Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
217-042
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-32 KUPARUK RIV UNIT 2K-32 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2K-32 50-103-20757-00-00 217-042-0 W SPT 6353 2170420 3000 2700 2700 2700 2700 293 405 381 366 REQVAR P Guy Cook 6/11/2025 MIT-IA to maximum anticipated injection pressure per AIO 2C.079. Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 2K-32 Inspection Date: Tubing OA Packer Depth 1730 3470 3400 3385IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612081640 BBL Pumped:5 BBL Returned:5 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-32 KUPARUK RIV UNIT 2K-32 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-32 50-103-20757-00-00 217-042-0 W SPT 6353 2170420 3000 2750 2750 2750 2750 200 393 354 335 REQVAR P Brian Bixby 6/27/2023 MITIA as per AIO 2C.079 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 2K-32 Inspection Date: Tubing OA Packer Depth 1300 3400 3320 3300IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230627152059 BBL Pumped:5.1 BBL Returned:5 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg 77��� P.I. Supervisor J�l FROM: Brian Bixby Petroleum Inspector I Well Name KUPARUK RIV UNIT 2K-32 Insp Num: mitBDB210623075829 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 29, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-32 KUPARUK RN UNIT 2K-32 Src: Inspector Reviewed By: P.I. Supry J-9c— Comm API Well Number 50-103-20757-00-00 Inspector Name: Brian Bixby Permit Number: 217-042-0 Inspection Date: 6/20/2021 ✓ Packer Wel( I2K-32 Initial IType Inj w TVD PTD 2170420 ' Type Test I SPT' Test psi BBL Pumped: 6.5 BBL Returned: Interval REQvAR P/F Notes: MITIA as per AIO 2C.079 — I– - Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6353 ! Tubing 2630 2630 - 2630. 2630- i 3000 IA 1170 3450 _ 3350 - 3350 - 6.3 OA 347 495 _ 450 438 P ./ Tuesday, June 29, 2021 Page 1 of I 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 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, March 3, 2020 1:21 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU injector 2K-32 (PTD #217-042) update and plan forward Attachments: 2K-32 90 day TIO plot 3-3-20.pdf; 2K-32 schematic.pdf Chris, Kuparuk WAG injector 2K-32 (PTD 217-042) has completed its 30 -day monitor period on water injection after being reported on 1/24/20 for IA pressurization while on gas injection. During the monitor period, the well did not exhibit any TxIA communication. Diagnostics culminated of a passing MITIA to 3000 psi and passing tubing and inner casing pack off tests. CPAI intends to perform additional diagnostics to attempt to locate the gas only leak. This well will be kept on water injection service only until diagnostics have concluded at which time CPAI will notify the AOGCC with the plan forward. Attached is a 90 -day TIO plot and a wellbore schematic. Please let me know if you have any questions or disagree with this plan. Thank you, Paul Duffy for Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM fonocc`P1JlIps Fro : Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: F ' gy, January 24, 2020 12:47 PM To: chris.walh Cc: CPA Wells Well Integrity Compliance Specialist CPF1 & 2 <n 1617@conocophillips.colnZ Subject: Kuparuk injector 2K-32 ( #217-042) Increase in IA pressure while on MI injection Chris- \ Kuparuk injector 2K-32 (PTD #217-042)has s�.increase in IA pressure while on MI injection. DHD will conduct the initial diagnostics and attempt any immediate repairs int -possible. Once the diagnostics are completed the well will be monitored for 30 days on MI injection. If the IA continues to shbwpc essure increase the well will be WAG'd to water injection for a 30 -day monitor period. At the completion of the monitoraeriod(s) the proper paperwork for continued injection, further diagnostics or repair will be submitted. Please let me know'ifyeq have any questions or disagree with the plan. Thank you. Attached are copies of the current well bore schematic and 90 -day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, January 24, 2020 12:47 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: Kuparuk injector 2K-32 (PTD #217-042) Increase in IA pressure while on MI injection Attachments: 2K-32.pdf; 2K-32 90 day TIO trend.JPG Chris- Kuparuk injector 2K-32 (PTD #217-042) has shown an increase in IA pressure while on MI injection. DHD will conduct the initial diagnostics and attempt any immediate repairs if possible. Once the diagnostics are completed the well will be monitored for 30 days on MI injection. If the IA continues to show pressure increase the well will be WAG'd to water injection for a 30 -day monitor period. At the completion of the monitor period(s) the proper paperwork for continued injection, further diagnostics or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Thank you. Attached are copies of the current well bore schematic and 90 -day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM C0r*0(;PMips MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg ��q / DATE: Wednesday, June 26, 2019 (� 7V _� 5 P.I. Supervisor ( 5 ( SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-32 FROM: Lou Laubenstein KUPARUK RIV UNIT 2K-32 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-32 Insp Num: mitLOL190611075621 Rel Insp Num: API Well Number 50-103-20757-00-00 Inspector Name: Lou Laubenstein Permit Number: 217-042-0 Inspection Date: 6/8/2019 ' Packer Depth Well 2K-32 Type Inj _ �' TVD 6353. Tubing PTD 2170420 Type Test SPT Test psi 1588— IA BBL Pumped: 14 - ;BBL Returned: 1.4 OA Interval 4vRTsr Notes: Pretest Initial 15 Min 30 Min 45 Min 60 Min 2450 - 2450 - 2450. 2450 - 1355 1900 1875 - 1870- 386 870-386 436 436- 436 Wednesday, .lune 26, 2019 Page I of I ti of Ty • tft)1 1 j/y 6. THE STA � IP Alaska Oil and Gas •! __ /A LAC Conservation Commission 111 111 11 11�J GOVERNOR BILL WALKER 333a West Seventh Alaska99 0135Avenue Anchorage, 99501-3572 �FALA5�P Main: 907.279.1433 Fax: 907.2 76.7542 www.aogcc.alaska.gov Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool,KRU 2K-32 Permit to Drill Number: 217-042 Sundry Number: 318-216 Dear Mr. Byrne: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of June, 2018. scANNED JUN U '%2 M RBDM JUN 0 6 2018 RECEIVED • • STATE OF ALASKA AY 2 ` 018 �,) ALASKA OIL AND GAS CONSERVATION COMMISSION 5' s fol Y ` APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 Lx 1.Type of Request: Abandon LJ Plug Perforations H Fracture Stimulate U Repair Well LJ Operations shutdown U Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Sealant Other: ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development Q . 217-042-0 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 501032075700 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No L KRU 2K-32 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL00255881ADL0025589IADL00256041ADL0025607 Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 25,598' • 6,442' ' 23119.6 6467.1 Casing Length Size MD TVD Burst Collapse Structural Conductor 140' 20" 179' 179' Surface 3,443' 11" 3,480' 2,955' Intermediate 13,691' 10" 13,728' 6,363' Production 4,771' 4.5" 18,326' 6,438' Liner 4,805' 4.5" 23,120' 6,467' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13,875-15,010';15,166'-16,303'; 6366-6374';6376'-6391';6390'- 3.500" L-80 13,584' 16,456-17,015';17,166-17,657' 6413';6416-6424' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development ❑ Service Q 14.Estimated Date for 6/1/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG E • 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: Jan Byrne Contact Name: Jan Byrne/Kelly Lyons Authorized Title: Well Integrity Supervisor Contact Email: N1617©conocophillips.com Contact Phone: 907-659-7224 Authorized Signature: 7— Authorized Date: 5/21/18 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313- 21 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No F Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 — 4 c 4- Q` Approved by: APPROVED BY I �'COMMISSIONER THE COMMISSION Date: V 4 ,� RBDMS JUN RIGINALSubmit Form and �� Form 10-403 Revised 4/2017 Approved application is vali or 12 months from the date of approval. Attachmin Duplicate • • pvRECEIVED ConocoPh i l i i ps Alaska MAI 23 2018 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC May 21, 2018 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 2K-32 (PTD# 217-042). The request is for approval to repair a production casing leak with a Seal-Tite application. If you need additional information,please contact myself or Kelly Lyons at 659-7224. Regards, Jan :yrne Well Integrity Supervisor • • 2K-32 Proposal Summary 2K-32 was in process of conversion from Oil Production to Water Alternating Gas Injection service as per Sundry#317-453 when a diagnostic MIT failed halting the conversion process. Diagnostics culminated in an LDL locating a production casing leak at 10,977' RKB. COPA intends to repair the production casing by sealing the leak with a Seal-Tite pill. 1. Wellbore will be prepared to circulate in Seal-Tite pill. a. A plug will be set in the tubing below the gas lift mandrel (GLM)at 11,884'. b. The dummy valve at 11,884' RKB will be removed to give a circulation point. c. Clean fluids will be circulated down the tubing and up the IA to set-up for the pill. 2. Seal-Tite pill will be circulated to leak depth. a. A pill of"'8 bbls of Seal-Tite product will be placed into the IA. b. The pill will be displaced down the IA with returns taken from the tubing, until the pill is near the leak site. c. The IA volume from surface to the production casing leak at 10,977' is—374 bbls. 3. A dummy valve will be put back in the GLM at 11,884'so that pressure can be applied to the Seal-Tite pill to push out and seal off the production casing leak. 4. A diagnostic MITIA will be performed. 5. The well will be brought on injection and allowed to stabilize. 6. A State witnessed MITIA will be performed. 7. A 10-404 will be submitted post passing State witnessed MITIA. -- -- • • 2K-32 Proposal Summary 2K-32 was in process of conversion from Oil Production to Water Alternating Gas Injection service as per Sundry#317-453 when a diagnostic MIT failed haltin 'the conversion process. Diagnostics culminated in an LDL locating a production casing leak at 10,977'RKB. COPA intends to repair the production casing by sealing the leak with a Seal-Tite pill. 1. Wellbore will be prepared to circulate in Seal-Tite pill. 2. Seal-Tite pill will be circulated to leak depth. 3. Pressure will be applied to the Seal-Tite pill to push out and seal off the production casing leak. 4. A diagnostic MITIA will be performed. 5. The well will be brought on injection and allowed to stabilize. 6. A State witnessed MITIA will be performed. 7. A 10-404 will be submitted post passing State witnessed MITIA. y KUP PROD 2K-32 ' Or Well Attributes Max Angle&MD TD ConocoPhillips Wellbore APWWI Field Name • Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) Alaska,Inc. 501032075700 KUPARUK RIVER UNIT PROD 95.56 24,358.51 25,598.0 ocroor;i4volps Comment H2S(ppm) Date Annotation End Date KB-Grd(it) Rig Release Date ... SSSV:NONE Last WO: 38.75 6/14/2017 2K-32,4/13/20185.41:59 PM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By HANGER 336 ® Last Tag: lennalt _...._...___F Last Rev Reason �' �V r Annotation End Date Last Mod By REV REASON:REMOVE CAT STANDING VALVE @ 13,476' 3/31/2018 raffep M CONDUCTOR 39.0-179.r Cin String s GAS LIFT;2,781.9 g g Casing Description OD(in) ID(in) Top(ftKB) Set Depth OMB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;37.9-3480.4CONDUCTOR 20 18.500 39.0 179.0 179.0 154.19 GRX52 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;4.536.1 SURFACE 103/4 9.950 37.9 3,480.4 2,954.8 45.50 L-80 Hydril 563 GAS LIFT;6,832.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;8,995.0 ! INTERMEDIATE 75/8 6.875 36.4 13,727.6 6,363.1 29.70 L-80 Hyd563 ® Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;10,658.3 = LINER-PERFORATED 4 1/2 3.958 13,555.2 18,326.1 6,438.3 12.60 L-80 Hyd 563 UPPER GAS LIFT;11,884.0 = Liner Details MN Nominal ID SLIDING SLEEVE;13,388.8 ;)!C. Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) NIPPLE;13,476.2.o - 13,575.2 6,352.3 84.44 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 15.5 ppf L-80 4.870 PLUG;13,497.8Hyd 563 box x box LOCATOR;13584.0 -, r. 13,578.0 6,352.6 84.48 HANGER Baker 5.5"x7.625"Flex-Lock Liner Hanger L-80 Hyd 4.800 563 pin pin SEAL ASSEMBLY;13,585.1 C C 13,599.5 6,354.6 84.85 SBE Baker 80-40 Sealbore Extension,5"L-80 Hyd 521 pin 4.000 x 4-1.2"Hyd 521 box INTERMEDIATE;36.4-13,727.6- 13,619.2 6,356.3 85.19 XO REDUCING Crossover Pup 4-1/2"L-80 Hyd 521 pin 4-1/2"Hyd 3.910 PERFP;13,875.6-13,881.6 in 563 pin PERFP;14,035.2-14,041.2 - 16,484.0 6,390.7 89.97 SWELL Baker-"Swell Packer#4-"D"6.07"OD SN: 3.910 PERFP;14,197.1-14,203.1 l iE PACKER 052826-002-10 16,497 PERFP;14,358.8-14,364.8 ;til; 16,702.5 6,393.5 87.98 SWELL Baker-"Swell Packer#3-"C"6.02"OD SR 3.930 PERFP;14,520.7-14,526.7 in PACKER 052826-002-28 16,707 PERFP;14,682314,688.3 ';l l Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER-PERFORATED 41/2 3.980 18,315.0 23,119.6 6,467.1 12.60 L-80 Hyd 563 PERFP;14,841.7-14.847.7 in LOWER PERFP;15,004.2-15,010.2 II - Liner Details PERFP;15,166.7-15,172.7 - tll Nominal ID PERFP;15,328.6-15,334.6Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) til' 18,315.0 6,438.4 90.10 SETTING Baker HRD-E Liner setting sleeve 5.5"x 7.625"L-80 4.900 PERFP;15,487.2-15.493.2 •jlii SLEEVE 5.5"Hyd 563 pin PERFP;15,649.6-15,655.6 EIaE 20,395.5 6,445.7 88.11 SWELL Baker-"Swell Packer#2-"B"6.01 OD SN: 3.930 PERFP;15,612.2-15,818.2 '.;tt; - PACKER 052826-002-1922817 PERFP;15.974.5-15,980.5 la 20,611.2 6,447.6 91.09 SWELL Baker-"Swell Packer#1-"A"6.03"OD SH 3.890 PERFP;16,135.1-16,141.1 it;li PACKER 052836-002-36 23020 PERFP;16297.0-16303.0 1.iE Tubing Strings PERFP;16,456.8-16,462.8 ia Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection iTUBING 31/2 2.992 33.6 13,613.8 6,355.8 9.30 L-80 EUE-m i Completion Details PERFP;16,849.4-16,855.4 Ii_p; Top(TVD) Top Incl Nominal Top(RKB) (ftKB) (°) Item Des Com ID(In) PERFP;17009.8-17015.8 Ei?l; 33,6 33.6 0.00 HANGER FMC 4.5"x11"Tubing hanger 3.900 PERFP;17,166.5-17,172.5 :Ill: 78.0 78.0 0.09 XO REDUCING 4.5"12.6 ppf L-80 TXP-m x 3.5"EUE pin Crossover 2.992 PERFP;17,327.7-17333.7 :Eft 13,388.8 6,331.5 82.69 SLIDING Baker CMU sliding sleeve w/2.813"DS profile 82.7°/5972'TVD 2.812 PERFP;17,488.3-17,494.3 RE SLEEVE PERFP;17,651.0-17,657.0 '.til' 13,476.2 6,341,6 83.61 NIPPLE Camco 2.75"DS profile Landing Nipple 83.6/ 2.750 PERFP;17,810.8-17,816.8 ;lit) - 6342'TVD PERFP;17,972.9-17,978.9 ilii 13,497.8 6,344.0 83.59 PLUG Halliburton 3-1/2"Mirage Plug,EUE-m,Rupture 7750 psi 83.6°/ 2.880 PERFP;18,129.1-18.135.1 - Mill 6344'TVD PERFP;18,289.1-18,295.1 .la, 13,584.0 6,353.1 84.59 LOCATOR Baker GBH-22 Locator(OD 4.651 Larger OD above located 3.050 LINER-PERFORATED Imo1 13,585.1 6,353.2 84.61 SEAL Baker GBH-22 Seal Assembly w/mule shoe----below located 2.980 UPPER;13,555.2-18,326.1MN ASSEMBLY - PERFP;18,436.1-18,442.1 :till Perforations&Slots PERFP;18,598.0-18,604.0 :t ii Shot PERFP;18,760.0-18,766.0 llai Dens PERFP;18,916.2-18,922.2 ;19! Top(TVD) Btm(TVD) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com PERFP;19.078.4-19.084.4 in 13,875.6 13,881.6 6,366.2 6,366.3 6/10/2017 4,0 PERFP PERFP;19,236.8-19,242.8 iii) 14,035.2 14,041.2 6,369.8' 6,369.9 6/10/2017 4.0 PERFP PERFP;19,398.8-19,404.8 Ii-li - 14,197.1 14,203.1 6,373.0 6,373.1 6/10/2017 4.0 PERFP PERFP;19.558.4-19,564.4 atli 14,358.8 14,364.8 6,375.2 6,375.2 6/10/2017 4.0 PERFP PERFP;19,718.7-19,724.7 EP 14,520.7 14,526.7 6,375.2 6,375.2 6/10/2017 4.0 PERFP PERFP;19,880.6-19,886.8 - ?ill PERFP;20042.4-20,048.414,682.3 14,688.3 6,372.6 6,372.5 6/10/2017 4.0 PERFP ata: PERFP;20,204.4-20,210.4 'slit. 14,841.7 14,847.7 6,372.7 6,372.8 6/10/2017 4.0 PERFP PERFP;20,366.1-20,372.1 a11E 15,004.2 15,010.2 6,374.4 6,374.5 6/10/2017 4.0 PERFP 11.1 15,166.7 15,172.7 6,376.0 6,376.0 6/10/2017 4.0 PERFP 15,328.6 15,334.6 6,380.6 6,380.8 6/10/2017 4.0 PERFP PERFP;20,759.5-20,765.5 itlE 15,487.2 15,493.2 6,385.9 6,386.2 6/10/2017 4.0 PERFP PERFP;20,921.0-20,927.0 - ;Ili PERFP;21,078.3-21,084.3 Its 15,649.6 15,655.6 6,391.3 6,391.4 6/10/2017 4.0 PERFP PERFP;21,237.3-21,243.3 15,812.2 15,818.2 6,395.0 6,395.0 6/10/2017 4.0 PERFP Ea; PERFP;21,398.2-21,4042 iti. 15,974.5 15,980.5 6,394.9 6,394.8 6/10/2017 4.0 PERFP PERFP;21.558.8-21,564.8 af4; 16,135.1 16,141.1 6,392.3 6,392.2 6/10/2017 4.0 PERFP PERFP;21,719.2-21,725.2 'it'll) 16,297.0 16,303.0 6,391.3 6,391.3 6/10/2017 4.0 PERFP PERFP;21,881.7-21,887.7 11�P. 16,456.8 16,462.8 6,390.7 6,390.7 6/10/2017 4.0 PERFP PERFP;22A42.7-22,048.7 :it�1: 16,849.4 16,855.4 6,401.8 6,402.3 6/10/2017 4.0 PERFP PERFP;22,202.8-22,208.8 :Eft 17,009.8 17,015.8 6,412.9 6,413.3 6/10/2017 4.0 PERFP PERFP;22,365.5-22,371.5 ;Ilii PERFP;22,528.5-22,534.5 17,166.5 17,172.5 6,416.6 6,416.6 6/10/2017 4.0 PERFP PERFP;22,690.5-22,698.5 - -:la. 17,327.7 17,333.7 6,418.8 6,418.9 6/10/2017 4.0 PERFP PERFP;22,853.2-22,659.2 sl1.li 17,488.3 17,494.3 6,421.4 6,421.4 6/10/2017 4.0 PERFP PERFP;23,013.7-23,019.71 LINER-PERFORATED 1.... LOWER;18,315.0.23,119.6, UP PROD 0 2K-32 , ConocoPhillips a 11111.1r Alaska,Inc:. 2K-32,4/132018 5.4201 PM Vertical schematic(actual) .................................. HANGER,33.6 - j"/CONDUCTOR 39019. I MIB -IC GAS LIFT,2,781.9 _. Perforations&Slots Shot SURFACE;37.9.3,480.4 Dens Top(TVD) Otto(TVD) (shots/ft GAS LIFT;4536.1lla Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com GAS LIFT;6,832.04m. 17,651.0 17,657.0 6,424.2 6,424.3 6/10/2017 4.0 PERFP GAS LIFT;8,995.0 11M1 17,810.8 17,816.8- 6,429.0 6,429.2 6/10/2017 4.0 PERFP GAS LIFT;10,658.3 17,972.9 17,978.9 6,433.1 6,433.2 6/10/2017 4.0 PERFP t 18,129.1 18,135.1 6,436.0 6,436.1 6/10/2017 4.0 PERFP GAS LIFT;11.884.0im 18,289.1 18,295.1 6,438.4 6,438.4 6/10/2017 4.0 PERFP MN SLIDING SLEEVE;13,388.8 --e' 18,436.1 18,442.1 6,437.8 6,437.8' 6/8/2017 4.0 PERFP NIPPLE;13,476.2 PLUG;13,497.8 _ 18,598.0 18,604.0 6,434.8 6,434.7 6/8/2017 4.0 PERFP 18,760.0 18,766.0 6,431.7 6,431.5 6/8/2017 4.0 PERFP LOCATOR;13,584.0 ;L' 18,916.2 18,922.2 6,429.1 6,429.1 6/8/2017 4.0 PERFP _1' SEAL ASSEMBLY;13,585.1 V 19,078.4 19,084.4 6,427.8 6,427.8 6/8/2017 4.0 PERFP 19,236.8 19,242.8 6,427.4 6,427.4 6/8/2017 4.0 PERFP INTERMEDIATE;36.4-13,727.6 1 1 PERFP;13,875.6-13,881.6 ;Mt. 19,398.8 19,404.8 6,428.9 6,428.9 6/8/2017 4.0 PERFP PERFP;14,035.2-14,041.2 '. ; 19,558.4 19,564.4 6,429.0 6,429.0 6/8/2017 4.0 PERFP PERFP;14,197.1-14,209.1 in 19,718.7 19,724.7 6,431.2 6,431.3 6/8/2017 4.0 PERFP PERFP;14,358.8 14,364.8 ;lar 19,880.8 19,886.8 6,435.3 6,435.4 6/8/2017 4.0 PERFP PERFP;14,520.7-14,526.7 (l t).- 20,042.4 20,048.4 6,438.3 6,438.4 6/8/2017 4.0 PERFP PERFP;14,682.3-14,688.3 ':lel: 20,204.4 20,210.4 6,440.5 6,440.5 6/8/2017 4.0 PERFP PERFP;14,841.7-14,847.7 6 - 20,366.1 20,372.1 6,444.7 6,444.9 6/8/2017 4.0 PERFP PERFP;15,004.2-15,010.2 31 20,759.5 20,765.5 6,446A 6,446A 6/8/2017 4.0 PERFP PERFP;15,166.7-15,172.7 :I.G - 20,921.0 20,927.0 6,446.8 6,446.8 6/8/2017 4.0 PERFP PERFP;15,328.6-15,334.6 Ili PERFP;15,487.2-10,493.2 ill 21,078.3 21,078.3 21,084.3 6,447.9 6,448.0 6/8/2017 4.0 PERFP PERFP;15,649.6-15.655.6 illi 21,237.3 21,243.3 6,449.2 6,449.2 6/8/2017 4.0 PERFP PERFP;15,812.2-15,818.2 331 21,398.2 21,404.2 6,449.8 6,449.8 6/8/2017 4.0 PERFP PERFP;15,974.5-15580.5 Iii) 21,558.8 21,564.8 6,452.3 6,452.4 6/8/2017 4.0 PERFP PERFP;16,135.1-16,141.1 - 1t; 21,719.2 21,725.2 6,455.6 6,455.7 6/8/2017 4.0 PERFP PERFP;16,297.0-16,303.0 }l; 21,881.7 21 887.7 6,458.8 6,459.0 6/8/2017 4.0 PERFP PERFP;16,456.8-16,462.8 (a: 22,042.7 22,048.7 6,464.7 6,464.9 6/8/2017 4.0 PERFP • 22,202.8 22,208.8 6,468.4 6,468.3 6/8/2017 4.0 PERFP Mil PERFP;16,849.4-16,855.4 ;ll, 22,365.5 22,371.5 6,462.8 6,462.5 6/8/2017 4.0 PERFP PERFP;17,009.8-17.015.8 Illi 22,528.5 22,534.5 6,458.4 6,458.4 6/8/2017 4.0 PERFP PERFP;17,166.5-17,172.5 (t ll 22,690.5 22,696.5 6,461.8 6,461.9 6/8/2017 4.0 PERFP PERFP;17,327.7-17.333.73t! 22,853.2 22,859.2 6,464.0 6,464.1' 6/8/2017 4.0 PERFP PERFP;17,488.3-17,494.3 'R It 23,013.7 23,019.7 6,464.9 6,464.9 6/8/2017 4.0 PERFP PERFP;17,651.0-17,657.0 (t ll - PERFP;17,810.8-17,816.8 - Ell, Mandrel Inserts PERFP:17,972.9-17,978.9 St 6I. ati PERFP;18,129.1-18,135.1 ;lel, - on Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) PERFP;18,289.1-18,295.1 - lI, N (psi) Run Date Com 1 2,781.9 2,491.5 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/30/2018 LINER-PERFORATED 1-1 2 4,536.1 3,592.4 Camco KBMG 1 GAS LIFT 'DMY BK 0.000 0.0 1/30/2018 UPPER;13,555.2-18,326.1 3 6,832.0 4,444.7 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/30/2018 PERFP;18,436.1-18,442.1 ll:. 4 8,995.0 5,098.2 Camco KBMG 1 GAS LIFT DMY 'BK 0.000 0.0 1/29/2018 PERFP;18,598.0-18,604.0 (lit: 5 10,658.3 5,598.6 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/28/2018 PERFP;18,760.0-18,766.0 ll: 6 11,884.0 5,972.1 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/28/2018 PERFP;18,916.2-18,922.2 :till Notes:General&Safety PERFP;19,078.4-19,084.4 ;l;l; End Date Annotation PERFP;19,236.8-19,242.8 „I1. 9/12/2017 NOTE:18,315'MILLED ALUMINUM SHOE OUT TO 2.74" PERFP;19,398.8-19,404.8 EI.t, NOTE: PERFP;19,558.4-19,564.4 .I:K PERFP;19.718.7-19,724.7 (El. PERFP;19,880.8-19,886.8 it'ti PERFP;20,042.4-20,048.4 .11. PERFP;20,204.4-20,210.4 IlEl, PERFP;20,366.1-20.372.1 'HI PERFP;20,759,5-20.765.5 (li PERFP;20,921.0-20,927.0 - ;kr PERFP;21,078.3-21,084.3 :fill PERFP;21,237.3-21,243.3 EE PERFP;21,398.2-21,404.2 ,ll) PERFP;21,558.8-21,564.8 ;ll. PERFP;21.719.2-21,725.2 Il-Ii PERFP;21,881.7-21,887.7 ,tsl. PERFP;22,042.7-22,048.7 ;l;l; PERFP;22,202.8-22,208.8 III) PERFP;22,365.5-22,371.5 lit: PERFP;22,528.5-22,534.5 ;ll. PERFP;22,690.5-22,696.5 :BE PERFP;22,853.2-22,859.2 lit PERFP;23,013.7-23,019.7 LINER-PERFORATED I?): LOWER;18,315.0-23,119.6\ • • Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent Monday,June 04, 2018 2:58 PM To: Loepp,Victoria T(DOA) Cc: NSK Well Integrity Supv CPF1 and 2 Subject: RE: [EXTERNAL]KRU 2K-32(PTD 217-042, Sundry 318-216) Sealant for PC leak Attachments: 2K-32 proposal summary_REV1.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached is a revised 2K-32 procedure with additional detail. Please let me know if you have any more questions. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday,June 4,2018 1:26 PM To: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: [EXTERNAL]KRU 2K-32(PTD 217-042,Sundry 318-216)Sealant for PC leak Jan, Please provide additional detail in the procedure. Circulation path,volumes... 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 aC7alaska.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 Victorialoem@alaska.gov 1 • • pro A./7---e, g � Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Thursday, May 24, 2018 9:27 AM To: 'Coberly,Jonathan' Subject: RE: [EXTERNAL]RE: 2K-32 (PTD:217-042) Straddle Packer Question Follow Up Flag: Follow up Flag Status: Flagged Jonathan, No definitive threshold. Please submit sundry and it will go through our review and approval process. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska SCANNED ,j U N 1 S 2 Q 18 Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservatipn 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 From:Coberly,Jonathan<Jonathan.CoberlYconoco hilli s.com> Sent:Thursday, May 24, 2018 9:11 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Buck, Brian R<Brian.R.Buck@conocophillips.com> Cc: Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL]RE: 2K-32 (PTD:217-042)Straddle Packer Question I'd feel comfortable at this time to propose sitting the packer within 25'of the leak at 10,977' MD. If you do propose further logging based on this TVD difference,what is the threshold we would have to get below to eliminate the additional testing? I ask that to gauge possible repairs for future project scopes in Kuparuk. TOC: 10,223 MD/5,467'ND Proposed Top Packer Set Depth: 10,952' MD/5,688'ND Difference: 729' MD/221'ND Jonathan Coberly Workover Engineering Team Lead ConocoPhillips Alaska, Inc. 700 G Street,ATO 1378 1 Anchorage,AK 99501 • 110 Office: 907-265-1013 Cell: 907-538-8398 From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent:Thursday, May 24, 2018 8:31 AM To: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Coberly,Jonathan<Jonathan.Coberly@conocophillips.com> Cc: Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov> Subject: [EXTERNAL]RE: 2K-32 (PTD:217-042)Straddle Packer Question Brian, What was the TVD distance between the TOC 7-5/8"and the top packer depth?The additional log that may be require d is a periodic WFL or possibly a more frequent MIT-IA. This additional testing will be specified when we review your submitted sundry for the workover. 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 aC�alaskagov 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: Buck, Brian R<Brian.R.Buck@conocophillips.com> Sent:Wednesday, May 23, 2018 11:35 AM To:Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov Cc: Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov> Subject: RE:2K-32 (PTD:217-042)Straddle Packer Question Victoria- Did you guys have a chance to look into this yet and/or do you have any questions for us? Thank you, Brian Buck Completions and Workover Supervisor office:907-265-6826,cell:907-223-6320,fax:918-662-6213;700 G St.,ATO-1340;Anchorage,AK 99501 From:Coberly,Jonathan Sent: Friday, May 18, 2018 1:46 PM To: 'victoria.loepp@alaska.gov'<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Melvin.rixse@alaska.gov Subject: 2K-32 (PTD:217-042)Straddle Packer Question 2 • • • Victoria, Thank you for spending the time today to discuss the potential post-rig monitoring/testing needs for the 2K-32 (PTD: 217-042)straddle packer rig workover. Please review the plan and let me know if you have an questions. We are particularly interested in if we will need to add any tests, logs,etc.to the operation of this well as a result of isolating he casing damage with this method to satisfy the high packer waiver. Jonathan Coberly Workover Engineering Team Lead ConocoPhillips Alaska, Inc. 700 G Street,ATO 1378 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 3 • 0 217042 110 WELL I,Ca 29197 771ANSMITTAL RECEIVED I,. PROACTIVE DIAGNOSTIC SERVICES, INC. APR 2 6 2018 To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907)245-8952 SCANNED :;' ' .. 1) Leak PointTM Survey 09-Apr-18 2K-32 CD 50-103-20757-00 2) Signed : liki, • Date : I t U Print Name: 1 V `ClAQ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CDMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:W chives\MasterTemplateFiles`,Templates\Distribution\TransmittalSheets\ConocoPhillipsTransmit.docx • 217042 WELL LOG 2 9 1 9 5 TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED APR 262018 To: AOGCC . Natural Resources Technician r AO 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED 1) Leak PointTM Survey 09-Apr-18 2K-32 run 2 CD 50-103-20757-00 2) L OP LI Signed : Date : ' 3 0 I Print Name: Uv '*1 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\IvlasterTemplateFiles\Templates\Distribution\Transmittal Sheets\ConocoPhillips_Transmit.docx 0 . o I I o o ' 6' @ @ (N o m E E o n - E E V 0 N Z • C Y y Y y Y in Y Y a)a ) E \- M C..) y 2 N ca N@ N N y N n n a) _I- _I- _I @ _I o 0 0 o 5 } :o Qo Qo QJI Q • Q in in a) 0 a) a) OZ ZO Z )e T 0 10 a 0 0 0� 0 o 0 co 8 0 0 0 U) m Z Z E -1 E —11•ai E @ E 5. E< NI NI NI NI NI NI NI NI ,� F. 3 @ 0 @Q' @ 2-11 M M M M- M M- M M -, d occ occ o@I a).z aa)2ci Y YI) YE Y � YE Q @ y a' N N ND N t ND Nr Nm NE c @ LL w � w E LL I it Cf I • I • I- ° a? a�:> a) 0 a)v 50 dN dE dJ dJ d -' d -' 0.U) dU) .J O (0 .(7) (07) u)0 (0Z u)'- 00 0r 00 00 00 00 O21 0= ci O = o w �° ayi ° ayi «° a)I :° a) :° N coW mu) ai ai ai 1 ai 1 ai�1 ai 21 ai 0 ui Z o 0 0W1 0wi 0 0 0Z1 OZ LL8 w � LL �1 LL �1 w �1 LL �1 w21 LL 21 y d E a) cv a) 0 u j c)0 0 0 0 1 0 1 0 c) w 0 y c) > 0 CC C CC 7 E 'Ea- •c O' .0 a) C C C 'E2 c 'j C 'j c 'j Es c I 'cI N @ , ° 20 O20 2T5 2° 2w 2W 2w 2:;-- o o o•— 28 20 co J �� 0� U~ 0> U> U T U T U N U N 0 y O N U Z U LL 0NI a),,,Ia),,IyNl a),,,Ia) @ N@ a) 0 N0 a) 0 N0 N0 a) a) Q EO w M w M w M w M w M w p' w w w w w w w w w Q' w u) w u) 0 O d 3 c oN. N. N. N. a Y 0 0 0 0 0 0 co No- No. 0 0 0 J @N- N N N N N N N N N N W 2 N N N N o) o) o) o> o) o) 0) o) o) 01 0) 0) 0) p, d N N N N N N N N N N N N N Ce Q @ a' 0 CO 0 CO CO 0 CO c0 c0 CO CO CO cD U W °z U V O O VI N CO c0 CO Q ao i4 y OIO co ,r y 7 \. @ fn CO N N co 01 . co N co co 0 C O 0 Z O 5 V O aD co O O O N a▪) o N co n a) M E a v U 0 E c o r u) — Q N re Z ou M 6. NN w r o 0 H n O a) 5 z o J 2 G ' N @ r co To Ca re 45 1 3 J N • a) Z (1) a o Q x▪ g I Y a) c Q zl N Z Iii U 0 E _, EL- @0 Z j ✓ c E 0 0 0 0 0 0 0 0 0 0 0 0 0 CO Z @ @ @ @ CO @ CO @ @ CO @ @ @ to O) O) _6) _) O) O) O) O) O) O) _5) 0) _) o rn 0 0 0 0 0 0 0 O 0 0 0 0 0 N 0 Z -I 0 N N N is)N N is)N N is)N cc)N N N N )!') • > 0 r y N N N N N N N N N N N N N O a) 0 CD E M M M M M M M M M M M M CO Z -C Co N N N N N N N N N N N NN 0 0 .2w O z N @ Q o E E _ w «°co7. z 15 o co W as c 0 d Cr N z W c 2 0 0 0 0 0 0 0 0 0 0 0 0 0 CU7 E D I Q N J O 0 0 I a) o- 0. 0 0 0 0 0 0 0 0 0 0 0 0 0 4 CL o ~ 3 2cA w w w w w w w w w w w w w • • o ' �' r o •y o • N o • • •• •• ° y N N co y y N y y N O OM '0 O o) (6 ( (o CO N CO CO CO (o U rZ o. a a 0. a a a a a a 0 I .o a. N . E >_ Y O o O O O O O O O O J N r o 0 0 >U U> >U >U >U >U >U 0 N I 0 0 Qel, Z ' > > > > > > > M O j j a a • r r r- r- r- M M M M M W w W W w w W w w W o a 0Nix Z Ml Ml > F>- N N N N N CO CO CO CO CO Z E I 0 0 0 0 0 0 0 0 0 n to = 'r F. Y Y Y cI cl cl Y cl Q Q Q Q Q Q Q Q Q Q > acc i Q N N - N'- N•- N •- N'- Z Z Z Z Z Z Z Z Z Z 1.- I rz INI INI ISI 1 1 N (N (N (N N (N N N N (N U Q V Q t Q N Q o) Q N Q N M M M M M M M M M ) Y ' I J a(/) a U) o. S2 d 9 a c) a. Y Y Y Y Y Y Y V Y Y V Y D N r 01- 07:1 0C 0C OC 0C N N N .-, N .0 N • N N N N .-; N .0 N • N W U)C 9 N 01 N 01 N u) N(/j N%j N(/j N j N O N y o) N N G) j N O N G) a) G) < Zli LL LL Il Zl Il ZI LL ZI LL Zl Il CD Il LL Li- Il,� Il CO Il Il Il j IL,� Q ° °� C� 0Q �Q .C.)(D �0_ 20 �g .c.)0_ .c.)co o•o aU a2 .c.)a. c)0 .C.)'0 Y� 1 1 = E I •E I c c c c c .� c — c— E — E °- c— c— c— c— c a o 'cH 2 O 2 O O U) O U) O U) O() O >. O >. O >. O T O T O > O > OO >• O >. N W O(n �. VV N N N Nt') N N N (r)' N N N IX U) II N � N N N N1 0 I N NI N NI a) a) a) a) _a) a) a) ti ) N j Or W N NI C N LI(<10) WU) WM T.,g' LTJ P,' LT,P4 W(/) W(/) WU) W(n WU) WU) WU) WU) WU) LTJ up) N2 IT g' O 0 . U N- N- N- r N- r n N- r N- N- N- N- N- n N- r•- O.a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 J N N N N N N N N N N N N N N N N N W x rn o) rn o) rn o) rn rn rn o) o) o) rn o) rn o) 0) a. NNNNNNNNNNNNNNNN N IX Q (O cfl f0 (D (O c� CO (O (O (0 c0 (O c0 CO CO (O (C V v o Z QTrTr CL Is. Q o 1 r•- 2 G G 0- ' O coo N v v QTa. C E 1 M o V r U ‘- 0 J N a) on Q csi (y tC a N r i- r 5 Z o G > N Ca CC CO c ' a 0 Q c Y10 I 0 Q OE '' Q m U , 0 E c co co m (o m )a )o m CO m CO m CO CO CO CO CO m 5 m N I m (o (o (o (o (o (o (o as (o co (o (o (o CO CO V CO N0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 aoi 0 co CO m N N N m CO N CO CO CO CO CO CO N M m a 0 5 o) a a a o) 0) CO 5 5 5 5 5 a) 0) a) C 0 0 0 0 0 0 0 0 0 b 0 0 0 0 0 0 J 0 NO I U (O LO(0(0 (0 (O �f) U) �0 u') U) O U) l0 l0 H (0 (0 N N N N N N N N N N N N N N N N N O M M CO M M CO CO CO CO CO CO CO CO CO M M M M h co c0 cc co cc cc cc cc c0 c0 cc c0 cc cc c0 cc cc co I ✓ N N N N N N N N N N N N N N N N N N N co OLa O (n U N ," 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 t) 0 o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d a. 2 W w w w w w W LU W W LU W LU LU W LU J LU • • o •N • oN c 2 • O O �Q o `o o o to 0 CL CL a a Z N. Z a 0 N N O O F F O } } } p M M N H H O E CIJ m m J w 0 U 0 ' N N@ N m p O O N 0 CL CL 0 O Y o c oc u) Cl) 0 0 0 M a >, Z Y m N 10f> MI d N U _ U m C C C C N O) c •0 O - H N m O O I- p II C Z E � E� u) Co V) N Z _o o Z' g Z 7 d D (0 C (0 C N N N N D L 0 �O U C a) c a) f`') M M M 0 LL f� Q N0 Nm a� E a� E Y Y Y Y > m m o lo LL Eu LL O N N N NI NI (X 0 0 co Tt( N. LL N I � 111"6 m O O- 073. O O D 0 U J J U c U W ( a U) a 0 4 U C U,_ U,_ u > < (0o mo o) -o v < O ain 2- a m� Tv.- ui c 6E 6a 6a 0_ a Z I1 Il 0 m 0 m lL = ll y ll O Il O C Q y c) 0 1 Y U p v_ p _U 0 U d' c)N U v Y m Yq m CF- E t N W Eo E o E C E ...- C C E ., N W £ lin N m O` V O`_ <t o O U O U O m O m O m O m .4'0 E } �J } N NIC _m NI▪ O W m 0 O o m o m N m N o W o V m 1e Q 5 [0 g; O We N2 Wu) Wu) WU WU WU WO N2 p LL O to IN IN IN n IN d m Y /� 0. a•• li J 0 N N N N N N N N lEE 0 N O 0 o III W d N N N N N N N N co co co ia co co to Z Ce ° CO CO N W Z o. oi m V ( Jmm OO) _ J as Z O o w Cl) < p 0 0 W os to 0 0 M LO 01 O J D. C 7 CD a. co o U Mt- co o 0 m • G 0 o co co 'a o N N m rn o, O M E .1- ,.., 0 V 0 Z 0 } � Q N O tw' M ra a. N p E r r __ co O �1 C� Z ,15 (0 N C CO > v a) co K o c c E Y t, .O - 7 Cl) m• a,, .O. C `O) ) V/ Q 0 N c c p Q d Y C (` mTo 63 c a Q c O a 0 c O Z E m >+ 121 E 0 C C 0 0 z co u) m (o `m m a) m a) m a) m I r- 0 m v 0 0 ai 0 0 0 0 0 0 ai I - Q N ✓ m Ta 2 m :° m :o . }0 2 O © Z : o ° 0 i (o O 0 0 0 J 0 0 0 0 0 0 J E G N > 0 0 o CO CO CO CO CO CO CO w W g >- er I- v c v o 0 0 0 0 0 0 C W Co Q ° O M M M CO CO CO Co CO Co CO t- CO Co CD OD W W W W W W r N N N N N N N N N N d W p 0 I.- u)N N a m a, a c ` _ ai E E Z m N Y W Co co Co (o 1 ° m o co y Z F Co VZ o O (� -- m Q O c0 Q O U w N U 0 0 0 0 0 0 0 0 0 C N .0 J N E t) ° a -o' o 20. E 0 d 0 0 0 0 o 0 0 0 0 0 0 ) a o ° as O o ti W W J W W W W W W J ? U a 0 0 0 • • o I o 0 0 o 0 M r. in o az f) z N N co U > 5 z 6 T ct Lo \. ci Za z EC I '• I Q i 1 I z o 1 1 r coVs OC < p coa. a J W = a. IX V 1 W 0Z V 0 o < 11 . II 0 3 0 co co o O• N a O U M 0 r 0 CO d E v QN C III IIIaocd Y V LLi r NII Z ► 5 F- r G N CO a1.. > > a) d 4111.1L CO a o 0 Q Do I Y m O a ICC Z E 1 ces z I. d N • N N lb..' ap N r 'ct N 0 A e' F 9 O 01 n C d N .> r2 D CO O N V N y a d R v m N E ° o E E 2 1 7 0 42 • RECEIVED. 28808 farm nnr Schlumberger AOGCGransmittal#: 27NOV17-SP02 Drilling & Measurements DATA LOGGED Product Delivery 1%/ 2ot1 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well Name: 2K-32 T.O.C. Date Dispatched: 8-Nov-17 Service Order#: 17AKA0005 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 1 Contents on CD 7-Jun-17 Processed Sonic Top of Cement Evaluation x x Digital Data N/A Contents on CD DLIS/LAS Data x CD 1 Contents on CD Data: DLIS/LAS x Graphics: PDF x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkampt conocophillips.com Alaska PTSPrintCenter(a�slb.com Attn:Tom Osterkamp Attn:Stephanie Pacillo Received By: 1), d • S Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Tuesday, November 21, 2017 10:55 AM To: jake.voss@conocophillips.com' Cc: Loepp, Victoria T (DOA); Bettis, Patricia K(DOA) Subject: KRU 2K-32, PTD 217-042, SonicScope data submission, logs missing Hello Jake, I am completing the compliance review for KRU 2K-32, PTD 217-042,completed June 14, 2017. During my review of the 10-407 packet submitted, I discovered a data CD attached to the 10-407.The data CD was for a SonicScope TOC completed on June 7, 107. No paper logs accompanied the data CD. Please note that downhole data should be submitted separately from a 10-407 packet as the data and packet are checked in differently. The well is not in compliance until the two paper logs for the SonicScope are submitted to the AOGCC office. Please send the logs to my attention. Please provide the logs by December 11, 2017. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 • • ®F Tit w Alaska Oil and Gas \� ��j,�s THE STATE g� -„.414 ®f® TT ®® sKA Conservation Commission 333 West Seventh Avenue =w-= GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 o� ALAS Y'� Fax: 907.276.7542 www.aogcc.alaska.gov Mark Shulman Senior Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-32 Permit to Drill Number: 217-042 Sundry Number: 317-453 Dear Mr. Shulman: 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, Hollis S. French Chair DATED this � day of October, 2017. RBDMS (,, OCT 1 2017 • S RECEIVED STATE OF ALASKA SEP 2 5 201 ALASKA OIL AND GAS CONSERVATION COMMISSION jJ' lei Ot APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon H Plug Perforations LJ Fracture Stimulate H Repair Well LJ Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to WAG injectiorD 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 217-042-0 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 501032075700 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No Z KRU 2K-32 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588,ADL 25589,ADL 25604,ADL 25607 . Kuparuk River Field/Kuparuk River Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 25,598' - 6,442' • 23119.6 - 6467.1 • Casing Length Size MD ND Burst Collapse Structural Conductor 140' 20" 179' 179' Surface 3,443' 10.75" 3,480' 2,955' Intermediate 13,691' 10.38" 13,728' 6,363' Upper Liner 4,771' 4.5" 18,326' 6,438' Lower Liner 4,805' 4.5" 23,120' 6,467' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13,876-15,010';15,166'-16,303'; • 6,366-6,374';6,376-6,391';6,390'- 3.500" L-80 13,614' 16,456-17,015';17,166'-17,657'' 6,413';6,416-6,424' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packer:Baker HRD-E ZXP Packer: 13,555.1'RKB(MD);6,350.3'(TVD) 12.Attachments: Proposal Summary E Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program LI BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ • 14.Estimated Date for 1/1/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended H 16.Verbal Approval: Date: GAS ❑ WAG ❑✓• GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned H 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.11 Authorized Name: Ad(K Shv/MAA Contact Name: Mark Shulman Authorized Title: $r,.; • Petro I c4.1 , Er5 IL.ter' Contact Email: Mark.shulman@conocophillips.com �� q Contact Phone: (907)263-3782 Authorized Signature: %��r✓�— .._4 Date: I Z L`/� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(7—i-f53 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test F7 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ErNo CC'� ��ll g7 Spacing Exception Required? Yes H No Subsequent Form Required: `Q 46 RB® � (.L U°� J 2017 APPROVED BY Approved by: --Cf4 ., COMMISSIONER THE COMMISSION Date: 1 i 1,4 gay - 0 ,nl,`/� /'rte Submit Form and r 0-4b3 Revised 17 ppro�di 11 io Lalid for 12 months from the date of approval. Attachments in Duplicate • • 2K-32 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2K-32 (PTD# 217-042) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been. complet Area of Review: Kuparuk well 2K-32 was completed as an injector on 6/14/1 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery o ofdil. This well will support existing producers 2K-30 and 2S-01. The top of the Kuparuk C sand was found at 13,296' MD/6,318' TVD Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset producers (2K-30 and 2S-01), there are no additional production/injection wells located within a 1/4 mile radius of the 2K-32 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2K-32 is good and is classified as a"Single Casing"well. The injection tubing/casing annulus is isolated via a Baker HRD-E ZXP packer located at 13,555'MD (6,350.3' TVD). A State-witnessed MIT-IA will be performed once well 2K-32 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (10,223' - 13,738' MD/5,467' -6,363'TVD)to insure injection zone conformance. The CBL interpretation was completed on the PTD's. The 20" Conductor was pre-driven The 13-1/2" Surface casing was cemented with 1465 sx 11.0 ppg bbls LiteCrete Lead Cement, 22sx 12.0 ppg LiteCrete Trail Cement. Stage 2: 211 sx 15.8 ppg Class G. The 7-5/8" Intermediate casing was cemented with 688 sx 15.8 Class"G" KUP PROD • 2K-32 • 10) . ConocoPhillips Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status Inel(°) MD(ftKB) Act Btm(ftKB) m«.,oylynrpc 501032075700 KUPARUK RIVER UNIT PROD 95.56 24,358.51 25,598.6 " ... Comment 1425(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2K-32,9121/2017 10)12:01 AM SSSV:NONE Last WO: 38.75 6/14/2017 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER 33.6 Last Tag: Rev Reason:18,315'MILLED ALUMINUM pproven 9/21/2017 ._..._....._...._...._...__..................._..._......_.....i. _"_._. SHOE OUT TO 2.74"-SEE NOTES Casing Strings JIM Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread "A-AJC0NDUCTOR39019.0• CONDUCTOR 20 18.500 39.0 179.0 179.0 154.19 GRX52 GAS LIFT;2,781.9 = Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 103/4 9.950 37.9 3,480.4 2,954.8 45.50 L-80 Hydril 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE;37.9.3,480.4 INTERMEDIATE 75/8 6.875 36.4 13,727.6 6,363.1 29.70 L-80 Hyd563 GAS LIFT;4,536.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread GAS LIFT;6,832.0 LINER-PERFORATED 41/2 3.958 13,555.2 18.326.1 6.438.3 12.60 L-80 Hyd 563 UPPER GAS LIFT;8,995.0 • Liner Details GAS LIFT;10,658.3Fili ) Nominal ID Top(ftKB) I Top(TVD)(ftKB)I Top Incl(") Item Des Com (in) GAS LIFT;11,884.0 13,575.2 6,352.3 84.44 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 15.5 ppf L-80 4,870 Hyd 563 box x box SLIDING SLEEVE;13,388.8 �, 13,578.0 6,352.6 84.48 HANGER 'Baker 5.5"x 7.625"Flex-Lock Liner Hanger L-80 Hyd 4.800 NIPPLE;13,476.2-. PLUG;13,497.8 ' 563 pin x pin 13,599.5 6,354.6 84.85 SBE Baker 80-40 Sealbore Extension,5"L-80 Hyd 521pin 4.000 LOCATOR;13,584.0 x 4-1.2"Hyd 521 box SEAL ASSEMBLY;13,585.1 'i. 13,619.2 6,356.3 85.19'XO REDUCING Crossover Pup 4-1/2"L-80 Hyd 521 pin x 4-1/2"Hyd 3.910 563 pin INTERMEDIATE;36.4-13,727.6 16,484.0 6,390.7 89.97 SWELL Baker-"Swell Packer#4-"D"6.07"OD SR 3.910 PACKER 052826-002-10 16,497 PERFP;13,875.6-13,881.8 ;tjt? • _ 16,702.5 6,393.5 87.98 SWELL Baker-"Swell Packer#3-"C"6.02"OD SR 3.930 PERFP;14,035.2-14,041.2 if EE PACKER 052826-002-28 16,707 PERFP;14,197,1-14,203.1 ..l:t: .� Casing DescriptionOD(in) IID(in) Top(ftKB) ISM Depth(ftKB) ISet Depth(TVD)...Wt/Len Grade !Top Thread PERFP:14,35e.e-14,364.e lLINER-PERFORATED 41123.980 18,3150 23,1196 6,467.1 12,60 L-80 Hyd 563 PERFP;14,520.7-14,526.7 ;l;l; - LOWER PERFP;14,682.3-14,688.3 113E Liner Details No PERFP;14,841.7-14,847.7 EtEtTop(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com Nominal ID PERFP;15,004.2-15,010.2 - ;l l) 18,315.0 6,438.4 90.10 SETTING Baker HRD-E Liner setting sleeve 5.5"x 7.625"L-80 4.900 PERFP;15,166.7-15,172.7 ;t_i_ SLEEVE 5.5"Hyd 563 pin PERFP;15,328.6-15,334.6 EEli 20,395.5 6,445.7 88.11 SWELL Baker-"Swell Packer#2-"B"6.01 GD SN: 3.930 PACKER 052826-002-19 22817 PERFP;15,4872-15,493.2 El • PERFP;15,649.6-15,855.6 Eft 20,611.2 6,447.6 91.09 SWELL Baker-"Swell Packer#1-"A"6.03"OD SN 3.890 PACKER 052836-002-36 23020 PERFP;15,8122-15,818.2 :ff PERFP;15,974.5-15,980.5 .fl) Tubing Strings Tubing Description 'String Ma...l ID(in) 'Top(ftKB) 'Set Depth(ft..f Set Depth(TVD)(...�Wt(Ib/ft) I Grade I Top Connection PERFP;16,135.1-16,141.1 l:' TUBING 3 1/2 2.992 33 6 13,613 0t 6,355 8 9.30 L-80 EUE-m PERFP;16,297.0-16,303.0 Eltl. Completion Details PERFP;16,458.8-18,462.8 fEi'. Nominal ID NNW Top(COB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) � 33.6 33.6 0.00 HANGER FMC 4.5"x 11"Tubing hanger 3.900 PERFP;16,849.4-16,855.4 1!!) 78.0 78.0 0.09 XO 4.5"12.6 ppf L-80 TXP-m x 3.5"EUE pin Crossover 2.992 PERFP;17,009.8-17,015.0 a - REDUCING PERFP;17,186.5-17,172.5 .illi;, 13,388.8 6,331.5 82.69 SLIDING Baker CMU sliding sleeve w/2.813"DS profile 2.812 SLEEVE 82.7°/5972TVD PERFP;17,327.7-17,333.7 :Ell PERFP;17,488.3-17.494.3 -!IEE i 13,476.2 6,341.6 83.61 NIPPLE Cameo 2.75"DS profile Landing Nipple 83.6/ 2.750 6342'ND PERFP;17,651.0-17,657.0 lit . �t 13,497.8 6,344.0' 83.59 PLUG Halliburton 3-1/2"Mirage Plug,EUE-m,Rupture 7750 psi 2.880 PERFP;17,810.8-17,816.8 Eli - 83.6°/6344'TVD PERFP;17,972.9-17,978.9 fl_IE 13,584.0 6,353.1 84.59 LOCATOR Baker GBH-22 Locator(OD 4.65")Larger OD above 3.050 PERFP;18,129.1-18,135.1 :fl) located PERFP;18,289.1-18,295.1 la! 13,585.1 6,353.2 84.61 SEAL Baker GBH-22 Seal Assembly w/mule shoe--below 2.980 LINER-PERFORATED ill ASSEMBLY located UPPER;13,555.2-18,326.1 Perforations&Slots PERFP;18,436.1-18,442.1 }?i? Shot PERFP;18,598.0-18,604.0 ;lt! Dens Top(TVD) Bun(TVD) (shots/f PERFP;18,780.0-18,766.0 :SE Top(ftKB) Btm(ftKB) (ftKB) (BOB) Zone Date t) Type Com PERFP;18,9162-18,922.2 0 13,875.6 13,881.6 6,366.2 6,366.3 6/10/2017 4.0 PERFP PERFP;19,078.4-19,084.4 - 6 14,035.2 14,041.2 6,369.8 6,369.9 6/10/2017 4.0 PERFP PERFP;19,236.8-19,242.8 Ili 14,197.1 14,203.1 6,373.0 6,373.1 6/10/2017 4.0 PERFP PERFP;19,398.8-19,404.8 :lel: 14,358.8 14,364.8 6,375.2 6,375.2 6/10/2017 4.0 PERFP PERFP;19,558.4-19,564.4 - 3i i 14,520.7 14,526.7 6,375.2 6,375.2 6/10/2017 4.0 PERFP PERFP;19,718.7-19,724.7 - it if PERFP;19,880.8-19,888.8 0)'d.. 14,682.3 14,688.3 6,372.6 6,372.5 6/10/2017 4.0 PERFP PERFP;20,042.4-20,048.4 - El. 14,841.7 14,847.7 6,372.7 6,372.8 6/10/2017 4.0 PERFP PERFP;20,204.4-20,210.4 6 15,004.2 15,010.2 6,374.4 6,374.5 6/10/2017 4.0 PERFP PERFP;20,366.1-20,372.1 if) 15,166.7 15,172.7 6,376.0 6,376.0 6/10/2017 4.0 PERFP 111 15,328.6 15,334.6 6,380.6 6,380.8 6/10/2017 4.0 PERFP 15,487.2 15,493.2 6,385.9 6,386.2 6/10/2017 4.0 PERFP PERFP;20,759.5-20,785.5 ififi PERFP;20,921.0-20,927.0 }?l;, - 15,649.6 15,655.6 6,391.3 6,391.4 6/10/2017 4.0 PERFP PERFP;21,078.3-21,084.3 ,1.1: 15,812.2 15,818.2 6,395.0 6,395.0 6(10/2017 4.0 PERFP PERFP;21,237.3-21,243.3 - ;ll; 15,974.5 15,980.5 6,394.9 6,394.8 6/10/2017 4.0 PERFP PERFP;21,398.2-21,404.2 ;El;. 16,135.1 16,141.1 6,392.3 6,392.2 6/10/2017 4.0 PERFP PERFP;21,558.8-21,564.8 8. 16,297.0 16,303.0 6,391.3 6,391.3 6/10/2017 4.0 PERFP PERFP;21,719.2-21,725.2 - .1? 16,456.8 16,462.8 6,390.7 6,390.7 6/10/2017 4.0 PERFP PERFP;21,881.7-21,887.7 ;EI: 16,849.4 16,855.4 6,401.8 6,402.3 6/10/2017 4.0 PERFP PERFP;22,042.7-22,048.7 ii li - 17,009.8 17,015.8 6,412.9 6,413.3 6/10/2017 4.0 PERFP PERFP;22,202.8-22,208.8 •(EII' - PERFP;22,365.5-22,371.5 17,166.5 17,172.5 6,416.6 6,416.6 6/10/2017 4.0 PERFP ilii PERFP;22,528.5-22,534.5 17,327.7 17,333.7 6,418.8 6,418.9 6/10/2017 4.0 PERFP @l: PERFP;22,890.5-22,696.5 3?l? - 17,488.3 17,494.3 6,421.4 6,421.4 6/10/2017 4.0 PERFP PERFP;22,853.2-22,859.2 ;fl) 17,651.0 17,657.0 6,424.2 6,424.3 6/10/2017 4.0 PERFP PERFP;23,013.7-23,019.7, LINER-PERFORATED ' :El'. LOWER;18,315.0-23,119.6A KUP PROD • 2K-32 . ConocoPhillips 0113 Alaska,Inc. dnOcaPMlaps. 2K-32,9/21/2017 10:12'.04 AM Vertical schematic(actual) HANGER 33.6 Perforations&Slots �� � snos CONDUCTOR;39.0-179.0• ^ Den GAS LIFT;2,781.9 - Top(ftKB Btrn 5KB T(RKB op D) Bt D) Zone Date (sht tslf TypeCom 1OMB) (RIO) (ftKB) ) 17,810.8 17,816.8 6,429.0 6,429.2 6/10/2017 4.0 PERFP SURFACE;37.9-3,480.4 17,972.9 17,978.9 6,433.1 6,433.2 6/10/2017 4.0 PERFP GAS LIFT;4,536.1 18,129.1 18 35 1 6436 I 6436 1 6/10/2017 4.0 PERFP GAS LIFT;6,832.0 GAS LIFT;8,995.0 IN 18,289.1 18 295 1 6 438 4 6 438 4 6/10/2017 4.0 PERFP MIK 18,436.1 18 442 1 6 437 8 6 437 8 6/8/2017 4.0 PERFP GAS LIFT;10,658.3 e M - 18,598.0 18.1. 1 6 434 8 6 434 7 6/8/2017 4.0 PERFP GAS LIFT;11,884.0 > 18,760.0 18 766 1 6 431 7 6 431 5 6/8/2017 4.0 PERFP SLIDING SLEEVE;13,388.8 18,916.2 18 922 2 6 429 1 6 429 6/8/2017 4.0 PERFP NIPPLE;13,4762.. = 19,078.4 19,084.4 6,427.8 6,427.8 6/8/2017 4.0 PERFP PLUG;13,497.8 19,236.8 19,242.8 6,427.4 6,427.4 6/8/2017 4.0 PERFP LOCATOR;13,584.0 .,�',� I 19,398.8 19,404.8 6,428.9 6,428.9 6/8/2017 4.0 PERFP SEAL ASSEMBLY;13,585.1 • 19,558.4 19,564.4 6,429.0 6,429.0 6/8/2017 4.0 PERFP 19,718.7 19,724.7 6,431.2 6,431.3 6/8/2017 4.0 PERFP INTERMEDIATE;36.4-13,727.6 19,880.8 19,886.8 6,435.3 6,435.4 6/8/2017 4.0 PERFP PERFP;13,875.6-13,881.6 '.&l'. .... 20,042.4 20,048.4 6,438.3 6,438.4 6/8/2017 4.0 PERFP PERFP;14,0352-14,041.2 illi PERFP;14,197.1-14,203.1 V20,204.4 20,210.4 6,440.5 6,440.5 6/8/2017 4.0 PERFP PERFP;14,35e.6-14,364.6 20,366.1 20,372.1 6,444.7 6,444.9 6/8/2017 4.0 PERFP PERFP;14,520.7-14,526.7 itEli 20,759.5 20,765.5 6,446.4 6,446.4 6/8/2017 4.0 PERFP PERFP;14,682.3-14,688.3 MI 20,921.0 20,927.0 6,446.8 6,446.8 6/8/2017 4.0 PERFP PERFP;14,841.7-14,847.7 lit 21,078.3 21,084.3 6,447.9 6,448.0 6/8/2017 4.0 PERFP PERFP;15,004.2-15,010.2la 21,237.3 21,243.3 6,449.2 6,449.2 6/8/2017 4.0 PERFP PERFP;15,166.7-15,172.7 iKL 21,398.2 21,404.2 6,449.8 6,449.8 6/8/2017 4.0 PERFP PERFP;15,328.6-15,334.6 -ilili 21,558.8 21,564.8 6,452.3 6,452.4 6/8/2017 4.0 PERFP PERFP;15,487.2-15,493.2 ;l?ll PERFP;15,849.8-15,655.6 El?G:. 21,719.2 21,725.2 6,455.6 6,455.7 6/8/2017 4.0 PERFP PERFP;15,812.2-15,818.2 in 21.881.7 21,887.7 6,458.8 6,459.0 6/8/2017 4.0 PERFP PERFP;15,974.5-15,980.5 - ME 22,042.7 22,048.7 6,464.7 6,464.9 6/8/2017 4.0 PERFP PERFP;16,135.1-16,141.1 - .loll 22,202.8 22,208.8 6,468.4 6,468.3 6/8/2017 4.0 PERFP PERFP;16,297.0-18,303.0 22,365.5 22,371.5 6,462.8 6,462.5 6/8/2017 4.0'PERFP PERFP;16,456.8-16,462.8 :!I'll 22,528.5 22,534.5 6,458.4 6,458.4 6/8/2017 4.0 PERFP - 22,690.5 22,696.5' 6,461.8 6,461.9 6/8/2017 4.0 PERFP SIMI PERFP;16,849.4-18,855.4 : 22,853.2 22,859.2 6,464.0 6,464.1 6/8/2017 4.0 PERFP PERFP;17,009.8-17,015.8 :IME 23,013.7 23,019.7' 6,464.9 6,464.9 6/8/2017 4.0 PERFP PERFP;17,166.5-17,172.5 :Ill; Mandrel Inserts PERFP;17,327.7-17,333.7 - iMI St MIPERFP;17,488.3-17,494.3 •tl' on Top(TVD) Valve Latch Port Size TRO Run PERFP;17,651.0-17,657.0 ilii; N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (pal) Run Date Com PERFP;17,810.8-17,818.6 ilii; 1' 2,781.9 2,491.5 Cameo KBMG 1 GAS LIFT GLV BK 0.156 1,313.0 7/21/2017 PERFP;17,972.9-17,978.9 ME 2 4,536.1 3,592.4 Cameo KBMG 1 GAS LIFT GLV BK 0.156 1,266.0 7/21/2017 PERFP;18,129.1-18,135.1 3 6,832.0 4,444,7 Cameo KBMG 1 5/16 GAS LIFT GLV BK 0.188 1,292.0 7/19/2017 PERFP;18,289.1-18,295.1 ME 4 8,995.0 5,098.2 Cameo KBMG 1 GAS LIFT GLV BK 0.188 1,281.0 7/21/2017 1111 LINER-PERFORATED I 1 5 10,658.3 5,598.6 Cameo KBMG 1 GAS LIFT GLV BK 0.188 1,273.0 7/21/2017 UPPER;13,555.2-18,326.1 6 11,884.0 5,972.1 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0.7/22/2017 PERFP;18,436.1-18,442.1 ilii'. Notes:General&Safety PERFP;18,5982-18,604.0 Mt End Date Annotation PERFP;18,760.0-18,766.0 [:}? 9/12/2017 'NOTE:18,315'MILLED ALUMINUM SHOE OUT TO 2.74" PERFP;18,9162-18,922.2 Mill - NOTE: PERFP;19,078.4-19,084.4 Ef?l? PERFP;19,236.8-19,242.8 - ME PERFP;19,398.8-19,404.8 El PERFP;19,558.4-19,564.4 ;till PERFP;19,718.7-19.724.7 leli PERFP;19,880.8-19,886.8 Nt? PERFP;20,042.4-20,048.4 ME PERFP;20,204.4-20,210.4 •,fill PERFP;20,366.1-20,372.1 Ell MI PERFP;20,759.5-20,785.5 In PERFP;20,921.0-20,927.0 '',In - PERFP;21,078.3-21,084.3 :ME PERFP;21,237.3-21,243.3 M.l'. PERFP;21,398.2-21,404.2 ,;fill PERFP;21,558.8-21,564.8 ;lift PERFP;21,719.2-21,725.2 In PERFP;21,881.7-21,887.7 ;til;. PERFP;22,042.7-22,048.7 Ill PERFP;22,202.8-22,208.8 - lit', PERFP;22,365.5-22,371.5 ;fl;', PERFP;22,528.5-22,534.5 ;fill PERFP;22,690.5-22,696.5 :#till PERFP;22,853.2-22,8592 ;lf; PERFP;23,013.7-23,019.71 LINER-PERFORATED - '.G1:. LOWER;18,315.0-23,119.6_ • 2K 0 • • • • • ADL025589 ADL025588 i 9 10 11 J 'SP1 i r s i i 1 i N f M 8- 16 16 N 15 14 ADL025605 ADL025604 Kuparuk PA 21 22 23 — — I Kuparuk River Unit 0 Well Pad Well Trajectory Open Interval(01) i Y 01 Quarter Mile Radius ADL025607 N ConocoPhillips Active Well 1 — — — — — ^7-------------------� Alaska —— — Inactive Well ---- ! 2K-32 Kuparuk PA • _! Unit Boundary ; 0 0.2 0.4 0.6 0.8 Injection Sundry CPAI Leases I Miles 9/12/2017 Document Path:ttconoco.nehak_shared\ANCILongtenn\GKA Geoscience!geotech_projects\GKA_WeIIstArea_2_Wells!Well_2K_321tne11_2K_32_Inj map.med RECEIVED • STATE OF ALASKA • JUL 14 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDIt z CC la.Well Status: Oil El • Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development LI ' Exploratory❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. - Aband.: 6/14/2017 217-042 • 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 4/29/2017 50-103-20757-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 188.7'FNL,94.4'FEL,Sec 11,T1ON, R8E,UM 5/30/2017 KRU 2K-32 Top of Productive Interval: 9. Ref Elevations: KB:155.8 ' 17. Field/Pool(s): 669.6'FNL,2060'FEL,Sec 15,T1ON, R8E, UM GL: 116.7 • BF: Kuparuk River Field/Kupark Oil Pool ' Total Depth: 10. Plug Back Depth MDlTVD: 18. Property Designation:MX (o0? f4 1885'FNL,3924'FEL,Sec 27,T1ON, R8E, UM N/A ADL 25588,ADL 25589,ADL 25604,A 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 498310 y- 5938115 Zone- 4 25598/6442 TPI: x- 491068 y- 5932360 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 489210 y- 5920588 Zone- 4 N/A 1542/1505 5. Directional or Inclination Survey: Yes 0 (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/ /Den/Neuy U gT T f or c Test M Cr 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 154 H-40 39 179 39 179 42 Driven 10 3/4 45.5 L-80 38 3480 38 2955 13.5 Stage 1:1455 sx 11.0ppg LiteCrete Lead Cement,22sx 12.0ppg LiteCrete Tail Cement. Stage 2: 211 sx 15.8ppg Class G 7 5/8 29.7 L-80 37 13727 37 6363 11 688 sx 15.8ppg Class G 4 1/2 12.6 L-80 13555 23120 6438 6467 6.75 Perforated Liner 24.Open to production or injection? Yes 2 No El 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 3 1/2 13614 PERFORATED LINER @ 13,875-18,312 MD and 6366-6438 ND PERFORATED LINER @ 18,419-23,037 MD and 6438-6465 ND 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. (,1)ngPLE_T 3, Was hydraulic fracturing used during completion? Yes❑ No 0 - Per 20 AAC 25.283(i)(2)attach electronic and printed information Co h,471-7 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L-- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 6/20/2017 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 6/21/2017 13 hrs.53 min Test Period 114.72 699.65 257.54 25 bean 6737 scf/stb Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 232 1324 24-Hour Rate -► 182 1224 439 - Form 10-407 Revised 5/2017 hL- ////71/7 CONTINUED ON PAGE 2 Submit ORIGINIAL onl . jlKfl 111)-4111' /%''�„7 RBDMS 1,1- JUL 1 7 2017 1 i 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1542 1505 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval 13661 6359 information, including reports,per 20 AAC 25.071. Formation @ TPI Kuparuk A4 W Sak D 2340 2169 C-80 3909 3217 C-37 8683 5003 HRZ 11944 5990 • Kalubik 12394 6120 Kuparuk C 13296 6318 Kuparuk A5 24833 6471 TD 25598 6442 Formation at total depth: Lower Kalubik 31. List of Attachments: Daily Operations Summary,Definitive Survey,Cement Report,Schematics, fcsale StcpE Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L.Alvord Contact Name: Jake Voss Authorized Title: Alaska Drilling Manager Contact Email: jake.vossc cop.c Authorized Contact Phone: 265-6935 Signature: /4. L_ Lt Date: 1(IS IL/'1 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • 2K-32 • . . 3 ConocoPhillips Grassroots Horizontal A-Sand Injector Proposed Wellbore Schematic(wp09) FMC Wellhead&Cameron Tree J Last Edited: 4-%"tree,top joint is 4-1/2"12.6#IBTM Voss 6/15/17 20"Conductor to-140' i m a a m :,,,,,it.," 7 rIP Base Permafrost 1542'MD/1505'TVD G O. L J - 13 . 13.5" Surface Hole :/ U1 G%/, Base West Sak:3130'MD/2746'ND I GL J 3-/1z' x 1-1/:' Camco MMG GLM • Surface Casing 10-3/4"45.5#L-80 Hydril 563 3,480' MD/2,959'TVD(52° INC) 9-7/8" x 11" Intermediate Hole 4Tubing: I 3-1/2" 9.3#L-80 EUE 8RD-MOD 3 GL j GLM w/SOOV Z J D-37 8517 MD/ti066 ND Fault:-9755'MD Baker 2.812"CMU Sliding Sleeve — Top of Cement 10,223'MD ,,, 3-'4"2.75"D Nipple {W . „ ... ram „.•; ;;;.„ „,,-'-''-` ' ' IRZ:12009 MD/6001'ND '? 6"x4Y swell Packer for fault Kalubik:12406'MD/6116'ND aru _.r- ,,'0,,,,,--- Kuoaruk C:13270'MD/6306'ND f ` Kuparuk A4:13804'MD/6361'ND 3'/"HES Mirage Plu. y :11 _ Packer/Flex Lock Liner 7-5/8"x 5-1/2"Baker ZXP - lilt _________._».___»�lig»_.» ._.__ Hanger Fault:-16592'MD 6-3/4" Production Holt Fault:-22967'MD 31'DT5 e,_ .. intermediate Casing Production Lower Liner; TD:25,598'MD/6,442'TVD 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"12.6#L-80 Hydril 563 w/Perf Joints 13738'MD/6,363 TVD(86° INC) Top of Liner: 13,555'MD/6,352'TVD Production Lower Liner Btm of Liner. 18,326'MD/6,438'TVD 4-1/2"12.6#L-80 Hydril 563 w/Perf Joints Top of Liner: 18,314'MD/6,438'TVD Btm of Liner:23,119'MD/6,466'TVD s - KUPOD 2K-32 ConocoPhillips Well Attri Max An D TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status nol(°) MD B) Act Btm(ftKB) Gor4pmt hos501 501032075700 KUPARUK RIVER UNIT PROD 95.56 24,358.51 25,598.6 .°. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-32,7/13,20179.2s 00 AM Last WO: 38.75 6/14/2017 Vertical s'YnmaPc(acfual) .... "Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;316 Last Tag. Rev Reason:NEW WELL jennalt 7/11/2017 illi Casing Strings W Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -""-^"cONDuciOli;3e.0-i 7e.o ir, . CONDUCTOR 20 18.500 39.0 179.0 179.0 154.19 GRX52 GAS LIFT;2,781.9 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 37.9 3,480.4 2,954.8 45.50 L-80 Hydril 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;37.9.9.480.4 INTERMEDIATE 7 5/8 6.875 36.4 13,727.6 6,363.1 29.70 L-80 Hyd563 GAS LIFT;4,536.1 Casing Description OD(in) ID(in) Top(ft)(B) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread GAS LIFT;8,832.0 LINER-PERFORATED 41/2 3.958 13,555.2 18,326.1 6,438.3 12.60 L-80 Hyd 563 GAB LIFT;8,995.0 II, UPPER nu Liner Details GAS LIFT;10,658.3 Nominal ID K, 7 Top(kKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;11,864.0 13,575.2 6,352.3 84.44 NIPPLE Baker 5.5""RS"Packoff Seal Nipple 15.5 ppf L-80 4.870 SLIDING SLEEVE;13,388.8 Hyd 563 box x box Mk 13,578.0 6,352.6 84.48 HANGER Baker 5.5"x 7.625"Flex-Lock Liner Hanger L-80 Hyd 4.800 PLUG;13,497 11•16 563 pin x pin 13,599.5 6,354.6- 84.85 SBE Baker 80-40 Sealbore Extension,5"L-80 Hyd 521pin 4.000 LOCATOR;13,584.0 x 4-1.2"Hyd 521 box SEAL ASSEMBLY;l3,sas.1 • - 13,619.2 6,356.3 85.19 XO Crossover Pup 4-1/2"L-80 Hyd 521 pin x 4-1/2"Hyd 3.910 REDUCING 563 pin INTERMEDIATE,36 4-13,727.6 • 16,484.0 6,390.7 89.97 SWELL Baker-"Swell Packer#4-"D"6.07"OD SN: 3.910 PERFP;13,875.6-13,8816 131: PACKER 052826-002-10 16,497 PERFP;14,035.2-14,0412 :j3(.' 16,702.5 6,393.5 87.98 SWELL Baker-"Swell Packer#3-"C"6.02"OD SN: 3.930 PERFP,14,197.7-14,203.1 PACKER 052826-002-28 16,707 PERFP;14,358.8-14,384.8 Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER-PERFORATED 4 1/2 3.980 18,315.0 23,119.6 6,467.1 12.60 L-80 Hyd 563 PERFP;14,520.7-14,528.7 LOWER PERFP;14,682.3-14,888.3 iii. Liner Details _ PERFP;14,841.7-14,847.7 Nominal ID PERFP;15,004.2-15,010.2 Top(ftKB) Top(TVD)(ftKB) Top Teel(°) Item Des Com (in) 18,315.0 6,438.4 90.10 SETTING Baker HRD-E Liner setting sleeve 5.5"x 7.625"L-80 4.900 PERFP;15,186.7-15,172.7 SLEEVE 5.5"Hyd 563 pin PERFP;15,328.6-75,334.6 i{�; 20,395.5 6,445.7 88.11 SWELL Baker-"Swell Packer#2-"B"6.01 OD SN: 3.930 PERFP;15,487.2-15,493.2 ;3.) PACKER 052826-002-1922817 PERFP;15,649.6-15,655.6 ±0 20,611.2 6,447.6 91.09 SWELL Baker-"Swell Packer#1-"A"6.03"OD SN; 3.890 PERFP;15,812.2-15,616.2 1;36: PACKER 052836-002-36 23020 PERFP;15,974.0.15,980.5 '.F1', Tubing Strings PERFP,16,135.7-16,141.1 ill: Tubing Description String Ma...ID(in) Top(51(13) Set Depth(k..I Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection PERFP,16,297 0.16,303.0ED TUBING 31/2 2.992 33.6 13,613.8 6,355.8 9.30 L-80 EUE-m PERFP;16,456.8-18,462.8 ):l:li). Completion Details ° _ Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(•) Item Des Com (in) PERFP;18,849 4-160.55 33.6 33.6 0.00 HANGER FMC 4.5"x 11"Tubing hanger 3.900 (il'l PERFP;17,009.8-17,015.8 :,lel,{,; 78.0 78.0 0.09 XO 4.5"12.6 ppf L-80 TXP-m x 3.5"EUE pin Crossover 2.992 REDUCING PERFP;17,168.5-17,172.5 il:l:t, 13,388.8 6,331.5 82.69 SLIDING Baker CMU sliding sleeve w/2.813"DS profile 2.812 PERFP;17,327.7-17,333.7 SLEEVE 82.7°/5972'TVD PERFP;17,486.317,494.3 13,476.2 6,341.6 83.61 NIPPLE Camco 2.75"DS profile Landing Nipple 83.6/ 2.750 PERFP;17,851.0.17,657.0 Mt:I-. 6342'TVD PERFP;17,810.8-17,816.8 13111!; 13,497.8 6,344.0 83.59 PLUG Halliburton 3-1/2"Mirage Plug,EUE-m,Rupture 7750 psi 2.880 PERFP;17,972.9-17,978.9 83.6°/6344'TVD PERFP;15,129.1-18,135.1 13,584.0 6,353.1 84.59 LOCATOR Baker GBH-22 Locator(OD 4.65")Larger OD above 3.050 PERFP;18,289.1-18,295.1 (iii;); located LINER-PERFORATED )y""y{I 13,585.1 6,353.2 84.61 SEAL Baker GBH-22 Seal Assembly w/mule shoe-below 2.980 UPPER;13,555.2-10,326.1� ASSEMBLY located PERFP;18,436.1-18,442.1 11 Perforations&Slots PERFP;18,598.0-18,604.0 Shot PERFP;18,760.0.18,766.0 'u' Dens Top D) Bt PERFP;18,976.2-18,922.2 �' Top(ftKB) Btm(ftKB) (9KB) (B D) Zone Date (s ft)�/ Type Com PERFP;19,078.4-19,084.4 13ttODl 13,875.6 13,881.6 6,366.2 6,366.3 6/10/2017 4.0 PERFP PERFP;19,238.8.19,242.8 augs 14,035.2 14,041.2 6,369.8 6,369.9 6/10/2017 4.0 PERFP PERFP,19,388.8-19,404.8 1/1)11, 14,197.1 14,203.1 6,373.0 6,373.1 6/10/2017 4.0 PERFP PERFP,19,558.4-19,584.4 ';1386, 14,358.8 14,364.8 6,375.2 6,375.2 6/10/2017 4.0 PERFP PERFP;19,718.7-19,724.7 ?p{!;, 14,520.7 14,526.7 6,375.2 6,375.2 6/10/2017 4.0 PERFP PERFP,19,880.0-19,888.8 ';111;5, 14,6823 14,688.3 6,372.6 6,372.5 6/10/2017 4.0 PERFP PERFP;20,042.4-20,048.4 61315 14,841.7 14,847.7 6,372.7 6,372.8 6/10/2017 4.0 PERFP PERF0.20,204.420,210.1 11:11, 15,0042 15,0102 6,374.4 6,374.5 6/10/2017 4.0 PERFP PERFP;20,368.1-20,372.1 8:1.1:1, 15,166.7 15,172.7 6,376.0 6,376.0 6/10/2017 4.0 PERFP 91.1.11, 15,328.6 15,334.6 6,380.6 6,380.8 6/10/2017 4,0 PERFP PERFP;20,759.5-20,785.5 -goni 15,487.2 15,493.2 6,385.9 6,386.2 6/10/2017 4.0 PERFP PERFP;20,921.0.20,927.0 ibis'' 15,649.6 15,655.6 6,391.3 6,391.4 6/10/2017 4.0 PERFP PERFP;21,078.321,084.3 1111.; 15,812.2 15,818.2 6,395.0 6,395.0 6/10/2017 4.0 PERFP PERFP;21,237.321,243.3 - 1131' 15,974.5 15,980.5 6,394.9 6,394.8 6/10/2017 4.0 PERFP PERFP;21,398.2-21,404.2 (:1 PERFP;21,558.8-21,564.8 16,135.1 16,141.1 6,392.3 6,392.2 6/10/2017 4.0 PERFP lel: PERFP;21,719.2-21,7252 1/111. 