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218-176
DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2181760 Well Name/No. MILNE PT UNIT M-12 F13 1-' Operator HILCORP ALASKA LLC POL MD 16792 TVD 4029 Completion Date 3/5/2019 Completion Status 1-0I1- Current Status 1 -OIL REQUIRED INFORMATION Mud Log No Samples NoZ DATA INFORMATION List of Logs Obtained: ROP/ABG/DGR/EWR/ADR 2"15" MD/ PBI/ PB2, ABG/DGR/EWR/ADR 2"/5" TVD / PB1/ PB2 Well Log Information: Log/ Electr API No. 50-029-23619-00-00 UIC No Directional Survey Yes V/ (from Master Well Data/Logs) Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop _ P CH Received Comments ED C 30433 Digital Data _ _ _ _ 100 16792 3/12/2019 Electronic Data Set, Filename: MPU M-12 DGR ABG EWR ADR.las ED C 30433 Digital Data 4915 16754 3/12/2019 Electronic Data Set, Filename: MPU M-12 ADR Quadrants All Curves.las ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD MD Finaf.cgm ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD TVD Final.cgm ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12—Definitive Survey Report.pdf ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12—Definitive Survey Report.txt ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 GIS.txt ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD MD Final.emf ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD TVD Final.emf ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 Geosteering.dlis ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 Geosteering.ver ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD MD Final.pdf ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD TVD Final.pdf ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD MD Final.tif ED C 30433 Digital Data 3/12/2019 Electronic File: MPU M-12 LWD TVD Final.tif ED C 30433 Digital Data 3/12/2019 Electronic File: EMFView3_1.zip ED C 30433 Digital Data 3/12/2019 Electronic File: Readme.txt Log C 30433 Log Header Scans 0 0 2181760 MILNE PT UNIT M-12 LOG HEADERS AOGCC Page 1 of 4 Monday, June 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2161760 Well NamelNo. MILNE PT UNIT M-12 Operator HILCORP ALASKA LLC API No. 50.029-23619-00-00 MD 16792 TVD 4029 Completion Date 3/5/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No Log C 30434 Log Header Scans 0 0 2181760 MILNE PT UNIT M-12 PB1 LOG HEADERS ED C 30434 Digital Data 100 5108 3/12/2019 Electronic Data Set, Filename: MPU M-12 13131 DGR EWR.Ias ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 P131 LWD MD Final.cgm ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 PB1 LWD TVD Final.cgm ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12P61_Defnitive Survey Report.pdf ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12PB1_Definitive Survey Report.txt ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12PB1 GlStxt ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 P131 LWD MD Final.emf ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 PB1 LWD TVD Final.emf ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 P61 LWD MD Final.pdf ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 P131 LWD TVD Final.pdf ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 PB1 LWD MD Final.tif ED C 30434 Digital Data 3/12/2019 Electronic File: MPU M-12 P61 LWD TVD Final.tif ED C 30434 Digital Data 3/12/2019 Electronic File: EMFView3_1.zip ED C 30434 Digital Data 3/12/2019 Electronic File: Readme.txt ED C 30435 Digital Data 100 16644 3/12/2019 Electronic Data Set, Filename: MPU M-12 PB2 DGR ABG EWR ADR -las ED C 30435 Digital Data 4915 16606 3/12/2019 Electronic Data Set, Filename: MPU M-12 P132 ADR Quadrants All Curves.las ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 PB2 LWD MD Final.cgm ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 P132 LWD TVD Final.cgm AOG('(' Page 2 of -4 Monday, June 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 permit to Drill 2181760 Well Name/No. MILNE PT UNIT