 42.33 90.00 115.25 5,150.00 16.09 36.71 16.09 TD:15781.68'MD,5216.7'ND-3S-613 2.Toe 100815 SS-3S-613 2.Toe 100815 SS_Cirlce 1/18/2016 2:58:28PM Page 7 COMPASS 5000.1 Build 74 SSchlumberger 1 Report- Errors Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-613 Project: Kuparuk River Unit TVD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan:39+27.7 @ 66.70usft(Doyon142) Well: Plan:3S-613 North Reference: True Wellbore: Plan:3S-613 Survey Calculation Method: Minimum Curvature Design: 3S-613wp06 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 89.00 89.00 16"x 42" 16 42 15,781.68 5,216.70 4 1/2"x 6-3/4" 4-1/2 6-3/4 11,251.37 5,186.70 7-5/8"x 9-7/8" 7-5/8 9-7/8 2,897.07 2,566.70 10 3/4"x 13-1/2 10-3/4 13-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (°) 11,035.64 5,166.70 TOP_MORAINE 0.00 2,715.41 2,458.70 WS_BASE 0.00 7,852.62 4,291.70 kku_possible_fault_crossing 0.00 7,252.39 4,092.70 K-3(Top Coyote) 0.00 2,115.94 2,018.70 WS_TOP 0.00 3,075.61 2,661.70 CAMP_SST 0.00 10,291.45 5,040.70 kku_possible_fault_crossing 0.00 9,737.55 4,899.70 kku_possible_fault_crossing_2 0.00 1,611.56 1,575.70 Base Permafrost 0.00 5,065.64 3,367.70 C-50 0.00 7,632.44 4,218.70 BASE COYOTE 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 360.00 360.00 0.00 0.00 KOP:Start 1.5°/100'DLS,220°TF,for 140.03' 500.03 500.00 -1.97 -1.65 Start 2°/100'DLS, 18°TF,for 1206.57' 1,706.60 1,661.70 -167.39 -241.45 Hold for 111.39' 1,817.99 1,761.70 -194.36 -282.45 Start 3°/100'DLS,20°TF,for 170.02' 1,988.01 1,911.00 -236.81 -351.69 Adjust TF to 30°,for 909.07' 2,897.07 2,566.70 -448.36 -931.53 Adjust TF to 49.98°,for 694.46' 3,591.54 2,878.97 -501.96 -1,545.21 Hold for 5117.47' 8,709.01 4,575.63 -261.34 -6,367.24 Start 3°/100'DLS,89.85°TF,for 2372.79' 11,081.80 5,171.70 1,115.97 -8,007.34 Adjust TF to-0.01°,for 34.31' 11,116.11 5,174.98 1,148.95 -8,016.18 Hold for 398.58' 11,514.68 5,209.52 1,532.48 -8,119.03 Start 3°/100'DLS,0.01°TF,for 165.69' 11,680.38 5,216.70 1,692.32 -8,161.89 Start 0.02°/100'DLS,90°TF,for 4101.3' 15,781.68 5,216.70 5,662.55 -9,190.24 TD: 15781.68'MD,5216.7'TVD Checked By: Approved By: Date: 1/18/2016 2:58:28PM Page 8 COMPASS 5000.1 Build 74 Pool Report ..... .......m........ IIIIr. 1O.... ...... 1.5.1 `r� 3S-08A 9 _ 1 dr -el > !�' —O el I el 1 '11 O a rt ssoos � ta0000 1..._ i.. _. a M O m m m ti 0 1 aQ gggUUixU� L TV. M N a ` `' F 00000 S� 8 S , O L. a>^romrom FQ- 1 CO W p u 1 W oSN8VN� N N Sd4 1o I p C C.-(VAN LO Z .CIVICIM M s£ 4"\-‘‘'' O 5' 3S-22 0 O r (0 + a-1 N ca W N64 ` £ ' (.° J 1 N-LOU) QW `� o _ _ O M 2 0) I r L CO C 401) i o O r a 1 i , , O , , 0 -4 1 — _0 N T" GO 1 r 0 N W T l I I I I O O O 0 0 O ca c O O O O O ca 10 O In 0 10 M co (u!/44sn (AO (+)1-11Jccfj/(-)gTnoS N ` •� \ . .• I • •• ■= • 0 M ;z' • • • • • • • • • • • • • • • • • • • • • • • • • ° ye O a • 5 M s • • • • • • M . th / \ . .. . , , 1 1. i tr‘ a) .. ,.. . ...., . . . . \ 4 ......:::: .. . . , .. •_ , . ,. . , ,..... > ........ , , .. . , \ . .. . ...... . . . . . , . . , ........ • • 1 M 1 . '; • I t. • ,•/ • • • l •• • • • • •• ...\ i ./././ . •M • j'...'t\''''''• //If ..4.\\\\N's..... CO M i �,v w Mi. r • ._ 0 I M )7/ . v 111../ ,.../.././..M r CU M N.. ...: 444%.4 ,( , . I/ A, 5 • M ,t f ii ... .. ji 1 . z...".....,. .. 