16,297.0 16,303.0 6,391.3 6,391.3 6/10/2017 4.0 PERFP PERFP;21,881.7-21,887.7 gilt 16,456.8 16,462.8 6,390.7 6,390.7 6/10/2017 4.0 PERFP PERFP;22,042.7-22,048.7 -. 16,849.4 16,855.4 6,401.8 6,402.3 6/10/2017 4.0 PERFP PERFP;22,202.8-21,208.8 ilii 17,009.8 17,015.8 6,412.9 6,413.3 6/10/2017 4.0 PERFP PERFP;22,385.5-22,371.5 ;{;1:. 17,166.5 17,172.5 6,416.6 6,416.6 6/10/2017 4.0 PERFP PERFP;22,528.5-22,534.5 .6). 17,327.7 17,333.7 6,418.8 6,418.9 6/10/2017 4.0 PERFP PERFP;22,680.5-zzsss.5 :{:{: 17,488.3 17,494.3 6,421.4 6,421.4 6/10/2017 4.0 PERFP PERFP;22,853.2-22,659.2 ;1:Pl 17,651.0 17,657.0 6,424.2 6,424.3 6/10/2017 4.0 PERFP PERFP;21071 230. 1FORA19.7` LINER-PERFORATED :l:l LOWER;18,315.0.23,119.6, KUP 10D 2K-32 ConocoPhillips A000T-1r6.: COnoco9h8lips 2K-32,761312017 9:26:00 AM Vertical schema.(actual) HANGER,33.6 F. yr..r.rrr.ower.r..r..r.....r.er.ra.,....,.r.MUM,r.I 1, - •1■■ •erforations&Slots �J! Shot '...N..CONDUCTOR;39,0,179.0 ^I Top(TVD) Btm(ND) (shots/ GAS LIFT;2,781.9 Top(ftKB) Btm(ftK8) (ftKB) (ftKB) Zone Date ft) Type Com d 17,810.8 17,816.8 6,429.0 6,429.2 6/10/2017 4,0 PERFP SURFACE;37.9-3,480.4 17,972.9 17,978.9 6,433.1 6,433.2 6/10/2017 4,0 PERFP GAS LIFT;4,536.1 ` GAS LIFT;6,532.0 `■` 18,129.1 18,135.1 6,436.0' 6,436.1 6/10/2017 4.0 PERFP GAS LIFT;8,995.0 ■lg 18,289.1 18,295.1 6,438.4 6,438.4 6/10/2017 4.0 PERFP 18,436.1 18,442.1 6,437.8 6,437.8 6/8/2017 ' 4.0 PERFP GAS LIFT;10,858.3 ' _ 4 3 18,598.0 18,604.0 6,434.8 6,434.7 6/8/2017 4,0 PERFP GAS LIFT;11,884.0 18,760.0 18,766.0 6,431.7 6,431.5 6/8/2017 4.0 PERFP SLIDING SLEEVE;13,388.8a 18,916.2 18,922.2 6,429.1 6,429.1 6/8/2017 4.0 PERFP 19,078.4 19,084.4 6,427.8 6,427.8 6/8/2017 4.0 PERFP PLUG;13,497.8 �� 19,236.8 19,242.8 6,427.4 6,427.4 6/8/2017 4.0 PERFP LOCATOR;13,584.0 19,398.8 19,404.8 6,428.9 6,428.9 6/8/2017 4.0 PERFP SEAL ASSEMBLY,13,505.1il r 19,558.4 19,564.4 6,429.0 6,429.0 6/8/2017 4.0 PERFP 19,718.7 19,724.7 6,431.2 6,431.3 6/8/2017 4.0 PERFP INTERMEDIATE;36.4-13,7276 19,880.8 19,886.8 6,435.3 6,435.4 6/8/2017 4.0 PERFP PERFP;13,875.6-13,8818 111' 20,042.4 20,048.4 6,438.3 6,438.4 6/8/2017 4.0 PERFP PERFP;14,035.2-14,0/1.2 ilii 20,204,4 20,210.4 6,440.5 6,440.5 6/8/2017 4.0 PERFP PERFP;14,197.1-14,2031 .:121 20,366.1 20,372.1 6,4443 6,444.9 6/8/2017 4.0 PERFP PERFP;14,358.8-14,364.8 8I1.t. PERFP,14,520.7-14,526.720,759.5 20,765.5 6.446.4 6,446.4 6/8/2017 4.0 PERFP 1:1: PERFP;14,692.3-14,888.3 • il_I. 20,921.0 20,927.0 6,446.8 6,446,8 6/8/2017 4.0 PERFP PERFP;14,841.7-14,847.7 ilii - 21,078.3 21,084.3 6,447.9 6,448.0 6/8/2017 4.0'PERFP PERFP;15,001.2-15,010.2 - JLi 21,237.3 21,243.3 6,449.2 6,449.2 6/8/2017 4.0 PERFP PERFP;15,1813.7-15,172.7 /118 - 21,398.2 21,404.2 6,449.8 6,449.8 6/8/2017 4.0 PERFP PERFP;15,328.6-15,334.6 81(11'.'' 21,558.8 21,564.8 6,452.3 6,452.4 6/8/2017 4.0 PERFP PERFP;15,487.2-15,493.2 lll2l>', 21,719.2 21,725.2 6,455.6 6,455.7 6/8/2017 4.0 PERFP • PERFP;15,619.6-15,655.8 81111. 21,881.7 21,887.7 6,458.8 6,459.0 6/8/2017 4.0 PERFP PERFP;15,812.2-15,818.2 11.'.. 22,042.7 22,048.7 6,464.7 6,464.9 6/8/2017 4.0 PERFP PERFP,15,974.5-15,960.5 (111..'. , 22,202.8 22,208.8 6,468.4 6,468.3 6/8/2017 4.0 PERFP PERFP;16,135.1-16,141.1 'lI:I:'. PERFP;16,297.0-16,303.0 ;ea 22,365.5 22,371.5 6,462.8 6,462.5 6/8/2017 4.0 PERFP PERFP;18,458.8-18,462.8 ,Li 22,528.5 22,534.5 6,458.4 6,458.4 6/8/2017 4.0 PERFP 22,690.5 22,696,5 6,461.8 6,461,9 6/8/2017 4.0 PERFP 22,853.2 22,859.2 6,464.0 6,4641 6/8/2017 4.0 PERFP PERFP;18,849.418,855.4 8f:12i: 23,013.7 23,019.7 6,464.9 6,464.9 6/8/2017 4,0 PERFP PERFP;17,009.8-17,015.8 GIEIlI:. PERFP;17,188.5-17,172.5 Mandrel Inserts 1tf:Yt: St PERFP;17,327.7-17,333.7 44.) ati PERFP;17,488.3.17,494.3 ';21::', N Top(TVD) Valve Latch Port Size TRO Run PERFP;17,657.0.17,857.0 /, Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (In) (psi) Run Date Corn 1 2,781.9 2,491.5 Camco KBMG 1 GAS LIFT DMY BK 6/13/2017 PERFP;17,510.8-17,816.8 2 4,536.1 3,592.4 Camco KBMG 1 GAS LIFT DMY BK 6/13/2017 PERFP;17,972.9-17,978.9 3 6,8320 4,444.7 Camco KBMG 1 GAS LIFT OV BEK 0.000 6/13/2017 PERFP,18,129.1-18,135.1 5/16 PERFP;18,289.1-18,295.1 - 4 8,995.0 5,0982 Camco KBMG 1 GAS LIFT DMY BK 6/13/2017 5 10,658.3 5,598.6 Camco KBMG 1 GAS LIFT DMY BK 6/13/2017 LINER-PERFORATED "` 6 11,884.0 5,972.1 Camco KBMG 1 GAS LIFT DMY BK 603/2017 UPPER,13,556.2-18,326.1 PERFP;18436.1-18,442.1 ',la. - Notes:General&Safety PERFP;18,5980-18,604.0 End Date Annotation PERFP;18,760 0-18,786.0 NOTE PERFP;18,9182-18,922.2 PERFP;19,078.419,084.4 PERFP;19,236.R-19,242.8 ,H. PERFP;19,398.8-19,404.8 (1l-t;. PERFP;19,558.4-19,584.4 881: PERFP;19,718.7-18,724.7 1)1(1' PERFP;19,880.8-19,888.8 1121,. PERFP;20,012.4-20,048.4 (1.1. PERFP;20,204.4-20,210.4 '. ' 81(1: PERFP,20,386.1-20,372.1 8121? MN PERFP;20,759.5-20,765.5 at PERFP;20,921.0-27,927.0 81)1:. PERFP;21,078.3-21,084.3 12121:. PERFP;21,237.3-21,243.3 111.1,. PERFP;21,398.2-21,404.2 )il)l:. PERFP;21,558.8-21,564.8 81(1:: PERFP;21,719.2-21,725.2 1.121:. PERFP;21,881.7-21,887.7 8121: PERFP;22,042.7-22,048.7 121:1: PERFP;22,202.8-22,208.8 )il)l' PERFP;22,385.5.22,371.5 '81(1:'. PERFP;22,528.5-22,534.5 '81)1 PERFP;22,690.5-22,696.5 81)1.. PERFP;22,853.2-22,859.2 X11121' PERFP;23,013.7-23,019.7 _ LINER-PERFORATED "l.P. LOWER;18,315.823,119.6\ • Operations Summary (with Timelog epths) 0 w 2K-32 ConocoPhiiiips 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(ftK8) 4/28/2017 4/28/2017 1.00 MIRU MOVE RURD P Disconnect electrical interconnects. 02:00 03:00 SIMOPS:load pipe shed with miscellaneous items,load trucks with tools and equipment,complete pre- skid checklist and slide back pipe shed cattle chute. 4/28/2017 4/28/2017 2.00 MIRU MOVE MOB P Jack up motor complex,pipe shed and 03:00 05:00 pump room,and hook up to trucks. 4/28/2017 4/28/2017 0.50 MIRU MOVE MOB P Pull motors,pumps pits and pipe shed 05:00 05:30 complexes away from sub base. 4/28/2017 4/28/2017 1.00 MIRU MOVE MOB P Skid rig floor into move position. 05:30 06:30 SIMOPS:install tow tongue on sub base. 4/28/2017 4/28/2017 1.00 MIRU MOVE MOB P Raise rear stompers on sub base. 06:30 07:30 SIMOPS;pick up rig mats. 4/28/2017 4/28/2017 0.50 MIRU MOVE MOB P Pull sub base off well 3R-101,clean 07:30 08:00 around cellar. 4/28/2017 4/28/2017 2.00 MIRU MOVE MOB P Turn around pits,motors and pump 08:00 10:00 complexes and prep for transport to 2K pad. 4/28/2017 4/28/2017 6.00 MIRU MOVE MOB P Pull off 3R pad @ 10:00 hours with all 10:00 16:00 modules and shop.Travel to 2K pad in 6 hours,left pumps,pits and motor complexes hold up at 2H pad until sub base was being spotted. 4/28/2017 4/28/2017 1.00 MIRU MOVE MOB P Make dummy run by pulling sub base 16:00 17:00 over well,stage sub base back out of the way for laying rig mats. 4/28/2017 4/28/2017 1.00 MIRU MOVE MOB P Lay rig mats for sub base.SIMOPS: 17:00 18:00 transport pits,motors and pumps from 2H to 2K pad. 4/28/2017 4/28/2017 1.00 MIRU MOVE MOB P Spot sub base over well 2K-32. 18:00 19:00 4/28/2017 4/28/2017 0.50 MIRU MOVE MOB P Lower stompers,SIMOPS:remove 19:00 19:30 tow tongue from sub base. 4/28/2017 4/28/2017 0.50 MIRU MOVE MOB P Skid rig floor into drill position, 19:30 20:00 SIMOPS:lower cellar doors. 4/28/2017 4/28/2017 1.00 MIRU MOVE MOB P Spot pits and pump complexes, 20:00 21:00 SIMOPS:install handrails on sub base and start hooking up interconnects. 4/28/2017 4/28/2017 1.00 MIRU MOVE MOB P Raise pit complex and shim to level 21:00 22:00 complex,install 2"of material to properly level complex.SIMOPS:spot rock washer. 4/28/2017 4/28/2017 0.50 MIRU MOVE MOB P Spot motors complex. 22:00 22:30 4/28/2017 4/28/2017 0.50 MIRU MOVE MOB P Spot pipe shed complex,SIMOPS: 22:30 23:00 begin plugging in electrical interconnects 4/28/2017 4/29/2017 1.00 MIRU MOVE RURD P Connect all interconnects,SIMOPS: 23:00 00:00 spot truck shop. Page 1/65 Report Printed: 6/19/2017 Operations Summary (with Timelog Depths) .t 2K-32 ConocaPhillips 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) 4/29/2017 4/29/2017 1.25 MIRU MOVE RURD P Cont to hook up electrical 00:00 01:15 interconnects,connect mud lines in pits.Rig up service lines and install beaver slide.Spot cuttings tank and Berm.Swap power off cold starts to Cat power @ 1:15 hours.Work on rig acceptance checklist. 4/29/2017 4/29/2017 1.75 MIRU MOVE RURD P Cont to hook on rig acceptance 01:15 03:00 checklist.Install skate rails and test run pipe skate. Install landings for stairs,tighten connections on sub mud lines and roll steam.Chink up cellar and Berm cellar and rock washer.Rig accepted @ 3:00 hours. 4/29/2017 4/29/2017 5.50 MIRU MOVE RURD P Take on 290 bbls of un weighted spud 03:00 08:30 mud,install bolts on diverter line and tighten.Install studs on diverter tee/annular and tighten.Hook up Koomey lines and load riser,pick up and install.empty pipe shed and load 5"DP,perform pre-spud derrick inspection.Perform PM's on top drive and draw works. 4/29/2017 4/29/2017 1.00 MIRU MOVE SFTY P Pre-spud meeting with DDI/CPAI/MI 08:30 09:30 Swaco and team. 4/29/2017 4/29/2017 0.50 MIRU MOVE RURD P Install mouse hole/rig up single joint 09:30 10:00 elevators. 4/29/2017 4/29/2017 2.00 MIRU MOVE PULD P Make up 11 STNDS via mouse hole& 10:00 12:00 STBK in Derrick. Drift SP with 2.76" rabbit. Test H2S and methane alarms. 4/29/2017 4/29/2017 1.00 MIRU MOVE PULD P M/U 6 stands of 5"DP via mousehole 12:00 13:00 and R/B in derrick. Drift with 2.76" rabbit. 4/29/2017 4/29/2017 1.00 MIRU MOVE SFTY P Pre-spud meeting with DDI/CPAI/MI 13:00 14:00 Swaco and team. 4/29/2017 4/29/2017 0.50 MIRU MOVE BOPE P Test diverter systems and PVTs. 14:00 14:30 Annular closing time 27 sec. Knife valve opening time 4 sec. System PSI 3,000 PSI.After function 1,850 PSI. 200 PSI pre charge time 12 sec. Full recovery=51 sec.with two air pumps. AVE press on 6 BU bottles=2,208 PSI. AOGCC rep Matt Herrera at 5:56 AM on 4-28-2017. 4/29/2017 4/29/2017 2.50 MIRU MOVE PULD P MU 15 stnds of 5"DP via mousehole 14:30 17:00 and SB in derrick. Drift with 2.76" rabbit. 4/29/2017 4/29/2017 0.50 MIRU MOVE PULD P M/U 5 stands of 5"HWDP via 17:00 17:30 mousehole and R/B in derrick. Drift with 2.375"rabbit. 4/29/2017 4/29/2017 1.50 MIRU MOVE RURD P Load surface equipment in pipe shed. 17:30 19:00 Strap and place in order. 4/29/2017 4/29/2017 2.00 MIRU MOVE BHAH P PJSM/RB mechanical jar stand and 7" 0.0 62.0 19:00 21:00 collar stand. Tag bottom at 62' Tag TOF at 62'MD. M/U clean out BHA as per SLMB DD t/62'MD. 4/29/2017 4/29/2017 0.50 MIRU MOVE SEQP P Fill all lines&conductor. Check for 62.0 62.0 21:00 21:30 leaks and PT mud lines to 3,500 PSI for 10 min. PAssed Page 2/65 Report Printed: 6/19/2017 a 0 !perations Summary (with Timelog 6epths) 2K-32 �Phiflips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time. Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/29/2017 4/29/2017 1.00 SURFAC DRILL DDRL P Drill 13 1/2"surface hole tfrom 62'MD 62.0 165.0 21:30 22:30 to 165'MD 165'TVD. 400 GPM,350 PSI, 10%F/O,40 RPM, 1K TQ, 1-3K WOB,PU 50K,S/O 56K,ROT 50K, 2K TQ. 4/29/2017 4/30/2017 1.50 SURFAC DRILL BHAH P POOH from 165'to 42'MD. PU 165.0 160.0 22:30 00:00 Gyropulse&MWD. MU collar Stand &RIH to 160'MD. 4/30/2017 4/30/2017 6.00 SURFAC DRILL DDRL P DDrill 13-1/2"hole f/165'MD to 477' 160.0 477.0 00:00 06:00 MD,476'TVD.Pump @ 550 gpm= 830 psi, 14%FO.Rotate @ 60 rpms w/1.5KTgon/1Koff. 4KWOB.P/U= 74K,5/0-80K,ROT=79K.AST= 1.35,ART=1.11,ADT=2.46,Total bit hours=2.46,Total jar hours=36.85 4/30/2017 4/30/2017 6.00 SURFAC DRILL DDRL P DDrill 13-1/2 hole f/477'MD to 945' 477.0 945.0 06:00 12:00 MD,941'TVD,Pump @ 550 gpm= 1125 psi, 14%FO,Rotate @ 60 rpms w/3-6K Tq on, 1.5K off,23K WOB. P/U=86K,S/O=92K,ROT=86K. AST=2.11,ART=1.27,ADT=3.38, Total bit hours=5.84,Total jar hours= 40.23 4/30/2017 4/30/2017 6.00 SURFAC DRILL DDRL P DDrill 13-1/2 hole f/945MD 941'TVD 945.0 1,368.0 12:00 18:00 ---1,368'MD 1,350'TVD,Pump @ 4- 600 gpm=982-1,250 psi, 10%FO, Rotate @ 60 rpms w/3-6K Tq on, 1.5K off,28K WOB.P/U=97K,S/O= 96K,ROT=96K.AST=3.18,ART= 1.09,ADT=4.27,Total bit hours= 10.11,Total jar hours=44.50 4/30/2017 5/1/2017 6.00 SURFAC DRILL DDRL P DDrill 13-1/2 hole f/1,368'MD 1,350' 1,368.0 1,891.0 18:00 00:00 TVD-1,891'MD 1,812'TVD,Pump @ 650 gpm=1,550 psi, 10%FO,Rotate @ 60 rpms w/3-6K Tq,2K off-25K WOB.P/U=103K,S/0=101K,ROT= 104K.AST=1.91,ART= 1.66,ADT= 3.57,Total bit hours=14.51,Total jar hours=48.07 Total run bit= 12.85. 5/1/2017 5/1/2017 6.00 SURFAC DRILL DDRL P DDrill 13-1/2"hole f/1891'MD to 1,891.0 2,480.0 00:00 06:00 2480'MD,2275'TVD,Pump @ 750 gpm=2040 psi on,1850 psi off w/ 16%FO.Rotate @ 60 rpm's w/6K Tq on,4K Tq off. 15K WOB,P/U=122K, S/O=108K,ROT=113K.AST=1.6, ART=2.19,ADT=3.79.Total bit hours=18.3,Total jar hours=51.86. 5/1/2017 5/1/2017 6.00 SURFAC DRILL DDRL P DDrill 13-1/2"hole f/2480'MD to 2,480.0 3,025.0 06:00 12:00 3025'MD,2654'TVD,Pump @ 775 gpm=2272 psi w/19%FO.Rotate @ 60 rpms w/7K Tq on,4K Tq off, 15K WOB,P/U=136K,S/O=113K,ROT= 121K,AST=1.5,ART=2.47,ADT= 3.97,Total bit hours=22,27,Total jar hours=55.83 Page 3/65 Report Printed: 6/19/2017 !perations Summary (with Timelog!pths) 2K-32 • Corioccehillips 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) 5/1/2017 5/1/2017 6.00 SURFAC DRILL DDRL P DDrill 13-1/2"hole f/3025'MD,2654' 3,025.0 3,488.0 12:00 18:00 TVD to 3,488'MD 2,960'TVD(((TD CALLED))),Pump @ 775 gpm=2494 psi w/19%FO.Rotate @ 70 rpms w/ 7K Tq on,4-7K Tq off,25K WOB, P/U=132K,S/O=118K,ROT=124K, AST=.7,ART=2.4,ADT=3.1,Total bit hours=25.37,Total jar hours= 58.93. 5/1/2017 5/1/2017 1.25 SURFAC CASING CIRC P Rotate and recipricate pipe from 3,488.0 3,402.0 18:00 19:15 3,488'to 3,402'MD with 775 GPM at 2,175 PSI CP. 70 RPM,3-6K TQ. P/U 132K,S/O=118K,ROT=142K. Total STKS pumped 14,818. 5/1/2017 5/1/2017 0.50 SURFAC CASING OWFF P Observe well for flow @ 3,402'MD. 3,402.0 3,402.0 19:15 19:45 (Static) ROT @ 6 RPM 5K TQ 126K ROT WT. 5/1/2017 5/2/2017 4.25 SURFAC CASING BKRM P BKRM OOH from 3,402'MD to 2,081' 3,402.0 2,081.0 19:45 00:00 MD at 775 GPM, ICP=2,175/FCP= 1,899 PSI. 3-6K TQ. UP WT=117K, S/O=104K. ROT=108K. 5/2/2017 5/2/2017 1.50 SURFAC CASING BKRM P Continue to POOH from 2,081 MDT/ 2,081.0 1,705.0 00:00 01:30 1,705'MD. 775 GPM, 1,960 PSI, 18% F/O, 60 RPM,3-5 K TQ,300-800 FPH pulling speed. U[p WT=109K,S/O 5/2/2017 5/2/2017 0.75 SURFAC CASING BKRM P CBU X2 while BROOH F/1,705'MD 1,705.0 1,541.0 01:30 02:15 T/1,541'MD W/775 MD. W 775 GPM 1,760 PSI, 15%F/O 60 RPM, 3K TQ. Pulling speed=300 FPH,P/U =104K,S/O=102K. Total strokes pumped=7222. 5/2/2017 5/2/2017 0.25 SURFAC CASING OWFF P Orient to high side, POOH to 1,512' 1,541.0 1,512.0 02:15 02:30 MD. BD top drive&monitor well. (dropped 3"in 10 min) 5/2/2017 5/2/2017 1.00 SURFAC CASING TRIP P POOH on elevators from 1,512' to 1,512.0 757.0 02:30 03:30 757'MD. Monitor displacement via pit #5. P/u=90K. S/O=89K. Observed 15K overpull @ 800'MD. Wiped and pulled thru with no overpull. 5/2/2017 5/2/2017 1.00 SURFAC CASING TRIP P POOH with HWDP from 757'MD to 757.0 323.0 03:30 04:30 Jar stand. Monitor disp via Pit#5. pu 62K,S/O=66K. 5/2/2017 5/2/2017 1.50 SURFAC CASING BHAH P LD BHA#1 as per DD/MWD. Monitor 323.0 0.0 04:30 06:00 well disp via Pit#5. Observe stabs& bit loaded with clay. 5/2/2017 5/2/2017 0.75 SURFAC CASING BHAH P Clean and clear rig floor. 0.0 0.0 06:00 06:45 5/2/2017 5/2/2017 1.25 SURFAC CASING RURD P RU ro run 10 3/4"casing utilizing 0.0 0.0 06:45 08:00 spiders/Volant/4'bail extensions and elevators. Verify pipe count is shed is right. 93 jts on location with 90 in the shed. 5/2/2017 5/2/2017 1.25 SURFAC CASING PUTB P PJSM to RIH with float equipment to 0.0 160.0 08:00 09:15 160'MD. Check floats on jnt#4. Install bow spring centrilizers and stop rings 10'from shoe and collar. 2 BPM =1%flow,4 BPM=3 1/2%,F/O,6 BPM=6%F/O.,8 BPM=8%F/O. Page 4/65 Report Printed: 6/19/2017 oni 0 operations Summary (with Timelogepths) 2K-32 0: iflips 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 (EKE). End Depth(ftKD) 5/2/2017 5/2/2017 2.75 SURFAC CASING PUTB P RIH with 10 3/4"45.5#563 dopeless 160.0 1,023.0 09:15 12:00 casing from 160'MD to 1,023'MD. Monitor disp via pit#5. TQ all connections to 19.4K Ft/LBS. Fill on the fly and top off every 10 jts. Install bow spring centralizers on every connection. 5/2/2017 5/2/2017 2.25 SURFAC CASING PUTB P RIH with 10 3/4"L-80 45.5#casing 1,023.0 1,594.0 12:00 14:15 from 1,023'to 1,594'MD. Monitor disp via active pits. TQ all connection to 19.4K fUlbs. Fill on the fly and top off every 10 jts. Install bow spring centrilizers on every connection. 5/2/2017 5/2/2017 2.25 SURFAC CASING CIRC P Circulate and condition mud from 1,594.0 1,625.0 14:15 16:30 1,594'MD. T//1,625 Staging pumps up t 170 GPM, ICP=205,FCP=97, F/O 1-3%,Up WT=115K.DW=90K. Pumped total of 2612 STKS. 5/2/2017 5/2/2017 5.50 SURFAC CASING PUTB P RIH with 10 3/4"casing from 1,625' 1,625.0 3,437.0 16:30 22:00 MD to 3,437'MD Monitor Disp via active pits. TQ connection to 19.4 fUlbs. Fill on fly every 10 jts. Install Bow spring centrilizers every joint. 5/2/2017 5/2/2017 0.75 SURFAC CASING RURD P MU landing joint and FMC 10 3/4" 3,437.0 3,481.0 22:00 22:45 mandrel fluted hanger,as per FMC rep. RIH to 3,481'MD. UP WT= 204K,S/O WT=116K. 5/2/2017 5/3/2017 1.25 SURFAC CEMENT CIRC P BD TD,RU cement circ hose. Circ 3,481.0 3,481.0 22:45 00:00 and condition mud from 3,481'MD to 3,469'MD. Staging pumps up to 297 GPM, ICP 230 FCP=308. F/O 3-7%. Up WT=185K,DW=122K. 5/3/2017 5/3/2017 2.25 SURFAC CEMENT CIRC P Continue to circulate and reciprocate 3,481.0 3,481.0 00:00 02:15 casing'f/3480'to 3469'.Pumping 297 gpm w/290 psi,6%flow out.Pump 60 bbls of a marker pill weighing 10.6 ppg and w/2 gallons of red dye and 15 ppb of nut plug.Observed the marker come back @ 5000 505 bbls pumped (Early to guage hole).Pumped 1326 total bbls.PU weight 186k,SO wt 124k.Held pre job safety meeting on cementing casing. 5/3/2017 5/3/2017 0.25 SURFAC CEMENT PRTS P Dowell pump 5 bbls of CW 100.SHut 3,481.0 3,481.0 02:15 02:30 down and pressure test lines to Volant tool to 3500 psi-OK. 5/3/2017 5/3/2017 0.25 SURFAC CEMENT CMNT P Dowell continue to pump a total of 40 3,481.0 3,481.0 02:30 02:45 bbls of CW100.Pumping 4.8 bpm w/ 160 to 179 psi. 5/3/2017 5/3/2017 0.25 SURFAC CEMENT CMNT P Dowell batch up MudPushll to 10.5 3,481.0 3,481.0 02:45 03:00 ppg. 5/3/2017 5/3/2017 0.25 SURFAC CEMENT CMNT P Dowell pump 75.3 bbls of MudPushll 3,481.0 3,481.0 03:00 03:15 10.5 ppg with 2 gallons of red dye in the first 20 bbls.Continuing to recprocate pipe f/3480'to 3469'.PU wt 193k,SO wt 122k.Pumping'5 bpm w/230 to 170 psi. Page 5/65 Report Printed: 6/19/2017 !perations Summary (with Timelog 6epths) 0 2K-32 CcoPhilliips 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) 5/3/2017 5/3/2017 0.25 SURFAC CEMENT CMNT P Shut down.Drop bottom wiper plug. 3,481.0 3,481.0 03:15 03:30 Re-engage Volant.Dowell mix 11 ppg LiteCRETE cement(Yield 1.91 cufUsx, thickening time 5 hr 55 min,mix water 6.831 gal/sx). 5/3/2017 5/3/2017 1.25 SURFAC CEMENT CMNT P Dowell pumping 11 ppg LiteCRETE 3,481.0 3,481.0 03:30 04:45 lead cement @'6.2 bpm w/280 psi initial and 430 psi final.Pumped a total of 495.2 bbls(1455 sx).Continued to reciprocate pipe.Final PU 178k,SO wt 87-91k. 5/3/2017 5/3/2017 0.50 SURFAC CEMENT CMNT P Dowell mix tail cement @ 12 ppg 3,481.0 3,481.0 04:45 05:15 (LiteCRETE,Yield 1.65 cuft/sx, thickening time 3 hr 45 min,mix water 5.739 gallon/sx).Pump 62 bbls (211sx).Pumping'5.5 bpm w/360 to 416 psi.PU wt 187k„SO wt 90-72k. 5/3/2017 5/3/2017 0.25 SURFAC CEMENT CMNT P Drop top plug,re-engage volant tool. 3,481.0 3,481.0 05:15 05:30 Dowell pump an additional 2.5 bbls of tail,then cleanup lines w/10 bbls of water.Final PU wt 230,SO wt 53k. Set on hanger for the rest of the job. 5/3/2017 5/3/2017 1.50 SURFAC CEMENT CMNT P Rig displace cement w/9.6 ppg mud 3,481.0 3,481.0 05:30 07:00 pumping 7 bpm w/467 to 490 psi for the first 150 bbls,then slow to 5 bpm for the next 100 bbls w/490 to 500 psi. Bump plug 500 psi over.held 5 min.bled off check floats good.CIP 0644 hrs 5-3-2017. 200.8 BBLS cement back to surface. 5/3/2017 5/3/2017 4.00 SURFAC CEMENT RURD P Clean rig floor and cellar area post 3,481.0 3,481.0 07:00 11:00 cement program. Cycle and clean vlaves/grease. RD volant CRT and landing joint. Disconnect diverter/ knofe valve etc. B/D top drive,pull/ lay down mouse hole. Jet flow line and wash out annlar. Clean Rock washer/pits etc. 5/3/2017 5/3/2017 2.50 SURFAC CEMENT RURD P Pull diverter T to BOP deck and send 3,481.0 3,481.0 11:00 13:30 out. Pull FMC starting head to BOP deck and send out as well. Continue cleaning pits and Rock washer. 5/3/2017 5/3/2017 4.50 SURFAC CEMENT RURD T R/U two strings of 3/4"pipe and run 3,481.0 3,481.0 13:30 18:00 into 20X10 3/4"annulus to 100'MD. Rig up test pump and test each string. Circulate out a total of 35 BBLS flush water to clean hole prior to Schlumberger pumping unit to arrive. 5/3/2017 5/3/2017 4.50 SURFAC CEMENT RURD T While waiting for Schlumberger 3,481.0 3,481.0 18:00 22:30 cement crew to arrive staged 13 5/8" X 11"adapter spool in cellar along with RCD MPD head and air valve to BOP deck., Stage new tree in cellar and clean BOP bolts fo nipple up. Stage Super Sucker hose in cellar to take returs whle perfoming top job. Page 6/65 Report Printed: 6/19/2017 0 0 • Operations Summary (with TimelogDepths) m 2K-32 coPhinips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB): End Depth(ftKB) 5/3/2017 5/4/2017 1.50 SURFAC CEMENT CMNT P PJSM with Schlumberger for cement 3,481.0 3,481.0 22:30 00:00 fill. Pumped 30 BBLS of 15.8 PPG class G cement at—.5 BPM. Very thick and clumpy contaminated cement for—8 BBLS of returns once cement was pumped up 20 X 10 3/4" annulas. After 15BBLS returns begin to take MW. at 15 BBLS/R 15.3 PPG. 20 BBBLS=15.6. 25 BBLS 15.77.28 BBLS 15.8. Clear tub for a total of 30 BBLS pumped during top job. Schlumberger released to assist CDR-3. 5/4/2017 5/4/2017 0.75 SURFAC CEMENT VVWWH P Rig down from cement fill program. 3,481.0 3,481.0 00:00 00:45 Flush and lay down 3/4"pipe. Clean cellar.Wash well head off. 5/4/2017 5/4/2017 1.25 SURFAC WHDBOP NUND P Clean hanger neck seal and nipple up 3,481.0 3,481.0 00:45 02:00 well head/tubing spool. Test metal to metal seal and secondary elastomer seal for 20-min at 1,000 PSI. ((PASSED)). 5/4/2017 5/4/2017 7.25 SURFAC WHDBOP NUND P Nipple Up BOPE and HP riser 3,481.0 3,481.0 02:00 09:15 equipment,choke lines, Install RCD& air valve assym. RU t/MPD manifold system. 5/4/2017 5/4/2017 1.25 SURFAC WHDBOP RURD P Shell pressure test all systems on 3,481.0 3,481.0 09:15 10:30 BOP/MPD. 5/4/2017 5/4/2017 5.00 SURFAC WHDBOP BOPE T Test all BOPE equpment to 250/3500 3,481.0 3,481.0 10:30 15:30 PSI as per approved permit to drill. All test charted 5/5.Rams 3 1/2"X 6". Testsed all with 5"test joint. Draw down test manifold pressure=1,475 PSI.Koomey PSI 3,100 PSI. 1,800 PSI after all functions 12 sec f/200 PSI build. 59 Sec for full bpressure build with 2 electric pumps and 2 air pumps. Ann closing time=22 Sec. VPR's upper/lower closing time 10 sec. Blind Sheer closing time=16 Sec. HCR choke and kill closing times=2 Sec. Ave of 6 back up Koomey bottles= 2,416 PSI. AOGCC rep Brian Bixby witnessed test. 5/4/2017 5/4/2017 2.00 SURFAC WHDBOP MPDA P Test MPD air valves and lines to 3,481.0 3,481.0 15:30 17:30 250/1250 highf 5/5 charted(Good). Test surface circ lines and cement line to 250/5000 PSI.(GOOD) charted same. Grease IBOP. 5/4/2017 5/4/2017 1.50 SURFAC WHDBOP THGR P Pull test plug and install 60'mouse 3,481.0 3,418.0 17:30 19:00 hole. Install 9 7/8"x 3.161 wear bushing and run in lock down screws. MU MPD trip nipple. BD all test lines. 5/4/2017 5/4/2017 0.25 SURFAC CEMENT SFTY P Pre-job safety meeting picking up 3,418.0 0.0 19:00 19:15 BHA. 5/4/2017 5/4/2017 2.75 SURFAC CEMENT BHAH P Pick up BHA as per SLB rep and plan 0.0 436.0 19:15 22:00 forward. to 436' 5/4/2017 5/4/2017 0.50 SURFAC CEMENT PULD P Lay down 3 STDS of 5"HWDP via 436.0 436.0 22:00 22:30 mouse hole and send to shed. Page 7/65 Report Printed: 6/19/2017 !perations Summary (with Timelogf pths) 0% 2K-32 Conoc ''hitiips 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(ftKE) 5/4/2017 5/5/2017 1.50 SURFAC CEMENT TRIP P RIH with BHA#3 utilizing 5"DP from 436.0 2,040.0 22:30 00:00 derrick from 436 MD-2,040'MD. UP wt 96K S/O WT=83 K. 5/5/2017 5/5/2017 0.50 SURFAC CEMENT MPDA P Pull busings and install trip nipple. 2,040.0 2,040.0 00:00 00:30 5/5/2017 5/5/2017 0.75 SURFAC CEMENT TRIP P Continue to RIH from 2,040'to 3,174' 2,040.0 3,174.0 00:30 01:15 MD. Monitor displacement via pit 1. PU-116 S/0 86K. 5/5/2017 5/5/2017 1.00 SURFAC CEMENT CIRC P Circulate surface to surface at 550 3,174.0 3,174.0 01:15 02:15 GPM 1,115PSI. 14%F/O 60 RPM. 6K TQ. MW 9.6 PPG. 3,300 STKS pumped. PU 134K/S/0116K. 5/5/2017 5/5/2017 1.75 SURFAC CEMENT PRTS P Pressure test casing to 3,500 PSI as 3,174.0 3,174.0 02:15 04:00 per program and charted for 30 min. 4.4 BBLS pumped. 4.4 BBLS returned.Test passed! 5/5/2017 5/5/2017 0.75 SURFAC CEMENT DHEQ P Shallow hole test MWD.Wash down 3,174.0 3,364.0 04:00 04:45 to 3,364'MD.W 5K,P/U 140K,S/O 105K. 5/5/2017 5/5/2017 7.25 SURFAC CEMENT DRLG P Drill cement and float equipment from 3,364.0 3,396.0 04:45 12:00 3,364'MD to 3,396'MD,84-350 GPM, 50-490 psi,6%F/O,40-100 RPM,6- 11K TQ,2-36K WOB.9K TQ,Tag plugs at 3,394'. 5/5/2017 5/5/2017 1.50 SURFAC CEMENT DRLG P Drill out cement shoe and rat hole 3,396.0 3,488.0 12:00 13:30 from 3,396'MD to 3,488'MD,460 GPM,860 psi, 12%F/O.Drill out shoe with 5K WOB,60-80 RPM,5-9K TQ. Top of shoe 3,475'MD,bottom of shoe 3,477'MD. 5/5/2017 5/5/2017 0.50 SURFAC CEMENT DDRL P Drill new hole from 3,488'MD to 3,488.0 3,508.0 13:30 14:00 3,508'MD,520 GPM, 1030 psi, 13% F/O,60 RPM,9K TQ,5K WOB. 5/5/2017 5/5/2017 1.25 SURFAC CEMENT CIRC P Circulate bottoms up while ROT and 3,508.0 3,508.0 14:00 15:15 RECIP from 3,472'MD to 3,454'MD with 518 GPM, 1040 psi, 13%F/O,60 RPM,8K TQ,7400 total strokes pumped,P/U 143K,S/O 105K 5/5/2017 5/5/2017 1.00 SURFAC CASING FIT P Rack back stands to 3,462'MD,Blow 3,508.0 3,462.0 15:15 16:15 down Top Drive,R/U and perform FIT obtaining 15.5 EMW,pumped 1.2 bbls and bled back 1 bbl.Bled down and rig down test equipment. 5/5/2017 5/5/2017 0.75 INTRM1 DRILL DISP P Pump 30 bbl high visc sweep, 3,462.0 3,508.0 16:15 17:00 displace well to 9.6 ppg LSND 5/5/2017 5/5/2017 1.00 INTRM1 DRILL DDRL P Drilling 9-7/8"intermediate hole from 3,508.0 3,600.0 17:00 18:00 3,508'MD to 3,600'MD at 748 GPM, 1670 psi, 16%F/O,80 RPM,6K WOB,7-9K TQ.Off bottom P/U 146K, S/O 105K,ROT 120K,7K TQ. 5/5/2017 5/5/2017 0.50 INTRM1 DRILL CIRC P Obtain survey at 3,600'MD.Drop 3,600.0 3,600.0 18:00 18:30 RFID chips,pump down at 748 GPM, 1670 psi, 16%F/O,30 RPM,MWD Turbin speed 4023 rpm for 400 stks. Reduce rate to 250 GPM till 700 stks then increase to 748 GPM till 1,000 stks.Noted pressure drop from 1700 psi to 1438 psi and turbin speed from 4023 rpm to 3398 rpm confirming open riptide under reamer. Page 8/65 Report Printed: 6/19/2017 k 0 Iterations Summary (with Timelog 6epths) 2K-32 CanocaPhiti®ps 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) 5/5/2017 5/6/2017 5.50 INTRM1 DRILL DDRL P Drill 9 7/8"x 11"hole from 3,600'MD 3,600.0 4,121.0 18:30 00:00 to 4,121'MD(3,348'TVD),825 GPM, 1895 psi, 17%F/O,140 RPM,9-12K TQ, 18K WOB,ECD 10.70 ppg,Off btm 1890 psi,UW 154K,DW 109K, ROT 125K,8K TQ,MW 9.7 ppg,Max gas-252 units. ADT-4.11,Bit hrs-5.35,Jar hrs 61.84. 5/6/2017 5/6/2017 6.00 INTRM1 DRILL DDRL P Drilled from 4,121'MD to 4,784'MD 4,121.0 4,784.0 00:00 06:00 (3,728'TVD),825 GPM,2070 psi, 18%F/O, 140 RPM,9-11K TQ, 16K WOB,PU 163K,SO 114K,ROT 129K, 8K TQ,ECD 10.56 ppg,Max gas units 320m ADT 4.6,total bit hours 9.95, total jar hours 66.44. Pumped 30 bbls 11.6#Nut Plug Hi Visc sweeps at 4,310'MD and 4,780' MD 5/6/2017 5/6/2017 6.00 INTRM1 DRILL DDRL P Drilled from 4,784'MD to 5,468'MD 4,784.0 5,468.0 06:00 12:00 (4,026'TVD),825 gpm,2360 psi, 18% F/O, 140 RPM,9-13K TQ,24K WOB, PU 178K,SO 112K,ROT 137K, 10K TQ,ECD 10.79 ppg,Max gas units 200,ADT 5.31,total bit hours 14.88, total jar hours 71.75. Pumped 30 bbls 11.6#Nut Plug Hi Visc sweeps at 5,256'MD. 5/6/2017 5/6/2017 6.00 INTRM1 DRILL DDRL P Drilled from 5,468'MD to 6,109'MD 5,468.0 6,109.0 12:00 18:00 (4,225'TVD),825 GPM,2590 psi, 17%F/O, 140 rpm, 11-14K TQ,24K WOB,PU 182K,SO 113K,ROT 137K, 10K TQ,ECD 10.85 ppg,Max gas units 194,ADT 4.79,total bit hours 19.67,total jar hours 76.16. Pumped 30 bbls 11.6#Nut Plug Hi Visc sweeps at 5,650'and 6,030'MD. 5/6/2017 5/6/2017 3.75 INTRM1 DRILL DDRL P Drilled from 6,109'MD to to 6,488'MD 6,109.0 6,488.0 18:00 21:45 (4,340'TVD),825 GPM,2780 psi, 17%F/O, 140 RPM, 11-14 TQ,24 WOB,PU 184K,SO 114K,ROT 140K, 11K TQ,ECD 11.2 ppg,Max gas unites 154,ADT 3.07,total bit hours 22.74,total jar hours 79.23. Pumped 30 bbls 11.6#Nut Plug Hi Visc sweeps at 6,455'MD. 5/6/2017 5/6/2017 1.00 INTRM1 DRILL CIRC P Circulate bottoms up wile ROT and 6,488.0 6,393.0 21:45 22:45 RECIP from 6,488'MD to 6,393'MD, 825 gpm,2750 psi, 18%F/O,9-11K TQ for 7500 total strokes then obtain survey. 5/6/2017 5/6/2017 0.75 INTRM1 DRILL CIRC P Drop RFID chips and pump down at 6,393.0 6,393.0 22:45 23:30 750 GMP,2370 psi, 18%F/O, 140 rpm,20 rpm, 12K TQ for 800 stks, reduce rate to 250 GPM for 400 stks, 1200 stks total,increase to 750 GPM with no indicators of closed under reamer. 750 GPM at 2360 psi,3398 TRPM, 6200 stks. Page 9/65 Report Printed: 6/19/2017 ` !perations Summary (with Timelog epths) 0. 0 2K-32 cc nocoPhitlips 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) 5/6/2017 5/7/2017 0.50 INTRM1 DRILL CIRC T Drop second RFID chips and pump 6,393.0 6,393.0 23:30 00:00 down at 750 GMP,2370 psi, 18%F/O, 140 rpm,20 rpm, 12K TQ for 800 stks, reduce rate to 250 GPM for 400 stks, 1200 stks total,increase to 750 GPM with no indicators of closed under reamer. 5/7/2017 5/7/2017 1.00 INTRM1 DRILL DDRL P Pumped 30 bbl 11.6#high visc sweep 6,393.0 6,488.0 00:00 01:00 at 750 GPM,2320 psi, 16%F/O, 120 rpm, 10K TQ,TRPM 3398,ECD 10.58 ppg and monitor pressure for activation of under reamer,no indication of closure.Total strokes pumped 28,500.MW in 9.6,MW out 9.6+,PU 180K,SO 117K,ROT 140K. 5/7/2017 5/7/2017 0.25 INTRM1 DRILL OWFF P Monitor well for flow,dropped 2"in 10 6,488.0 6,488.0 01:00 01:15 minutes. 5/7/2017 5/7/2017 3.00 INTRM1 DRILL TRIP P Trip out of hole on elevators from 6,488.0 3,455.0 01:15 04:15 6,488'MD to 3,455'MD.Monitor displacement.PU 144K,SO 103K. 5/7/2017 5/7/2017 1.25 INTRM1 DRILL CIRC P Circulate bottoms up while ROT and 3,455.0 3,364.0 04:15 05:30 RECIP from 3,455'MD to 3,364'MD, 750 GPM,2150 psi 15%F/O,60 rpm, 8K TQ,EDC 10.36 ppg,MW in 9.6 ppg,MW out 9.6 ppg,PU 136K,SO 105K,total strokes pumped 11,500. 5/7/2017 5/7/2017 1.25 INTRM1 DRILL MPDA P BD top drive,pull trip nipple and install 3,364.0 3,364.0 05:30 06:45 bearing,install drip nipple,wrap with herculite. 5/7/2017 5/7/2017 1.50 INTRMI DRILL SLPC P Slip and cut 30'1-3/8"ext imp plow 3,364.0 3,364.0 06:45 08:15 steel drill line. 5/7/2017 5/7/2017 0.50 INTRM1 DRILL SVRG P Service top drive,blocks and crown. 3,364.0 3,364.0 08:15 08:45 5/7/2017 5/7/2017 0.25 INTRM1 DRILL RURD P Calibrate amphion,totco and SLB blk 3,364.0 3,364.0 08:45 09:00 position. 5/7/2017 5/7/2017 1.25 INTRM1 DRILL MPDA P Kelly up and calibrate MPD chokes, 3,364.0 3,364.0 09:00 10:15 test pressure limit setpoints,conduct ramp down,calibrate choke speed. 5/7/2017 5/7/2017 1.75 INTRM1 DRILL PULD P BD topdrive,RIH PU 43 singles from 3,364.0 4,818.0 10:15 12:00 3,461'MD to 4,818'MD.Drift DP to 2.76".Monitor displacement via trip tank,PU 160K,SO 91 K. 5/7/2017 5/7/2017 2.75 INTRM1 DRILL PULD P RIH with 5"singles from 4,818'MD to 4,818.0 6,392.0 12:00 14:45 6,392'MD'.Drift DP to 2.76",monitor displacemnt via trip tank,fill pipe and BD top drive.PU 177K,SO 107K at 4,880'. 5/7/2017 5/7/2017 0.50 INTRM1 DRILL CIRC P Break circulation while ROT and 6,392.0 6,363.0 14:45 15:15 RECIP from 6,392'MD to 6,363'MD, staging pumps to 510 GPM, 1660 psi, 16%F/O,80 rpm, 10K TQ,losses began at 1300 stks at 300 bph. 5/7/2017 5/7/2017 2.00 INTRM1 DRILL PMPO T Pump out of the hole from 6,363'MD 6,363.0 5,440.0 15:15 17:15 to 5,440'MD at 1.5 bpm,285 psi, 1% F/O,PU 170K 5/7/2017 5/7/2017 0.25 INTRM1 DRILL CIRC T Stage pump to 172 GPM,480 psi, 1% 5,440.0 5,440.0 17:15 17:30 F/O with 180 BPH dynamic losses. Page 10/65 Report Printed: 6/19/2017 ` !perations Summary (with Timelog Depths) 0 rpt 2K-32 Conoo> iliips 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 MKS) End Depth(ftKS) 5/7/2017 5/7/2017 1.25 INTRM1 DRILL PMPO T Pump out of the hole from 5,440'MD 5,440.0 4,500.0 17:30 18:45 to 4,500'MD at 1.5 BPM,240 psi, 1% F/O, PU 165K 5/7/2017 5/7/2017 1.25 INTRM1 DRILL CIRC T Circulating while ROT and RECIP 4,500.0 4,505.0 18:45 20:00 from 4,500'MD to 4,405'MD,staging pump to 3 BPM,300 psi,4%F/O for 2300 stks 5/7/2017 5/7/2017 0.50 INTRM1 DRILL TRIP T RIH on elevators from 4,505'MD to 4,505.0 5,440.0 20:00 20:30 5,440'MD,PU 162K,SO 11K. 5/7/2017 5/7/2017 2.00 INTRM1 DRILL CIRC T Circulating while ROT and RECIP 5,440.0 5,440.0 20:30 22:30 from 5,440'MD to 5,350'MD staging pumps up to 750 GPM,2560 psi,21% F/O, 140 rpm, 10K TQ,ECD's 10.5 ppg with no losses, 12,400 total strokes pumped. 5/7/2017 5/7/2017 0.75 INTRM1 DRILL TRIP T RIH on elevators from 5,440'MD to 5,440.0 6,395.0 22:30 23:15 6,395'MD,PU 180K,SO 107K, monitor displacement on trip tank. 5/7/2017 5/8/2017 0.75 INTRM1 DRILL CIRC P Circulating while ROT and RECIP 6,395.0 6,300.0 23:15 00:00 from 5,395'MD to 6,300'MD staging pumps up to 750 GPM,2560 psi,20% F/O, 140 rpm, 10K TQ, 10.5 ppg ECDs 5/8/2017 5/8/2017 1.75 INTRM1 DRILL CIRC P Circulated and pumped a 30 bbl LCM 6,300.0 6,485.0 00:00 01:45 pill while ROT&RECIP from 6,485' MD to 6,390'MD,750 GPM,2680 psi, 20%F/O, 10.48 ECD, 120 rpm, 11K TQ. Drop RFID tags to open under reaamer,indicated activation with pump pressure reduction from 2680 psi to 2160 psi and turbine reduction from 4023 rpm to 3398 rpm. 5/8/2017 5/8/2017 4.25 INTRM1 DRILL DDRL P Drilled 9-7/8"x 11"intermediate from 6,485.0 6,625.0 01:45 06:00 6,488'MD to 6,625'MD(4,382'TVD), 850 GPM,2910 psi, 19%F/O, 150 rpm, 12K TQ,24 WOB,PU 193K,SO 117K,ROT 129K, 11K TQ,ECD 10.53 ppg,Max gas units 30,ADT 25.06 hrs, total bit hrs 25.06,total jar hours 78.48. Pump 30 bbl high visc WTD sweep with nut plug at 6,593'MD for bit balling.Pump low visc 9 ppg nut plug sweep at 6,593'MD for bit baling. 5/8/2017 5/8/2017 6.00 INTRM1 DRILL DDRL P Drilled 9-7/8"x 11"intermediate from 6,625.0 7,271.0 06:00 12:00 6,625'MD to 7,271'MD(4,577'TVD), 825 GPM,2930 psi, 19%F/O, 150 rpm, 14K TQ,21 WOB,PU 177K,SO 119K,ROT 139K, 10K TQ,ECD 10.94 ppg,Max gas units 60,ADT 4.53,total bit hrs 29.59,total jar hrs 83.01. Pump 30 bbl high visc WTD sweep with nut plug at 6,593'MD and 7,057' MD, Page 11/65 Report Printed: 6/19/2017 1 0 Operations Summary (with Timelog epths) O 2K-32 Conoccsehillips 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) 5/8/2017 5/8/2017 6.00 INTRM1 DRILL DDRL P Drilled 9-7/8"x 11"intermediate from 7,271.0 7,814.0 12:00 18:00 7,271'MD to 7,814'MD(4,740'TVD), 825 GPM,3245 psi,20%F/O, 150 rpm, 13K TQ, 17K WOB,PU 191K, SO 113K,ROT 143K, 11K TQ,ECD 11.28 ppg,max gas units 71,ADT 4.94,total bit hours 34.53,total jar hours 83.42. 5/8/2017 5/8/2017 2.50 INTRM1 DRILL DDRL P Drilled 9-7/8"x 11"intermediate from 7,814.0 8,003.0 18:00 20:30 7,814'MD to 8,003'MD(4,797'TVD), 825 GPM,3365 psi,20%F/0, 150 rpm, 13K TQ, 15K WOB,PU 193K, SO 116K,ROT 143K, 11K TQ,ECD 11.25 ppg,max gas units 71. 5/8/2017 5/8/2017 1.50 INTRM1 DRILL CIRC P Circulate 3X bottoms up while ROT 8,003.0 8,003.0 20:30 22:00 and RECIP from 8,003'MD to 7,903' MD at 825 GPM, ICP 3370 psi,20% F/O, 150 rpm, 12K TQ. Dump and dilute with new 9.6 ppg LSND,FCP 2920, ECDs 10.86 ppg, 18000 total strokes pumped. 5/8/2017 5/9/2017 2.00 INTRM1 DRILL DDRL P Drilled 9-7/8"x 11"intermediate from 8,003.0 8,160.0 22:00 00:00 8,003'MD to 8,160'MD(4,832'TVD), 825 GPM,3085 psi,18%F/O, 150 rpm, 13K TQ, 17K WOB,PU 190K, SO 122K,ROT 147K,9K TQ,ECDs 11.17 ppg,max gas units 71,ADT 3.29,total bit hours 37.82,total jar hours 94.31. 5/9/2017 5/9/2017 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 8,160.0 8,800.0 00:00 06:00 8,160'MD to 8,800'MD,TVD=5,039. Pump @ 825 gpm=3120 psi on btm w/20%flow out.Rotate @ 150 rpm's w/12K Tq on,9K Tq off, 17K WOB, ECD= 11.04 ppg, Max gas=350. P/U= 187K,S/O=133K, ROT=155K.ADT= 4.85,Bit hrs=42.67,Jar hrs=99.16 SPRs @ 8661'MD 4997'TVD, MW=9.75 ppg,04:55 hours MP#1:30 spm=320 psi,40 spm=370 psi. MP#2:30 spm=320 psi,40 spm=380 psi. 5/9/2017 5/9/2017 3.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 8,800.0 9,119.0 06:00 09:00 8,800'MD to 9,119'MD,TVD=5,135. Pump @ 825 gpm=3220 psi on btm w/20%flow out.Rotate @ 150 rpm's w/12K Tq on,8K Tq off, 12K WOB, ECD=11.03 ppg,Max gas=90.P/U= 190K,S/O=137K,ROT=152K.ADT= 2.08,Bit hrs=44.75,Jar hrs=101.24 5/9/2017 5/9/2017 0.50 INTRM1 DRILL RGRP T Change out#3 swab on mud pump 9,119.0 9,119.0 09:00 09:30 #2.Circulate w/reciprocation at 378 gpm,970 psi,8%F/0,70 rpm,9k Tq. Note:Swab and liner had 728 hours. Page 12/65 Report Printed: 6/19/2017 • .24 0 Operations Summary (with TimelogDepths) 2K-32 C oris coPhiiiipps 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) 5/9/2017 5/9/2017 0.75 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 9,119.0 9,192.0 09:30 10:15 9,119'MD to 9,192'MD.Pump @ 825 gpm=3230 psi on btm w/20%flow out.Rotate @ 150 rpm's w/12K Tq on btm, 10K WOB,ECD=10.92 ppg, P/U=190K,S/O=137K,ROT=152K. ADT=0.52,Bit hrs=45.27,Jar hrs= 101.76 5/9/2017 5/9/2017 0.25 INTRM1 DRILL RGRP T Change out#2 swab on mud pump 9,192.0 9,192.0 10:15 10:30 #1.Circulate w/reciprocation at 378 gpm,980 psi,9%F/O,90 rpm,9k Tq. Note:Swab and liner had 615 hours. 5/9/2017 5/9/2017 1.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 9,192.0 9,332.0 10:30 12:00 9,192'MD to 9,332'MD,TVD=5,199'. Pump @ 825 gpm=3200 psi on btm w/20%flow out.Rotate @ 150 rpm's w/12K Tq on,9K Tq off, 15K WOB, ECD= 10.95 ppg,Max gas=200.P/U= 189K,S/0=135K, ROT=155K.ADT= 1.05,Bit hrs=46.32,Jar hrs=102.81 SPRs @ 9,326'MD,5,197'TVD, MW=9.70 ppg, 11:50 hours MP#1:30 spm=220 psi,40 spm=300 psi. MP#2:30 spm=230 psi,40 spm=300 psi. 5/9/2017 5/9/2017 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 9,332.0 9,984.0 12:00 18:00 9,332'MD to 9,984'MD,TVD=5,395'. Pump @ 825 gpm=3510 psi on,3500 psi off,w/20%flow out.Rotate @ 150 rpm's w/16K Tq on, 12K Tq off, 25K WOB,ECD=11.08 ppg,Max gas=295.P/U=206K,S/O=131K, ROT=155K.ADT=4.87,Bit hrs= 51.19,Jar hrs= 107.68 5/9/2017 5/9/2017 3.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 9,984.0 10,276.0 18:00 21:30 9,984'MD to 10,276'MD,TVD= 5,490'.Pump @ 825 gpm=3590 psi on,3500 psi off,w/20%flow out. Rotate @ 150 rpm's w/16K Tq on, 13K Tq off,20K WOB,ECD=11.08 ppg,Max gas=67.P/U=208K,S/O= 132K,ROT=157K.ADT=2.19,Bit hrs =53.38,Jar hrs=109.87. SPRs @ 10,086'MD,5,425'TVD, MW=9.65 ppg, 19:10 hours MP#1:30 spm=280 psi,40 spm=340 psi. MP#2:30 spm=280 psi,40 spm=340 psi. 5/9/2017 5/9/2017 0.50 INTRM1 DRILL RGRP T Change out#3 swab on mud pump 10,276.0 10,276.0 21:30 22:00 #1.Circulate w/reciprocation at 387 gpm,990 psi,6%F/O,90 rpm, 13k Tq. Note:Swab and liner had 659 hours. Page 13/65 Report Printed: 6/19/2017 0 0 Aerations Summary (with Timelog 6epths) 2K-32 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) 5/9/2017 5/10/2017 2.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 10,276.0 10,468.0 22:00 00:00 10,276'MD to 10,468'MD,TVD= 5,538'.Pump @ 825 gpm=3680 psi on,3660 psi off,w/19%flow out. Rotate @ 150 rpm's w/18K Tq on, 14K Tq off,23K WOB,ECD=11.14 ppg,Max gas=67.P/U=213K,S/O= 134K,ROT=160K.ADT=1.42,Bit hrs =54.80,Jar hrs=111.29. SPRs @ 10,086'MD,5,425'TVD, MW=9.65 ppg, 19:10 hours MP#1:30 spm=280 psi,40 spm=340 psi. MP#2:30 spm=280 psi,40 spm=340 psi. Total downhole losses for 24 hours= 60 bbls 5/10/2017 5/10/2017 5.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 10,468.0 11,033.0 00:00 05:00 10,468'MD to 11,033'MD,TVD= 5,711'.Pump @ 821 gpm=3850 psi on,3845 psi off,w/20%flow out. Rotate @ 150 rpm's w/18K Tq on, 12K Tq off,21K WOB,ECD= 11.30 ppg,Max gas=180.P/U=236K,5/0= 132K,ROT= 160K.ADT=4.32, Bit hrs =59.12,Jar hrs=115.61. 5/10/2017 5/10/2017 3.25 INTRM1 DRILL CIRC P Circulate 2 x bottoms up while 11,033.0 10,746.0 05:00 08:15 backreaming OOH from 11033'- 10746'MD and perform 580 bbl dilution w/825 gpm, ICP 3730 psi, FCP 3270 psi,20%F/O,ECD 10.74 ppg,80 rpm, 14k Tq,MW in 9.75ppg, MW out 9.8ppg, 125 ft/hr pulling speed,PUW 217k,SOW 123k,ROT 165k. 5/10/2017 5/10/2017 0.25 INTRM1 DRILL OWFF P Obtain SPR's,Service washpipe,and 10,746.0 10,746.0 08:15 08:30 Monitor well for flow-well static. SPRs @ 10,747'MD,5,624'TVD, MW=9.75 ppg,08:06 hours MP#1:30 spm=300 psi,40 spm=360 psi. MP#2:30 spm=280 psi,40 spm=360 psi. 5/10/2017 5/10/2017 3.50 INTRM1 DRILL BKRM P Backream OOH f/10476'-9711'MD 10,746.0 9,711.0 08:30 12:00 w/820 gpm,3100 psi,20%F/O,ECD 10.85ppg, 100 rpm,12k Tq,PUW 207k,SOW 117k,ROT 156k,500-700 ft/hr pulling speed. 5/10/2017 5/10/2017 4.75 INTRM1 DRILL BKRM P Backream OOH f/9711'-8348'MD w/ 9,711.0 8,348.0 12:00 16:45 822 gpm,3100 psi, 18%F/0,Initial ECD 10.7ppg,Final ECD 11.4 ppg, 100 rpm, 12k Tq,PUW 170k,SOW 110k,ROT 145k,700-900 ft/hr pulling speed. Page 14/65 Report Printed: 6/19/2017 !perations Summary (with Timelog Depths) 0~ex Flt 2K-32 +ConocoPtaiirp 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) 5/10/2017 5/10/2017 4.50 INTRM1 DRILL BKRM T Observe hole packoff at 8348'MD. 8,348.0 8,348.0 16:45 21:15 Work pipe down 1 x stand to 8473' and slowly stage up rate to 823 gpm, 3045 psi,20%F/O, 100 rpm, 11k Tq, ECD 10.62 ppg,PUW 188k,SOW 129k,ROT 145k.Once at full rate, circulate 1 x bottoms up and rack back stand. Note:Observe 10.4ppg/115 vis mud over blinding off shakers after first bottoms up.Once up to 700 gpm, shakers started unloading with clay and shaly hard siltstone cuttings at surface. 5/10/2017 5/11/2017 2.75 INTRM1 DRILL BKRM P Backream OOH f/8348'-7912'MD w/ 8,348.0 7,912.0 21:15 00:00 823 gpm, ICP 3040 psi,FCP 2970 psi, 20%F/O, 100 rpm,10K Tq,Initial ECD 10.62,Final ECD 10.65 ppg, staging up pulling speed from 100 to 475 ft/hr. Total losses for 24 hours=24 bbls 5/11/2017 5/11/2017 3.25 INTRM1 DRILL BKRM P Backream OOH f/7912'-6915'MD w/ 7,912.0 6,915.0 00:00 03:15 820 gpm,2930 psi,20%F/O, 100 rpm, 11k Tq,ECD 11.14,varying pulling speed 150-600 ft/hr. 5/11/2017 5/11/2017 3.25 INTRM1 DRILL CIRC T Observe hole packoff at 200 ft/hr 6,915.0 6,915.0 03:15 06:30 pulling speed.Run in hole 1 x stand to 7054'and slowly stage up pumps to 820 gpm,2870 psi,20%F/O, 100 rpm,9k Tq,ECD 10.6,SOW 109k, MW in 9.8ppg,MW out 9.8+ppg.Rack back stand and continue backreaming out to 6915'. 5/11/2017 5/11/2017 5.50 INTRMI DRILL BKRM P Backream OOH f/6961'-6713'MD w/ 6,915.0 6,713.0 06:30 12:00 820 gpm,2700 psi,20%F/O, 100 rpm, 10k Tq,ECD 10.75,working through several packoff events between 6944'to 6850'MD.Max ECD seen 12.8ppg. 5/11/2017 5/11/2017 1.50 INTRM1 DRILL BKRM P Backream OOH f/6713'-6642'MD w/ 6,713.0 6,642.0 12:00 13:30 820 gpm,2700 psi,20%F/O, 100 rpm, 10k Tq,ECD 10.88,working through packoff events. 5/11/2017 5/11/2017 0.50 INTRMI DRILL RGRP T Change out#2 swab and liner on mud 6,642.0 6,642.0 13:30 14:00 pump#2.Work pipe f/6676'-6646'w/ 412 gpm,800 psi, 10%F/O,80 rpm, 8k Tq. Note:swab and liner had 622 hours 5/11/2017 5/11/2017 3.25 INTRM1 DRILL BKRM P Backream OOH f/6642'-6522'MD w/ 6,642.0 6,522.0 14:00 17:15 820 gpm,2750 psi,20%F/O, 100 rpm, 10k Tq,ECD 10.7-11.2 ppg, working through packoff events. Note:turbine rpm @ 820 gpm—3800 5/11/2017 5/11/2017 1.00 INTRM1 DRILL MPDA T Observe MPD bearing with failed seal. 6,522.0 6,522.0 17:15 18:15 PJSM.Pull MPD bearing and install trip nipple,PUW 170k,SOW 117k. Page 15/65 Report Printed: 6/19/2017 !perations Summary (with Timelog epths) 01,1 2K-32 Conoco ehiilips 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) 5/11/2017 5/11/2017 2.75 INTRM1 DRILL CIRC T Decision made to close underreamer. 6,522.0 6,580.0 18:15 21:00 Establish circulation w/710 gpm, 2060 psi, 17%F/O,30 rpm,8k Tq, ECD 10.35,3281 turbine rpm and wipe section.Drop 6 x RFID chips to close underreamer and pump down per WFT w/710 gpm for 700 strokes and 250 gpm for 500 strokes.Kill pumps,open bleeder,and wait 10 minutes per WFT while rotating 15 rpm,8k tq.Bring on pumps to 710 gpm,2120 psi,30-100 rpm,8k Tq, 3281 turbine rpm-underreamer still open.Kill pumps and wipe 1 x joint, PUW 166k,SOW 124k.Bring on pumps 710 gpm,2130 psi,3281 turbine rpm-underreamer still open. Rack back stand to 6580'.Drop 6 x RFID chips to close underreamer and pump down per WFT w/710 gpm for 900 strokes,250 gpm for 350 strokes. Increase rate to 710 gpm,2120 psi, 3281 turbine rpm-underreamer still open.Backream OOH per WFT in attempt to help close reamer and observe hole exhibit packoff tendencies at 6540'MD.Work down to 6551'and regain good circulation and then cycle pumps off and stage back to 710 gpm,2110 psi,3281 turbine rpm.Backream OOH to 6525 and observe hole trying to pack off. 5/11/2017 5/11/2017 1.00 INTRM1 DRILL CIRC T Ream down 1 x stand to 6676'w/820 6,580.0 6,646.0 21:00 22:00 gpm,2700 psi, 17%F/O,ECD 10.39, 3790 turbine rpm, 100 rpm,8k Tq and pump 60 bbl nut plug sweep.Circulate out of hole,observing sweep at surface 300 strokes early and-50% increase in cuttings at shakers. 5/11/2017 5/11/2017 0.50 INTRM1 DRILL CIRC T Kill pumps,open bleeder,and wait 10 6,646.0 6,580.0 22:00 22:30 minutes w/15 rpm,8k Tq per WFT. Cycle pumps to 710 gpm,2100 psi, 3281 turbine rpm-underreamer still open.Decrease flow to 123 gpm, 160 psi and pick up 60 ft.Increase rate to 710 gpm,2090 psi,3281 turbine rpm- underreamer still open.Rack back stand to 6580'. 5/11/2017 5/11/2017 1.00 INTRM1 DRILL BKRM T Backream OOH f/6580'-6515'w/710 6,580.0 6,515.0 22:30 23:30 gpm,2070 psi, 16%F/O,ECD 10.34, 3281 turbine rpm, 100 rpm,8k Tq. Observe hole trying to packoff at 6541' and 6515'. Note:When section from 6488'-6679' was drilled on May 8,observed limited ROP due to apparent bit balling. Required 4.5 hours to drill 2 x stands and pumped nut plug sweeps to help mitigate.After getting past this zone, did not see any more bit balling issues Page 16/65 Report Printed: 6/19/2017 0, !perations Summary (with Timelogtepths) 2K-32 ConocoPhinips 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(WE) 5/11/2017 5/12/2017 0.50 INTRM1 DRILL PMPO T Wipe stand to 6576',decrease flow to 6,515.0 6,464.0 23:30 00:00 4 bpm,230 psi,3%F/O,and no rotary.Obtain parameters PUW 160k, SOW 122k.Pump OOH f/6576' to 6464'MD Total losses downhole for 24 hours= 21 bbls 5/12/2017 5/12/2017 2.00 INTRM1 DRILL PMPO T Pump OOH f/6464'-6324'MD w/4 6,464.0 6,324.0 00:00 02:00 bpm,270 psi,PUW 160k,SOW 124k, working through packoff tendencies. Max overpull of 15k seen at 6333'MD. 5/12/2017 5/12/2017 0.50 INTRM1 DRILL CIRC P Wipe stand and stage up pumps/ 6,324.0 6,350.0 02:00 02:30 rotary at 6350'MD to 710 gpm,2290 psi,ECD 10.33, 15%F/O,80 rpm.8k Tq. Observe turbine rpm increase to 3710 and pump pressure increase —200 psi from prior to pumping OOH, indicating underreamer closed. 5/12/2017 5/12/2017 3.50 INTRM1 DRILL BKRM P Backream OOH slowly f/6324'-5820' 6,350.0 5,820.0 02:30 06:00 w/710 gpm, ICP 2290 psi,FCP 2100 psi,ECD 10.4, 16%F/O,80 rpm,8k Tq,working through packoff tendencies. Note:Observed turbine rpm decrease to 3430 and then fluctuated between 3430-3650.Also observed turbine rpm increase in correlation with packoff tendencies,and would decrease once pressure normalized. 5/12/2017 5/12/2017 8.00 INTRM1 DRILL BKRM P Backream OOH f/5820'-3585'MD w/ 5,820.0 3,585.0 06:00 14:00 710 gpm, 1780 psi, 15%F/O,ECD 10.4,80 rpm,5k Tq,PUW 131k,SOW 113k,ROT 114k. Note:Observe temporary—125 psi increase when pulling upper stab into shoe. Page 17/65 Report Printed: 6/19/2017 .. . . . , ,,, . . , o, , , perations Summary (with Timelog Depths) .,. , ,,,..„,,,, 0 . ..„.. . 2K-32 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(Mr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 5/12/2017 5/12/2017 1.50 INTRM1 DRILL BKRM P Kill rotary.Turbine rpm prior to pulling 3,585.0 3,552.0 14:00 15:30 reamer into shoe=3359.Pull underreamer into casing f/3585'- 3573'w/710 gpm, 1780 psi, 15%F/O, no change in turbine rpm.Observe 3k overpull.Slack off inside casing w/ pumps on and observe no drag. Attempt to rotate and observe string stall out.Work reamer back down into open hole.Pull back inside casing w/ pumps on 710 gpm,no rotary,and observe 20k overpull,pump pressure increase to 1940 psi,and turbine rpm increase to 3750.Run reamer into open hole,engage rotary,and ream stand.Kill rotary and pumps and pull underreamer into casing-no overpull observed.Circulate at 740 gpm,2090 psi,15%F/O and slack off inside casing-no drag observed.Engage rotary at 80 rpm 5k tq and confirm ability to rotate. Rack back stand to 3552'MD. 5/12/2017 5/12/2017 2.00 INTRM1 DRILL BKRM P Backream OOH f/3552'-3269'MD w/ 3,552.0 3,170.0 15:30 17:30 650 gpm, 1615 psi, 14%F/O,80 rpm, 5k Tq.Pump 60 bbl hi-vis sweep at 3269'and continue backreaming OOH to 3170'MD,observing-200% increase in cuttings over shakers when sweep came to surface. 5/12/2017 5/12/2017 0.25 INTRM1 DRILL OWFF P Monitor well for flow-well static. 3,170.0 3,170.0 17:30 17:45 5/12/2017 5/12/2017 2.50 INTRM1 DRILL BKRM P Backream OOH f/3170'-2322'MD w/ 3,170.0 2,232.0 17:45 20:15 650 gpm, 1505 psi, 14%F/O,80 rpm, 3k Tq. Pump 60 bbl hi-vis sweep at 2322'(-40° INC)and continue backreaming OOH to 2232'MD, observing-50%increase in cuttings over shakers when sweep came to surface.PUW 105k,SOW 105k 5/12/2017 5/12/2017 0.25 INTRM1 DRILL OWFF P Blow down topdrive and monitor well 2,232.0 2,232.0 20:15 20:30 for flow-well static. 5/12/2017 5/12/2017 1.00 INTRM1 DRILL TRIP P Pull OOH on elevators f/2232'-436' 2,232.0 436.0 20:30 21:30 MD,monitoring displacement via trip tank. 5/12/2017 5/12/2017 0.25 INTRM1 DRILL OWFF P Monitor well for flow at top of BHA- 436.0 436.0 21:30 21:45 well static. Page 18/65 Report Printed: 6/19/2017 • Operations Summary (with Timelogtpths) 2K-32 ConocoPhitttps 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 - (EKE) End Depth(ftKS). 5/12/2017 5/12/2017 2.00 INTRM1 DRILL BHAH P Lay down BHA#3 and rack back 436.0 0.0 21:45 23:45 HWDP,Jars,and NMDC's.Observe moderate amount of clay and metal shavings packed in and around reamer cutter blocks.Reamer had multiple chipped/broken teeth.Minimal to zero clay/cuttings around remaining part of BHA.Top 9-3/4"NM Stab was in gauge. Bottom 9-3/4"NM stab was 1/16"undergauge.Top non-ported flapper float had a broken spring. Bottom non-ported plunger float was in good condition.Bit was in gauge and had 1 x chipped cutter,graded 0- 1-CT-G-X-0-NO-TD. 5/12/2017 5/13/2017 0.25 INTRM1 DRILL BHAH P Clean and clear rig floor of BHA 0.0 0.0 23:45 00:00 equipment. 5/13/2017 5/13/2017 1.00 INTRM1 WHDBOP RURD P PU/MU stack washing tool, Flush 0.0 0.0 00:00 01:00 stack,blow down,lay down tool. 5/13/2017 5/13/2017 1.00 INTRM1 WHDBOP OTHR P Change out 4-1/2"IF saver sub. 0.0 0.0 01:00 02:00 5/13/2017 5/13/2017 0.50 INTRM1 WHDBOP RURD P Pull FMC 9-7/8"ID 3.16'long wear 0.0 0.0 02:00 02:30 bushing. 5/13/2017 5/13/2017 0.50 INTRM1 WHDBOP RURD P Install FMC lower test plug.Fill stack 0.0 0.0 02:30 03:00 with water,work air out of system.Rig up testing equipment. 5/13/2017 5/13/2017 4.50 INTRM1 WHDBOP BOPE P Test BOPE w/5"test joint.Witness of 0.0 0.0 03:00 07:30 test waived by AOGCC inspector Guy Cook.Testing to 250 psi low and 3500 psi high,holding each 5 minutes. Chart test.Accumulator test:(6)bottle N2 average 2233 psi.200 psi build up 8 seconds,full charge 56 seconds. Accumulator 2900 psi,manifold 1500 psi.ConocoPhillips pump test with bottles isolated:Electric 19 seconds, air 75 seconds.Functioned(2)rams, 1 HCR. 5/13/2017 5/13/2017 0.50 INTRM1 WHDBOP RURD P Blow down top drive,choke and kill 0.0 0.0 07:30 08:00 line.Pull FMC test plug,install FMC long wear bushing,9-7/8"ID,3.16' long. 5/13/2017 5/13/2017 0.25 INTRM1 DRILL SFTY P Pre job safety meeting on picking up 0.0 0.0 08:00 08:15 BHA#4(9-7/8"x 11"). 5/13/2017 5/13/2017 1.75 INTRM1 DRILL BHAH P Pickup/makeup 9-7/8"x 11" 0.0 437.0 08:15 10:00 Intermediate BHA(BHA#4)to 437.05'.Install 2 x non-ported floats above underreamer for MPD. 5/13/2017 5/13/2017 2.00 INTRM1 DRILL TRIP P Run in the hole f/437'to 3463', 437.0 3,463.0 10:00 12:00 monitoring displacement via pit#5.Fill pipe every 2000'.PU wt 127k,SO wt 106k. 5/13/2017 5/13/2017 0.75 INTRM1 DRILL CIRC P Circulate bottom's up at the shoe and 3,463.0 3,463.0 12:00 12:45 test MWD tools,pumping 629 gpm w/ 1585 psi and 13%flow out.Rotate 80 rpm w/4k ft lbs of torque.PU wt 130k, SO wt 111k,Rot wt 121k.Pumped 4500 total strokes @ 629 gpm.ECD's 10.18 ppg w/9.6 ppg mud. Page 19/65 Report Printed: 6/19/2017 Operations Summary (with Timelogepths) Ea; 2K-32 ConocoPhimlips 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(ftt(B) 5/13/2017 5/13/2017 1.25 INTRM1 DRILL TRIP P Blow down the top drive.Run in the 3,463.0 5,353.0 12:45 14:00 hole f/3463'to 5353'.Monitor displacement using pit#5. 5/13/2017 5/13/2017 1.00 INTRM1 DRILL CIRC P Fill pipe.Stage pumps up to 750 gpm 5,353.0 5,353.0 14:00 15:00 w/2500 psi and 15%flow out.Rotate 80 rpm w/7k ft lbs of torque.ECD's 10.32 ppg w/9.6 ppg mud weight.PU wt 157k,SO wt 115k, 4bpm was 288 psi,6 bpm was 415 psi and 3%,8 bpm was 600 psi and 7%, 10 bpm was 910 psi and 9%, 12 bpm was 1245 psi and 11%, 14 bpm was 1605 psi and 13%, 16 bpm was 2100 psi and 15% 5/13/2017 5/13/2017 1.00 INTRM1 DRILL TRIP P Run in the hole f/5353'to 7250'.Fill 5,353.0 7,250.0 15:00 16:00 pipe every 2000'.PU wt 127k,SO wt 106k,Filled pipe and circulate @ 3463',pumping 629 gpm w/1577 psi. 5/13/2017 5/13/2017 0.75 INTRM1 DRILL CIRC P Fill pipe.Stage pumps up to 750 gpm 7,250.0 7,250.0 16:00 16:45 w/2824 psi and 14%flow out.Rotate 80 rpm w/9.8k ft lbs of torque. ECD's 10.38 ppg w/9.6 ppg mud weight.PU wt 188k,SO wt 119k, 2bpm was 220 psi and 1%,4bpm was 325 psi and 3%,6 bpm was 485 psi and 4%,8 bpm was 730 psi and 6%, 10 bpm was 1065 psi and 10%, 12 bpm was 1445 psi and 11%, 14 bpm was 1890 psi and 13%, 16 bpm was 2375 psi and 15% 5/13/2017 5/13/2017 1.00 INTRM1 DRILL TRIP P Run in the hole f/7250'to 9144'.Fill 7,250.0 9,144.0 16:45 17:45 pipe every 2000'.PU wt 127k,SO wt 106k. 5/13/2017 5/13/2017 0.75 INTRM1 DRILL CIRC P Fill pipe and stage up pumps to 750 9,144.0 9,144.0 17:45 18:30 gpm,3150 psi, 16%F/O,ECD 10.48, 80 rpm, 12k Tq,9.6 ppg MW,PUW 202k,SOW 125k,ROT 150k,3380 strokes pumped. Rates w/reamer closed:2bpm=300 psi, 1%;4bpm=403 psi,3%;6 bpm= 580 psi,4%;8 bpm=835 psi,6%; 10 bpm=1220,9%; 12 bpm=1635 psi, 11%; 14 bpm=2130 psi, 14%; 16 bpm=2650 psi, 15% 5/13/2017 5/13/2017 1.00 INTRM1 DRILL TRIP P RIH on 5"DP stands f/9144'-10847' 9,144.0 10,847.0 18:30 19:30 MD,monitoring displacement via pit# 5. Note:From stand#104 onward (10185'MD),start using NSC30 Pipe dope and torque connections to 35,300 ft-lbs. Page 20/65 Report Printed: 6/19/2017 • �� Operations Summary (with Timelog!pths) 0 ,-t 2K-32 conocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time: End Time Our(hr) Phase Op Code Activity Code Time P-T x Operation (ftKB) End Depth(ftKB) 5/13/2017 5/13/2017 0.75 INTRM1 DRILL CIRC P Fill pipe and stage up pumps to 710 10,847.0 10,847.0 19:30 20:15 gpm,3190 psi,3750 turbine rpm, 16% F/O,ECD 10.51, 100 rpm, 17k Tq,9.6 ppg MW,PUW 225k,SOW 128k,ROT 158k,3800 strokes pumped. Rates w/reamer closed:2bpm=325 psi,1%;4bpm=450 psi,3%;6 bpm= 635 psi,4%;8 bpm=910 psi,6%; 10 bpm=1315,9%; 12 bpm=1800 psi, 11%; 14 bpm=2380 psi, 14%; 16 bpm=2965 psi, 15% 5/13/2017 5/13/2017 0.75 INTRM1 DRILL CIRC P Drop 6 x RFID chips and pump down 10,847.0 10,938.0 20:15 21:00 to open underreamer per WFT,710 gpm,3140 psi,3789 turbine rpm, 15% F/O,ECD 10.4,30 rpm, 12k Tq.After 1400 strokes,drop rate to 250 gpm for 400 strokes.Increase rate to 710 gpm and observe pump pressure decrease to 2887 psi and turbine rpm decrease to 3125,confirming underreamer open. Increase rate to 820 gpm,3670 psi,3672 turbine rpm, 16%F/O,ECD 10.5,100 rpm, 15k Tq and ream down to 10938'MD. 5/13/2017 5/13/2017 1.50 INTRM1 DRILL REAM P Ream to bottom at 11033'MD w/820 10,938.0 10,905.0 21:00 22:30 gpm,3580 psi, 17%F/O,ECD 10.6, 100 rpm, 15-21k Tq.Backream out to 10905'MD and blow down top drive. 5/13/2017 5/13/2017 1.25 INTRM1 DRILL MPDA P PJSM.Drain riser and confirm well 10,905.0 10,942.0 22:30 23:45 static.Pull trip nipple,Install MPD bearing,Install drip nipple and herculite cover.Line up to use MPD. Note:MPD bearing is Weatherford Model 7000 Dual Element bearing assembly with poly rubber element on top and natural rubber element on bottom 5/13/2017 5/14/2017 0.25 INTRM1 DRILL MPDA P Stage up pumps to 820 gpm,3645 10,942.0 10,942.0 23:45 00:00 psi,ECD 10.62.Calibrate chokes and break in new bearing w/30 rpm per MPD advisor. Total downhole losses for 24 hours= 7 bbls 5/14/2017 5/14/2017 0.75 INTRM1 DRILL MPDA P Finish warming up MPD bearing per 10,942.0 11,033.0 00:00 00:45 MPD advisor and wash/ream to bottom w/817 gpm,3630 psi,110 rpm, 18k Tq,ROT 144k. Note:New crew set up and make up first stand in mousehole for drilling. Page 21/65 Report Printed: 6/19/2017 !perations Summary (with Timelog 6epths) 0-4 2K-32 Conaconilithps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-TA Operation (ftKB)i End Depth(ftKB) 5/14/2017 5/14/2017 2.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 11,033.0 11,190.0 00:45 02:45 11,032'MD to 11,190'MD,TVD= 5,760'.Pump @ 820 gpm=3633 psi on,3600 psi off,w/18%flow out. Rotate @ 150 rpm's w/21K Tq on, 20K Tq off, 18-25K WOB,ECD= 10.76 ppg,Max gas=502.P/U=253K, S/O=127K,ROT=166K.ADT=1.47, Bit hrs=60.59,Jar hrs=173.87. Close chokes on connections-no pressure buildup observed. SPRs @ 11,031'MD,5,708'TVD, MW=9.70 ppg,00:51 hours MP#1:30 spm=280 psi,40 spm=360 psi. MP#2:30 spm=280 psi,40 spm=360 psi. 5/14/2017 5/14/2017 1.00 INTRM1 DRILL RGRP T Change out#3 swab and liner on mud 11,190.0 11,190.0 02:45 03:45 pump#2.Work pipe f/11,888'- 11,130'w/446 gpm, 1280 psi, 11% F/O,80 rpm, 17k Tq. Note:Swab hours=77, Liner hours= 805 5/14/2017 5/14/2017 2.25 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 11,190.0 11,412.0 03:45 06:00 11,190'MD to 11,412'MD,TVD= 5820'.Pump @ 820 gpm=3660 psi on,3630 psi off,w/18%flow out. Rotate @ 150 rpm's w/23K Tq on, 22K Tq off, 18-25K WOB,ECD= 10.90 ppg,Max gas=459.P/U=259K, S/O= 120K,ROT=167K.ADT= 1.68, Bit hrs=62.27,Jar hrs=175.55. Close chokes on connections-no pressure buildup observed. 5/14/2017 5/14/2017 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 11,412.0 11,790.0 06:00 12:00 11,412'MD to 11,790'MD,TVD= 5943'.Pump @ 820 gpm=3780 psi on,3750 psi off,w/18%flow out. Rotate @ 150 rpm's w/23K Tq on, 22K Tq off, 18-25K WOB,ECD= 11.15 ppg,Max gas=358.P/U=265K, S/O=117K,ROT=166K.ADT=4.09, Bit hrs=66.36,Jar hrs= 179.64. Close chokes on connections-no pressure buildup observed. SPRs @ 11,788'MD,5,942'TVD, MW=10.0 ppg, 11:00 hours MP#1:30 spm=420 psi,40 spm=500 psi. MP#2:30 spm=420 psi,40 spm=500 psi. Note:Start adding 10.0ppg mud at 11615'MD to weight up active system to 10.Oppg prior to HRZ.Start treating mud with Asphasol and Resinex. Page 22/65 Report Printed: 6/19/2017 '' operations Summary (with Timelog 6epths) 2K-32 Corsoc Phillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Starts Depth Start Time End Time Dur(Er) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 5/14/2017 5/14/2017 1.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 11,790.0 11,885.0 12:00 13:30 11,790'MD to 11,885'MD,TVD= 5970'.Pump @ 820 gpm=3590 psi on,3580 psi off,w/20%flow out. Rotate @ 150 rpm's w/22K Tq on, 20K Tq off, 16K WOB,ECD= 11.08 ppg,Max gas=400.P/U=265K,S/O= 117K,ROT=164K.ADT= 1.64, Bit hrs =68.0,Jar hrs= 181.28.Start holding 11.0ppg EMW on connections w/MPD chokes at 11,885'MD. 5/14/2017 5/14/2017 1.00 INTRM1 DRILL CIRC T Observe gas increasing at stand 11,885.0 11,885.0 13:30 14:30 down.Circulate bottoms up while working stand 11,885'-11,813'MD w/ 820 gpm,3610 psi,20%F/O,ECD 11.01, 150 rpm,21k Tq.Max gas observed=1639 units. 5/14/2017 5/14/2017 3.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 11,885.0 12,075.0 14:30 18:00 11,885'MD to 12,075'MD,TVD= 6024'.Pump @ 820 gpm=3650 psi on,3640 psi off,w/20%flow out. Rotate @ 150 rpm's w/23K Tq on, 20K Tq off,22K WOB, ECD=11.08 ppg,Max gas=2295.P/U=269K,S/O =112K,ROT=165K.ADT=1.98,Bit hrs=69.98,Jar hrs=183,26.Trap 11.0ppg EMW on connections w/MPD chokes.Top of HRZ found at 11,940' MD/5,989'TVD. Note:Rig swapped from hi-line to generator power @ 16:00 hrs due to not receiving enough power from hi- line. 5/14/2017 5/14/2017 1.25 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 12,075.0 12,171.0 18:00 19:15 12,075'MD to 12,171'MD,TVD= 6058'.Pump @ 820 gpm=3685 psi on,3675 psi off,w/20%flow out. Rotate @ 150 rpm's w/23K Tq on, 20K Tq off, 14K WOB,ECD=11.12 ppg,Max gas=3455.P/U=269K,S/O =112K,ROT=165K.ADT=0.80,Bit hrs=70.82,Jar hrs=184.1.Trap 11.0ppg EMW on connections w/MPD chokes. 