M-12 Operator HILCORP ALASKA LLC API No. 50-029-23619-00-00 MD 16792 TVD 4029 Completion Date 3/5/2019 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12PB2_Definitive Survey Report.pdf ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12PB2_Definitive Survey Report.txt ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12PB2 GIS.txt ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 PB2 LWD MD Final.emf ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 P132 LWD TVD Final.emf ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 P82 Geosteering.dlis ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 PB2 Geosteering.ver ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 PB2 LWD MD Final.pdf ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 P82 LWD TVD Final.pdf ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 PB2 LWD MD Final.tif ED C 30435 Digital Data 3/12/2019 Electronic File: MPU M-12 PB2 LWD TVD Final.tif ED C 30435 Digital Data 3/12/2019 Electronic File: EMFView3_t.zip ED C 30435 Digital Data 3/12/2019 Electronic File: Readme.txt Log C 30435 Log Header Scans 0 0 2181760 MILNE PT UNIT M-12 PB2 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report O Production Test Information YNA Geologic Markers/Tops �) Directional / Inclination Data O Mechanical Integrity Test Information Y / NA Daily Operations Summary CY Mud Logs, Image Files, Digital Data Y / Core Chips Y/6? Composite Logs, Image, Data Files O Core Photographs Y ndA Cuttings Samples Y / 1 Laboratory Analyses Y AOGCC Page 3 of 4 Monday, lune 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2181760 Well Name/No. MILNE PT UNIT M-12 Operator HILCORP ALASKA LLC MD 16792 TVD 4029 Completion Date 3/5/2019 Completion Status i -OIL Current Status 1 -OIL COMPLIANCE HISTORY Completion Date: 3/5/2019 Release Date: 1/3/2019 Description Date Comments Comments: Compliance Reviewed By: Date: API No. 50.029-23619-00-00 UIC No AOGCC Page 4 of 4 Monday, June 10, 2019 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, May 3, 2019 10:48 AM To: Taylor Wellman; Roby, David S (DOA) Cc: Tom Fouts Subject: RE: Milne Point Wells M-10 (PTD 218-165) Sundry 319-170 & M-12 (PTD 218-176) Sundry 319-171 For Temp Flow Extension Request Taylor, You have approval to extend the temporary flowback configuration for M-12 and M-30 an additional 7 days (until May 11th) Per our phone conversation you can continue to produce the two wells using remote pump trucks for power fluid supply and bypassing the Moose pad facility. Please update me periodically on your progress for full Moose Pad production. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwortz@alaska.aov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, May 2, 2019 5:29 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Roby, David S (DOA) <dave.roby@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com> Subject: Milne Point Wells M-10 (PTD 218-165) Sundry 319-170 & M-12 (PTD 218-176) Sundry 319-171 For Temp Flow Extension Request Mr. Schwartz and Mr. Roby, We request to extend the temporary flow configuration for Milne Point wells M-10 (PTD 218-165) & M-12 (PTD 218-176) by 1-2 weeks. Both wells are currently operating under Sundry 319-170 & 319-171 respectively. Facility Update The construction of the facility on Moose Pad is complete but we are currently commissioning all the control systems. All the fluid systems in the facility are fluid packed and are cycling fluids (isolated from outside fluids). This has been a little slower than our original estimations to ensure everything is correct prior to running full production fluids through the facility. Our plans are to introduce hydrocarbons from F&L pads today and continue with the confirmation checks that all our control systems are operating as intended. Following this we would follow with introducing the production header from Moose Pad (currently M-10 & M-12) into the facility. The timing for this will