4 ., .. ... ..,.,.. ...i .. . ..,. ... ........ , ...... . . . „,..,.:,...... O S el , tea: N'' C� M •::, •• • 1 0 • 3S-613wp06 Surface Location 'I!) 1 From: , To: Datum: rAD83 A Region: lalaska A Datum: 1NAD27 ii, Region. [alaska A C-- Latitude/Longitude (Decimal Degrees J C Latitude/Longitude (Decimal Degrees J C" UTM Zone: r-- 1` South C UTM Zone: (True (— South State Plane Zone: 14 1 Units: us•ft ( State Plane Zone: (4 j Units: (us-ft Legal Description tNAD27 only) C" Legal Description(NAD27 only) Starting Coordinates: Ending Coordinates: — X: 11616239.97 X: ( 476207.898913584 L______ Y: 15993651.72 Y: ( 5993901.18522044 Transform Quit I Help i,_ -� 3S-613wp06 Intermediate Casing tI:j CPAI Coordinate -- o From: _ To: -- Datum: (NAD83 A Region: (alaska A Datum: (NAD27 _.j Region: lalaska J (• Latitude/Longitude (Decimal Degrees J C Latitude/Longitude (Decimal Degrees ..:d 1 C UTM Zone: 1 (" South C' UTM Zone: (True 1— South a r. State Plane Zone: rq���1 Units: (us ft a State Plane Zone: F-4----... Units: (us ft 1 r_. Legal Description(NAD27 only) Cr" Legal Description(NAD27 only) i Starting Coordinates: , Ending Coordinates: X: 11608193.87 i X: ( 468161.769249938 Y: 15994956.73 Y: ( 5995206.41677914 Transform Quit I Help I 0 0 W W r 3S-613wp06 TD -i_ -- ---- � CPA!Coordinate Converter1. ,-_, , ' -ice a< From r To:.._. Datum: INAD83 J Region: lalaska j Datum: [NAD27 J Region: lalaska J Latitude/Longitude 'Decimal Degrees J C Latitude/Longitude 'Decimal Degrees z1 UTtv1 Zone: J r South C UTM Zone: True r South '• State Plane Zone: 14 J Units: Jus-ft J a State Plane Zone: 4 Units: Jus-ft J C' Legal Description(NAD27 only) C Legal Description(NAD27 only) Starting Coordinates — Ending Coordinates:-- X: 11607069 ><: (467037.028130397 Y: 15999343.40 Y: 15999593.10283492 r Transform . _ ' Quit I Help I ill 0 3S-613wp06 Surface Location I...;._=...i k,t ..3 Api En. CPAI Coordinate Converter f=! From: _ -To: Datum: INAD83 J Region: lalaska J Datum: (NAD27 J Region: (alaska J C Latitude/Longitude (Decimal Degrees J C Latitude/Longitude (Decimal Degrees J 4 UTM Zone: Ir--- r South C UTM Zone: ITrue r South r: State Plane Zone: Fr-7A Units: lus-ft J C State Plane Zone: 4 Units: (us-ft J C Legal Description(NAD27 only) a Legal Description(NAD27 only) Starting Coordinates: Legal Description X1616239.97 I Township: 012 IN J Range: 008 (E J Y: 15993651.72 Merician: (U J Section 118 1 (FNL J 12514.3103 ITE-C--E 11051.6566 (m- Transform 11 Quit I Help it 3S-613wp06 Intermediate Casing to CPA(Coordinate Convert From: To: Datum: (NAD83 J Region: (alaska J Datum: (NAD27 J Region: Kaska J C Latitude/Longitude (Decimal Degrees J C Latitude/Longitude (Decimal Degrees J r UTM Zone: r--- r South c UTM Zone: [True r South a State Pyre Zone: 14 J Units: (us.ft J C• State Plane Zone: (4 J Units: lus-ft J C Legal Description(NAD27 only) ( Legal Description(NAD27 only) -Starting Coordinates: Legal Description X 11608193.87 Township: 012 IN J Range: 007 1E ...........1 Y: 15994956.73 Meridian: lU J Section: 13 (FNL J 1238.8893 FEE (4297.2375 j I Transform w) Quit ' Help • 0 r 3S-613wp06 TD _ . CPAI Coordinate Converter .,. From: i To: Datum NAD83 ( Region: lalaska A Datum: JNAD27 A Region: lalaska Lid r. Latitude/Longitude 'Decimal Degrees A C Latitude/Longitude (Decimal Degrees • t- UTM Zone: 1--- E South C' UTM Zone: rTrue E South t State Plane Zone: 14 J Units: us•ft C State Plane Zone: 4 Units: us•ft . r Legal Description(NAD 27 only) C:' Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11607069 Township: (012 N Range: 1007 E • Y: 15999343.40 Meridian: (U j Section:111 IFNL j 12136.6992 FEL 1158.24889 LTransform Quit I Help J • • As - built Incomplete REV DATE BY CK APP • DESCRIPTION REV DATE BY n APP DESCRIPTION 1 11/7/02 MRT BGM DRAWN PER K02100ACS + DS-6H+ N 7 6 9 -Th10 11 Ir/PL �� 4$ITE +itri + + . DS-3S °� 111ttt 18 7..a 17 16 15 l 14 i 1 13 DS-3G e 20 1 z2 vr.womb— 24 SCALE + + + '4 .---a- 1" = 200' 30 2928 °0 , 26 25 S , q + 1 h 31 32 33 34 3 0 LEGEND CD 41 i 11? I • Planned Conductor Location (�"�( j], 6 `I) �4 3 2 1 o Conductor Locations V DS-2T As—Built This Survey -+- + — + .i • Existing Conductor w Vu , 8 c 10 11 , 17 ct co 0 Pit F 1 VICINITY MAP i Sec. 18, T 12 N, R 8 E, U.M., AK. NOT TO SCALE � e 35 Dr site N o . ) • .o°° ® ' -rn • O ._, wOOO • N N tO CP W LOUNSBURY & ASSOCIATES, INC. SEE SHEET 2 FOR NOTES AND LOCATIONS SURVEYORS PLANNERS ENGINEERS 1;< '1.11.11 AREA: 3S MODULE:XXXX UNIT: D3 PHILLIPS Alaska, Inc.I DS3S A Subsidiary of PHILLIPS PETROLEUM COMPANY WELL CONDUCTORS ASBUILT LOCATIONS CADD FILE NO, DRAWING NO: SHEET: REV: LK6319D42 10/16/02 CEA-D3SX-6319D42 1 OF 2 1 ...... ..,...= ...........41b REV DATE BY CK APP DESCRIPTION REV DATE BY PP DESCRIPTION 1 11/7/02 MRT BGM DRAWN PER K02100ACS T NOTES �.4PNE,�F +OA 1. BASIS OF LOCATIONS AND ELEVATIONS ARE ,,, / J, ,.# D.S. 3S MONUMENTS PER LOUNSBURY AND ; ''�i ' •th.,,'/\ _ '' �o ASSOCIATES. 2. COORDINATES SHOWN ARE A.S.P. ZONE 4, f •,� ' r , 0 N.A.D. 27. �,:, c �v J. ROOKUS �o r 3. ALL GEODETIC COORDINATES ARE NAD 27. 1 0,„..., LS- 0 5 �'� 4. ALL ELEVATIONS SHOWN ARE BRITISH � ;,' PETROLEUM MEAN SEA LEVEL. 1 O IS ��.� 5. ALL DISTANCES ARE TRUE. >>evr`��� 6. DRILL SITE 3-S GRID NORTH IS ROTATED SURVEYOR'S CERTIFICATE 13'00'00" WEST FROM GRID NORTH. / HEREBY CERTIFY THAT I AM PROPERLY 7. DATE OF SURVEY: 10/17-18/02, F.B. L02-49, REGISTERED AND LICENSED TO PRACTICE Pp's 1-5, 10/21/02, F.B. L02-50, Pp's 1-4, LAND SURVEYING IN THE STATE OF 10/25/02, F.B. L02-49, Pp's 52-55 & 10/27/02 ALASKA AND THAT THIS PLAT REPRESENTS F.B. LO2-49, Pp's 64-65. A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER 07, 2002. Sec. 18, T. 12 N., R. 8 E., U.M., AK. Well SEC, SEC. PAD O.G. No. ,Y, A.S.P.s ,X, LATITUDE LONGITUDE U1mE 1NE ELEV. ELEV. F.N.L. F.E.L. 1 5,993,955.06 476,441.80 70'23'40.621" 150'11'30.043" 2460' 818' 27.7' 22.7' I 2 5,993,950.55 476,422.25 70'23'40.576" 15011'30.615" 2464' 837' 27.7' 22.8' 3 5,993,946.19 476,402.92 70'23'40.533" 150'11'31.181" 2469' 857' 27.7' 22.8' 6 5,993,932.58 476,344.38 70'23'40.397" 15011'32.894" 2483' 915' 27.7' 23.0' 7 5,993,928.18 476,324.84 70'23'40.353" 150'11'33.466" 2487' 935' 27.7' 23,0' 8 5,993,923.52 476,305.45 70'23'40.307" 15011'34.033" 2492' 954' 27.7' 23.0' 9 5,993,919.05 476,285.95 70'23'40.262" 15011'34.604" 2497' 974' 27.7' 23,0' 10 5,993,914.52 476,266.35 7023'40.217" 15011'35.178" 2501' 993' 27.7' 23.0' 14 5,993,896.63 