5/14/2017 5/14/2017 1.00 INTRM1 DRILL CIRC T Observe gas increasing at stand 12,171.0 12,171.0 19:15 20:15 down,Non-pressurized MW in 9.7,out 9.2.Circulate bottoms up while working stand 11,885'-11,813'MD w/ 820 gpm,3610 psi,20%F/O,ECD 11.01, 150 rpm,21k Tq.Max gas observed=1639 units. 5/14/2017 5/14/2017 0.25 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 12,171.0 12,176.0 20:15 20:30 12,171'MD to 12,176'MD,TVD= 6058'.Pump @ 820 gpm=3685 psi on,3675 psi off,w/20%flow out. Rotate @ 150 rpm's w/23K Tq on, 20K Tq off,14K WOB,ECD=11.12 ppg,Max gas=850.P/U=269K,SIO= 112K,ROT=165K.Trap 11.0ppg EMW on connections w/MPD chokes. Page 23/65 Report Printed: 6/19/2017 Dr+iiMow� Operations Summary (with Timelogpths) &Weils 2K-32 +Co ocoPhithps 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 (EKE) End Depth(ftKB) 5/14/2017 5/14/2017 1.00 INTRM1 DRILL RGRP T Observe swab fail on pump#1.Rack 12,176.0 12,176.0 20:30 21:30 back stand and change out#1 swab and liner on mud pump#1.Work pipe f/12,171'-12,071'w/383 gpm, 1348 psi,9%F/O,ECD 11.15,80 rpm, 19k Tq. Note:Swab hours=26, Liner hours= 711 5/14/2017 5/15/2017 2.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 12,176.0 12,360.0 21:30 00:00 12,176'MD to 12,360'MD,TVD= 6113'. Pump @ 820 gpm=3750 psi on,3740 psi off,w/20%flow out. Rotate @ 150 rpm's w/23K Tq on, 20K Tq off,20K WOB, ECD= 11.16 ppg, Max gas=1561. P/U=283K,S/O = 118K, ROT=167K.ADT=2.16,Bit hrs=72.94,Jar hrs= 186.22.Trap 11 ppg EMW on connections w/MPD chokes.Observe pressure falling off at 250 psi,and continue to fall off—50 psi over connection. Increase lube concentration by 0.25%to total of 2.25%Lo-Torq. SPRs @ 12,265'MD,6,086'TVD, MW=10.0 ppg,22:40 hours MP#1:30 spm=445 psi,40 spm=500 psi. MP#2:30 spm=440 psi,40 spm=520 psi. Total downhole losses for 24 hours= 46 bbls. 5/15/2017 5/15/2017 3.75 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 12,360.0 12,548.0 00:00 03:45 12,360'MD to 12,548'MD,TVD= 6160'.Pump @ 820 gpm=3750 psi on,3690 psi off,w/19%flow out. Rotate @ 150 rpm's w/23K Tq on, 22K Tq off, 16-25K WOB, ECD= 11.07 ppg,Max gas=3627.P/U= 280K,S/O= 120K,ROT=167K.ADT= 3.41,Bit hrs=76.35,Jar hrs= 189.63. Attempt to trap 11.0ppg EMW on connection but observe hole taking fluid at 250 psi w/chokes closed.Trap 250 psi and observe pressure bleed down—50 psi over connection.With 10.Oppg MW,250 psi gives—10.8ppg EMW at 6135'TVD. Note:Observe drilled gas increasing each stand.Slow ROP to 50 ft/hr and continue running degasser.Observe non-pressurized MW of 9.6 in/9.3 out at 12470'MD.Observe top of Kalubik at 12,406'MD. Page 24/65 Report Printed: 6/19/2017 • Operations Summary (with Timelogtpths) rrt 2K-32 ConocoPIhimps #�seka Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/15/2017 5/15/2017 1.50 INTRM1 DRILL RGRP T Change out#1 swab on mud pump 12,548.0 12,548.0 03:45 05:15 #1.Change out remaining swabs/ liners in mud pump#1 as the other two liners each had over 700 hours. Work pipe f/12,540'-12,465 w/466 gpm, 1715 psi, 12%F/O,ECD 11.17, 100 rpm,23k Tq. MPD pressure initially set for ramp schedule to maintain drilling ECD but started seeing losses of—18 bbl/hr.Decrease MPD pressure to as needed to minimize losses. Note:Swab hours=8,Liner hours= 8. 5/15/2017 5/15/2017 3.75 INTRM1 DRILL CIRC T Circulate/condition mud to reduce 12,548.0 12,548.0 05:15 09:00 gas-cut.Observe background gas decrease to 700 units over circulation w/813 gpm,Initial 3780 psi, Final 3755 psi,Initial ECD 11.08,Final ECD 11.02, 100 rpm,21-23k Tq After circulating 5 x bottoms up,observe Pressurized MW in 10.Oppg/out 10.05ppg, Non-pressurized MW in 9.7ppg/out 9.45ppg.Start treating mud system w/LCM(Mix!!Fine)and weight up to 10.1ppg. Note: Inspect degasser and re- arrange lineup to try and help it work better.Confirm degasser lines clear and not plugged up. 5/15/2017 5/15/2017 3.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 12,548.0 12,643.0 09:00 12:00 12,548'MD to 12,643'MD,TVD= 6181'.Pump @ 817 gpm=3744 psi on,3700 psi off,w/19%flow out. Rotate @ 150 rpm's w/25K Tq on, 23K Tq off, 16K WOB,ECD=11.17 ppg,Max gas=1000.P/U=250K,S/O =117K,ROT=168K.ADT=2.17,Bit hrs=78.52,Jar hrs=191.0.Trap —10.8ppg EMW on connections and observe pressure bleed down—50 psi over connection.Pressurized MW 10.1 ppg,observe non-pressurized MW increase to 9.9 in/9.7 out. SPRs @ 12,640'MD,6,181'TVD, MW=10.1 ppg, 11:50 hours MP#1:30 spm=395 psi,40 spm=442 psi. MP#2:30 spm=395 psi,40 spm=482 psi. Note:Closed air valve on connection and confirmed that MPD pressure loss over connection formation-related. Page 25/65 Report Printed: 6/19/2017 -' Iperations Summary (with Timelog epths) 2K-32 COnOC Phiifips 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 (8KB).. End Depth(ftKB) 5/15/2017 5/15/2017 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 12,643.0 13,022.0 12:00 18:00 12,643'MD to 13,022'MD,TVD= 6269'.Pump @ 808 gpm=3865 psi on,3860 psi off,w/20%flow out. Rotate @ 140 rpm's w/25K Tq on, 23K Tq off,20K WOB,ECD=11.28 ppg,Max gas=2905.P/U=307K,S/O =93K,ROT=173K.ADT=4.80, Bit hrs=83.32,Jar hrs=196.60.Trap -10.8ppg EMW on connections and observe pressure bleed down-50 psi over connection.Pressurized MW 10.1 ppg,Non-pressurized MW 10.0ppg. 5/15/2017 5/15/2017 0.50 INTRM1 DRILL SVRG P Service topdrive.Clean out traction 13,022.0 13,022.0 18:00 18:30 motor vents.Circulate w/173 gpm, 660 psi,2%F/O. Note:Initial MPD pressure from ramp down of 195 psi inducing losses of -130 bbl/hr.Reduce MPD pressure to 135 psi and observe losses reduce to -20 bbl/hr,giving-10.7ppg EMW at bottom. 5/15/2017 5/15/2017 1.25 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 13,022.0 13,079.0 18:30 19:45 13,022'MD to 13,079'MD,TVD= 6275'.Pump @ 817 gpm=3880 psi on,3870 psi off,w/19%flow out. Rotate @ 150 rpm's w/25K Tq on, 23K Tq off, 16K WOB,ECD=11.28 ppg,Max gas= 1383.P/U=307K,SIO =93K,ROT=173K.ADT=0.83,Bit hrs=84.15,Jar hrs=197.43.Trap -10.8ppg EMW on connections and observe pressure bleed down-50 psi over connection.Pressurized MW 10.1 ppg,Non-pressurized MW 9.85ppg. 5/15/2017 5/15/2017 0.50 INTRM1 DRILL RGRP T Change out#2 swab on mud pump 13,079.0 13,079.0 19:45 20:15 #1.Work pipe f/13,076'-13,027'w/ 361 gpm, 1715 psi,12%F/O,ECD 11.17, 100 rpm,23k Tq.MPD pressure of 105 psi. Note:Swab hours=13,Liner hours= 13. Page 26/65 Report Printed: 6/19/2017 • Operations Summary (with Timelog!pths) 2K-32 C€illps 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(FMB) 5/15/2017 5/16/2017 3.75 INTRMI DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 13,079.0 13,211.0 20:15 00:00 13,079'MD to 13,211'MD,TVD= 6306'.Pump @ 803 gpm=3885 psi on,3880 psi off,w/20%flow out. Rotate @ 125 rpm's w/24-29K Tq on, 25K Tq off,23K WOB,ECD=11.27 ppg,Max gas=1559.P/U=310K,S/O =95K,ROT=175K.ADT=2.24,Bit hrs=86.39,Jar hrs=199.67.Trap —10.8ppg EMW on connections and observe pressure bleed down—50 psi over connection.Pressurized MW 10.1ppg,Non-pressurized MW 10.0ppg.Increase lube concentration to 3%Lo-Torq. SPRs @ 13,211'MD,6,306'TVD, MW=10.1 ppg,23:40 hours MP#1:30 spm=380 psi,40 spm=440 psi. MP#2:30 spm=395 psi,40 spm=480 psi. Total downhole losses for 24 hours= 206 bbls 5/16/2017 5/16/2017 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 13,211.0 13,350.0 00:00 06:00 13,211'MD to 13,350'MD,TVD= 6329'.Pump @ 803 gpm=3750 psi on,3700 psi off,w/20%flow out. Rotate @ 110-150 rpm's w/26-30K Tq on,26K Tq off, 16-20K WOB,ECD= 11.11 ppg,Max gas=3400.P/U= 310K,S/O=95K,ROT=175K.ADT= 5.64,Bit hrs=92.03,Jar hrs=205.31. Trap—10.8ppg EMW on connections and observe pressure bleed down—50 psi over connection.Pressurized MW 10.1ppg,Non-pressurized MW 9.7ppg. Note:Drill through hard spots at 13,248'and 13,289'w/bit and underreamer.Found top of Kuparuk C at 13,243'. 5/16/2017 5/16/2017 2.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 13,350.0 13,408.0 06:00 08:30 13,350'MD to 13,408'MD,TVD= 6334'.Pump @ 803 gpm=3750 psi on,3700 psi off,w/20%flow out. Rotate @ 110-140 rpm's w/27-31 K Tq on,27K Tq off, 16-20K WOB,ECD= 11.11 ppg,Max gas=1675. P/U= 305K,S/O=105K, ROT=165K.ADT= 1.72,Bit hrs=93.75,Jar hrs=207.03. Trap—10.8ppg EMW on connections and observe pressure bleed down—40 psi over connection.Pressurized MW 10.15ppg,Non-pressurized MW 9.7ppg. 5/16/2017 5/16/2017 0.50 INTRMI DRILL SVRG P Service rig.Change out swab#3 on 13,408.0 13,408.0 08:30 09:00 mud pump#2 while circulating w/456 gpm, 1570 psi, 14%F/O, 10.96 ECD, 100 rpm,26k Tq. Page 27/65 Report Printed: 6/19/2017 0,1‘ erations Summary (with Timelog 6epths) 2K-32 ConIterations tfssl..� 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) 5/16/2017 5/16/2017 1.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 13,408.0 13,451.0 09:00 10:30 13,408'MD to 13,451'MD,TVD= 6340'.Pump @ 803 gpm=3730 psi on,3700 psi off,w/20%flow out. Rotate @ 110-140 rpm's w/27-31 K Tq on,27K Tq off, 16-20K WOB,ECD= 11.10 ppg,Max gas=1355.P/U= 305K,S/O=105K,ROT= 165K.ADT= 1.26,Bit hrs=95.01,Jar hrs=208.29. Pressurized MW 10.1 ppg,Non- pressurized MW 9.6ppg. 5/16/2017 5/16/2017 0.25 INTRM1 DRILL RGRP T Change out swab#2 on mug pump#2 13,451.0 13,451.0 10:30 10:45 while circulating w/456 gpm, 1485 psi, 14%F/O,ECD 10.95, 100 rpm,24k Tq. 5/16/2017 5/16/2017 1.25 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 13,451.0 13,480.0 10:45 12:00 13,451'MD to 13,480'MD,TVD= 6345'. Pump @ 803 gpm=3730 psi on,3700 psi off,w/20%flow out. Rotate @ 120-140 rpm's w/27-31K Tq on,27K Tq off, 16-26K WOB,ECD= 11.08 ppg, MW 10.1 ppg,Max gas= 1891. P/U=305K,S/O=105K,ROT= 165K.ADT=1.04,Bit hrs=96.05,Jar hrs=209.33. 5/16/2017 5/16/2017 6.50 INTRM1 DRILL DDRL P DDrill 9-7/8"x 11"Intermediate hole f/ 13,480.0 13,738.0 12:00 18:30 13,480'MD to TD of 13,738'MD, TVD=6363'.Pump @ 806 gpm=3850 psi on,3840 psi off,w/20%flow out. Rotate @ 125 rpm's w/29K Tq on, 21K Tq off, 19K WOB,ECD=11.15 ppg,Max gas=4552.P/U=302K,S/0 =95K,ROT=172K.ADT=4.44,Bit hrs=100.49,Jar hrs=213.77. Note:Top of A4 at 13680'MD/6359' TVD Rig swap from generator power to Hi- Line power at 15:20 hrs. 5/16/2017 5/16/2017 2.50 INTRM1 CASING CIRC P Obtain final survey and slow pump 13,738.0 13,556.0 18:30 21:00 rates and circulate 2 x bottoms up while backreaming OOH slowly f/ 13738'-13556'w/810 gpm,3900 psi, 19%F/O, 120 rpm,27k Tq,Max gas 4193 units after first bottoms up. SIMOPS: Prep pits for weighting up system to 10.4 SPRs @ 13,738'MD,6,363'TVD, MW=10.1 ppg, 18:30 hours MP#1:30 spm=395 psi,40 spm=460 psi. MP#2:30 spm=410 psi,40 spm=490 psi. Page 28/65 Report Printed: 6/19/2017 operations Summary (with Timelog!pths) 2K-32 t mxic®Phiiitps s'AFI�.M1 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 (EKE) End Depth(EKE) 5/16/2017 5/16/2017 0.50 INTRM1 CASING OWFF P Perform wellbore breathing test w/ 13,556.0 13,556.0 21:00 21:30 MPD and confirm 10.4ppg kill-weight fluid.Observe initial pressure buildup of 109 psi decrease to 92 psi,then 86 psi,then 72 psi,and finally 60 psi over 5 minute increments.Rotate at 20 rpm,24k Tq during test. SIMOPS:Continue prep pits for weighting up system to 10.4 5/16/2017 5/16/2017 1.50 INTRM1 CASING CIRC P Continue circulating w/806 gpm,3760 13,556.0 13,495.0 21:30 23:00 psi,20%F/O,ECD 11.08, 100 rpm, 26k Tq while bringing on 11.4ppg spike fluid,dumping 10.1ppg mud to rockwasher to make space for dilution, and weighting up active system in pits to 10.4. Note:At 13,530'MD,observe pump 'pressure drop 300 psi and turbine rpm decrease 200 rpm.Confirmed loss of pump pressure and decrease of turbine rpm due to lowered head on charge pump for the mud pumps while moving mud for weight up. 5/16/2017 5/17/2017 1.00 INTRM1 CASING DISP P Displace well to 10.4ppg LSND per 13,495.0 13,495.0 23:00 00:00 mud engineer,performing-30% dilution on active mud system,starting at 775 gpm,3300 psi, 19%F/O, 100 rpm,28k Tq,ROPT 170k,adjusting flow rate to maintain under 11.1 ppg ECD. Total downhole losses for 24 hours= 95 bbls 5/17/2017 5/17/2017 1.00 INTRM1 CASING CIRC P Cont to increase MW to 10.4ppg 13,495.0 13,400.0 00:00 01:00 LSND per mud engineer,performing -30%dilution on active mud system by adding 11.4ppg spike fluid.Pump @ 775 gpm=3300 psi w/19%FO, stage pumps down to 489 gpm=1600 psi to keep ECD under 11.1 ppg EMW.Rotate @ 100 rpm's,ROT= 170K.Total of 1700 bbls pumped, 10.4 in/out. Page 29/65 Report Printed: 6/19/2017 !perations Summary (with Timelog!pths) 2K-32 ConocoPhiH ps ikxks 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) 5/17/2017 5/17/2017 2.00 INTRM1 CASING CIRC P Drop 7 x RFID chips and pump down 13,400.0 13,495.0 01:00 03:00 to close under reamer as per WFT rep.Pump down @ 488 gpm=1640 psi w/2070 Trpm's for 1800 strokes, reduce pump rate to 250 gpm=700 psi for 600 strokes.Shut down pumps, open bleeder and MPD chokes,and rotate string @ 15 rpm's for 10 min to allow reamer to relax.Pump @ 488 gpm=1700 psi w/22K Tq,no change in Trpm's.Shut down pump and rotary for 5 min then return to full rate,still no change in pump pressure or Trpm's. Drop 6 x RFID chips and repeat closing process per WFT.No change in pump pressure or Trpm's.Can not confirm reamer is closed.Discuss with town and decide to continue out of hole. 5/17/2017 5/17/2017 0.25 INTRM1 CASING CIRC P Obtain SPR's and parameters with 13,495.0 13,495.0 03:00 03:15 10.4ppg MW.P/U=270K,S/O=112K, ROT=175K. SPR's @ 13468'MD,6354'TVD, MW=10.4 ppg MP#1:30 spm=420 psi,40 spm=490 psi MP#2:30 spm=410 psi,40 spm=490 psi. 5/17/2017 5/17/2017 0.75 INTRM1 CASING OWFF P Monitor well for flow,confirm well is 13,495.0 13,495.0 03:15 04:00 breathing back with returns to vis cup on decreasing trend.Rotate @ 10 rpm's while monitoring well.Blow down top drive. 5/17/2017 5/17/2017 8.00 INTRM1 CASING SMPD P Line up mud pump#2 to MPD and 13,495.0 9,600.0 04:00 12:00 circulate through chokes w/3.5 bpm. Strip OOH f/13495'MD to 9600'MD, pulling @ 500-1000 fph.Hold 100 psi back pressure when pulling and 40 psi back pressure when in the slips.P/U= 210K,S/O=120K.Worked though tight spots @ 11526'MD, 11502'MD, 11471'MD,and 11391'MD to 11320' MD. 5/17/2017 5/17/2017 5.50 INTRM1 CASING SMPD P Strip OOH f/9600'-3460'MD,holding 9,600.0 3,460.0 12:00 17:30 100 psi backpressure when pulling and 40 psi backpressue when in slips, PUW 133k,SOW 108k.No overpull seen while pulling BHA into shoe. Pump at 3.5 bpm through MPD chokes w/mud pump#2. Page 30/65 Report Printed: 6/19/2017 Operations Summary (with Timelog Depths) hx.. ' 2K-32 .r ConocoPhitlips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op CodaActivity Code Time P-T-X Operation (ftKB) End Depth(5KB) 5/17/2017 5/17/2017 1.25 INTRM1 CASING CIRC P Stage up pumps to 654 gpm, 1756 3,460.0 3,460.0 17:30 18:45 psi,11.10 ECD,and pick up/slack off with no drag to confirm reamer closed. Observe hole taking fluid so back off rate to 450 gpm,915 psi, 11.0 ECD and engage rotary to 60 rpm,5k Tq. Slowly stage rate up to 600 gpm, 1464 psi,11.15 ECD,60 rpm,5k Tq while monitoring losses and ECD.Circulate -1.5 bottoms up at 600 gpm, reciprocating pipe f/3460'-3363'. Note:Observe turbine rpm of 2570 at 490 gpm,showing a-500 rpm increase from prior to dropping RFID chips to close it,indicating reamer is now closed. 5/17/2017 5/17/2017 0.50 INTRM1 CASING OWFF P Monitor well for flow,confirm well is 3,460.0 3,460.0 18:45 19:15 breathing back with returns to vis cup on decreasing trend.Blow down top drive. 5/17/2017 5/17/2017 2.00 INTRM1 CASING SMPD P Strip OOH f/3460'-528'MD,holding 3,460.0 528.0 19:15 21:15 100 psi backpressure when pulling and 40 psi backpressure when in slips,pumping w/mud pump#2 through MPD manifold at 3.5 bpm. 5/17/2017 5/17/2017 1.25 INTRM1 CASING MPDA P PJSM.Monitor well and confirm static. 528.0 528.0 21:15 22:30 Pull MPD bearing and drill nipple. Install trip nipple.Clean and clear floor of MPD bearing and drill nipple. 5/17/2017 5/18/2017 1.50 INTRM1 CASING BHAH P PJSM. Pull OOH on elevators f/528'- 528.0 77.0 22:30 00:00 77',laying down BHA#4. Observe small amount of cuttings packed around reamer cutter blocks. No chipped or broken teeth observed. 5/18/2017 5/18/2017 1.50 INTRM1 CASING BHAH P Cont to L/D BHA as per SLB. 77.0 0.0 00:00 01:30 Bit Grade=0-1-CT-G-X-I-NO-TD Calculated disp=127.4bbls Actual disp=136.5 bbls 5/18/2017 5/18/2017 1.25 INTRM1 CASING BOPE P Wash stack with stack washer,pull 0.0 0.0 01:30 02:45 wear bushing and install test plug. 5/18/2017 5/18/2017 1.00 INTRM1 CASING BOPE P CIO upper rams from 3-1/2"X 6"VBR 0.0 0.0 02:45 03:45 to 7-5/8"solid body rams.SIMOPS: L/D remaining SLB tools. 5/18/2017 5/18/2017 1.00 INTRM1 CASING BOPE P R/U and test 7-5/8"rams to 250/3500 0.0 0.0 03:45 04:45 psi for 5 min and annular to 250/2500 psi for 5 min on chart with 7-5/8"test joint. 5/18/2017 5/18/2017 0.25 INTRM1 CASING BOPE P R/D testing equipment and pull test 0.0 0.0 04:45 05:00 plug. 5/18/2017 5/18/2017 1.25 INTRM1 CASING RURD P R/U to run 7-5/8"casing,M/U Volant 0.0 0.0 05:00 06:15 CRT,bail extensions,spiders,250T side doors and XO f/7-5/8"H563 to 4- 1/2"IF. Page 31/65 Report Printed: 6/19/2017 operations Summary (with Timelog epths) 2K-32 Con coP`hitihps 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) 5/18/2017 5/18/2017 1.00 INTRM1 CASING PUTB P M/U 7-5/8",#29.7,L-80,Hydril 563 0.0 129.0 06:15 07:15 shoe track to 129'MD consisting of DavisLynch Double valve shoe,WFT float collar and WFT landing collar. Test floats,good.Bakerlock connections and torque to 12,400 n- ibs.Monitor displacement via pit#5. 5/18/2017 5/18/2017 4.75 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 129.0 2,200.0 07:15 12:00 Hydril 563 dopeless casing f/129'MD to 2200'MD,Making up casing to 12,400fUlbs,P/U=93K,S/0=93K.Fill every joint and top off every 10 w/ Volant tool.Monitor displacement via pit#5. 5/18/2017 5/18/2017 2.50 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 2,200.0 3,447.0 12:00 14:30 Hydril 563 dopeless casing f/2200' MD to 3447'MD,Torque casing to 12,400fUlbs,S/O=116K.Fill every joint and top off every 10 w/Volant tool.Monitor displacement via pit#5. 5/18/2017 5/18/2017 1.00 INTRM1 CASING CIRC P Circulate 1 x bottoms up at shoe, 3,447.0 3,447.0 14:30 15:30 staging up pumps to 5.5 bpm,235 psi, 3%F/O,SOW 118k. 5/18/2017 5/18/2017 5.25 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 3,447.0 5,460.0 15:30 20:45 Hydril 563 dopeless casing f/3447' MD to 5505'MD,Torque casing to 12,400fUlbs,5/0=125K.Fill every joint and top off every 10 w/Volant tool.Monitor displacement via pit#5. Note:Rejected joint#118(41.40')prior to making up due to damaged threads. Thread protector came off on skate while lifting to rig floor.Confirm all remaining thread protectors tight on pipe prior to going up skate. 5/18/2017 5/19/2017 3.25 INTRM1 CASING CIRC P Circulate/condition mud, 5,460.0 5,505.0 20:45 00:00 reciprocating f/5505'to 5440'MD. Observe losses of-50 bb/hr at 1 bpm/ 225 psi on downstroke.Start pumping only on the upstroke and vary rate.At 0.5 bpm/199 psi,-25 bbl/hr losses. At 0.75 bpm,205 psi/-40 bb/hr losses.At 1 bpm/212 psi/-50 bb/hr losses.Vary pulling speed from 50 ft/hr to 150 ft/hr on upstroke.Observe MW in 10.4ppg w/60 Vis,MW out 10.1 to 10.4ppg/62 to 73 Vis, Pumped-1300 strokes at midnight. 5/19/2017 5/19/2017 1.00 INTRM1 CASING CIRC P Cont to attempt to Circulate/condition 5,505.0 5,505.0 00:00 01:00 mud,reciprocating f/5505'to 5440' MD.Pumping @ 1 bpm=208 psi. Losing 83%of mud pumped.Decision made to cont RIH w/7-5/8"to attempt to regain circulation after getting below suspected loss zone.Pumped a total of 169 bbls and lost 141 bbls while attempting to condition mud. P/U= 167K,S/O=125K. Page 32/65 Report Printed: 6/19/2017 !perations Summary (with Timelog Depths) 2K-32 ConocoPhithps 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) 5/19/2017 5/19/2017 6.50 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 5,505.0 7,240.0 01:00 07:30 Hydril 563 dopeless casing f/5505' MD to 7240'MD,Torque casing to 12,400fUlbs,S/O=125K.Fill every joint and top off every 10 w/Volant tool.Monitor displacement via pit#5. Running casing @ 600 fph observed slight returns to 6115'MD when returns stopped.Slowed running speed to 400 fph,very little returns to 6814'MD where returns stopped. Torque and drag tends are holding steady—.3 FF 5/19/2017 5/19/2017 1.00 INTRM1 CASING CIRC P Attempt to establish circulation @ 1 7,240.0 7,240.0 07:30 08:30 bpm=275 psi,reciprocating f/7240'- 7190',PUW 165k,SOW 125k. Observed 95%losses pumping at 1 bpm,pumped 40 bbls and lost 38 bbls.Decision made to cont RIH w/7- 5/8"casing. 5/19/2017 5/19/2017 3.50 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 7,240.0 7,989.0 08:30 12:00 Hydril 563 dopeless casing f/7240' MD to 7989'MD,Torque casing to 12,400fUlbs,SIO=122K.Fill every joint and top off every 10 w/Volant tool.Monitor displacement via pit#5. Running casing @ 400 fph observed minimal returns to 7300'MD when returns stopped and fluid level started dropping below flow line.Slowed running speed to 300 fph and observe no returns.Continue to monitor fluid level and top off backside as needed. Torque and drag tends are holding steady—.3 FF 5/19/2017 5/19/2017 3.25 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 7,989.0 8,611.0 12:00 15:15 Hydril 563 dopeless casing f/7989' MD to 8611'MD,Torque casing to 12,400fUlbs,S/O=121K.Fill every joint and top off every 10 w/Volant tool.Monitor displacement via pit#5. Running casing @ 300 fph with no returns,continue to monitor fluid level and top off backside as needed. Torque and drag tends are holding steady—.3 FF 5/19/2017 5/19/2017 0.75 INTRM1 CASING CIRC P Attempt to establish circulation @ 1 8,611.0 8,611.0 15:15 16:00 bpm=285 psi,reciprocating f/8611'- 8597',PUW 240k,SOW 122k. Observed 95%losses pumping at 1 bpm,pumped 40 bbls and lost 38 bbls.Decision made to cont RIH w/7- 5/8"casing. Page 33/65 Report Printed: 6/19/2017 Iterations Summary (with Timelog Depths) ICt 2K-32 Qmoco 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) 5/19/2017 5/20/2017 8.00 INTRMI CASING PUTB P Cont to RIH w/7-5/8",#29.7, L-80, 8,611.0 10,250.0 16:00 00:00 Hydril 563 dopeless casing f/8,611' MD to 10,250'MD,Torque casing to 12,400ft/lbs,SIO=121K.Fill every joint and top off every 10 w/Volant tool.Monitor displacement via pit#5. Running casing @ 300-400 fph with no returns,continue to monitor fluid level and top off backside as needed. Torque and drag tends are holding steady—.3 FF Losses for 24 hours while tripping= 239 bbls Losses for 24 hours while circulating= 163 bbls Total losses for 24 hours=402 bbls 5/20/2017 5/20/2017 3.00 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 10,250.0 11,065.0 00:00 03:00 Hydril 563 dopeless casing f/10,250' MD to 11,065'MD,Torque casing to 12,400ft/Ibs,S/O=125K.Fill every joint and top off every 10 w/Volant tool.Monitor displacement via pit#5. Running casing @ 400 fph with no returns,continue to monitor fluid level and top off backside as needed. Torque and drag tends are holding steady—.3 FF 5/20/2017 5/20/2017 1.25 INTRM1 CASING CIRC P Attempt to establish circulation @ 1 11,065.0 11,065.0 03:00 04:15 bpm,ICP 420 psi,FCP 380 psi, reciprocating f/11,065'-11,020',PUW 285k,SOW 123k.Observed 95% losses pumping at 1 bpm,pumped 70.6 bbls and lost 67.3 bbls.Decision made to cont RIH w/7-5/8"casing. 5/20/2017 5/20/2017 7.75 INTRM1 CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 11,065.0 12,720.0 04:15 12:00 Hydril 563 dopeless casing f/11,065' MD to 12,720'MD,Torque casing to 12,400f/lbs,P/U=310K,S/0=110K. Fill every joint and top off every 10 w/ Volant tool.Monitor displacement via pit#5.Running casing @ 400 fph, slowing to 200-300 fph once in Kalubik at—12,400'with no returns,continue to monitor fluid level and top off backside as needed.Drag start to deviate towards—0.4 FF through Kalubik. 5/20/2017 5/20/2017 6.75 INTRMI CASING PUTB P Cont to RIH w/7-5/8",#29.7,L-80, 12,720.0 13,688.0 12:00 18:45 Hydril 563 dopeless casing f/12,720' MD to 13,688'MD,Torque casing to 12,400ft/Ibs,P/U=372K,S/O=110K. Fill every joint and top off every 10 w/ Volant tool. Monitor displacement via pit#5.Running casing @ 200-300 fph through Kalubik at—12,400',and top off backside as needed.Drag hold around—0.4 FF through Kalubik. 5/20/2017 5/20/2017 0.50 INTRMI CASING HOSO P Make up FMC hanger and landing 13,688.0 13,727.6 18:45 19:15 joint.RIH and land off hanger at 13,727.62'. Page 34/65 Report Printed: 6/19/2017 !perations Summary (with Timelogepths) 2K-32 ConocoPhillips ,zf:g Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time r= End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/20/2017 5/20/2017 3.25 INTRM1 CEMENT CIRC P Attempt to establish circulation. 13,727.6 13,727.6 19:15 22:30 Circulate at 0.5 bpm on downstroke, 1 -1.5 bpm on upstroke.At 0.5 bpm/ 510 psi,at 1.0 bpm/520 psi,at 1.5 bpm,540 psi.Reciprocate f/13727'- 13,711',PUW 355k,SOW 102k. Pumped 140 bbls,lost 140 bbls. 5/20/2017 5/20/2017 0.50 INTRM1 CEMENT CIRC P Land off hanger at 13727.62'MD. 13,727.6 13,727.6 22:30 23:00 Stage up pumps and establish injection rate with no returns at surface.Pumped 84 bbls,lost 84 bbls. 0.5 bpm/475 psi 1.0 bpm/542 psi 2.0 bpm/588 psi 3.0 bpm/625 psi 4.0 bpm/660 psi 5.0 bpm/665 psi 5/20/2017 5/20/2017 0.50 INTRM1 CEMENT RURD P Blow down topdrive,rig up cement 13,727.6 13,727.6 23:00 23:30 hose,and line up to cementers and hold PJSM. 5/20/2017 5/21/2017 0.50 INTRM1 CEMENT CMNT P Fill lines w/5 bbls water.Change out 13,727.6 13,727.6 23:30 00:00 sensator on cement line.Pressure test lines to 4000 psi. Total downhole losses for 24 hours= 455 bbls 5/21/2017 5/21/2017 4.00 INTRM1 CEMENT CMNT P PJSM,Cement 1st stage as follows: 13,727.6 13,727.6 00:00 04:00 batch up 12.5 ppg Mud Push II, pump 39 bbls MP II @ 4.5 bpm=650 psi. Shut down and drop bypass plug as per PESI. Batch up 15.8 ppg cement, cement wet at 00:33 hrs, Pump 141.1 bbls of 15.8 ppg cement @ 5 bpm= 600 psi ICP, 185 psi FCP(first 5 bbls were neat,then added 1.5 lb/bbl CemNet to 130 bbls,and last 5 bbls were neat).Drop bottom plug as per PESI,kick plug out with 10.1 bbls of water and swap to the rig.Displace cement with 10.4ppg LSND using rig mud pump#1 @ 5 bpm=275 psi ICP, 3 bpm-778 psi FCP.Observed pump pressure begin to increase @ 4800 stokes from 262 psi to bump @ 6079 strokes=778 psi,good lift pressure observed.After bumping the plug @ 6079 strokes,pressure up to 1200 psi and hold for 5 min,bleed off and check floats,good.2.6 bbls bled back. Cemented 1st with no returns, 100% loses.Lost 810 bbls of 10.4 ppg LSND mud while cementing. Cement in place @ 03:46 hrs Page 35/65 Report Printed: 6/19/2017 tperations Summary (with Timelog Isepths) = pre lung N 2K-32 ConocoPhiiiips 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) 5/21/2017 5/21/2017 1.50 INTRM1 CEMENT CIRC P Pressure up to 3100 psi to open stage 13,727.6 13,727.6 04:00 05:30 collar per PESI,observed tool shift open at 3100 psi,observed casing jump at surface. Pump @ 1 bpm, pressure increased to 1330 psi after pumping 4 bbls,indicating a possible packoff above stage collar.Shut down pumps and pressure bled to 842 psi, bleed off all pressure and shut in. Observed pressure increase to 200 psi.Discussed options with town. Pump @ 0.5 bpm,pressure built to 1015 psi then broke over @ 42 stokes to 827 psi,increase pump rate to 1 bpm,pressure built to 860 psi and stabilized @ 815 psi a 1 bpm. Observed pressure start decreasing slowly,kill pumps after 10 bbls pumped and observe 685 psi.Shut in and discuss with town. 5/21/2017 5/21/2017 0.25 INTRM1 CEMENT WOC T Decision made to WOC until 1st stage 13,727.6 13,727.6 05:30 05:45 reaches 500 psi compressive strength. Bled off pressure from casing,closed bleeder,and observed pressure build to 210 psi.Also observed fluid level on backside drop—2 inches. Pressure back up on casing @.5 bpm to 750 psi,shut in and WOC,2.4 bbls pumped.UCA=10:12 hours to 500 psi compressive strength. 5/21/2017 5/21/2017 8.25 INTRM1 CEMENT WOC T Wait on 1st stage cement slurry to 13,727.6 13,727.6 05:45 14:00 attain 500 psi compressive strength. Observe pressure decrease down to 435 psi at 06:00 hrs and then began to climb,up to 750 psi at 14:00 hrs. Service crown and blocks.Clear floor of casing running tools, blow down and clean out cement valves.Rig down bail extensions. Perform rig housekeeping and PM's. Page 36/65 Report Printed: 6/19/2017 DrillMing Operations Summary (with Timelogepths) v &W,e 2K-32 ConocoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time', End Time our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 5/21/2017 5/21/2017 1.50 INTRM1 CEMENT CIRC T Bleed off pressure from 750 psi to 0 13,727.6 13,727.6 14:00 15:30 psi,total 2.4 bbls bled back-well static.Obtain circulation/injection rates through stage collar as follows. Pump at 1 bpm,pressure up to 1600 psi,total 4.7 bbls pumped.Shut in and observe pressure fall to 1505 psi over 10 minutes.Pressure up to 2000 psi, 1.6 bbls pumped.Shut in and dump pressure down to 1500 psi. Ramp back to 2000 psi and repeat cycle 3 x times-no success.Shut in and dump pressure to 1000 psi.Ramp back to 2000 psi and repeat cycle 9 x times- no success.Ramp back to 2000 psi, shut in,and dump pressure to 0 psi. Ramp up to 2500 psi and dump pressure to 1000 psi. Ramp up at 3bpm and observe injection pressure, pump 30 bbls, ICP 1250 psi,FCP 1225 psi. Increase rate to 4 bpm and pump 70 bbls, ICP 1274 psi,FCP 1241 psi.Shut down and bleed back, initial flowback rate of 7 bbl/hr taper off to static. Note:No returns to surface, 100% losses downhole. 5/21/2017 5/21/2017 2.25 INTRM1 CEMENT RURD P Rig down GBR Volant tool. Make up 13,727.6 13,727.6 15:30 17:45 Schlumberger cement head and XO to landing joint. Page 37/65 Report Printed: 6/19/2017 • • Operations Summary (with Timelog Depths) " &Wells 2K-32 ConocoPhillips ir 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) 5/21/2017 5/21/2017 4.25 INTRM1 CEMENT CMNT P PJSM,Line up SLB and fill lines with 13,727.6 0.0 17:45 22:00 water. Pressure test lines to 4000 psi- good test.Cement 2nd stage as follows:batch up 12.5 ppg Mud Push II, pump 40.1 bbls MP II @ 3.3 bpm= 1140 psi.Batch up 15.8 ppg cement, cement wet at 18:19 hrs,Pump 78.3 bbls of 15.8 ppg cement @ 4 bpm= 1089 psi ICP,800 psi FCP.Drop closing plug out of cement head and kick out with 10 bbls of water- observe good indication of plug dropping.Swap to the rig.Displace cement with 10.45ppg LSND using rig mud pump#1 @ 4 bpm=753 psi ICP, at 3730 strokes w/4 bpm-1056 psi (mudpush turning corner),at 4128 strokes w/4 bpm-1075 psi(cement turning corner),at 3 bpm-1150 psi FCP.After bumping the plug @ 4952 strokes(61 strokes past calculated), pressure up to 2850 psi at 3 bpm and kill pump per PESI.No pressure shift observed to indicate stage tool closed. Increase pressure to 3000 psi and hold for 5 min. Bleed off pressure to 0 psi,5.0 bbls bled back,and shut in. No pressure buildup observed. Pressure up at 4 bpm to 2350 psi per PESI,shut in and hold for 5 min. Bleed off pressure,3.6 bbls bled back. Remove cement hose and monitor flowback through cement head at surface-initially observed small amount of aired-up mud flowing back, tapering off to static-stage collar closed.Cemented 2nd stage with no returns, 100%loses.Lost 624 bbls of 10.45 ppg LSND mud while cementing. 2nd Stage Cement in place©21:23 hrs 5/21/2017 5/21/2017 1.00 INTRM1 CEMENT RURD P Rig down cement head,pull landing 0.0 0.0 22:00 23:00 joint,and drain stack.Clear floor of cement head,bail extensions, elevators,and casing XO. 5/21/2017 5/22/2017 1.00 INTRM1 CEMENT VWVSP P Install 5"elevators and make up FMC 0.0 0.0 23:00 00:00 7-5/8"packoff. RIH on stand of 5"DP and set per FMC. Run in lock down screws and pressure test to 5000 psi/ 10 min,test witnessed by CPAI-good test.SIMOPS:clean cement valves Total downhole losses for 24 hours= 1733 bbls. 5/22/2017 5/22/2017 0.50 INTRM1 CEMENT VWVSP P Cont to test 10-3/4"X 7-5/8'packoff to 0.0 0.0 00:00 00:30 5000 psi f/10 min,witnessed by CPAI -good test.Release running tools and L/D. Page 38/65 Report Printed: 6/19/2017 `-' Operations Summary (with TimeloRepths) t 2K-32 Conoco/114110s 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 (ftK6) End Depth(ftK8) 5/22/2017 5/22/2017 1.25 INTRM1 CEMENT SLPC P Cut and slip 88'of drilling line. 0.0 0.0 00:30 01:45 5/22/2017 5/22/2017 1.75 INTRM1 CEMENT RURD P Change out saver sub from 4-1/2"IF 0.0 0.0 01:45 03:30 to 4"XT39,SIMOPS;C/O upper pipe rams from 7-5/8"solid body to 3-1/2" X 6"VBR. 5/22/2017 5/22/2017 0.50 INTRM1 CEMENT RURD P Install short mouse hole in table and 0.0 0.0 03:30 04:00 rig up to L/D 5"DP in derrick. 5/22/2017 5/22/2017 8.00 INTRM1 CEMENT PULD P L/D 5"DP from derrick via mouse 0.0 0.0 04:00 12:00 hole,L/D a total of 81 stands of 5"DP. 5/22/2017 5/22/2017 1.50 INTRM1 CEMENT RURD P 'Rig up to flush 10-3/4"X 7-5/8"OA, 0.0 0.0 12:00 13:30 Spot Vac trucks and pump truck,rig up LRS to OA and test lines to 3500 psi. 5/22/2017 5/22/2017 1.50 INTRM1 CEMENT FRZP P Freeze protect 10-3/4"X 7-5/8"OA as 0.0 0.0 13:30 15:00 follows:Pump down OA with rig at 1 bpm,observed pressure increase to 450 psi @ 10 strokes,observed stable injection pressure @ 1 bpm-=400 psi, staged pumps up to 4 bpm=700 psi, pumped a total of 152 bbls of fresh water.Shut down and swapped over to LRS @ 2.5 bpm=650 ICP and 1.5 bpm=1150 psi FCP.Pumped a total of 87.5 bbls of Isotherm in OA.Shut in OA with 750 psi. 5/22/2017 5/22/2017 7.25 INTRM1 CEMENT PULD P L/D 5"DP from derrick vai mouse 0.0 0.0 15:00 22:15 hole,UD a total of 60 stands of 5"DP. Last 38 x stands were high-torque pipe(stands#104-141) Note:Observed second connection on stand#135 very tight,steam connection and break it free. 5/22/2017 5/22/2017 1.25 INTRM1 CEMENT RURD P L/D mousehole and master bushings. 0.0 0.0 22:15 23:30 Change out die blocks on ST-100 iron roughneck.Pick up 4-1/2"test joint and install test plug. 5/22/2017 5/23/2017 0.50 INTRM1 WHDBOP RURD P Rig up to test BOPE. Fill lines with 0.0 0.0 23:30 00:00 water and obtain 3500 psi shell test. OA pressure @ midnight=550 psi. 5/23/2017 5/23/2017 3.50 INTRM1 WHDBOP BOPE P Test BOPE,tested all choke valves, 0.0 0.0 00:00 03:30 upper pipe rams,lower pipe rams and annular w/3-1/2"and 4-1/2"test joints. Tested 4"XT-39 floor valve and 4"XT-39 Dart valve.All Witness of test waived by AOGCC inspector Brian Bixby.Testing to 250 psi low and 3500 psi high,holding each 5 minutes.Chart test.Accumulator test: (6)bottle N2 average 2283 psi.200 psi build up 9 seconds,full charge 59 seconds.Accumulator 2900 psi, manifold 1500 psi. 5/23/2017 5/23/2017 0.50 INTRM1 WHDBOP RURD P Pull test plug,blow down choke and 0.0 0.0 03:30 04:00 kill lines and install wear bushing,9" ID,length 12". 5/23/2017 5/23/2017 0.25 INTRM1 CEMENT RURD P Change handling equipment and R/U 0.0 0.0 04:00 04:15 to pick up SLB BHA tools. Page 39/65 Report Printed: 6/19/2017 = operations Summary (with Timelo gepths) 2K-32 ConocoPhillips • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time. End Time Dur(Er) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 5/23/2017 5/23/2017 2.25 INTRM1 CEMENT BHAH P Pick up 6-3/4"drilling BHA as per 0.0 399.0 04:15 06:30 SLB: 6-3/4"MM55 PDC bit,475 Orbit power drive,PeriScope,andVison,3 non ported floats,4-3/4"drill collars,4- 3/4"jars and HWDP to 399'MD 5/23/2017 5/23/2017 4.50 INTRM1 CEMENT TRIP P RIH picking up 4"XT-39 drill pipe f/ 399.0 3,716.0 06:30 11:00 399'MD to 3716'MD,shallow hole testing tools @ 1500'MD.Picked up a total of 105 joints.P/U= 101K,S/O= 84K. 5/23/2017 5/23/2017 0.50 INTRM1 CEMENT QEVL P Obtain free ring in 7-5/8"casing with 3,716.0 3,811.0 11:00 11:30 real time sonic tool as per SLB,pump @ 250 gpm=1540 psi,RIH @ 800 fph.Sensor 97'back from bit. 5/23/2017 5/23/2017 7.25 INTRM1 CEMENT TRIP P RIH pickikng up singles from pipe 3,811.0 9,678.0 11:30 18:45 shed fill pipe every 2,000'. 5/23/2017 5/23/2017 4.75 INTRM1 CEMENT QEVL P PJSM/MU stands in mouse hole 9,678.0 10,908.0 18:45 23:30 logging from 9,678 to top of closing plug at 10,908'MD. 5/23/2017 5/24/2017 0.50 INTRM1 CEMENT PRTS P Pressure test 7 5/8"casing to 3,000 10,908.0 10,908.0 23:30 00:00 PSI. (PASSED). RD test equipment. 63 STKS to pressure up. 5.5 BBLS bled back. 5/24/2017 5/24/2017 0.50 INTRM1 CEMENT QEVL P Continue to RIH logging cement to 10,908.0 10,977.0 00:00 00:30 10,977'MD. Tag top of closing plug and set dwn 5K. 80K DWN, 120K UP,230 GPM @ 1,800 PSI. 5/24/2017 5/24/2017 2.50 INTRM1 CEMENT DRLG P Drill up closing plug/stage collar from 10,977.0 10,983.0 00:30 03:00 10,977'MD to 10,980'MD. 230-130 GPM with 850-1,850 PSI. 18-20% F/O. 30-60 RPM,w/12-15K WOB. TQ=12-15K. Off BTM 1,800 PSI,up WT-205K,DWN 80K. ROT-120K, 12K TQ. Ream 10,970-10,983 three times. No additional torque. 5/24/2017 5/24/2017 7.00 INTRM1 CEMENT QEVL P Cont RIH logging cement with real 10,983.0 13,465.0 03:00 10:00 time SonicScope as per SLB f/10983' MD to 13465'MD,Pumping @ 233 gpm=2258 psi,RIH @ 800 fph.Rotate last stand down to establish parameters for drilling out shoe track, P/U=250K,S/O=72K, ROT=123K, 40 rpm's w/14K Tq. 5/24/2017 5/24/2017 2.00 INTRM1 CEMENT PRTS P RU to pressure test casing. Pressure 13,465.0 13,465.0 10:00 12:00 up to 3,500 PSI for 30 min. 8 SPM for 7.2 BBLS to achieve pressure. RD/BD testing equip. (Charted) 5/24/2017 5/24/2017 0.50 INTRM1 CEMENT COCF P Drill down to Top of cement at 13,588' 13,465.0 13,588.0 12:00 12:30 MD. 235 GPM 2,305 PSI @ 22%F/O. 60 RPM 15K TQ. 5/24/2017 5/24/2017 3.00 INTRM1 CEMENT DRLG P Drill cement,landing collar,float 13,588.0 13,738.0 12:30 15:30 collar,and shoe track from 13,588'to 13,738'MD @ 200 GPM. 1,865 PSI, 20%F/O,60 RPM. 17-20K TQ. 5- 15K WOB. UP WT=215K. DWN WT =80K. ROT=126K. 15K TQ,MW= 10.4 PPG. Page 40/65 Report Printed: 6/19/2017 • Operations Summary (with Timelog epths) 0.ii 0 2K-32 cOPhitiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(Er) Phase Op Code Activity Code Time P T X Operation (EKE) End Depth(ftKB) 5/24/2017 5/24/2017 0.75 INTRM1 CEMENT DDRL P Drill 6 3/4"production hole from 13,738.0 13,758.0 15:30 16:15 13,738'to 13,758'MD. 250 GPM @ 2,615 PSI.21%F/O. 60 RPM,7-17K WOB.off BTM=2,300 PSI,UP WT= 215K. DWN WT=80K. ROT= 126K. 15K TQ. MW= 10.4 PPG. 5/24/2017 5/24/2017 2.50 INTRM1 CEMENT CIRC P Rotate and recip pipe from 13,690'- 13,758.0 13,758.0 16:15 18:45 13,758'MD while circulating at 250 GPM,2,488 PSI. 23%F/O.60 RPM, 14K TQ. 7,635 STKS plus a 35 BBL high Vis sweep. 5/24/2017 5/24/2017 0.75 INTRM1 CEMENT FIT P BD top drive and RU for FIT/LOT. 13,758.0 13,758.0 18:45 19:30 achieved 13 PPG.EMW w/860 PSI. Prepare to drill ahead. 5/24/2017 5/24/2017 1.50 PROD1 DRILL CIRC P Condition mud while rotating and 13,758.0 13,758.0 19:30 21:00 circulating from 13,690'-13,758'MD. Pumping at 235 GPM 2,286 PSI,22% F/O. 40 RPM 16KTQ. Total stks pumped 4,513. 5/24/2017 5/24/2017 2.00 PROD1 DRILL MPDA P Pull trip nipple and install RCD 13,758.0 13,758.0 21:00 23:00 bearing. Calibrate MPD chokes @234 GPM at 2,203 PSI,17%F/O 40 RPM 16K TQ. 5/24/2017 5/25/2017 1.00 PROD1 DRILL DISP P Rotate and recip 13,690-13,757'MD 13,758.0 13,758.0 23:00 00:00 displacing well from 10.4 PPG LSND to 9.5 PPG Flo Pro @ 236 GPM,F/O 24%. @ 2,263 PSI, 40 RPM 15K TQ. 5/25/2017 5/25/2017 2.00 PROD1 DRILL DISP P Rotate and recipricate from 13,690- 13,758.0 13,758.0 00:00 02:00 13,720'MD displacing well from 10.4 LSND to 9.5 PPG Flo Pro @ 236 GPM,2,136 PSI/40 RPM with 7K TQ. 5/25/2017 5/25/2017 1.25 PROD1 DRILL MPDA P Perform Draw down test with MPD to 13,758.0 13,758.0 02:00 03:15 obtain reservoir pressure. WI-IP=13 PSI with 9.5 EMW,6,362'TVD. 5/25/2017 5/25/2017 1.75 PROD1 DRILL CIRC P Circulate BU at 223 GPM as per plan 13,758.0 13,578.0 03:15 05:00 forward. 1,919 PSI, 125K ROT DWN WT. 136 K ROT UP WT. 40 RPM 8K TQ. Obtain SRP @ 13720'MD,6365'TVD w/9.5 ppg mud MP#1:30 spm=760 psi,40 spm=1039 psi. MP#2 30 spm=713 psi,40 spm=993 psi. 5/25/2017 5/25/2017 1.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/13758' 13,578.0 13,843.0 05:00 06:00 MD to 13843'MD,6366'TVD,Pump @ 254 gpm=2245 psi on,2240 psi off w/22%FO.Roate @ 80-120 rpms w/ 8-11K tq on, 10K WOB, 10.61 ppg EMW ECD.P/U=170K,S/O=100K, ROT=120K,ADT=.92,Bit hrs=1.6, Total Jar hrs=1.26,Max gas-20 units. Page 41/65 Report Printed: 6/19/2017 operations Summary (with Timelog epths) 2K-32 ConocoPhitlips 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 (MKS) End Depth(ftKB) 5/25/2017 5/25/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/13843' 13,843.0 14,295.0 06:00 12:00 MD to 14295'MD,6375'TVD,Pump @ 260 gpm=2500 psi,2478 psi off w/ 23%FO,Rotate @ 80-120 rpms w/8- 11K Tq on,9K Tq off.WOB 5-7K, ECD=10.9 ppg EMW. P/U=172K, S/O=100K, ROT=120K,ADT=4.23, Bit hrs=5.49,Total Jar hrs=5.49,Max gas=200 units. 5/25/2017 5/25/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f114295' 14,295.0 14,816.0 12:00 18:00 MD,6375'TVD to 14,816'MD 6,373' TVD.,Pump @ 270 gpm=2,662 psi, 2,660 psi off w/26%FO,Rotate @ 80 -120 rpms w/8-11K Tq on,9K Tq off. WOB 7-12K,ECD=11.02 ppg EMW. P/U=172K,S/O=92K,ROT=120K, ADT=4.29,Bit hrs=9.78,Total Jar hrs=9.78,Max gas=871 units. MW= 9.5 PPG. SPR 14,500'MD-6,377'TVD MW=9.5 PPG 1430 hrs. MP#2 20 SPM 680 PSI 30 SPM 970 PSI 5/25/2017 5/26/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/14,816' 14,816.0 15,340.0 18:00 00:00 MD 6,373'TVD to 15,340'MD 6,379' TVD.,Pump @ 270 gpm=2,743 psi, 2,740 psi off w/26%FO, Rotate @ 80 -120 rpms w/9-11K Tq on,9K Tq off. WOB 7-12K,ECD= 11.08 ppg EMW. P/U=180K,S/O=90K,ROT= 120K, ADT=4.31,Bit hrs= 14.09,Total Jar hrs=14.09,Max gas=622 units. MW =9.5 PPG. 5/26/2017 5/26/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/15340' 15,340.0 16,009.0 00:00 06:00 MD to 16009'MD,6394'TVD,Pump @ 260 gpm=2550 psi on,2500 psi off w/24%FO,Rotate @ 120 rpm's w/ 11K Tq on,9K Tq off. WOB=5-11K, ECD=11.14 ppg EMW,Max gas= 2200 units..P/U=182K,S/O=90K, ROT=128K,ADT=4.61,Bit hrs= 18.70,Total Jar hrs=18.70 Obtain SRP's @ 15736'MD,6393' TVD w/9.5 ppg MW @ 03:00 hrs 5/26/2017 5/26/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/16009' 16,009.0 16,588.0 06:00 12:00 MD to 16588'MD,6393'TVD,Pump @ 260 gpm=2750 psi on,2725 psi off w/26%FO,Rotate @ 120-140 rpm's w/11K Tq on, 10K Tq off. WOB=3- 7K,ECD=11.20 ppg EMW,Max gas= 2003 units..P/U=180K,S/0=88K, ROT=122K,ADT=4.04,Bit hrs= 22.74,Total Jar hrs=22.74 Page 42/65 Report Printed: 6/19/2017 02 all 0 Operations Summary (with Timelo gepths) 2K-32 c nillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cade Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/26/2017 5/26/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/16588' 16,588.0 17,156.0 12:00 18:00 MD,6393'TVD to 17,156'MD 6,423' TVD,Pump @ 260 gpm=2700 psi on, 2682 psi off w/27%FO,Rotate @ 110 -120 rpm's w/12K Tq on, 10K Tq off. WOB=5-10K,ECD= 11.11 ppg EMW, Max gas=917 units..P/U=190K, S/O=90K, ROT=120K,ADT=3.96, Bit hrs=26.71,Total Jar hrs=26.71 SPR's 5/26/2017 5/27/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/17,156' 17,156.0 17,724.0 18:00 00:00 ' - MD 6,423'TVD to 17,724'MD 6,325' TVD,Pump @ 260 gpm=2784 psi on,2777 psi off w/26%FO,Rotate @ 80-120 rpm's w/12K Tq on,9K Tq off. WOB=5-10K,ECD=11.17 ppg EMW, Max gas=658 units..P/U=187K, S/O=84K,ROT=123K,ADT=4.22, Bit hrs=30.96,Total Jar hrs=30.96 5/27/2017 5/27/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/17,724' 17,724.0 18,482.0 00:00 06:00 MD to 18482'MD 6,337'TVD,Pump @ 260 gpm=2690 psi on,2690 psi off w/25%FO, Rotate @ 140 rpm's w/ 13K Tq on, 11K Tq off. WOB=11K, ECD=11.32 ppg EMW,Max gas=700 units..P/U=220K,S/O=80K,ROT= 131K,ADT=4.26,Bit hrs=35.22, Total Jar hrs=35.22. SPR's @ 17815'MD,6428 TVD,MW= 9.5 ppg @ 00:30 hours MP#1;20 spm=760 psi,30 spm=1050 psi MP#2:20 spm=760 psi,30 spm=1050 psi 5/27/2017 5/27/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/18482' 18,482.0 19,228.0 06:00 12:00 MD to 19228'MD 6,428'TVD,Pump @ 260 gpm=2840 psi on,2835 psi off w/25%FO,Rotate @ 140 rpm's w/ 13K Tq on, 11K Tq off. WOB=12K, ECD= 11.42 ppg EMW,Max gas= 2234 units..P/U=212K,S/O=80K, ROT=127K,ADT=4.07,Bit hrs= 39.29,Total Jar hrs=39.29. SPR's @ 18765'MD,6431 TVD,MW= 9.5+ppg @ 8:40 hours MP#1;20 spm=760 psi,30 spm=1040 psi MP#2:20 spm=760 psi,30 spm=1040 psi Swapped over to generator power @ 8:30 hours due to high line cable spool subsidence issues. Page 43/65 Report Printed: 6/19/2017 • Operations Summary (with Timelog epths) 2K-32 P'#�itilp ' Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log • Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/27/2017 5/27/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f119228' 19,228.0 19,902.0 12:00 18:00 MD 6,428'TVD to 19,902'MD 6,437' TVD,Pump @ 260 gpm=2933 psi on,2,837 psi off w/26%FO,Rotate @ 140 rpm's w/12K Tq on, 10K Tq off. WOB=14K,ECD=11.61 ppg EMW, Max gas=1739 units..P/U=214K, S/O=70K,ROT=127K,ADT=4.27, Bit hrs=43.56,Total Jar hrs=43.56. SPR's @ 19,338'MD,6426 TVD, MW=9.5+ppg©1300 hours MP#1;20 spm=980 psi,30 spm=1230 psi MP#2:20 spm=980 psi,30 spm=1240 psi Swapped over to generator power @ 8:30 hours due to high line cable spool subsidence issues. 5/27/2017 5/28/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/19,902' 19,902.0 20,567.0 18:00 00:00 MD 6,437'TVD to 20,567'MD 6,451' TVD,Pump @ 260 gpm=3,048 PSI psi on,3,040 psi off w/25%FO, Rotate @ 140 rpm's w/13K Tq on, 10K Tq off. WOB=12K,ECD=11.74 ppg EMW,Max gas=841 units..P/U= 212K,S/O=70K,ROT=127K,ADT= 3.80,Bit hrs=47.36,Total Jar hrs= 47.36. SPR's @20,377"MD,6442 TVD, MW=9.5+ppg @ 22:15 hours MP#1;20 spm=950 psi,30 spm=1285 psi Swapped over to generator power @ 8:30 hours due to high line cable spool subsidence issues. 5/28/2017 5/28/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/20567' 20,567.0 21,229.0 00:00 06:00 MD to 21229'MD 6450 TVD,Pump @ 260 gpm=2950 psi on,2,940 psi off w/25%FO,Rotate @ 140 rpm's w/ 15K Tq on, 12K Tq off. WOB=11K, ECD=11.42 ppg EMW,Max gas=260 units..P/U=238K,S/O=65K,ROT= 133K,ADT=4.26,Bit hrs=51.62, Total Jar hrs=51.62. SPR's @ 20661'MD,6446 TVD,MW= 9.5+ppg @ 04:00 hours MP#1;20 spm=880 psi,30 spm=1190 psi MP#2:20 spm=860 psi,30 spm=1165 psi Page 44/65 Report Printed: 6/19/2017 i 0 Iperations Summary (with Timeloggepths) 2K-32 ConocaPthiili ps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log ' Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time PPT-X Operation (5KB) End Depth(tKB)< 5/28/2017 5/28/2017 3.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/21,229' 21,229.0 21,608.0 06:00 09:00 MD to 21,608'MD 6452 TVD,Pump @ 262 gpm=3005 psi on,3000 psi off w/24%FO,Rotate @ 130 rpm's w/ 14K Tq on, 12K Tq off. WOB=13K, ECD=11.75 ppg EMW,Max gas=320 units..P/U=230K,S/O=N/A (Lost slack off),ROT=135K,ADT=2.17,Bit hrs=53.79,Total Jar hrs=53.79. 5/28/2017 5/28/2017 1.00 PROD1 DRILL CIRC P RCD bearing leaking,circulate open 21,608.0 21,608.0 09:00 10:00 hole volume to change out RCD bearing.Pump @ 260 gpm=2990 psi w/24%FO,Rotate @ 90 rpm's w/11- 13K Tq.P/U-230K,ROT= 135K,No slack off.SIMOPS;Hold PJSM on changing out RCD bearing. 5/28/2017 5/28/2017 1.50 PROD1 DRILL MPDA P Close annular and hold 150-250 psi, 21,608.0 21,608.0 10:00 11:30 C/O bearing as per MPD rep.Warm up new bearing @ 50 rpm's f/15min. 5/28/2017 5/28/2017 0.50 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/21,608' 21,608.0 21,694.0 11:30 12:00 MD to 21,694'MD 6456 TVD,Pump @ 260 gpm=2990 psi on,2990 psi off w/24%FO,Rotate @ 140 rpm's w/ 15K Tq on, 13K Tq off. WOB=14K, ECD=11.60 ppg EMW, Max gas=220 units..P/U=231K,S/O=N/A (Lost slack off),ROT= 131K,ADT=.50,Bit hrs=54.29,Total Jar hrs=54.29. 5/28/2017 5/28/2017 2.25 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/21,694' 21,694.0 21,848.0 12:00 14:15 MD 6456 TVD to 21,848'MD 6,458' TVD,Pump @ 260 gpm=3,078 psi on,3,150 psi off w/26%FO,Rotate @ 140 rpm's w/13-14K Tq on, 12K Tq off. WOB=12K,ECD=11.65 ppg EMW,Max gas=24 units..P/U=230K, S/O=65,ROT=135K,ADT=.95, Bit hrs=55.24,Total Jar hrs=55.24. SPR 21,793'MD 6,457'TVD. MW= 9.6 PPG/hrs=1330 MP 1)20 SPM=990 30 SPM=1300 PSI MP 2)20 SPM= 1000 30 SPM= 1360 PSI 5/28/2017 5/28/2017 1.75 PROD1 DRILL CIRC T Observe 152 PSI increase in pump 21,848.0 21,848.0 14:15 16:00 PSI and ECD increase to 11.93 PPG EMW. Circulate bottoms up while recip from 21,848-21,793 MD. Monitoring returns and solid content. 260 GPM,3220 PSI ICP. 3,138 PSI FCP. Initial ECD=11.93-11.66 Final ECD EMW. 26%F/O.80-120 RPM. 11-13K TQ. 7200 stks pumped. Page 45/65 Report Printed: 6/19/2017 „ - cnm ltperations Summary (with Timelog!epths) 2K-32 ConacoPhillips 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 (EKE) End Depth(EKE). 5/28/2017 5/28/2017 0.50 PROD1 DRILL DDRL P DDrill 6-3/4”production hole f/21,848' 21,848.0 21,891.0 16:00 16:30 MD 6,458'TVD to 21,891 MD 6,459' TVD,Pump @ 260 gpm=3,154 psi on,3,120 psi off w/24%FO, Rotate© 140 rpm's w/12-14K Tq on, 12K Tq off. WOB= 11K,ECD= 11.71 ppg EMW, Max gas=24 units..P/U=230K, 5/0=65, ROT=135K,ADT=.44,Bit hrs=55.68,Total Jar hrs=55.68. 5/28/2017 5/28/2017 2.25 PROD1 DRILL CIRC T On stand 228 observed 3,500 PSI 21,891.0 21,891.0 16:30 18:45 spike on DPP. stand back std 227& BROOH from 21,891-21,700'.MD. ramp pumps 2-4 BPM attempting to gain returns. 150K up wt rotate and still no returns. Trouble shoot systems and find air valve closed. 5/28/2017 5/28/2017 3.75 PROD1 DRILL CIRC T After openning air valve pumped a 21,891.0 21,891.0 18:45 22:30 high vis sweep with bi-carb pill. rotate and recipricate while maintaining returns from 21,700'MS-21,891'MD. 260 GPM with ICP 3020 PSI,FCP 3,186 PSI. 50 RPM with 11-13K TQ. ECD= 11.71. UP WT with rot=137K, RT dwn= 105. pump 12,876 stks. 5/28/2017 5/29/2017 1.50 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/ 21,891 21,891.0 21,986.0 22:30 00:00 MD 6,459'TVD to 21,986'MD 6,462' TVD,Pump @ 260 gpm=3,166 psi on,3,121 psi off w/25%FO,Rotate @ 120 rpm's w/12-14K Tq on, 13K Tq off. WOB=14K,ECD=11.76 ppg EMW,Max gas=612 units..P/U= 219K,S/O=65,ROT=127K, ADT=.93,Bit hrs=56.61,Total Jar hrs=56.61. Total losses during event=234 BBLS 5/29/2017 5/29/2017 6.00'PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/21,986' 21,986.0 22,460.0 00:00 06:00 MD 6,462'TVD to 22,460 MD 6,459' TVD,Pump @ 260 gpm=3,380 psi on,3,350 psi off w/24%FO, Rotate @ 120 rpm's w/14K Tq on, 14K Tq off. WOB= 15K,ECD=12.03 ppg EMW, Max gas=130 units.. P/U=236K, S/O=0,ROT=140K,ADT=5.53,Bit hrs=62.14,Total Jar hrs=62.14. SPR 22,077 MD 6,466'TVD. MW= 9.5 PPG 0150 hrs Pump1 )20 SPM 1,030 PSI 30 SPM 1,345 PSI Pump2)20 SPM 1,000 PSI 30 SPM 1,325 PSI OA=650 PSI Page 46/65 Report Printed: 6/19/2017 Summa with Timelo a!perations rY 9 p 014 2K-32 the � Conoccieh iitikps 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 (EKE) End Depth(EKE) 5/29/2017 5/29/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/ 22,460' 22,460.0 23,029.0 06:00 12:00 MD 6,459"TVD to 23,029'MD 6,466' TVD. Pump @ 262 gpm=3,240 psi on,3,230 psi off w/24%FO, Rotate @ 140 rpm's w/15K Tq on, 14K Tq off. WOB=15K,ECD=11.92 ppg EMW, Max gas=130 units..P/U=190K, 5/0=N/A,ROT=140K,ADT=4.08, Bit hrs=66.22,Total Jar hrs=66.22. 5/29/2017 5/29/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/23,029' 23,029.0 23,637.0 12:00 18:00 MD 6,466'TVD to 23,637'MD 6,491' TVD. Pump @ 260 gpm=3,502 psi on,3,467 psi off w/24%FO,Rotate @ 140 rpm's w/14-16K Tq on, 14K Tq off. WOB=15K,ECD=12.48 ppg EMW, Max gas=882 units.. P/U= 1212K,5/0=91,ROT=140K,ADT= 4.25,Bit hrs=70.47,Total Jar hrs= 70.47. SPR 23,123 MD 6,465'TVD. MW= 9.6 PPG 1300 hrs Pump1 )20 SPM 1,165 PSI 30 SPM 1,485 PSI Pump2)20 SPM 1,160 PSI 30 SPM 1,525 PSI 5/29/2017 5/30/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/23,637' 23,637.0 24,235.0 18:00 00:00 MD 6,491'TVD to 24,235 MD 6,517'TVD. Pump @ 260 gpm=3,570 psi on,3,565 psi off w/26%FO, Rotate @ 140 rpm's w/14-17K Tq on, 13K Tq off. WOB=14K,ECD=12.35 ppg EMW, Max gas= 114 units.. P/U= 247K,5/0=100,ROT=140K,ADT= 3.59,Bit hrs=74.06,Total Jar hrs= 74.06. SPR 24,143 MD 6,509'TVD. MW= 9.6 PPG 2300 hrs Pump1 )20 SPM 1,165 PSI 30 SPM 1,485 PSI 5/30/2017 5/30/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/24,235 24,235.0 24,818.0 00:00 06:00 MD 6,517'TVD to 24,818'MD 6,475' TVD. Pump @ 260 gpm=3,470 psi on,2,460 psi off w/25%FO,Rotate @ 140 rpm's w/12-16K Tq on, 15K Tq off. WOB=14K,ECD= 12.39 ppg EMW,Max gas=50 units..P/U=267K, S/O=0,ROT=136K,ADT=3.99, Bit hrs=78.05,Total Jar hrs=78.05. SPR 24,327 MD 6,516'TVD. MW= 9.5 PPG 0050 hrs Pump1 )20 SPM 1,080 PSI 30 SPM 1,425 PSI Pump 2)20 SPM 1,070 PSI 30 SPM 1,415 PSI Page 47/65 Report Printed: 6/19/2017 0'1' iterations Summary (with Timelog!epths) :14 2K-32 Primps 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) 5/30/2017 5/30/2017 6.00 PROD1 DRILL DDRL P DDrill 6-3/4"production hole f/24,818' 24,818.0 25,322.0 06:00 12:00 MD 6,475'TVD to 25,322'MD,6,453 TVD. Pump©260 gpm=3,480 psi on,3,470 psi off w/25%FO,Rotate© 140 rpm's w/15K Tq on, 14K Tq off. WOB= 15K,ECD= 12.34 ppg EMW, Max gas=100 units..P/U=277K, SIO=0,ROT= 137K,ADT= 4.57, Bit hrs=82.62,Total Jar hrs=82.62. OA=550 PSI 5/30/2017 5/30/2017 3.50 PROD1 DRILL DDRL X Well extended by Anchorage Geo 25,322.0 25,598.0 12:00 15:30 group. DDrill 6-3/4"production hole f/ 25,322'MD,6,453 TVD to 25,598'MD 6,442'TVD. Pump @ 260 gpm= 3,903 psi on,3,870 psi off w/25%FO, Rotate @ 140 rpm's w/15K Tq on, 14K Tq off. WOB=15K,ECD=12.92 ppg EMW,Max gas=25 units.. P/U= 277K,S/O=0, ROT=137K,ADT=1.5, Bit hrs=85,Total Jar hrs=85 OA=550 PSI 5/30/2017 5/30/2017 4.25 PROD1 DRILL CIRC X rotate and reciprocate from 25,598'- 25,598.0 25,598.0 15:30 19:45 25,534'MD while pumping at 260 GPM Initial circ pressure 3,900 PSI. Final circ press=3,770 PSI, Initial ECD=12.78 PPG EMW Final= 12.66 PPG EMW. 26%F/O. 80 RPM. 11-15K tq UP WT=156K with pumps.117K W/O. Total stks= 14,535. SPR's 25,339'MD 6,453'TVD. MW=9.7 PPG 13:00 hrs Pump#1. 20 SPM-1140 PSI 30 SPM-1,500 PSI. 5/30/2017 5/30/2017 1.75 PROD1 DRILL OWFF X Perform MPD draw down as per MPD 25,598.0 25,598.0 19:45 21:30 rep while rotating©10 RPM. 13K TQ ROT WT=138 ISIP=285 PSI. FSIP=4. Bled back 4 BBLS. 5/30/2017 5/30/2017 0.25 PROD1 DRILL BKRM X BKRM OOH from 25,593'MD to 25,598.0 25,526.0 21:30 21:45 35,526'MD with 260 GPM©3,850 PSI DPP. 26%F/O,80 RPM 14K TQ. LD STND#267. 5/30/2017 5/31/2017 2.25 PROD1 DRILL CIRC X Rotate and reciprocate from 25,526'- 25,526.0 25,430.0 21:45 00:00 25,430'MD. While pumping at 260 GPM ICP=2,814 PSI. Final=3,874 PSI Initial ECD=12.93 PPG while final=12.39 PPG. 26%F/O 80 RPM 11-14KTQ. Upwtw/pumps=116K. max gas=156 units and total strokes pumped=8,600. Page 48/65 Report Printed: 6/19/2017 • • Operations Summary (with Timelog Depths) p ) 2K-32 ConocoPhilliips ,g1rik:3 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 MKS) End Depth(ftKB) 5/31/2017 5/31/2017 3.00 PROD1 CASING CIRC P Continue to circ while rotate from 25,430.0 24,443.0 00:00 03:00 24,443'MD to 25,522'MD with 260 GPM,3,550 PSI DPP. 25%F/O. 80- 120 RPM 13-15K. ECD=12.27 PPG EMW. Add Lo-TQ&776 bringin lube concentration to 3%. Add Nut Plug at 5#p/BBL. MW in 9.5#+out 9.6. Total stks pumped=20,567. UP WT= 302K.Unable to RIH without rotating. ROT= 133K. 14K TQ. 5/31/2017 5/31/2017 2.00 PROD1 CASING OWFF P Perfrom draw down test as per MPD. 24,443.0 25,530.0 03:00 05:00 Initial build up=156 PSI. Final build up=58 PSI. Opern chokes 100%. and monitor flow. Inital time to fill 1 qt =9 sec. Final time to fill 1 QT=40 sec. 5/31/2017 5/31/2017 0.50 PROD1 CASING BKRM X BKRM OOH from 25530'MD to 25,530.0 25,353.0 05:00 05:30 25,353'MD. 260 GPM @ 3,740 PSI. F/O=24%. 80-120 RPM. 15K TQ. ECD=12.3 PPG EMW. Packoff and stall out with 20K TQ.@ 23,355'MD. 5/31/2017 5/31/2017 6.50 PROD1 CASING REAM X Drop down in 30'increments from 25,353.0 25,355.0 05:30 12:00 25,355'MD to 25,429'MD. and continue to BKRM OOH. Work through several 400-600PSI packoffs.&TQ stalls to 24K. Ream out with 212 GPM 2,800 PSI,to RPM. 14-24K TQ.,25,389'MD Straight pull with pumps at 168 GPM 2,300 PSI. UP WT=360K. Shut pumps off with packoffsl to 600 PSI over. Pull up to 25,434'MD. 5/31/2017 5/31/2017 6.50 PROD1 CASING BKRM T Cont to POOH from 25,355 to 25,141' 25,355.0 25,141.0 12:00 18:30 MD working pipe and pack off+ overpulls. with 43 to 169 GPM @ 900 -2,800 PSI 10-19%F/O. up wt Max pull 370K. 5/31/2017 5/31/2017 0.50 PROD1 CASING OTHR T Apply 24K TQ to string @ 60 RPM 25,141.0 25,153.0 18:30 19:00 and work dwn. Apply 185 PSI on back side via MPD then pump at 85 GPM, 1,600 PSI to successfully free pipe from obstruction. 5/31/2017 5/31/2017 1.50 PROD1 CASING CIRC T At 25,153'ROT @ 100-130 RPM 17- 25,153.0 25,153.0 19:00 20:30 24K TQQ. 21%F/O 170 GPM 3,180 PSI total stks pumped 12,150. 5/31/2017 5/31/2017 2.00 PROD1 CASING BKRM T PU one stand from derrick and 25,153.0 25,150.0 20:30 22:30 attempt to RIH 30'.from 25,150'MD to 25,180'MD.and work string 10'until it brode free at 25,177'MD ROT @ 70- 100 RPM TQ 14-16K. 146K ROT. 84 GPM @ 2,500 PSI. 1,370 after free up. total stks pumped 1,200 Rack back stand. 5/31/2017 6/1/2017 1.50 PROD1 CASING BKRM T Continue to POOH from 25,150'to 25,150.0 24,982.0 22:30 00:00 24,982'MD SPM=10-20. 1000-1535 PSI DPP. F/O=22%. Break over at 314K. Working through multiple pack offs and overpulls. at 25,024'Weight dropped up quickly to 285K. Page 49/65 Report Printed: 6/19/2017 O0 perations Summary (with Timelo9�e the ) 2K-32 hilfiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 6/1/2017 6/1/2017 5.25 PROD1 CASING PMPO T Continue to Pump OOH from 24,982' 24,982.0 24,815.0 00:00 05:15 to 24,815'MD. Heavy weight swings with many packoffs. Best at this time is 1.5 BPM @ 1,300 PSI. Hold80-225 PSI back pressure with MPD. UP WT=290-370K. 6/1/2017 6/1/2017 6.75 PROD1 CASING BKRM T Stage pumps to 1.5 BPM&BKRM f/ 24,815.0 24,622.0 05:15 12:00 24,825'MD t/24,622'MD Initial RT= 1.5 BPM @ 1,263 PSI,22%F/O 100 PSI ann back pressure from MPD. 55 RPM 14-19K TQ.POOH speed=30 FPH. Stage pump&pulling speed up as back reaming occurs. Allowing hole to dictate pulling/rotating/ pump speeds. OA 475 PSI 6/1/2017 6/2/2017 12.00 PROD1 CASING BKRM T Continue to Backream OOH from 24,622.0 24,100.0 12:00 00:00 24,622'MD to 24,100'MD Initial rotating at 2.5 BPM 1,517 PSI with 22%F/O. 100 PSI Back pressure via MPD. 55-65 RPM, 14-19K TQ. Pulling speed 30-50 FPH. Stage pumps&adjust pulling speed while backreaming to 2.5 BPM @ 1,530 PSI/135 PSI Back press via MPD of 135 PSI and 50-90 FPH pulling speed. Rotating WT= 157K; variable packoffs and stalls of 24K TQ @ 24,455'MD&24,140'MD 1,400 PSI held on DP while working pipe 15'to assist in bleed dwn of DP and slowly stage circ rate back to 2 BPM. 6/2/2017 6/2/2017 5.25 PROD1 CASING BKRM T Continue to BKRM from 24,200'to 24,100.0 23,645.0 00:00 05:15 23,645'MD staging up to 4.4 BPM, 2,200 PSI @ 22%F/O. 125 PSI Ann back pressure via MPD. 55-65 RPM with 17K TQ. 250 FPH pulling speed///Stall out with 24K TQ- packoff @ 23,645'MD. 6/2/2017 6/2/2017 6.75 PROD1 CASING BKRM T Continue to BKRM from 23,645'MD to 23,645.0 23,280.0 05:15 12:00 23,280'MD stagin up to 2.5 BPM, 1,530 PSI,22%F/O, 125 PSI ann back pressure via MPD. 55-80 RPM 15K TQ,60 FPH pulling speed. OA 525PSI 6/2/2017 6/2/2017 6.00 PROD1 CASING BKRM T Continue to BKRM from 23,280'to 23,280.0 22,993.0 12:00 18:00 22,993'MD. with 3.1 BPM @ 1,680 PSI,26%F/O, 125 PSI ANN pressure via MPD. 55 RPM 14K TQ and 60 FPH pulling speed. 6/2/2017 6/2/2017 4.00 PROD1 CASING BKRM T Continue to BKRM from 22,933'to 22,993.0 22,770.0 18:00 22:00 22,770'MD. Dtaging pump reate at 5.1 BPM. 2,710 PSI 26%F/O. ECD's 11.9. 125 PSI Ann Backpressure,80 RPM-14K TQ. 110 FPH Pull speed. PU WT=245K. 6/2/2017 6/2/2017 0.75 PROD1 CASING MPDA P Remove MPD system and install trip 22,770.0 22,770.0 22:00 22:45 nipple. Page 50/65 Report Printed: 6/19/2017 '' !perations Summary (with Timelog!epths) 0 2K-32 conocophimps Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(MKS) 6/2/2017 6/3/2017 1.25 PROD1 CASING BKRM P Continue to BKRM from 22,770- 22,770.0 22,700.0 22:45 00:00 22700'MD. 260 GPM at 3265 PSI. 25%F/O. 110 RPM 14KTQ. ECD's 11.88 EMW. Gradually increase pulling speed and pump rates. 6/3/2017 6/3/2017 12.00 PROD1 CASING BKRM P Continue backreamming OOH from 22,700.0 20,570.0 00:00 12:00 22,700'to 20,570'MD 260 GPM @ 2,960 PSI DPP> 24%F/O. . 11.68 ECD EMW. 80 RPM, 11K TQ. Working pulling speed up to 500 FPH. 6/3/2017 6/3/2017 6.00 PROD1 CASING BKRM P Continue to BKRM OOH. from 20,570.0 19,336.0 12:00 18:00 20,570'MD to19,336'MD using 260 GPM @ 2,905 PSI DPP. 25%F/O. 11.58 ECD EMW with 80-100 RPM. 11K TQ. 30-500FPH pulling speed as conditions dictate. ROT= 133K. 6/3/2017 6/4/2017 6.00 PROD1 CASING BKRM P Continue to BKRM OOH. from19,336' 19,336.0 17,917.0 18:00 00:00 MD to 17,917'using 260 GPM @ 2,775 PSI DPP. 45%F/O. 11.46 ECD EMW with 80-100 RPM. 10K TQ. 500FPH ROT= 132K. 6/4/2017 6/4/2017 6.50 PROD1 CASING BKRM P Continue to BAck Ream OOH from 17,917.0 16,874.0 00:00 06:30 17,917'-16,874'MD. 260 GPM @ 2,730 PSI. 24%F/O. 11.33 ECD. 110 RPM 9K TQ. Encounter packoffs and high torque form 16,874-17,066'MD. rotating weight=129K. 6/4/2017 6/4/2017 0.50 PROD1 CASING BKRM T RIH from 16,874'to 17,066'MD to 16,874.0 17,155.0 06:30 07:00 ream area again. S/O 84K. 6/4/2017 6/4/2017 3.25 PROD1 CASING BKRM T Continue to Back Ream OOH from 17,155.0 16,899.0 07:00 10:15 17,155 to 16,899'MD. 260 GPM AT 2,750 PSI DPP. 24%f/o 11.38 ECD EMW. 110 RPM. 10K with troublesome packoffs/TQ out. @ 16,899'MD. 6/4/2017 6/4/2017 1.75 PROD1 CASING BKRM T RIH to 17,021'MD and BKRM OOH 16,899.0 16,889.0 10:15 12:00 from 17,021'-16,967'MD. Staging up to 290 GPM @ 3,180 PSI. 26%F/O 11.55ECD. 120 RPM. 9K TQ. ROT 128K. OA pressuer=595 PSI 6/4/2017 6/4/2017 8.25 PROD1 CASING BKRM P Continue to BKRM from 16,899'MD to 16,889.0 16,862.0 12:00 20:15 16,774'MD with 292 GPM @ 3,200 PSI 26%F/O 11.60 ECD. 120 RPM with 9-11K TQ. 60 FPH pulling speed or as hole dictates. ROT= 126K. S/O=79K 6/4/2017 6/4/2017 0.25 PROD1 CASING BKRM T RIH from 16,774 to 16,867'MD at 3 16,862.0 16,867.0 20:15 20:30 BPM, 1,215 PSI DPP. DAN=74K no obstructions. 