be after 5/4/19, which is the end date for the flow configuration approved under Sundry 319-170 & 319-171. While the well's safety systems are hooked up we do not want to put them into full service yet as while we are dialing in the facility controls, there are times that the facility shuts in, which in turn sends the signals to shut in all the wells. Once the facility is running with F&L fluids and begin injection of disposal water into M-03, our primary target would be to get M-10 & M -12's safety surface safety systems operational & tested (inspectors witnessed) as soon as possible. Following this the power fluid pumps and the test separator. If you would like further information or to discuss this please let me know and I will provide. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC— Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcora.com THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU M-12 Permit to Drill Number: 218-176 Sundry Number: 319-171 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a og cc. a l oska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Conditions of approval: 1. Well must be manned 24/7 while operating. Hourly inspections of wellhead and hardlines must be documented. Include wellhead T /IA/OA pressures. 2. SSV must be function/performance tested within 2 days of start-up. SSV test procedure must be on site for review by AOGCC inspector. 3. Written procedure for ESD of power -fluid and well SSV on location. 4. Per CO 477 Rule 6.c. Moose pad wells must be tested twice during the month of April. If the production facility is not operable by month end a portable test separator must be used to test M- 10 and M-12. 5. This flowback configuration is valid for 30 days. Additional flowback time using temporary flowline and pumps must be approved in writing by the AOGCC. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCCgrants 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, Je sie�lowski Commissioner DATED this C day of April, 2019. RBpM$(- L-�ZVAPR 5 5 niq STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ��A APR 0 3 2019 101 r-- i„ 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Temporary Flow ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 218-176 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23619-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477,05 ' Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MPU M-12 9. Property Designation (Lease Number): • 10. Field/Pool(s): ADL025514, ADL388235, ADL025515 Milne Point/ Schrader Bluff 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): 16,792' 4,029 16,78T 4,029' 1,740 N/A NIA Casing Length Size MD TVD Burst Collapse Conductor 114' 20" 114' 114' NIA NIA Surface 4,885' 9-518' 4,885' 3,945' 5,750psi 3,090psi Tie -back 4,724' 7" 4,724' 3,936' 7,240psi 5,410psi Liner 12,082' 6-5/8" 16,792' 4,029' 6,090psi 3,470psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.3 / L-80 / EUE 8rd 4745 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PHL Retrievabl SLZXP LTP and N/A 4,485 MD/ 3,880 TVD & 4,710 MD/ 3,934 TVD and NIA 12. Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑D Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/4/2019 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman -717d- Authorized Title: Operations Manager Contact Email: TA ellman hllcor .com 1 I Contact Phone: 777-8449 Authorized Signatu 0- Cti..i P Date: 4/3/2019 COMMISSION USE ONLY Conditions of apprWaV Notify Commission so that a representative may witness Sundry Number: n I G I —7 ✓h I Plug Integrity ❑ SOP Test ❑ Mechanical Integrity/)Test ❑ Location Clearance ❑ Other li F/aW l^-on.-Y•a,��u. rz„py.® U4d �Otlr l� ��5. Ir IT-h.-Qs5' Post Initial Injection MIT Req'd? Yes ❑ No �. T Spacing Exception Required? Yes ❑ No d Subsequent Form Required: Yo Y RB®M$iT;✓APR 0 5 2019 APPROVED BY l r' Approved by: COMMISSIONER THE COMMISSION Date: \y��50\N"-fs ORIGINAL . 