476,188.43 70'23'40.039" 15011'37.459" 2519' 1071' 27.7' 23.0' 15 5,993,892.07 476,168.97 ' 70'23'39.993" 15011'38.028" 2524' 1091' 27.7' 23.0' 16 5,993,887.49 476,149.43 70'23'39.948" 15011'38.600" 2528' 1110' 27.7' 23.0' 17 5,993,883.06 476,130.01 70'23'39.903" 150'11'39.169" 2533' 1130' 27.7' 23.0' 18 5,993,878.54 476,110.46 70'23'39.858" 150'11'39.741" 2538' 1149' 27.7' 23.0' 19 5,993,874.02 476,091.01 70'23'39.813" 150'11'40.310" 2542' 1169' 27.7' 23.0' 20 5,993,869.45 476,071.76 70'23'39.768" 150'11'40.873" 2547' 1188' 27.7' 23.0' 21 5,993,865.00 476,052.15 70'23'39.723" 150'11'41.447" 2551' 1207' 27.7' 22.9' 22 5,993,860.59 476,032.71 70'23'39.679" 150'11'42,016" 2556' 1227' 27.7' 22.7' 23 5,993,856.07 476,013.11 70'23'39.634" 150'11'42.590" 2560' 1246' 27.7' 22.5' 24 5,993,851.58 475,993.50 70'23'39.590" 150'11'43.164" 2565' 1266' 27.7' 22.4' 26 5,993,842.53 475,954.69 70'23'39.499" 150'11'44.300" 2574' 1305' 27.7' 23.0' 0. LOUNSBURY & ASSOCIATES, INC. SURVEYORS PLANNERS ENGINEERS ti PNIUIPS AREA: 3S MODULE:XXXX UNIT: D3 PHILLIPS Alaska, Inc. DS3S 66' A Subsidiary of PHILLIPS PETROLEUM COMPANY WELL CONDUCTORS ASBUILT LOCATIONS CADD FILE NO. DRAWING N0: SHEET: REV: LK6319D42 10/16/02 CEA-D3SX-6319D42 2 OF 2 Is • 3) t 1-_-- . o .52 .J co a.+ C ON4 W u .�. a) u `I. eo CO y ._ CO L. 3 CO {1 L �J (p co D v I9 D a) W L C L. E co o p a) w — to toC 1 a) '-• o a o a) o DA a) ' TA COa 00 V U J wl y m v a) C = 10 u V CO 1?.... o k u f0 CW > a) r u N O Y C m C i ..10 cc 0t am) u a> a+ N CO 0, ca E 2 E 2 Co a 0 'fl �4- 02 to' E N a) m C m 3 �+ OU m Y a)L 7__. Y Y '' a) O o w a, v O a) 3 c o YC +L+ a,+ •O - 3cto) a+ U O = — E •tot F Z . E a )a) 'O m 0 a) N a) a) O Z O N A Y Y Y Y U C Q) 1°T 00 c y oa a0+ ai u -o -o E C C m a) r O C .0 Q 'f- 7 7 >O y cYa 7 3 a \ E E o 0 to o a C 'a 0 c o m c o o o ro 3 > co y _ Y Y Q. "O a) O ? T O U L L V1 C Y = O C 7 c C w m N .Y C O u 0) ? C C 2 N N N N .0 a7 a61. 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F a- _� _a o f o v v v v U Y u v C o (� ^ a 0 Y t E a) E O E s U U \ -Y 0 N N = Q to CO ' aL L Y U Y Y C7 = ma) S > c*a > o > • ! Loepp, Victoria T (DOA) From: Shultz, Steve(Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent Tuesday, March 15, 2016 11:48 AM To: Loepp,Victoria T(DOA) Subject: 3S-613 Permit to Drill.doc Victoria, I have made the changes and recorded them in blue. I also made a change to the completion set up concerning the use of seals rather than a permanent packer. Thank you, Steve Shultz CPAI Drilling and Wells 35-613 Permit to Drill.doc 1 i S Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Wednesday, February 10, 2016 2:39 PM To: steve.shultz@contractor.conocophillips.com Subject: KRU 3S-613(PTD 216-020)AOR Attachments: 1.7.16 AOR Spreadsheet.xlsx Steve, The Moraine 1 well appears to be within the AOR. Could you please fill out the attached table including the Moraine well?The table is currently filled in with example data. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(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 1 • • Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Wednesday, February 03, 2016 6:12 AM To: Bettis, Patricia K (DOA) Subject: FW: 3S-613 Spacing Exception Patricia, It looks like the asset might have got their wires crossed on the spacing exception for 3S-613. I think they will be going into high gear to get that out. Thank you for giving us notice on this, it is greatly appreciated. Steve From: Kowalewski, Kasper Sent: Tuesday, February 02, 2016 3:13 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: RE: 3S-613 Spacing Exception Steve, I was under the impression that the spacing exemption was required after the drilling permit was approved. So the spacing exemption is needed first? I don't think we submitted one; I'll double-check my handover notes from Ashok and get back to you. Thanks for the help, Kasper From: Shultz, Steve (Orbis Engineering, Inc.) Sent:Tuesday, February 02, 2016 5:01:59 PM To: Kowalewski, Kasper Subject: 3S-613 Spacing Exception Kasper, I submitted the Permit to Drill last week and the AOGCC called and wanted to know where the "Spacing Exception" was, since they will not approve a permit until they have that. I thought the asset submitted one for this well since we had to for 3S-620, so the question is did we? Thanks, Steve 1 • s Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering, Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Monday, February 01, 2016 9:22 AM To: Bettis, Patricia K (DOA) Subject: FW: Pre-producing 3S-613 Patricia, It could be thirty days of pre-production for 3S-613, but wouldn't be more than that. Thanks, Steve From: Kowalewski, Kasper Sent: Monday, February 01, 2016 9:17 AM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: RE: Pre-producing 3S-613 Hi Steve, The plan is 30 days, but we may end up shorting the time depending on the results. Take care, Kasper From:Shultz, Steve (Orbis Engineering, Inc.) Sent: Monday, February 01, 2016 12:00:02 PM To: Kowalewski, Kasper Subject: Pre-producing 35-613 Kasper, The state wants to know how long we plan on pre-producing 3S-613, is that two weeks? Steve 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. O 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: /«cam. .3.S -- Cn/3 PTD: 02/c - 6Z0 Z0 ___ Development Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: Kupb }2'JLPOOL: gyo.AVK IUe.1ri guA Zll V. ' Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subje o full compliance with MC 25.055. Approval to produce inject is contingen on issuance of a Spacing Exception conservation or approving a spacing ception. (Company Name) Operator umes the liability of an rotest to the spacing exception 7 that ma 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 MC 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 Well Lo ,n also required for this well: gg g / Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, I/ 7 composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. , ) r�a�o.� 1cJ A- �� Ssc Jl IY1U✓� 4�I� l tCs lG 11 'n� 6Xc.A f/an 4-0 w�l( M)I.S1 . . a6 A-Ac a o.- '3 , / Revised 4/2014 6 0 1 , „ , . , , , . . ii rn N a) : p o N, 0 O yo a) a No >, a). 3' , , , o, :( O' a, U) p, 'V, c0 0 o , a :c �, v. az 0 v v`, , a) : O) , a) O. C• cV' a) 3 N. —, a) m p. Z°I' p o c o a oa a 0 , a) , CO d• 0 3, col f0 d C,")I- a EE ° o p ,g," Ep C 1 acv i r7 y 1 ND 0 w 8wN• co cd ' 'N. 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