6/4/2017 6/5/2017 3.50 PROD1 CASING BKRM P Continue to BKRM OOH from 16,867' 16,867.0 16,425.0 20:30 00:00 to 16,425'MD W 260 GPM 2,690 PSI DPP. 26%F/O. 11.31 ECD, 120 RPM with 8-10 K TQ. 300 FPH POOH speed. ROT=126 OA Press=550. . Page 51/65 Report Printed: 6/19/2017 Aerations Summary (with Timeloggepths) 2K-32 iliips �is:kn 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 (EKE) End Depth(ftKB) 6/5/2017 6/5/2017 10.25 PROD1 CASING BKRM P Continue to BKRM OOH from16,425' 16,425.0 13,651.0 00:00 10:15 MD to 13651'MD. W 260 GPM 2,380 PSI DPP. 24%F/O. 10.99 ECD, 100 RPM with 9K TQ. 500 FPH POOH speed. @ 16,000'peformed a dump and dilute an weighted up to 16.8 PPG on the fly. 6/5/2017 6/5/2017 0.25 PROD1 CASING OTHR P Drop 2.11"O.D. 1.61"ID drift with 110' 13,651.0 13,651.0 10:15 10:30 tail on stand#140. Let fall while optaining torque and drag. UP WT= 175K,Dwn WT=105K. ROT=132K. 9K TQ with 20 RPM. 6/5/2017 6/5/2017 4.00 PROD1 CASING BKRM P Continue to BKRM OOH from 13,651' 13,651.0 12,043.0 10:30 14:30 to 12,043' MD W 250 GPM 2,030 PSI DPP. 24%F/O. 10.78 ECD,70 RPM with 7.5 K TQ. ROT=126K UP WT= 158K Dwn WT=109K 6/5/2017 6/5/2017 2.75 PROD1 CASING CIRC P Pump 50 BBL Hi-Vis sweep,Circulate 12,043.0 12,043.0 14:30 17:15 2 bottoms up with rotation from 12,037 to 11,994'MD during recip. @ 250 GPM 25%F/O,60-80 RPM,7.5K TQ. UP WT=106K,7,565 Total stks pumped.BD Top drive and monitor well for 30 min. 6/5/2017 6/5/2017 1.50 PROD1 CASING SLPC P Slip and Cut 109'of drill line. Simops 12,043.0 12,043.0 17:15 18:45 with replacing KR valve on koomy with rams closed. 6/5/2017 6/5/2017 0.50 PROD1 CASING SVRG P Service top drive and blocks. 12,043.0 12,043.0 18:45 19:15 calibrate. 6/5/2017 6/5/2017 0.75 PROD1 CASING MPDA P Remove trip nipple and install MPD 12,043.0 12,043.0 19:15 20:00 bearing. 6/5/2017 6/5/2017 1.75 PROD1 CASING SMPD P Line up to striop OOH. Calibrate 12,043.0 11,947.0 20:00 21:45 chokes and strip OOH from 12,043' MD to 11,947'MD. Check floats and failed. Prepare to Pump OOH. 6/5/2017 6/6/2017 2.25 PROD1 CASING PMPO P Continue to PUmp OOH form 11,947' 11,947.0 10,434.0 21:45 00:00 to 10,434'MD. @ 280 GPM 2,360 PSI. 22%F/O ECD= 10.72 PPG EMW. 40 RPM with 6.5K TQ. Up WT =150K.DN WT=103K,ROT= 131K. 200 FPH pull rate. monitor displacement via pits#1-5. 6/6/2017 6/6/2017 8.25 PROD1 CASING PMPO P Pump OOH f/10,434'-4,755'MD w/ 10,434.0 4,755.0 00:00 08:15 280 gpm, ICP 2340 psi,FCP 1950 psi, Initial ECD 10.71ppg,Final ECD 10.57 ppg,22%F/O,40 rpm,2-5k Tq,PUW 108k SOW 94k, ROT 100k w/2.5k Tq. Note:Observe significant wear to hardbanding on large amount of 4"DP tooljoints. 6/6/2017 6/6/2017 1.25 PROD1 CASING CIRC P Pump 50 bbl hi-vis sweep and 4,755.0 4,665.0 08:15 09:30 circulate bottoms up while reciprocating from 4,755'-4,665'MD w/280 gpm, 1950 psi,22%F/O,60 rpm,2.5k Tq,ECD 10.61 ppg,385 bbls pumped. No significant amount of cuttings seen at shakers. Page 52/65 Report Printed: 6/19/2017 ii 0 !perations Summary (with Timelogtepths) 2K-32 "ConmoPhillips 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(ftKE) 6/6/2017 6/6/2017 1.00 PROD1 CASING MPDA P PJSM.Blowdown topdrive,pull MPD 4,665.0 4,665.0 09:30 10:30 bearing and drain nipple,install trip nipple,and clear floor of used bearing and drain nipple. 6/6/2017 6/6/2017 7.00 PROD1 CASING PULD P Pull OOH on elevators f/4,755'-398' 4,665.0 398.0 10:30 17:30 MD laying out 4"DP sideways, adjusting pulling speed per trip schedule,monitoring displacement via trip tank. 6/6/2017 6/6/2017 0.25 PROD1 CASING OWFF P Monitor well for flow-well static.Hold 398.0 398.0 17:30 17:45 PJSM for laying down BHA. 6/6/2017 6/6/2017 2.25 PROD1 CASING BHAH P Lay down 4"HWDP,jars,and BHA 398.0 0.0 17:45 20:00 per SLB,monitoring displacement via trip tank.Actual 29.4 bbls,Calc 36.8 bbls from once started pulling on elevators. -Rabbit went through jars and was recovered on top of upper float. -Observed—19k torque required to breakout BHA components that were originally torqued to 10k.No visible damage to threads observed at rig floor. -Upper 6-5/8"NM Stab was significantly worn,coming out of hole —1.5"undergauge -Upper plunger float stuck open w/ debris. -Flapper float had washing on the flapper portion of the float -Lower plunger float had minimal debris but spring was stiff and did not fully seat each time functioned. -Stabilizer on powerdrive was partially worn down—1/8". -Bit observed to be in gauge and had two x gauge cutters of bit that were delaminated,meaning that PDC part of cutter was worn off.Graded 1-1-WT -A-X-O-DL-TD. 6/6/2017 6/6/2017 0.50 PROD1 CASING BHAH P Clean and clear floor of BHA 0.0 0.0 20:00 20:30 equipment. 6/6/2017 6/6/2017 1.25 COMPZN WHDBOP WWWH P Make up stack washer and jet stack w/ 0.0 0.0 20:30 21:45 800 gpm.Lay out stack washer,rack back stand,and blow down topdrive. 6/6/2017 6/6/2017 1.00 COMPZN WHDBOP RURD P 'Pick up 4-1/2"test joint and 0.0 0.0 21:45 22:45 wearbushing puller,Run in and pull FMC wearbushing.Lay out wearbushing,make up test plug,run in and install FMC test plug w/4-1/2" test joint. Rig up test equipment and purge lines with water. Page 53/65 Report Printed: 6/19/2017 f.` !perations Summary (with Timelog!epths) 2K-32 ComcoPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time. Dur(hr) Phase Op Code Activity Code Time P-T-X Operation Start(ftKBDe)pth End Depth(ftKS) 6/6/2017 6/7/2017 1.25 COMPZN WHDBOP BOPE P Test BOPE w/4-1/2"and 3-1/2"test 0.0 0.0 22:45 00:00 joints to 250/3500 psi,5/5 min, charted.Witness waived by AOGCC rep Lou Laubenstein. Test Sequence up to midnight as follows: With 4-1/2"Test joint 1)Annular,Mud Manifold valves 1,12,13, 14,4"Kill line,and Upper IBOP 2)Upper Rams, Mud Manifold valves 9, 11,Mezz Kill line,and Lower IBOP 3)Upper Rams,Mud Manifold valves 8,10, HCR Kill line,and 4"Dart valve OA pressure at midnight=450 psi 6/7/2017 6/7/2017 3.00 COMPZN WHDBOP BOPE P Finish testing BOPE w/4-1/2"and 3- 0.0 0.0 00:00 03:00 1/2"test joints to 250/3500 psi,5/5 min,charted.Witness waived by AOGCC rep Lou Laubenstein. Test Sequence after midnight as follows: With 4-1/2"Test joint 4)Mud Manifold valves 6,7,Manual Kill line,and 4"FOSV 5)Manually Operated Choke and Super Choke tested to 2000 psi 6)Mud Manifold valves 2 and 5 7)Lower 3-1/2"x 6"Rams Remove 4-1/2"test joint 8)Blinds,Mud Manifold valves 3 and 4 With 3-1/2"Test Joint 9)Annular,and HCR Choke 10)Upper 3-1/2"x 6"Rams and Manual Choke 11)Lower 3-1/2"x 6"Rams System Pressure=3,100 psi PSI after closure=1,800 psi 200 psi Attained with 2 x electric pumps=7 seconds Full Pressure attained with 2 x electric and 2 x air pumps=56 seconds N2=6 each @ 2,592 psi Tested all gas and H2S sensors,PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls-all good. 6/7/2017 6/7/2017 0.75 COMPZN WHDBOP RURD P Rig down and blow down all test 0.0 0.0 03:00 03:45 equipment.Pull test plug and install short FMC wearbushing w/9"ID. Change out washpipe and pressure test to 3500 psi-good test. 6/7/2017 6/7/2017 1.25 COMPZN CASING SVRG P Change out XT39 Saver sub.SIMOPS 0.0 0.0 03:45 05:00 Mobilize casing running equipment to floor and hydroform centralizers. Page 54/65 Report Printed: 6/19/2017 • 0 Operations Summary (with Timeloggepths) or 2K-32 itpps 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(ft KB). 6/7/2017 6/7/2017 0.50 COMPZN CASING RURD P Rig up GBR double stack tongs, 0.0 0.0 05:00 05:30 elevators,air slips,and power unit. Confirm pipe count and order in shed and hold PJSM for running casing. 6/7/2017 6/7/2017 4.75 COMPZN CASING PUTB P Pick up Ray Oil tools silver bullet 0.0 4,781.0 05:30 10:15 eccentric composite float shoe shoe joint w/6-1/2"hydroform centralizer and 2 x stop rings installed 10'above shoe and baker lock first connection. Continue RIH w/4-1/2"12.6#L-80 Hydril 563 Doped perforated/blank liner per tally to 4781'MD,allowing pipe to self-fill,monitoring displacement via trip tank,using JetLube SealGuard dope and torquing to 4700 ft-lbs. Install 6-1/8"Hydroform centralizers free-floating on each joint with set-screw type stop ring installed mid-joint,except for swell packer pup joint and joint above swell packer which had 6-1/2"hydroform centralizer installed.Total of 115 x 6-1/8" hydroforms,5 x 6-1/2"hydroforms, 117 x solid set-screw stop rings,and 2 x hinged set-screw stop rings run in hole.Total of 28 x perforated joints,89 x blank joints, 6/7/2017 6/7/2017 0.50 COMPZN CASING OTHR P Change out elevators and make up 4,781.0 4,781.0 10:15 10:45 Baker HRD Liner hanger/packer (element and slips removed)per Baker rep.RIH w/1 x stand 4"DP to 4900'MD and obtain parameters. PUW 90k,SOW 82k,ROT 85k, 10 rpm w/2K Tq,20 rpm w/2K Tq. 6/7/2017 6/7/2017 6.00 COMPZN CASING RUNL P Run liner in hole on 4"DP f/4900'- 4,781.0 13,710.0 10:45 16:45 13710'MD,monitoring displacement via trip tank,PUW 167k,SOW 103k, adjusting super sliders as needer per WWT. 6/7/2017 6/7/2017 0.75 COMPZN CASING CIRC P Break circulation and obtain 13,710.0 13,710.0 16:45 17:30 parameters above shoe. 1 bpm=360 psi,2 bpm=500 psi w/14%F/O,3 bpm=675 psi w/18%F/O,4 bpm= 860 psi w/22%F/O,5 bpm=1095 psi w/23%F/O.RIH at 20 ft/min and obtain torque parameters at 2 bpm, 550 psi w/10rpm=4.3k Tq,20 rpm= 6k Tq,30 rpm=6.6k Tq,40 rpm=7k Tq.PUW 167k,SOW 106k,ROT 116k.Stationary free-rotating torque at 7500 ft-lbs w/40 rpm.Total of 92 bbls pumped. 6/7/2017 6/8/2017 6.50 COMPZN CASING RUNL P Run liner in hole on 4"DP f/13710'- 13,710.0 20,814.0 17:30 00:00 20,814'MD,allowing pipe to self-fill and monitoring displacement via trip tank,SOW 85k,adjusting super sliders as needer per WWT.Drift pipe out of derrick from stand#95 onwards with 2.34"OD drift. OA pressure at midnight=450 psi Page 55/65 Report Printed: 6/19/2017 0 operations Summary (with TimelogDepths) p ) • 2K-32 ConocoPhiiiiips 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 MKS)' 6/8/2017 6/8/2017 2.25 COMPZN CASING RUNL P Run liner in hole on 4"DP f/20,814'- 20,814.0 21,820.0 00:00 02:15 21,820'MD,allowing pipe to self-fill and monitoring displacement via trip tank,PUW 210k,SOW 94k.Drift pipe out of derrick with 2.34"OD drift. Actual displacement=96.8 bbls. Calculated displacement= 100.8 bbls Note:From—21,600'onwards,started seeing diminishing returns when we went much below—60k hookload.At 21,820',unable to work past section, slacking off to block weight. 6/8/2017 6/8/2017 1.25 COMPZN CASING CIRC P Wipe section up to 21793'and slowly 21,820.0 21,793.0 02:15 03:30 stage up pumps.Circulate open hole volume from circulation point at top perfjoint to 7-5/8"shoe,staging up to 2.5 bpm, 1015 psi, 18%F/O,MW in 9.8,MW out 10.0ppg,total 120 bbls pumped.Remain under 1100 psi while circulating per Baker. 6/8/2017 6/8/2017 9.25 COMPZN CASING RUNL P Wash down liner on 4"DP f/21793'- 21,793.0 22,986.0 03:30 12:45 22,986'MD w/2 bpm,880 psi, 15% F/O,PUW 197k,SOW 75k.No issues working pipe up with clean pickup weight.Vary running speed from 150- 600 ft/hr to try and maintain momentum but not stack too much weight on pipe to cause buckling. 6/8/2017 6/8/2017 3.00 COMPZN CASING RUNL P Wash down liner on 4"DP f/22,986'- 22,986.0 22,995.0 12:45 15:45 22,995'MD w/2 bpm,930 psi, 15% F/O. 6/8/2017 6/8/2017 4.00 COMPZN CASING RUNL P Wash down liner on 4"DP f/22,995'- 22,995.0 23,238.0 15:45 19:45 23,238'MD w/2 bpm,950 psi, 15% F/0,PUW 215k,SOW 75k,MW in 9.8ppg Vis 54,MW out 9.75ppg Vis 58.Continue to see diminishing returns when dropping below—60k hookload. Decision made by town to proceed with releasing from liner. 6/8/2017 6/8/2017 0.50 COMPZN CASING TRIP P Pull OOH f/23,328'-23,119'MD and 23,238.0 23,119.3 19:45 20:15 wipe section above/below 23,119'MD. Obtain parameters with no pumps, PUW 205k,SOW 85k Note:Pulled up to place shoe at 23,119.26'MD,thereby ensuring we did not have any perforated joints within the faulted section between 22,907'-22,967'MD. Page 56/65 Report Printed: 6/19/2017 Operations Summary (with TimeloPepths) 2K-32 ConocoPhitlips 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 (ftKE) End Depth(ftKE). 6/8/2017 6/8/2017 1.50 COMPZN CASING OTHR P Drop 29/32"phenolic ball and pump 23,119.3 18,236.0 20:15 21:45 down per Baker,staging up to 4 bpm, 1540 psi,22%F/O for 1700 strokes and then decreased rate to 2 bpm, 965 psi, 16%F/O.Ball on seat at 1795 strokes. Increased pressure up to 3500 psi per Baker-no indication seen for liner running tool shear(was pinned to shear at 2065 psi nominal) but observed ball seat shear at 3461 psi(was pinned to shear at 4000 psi nominal).Kill pumps,open bleeder, and slack off to 100k hookload. Pick up and observe travel at 188k hookload,indicating released from liner.Roll pumps at 2 bpm and pump out of sleeve,racking back stand and continuing out to 18236'MD to ensure liner running tools above sleeve. Top of liner at 18,314.62'MD Shoe at 23,119.26'MD 6/8/2017 6/8/2017 2.00 COMPZN CASING CIRC P Stage up pumps and circulate 1 x 18,236.0 18,174.0 21:45 23:45 bottoms up once at 6 bpm, 1715 psi, 24%F/O,PUW 182k,SOW 101k, reciprocating pipe from18,236'- 18,174'MD, MW in 9.8ppg,MW out 9.75 ppg,total 567 bbls pumped. 6/8/2017 6/9/2017 0.25 COMPZN CASING OWFF P Blowdown topdrive and monitor well 18,174.0 18,174.0 23:45 00:00 for flow-well static. OA pressure at midnight=620 psi. Total downhole losses for 24 hours= 13 bbls 6/9/2017 6/9/2017 0.50 COMPZN CASING TRIP P Pull OOH on elevators slowly from 18,174.0 17,985.0 00:00 00:30 18,174'-17,985'MD,monitoring fluid level on backside-observe hole swabbing. 6/9/2017 6/9/2017 5.75 COMPZN CASING PMPO P Pump OOH to offset swab from 17,985.0 13,534.0 00:30 06:15 17,985'-13,534'MD w/4 bpm, 1015 psi,20%F/O,—3600 ft/hr pulling speed.Observe 20k overpull at 16,991'MD. 6/9/2017 6/9/2017 0.25 COMPZN CASING OWFF P Monitor well for flow-well static. 13,534.0 13,534.0 06:15 06:30 Obtain parameters for upcoming liner run-at 13,534'MD with no pumps, PUW 178k,SOW 103k. 6/9/2017 6/9/2017 1.25 COMPZN CASING TRIP P Pull OOH on elevators from 13,554'- 13,534.0 12,682.0 06:30 07:45 12,682'MD,monitoring displacement via trip tank.Observe hole taking incorrect fill. 6/9/2017 6/9/2017 6.50 COMPZN CASING PMPO P Pump OOH to offset swab from 12,682.0 7,192.0 07:45 14:15 12,682'-7,192'MD w/4bpm ICP 780 psi,FCP 500 psi,20%F/O,PUW 123k,SOW 96k. Page 57/65 Report Printed: 6/19/2017 ii operations Summary (with Timelo ! 9e pthe ) 2K-32 Ccicxxof hil lips 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) 6/9/2017 6/10/2017 9.75 COMPZN CASING PULD P Blow down topdrive and pull OOH on 7,192.0 0.0 14:15 00:00 elevatorser tripping pping schedule from 7,192'to surface,laying down 4"DP sideways,monitoring displacement via trip tank.Pull liner tools to surface- observe seals missing from running tool. OA pressure at midnight=200 psi 6/10/2017 6/10/2017 0.50 COMPZN CASING PULD P Lay down Baker liner running tools 0.0 0.0 00:00 00:30 and clean/clear rig floor. 6/10/2017 6/10/2017 1.00 COMPZN CASING RURD P Rig up to run 4-1/2"upper liner. 0.0 0.0 00:30 01:30 6/10/2017 6/10/2017 0.25 COMPZN CASING SFTY P Hold PJSM for running upper liner. 0.0 0.0 01:30 01:45 6/10/2017 6/10/2017 4.75 COMPZN CASING PUTB P Pick up Baker guide shoe and baker 0.0 4,705.0 01:45 06:30 lock first connection.Continue RIH w/ 4-1/2"12.6#L-80 Hydril 563 Doped perforated/blank liner per tally to 4705'MD,allowing pipe to self-fill, monitoring displacement via trip tank, using JetLube SealGuard dope and torquing to 4700 ft-lbs. Install 6-1/8" Hydroform centralizers free-floating on each joint up to joint#65,except for swell packer pup joint and joint above swell packer which had 6-1/2" hydroform centralizer installed and stop ring on joint above each swell packer.From#65 onwards,install 6- 1/2"hydroform centralizers free floating.Total of 62 x 6-1/8" hydroforms,56 x 6-1/2"hydroforms, and 2 x solid set-screw stop rings run in hole.Total of 27 x perforated joints and 89 x blank joints run for upper liner.No remakes/no rejects. 6/10/2017 6/10/2017 1.00 COMPZN CASING OTHR P Change out elevators and make up 4,705.0 4,780.0 06:30 07:30 sealbore extension and liner hanger/packer assembly per Baker to 4780'MD.Fill tieback sleeve with XanPlex D. 6/10/2017 6/10/2017 0.75 COMPZN CASING RURD P Rig down GBR equipment and clear 4,780.0 4,780.0 07:30 08:15 floor. 6/10/2017 6/10/2017 0.25 COMPZN CASING RUNL P Run in hole on 1 x stand 4"DP to 4,780.0 4,874.0 08:15 08:30 4874'MD and obtain parameters, PUW 90k,SOW 81k,ROT 85k w/10 rpm=2k Tq,20 rpm=2k Tq. 6/10/2017 6/10/2017 5.00 COMPZN CASING RUNL P Run liner in hole on 4"DP f/4874'- 4,874.0 13,673.0 08:30 13:30 13673'MD,allowing pipe to self-fill, monitoring displacement via trip tank, PUW 167k,SOW 105k. Page 58/65 Report Printed: 6/19/2017 i n per at o s Summary (with Timelog�epths) 0"— 6 2K-32 hillips 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)'.. 6/10/2017 6/10/2017 1.00MP CO ZN CASINGIR C C P Stageums1w/42 psi,2 13 673.0 up pumps, bpm 13,673.0 13:30 14:30 bpm w/545 psi and 16%F/O,3 bpm w/675 psi and 19%F/O,4 bpm w/ 815 psi and 22%F/O,5 bpm w/975 psi and 24%F/O.At 2 bpm,500 psi, 15%F/O,rotate down at 10 rpm w/5 k Tq,20 rpm w/6k Tq,30 rpm w/6.2k Tq,40 rpm w/6.2k Tq, ROT wt on downstroke=110k,ROT wt sitting still =113k.PUW w/2 bpm,500 psi= 164k.Pumped 130 bbls total.Blow down topdrive. 6/10/2017 6/10/2017 5.25 COMPZN CASING RUNL P Run liner in hole on 4"DP/HWDP f/ 13,673.0 18,326.0 14:30 19:45 13673'-18,263'MD,allowing pipe to self-fill,monitoring displacement via trip tank, PUW 204k,SOW 117k.No indication seen of shoe entering top of liner.Continue in hole and tag up on no-go right on depth at 18,326'MD. Stack 30k weight on it to confirm. 6/10/2017 6/10/2017 0.25 COMPZN CASING CIRC P Pick up to up weight of 204k and 18,326.0 18,326.0 19:45 20:00 establish circulation.Stage up pumps, 1 bpm w/675 psi, 1.5 bpm w/760 psi and 11%F/O,2 bpm w/812 psi and 16%F/O,3 bpm w/970 psi and 19% F/O,4 bpm w/1179 psi and 22%F/O, total of 50 bbls pumped. 6/10/2017 6/10/2017 1.25 COMPZN CASING PACK P Drop 1.625"frac ball and pump down 18,326.0 18,326.0 20:00 21:15 per Baker at 4 bpm, 1165 psi,22% F/O,dropping to 2.5 bpm,850 psi, 18%F/O after 1000 strokes.Ball on seat at 1110 strokes(-20 bbls early). Increase pressure to 2500 psi to set hanger and hold for 3 minutes.Set down 45k weight onto hanger and confirm set.Pressure up to 4000 psi and hold for 3 minutes. Bleed off pressure,leave bleeder open,and pick up observing string travel at 194k. Pick up total of 5'to expose dog sub. Rotate at 15 rpm and set down—60k onto packer.observing good indication of shear at 95k hookload(with 45k weight on-packer). 6/10/2017 6/10/2017 0.50 COMPZN CASING PRTS P Pick up to up weight,line up to test 18,326.0 13,555.0 21:15 21:45 down IA and purge out air,close annular,and pressure test liner top packer/IA to 2500 psi/10 minutes- charted.Good test.Bleed off pressure.4.1 bbls pumped,4.1 bbls returned. Top of liner at 13,555.25'MD 6/10/2017 6/10/2017 1.00 COMPZN WELLPR CIRC P Pick up to release packoff and roll 13,555.0 13,545.0 21:45 22:45 pumps at 2 bpm,730 psi, 13%F/O while pulling out of tieback sleeve. Once above liner top,stage up pumps to 10 bpm,2680 psi,34%F/O,PUW 163k,SOW 120k w/pumps on at 10 bpm.Hold PJSM for displacing well to 9.8ppg NaCI brine. Page 59/65 Report Printed: 6/19/2017 Y' la 0 leperations Summary (with Timelog!epths) 0 2K-32 Coirmiazi`Ptvlfips �,,1;sska 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) 6/10/2017 6/11/2017 1.25 COMPZN WELLPR DISP P Displace cased hole to 9.8ppg NaCI 13,545.0 13,530.0 22:45 00:00 brine,pumping 60 bbl hi-vis sweep and chasing w/9.8ppg NaCI brine at 5 -10 bpm,adjusting flowrate to allow return trucks to keep up.Reciprocate pipe from 13,530'to 13,438'MD, dropping down to lowest mark per Baker as brine turned corner. OA pressure at midnight=630 psi 6/11/2017 6/11/2017 0.50 COMPZN WELLPR DISP P Finish displacing cased hole to 9.8ppg 13,530.0 13,530.0 00:00 00:30 NaCI brine,pumping 60 bbl hi-vis sweep and chasing w/9.8ppg NaCI brine at 5-7 bpm, 1600 psi,adjusting flowrate to allow return trucks to keep up. Reciprocate pipe from 13,530'to 13,438'MD.Total of 63 bbls of hi-vis spacer and 583 bbls of 9.8ppg NaCI brine pumped. 6/11/2017 6/11/2017 2.00 COMPZN WELLPR CIRC P Circulate 2 x bottoms up at 9 bpm, 13,530.0 13,530.0 00:30 02:30 2900 psi,9.75ppg in/out MW.Take slow pump rates. SPRs @ 13,530'MD,6,347.6'TVD, MW=9.75 ppg,02:25 hours MP#1:30 spm=380 psi,40 spm=640 psi. MP#2:30 spm=370 psi,40 spm=640 psi. 6/11/2017 6/11/2017 0.75 COMPZN WELLPR CIRC P Pump 85 bbls corrosion-inhibited brine 13,530.0 13,530.0 02:30 03:15 and chase w/117 bbls 9.8ppg NaCI brine to spot per mud engineer,pump at 9 bpm,2700 psi. 6/11/2017 6/11/2017 0.50 COMPZN WELLPR OWFF P L/D 4"DP joint,blow down top drive, 13,530.0 13,511.0 03:15 03:45 and monitor well for flow-well static. 6/11/2017 6/11/2017 2.50 COMPZN WELLPR PULD P Pull OOH sideways laying down 4"DP 13,511.0 11,238.0 03:45 06:15 from 13,511'-11,238'MD,PUW 193k, SOW 130k,monitoring displacement via trip tank.Remove super sliders from pipe in pipe shed per VVWT rep. 6/11/2017 6/11/2017 0.50 COMPZN WELLPR RURD P Rig up to remove super sliders on rig 11,238.0 11,238.0 06:15 06:45 floor instead of pipe shed per WWT rep. 6/11/2017 6/11/2017 14.75 COMPZN WELLPR PULD P Pull OOH sideways laying down 4"DP 11,238.0 0.0 06:45 21:30 from 11,238'to surface,pulling liner running tools to rig floor,monitoring displacement via trip tank,removing super sliders on rig floor per WWT rep.Actual displacement=103.8 bbls, Calculated displacment 92.0 bbls. Note:Overall for all 4"DP used for drilling 6-3/4"section,observed significant wear/minimal remaining hardbanding on 134 x joints of 4"DP. Kept the worn joints separate from other joints to allow for inspection prior to next well. Page 60/65 Report Printed: 6/19/2017 0 .. operations Summary (with TimelogDepths V 2K-32 Conomehillips �h�kg 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(EKE)'.. 6/11/2017 6/11/2017 1.00 COMPZN WELLPR RURD P Lay down Baker liner running tools per 0.0 0.0 21:30 22:30 Baker rep and clean/clear rig floor. Observed good indication of shear on dog sub. 6/11/2017 6/12/2017 1.50 COMPZN WELLPR SLPC P PJSM.Slip/cut 88'of drilling line, 0.0 0.0 22:30 00:00 calibrate amphion system,and service/inspect topdrive and blocks. 6/12/2017 6/12/2017 3.00 COMPZN WELLPR ELOG P PJSM.Mobilize E-line USIT tools to 0.0 0.0 00:00 03:00 floor,spot E-line unit,Rig up sheaves for e-line,Make up tool string in mousehole and calibrate per SLB E- line,41.5'total length,750 lbs,Max tool OD=4.645",Centralizer OD=7". Monitor displacement via trip tank- hole losing statically at-0.5 bbl/hr Note:Unit hooked up to rig's ethernet to stream data realtime to town. 6/12/2017 6/12/2017 1.75 COMPZN WELLPR FLOG P RIH w/E-line to-1000'MD and 0.0 4,000.0 03:00 04:45 confirm tool workingproperly p p y-good test.Continue RIH to 4000'MD. Monitor displacement via trip tank. 6/12/2017 6/12/2017 6.75 COMPZN WELLPR ELOG P Start logging out of hole from 4000'to 4,000.0 0.0 04:45 11:30 surface at 1000 ft/hr per SLB to perform USIT log for analyzing casing wear in 7-5/8"casing.Monitor displacement via trip tank.Discuss results with town and decision made to rig down E-line once confirmed we have good data.No significant wear was observed. 6/12/2017 6/12/2017 1.00 COMPZN WELLPR FLOG P Lay down E-line tools,rig down 0.0 0.0 11:30 12:30 sheaves,and clear floor. 6/12/2017 6/12/2017 0.50 COMPZN WELLPR WWWH P Make up stackwasher on joint of 4"DP 0.0 0.0 12:30 13:00 and jet stack w/800 gpm. Lay down stackwasher. 6/12/2017 6/12/2017 0.50 COMPZN WELLPR RURD P Make up wearbushing running tool on 0.0 0.0 13:00 13:30 4"DP and pull FMC short wearbushing.Lay down same. 6/12/2017 6/12/2017 1.00 COMPZN WELLPR RURD P Rig up 3-1/2"handling equipment and 0.0 0.0 13:30 14:30 GBR double-stack tongs to run upper completion.Confirm pipe count and ' jewlery placement in pipe shed.Hold PJSM for running upper completion. 6/12/2017 6/12/2017 1.00 COMPZN RPCOMP PUTB P Run 3-1/2"9.3#L-80 EUE upper 0.0 221.0 14:30 15:30 completion per tally to 221'MD, picking up Baker seal assembly, Halliburton Mirage plug,and Camco 2.75"DS Landing Nipple,monitoring displacement via pit#1. Use Jet-Lube Run-N-Seal dope and torque connections to 2240 ft-lbs. 6/12/2017 6/12/2017 0.50 COMPZN RPCOMP PRTS P Fill tubing,make up headpin,line up to 221.0 221.0 15:30 16:00 tubing with test pump,and pressure test tubing to 1000 psi/5 min to confirm Mirage plug integrity-good test.Rig down test equipment. Page 61/65 Report Printed: 6/19/2017 • r>,� Operations Summary (with TimeloRe the ) 2K-32 ConocoPhitiips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKB) 6/12/2017 6/12/2017 4.00 COMPZN RPCOMP PUTB P Run 3-1/2"9.3#L-80 EUE upper 221.0 3,060.0 16:00 20:00 completion per tally from 221'-3,060' MD,filling on the fly with fill-up hose, picking up Baker CMU sliding sleeve and Camco 3-1/2"x 1"KBMG GLM assemblies#1 and#2 with dummy valves installed,monitoring displacement via pit#1.Use Jet-Lube Run-N-Seal dope and torque connections to 2240 ft-lbs. 6/12/2017 6/12/2017 0.50 COMPZN RPCOMP OTHR T Troubleshoot GBR hydraulic power 3,060.0 3,060.0 20:00 20:30 unit due to loss of hydraulic power to tongs.Swap out with backup hydraulic power unit. 6/12/2017 6/13/2017 3.50 COMPZN RPCOMP PUTB P Run 3-1/2"9.3#L-80 EUE upper 3,060.0 6,103.0 20:30 00:00 completion per tally from 3,060'- 6,103'MD,filling on the fly with fill-up hose,picking up Camco 3-1/2"x 1" KBMG GLM assembly#3 with dummy valve installed,monitoring displacement via pit#1. Use Jet-Lube Run-N-Seal dope and torque connections to 2240 ft-lbs. OA pressure at midnight=450 psi 6/13/2017 6/13/2017 1.00 COMPZN RPCOMP PUTB P Run 3-1/2"9.3#L-80 EUE upper 6,103.0 6,820.0 00:00 01:00 completion per tally from 6,103'- 6,820'MD,filling on the fly with fill-up hose,picking up Camco 3-1/2"x 1" KBMG GLM assembly#4 with SOOV installed,monitoring displacement via pit#1.Use Jet-Lube Run-N-Seal dope and torque connections to 2240 ft-lbs. Note:SOOV is pinned to shear at 2500 psi IA to tubing differential and has a one-way check valve installed 6/13/2017 6/13/2017 0.50 COMPZN RPCOMP PRTS P Fill tubing,make up headpin,line up to 6,820.0 6,820.0 01:00 01:30 tubing with test pump,and pressure test tubing to 1000 psi/5 min to confirm Mirage plug integrity-good test.Rig down test equipment. 6/13/2017 6/13/2017 3.25 COMPZN RPCOMP PUTB P Run 3-1/2"9.3#L-80 EUE upper 6,820.0 10,030.0 01:30 04:45 completion per tally from 6,820'- 10,030'MD,filling on the fly with fill-up hose,picking up Camco 3-1/2"x 1" KBMG GLM assembly#5 with dummy valve installed,monitoring displacement via pit#1.Use Jet-Lube Run-N-Seal dope and torque connections to 2240 ft-lbs. 6/13/2017 6/13/2017 0.25 COMPZN RPCOMP PRTS P Fill tubing,make up headpin,line up to 10,030.0 10,030.0 04:45 05:00 tubing with test pump,and pressure test tubing to 1000 psi/5 min to confirm Mirage plug integrity-good test. Rig down test equipment. Page 62/65 Report Printed: 6/19/2017 Operations Summary (with Timelog!epths) • ,�t 2K-32 ConocoPhillips til'rk.m Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartDepth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P T X Operation (ftKB) End Depth(ftKB)'. 6/13/2017 6/13/2017 4.00 COMPZN RPCOMP PUTB P Run 3-1/2"9.3#L-80 EUE upper 10,030.0 13,616.0 05:00 09:00 completion per tally from 10,030'- 13,515'MD,filling on the fly with fill-up hose,picking up Camco 3-1/2"x 1" KBMG GLM assembly#6 with dummy valve installed,monitoring displacement via pit#1.Use Jet-Lube Run-N-Seal dope and torque connections to 2240 ft-lbs.Obtain parameters above liner top, PUW 123k,SOW 74k. Run in hole and sting into sealbore extension,tagging up on no-go at 13,619'MD(9.0'in on jt# 425),2.48'deep to plan.Set down 10k weight to confirm tag. Pick up 3'off no -go. Actual displacement=33.5 bbls, Calculated displacement=45.2 bbls Note:Observed damaged threads on jt#391 prior to making up.Layout joint and replace with extra jt#449 which was same length,31.56'. 6/13/2017 6/13/2017 2.00 COMPZN RPCOMP PUTB P Rig up and pressure test IA to 500 13,616.0 13,616.0 09:00 11:00 psi/5 min to confirm seals stabbed in. Bleed off IA pressure,line up and pressure test tubing to 3500 psi/5 min.Bleed tubing down to 2200 psi and hold.Pressure test IA to 3300 psi/10 min.All tests charted and witnessed by CPAI.Bleed off IA pressure then tubing pressure to 0 psi. 6/13/2017 6/13/2017 1.00 COMPZN RPCOMP HOSO P Lay down joints#425,424,423,and 13,616.0 13,574.7 11:00 12:00 422.Pick up 3-1/2"spaceout pups 4.41',8.14',and 8.06'.Make up XO and 1 x joint 4-1/2"12.6#L-80 TXP. 6/13/2017 6/13/2017 0.75 COMPZN RPCOMP THGR P Make up FMC tubing hanger with pre- 13,574.7 13,613.8 12:00 12:45 installed and pre-tested HP-type BPV and landing joint.Drain stack,open IA, and land off tubing hanger at 13,613.83'MD,spaced out 3.08' above no-go. 6/13/2017 6/13/2017 0.75 COMPZN RPCOMP THGR P Run in lock down screws.SIMOPS 13,613.8 0.0 12:45 13:30 Rig down casing handling equipment and clean/clear rig floor. 6/13/2017 6/13/2017 0.75 COMPZN RPCOMP THGR P Monitor well for flow for 30 min-well 0.0 0.0 13:30 14:15 static.SIMOPS Continue cleaning/clearing rig floor. 6/13/2017 6/13/2017 0.75 COMPZN RPCOMP THGR P Rig up test equipment,purge lines, 0.0 0.0 14:15 15:00 close upper rams on landing joint,and attempt to pressure test tubing hanger seals from the top to 3500 psi/15 min.Observe pressure dropping off quickly. Note:With FMC system on 2K-32, there is not a port to test hanger seals to 5000 psi prior to N/D BOPE. 6/13/2017 6/13/2017 0.75 COMPZN RPCOMP THGR T Troubleshoot lineup and identify two 0.0 0.0 15:00 15:45 bleeder valves on mud manifold leaking. Isolate from test lineup Page 63/65 Report Printed: 6/19/2017 lac ,Ked.0 '''?•,,,,.`, , perations Summary (with Timelog epths) 2K-32 ConacciPhillips 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) 6/13/2017 6/13/2017 0.50 COMPZN RPCOMP THGR P Pressure test tubing hanger seals 0.0 0.0 15:45 16:15 from the top to 3500 psi/15 min, charted-good test.R/D and blow down test equipment and lay down landing joint. 6/13/2017 6/13/2017 1.25 COMPZN WHDBOP NUND P Pull trip nipple and lay out mousehole. 0.0 0.0 16:15 17:30 Suck out stack from the top and nipple down air valve,katchakan,and Weatherford RCD head. 6/13/2017 6/13/2017 1.75 COMPZN WHDBOP NUND P Nipple down choke and kill lines and 0.0 0.0 17:30 19:15 BOP stack.Pick up and secure to pedestal. Nipple down extension and adapter.SIMOPS:Check moving hydraulic power units and all cold starts. 6/13/2017 6/14/2017 4.75 COMPZN WHDBOP NUND P Clean seals and profile and nipple up 0.0 0.0 19:15 00:00 tree adapter and tree.Vary combination of bolt patterns to attempt to line up direct with flowline.2K-pad operator Norman Adams called to pad and inspected multiple different lineups and confirmed final lineup was acceptable.Finish torquing up connections.Mobilize squeeze manifold and hoses to cellar.SIMOPS Disconnect unneeded interconnect lines prepping for rig move. 6/14/2017 6/14/2017 1.00 COMPZN WHDBOP NUND P Finish nippling up tree and pressure 0.0 0.0 00:00 01:00 test void to 250/5000 psi 15/15 min, witnessed by CPAI-good test. 6/14/2017 6/14/2017 1.25 COMPZN WHDBOP RURD P Convert HP-type BPV to two-way 0.0 0.0 01:00 02:15 check.Rig up to test tree,IA,and - tubing with test pump/rig pump. 6/14/2017 6/14/2017 2.25 COMPZN WHDBOP PRTS P Fill tree with diesel and pressure test 0.0 0.0 02:15 04:30 to 250/5000 psi 15/15 min charted- good test.SIMOPS Change out saver sub to 4-1/2"IF. 6/14/2017 6/14/2017 0.75 COMPZN WHDBOP MPSP P Remove tree cap,convert two-way 0.0 0.0 04:30 05:15 check to BPV and pull BPV per FMC rep. 6/14/2017 6/14/2017 2.50 COMPZN WHDBOP PRTS P Line up to pressure test tubing/IA.Fill 0.0 0.0 05:15 07:45 well,2.5 bbls required,with 9.8ppg NaCI brine.Pressure test tubing to 3500 psi/30 min-good test.Bleed off tubing to 2000 psi and hold.Pressure test IA to 3300 psi/30 min-good test. Bleed off IA to 0 psi then tubing to 0 psi. 6/14/2017 6/14/2017 0.75 COMPZN WHDBOP OTHR P Pressure up on IA to 3000 psi to shear 0.0 0.0 07:45 08:30 out SOOV(pinned to shear at 2500 psi).No clear indication of pressure drop to indicate shear. Kill pump and allow pressure to bleed off,taking returns from tubing.Established circulation down IA taking returns up tubing at 1 bpm/1600 psi,circulated 10 bbls-confirmed SOOV is sheared. Page 64/65 Report Printed: 6/19/2017 Operations Summary (with Timelogtepths) 2K-32 C n0 oc hillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(Er) Phase Op Code Activity Code Time P=T-X Operation (EKE) End Depth(ftKS) 6/14/2017 6/14/2017 1.50 COMPZN WHDBOP OTHR P Pressure up on tubing to 4100 psi with 0.0 0.0 08:30 10:00 rig pump and then swap to test pump. Continue pressuring up with test pump and observe mirage plug rupture at 4500 psi.Line up to rig pump and bullhead 15 bbls of 9.8ppg NaCl brine to formation to clean debris from mirage plug.Formation broke down at 1015 psi,inject at 0.5 bpm/850 psi, 1 bpm/1150 psi.Kill pumps and monitor for flow-well flowed back 7.3 bbls total before going static. 6/14/2017 6/14/2017 0.50 COMPZN WHDBOP MPSP P Confirm no pressure and dry-rod in H- 0.0 0.0 10:00 10:30 type BPV per FMC.Final tubing pressure=0 psi, IA=0 psi,OA=525 psi. 6/14/2017 6/14/2017 1.50 COMPZN WHDBOP RURD P Remove rig equipment from wellhead 0.0 0.0 10:30 12:00 and install flanges/gauges per FMC. Secure tree and shut in all valves, ensuring all caps and plugs are in place. 6/14/2017 6/14/2017 1.00 DEMOB MOVE RURD P Disconnect all lines at interconnects, 0.0 0.0 12:00 13:00 clean out cellar box,and continue prepping for rig move to 2K-30.Rig released at 13:00 hrs. Page 65/65 Report Printed: 6/19/2017 • • NADConversion Kuparuk River Unit Kuparuk 2K Pad 2K-32 2K-32 Definitive Survey Report 20 June, 2017 • i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKE D M P2 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 2K-32 Well Position +N/-S 0.00 usft Northing: 5,938,115.25 usft Latitude: 70°14'31.749 N +E/-W 0.00 usft Easting: 498,310.31 usft Longitude: 150°0'49.126 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 116.70 usft Wellbore 2K-32 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 5/13/2017 17.50 80.86 57,529 Design 2K-32 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft)', (°) 39.10 0.00 0.00 190.00 Survey Program Date From To (usft), (usft) Survey(Wellbore) Tool Name Description Survey Date 127.95 1,369.87 2K-32 Srvy 1-SLB_GWD70(2K-32) GYD-GC-SS Gyrodata gyro single shots 4/30/2017 8:23: 1,465.51 3,405.64 2K-32 Srvy 2-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/1/2017 8:26:0 3,490.68 3,490.68 2K-32 Srvy 3-SLB_MWD-INC-Filler(2K INC+TREND Inclinometer+known azi trend 5/5/2017 2:32:0. 3,537.56 10,963.19 2K-32 Srvy 4-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/4/2017 2:51:0 11,063.99 13,674.55 2K-32 Srvy 5-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/14/2017 1:25: 13,719.35 13,719.35 2K-32 Srvy 6-SLB_MWD-INC-Filler(2K INC+TREND Inclinometer+known azi trend 5/24/2017 10:25 13,787.31 25,534.53 2K-32 Srvy 7-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/24/2017 10:28 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section (usft);, (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100) (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -116.70 0.00 0.00 5,938,115.25 498,310.31 0.00 0.00 UNDEFINED 127.95 0.21 42.66 127.95 -27.85 0.12 0.11 5,938,115.37 498,310.42 0.24 -0.14 GYD-GC-SS(1) 147.32 0.56 32.70 147.32 -8.48 0.23 0.19 5,938,115.48 498,310.50 1.83 -0.25 GYD-GC-SS(1) 183.06 0.76 56.16 183.06 27.26 0.50 0.48 5,938,115.75 498,310.79 0.93 -0.58 GYD-GC-SS(1) 243.18 1.49 87.81 243.17 87.37 0.76 1.59 5,938,116.01 498,311.90 1.55 -1.02 GYD-GC-SS(1) 273.18 1.86 91.16 273.15 117.35 0.76 2.47 5,938,116.01 498,312.78 1.28 -1.18 GYD-GC-SS(1) 303.35 2.20 98.41 303.30 147.50 0.67 3.53 5,938,115.92 498,313.84 1.41 -1.27 GYD-GC-SS(1) 335.22 2.93 103.77 335.14 179.34 0.38 4.92 5,938,115.63 498,315.23 2.41 -1.23 GYD-GC-SS(1) 367.71 3.80 111.21 367.58 211.78 -0.20 6.73 5,938,115.04 498,317.04 2.99 -0.97 GYD-GC-SS(1) 6/20/2017 8:51:37AM Page 2 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NFF.S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 398.79 4.69 115.57 398.57 242.77 -1.12 8.84 5,938,114.12 498,319.15 3.04 -0.43 GYD-GC-SS(1) 431.00 5.09 120.53 430.66 274.86 -2.42 11.26 5,938,112.83 498,321.57 1.81 0.43 GYD-GC-SS(1) 522.22 5.83 124.77 521.47 365.67 -7.12 18.55 5,938,108.13 498,328.86 0.92 3.79 GYD-GC-SS(1) 616.15 6.21 135.78 614.88 459.08 -13.48 26.01 5,938,101.77 498,336.32 1.29 8.76 GYD-GC-SS(1) 710.84 5.43 136.59 709.08 553.28 -20.40 32.66 5,938,094.84 498,342.97 0.83 14.42 GYD-GC-SS(1) 803.24 8.40 128.70 800.80 645.00 -27.80 40.94 5,938,087.44 498,351.24 3.37 20.27 GYD-GC-SS(1) 898.89 8.84 127.91 895.37 739.57 -36.69 52.19 5,938,078.56 498,362.49 0.48 27.07 GYD-GC-SS(1) 993.31 10.03 129.51 988.52 832.72 -46.37 64.26 5,938,068.87 498,374.55 1.29 34.51 GYD-GC-SS(1) 1,086.49 12.71 130.99 1,079.86 924.06 -58.26 78.26 5,938,056.98 498,388.55 2.89 43.79 GYD-GC-SS(1) 1,182.83 15.50 130.74 1,173.28 1,017.48 -73.62 96.01 5,938,041.62 498,406.30 2.90 55.83 GYD-GC-SS(1) 1,276.11 18.31 130.08 1,262.52 1,106.72 -91.19 116.67 5,938,024.04 498,426.95 3.02 69.54 GYD-GC-SS(1) 1,369.87 22.04 127.89 1,350.52 1,194.72 -111.48 141.83 5,938,003.75 498,452.11 4.06 85.16 GYD-GC-SS(1) 1,465.51 26.77 129.82 1,437.59 1,281.79 -136.31 172.56 5,937,978.91 498,482.82 5.01 104.28 MWD+IFR-AK-CAZ-SC(2) 1,523.47 26.69 130.95 1,489.36 1,333.56 -153.20 192.41 5,937,962.02 498,502.67 0.89 117.46 MWD+IFR-AK-CAZ-SC(2) 1,559.12 26.85 130.49 1,521.18 1,365.38 -163.68 204.58 5,937,951.54 498,514.84 0.73 125.67 MWD+IFR-AK-CAZ-SC(2) 1,617.79 27.45 133.25 1,573.39 1,417.59 -181.55 224.51 5,937,933.67 498,534.76 2.38 139.80 MWD+IFR-AK-CAZ-SC(2) 1,712.07 28.91 139.14 1,656.51 1,500.71 -213.68 255.25 5,937,901.53 498,565.49 3.33 166.11 M1.ND+IFR-AK-CAZ-SC(2) 1,807.56 31.73 142.04 1,738.94 1,583.14 -250.94 285.81 5,937,864.27 498,596.03 3.33 197.50 MWD+IFR-AK-CAZ-SC(2) 1,903.21 33.29 142.70 1,819.59 1,663.79 -291.66 317.19 5,937,823.55 498,627.40 1.67 232.15 MWD+IFR-AK-CAZ-SC(2) 1,997.72 35.26 142.14 1,897.69 1,741.89 -333.83 349.65 5,937,781.37 498,659.85 2.11 268.04 MWD+IFR-AK-CAZ-SC(2) 2,091.55 36.12 144.95 1,973.90 1,818.10 -377.86 382.16 5,937,737.34 498,692.35 1.97 305.76 MWD+IFR-AK-CAZ-SC(2) 2,186.31 37.72 148.80 2,049.67 1,893.87 -425.53 413.22 5,937,689.67 498,723.39 2.97 347.31 MWD+IFR-AK-CAZ-SC(2) 2,281.00 39.00 150.95 2,123.92 1,968.12 -476.36 442.70 5,937,638.84 498,752.86 1.95 392.25 MVVD+IFR-AK-CAZ-SC(2) 2,375.39 40.31 153.49 2,196.59 2,040.79 -529.65 470.75 5,937,585.55 498,780.89 2.21 439.86 MWD+IFR-AK-CAZ-SC(2) 2,469.17 41.49 157.22 2,267.49 2,111.69 -585.44 496.32 5,937,529.75 498,806.45 2.89 490.36 MWD+IFR-AK-CAZ-SC(2) 2,563.41 42.98 161.31 2,337.27 2,181.47 -644.67 518.71 5,937,470.53 498,828.82 3.32 544.80 MWD+IFR-AK-CAZ-SC(2) 2,659.17 44.91 165.09 2,406.23 2,250.43 -708.27 537.87 5,937,406.93 498,847.97 3.40 604.11 MWD+IFR-AK-CAZ-SC(2) 2,753.09 46.58 169.31 2,471.78 2,315.98 -773.85 552.73 5,937,341.36 498,862.81 3.68 666.11 MWD+IFR-AK-CAZ-SC(2) 2,848.07 48.12 174.03 2,536.15 2,380.35 -842.93 562.81 5,937,272.28 498,872.88 4.00 732.40 MWD+IFR-AK-CAZ-SC(2) 2,943.05 49.22 175.62 2,598.88 2,443.08 -913.96 569.24 5,937,201.25 498,879.29 1.71 801.23 MWD+IFR-AK-CAZ-SC(2) 3,036.49 47.43 177.13 2,661.01 2,505.21 -983.61 573.66 5,937,131.61 498,883.69 2.26 869.05 MWD+IFR-AK-CAZ-SC(2) 3,131.43 48.48 177.14 2,724.59 2,568.79 -1,054.02 577.19 5,937,061.21 498,88720 1.11 937.78 MWD+IFR-AK-CAZ-SC(2) 3,225.65 46.69 177.62 2,788.14 2,632.34 -1,123.51 580.37 5,936,991.73 498,890.37 1.94 1,005.66 MWD+IFR-AK-CAZ-SC(2) 3,321.00 47.60 177.97 2,852.99 2,697.19 -1,193.35 583.06 5,936,921.89 498,893.04 0.99 1,073.98 MWD+IFR-AK-CAZ-SC(2) 3,405.64 50.81 178.33 2,908.28 2,752.48 -1,257.39 585.12 5,936,857.86 498,895.09 3.81 1,136.68 MWD+IFR-AK-CAZ-SC(2) 3,481 00 52.11 179.90 2,955.23 2,799.43 -1,316.32 586.02 5,936,798.93 498,895.98 2.38 1,194.56 INC+TREND(3) 10 3/4"x 13.112" 3,490.68 52.28 180.10 2,961.17 2,805.37 -1,323.97 586.02 5,936,791.28 498,895.98 2.38 1,202.09 INC+TREND(3) 3,537.56 52.79 181.06 2,989.68 2,833.88 -1,361.18 585.64 5,936,754.08 498,895.59 1.96 1,238.80 MWD+IFR-AK-CAZ-SC(4) 3,585.25 52.72 182.13 3,018.55 2,862.75 -1,399.12 584.59 5,936,716.14 498,894.53 1.79 1,276.36 MWD+IFR-AK-CAZ-SC(4) 6/20/2017 8.'51:37AM Page 3 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit , TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 3,679.71 52.33 186.67 3,076.04 2,920.24 -1,473.83 578.85 5,936,641.43 498,888.77 3.84 1,350.93 MWD+1FR-AK-CAZ-SC(4) 3,775.79 51.86 192.44 3,135.09 2,979.29 -1,548.54 566.28 5,936,566.74 498,876.19 4.76 1,426.68 MWD+IFR-AK-CAZ-SC(4) 3,868.15 51.59 196.76 3,192.32 3,036.52 -1,618.68 548.02 5,936,496.61 498,857.91 3.68 1,498.92 MWD+IFR-AK-CAZ-SC(4) 3,964.44 51.81 202.32 3,252.03 3,096.23 -1,689.84 522.76 5,936,425.46 498,832.64 4.54 1,573.39 MWD+IFR-AK-CAZ-SC(4) 4,057.87 51.97 204.70 3,309.70 3,153.90 -1,757.24 493.44 5,936,358.07 498,803.30 2.01 1,644.86 MWD+IFR-AK-CAZ-SC(4) 4,153.07 51.94 209.63 3,368.39 3,212.59 -1,823.91 459.23 5,936,291.42 498,769.08 4.08 1,716.45 MW3+IFR-AK-CAZ-SC(4) 4,247.71 52.99 211.73 3,426.05 3,270.25 -1,888.44 420.93 5,936,226.91 498,730.77 2.08 1,786.66 MWD+IFR-AK-CAZ-SC(4) 4,341.98 54.45 215.14 3,481.84 3,326.04 -1,951.83 379.05 5,936,163.53 498,688.89 3.30 1,856.35 MWD+IFR-AK-CAZ-SC(4) 4,435.93 55.35 219.26 3,535.88 3,380.08 -2,013.02 332.58 5,936,102.36 498,642.41 3.71 1,924.69 MWD+IFR-AK-CAZ-SC(4) 4,530.41 55.82 222.58 3,589.29 3,433.49 -2,071.90 281.54 5,936,043.49 498,591.36 2.94 1,991.53 MWD+IFR-AK-CAZ-SC(4) 4,625.37 56.30 225.90 3,642.32 3,486.52 -2,128.32 226.58 5,935,987.09 498,536.39 2.94 2,056.64 MWD+IFR-AK-CAZ-SC(4) 4,720.39 57.24 228.83 3,694.40 3,538.60 -2,182.14 168.11 5,935,933.29 498,477.92 2.76 2,119.80 MWD+IFR-AK-CAZ-SC(4) 4,814.46 57.99 230.05 3,744.78 3,588.98 -2,233.79 107.76 5,935,881.66 498,417.56 1.35 2,181.14 MWD+IFR-AK-CAZ-SC(4) 4,908.78 59.91 231.94 3,793.43 3,637.63 -2,284.63 44.97 5,935,830.84 498,354.76 2.66 2,242.11 MWD+IFR-AK-CAZ-SC(4) 5,004.27 61.66 232.67 3,840.04 3,684.24 -2,335.59 -20.98 5,935,779.90 498,288.81 1.95 2,303.75 MVVD+IFR-AK-CAZ-SC(4) 5,098.64 64.03 234.85 3,883.11 3,727.31 -2,385.20 -88.70 5,935,730.30 498,221.08 3.25 2,364.37 MWD+IFR-AK-CAZ-SC(4) 5,193.88 66.29 236.87 3,923.12 3,767.32 -2,433.69 -160.24 5,935,681.84 498,149.54 3.06 2,424.54 MWD+IFR-AK-CAZ-SC(4) 5,288.26 67.48 239.58 3,960.18 3,804.38 -2,479.39 -234.02 5,935,636.16 498,075.75 2.93 2,482.36 MWD+IFR-AK-CAZ-SC(4) 5,383.63 68.75 241.88 3,995.73 3,839.93 -2,522.64 -311.22 5,935,592.93 497,998.56 2.60 2,538.36 MWD+IFR-AK-CAZ-SC(4) 5,477.65 69.85 245.12 4,028.97 3,873.17 -2,561.87 -389.92 5,935,553.72 497,919.86 3.43 2,590.66 MWD+IFR-AK-CAZ-SC(4) 5,572.69 70.59 247.79 4,061.14 3,905.34 -2,597.59 -471.90 5,935,518.03 497,837.88 2.76 2,640.07 MWD+IFR-AK-CAZ-SC(4) 5,667.17 72.33 250.98 4,091.18 3,935.38 -2,629.11 -555.73 5,935,486.53 497,754.05 3.69 2,685.67 MWD+IFR-AK-CAZ-SC(4) 5,762.10 72.33 252.05 4,120.00 3,964.20 -2,657.79 -641.51 5,935,457.87 497,668.27 1.07 2,728.81 MWD+IFR-AK-CAZ-SC(4) 5,856.61 72.30 253.66 4,148.71 3,992.91 -2,684.33 -727.55 5,935,431.35 497,582.23 1.62 2,769.89 MWD+IFR-AK-CAZ-SC(4) 5,951.73 72.30 254.91 4,177.63 4,021.83 -2,708.87 -814.78 5,935,406.83 497,495.01 1.25 2,809.20 MWD+IFR-AK-CAZ-SC(4) 6,046.44 72.17 253.62 4,206.53 4,050.73 -2,733.33 -901.59 5,935,382.39 497,408.20 1.30 2,848.37 MWD+IFR-AK-CAZ-5C(4) 6,140.63 72.24 252.56 4,235.32 4,079.52 -2,759.42 -987.39 5,935,356.33 497,322.40 1.07 2,888.95 MWD+IFR-AK-CAZ-SC(4) 6,235.96 72.43 252.83 4,264.24 4,108.44 -2,786.44 -1,074.12 5,935,329.33 497,235.68 0.34 2,930.62 MWD+IFR-AK-CAZ-SC(4) 6,329.99 72.27 252.42 4,292.75 4,136.95 -2,813.19 -1,159.63 5,935,302.60 497,150.17 0.45 2,971.82 MWD+IFR-AK-CAZ-SC(4) 6,424.01 72.36 252.51 4,321.32 4,165.52 -2,840.18 -1,245.04 5,935,275.63 497,064.75 0.13 3,013.23 MWD+IFR-AK-CAZ-SC(4) 6,520.71 72.36 253.24 4,350.62 4,194.82 -2,867.32 -1,333.11 5,935,248.52 496,976.69 0.72 3,055.25 MWD+IFR-AK-CAZ-SC(4) 6,613.94 72.46 252.39 4,378.80 4,223.00 -2,893.58 -1,418.01 5,935,222.28 496,891.79 0.88 3,095.85 MWD+IFR-AK-CAZ-SC(4) 6,707.61 72.42 253.18 4,407.06 4,251.26 -2,920.01 -1,503.32 5,935,195.87 496,806.49 0.81 3,136.69 M1M3+IFR-AK-CAZ-SC(4) 6,803.32 72.29 252.91 4,436.07 4,280.27 -2,946.60 -1,590.56 5,935,169.30 496,719.25 0.30 3,178.04 MWD+IFR-AK-CAZ-SC(4) 6,897.82 72.42 252.94 4,464.71 4,308.91 -2,973.05 -1,676.64 5,935,142.88 496,633.17 0.14 3,219.02 MWD+IFR-AK-CAZ-SC(4) 6,992.05 72.39 252.12 4,493.20 4,337.40 -3,000.01 -1,762.32 5,935,115.93 496,547.49 0.83 3,260.46 MWD+IFR-AK-CAZ-SC(4) 7,087.55 72.36 252.02 4,522.11 4,366.31 -3,028.03 -1,848.92 5,935,087.94 496,460.90 0.10 3,303.09 MWD+IFR-AK-CAZ-SC(4) 7,181.73 72.38 250.53 4,550.64 4,394.84 -3,056.84 -1,933.92 5,935,059.15 496,375.90 1.51 3,346.23 MWD+IFR-AK-CAZ-SC(4) 7,277.61 72.42 249.38 4,579.63 4,423.83 -3,088.17 -2,019.78 5,935,027.84 496,290.04 1.14 3,391.98 MWD+IFR-AK-CAZ-SC(4) 7,372.67 72.54 249.45 4,608.25 4,452.45 -3,120.04 -2,104.64 5,934,995.99 496,205.18 0.14 3,438.11 MWD+IFR-AK-CAZ-SC(4) 820/2017 8:51:37AM Page 4 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual©155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 7,466.70 72.42 249.82 4,636.55 4,480.75 -3,151.25 -2,188.70 5,934,964.81 496,121.12 0.40 3,483.43 MWD+IFR-AK-CAZ-SC(4) 7,561.59 72.51 250.18 4,665.14 4,509.34 -3,182.19 -2,273.73 5,934,933.89 496,036.10 0.37 3,528.68 MWD+IFR-AK-CAZ-SC(4) 7,656.11 72.48 250.22 4,693.57 4,537.77 -3,212.73 -2,358.54 5,934,903.37 495,951.29 0.05 3,573.47 MVVD+IFR-AK-CAZ-SC(4) 7,750.65 72.48 251.44 4,722.04 4,566.24 -3,242.33 -2,443.69 5,934,873.79 495,866.14 1.23 3,617.41 MWD+IFR-AK-CAZ-SC(4) 7,845.23 72.30 251.15 4,750.65 4,594.85 -3,271.24 -2,529.08 5,934,844.90 495,780.75 0.35 3,660.71 MWD+IFR-AK-CAZ-SC(4) 7,939.83 72.27 251.23 4,779.43 4,623.63 -3,300.30 -2,614.38 5,934,815.87 495,695.45 0.09 3,704.14 MWD+IFR-AK-CAZ-SC(4) 8,034.74 72.30 251.08 4,808.31 4,652.51 -3,329.50 -2,699.94 5,934,786.69 495,609.89 0.15 3,747.76 MWD+IFR-AK-CAZ-SC(4) 8,129.25 72.34 251.13 4,837.02 4,681.22 -3,358.66 -2,785.14 5,934,757.55 495,524.70 0.07 3,791.27 MWD+IFR-AK-CAZ-SC(4) 8,224.42 72.39 250.99 4,865.85 4,710.05 -3,388.10 -2,870.92 5,934,728.14 495,438.91 0.15 3,835.15 M1M3+IFR-AK-CAZ-SC(4) 8,318.72 72.57 251.87 4,894.24 4,738.44 -3,416.73 -2,956.17 5,934,699.52 495,353.67 0.91 3,878.16 MWD+IFR-AK-CAZ-5C(4) 8,412.38 72.44 252.53 4,922.39 4,766.59 -3,444.04 -3,041.22 5,934,672.23 495,268.62 0.69 3,919.82 MWD+IFR-AK-CAZ-SC(4) 8,508.39 72.45 252.59 4,951.35 4,795.55 -3,471.48 -3,128.55 5,934,644.82 495,181.30 0.06 3,962.00 MWD+IFR-AK-CAZ-SC(4) 8,603.53 72.39 252.29 4,980.09 4,824.29 -3,498.84 -3,215.02 5,934,617.48 495,094.83 0.31 4,003.97 MWD+IFR-AK-CAZ-SC(4) 8,698.22 72.33 251.97 5,008.78 4,852.98 -3,526.53 -3,300.90 5,934,589.81 495,008.95 0.33 4,046.15 MWD+IFR-AK-CAZ-SC(4) 8,792.87 72.45 251.87 5,037.42 4,881.62 -3,554.53 -3,386.66 5,934,561.84 494,923.19 0.16 4,088.61 MWD+IFR-AK-CAZ-SC(4) 8,886.58 72.48 251.95 5,065.65 4,909.85 -3,582.27 -3,471.60 5,934,534.11 494,838.25 0.09 4,130.69 MWD+IFR-AK-CAZ-SC(4) 8,982.52 72.48 252.42 5,094.53 4,938.73 -3,610.26 -3,558.70 5,934,506.15 494,751.15 0.47 4,173.38 MWD+IFR-AK-CAZ-SC(4) 9,076.94 72.51 252.54 5,122.93 4,967.13 -3,637.37 -3,644.57 5,934,479.06 494,665.29 0.13 4,214.99 MWD+IFR-AK-CAZ-SC(4) 9,171.60 72.58 252.39 5,151.33 4,995.53 -3,664.58 -3,730.68 5,934,451.87 494,579.18 0.17 4,256.73 MWD+IFR-AK-CAZ-SC(4) 9,266.01 72.47 251.69 5,179.68 5,023.88 -3,692.35 -3,816.34 5,934,424.13 494,493.52 0.72 4,298.95 MWD+IFR-AK-CAZ-SC(4) 9,360.65 72.60 251.82 5,208.08 5,052.28 -3,720.61 -3,902.08 5,934,395.89 494,407.78 0.19 4,341.67 MWD+IFR-AK-CAZ-SC(4) 9,455.06 72.54 251.74 5,236.36 5,080.56 -3,748.77 -3,987.64 5,934,367.75 494,322.23 0.10 4,384.27 MWD+IFR-AK-CAZ-SC(4) 9,550.09 72.42 250.60 5,264.97 5,109.17 -3,778.02 -4,073.41 5,934,338.52 494,236.46 1.15 4,427.97 MWD+IFR-AK-CAZ-SC(4) 9,644.93 72.55 250.20 5,293.51 5,137.71 -3,808.36 -4,158.61 5,934,308.20 494,151.26 0.42 4,472.64 MWD+IFR-AK-CAZ-SC(4) 9,739.40 72.47 251.02 5,321.91 5,166.11 -3,838.27 -4,243.60 5,934,278.31 494,066.27 0.83 4,516.86 MWD+IFR-AK-CAZ-SC(4) 9,833.30 72.51 251.70 5,350.16 5,194.36 -3,866.90 -4,328.46 5,934,249.71 493,981.42 0.69 4,559.78 MWD+IFR-AK-CAZ-SC(4) 9,927.98 72.51 251.01 5,378.61 5,222.81 -3,895.77 -4,414.02 5,934,220.86 493,895.86 0.70 4,603.07 MWD+IFR-AK-CAZ-SC(4) 10,022.58 72.49 250.81 5,407.06 5,251.26 -3,925.27 -4,499.28 5,934,191.38 493,810.60 0.20 4,646.93 MWD+IFR-AK-CAZ-SC(4) • 10,117.39 72.52 250.66 5,435.56 5,279.76 -3,955.11 -4,584.64 5,934,161.57 493,725.24 0.15 4,691.13 MWD+IFR-AK-CAZ-SC(4) 10,211.63 72.42 250.90 5,463.95 5,308.15 -3,984.69 -4,669.49 5,934,132.00 493,640.39 0.27 4,735.00 MWD+IFR-AK-CAZ-SC(4) 10,306.40 72.52 251.50 5,492.49 5,336.69 -4,013.81 -4,755.04 5,934,102.90 493,554.85 0.61 4,778.54 MWD+IFR-AK-CAZ-SC(4) 10,401.38 72.42 251.51 5,521.10 5,365.30 -4,042.54 -4,840.93 5,934,074.20 493,468.96 0.11 4,821.75 MWD+IFR-AK-CAZ-SC(4) 10,495.87 72.42 251.32 5,549.64 5,393.84 -4,071.25 -4,926.31 5,934,045.51 493,383.58 0.19 4,864.85 MWD+IFR-AK-CAZ-SC(4) 10,590.24 72.42 250.50 5,578.14 5,422.34 -4,100.67 -5,011.33 5,934,016.11 493,298.57 0.83 4,908.58 MWD+IFR-AK-CAZ-SC(4) 10,684.97 72.51 250.09 5,606.69 5,450.89 -4,131.13 -5,096.36 5,933,985.67 493,213.53 0.42 4,953.34 MWD+IFR-AK-CAZ-SC(4) 10,779.98 72.36 250.07 5,635.36 5,479.56 -4,161.99 -5,181.53 5,933,954.84 493,128.37 0.16 4,998.52 MWD+IFR-AK-CAZ-SC(4) 10,874.70 72.40 250.21 5,664.03 5,508.23 -4,192.66 -5,266.43 5,933,924.19 493,043.46 0.15 5,043.47 MVVD+IFR-AK-CAZ-SC(4) 10,963.19 72.09 249.81 5,691.02 5,535.22 -4,221.47 -5,345.63 5,933,895.40 492,964.27 0.56 5,085.60 MWD+IFR-AK-CAZ-SC(4) 11,063.99 72.15 248.96 5,721.96 5,566.16 -4,255.25 -5,435.42 5,933,861.65 492,874.48 0.80 5,134.45 MWD+IFR-AK-CAZ-SC(5) 11,109.45 72.45 249.34 5,735.79 5,579.99 -4,270.66 -5,475.89 5,933,846.24 492,834.01 1.03 5,156.66 MWD+IFR-AK-CAZ-SC(5) 6/20/2017 8:51:37AM Page 5 COMPASS 5000.1 Build 74 • i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual©155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKE DM P2 Survey MD Inc Azi TVD TVDSS +N/-S +E/-WMap Map Vertical Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,159.39 72.31 250.52 5,750.90 5,595.10 -4,286.99 -5,520.60 5,933,829.92 492,789.31 2.27 5,180.51 MVUD+IFR-AK-CAZ-SC(5) 11,253.06 72.32 251.74 5,779.36 5,623.56 -4,315.86 -5,605.04 5,933,801.08 492,704.86 1.24 5,223.59 MWD+IFR-AK-CAZ-SC(5) 11,348.98 72.23 251.92 5,808.56 5,652.76 -4,344.35 -5,691.85 5,933,772.61 492,618.05 0.20 5,266.73 MWD+IFR-AK-CAZ-SC(5) 11,442.72 72.22 251.96 5,837.18 5,681.38 -4,372.02 -5,776.72 5,933,744.96 492,533.19 0.04 5,308.72 MWD+IFR-AK-CAZ-SC(5) 11,538.39 72.07 251.10 5,866.51 5,710.71 -4,400.87 -5,863.09 5,933,716.13 492,446.82 0.87 5,352.13 MWD+IFR-AK-CAZ-SC(5) 11,632.89 72.23 251.20 5,895.48 5,739.68 -4,429.93 -5,948.22 5,933,687.09 492,361.70 0.20 5,395.53 MWD+IFR-AK-CAZ-SC(5) 11,727.15 72.26 250.51 5,924.22 5,768.42 -4,459.37 -6,033.02 5,933,657.67 492,276.89 0.70 5,439.25 MIND+IFR-AK-CAZ-SC(5) 11,822.13 72.13 250.61 5,953.27 5,797.47 -4,489.47 -6,118.30 5,933,627.60 492,191.62 0.17 5,483.70 MWD+IFR-AK-CAZ-SC(5) 11,917.49 72.35 250.77 5,982.35 5,826.55 -4,519.50 -6,204.00 5,933,597.59 492,105.92 0.28 5,528.15 MWD+IFR-AK-CAZ-SC(5) 12,012.12 72.28 248.92 6,011.10 5,855.30 -4,550.56 -6,288.63 5,933,566.55 492,021.28 1.86 5,573.44 MWD+IFR-AK-CAZ-SC(5) 12,106.98 72.62 245.54 6,039.72 5,883.92 -4,585.57 -6,372.01 5,933,531.57 491,937.90 3.42 5,622.39 MVVD+IFR-AK-CAZ-SC(5) 12,201.76 73.14 241.73 6,067.63 5,911.83 -4,625.79 -6,453.15 5,933,491.37 491,856.77 3.88 5,676.09 MWD+IFR-AK-CAZSC(5) 12,296.53 73.95 237.55 6,094.48 5,938.68 -4,671.72 -6,531.55 5,933,445.46 491,778.36 4.32 5,734.94 MWD+IFR-AK-CAZ-SC(5) 12,391.16 75.12 235.47 6,119.72 5,963.92 -4,722.04 -6,607.61 5,933,395.16 491,702.31 2.45 5,797.70 MWD+IFR-AK-CAZ-SC(5) 12,485.42 75.75 230.26 6,143.44 5,987.64 -4,777.10 -6,680.31 5,933,340.12 491,629.60 5.39 5,864.55 MWD+IFR-AK-CAZ-SC(5) 12,579.88 75.83 225.23 6,166.64 6,010.84 -4,838.65 -6,748.06 5,933,278.59 491,561.84 5.16 5,936.93 MWD+IFR-AK-CAZ-SC(5) 12,674.56 75.85 221.77 6,189.81 6,034.01 -4,905.24 -6,811.24 5,933,212.03 491,498.65 3.54 6,013.47 MWD+IFR-AK-CAZ-SC(5) 12,769.60 76.26 220.55 6,212.71 6,056.91 -4,974.68 -6,871.95 5,933,142.61 491,437.94 1.32 6,092.40 MWD+IFR-AK-CAZ-SC(5) 12,863.92 77.09 218.97 6,234.45 6,078.65 -5,045.23 -6,930.64 5,933,072.08 491,379.23 1.85 6,172.08 MWD+IFR-AK-CAZ-SC(5) 12,958.66 77.70 215.53 6,255.13 6,099.33 -5,118.82 -6,986.59 5,932,998.51 491,323.27 3.60 6,254.26 MWD+IFR-AK-CAZ-SC(5) 13,052.89 78.53 212.05 6,274.54 6,118.74 -5,195.44 -7,037.86 5,932,921.91 491,271.99 3.72 6,338.62 MWD+IFR-AK-CAZ-SC(5) 13,147.41 79.06 209.09 6,292.91 6,137.11 -5,275.26 -7,085.01 5,932,842.10 491,224.82 3.12 6,425.42 MWD+IFR-AK-CAZ-SC(5) 13,241.62 80.53 205.09 6,309.61 6,153.81 -5,357.79 -7,127.22 5,932,759.59 491,182.60 4.46 6,514.02 MWD+IFR-AK-CAZ-SC(5) 13,336.63 81.54 200.96 6,324.42 6,168.62 -5,444.15 -7,163.91 5,932,673.25 491,145.89 4.42 6,605.44 MWD+IFR-AK-CAZ-SC(5) 13,431.33 83.63 196.64 6,336.65 6,180.85 -5,533.02 -7,194.16 5,932,584.40 491,115.63 5.03 6,698.21 M1IvD+IFR-AK-CAZ-SC(5) 13,525.38 83.58 192.16 6,347.13 6,191.33 -5,623.53 -7,217.40 5,932,493.90 491,092.37 4.73 6,791.38 MWD+IFR-AK-CAZ-SC(5) 13,619.60 85.20 189.07 6,356.34 6,200.54 -5,715.68 -7,234.66 5,932,401.77 491,075.09 3.69 6,885.13 MWD+IFR-AK-CAZ-SC(5) 13,674.55 86.64 188.88 6,360.25 6,204.45 -5,769.81 -7,243.21 5,932,347.64 491,066.53 2.64 6,939.93 MWD+IFR-AK-CAZ-SC(5) 13,719.35 86.99 189.25 6,362.74 6,206.94 -5,813.99 -7,250.26 5,932,303.47 491,059.47 1.14 6,984.65 INC+TREND(6) 13,728.00 87.25 189.32 6,363.18 6,207.38 -5,822.51 -7,251.66 5,932,294.95 491,058.07 3.16 6,993.29 MWD+IFR-AK-CAZ-SC(7) 7-5/8"x 9-7/8-11" 13,787.31 89.06 189.82 6,365.08 6,209.28 -5,880.96 -7,261.51 5,932,236.50 491,048.21 3.16 7,052.57 MWD+IFR-AK-CAZ-5C(7) 13,877.43 89.39 188.39 6,366.30 6,210.50 -5,969.94 -7,275.77 5,932,147.54 491,033.93 1.63 7,142.66 MWD+IFR-AK-CAZ-SC(7) 13,971.54 88.43 187.28 6,368.09 6,212.29 -6,063.15 -7,288.60 5,932,054.34 491,021.08 1.56 7,236.69 MWD+IFR-AK-CAZ-SC(7) 14,023.06 88.43 188.41 6,369.50 6,213.70 -6,114.17 -7,295.63 5,932,003.33 491,014.04 2.19 7,288.15 MWD+IFR-AK-CAZ-SC(7) 14,066.69 88.60 188.04 6,370.63 6,214.83 -6,157.33 -7,301.87 5,931,960.17 491,007.79 0.93 7,331.75 MWD+IFR-AK-CAZ-SC(7) 14,114.52 88.97 187.77 6,371.65 6,215.85 -6,204.70 -7,308.44 5,931,912.81 491,001.21 0.96 7,379.53 MWD+IFR-AK-CAZ-SC(7) 14,160.75 89.08 187.85 6,372.44 6,216.64 -6,250.49 -7,314.72 5,931,867.02 490,994.92 0.29 7,425.72 MWD+IFR-AK-CAZ-SC(7) 14,210.24 89.01 187.78 6,373.26 6,217.46 -6,299.52 -7,321.45 5,931,818.00 490,988.18 0.20 7,475.17 MWD+IFR-AK-CAZ-SC(7) 14,253.61 89.18 186.62 6,373.95 6,218.15 -6,342.54 -7,326.89 5,931,774.99 490,982.73 2.70 7,518.48 MWD+IFR-AK-CAZ-SC(7) 6/202017 8:51:37AM Page 6 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual©155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100) (ft) Survey Tool Name 14,347.94 89.39 185.63 6,375.12 6,219.32 -6,436.32 -7,336.95 5,931,681.22 490,972.65 1.07 7,612.59 MVVD+IFR-AK-CAZ-SC(7) 14,442.45 89.90 183.92 6,375.71 6,219.91 -6,530.50 -7,344.82 5,931,587.05 490,964.76 1.89 7,706.70 MVVD+IFR-AK-CAZ-SC(7) 14,483.90 90.41 183.68 6,375.60 6,219.80 -6,571.86 -7,347.57 5,931,545.70 490,962.01 1.36 7,747.91 MWD+IFR-AK-CAZ-SC(7) 14,537.38 90.62 182.48 6,375.12 6,219.32 -6,625.26 -7,350.44 5,931,492.30 490,959.12 2.28 7,800.99 MVVD+IFR-AK-CAZ-SC(7) 14,632.47 91.35 184.28 6,373.48 6,217.68 -6,720.16 -7,356.04 5,931,397.41 490,953.50 2.04 7,895.43 MWD+IFR-AK-CAZ-SC(7) 14,727.54 90.00 185.76 6,372.36 6,216.56 -6,814.86 -7,364.36 5,931,302.73 490,945.16 2.11 7,990.13 M1ND+1FR-AK-CAZ-SC(7) 14,822.97 89.63 186.35 6,372.67 6,216.87 -6,909.75 -7,374.43 5,931,207.84 490,935.07 0.73 8,085.33 MWD+IFR-AK-CAZ-SC(7) 14,917.39 89.45 188.55 6,373.43 6,217.63 -7,003.37 -7,386.67 5,931,114.24 490,922.81 2.34 8,179.65 M1ND+IFR-AK-CAZ-SC(7) 15,012.09 89.15 188.40 6,374.58 6,218.78 -7,097.03 -7,400.63 5,931,020 59 490,908.83 0.35 8,274.31 MWD+1FR-AK-CAZ-SC(7) 15,106.46 89.80 189.75 6,375.45 6,219.65 -7,190.21 -7,415.51 5,930,927.42 490,893.93 1.59 8,368.66 MWD+IFR-AK-CAZ-SC(7) 15,202.17 88.80 190.27 6,376.62 6,220.82 -7,284.45 -7,432.14 5,930,833.19 490,877.28 1.18 8,464.36 MWD+IFR-AK-CAZ-SC(7) 15,297.52 87.76 190.23 6,379.48 6,223.68 -7,378.24 -7,449.10 5,930,739.42 490,860.30 1.09 8,559.67 MWD+IFR-AK-CAZ-SC(7) 15,392.52 88.25 191.05 6,382.79 6,226.99 -7,471.55 -7,466.63 5,930,646.13 490,842.75 1.01 8,654.60 MWD+IFR-AK-CAZ-SC(7) 15,485.83 87.91 188.80 6,385.91 6,230.11 -7,563.40 -7,482.71 5,930,554.28 490,826.66 2.44 8,747.85 MWD+IFR-AK-CAZ-SC(7) 15,580.16 88.01 188.02 6,389.27 6,233.47 -7,656.66 -7,496.49 5,930,461.04 490,812.85 0.83 8,842.09 MWD+IFR-AK-CAZ-SC(7) 15,630.76 88.49 188.56 6,390.82 6,235.02 -7,706.70 -7,503.79 5,930,411.00 490,805.55 1.43 8,892.64 MWD+IFR-AK-CAZ-SC(7) 15,675.24 88.63 188.37 6,391.93 6,236.13 -7,750.69 -7,510.33 5,930,367.02 490,798.99 0.53 8,937.09 MWD+IFR-AK-CAZ-SC(7) 15,770.26 88.66 188.06 6,394.18 6,238.38 -7,844.70 -7,523.90 5,930,273.02 490,785.40 0.33 9,032.04 MWD+IFR-AK-CAZ-SC(7) 15,864.74 89.73 187.35 6,395.51 6,239.71 -7,938.32 -7,536.57 5,930,179.41 490,772.71 1.36 9,126.43 MWD+IFR-AK-CAZ-SC(7) 15,959.55 90.72 187.78 6,395.14 6,239.34 -8,032.30 -7,549.05 5,930,085.44 490,760.21 1.14 9,221.15 MVVD+IFR-AK-CAZ-SC(7) 16,054.41 91.17 187.46 6,393.57 6,237.77 -8,126.31 -7,561.63 5,929,991.45 490,747.62 0.58 9,315.92 MWD+IFR-AK-CAZ-SC(7) 16,149.67 90.55 188.15 6,392.14 6,236.34 -8,220.68 -7,574.56 5,929,897.09 490,734.66 0.97 9,411.10 MWD+1FR-AK-CAZ-SC(7) 16,244.29 90.21 187.72 6,391.51 6,235.71 -8,314.39 -7,587.63 5,929,803.39 490,721.58 0.58 9,505.65 MWD+IFR-AK-CAZ-SC(7) 16,338.98 90.24 189.11 6,391.14 6,235.34 -8,408.06 -7,601.48 5,929,709.74 490,707.70 1.47 9,600.30 MWD+IFR-AK-CAZ-SC(7) 16,432.99 90.17 190.02 6,390.81 6,235.01 -8,500.76 -7,617.10 5,929,617.05 490,692.06 0.97 9,694.31 MVVD+IFR-AK-CAZ-SC(7) 16,527.54 89.80 190.69 6,390.83 6,235.03 -8,593.77 -7,634.10 5,929,524.05 490,675.05 0.81 9,788.86 MWD+IFR-AK-CAZ-SC(7) 16,620.84 89.25 192.96 6,391.60 6,235.80 -8,685.08 -7,653.22 5,929,432.76 490,655.91 2.50 9,882.10 MWD+IFR-AK-CAZ-SC(7) 16,716.08 87.77 193.51 6,394.08 6,238.28 -8,777.75 -7,675.01 5,929,340.09 490,634.10 1.66 9,977.15 MWD+IFR-AK-CAZ-SC(7) 16,811.25 86.01 195.43 6,399.24 6,243.44 -8,869.76 -7,698.75 5,929,248.10 490,610.34 2.73 10,071.89 MWD+IFR-AK-CAZ-SC(7) 16,906.30 86.16 194.67 6,405.73 6,249.93 -8,961.34 -7,723.38 5,929,156.54 490,585.70 0.81 10,166.34 MWD+IFR-AK-CAZ-SC(7) 17,000.16 85.89 194.34 6,412.24 6,256.44 -9,051.99 -7,746.83 5,929,065.90 490,562.23 0.45 10,259.69 MWD+IFR-AK-CAZ-SC(7) 17,095.53 89.33 192.62 6,416.22 6,260.42 -9,144.63 -7,769.03 5,928,973.27 490,540.00 4.03 10,354.78 MWD+IFR-AK-CAZ-SC(7) 17,189.37 90.19 191.02 6,416.61 6,260.81 -9,236.48 -7,788.26 5,928,881.44 490,520.76 1.94 10,448.57 MWD+1FR-AK-CAZ-SC(7) 17,283.34 88.48 189.27 6,417.70 6,261.90 -9,328.97 -7,804.81 5,928,788.97 490,504.19 2.60 10,542.53 MWD+IFR-AK-CAZ-SC(7) 17,378.86 89.01 187.65 6,419.79 6,263.99 -9,423.42 -7,818.85 5,928,694.53 490,490.13 1.78 10,637.99 MWD+IFR-AK-CAZ-SC(7) 17,473.79 89.28 187.25 6,421.21 6,265.41 -9,517.54 -7,831.16 5,928,600.42 490,477.80 0.51 10,732.81 MWD+IFR-AK-CAZ-SC(7) 17,568.63 89.04 186.98 6,422.60 6,266.80 -9,611.64 -7,842.91 5,928,506.33 490,466.03 0.38 10,827.52 MWD+IFR-AK-CAZ-SC(7) 17,663.28 88.70 186.63 6,424.47 6,268.67 -9,705.60 -7,854.12 5,928,412.38 490,454.80 0.52 10,922.01 MWD+IFR-AK-CAZ-SC(7) 17,759.29 87.93 186.96 6,427.29 6,271.49 -9,800.90 -7,865.47 5,928,317.10 490,443.43 0.87 11,017.82 MWD+IFR-AK-CAZ-SC(7) 17,854.14 88.49 187.52 6,430.25 6,274.45 -9,894.94 -7,877.42 5,928,223.06 490,431.46 0.83 11,112.52 MWD+IFR-AK-CAZ-SC(7) 6/20/2017 8:51:37AM Page 7 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 17,948.57 88.67 189.58 6,432.59 6,276.79 -9,988.29 -7,891.46 5,928,129.73 490,417.40 2.19 11,206.88 MVD+1FR-AK-CAZ-SC(7) 18,043.69 89.11 191.36 6,434.44 6,278.64 -10,081.80 -7,908.74 5,928,036.23 490,400.10 1.93 11,301.98 MWD+IFR-AK-CAZ-SC(7) 18,138.00 88.70 190.75 6,436.24 6,280.44 -10,174.35 -7,926.82 5,927,943.70 490,382.00 0.78 11,396.25 MWD+IFR-AK-CAZ-SC(7) 18,233.38 89.25 190.30 6,437.94 6,282.14 -10,268.11 -7,944.24 5,927,849.95 490,364.56 0.75 11,491.61 MW1J+IFR-AK-CAZ-SC(7) 18,328.13 90.24 190.90 6,438.37 6,282.57 -10,361.24 -7,961.67 5,927,756.83 490,347.12 1.22 11,586.35 MVVD+IFR-AK-CAZ-SC(7) 18,422.06 90.28 190.96 6,437.94 6,282.14 -10,453.46 -7,979.48 5,927,664.62 490,329.29 0.08 11,680.27 MWD+IFR-AK-CAZ-SC(7) 18,516.78 91.31 190.78 6,436.63 6,280.83 -10,546.47 -7,997.34 5,927,571.63 490,311.41 1.10 11,774.97 MVVD+IFR-AK-CAZ-SC(7) 18,611.64 91.17 191.53 6,434.57 6,278.77 -10,639.52 -8,015.69 5,927,478.59 490,293.04 0.80 11,869.79 MWD+IFR-AK-CAZ-SC(7) 18,706.70 91.07 191.84 6,432.71 6,276.91 -10,732.59 -8,034.93 5,927,385.54 490,273.77 0.34 11,964.79 MWD+IFR-AK-CAZ-SC(7) 18,801.23 91.17 191.40 6,430.87 6,275.07 -10,825.16 -8,053.97 5,927,292.97 490,254.72 0.48 12,059.26 MWD+IFR-AK-CAZ-SC(7) 18,896.08 90.62 191.59 6,429.39 6,273.59 -10,918.10 -8,072.87 5,927,200.05 490,235.80 0.61 12,154.07 MVVD+IFR-AK-CAZ-SC(7) 18,991.01 90.62 191.01 6,428.36 6,272.56 -11,011.18 -8,091.47 5,927,106.98 490,217.18 0.61 12,248.97 MWD+IFR-AK-CAZ-SC(7) 19,085.09 90.07 190.57 6,427.79 6,271.99 -11,103.60 -8,109.08 5,927,014.58 490,199.55 0.75 12,343.04 MWD+IFR-AK-CAZ-SC(7) 19,179.20 90.35 189.66 6,427.45 6,271.65 -11,196.24 -8,125.61 5,926,921.95 490,183.00 1.01 12,437.14 MWD+IFR-AK-CAZ-SC(7) 19,274.07 89.39 188.89 6,427.66 6,271.86 -11,289.87 -8,140.90 5,926,828.33 490,167.69 1.30 12,532.01 MWD+IFR-AK-CAZ-SC(7) 19,369.80 89.42 187.56 6,428.66 6,272.86 -11,384.61 -8,154.59 5,926,733.61 490,153.98 1.39 12,627.68 MWD+IFR-AK-CAZ-SC(7) 19,463.30 89.73 186.26 6,429.35 6,273.55 -11,477.43 -8,165.84 5,926,640.80 490,142.71 1.43 12,721.04 MWD+IFR-AK-CAZ-SC(7) 19,558.56 90.64 185.36 6,429.04 6,273.24 -11,572.19 -8,175.49 5,926,546.05 490,133.05 1.34 12,816.04 MWD+IFR-AK-CAZ-SC(7) 19,652.88 88.61 185.12 6,429.66 6,273.86 -11,666.11 -8,184.10 5,926,452.14 490,124.41 2.17 12,910.03 MWD+IFR-AK-CAZ-SC(7) 19,746.98 88.70 185.83 6,431.87 6,276.07 -11,759.76 -8,193.07 5,926,358.51 490,115.42 0.76 13,003.81 MVD+IFR-AK-CAZ-SC(7) 19,841.59 88.39 187.18 6,434.27 6,278.47 -11,853.72 -8,203.79 5,926,264.55 490,104.68 1.46 13,098.21 MWD+IFR-AK-CAZ-SC(7) 19,936.78 88.77 189.02 6,436.63 6,280.83 -11,947.93 -8,217.20 5,926,170.35 490,091.26 1.97 13,193.32 MWD+IFR-AK-CAZ-SC(7) 20,031.06 89.32 192.19 6,438.20 6,282.40 -12,040.58 -8,234.54 5,926,077.72 490,073.89 3.41 13,287.57 MWD+IFR-AK-CAZ-SC(7) 20,126.97 89.18 195.03 6,439.46 6,283.66 -12,133.78 -8,257.11 5,925,984.54 490,051.31 2.96 13,383.27 MVVD+IFR-AK-CAZ-SC(7) 20,221.52 89.32 194.36 6,440.70 6,284.90 -12,225.22 -8,281.09 5,925,893.10 490,027.31 0.72 13,477.49 MWD+IFR-AK-CAZ-SC(7) 20,316.23 87.93 192.33 6,442.97 6,287.17 -12,317.34 -8,302.94 5,925,801.00 490,005.44 2.60 13,572.01 MWD+IFR-AK-CAZ-SC(7) 20,411.32 88.15 190.97 6,446.22 6,290.42 -12,410.42 -8,322.13 5,925,707.94 489,986.23 1.45 13,667.00 MWD+IFR-AK-CAZ-SC(7) 20,505.38 89.35 189.21 6,448.27 6,292.47 -12,503.00 -8,338.61 5,925,615.37 489,969.73 2.26 13,761.03 MVVD+IFR-AK-CAZ-SC(7) 20,601.13 91.19 185.89 6,447.82 6,292.02 -12,597.90 -8,351.19 5,925,520.48 489,957.14 3.96 13,856.68 MWD+IFR-AK-CAZ-SC(7) 20,695.81 90.28 185.17 6,446.61 6,290.81 -12,692.13 -8,360.31 5,925,426.27 489,947.99 1.23 13,951.06 MWD+IFR-AK-CAZ-SC(7) 20,790.41 89.90 184.11 6,446.46 6,290.66 -12,786.42 -8,367.96 5,925,331.99 489,940.32 1.19 14,045.24 MWD+IFR-AK-CAZ-SC(7) 20,883.89 89.80 185.22 6,446.70 6,290.90 -12,879.58 -8,375.56 5,925,238.83 489,932.70 1.19 14,138.32 MWD+IFR-AK-CAZ-SC(7) 20,979.16 89.76 186.13 6,447.07 6,291.27 -12,974.39 -8,384.98 5,925,144.04 489,923.26 0.96 14,233.31 MWD+IFR-AK-CAZ-SC(7) 21,074.14 89.21 188.12 6,447.92 6,292.12 -13,068.62 -8,396.76 5,925,049.82 489,911.46 2.17 14,328.16 MW3+IFR-AK-CAZ-SC(7) 21,168.19 89.69 187.93 6,448.83 6,293.03 -13,161.75 -8,409.89 5,924,956.70 489,898.31 0.55 14,422.15 MWD+IFR-AK-CAZ-SC(7) 21,263.09 89.66 189.39 6,449.36 6,293.56 -13,255.56 -8,424.18 5,924,862.90 489,884.00 1.54 14,517.02 MWD+IFR-AK-CAZ-SC(7) 21,357.63 89.93 189.80 6,449.70 6,293.90 -13,348.78 -8,439.94 5,924,769.70 489,868.22 0.52 14,611.56 MWD+IFR-AK-CAZ-SC(7) 21,452.75 89.32 191.00 6,450.32 6,294.52 -13,442.33 -8,457.11 5,924,676.16 489,851.03 1.42 14,706.67 MW1+IFR-AK-CAZ-SC(7) 21,547.33 88.60 190.36 6,452.04 6,296.24 -13,535.26 -8,474.64 5,924,583.25 489,833.49 1.02 14,801.23 MWD+IFR-AK-CAZ-SC(7) 21,640.81 88.84 188.51 6,454.13 6,298.33 -13,627.45 -8,489.95 5,924,491.07 489,818.15 2.00 14,894.68 MWD+IFR-AK-CAZ-SC(7) 620/2017 8:51:37AM Page 8 COMPASS 5000.1 Build 74 4111 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 21,735.22 88.94 188.06 6,455.96 6,300.16 -13,720.85 -8,503.56 5,924,397.68 489,804.53 0.49 14,989.03 MWD+IFR-AK-CAZ-SC(7) 21,830.75 88.94 187.71 6,457.73 6,301.93 -13,815.46 -8,516.66 5,924,303.08 489,791.41 0.37 15,084.48 MWD+IFR-AK-CAZ-SC(7) 21,924.89 88.08 186.56 6,460.17 6,304.37 -13,908.84 -8,528.35 5,924,209.71 489,779.70 1.53 15,178.47 MWD+IFR-AK-CAZ-SC(7) 22,021.01 87.57 187.90 6,463.82 6,308.02 -14,004.12 -8,540.44 5,924,114.44 489,767.59 1.49 15,274.40 MWD+IFR-AK-CAZ-SC(7) 22,116.35 87.89 187.65 6,467.60 6,311.80 -14,098.51 -8,553.32 5,924,020.06 489,754.68 0.43 15,369.59 MWD+IFR-AK-CAZ-SC(7) 22,210.68 91.25 186.66 6,468.31 6,312.51 -14,192.09 -8,565.07 5,923,926.50 489,742.92 3.71 15,463.79 MWD+IFR-AK-CAZ-SC(7) 22,304.87 92.37 187.06 6,465.33 6,309.53 -14,285.56 -8,576.31 5,923,833.04 489,731.65 1.26 15,557.79 MWD+IFR-AK-CAZ-SC(7) 22,400.27 92.49 186.41 6,461.29 6,305.49 -14,380.21 -8,587.49 5,923,738.40 489,720.45 0.69 15,652.95 MWD+IFR-AK-CAZ-SC(7) 22,495.22 90.69 186.64 6,458.65 6,302.85 -14,474.51 -8,598.28 5,923,644.12 489,709.65 1.91 15,747.68 MWD+IFR-AK-CAZ-SC(7) 22,589.97 88.65 185.53 6,459.20 6,303.40 -14,568.72 -8,608.32 5,923,549.92 489,699.58 2.45 15,842.21 MWD+IFR-AK-CAZ-SC(7) 22,684.85 88.41 186.85 6,461.63 6,305.83 -14,663.01 -8,618.55 5,923,455.64 489,689.34 1.41 15,936.84 MWD+IFR-AK-CAZ-SC(7) 22,779.13 89.49 187.94 6,463.36 6,307.56 -14,756.49 -8,630.68 5,923,362.17 489,677.19 1.63 16,031.01 MWD+IFR-AK-CAZ-SC(7) 22,873.99 89.39 188.94 6,464.29 6,308.49 -14,850.32 -8,644.60 5,923,268.36 489,663.24 1.06 16,125.83 MWD+IFR-AK-CAZ-SC(7) 22,968.69 90.04 191.10 6,464.76 6,308.96 -14,943.56 -8,661.08 5,923,175.12 489,646.75 2.38 16,220.52 MWD+IFR-AK-CAZ-SC(7) 23,061.70 89.04 192.10 6,465.50 6,309.70 -15,034.67 -8,679.78 5,923,084.03 489,628.03 1.52 16,313.49 MWD+IFR-AK-CAZ-SC(7) 23,119 00 87.70 192.29 6,467.13 6,311.33 -15,090.65 -8,691.88 5,923,028.06 489,615.92 2.35 16,370.72 MWD+IFR-AK-CAZ-SC(7) 4 1/2"x 6-3/4" 23,156.52 86.83 192.41 6,468.92 6,313.12 -15,127.26 -8,699.89 5,922,991.45 489,607.90 2.35 16,408.17 MWD+1FR-AK-CAZ-SC(7) 23,252.79 86.36 192.06 6,474.64 6,318.84 -15,221.18 -8,720.26 5,922,897.55 489,587.51 0.61 16,504.19 MWD+IFR-AK-CAZ-SC(7) 23,347.54 86.43 192.64 6,480.60 6,324.80 -15,313.55 -8,740.48 5,922,805.19 489,567.27 0.62 16,598.67 MWD+IFR-AK-CAZ-SC(7) 23,437.58 87.04 192.17 6,485.72 6,329.92 -15,401.35 -8,759.79 5,922,717.41 489,547.94 0.85 16,688.49 MWD+IFR-AK-CAZ-SC(7) 23,530.32 88.94 194.04 6,488.98 6,333.18 -15,491.61 -8,780.81 5,922,627.16 489,526.91 2.87 16,781.03 MWD+IFR-AK-CAZ-5C(7) 23,622.19 87.84 188.38 6,491.56 6,335.76 -15,581.65 -8,798.65 5,922,537.13 489,509.04 6.27 16,872.80 MVVD+IFR-AK-CAZ-SC(7) 23,714.94 87.67 185.32 6,495.19 6,339.39 -15,673.66 -8,809.71 5,922,445.13 489,497.97 3.30 16,965.33 MVVD+IFR-AK-CAZ-SC(7) 23,805.93 87.50 184.16 6,499.03 6,343.23 -15,764.25 -8,817.22 5,922,354.55 489,490.44 1.29 17,055.85 MWD+IFR-AK-CAZ-SC(7) 23,897.75 87.41 184.54 6,503.11 6,347.31 -15,855.72 -8,824.18 5,922,263.09 489,483.46 0.42 17,147.14 MWD+IFR-AK-CAZ-SC(7) 23,990.16 89.04 184.10 6,505.97 6,350.17 -15,947.82 -8,831.13 5,922,171.01 489,476.49 1.83 17,239.05 MWD+IFR-AK-CAZ-SC(7) 24,081.84 87.13 186.66 6,509.03 6,353.23 -16,039.03 -8,839.72 5,922,079.80 489,467.88 3.48 17,330.37 M1M3+IFR-AK-CAZ-SC(7) 24,173.74 88.62 191.23 6,512.44 6,356.64 -16,129.73 -8,854.00 5,921,989.12 489,453.58 5.23 17,422.16 MWD+IFR-AK-CAZ-SC(7) 24,267.11 92.51 188.84 6,511.52 6,355.72 -16,221.64 -8,870.26 5,921,897.22 489,437.30 4.89 17,515.50 MVVD+IFR-AK-CAZ-SC(7) 24,358.51 95.56 187.93 6,505.09 6,349.29 -16,311.83 -8,883.56 5,921,807.05 489,423.98 3.48 17,606.63 MWD+1FR-AK-CAZ-SC(7) 24,449.69 95.33 188.81 6,496.44 6,340.64 -16,401.63 -8,896.77 5,921,717.26 489,410.75 0.99 17,697.36 MVVD+IFR-AK-CAZ-SC(7) 24,540.67 95.42 189.05 6,487.91 6,332.11 -16,491.11 -8,910.83 5,921,627.79 489,396.67 0.28 17,787.92 MWD+IFR-AK-CAZ-SC(7) 24,632.74 92.45 189.90 6,481.60 6,325.80 -16,581.70 -8,925.95 5,921,537.21 489,381.53 3.35 17,879.76 MWD+IFR-AK-CAZ-SC(7) 24,724.59 91.90 189.85 6,478.11 6,322.31 -16,672.12 -8,941.69 5,921,446.80 489,365.77 0.60 17,971.54 MWD+IFR-AK-CAZ-SC(7) 24,816.48 94.04 189.53 6,473.35 6,317.55 -16,762.57 -8,957.14 5,921,356.36 489,350.31 2.35 18,063.30 MWD+IFR-AK-CAZ-SC(7) 24,909.38 93.39 190.38 6,467.33 6,311.53 -16,853.88 -8,973.17 5,921,265.07 489,334.27 1.15 18,156.01 MWD+IFR-AK-CAZ-SC(7) 25,002.17 93.94 190.61 6,461.40 6,305.60 -16,944.93 -8,990.03 5,921,174.03 489,317.38 0.64 18,248.60 M1ND+IFR-AK-CAZ-SC(7) 25,094.80 91.46 189.01 6,457.04 6,301.24 -17,036.10 -9,005.79 5,921,082.88 489,301.60 3.19 18,341.12 MWD+IFR-AK-CAZ-SC(7) 25,187.68 90.99 189.69 6,455.05 6,299.25 -17,127.72 -9,020.88 5,920,991.27 489,286.49 0.89 18,433.97 M1.ND+IFR-AK-CAZ-SC(7) 6/20/2017 8.'51:37AM Page 9 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVOSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft); (ft) (ft) (°1t00') (ft) Survey Tool Name 25,277.53 91.82 190.01 6,452.85 6,297.05 -17,216.22 -9,036.25 5,920,902.78 489,271.11 0.99 18,523.79 MWD+IFR-AK-CAZ SC(7) 25,369.47 91.62 190.71 6,450.09 6,294.29 -17,306.62 -9,052.77 5,920,812.39 489,254.56 0.79 18,615.69 MWD+IFR-AK-CAZ-SC(7) 25,465.03 91.39 189.64 6,447.58 6,291 78 -17,400.64 -9,069.65 5,920,718.38 489,237.67 1.14 18,711.21 MWD+IFR-AK-CAZ-SC(7) 25,534.53 92.87 192.88 6,444.99 6,289.19 -17,468.74 -9,083.21 5,920,650.29 489,224.10 5.12 18,780.64 MWD+IFR-AK-CAZ-SC(7) 25,598.00 92.87 192.88 6,441.82 6,286.02 -17,530.54 -9,097.34 5,920,588.50 489,209.96 0.00 18,843.95 PROJECTED to TD 6/20/2017 8 51:37AM Page 10 COMPASS 5000.1 Build 74 Cement Detail Report &Wells 2K-32 C onocc Phillips String: Conductor Job: DRILLING ORIGINAL,4/28/2017 02:00 Cement Details • Description Cementing Start Date Cementing End Date Wellbore Name Conductor 4/13/2017 18:00 4/13/2017 19:00 2K-32 Comment Conductor hole drilled to 40'with a 24"bit. Hole was wet.Drove 20"conductor w/3/4"wall pipe to 140' below pad level. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor 43.0 79.0 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 Cement Fluids&Additives Fluid' Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Portland 43.0 79.0 6 Yield(ft'/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: 7/12/2017 0 Cement Detail Report 2K-32 carp - t4.IGxks String: Surface Casing Cement Job: DRILLING ORIGINAL,4/28/2017 02:00 Gement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 5/3/2017 02:34 5/3/2017 06:41 2K-32 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement Cement 10-3/4"Surface 40.0 3,480.4 Yes 200.8 Yes Yes casing Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 6 457.0 1,000.0 Yes 11.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 3,364.0 Drill Bit 3,488.0 9 7/8 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW 100 40.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.34 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push!! 75.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement-- 40.0 2,938.0 1,455 LiteCrete 495.2 LiteCrete Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.83 11.00 5.92 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D185 Dispersant 0.08 gal/sx Additive Type Concentration Conc Unit label D177 Retarder 0.03 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement-- 2,938.0 3,488.0 211 LiteCrete 62.0 LiteCrete Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.65 5.74 12.00 3.75 Additives Additive Type Concentration Conc Unit label D046 0.2 %BWOC Additive Type Concentration Concgal/sx Unit label D177 0.03 Additive Type Concentration Conc Unit label D185 0.1 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) Page 1/2 Report Printed: 7/12/2017 • • Cement Detail Report 0 2K-32 comsofititups AI,^4, String: Surface Casing Cement Job: DRILLING ORIGINAL,4/28/2017 02:00 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? Surface Casing Cement top off 100'in the 43.0 139.0 Yes 8.0 No No top off conductor 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) 1 1 1 54.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) 15.8 ppg top out 43.0 139.0 145 G 30.0 cement Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.13 15.80 5.37 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.05 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam %BWOC /oBWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D255 Fluid loss 0.4 %BWOC Page 2/2 Report Printed: 7/12/2017 • • 04, Cement Detail Report a 2K-32 conn ' hips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,4/28/2017 02:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 5/20/2017 00:00 5/21/2017 22:00 2K-32 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 12,176.0 13,738.0 No Yes Yes Cement Q Pump'nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 5 778.0 1,300.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement 1st stage as follows: batch up 12.5 ppg Mud Push II, pump MP II @ 4.5 bpm=650 psi.Shut down and drop bypass plug as per PESI. Batch up 15.8 ppg cement,Pump 141.1 bbls of 15.8 ppg cement @ 5 bpm=600 psi ICP, 185 psi FCP.Drop bottom plug as per PESI,kick plug out with 10 bbls of water and swap to the rig. Displace cement with rig pumps @ 5 bpm=275 psi ICP,3 bpm-778 psi FCP.Observed pump pressure begin to increase @ 4800 stokes from 262 psi to bump @ 6079 strokes=778 psi,good lift pressure observed.After bumping the plug @ 6079 strokes,pressure up to 1200 psi and hold for 5 min, bleed off and check floats,good.Cemented 1st with no returns, 100%loses.Lost 810 bbls of 10.4 ppg LSND mud while cementing. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MPH 11,502.0 12,176.0 39.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 12,176.0 13,738.0 688 G 141.1 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.11 15.80 132.0 0.00 Additives Additive Type Concentration Conc Unit label CemNet LCM Additive 1.5 lbs/bbl Type Concentration Conc Unit label Antifoam Additive D046 0.2 %BWOC Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Retarder D177 Additive 0.03 gal/sx Type Concentration Conc Unit label Liquid Fluid Loss D255 0.4 %BWOC Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 10,100.0 10,981.0 No Yes No Cement Q Pump'nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 4 1,150.0 3,000.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM, Line up SLB and fill lines with water. Pressure test lines to 4000 psi-good test.Cement 2nd stage as follows:batch up 12.5 ppg Mud Push II, pump 40.1 bbls MP II @ 3.3 bpm= 1140 psi. Batch up 15.8 ppg cement,cement wet at 18:19 hrs,Pump 78.3 bbls of 15.8 ppg cement @ 4 bpm=1089 psi ICP,800 psi FCP. Drop closing plug out of cement head and kick out with 10 bbls of water-observe good indication of plug dropping.Swap to the rig. Displace cement with 10.45ppg LSND using rig mud pump#1 @ 4 bpm=753 psi ICP,at 3730 strokes w/4 bpm-1056 psi(mudpush turning corner),at 4128 strokes w/4 bpm-1075 psi(cement turning corner),at 3 bpm-1150 psi FCP.After bumping the plug @ 4952 strokes(61 strokes past calculated),pressure up to 2850 psi at 3 bpm and kill pump per PESI. No pressure shift observed to indicate stage tool closed. Increase pressure to 3000 psi and hold for 5 min. Bleed off pressure to 0 psi,5.0 bbls bled back,and shut in. No pressure buildup observed. Pressure up at 4 bpm to 2350 psi per PESI,shut in and hold for 5 min. Bleed off pressure,3.6 bbls bled back. Remove cement hose and monitor flowback through cement head at surface-initially observed small amount of aired-up mud flowing back,tapering off to static-stage collar closed.Cemented 2nd stage with no returns, 100%loses. 2nd Stage Cement in place @ 21:23 hrs Page 1/2 • Report Printed: 7/12/2017 0 • Cement Detail Report Oil 2K-32 conamehurips irr Rd:,kro String: Intermediate Casing Cement Job: DRILLING ORIGINAL,4/28/2017 02:00 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MPI I 9,444.0 10,100.0 40.1 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,100.0 10,981.0 688 G 78.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.11 15.80 116.0 8.03 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 Retarder D177 0.03 gal/sx Additive Type Concentration 'Conc Unit label Liquid Fluid Loss D255 0.4 %BWOC Page 2/2 Report Printed: 7/12/2017 0 • H—� � -0 0 0 D H O 3 y j cz n to O — O O Z ^ ^J w W � NNw 1- N D 33 ? 3cnm23TO � v � cnoo C rmT 3 et o .. _. j W _ z •3 z S O O w' 7 rr+ N J t0 0 _, V N A o D + D O. a- Ol Jv N d 3 3 u xi m 8 pc m Ce n CD d O 3 0 'O N N N N N N N N UI CO CO 3 0~0 0 7 + * o O O o o O o 0 O o 0 o 0 n y 0 0 0 0 0 0 .. L O C O N) N 0 N N N N 0 0 N N 3 • N 0 CD W CO 0 CO 0 W (4 CO (O > V S- 3 43 N N N N N N N N N N NJ _ N 0 N N W 0 0 0 W V 0 O) A N Co N V V V N A 4* UJ M V 4.f 0) 0 A N A N N CO �' yr 0.) Cil V 0 V A W V N V f0 - A D n o 0 0 0 0 0 0 0 0 0 o m r"r O o 0 o O O O O O 0 0 Xi 3 La X Drn oCO n n D 00000 v v v v v v z Z <— 3 3 3 0 0 0 0 0 o <' o�0 coVcoVN fn fn (n to L !n v m y' 0 cMD o m m 0 0 0 0 0 0 0 0 0 0 0 !! 0 0 0 o 0 0 o 0 0 0 0 Ol ^ mow 3 0 A W N 0 N) COa " ~' Co - � x73 n - m O W . 3 o °: CCCCCCCCCCC O C T T T 71 'U T T T T T -0 T titmt. D D D D D D D D D D D r CCCCCCCCCCC < < < < < < < < < < < m m MMMM MMMMMM XXIX P323 X173 ;3737177id4.....,644..1v m r r r r r r r r r r r -1 m .e ti {y m Qa SV Z '. b d O 0 O � rt D Ca MI ro rot M R. " r' 2 too \ , z F oo 4)C) co O 73 D O o 4,,oo O 0 cn mcn 2O cn 0 O q * cnO O "� , me O T T T N y f) ^ p CD D a r n w 0, 0 C v < _, m A n O 3 ^. rD v r -moi 0 ,, a o —0 (( 3 O co 3 04 rD r-r 7 rD rD n — co r+ro rD 3 rD T T '17 T m m T T T T T v to O• 3 0 rD a n ZZZZZZZZZZZ (10 _., 3 - r-rrrrrrrrrrr -� — a CD 7N T T T T T T T T T T T m m m m m m m m m m m EP v OA r r r r r r r r r r r m 7 00000 ODOCJOCI n `" a rD v O v ,,.* N C -i 3 O 0 D N n rD Z O 0l a n N N N N > Z r3D 3 n - f!1 A W 0 0 0 ao V N O ;n m O-' 0) 3 7 � L L L L L L. L L L L c- -{ N r+ a R - C C C C C C C C C C C 0 -1 L,-.7 o a 3- ,t 3 3 3 3 3 3 3 3 3 3 3 D r -, n rD 3 t _ "+ r co .n -°v 3 fD ,•-•• V V V V V -I V V V V V �„ D 0 > v. < a, o v v C - -0 a 3 ,- m fl < 5• n ,-+ n 0 ,-r 3 7 0 n •• �� m 3 m LA p ; 0 n N CU a -,, a N Wer D, ..< n� , 00 m p E. S O CT rD a p L7 111 CO `9 C 3 o s m-LLJ m CEJ 3 m• o n o c' o eill CD TV • a 21 704. "/ RECEIVE 2 8 3 2 5 Schlumberger JUN 29 2017 V Transmittal#: 28JUN17-SPO2 Drilling & MebfrOCf Product Delivery DATA LOGGED 1 /3/201-1 M.K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well Name: 2K-32 Date Dispatched: 28-Jun-17 Service Order#: 17AKA0005 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: 4 Contents on CD 6-Jun-17 VISION*Service 2" MD x x 2"TVD x x 5"MD x x 5"TVD x x Digital Data N/A Contents on CD LAS/DLIS Data x Surveys 2 Contents on CD Nad27 x x Nad83 x x CD 1 Contents on CD Data: DLIS/LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a�conocophillips.com AlaskaPTSPrintCenter(a�slb.com Attn:Tom Osterkamp Attn:Stephanie Pacillo Received By: m:4464744) 45..e,,teett • 21 7042 28325 RECEIVED JUN 29 2017 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 2K Pad 2K-32 2K-32 NAD 27 Definitive Survey Report 20 June, 2017 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 2K-32 Well Position +N/-S 0.00 usft Northing: 5,938,115.25 usft Latitude: 70°14'31.749 N +E/-W 0.00 usft Easting: 498,310.31 usft Longitude: 150°0'49.126 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 116.70 usft Wellbore 2K-32 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2016 5/13/2017 17.50 80.86 57,529 Design 2K-32 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) (0) 39.10 0.00 0.00 190.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.95 1,369.87 2K-32 Srvy 1-SLB_GWD70(2K-32) GYD-GC-SS Gyrodata gyro single shots 4/30/2017 8:23: 1,465.51 3,405.64 2K-32 Srvy 2-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/1/2017 8:26:0 3,490.68 3,490.68 2K-32 Srvy 3-SLB_MWD-INC-Filler(2K INC+TREND Inclinometer+known azi trend 5/5/2017 2:32:0 3,537.56 10,963.19 2K-32 Srvy 4-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/4/2017 2:51:0 11,063.99 13,674.55 2K-32 Srvy 5-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/14/2017 1:25: 13,719.35 13,719.35 2K-32 Srvy 6-SLB_MWD-INC-Filler(2K INC+TREND Inclinometer+known azi trend 5/24/2017 10:25 13,787.31 25,534.53 2K-32 Srvy 7-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/24/2017 10:28 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -116.70 0.00 0.00 5,938,115.25 498,310.31 0.00 0.00 UNDEFINED 127.95 0.21 42.66 127.95 -27.85 0.12 0.11 5,938,115.37 498,310.42 0.24 -0.14 GYD-GC-SS(1) 147.32 0.56 32.70 147.32 -8.48 0.23 0.19 5,938,115.48 498,310.50 1.83 -0.25 GYD-GC-SS(1) 183.06 0.76 56.16 183.06 27.26 0.50 0.48 5,938,115.75 498,310.79 0.93 -0.58 GYD-GC-SS(1) 243.18 1.49 87.81 243.17 87.37 0.76 1.59 5,938,116.01 498,311.90 1.55 -1.02 GYD-GC-SS(1) 273.18 1.86 91.16 273.15 117.35 0.76 2.47 5,938,116.01 498,312.78 1.28 -1.18 GYD-GC-SS(1) 303.35 2.20 98.41 303.30 147.50 0.67 3.53 5,938,115.92 498,313.84 1.41 -1.27 GYD-GC-SS(1) 335.22 2.93 103.77 335.14 179.34 0.38 4.92 5,938,115.63 498,315.23 2.41 -1.23 GYD-GC-SS(1) 367.71 3.80 111.21 367.58 211.78 -0.20 6.73 5,938,115.04 498,317.04 2.99 -0.97 GYD-GC-SS(1) 6/20/2017 8:51:37AM Page 2 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 398.79 4.69 115.57 398.57 242.77 -1.12 8.84 5,938,114.12 498,319.15 3.04 -0.43 GYD-GC-SS(1) 431.00 5.09 120.53 430.66 274.86 -2.42 11.26 5,938,112.83 498,321.57 1.81 0.43 GYD-GC-SS(1) 522.22 5.83 124.77 521.47 365.67 -7.12 18.55 5,938,108.13 498,328.86 0.92 3.79 GYD-GC-SS(1). 616.15 6.21 135.78 614.88 459.08 -13.48 26.01 5,938,101.77 498,336.32 1.29 8.76 GYD-GC-SS(1) 710.84 5.43 136.59 709.08 553.28 -20.40 32.66 5,938,094.84 498,342.97 0.83 14.42 GYD-GC-SS(1) 803.24 8.40 128.70 800.80 645.00 -27.80 40.94 5,938,087.44 498,351.24 3.37 20.27 GYD-GC-SS(1) 898.89 8.84 127.91 895.37 739.57 -36.69 52.19 5,938,078.56 498,362.49 0.48 27.07 GYD-GC-SS(1) 993.31 10.03 129.51 988.52 832.72 -46.37 64.26 5,938,068.87 498,374.55 1.29 34.51 GYD-GC-SS(1) 1,086.49 12.71 130.99 1,079.86 924.06 -58.26 78.26 5,938,056.98 498,388.55 2.89 43.79 GYD-GC-SS(1) 1,182.83 15.50 130.74 1,173.28 1,017.48 -73.62 96.01 5,938,041.62 498,406.30 2.90 55.83 GYD-GC-SS(1) 1,276.11 18.31 130.08 1,262.52 1,106.72 -91.19 116.67 5,938,024.04 498,426.95 3.02 69.54 GYD-GC-SS(1) 1,369.87 22.04 127.89 1,350.52 1,194.72 -111.48 141.83 5,938,003.75 498,452.11 4.06 85.16 GYD-GC-SS(1) 1,465.51 26.77 129.82 1,437.59 1,281.79 -136.31 172.56 5,937,978.91 498,482.82 5.01 104.28 MWD+IFR-AK-CAZ-SC(2) 1,523.47 26.69 130.95 1,489.36 1,333.56. -153.20 192.41 5,937,962.02 498,502.67 0.89 117.46 MWD+IFR-AK-CAZ-SC(2) 1,559.12 26.85 130.49 1,521.18 1,365.38 -163.68 204.58 5,937,951.54 498,514.84 0.73 125.67 MWD+IFR-AK-CAZ-SC(2) 1,617.79 27.45 133.25 1,573.39 1,417.59 -181.55 224.51 5,937,933.67 498,534.76 2.38 139.80 MWD+IFR-AK-CAZ-SC(2) 1,712.07 28.91 139.14 1,656.51 1,500.71 -213.68 255.25 5,937,901.53 498,565.49 3.33 166.11 MWD+IFR-AK-CAZ-SC(2) 1,807.56 31.73 142.04 1,738.94 1,583.14 -250.94 285.81 5,937,864.27 498,596.03 3.33 197.50 MWD+IFR-AK-CAZ-SC(2) 1,903.21 33.29 142.70 1,819.59 1,663.79 -291.66 317.19 5,937,823.55 498,627.40 1.67 232.15 MWD+IFR-AK-CAZ-SC(2) 1,997.72 35.26 142.14 1,897.69 1,741.89 -333.83 349.65 5,937,781.37 498,659.85 2.11 268.04 MWD+IFR-AK-CAZ-5C(2) 2,091.55 36.12 144.95 1,973.90 1,818.10 -377.86 382.16 5,937,737.34 498,692.35 1.97 305.76 MWD+IFR-AK-CAZ-SC(2) 2,186.31 37.72 148.80 2,049.67 1,893.87 -425.53 413.22 5,937,689.67 498,723.39 2.97 347.31 MWD+IFR-AK-CAZ-SC(2) 2,281.00 39.00 150.95 2,123.92 1,968.12 -476.36 442.70 5,937,638.84 498,752.86 1.95 392.25 MWD+IFR-AK-CAZ-SC(2) 2,375.39 40.31 153.49 2,196.59 2,040.79 -529.65 470.75 5,937,585.55 498,780.89 2.21 439.86 MWD+IFR-AK-CAZ-SC(2) 2,469.17 41,49 157.22 2,267.49 2,111.69 -585.44 496.32 5,937,529.75 498,806.45 2.89 490.36 MWD+IFR-AK-CAZ-SC(2) 2,563.41 42.98 161.31 2,337.27 2,181.47 -644.67 518.71 5,937,470.53 498,828.82 3.32 544.80 MWD+IFR-AK-CAZ-SC(2) 2,659.17 44.91 165.09 2,406.23 2,250.43 -708.27 537.87 5,937,406.93 498,847.97 3.40 604.11 MWD+IFR-AK-CAZ-SC(2) 2,753.09 46.58 169.31 2,471.78 2,315.98 -773.85 552.73 5,937,341.36 498,862.81 3.68 666.11 MWD+IFR-AK-CAZ-SC(2) 2,848.07 48.12 174.03 2,536.15 2,380.35 -842.93 562.81 5,937,272.28 498,872.88 4.00 732.40 MWD+IFR-AK-CAZ-SC(2) 2,943.05 49.22 175.62 2,598.88 2,443.08 -913.96 569.24 5,937,201.25 498,879.29 1.71 801.23 MWD+IFR-AK-CAZ-5C(2) 3,036.49 47.43 177.13 2,661.01 2,505.21 -983.61 573.66 5,937,131.61 498,883.69 2.26 869.05 MWD+IFR-AK-CAZ-SC(2) 3,131.43 48.48 177.14 2,724.59 2,568.79 -1,054.02 577.19 5,937,061.21 498,887.20 1.11 937.78 MWD+IFR-AK-CAZ-SC(2) 3,225.65 46.69 177.62 2,788.14 2,632.34 -1,123.51 580.37 5,936,991.73 498,890,37 1.94 1,005.66 MWD+IFR-AK-CAZ-5C(2) 3,321.00 47.60 177.97 2,852.99 2,697.19 -1,193.35 583.06 5,936,921.89 498,893.04 0.99 1,073.98 MWD+IFR-AK-CAZ-SC(2) 3,405.64 50.81 178.33 2,908.28 2,752.48 -1,257.39 585.12 5,936,857.86 498,895.09 3.81 1,136.68 MWD+IFR-AK-CAZ-SC(2) 3,481.00 52.11 179.90 2,955.23 2,799.43 -1,316.32 586.02 5,936,798.93 498,895.98 2.38 1,194.56 NOT an Actual Survey 10 3/4"x 13-1/2" 3,490.68 52.28 180.10 2,961.17 2,805.37 -1,323.97 586.02 5,936,791.28 498,895.98 2.38 1,202.09 INC+TREND(3) 3,537.56 52.79 181.06 2,989.68 2,833.88 -1,361.18 585.64 5,936,754.08 498,895.59 1.96 1,238.80 MWD+IFR-AK-CAZ-SC(4) 3,585.25 52.72 182.13 3,018.55 2,862.75 -1,399.12 584.59 5,936,716.14 498,894.53 1.79 1,276.36 MWD+IFR-AK-CAZ-SC(4) 6/20t2017 8:51:37AM Page 3 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 3,679.71 52.33 186.67 3,076.04 2,920.24 -1,473.83 578.85 5,936,641.43 498,888.77 3.84 1,350.93 MWD+1FR-AK-CAZ-SC(4) 3,775.79 51.86 192.44 3,135.09 2,979.29 -1,548.54 566.28 5,936,566.74 498,876.19 4.76 1,426.68 MWD+IFR-AK-CAZ-SC(4) 3,868.15 51.59 196.76 3,192.32 3,036.52 -1,618.68 548.02 5,936,496.61 498,857.91 3.68 1,498.92 MWD+IFR-AK-CAZ-SC(4) 3,964.44 51.81 202.32 3,252.03 3,096.23 -1,689.84 522.76 5,936,425.46 498,832.64 4.54 1,573.39 MWD+IFR-AK-CAZ-SC(4) 4,057.87 51.97 204.70 3,309.70 3,153.90 -1,757.24 493.44 5,936,358.07 498,803.30 2.01 1,644.86 MWD+IFR-AK-CAZ-SC(4) 4,153.07 51.94 209.63 3,368.39 3,212.59 -1,823.91 459.23 5,936,291.42 498,769.08 4.08 1,716.45 MWD+IFR-AK-CAZ-SC(4) 4,247.71 52.99 211.73 3,426.05 3,270.25 -1,888.44 420.93 5,936,226.91 498,730.77 2.08 1,786.66 MWD+1FR-AK-CAZ-SC(4) 4,341.98 54.45 215.14 3,481.84 3,326.04 -1,951.83 379.05 5,936,163.53 498,688.89 3.30 1,856.35 MWD+1FR-AK-CAZ-SC(4) 4,435.93 55.35 219.26 3,535.88 3,380.08 -2,013.02 332.58 5,936,102.36 498,642.41 3.71 1,924.69 MWD+1FR-AK-CAZ-SC(4) 4,530.41 55.82 222.58 3,589.29 3,433.49 -2,071.90 281.54 5,936,043.49 498,591.36 2.94 1,991.53 MWD+IFR-AK-CAZ-SC(4) 4,625.37 56.30 225.90 3,642.32 3,486.52 -2,128.32 226.58 5,935,987.09 498,536.39 2.94 2,056.64 MWD+1FR-AK-CAZ-SC(4) 4,720.39 57.24 228.83 3,694.40 3,538.60 -2,182.14 168.11 5,935,933.29 498,477.92 2.76 2,119.80 MWD+IFR-AK-CAZ-SC(4) 4,814.46 57.99 230.05 3,744.78 3,588.98 -2,233.79 107.76 5,935,881.66 498,417.56 1.35 2,181.14 MWD+1FR-AK-CAZ-SC(4) 4,908.78 59.91 231.94 3,793.43 3,637.63 -2,284.63 44.97 5,935,830.84 498,354.76 2.66 2,242.11 MWD+IFR-AK-CAZ-SC(4) 5,004.27 61.66 232.67 3,840.04 3,684.24 -2,335.59 -20.98 5,935,779.90 498,288.81 1.95 2,303.75 MWD+IFR-AK-CAZ-SC(4) 5,098.64 64.03 234.85 3,883.11 3,727.31 -2,385.20 -88.70 5,935,730.30 498,221.08 3.25 2,364.37 MWD+1FR-AK-CAZ-SC(4) 5,193.88 66.29 236.87 3,923.12 3,767.32 -2,433.69 -160.24 5,935,681.84 498,149.54 3.06 2,424.54 MWD+1FR-AK-CAZ-SC(4) 5,288.26 67.48 239.58 3,960.18 3,804.38 -2,479.39 -234.02 5,935,636.16 498,075.75 2.93 2,482.36 MWD+1FR-AK-CAZ-SC(4) 5,383.63 68.75 241.88 3,995.73 3,839.93 -2,522.64 -311.22 5,935,592.93 497,998.56 2.60 2,538.36 MWD+1FR-AK-CAZ-SC(4) 5,477.65 69.85 245.12 4,028.97 3,873.17 -2,561.87 -389.92 5,935,553.72 497,919.86 3.43 2,590.66 MWD+IFR-AK-CAZ-SC(4) 5,572.69 70.59 247.79 4,061.14 3,905.34 -2,597.59 -471.90 5,935,518.03 497,837.88 2.76 2,640.07 MWD+1FR-AK-CAZ-SC(4) 5,667.17 72.33 250.98 4,091.18 3,935.38 -2,629.11 -555.73 5,935,486.53 497,754.05 3.69 2,685.67 MWD+IFR-AK-CAZ-SC(4) 5,762.10 72.33 252.05 4,120.00 3,964.20 -2,657.79 -641.51 5,935,457.87 497,668.27 1.07 2,728.81 MWD+1FR-AK-CAZ-SC(4) 5,856.61 72.30 253.66 4,148.71 3,992.91 -2,684.33 -727.55 5,935,431.35 497,582.23 1.62 2,769.89 MWD+1FR-AK-CAZ-SC(4) 5,951.73 72.30 254.91 4,177.63 4,021.83 -2,708.87 -814.78 5,935,406.83 497,495.01 1.25 2,809.20 MWD+IFR-AK-CAZ-SC(4) 6,046.44 72.17 253.62 4,206.53 4,050.73 -2,733.33 -901.59 5,935,382.39 497,408.20 1.30 2,848.37 MWD+1FR-AK-CAZ-SC(4) 6,140.63 72.24 252.56 4,235.32 4,079.52 -2,759.42 -987.39 5,935,356.33 497,322.40 1.07 2,888.95 MWD+IFR-AK-CAZ-SC(4) 6,235.96 72.43 252.83 4,264.24 4,108.44 -2,786.44 -1,074.12 5,935,329.33 497,235.68 0.34 2,930.62 MWD+IFR-AK-CAZ-SC(4) 6,329.99 72.27 252.42 4,292.75 4,136.95 -2,813.19 -1,159.63 5,935,302.60 497,150.17 0.45 2,971.82 MWD+1FR-AK-CAZ-SC(4) 6,424.01 72.36 252.51 4,321.32 4,165.52 -2,840.18 -1,245.04 5,935,275.63 497,064.75 0.13 3,013.23 MWD+IFR-AK-CAZ-SC(4) 6,520.71 72.36 253.24 4,350.62 4,194.82 -2,867.32 -1,333.11 5,935,248.52 496,976.69 0.72 3,055.25 MWD+1FR-AK-CAZ-SC(4) 6,613.94 72.46 252.39 4,378.80 4,223.00 -2,893.58 -1,418.01 5,935,222.28 496,891.79 0.88 3,095.85 MWD+IFR-AK-CAZ-SC(4) 6,707.61 72.42 253.18 4,407.06 4,251.26 -2,920.01 -1,503.32 5,935,195.87 496,806.49 0.81 3,136.69 MWD+IFR-AK-CAZ-SC(4) 6,803.32 72.29 252.91 4,436.07 4,280.27 -2,946.60 -1,590.56 5,935,169.30 496,719.25 0.30 3,178.04 MWD+IFR-AK-CAZ-SC(4) 6,897.82 72.42 252.94 4,464.71 4,308.91 -2,973.05 -1,676.64 5,935,142.88 496,633.17 0.14 3,219.02 MWD+IFR-AK-CAZ-SC(4) 6,992.05 72.39 252.12 4,493.20 4,337.40 -3,000.01 -1,762.32 5,935,115.93 496,547.49 0.83 3,260.46 MWD+1FR-AK-CAZ-SC(4) 7,087.55 72.36 252.02 4,522.11 4,366.31 -3,028.03 -1,848.92 5,935,087.94 496,460.90 0.10 3,303.09 MWD+IFR-AK-CAZ-SC(4) 7,181.73 72.38 250.53 4,550.64 4,394.84 -3,056.84 -1,933.92 5,935,059.15 496,375.90 1.51 3,346.23 MWD+1FR-AK-CAZ-SC(4) 7,277.61 72.42 249.38 4,579.63 4,423.83 -3,088.17 -2,019.78 5,935,027.84 496,290.04 1.14 3,391.98 MWD+1FR-AK-CAZ-SC(4) 7,372.67 72.54 249.45 4,608.25 4,452.45 -3,120.04 -2,104.64 5,934,995.99 496,205.18 0.14 3,438.11 MWD+IFR-AK-CAZ-SC(4) 6/20/2017 8:51:37AM Page 4 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 7,466.70 72.42 249.82 4,636.55 4,480.75 -3,151.25 -2,188.70 5,934,964.81 496,121.12 0.40 3,483.43 MWD+1FR-AK-CAZ-SC(4) 7,561.59 72.51 250.18 4,665.14 4,509.34 -3,182.19 -2,273.73 5,934,933.89 496,036.10 0.37 3,528.68 MWD+IFR-AK-CAZ-SC(4) 7,656.11 72.48 250.22 4,693.57 4,537.77 -3,212.73 -2,358.54 5,934,903.37 495,951.29 0.05 3,573.47 MWD+1FR-AK-CAZ-SC(4) 7,750.65 72.48 251.44 4,722.04 4,566.24 -3,242.33 -2,443.69 5,934,873.79 495,866.14 1.23 3,617.41 MWD+IFR-AK-CAZ-SC(4) 7,845.23 72.30 251.15 4,750.65 4,594.85 -3,271.24 -2,529.08 5,934,844.90 495,780.75 0.35 3,660.71 MWD+1FR-AK-CAZ-SC(4) 7,939.83 72.27 251.23 4,779.43 4,623.63 -3,300.30 -2,614.38 5,934,815.87 495,695.45 0.09 3,704.14 MWD+1FR-AK-CAZ-SC(4) 8,034.74 72.30 251.08 4,808.31 4,652.51 -3,329.50 -2,699.94 5,934,786.69 495,609.89 0.15 3,747.76 MWD+IFR-AK-CAZ-SC(4) 8,129.25 72.34 251.13 4,837.02 4,681.22 -3,358.66 -2,785.14 5,934,757.55 495,524.70 0.07 3,791.27 MWD+1FR-AK-CAZ-SC(4) 8,224.42 72.39 250.99 4,865.85 4,710.05 -3,388.10 -2,870.92 5,934,728.14 495,438.91 0.15 3,835.15 MWD+IFR-AK-CAZ-SC(4) 8,318.72 72.57 251.87 4,894.24 4,738.44 -3,416.73 -2,956.17 5,934,699.52 495,353.67 0.91 3,878.16 MWD+IFR-AK-CAZ-SC(4) 8,412.38 72.44 252.53 4,922.39 4,766.59 -3,444.04 -3,041.22 5,934,672.23 495,268.62 0.69 3,919.82 MWD+IFR-AK-CAZ-SC(4) 8,508.39 72.45 252.59 4,951.35 4,795.55 -3,471.48 -3,128.55 5,934,644.82 495,181.30 0.06 3,962.00 MWD+IFR-AK-CAZ-SC(4) 8,603.53 72.39 252.29 4,980.09 4,824.29 -3,498.84 -3,215.02 5,934,617.48 495,094.83 0.31 4,003.97 MWD+1FR-AK-CAZ-SC(4) 8,698.22 72.33 251.97 5,008.78 4,852.98 -3,526.53 -3,300.90 5,934,589.81 495,008.95 0.33 4,046.15 MWD+IFR-AK-CAZ-SC(4) 8,792.87 72.45 251.87 5,037.42 4,881.62 -3,554.53 -3,386.66 5,934,561.84 494,923.19 0.16 4,088.61 MWD+1FR-AK-CAZ-SC(4) 8,886.58 72.48 251.95 5,065.65 4,909.85 -3,582.27 -3,471.60 5,934,534.11 494,838.25 0.09 4,130.69 MWD+IFR-AK-CAZ-SC(4) 8,982.52 72.48 252.42 5,094.53 4,938.73 -3,610.26 -3,558.70 5,934,506.15 494,751.15 0.47 4,173.38 MWD+IFR-AK-CAZ-SC(4) 9,076.94 72.51 252.54 5,122.93 4,967.13 -3,637.37 -3,644.57 5,934,479.06 494,665.29 0.13 4,214.99 MWD+1FR-AK-CAZ-SC(4) 9,171.60 72.58 252.39 5,151.33 4,995.53 -3,664.58 -3,730.68 5,934,451.87 494,579.18 0.17 4,256.73 MWD+IFR-AK-CAZ-SC(4) 9,266.01 72.47 251.69 5,179.68 5,023.88 -3,692.35 -3,816.34 5,934,424.13 494,493.52 0.72 4,298.95 MWD+1FR-AK-CAZ-SC(4) 9,360.65 72.60 251.82 5,208.08 5,052.28 -3,720.61 -3,902.08 5,934,395.89 494,407.78 0.19 4,341.67 MWD+IFR-AK-CAZ-SC(4) 9,455.06 72.54 251.74 5,236.36 5,080.56 -3,748.77 -3,987.64 5,934,367.75 494,322.23 0.10 4,384.27 MWD+IFR-AK-CAZ-SC(4) 9,550.09 72.42 250.60 5,264.97 5,109.17 -3,778.02 -4,073.41 5,934,338.52 494,236.46 1.15 4,427.97 MWD+IFR-AK-CAZ-SC(4) 9,644.93 72.55 250.20 5,293.51 5,137.71 -3,808.36 -4,158.61 5,934,308.20 494,151.26 0.42 4,472.64 MWD+IFR-AK-CAZ-SC(4) 9,739.40 72.47 251.02 5,321.91 5,166.11 -3,838.27 -4,243.60 5,934,278.31 494,066.27 0.83 4,516.86 MWD+1FR-AK-CAZ-SC(4) 9,833.30 72.51 251.70 5,350.16 5,194.36 -3,866.90 -4,328.46 5,934,249.71 493,981.42 0.69 4,559.78 MWD+IFR-AK-CAZ-SC(4) 9,927.98 72.51 251.01 5,378.61 5,222.81 -3,895.77 -4,414.02 5,934,220.86 493,895.86 0.70 4,603.07 MWD+IFR-AK-CAZ-SC(4) 10,022.58 72.49 250.81 5,407.06 5,251.26 -3,925.27 -4,499.28 5,934,191.38 493,810.60 0.20 4,646.93 MWD+IFR-AK-CAZ-SC(4) 10,117.39 72.52 250.66 5,435.56 5,279.76 -3,955.11 -4,584.64 5,934,161.57 493,725.24 0.15 4,691.13 MWD+IFR-AK-CAZ-SC(4) 10,211.63 72.42 250.90 5,463.95 5,308.15 -3,984.69 -4,669.49 5,934,132.00 493,640.39 0.27 4,735.00 MWD+1FR-AK-CAZ-SC(4) 10,306.40 72.52 251.50 5,492.49 5,336.69 -4,013.81 -4,755.04 5,934,102.90 493,554.85 0.61 4,778.54 MWD+IFR-AK-CAZ-SC(4) 10,401.38 72.42 251.51 5,521.10 5,365.30 -4,042.54 -4,840.93 5,934,074.20 493,468.96 0.11 4,821.75 MWD+IFR-AK-CAZ-SC(4) 10,495.87 72.42 251.32 5,549.64 5,393.84 -4,071.25 -4,926.31 5,934,045.51 493,383.58 0.19 4,864.85 MWD+IFR-AK-CAZ-SC(4) 10,590.24 72.42 250.50 5,578.14 5,422.34 -4,100.67 -5,011.33 5,934,016.11 493,298.57 0.83 4,908.58 MWD+IFR-AK-CAZ-SC(4) 10,684.97 72.51 250.09 5,606.69 5,450.89 -4,131.13 -5,096.36 5,933,985.67 493,213.53 0.42 4,953.34 MWD+1FR-AK-CAZ-SC(4) 10,779.98 72.36 250.07 5,635.36 5,479.56 -4,161.99 -5,181.53 5,933,954.84 493,128.37 0.16 4,998.52 MWD+IFR-AK-CAZ-SC(4) 10,874.70 72.40 250.21 5,664.03 5,508.23 -4,192.66 -5,266.43 5,933,924.19 493,043.46 0.15 5,043.47 MWD+IFR-AK-CAZ-SC(4) 10,963.19 72.09 249.81 5,691.02 5,535.22 -4,221.47 -5,345.63 5,933,895.40 492,964.27 0.56 5,085.60 MWD+IFR-AK-CAZ-SC(4) 11,063.99 72.15 248.96 5,721.96 5,566.16 -4,255.25 -5,435.42 5,933,861.65 492,874.48 0.80 5,134.45 MWD+IFR-AK-CAZ-SC(5) 11,109.45 72.45 249.34 5,735.79 5,579.99 -4,270.66 -5,475.89 5,933,846.24 492,834.01 1.03 5,156.66 MWD+1FR-AK-CAZ-SC(5) 6/20/2017 8:51:37AM Page 5 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 11,159.39 72.31 250.52 5,750.90 5,595.10 -4,286.99 -5,520.60 5.933 829 92 492,789.31 2.27 5,180.51 MWD+IFR-AK-CAZ-SC(5) 11,253.06 72.32 251.74 5,779.36 5,623.56 -4,315.86 -5,605.04 5,933,801.08 492,704.86 1.24 5,223.59 MWD+IFR-AK-CAZ-5C(5) 11,348.98 72.23 251.92 5,808.56 5,652.76 -4,344.35 -5,691.85 5,933,772.61 492,618.05 0.20 5,266.73 MWD+IFR-AK-CAZ-SC(5) 11,442.72 72.22 251.96 5,837.18 5,681.38 -4,372.02 -5,776.72 5,933,744.96 492,533.19 0.04 5,308.72 MWD+IFR-AK-CAZ-SC(5) 11,538.39 72.07 251.10 5,866.51 5,710.71 -4,400.87 -5,863.09 5,933,716.13 492,446.82 0.87 5,352.13 MWD+IFR-AK-CAZ-SC(5) 11,632.89 72.23 251.20 5,895.48 5,739.68 -4,429.93 -5,948.22 5,933,687.09 492,361.70 0.20 5,395.53 MWD+IFR-AK-CAZ-SC(5) 11,727.15 72.26 250.51 5,924.22 5,768.42 -4,459.37 -6,033.02 5,933,657.67 492,276.89 0.70 5,439.25 MWD+IFR-AK-CAZ-SC(5) 11,822.13 72.13 250.61 5,953.27 5,797.47 -4,489.47 -6,118.30 5,933,627.60 492,191.62 0.17 5,483.70 MWD+IFR-AK-CAZ-5C(5) 11,917.49 72.35 250.77 5,982.35 5,826.55 -4,519.50 -6,204.00 5,933,597.59 492,105.92 0.28 5,528.15 MWD+IFR-AK-CAZ-SC(5) 12,012.12 72.28 248.92 6,011.10 5,855.30 -4,550.56 -6,288.63 5,933,566.55 492,021.28 1.86 5,573.44 MWD+IFR-AK-CAZ-SC(5). 12,106.98 72.62 245.54 6,039.72 5,883.92 -4,585.57 -6,372.01 5,933,531.57 491,937.90 3.42 5,622.39 MWD+IFR-AK-CAZ-SC(5) 12,201.76 73.14 241.73 6,067.63 5,911.83 -4,625.79 -6,453.15 5,933,491.37 491,856.77 3.88 5,676.09 MWD+IFR-AK-CAZ-SC(5) 12,296.53 73.95 237.55 6,094.48 5,938.68 -4,671.72 -6,531.55 5,933,445.46 491,778.36 4.32 5,734.94 MWD+IFR-AK-CAZ-SC(5) 12,391.16 75.12 235.47 6,119.72 5,963.92 -4,722.04 -6,607.61 5,933,395.16 491,702.31 2.45 5,797.70 MWD+IFR-AK-CAZ-SC(5) 12,485.42 75.75 230.26 6,143.44 5,987.64 -4,777.10 -6,680.31 5,933,340.12 491,629.60 5.39 5,864.55 MWD+IFR-AK-CAZ-5C(5) 12,579.88 75.83 225.23 6,166.64 6,010.84 -4,838.65 -6,748.06 5,933,278.59 491,561.84 5.16 5,936.93 MWD+IFR-AK-CAZ-SC(5) 12,674.56 75.85 221.77 6,189.81 6,034.01 -4,905.24 -6,811.24 5,933,212.03 491,498.65 3.54 6,013.47 MWD+IFR-AK-CAZ-SC(5) 12,769.60 76.26 220.55 6,212.71 6,056.91 -4,974.68 -6,871.95 5,933,142.61 491,437.94 1.32 6,092.40 MWD+IFR-AK-CAZ-5C(5) 12,863.92 77.09 218.97 6,234.45 6,078.65 -5,045.23 -6,930.64 5,933,072.08 491,379.23 1.85 6,172.08 MWD+IFR-AK-CAZ-SC(5) 12,958.66 77.70 215.53 6,255.13 6,099.33 -5,118.82 -6,986.59 5,932,998.51 491,323.27 3.60 6,254.26 MWD+IFR-AK-CAZ-SC(5) 13,052.89 78.53 212.05 6,274.54 6,118.74 -5,195.44 -7,037.86 5,932,921.91 491,271.99 3.72 6,338.62 MWD+IFR-AK-CAZ-SC(5) 13,147.41 79.06 209.09 6,292.91 6,137.11 -5,275.26 -7,085.01 5,932,842.10 491,224.82 3.12 6,425.42 MWD+IFR-AK-CAZ-SC(5) 13,241.62 80.53 205.09 6,309.61 6,153.81 -5,357.79 -7,127.22 5,932,759.59 491,182.60 4.46 6,514.02 MWD+IFR-AK-CAZ-SC(5) 13,336.63 81.54 200.96 6,324.42 6,168.62 -5,444.15 -7,163.91 5,932,673.25 491,145.89 4.42 • 6,605.44 MWD+IFR-AK-CAZ-5C(5) 13,431.33 83.63 196.64 6,336.65 6,180.85 -5,533.02 -7,194.16 5,932,584.40 491,115.63 5.03 6,698.21 MWD+IFR-AK-CAZ-SC(5) 13,525.38 83.58 192.16 6,347.13 6,191.33 -5,623.53 -7,217.40 5,932,493.90 491,092.37 4.73 6,791.38 MWD+IFR-AK-CAZ-5C(5) 13,619.60 85.20 189.07 6,356.34 6,200.54 -5,715.68 -7,234.66 5,932,401.77 491,075.09 3.69 6,885.13 MWD+IFR-AK-CAZ-SC(5) 13,674.55 86.64 188.88 6,360.25 6,204.45 -5,769.81 -7,243.21 5,932,347.64 491,066.53 2.64 6,939.93 MWD+IFR-AK-CAZ-SC(5) 13,719.35 86.99 189.25 6,362.74 6,206.94 -5,813.99 -7,250.26 5,932,303.47 491,059.47 1.14 6,984.65 INC+TREND(6) 13,728.00 87.25 189.32 6,363.18 6,207.38 -5,822.51 -7,251.66 5,932,294.95 491,058.07 3.16 6,993.29 NOT an Actual Survey 7-5/8"x 9-7/8-11" 13,787.31 89.06 189.82 6,365.08 6,209.28 -5,880.96 -7,261.51 5,932,236.50 491,048.21 3.16 7,052.57 MWD+IFR-AK-CAZ-SC(7) 13,877.43 89.39 188.39 6,366.30 6,210.50 -5,969.94 -7,275.77 5,932,147.54 491,033.93 1.63 7,142,66 MWD+IFR-AK-CAZ-SC(7) 13,971.54 88.43 187.28 6,368.09 6,212.29 -6,063.15 -7,288.60 5,932,054.34 491,021.08 1.56 7,236.69 MWD+IFR-AK-CAZ-SC(7) 14,023.06 88.43 188.41 6,369.50 6,213.70 -6,114.17 -7,295.63 5,932,003.33 491,014.04 2.19 7,288.15 MWD+IFR-AK-CAZ-SC(7) 14,066.69 88.60 188.04 6,370.63 6,214.83 -6,157.33 -7,301.87 5,931,960.17 491,007.79 0.93 7,331.75 MWD+IFR-AK-CAZ-SC(7) 14,114.52 88.97 187.77 6,371.65 6,215.85 -6,204.70 -7,308.44 5,931,912.81 491,001.21 0.96 7,379.53 MWD+IFR-AK-CAZ-SC(7) 14,160.75 89.08 187.85 6,372.44 6,216.64 -6,250.49 -7,314.72 5,931,867.02 490,994.92 0.29 7,425.72 MWD+IFR-AK-CAZ-SC(7) 14,210.24 89.01 187.78 6,373.26 6,217.46 -6,299.52 -7,321.45 5,931,818.00 490,988.18 0.20 7,475.17 MWD+IFR-AK-CAZ-SC(7) 14,253.61 89.18 186.62 6,373.95 6,218.15 -6,342.54 -7,326.89 5,931,774.99 490,982.73 2.70 7,518.48 MWD+IFR-AK-CAZ-SC(7) 6/20/2017 8:51:37AM Page 6 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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) (°I100') (ft) Survey Tool Name 14,347.94 89.39 185.63 6,375.12 6,219.32 -6,436.32 -7,336.95 5,931,681.22 490,972.65 1.07 7,612.59 MWD+IFR-AK-CAZ-SC(7) 14,442.45 89.90 183.92 6,375.71 6,219.91 -6,530.50 -7,344.82 5,931,587.05 490,964.76 1.89 7,706.70 MWD+IFR-AK-CAZ-SC(7) 14,483.90 90.41 183.68 6,375.60 6,219.80 -6,571.86 -7,347.57 5,931,545.70 490,962.01 1.36 7,747.91 MWD+IFR-AK-CAZ-SC(7) 14,537.38 90.62 182.48 6,375.12 6,219.32 -6,625.26 -7,350.44 5,931,492.30 490,959.12 2.28 7,800.99 MWD+IFR-AK-CAZ-SC(7) 14,632.47 91.35 184.28 6,373.48 6,217.68 -6,720.16 -7,356.04 5,931,397.41 490,953.50 2.04 7,895.43 MWD+IFR-AK-CAZ-SC(7) 14,727.54 90.00 185.76 6,372.36 6,216.56 -6,814.86 -7,364.36 5,931,302.73 490,945.16 2.11 7,990.13 MWD+IFR-AK-CAZ-SC(7) 14,822.97 89.63 186.35 6,372.67 6,216.87 -6,909.75 -7,374.43 5,931,207.84 490,935.07 0.73 8,085.33 MWD+IFR-AK-CAZ-SC(7) 14,917.39 89.45 188.55 6,373.43 6,217.63 -7,003.37 -7,386.67 5,931,114.24 490,922.81 2.34 8,179.65 MWD+IFR-AK-CAZ-SC(7) 15,012.09 89.15 188.40 6,374.58 6,218.78 -7,097.03 -7,400.63 5,931,020.59 490,908.83 0.35 8,274.31 MWD+IFR-AK-CAZ-SC(7) 15,106.46 89.80 189.75 6,375.45 6,219.65 -7,190.21 -7,415.51 5,930,927.42 490,893.93 1.59 8,368.66 MWD+IFR-AK-CAZ-SC(7) 15,202.17 88.80 190.27 6,376.62 6,220.82 -7,284.45 -7,432.14 5,930,833.19 490,877.28 1.18 8,464.36 MWD+IFR-AK-CAZ-SC(7) 15,297.52 87.76 190.23 6,379.48 6,223.68 -7,378.24 -7,449.10 5,930,739.42 490,860.30 1.09 8,559.67 MWD+IFR-AK-CAZ-SC(7) 15,392.52 88.25 191.05 6,382.79 6,226.99 -7,471.55 -7,466.63 5,930,646.13 490,842.75 1.01 8,654.60 MWD+IFR-AK-CAZ-SC(7) 15,485.83 87.91 188.80 6,385.91 6,230.11 -7,563.40 -7,482.71 5,930,554.28 490,826.66 2.44 8,747.85 MWD+IFR-AK-CAZ-SC(7) 15,580.16 88.01 188.02 6,389.27 6,233.47 -7,656.66 -7,496.49 5,930,461.04 490,812.85 0.83 8,842.09 MWD+IFR-AK-CAZ-SC(7) 15,630.76 88.49 188.56 6,390.82 6,235.02 -7,706.70 -7,503.79 5,930,411.00 490,805.55 1.43 8,892.64 MWD+IFR-AK-CAZ-SC(7) 15,675.24 88.63 188.37 6,391.93 6,236.13 -7,750.69 -7,510.33 5,930,367.02 490,798.99 0.53 8,937.09 MWD+IFR-AK-CAZ-SC(7) 15,770.26 88.66 188.06 6,394.18 6,238.38 -7,844.70 -7,523.90 5,930,273.02 490,785.40 0.33 9,032.04 MWD+IFR-AK-CAZ-SC(7) 15,864.74 89.73 187.35 6,395.51 6,239.71 -7,938.32 -7,536.57 5,930,179.41 490,772.71 1.36 9,126.43 MWD+IFR-AK-CAZ-SC(7) 15,959.55 90.72 187.78 6,395.14 6,239.34 -8,032.30 -7,549.05 5,930,085.44 490,760.21 1.14 9,221.15 MWD+IFR-AK-CAZ-SC(7) 16,054.41 91.17 187.46 6,393.57 6,237.77 -8,126.31 -7,561.63 5,929,991.45 490,747.62 0.58 9,315.92 MWD+IFR-AK-CAZ-SC(7) 16,149.67 90.55 188.15 6,392.14 6,236.34 -8,220.68 -7,574.56 5,929,897.09 490,734.66 0.97 9,411.10 MWD+IFR-AK-CAZ-SC(7) 16,244.29 90.21 187.72 6,391.51 6,235.71 -8,314.39 -7,587.63 5,929,803.39 490,721.58 0.58 9,505.65 MWD+IFR-AK-CAZ-SC(7) 16,338.98 90.24 189.11 6,391.14 6,235.34 -8,408.06 -7,601.48 5,929,709.74 490,707.70 1.47 9,600.30 MWD+IFR-AK-CAZ-SC(7) 16,432.99 90.17 190.02 6,390.81 6,235.01 -8,500.76 -7,617.10 5,929,617.05 490,692.06 0.97 9,694.31 MW0+IFR-AK-CAZ-SC(7) 16,527.54 89.80 190.69 6,390.83 6,235.03 -8,593.77 -7,634.10 5,929,524,05 490,675.05 0.81 9,788.86 MWD+IFR-AK-CAZ-SC(7) 16,620.84 89.25 192.96 6,391.60 6,235.80 -8,685.08 -7,653.22 5,929,432.76 490,655.91 2.50 9,882.10 MWD+IFR-AK-CAZ-SC(7) 16,716.08 87.77 193.51 6,394.08 6,238.28 -8,777.75 -7,675.01 5,929,340.09 490,634.10 1.66 9,977.15 MWD+IFR-AK-CAZ-SC(7) 16,811.25 86.01 195.43 6,399.24 6,243.44 -8,869.76 -7,698.75 5,929,248.10 490,610.34 2.73 10,071.89 MWD+IFR-AK-CAZ-SC(7) 16,906.30 86.16 194.67 6,405.73 6,249.93 -8,961.34 -7,723.38 5,929,156.54 490,585.70 0.81 10,166.34 MWD+IFR-AK-CAZ-SC(7) 17,000.16 85.89 194.34 6,412.24 6,256.44 -9,051.99 -7,746.83 5,929,065.90 490,562.23 0.45 10,259.69 MWD+IFR-AK-CAZ-SC(7) 17,095.53 89.33 192.62 6,416.22 6,260.42 -9,144.63 -7,769.03 5,928,973.27 490,540.00 4.03 10,354.78 MWD+IFR-AK-CAZ-SC(7) 17,189.37 90.19 191.02 6,416.61 6,260.81 -9,236.48 -7,788.26 5,928,881.44 490,520.76 1.94 10,448.57 MWD+IFR-AK-CAZ-SC(7) 17,283.34 88.48 189.27 6,417.70 6,261.90 -9,328.97 -7,804.81 5,928,788.97 490,504.19 2.60 10,542.53 MW0+IFR-AK-CAZ-SC(7) 17,378.86 89.01 187.65 6,419.79 6,263.99 -9,423.42 -7,818.85 5,928,694.53 490,490.13 1.78 10,637.99 MWD+IFR-AK-CAZ-SC(7) 17,473.79 89.28 187.25 6,421.21 6,265.41 -9,517,54 -7,831.16 5,928,600.42 490,477.80 0.51 10,732.81 MWD+IFR-AK-CAZ-SC(7) 17,568.63 89.04 186.98 6,422.60 6,266.80 -9,611.64 -7,842.91 5,928,506.33 490,466.03 0.38 10,827.52 MWD+IFR-AK-CAZ-SC(7) 17,663.28 88.70 186,63 6,424.47 6,268.67 -9,705.60 -7,854.12 5,928,412.38 490,454.80 0.52 10,922.01 MWD+IFR-AK-CAZ-SC(7) 17,759.29 87.93 186.96 6,427.29 6,271.49 -9,800.90 -7,865.47 5,928,317.10 490,443.43 0.87 11,017.82 MWD+IFR-AK-CAZ-SC(7) 17,854.14 88.49 187.52 6,430.25 6,274.45 -9,894.94 -7,877.42 5,928,223.06 490,431.46 0.83 11,112.52 MWD+IFR-AK-CAZ-SC(7) 6/20/2017 8:51:37AM Page 7 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit ND Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual©155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 .Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 17,948.57 88.67 189.58 6,432.59 6,276.79 -9,988.29 -7,891.46 5,928,129.73 490,417.40 2.19 11,206.88 MWD+IFR-AK-CAZ-SC(7) 18,043.69 89.11 191.36 6,434.44 6,278.64 -10,081.80 -7,908.74 5,928,036.23 490,400.10 1.93 11,301.98 MWD+IFR-AK-CAZ-SC(7) 18,138.00 88.70 190.75 6,436.24 6,280.44 -10,174.35 -7,926.82 5,927,943.70 490,382.00 0.78 11,396.25 MWD+IFR-AK-CAZ-SC(7) 18,233.38 89.25 190.30 6,437.94 6,282.14 -10,268.11 -7,944.24 5,927,849.95 490,364.56 0.75 11,491.61 MWD+1FR-AK-CAZ-SC(7) 18,328.13 90.24 190.90 6,438.37 6,282.57 -10,361.24 -7,961.67 5,927,756.83 490,347.12 1.22 11,586.35 MWD+IFR-AK-CAZ-SC(7) 18,422.06 90.28 190.96 6,437.94 6,282.14 -10,453.46 -7,979.48 5,927,664.62 490,329.29 0.08 11,680.27 MWD+IFR-AK-CAZ-SC(7) 18,516.78 91.31 190.78 6,436.63 6,280.83 -10,546.47 -7,997.34 5,927,571.63 490,311.41 1.10 11,774.97 MWD+IFR-AK-CAZ-SC(7) 18,611.64 91.17 191.53 6,434.57 6,278.77 -10,639.52 -8,015.69 5,927,478.59 490,293.04 0.80 11,869.79 MWD+1FR-AK-CAZ-SC(7) 18,706.70 91.07 191.84 6,432.71 6,276.91 -10,732.59 -8,034.93 5,927,385.54 490,273.77 0.34 11,964.79 MWD+IFR-AK-CAZ-SC(7) 18,801.23 91.17 191.40 6,430.87 6,275.07 -10,825.16 -8,053.97 5,927,292.97 490,254.72 0.48 12,059.26 MWD+1FR-AK-CAZ-SC(7) 18,896.08 90.62 191.59 6,429.39 6,273.59 -10,918.10 -8,072.87 5,927,200.05 490,235.80 0.61 12,154.07 MWD+IFR-AK-CAZ-SC(7) 18,991.01 90.62 191.01 6,428.36 6,272.56 -11,011.18 -8,091.47 5,927,106.98 490,217.18 0.61 12,248.97 MWD+1FR-AK-CAZ-SC(7) 19,085.09 90.07 190.57 6,427.79 6,271.99 -11,103.60 -8,109.08 5,927,014.58 490,199.55 0.75 12,343.04 MWD+1FR-AK-CAZ-SC(7) 19,179.20 90.35 189.66 6,427.45 6,271.65 -11,196.24 -8,125.61 5,926,921.95 490,183.00 1.01 12,437.14 MWD+IFR-AK-CAZ-SC(7) 19,274.07 89.39 188.89 6,427.66 6,271.86 -11,289.87 -8,140.90 5,926,828.33 490,167.69 1.30 12,532.01 MWD+1FR-AK-CAZ-SC(7) 19,369.80 89.42 187.56 6,428.66 6,272.86 -11,384.61 -8,154.59 5,926,733.61 490,153.98 1.39 12,627.68 MWD+IFR-AK-CAZ-SC(7) 19,463.30 89.73 186.26 6,429.35 6,273.55 -11,477.43 -8,165.84 5,926,640.80 490,142.71 1.43 12,721.04 MWD+1FR-AK-CAZ-SC(7) 19,558.56 90.64 185.36 6,429.04 6,273.24 -11,572.19 -8,175.49 5,926,546.05 490,133.05 1.34 12,816.04 MWD+1FR-AK-CAZ-SC(7) 19,652.88 88.61 185.12 6,429.66 6,273.86 -11,666.11 -8,184.10 5,926,452.14 490,124.41 2.17 12,910.03 MWD+IFR-AK-CAZ-SC(7) 19,746.98 88.70 185.83 6,431.87 6,276.07 -11,759.76 -8,193.07 5,926,358.51 490,115.42 0.76 13,003.81 MWD+1FR-AK-CAZ-SC(7) 19,841.59 88.39 187.18 6,434.27 6,278.47 -11,853.72 -8,203.79 5,926,264.55 490,104.68 1.46 13,098.21 MWD+IFR-AK-CAZ-SC(7) 19,936.78 88.77 189.02 6,436.63 6,280.83 -11,947.93 -8,217.20 5,926,170.35 490,091.26 1.97 13,193.32 MWD+IFR-AK-CAZ-SC(7) 20,031.06 89.32 192.19 6,438.20 6,282.40 -12,040.58 -8,234.54 5,926,077.72 490,073.89 3.41 13,287.57 MWD+IFR-AK-CAZ-SC(7) 20,126.97 89.18 195.03 6,439.46 6,283.66 -12,133.78 -8,257.11 5,925,984.54 490,051.31 2.96 13,383.27 MWD+IFR-AK-CAZ-SC(7) 20,221.52 89.32 194.36 6,440.70 6,284.90 -12,225.22 -8,281.09 5,925,893.10 490,027.31 0.72 13,477.49 MWD+1FR-AK-CAZ-SC(7) 20,316.23 87.93 192.33 6,442.97 6,287.17 -12,317.34 -8,302.94 5,925,801.00 490,005.44 2.60 13,572.01 MWD+1FR-AK-CAZ-SC(7) 20,411.32 88.15 190.97 6,446.22 6,290.42 -12,410.42 -8,322.13 5,925,707.94 489,986.23 1.45 13,667.00 MWD+IFR-AK-CAZ-SC(7) 20,505.38 89.35 189.21 6,448.27 6,292.47 -12,503.00 -8,338.61 5,925,615.37 489,969.73 2.26 13,761.03 MWD+1FR-AK-CAZ-SC(7) 20,601.13 91.19 185.89 6,447.82 6,292.02 -12,597.90 -8,351.19 5,925,520.48 489,957.14 3.96 13,856.68 MWD+IFR-AK-CAZ-SC(7) 20,695.81 90.28 185.17 6,446.61 6,290.81 -12,692.13 -8,360.31 5,925,426.27 489,947.99 1.23 13,951.06 MWD+1FR-AK-CAZ-SC(7) 20,790.41 89.90 184.11 6,446.46 6,290.66 -12,786.42 -8,367.96 5,925,331.99 489,940.32 1.19 14,045.24 MWD+IFR-AK-CAZ-SC(7) 20,883.89 89.80 185.22 6,446.70 6,290.90 -12,879.58 -8,375.56 5,925,238.83 489,932.70 1.19 14,138.32 MWD+IFR-AK-CAZ-SC(7) 20,979.16 89.76 186.13 6,447.07 6,291.27 -12,974.39 -8,384.98 5,925,144.04 489,923.26 0.96 14,233.31 MWD+IFR-AK-CAZ-SC(7) 21,074.14 89.21 188.12 6,447.92 6,292.12 -13,068.62 -8,396.76 5,925,049.82 489,911.46 2.17 14,328.16 MWD+IFR-AK-CAZ-SC(7) 21,168.19 89.69 187.93 6,448.83 6,293.03 -13,161.75 -8,409.89 5,924,956.70 489,898.31 0.55 14,422.15 MWD+IFR-AK-CAZ-SC(7) 21,263.09 89.66 189.39 6,449.36 6,293.56 -13,255.56 -8,424.18 5,924,862.90 489,884.00 1.54 14,517.02 MWD+1FR-AK-CAZ-SC(7) 21,357.63 89.93 189.80 6,449.70 6,293.90 -13,348.78 -8,439.94 5,924,769.70 489,868.22 0.52 14,611.56 MWD+IFR-AK-CAZ-SC(7) 21,452.75 89.32 191.00 6,450.32 6,294.52 -13,442.33 -8,457.11 5,924,676.16 489,851.03 1.42 14,706.67 MWD+1FR-AK-CAZ-SC(7) 21,547.33 88.60 190.36 6,452.04 6,296.24 -13,535.26 -8,474.64 5,924,583.25 489,833.49 1.02 14,801.23 MWD+IFR-AK-CAZ-SC(7) 21,640.81 88.84 188.51 6,454.13 6,298.33 -13,627.45 -8,489.95 5,924,491.07 489,818.15 2.00 14,894.68 MWD+IFR-AK-CAZ-SC(7) 6/20/2017 8:51:37AM Page 8 COMPASS 5000.1 Build 74 II . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey MD Inc Azi TVD TVDSS +N/-S +E/-W Map Map Vertical Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 21,735.22 88.94 188.06 6,455.96 6,300.16 -13,720.85 -8,503.56 5,924,397.68 489,804.53 0.49 14,989.03 MWD+IFR-AK-CAZ-SC(7) 21,830.75 88.94 187.71 6,457.73 6,301.93 -13,815.46 -8,516.66 5,924,303.08 489,791.41 0.37 15,084.48 MWD+IFR-AK-CAZ-SC(7) 21,924.89 88.08 186.56 6,460.17 6,304.37 -13,908.84 -8,528.35 5,924,209.71 489,779.70 1.53 15,178.47 MWD+IFR-AK-CAZ-SC(7) 22,021.01 87.57 187.90 6,463.82 6,308.02 -14,004.12 -8,540.44 5,924,114.44 489,767.59 1.49 15,274.40 MWD+IFR-AK-CAZ-SC(7) 22,116.35 87.89 187.65 6,467.60 6,311.80 -14,098.51 -8,553.32 5,924,020.06 489,754.68 0.43 15,369.59 MWD+IFR-AK-CAZ-SC(7) 22,210.68 91.25 186.66 6,468.31 6,312.51 -14,192.09 -8,565.07 5,923,926.50 489,742.92 3.71 15,463.79 MWD+IFR-AK-CAZ-SC(7) 22,304.87 92.37 187.06 6,465.33 6,309.53 -14,285.56 -8,576.31 5,923,833.04 489,731.65 1.26 15,557.79 MWD+IFR-AK-CAZ-SC(7) 22,400.27 92.49 186.41 6,461.29 6,305.49 -14,380.21 -8,587.49 5,93,738.40 489,720.45 0.69 15,652.95 MWD+IFR-AK-CAZ-SC(7) 22,495.22 90.69 186.64 6,458.65 6,302.85 -14,474.51 -8,598.28 5,923,644.12 489,709.65 1.91 15,747.68 MWD+IFR-AK-CAZ-SC(7) 22,589.97 88.65 185.53 6,459.20 6,303.40 -14,568.72 -8,608.32 5,923,549.92 489,699.58 2.45 15,842.21 MWD+IFR-AK-CAZ-SC(7) 22,684.85 88.41 186.85 6,461.63 6,305.83 -14,663.01 -8,618.55 5,923,455.64 489,689.34 1.41 15,936.84 MWD+IFR-AK-CAZ-SC(7) 22,779.13 89.49 187.94 6,463.36 6,307.56 -14,756.49 -8,630.68 5,923,362.17 489,677.19 1.63 16,031.01 MWD+IFR-AK-CAZ-SC(7) 22,873.99 89.39 188.94 6,464.29 6,308.49 -14,850.32 -8,644.60 5,923,268.36 489,663.24 1.06 16,125.83 MWD+IFR-AK-CAZ-SC(7) 22,968.69 90.04 191.10 6,464.76 6,308.96 -14,943.56 -8,661.08 5,923,175.12 489,646.75 2.38 16,220.52 MWD+IFR-AK-CAZ-SC(7) 23,061.70 89.04 192.10 6,465.50 6,309.70 -15,034.67 -8,679.78 5,923,084.03 489,628.03 1.52 16,313.49 MWD+IFR-AK-CAZ-SC(7) 23,119.00 87.70 192.29 6,467.13 6 311.33 -15,090.65 -8,691.88 5,923,028.06 489,615.92 2.35 16,370.72 NOT an Actual Survey 4 1/2"x 6-3/4" V- ,,. 23,156.52 86.83 192.41 6,468.92 6,313.12 -15,127.26 -8,699.89 5,922,991.45 489,607.90 2.35 16,408 17 MWD+IFR-AK-CAZ-SC(7) 23,252.79 86.36 192.06 6,474.64 6,318.84 -15,221.18 -8,720.26 5,922,897.55 489,587.51 0.61 16,504.19 MWD+IFR-AK-CAZ-SC(7) 23,347.54 86.43 192.64 6,480.60 6,324.80 -15,313.55 -8,740.48 5,922,805.19 489,567.27 0.62 16,598.67 MWD+IFR-AK-CAZ-SC(7) 23,437.58 87.04 192.17 6,485.72 6,329.92 -15,401.35 -8,759.79 5,922,717.41 489,547.94 0.85 16,688.49 MWD+IFR-AK-CAZ-SC(7) 23,530.32 88.94 194.04 6,488.98 6,333.18 -15,491.61 -8,780.81 5,922,627.16 489,526.91 2.87 16,781.03 MWD+IFR-AK-CAZ-SC(7) 23,622.19 87.84 188.38 6,491.56 6,335.76 -15,581.65 -8,798.65 5,922,537.13 489,509.04 6.27 16,872.80 MWD+IFR-AK-CAZ-SC(7) 23,714.94 87.67 185.32 6,495.19 6,339.39 -15,673.66 -8,809.71 5,922,445.13 489,497.97 3.30 16,965.33 MWD+IFR-AK-CAZ-SC(7) 23,805.93 87.50 184.16 6,499.03 6,343.23 -15,764.25 -8,817.22 5,922,354.55 489,490.44 1.29 17,055.85 MWD+IFR-AK-CAZ-SC(7) 23,897.75 87.41 184.54 6,503.11 6,347.31 -15,855.72 -8,824.18 5,922,263.09 489,483.46 0.42 17,147.14 MWD+IFR-AK-CAZ-SC(7) 23,990.16 89.04 184.10 6,505.97 6,350.17 -15,947.82 -8,831.13 5,922,171.01 489,476.49 1.83 17,239.05 MWD+IFR-AK-CAZ-SC(7) 24,081.84 87.13 186.66 6,509.03 6,353.23 -16,039.03 -8,839.72 5,922,079.80 489,467.88 3.48 17,330.37 MWD+IFR-AK-CAZ-SC(7) 24,173.74 88.62 191.23 6,512.44 6,356.64 -16,129.73 -8,854.00 5,921,989.12 489,453.58 5.23 17,422.16 MWD+IFR-AK-CAZ-SC(7) 24,267.11 92.51 188.84 6,511.52 6,355.72 -16,221.64 -8,870.26 5,921,897.22 489,437.30 4.89 17,515.50 MWD+1FR-AK-CAZ-SC(7) 24,358.51 95.56 187.93 6,505.09 6,349.29 -16,311.83 -8,883.56 5,921,807.05 489,423.98 3.48 17,606.63 MWD+IFR-AK-CAZ-SC(7) 24,449.69 95.33 188.81 6,496.44 6,340.64 -16,401.63 -8,896.77 5,921,717.26 489,410.75 0.99 17,697.36 MWD+IFR-AK-CAZ-SC(7) 24,540.67 95.42 189.05 6,487.91 6,332.11 -16,491.11 -8,910.83 5,921,627.79 489,396.67 0.28 17,787.92 MWD+IFR-AK-CAZ-SC(7) 24,632.74 92.45 189.90 6,481.60 6,325.80 -16,581.70 -8,925.95 5,921,537.21 489,381.53 3.35 17,879.76 MWD+IFR-AK-CAZ-SC(7) 24,724.59 91.90 189.85 6,478.11 6,322.31 -16,672.12 -8,941.69 5,921,446.80 489,365.77 0.60 17,971.54 MWD+IFR-AK-CAZ-SC(7) 24,816.48 94.04 189.53 6,473.35 6,317.55 -16,762.57 -8,957.14 5,921,356.36 489,350.31 2.35 18,063.30 MWD+IFR-AK-CAZ-SC(7) 24,909.38 93.39 190.38 6,467.33 6,311.53 -16,853.88 -8,973.17 5,921,265.07 489,334.27 1.15 18,156.01 MWD+IFR-AK-CAZ-SC(7) 25,002.17 93.94 190.61 6,461.40 6,305.60 -16,944.93 -8,990.03 5,921,174.03 489,317.38 0.64 18,248.60 MWD+IFR-AK-CAZ-SC(7) 25,094.80 91.46 189.01 6,457.04 6,301.24 -17,036.10 -9,005.79 5,921,082.88 489,301.60 3.19 18,341.12 MWD+IFR-AK-CAZ-SC(7) 25,187.68 90.99 189.69 6,455.05 6,299.25 -17,127.72 -9,020.88 5,920,991.27 489,286.49 0.89 18,433.97 MWD+IFR-AK-CAZ-SC(7) 6/20/2017 8:51:37AM Page 9 COMPASS 5000.1 Build 74 a • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 25,277.53 91.82 190.01 6,452.85 6,297.05 -17,216.22 -9,036.25 5,920,902.78 489,271.11 0.99 18,523.79 MWD+IFR-AK-CAZ-SC(7) 25,369.47 91.62 190.71 6,450.09 6,294.29 -17,306.62 -9,052.77 5,920,812.39 489,254.56 0.79 18,615.69 MWD+IFR-AK-CAZ-SC(7) 25,465.03 91.39 189.64 6,447.58 6,291.78 -17,400.64 -9,069.65 5,920,718.38 489,237.67 1.14 18,711.21 MWD+1FR-AK-CAZ-SC(7) 25,534.53 92.87 192.88 6,444.99 6,289.19 -17,468.74 -9,083.21 5,920,650.29 489,224.10 5.12 18,780.64 MWD+IFR-AK-CAZ-SC(7) 25,598.00 92.87 192.88 6,441.82 6,286.02 -17,530.54 -9,097.34 5,920,588.50 489,209.96 0.00 18,843.95 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. [j Yes jjNo I have checked to the best of my ability that the following data is correct: Surface Coordinates I] Declination & Convergence ri GRS Survey Corrections E Survey Tool Codes SLB DE: 51.a iL /im 3' Jake Voss H'a'rem Client Representative: L.,.1rm, „ ..0>.1.0,x0.k., _ ,.. ...1 1.0 01Z.0677090M7.05.00 Date: 6/20/2017 6/20/2017 8.51.37AM Page 10 COMPASS 5000.1 Build 74 • • 21 7042 28325 RECEIVED JUN 29 2017 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-32 2K-32 NAD 83 Definitive Survey Report 19 June, 2017 • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual©155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 2K-32 Well Position +N/-S 0.00 usft Northing: 5,937,865.30 usft Latitude: 70°14'30.645 N +E/-W 0.00 usft Easting: 1,638,343.11 usft Longitude: 150°1'0.288 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 116.70 usft Wellbore 2K-32 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 5/13/2017 17.50 80.86 57.529 Design 2K-32 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.10 0.00 0.00 190.00 Survey Program Date 6/19/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 127.95 1,369.87 2K-32 Srvy 1-SLB_GWD70(2K-32) GYD-GC-SS Gyrodata gyro single shots 4/30/2017 8:23: 1,465.51 3,405.64 2K-32 Srvy 2-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/1/2017 8:26:1 3,490.68 3,490.68 2K-32 Srvy 3-SLB_MWD-INC-Filler(2K INC+TREND Inclinometer+known azi trend 5/5/2017 2:32:4 3,537.56 10,963.19 2K-32 Srvy 4-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/4/2017 2:51:3 11,063.99 13,674.55 2K-32 Srvy 5-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/14/2017 1:25: 13,719.35 13,719.35 2K-32 Srvy 6-SLB_MWD-INC-Filler(2K INC+TREND Inclinometer+known azi trend 5/24/2017 10:25 13,787.31 25,534.53 2K-32 Srvy 7-SLB_MWD+GMAG(2K-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/24/2017 10:28 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -116.70 0.00 0.00 5,937,865.30 1,638,343.11 0.00 0.00 UNDEFINED 127.95 0.21 42.66 127.95 -27.85 0.12 0.11 5,937,865.42 1,638,343.22 0.24 -0.14 GYD-GC-SS(1) 147.32 0.56 32.70 147.32 -8.48 0.23 0.19 5,937,865.53 1,638,343.30 1.83 -0.25 GYD-GC-SS(1) 183.06 0.76 56.16 183.06 27.26 0.50 0.48 5,937,865.81 1,638,343.59 0.93 -0.58 GYD-GC-SS(1) 243.18 1.49 87.81 243.17 87.37 0.76 1.59 5,937,866.06 1,638,344.70 1.55 -1.02 GYD-GC-SS(1) 273.18 1.86 91.16 273.15 117.35 0.76 2.47 5,937,866.06 1,638,345.58 1.28 -1.18 GYD-GC-SS(1) 303.35 2.20 98.41 303.30 147.50 0.67 3.53 5,937,865.97 1,638,346.64 1.41 -1.27 GYD-GC-SS(1) 335.22 2.93 103.77 335.14 179.34 0.38 4.92 5,937,865.69 1,638,348.04 2.41 -1.23 GYD-GC-SS(1) 367.71 3.80 111.21 367.58 211.78 -0.20 6.73 5,937,865.10 1,638,349.85 2.99 -0.97 GYD-GC-SS(1) 6/19/2017 2:01:15PM Page 2 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 398.79 4.69 115.57 398.57 242.77 -1.12 8.84 5,937,864.18 1.638,351.95 3.04 -0.43 GYD-GC-SS(1) 431.00 5.09 120.53 430.66 274.86 -2.42 11.26 5,937,862.88 1,638,354.37 1.81 0.43 GYD-GC-5S(1) 522.22 5.83 124.77 521.47 365.67 -7.12 18.55 5,937,858.18 1,638,361.66 0.92 3.79 GYD-GC-SS(1) 616.15 6.21 135.78 614.88 459.08 -13.48 26.01 5,937,851.82 1,638,369.12 1.29 8.76 GYD-GC-55(1) 710.84 5.43 136.59 709.08 553.28 -20.40 32.66 5,937,844.89 1,638,375.77 0.83 14.42 GYD-GC-SS(1) 803.24 8.40 128.70 800.80 645.00 -27.80 40.94 5,937,837.49 1,638,384.04 3.37 20.27 GYD-GC-SS(1) 898.89 8.84 127.91 895.37 739.57 -36.69 52.19 5,937,828.61 1,638,395.28 0.48 27.07 GYD-GC-SS(1) 993.31 10.03 129.51 988.52 832.72 -46.37 64.26 5,937,818.92 1,638,407.35 1.29 34.51 GYD-GC-SS(1) 1,086.49 12.71 130.99 1,079.86 924.06 -58.26 78.26 5,937,807.03 1,638,421.34 2.89 43.79 GYD-GC-SS(1) 1,182.83 15.50 130.74 1,173.28 1,017.48 -73.62 96.01 5,937,791.67 1,638,439.10 2.90 55.83 GYD-GC-SS(1) 1,276.11 18.31 130.08 1,262.52 1,106.72 -91.19 116.67 5,937,774.09 1,638,459.75 3.02 69.54 GYD-GC-SS(1) 1,369.87 22.04 127.89 1,350.52 1,194.72 -111.48 141.83 5,937,753.79 1,638,484.90 4.06 85.16 GYD-GC-SS(1) 1,465.51 26.77 129.82 1,437.59 1,281.79 -136.31 172.56 5,937,728.96 1,638,515.61 5.01 104.28 MWD+IFR-AK-CAZ-SC(2) 1,523.47 26.69 130.95 1,489.36 1,333.56 -153.20 192.41 5,937,712.06 1,638,535.46 0.89 117.46 MWD+1FR-AK-CAZ-5C(2) 1,559.12 26.85 130.49 1,521.18 1,365.38 -163.68 204.58 5,937,701.59 1,638,547.63 0.73 125.67 MWD+1FR-AK-CAZ-SC(2) 1,617.79 27.45 133.25 1,573.39 1,417.59 -181.55 224.51 5,937,683.71 1,638,567.55 2.38 139.80 MWD+1FR-AK-CAZ-5C(2) 1,712.07 28.91 139.14 1,656.51 1,500.71 -213.68 255.25 5,937,651.58 1,638,598.28 3.33 166.11 MWD+IFR-AK-CAZ-SC(2) 1,807.56 31.73 142.04 1,738.94 1,583.14 -250.94 285.81 5,937,614.31 1,638,628.82 3.33 197.50 MWD+1FR-AK-CAZ-5C(2) 1,903.21 33.29 142.70 1,819.59 1,663.79 -291.66 317.19 5,937,573.59 1,638,660.19 1.67 232.15 MWD+IFR-AK-CAZ-5C(2) 1,997.72 35.26 142.14 1,897.69 1,741.89 -333.83 349.65 5,937,531.41 1,638,692.64 2.11 268.04 MWD+1FR-AK-CAZ-SC(2) 2,091.55 36.12 144.95 1,973.90 1,818.10 -377.86 382.16 5,937,487.38 1,638,725.13 1.97 305.76 MWD+1FR-AK-CAZ-SC(2) 2,186.31 37.72 148.80 2,049.67 1,893.87 -425.53 413.22 5,937,439.70 1,638,756.17 2.97 347.31 MWD+IFR-AK-CAZ-SC(2) 2,281.00 39.00 150.95 2,123.92 1,968.12 -476.36 442.70 5,937,388.87 1,638,785.63 1.95 392.25 MWD+1FR-AK-CAZ-SC(2) 2,375.39 40.31 153.49 2,196.59 2,040.79 -529.65 470.75 5,937,335.58 1,638,813.67 2.21 439.86 MWD+IFR-AK-CAZ-SC(2) 2,469.17 41.49 157.22 2,267.49 2,111.69 -585.44 496.32 5,937,279.78 1,638,839.22 2.89 490.36 MWD+1FR-AK-CAZ-SC(2) 2,563.41 42.98 161.31 2,337.27 2,181.47 -644.67 518.71 5,937,220.56 1,638,861.59 3.32 544.80 MWD+IFR-AK-CAZ-5C(2) 2,659.17 44.91 165.09 2,406.23 2,250.43 -708.27 537.87 5,937,156.95 1,638,880.73 3.40 604.11 MW0+IFR-AK-CAZ-SC(2) 2,753.09 46.58 169.31 2,471.78 2,315.98 -773.85 552.73 5,937,091.38 1,638,895.58 3.68 666.11 MWD+1FR-AK-CAZ-5C(2) 2,848.07 48.12 174.03 2,536.15 2,380.35 -842.93 562.81 5,937,022.30 1,638,905.64 4.00 732.40 MWD+IFR-AK-CAZ-SC(2) 2,943.05 49.22 175.62 2,598.88 2,443.08 -913.96 569.24 5,936,951.28 1,638,912.04 1.71 801.23 MWD+1FR-AK-CAZ-SC(2) 3,036.49 47.43 177.13 2,661.01 2,505.21 -983.61 573.66 5,936,881.64 1,638,916.45 2.26 869.05 MWD+IFR-AK-CAZ-SC(2) 3,131.43 48.48 177.14 