411 Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. V, �` f� � !� / Submit Farm and Attacheuplica e �� U HiI.1, AI.A., LL, IA pA Temporary Flow Well: MPU M-12 Date: 04/30/2019 Well Name: MPU M-12 API Number: 50-029-23619-00 Current Status: Shut in Producer Pad: M -Pad Estimated Start Date: April 4, 2019 Rig: N/A Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 218-176 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type: Temporary Flow Current Bottom Hole Pressure: 2,121 psi @ 4,000' TVDss Weight of completion fluid/ 10.2ppg EMW Maximum Expected BHP: 2,121 psi @ 4,000' TVDss Weight of completion fluid/ 10.2ppg EMW MPSP: 1,721 psi (O.lpsi/ft gradient to surface) Brief Well Summary: MPU M-12 was drilled and completed as a Schrader Bluff OA production well. The well was completed with a jet pump artificial lift mechanism in March 2019. The well and M-10 are scheduled to be the first 2 production wells on the newly constructed Moose Pad. The fluid flow path after commissioning the Moose Pad facility, is to comingle with F&L fluids at Moose Pad Facility, separate out and dispose of the water before shipping the combined oil/gas to the Milne Central Plant. As time has progressed the Moose Pad Facility commissioning date has slipped. The wells M-10 & M-12 have completed their post rig work and are ready to be brought online. Notes Regarding Wellbore Condition: • The 3-1/2"x7" casing passed an MIT -IA to 3,600psi on 3/05/2019 (during the original completion). • The 7"x9-5/8" casing passed an MIT -IA to 1,000psi on 3/05/2019 (during the original completion). Objective: Produce the well under temporary flow operations until Moose Pad Facility is operational and 'normal' operating 4 of the well is possible. Temporary Flow System Description: SVS System These wells will not have functional pressure trips installed to automatically shut in the well at the SSV and will therefore be continuously manned cto omply with 20AAC25.265.1.2. See the attached redlined P&ID for the wells flowpath. Also note that the pump truck will need to be continuously operated (manned operation) so in —' the case of an emergency, it can be shut down immediately by the operator. SSV will be in open and able to be dumped via valve 1/4 turn valve or button located in the wellhouse. These are captured as part of an MOC for temporary flow conditions until the facility is commissioned and the temporary piping is removed. Temporary Piping There are 4 sections of temporary 2" hardline piping that will be installed and monitored for leaks during operation. 1. 2" hardline from the pump truck to the power fluid line upstream of the check valve for M-12 (highlighted on sheet #2 or Drawing # PI -MOM -10003 of the P&ID's attached). 2. 2" hardline from the pump truck to the power fluid line upstream of the check valve for M-10 (highlighted on sheet #1 or Drawing # PI -MOM -10002 of the P&ID's attached). n Hilmra Alaska, LU Temporary Flow Well: MPU M-12 Date: 04/30/2019 3. 2" hardline (approx. 20') from Methanol Header to the Oil & Gas Header routing fluids back to the Milne Central Processing Facility (reference sheet #3 & 4 or Drawing #'s PI -MOM -00007-002 & PI -MOM - 00004 -001). 4. 2" hardline (approx. 20') from Disposal Header to the F&L Production Header which connects to the Oil & Gas Header routing fluids back to the Milne Central Processing Facility (reference sheet #3 & 4 or Drawing #'s PI -MOM -00007-002 & PI -MOM -00004-001). Jet Pump Flow Direction The original plan was using Normal Flow jet pumps (power fluid down tubing and returns/production from the IA). One of the test lower completions was on well MPU F-107, where we encountered solids production which required a coil clean out of the lateral to return to production. The risk of depositing sand in the IA has lead us to opt for Reverse Flow jet pumps (power fluid down the IA and returns/production up the tubing). Both Normal Flow and Reverse Flow will be used on Moose