2,724.59 2,568.79 -1,054.02 577.19 5,936,811.23 1,638,919.95 1.11 937.78 MWD+IFR-AK-CAZ-SC(2) 3,225.65 46.69 177.62 2,788.14 2,632.34 -1,123.51 580.37 5,936,741.75 1,638,923.11 1.94 1,005.66 MWD+IFR-AK-CAZ-SC(2) 3,321.00 47.60 177.97 2,852.99 2,697.19 -1,193.35 583.06 5,936,671.91 1,638,925.78 0.99 1,073.98 MWD+IFR-AK-CAZ-SC(2) 3,405.64 50.81 178.33 2,908.28 2,752.48 -1,257.39 585.12 5,936,607.88 1,638,927.83 3.81 1,136.68 MWD+IFR-AK-CAZ-SC(2) 3,481.00 52.11 179.90 2,955.23 2,799.43 -1,316.32 586.02 5,936,548.95 1,638.928 71 2.38 1,194.56 NOT an Actual Survey 10 3/4"x 13-1/2" 3,490.68 52.28 180.10 2,961.17 2,805.37 -1,323.97 586.02 5,936,541.31 1,638,928.71 2.38 1,202.09 INC+TREND(3) 3,537.56 52.79 181.06 2,989.68 2,833.88 -1,361.18 585.64 5,936,504.10 1,638,928.32 1.96 1,238.80 MWD+IFR-AK-CAZ-5C(4) 3,585.25 52.72 182.13 3,018.55 2,862.75 -1,399.12 584.59 5,936,466.16 1,638,927.26 1.79 1,276.36 MWD+1FR-AK-CAZ-5C(4) 6/19/2017 2:01:15PM Page 3 COMPASS 5000 1 Build 74 1110 0 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 I Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,679.71 52.33 186.67 3,076.04 2,920.24 -1,473.83 578.85 5,936,391.46 1,638,921.50 3.84 1,350.93 MWD+IFR-AK-CAZ-SC(4) 3,775.79 51.86 192.44 3,135.09 2,979.29 -1,548.54 566.28 5,936,316.76 1,638,908.91 4.76 1,426.68 MWD+IFR-AK-CAZ-SC(4) 3,868.15 51.59 196.76 3,192.32 3,036.52 -1,618.68 548.02 5,936,246.64 1,638,890.63 3.68 1,498.92 MWD+IFR-AK-CAZ-SC(4) 3,964.44 51.81 202.32 3,252.03 3,096.23 -1,689.84 522.76 5,936,175.49 1,638,865.35 4.54 1,573.39 MWD+IFR-AK-CAZ-SC(4) 4,057.87 51.97 204.70 3,309.70 3,153.90 -1,757.24 493.44 5,936,108.10 1,638,836.01 2.01 1,644.86 MWD+IFR-AK-CAZ-SC(4) 4,153.07 51.94 209.63 3,368.39 3,212.59 -1,823.91 459.23 5,936,041.45 1,638,801.79 4.08 1,716.45 MWD+IFR-AK-CAZ-SC(4) 4,247.71 52.99 211.73 3,426.05 3,270.25 -1,888.44 420.93 5,935,976.94 1,638,763.48 2.08 1,786.66 MWD+IFR-AK-CAZ-SC(4) 4,341.98 54.45 215.14 3,481.84 3,326.04 -1,951.83 379.05 5,935,913.57 1,638,721.59 3.30 1,856.35 MWD+IFR-AK-CAZ-SC(4) 4,435.93 55.35 219.26 3,535.88 3,380.08 -2,013.02 332.58 5,935,852.39 1,638,675.11 3.71 1,924.69 MWD+IFR-AK-CAZ-SC(4) 4,530.41 55.82 222.58 3,589.29 3,433.49 -2,071.90 281.54 5,935,793.53 1,638,624.05 2.94 1,991.53 MWD+IFR-AK-CAZ-SC(4) 4,625.37 56.30 225.90 3,642.32 3,486.52 -2,128.32 226.58 5,935,737.13 1,638,569.09 2.94 2,056.64 MWD+IFR-AK-CAZ-SC(4) 4,720.39 57.24 228.83 3,694.40 3,538.60 -2,182.14 168.11 5,935,683.34 1,638,510.61 2.76 2,119.80 MWD+IFR-AK-CAZ-SC(4) 4,814.46 57.99 230.05 3,744.78 3,588.98 -2,233.79 107.76 5,935,631.71 1,638,450.25 1.35 2,181.14 MWD+IFR-AK-CAZ-SC(4) 4,908.78 59.91 231.94 3,793.43 3,637.63 -2,284.63 44.97 5,935,580.89 1,638,387.45 2.66 2,242.11 MWD+IFR-AK-CAZ-SC(4) 5,004.27 61.66 232.67 3,840.04 3,684.24 -2,335.59 -20.98 5,935,529.96 1,638,321,49 1.95 2,303.75 MWD+IFR-AK-CAZ-SC(4) 5,098.64 64.03 234.85 3,883.11 3,727.31 -2,385.20 -88.70 5,935,480.36 1,638,253.76 3.25 2,364.37 MWD+IFR-AK-CAZ-SC(4) 5,193.88 66.29 236.87 3,923.12 3,767.32 -2,433.69 -160.24 5,935,431.90 1,638,182.22 3.06 2,424.54 MWD+IFR-AK-CAZ-SC(4) 5,288.26 67.48 239.58 3,960.18 3,804.38 -2,479.39 -234.02 5,935,386.23 1,638,108.43 2.93 2,482,36 MWD+IFR-AK-CAZ-SC(4) 5,383.63 68.75 241.88 3,995.73 3,839.93 -2,522.64 -311.22 5,935,343.00 1,638,031.23 2.60 2,538.36 MWD+IFR-AK-CAZ-SC(4) 5,477.65 69.85 245.12 4,028.97 3,873.17 -2,561.87 -389.92 5,935,303.80 1,637,952.53 3.43 2,590.66 MWD+IFR-AK-CAZ-SC(4) 5,572.69 70.59 247.79 4,061.14 3,905.34 -2,597.59 -471.90 5,935,268,10 1,637,870.55 2.76 2,640.07 MWD+IFR-AK-CAZ-SC(4) 5,667.17 72.33 250.98 4,091.18 3,935.38 -2,629.11 -555.73 5,935,236.61 1,637,786.72 3.69 2,685.67 MWD+IFR-AK-CAZ-SC(4) 5,762.10 72.33 252.05 4,120.00 3,964.20 -2,657.79 -641.51 5,935,207.96 1,637,700.94 1.07 2,728.81 MWD+IFR-AK-CAZ-SC(4) 5,856.61 72.30 253.66 4,148.71 3,992.91 -2,684,33 -727.55 5,935,181.44 1,637,614.90 1.62 2,769.89 MWD+IFR-AK-CAZ-SC(4) 5,951.73 72.30 254.91 4,177.63 4,021.83 -2,708.87 -814.78 5,935,156.93 1,637,527.67 1.25 2,809.20 MWD+IFR-AK-CAZ-SC(4) 6,046.44 72.17 253.62 4,206.53 4,050.73 -2,733.33 -901.59 5,935,132.49 1,637,440.86 1.30 2,848.37 MWD+IFR-AK-CAZ-SC(4) 6,140.63 72.24 252.56 4,235.32 4,079.52 -2,759.42 -987.39 5,935,106.43 1,637,355.06 1.07 2,888.95 MWD+IFR-AK-CAZ-SC(4) 6,235.96 72.43 252.83 4,264.24 4,108.44 -2,786.44 -1,074.12 5,935,079.44 1,637,268.34 0.34 2,930.62 MWD+IFR-AK-CAZ-SC(4) 6,329.99 72.27 252.42 4,292.75 4,136.95 -2,813.19 -1,159.63 5,935,052.71 1,637,182.82 0.45 2,971.82 MWD+IFR-AK-CAZ-SC(4) 6,424,01 72.36 252.51 4,321.32 4,165,52 -2,840.18 -1,245.04 5,935,025.75 1,637,097.41 0.13 3,013.23 MWD+IFR-AK-CAZ-SC(4) 6,520.71 72.36 253.24 4,350.62 4,194.82 -2,867.32 -1,333.11 5,934,998.64 1,637,009.34 0.72 3,055.25 MWD+IFR-AK-CAZ-SC(4) 6,613.94 72.46 252.39 4,378.80 4,223.00 -2,893.58 -1,418.01 5,934,972.41 1,636,924.44 0.88 3,095.85 MWD+IFR-AK-CAZ-SC(4) 6,707.61 72.42 253.18 4,407.06 4,251.26 -2,920.01 -1,503.32 5,934,946.00 1,636,839.14 0.81 3,136.69 MWD+IFR-AK-CAZ-SC(4) 6,803.32 72.29 252.91 4,436.07 4,280.27 -2,946.60 -1,590.56 5,934,919,43 1,636,751.90 0.30 3,178.04 MWD+IFR-AK-CAZ-SC(4) 6,897.82 72.42 252.94 4,464.71 4,308.91 -2,973.05 -1,676.64 5,934,893.02 1,636,665.82 0.14 3,219.02 MWD+IFR-AK-CAZ-SC(4) 6,992.05 72.39 252.12 4,493.20 4,337.40 -3,000.01 -1,762.32 5,934,866.08 1,636,580.14 0.83 3,260.46 MWD+IFR-AK-CAZ-SC(4) 7,087.55 72.36 252.02 4,522.11 4,366.31 -3,028.03 -1,848.92 5,934,838.08 1,636,493,54 0.10 3,303.09 MWD+IFR-AK-CAZ-SC(4) 7,181.73 72.38 250.53 4,550.64 4,394.84 -3,056.84 -1,933.92 5,934,809.30 1,636,408.54 1.51 3,346.23 MWD+IFR-AK-CAZ-SC(4) 7,277.61 72.42 249,38 4,579.63 4,423.83 -3,088.17 -2,019.78 5,934,778.00 1,636,322.69 1.14 3,391.98 MWD+IFR-AK-CAZ-SC(4) 7,372.67 72.54 249.45 4,608.25 4,452.45 -3,120.04 -2,104,64 5,934,746.15 1,636,237.83 0.14 3,438.11 MWD+IFR-AK-CAZ-SC(4) 6/19/2017 2:01:15PM Page 4 COMPASS 5000.1 Build 74 • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey MD Inc Azi TVD TVDSS +N/_S +E/-W Map Map Vertical Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,466.70 72.42 249.82 4,636.55 4,480.75 -3,151.25 -2,188.70 5,934,714.98 1,636,153.76 0.40 3,483.43 MWD+IFR-AK-CAZ-SC(4) 7,561.59 72.51 250.18 4,665.14 4,509.34 -3,182.19 -2,273.73 5,934,684.06 1,636,068.74 0.37 3,528.68 MWD+IFR-AK-CAZ-SC(4) 7,656.11 72.48 250.22 4,693.57 4,537.77 -3,212.73 -2,358.54 5,934,653.55 1,635,983.92 0.05 3,573.47 MWD+IFR-AK-CAZ-SC(4) 7,750.65 72.48 251.44 4,722.04 4,566.24 -3,242.33 -2,443.69 5,934,623.97 1,635,898.77 1.23 3,617.41 MWD+IFR-AK-CAZ-SC(4) 7,845.23 72.30 251.15 4,750.65 4,594.85 -3,271.24 -2,529.08 5,934,595.09 1,635,813.39 0.35 3,660.71 MWD+IFR-AK-CAZ-SC(4) 7,939.83 72.27 251.23 4,779.43 4,623.63 -3,300.30 -2,614.38 5,934,566.06 1,635,728.09 0.09 3,704.14 MWD+IFR-AK-CAZ-SC(4) 8,034.74 72.30 251.08 4,808.31 4,652.51 -3,329.50 -2,699.94 5,934,536.88 1,635,642.52 0.15 3,747.76 MWD+IFR-AK-CAZ-SC(4) 8,129.25 72.34 251.13 4,837.02 4,681.22 -3,358.66 -2,785.14 5,934,507.75 1,635,557.33 0.07 3,791.27 MWD+IFR-AK-CAZ-SC(4) 8,224.42 72.39 250.99 4,865.85 4,710.05 -3,388.10 -2,870.92 5,934,478.34 1,635,471.54 0.15 3,835.15 MWD+IFR-AK-CAZ-SC(4) 8,318.72 72.57 251.87 4,894.24 4,738.44 -3,416.73 -2,956.17 5,934,449.72 1,635,386.30 0.91 3,878.16 MWD+IFR-AK-CAZ-SC(4) 8,412.38 72.44 252.53 4,922.39 4,766.59 -3,444.04 -3,041.22 5,934,422.44 1,635,301.25 0.69 3,919.82 MWD+IFR-AK-CAZ-SC(4) 8,508.39 72.45 252.59 4,951.35 4,795.55 -3,471.48 -3,128.55 5,934,395.04 1,635,213.92 0.06 3,962.00 MWD+IFR-AK-CAZ-5C(4) 8,603.53 72.39 252.29 4,980.09 4,824.29 -3,498.84 -3,215.02 5,934,367.70 1,635,127.45 0.31 4,003.97 MWD+IFR-AK-CAZ-SC(4) 8,698.22 72.33 251.97 5,008.78 4,852.98 -3,526.53 -3,300.90 5,934,340.03 1,635,041.57 0.33 4,046.15 MWD+IFR-AK-CAZ-SC(4) 8,792.87 72.45 251.87 5,037.42 4,881.62 -3,554.53 -3,386.66 5,934,312.06 1,634,955.81 0.16 4,088.61 MWD+IFR-AK-CAZ-SC(4) 8,886.58 72.48 251.95 5,065.65 4,909.85 -3,582.27 -3,471.60 5,934,284.34 1,634,870.87 0.09 4,130.69 MWD+IFR-AK-CAZ-SC(4) 8,982.52 72.48 252.42 5,094.53 4,938.73 -3,610.26 -3,558.70 5,934,256.38 1,634,783,77 0.47 4,173.38 MWD+IFR-AK-CAZ-SC(4) 9,076.94 72.51 252.54 5,122.93 4,967.13 -3,637.37 -3,644.57 5,934,229.30 1,634,697.90 0.13 4,214.99 MWD+IFR-AK-CAZ-SC(4) 9,171.60 72.58 ' 252.39 5,151.33 4,995.53 -3,664.58 -3,730.68 5,934,202.12 1,634,611.80 0.17 4,256.73 MWD+IFR-AK-CAZ-SC(4) 9,266.01 72.47 251.69 5,179.68 5,023.88 -3,692.35 -3,816.34 5,934,174.38 1,634,526.13 0.72 4,298.95 MWD+IFR-AK-CAZ-SC(4) 9,360.65 72.60 251.82 5,208.08 5,052.28 -3,720.61 -3,902.08 5,934,146.14 1,634,440.40 0.19 4,341.67 MWD+IFR-AK-CAZ-SC(4) 9,455.06 72.54 251.74 5,236.36 5,080.56 -3,748.77 -3,987.64 5,934,118.00 1,634,354.84 0.10 4,384.27 MWD+IFR-AK-CAZ-SC(4) 9,550.09 72.42 250.60 5,264.97 5,109.17 -3,778.02 -4,073.41 5,934,088.78 1,634,269,07 1.15 4,427.97 MWD+IFR-AK-CAZ-SC(4) 9,644.93 72.55 250.20 5,293.51 5,137.71 -3,808.36 -4,158.61 5,934,058.47 1,634,183.87 0.42 4,472.64 MWD+IFR-AK-CAZ-SC(4) 9,739.40 72.47 251.02 5,321.91 5,166.11 -3,838.27 -4,243.60 5,934,028.58 1,634,098.88 0.83 4,516.86 MWD+IFR-AK-CAZ-SC(4) 9,833.30 72.51 251.70 5,350.16 5,194.36 -3,866.90 -4,328.46 5,933,999.99 1,634,014.03 0.69 4,559.78 MWD+IFR-AK-CAZ-SC(4) 9,927.98 72.51 251.01 5,378.61 5,222.81 -3,895.77 -4,414,02 5,933,971.14 1,633,928.46 0.70 4,603.07 MWD+IFR-AK-CAZ-SC(4) 10,022.58 72.49 250.81 5,407.06 5,251.26 -3,925.27 -4,499.28 5,933,941.66 1,633,843.20 0.20 4,646.93 MWD+IFR-AK-CAZ-SC(4) 10,117.39 72.52 250.66 5,435.56 5,279.76 -3,955.11 -4,584.64 5,933,911.85 1,633,757.84 0.15 4,691.13 MWD+IFR-AK-CAZ-SC(4) 10,211.63 72.42 250.90 5,463,95 5,308.15 -3,984.69 -4,669.49 5,933,882.30 1,633,672.99 0.27 4,735.00 MWD+IFR-AK-CAZ-SC(4) 10,306.40 72.52 251.50 5,492.49 5,336.69 -4,013.81 -4,755.04 5,933,853.20 1,633,587.44 0.61 4,778.54 MWD+IFR-AK-CAZ-SC(4) 10,401.38 72.42 251.51 5,521.10 5,365.30 -4,042.54 -4,840.93 5,933,824.50 1,633,501.55 0.11 4,821.75 MWD+IFR-AK-CAZ-SC(4) 10,495.87 72.42 251.32 5,549.64 5,393.84 -4,071.25 -4,926.31 5,933,795,81 1,633,416.17 0.19 4,864.85 MWD+IFR-AK-CAZ-SC(4) 10,590,24 72.42 250.50 5,578.14 5,422.34 -4,100.67 -5,011.33 5,933,766.42 1,633,331.16 0.83 4,908.58 MWD+IFR-AK-CAZ-SC(4) 10,684.97 72.51 250.09 5,606.69 5,450.89 -4,131.13 -5,096.36 5,933,735.99 1,633,246.12 0.42 4,953.34 MWD+IFR-AK-CAZ-SC(4) 10,779.98 72.36 250.07 5,635.36 5,479,56 -4,161.99 -5,181.53 5,933,705.15 1,633,160.96 0.16 4,998.52 MWD+IFR-AK-CAZ-SC(4) 10,874.70 72.40 250,21 5,664.03 5,508.23 -4,192.66 -5,266.43 5,933,674.51 1,633,076.05 0.15 5,043.47 MWD+IFR-AK-CAZ-SC(4) 10,963.19 72.09 249.81 5,691.02 5,535.22 -4,221.47 -5,345.63 5,933,645.73 1,632,996.86 0.56 5,085.60 MWD+IFR-AK-CAZ-SC(4) 11,063.99 72.15 248.96 5,721.96 5,566.16 -4,255.25 -5,435.42 5,933,611.98 1,632,907.07 0.80 5,134.45 MWD+IFR-AK-CAZ-SC(5) 11,109.45 72.45 249.34 5,735.79 5,579.99 -4,270.66 -5,475.89 5,933,596.58 1,632,866.60 1.03 5,156.66 MWD+IFR-AK-CAZ-SC(5) 6/19/2017 2:01:15PM Page 5 COMPASS 5000.1 Build 74 • i 0 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 11,159.39 72.31 250.52 5,750.90 5,595.10 -4,286.99 -5,520.60 5,933,580.26 1,632,821.89 2.27 5,180.51 MWD+IFR-AK-CAZ-SC(5) 11,253.06 72.32 251.74 5,779.36 5,623.56 -4,315.86 -5,605.04 5,933,551.42 1,632,737.45 1.24 5,223.59 MWD+IFR-AK-CAZ-SC(5) 11,348.98 72.23 251.92 5,808.56 5,652.76 -4,344.35 -5,691.85 5,933,522.96 1,632,650.64 0.20 5,266.73 MWD+1FR-AK-CAZ-SC(5) 11,442.72 72.22 251.96 5,837.18 5,681.38 -4,372.02 -5,776.72 5,933,495.31 1,632,565.77 0.04 5,308.72 MWD+IFR-AK-CAZ-SC(5) 11,538.39 72.07 251.10 5,866.51 5,710.71 -4,400.87 -5,863.09 5,933,466.49 1,632,479.40 0.87 5,352.13 MWD+1FR-AK-CAZ-SC(5) 11,632.89 72.23 251.20 5,895.48 5,739.68 -4,429.93 -5,948.22 5,933,437.45 1,632,394.27 0.20 5,395.53 MWD+1FR-AK-CAZ-SC(5) 11,727.15 72.26 250.51 5,924.22 5,768.42 -4,459.37 -6,033.02 5,933,408.04 1,632,309.47 0.70 5,439.25 MWD+1FR-AK-CAZ-SC(5) 11,822.13 72.13 250.61 5,953.27 5,797.47 -4,489.47 -6,118.30 5,933,377.97 1,632,224.19 0.17 5,483.70 MWD+1FR-AK-CAZ-SC(5) 11,917.49 72.35 250.77 5,982.35 5,826.55 -4,519.50 -6,204.00 5,933,347.96 1,632,138.49 0.28 5,528.15 MWD+1FR-AK-CAZ-SC(5) 12,012.12 72.28 248.92 6,011.10 5,855.30 -4,550.56 -6,288.63 5,933,316.92 1,632,053.85 1.86 5,573.44 MWD+1FR-AK-CAZ-SC(5) 12,106.98 72.62 245.54 6,039.72 5,883.92 -4,585.57 -6,372.01 5,933,281.95 1,631,970.47 3.42 5,622.39 MWD+IFR-AK-CAZ-SC(5) 12,201.76 73.14 241.73 6,067.63 5,911.83 -4,625.79 -6,453.15 5,933,241.76 1,631,889.33 3.88 5,676.09 MWD+1FR-AK-CAZ-SC(5) 12,296.53 73.95 237.55 6,094.48 5,938.68 -4,671.72 -6,531.55 5,933,195.85 1,631,810.93 4.32 5,734.94 MWD+IFR-AK-CAZ-SC(5) 12,391.16 75.12 235.47 6,119.72 5,963.92 -4,722.04 -6,607.61 5,933,145.55 1,631,734.87 2.45 5,797.70 MWD+1FR-AK-CAZ-SC(5) 12,485.42 75.75 230.26 6,143.44 5,987.64 -4,777.10 -6,680.31 5,933,090.52 1,631,662.16 5.39 5,864.55 MWD+1FR-AK-CAZ-SC(5) 12,579.88 75.83 225.23 6,166.64 6,010.84 -4,838.65 -6,748.06 5,933,028.99 1,631,594.40 5.16 5,936.93 MWD+IFR-AK-CAZ-SC(5) 12,674.56 75.85 221.77 6,189.81 6,034.01 -4,905.24 -6,811.24 5,932,962.43 1,631,531.20 3.54 6,013.47 MWD+1FR-AK-CAZ-SC(5). 12,769.60 76.26 220.55 6,212.71 6,056.91 -4,974.68 -6,871.95 5,932,893.01 1,631,470.48 1.32 6,092.40 MWD+1FR-AK-CAZ-SC(5) 12,863.92 77.09 218.97 6,234.45 6,078.65 -5,045.23 -6,930.64 5,932,822.48 1,631,411.78 1.85 6,172.08 MWD+1FR-AK-CAZ-SC(5) 12,958.66 77.70 215.53 6,255.13 6,099.33 -5,118.82 -6,986.59 5,932,748.92 1,631,355.81 3.60 6,254.26 MWD+1FR-AK-CAZ-SC(5) 13,052.89 78.53 212.05 6,274.54 6,118.74 -5,195.44 -7,037.86 5,932,672.32 1,631,304.52 3.72 6,338.62 MWD+IFR-AK-CAZ-5C(5) 13,147.41 79.06 209.09 6,292.91 6,137.11 -5,275.26 -7,085.01 5,932,592.52 1,631,257.36 3.12 6,425.42 MWD+1FR-AK-CAZ-SC(5) 13,241.62 80.53 205.09 6,309.61 6,153.81 -5,357.79 -7,127.22 5,932,510.01 1,631,215.13 4.46 6,514.02 MWD+IFR-AK-CAZ-SC(5) 13,336.63 81.54 200.96 6,324.42 6,168.62 -5,444.15 -7,163.91 5,932,423.67 1,631,178.42 4.42 6,605.44 MWD+IFR-AK-CAZ-SC(5) 13,431.33 83.63 196.64 6,336.65 6,180.85 -5,533.02 -7,194.16 5,932,334.82 1,631,148.15 5.03 6,698.21 MWD+1FR-AK-CAZ-SC(5) 13,525.38 83.58 192.16 6,347.13 6,191.33 -5,623.53 -7,217.40 5,932,244.33 1,631,124.89 4.73 6,791.38 MWD+1FR-AK-CAZ-SC(5) 13,619.60 85.20 189.07 6,356.34 6,200.54 -5,715.68 -7,234.66 5,932,152.19 1,631,107.60 3.69 6,885.13 MWD+IFR-AK-CAZ-SC(5) 13,674.55 86.64 188.88 6,360.25 6,204.45 -5,769.81 -7,243.21 5,932,098.06 1,631,099.04 2.64 6,939.93 MWD+1FR-AK-CAZ-SC(5) 13,719.35 86.99 189.25 6,362.74 6,206.94 -5,813.99 -7,250.26 5,932,053.89 1,631,091.98 1.14 6,984.65 INC+TREND(6) 13,728.00 87.25 189.32 6,363.18 6,207.38 -5,822.51 -7,251.66 5,932,045.37 1,631,090.58 3.16 6,993.29 NOT an Actual Survey 7-5/8"x 9-7/8-11" 13,787.31 89.06 189.82 6,365.08 6,209.28 -5,880.96 -7,261.51 5,931,986.93 1,631,080.71 3.16 7,052.57 MWD+IFR-AK-CAZ-SC(7) 13,877.43 89.39 188.39 6,366.30 6,210.50 -5,969.94 -7,275.77 5,931,897.97 1,631,066.43 1.63 7,142.66 MWD+IFR-AK-CAZ-SC(7) 13,971.54 88.43 187.28 6,368.09 6,212.29 -6,063.15 -7,288.60 5,931,804.77 1,631,053.58 1.56 7,236.69 MWD+1FR-AK-CAZ-SC(7) 14,023.06 88.43 188.41 6,369.50 6,213.70 -6,114.17 -7,295.63 5,931,753.76 1,631,046.53 2.19 7,288.15 MWD+1FR-AK-CAZ-5C(7) 14,066.69 88.60 188.04 6,370.63 6,214.83 -6,157.33 -7,301.87 5,931,710.59 1,631,040.28 0.93 7,331.75 MWD+IFR-AK-CAZ-SC(7) 14,114.52 88.97 187.77 6,371.65 6,215.85 -6,204.70 -7,308.44 5,931,663.24 1,631,033.69 0.96 7,379.53 MWD+1FR-AK-CAZ-SC(7) 14,160.75 89.08 187.85 6,372.44 6,216.64 -6,250.49 -7,314.72 5,931,617.45 1,631,027.40 0.29 7,425.72 MWD+1FR-AK-CAZ-SC(7) 14,210.24 89.01 187.78 6,373.26 6,217.46 -6,299.52 -7,321.45 5,931,568.43 1,631,020.66 0.20 7,475.17 MWD+1FR-AK-CAZ-5C(7) 14,253.61 89.18 186.62 6,373.95 6,218.15 -6,342.54 -7,326.89 5,931,525.42 1,631,015.21 2.70 7,518.48 MWD+1FR-AK-CAZ-SC(7) 6/19/2017 2:01:15PM Page 6 COMPASS 5000.1 Build 74 • • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,347.94 89.39 185.63 6,375.12 6,219.32 -6,436.32 -7,336.95 5,931,431.64 1,631,005.12 1.07 7,612.59 MWD+IFR-AK-CAZ-SC(7) 14,442.45 89.90 183.92 6,375.71 6,219.91 -6,530.50 -7,344.82 5,931,337.48 1,630,997.23 1.89 7,706.70 MWD+IFR-AK-CAZ-SC(7) 14,483.90 90.41 183.68 6,375.60 6,219.80 -6,571.86 -7,347.57 5,931,296.13 1,630,994.47 1.36 7,747.91 MWD+IFR-AK-CAZ-SC(7) 14,537.38 90.62 182.48 6,375.12 6,219.32 -6,625.26 -7,350.44 5,931,242.73 1,630,991.59 2.28 7,800.99 MWD+IFR-AK-CAZ-SC(7) 14,632.47 91.35 184.28 6,373.48 6,217.68 -6,720.16 -7,356.04 5,931,147.84 1,630,985.96 2.04 7,895,43 MWD+IFR-AK-CAZ-SC(7) 14,727.54 90.00 185.76 6,372.36 6,216,56 -6,814.86 -7,364.36 5,931,053.16 1,630,977.61 2.11 7,990.13 MWD+IFR-AK-CAZ-SC(7) 14,822.97 89.63 186.35 6,372.67 6,216.87 -6,909.75 -7,374.43 5,930,958.27 1,630,967.52 0.73 8,085.33 MWD+IFR-AK-CAZ-SC(7) 14,917.39 89.45 188.55 6,373.43 6,217.63 -7,003.37 -7,386.67 5,930,864.67 1,630,955.25 2.34 8,179.65 MWD+IFR-AK-CAZ-SC(7) 15,012.09 89.15 188.40 6,374.58 6,218.78 -7,097.03 -7,400.63 5,930,771.02 1,630,941.27 0.35 8,274.31 MWD+IFR-AK-CAZ-SC(7) 15,106.46 89.80 189.75 6,375.45 6,219.65 -7,190.21 -7,415.51 5,930,677.86 1,630,926.37 1.59 8,368.66 MWD+IFR-AK-CAZ-SC(7) 15,202.17 88.80 190.27 6,376.62 6,220.82 -7,284.45 -7,432.14 5,930,583.62 1,630,909.71 1.18 8,464.36 MWD+IFR-AK-CAZ-SC(7) 15,297.52 87,76 190.23 6,379.48 6,223.68 -7,378.24 -7,449.10 5,930,489.85 1,630,892.72 1.09 8,559.67 MWD+IFR-AK-CAZ-SC(7) 15,392.52 88.25 191.05 6,382.79 6,226.99 -7,471.55 -7,466.63 5,930,396.56 1,630,875.17 1.01 8,654.60 MWD+1FR-AK-CAZ-SC(7) 15,485.83 87.91 188.80 6,385.91 6,230.11 -7,563.40 -7,482.71 5,930,304.72 1,630,859.07 2.44 8,747.85 MWD+IFR-AK-CAZ-SC(7) 15,580.16 88.01 188.02 6,389.27 6,233.47 -7,656.66 -7,496.49 5,930,211.47 1,630,845.26 0.83 8,842.09 MWD+IFR-AK-CAZ-SC(7) 15,630.76 88.49 188.56 6,390.82 6,235.02 -7,706.70 -7,503.79 5,930,161.43 1,630,837.96 1.43 8,892.64 MWD+IFR-AK-CAZ-SC(7) 15,675.24 88.63 188,37 6,391.93 6,236.13 -7,750.69 -7,510.33 5,930,117.46 1,630,831.40 0.53 8,937.09 MWD+IFR-AK-CAZ-SC(7) 15,770.26 88.66 188.06 6,394.18 6,238.38 -7,844.70 -7,523.90 5,930,023.45 1,630,817.80 0.33 9,032.04 MWD+IFR-AK-CAZ-SC(7) 15,864.74 89.73 187.35 6,395.51 6,239.71 -7,938.32 -7,536.57 5,929,929.85 1,630,805.11 1.36 9,126.43 MWD+IFR-AK-CAZ-SC(7) 15,959.55 90.72 187.78 6,395.14 6,239.34 -8,032.30 -7,549.05 5,929,835.88 1,630,792.61 1.14 9,221.15 MWD+IFR-AK-CAZ-SC(7) 16,054.41 91.17 187.46 6,393.57 6,237.77 -8,126.31 -7,561.63 5,929,741.88 1,630,780.00 0.58 9,315.92 MWD+IFR-AK-CAZ-SC(7) 16,149.67 90.55 188.15 6,392.14 6,236.34 -8,220.68 -7,574.56 5,929,647.53 1,630,767.05 0.97 9,411,10 MWD+IFR-AK-CAZ-SC(7) 16,244.29 90.21 187.72 6,391.51 6,235.71 -8,314.39 -7,587.63 5,929,553.83 1,630,753.96 0.58 9,505.65 MWD+IFR-AK-CAZ-SC(7) 16,338.98 90.24 189.11 6,391.14 6,235.34 -8,408.06 -7,601.48 5,929,460.18 1,630,740.08 1.47 9,600.30 MWD+IFR-AK-CAZ-SC(7) 16,432.99 90.17 190.02 6,390.81 6,235.01 -8,500.76 -7,617.10 5,929,367.49 1,630,724.43 0.97 9,694.31 MWD+IFR-AK-CAZ-SC(7) 16,527.54 89.80 190.69 6,390.83 6,235.03 -8,593.77 -7,634.10 5,929,274.49 1,630,707.41 0.81 9,788.86 MWD+IFR-AK-CAZ-SC(7) 16,620.84 89.25 192.96 6,391.60 6,235.80 -8,685.08 -7,653.22 5,929,183.20 1,630,688.27 2.50 9,882.10 MWD+IFR-AK-CAZ-5C(7) 16,716.08 87.77 193.51 6,394.08 6,238.28 -8,777.75 -7,675.01 5,929,090.54 1,630,666.45 1.66 9,977.15 MWD+IFR-AK-CAZ-5C(7) 16,811.25 86.01 195.43 6,399.24 6,243.44 -8,869.76 -7,698.75 5,928,998.55 1,630,642.69 2.73 10,071.89 MWD+IFR-AK-CAZ-SC(7) 16,906.30 86.16 194.67 6,405.73 6,249.93 -8,961.34 -7,723.38 5,928,906.99 1,630,618.04 0.81 10,166.34 MWD+IFR-AK-CAZ-SC(7) 17,000.16 85.89 194.34 6,412.24 6,256.44 -9,051.99 -7,746.83 5,928,816.35 1,630,594.57 0.45 10,259.69 MWD+IFR-AK-CAZ-SC(7) 17,095.53 89.33 192.62 6,416.22 6,260.42 -9,144.63 -7,769.03 5,928,723.72 1,630,572.34 4.03 10,354.78 MWD+IFR-AK-CAZ-SC(7) 17,189.37 90.19 191.02 6,416.61 6,260.81 -9,236.48 -7,788.26 5,928,631.89 1,630,553.09 1,94 10,448.57 MWD+IFR-AK-CAZ-SC(7) 17,283.34 88.48 189.27 6,417.70 6,261.90 -9,328.97 -7,804.81 5,928,539.42 1,630,536.52 2.60 10,542.53 MWD+IFR-AK-CAZ-SC(7) 17,378.86 89.01 187.65 6,419.79 6,263,99 -9,423.42 -7,818.85 5,928,444.98 1,630,522.45 1.78 10,637.99 MWD+IFR-AK-CAZ-SC(7) 17,473,79 89.28 187.25 6,421.21 6,265.41 -9,517.54 -7,831.16 5,928,350.87 1,630,510.12 0.51 10,732.81 MW0+IFR-AK-CAZ-SC(7) 17,568.63 89.04 186.98 6,422.60 6,266.80 -9,611,64 -7,842.91 5,928,256.79 1,630,498.35 0.38 10,827.52 MWD+IFR-AK-CAZ-SC(7) 17,663.28 88.70 186.63 6,424.47 6,268.67 -9,705.60 -7,854.12 5,928,162.83 1,630,487.11 0.52 10,922.01 MWD+IFR-AK-CAZ-5C(7) 17,759.29 87.93 186.96 6,427.29 6,271.49 -9,800.90 -7,865.47 5,928,067.55 1,630,475.73 0.87 11,017.82 MWD+IFR-AK-CAZ-SC(7) 17,854.14 88,49 187.52 6,430.25 6,274.45 -9,894.94 -7,877.42 5,927,973.52 1,630,463.76 0.83 11,112.52 MWD+IFR-AK-CAZ-SC(7) 6/19/2017 2:01:15PM Page 7 COMPASS 5000.1 Build 74 0 • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 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 17,948.57 88.67 189.58 6,432.59 6,276.79 -9,988.29 -7,891.46 5,927,880.18 1,630,449.70 2.19 11,206.88 MWD+IFR-AK-CAZ-SC(7) 18,043.69 89.11 191.36 6,434.44 6,278.64 -10,081.80 -7,908.74 5,927,786.68 1,630,432.39 1.93 11,301.98 MWD+IFR-AK-CAZ-SC(7) 18,138.00 88.70 190.75 6,436.24 6,280.44 -10,174.35 -7,926.82 5,927,694.16 1,630,414.29 0.78 11,396.25 MWD+IFR-AK-CAZ-SC(7) 18,233.38 89.25 190.30 6,437.94 6,282.14 -10,268.11 -7,944.24 5,927,600.41 1,630,396.84 0.75 11,491.61 MWD+IFR-AK-CAZ-SC(7) 18,328.13 90.24 190.90 6,438.37 6,282.57 -10,361.24 -7,961.67 5,927,507.29 1,630,379.39 1.22 11,586.35 MWD+IFR-AK-CAZ-SC(7) 18,422.06 90.28 190.96 6,437.94 6,282.14 -10,453.46 -7,979.48 5,927,415.08 1,630,361.56 0.08 11,680.27 MWD+1FR-AK-CAZ-SC(7) 18,516.78 91.31 190.78 6,436.63 6,280.83 -10,546.47 -7,997.34 5,927,322.09 1,630,343.67 1.10 11,774.97 MWD+IFR-AK-CAZ-SC(7) 18,611.64 91.17 191.53 6,434.57 6,278.77 -10,639.52 -8,015.69 5,927,229.06 1,630,325.30 0.80 11,869.79 MWD+IFR-AK-CAZ-SC(7) 18,706.70 91.07 191.84 6,432.71 6,276.91 -10,732.59 -8,034.93 5,927,136.00 1,630,306.03 0.34 11,964.79 MWD+IFR-AK-CAZ-SC(7) 18,801.23 91.17 191.40 6,430.87 6,275.07 -10,825.16 -8,053.97 5,927,043.44 1,630,286.97 0.48 12,059.26 MWD+IFR-AK-CAZ-SC(7) 18,896.08 90.62 191.59 6,429.39 6,273.59 -10,918.10 -8,072.87 5,926,950,52 1,630,268.05 0.61 12,154.07 MWD+IFR-AK-CAZ-SC(7) 18,991.01 90.62 191.01 6,428.36 6,272.56 -11,011.18 -8,091.47 5,926,857.45 1,630,249.42 0.61 12,248.97 MWD+IFR-AK-CAZ-SC(7) 19,085.09 90.07 190.57 6,427.79 6,271.99 -11,103.60 -8,109.08 5,926,765.05 1,630,231.79 0.75 12,343.04 MWD+IFR-AK-CAZ-SC(7) 19,179.20 90.35 189.66 6,427.45 6,271.65 -11,196.24 -8,125.61 5,926,672.42 1,630,215.23 1.01 12,437.14 MWD+IFR-AK-CAZ-SC(7) 19,274.07 89.39 188.89 6,427.66 6,271.86 -11,289.87 -8,140.90 5,926,578.80 1,630,199.92 1.30 12,532.01 MWD+tFR-AK-CAZ-SC(7) 19,369.80 89.42 187.56 6,428.66 6,272.86 -11,384.61 -8,154.59 5,926,484.08 1,630,186.20 1.39 12,627.68 MWD+IFR-AK-CAZ-SC(7) 19,463.30 89.73 186.26 6,429.35 6,273.55 -11,477.43 -8,165.84 5,926,391.27 1,630,174.93 1.43 12,721.04 MWD+IFR-AK-CAZ-SC(7) 19,558.56 90.64 185.36 6,429.04 6,273.24 -11,572.19 -8,175.49 5,926,296.52 1,630,165.26 1.34 12,816.04 MWD+IFR-AK-CAZ-SC(7) 19,652.88 88.61 185.12 6,429.66 6,273.86 -11,666.11 -8,184.10 5,926,202.61 1,630,156.62 2.17 12,910.03 MWD+IFR-AK-CAZ-SC(7) 19,746.98 88.70 185.83 6,431.87 6,276.07 -11,759.76 -8,193.07 5,926,108.98 1,630,147.62 0.76 13,003.81 MWD+IFR-AK-CAZ-SC(7) 19,841.59 88.39 187.18 6,434.27 6,278.47 -11,853.72 -8,203.79 5,926,015.02 1,630,136.88 1.46 13,098.21 MWD+IFR-AK-CAZ-SC(7) 19,936.78 88.77 189.02 6,436.63 6,280.83 -11,947.93 -8,217.20 5,925,920.83 1,630,123.45 1.97 13,193.32 MWD+IFR-AK-CAZ-SC(7) 20,031.06 89.32 192.19 6,438.20 6,282.40 -12,040.58 -8,234.54 5,925,828.20 1,630,106.08 3.41 13,287.57 MWD+IFR-AK-CAZ-SC(7) 20,126.97 89.18 195.03 6,439.46 6,283.66 -12,133.78 -8,257.11 5,925,735.01 1,630,083.49 2.96 13,383.27 MWD+IFR-AK-CAZ-SC(7) 20,221.52 89.32 194.36 6,440.70 6,284.90 -12,225.22 -8,281.09 5,925,643.58 1,630,059.49 0.72 13,477.49 MWD+IFR-AK-CAZ-SC(7) 20,316.23 87.93 192.33 6,442.97 6,287.17 -12,317.34 -8,302.94 5,925,551.48 1,630,037.61 2.60 13,572.01 MWD+IFR-AK-CAZ-SC(7) 20,411.32 88.15 190.97 6,446.22 6,290.42 -12,410.42 -8,322.13 5,925,458.42 1,630,018.40 1.45 13,667.00 MWD+IFR-AK-CAZ-SC(7) 20,505.38 89.35 189.21 6,448.27 6,292.47 -12,503.00 -8,338.61 5,925,365.85 1,630,001.90 2.26 13,761.03 MWD+IFR-AK-CAZ-SC(7) 20,601.13 91.19 185.89 6,447.82 6,292.02 -12,597.90 -8,351.19 5,925,270.96 1,629,989.30 3.96 13,856.68 MWD+IFR-AK-CAZ-SC(7) 20,695.81 90.28 185.17 6,446.61 6,290.81 -12,692.13 -8,360.31 5,925,176.75 1,629,980.15 1.23 13,951.06 MWD+IFR-AK-CAZ-SC(7) 20,790.41 89.90 184.11 6,446.46 6,290.66 -12,786.42 -8,367.96 5,925,082.47 1,629,972.47 1.19 14,045.24 MWD+IFR-AK-CAZ-SC(7) 20,883.89 89.80 185.22 6,446.70 6,290.90 -12,879.58 -8,375.56 5,924,989.31 1,629,964.84 1.19 14,138.32 MWD+IFR-AK-CAZ-SC(7) 20,979.16 89.76 186.13 6,447.07 6,291.27 -12,974.39 -8,384.98 5,924,894.52 1,629,955.40 0.96 14,233.31 MWD+IFR-AK-CAZ-SC(7) 21,074.14 89.21 188.12 6,447.92 6,292.12 -13,068.62 -8,396.76 5,924,800.30 1,629,943.59 2.17 14,328.16 MWD+IFR-AK-CAZ-SC(7) 21,168.19 89.69 187.93 6,448.83 6,293.03 -13,16175 -8,409.89 5,924,707.19 1,629,930.44 0.55 14,422.15 MWD+IFR-AK-CAZ-SC(7) 21,263.09 89.66 189.39 6,449.36 6,293.56 -13,255.56 -8,424.18 5,924,613.38 1,629,916.13 1.54 14,517.02 MWD+IFR-AK-CAZ-SC(7) 21,357.63 89.93 189.80 6,449.70 6,293.90 -13,348.78 -8,439.94 5,924,520.18 1,629,900.34 0.52 14,611.56 MWD+IFR-AK-CAZ-SC(7) 21,452.75 89.32 191.00 6,450.32 6,294.52 -13,442.33 -8,457.11 5,924,426.64 1,629,883.15 1.42 14,706.67 MWD+IFR-AK-CAZ-SC(7) 21,547.33 88.60 190.36 6,452.04 6,296.24 -13,535.26 -8,474.64 5,924,333.73 1,629,865.60 1.02 14,801.23 MWD+IFR-AK-CAZ-SC(7) 21,640.81 88.84 188.51 6,454.13 6,298.33 -13,627.45 -8,489.95 5,924,241.56 1,629,850.26 2.00 14,894.68 MWD+IFR-AK-CAZ-SC(7) 6/19/2017 2:01:15PM Page 8 COMPASS 5000.1 Build 74 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual©155.80usft(Doyon 142) Well: 2K-32 North Reference: True . Wellbore: 2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 21,735.22 88.94 188.06 6,455.96 6,300.16 -13,720.85 -8,503.56 5,924,148.16 1,629,836.63 0.49 14,989.03 MWD+1FR-AK-CAZ-SC(7) 21,830.75 88.94 187.71 6,457.73 6,301.93 -13,815.46 -8,516.66 5,924,053.57 1,629,823.50 0.37 15,084.48 MWD+IFR-AK-CAZ-SC(7) 21,924.89 88.08 186.56 6,460.17 6,304.37 -13,908.84 -8,528.35 5,923,960.20 1,629,811.79 1,53 15,178.47 MWD+IFR-AK-CAZ-SC(7) 22,021.01 87.57 187.90 6,463.82 6,308.02 -14,004.12 -8,540.44 5,923,864.93 1,629,799.68 1.49 15,274.40 MWD+IFR-AK-CAZ-SC(7) 22,116.35 87.89 187.65 6,467.60 6,311.80 -14,098.51 -8,553.32 5,923,770.55 1,629,786.77 0.43 15,369.59 MWD+IFR-AK-CAZ-SC(7) 22,210.68 91.25 186.66 6,468.31 6,312.51 -14,192.09 -8,565.07 5,923,676.99 1,629,774.99 3.71 15,463.79 MWD+IFR-AK-CAZ-SC(7) 22,304.87 92.37 187.06 6,465.33 6,309.53 -14,285.56 -8,576.31 5,923,583.53 1,629,763.73 1.26 15,557.79 MWD+IFR-AK-CAZ-SC(7) 22,400.27 92.49 186.41 6,461.29 6,305.49 -14,380.21 -8,587.49 5,923,488.89 1,629,752.52 0.69 15,652.95 MWD+IFR-AK-CAZ-SC(7) 22,495.22 90.69 186.64 6,458.65 6,302.85 -14,474.51 -8,598.28 5,923,394.61 1,629,741.71 1.91 15,747.68 MWD+IFR-AK-CAZ-SC(7) 22,589.97 88.65 185.53 6,459.20 6,303.40 -14,568.72 -8,608.32 5,923,300.41 1,629,731.64 2.45 15,842.21 MWD+1FR-AK-CAZ-SC(7) 22,684.85 88.41 186.85 6,461.63 6,305.83 -14,663.01 -8,618.55 5,923,206.13 1,629,721.39 1.41 15,936.84 MWD+IFR-AK-CAZ-SC(7) 22,779.13 89.49 187.94 6,463.36 6,307.56 -14,756.49 -8,630.68 5,923,112.67 1,629,709.24 1.63 16,031.01 MWD+1FR-AK-CAZ-SC(7) 22,873.99 89.39 188.94 6,464.29 6,308.49 -14,850.32 -8,644.60 5,923,018.85 1,629,695.29 1.06 16,125.83 MWD+IFR-AK-CAZ-SC(7) 22,968.69 90.04 191.10 6,464.76 6,308.96 -14,943.56 -8,661.08 5,922,925.62 1,629,678.79 2.38 16,220.52 MWD+1FR-AK-CAZ-SC(7) 23,061.70 89.04 192.10 6,465.50 6,309.70 -15,034.67 -8,679.78 5,922,834.53 1,629,660.06 1.52 16,313.49 MWD+IFR-AK-CAZ-SC(7) 23,119.00 87,70 192.29 6,467.13 6,311.33 -15,090.65 -8,691.88 5,922,778.55 1,629,647.95 2.35 16,370.72 NOT an Actual Survey 4 1/2"x 6-3/4" 23,156.52 86.83 192.41 6,468.92 6,313.12 -15,127.26 -8,699.89 5,922,741.95 1,629,639.93 2.35 16,408.17 MWD+IFR-AK-CAZ-SC(7) 23,252.79 86.36 192.06 6,474.64 6,318.84 -15,221.18 -8,720.26 5,922,648.05 1,629,619.54 0.61 16,504.19 MWD+IFR-AK-CAZ-SC(7) 23,347.54 86.43 192.64 6,480.60 6,324.80 -15,313.55 -8,740.48 5,922,555.69 1,629,599.29 0.62 16,598.67 MWD+1FR-AK-CAZ-SC(7) 23,437.58 87.04 192.17 6,485.72 6,329.92 -15,401.35 -8,759.79 5,922,467.91 1,629,579.96 0.85 16,688.49 MWD+IFR-AK-CAZ-SC(7) 23,530.32 88.94 194.04 6,488.98 6,333.18 -15,491.61 -8,780.81 5,922,377.66 1,629,558.92 2.87 16,781.03 MWD+IFR-AK-CAZ-SC(7) 23,622.19 87.84 188.38 6,491.56 6,335.76 -15,581.65 -8,798.65 5,922,287.63 1,629,541.05 6.27 16,872.80 MWD+IFR-AK-CAZ-SC(7) 23,714.94 87.67 185.32 6,495.19 6,339.39 -15,673.66 -8,809.71 5,922,195.64 1,629,529.98 3.30 16,965.33 MWD+IFR-AK-CAZ-SC(7) 23,805.93 87.50 184.16 6,499.03 6,343.23 -15,764.25 -8,817.22 5,922,105.05 1,629,522.44 1.29 17,055.85 MWD+IFR-AK-CAZ-SC(7) 23,897.75 87.41 184.54 6,503.11 6,347.31. -15,855.72 -8,824.18 5,922,013.60 1,629,515.46 0.42 17,147.14 MWD+IFR-AK-CAZ-SC(7) 23,990.16 89.04 184.10 6,505.97 6,350.17 -15,947.82 -8,831.13 5,921,921.51 1,629,508.48 1.83 17,239.05 MWD+IFR-AK-CAZ-SC(7) 24,081.84 87.13 186.66 6,509.03 6,353.23 -16,039.03 -8,839.72 5,921,830.31 1,629,499.86 3.48 17,330.37 MWD+IFR-AK-CAZ-SC(7) 24,173.74 88.62 191.23 6,512.44 6,356.64 -16,129.73 -8,854.00 5,921,739.63 1,629,485.56 5.23 17,422,16 MWD+IFR-AK-CAZ-SC(7) 24,267.11 92.51. 188.84 6,511.52 6,355.72 -16,221.64 -8,870.26 5,921,647.73 1,629,469.27 4.89 17,515.50 MWD+1FR-AK-CAZ-SC(7) 24,358.51 95.56 187.93 6,505.09 6,349.29 -16,311.83 -8,883.56 5,921,557.55 1,629,455.95 3.48 17,606.63 MWD+IFR-AK-CAZ-SC(7) 24,449.69 95.33 188.81 6,496.44 6,340.64 -16,401.63 -8,896.77 5,921,467.77 1,629,442.72 0.99 17,697.36 MWD+1FR-AK-CAZ-SC(7) 24,540.67 95.42 189.05 6,487.91 6,332.11 -16,491.11 -8,910.83 5,921,378.30 1,629,428.63 0.28 17,787.92 MWD+IFR-AK-CAZ-SC(7) 24,632.74 92.45 189.90 6,481.60 6,325.80 -16,581.70 -8,925.95 5,921,287,72 1,629,413.49 3.35 17,879.76 MWD+IFR-AK-CAZ-SC(7) 24,724.59 91.90 189.85 6,478.11 6,322.31 -16,672.12 -8,941.69 5,921,197.31 1,629,397.73 0.60 17,971.54 MWD+IFR-AK-CAZ-SC(7) 24,816.48 94.04 189.53 6,473.35 6,317.55 -16,762.57 -8,957.14 5,921,106.87 1,629,382.26 2.35 18,063.30 MWD+1FR-AK-CAZ-SC(7) 24,909.38 93.39 190.38 6,467.33 6,311.53 -16,853.88 -8,973.17 5,921,015.58 1,629,366.21 1.15 18,156.01 MWD+IFR-AK-CAZ-SC(7) 25,002.17 93.94 190.61 6,461.40 6,305.60 -16,944.93 -8,990.03 5,920,924.54 1,629,349.32 0.64 18,248.60 MWD+IFR-AK-CAZ-SC(7) 25,094.80 91.46 189.01 6,457.04 6,301.24 -17,036.10 -9,005.79 5,920,833.39 1,629,333.53 3.19 18,341.12 MWD+IFR-AK-CAZ-SC(7) 25,187.68 90.99 189.69 6,455.05 6,299.25 -17,127.72 -9,020.88 5,920,741.78 1,629,318.42 0.89 18,433.97 MWD+1FR-AK-CAZ-SC(7) 6/19/2017 2:01:15PM Page 9 COMPASS 5000.1 Build 74 0 • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-32 Project: Kuparuk River Unit TVD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: 2K-32 Actual @ 155.80usft(Doyon 142) Well: 2K-32 North Reference: True Wellbore: 2K-32 Survey Calculation Method: - Minimum Curvature Design: 2K-32 Database: OAKE D M P2 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 25,277.53 91.82 190.01 6,452.85 6,297.05 -17,216.22 -9,036.25 5,920,653.29 1,629,303.03 0.99 18,523.79 MWD+IFR-AK-CAZ-SC(7) 25,369.47 91.62 190.71 6,450.09 6,294.29 -17,306.62 -9,052.77 5.920,562.91 1,629,286.48 0.79 18,615.69 MWD+IFR-AK-CAZ-SC(7) 25,465.03 91.39 189.64 6,447.58 6,291.78 -17,400.64 -9,069.65 5,920.468.90 1,629,269.59 1.14 18,711.21 MWD+IFR-AK-CAZ-SC(7) 25,534.53 92.87 192.88 6,444.99 6,289.19 -17,468.74 -9,083.21 5,920,400.80 1.629,256.01 5.12 18,780.64 MWD+IFR-AK-CAZ-SC(7) 25,598.00 92.87 192.88 6,441.82 6,286.02 -17,530.54 -9,097.34 5,920,339.02 1.629,241.86 0.00 18,843.95 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes [1 No I have checked to the best of my ability that the following data is correct: E Surface Coordinates I Declination & Convergence E] GRS Survey Corrections [] Survey Tool Codes SLB DE: '4..aof 2 n.— /QJ,o-& i' agree,Py11[E DSA{@ VMS Client Representative: Ja e VossDm crmrake �od.OD,+«.e,ya,Mm..US Dale Date: 6/20/2017 6/19/2017 2:01:15PM Page 10 COMPASS 5000.1 Build 74 rpTO / 7- —oi2- Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Wednesday, May 24, 2017 7:16 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2K-32(PTD 217-042) -Intermediate Cement Job Update Attachments: Cement Job Summary Report.pdf;CPAI_2K-32_RT_TOC_9600-13300ft_1200_Scale.pdf Follow Up Flag: Follow up Flag Status: Flagged Good Evening Victoria, Here are the results of the Sonic Log and FIT for 2K-32. Please see the responses to the provisions below.Additional information is attached. 2K-32 Cement Job • Primary Stage o Pumped 141.1 bbls(including 40%excess)of 15.8 ppg Cement without returns—saw good lift pressure. o TOC:The TOC for the 1st stage was logged at 11050' MD/5718'TVD.This equals to 2193' MD/591'TVD above the Kuparuk C sand at 13243' MD/6309' MD.This TOC depth indicates gauge hole based on our calculations with 40%excess of 15.8 ppg cement pumped. 0 • 2' Stage o Pumped 78.3 bbls (including 40%excess)of 15.8 ppg Class G without returns—did not see lift pressure o TOC:The TOC for the 2"d stage was logged at 10245' MD/5482'TVD.This equals 681' MD/205'ND above a thin sand of marginal quality at 10956' MD/5687' MD.This sand is not part of the Cairn Oil Pool, but we wanted to be cautious in case of any potential future development. • Sonic Log Evaluation o ConocoPhillips concludes that the cemented intervals meet our objective requirements for competent annular and reservoir isolation of the Kuparuk Oil Pool. o The log validates the original assumption in the email below;that our lost returns were a result of the fault(^'9700' MD) at a shallower depth of planned cement. o Log data and annotations can be seen below in the pictures below. • FIT at the 7-5/8" Intermediate shoe: o Was performed to a 13.0 ppg EMW indicating a good shoe. 1 • • 2K-32: 2nd Stage Sonic Log Evaluation P 3 C 0�® Mi IOWnlymmin y u�ws 200 '.. + _.r m, iimaritge • we:, -21111111111111 ill .... a 1111 Jr To um t ii,, t. t 1 E • TOC p. 10275' M D/5.482' TVD .. m I e i #-. S, F { . . I i i i 1 4 r 1 i 10750 t i I ; i i f C-35 P. 10956' ME f 56&71 TVD ,.L .- . A i i Stage Mar 9811 l n 1 _ �. _ .- s r-K.~ Wawa- - _ _ .. �� 2 • 2K-32: 1st Stage Sonic Log Evaluation A -4- lb+ par_so oto. 4 . I T--"` — -"••• ;•••••••• *4 •+ " •.• •• •. ••4•••• 7 7 T C 12050' MD/5718P IVO ; 74- i f ; • J47 H Se, - itt't 0 4 • 111.1.11 :e . . SH• i 1 • • • + + I + ' • ; ; • ; •••414W t HZ @ 11940b /5 7 7 7 7 1 ""Tanh.l.'"TrrT4114 . 4 - t - tt t I • • ;t, - • • ; - 4 , •,1 ' 1 1 .11110 .14*4 • + t 4 4 ' Kalubik 12406' MD/6123 TIVO ; • 48111111. .44 4 4 t 4 4 • • . 1 ; 1 4 401011 ' : t . 4 • I 4 ! • ; 41110- • " Kuparuk C 13243' IvIDI 6309' TVD t reiveratrakomi....JOINIMMINIIIIMMINI W.14•11411L104,1A. Al•.74.NM • • *Pease let me know if you require any follow up. Thanks, Jake Voss Sr Drilling Engineer I ConocoPhillips Alaska I Office: (907)265-6935 I Mobile:(832)-499-9085 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 23, 2017 9:57 AM To:Voss,Jake<Jake.Voss@conocophillips.com> 3 • Cc: Quick, Michael 1 (DOA)<michaee nick@alaska.gov>; Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: KRU 2K-32(PTD 217-042)- Intermediate Cement Job Update Jake, Thanx for the intermediate cement update. Please see the notes below outlining AOGCC expectations when running the Sonic LWD. Johnson, We have reviewed the comparison information CPAI has provided between the LWD-Sonic and the Wireline- SCMT. Approval is granted to run the LWD-Sonic on upcoming well CRU CD5-20 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement(and lengths)that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation,or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement,just as the e-line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report,the logs and the FIT, remedial measures or additional logging may be required. Victoria From:Voss,Jake [mailto:Jake.Voss@conocophillips.com] Sent:Tuesday, May 23, 2017 9:50 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Bearden,J Daniel«.Daniel.Bearden@conocophillips.com> Subject: RE: KRU 2K-32(PTD 217-042)- Intermediate Cement Job Update Good Morning Victoria, I wanted to give you an operational update on well KRU 2K-32's intermediate cement job. We successfully ran casing to TD in the Kuparuk A4 sand. However, we were unable to get full returns when circulating at various spots in our open hole. We also pushed fluid away when running our casing. We currently suspect a transmitting fault midway through the intermediate hole being our loss zone. We circulated 220 bbls at TD without returns to surface. We performed our primary cement job without returns. During displacement,we saw good indication of lift pressure as cement traveled up the annulus. We then opened the stage collar and saw higher pump pressure indicating possible pack-off above our stage tool. We decided to wait on cement for 11 hours to allow the first stage to reach 500 psi compressive strength and minimize any risk to the primary cement job. We then pumped our 2nd stage (again without returns). During this job,we did not see significant lift pressure. We believe the fault, or a weaker zone above our planned 2nd stage TOC, consumed our returns. This area would be above the top of cement for our primary 15t stage job,as well as the 2nd stage.We are currently running in hole with our production BHA with real-time SonicScope. We plan to begin our SonicScope logging interval 500' MD above the estimated top of cement on the 2nd stage and will continue logging to our primary 1St stage. 4 • • We are logging under Real Time Operations and I will update you with our log interpretations when we receive them. Below is a schematic of what we believe our current well status is on 2K-32. 2K-32 wp10 Current Status 4111111111111111111 20" Conductor to 179' .41 L 103/4"45.5# L40 HYD563 3.480' MD/2,955'ND @ 52° inc. Cement Summary 1" Stage = 141 bbls Class 15.8 ppg with LCM (Good Lift Pressure) 9-7/8" x 11" Hole 2nd stage = 78.3 bbls Class 15.8 ppg (Poor Lift Pressure) Estimated Fault Depth 9700' tai D Top of 2nd Stage 10100'MD/5,434' TVD C-35 2"d Stage Collar 10940' MD 15,6$7' TVD 10,981' MD /5,693' TVD HRZ 11940' MD/5,989'ND Top of 1� Stage '2123' MD /6,040' TVD Kalubik 12,406' MD/6,123'ND Kuparuk C 13.243'MD/6,309' TVD Kuparuk A 13.420' MD/6.337' ND 1166,. 5 S Please let me know if I can be of more assistance. Thanks, Jake Voss Sr Drilling Engineer ConocoPhillips Alaska 1Office: (907)265-69351 Mobile: (832)-499-9085 6 • 0 ' tis‘ Cement Detail Report a ' 2K-32 Conocat'ttiilips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,4/28/2017 02:00 Cerlent;Detalls -: 4 .- . Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 5/20/2017 00:00 5/21/2017 22:00 2K-32 Comment Cement Stages� . .=Y iia=b _ '' -� - - .-ms's _z __ Stage.#1: = Description Objective Top Depth(ttKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 12,176.0 13,738.0 No Yes Yes Cement Q Pump lnit(bbl/m...Q Pump Final tbbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 5 778.0 1,300.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement 1st stage as follows:batch up 12.5 ppg Mud Push Ii, pump MP II @ 4.5 bpm=650 psi.Shut down and drop bypass plug as per PESI.Batch up 15.8 ppg cement,Pump 141.1 bbls of 15.8 ppg cement @ 5 bpm=600 psi ICP,185 psi FCP.Drop bottom plug as per PESI,kick plug out with 10 bbls of water and swap to the rig.Displace cement with rig pumps @ 5 bpm=275 psi ICP,3 bpm-778 psi FCP.Observed pump pressure begin to increase @ 4800 stokes from 282 psi to bump @ 6079 strokes=778 psi,good lift pressure observed.After bumping the plug @ 6079 strokes,pressure up to 1200 psi and hold for 5 min, bleed off and check floats,good.Cemented 1st with no returns,100%loses.Lost 810 bbls of 10.4 ppg LSND mud while cementing. Cement Fiufds&Additives_ ., _ _ Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MPiI 11,502.0 12,176.0 39.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluidf- _ _ = - _ Fluid Type Fluid Description Estimated Top(ftKB) 'Est Btm(ftKB) � Amount(sacks) Class Volume Pumped(bbl)` Intermediate Cement 12,176.0 13,738.0 688 G 141.1 Yield(ft'/sack) Mix H2O Ratio(galsa... Free Water(%) Density(Ibigal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.11 15.80 132.0 0.00 Additives Additive Type Concentration Conc Unit label CemNet LCM 1.5 lbs/bbl 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 Retarder D177 0.03 gal/sx Additive Type Concentration Conc Unit label Liquid Fluid Loss D255 0.4%BWOC Stage#2 - -. _,1 = _ - _ V Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? -Vol Cement...Top Plug? Btm Plug? Intermediate Casing 10,100.0 10,981.0 No Yes No Cement Q Pump Mit(bbl/m...Q Pump Final(bbl/...0 Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 4 1,150.0 3,000.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM,Line up SLB and fill lines with water.Pressure test lines to 4000 psi-good test.Cement 2nd stage as follows:batch up 12.5 ppg Mud Push iI, pump 40.1 bbls MP II @ 3.3 bpm=1140 psi.Batch up 15.8 ppg cement,cement wet at 18:19 hrs,Pump 78.3 bbls of 15.8 ppg cement @ 4 bpm=1089 psi ICP,800 psi FCP.Drop closing plug out of cement head and kick out with 10 bbls of water-observe good indication of plug dropping.Swap to the rig.Displace cement with 10.45ppg LSND using rig mud pump#1 @ 4 bpm=753 psi ICP,at 3730 strokes w/4 bpm-1056 psi(mudpush turning corner),at 4128 strokes w/4 bpm-1075 psi(cement turning corner), at 3 bpm-1150 psi FCP.After bumping the plug @ 4952 strokes(61 strokes past calculated),pressure up to 2850 psi at 3 bpm and kill pump per PESI.No pressure shift observed to indicate stage tool closed.Increase pressure to 3000 psi and hold for 5 min.Bleed off pressure to 0 psi,5.0 bbls bled back,and shut in. No pressure buildup observed.Pressure up at 4 bpm to 2350 psi per PESI,shut in and hold for 5 min.Bleed off pressure,3.6 bbls bled back.Remove cement hose and monitor flowback through cement head at surface-initially observed small amount of aired-up mud flowing back,tapering off to static-stage collar closed.Cemented 2nd stage with no returns,100%loses. 2nd Stage Cement in place @ 21:23 hrs Page 1/2 Report Printed: 5/24/2017 ! S Cement Detail Report &Wel 2K-32 CoriocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL,4/28/2017 02:00 Cement-FlUldslk Additives - _ — i:_ Fluid ' Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MPH 9,444.0 10,100.0 40.1 Yield(ft'/sack) Mix H2O Ratio(gat/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pars) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid _ - v rte = _ Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,100.0 10,981.0 688 G 78.3 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ibigal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.11 15.80 116.0 8.03 Additives Additive Type Concentration Conc Unit label Antifoam 0046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Cone Unit label Retarder 0177 0.03 gai/sx Additive Type Concentration Conc Unit label Liquid Fluid Loss D255 0.4 %BWOC Page 2/2 Report Printed: 5/24/2017 Emco � 0 O C/) fl C7 mO C CA B o oo r- Z . . . r - - C 0 0 CO : E. a, Q 311 9 o 0' "p IC CD Y >5 4, c0 0 CCM Cn w , msl, C CD � � � �' �, mn _ 0 co 73 w = CLC 2 ry O o C CD X" 13 o CD 0 Eir cn21 7 m B =■ 0 C Cl)c0 CD 0� CnCD X = G) 7 o Pim' 0 - ; �' cr rz A' 5 — I CD F r C MO s ° ` o to C 7-1 PI CD 3 _ * cri � .71 m 13, .gt 1‘) 8 UI C OCD = CD FOLD HERE: The well rwre,Iccaticn and bcrehde reference data were finished by the custom: Any interpretation,research,analysis,data,results,estirretes,or recommendation furnished with the services or otherwise conmrnicated by Schlumberger to the customer at any time in connection with the services are opinions based on inferences from rreasurerrents, empirical relationships, and/or assumptions; which, inferences, empirical relationships and/or assumptions are not infallible and with respect to which professionals in the industry may differ.Accordingly, Schlumberger cannot and does not warrant the accuracy,correctness,or completeness of any such interpretation,research,analysis,data,results,estimates, or recommendation.The cusbrrer acknowledges that it is accepting the services"as is,"that Schlumberger makes no representation or warranty,express or implied,of any kind or description in respect thereto,and that such services are delivered with the explicit understanding and agreerrent that any action taken based on the services received shall be at its own risk and responsibility,and no daim shall be made against Schlumberger as a consequence thereof. Svc.Order#: 17AKA0005 Interpretation Center: Houston-SIS Analyst Andrew C.Johnson Process Date: 24 May2017 P Y Teddog Vers:2015.3 Mud and Borehole Measurements: 1 Casing Size:7.625 in BHT:212 degF Bit Size:6.75 in Casing ID:6.875 in Type Fluid in Hole: Casing Might 29.7 Ibm fft Mud density:9.5 Ibm'gal Remarks: • 0 AMP1 CSG CD .1" NI- .1- •.' t' 0 0 0 0 1.- CD 0 unitless 200 DTCO MH RT AMP2 CSG , Projection MD 40 us/ft 240 0 unitless 200 (ft) ROP5 AMP3 CSG 11:11° STPPI MH RA 1:1200 0 ft/h 1000 0 unitless 200 0 us/ft 1 1 1 1 1 i II ._ 9 tr 4.i'-----:- —...— d•i _ I- I -Tamar ,:i,, ,,,4,i - . I I L I 4 I ( -id L.) - - 975 - 1 1-'41''411111111, 11 \ . 0 _ - - 1 I : . 1, /1 ---. - - I — MMIWAIII 1 i I .---- _- - NO < 111116:71*- _....____ = .. w w I- -' .111111." i < - ME •Arsis CI I ...— — .. .. i ,Allir t . '' FA 411 < i _ -Allo___ . -...... :10000 _.... .-- _ ti ,. ..-- 4 4 t '41140 iLJI '''. w - uuuuI ' 1 1"lirli rirtmemsiminninli I I I gunk - - I I < .91111110. - -....41 1 1 :7 i - Illr J mmi < 444,1, - I ----tonillIMIIIMINI 11F E i - - - - < . --- f A' A aft -10250 —7-7.' — --- C Nk._ .Iir:Ii. - - - ! VP " i ,,, VIII id ,.... MMINIMM < * 1 I I I I - - - i i i i ) , l alk ; i .., lir. 1 –.....mmomm.. ..MI as .:10. 0 IL,:fik tr > '11 INS V s' ... .I AllI –10500 _ 441 1 It'a - fil4 Imitt,101 jrit,.11 a - N. —.. . a t.,a .... a - I _ . .11. _ , ...r - - - iillii 41, - a. I 11. I I I ' - 4_______I I . I I a- I I I I _ V r 1 1 1 rr i . 1 1 –10750 . I ri , I ,....._ I 'I 1 , i 1 1 1 1 1 Q 1 1 1 1 1 1 I -1.... 1 ] 41.... --=-- I I I I I I _ 1 1 1 I 1 - 1 1 I _ 1 1 1 1 1 1 1 1 il II , l.:,;....,..,.,i,,,,,, 11111 I I -t- -....., 41 -4 I I IA —44 4 As ma 1--- I I I I I I )....JI I I I I I I I •f. ,.; id -----.......... t, • I Ift....— • .....- 1 I –11000 • I 1 ., ....„... 1 I 1 I - - I I I I I I I 1 ... , . ilig - 1 1 1 1 ( I I 1 I I 1 I 1 1 I 1 - , . . - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 _ I ] I I I I , , .. , 1 1 1 1 1 1 ;AI _ - ----,,,____ I .. *a 1 1 1 1 1 1 1 1 7 i ) 111 I 1 16._ 1 k 4 I I I .. I I I I 4.4 I I I I I –11250 I I -'---1' I I I I I I I I ._ ^ I I I to I I I I * -- ..444 4.44mmook..444M IMIIMMIIIIII I I I I I etts1,.. .-4,._.1:4 ,...., - r- I I I I I I I I ,mir't 1 I I I I I I I I 4till I I I I I I I I - I I I I I I I I j illi - I I I 5 I I I I I • pee _ I 1 1 1 1 I el ( I I I I I I I at 'A- 1 _ _ 1 I I I I I I I I '- I I i 1 1 1 1 ...nommi 1 I I I I I I I 5111411 1 I - I I I I -- iicnn I arilliMill I - I I I ., _ _ ,.. ...... Y .. - A....., . ,... _ I I . , _ , _ , I -11750 Oil ... 4.. . . . _ — -- I .0, 1 _ _ I 1 4 Nis y 't _ ____ AI' I I . I 1 1 1 I I 1 *. 4110 4 4 I I I I I I Ilk. 111 I ill I I I ..4 I I <I ... -...... I I I I I I I I I I I I I -12000 I I I .' I I I I 1 1 1 _ .. I I . li, At I I I I C I S - I I ill I I I I I I I it I I ... ' it . 14 , 1 .....,,,, , 1 4 1 1 1 1 1 I 1 1 1 _ . I I I 1 , .,,,.... , 1 1 1 1 1 , -12250 _ r 1 I I I 1 , -Yfr , < 1' I I I I I tali i i II I iligiir 1 1 it I I I _ , 1 1 f — I I < -,... I I I - I , . . I 1/41 1 1 1 1 1 1 1 4...... .,, , _ 1 1 I I .5 I 1 I I I I I I I I I -12500 1 I I I i I i 1 I 1 I 1 I i I . I I ) II I I I I I 11'11: i ',akI ... "" elf) I I I I - --'' '' '-/-11---1 .`-i 1 1 1 • ` 1 I I • 0 . R 1M.. t., 1 , P _ Familinlimili-12750 milimil - ?f 1 A ' .t 1 I I I - _ ______ -,.........iiii, IC I MIMI r At, 44 I t 111 - lirMill 1 -13000 mom , vir IIIIIIIIIIIIIII 41 , i NMIt1ii,,,...3.10., 11 miliming , i= 1,, , immi IL-; , A 13250 All ea i -I 1 ti — I I f frt Company: ConocoPhillips Alaska, Inc. Schlumberger Well: 2K-32 Field: Kuparuk River Unit State: Alaska Date Logged: 13-May-2017 Date Processed: 5/24/2017 Well Location: NAD83 Alaska State Plane, Zone 04, US Feet X: E 1638343.110 ft. ft Y: N 5937865.300 ft. ft Elevations: DF: 155.45ft GL: 116.7ft API Number: 50-103-20757-00-00 Job Number:17AKA0005 110 • pro ai3 -092- Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Tuesday, May 16, 2017 8:31 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2K-32(PTD 217-042) -Intermediate Cement Design Update Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the reply,just to clarify,do you want this email along with the PTD when we submit our 10-407 form? Thanks, Jake From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 16,2017 8:06 AM To:Voss,Jake<Jake.Voss@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2K-32(PTD 217-042)-Intermediate Cement Design Update Jake, Thanx for the update. Approval is granted for the cement job modification as outlined below. Please include this approved modification with your approved copy of the PTD. 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.Loeopaalaska.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:Voss,Jake [mailto:Jake.Voss@conocophillips.comj Sent: Monday, May 15, 2017 3:03 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: FW: KRU 2K-32(PTD 217-042)- Intermediate Cement Design Update 1 S • Good afternoon Victoria, Just wanted to give you an update on the cement design for well KRU 2K-32 (PTD 217-042). While drilling the 9-7/8"x 11" Intermediate hole section,we encountered the C-35 sand which showed over 10 ohm resistivity. During well planning, it was believed that this Cairn-type sand would pinch out toward 2K Pad. However,this log data demonstrates a further extent than originally assumed. While no development plan is in place for this sand,we would like to cover that interval with a second stage cement job(similar to the original Shark Tooth program found in Attachment 1),for isolation from potential development. I have updated the calculations with estimated top of cement for both the 1st stage and 2nd stages shown below. Please note that this differs from our planned top of cement(top of the HRZ from our PTD).Also attached is a comparison of our cement design in Attachment 2—Design Comparisons. Similar to the original design, both stages will cover a minimum 250'ND above the Kuparuk Oil sand and also the C-35 sand. Intermediate 1st Stage Cement: Cement from 13,810'MD to 12,700'MD Slurry: Capacities: 15.8ppg Class G yielding 1.16ft&3/sk 11"x 7-5/8" 0. XS%for open hole and annulus: 40% 11"OH 0, 7-5/8"ST 0, Annulus Cement 1110 x 0.05578189 x 1.4 = 86.68505 bb Rathole Cement 2 x 0.14577667 x 1.4 = 0.408175 bb Shoe Track 120 x 0.0459157 x 1 = 5.509884 bb Total 93 bb 520 ft3 448 sx Intermediate 2nd StageCement: Cement from 10,956'MD to 10,100'MD Slurry: Capacities: 15.8ppg Class G yielding 1.16ftA3/sk 11"x 7-5/8" 0. XS%for open hole and annulus: 40% 11"OH 0. 7-5/8"ST 0, Annulus Cement 860 x 0.05578189 x 1.4 = 67.16139 bb Total 67 bb 377 ft3 325 sx Please let me know if you need me to follow up on anything else. Thanks Jake Voss Sr Drilling Engineer 1 ConocoPhillips Alaska!Office:(907)265-6935 I Mobile:(832)-499-9085 2 pro 214 47— Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Wednesday, May 03,2017 3:06 PM To: Loepp,Victoria T(DOA) Subject: KRU 2K-32(PTD 217-042) - Cement Top off Follow Up Flag: Follow up Flag Status: Flagged Good Afternoon Victoria, Just wanted to give you a courtesy update on the well KRU 2K-32 surface cement job. We performed our surface cement job on KRU 2K-32 this morning with full returns(200 bbls to surface)and cement in place at 0641 hrs 5/3/17.At noon today, it was noticed that cement level had dropped.The rig measured a fluid level at 30' MD below ground level,and after running in with%"conduit pipe, hard cement was tagged at 100' below ground level,which is 40'above the 20"conductor shoe(conductor was driven to 140' below ground level). Here is our plan forward: 1. Flush out annulus with fresh water 2. Pump cement top off per SLB to surface a. Volume to get cement to surface is approximately 22 bbls. Once cement is pumped we plan to resume normal operations Thanks and please let me know if you have any questions or concerns, Jake Voss Sr Drilling Engineer I ConocoPhillips Alaska I Office:(907)265-6935 I Mobile: (832)-499-9085 1 • S Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Wednesday,April 26, 2017 3:34 PM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2K-32(PTD 217-042) - Managed Pressure Drilling/Bottom Hole Pressure Measurement Follow Up Flag: Follow up Flag Status: Flagged Thanks Victoria From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,April 26,2017 10:46 AM To:Voss,Jake<Jake.Voss@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2K-32(PTD 217-042)-Managed Pressure Drilling/Bottom Hole Pressure Measurement Jake, Your proposal for BHP acquisition for 2K-32 is approved subject to the same conditions as previously approved for DS-2S which are excerpted from the previous correspondence and outlined below: "We have reviewed this request for two alternate methods for obtaining the required bottom hole pressures on pre- produced injectors on 2S pad. Both methods are acceptable and approved in the special circumstance you describe. Use of these methods as standard practice elsewhere is not approved. Please insure the accuracy of the surface gauges,and consistency of the mud column prior to obtaining the pressures." 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(7a 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 From:Voss,Jake [mailto:Jake.Voss@conocophillips.com] Sent:Tuesday,April 18,2017 3:40 PM To: Loepp,Victoria T(DOA)<victoria.Ioepp@alaska.gov> Subject: KRU 2K-32(PTD 217-042)- Managed Pressure Drilling/Bottom Hole Pressure Measurement 1 • • Victoria, Just to follow up on our phone call, Our operations folks were wondering if we can use the MPD bottom hole pressure measurement as our SBHP requirement before putting the well on production for well KRU 2K-32 (PTD 217-042). We were able to do this during the initial Drill Site 25(Sharktooth) Pre-Produced Injector Program,and wanted to confirm if we can do this with the KRU 2K-32 well. We were able to show the accuracy of the MPD measurement on 2S-10 when we compared it to a slickline SBHP measurement post rig shown below. • 2S-10 Bottom Hole Pressure o MPD Measurement= 10.7 ppg mud+305 psi MPD Choke Pressure at 6430'ND=11.75 ppg Equivalent Mud Weight(EMW) o Post Rig Slickline Measurement=3845 psi at 6313'ND= 11.71 ppg EMW 2K-32 (and upcoming 2K-30) is"Shark Tooth Phase 2 Program"which is a 2 well package and depending on reservoir quality,an upside of 1 more injector/producer pair. Being able to utilize the MPD measurement allows us to eliminate post-rig slickline work that could delay the pre- production for 2K-32 (slickline and post rig work access on 2K-32 would be difficult to achieve due to the footprint of the rig while drilling 2K-30). Below are the two methods that we would attain the measurement with MPD—(on all of the Drill Site 2S pre-produced injectors,we were able to use Method 1 and will likely use it on 2K-32) 1. If the mud weight used to drill the production lateral is below the pore pressure,we will use our managed pressure drilling system to fingerprint the pore pressure. This will involve shutting the MPD chokes and allowing the pressure to build until it levels out,giving us a static bottom hole pore pressure(the surface pressure plus the hydrostatic of our known mud weight). 2. If the mud weight used to drill the production lateral remains above pore pressure for the entire drilling portion, we will not be able to finger print with the MPD system. In that case,we would wait until the last step of the well when we are freeze protecting. Instead of pumping diesel around the top 2,000'of the well as is our standard,we would pump it around the entire tubing volume, leaving a full column of diesel in the well. We could then measure the wellhead pressure after it becomes static and add it to the hydrostatic of the diesel column to get an accurate BHP. I have attached an email chain from the original correspondence for Drill Site 25 Pre-Produced Injector's MPD bottom hole pressure measurements for reference. Please let me know of any questions or if I can be of any assistance please don't hesitate to contact. Thanks Jake Voss Sr Drilling Engineer;ConocoPhillips Alaska Office (907)265-6935 G Mobile (832)-499-9085 2 • • Loepp, Victoria T (DOA) Subject: IRE:2S Pad Static BHP Measurement Methods From: Callahan, Mike S Sent: Friday,June 12, 2015 9:32 AM To: Pardo,Javier M; Hunter, Lindsey L Subject: Fwd: [EXTERNAL]RE: 2S Pad Static BHP Measurement Methods • We are approved to move forward with these methods. Sent from my iPhone Begin forwarded message: From: "Loepp,Victoria T(DOA)"<victoria.loepp@alaska.gov> Date:June 12,2015 at 8:46:35 AM AKDT To: "Callahan, Mike S"<Mike.Callahan@conocophillips.com> Cc: "Jackson,Jasper C(DOA)"<jasper.jackson@alaska.gov> Subject: [EXTERNAL]RE:2S Pad Static BHP Measurement Methods Mike, We have reviewed this request for two alternate methods for obtaining the required bottom hole pressures on pre-produced injectors on 2S pad. Both methods are acceptable and approved in the special circumstance you describe. Use of these methods as standard practice elsewhere is not approved. Please insure the accuracy of the surface gauges,and consistency of the mud column prior to obtaining the pressures. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeopalaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.Loeop@alaska.gov From: Callahan, Mike S [mailto:Mike.Callahan@conocophillips.com] Sent: Tuesday, June 02, 2015 3:55 PM 1 • 111, To: Loepp, Victoria T(DOA) Cc: Klem, Adam Subject: 2S Pad Static BHP Measurement Methods Victoria,as we discussed on the phone this afternoon,we are looking into a method for getting the required bottom hole pressure measurement prior to producing our pre-produced injectors at 2S pad (6 wells). This is to eliminate post-rig slickline work that could delay the production on the wells between 1-2 months(slickline access would not be possible for certain wells because of the rig footprint covering access to the previous well while it is drilling subsequent wells on the pad). The two methods we would like approval to use are: 1. If the mud weight used to drill the production lateral is below the pore pressure,we will use our managed pressure drilling system to fingerprint the pore pressure. This will involve shutting the MPD chokes and allowing the pressure to build until it levels out,giving us a static bottom hole pore pressure(the surface pressure plus the hydrostatic of our known mud weight). 2. If the mud weight used to drill the production lateral remains above pore pressure for the entire drilling portion,we will not be able to finger print with the MPD system. In that case,we would wait until the last step of the well when we are freeze protecting. Instead of pumping diesel around the top 2,000'of the well as is our standard,we would pump it around the entire tubing volume, leaving a full column of diesel in the well. We could then measure the wellhead pressure after it becomes static and add it to the hydrostatic of the diesel column to get an accurate BHP. Please let me know if you have any questions or would like any more information on either of these proposed methods. Regards, Mike Callahan Drilling Engineer ConocoPhillips Alaska ATO 15-1564 Office: (907)263-4180 Cell: (907)231-2176 2 SOF T� S THE STATE Alaska Oil and Gas Of Conservation Commission 333 West Seventh Avenue ..: — Vlit* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-32 ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-042 Surface Location: 188.7' FNL, 94.4' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 1642.6' FNL, 3890.2' FEL, SEC. 27, T1ON, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071,composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, .0 / r Daniel T. Seamount, Jr. n Commissioner DATED this 2-day of April, 2017. • 1111 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL y)0/.7 11 20 AAC 25.005 _f )LJ--- la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp 0 1c.Specify if well Is proposed fon Drill ❑., ' Lateral ❑ Stratigraphic Test 0 Development-Oil 0 Service- Winj CI ' Single Zone El ' Coalbed Gas 0 Gas Hydrates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket D • Single Well❑ 11,Well Name and Number: ConocoPhilllps Alaska,Inc. Bond No. 59-52-180 - KRU 2K-32 t 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100380 Anchorage,AK 99510-0360 MD: 25,394 • TVD: • 6,456 Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 188.7'FNL, 94.4'FEL, Sec 11, T1ON,R008E,UM ADL 25588,25589,25804,25607 Kuparuk River Oil Pool ' Top of Productive Horizon: 8.Land Use Permit: 13. Approximate Spud Date: 665.4'FNL,2076.2'FEL,Sec 15,T1ON,R008E,UM 2674,2675,2677,2678 4/30/2017 Total Depth: 9.Acres In Property: 14.Distance to Nearest Property: 1642.6'FNL, 3890.2'FEL, Sec 27,T1ON.ROO8E,UM 10240 ' 3890'from ADL 392952 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 155.7• 15.Distance to Nearest Well Open Surface: x- 498310 y- 5938115 Zone- 4 • GL Elevation above MSL(ft): 116.7 . to Same Pool: KRU 2S-01:1,281' 16.Deviated wells: Kickoff depth: 300 feet k 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees . Downhole: 3422 • Surface: 2789 • 18.Casing Program: Spedticallons Top - Setting Depth - Bottom Cement Quantity.c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Including stage data) 24" 20" 62.5# H-40 Welded 79' 39' 39' 118' 118' Cement to surface 13.5" 10.75" 45.5# L-80 Hydrll 563 3,394' 39' 39' 3433' 2941' 1435 sx 11#1196 sx 12#DeepCRETE 11" 7.625" 29.7# L-80 Hydrll 563 13,675' 39' 39' 13714' 6356' 621 sx 15.8 Gass G 6.75° 4.5" 12.6# L-80 Hydril 563 11,880' 13514' 6339' 25394' 6456' Uncemented Liner with Peri Pups 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 TVO(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 [J Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report 0 Drilling Fluid Program ❑ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not Jeoob Voss @ 265.6935 be deviated from without prior written approval. Contact jake.voss(d coo.com Email Printed Name rja_G.L.Alvord . ,. Title Alaska Drilling Manager '�rr Signature 11-�i-Zo I Phone 265-6120 Date Commission Use Only Permit to DrillAPI Number. Permit Approval See cover letter for other Number: (4I - 14 50- /03'' 40 ,6-1 -ca ale: (;1 I 11 requirements. Conditions of approval: If box is checked,well may not be used to explore for,lest,or produce coalbed methane gas hydrates,or gas contained in shales: [Y" Other: �e p fC 5 f- to 3 $-Uv p b-/ Samples req'd: Yes Nod Mud log req'd:Yes❑ No Lir �yz vi vj r--- r r v�,, f r - rt---..,5 H2S measures: Yes No Directional svy req'd:Yes Ur No Ip , 5 0 c r $ / Spacing exception req'd: Yes 0 NoIJ Inclination-only svy req'd:Yes a/No �/ �y r 0,,rp r--o V-1 ci ,.) Post initial injection MIT reqd:Yes No CI APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: + )7j 1 7 *4 1 J �7-- 'l>4 lin, 4/2 ? '� /� ` Submit Form and Form 10-401(Revised 11/2015) This pe mfi is valid for 24 monthsf m the date of approval(20 AAC 25.O05(g)) Attachments in Musicale ORIGINAL RECEIVED STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COMMON APR 0 3 2017 PERMIT TO DRILL 20 AAC 25.005 AUG CC la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1c.Specify if well is propose. or: Drill ❑., Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑., Service- Winj ❑ Single Zone ❑✓ Coalbed Gas ❑ Gas H .rates ❑ Redrill❑ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shal• Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and N ber: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 KRU -32 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 25,394 TVD: 6,456 Kup- uk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 188.7'FNL, 94.4'FEL, Sec 11, T1ON,R008E,UM ADL 25588,25589,25604,25607 paruk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Ap. oximate Spud Date: 665.4'FNL,2076.2'FEL,Sec 15,T1ON,R008E,UM 2674,2675,2677,2678 4/30/2017 Total Depth: 9.Acres in Property: 14 Distance to Nearest Property: 1642.6'FNL, 3890.2'FEL, Sec 27,T1ON,R008E,UM 10240 :90'from ADL 392952 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 155.7 15.Distance to Nearest Well Open Surface: x- 498310 y- 5938115 Zone- 4 GL Elevation above MSL(ft): 116.7 to Same Pool: KRU 2S-01:1,281' 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Potential Pressures in psig(s- 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3422 Surf. e: 2789 18.Casing Program: Specifications Top - Setting Depth - Botto. Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 24" 20" 62.5# H-40 Welded 79' 39' 39' 118' 118' Cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 3,394' 39' 39' 3433' 2941' 1435 sx 11#/196 sx 12#DeepCRETE 11" 7.625" 29.7# L-80 Hydril 563 13,675' 39' 39' 137 6356' 621 sx 15.8 Class G 6.75" 4.5" 12.6# L-80 Hydril 564 11,880' 13514' 6339' 2 :94' 6456' Uncemented Liner with Perf Pups 19. PRESENT WELL CONDITION SUMMARY(To be completed for--.ri a . Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect. 0:. MD(ft): Effect.Depth ND(ft): Junk(measured): 1, Casing Length Size •- *Time MD TVD Conductor/Structural Surface Intermediate Production / Liner Perforation Depth MD(ft): -erforation Depth ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch II% Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Skgtch Q Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 3/30/(7 //� 22.I hereby certify that the foregoing is true and the procedure=pproved herein will not Jacob Voss @ 265-6935 D be deviated from without prior written approval. Contact jake.vosscop.com Email Printed Name G.L^Alvord Title Alaska Drilling Manager Signature , Phone 265-6120 Date 4(3 leo,' /// Commission Use Only Permit to Drill mber: Permit Approval See cover letter for other Number: 2J ?- DI 2._ IAPI 50- /03- as?-6-"v?-co-oz) Date: requirements. Conditions of approval: If box i: checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: Samples req'd: Yes❑( No E Mud log req'd:Yes❑ No 7 H2S measures: Yes 1Z No❑ Directional svy req'd:Yes[7rrNo❑ Spacing exception req'd: Yes❑ No Inclination-only svy req'd:Yes❑ No 121 Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY Approved lfy: COMMISSIONER THE COMMISSION Date: OhFZeireSNALSubs in Form ane Form 10-401(Revised 11/2015) onths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate RECEIVED Application for Permit to Drill,Well 2S-05 Saved:3-Apr-17 Post Office Box 100360 APR 0 3 2017Anc Phone 90 ,Alaska 99510-0360 AOGCConocoMI IpS Phone(907)265-6935 Email: jake.vossO,conocophillips.com March 30,2016 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Well 2K-32,A Kuparuk A4 Sand Injector / Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a permit to drill an onshore grassroots pre-produced injector/well from the 2K pad. The expected spud date for this well is April 30th,2017.It is planned to use rig Doyon 142./ 2K-32 is planned to be a horizontal well in the Kuparuk A4 sand.The surface section will be drilled with 13-1/2"bit and run 10-3/4"casing to+/-3,433'MD/2,941' TVD. The intermediate section will be drilled with 9-7/8"x 11"bit/Under Reamer and run 7-5/8"casing to 13,714'/6,356'TVD.The production hole will be drilled with 6-3/4"bit and run 4-1/2" perf and blank jointed liner to+/-25,394'/6,456'TVD.The upper completion will be run with 3-1/2"tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment,diverter equipment and choke manifold 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 Jake Voss at 265-6935 (j ake.voss(&,conocophillips.com)or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager • • Application for Permit to Drill Document Os Kuparuk Well 2K-32 C.on ,,;,li ps Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 2K-32 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identfing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 188.7'FNL, 94.4'FEL, Sec 11, T 1ON,R008E,UM NGS Coordinates RKB Elevation 155.7'AMSL Northings: 5,938,115.23' Eastings: 498,310.15' Pad Elevation 116.7'AMSL Location at Top of 655.4'FNL,2076.2'FEL,Sec 15,T1ON,R008E,UM Productive Interval (Kuparuk A4 Sand) NGS Coordinates Measured Depth, RKB: 13,714' Northings: 5,932,364.21' Eastings:491,051.96' Total Vertical Depth, RKB: 6,356' Total Vertical Depth,SS: 6,200' Location at Total Depth 1642.6'FNL, 3890.2'FEL, Sec 27,T1ON,R008E,UM NGS Coordinates Measured Depth,RKB: 25,394' Northings: 5,920,830.5' Eastings:489,243.78' Total Vertical Depth,RKB: 6,456' Total Vertical Depth, SS: 6,300' (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drmvn to a suitable scale,showing the path of the proposed wellbore,including all adjacent ivellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 142. • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) wihile drilling 2K-32 is calculated using an estimated maximum reservoir pressure of 3,422 psi (10.6 ppg, based on 2K-21 development well), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,337' TVD (WP09): A Sand Estimated. BHP =3,422 psi A Sand estimated depth (WP09) = 6,337' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 633 psi (6,337' TVD * 0.10 psi/ft) MPSP=BHP—gas column =2,789 psi (3,422 psi—633psi) (B)data on potential gas-ones; The well bore is not expected to penetrate any shallow gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and:ones that have a propensity for differential sticking; See attached 2K-32 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing and Cement Program 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" 20" 62.5# H-40 Welded 79' 39' 39' 118' 118' Cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 3,394' 39' 39' 3433' 2941' 1435 sx DeepCRETE,196 sx 12#DeepCRETE 11" 7.625" 29.7# L-80 Hydril 563 13,675' 39' 39' 13714' 6356' 869 sx Class G,205 sx Gass G 6.75" 4.5" 12.6# L-80 Hydril 564 11,880' 13514' 6339' 25394' 6456' Uncemented Liner w ith Perf Pups • 2K-32 wp09 Cementing Schematic ^11 | | 20" Conductor to 118' U� 10'3/4^45.5#L'80HYD563 k 3.433' K8D/2.041'TVD 52°inc. 9'7/8^x11^ Hole Top of Cement(top HRZ) 12.00O' N1D/5.00Q'TVD Kalubik 12.405' K8D/G.118'TVD �‹ Kuparuk A 7-5/8"29.7#L-80 HYO563 Casing 13,503' 6,336'&4D/ TVD ^� �� 13.714K8D/O.356'TVD �� 80° � .� 6'3/4^ Hole 4-1/2" Liner 11.8#LD0 IBT u� Au 25.394' MD/8.450'TVD Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Tuesday, April 18, 2017 11:38 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2K-32(PTD 217-042) Surface Cement Calculations Good afternoon Victoria, Please see updated cement calculations (changes in red). Some of the cells on my excel sheet did not link when I changed parameters. • ID on 10-3/4" increased • Conductor length increase • Excess percentage from 40%to 50% (1.4 to 1.5) on the Lead cement. 2K-32 Cement Calculations Hole Size ft(TOC) ft (Bottom) OD ID ppf Conductor Depth: 42 39 110 20 19.14 94 Surface Casing Depth: 13.5 39 3433 10.75 9.95 45.5 Intermediate Casing Depth: 11 12000 13714 7.625 6.875 29.7 Surface Cement:Surface to 3,433' MD Capacities Lead 1.84 ft3/sx of 11.0 ppg DeepCRETE Tail 1.64 ft3/sx of 12.0 DeepCRETE OH 0.177045 Permafrost(PF) depth 1541 ft 13-1/2" x 10-3/4" 0.0r XS% Above PF 250 % 20" x 10-3/4" 0.243615 XS% Below PF 50 % 10-3/4" 0.096175 Tail Cement Length 500 ft 500 x 0.06478288 x 1.5 48.5871624 Shoe Track 80 ft 80 x 0.09617496 x 1 7.6939965 Open Hole x 0.17704488 x 1.5 0.5311346f Total 57 bbl 319 ft3 194 sx Lead Top Tail Cement to Permafrost 1392 ft 1392 x 0.06478288 x 1.5 135.2666k bbl Permafrost to 20" Casing 1431 ft 1431 x 0.06478288 x 3.5 324.465071 bbl Conductor Length 80 ft x 0.24361482 w° 79763C bbl Total: 487 bbl 1 • • 2731 ft3 1AQA SX Please let me know if this is closer to what you had. Thanks, Jake From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,April 18, 2017 11:07 AM To:Voss,Jake<Jake.Voss@conocophillips.com> Subject: [EXTERNAL]KRU 2K-32(PTD 217-042)Surface Cement Calculations Jake, Could you please check the surface casing cement calculations? Our calculations differ. 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.Loepnaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 • • 10-3/4" Surface casing run to 3,433' MD/2,941'TVD Cement from 3433' MD to 2933'(500' of tail)with DeepCRETE @ 12 ppg,and from 2933'to su 'ace with 11 ppg DeepCrete.Assume 250%excess annular volume in permafrost and 50%excess below the pe r afrost(1541' MD), zero excess in 20"conductor. 2K-32 Cement Calculations Hole Size ft(TOC) ft(Bottom) OD ID ppf Conductor Depth: 42 39 110 20 19.14 94 Surface Casing Depth: 13.5 28 3433 10.75 8.89 45.5 Intermediate Casing Depth: 11 12000 13714 7. 25 6.875 29.7 Surface Cement:Surface to 3,433' MD Capacities Lead 1.84 ft3/sx of 11.0 ppg De CRETE Tail 1.64 ft3/sx of 12.0 Deep ETE OH 0.177045 Permafrost(PF) depth 1541 ft 13-1/2"x 10-3/4" 0.064783 XS% Above PF 250 % 20" x 13-1/2" 0.243615 XS% Below PF 50 % 10-3/4" 0.076775 Tail Cement Length 500 ft 500 x 0.06478288 x 1.5 48.5871624 Shoe Track 80 ft 80 x 0.07677492 x 1 6.14199339 Open Hole 10 x 0.17704488 x 1.5 2.65567321 Total 57 bbl 322 ft3 196 sx Lead Top Tail Cement to Permafrost 1392 ft 1392 x 0.06478288 x 1.4 126.248883 bbl Permafrost to 20"Casing 1431 ft 1431 x 0.06478288 x 3.5 324.465071 bbl Conductor Length 80 ft 80 x 0.24361482 19.4891859 b b l Total: 470 bbl 2640 ft3 1435 sx I • 7-5/8"Intermediate casing run to 13,714'MD/6,356'TVD Intermediate slurry designed to be at the top of HRZ at 12,000' MD/5,99" 1VD which is 1270'MD/307' TVD above the Kuparuk Oil Pool.Assume 30%excess annular volume. I Intermediate#1 Cement: Cement from 13,714' MD to 12,� D Slurry: Capacities: 15.8ppg Class G yielding 1.16ft^3/sk 1 " 7-5/8" 0.055782 XS%for open hole and annulus: 30% 11"OH 0.145777 7-5/8"ST0.045916 Annulus Cement 1714 x /0.05578189 1. = 124.2932 bbls RatholeCement 2 0.14577667 x .3 ' 0y4'79019 s i —f Shoe Track 80 x 0.0459157 x 1 3'6Is Total 128 bbls 721 621 sx sx Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 142. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Intermediate Production 9-7/8"x 11" 13-1/2" Hole Hole 6-3/4" Hole 10-3/4"Casing 7-5/8"Casing 4-1/2" Liner Spud LSND FlowPro Mud System (WBM) (WBM) (WBM) Density 8.6- 10 9.2-10.8 9.5-11.0 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10- 12 5-8 10 minute Gel 30-50 10- 18 5- 12 API Filtrate NC < 6 <6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0- 10.0 9.0- 10.0 9.5- 10.0 • • Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A- Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to 0ril1 must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic • • 1. Move in/rig up Doyon Rig 142. Install Annular with 16"diverter line and function test. 2. Spud and directionally drill 13.5"hole to casing point at+/-/3433'MD/2,941'TVD as per directional plan (wp09). Survey with MWD,Gamma,Resistivity, GWD. J 3. Run and cement 10-3/4",45.5#,L80,Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job(post rig.) 4. In the event cement returns are not seen at surface,perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system,install and test 13-5/8"x 5,000 psi BOP's to 3500 psi(annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8"PDC bit and directional drilling assembly,with MWD/LWD(Gamma,resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 13.0 ppg,maximum of 15 ppg EMW leak off,recording results. 8. Open 9-5/8"x 11"Under Reamer and directionally drill to the top of the HRZ 9. Install RCD bearing at this time for use of MPD if necessary. 10. Directionally drill to intermediate TD of 13,714'MD/6,356' TVD,wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean,minimum of 3 bottoms up. 11. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 12. Lay down intermediate BHA and rack back 5"DP 13. Run 7-5/8",29.7#L80,Hydril 563 casing from surface to TD at 3,714'MD. 14. Pump cement job as per Schlumberger proposal. Top of cement to be 12,000'MD(top of HRZ formation OR approximately 1270 MD/307' TVD above Kuparuk Pool), 15. Flush 10-3/4"x 7-5/8"annulus with water,followed by diesel to freeze protect. 16. Lay down 5"DP. 17. PU 4"DP,6-3/4"bit,and drilling assembly with MWD/LWD(Gamma,resistivity,Periscope,and neutron/ density, SonicScope-top of cement) ✓ 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes and chart. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 13.ppg,maximum of 14.5 ppg EMW leak off,recording results. 20. Install RCD and swap mud over to 9.5 ppg FlowPro mud system 21. Directionally drill 6-3/4"hole geosteering through the Kuparuk A4 sand to TD 25,394'MD as per directional plan(wp09).Hold back pressure on connections with MPD as needed. 22. Circulate hole clean and BROOH to shoe. Circulate hole clean and swap to KWF brine. POOH 23. Lay down production BHA. 24. PU and run 4-1/2", 11.6#liner. The top of liner will be placed at-13,514 MD,allowing for 200' of overlap in the 7-5/8"casing. 25. Set liner hanger. Slackoff and set liner top packer. 26. Monitor well for flow for 15 minutes • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday,April 27, 2017 8:36 AM To: jake.voss@conocophillips.com Subject: KRU 2K-32(PTD 217-042) LWD-Sonic Jake, These provisions will be included in the approved PTD. Approval is granted to run the LWD-Sonic on upcoming well KRU 2K-32 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement(and lengths)that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation,or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement,just as the e-line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC.Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report,the logs and the FIT, remedial measures or additional logging may be required. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCcilalaska.gov 1 • • 27. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes,chart results. 28. Flow check well for 30 minutes and POOH 29. Run 3-1/2"upper completion. 30. Nipple down BOPE,nipple up tree and test. 31. Freeze protect well with diesel and install BPV. 32. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (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. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary • • Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Thursday,April 27,2017 8:19 AM To: Loepp,Victoria T(DOA) Cc: Bearden,J Daniel Subject: RE: KRU 2K-32(PTD 217-042)Anti-collision Victoria, 2K-18 has been plugged and abandoned.We will be using Gyro-while-drilling for directional control until we pass our anti-collision issues(close to 500' MD). This will be similar to the KRU 2M-37 (PTD 216-083)and 2M-38(PTD 216-083)wells we drilled in November 2016 and the January of this year which had similar anti-collision issues with P&A wells in the surface section. Please let me know if you need any more info from me. Thanks-Jake From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,April 27,2017 8:02 AM To:Voss,Jake<Jake.Voss@conocophillips.com> Cc: Bearden,J Daniel<1.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]KRU 2K-32(PTD 217-042)Anti-collision Jake, KRU 2K-18 fails major risk when drilling KRU 2K-32 in the anti-collision analysis. Will 2K-18 be shut in while drilling 2K-32 or a deep plug set? Please outline anti-collision mitigation measures. 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.Loeppl 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.Loem@alaska.gov 1 • s 2 K-32 ConocoPhillips Grassroots Horizontal A Sand Injector Proposed Wellbore Schematic(wp09) ) 0'0, FMC Wdoead&Caoeron Tree Last Edited: 4 4'bee,topjioiis 44.1257 BTM Voss 3-30-17 ,2D'Conductor to-115 A '� Base Permafrost 154T MDI 1505'IVO u J 13.5"Surface Hole Base West Sak:3130'MDI 2745'IVO a J 3-W'x 1-W'Camco MMG GLM Al — Surface Casing 10-3/4"45.5#L-80 Hydril 563 3,433 MD/2,941'TVD(52' INC) il el 9-7/8"x 11"Intermediate Hole m. a Tuba: 'i 3-12'9.31 L•80 EUE 8RD-MOD ra , C1.MMN4SOV Z en C37:691T MDI506C TVD „akerzatr cuu Shang sleeve i .nG.l\ 3-•h^275"D Nipple Wim" HiQ:121109'MD16001'TVD rs Soo- s"er Prckaroj,u Kaiubilc 12406'1,11316116'TVD z I. Kumaruk C:13276•MDI6396'TVD p 19 'a�r+` ^_^�^_' Kuparut A4:1390(MDI6361'1VD a. er sx•o+.w we u V 2 Packer/Floc Lock Liner 0 �r Hanger 7D.25,39C MD I6,466'1O Intermediate Casing Production Liner 1 -3/4"Production Hole 7-5/8"29.7#L-80 Hyd563 Casing 4-1/2"12.6#1-80 1-lydril 563 red Pert Joints 13714'MD!6,6356 TVD(86n INC) 25,394'MDI 6,456'TVD N O • w O w • N N • N 8 ' 44\0011111/4 N cn --ter -o Ir—\-1[. : °CNN O O f U > I • r 4, r C 1 r-n– r r • ° (.4 `` '9 1 '9 Kil 3 1R • NL' � I El 41 • N L. -9 t z . :: � v 3:11 • � - • � rp N -�� ° N _ r N . • N y // 7- Iml Nv 75D'. // 11.11 5 F m ET.' m r La o P INI/ O W N 1 a J al m • • 13:45,Mach 20 201.7 2K-32wp09 Permit Pack .,' 'Plan Summary top T-3-Sand C-80 A5 Lower Kalubik(K-1 mkr) K-5 Marker Top W Sak(W Stik'D) Kuparuk C(Top 04) , •, - � i • I on 5-� I / --- UpperKalubik(base HRZ5 \ Blase permafrost ki) / __-- L._5"-` at -y1 I / /Base W Sak - 0 ti 11 / // /! . --A4 0 rn 1 1 r ,./ "5/., C-37 Top HRZ K-2 ). I �� • 0 1 -- -0 „. I I 11 I I I I 1 ' I \A i I I I I I �tA!, . 0 I 6000 12000 18000 24000 10 3/4"x13-1/4 Measured Depth 7-5/8"x 9-718 x ti" o- 0" Geodetic Datum: 10 3/4"x 13-1 _ p4 Depth Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) }�Q% Rig: Doyon 142 _ / a a o 0 0 I7-5/8"x 9-718 x 11"� 14 1/2"x 6-3/41 110105.,.../. ��/1/L -rib-- CV �o . o 0 0 / \ o , ^ 010 0 0 0 0 / o 0 0 0 0 0 0 0 o.n ---..• '� i 0�� .� o 0 0 0 0 0 0 0 0 0 oro -.- a w / ii goo ao1 o N oCrd '�C\\oon, '•••= -• Xt.? tH• .- .-• N Ndb N N 0 \NN •••-••- - ' ''''''''''''''''''''''''''''''''''' 1 1 II 1 I I I 41 1,5 I I I, 1 r1 tl I I, ,, I t1 tr 1 39 "`""' 300 0 2500 5000 7500 100008 6;543 15000 17500 20000 22500 300 -490 Horizontal Departure -c'=-a's> a 330 ' !AT/L-..1111 30 490- 670 - 670 -660 0 60 1 ®� - ®® 11=11111111®® ��`4,04,, 8601040 - 1230 II 300 r.; aay.OA� 1230 - 1410 °E.-' L'i a ri;lc°`' _'��\\\� 1410 - 1600 lD •I l�i ��4 •y `iiiiktii'4`'- i.4.Z.ZNA tl�� 1600 -2590 p V ol/ 4,' � 2590 3560 <j 30 1- 'AS,'j p�J((I,1iJ;r,:.r- Ull � 3560 -4560 o 270.`-_:_Iii li•1. :-/;"/ 4560 -5550 m 1 r41!/t je' 4ir71 .,. 90 5550 -6540 (42! . IRDS;•�MVAVINO ? ;• - 6540 -7520 ♦ z 7520 e510 Vtr0 *4e ' 4++0410 6510 -9500 0 3500 7000 10500 14000 17500 21000 24500 240 'x! r .- • 120 9500 - 11490 � "silk$ �,766.i 1 -- 11490 - 13470 SURVEY PROGRAM y11b►\L7.RS aJ 13470- 15460 Surface Location - -e yyap•! •A:..•`• epth From Depth To Survey/Plan Tool North/Y: 4:51 1 1 1�))).', .. 15460 - 17a50 East/X: ..\t. l•;-- 17450- 19440 39.00 898.20 2K-32wp09(Plan:2K-32) GYD-GC-SS pad Elevation:116.70 210 -Itc, 150 89820 1898.20 2K-32wp09(Plan:2K-32) MWD 7 . 19440 21420 898.20 3432.75 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC 180 21420 - 23410 3432.75 4932.75 2K-32wp09(Plan:2K-32) MWD CASING DETAILS 3432.75 13714.20 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC 23410 -25394 Name TM 13714.20 15214.20 2K-32wp09(Plan:2K-32) MWD TVD MD 13714.20 25394.36 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC 6355.70 3734.25 10 x 9-/13-112 Magnetic ModelMagnetid Date: BGCab-716 6455.70 15314.36 7-5/8"1 2 x8 x/1" Magnettc lition: 13-Jul-17 6455.70 25394.36 4 1/2"x 6-3/4" Magnetic Declination: i 7.40' To convert a Magnetic Direction to a True Direction,Add 17.40°East SECTION DETAILS - iec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation -590`465Z-7 T3 Sand 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.51100'DLS,130°TF,for 500' K-15 Marker 3 800.00 7.50 130.00 798.57 -21.01 25.03 1.50 130.00 16.34 Start 2.51100'DLS,0°TF,for 686.45' 4 1486.45 24.66 130.00 1455.70 -142.77 170.14 2.50 0.00 111.05 Hold for 110.04' 5 1596.48 24.66 130.00 1555.70 -17228 205.32 0.00 0.00 134.01 Start 31100'DLS,40°TF,for 532.36' -1505.7 6 2128.84 38.21 146.62 2009.70 -382.50 382.14 3.00 40.00 310.34 Start 2.07%100'DLS,72.56°TF,for 1303.9' Base permafrost(? 7 3432.75 52.00 180.00 2940-70 -1249.09 608.24 2.07 72.56 1124.50 Hold for 20' 8 3452.75 52.00 180.00 2953.01 -1264.85 608.24 0.00 0.00 1140.02 Start 3%100'DLS,93.29°TF,for 2162.42' -2185.7 9 5615.17 72.40 251.49 4067.28 -2588.58 -488.82 3.00 9329 2634.14 Hold for 6395.73' 10 12010.89 72.40 251.49 6001.27 -4524.03 -6269.74 0.00 0.00 5544.03 Start 3.751100'DLS,-85.75°TF,for 1703.31' Top W Oak(W Sak 1) 11 13714.20 86.00 187.65 6355.70 -5753.86 -7257.09 3.75 -85.75 6926.62 2K-32 01.Heel 020717 JH Hold for 20' -2745.7 12 13734.20 86.00 187.65 6357.10 -5773.63 -7259.75 0.00 0.00 6946.56 Start 311100'DLS,-1.73"TF,for 138.18' 13 13872.38 90.14 187.53 6361.74 -5910.49 -7277.99 3.00 -1.73 7084.50 Hold for 2341.84' Base W Sak 14 16214.22 90.14 187.53 6355.88 -8232.14 -7584.73 0.00 0.00 9424.15 Start 311100'DLS,91.87°TF,for 146.21' -3233.7 15 16360.42 90.00 191.91 6355.70 -8376.21 -7609.41 3.00 91.87 9570.32 2K-32 02.Prefault 020717 JH Adjust TF to 175.84°,for 117.76' 16 16478.18 86.48 192.17 6359.32 -8491.31 -7633.95 3.00 175.84 9687.93 Hold for 753.08' 17 17231.26 86.48 192.17 6405.60 -9226.08 -7792.37 0.00 0.0010439.05 Start 311100'DLS,-45.47"TF,for 151.98' 18 17383.24 89.68 188.92 6410.70 -9375.37_-7820.16 3.00 -45.4710590.90 2K-32 03.Postfault 020717 JH Hold for 8011.12' C-e0 19 25394.36 89.68 188.92 6455.70-17289.51 -9062.10 0.00 0.0018600.46 2K-32 04.Toe 020717 JH TD:25394.36'MD,6455.T TVD -4607.7 - Failed AC against ��0??-50 -5065.0 2K-18 near C-37 1 1 1' • TCR required surface. TCR 5715.7 C-35required. 7 PV,,H151_KZ- q )) irr A4 By signing this Iaknowledge Mal I nava been informed of all dsh.eked.that1.e dale is coned,ensured Rs completeness,and NI surrounding wells are assigned to be proper pinion and I approve b be In and=baron avoidance pan as set out in be a ar pal.I appom eas Na basis for the Ii,W well plan and wells.drawings.lalso acknowledge Mak unless notified aMrcnse,all targets M1..1001.lad. Wered.T. Prepared by: Checked by: Accepted by: Approved by: 1 B.Temple V.Osara E.Sterk J.Voss • s Spider View • • 10:34,March 29 2017 Easting(3000 usft/in) I . I : . . I I , , , I , , , , , , I : 1 , , I IP-d41 , , , , ,`(,pi, , , ,2'x'051 , ' 24id1, , , 1 , , , , I , , , , i -/2M-33 1®PBAg 15 — ^c _ 2M-32L1PB1 2M 4 M-08 2M-09 --" '''';= 8Ap Kuparuk 2K Pa 2K-07 2G-14 2G-13 _ _r 15L1 2G-14AL1 2G-13P - 2G-13P4.2_ 2 X1413@11 � �e�/,, 2M-351Vi e 2M-0: 1-01 - � 2K-15 - 2S-11 - 2K- 2K-13AL2 2 26 _ 2M-08L1 W 2S-09A 13AL1 : / _ 23-04 2S-07 2S-05 K- 'AL91pp 2K-19 46,204 jyi..S11 1 I _ - 2K-18 'K21KSL3 2K-23 _ - 2S-09 2K-20 - 2K-22A c 2K-28AL —Z w : K-21A - a _ 2K-25 2K-21 2K-22 2K-24 - Kuparuk 2S Pas 2S-02 _W _ o c. r— Z ''�.y,,..% y 2K-22AL1-01 c ir2K-22AL1 • yKRU 21-10-8 S ,rk Tooth til - i _ 2S-03PB1 2S-01 2S-10 2K-32wp09- --- _ 2S-03 25,01011 . . i . . 11 1 , . . i , i 1 I1IIIIIIIIIIIi1I [ IIIIIT , , i 1 III 1 . 1 1 1 IIIIIIIIIIIIIIIIII . , 1 Easting(3000 usftlin) Plan View • • 2K-32wp09 Plan View 2K-Timberlinew p10 IP 3500 -K-TfmberlinePBlwp 10 3/4"x 13-1/2M il ,-----N:1-Aeir***0417 -- ..is ze,i',s, 1Q+`�"44:16441141=_t ,4 _ oPf I -E-3500- 75/8"x97/8x 11" - -- %- . Sf;U$ lip cp‘qtr ___4p 1. .... _,._ ..._-: _ . ---,_, , ,, . cc,?, -._ ___;(1, atir,e„011__0",,,, i*, __, --- e__ ___--- /0 +7000- 15 W�{� 1 000 �y "f'j`il�0 z 16000 .__t _`moi `1'_a_la�` 17000 ..,.,::::-_--ie 10500- 18000 c°n 19000 20000 2S-01 21000 •-14000- 22000 23000 © -33wp.y 2K-32wp09 2K-31 wwo5 24000 4 1/2"x 6-3/4" - 'L 550o000 -17500 5396 2K-30w Po8 Wip -21000 -17500 -14000 -10500 -7000 -3500 0 3500 7000 10500 West(-)/East(+) (3500 usft/in) Section View 0 0 2K-32wp09 Section View -2500- 0- A 2 [0° 103/4"x13-1/2 K-15 MarkdA o --- ---1- _„v.� Base permafrost(?),,-. a "� 2500- Top W Sak(W Sak,b) N a O 7-5/8”x 9-7/8 x 11" 4 1/2"x 6-3/4" c? a ,.Base W Sak__ ®o o Y p C 80 000 OO N O O Ta C-50 o00 to 00 5000 7 — — — ,',-+. -f- — — — --0-- Cc-43°71 8 8—o— —. —o�n4a, ,'�,M a,- ccc o 0 0. 0 0 0 0m - - Kuparuk C (Top C4) i1 . i :A4 0 0 0 7500 0 0 0 A5; Top HRZ (K-2 mkr) 2K-32 01.Heel 020717 JH 2K-32 03.Postfault 020717,H Lower Kalubik(K-1 mkr) 10000- Upper Kalubik(base HRZ) 2K-32 02.Prefault 020717.,1H 2K-32 04.Toe 020717 JH 1 I I I I 1 I I 1 0 2500 5000 7500 10000 12500 15000 17500 20000 Vertical Section at 190.00°(2500 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-32 Plan: 2K-32 Plan: 2K-32wp09 Report 29 March, 2017 • . Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 21(Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 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 2K Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.02 ° Well Plan:2K-32 Well Position +N/-S 0.00 usft Northing: Latitude: +E/-W 0.00 usft Fasting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 116.70 usft Wellbore Plan:2K-32 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2016 7/13/2017 17.40 80.86 57,527 Design 2K-32wp09 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 0.00 190.00 Survey Tool Program Date 3/29/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 898.20 2K-32wp09(Plan:2K-32) GYD-GC-SS Gyrodata gyro single shots 898.20 1,898.20 2K-32wp09(Plan:2K-32) MWD MWD-Standard 898.20 3,432.75 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,432.75 4,932.75 2K-32wp09(Plan:2K-32) MWD MWD-Standard 3,432.75 13,714.20 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,714.20 15,214.20 2K-32wp09(Plan:2K-32) MWD MWD-Standard 13,714.20 25,394.36 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 39.00 0.00 0.00 39.00 -116.70 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -55.70 0.00 0.00 0.05 200.00 0.00 0.00 200.00 44.30 0.00 0.00 0.19 300.00 0.00 0.00 300.00 144.30 0.00 0.00 0.34 KOP:Start 1.5°1100'DLS,130°TF,for 500' 400.00 1.50 130.00 399.99 244.29 1.50 130.00 0.43 3/29/2017 10:08:06AM Page 2 COMPASS 5000.1 Build 74 • • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°1100usft) (°) (usft) 465.75 2.49 130.00 465.70 310.00 1.50 0.00 0.50 top T-3 Sand 500.00 3.00 130.00 499.91 344.21 1.50 0.00 0.50 590.98 4.36 130.00 590.70 435.00 1.50 0.00 0.60 K-15 Marker 600.00 4.50 130.00 599.69 443.99 1.50 0.00 0.61 700.00 6.00 130.00 699.27 543.57 1.50 0.00 0.73 800.00 7.50 130.00 798.57 642.87 1.50 0.00 0.86 Start 2.51100'DLS,0°TF,for 686.45' 900.00 10.00 130.00 897.40 741.70 2.50 0.00 1.01 1,000.00 12.50 130.00 995.47 839.77 2.50 0.00 1.11 1,100.00 15.00 130.00 1,092.60 936.90 2.50 0.00 1.23 1,200.00 17.50 130.00 1,188.60 1,032.90 2.50 0.00 1.49 1,300.00 20.00 130.00 1,283.28 1,127.58 2.50 0.00 1.87 1,400.00 22.50 130.00 1,376.48 1,220.78 2.50 0.00 2.37 1,486.45 24.66 130.00 1,455.70 1,300.00 2.50 0.00 2.87 Hold for 110.04' 1,500.00 24.66 130.00 1,468.02 1,312.32 0.00 0.00 2.96 1,541.47 24.66 130.00 1,505.70 1,350.00 0.00 0.00 3.57 Base permafrost(?) 1,596.48 24.66 130.00 1,555.70 1,400.00 0.00 0.00 3.57 Start 3°/100'DLS,40°TF,for 532.36' 1,600.00 24.74 130.16 1,558.89 1,403.19 3.00 40.00 3.59 1,700.00 27.11 134.38 1,648.83 1,493.13 3.00 39.85 4.21 1,800.00 29.58 137.96 1,736.84 1,581.14 3.00 36.06 4.89 1,900.00 32.14 141.02 1,822.68 1,666.98 3.00 32.91 5.57 2,000.00 34.76 143.68 1,906.11 1,750.41 3.00 30.28 2.98 2,100.00 37.43 146.00 1,986.92 1,831.22 3.00 28.06 3.32 2,128.84 38.21 146.62 2,009.70 1,854.00 3.00 26.19 3.42 Start 2.07°/100'DLS,72.56°TF,for 1303.9' 2,200.00 38.67 148.87 2,065.44 1,909.74 2.07 72.56 3.63 2,300.00 39.40 151.95 2,143.12 1,987.42 2.07 70.79 3.90 2,355.27 39.83 153.62 2,185.70 2,030.00 2.07 68.40 4.18 Top W Sak(W Sak D) 2,400.00 40.20 154.94 2,219.96 2,064.26 2.07 67.12 4.19 2,500.00 41.07 157.83 2,295.85 2,140.15 2.07 66.10 4.49 2,600.00 42.02 160.61 2,370.70 2,215.00 2.07 63.91 4.81 2,700.00 43.03 163.29 2,444.41 2,288.71 2.07 61.83 5.14 2,800.00 44.10 165.86 2,516.87 2,361.17 2.07 59.86 5.49 2,900.00 45.23 168.34 2,588.00 2,432.30 2.07 57.99 5.84 3,000.00 46.40 170.72 2,657.70 2,502.00 2.07 56.23 6.20 3,100.00 47.63 173.01 2,725.89 2,570.19 2.07 54.57 6.57 3,129.51 48.00 173.66 2,745.70 2,590.00 2.07 53.01 6.95 Base W Sak 3,200.00 48.90 175.20 2,792.46 2,636.76 2.07 52.57 6.95 3/29/2017 10:08:06AM Page 3 COMPASS 5000.1 Build 74 • • R r1irt Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 3,300.00 50.21 177.32 2,857.34 2,701.64 2.07 51.54 7.34 3,400.00 51.55 179.35 2,920.44 2,764.74 2.07 50.17 7.74 3,432.75 52.00 180.00 2,940.70 2,785.00 2.07 48.89 7.88 Hold for 20'-10 3/4"x 13-1/2 3,452.75 52.00 180.00 2,953.01 2,797.31 0.00 0.00 7.97 Start 3°/100'DLS,93.29°TF,for 2162.42' 3,500.00 51.93 181.80 2,982.13 2,826.43 3.00 93.29 8.13 3,600.00 51.88 185.61 3,043.84 2,888.14 3.00 92.18 8.51 3,700.00 51.95 189.42 3,105.54 2,949.84 3.00 89.83 8.97 3,800.00 52.14 193.22 3,167.05 3,011.35 3.00 87.48 9.50 3,900.00 52.46 196.99 3,228.22 3,072.52 3.00 85.14 10.07 3,909.00 52.49 197.33 3,233.70 3,078.00 3.00 82.84 10.66 C-80 4,000.00 52.89 200.72 3,288.87 3,133.17 3.00 82.63 10.67 4,100.00 53.44 204.41 3,348.83 3,193.13 3.00 80.57 11.30 4,200.00 54.10 208.04 3,407.95 3,252.25 3.00 78.36 11.95 4,300.00 54.87 211.60 3,466.06 3,310.36 3.00 76.22 12.62 4,400.00 55.74 215.09 3,522.99 3,367.29 3.00 74.15 13.29 4,500.00 56.70 218.51 3,578.61 3,422.91 3.00 72.16 13.98 4,600.00 57.76 221.85 3,632.74 3,477.04 3.00 70.26 14.67 4,700.00 58.90 225.11 3,685.25 3,529.55 3.00 68.45 15.38 4,800.00 60.13 228.28 3,735.98 3,580.28 3.00 66.74 16.09 4,900.00 61.43 231.38 3,784.81 3,629.11 3.00 65.13 16.62 5,000.00 62.79 234.41 3,831.60 3,675.90 3.00 63.61 7.98 5,100.00 64.22 237.35 3,876.21 3,720.51 3.00 62.20 8.12 5,200.00 65.71 240.23 3,918.53 3,762.83 3.00 60.89 8.28 5,300.00 67.25 243.04 3,958.44 3,802.74 3.00 59.67 8.46 5,400.00 68.84 245.78 3,995.84 3,840.14 3.00 58.55 8.65 5,500.00 70.47 248.46 4,030.61 3,874.91 3.00 57.52 8.84 5,600.00 72.14 251.09 4,062.66 3,906.96 3.00 56.59 9.05 5,615.17 72.40 251.49 4,067.28 3,911.58 3.00 55.74 9.08 Hold for 6395.73' 5,700.00 72.40 251.49 4,092.93 3,937.23 0.00 0.00 9.48 5,800.00 72.40 251.49 4,123.17 3,967.47 0.00 0.00 9.92 5,900.00 72.40 251.49 4,153.41 3,997.71 0.00 0.00 10.37 6,000.00 72.40 251.49 4,183.65 4,027.95 0.00 0.00 10.83 6,100.00 72.40 251.49 4,213.89 4,058.19 0.00 0.00 11.31 6,200.00 72.40 251.49 4,244.12 4,088.42 0.00 0.00 11.79 6,300.00 72.40 251.49 4,274.36 4,118.66 0.00 0.00 12.28 6,400.00 72.40 251.49 4,304.60 4,148.90 0.00 0.00 12.78 6,500.00 72.40 251.49 4,334.84 4,179.14 0.00 0.00 13.29 6,600.00 72.40 251.49 4,365.08 4,209.38 0.00 0.00 13.80 6,700.00 72.40 251.49 4,395.32 4,239.62 0.00 0.00 14.32 6,800.00 72.40 251.49 4,425.56 4,269.86 0.00 0.00 14.84 6,900.00 72.40 251.49 4,455.80 4,300.10 0.00 0.00 15.37 3/29/2017 10:08:06AM Page 4 COMPASS 5000.1 Build 74 • • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°l100usft) (°) (usft) 7,000.00 72.40 251.49 4,486.04 4,330.34 0.00 0.00 15.90 7,100.00 72.40 251.49 4,516.27 4,360.57 0.00 0.00 16.43 7,200.00 72.40 251.49 4,546.51 4,390.81 0.00 0.00 16.97 7,300.00 72.40 251.49 4,576.75 4,421.05 0.00 0.00 17.51 7,400.00 72.40 251.49 4,606.99 4,451.29 0.00 0.00 18.05 7,402.35 72.40 251.49 4,607.70 4,452.00 0.00 0.00 18.59 C-50 7,500.00 72.40 251.49 4,637.23 4,481.53 0.00 0.00 18.60 7,600.00 72.40 251.49 4,667.47 4,511.77 0.00 0.00 19.14 7,700.00 72.40 251.49 4,697.71 4,542.01 0.00 0.00 19.69 7,800.00 72.40 251.49 4,727.95 4,572.25 0.00 0.00 20.24 7,900.00 72.40 251.49 4,758.18 4,602.48 0.00 0.00 20.80 8,000.00 72.40 251.49 4,788.42 4,632.72 0.00 0.00 21.35 8,100.00 72.40 251.49 4,818.66 4,662.96 0.00 0.00 21.91 8,200.00 72.40 251.49 4,848.90 4,693.20 0.00 0.00 22.46 8,255.55 72.40 251.49 4,865.70 4,710.00 0.00 0.00 23.01 C-40 8,300.00 72.40 251.49 4,879.14 4,723.44 0.00 0.00 23.02 8,400.00 72.40 251.49 4,909.38 4,753.68 0.00 0.00 23.58 8,500.00 72.40 251.49 4,939.62 4,783.92 0.00 0.00 24.14 8,600.00 72.40 251.49 4,969.86 4,814.16 0.00 0.00 24.70 8,700.00 72.40 251.49 5,000.10 4,844.40 0.00 0.00 25.26 8,800.00 72.40 251.49 5,030.33 4,874.63 0.00 0.00 25.83 8,900.00 72.40 251.49 5,060.57 4,904.87 0.00 0.00 26.39 8,916.96 72.40 251.49 5,065.70 4,910.00 0.00 0.00 26.95 C-37 9,000.00 72.40 251.49 5,090.81 4,935.11 0.00 0.00 26.96 9,100.00 72.40 251.49 5,121.05 4,965.35 0.00 0.00 27.52 9,200.00 72.40 251.49 5,151.29 4,995.59 0.00 0.00 28.09 9,300.00 72.40 251.49 5,181.53 5,025.83 0.00 0.00 28.65 9,400.00 72.40 251.49 5,211.77 5,056.07 0.00 0.00 29.22 9,500.00 72.40 251.49 5,242.01 5,086.31 0.00 0.00 29.79 9,600.00 72.40 251.49 5,272.24 5,116.54 0.00 0.00 30.36 9,700.00 72.40 251.49 5,302.48 5,146.78 0.00 0.00 30.93 9,800.00 72.40 251.49 5,332.72 5,177.02 0.00 0.00 31.49 9,900.00 72.40 251.49 5,362.96 5,207.26 0.00 0.00 32.06 10,000.00 72.40 251.49 5,393.20 5,237.50 0.00 0.00 32.63 10,100.00 72.40 251.49 5,423.44 5,267.74 0.00 0.00 33.20 10,200.00 72.40 251.49 5,453.68 5,297.98 0.00 0.00 33.78 10,300.00 72.40 251.49 5,483.92 5,328.22 0.00 0.00 34.35 10,400.00 72.40 251.49 5,514.16 5,358.46 0.00 0.00 34.92 10,500.00 72.40 251.49 5,544.39 5,388.69 0.00 0.00 35.49 10,600.00 72.40 251.49 5,574.63 5,418.93 0.00 0.00 36.06 10,700.00 72.40 251.49 5,604.87 5,449.17 0.00 0.00 36.63 10,800.00 72.40 251.49 5,635.11 5,479.41 0.00 0.00 37.21 3/29/2017 10:08:06AM Page 5 COMPASS 5000.1 Build 74 • • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (0) (usft) 10,900.00 72.40 251.49 5,665.35 5,509.65 0.00 0.00 37.78 11,000.00 72.40 251.49 5,695.59 5,539.89 0.00 0.00 38.35 11,066.51 72.40 251.49 5,715.70 5,560.00 0.00 0.00 38.92 C-35 11,100.00 72.40 251.49 5,725.83 5,570.13 0.00 0.00 38.93 11,200.00 72.40 251.49 5,756.07 5,600.37 0.00 0.00 39.50 11,300.00 72.40 251.49 5,786.30 5,630.60 0.00 0.00 40.07 11,400.00 72.40 251.49 5,816.54 5,660.84 0.00 0.00 40.65 11,500.00 72.40 251.49 5,846.78 5,691.08 0.00 0.00 41.22 11,600.00 72.40 251.49 5,877.02 5,721.32 0.00 0.00 41.80 11,700.00 72.40 251.49 5,907.26 5,751.56 0.00 0.00 42.37 11,800.00 72.40 251.49 5,937.50 5,781.80 0.00 0.00 42.95 11,900.00 72.40 251.49 5,967.74 5,812.04 0.00 0.00 43.52 12,000.00 72.40 251.49 5,997.98 5,842.28 0.00 0.00 44.10 12,009.01 72.40 251.49 6,000.70 5,845.00 0.00 0.00 44.16 Top HRZ(K-2 mkr) 12,010.89 72.40 251.49 6,001.27 5,845.57 0.00 0.00 44.16 Start 3.75°/100'DLS,-85.75°TF,for 1703.31' 12,100.00 72.68 248.00 6,028.02 5,872.32 3.75 -85.75 44.90 12,200.00 73.06 244.10 6,057.48 5,901.78 3.75 -84.70 45.42 12,300.00 73.52 240.21 6,086.25 5,930.55 3.75 -83.55 45.73 12400.00 74.05 236.34 6,114.18 5,958.48 3.75 -82.44 45.82 12,405.52 74.08 236.13 6,115.70 5,960.00 3.75 -81.36 45.71 Upper Kalubik(base HRZ) 12,500.00 74.64 232.50 6,141.18 5,985.48 3.75 -81.30 45.70 12,600.00 75.31 228.68 6,167.11 6,011.41 3.75 -80.32 45.38 12,700.00 76.03 224.88 6,191.87 6,036.17 3.75 -79.33 44.86 12,736.96 76.32 223.48 6,200.70 6,045.00 3.75 -78.39 44.16 Lower Kalubik(K-1 mkr) 12,800.00 76.82 221.11 6,215.35 6,059.65 3.75 -78.05 44.14 12,900.00 77.65 217.36 6,237.45 6,081.75 3.75 -77.50 43.25 13,000.00 78.54 213.63 6,258.08 6,102.38 3.75 -76.67 42.18 13,100.00 79.48 209.94 6,277.15 6,121.45 3.75 -75.90 40.95 13,200.00 80.46 206.26 6,294.57 6,138.87 3.75 -75.20 39.56 13,269.69 81.16 203.71 6,305.70 6,150.00 3.75 -74.56 38.06 Kuparuk C(Top C4) 13,300.00 81.48 202.60 6,310.27 6,154.57 3.75 -74.15 38.04 13,400.00 82.53 198.97 6,324.20 6,168.50 3.75 -73.98 36.38 13,500.00 83.61 195.35 6,336.27 6,180.57 3.75 -73.48 34.62 13,503.87 83.65 195.21 6,336.70 6,181.00 3.75 -73.04 32.79 A5 13,600.00 84.71 191.75 6,346.45 6,190.75 3.75 -73.03 32.75 13,700.00 85.84 188.16 6,354.69 6,198.99 3.75 -72.67 30.82 13,714.20 86.00 187.65 6,355.70 6,200.00 3.75 -72.38 30.58 Hold for 20'-7-5/8"x 9-7/8 x 11" 3/29/2017 10:08:06AM Page 6 COMPASS 5000.1 Build 74 • • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 13,734.20 86.00 187.65 6,357.09 6,201.39 0.00 0.00 30.75 Start 3°1100'DLS,-1.73°TF,for 138.18' 13,800.00 87.97 187.59 6,360.55 6,204.85 3.00 -1.73 31.27 13,804.26 88.10 187.59 6,360.70 6,205.00 3.00 -1.73 31.88 A4 13,872.38 90.14 187.53 6,361.74 6,206.04 3.00 -1.73 31.88 Hold for 2341.84' 13,900.00 90.14 187.53 6,361.67 6,205.97 0.00 0.00 32.13 14,000.00 90.14 187.53 6,361.42 6,205.72 0.00 0.00 33.07 14,100.00 90.14 187.53 6,361.17 6,205.47 0.00 0.00 34.04 14,200.00 90.14 187.53 6,360.92 6,205.22 0.00 0.00 35.05 14,300.00 90.14 187.53 6,360.67 6,204.97 0.00 0.00 36.10 14,400.00 90.14 187.53 6,360.42 6,204.72 0.00 0.00 37.17 14,500.00 90.14 187.53 6,360.17 6,204.47 0.00 0.00 38.27 14,600.00 90.14 187.53 6,359.92 6,204.22 0.00 0.00 39.40 14,700.00 90.14 187.53 6,359.67 6,203.97 0.00 0.00 40.54 14,800.00 90.14 187.53 6,359.42 6,203.72 0.00 0.00 41.71 14,900.00 90.14 187.53 6,359.17 6,203.47 0.00 0.00 42.90 15,000.00 90.14 187.53 6,358.92 6,203.22 0.00 0.00 44.10 15,100.00 90.14 187.53 6,358.67 6,202.97 0.00 0.00 45.32 15,200.00 90.14 187.53 6,358.42 6,202.72 0.00 0.00 46.33 15,300.00 90.14 187.53 6,358.17 6,202.47 0.00 0.00 35.33 15,400.00 90.14 187.53 6,357.92 6,202.22 0.00 0.00 35.69 15,500.00 90.14 187.53 6,357.67 6,201.97 0.00 0.00 36.06 15,600.00 90.14 187.53 6,357.42 6,201.72 0.00 0.00 36.44 15,700.00 90.14 187.53 6,357.17 6,201.47 0.00 0.00 36.82 15,800.00 90.14 187.53 6,356.92 6,201.22 0.00 0.00 37.20 15,900.00 90.14 187.53 6,356.67 6,200.97 0.00 0.00 37.59 16,000.00 90.14 187.53 6,356.42 6,200.72 0.00 0.00 37.99 16,100.00 90.14 187.53 6,356.17 6,200.47 0.00 0.00 38.39 16,200.00 90.14 187.53 6,355.92 6,200.22 0.00 0.00 38.79 16,214.22 90.14 187.53 6,355.88 6,200.18 0.00 0.00 38.85 Start 3°/100'DLS,91.87°TF,for 146.21' 16,300.00 90.06 190.10 6,355.73 6,200.03 3.00 91.87 40.56 16,360.42 90.00 191.91 6,355.70 6,200.00 3.00 91.87 41.69 Adjust TF to 175.84°,for 117.76' 16,400.00 88.82 192.00 6,356.11 6,200.41 3.00 175.84 41.82 16,478.18 86.48 192.17 6,359.32 6,203.62 3.00 175.84 42.03 Hold for 753.08' 16,500.00 86.48 192.17 6,360.66 6,204.96 0.00 0.00 42.09 16,600.00 86.48 192.17 6,366.81 6,211.11 0.00 0.00 42.48 16,700.00 86.48 192.17 6,372.95 6,217.25 0.00 0.00 42.88 16,800.00 86.48 192.17 6,379.10 6,223.40 0.00 0.00 43.29 16,900.00 86.48 192.17 6,385.24 6,229.54 0.00 0.00 43.69 17,000.00 86.48 192.17 6,391.39 6,235.69 0.00 0.00 44.11 3/29/2017 10:08:06AM Page 7 COMPASS 5000.1 Build 74 II • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 17,100.00 86.48 192.17 6,397.53 6,241.83 0.00 0.00 44.52 17,200.00 86.48 192.17 6,403.68 6,247.98 0.00 0.00 44.94 17,231.26 86.48 192.17 6,405.60 6,249.90 0.00 0.00 45.07 Start 3°/100'DLS,-45.47°TF,for 151.98' 17,300.00 87.92 190.70 6,408.96 6,253.26 3.00 -45.47 44.59 17,383.24 89.68 188.92 6,410.70 6,255.00 3.00 -45.39 43.98 Hold for 8011.12' 17,400.00 89.68 188.92 6,410.79 6,255.09 0.00 0.00 44.05 17,500.00 89.68 188.92 6,411.36 6,255.66 0.00 0.00 44.49 17,600.00 89.68 188.92 6,411.92 6,256.22 0.00 0.00 44.93 17,700.00 89.68 188.92 6,412.48 6,256.78 0.00 0.00 45.37 17,800.00 89.68 188.92 6,413.04 6,257.34 0.00 0.00 45.82 17,900.00 89.68 188.92 6,413.60 6,257.90 0.00 0.00 46.27 18,000.00 89.68 188.92 6,414.16 6,258.46 0.00 0.00 46.72 18,100.00 89.68 188.92 6,414.73 6,259.03 0.00 0.00 47.17 18,200.00 89.68 188.92 6,415.29 6,259.59 0.00 0.00 47.63 18,300.00 89.68 188.92 6,415.85 6,260.15 0.00 0.00 48.09 18,400.00 89.68 188.92 6,416.41 6,260.71 0.00 0.00 48.55 18,500.00 89.68 188.92 6,416.97 6,261.27 0.00 0.00 49.02 18,600.00 89.68 188.92 6,417.53 6,261.83 0.00 0.00 49.49 18,700.00 89.68 188.92 6,418.10 6,262.40 0.00 0.00 49.95 18,800.00 89.68 188.92 6,418.66 6,262.96 0.00 0.00 50.43 18,900.00 89.68 188.92 6,419.22 6,263.52 0.00 0.00 50.90 19,000.00 89.68 188.92 6,419.78 6,264.08 0.00 0.00 51.38 19,100.00 89.68 188.92 6,420.34 6,264.64 0.00 0.00 51.85 19,200.00 89.68 188.92 6,420.91 6,265.21 0.00 0.00 52.33 19,300.00 89.68 188.92 6,421.47 6,265.77 0.00 0.00 52.82 19,400.00 89.68 188.92 6,422.03 6,266.33 0.00 0.00 53.30 19,500.00 89.68 188.92 6,422.59 6,266.89 0.00 0.00 53.79 19,600.00 89.68 188.92 6,423.15 6,267.45 0.00 0.00 54.27 19,700.00 89.68 188.92 6,423.71 6,268.01 0.00 0.00 54.76 19,800.00 89.68 188.92 6,424.28 6,268.58 0.00 0.00 55.26 19,900.00 89.68 188.92 6,424.84 6,269.14 0.00 0.00 55.75 20,000.00 89.68 188.92 6,425.40 6,269.70 0.00 0.00 56.24 20,100.00 89.68 188.92 6,425.96 6,270.26 0.00 0.00 56.74 20,200.00 89.68 188.92 6,426.52 6,270.82 0.00 0.00 57.24 20,300.00 89.68 188.92 6,427.08 6,271.38 0.00 0.00 57.74 20,400.00 89.68 188.92 6,427.65 6,271.95 0.00 0.00 58.24 20,500.00 89.68 188.92 6,428.21 6,272.51 0.00 0.00 58.74 20,600.00 89.68 188.92 6,428.77 6,273.07 0.00 0.00 59.24 20,700.00 89.68 188.92 6,429.33 6,273.63 0.00 0.00 59.75 20,800.00 89.68 188.92 6,429.89 6,274.19 0.00 0.00 60.25 20,900.00 89.68 188.92 6,430.45 6,274.75 0.00 0.00 60.76 21,000.00 89.68 188.92 6,431.02 6,275.32 0.00 0.00 61.27 21,100.00 89.68 188.92 6,431.58 6,275.88 0.00 0.00 61.78 3/29/2017 10:08:06AM Page 8 COMPASS 5000.1 Build 74 • • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39©155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39©155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 21,200.00 89.68 188.92 6,432.14 6,276.44 0.00 0.00 62.29 21,300.00 89.68 188.92 6,432.70 6,277.00 0.00 0.00 62.80 21,400.00 89.68 188.92 6,433.26 6,277.56 0.00 0.00 63.32 21,500.00 89.68 188.92 6,433.82 6,278.12 0.00 0.00 63.83 21,600.00 89.68 188.92 6,434.39 6,278.69 0.00 0.00 64.35 21,700.00 89.68 188.92 6,434.95 6,279.25 0.00 0.00 64.86 21,800.00 89.68 188.92 6,435.51 6,279.81 0.00 0.00 65.38 21,900.00 89.68 188.92 6,436.07 6,280.37 0.00 0.00 65.90 22,000.00 89.68 188.92 6,436.63 6,280.93 0.00 0.00 66.42 22,100.00 89.68 188.92 6,437.19 6,281.49 0.00 0.00 66.94 22,200.00 89.68 188.92 6,437.76 6,282.06 0.00 0.00 67.46 22,300.00 89.68 188.92 6,438.32 6,282.62 0.00 0.00 67.98 22,400.00 89.68 188.92 6,438.88 6,283.18 0.00 0.00 68.51 22,500.00 89.68 188.92 6,439.44 6,283.74 0.00 0.00 69.03 22,600.00 89.68 188.92 6,440.00 6,284.30 0.00 0.00 69.56 22,700.00 89.68 188.92 6,440.57 6,284.87 0.00 0.00 70.08 22,800.00 89.68 188.92 6,441.13 6,285.43 0.00 0.00 70.61 22,900.00 89.68 188.92 6,441.69 6,285.99 0.00 0.00 71.14 23,000.00 89.68 188.92 6,442.25 6,286.55 0.00 0.00 71.67 23,100.00 89.68 188.92 6,442.81 6,287.11 0.00 0.00 72.20 23,200.00 89.68 188.92 6,443.37 6,287.67 0.00 0.00 72.73 23,300.00 89.68 188.92 6,443.94 6,288.24 0.00 0.00 73.26 23,400.00 89.68 188.92 6,444.50 6,288.80 0.00 0.00 73.79 23,500.00 89.68 188.92 6,445.06 6,289.36 0.00 0.00 74.32 23,600.00 89.68 188.92 6,445.62 6,289.92 0.00 0.00 74.85 23,700.00 89.68 188.92 6,446.18 6,290.48 0.00 0.00 75.39 23,800.00 89.68 188.92 6,446.74 6,291.04 0.00 0.00 75.92 23,900.00 89.68 188.92 6,447.31 6,291.61 0.00 0.00 76.45 24,000.00 89.68 188.92 6,447.87 6,292.17 0.00 0.00 76.99 24,100.00 89.68 188.92 6,448.43 6,292.73 0.00 0.00 77.53 24,200.00 89.68 188.92 6,448.99 6,293.29 0.00 0.00 78.06 24,300.00 89.68 188.92 6,449.55 6,293.85 0.00 0.00 78.60 24,400.00 89.68 188.92 6,450.11 6,294.41 0.00 0.00 79.14 24,500.00 89.68 188.92 6,450.68 6,294.98 0.00 0.00 79.68 24,600.00 89.68 188.92 6,451.24 6,295.54 0.00 0.00 80.22 24,700.00 89.68 188.92 6,451.80 6,296.10 0.00 0.00 80.75 24,800.00 89.68 188.92 6,452.36 6,296.66 0.00 0.00 81.29 24,900.00 89.68 188.92 6,452.92 6,297.22 0.00 0.00 81.84 25,000.00 89.68 188.92 6,453.48 6,297.78 0.00 0.00 82.38 25,100.00 89.68 188.92 6,454.05 6,298.35 0.00 0.00 82.92 25,200.00 89.68 188.92 6,454.61 6,298.91 0.00 0.00 83.46 25,300.00 89.68 188.92 6,455.17 6,299.47 0.00 0.00 84.00 25,394.36 89.68 188.92 6,455.70 6,300.00 0.00 0.00 84.51 TD:25394.36'MD,6456.7'TVD-4 1/2"x 6-3/4" 3/29/2017 10:08:06AM Page 9 COMPASS 5000.1 Build 74 • • Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) I Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,432.75 2,940.70 10 3/4"x 13-1/2 10-3/4 13-1/2 13,714.20 6,355.70 7-5/8"x 9-7/8 x 11" 7-5/8 11 25,394.36 6,455.70 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 11,066.51 5,715.70 C-35 13,804.26 6,360.70 A4 3,909.00 3,233.70 C-80 12,736.96 6,200.70 Lower Kalubik(K-1 mkr) 7,402.35 4,607.70 C-50 8,255.55 4,865.70 C-40 8,916.96 5,065.70 C-37 465.75 465.70 top T-3 Sand 0.00 1,541.47 1,505.70 Base permafrost(?) 590.98 590.70 K-15 Marker 13,269.69 6,305.70 Kuparuk C(Top C4) 2,355.27 2,185.70 Top W Sak(W Sak D) 12,405.52 6,115.70 Upper Kalubik(base HRZ) 12,009.01 6,000.70 Top HRZ(K-2 mkr) 13,503.87 6,336.70 A5 3,129.51 2,745.70 Base W Sak Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.50100'DLS,130°TF,for 500' 800.00 798.57 -21.01 25.03 Start 2.50100'DLS,0°TF,for 686.45' 1,486.45 1,455.70 -142.77 170.14 Hold for 110.04' 1,596.48 1,555.70 -172.28 205.32 Start 30100'DLS,40°TF,for 532.36' 2,128.84 2,009.70 -382.50 382.14 Start 2.070100'DLS,72.56°TF,for 1303.9' 3,432.75 2,940.70 -1,249.09 608.24 Hold for 20' 3,452.75 2,953.01 -1,264.85 608.24 Start 3°/100'DLS,93.29°TF,for 2162.42' 5,615.17 4,067.28 -2,588.58 -488.82 Hold for 6395.73' 12,010.89 6,001.27 -4,524.03 -6,269.74 Start 3.750100'DLS,-85.75°TF,for 1703.31' 13,714.20 6,355.70 -5,753.85 -7,257.09 Hold for 20' 13,734.20 6,357.09 -5,773.63 -7,259.75 Start 30100'DLS,-1.73°TF,for 138.18' 13,872.38 6,361.74 -5,910.49 -7,277.99 Hold for 2341.84' 16,214.22 6,355.88 -8,232.14 -7,584.73 Start 30100'DLS,91.87°TF,for 146.21' 16,360.42 6,355.70 -8,376.21 -7,609.41 Adjust TF to 175.84°,for 117.76' 16,478.18 6,359.32 -8,491.31 -7,633.95 Hold for 753.08' 17,231.26 6,405.60 -9,226.08 -7,792.37 Start 30100'DLS,-45.47°TF,for 151.98' 17,383.24 6,410.70 -9,375.37 -7,820.16 Hold for 8011.12' 25,394.36 6,455.70 -17,289.51 -9,062.10 TD:25394.36'MD,6455.7'TVD Checked By: Approved By: Date: 3/29/2017 10:08:06AM Page 10 COMPASS 5000.1 Build 74 AC Summary • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-32 Plan:2K-32 2K-32wp09 Clearance Summary Anticollision Report 28 March,2017 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 2K Pad-Plan:2K-32-Plan:2K-32-2K-32wp09 Well Coordinates:5,937,865.28 N,1,638,342.95 E(70°14'30.64"N,150°01'00.29"W) Datum Height: Plan:116.7+39 @ 155.70usft(Doyon 142) Scan Range:0.00 to 25,394.36 usft.Measured Depth. Scan Radius is 2,735.54 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale FactorApplied Version:5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 • • Anticollision Report for Plan:2K-32 -2K-32wp09 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2K Pad-Plan:2K-32-Plan:2K-32-2K-32wp09 Scan Range: 0.00 to 25,394.36 usft.Measured Depth. Scan Radius is 2735.54 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Kuparuk 2K Pad 2K-11-2K-11-2K-11 176.70 235.04 176.70 232.18 175.00 82.386 Centre Distance Pass-Major Risk 2K-11-2K-11-2K-11 398.20 236.32 398.20 229.31 400.00 33.709 Clearance Factor Pass-Major Risk 2K-11-2K-11A-2K-11A 176.70 235.04 176.70 232.53 175.00 93.868 Centre Distance Pass-Major Risk 2K-11-2K-11A-2K-11A 398.20 236.32 398.20 229.66 400.00 35.475 Clearance Factor Pass-Major Risk 2K-11-2K-11AL1-2K-11AL1 176.70 235.04 176.70 232.53 175.00 93.868 Centre Distance Pass-Major Risk 2K-11-2K-11AL1-2K-11AL1 398.20 236.32 398.20 229.66 400.00 35.475 Clearance Factor Pass-Major Risk 2K-11-2K-11APB1-2K-11APB1 176.70 235.04 176.70 232.18 175.00 82.386 Centre Distance Pass-Major Risk 2K-11-2K-11APB1-2K-11APB1 398.20 236.32 398.20 229.31 400.00 33.709 Clearance Factor Pass-Major Risk 2K-12-2K-12-2K-12 300.00 209.32 300.00 204.11 300.00 40.215 Centre Distance Pass-Major Risk 2K-12-2K-12-2K-12 398.20 210.05 398.20 203.04 400.00 29.962 Clearance Factor Pass-Major Risk 2K-13-2K-13-2K-13 51.70 120.23 51.70 119.03 50.00 99.599 Centre Distance Pass-Major Risk 2K-13-2K-13-2K-13 375.09 121.27 375.09 114.81 375.00 18.774 Clearance Factor Pass-Major Risk 2K-13-2K-13A-2K-13A 51.70 120.23 51.70 119.03 50.00 99.599 Centre Distance Pass-Major Risk 2K-13-2K-13A-2K-13A 375.09 121.27 375.09 114.81 375.00 18.774 Clearance Factor Pass-Major Risk 2K-13-2K-13AL1-2K-13AL1 51.70 120.23 51.70 119.07 50.00 103.622 Centre Distance Pass-Major Risk 2K-13-2K-13AL1-2K-13AL1 375.09 121.27 375.09 114.85 375.00 18.911 Clearance Factor Pass-Major Risk 2K-13-2K-13AL2-2K-13AL2 51.70 120.23 51.70 119.07 50.00 103.622 Centre Distance Pass-Major Risk 2K-13-2K-13AL2-2K-13Al2 375.09 121.27 375.09 114.85 375.00 18.911 Clearance Factor Pass-Major Risk 2K-14-2K-14-2K-14 51.70 95.00 51.70 93.81 50.00 79.980 Centre Distance Pass-Major Risk 2K-14-2K-14-2K-14 375.46 95.90 375.46 89.43 375.00 14.823 Clearance Factor Pass-Major Risk 2K-14-2K-14A-2K-14A 51.70 95,00 51.70 93.81 50.00 79.980 Centre Distance Pass-Major Risk 2K-14-2K-14A-2K-14A 375.46 95.90 375.46 89.43 375.00 14.823 Clearance Factor Pass-Major Risk 2K-14-2K-14AL1-2K-14AL1 51.70 95.00 51.70 93.81 50.00 79.980 Centre Distance Pass-Major Risk 2K-14-2K-14AL1-2K-14AL1 375.46 95.90 375.46 89.43 375.00 14.823 Clearance Factor Pass-Major Risk 2K-15-2K-15-2K-15 176.70 69.91 176.70 67.00 175.00 24.002 Centre Distance Pass-Major Risk 2K-15-2K-15-2K-15 425.14 71.99 425.14 63.10 425.00 8.099 Clearance Factor Pass-Major Risk 2K-15-2K-15L1-2K-15L1 176.70 69.91 176.70 67.35 175.00 27.269 Centre Distance Pass-Major Risk 2K-15-2K-15L1-2K-15L1 425.14 71.99 425.14 63.45 425.00 8.430 Clearance Factor Pass-Major Risk 28 March,2017- 13:44 Page 2 of 8 COMPASS • • Anticollision Report for Plan: 2K-32 -2K-32wpO9 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2K Pad-Plan:2K-32-Plan:2K-32-2K-32wp09 Scan Range:0.00 to 25,394.36 usft.Measured Depth. Scan Radius is 2,735.54 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 2K-15-2K-15L1-01-2K-15L1-01 176.70 69.91 176.70 67.00 175.00 24.002 Centre Distance Pass-Major Risk 2K-15-2K-15L1-01-2K-15L1-01 425.14 71.99 425.14 63.10 425.00 8.099 Clearance Factor Pass-Major Risk 2K-15-2K-15L1-02-2K-15L1-02 176.70 69.91 176.70 67.35 175.00 27.269 Centre Distance Pass-Major Risk 2K-15-2K-15L1-02-2K-15L1-02 425.14 71.99 425.14 63.45 425.00 8.430 Clearance Factor Pass-Major Risk 2K-16-2K-16-2K-16 301.69 44.72 301.69 38.80 300.00 7.546 Centre Distance Pass-Major Risk 2K-16-2K-16-2K-16 450.51 46.43 450.51 36.96 450.00 4.900 Clearance Factor Pass-Major Risk 2K-17-2K-17-2K-17 251.70 19.97 251.70 15.63 250.00 4.601 Centre Distance Pass-Major Risk 2K-17-2K-17-2K-17 376.41 20.34 376.41 13.98 375.00 3.199 Clearance Factor Pass-Major Risk 2K-18-2K-18-2K-18 MEM 2K-18-2K-18-2K-18 --[AIL-Major Risk 2K-19-2K-19-2K-19 577.13 26.98 577.13 17.31 575.00 2.790 Centre Distance Pass-Major Risk 2K-19-2K-19-2K-19 602.02 27.17 602.02 17.10 600.00 2.697 Clearance Factor Pass-Major Risk 2K-19-2K-19A-2K-19A 577.13 26.98 577.13 17.31 575.00 2.790 Centre Distance Pass-Major Risk 2K-19-2K-19A-2K-19A 602.02 27.17 602.02 17.10 600.00 2.697 Clearance Factor Pass-Major Risk 2K-19-2K-19AL1-2K-19AL1 577.13 26.98 577.13 17.31 575.00 2.790 Centre Distance Pass-Major Risk 2K-19-2K-19AL1-2K-19AL1 602.02 27.17 602.02 17.10 600.00 2.697 Clearance Factor Pass-Major Risk 2K-20-2K-20-2K-20 728.92 47.30 728.92 31.12 725.00 2.924 Centre Distance Pass-Major Risk 2K-20-2K-20-2K-20 753.75 47.86 753.75 31.06 750.00 2.849 Clearance Factor Pass-Major Risk 2K-21-2K-21-2K-21 655.68 75.34 655.68 64.99 650.00 7.277 Centre Distance Pass-Major Risk 2K-21-2K-21-2K-21 680.76 75.54 680.76 64.80 675.00 7.034 Clearance Factor Pass-Major Risk 2K-21-2K-21A-2K-21A 655.68 75.34 655.68 64.99 650.00 7.277 Centre Distance Pass-Major Risk 2K-21-2K-21A-2K-21A 680.76 75.54 680.76 64.80 675.00 7.034 Clearance Factor Pass-Major Risk 2K-22-2K-22-2K-22 657.33 98.67 657.33 84.34 650.00 6.883 Centre Distance Pass-Major Risk 2K-22-2K-22-2K-22 733.05 99.22 733.05 83.05 725.00 6.135 Clearance Factor Pass-Major Risk 2K-22-2K-22A-2K-22A 657.33 98.67 657.33 84.34 650.00 6.883 Centre Distance Pass-Major Risk 2K-22-2K-22A-2K-22A 733.05 99.22 733.05 83.05 725.00 6.135 Clearance Factor Pass-Major Risk 2K-22-2K-22AL1-2K-22AL1 657.33 98.67 657.33 84.69 650.00 7.055 Centre Distance Pass-Major Risk 2K-22-2K-22AL1-2K-22AL1 733.05 99.22 733.05 83.40 725.00 6.270 Clearance Factor Pass-Major Risk 2K-22-2K-22AL1-01-2K-22AL1-01 657.33 98.67 657.33 84.69 650.00 7.055 Centre Distance Pass-Major Risk 2K-22-2K-22AL1-01-2K-22AL1-01 733.05 99.22 733.05 83.40 725.00 6.270 Clearance Factor Pass-Major Risk 28 March,2017- 13:44 Page 3 of 8 COMPASS • • Anticollision Report for Plan: 2K-32-2K-32wp09 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 21(Pad-Plan:2K-32-Plan:2K-32-2K-32wp09 Scan Range: 0.00 to 25,394.36 usft.Measured Depth. Scan Radius is 2,735.54 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 2K-23-2K-23-2K-23 201.70 129.92 201.70 126.71 200.00 40.431 Centre Distance Pass-Major Risk 2K-23-2K-23-2K-23 531.78 131.25 531.78 122.82 525.00 15.573 Clearance Factor Pass-Major Risk 2K-23-2K-23A-2K-23A wp06 201.70 129.92 201.70 127.06 200.00 45.357 Centre Distance Pass-Major Risk 2K-23-2K-23A-2K-23A_wp06 531.78 131.25 531.78 123.17 525.00 16.246 Clearance Factor Pass-Major Risk 2K-23-2K-23AL1-2K 23AL1_wp08 201.70 129.92 201.70 127.06 200.00 45.357 Centre Distance Pass-Major Risk 2K-23-2K-23AL1-2K-23AL1_wp08 531.78 131.25 531.78 123.17 525.00 16.246 Clearance Factor Pass-Major Risk 2K-24-2K-24-2K-24 226.70 154.89 226.70 151.26 225.00 42.710 Centre Distance Pass-Major Risk 2K-24-2K-24-2K-24 506.97 157.25 506.97 149.31 500.00 '19.806 Clearance Factor Pass-Major Risk 2K-24-2K-24AL2-2K-24AL2_wp02 226.70 154.89 226.70 151.61 225.00 47.257 Centre Distance Pass-Major Risk 2K-24-2K-24AL2-2K-24AL2_wp02 506.97 157.25 506.97 149.66 500.00 20.717 Clearance Factor Pass-Major Risk 2K-24-2K-24AL2-01-2K-24AL2-01_wp02 226.70 154.89 226.70 151.61 225.00 47.257 Centre Distance Pass-Major Risk 2K-24-2K-24AL2-01-2K-24AL2-01_wp02 506.97 157.25 506.97 149.66 500.00 20.717 Clearance Factor Pass-Major Risk 2K-25-2K-25-2K-25 176.70 180.07 176.70 177.24 175.00 63.687 Centre Distance Pass-Major Risk 2K-25-2K-25-2K-25 404.89 181.33 404.89 174.79 400.00 27.743 Clearance Factor Pass-Major Risk 2K-25-2K-25L1-2K-25L1 176.70 180.07 176.70 177.24 175.00 63.687 Centre Distance Pass-Major Risk 2K-25-2K-25L1-2K-25L1 404.89 181.33 404.89 174.79 400.00 27.743 Clearance Factor Pass-Major Risk 2K-25-2K-25L1-01-2K-25L1-01 176.70 180.07 176.70 177.24 175.00 63.687 Centre Distance Pass-Major Risk 2K-25-2K-25L1-01-2K-25L1-01 404.89 181.33 404.89 174.79 400.00 27.743 Clearance Factor Pass-Major Risk 2K-27-2K-27-2K-27 972.30 195.65 972.30 177.76 950.00 10.937 Clearance Factor Pass-Major Risk 2K-28-2K-28-2K-28 57.05 185.41 57.05 184.13 50.00 144.499 Centre Distance Pass-Major Risk 2K-28-2K-28-2K-28 476.00 189.26 476.00 180.31 475.00 21.160 Clearance Factor Pass-Major Risk 2K-28-2K-28A-2K-28A 57.05 185.41 57.05 184.13 50.00 144.499 Centre Distance Pass-Major Risk 2K-28-2K-28A-2K-28A 476.00 189.26 476.00 180.31 475.00 21.160 Clearance Factor Pass-Major Risk 2K-28-2K-28AL1-2K-28AL1 57.05 185.41 57.05 184.17 50.00 149.978 Centre Distance Pass-Major Risk 2K-28-2K-28AL1-2K-28AL1 476.00 189.26 476.00 180.36 475.00 21.271 Clearance Factor Pass-Major Risk 2K-28-2K-28AL1 PB1-2K-28AL1 PB1 57.05 185.41 57.05 184.13 50.00 144.499 Centre Distance Pass-Major Risk 2K-28-2 K-28AL1PB 1-2 K-28AL1PB1 476.00 189.26 476.00 180.31 475.00 21.160 Clearance Factor Pass-Major Risk 2K-28-2K-28AL1 PB2-2K-28AL1 PB2 57.05 185.41 57.05 184.13 50.00 144.499 Centre Distance Pass-Major Risk 2K-28-2K-28AL1 PB2-2K-28AL1 P82 476.00 189.26 476.00 180.31 475.00 21.160 Clearance Factor Pass-Major Risk 2K-28-2K-28APB1-2K-28APB1 57.05 185.41 57.05 184.13 50.00 144.499 Centre Distance Pass-Major Risk 28 March,2017- 13:44 Page 4 of 8 COMPASS • • Anticollision Report for Plan: 2K-32-2K-32wpO9 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2K Pad-Plan:2K-32-Plan:2K-32-2K-32wp09 Scan Range: 0.00 to 25,394.36 usft.Measured Depth. Scan Radius is 2,735.54 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 2K-28-2K-28APB1-2K-28APB1 476.00 189.26 476.00 180.31 475.00 21.160 Clearance Factor Pass-Major Risk Plan:2K-30-Plan:2K-30-2K-30wp08 WiP 298.20 49.89 298.20 44.56 300.00 9.375 Centre Distance Pass-Major Risk Plan:2K-30-Plan:2K-3D-2K-30wp08 WiP 347.80 50.24 347.80 44.14 350.00 8.226 Clearance Factor Pass-Major Risk Plan:2K-31-Plan:2K-31-2K-31wp05 284.70 24.98 284.70 19.91 275.00 4.933 Centre Distance Pass-Major Risk Plan:2K-31-Plan:2K-31-2K-31wp05 881.87 29.05 881.87 14.56 875.00 2.005 Clearance Factor Pass-Major Risk Plan:2K-33-Plan:2K-33-2K-33wp06 335.97 209.87 335.97 204.00 325.00 35.766 Centre Distance Pass-Major Risk Plan:2K-33-Plan:2K-33-2K-33wp06 491.38 210.96 491.38 202.94 475.00 26.330 Clearance Factor Pass-Major Risk Plan:2K-Timberline-Plan 2K-TimberlinePB1-2K-Tim 284.20 24.98 284.20 19.81 275.00 4.836 Centre Distance Pass-Major Risk Plan:2K-Timberline-Plan 2K-TimberlinePB1-2K-Tim 358.95 25.36 358.95 18.99 350.00 3.982 Clearance Factor Pass-Major Risk Plan:2K-Timberline-Plan:2K-Timberline-2K-Timber 284.20 24.98 284.20 19.81 275.00 4.836 Centre Distance Pass-Major Risk Plan:2K-Timberline-Plan:2K-Timberline-2K-Timber 358.95 25.36 358.95 18.99 350.00 3.982 Clearance Factor Pass-Major Risk Kuparuk 2S Pad 2S-01-2S-01-2S-01 15,166.25 1,282.22 15,166.25 1,015.54 13,300.00 4.808 Centre Distance Pass-Major Risk 2S-01-2S-01-2S-01 15,191.12 1,282.39 15,191.12 1,014.93 13,325.00 4.795 Clearance Factor Pass-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 898.20 2K-32wp09 GYD-GC-SS 898.20 1,898.20 2K-32wp09 MWO 898.20 3,432.75 2K-32wp09 MWD+IFR-AK-CAZ-SC 3,432.75 4,932.75 2K-32wp09 MWD 3,432.75 13,714.20 2K-32wp09 MWD+IFR-AK-CAZ-SC 13,714.20 15,214.20 2K-32wp09 MWD 13,714.20 25,394.36 2K-32wp09 MWD+IFR-AK-CAZ-SC 28 March,2017- 13:44 Page 5 of 8 COMPASS • S Anticollision Report for Plan: 2K-32-2K-32wp09 Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 28 March,2017- 13:44 Page 6 of 8 COMPASS Ladder View • • Ladder View March 29 2a1 2K-32wp09 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. a ,4.f." a a rt Y2 Y Y Y Y o4 44 N 300 I r« Ni 14! if i M /Ir ' l ca iii I il. ami ` ir `al JJ11j_ ' N150 -SEI-� '',1 I I SII Equivelant Magnetic Distance 0 I I 1 1 I 1 I 1 1 I I I 1 I I 1 I I I I I 1 I I I I I I I I I I 0 4000 8000 12000 16000 20000 24000 Displayed interval could be less than entire well:Measured Depth 39.00 To 25394.36 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 898.20 2K-32wp09(Plan:2K-32) GYD-GC-SS 2940.70 3432.75 10 3/4"x 13-1/2 898.20 1898.20 2K-32wp09 (Plan:2K-32) MWD 6355.70 13714.20 7-5/8"x 9-7/8 x 11" 898.20 3432.75 2K-32wp09 (Plan:2K-32) MWD+IFR-AK-CAZ-SC 6455.70 25394.36 4 1/2"x 6-3/4" 3432.75 4932.75 2K-32wp09 (Plan:2K-32) MWD 3432.75 13714.20 2K-32wp09 (Plan:2K-32) MWD+IFR-AK-CAZ-SC 13714.20 15214.20 2K-32wp09(Plan:2K-32) MWD 13714.20 25394.36 2K-32wp09 (Plan:2K-32) MWD+IFR-AK-CAZ-SC g t a E. I a t 3 Y Y Y lk Y Y N N N i /60 1 / 1"I / Z phi.:. � ' AHI I� ��� , _ ... a - Ilq11119301019 V), N 30 �����' �.#41101161Fili r U IIIILI .-,; oil i ...0000,' ir "IIIININiblipiLefik P _ Equivalent Magnetic Distance _. . 0 / I 1 I I I I I I I I I I I I I I I III I I I I II I I I I 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth TC View 0 I. P. MD Inc ,13 4,08-3 .5/.1./ Oleg Trace Wed Tar 39.00 0.00 0.00 39.00 0.00 000 0.00 0.00 0.00 300.00 0.00 0.00 30000 0.00 0.00 0.00 0.00 0.00 800.00 7.50 130.00 798.57 -21.01 25.03 1.50 130.00 16.34 39 -' ' 300 2K-32wp09 1 486.45 24.66 130.00 1455.70 -142.77 170.14 2.50 0.00 111.05 1596.46 24.66 130.00 1555.70 -172.28 205.32 0.00 0.00 134.01 399 -- 490 2128.84 38.21 2009.70 -382.50 362.14 9.00 00.00 310.34 39.00 To 25394.36 3432.75 52.00 106.62 180.00 2940.70 -1249.00 60824 2.07 72.56 1124.50 3052.75 52.00 180.00 2953.01 -1264.65 608.24 0.00 0.00 1100.02 490 - 670 5615.17 72.40 251.09 4067.28 -2588.58 -488.82 3.00 9329 2634.14 12010.89 72.40 251.49 600127 -4524.03 .6269.74 0.00 0.00 5544.03 13714.20 86.00 167.65 6355.70 -5753.66 -7257.09 3.75 -85.75 6926.62 20-32 01.1144 020717 JH 670 860 13734.20 88.00 187.65 6357.10 -5773.63 -7259.75 0.00 0.00 6946.56 1 0:30,March 29 2017 13872.38 90.14 187.53 6361.74 .5910.49 -7277.99 3.00 -1.73 7084.50 16214.22 90.14 187.53 6355.88 -8232.14 -7584.73 0.00 0.00 9424.15 860 16360.42 60.00 191.91 6355.70 43376.21 -7609.41 9.00 91.87 9570.32 20-32 02.Prelal100070729 1040 16478.18 90.48 192.17 6359.32 -8491.31 -7693.95 3.00 175.84 9687.93 17231.26 86.48 192.17 6405.60 .922608 -779237 0.00 0.00 10439.05 URVEY PROGRAM 17383.24 89.68 168.92 641070 -9375.37 -7820.16 3.00 -45.47 10590.90 2K-32 03.1.06.6a0 020717 Jil 1040 1230 S 2539426 89.68 165.92 645670 -17289.51 .9062.10 0.00 0.00 18600.46 2K-32 04.70e 020717 JH r pth FromDepth To Survey/1,0n 39.03 89520 214-32,09(Plan,2K-32) GYO-00.5.9 1230 1410 89820 1098.20 21,32,50(Flan:214-32) MWD 89520 3432.75 20-320203(Flan:214-32) MWO..1.-014-..-9. 1410 - 1600 343275 023275 2K-32,09 Mae,2K-32) MWO 3432.75 1371420 2K-32w909(Plan:2K-32) 5/IWNIFR-PX-Cia-SC 13714.20 15214.20 21432.903(Flan:2K-32) MWD 13714.20 25394.36 20-32,03(Flan:2K-32) MWD,F11-AK-C22-SC 1600-- 2590 CASING DETAILS 2590 3580 ND MD Name Size 3580 4560 2940.70 3432.75 10 3/4"x 13-1/2 10-3/4 6355.70 13714.27-5/8"x 9-7/8 x 11" 7-5/8 4560 -- 5550 6455.70 25394.36 4 1/2"x 6-3/4* 4-1/2 5550 -- 6540 6540 - 7520 7520 -- 8510 k-g(9.9.s 8'i" 8510 - 9500 -7,• •,,,,„.::-:,, ••••••••••'-',.•:,•s..54Ci-lic72.^•;4- ....• 1--,•---..tr,7•,:::‘,..1.,.•,-•• ,AlaBi,, Cr4A,._ 9500- 11490 7.+;"rF-.. '717ii.:..':41',4b1• ,,,,,,:'''':1 1'44.,?,,.- '7Aisc,--Alith ...., ... , ,, '.,'''''.',',...-7-`.4.4.-,;-0.-'2'9---'ilia-6.-..i.-,...I, 30 11490- 13470 30/ 74 .,,,,ziae--_-- -,.44 . f.'[.,•:;,:-.,.„...' -1;11, .Avitivri„,• ,, ,...........,,,,,-..,,,,-,,,,,,r.,:,,,„1„ .voliir, . 10„ ,,,,-\..,,'..,...,,,,-.:-....,,,,,-,,,,,,..,,,y7-_.,.---...,-,_,..,,te :!......„-,--,,--.4.* vow;A .$44.10,,, 13470 - 15460 4, ',1-7,1-1!--414.r,..iglay;:_-.4.41-•rre,•••••-•ny tz•ge.,•• 411-11rit AS.A„,' Ith, '-. ,,, • ,,,„,:_ds.,---. 15460 17450 . -•'--,-.'- .• ..-4'; •-•,--%-..Vrie-4,e4:14AW.k*F-t11,4,4,111,.v.‘v.,,A...‘,..41/4 -k-, '.7.T7-'-?.---ePAID.- 5r*-441,0040*.Vitaiii.v.iivit-v.4st..4444,14,it. --k, 17450 - 19440 ;..-'",-.2...;:"-!•I'. IC f'!"*.- •-)tAv , _• •%,.• . -,.44,itt-.!'-11••••- TO 'al,vv, -.7' ''z''12•''' '`i20(''; ',-,k• 'It;S‘tlAW,,.001.*011e,,,,,A,64,04,4 it)A ,ii, ... 4,004‘,...,..,--",,,,..,17 .4,A. -•AW ',:'tiFnifetutoolIVATIP-A 404 A ,, 't,-,i, lik- 21420 „,,,f.1;•-1-,/-'•kk;,. ..`•1:10-0 9 tprpi•L '•''IR, -:* -'-''si'r I 7.111-# 47414PVTliti 4 '4144* fr-Th,2,5,1 1-•••:+-.,•,t,, .,:ila.#4*:- 4,-4V ''•'.4:4?1*-1F"-Mti le.1.,...„„ ,.4 •, ,tik ..\ \\ 21420 23410 iptil , 11,:_••••:.7. Z•14,ti iitail4-''•,,.:.•ii.4M A egks--Nrk•IF•li-h• 10), sv. 60/300,/Or IRA.'••..i!)44,1;7•':;:".,at"..)i,,A...,:.;*,‘Itt.. .:ZtilFA';;011.4,144141.11t.k.44,$.410 40 '' \ ' \60 23410 25394 i`°1, **..";Vilf4/1,f*,.4. '-'z•-4-112..:'''' 's:'‘----;,',474=w4v.f.mstk‘ti#\ 4 4 ti,1/4 ,'.;;:::-..,..-,-;-,..-.,,..-..::::,:-. ,..-:;:;-:44,-.---;,;4-..:.:,,,,t40,0,:if,-, • -:-..ii.i..-_,,sitv.,....kil„r A* w, Aftw, V• \IP 4$ stelvitr% ' -4404tck ttiOwat,ct ., , .----:-.:.----;;;-;-4••••"4,04 I* •##4 V.wfrtrii,c, ...:-.7_--..-2:::.";74•444,4P441.44.11 iti.itote400,04.04, - ta..'7C-4:e-XliaN.--**v.-*4,v..- ‘vok.- wos)kt t /,;;;i=-', ...$44...,S4VitAfittP#1 401 rirlIf ik11,ij*Sit '''kfle-.40010.4.,_.,-:4141VOlikk***14,01.itti*i)., :\ ;;;-//j,ty elb#JA.A.t,?1,1 iiiivi:fit ii4A Olar,k, ,.•:',' ----,-,'-'3-`"-Z,N4,1•4Viti,32,i1Okui"AV"'*VI'AV ' r7:,‘' 1:.:1'' '7 Itip•t•r,";j,ICC4iiii(4;;:a/PZIA-' ' -\N\\V\,\''''','1W13`,1%.1inilli& '406116 alii . 7, ..oV.1411.7.411111211un..:.--2.44 • com v. 90 El.'.....;-•;•••,,',,, ;?814,01:146,..4!...s,‘.. : , ‘'.,\ ,',' •',• •-:---t•••,loototivanilla „fillip, .,- • 41;,,-..effreiFFSWIr..... te,ft:A4 2K..,....., ,4t1.4 ,,,,,,,,,,,,,, -90/270 - - - --'=fiY.,4%git.;41-'!fiN:g.'*7-t"-''AVAIiratiV4Z,',47ANIP'. .."'-'4.''' , ,..... gik.1.1101,1MMIONI11 ',.T.k.11.1111.11NLMI la `turpt -st..:,..: r........:4„;.1.Apodv.,....11,- : t il Tr IniOnim''IV 431,01,4VM VT likertiVp---1,..;.1,-. ;. ,Ill 1.'sizkillij,..k A i ViplrietakTA*41041"LTLF TA 44 i+te eiKV,v-':' --.48 •slii 4''.(-4_4i44644.A1Se•v" \VO$V411 i 1 i i)'L likillilk\*.unItitrititiTir.1-ri5- 5 ,..,e\--...-- li i--•;1141-fitrviffrilkfttts4.4rig.:,.....,;!!!..,, :,..,:do :..„,_.,..., ei ;10":4,--ZI:E.S.4114011,,,ts..,1•7,,t,.`:V404i1:44,'P-- 120 120 120/240 %GM, ‘-,ti-A"'4"410,'%it•V4 -,.4-''----- , _ - -----.>--, r.r.,-,',.41..iovto kvtA-lt,,'- ''''' . ''":-`4!INv,--- *.o.t------ NINay '-vv,'"14t,414.,Arkfr,..tri,...-,--,-..s. ..:,---..._ ..:1,',• A. ',',4",-..;.....;;:,,,-- -7411$4 A V'44.'1!,14tikrili•-----..,..::-:=:.-- .-:::::,.. AN-Mk f;:',;,' 'V,40.4,04,.:',41.'qlrio.::.'"...''', '',... ApinTrik ,r,,4.0,7,,.,,,, i),•Ivi-;-....,. ___Atv;,,,„•!...,:at,. --,:‘•;-,-v,„ ::•..t.7-7;:40,A-•• .: •:•,:,•-••---?--,- -, :,., -,,,-..-ff.,--*/,-7)""i•-r-•- -150/210 .•'••:i-r-f".,,A1Dit.',;,'..•.''',14-!.., 'Ff?..7-•:-., ,.,.,,11/1_,,„„,,,eh,,,01:%•:.- 150 714..,.7.-1,?,-•'-:.. ...1.-i, 7.4.,,.........,;.,.., -,= ....1... , . ...•-•. .,....1.744A0.-. , ••••,-. U.sr...i..._..i.:_'',••- • -..' -180/180 --&-- 06.11,06./I.20.1/21 -4-- 2315,23150,210 9.1 1/0 -73- 21022,25225,0004 -6- 24,25,OM 23,28 1/5 1-1- 201.217,11k 20112 VO -0-- 1314 21.4141,2141500,VO -0- 2022,202300,242200 VO -16- 232420.,2302,0 -G- 201.221100 2410029 -El- 2214 2101.145 24151.1,02 VO -7t1-- 2324 26266L121,41340.12//0 -X-- 2526.21(.2601.1,2K.Zou vo -B-- 31011,28.01029i.200.1/348 1/02 -0-- 3018130oc2CIIIVO -A- 202,023.20000 -0- 25,25.22 28.41.1551,al 23161451 50 -0- 2312,2315 851208 --X-- 2017,2011,2311 VO --X- 237053221.20230,0211514 --13- 20,15.12,20.471712.21048.41462 SO -13- 2314 MIS 231300 --6- 861532-/K 2101/072 --A- 20-23.21(83.4o.26.8341.1,038 90 -0- 21a2.2K2a4PB1.2K2a4PBI VO -6- 2313 215154,210194W --A- 2379,204 201002 -19•-• 32.0,25.22,258<0 --tr.-' 790 3225 Plan D(.3428.30q08w.VO -49- 2013 241300,241440 00 -6- 2474 21052,24130 W -0- 21022,2324664 2105012,412 VO -X-- P1222<51,Pe2121121.21/.3,051/0 -8-- 20112315413,2342102 VO --9-- 2314 231.0 20-1232/56 -9- .47,232411.3111,214240241,402 00 -6- 319112543 17154.03.3207.. -13- Ren 2/1.1202412,P8.at TombefroP81,2411mbalimP51.10 VO -91-- 2102,2104 231150 --I-- 2424.024 23,20110 --0-- 252,34.01. -e- #2025150.4I.PS..21412.31.4 345,4.212.10 MP_Vo -tr- 231,21414k 2010 00 --67- 2041,2521,V.02 1-11/5- 2325 23221.23231 107 -X- 2014 21(10/10,23100 vo -8- 2321,25,213.2.210 13 -"N" 210002333141,210.0.VO -8-- 2301,2541,2301 V0 -,e,-- 2775 2315.205 vo -X-- 2022.2323 2020 vo -0(.- 23302337,25 27.8 __B-- 2102020 AC Wells Only • • • 10;32,March 29 20171 Easting(3000 usft/in) , I , i , , lii , , I , I , , li ili il , , , , I , ilii , I , ' ili ' ' , I , , li ' , I , 1 , li ili1 , I , IAC wells ONLY r 2K-Timberlinewp10 WIP... _ (NOT a Spider) r 2K-TimberlinePB1wp10 = Kuparuk 2K Padgq r111APB1 2K-15L1 2K-14AL1 2K-2:.r % Y -� 13 —�� -_ 2K- :r• r2K-13AL2 /, 2K-15 \NI.4,001,....•sA 11 jI K- 'AL1 2K-19 2K-18 '1(21K51.7 " 2K-23 2K- ' 2.22A c K-28A L' —o w= K-21A II - 2K-25 -- = - 2K- 2 22 ' 2K-24 =� c Kuparuk 2S Pa. , 12K-23ALN_aO1i08 - o 2- �. 2K-24AL2-01 p02 = o 2._ _c `p - 2 -22AL1-01 = c - 2.-22AL1 2K-24AL2_wpr,•g4 #-01 -8 z - 2S-01- 2K-33wp06 2K-32wp09- 2K-31wp05 _ - 2K-30wp08 WiP = 111,-111-„ ITr11l1r1-11r-r1111111IIIIIiirr1iIIIIIhhtII IIIIII1111 I IIIIIIIIIIIIIIIII1Ii1111111111 I1 Easting(3000 usft/in) AC Flipbook 0 • Casing Details Survey Program TVD MD Nartre Depth From Depth To Survey/Plan Tool 2K-32wpo9 990.70 343x.75 0314"xt3't/a 98.x0 898z aK-3awpo9(Nam AK-30) CYO DOWO i9 835070 +3734-x0 7.518"x9918 x+P 898.x0 1898.75 xK3x+Wo9 Marc Ala) MWD 645570 x539436 4+d"x6.314" 898.x0 3438.75 aK-3awpo9(Pbrt Ala) MWD.IFR-AK CA2-SC 3430.75 493x75 0Kg0wp9(Pbrc 08 30) MWD 39.00 To 1000.00 343x75 13714a aK32. 9(Pbrc aK-3x) MWD IF AK{A2-SC 300 974.10 +¢y.xo aK-3xw900p09(PbrcaKgx) MWD 39 97,4.x0 05394 36 0.30wp09(Pbrc aK-3a) MWD.IFR-AKGZ-X MD Azi 7 - 300 490 39.00 0.00 490 670 300.00 0.00 21C Tim le il.,'•i),V.-gi../ WIP 800.00 130.00 -30 /3 2 � �.Iroti�`6�O,; ,istvo.. 670 860 1486.45 130.00 �r� `� a���.V:�4 � 860 1040 1596.48 130.00 . ."4711141P14� 4 „� z,:pl rw, 7t , i �,..1-Wei 1040 1230 0108.84 146.62 i 3432.75 180.004.11.01.004-...► `p.94 I " �q4� •-.;""c 3452.75 1030 1410 �:�P�te� j/ s�qr� sF���� 3452.75 180.00 �`.04--Pr-----44-11-1-.0.41-4. F���.® X14/ 141 41 5615.17 251.49 -(0 /300 r-V0-1(.44T4hir-itto--------------.0 -P?"-4 . ,P� 1 1410 1600 12010.89 251.49 ' \1J6 01600 0590 1 1 20 18 6 .4..„,-...4440,,��[.. . _.�_�ti37 4• 7. 5 ems;" (4'7 . .at�� ►�7" F �'A`,as��a`FQ 2590 3580 13734.20 187.65 <�i♦' a•s \ " ,i1 05 �I :.+`��, 1/108 3580 4560 13872.38 187.53 vAigoi/�/%v"'� e , rjir 16014.00 187.53 '��A/�1�`�`#i)111_'� . 4560 5550 16360.40 191.91 ��a�� `--•`‘11114l0 , 16478.18 192.17 2 K-1 ® :© iii : 5550 6540 1 ��-o ..a: iiP, 6 40 7 20 17231.26 192.17 _90 ,!► �� ` ::... � 0 5 5 15394.34 188.90 l.( r` r (i Ai���►�• . 4/. 9 7520 8510 25394.36 188.92 �r�i ���0/t. ®p�w_.lgrar 0� ,y1/r �"e.: 8510 9500 pr-Air 4,��i�`.414604113 0 9500 11490 i���, A.0447-6-11:-., / 11490 13470 or ifiliftillrif44PPrAil• / 13470 15460 -120 / 240 4 � itt>0�/Wert � 120 15460 17450 _!��_�__,1...dNa soil• 17450 19440 -� - - - - ♦♦1*.t..' '1ic�• ` 19440 21420 •4APA A�_w�l�A�,��/f'4414/11V% 21420- 23410 - 5 / 1('i��Q�d�k t�Ifri ' S 1 0 'h♦O�`.4_44 414:',; 1 0 23410 25394 - -180 /180 10:31,March 29 2017 0 • Casing Details Survey Program WO MD Name 0314"x1;1p Depth From Depth To Survey/Plan Tool K 2K-32wpo9 2940.70 343075 3900 egeao aK-3xwp9(PWnaK-3x) GYD -SS 635570 13714.10 }5/8"x97/8 611" 898.10 1898.00 2K-31013 09(P12rt 26y2) MWD 845570 2539436 41/2"x6-3/4" 898.20 3432.75 zK32wp09(P9rt01(-31) MWDAFR-AK-CAZ-SC 3430.75 4932.]5 9'16r. MWD 1000.00 To 25394.36 3431.75 137420 aK-;xwpoq(Plan an 26 38) MWDHFRAKCAZ-SC 9]4.50 1594 lo 2K-32wpo9(99r62K-32) MWD 39 300 s3]14xo 25394.36 aK-3xwpo9(Plan All) MWDsIFWAKCAZ-SC MD Azi 0 / 360 / 36o 300 490 39.00 0.00 490 670 300.00 0.00 .". -..... ....=;.',.-„,„- s •C 670 860 800.00 130.00 1486.45 ,32.00 -3Q / 33��fillrili • \ 0 67o 86 o 1596.48 130.00 o��•4/ �s�3 ossoiiie=i, - /7. �, �000w iTtf eg®{ 1040 ,230 2,28.84 ,46.65 3 A• ILMI / ,004 . .S -=4'. zK- �i/ice.. ,=e, � ,, ►ilndfGli i•`�-• .• �. \ iosiN j r/ice 4 3435.75180.00 '�Z�. 1530 1 10 3455.75 180.00 �,.01114.4".: rav y,,i.� g �, �' folI %i '. \ 1410 1600 56,5.,7 251.49 -60 �i`/') F���� � �" �:� � N ---� 60 ,600 2590 3 1.4104400470111/9 4� '. - � . 150,0.89251.49 I'°Iv-. 4.40I� 13714.20 187.65 4_04.. ...I0�4111,4��o '-'.0 ^k �,`� 2590 3580 1 50 18 6 - ' %.1"� .- 3734• 7. 5 a _ - x� �, \ 358o 456o 13872.38 187.53 �, -J t • \ 16514.55 187.53 4560 5550 16360.45 191.91 16478.18 192.17 l 5550 6540 9 17231.26 192.17 - 0 / 270 / O 6540 7550 17383.24 188.92 9 7520 85,0 25394.36 188.92 g51O ----- 9500 11-F\ 30---- // 0 9500 11490 „490 13470 13470 15460 -120 / 240 120 15460 17450 • 6 0 17450 19440 ,k -,.- 19440 51420 21420 534,0 -150 210 15 0 23410____-_25394 90 -180 /18 0 io:32,March 29 2017 Errors Report • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad Plan: 2K-32 Plan: 2K-32 Plan: 2K-32wp09 Errors Report 29 March, 2017 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 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 2K Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.02° Well Plan:2K-32 Well Position +N/-S 0.00 usft Northing: Latitude: +E/-W 0.00 usft Fasting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 116.70 usft Wellbore Plan:2K-32 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2016 7/13/2017 17.40 80.86 57,527 Design 2K-32wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From(TVD) +NI-S +El-W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 190.00 Survey Tool Program Date 3/29/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.00 898.20 2K-32wp09(Plan:2K-32) GYD-GC-SS Gyrodata gyro single shots 898.20 1,898.20 2K-32wp09(Plan:2K-32) MWD MWD-Standard 898.20 3,432.75 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,432.75 4,932.75 2K-32wp09(Plan:2K-32) MWD MWD-Standard 3,432.75 13,714.20 2K-32wp09(Plan:2K-32) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,714.20 15,214.20 2K-32wp09(Plan:2K-32) MWD MWD-Standard 13,714.20 25,394.36 2K-32wp09(Plan:2K-32) 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 -116.70 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -55.70 1.15 0.05 0.05 200.00 1.15 0.00 0.00 44.30 1.15 0.19 0.19 300.00 1.15 0.00 0.00 144.30 1.15 0.34 0.34 400.00 1.15 1.50 45.00 244.29 1.15 0.43 0.43 500.00 1.15 3.00 45.00 344.21 1.15 0.50 0.50 600.00 1.15 4.50 45.00 443.99 1.15 0.61 0.60 3/29/2017 10:07:09AM Page 2 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 700.00 1.16 6.00 45.00 543.57 1.15 0.73 0.72 800.00 1.16 7.50 128.17 642.87 1.15 0.86 0.85 900.00 1.17 10.00 129.01 741.70 1.15 1.01 0.98 1,000.00 1.18 12.50 129.85 839.77 1.15 1.11 1.05 1,100.00 1.19 15.00 130.99 936.90 1.14 1.23 1.06 1,200.00 1.20 17.50 131.08 1,032.90 1.14 1.49 1.09 1,300.00 1.21 20.00 131.04 1,127.58 1.13 1.87 1.14 1,400.00 1.23 22.50 130.97 1,220.78 1.13 2.37 1.22 1,486.45 1.25 24.66 130.92 1,300.00 1.13 2.87 1.30 1,500.00 1.25 24.66 130.91 1,312.32 1.13 2.96 1.32 1,596.48 1.26 24.66 130.87 1,400.00 1.15 3.57 1.44 1,600.00 1.26 24.74 130.87 1,403.19 1.15 3.59 1.44 1,700.00 1.28 27.11 131.15 1,493.13 1.18 4.21 1.58 1,800.00 1.33 29.58 131.95 1,581.14 1.21 4.89 1.76 1,900.00 1.41 32.14 133.08 1,666.98 1.24 5.57 1.96 2,000.00 1.38 34.76 137.25 1,750.41 1.17 2.98 1.58 2,100.00 1.43 37.43 138.43 1,831.22 1.20 3.32 1.68 2,128.84 1.45 38.21 138.73 1,854.00 1.20 3.42 1.70 2,200.00 1.48 38.67 139.54 1,909.74 1.23 3.63 1.79 2,300.00 1.53 39.40 140.71 1,987.42 1.28 3.90 1.92 2,400.00 1.60 40.20 142.08 2,064.26 1.34 4.19 2.05 2,500.00 1.68 41.07 143.59 2,140.15 1.40 4.49 2.19 2,600.00 1.78 42.02 145.19 2,215.00 1.46 4.81 2.33 2,700.00 1.89 43.03 146.84 2,288.71 1.54 5.14 2.47 2,800.00 2.02 44.10 148.51 2,361.17 1.61 5.49 2.62 2,900.00 2.15 45.23 150.19 2,432.30 1.69 5.84 2.76 3,000.00 2.31 46.40 151.85 2,502.00 1.77 6.20 2.91 3,100.00 2.48 47.63 153.49 2,570.19 1.86 6.57 3.05 3,200.00 2.66 48.90 155.11 2,636.76 1.96 6.95 3.20 3,300.00 2.85 50.21 156.71 2,701.64 2.05 7.34 3.33 3,400.00 3.06 51.55 158.27 2,764.74 2.16 7.74 3.47 3,432.75 3.13 52.00 158.76 2,785.00 2.19 7.88 3.51 103/4"x13-1/2 3,452.75 3.16 52.00 158.84 2,797.31 2.16 7.97 3.53 3,500.00 3.31 51.93 159.47 2,826.43 2.16 8.13 3.59 3,600.00 3.66 51.88 161.23 2,888.14 2.19 8.51 3.76 3,700.00 4.04 51.95 163.44 2,949.84 2.25 8.97 3.97 3,800.00 4.45 52.14 165.95 3,011.35 2.33 9.50 4.22 3,900.00 4.89 52.46 168.62 3,072.52 2.42 10.07 4.50 4,000.00 5.37 52.89 171.37 3,133.17 2.54 10.67 4.81 4,100.00 5.88 53.44 174.15 3,193.13 2.68 11.30 5.12 4,200.00 6.43 54.10 176.94 3,252.25 2.83 11.95 5.45 4,300.00 7.02 54.87 179.66 3,310.36 2.99 12.62 5.79 4,400.00 7.64 55.74 2.36 3,367.29 3.17 13.29 6.12 3/29/2017 10:07:09AM Page 3 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 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) 4,500.00 8.30 56.70 5.04 3,422.91 3.37 13.98 6.45 4,600.00 8.99 57.76 7.67 3,477.04 3.57 14.67 6.76 4,700.00 9.72 58.90 10.26 3,529.55 3.79 15.38 7.06 4,800.00 10.48 60.13 12.81 3,580.28 4.02 16.09 7.34 4,900.00 11.25 61.43 15.07 3,629.11 4.23 16.62 7.57 5,000.00 8.75 62.79 1.05 3,675.90 3.00 7.98 5.26 5,100.00 9.11 64.22 3.36 3,720.51 3.11 8.12 5.25 5,200.00 9.47 65.71 5.73 3,762.83 3.22 8.28 5.23 5,300.00 9.82 67.25 8.14 3,802.74 3.33 8.46 5.19 5,400.00 10.17 68.84 10.59 3,840.14 3.45 8.65 5.15 5,500.00 10.52 70.47 13.06 3,874.91 3.57 8.84 5.10 5,600.00 10.86 72.14 15.54 3,906.96 3.70 9.05 5.05 5,615.17 10.92 72.40 15.92 3,911.58 3.72 9.08 5.04 5,700.00 10.92 72.40 17.81 3,937.23 3.84 9.48 5.14 5,800.00 10.92 72.40 19.83 3,967.47 3.97 9.92 5.26 5,900.00 10.92 72.40 21.84 3,997.71 4.11 10.37 5.38 6,000.00 10.92 72.40 23.83 4,027.95 4.25 10.83 5.50 6,100.00 10.92 72.40 25.79 4,058.19 4.39 11.31 5.63 6,200.00 10.93 72.40 27.70 4,088.42 4.54 11.79 5.76 6,300.00 10.93 72.40 29.56 4,118.66 4.69 12.28 5.90 6,400.00 10.93 72.40 31.35 4,148.90 4.83 12.78 6.03 6,500.00 10.93 72.40 33.07 4,179.14 4.98 13.29 6.17 6,600.00 10.93 72.40 34.71 4,209.38 5.13 13.80 6.31 6,700.00 10.94 72.40 36.27 4,239.62 5.28 14.32 6.45 6,800.00 10.94 72.40 37.75 4,269.86 5.43 14.84 6.59 6,900.00 10.94 72.40 39.15 4,300.10 5.59 15.37 6.74 7,000.00 10.94 72.40 40.48 4,330.34 5.74 15.90 6.88 7,100.00 10.95 72.40 41.72 4,360.57 5.89 16.43 7.03 7,200.00 10.95 72.40 42.89 4,390.81 6.05 16.97 7.18 7,300.00 10.95 72.40 43.99 4,421.05 6.20 17.51 7.33 7,400.00 10.95 72.40 45.03 4,451.29 6.36 18.05 7.48 7,500.00 10.96 72.40 46.00 4,481.53 6.52 18.60 7.63 7,600.00 10.96 72.40 46.91 4,511.77 6.67 19.14 7.78 7,700.00 10.96 72.40 47.77 4,542.01 6.83 19.69 7.93 7,800.00 10.96 72.40 48.57 4,572.25 6.99 20.24 8.09 7,900.00 10.97 72.40 49.33 4,602.48 7.15 20.80 8.24 8,000.00 10.97 72.40 50.05 4,632.72 7.31 21.35 8.40 8,100.00 10.97 72.40 50.72 4,662.96 7.47 21.91 8.56 8,200.00 10.98 72.40 51.36 4,693.20 7.63 22.46 8.71 8,300.00 10.98 72.40 51.96 4,723.44 7.79 23.02 8.87 8,400.00 10.98 72.40 52.53 4,753.68 7.95 23.58 9.03 8,500.00 10.98 72.40 53.06 4,783.92 8.11 24.14 9.19 8,600.00 10.99 72.40 53.57 4,814.16 8.27 24.70 9.35 8,700.00 10.99 72.40 54.06 4,844.40 8.43 25.26 9.51 8,800.00 10.99 72.40 54.51 4,874.63 8.59 25.83 9.67 3/29/2017 10:07:09AM Page 4 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 8,900.00 11.00 72.40 54.95 4,904.87 8.75 26.39 9.83 9,000.00 11.00 72.40 55.36 4,935.11 8.91 26.96 10.00 9,100.00 11.00 72.40 55.76 4,965.35 9.08 27.52 10.16 9,200.00 11.01 72.40 56.13 4,995.59 9.24 28.09 10.32 9,300.00 11.01 72.40 56.49 5,025.83 9.40 28.65 10.48 9,400.00 11.01 72.40 56.83 5,056.07 9.56 29.22 10.65 9,500.00 11.02 72.40 57.16 5,086.31 9.73 29.79 10.81 9,600.00 11.02 72.40 57.47 5,116.54 9.89 30.36 10.98 9,700.00 11.03 72.40 57.77 5,146.78 10.05 30.93 11.14 9,800.00 11.03 72.40 58.06 5,177.02 10.21 31.49 11.31 9,900.00 11.03 72.40 58.33 5,207.26 10.38 32.06 11.47 10,000.00 11.04 72.40 58.59 5,237.50 10.54 32.63 11.64 10,100.00 11.04 72.40 58.85 5,267.74 10.70 33.20 11.80 10,200.00 11.05 72.40 59.09 5,297.98 10.87 33.78 11.97 10,300.00 11.05 72.40 59.32 5,328.22 11.03 34.35 12.14 10,400.00 11.05 72.40 59.55 5,358.46 11.20 34.92 12.30 10,500.00 11.06 72.40 59.77 5,388.69 11.36 35.49 12.47 10,600.00 11.06 72.40 59.97 5,418.93 11.52 36.06 12.64 10,700.00 11.07 72.40 60.17 5,449.17 11.69 36.63 12.80 10,800.00 11.07 72.40 60.37 5,479.41 11.85 37.21 12.97 10,900.00 11.07 72.40 60.56 5,509.65 12.02 37.78 13.14 11,000.00 11.08 72.40 60.74 5,539.89 12.18 38.35 13.31 11,100.00 11.08 72.40 60.91 5,570.13 12.35 38.93 13.48 11,200.00 11.09 72.40 61.08 5,600.37 12.51 39.50 13.64 11,300.00 11.09 72.40 61.24 5,630.60 12.67 40.07 13.81 11,400.00 11.10 72.40 61.40 5,660.84 12.84 40.65 13.98 11,500.00 11.10 72.40 61.55 5,691.08 13.00 41.22 14.15 11,600.00 11.11 72.40 61.70 5,721.32 13.17 41.80 14.32 11,700.00 11.11 72.40 61.85 5,751.56 13.33 42.37 14.49 11,800.00 11.12 72.40 61.99 5,781.80 13.50 42.95 14.66 11,900.00 11.12 72.40 62.12 5,812.04 13.66 43.52 14.83 12,000.00 11.13 72.40 62.25 5,842.28 13.83 44.10 15.00 12,010.89 11.13 72.40 62.27 5,845.57 13.85 44.16 15.01 12,100.00 9.93 72.68 62.35 5,872.32 13.99 44.90 15.02 12,200.00 9.24 73.06 62.39 5,901.78 14.16 45.42 15.07 12,300.00 9.43 73.52 62.41 5,930.55 14.32 45.73 15.17 12,400.00 10.45 74.05 62.40 5,958.48 14.49 45.82 15.30 12,500.00 12.11 74.64 62.36 5,985.48 14.65 45.70 15.47 12,600.00 14.17 75.31 62.29 6,011.41 14.82 45.38 15.66 12,700.00 16.45 76.03 62.21 6,036.17 14.99 44.86 15.85 12,800.00 18.86 76.82 62.11 6,059.65 15.16 44.14 16.04 12,900.00 21.32 77.65 61.99 6,081.75 15.33 43.25 16.21 13,000.00 23.78 78.54 61.86 6,102.38 15.50 42.18 16.37 13,100.00 26.22 79.48 61.72 6,121.45 15.67 40.95 16.50 3/29/2017 10:07:09AM Page 5 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 13,200.00 28.60 80.46 61.57 6,138.87 15.84 39.56 16.60 13,300.00 30.90 81.48 61.41 6,154.57 16.01 38.04 16.68 13,400.00 33.11 82.53 61.24 6,168.50 16.18 36.38 16.75 13,500.00 35.20 83.61 61.07 6,180.57 16.35 34.62 16.79 13,600.00 37.18 84.71 60.89 6,190.75 16.53 32.75 16.84 13,700.00 39.03 85.84 60.72 6,198.99 16.70 30.82 16.89 13,714.20 39.37 86.00 60.71 6,200.00 16.70 30.58 16.89 7-5/8"x 9-7/8 x 11" 13,734.20 39.37 86.00 60.55 6,201.40 16.70 30.75 16.89 13,800.00 39.46 87.97 60.01 6,204.85 16.70 31.27 16.75 13,872.38 39.52 90.14 59.41 6,206.04 16.71 31.88 16.71 13,900.00 39.52 90.14 59.17 6,205.97 16.71 32.13 16.71 14,000.00 39.52 90.14 58.30 6,205.72 16.73 33.07 16.73 14,100.00 39.52 90.14 57.41 6,205.47 16.76 34.04 16.76 14,200.00 39.52 90.14 56.49 6,205.22 16.79 35.05 16.79 14,300.00 39.53 90.14 55.56 6,204.97 16.84 36.10 16.84 14,400.00 39.53 90.14 54.60 6,204.72 16.89 37.17 16.89 14,500.00 39.53 90.14 53.63 6,204.47 16.95 38.27 16.95 14,600.00 39.53 90.14 52.65 6,204.22 17.02 39.40 17.02 14,700.00 39.53 90.14 51.65 6,203.97 17.09 40.54 17.09 14,800.00 39.54 90.14 50.65 6,203.72 17.17 41.71 17.17 14,900.00 39.54 90.14 49.64 6,203.47 17.26 42.90 17.26 15,000.00 39.54 90.14 48.63 6,203.22 17.36 44.10 17.36 15,100.00 39.54 90.14 47.62 6,202.97 17.46 45.32 17.46 15,200.00 39.54 90.14 46.80 6,202.72 17.56 46.33 17.56 15,300.00 39.55 90.14 56.31 6,202.47 16.94 35.33 16.94 15,400.00 39.55 90.14 55.99 6,202.22 16.97 35.69 16.97 15,500.00 39.55 90.14 55.65 6,201.97 17.00 36.06 17.00 15,600.00 39.55 90.14 55.32 6,201.72 17.04 36.44 17.04 15,700.00 39.55 90.14 54.98 6,201.47 17.07 36.82 17.07 15,800.00 39.56 90.14 54.64 6,201.22 17.11 37.20 17.11 15,900.00 39.56 90.14 54.29 6,200.97 17.15 37.59 17.15 16,000.00 39.56 90.14 53.94 6,200.72 17.20 37.99 17.20 16,100.00 39.56 90.14 53.58 6,200.47 17.24 38.39 17.24 16,200.00 39.57 90.14 53.22 6,200.22 17.28 38.79 17.28 16,214.22 39.57 90.14 53.17 6,200.18 17.29 38.85 17.29 16,300.00 38.11 90.06 52.91 6,200.03 17.33 40.56 17.33 16,360.42 37.06 90.00 52.77 6,200.00 17.36 41.69 17.36 16,400.00 37.00 88.82 52.70 6,200.41 17.38 41.82 17.40 16,478.18 36.84 86.48 52.61 6,203.62 17.42 42.03 17.57 16,500.00 36.84 86.48 52.56 6,204.96 17.43 42.09 17.58 16,600.00 36.84 86.48 52.22 6,211.11 17.48 42.48 17.63 16,700.00 36.85 86.48 51.87 6,217.25 17.54 42.88 17.68 16,800.00 36.85 86.48 51.52 6,223.40 17.59 43.29 17.74 3/29/2017 10:07:09AM Page 6 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 16,900.00 36.85 86.48 51.17 6,229.54 17.65 43.69 17.79 17,000.00 36.85 86.48 50.82 6,235.69 17.71 44.11 17.85 17,100.00 36.86 86.48 50.46 6,241.83 17.77 44.52 17.91 17,200.00 36.86 86.48 50.10 6,247.98 17.83 44.94 17.97 17,231.26 36.86 86.48 49.99 6,249.90 17.85 45.07 17.99 17,300.00 37.81 87.92 49.76 6,253.26 17.89 44.59 17.95 17,383.24 38.92 89.68 49.48 6,255.00 17.95 43.98 17.95 17,400.00 38.92 89.68 49.42 6,255.09 17.96 44.05 17.96 17,500.00 38.92 89.68 49.05 6,255.66 18.03 44.49 18.03 17,600.00 38.92 89.68 48.68 6,256.22 18.09 44.93 18.10 17,700.00 38.92 89.68 48.30 6,256.78 18.16 45.37 18.17 17,800.00 38.93 89.68 47.92 6,257.34 18.24 45.82 18.24 17,900.00 38.93 89.68 47.55 6,257.90 18.31 46.27 18.31 18,000.00 38.93 89.68 47.17 6,258.46 18.38 46.72 18.38 18,100.00 38.93 89.68 46.79 6,259.03 18.46 47.17 18.46 18,200.00 38.94 89.68 46.41 6,259.59. 18.54 47.63 18.54 18,300.00 38.94 89.68 46.04 6,260.15 18.61 48.09 18.62 18,400.00 38.94 89.68 45.66 6,260.71 18.69 48.55 18.70 18,500.00 38.94 89.68 45.28 6,261.27 18.78 49.02 18.78 18,600.00 38.95 89.68 44.91 6,261.83 18.86 49.49 18.86 18,700.00 38.95 89.68 44.53 6,262.40 18.94 49.95 18.94 18,800.00 38.95 89.68 44.16 6,262.96 19.03 50.43 19.03 18,900.00 38.96 89.68 43.78 6,263.52 19.11 50.90 19.12 19,000.00 38.96 89.68 43.41 6,264.08 19.20 51.38 19.20 19,100.00 38.96 89.68 43.04 6,264.64 19.29 51.85 19.29 19,200.00 38.96 89.68 42.67 6,265.21 19.38 52.33 19.38 19,300.00 38.97 89.68 42.31 6,265.77 19.47 52.82 19.47 19,400.00 38.97 89.68 41.94 6,266.33 19.57 53.30 19.57 19,500.00 38.97 89.68 41.58 6,266.89 19.66 53.79 19.66 19,600.00 38.98 89.68 41.22 6,267.45 19.75 54.27 19.76 19,700.00 38.98 89.68 40.86 6,268.01 19.85 54.76 19.85 19,800.00 38.98 89.68 40.51 6,268.58 19.95 55.26 19.95 19,900.00 38.98 89.68 40.15 6,269.14 20.05 55.75 20.05 20,000.00 38.99 89.68 39.81 6,269.70 20.15 56.24 20.15 20,100.00 38.99 89.68 39.46 6,270.26 20.25 56.74 20.25 20,200.00 38.99 89.68 39.11 6,270.82 20.35 57.24 20.35 20,300.00 39.00 89.68 38.77 6,271.38 20.45 57.74 20.45 20,400.00 39.00 89.68 38.44 6,271.95 20.56 58.24 20.56 20,500.00 39.00 89.68 38.10 6,272.51 20.66 58.74 20.66 20,600.00 39.00 89.68 37.77 6,273.07 20.77 59.24 20.77 20,700.00 39.01 89.68 37.44 6,273.63 20.88 59.75 20.88 20,800.00 39.01 89.68 37.12 6,274.19 20.98 60.25 20.99 20,900.00 39.01 89.68 36.80 6,274.75 21.09 60.76 21.09 21,000.00 39.02 89.68 36.48 6,275.32 21.20 61.27 21.20 3/29/2017 10:07:09AM Page 7 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39©155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 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) 21,100.00 39.02 89.68 36.17 6,275.88 21.31 61.78 21.32 21,200.00 39.02 89.68 35.86 6,276.44 21.42 62.29 21.43 21,300.00 39.03 89.68 35.55 6,277.00 21.54 62.80 21.54 21,400.00 39.03 89.68 35.25 6,277.56 21.65 63.32 21.65 21,500.00 39.03 89.68 34.95 6,278.12 21.77 63.83 21.77 21,600.00 39.04 89.68 34.66 6,278.69 21.88 64.35 21.88 21,700.00 39.04 89.68 34.37 6,279.25 22.00 64.86 22.00 21,800.00 39.04 89.68 34.08 6,279.81 22.11 65.38 22.12 21,900.00 39.04 89.68 33.80 6,280.37 22.23 65.90 22.23 22,000.00 39.05 89.68 33.52 6,280.93 22.35 66.42 22.35 22,100.00 39.05 89.68 33.24 6,281.49 22.47 66.94 22.47 22,200.00 39.05 89.68 32.97 6,282.06 22.59 67.46 22.59 22,300.00 39.06 89.68 32.70 6,282.62 22.71 67.98 22.71 22,400.00 39.06 89.68 32.43 6,283.18 22.83 68.51 22.84 22,500.00 39.06 89.68 32.17 6,283.74 22.96 69.03 22.96 22,600.00 39.07 89.68 31.91 6,284.30 23.08 69.56 23.08 22,700.00 39.07 89.68 31.66 6,284.87 23.20 70.08 23.21 22,800.00 39.07 89.68 31.41 6,285.43 23.33 70.61 23.33 22,900.00 39.08 89.68 31.16 6,285.99 23.45 71.14 23.46 23,000.00 39.08 89.68 30.92 6,286.55 23.58 71.67 23.58 23,100.00 39.08 89.68 30.68 6,287.11 23.71 72.20 23.71 23,200.00 39.09 89.68 30.44 6,287.67 23.84 72.73 23.84 23,300.00 39.09 89.68 30.21 6,288.24 23.96 73.26 23.97 23,400.00 39.09 89.68 29.98 6,288.80 24.09 73.79 24.09 23,500.00 39.10 89.68 29.76 6,289.36 24.22 74.32 24.22 23,600.00 39.10 89.68 29.53 6,289.92 24.35 74.85 24.35 23,700.00 39.10 89.68 29.31 6,290.48 24.48 75.39 24.48 23,800.00 39.11 89.68 29.10 6,291.04 24.61 75.92 24.62 23,900.00 39.11 89.68 28.88 6,291.61 24.75 76.45 24.75 24,000.00 39.12 89.68 28.67 6,292.17 24.88 76.99 24.88 24,100.00 39.12 89.68 28.47 6,292.73 25.01 77.53 25.01 24,200.00 39.12 89.68 28.26 6,293.29 25.15 78.06 25.15 24,300.00 39.13 89.68 28.06 6,293.85 25.28 78.60 25.28 24,400.00 39.13 89.68 27.87 6,294.41 25.41 79.14 25.42 24,500.00 39.13 89.68 27.67 6,294.98 25.55 79.68 25.55 24,600.00 39.14 89.68 27.48 6,295.54 25.69 80.22 25.69 24,700.00 39.14 89.68 27.29 6,296.10 25.82 80.75 25.82 24,800.00 39.14 89.68 27.11 6,296.66 25.96 81.29 25.96 24,900.00 39.15 89.68 26.92 6,297.22 26.10 81.84 26.10 25,000.00 39.15 89.68 26.74 6,297.78 26.24 82.38 26.24 25,100.00 39.15 89.68 26.57 6,298.35 26.37 82.92 26.38 25,200.00 39.16 89.68 26.39 6,298.91 26.51 83.46 26.51 25,300.00 39.16 89.68 26.22 6,299.47 26.65 84.00 26.65 25,394.36 39.17 89.68 26.06 6,300.00 26.78 84.51 26.79 4 1/2"x 6-314" 3/29/2017 10:07:09AM Page 8 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit TVD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKE DM P2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert.Error Lat.Error Horz.Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 3/29/2017 10:07:09AM Page 9 COMPASS 5000.1 Build 74 • • Errors Report Company: ConocoPhillips s(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2K-32 Project: Kuparuk River Unit ND Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Site: Kuparuk 2K Pad MD Reference: Plan:116.7+39 @ 155.70usft(Doyon 142) Well: Plan:2K-32 North Reference: True Wellbore: Plan:2K-32 Survey Calculation Method: Minimum Curvature Design: 2K-32wp09 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,432.75 2,940.70 10 3/4"x 13-1/2 10-3/4 13-1/2 13,714.20 6,355.70 7-5/8"x 9-7/8 x 11" 7-5/8 11 25,394.36 6,455.70 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (1 11,066.51 5,715.70 C-35 13,804.26 6,360.70 A4 3,909.00 3,233.70 C-80 12,736.96 6,200.70 Lower Kalubik(K-1 mkr) 7,402.35 4,607.70 C-50 8,255.55 4,865.70 C-40 8,916.96 5,065.70 C-37 465.75 465.70 top T-3 Sand 0.00 1,541.47 1,505.70 Base permafrost(?) 590.98 590.70 K-15 Marker 13,269.69 6,305.70 Kuparuk C(Top C4) 2,355.27 2,185.70 Top W Sak(W Sak D) 12,405.52 6,115.70 Upper Kalubik(base HRZ) 12,009.01 6,000.70 Top HRZ(K-2 mkr) 13,503.87 6,336.70 A5 3,129.51 2,745.70 Base W Sak Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 KOP:Start 1.5°/100'DLS,130°TF,for 500' 800.00 798.57 -21.01 25.03 Start 2.5°/100'DLS,0°TF,for 686.45' 1,486.45 1,455.70 -142.77 170.14 Hold for 110.04' 1,596.48 1,555.70 -172.28 205.32 Start 3°/100'DLS,40°TF,for 532.36' 2,128.84 2,009.70 -382.50 382.14 Start 2.07°/100'DLS,72.56°TF,for 1303.9' 3,432.75 2,940.70 -1,249.09 608.24 Hold for 20' 3,452.75 2,953.01 -1,264.85 608.24 Start 3°/100'DLS,93.29°TF,for 2162.42' 5,615.17 4,067.28 -2,588.58 -488.82 Hold for 6395.73' 12,010.89 6,001.27 -4,524.03 -6,269.74 Start 3.75°/100'DLS,-85.75°TF,for 1703.31' 13,714.20 6,355.70 -5,753.85 -7,257.09 Hold for 20' 13,734.20 6,357.09 -5,773.63 -7,259.75 Start 3°/100'DLS,-1.73°TF,for 138.18' 13,872.38 6,361.74 -5,910.49 -7,277.99 Hold for 2341.84' 16,214.22 6,355.88 -8,232.14 -7,584.73 Start 3°/100'DLS,91.87°TF,for 146.21' 16,360.42 6,355.70 -8,376.21 -7,609.41 Adjust TF to 175.84°,for 117.76' 16,478.18 6,359.32 -8,491.31 -7,633.95 Hold for 753.08' 17,231.26 6,405.60 -9,226.08 -7,792.37 Start 3°/100'DLS,-45.47°TF,for 151.98' 17,383.24 6,410.70 -9,375.37 -7,820.16 Hold for 8011.12' 25,394.36 6,455.70 -17,289.51 -9,062.10 TD:25394.36'MD,6455.7'ND Checked By: Approved By: Date: 3/29/2017 10:07:09AM Page 10 COMPASS 5000.1 Build 74 Pool Report I • I 2K-32wp09Surface Location v.. . CPAI Coordinate Converter -From:- , T a I I • 1 Datum: Region: Datum: r-1NAD83 . Region: falaska .2:1 1NAD2i -211 lalaska- :1,1 I C Latitude/Longitude Decimal Degrees C Latitude/Longitude Decima I Degrees _7.1 C UTM Zone:1 r South r UTM Zone:IT rue r South ,A 1 Plane0 State Plane Zone:r i , Units: triii LT State Zone: 41 ,1 Units:jus _I r Legal Description(NAD27 only) r Legal Description(NAD27 only) . -Starting Coordinates: --- Ending Co ordinates: --- x: •-F3WIE97--- X: 1 498310.148203123 , Y: 13§57Eig6aF Y: 1 593811E22632493 Transform 11 Quit I Help .-‘- allINIMIMINIMON.E., - -,. r +, in, CPAI Coordinate Converter 1 I E 11' 23 -I -From: ---- - ---- r-T o: I Datum: NAD83 j Region: [alaska I Datum: INAD27 21 Region: falaska A C Latitude/Longitude 1Decimal Degrees jj C Latitude/Longitude 'Decimal Degrees •.: r UTM Zone;1 r South C UTM Zone:1True r South (.- State Plane Zone:171-71,. Units: L;"..ircl C State Plane Zone: ef Units:fus.ft L,j, r Legal Description(NAD27 only) a Legal Description(NAD27 only) -Starting Coordinates r Legal Description -- X: 11638342.95 Township: 1 1010 F.. Range:1008 rE-7.3 Y: )5937865.28 Meridian: lu 17:1 Section:11 1 FT- - 1188.66867 J [ j 94.427204 1 _ _ ----- Transform Quit I . Help 1 .-. , .mingisinampr, • • [ 2K-32wp09Surface Casing -_— 1 E. CPA!Coordinate Converter S.ix I> J y °f I C' I ffI j_,"t From: r To: i Datum: INAD83 Region: lalaska Datum: NAD27 Region: alaska I C- Latitude/Longitude Decimal Degrees _.:f C Latitude/Longitude 'Decimal Degrees 1 r UTM Zone: r South r UTM Zone: True f South State Plane Zone: 4 Units: us-ft r+ State Plane Zone:Fra Units: us-ft z.1 C Legal Description[NAD27 only) i Legal Description[NAD27 only) W X: 1 -Starting Coordinates: -Ending Coordinates: -- 1638950.75 X: 1 498917.983795254 I Y: 15936616.15 Y: 1 5936866.1174608 Transform Quit j Help I s --- --M r 4. CPAI Coordinate Converter I, G f-From: ------ -To:- Datum: jNAD83 . Region: jalaska Datum: NAD27 Region: lalaska j! ( Latitude/Longitude Decimal Degrees III r: Latitude/Longitude Decimal Degrees .�! C UTM Zone:1 r South C UTM Zone: True I— South t+ State Plane Zone: 4 t', Units: Ius-ft j re State Plane Zone:'4 . Units: .us-ft C Legal Description[NAD27 only) 1 d+ Legal Description(NAD27 only) L. li Starting Coordinates: ---- -Legal Description X: 1163895a78 p 010 N 9 OOB E Townshi : Ran e: 5936616.15 I Y: Meridian: lU _„.1 Section:112 FNL . 11437.7915 1FEL zi. 14767.1446 Transform Quit I Help t .. k • • 2K-32wp09 Intermediate Casing & Production Horizon ---_ r IfZi CRA(Coordinate Converter [ From: — — — — — — — -- Datum: JNAD83 •1 Region: alaska Datum: NAD27 Region: talaska ..1 s` Latitude/Longitude Decimal Degreesr- LatitudelLongitude Decimal Degrees C` UTM Zone:i r South r UTM Zone: True r South State Plane Zone: 4 Units:jus-it C+ State Plane Zone: q Units: us-ft C Legal Description(NAD27 only) C Legal Description(NAD27 only) a —Starting Coordinates: —Ending Coordinates: I X: 11631085.00 X: 1 491051.959799326 Y: 15932114.00 Y: 1 5932364.20661646 �� Transform Quit Help : n CPA!Coordinate Ccn•:erter I, o i O I_ S From: To: --- — Datum: JNAD83 Region: alaska .1 Datum: NAD27 . Region: alaska 1' Latitude/Longitude !Decimal Degrees ..7.1 C Latitude/Longitude !Decimal Degrees i 11 1 r UTM Zone:1 r South C" UTM Zone:1True r South t+ State Plane Zone:r:47„ Units: us-Ft � r` State Plane Zone:1 4 � Units: us-ft �. C Legal Description(NAD27 only) 0" Legal Description(NAD27 only) -Starting Coordinates: —Legal Description--- — Ili X: .1631085.00 — Township: 1010 N Range:j00$ E 1 Y: [5932114.00I 117-- Section: 15 L F"-Nr 1665.37246 'FEL 71 12076.1587 Transform Quit I Help I • • 2K-32w-p09TD r I CPAI Coordinate Convener 1 = I g1� —From: — — -To: — — — — Datum: INAD83 Region: ialaska zi Datum: 1NAD27 zi Region: lalaska .j r Latitude/Longitude IDecimal Degrees C Latitude/Longitude ID ecimal Degrees r UTM Zone:r r South r UTM Zone:jTrue r South 1 r State Plane Zone:{4 j Units: us ft . a State Plane Zone: 4 Units: lus-ft .1 C Legal Description(NAD27 only) r Legal Description(NAD27 only)ii —Starting Coordinates: —Ending Coordinates:- - X: 11629277.00 X: !489243.778998298 "' Y: 159205130.00 -_ Y: 5920830.50299616 Transform Quit IHelp In CPA[Coo•dinate Converter 1 fa! i` —From: [To:— Datum: To:— —� Datum: INAD83 Region: ]alaska .j Datum: JNAD27 A Region: Jalaska r Latitude/Longitude ]Decimal Degrees ..f r Latitude/Longitude Decimal Degrees zi 9 r UTM Zone:1 r South r UTM Zone: True South 1 0 State Plane Zone:171—E,. Units:rus-ft 2711 r State Plane Zone:1.7"--.D. Units: us-it r Legal Description(NAD27 only) Cr Legal Description(NAD27 only) it r Starting Coordinates: — r Legal Description X: 11629277.00 I Township: 1010 IN 2..1 Range:1008 E . Y: 15920580.00 ti i Meridian: U Section:127 FNL 11642.6010 JFEL A 13890.1609 Transform Quit Help -.. • . • 10:19,March 29 2017 WELLBORE TARGET DETAILS AP CO-ORDINATES) 21(-32wp09 Name TVD Shape .5-32 01.Heel 020717 JH 630.70 Grde(RadIus:100.00) Quarter Mile View 2K.321( 029 Heu002011]JH 6355.10 Grce(Rad us:100.00) 21(-320009 Heel 1'4 We 6355.70 Gide(Radius:1320.00) 21(-3203.PoSNau1717 JH 6455.70 6410.]0 Circle(Radius:100.00) 26-32 04.Toe 020717 JH 6455.70 0100(Radius:10000) 21-32vp09 Toe 174 Ma 645070 Circle(Radius:1320.00) 4000-......_. __.. ______ aK ry1W P,1 I , � 1p?‘' : �`�' l A 0 4444— .... tAP E1._.., —__—_ lia*7 '4 CA 7. 11-0.. it , , ;.,,, 57 �-4000 _4444 — — — F � 4.170.2 pi, yy'2K-79- �_ _...........- ry� ), O ' i I I u 4.0 ZK25 'q' qt, 21(42 8000 .....-- -- — --- -- - 249 2_?2 111'07 Atz `2�i 2 -01Att .�i TI ' u) 2s.o1 -16000axpiii.pei 1 — -- - __ f 2K30y 33wpp 2K�/ p08 I I 1 I I I I -20000 -16000 -12000 -8000 -4000 0 4000 8000 12000 West(-)/East(+) (4000 usft/in) 410 • : .......................... , 2K-32wp09 3-D View • • 1K 19AL1 2K.14AL f _�� 2K-14,2 ,2K-1 AL / 3 2K 13 2K J • 2K-f3>2K-13A,2f(13A • 2K-13,2K-13AL1,2K-13AL - i • :•' .'- ® 28AP 28APB1 —_2 _ __ 1 :'- � Ran Timberline,Pla 2KTmberlin ® 21(-14, ® 2KB BAKK28A i,2K / _2K 20 2K 2 i 2K 1 ,. � �� 4,2K-14A,:2K-23,7K-28,21(28 2K-11,214-11,2K-11' 11 -- AP.f,EK-14AP@7 K ` / • "-�. 21<-00,2K-20,2K-2A 2K-11,2K-71AL1,2K-11AL • • 2K-28,2K-28AL7,2K-28AL ......_ 21(-22,2K-228,2K-22A _ I K-18 • if~ 21(-22,2K-22,2K-22 2K-22,2K-22AL7-01,2K-22AL1/ 2K-24 -01.214-24AL2- • 28-01,28-01,20-01 �:� / '24'02 lu. f.IX�JJ.IXYJYJ.G. fr{ Plan:2K-n Plan:21•(-30,2K30wp08 Ar • • 2K-32wp09 3-D View �-'' / / , -..... y r,;.r / ® ..: 2K-20,2K-20,21-20 2K-19,2K-19A,2K-79A 2K-19,2K-19AL1,2K-19AL ID • 2K-32wp09 3-D View Plan:2K30,Plan:2K-30,2K30wp08 Wi- ( —_, _ r. / . ill • .. 2S 25-01 2S-01 J� 1 • • Tollerable Collision Risk Worksheet As- built REY LIME BY 1:1< APP 41111 DESCRIPT1C1f1 REY DA1E BY 0 APP CIE RPT1I7h1 0 019/17 IFC AILS Create Drawing a-r F 5122V l i',„_et_ . �. • EL " J 44. Il} 14 k 1`1 ,.._.__ 1a 5 93 VIII !''.. .4{ 7a. WA 1 - �'`_ 191; 1,� ;.. �—• ti Jeri , 7 "4 as �;�? r—jj. �� ----7:, s - �_ fi4�1 i C� — `�' - --4F.P- B at -4-1------L. 34 7 I rma 111H i "--,-,■Rin. �1- I TI W 1 ___. PROJ CT _ 34 ii 8 nog LOCATION 1I . ( ,.. , I e 9g 1 1, 11 s----.-,--( 1_011 11 _ 12 * i VICINITY MAP f ---23-*--- --11 1 2 NOTES; NTS 11 * 13 14 • 15 * 1) BASIS OF LOCATION AND ELEVATION IS DS2K 1I5, * 30 MONUMENTATION PER LOUNSBURY de ASSOC, 17 Iiii 31 2) COORDINATES SHOWN ARE ALASKA STATE PLANE, 18 * 2 ZONE 4-, N.A.D. 27, AND GEODETIC COORDINATES 2D * 1 ARE NAD 27_ * 21 3) ELEVATIONS ARE a,P.M.S,L. 22 • ▪ 23 4) ALL WELLS ARE LOCATED WITHIN PROTRACTED 21- * SECTIONS 2 de 11. TOWNSHIP 10 NORTH, RANGE B 27 25 1 EAST, ►JMIAT MERIDIAN. 5) DATES OF SURVEY: 03-1B-17, FIELD BOOK L17-07 Pp. 62-64, EB-73_ 6) ALL DISTANCES SHOWN ARE GROUND. Well NAB 27 NAD 27 Section El EV. NQ. ASP OQorcl nutee Geographic Coordinates Offeat_ Y K L . Lung, FAL F,E.L, O.G_ PAD 3D 5.938.155.22 496,310.15 70' 14' 32.24' 150' cl' 4-91 3- 139' 94' 113.4' 115,7 31 6,938.140.22 436,31015 713' 14' 32.011. 150' OD' 4-0.13" 154' 94' 113.9' 115.4' . 2 5,938015.23 4'98,310.15 7D' 14 31.75' 150' OD' 49.13" 189' 94' 114-IY 115.7 •N 5„931,905.25 498,311.15 TT 14' 29.#715- 150` 00' +1 .13" 399' 95' 113.8' 117.3' LEGEND: lib AS—STAKED CONDUCTOR LOCATION ts1 HILE • EXISTING CONDUCTOR LO ATION 'r 1 TT!L€IUNSBUTRY d71228, DK rall K ABANDONED CONDUCTOR LOCATION 1 ineih — 250 ft, 'NeerAREA: 3( MODULE: YAC} £ UNI P D2 ConoPhilhl DS2K 'TELL CONDUCTORS Alaska, Ina. AS—STAKED Grua FILE NCL OF,PAIJD NO. L1K5211 D35 3/1907 N B_211 — d35 PART: 1 €i= 1 I RE CI • • 2K-32 Drilling Hazards Summary 13-1/2"Hole/10-3/4"Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed-control drill,reduce pump rates,reduce drilling fluid • temperatures,Additions of Lecithin. Anti-collision High Run Gyro While Drilling as needed for magnetic interference.Due to the P&A of 2K-18,2K-32 is 5 ft away from existing slot.Fails anti- collision and requires TCR. Gravel/Sand Sloughing Low Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections. Hole Swabbing/Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill(use of trip sheets), Pumping out of hole as needed. Lost circulation Moderate Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM Unsuccessful cement job Moderate Use lower density cement slurry.Adjust the mud properties prior pump cement.Use proper pump rate.Due to subsidence—offsite 2K wells have had to perform top jobs. 9-7/8"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of—12.0-12.5 ppg.In event that overburden cannot be strengthened to—12 ppg FG,top setting is back up plan for 2K-32. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning,stabilized BHA,proper mud weight,PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected.BHP of 2K-21 was taken in January at 10.6 ppg EMW. Well has been on production to help aid in drawdown while offset injectors are off. 6-3/4"Hole/4-1/2"Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology,add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning,stabilized BHA,proper mud weight to minimize differential stuck,PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping,good hole cleaning.Backream out to intermediate shoe,then utilize MPD to strip out and eliminate swab. • • I (2(1 y/'(l!7- Area of Review — KRU 2K-32 (PTD #217-042) This Area of Review is required prior to the conversion of well 2K-32 from pre-production to water injection. This AOR discusses the well (2K-21A)within the1/4 mile of the well's entry point into the Kuparuk reservoir to the end of the well bore completion. As shown below in the red wellpath penetrating2K-32 circular area, 2K-21A ' p lies within our/ mile radius with a distance of approximately 1,050'from our planned wellbore. _.rhe_ .i - _ _ .. ......,.: .... -4331 I _ ____________ i t��f . . . : ill ' , 24-3avpa• -410 29(40.pte . . Well 2K-21 (API#50-103-20123-00) is the original motherbore, and was drilled in January 1990 by Doyon 14 and SI for low productivity in 1998. The original motherbore entered the Kuparuk formation at 10,369' MD (6,266'TVD). 7" production casing was run to 10,757' MD. The 7" production casing was run on 1/17/1990, and cemented with 400 sx (1.22 yield =488 ft3,87 bbls) of 15.5 ppg Class G cement, good displacement was seen and the plug bumped at 381 bbls into the displacement as calculated and float held. TOC was estimated at 9,808' MD (561' MD above Kuparuk). Although no CBL was performed, future window milling during CTD sidetracking operations confirmed presence of competent original 7" cement job at the window. In preparation for the CTD sidetracking operations in 1998, 20 bbls of 17 ppg cement kickoff plug was placed inside the 7" casing-covering and squeezing prior perforations with 1,000 psi squeeze pressure being achieved across the perfs-from 10,598'to 10,385' MD. Well 2K-21A(PTD 198-158) is a 2-3/4" hole with 2-3/8" slotted liner CTD sidetrack that enters the Kuparuk formation through a window in the 7"casing at 10,425' MD. Upon milling the window, competent cement (from the original 7" casing job) was found and a 1,892' horizontal 'A'sand CTD lateral was drilled. Currently, due to lack of injection support to this lateral, productivity has suffered, and the well is frequently SI due to low flow freeze-ups. It is the intent of the upcoming horizontal rotary injection well 2K-32 to waterflood sweep these resources toward the upcoming horizontal rotary • • production well 2K-30. With the resources being drained by these new wells,the near-term plan for 2K- 21A is to be properly P&A'd with cement. 0 11111 �, t -\ KUP PROD 2K-21A ConocoPhillips ia 1 well Attributes Max angle s ono TD Alaska.nc. J WsllDdre ANOVA nem NOM 5.110010 Statue Incl t'1 MD I6K8) Act Mtn MO) ,..ya 551032012301 KUPARUK RIVER UNIT PROD 54 30 '2 440-02 12.570.0 .• Comment 112$gpm) Dale Alnota0on End Dab 08GId I7.) Rip ROMAN Dab ZS-M.1132015 12.5E 5E*Is' 055(1 LOCKED OUT 75 11/1120/4 Last WO- 05.05 1118/1000 velttalectenix a1t,DI 4nn0l*lon Nolte MKS) 6011 Dab 4metetlon Lam Mod 05 End Dab Last Taff 12.182 0 625.'955 Rev Reason:GLV CO ARerrlpled'SLSOENDED 55(0400 11/3/2015 1 7 HANGER;311 .I] Casing Strings Casing Dea0nptlon 00(a1) 101m) Top(d(B) Se 0.9W 81148) SM Det,1*0)_.WOL.m p.-.Goes Tp Tnrud v. I-F} CONDUCTOR 10 15.082 36.0 115.5 115.0 02.58 H.40 WELDED 111,1111811 uwWI o 9 Pa sing Dcnplen OD tin) T0m) Sal0ptn pour) SO DWI.01,01,0),..W D). U 'Moan 9...Grade TOP ean SURFACE 5013 8821 35.0 3.910.3 2.023.3 3800.-55 BTC ,,,.,,„-,,.b.�,,..�a,....,. ..,,,. casino 0.0019550 oD gni ID Im) Top 011(8) set Digit Mom sa Dv*ITR'07-.WiDLu p...Grade Tp rnr.w PRODUCTION 7 6278 33.' 10.7575 8,335.0 20.00 J-55 BTC CaMnp DuElptlon OD Om DRI) Top p6(B) SN Dp1n p9KB) Se!Dap%RPM...101/Lits p..'Gude Top Tarsal WINDOW'A' 0 5.000 10.42E 0 10.430.5 0,287.2 Casing 535019tton OD m) 10(m) Top MKS) 10 Dp1n 11(8) Sot Dep,(TVD)_.WUL0 P.. Gm* Top 701000 I SLOTTED LINER 2 3:8 1.005 15.008.2 12.3'0.5 8,381.8 4.65 L-80 FL4S. -n-^-,CONDUCTOR:36.0.11'.'.J A Liner Details Top IMPS) Top(TVD)(10031 Top old r) nom DMo COm Nominal(In> ID 10.0682 0.1120 59.71 FISH NECK 3.5'GS'FISH NECK 1840 12.280.3 8,381.7 89.19 SEAL SEAL SUB 1.303 SARTYVLV.1,610• . Tubing Tubing Strings toning,Duomp/en String Ma ID 1011 Top.005'� 1K D.p10 a( SeL'.Tx,r:Ji 5: 01 r-5n Top 1.000.000, . TUBING _ 9i._ '7 3F' (: ..- 1 111 0.170 5160.02 Completion Details GAS 5(67:2.080.1 pum Top OMB) Top(TVD)IttK6) 109 and try nom Du Con N pe) t0 31.1 31.1 005 HANGER FlAC GEN 1V TUBING HANGER 3 500 1.810.0 1.7200 41 32 SAFETY VLV CAMCO TROP.-1A-ENC SAFETY VALVE(LOCKED 0JT 2.612 9127166) 0.940.0 6,0484 6021 GASLIFT CAMCO►MG ' 2.867 SURFACE 350,1.9193-• 0.955 3 6.055.8 00.13 NIPPLE 0775 Y.SELECTIVE 5540(65 NIPPLE 2.813 9.986.F 0.071.3 80.11 PER BAKER PBR WI 1 V STROKE aM'SEAL 3000 GAS UFT 0.797- 10,000.6 8.078.1 601505.55:8„:8096111 0118 PACKER BRO708:1131H83" �TREVA@LE PACKER280010.188.06.173.85886PACKEREROETREV 68&.8 PAGIER2.892 540 U0':7,fms 10.227 5670355901NWPLE11'"15 4110 W t'sJe.7f ND GO _750 ...2331 OtEk3 .'91.8 505 BAn ER..181612 0,17 SJE 1222 Perforations&Slots GAS LRT:6.701 SnO1 4-..--,1-4 Dona Dm 111/11,1 GAS LIFT.9.18.6 I T0p MKS) -1m 0108) 7000(1190094 Tool mooMG0bn Typo Cam 10.1830 '2280.0 8.1708 8.3517 115.1350 320 SLOTS Mandrel Inserts ■ S1 30 GASLMT;9.940.9 • On T (TVD) 05VW, Lazo Pon 558 TRO Run R Top(RPBOD) ptKB) 30 MOON x(01) Sow Typo p0) poll Ran Daft Cyr, 1 2.800.1 2.3385 MEALS "MPD 1 GAS LIFT GLV Si'. 0.158 1,343.0 7/161109) NIPPLE;9.9553 .7 2 5,7008 3,003.0 MERLA -1102 1 GAS lin' GLV Ea. 0.250 1.382.0 71611051 3 7,8445 4.8784 MERLE. -MP:' 1 GAS LIFT GL Ea 3.259 1,454.0"5'11F u Nos Mk 9,986.9 - 4 8.7014 5.433.4 MERLA TMPD ' 1 GAS LIFT OV Be 0.188 0.0 801312013 5 5.085 e 5.780 5 MERLA TM02 1 GAS LIFT DM'+ RI- 0.000 0.0 0/26/1998 PACKER;10.131336 F 5.043 i 5.048 4 CARICO MAIG.2 1 112 GAS LAT DM 5: 7 00 D0 9.28+098 I Notes:General&Safety EnO Deo Alnol*Bn 0:2511908 NOTE:WELL SIDEDTRACKED TO'A' 'i 11472010 NOTE 1.100544.00.00 t✓Alaska S 4ernad08.0 1W31/2015 NOTE.LEFT 4 pieces of 7/8'G(Dppl.on GLV @7545'129151-15'ea01I II I 1 PACKER.10,156.9 II NIPPLE 10223 1 Il SOS.102302 1 01 ■ II I C _ WINDOW'A:14425.-10430E IIE 111 I III U 080351.1 ON;33.1-10,7575 5,015.10,16316122010--/ SLOTTED LOME 10,0062. 12.)(61 • Well: KRU 2K-32 <==Data Input Name: CPAI <_=Data Input r Mud Weight(ppg) 11.00 <==Data Input Weak point or LOT-Measured depth(ft) 3,433' <==Data Input Weak point or LOT True vertical depth(ft) 2,941' <==Data Input Weak point or LOT-Hole angle(deg) 45.2° <==Data Input Weak point or LOT-Hole size(in) 13.500" <==Data Input Weak point pressure or LOT-EMW(ppg) 13.00 <==Data Input Zone of interest-Measured depth(ft) 13, <==Data Input Zone of interest-True vertical depth (ft) 6,356' <==Data Input Zone of interest-Hole angle(deg) 86.0° <==Data Input Zone of interest-Hole size(in) 11.000" <==Data Input Zone of interest-Pore pressure EMW(ppg) 10.60 <==Data Input Gas gradient(psi/ft) r 0.10 ' <_=Data Input Bottom hole assembly OD(in) 8.0" <==Data Input Bottom hole assembly length(ft) 151' <_=Data Input Drill pipe OD(in) 5.000" <==Data Input BHA annular vol.@ zone of interest(bbl/ft) 0.0554 DP annular vol.@ zone of interest (bbl/ft) 0.0933 DP annular vol.@ weak point(bbl/ft 0.1528 Additional safety margin(psi) 0.00 <==Data Input Weak point pressure(psi): Plo 1,988 psi Weak point pressure-Safety margin: Pmax 1,988 psi Pmax EMW 13.00 ppg Max anticipated formation pressure(psi): Pf 3,503 psi Weak Pt to Zone of Interest distance(ND ft): OH {TVD} 3,415' Weak Pt to Zone of Interest distance(MD ft): OH {MD} 10,281' Maximum influx height at the bit (TVD ft): H {TVD} 928' Maximum influx height at the bit (MD ft): H {MD} 13,305' Calc.volume of{H}around BHA: V1 bha 8.4 bbl Calc.volume of(H)around drill pipe: V1 dp 1226.7 bbl Calc.volume that H equals @ initial shut in: V1 1235.1 bbl Calc.vol.that H equals @ weak point(MD ft): Vwp 201.2 bbl Calc.volume of Vwp @ initial shut in: V2 114.2 bbl Kick Tolerance: V2 114.2 bbl _.. NOTE: V Loepp 4/27/17 • i Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent Thursday,April 27, 2017 8:40 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2K-32(PTD 217-042) LWD-Sonic This well will not be frac'd,we will only pre-produce. From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,April 27, 2017 8:37 AM To:Voss,Jake<Jake.Voss@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2K-32(PTD 217-042) LWD-Sonic Are there plans to frac this well? From: Loepp,Victoria T(DOA) Sent:Thursday,April 27,2017 8:36 AM To:jake.voss@conocophillips.com Subject: KRU 2K-32(PTD 217-042)LWD-Sonic Jake, These provisions will be included in the approved PTD. Approval is granted to run the LWD-Sonic on upcoming well KRU 2K-32 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement(and lengths)that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation,or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement,just as the e-line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report,the logs and the FIT, remedial measures or additional logging may be required. Victoria 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.00v 1 • S Loepp, Victoria T (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Wednesday,April 26,2017 3:14 PM To: Loepp,Victoria T(DOA) Cc: Voss,Jake Subject: PTD Status Inquiry- KRU 2K-32 (PTD 217-042) Hi Victoria, Doyon 142 is running upper completion on our current well(3R-101),and we expect to be moving onto 2K-32 over the weekend. PTD approval has not yet been granted and I was curious if there is any information or clarification needed by the AOGCC before approval is granted. Thank you, Daniel Bearden Supervising Drilling Engineer ConocoPhillips,Alaska 907-263-4864 work 907-602-7068 cell 1 • • Loepp, Victoria T (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Thursday,April 27, 2017 8:19 AM To: Loepp,Victoria T(DOA) Cc: Bearden,J Daniel Subject: RE: KRU 2K-32(PTD 217-042)Anti-collision Victoria, 2K-18 has been plugged and abandoned.We will be using Gyro-while-drilling for directional control until we pass our anti-collision issues(close to 500' MD). This will be similar to the KRU 2M-37(PTD 216-083)and 2M-38(PTD 216-083)wells we drilled in November 2016 and the January of this year which had similar anti-collision issues with P&A wells in the surface section. Please let me know if you need any more info from me. Thanks-Jake From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,April 27,2017 8:02 AM To:Voss,Jake<Jake.Voss@conocophillips.com> Cc: Bearden,J Daniel<J.Daniel.Bearden@conocophillips.com> Subject: [EXTERNALjKRU 2K-32(PTD 217-042)Anti-collision Jake, KRU 2K-18 fails major risk when drilling KRU 2K-32 in the anti-collision analysis. Will 2K-18 be shut in while drilling 2K-32 or a deep plug set? Please outline anti-collision mitigation measures. 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.LoeppCa?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 • • Loepp, Victoria T (DOA) From: Voss, Jake <Jake.Voss@conocophillips.com> Sent: Tuesday, April 18, 2017 11:38 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2K-32(PTD 217-042) Surface Cement Calculations Good afternoon Victoria, Please see updated cement calculations (changes in red). Some of the cells on my excel sheet did not link when I changed parameters. • ID on 10-3/4" increased • Conductor length increase • Excess percentage from 40%to 50% (1.4 to 1.5)on the Lead cement. 2K-32 Cement Calculations Hole Size ft(TOC) ft(Bottom) OD ID ppf Conductor Depth: 42 39 110 20 19.14 94 Surface Casing Depth: 13.5 39 3433 10.75 q-q5 45.5 Intermediate Casing Depth: 11 12000 13714 7.625 6.875 29.7 Surface Cement:Surface to 3,433' MD Capacities Lead 1.84 ft3/sx of 11.0 ppg DeepCRETE Tail 1.64 ft3/sx of 12.0 DeepCRETE OH 0.177045 Permafrost (PF)depth 1541 ft 13-1/2" x 10-3/4" 0.064783 XS% Above PF 250 % 20" x 10-3/4" 0.243615 XS% Below PF 50 % 10-3/4" 0.096175 Tail Cement Length 500 ft 500 x 0.06478288 x 1.5 48.5871624 Shoe Track 80 ft 80 x 0.09617496 x 1 7.6939965 Open Hole x 0.17704488 x 1.5 0.53113464 Total 57 bbl 319 ft3 194 sx Lead Top Tail Cement to Permafrost 1392 ft 1392 x 0.06478288 x 1.5 135.2666o bbl Permafrost to 20" Casing 1431 ft 1431 x 0.06478288 x 3.5 324.465071 bbl Conductor Length 80 ft x 0.24361482 26.7976307 bbl Total: 487 bbl 1 • • 2731 ft3 1484 sx Please let me know if this is closer to what you had. Thanks, Jake From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, April 18, 2017 11:07 AM To:Voss,Jake<Jake.Voss@conocophillips.com> Subject: (EXTERNAL]KRU 2K-32(PTD 217-042)Surface Cement Calculations Jake, Could you please check the surface casing cement calculations? Our calculations differ. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepo(&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.Loeoo@alaska.gov 2 • • Bettis, Patricia K (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Thursday, April 6, 2017 9:25 PM To: Bettis, Patricia K (DOA) Cc: Voss,Jake Subject: RE: KRU 2K-32 Permit to Drill Application (PTD 217-042): AOR Guidance Attachments: Amended 10-401 signed Water Service.pdf;Area of Review for Injection.pdf Good evening Patricia, Please find attached the AOR for the specific description of well KRU 2K-21A that lies within the%mile radius of our planned pre-produced injection well 2K-32. We have also included an updated and signed 10-401 that properly describes well 2K-32 as a Water Injection Service well. Our 10-407 post-rig completion report will identify as a producing well (for a period of 6 months or less). Regards,and please let me know if any additional information is requested, Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,April 06, 2017 2:24 PM To: Bearden,J Daniel<1.Daniel.Bearden@conocophillips.com> Subject: [EXTERNAL]KRU 2K-32 Permit to Drill Application (PTD 217-042):AOR Guidance Good morning Daniel, We appreciate ConocoPhillips providing the plats for the AOR, including the 3-D view; however, at times it is difficult to determine from those plats what wells are within the AOR. I attached a guidance document for ConocoPhillips' use and a AOR "go-by"that includes a table that includes distance from proposed injection well, completion details,and annulus integrity/cement conditions and discussion of other wells within the AOR. Submittal of this type of form with the Permit to Drill Application for an injector or for a request to convert a producer to injector would greatly aid the AOGCC's review of ConocoPhillips'applications. Please submit a detailed discussion for the AOR for KRU 2K-32 that includes an evaluation of the integrity/cement conditions of all wells within the AOR. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 1 • • 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. 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,April 6, 2017 1:51 PM To: Alexa, Kurt J Subject: FW: KRU 2K-32: Permit to Drill Application (PTD 217-042) Good afternoon Kurt, Jake is out of the office and referred any questions concerning Shark Tooth Phase 2 to you. Please see the below email. Patricia From: Bettis, Patricia K(DOA) Sent:Thursday,April 6, 2017 1:49 PM To:Voss,Jake<Jake.Voss@conocophillips.com> Subject: KRU 2K-32: Permit to Drill Application (PTD 217-042) Good afternoon Jake, On the cover letter for the Application, ConocoPhillips states that KRU 2K-32 will be a pre-produced injector. On Form 10-401, BOX lb,the development box is checked. Can it be assumed that the well will be pre-produced for approximately 6 months and then a Sundry Application will be submitted for the conversion from development well to injector well? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 i i Bettis, Patricia K (DOA) From: Voss,Jake <Jake.Voss@conocophillips.com> Sent: Thursday, April 6, 2017 1:49 PM To: Bettis, Patricia K (DOA) Subject: Automatic reply: KRU 2K-32: Permit to Drill Application (PTD 217-042) I will be out of the office from 12/23 to 1/3/17. I will have limited cell service during that time. For Shark Tooth Phase 2-Please contact Kurt Alexa: 907-263-4933 For 2M-38, Please contact Dan Bearden: 907-263-4864 Thanks, Jake 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,April 6, 2017 1:49 PM To: Voss, Jake Subject: KRU 2K-32: Permit to Drill Application (PTD 217-042) Good afternoon Jake, On the cover letter for the Application, ConocoPhillips states that KRU 2K-32 will be a pre-produced injector. On Form 10-401, BOX lb,the development box is checked. Can it be assumed that the well will be pre-produced for approximately 6 months and then a Sundry Application will be submitted for the conversion from development well to injector well? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis yalaska.gov. 1 • • TRANSMITTAL LETTER CHECKLIST WELL NAME: K i (A, 02K-32, PTD: 02/ Oy Development V Service Exploratory Stratigraphic Test Non-Conventional FIELD: glkyratAfr. POOL: �i Wu- XyckilAk. V�x�k � ) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are / also required for this well: Well Logging Requirements Per Statute AS 31.05.030(dX2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 • 40 I ❑ To U) O) 0 0) 0- u) N U) a) 5 C. —> C CO. , Q U a L c' o co 5 co o o 12 05 Lu (n �� L• to O. 0 E 0 a`' c, sa 3' D O cop �� �� O 00� 0 T m 3' Q op 3 a: o _ a) = Q 3 3, o L. v, a voi 3 rNi o 3. ° �. ,� a o N '9 -)� 0� �� • � '3. >O' 00 ,-rr M ?: co F- . 0 O `� > pop •V� Z. O. ai N' O' U. a) �' 1 1,0 C a 0� � E. O ) O, N4, app Q y N O •� -O W «. CO 0) a -0 M N. N a). co 0E DI7, '13 d 01 Q Y c a? y U)co y . a �, ° a 2 N > ,m c, o' �: �� �: �: c o, a a rm U> Z: v, v E a) �� M. O L 3 3 N, U U. N N O C 17.-a N U) N CO N U). coo N' Y DO a �, Y, vo 0 >_ v_t m E °, Y' m. 2, Z O. N < M M O C.) N c M U U) ) N O-0 Na' N. ° aa)) p o 0, a' v, v, a�; O, 0' a��i o cM) v o; rn . > m d (> D' U CD . C. Lu . Q, Y. Y U U < Y' a' N- C+) a. * < o 2' 2' Y' I a' 0 rtU)U)U) U)U)(4 f0 U) U)U) co co U) U> CO U) CO CO U) co U) U) CO CO CO CO CO CO CO CO CO '��l . Q a) a) a), o, a), a), a), a), a), a), a), a), a), Q, co a) a), a), o, a), a), Q, a), a) a) a), co a) a), a), a) o, a), Q, Q; Q, w o, a), ° z >- >- >- >- >- >- >-, >-, }, >- >- >-, >-, >- >- z, >-, >- >- >- z, >-, >- z r >-, >-, >- >- >- >- >- >- z >- z z, z — >, C o, a) t y T CO as U W,1 i2O E. a> . 30 S 43*a c o flO al E2 c O o. Z, s O avi o. m l6, N. co co y� ¢ y O` a)� p. O. U). x- CC V� j� 'C. O� N N 0 N� U LL a), a) N Q O O. �. c. LI th hC1 t.a a) o 2 ..9 ., O' N' N E I 0 .c OS 2: �: t0' (0 „9 3' o U) C' O L. C' U' 7 <' co co a)' N Z .o O C v O a) c v @ ° o� D o. `. a) CO O O 0) a). L. 0 N' c D E E = -° c c E c 0' 3' o °' ~' a o 0' ' w o o L' o `t Nn F0 u- C o a a' o' .- m c o � � ° v m o o a a) a o' U y m, o E ° , Q % u) -o o, o) o 0 c 9) g E a (> (> a) . ° ° ° c' ° %, u, - 3 c a o, Z' o' - E ° 3 o' o' a) L' a 3 a) E a?, . c, B m L' L' �: m' ° ° ° o' a> '- _ o 0 4 (Pr, a c)- 3 0' ' o " ._ c E Q 03 C• '°� 40 (0 f6. 3L 0, .• v' co' CO v, ,_ a), co t= CU' c a) coM. Cps U) U d� ° ' O co � a) CO N O w O o a .Q v' c' w L, is a)' v' 1°, 3, 3, > o a, 1.5 ° w o 0, �' 0 oo u) a •a .... ca 0 3 0 -c' Z U a D o' m 0' v 'v S O o, `O 0 Cl.)vo m' 'E. o c O - o' - c aacr) o o ,�' °' c' •a m' E °) o aa))' a CO' ,' c J a) a •O' N' N _a U. O. 0' m' a c �; U O Q O' ai a)' Y. .O CV '' a): — U) E' co o (/)' 0 O, C• o W� O xs = L' U). CO' a a 01 N °' y y a L' ,- -' U) m o- N (6 @ @' C0• p N' Ca T C U .3,, 2, - CO °' y' O, 0. -° a m +- C O. O. CO 3 CO (0. . C. (6 ` O 7• 7 U).. - co -0 . . °' a) @ -° 7. - 3 - co c a o. a) N A Uj a> a> a)� 3� c .°� 0) c a a N' c� C 0> 3 CT a �' °' U O' O a> N: T :0 N' LL o co' L _ v v U. • C a, L� a, a -O w' U). ° 'N� U). a). >, .0 IS L. a) ro U' 4... c C c E' U ay E' 3. .2 -2 (0. .c� °, L. c. c, . .O+' U. C .9 v v O U) a) O O. a) c O. V, c. U, C. O. N. p 3' 3 > o U CO CO U N' N = a) O d (0' U N, ay CO o c I— Z, 2 c ;. (f0) coi c' :: ca o' E. m. ° > ° y. E - c. w a) ``g o' m °, ° . m' U v_> o, c 0 a). o. o. is `q m, r uu 4 3' o c ° ) c> OU E a' 'v �' �' o' S a>): m' m' E E c o. a U' v m' H H H c - >' m a a; o; a 0 E, s 0E), 0, c, m J . a> 3. c c •t N g - a); a 'c o o Ti) ° •° a a a). a), a>, o — � o 0, ° 2, 2 2 co v co v, � - O O t ° a) m, no. m a) o, 0 V ' a, J, �, �, � cn �-; 00ct' 0.. 0 Q, az 0c7) 0000< .c- Qw o CO m0 ? a0Ocn0 Wa O — N CO '7 U) CO N- CO 0) 0 N M a CO CO h CO 0) 0 N M U) CO N- CO CO I E N M M co N. o O - N N N N N N N N N N CO CO CO CO M CO COCOCOCOo U .- If a) O C w r N w, (N0 co ° O V .�°- 0 (N t3) G N N Oo u)W o R v E v v E J N .E a) O O O c lc .. Occ, 0 uj Q ° a 5 a) °' a CT- CC a a c Ill a Q