Pad. For the M-10 and M-12 completions, these wells are configured for Reverse Flow and will have the SSV in the vertical run of the tree. Well Testing��> _-7tZV-, wcej� -,/Z . /7,, ,C-0We will obtain well estsbn these wells by month end. We are currently working thails on this with options including the following. - Primary Option: Have Moose Pad Facility commissioned and able to use the pad test separator. If the facility is not looking to be completed, we will contact ahead of time for discussion on approved test method. - Flow to a tank and measure the fluids produced. This will account for the oil/water and the gas will be allocated based on the solution GOR. - Strap on Ultrasonic meter for fluid measurement, shake out samples for WC and gas will be allocated based on the solution GOR. - Portable test separator. Attachments: 1. As -built Schematic 2. Wellhead /Tree Schematic 3. P&ID/Drawings H corp Alaska, LLC SCHEMATIC Orig. KB Elev.: 59.3'/GL Elev.: 25' TREE & WELLHEAD TD=16,792' (MD) / TD = 4,02Y(TVD) PBTD =16,787 (MD) / TD= 4,029(TVD) Milne Point Unit Well: MPU Moose Pad M-12 Last Completed: 3/5/19 PTD: 218-176 Tree Cameron 3 1/8" 5M Wellhead FMC 11" 5M TC -1A w/11" x 31/2" TC -II Top and Bottom Tubing Hanger with 3" CIW "H" BPV profile. Zea 3/8" NPT control lines. OPEN HOLE / CEMENT DETAIL 42" 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4" 1st stage 275 sx 12.Off Extenda, 485 sx 15.8# SwiftCEM 12-1/4" 2nd stage 277 sx 10.7!7 Perm L, 270 sx 15.8f1 SwiftCEM 8-1/2" Cementless Pre -Drilled Liner in 8-1/2" hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm I BPF 20"04" Conductor (insulated) 216/X-52/Weld N/A Surface 114' 1 N/A 9-5/8" Surface 40/L-80/TXP 8.679" Surface 4,885' 0.0758 7" Tieback 26/L-80/TXP 6.151" Surface 4,724' 0.0383 6-5/8" Liner (Pre -Drilled) 20/L-80/Hydril 563 5.924" 4,710' 16,792' 0.0355 TUBING DETAIL 3-1/2' Tubing 9.3/L-80/EUE 1 2.867" 1 Surf 1 4,745' 0.0087 WELL INCLINATION DETAIL KOP @ 400' Max Hale An = 70.00 deg. @ let Pump Max HOIe Angle = 74.00 deg. @ XN profile Max Hole Angle= 82.00 deg. @ Tubing tail Max Hole Angle = 93.5 deg. @ 16,020' MD IEWELRY DETAII No. Top MD Item Drift ID Upper Completion 1 29' Tubing Hanger (3-1/2" TC -II Top & Btm) w/ Blast Rings on hanger pup 2.867" 2 2,230' 3.5" GLM w/ 1.5" Shear Out Valve (2,000 psi) 2.867" 3 4,398' 3.5" Discharge Pressure Gauge Mandrel (Discharge Gauge) 2.875" 4 4,408' 3.5" XD Sliding Sleeve 2.813" Packing Bore (Set 9D JP on 4-2-19) 2.813" 5 4,416' 3.5" Gauge Mandrel w/ Y" Wire (Intake Gauge) 2.875" 6 4,438' 3.5" X Nipple (2.813" Packing Bore) 2.813" 7 4,485' 7" x 3.5" PHL Retrievable Packer (SOk Shear Release) 2.885" 8 4,542' 3.5" XN Nipple (2.813" Packing Bore; 2.75" No -Go) Min ID = 2.750" RHC -P set 2.750" 9 4,743' 1 3.5" WLEG (Btm @ 4,745') 2.867" Lower Completion 10 4,710' BOT SLZXP Liner Top Packer vv/BD Slips 7-5/8" x 9-5/8" (11.33' Tieback Sleeve) 6.170" 11 4,724' 7" Tieback Assy. (8.25" OD No -Go @ 4,713') 6.151" 12 4,731' 7" Hydril 563 L-80 x 6-5/8" Hydril 563 L-80 XO 5.924" 13 5,512' 1 6-5/8" Pre -Drilled Liner (72 holes per ft) w/ 1 straight -vane centralizer per 5.924" 14 16,792' 1 Shoe; Btm @ 16,792') GENERAL WELL INFO API: 50-029-23619-00-00 Drilled and Completed by Doyon 14-3-5-2019 Revised By: CJD 3/27/2019 Date: 4/01/19 Rig: Doyon 14 Well Number: MPM-12 Production 3-1/8" Manual valve i / 3-1/8" SSActuated valve Cre Manual valve —� 4-1/16" 4-1/16" Manual valve \Manual valve i Power Fluid 9 .r„, q - f 11"-5K Fig. Mm IN FMC O FMC O n 1.00 1.56 .92 1.56 1.56 0.72 2-1/16" R Manual valve o ® 2.25 44 #0 2-1/16" R I�/Manual valve 2.20 mr rgsl slm na %r arva°c x vMK vxrc m� M06' _ as sows Iw nz Px asw nst la aq x 1 aiv°ni rxwE . a xwa a,- sun d°o ugseu " dna , I I allasE nmxars l 1 •Ir I i i i 1 I I I ✓ "� I j I 1 I I 1 IIV� I I 1� 1 1 +__e ® 1 i I'% r-Issl(1 i Y m I a RM�-a 9 1 1 1 Y : 1 — I I 1 M➢A y i 1 I � I i i �. ia... 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MtlIW I I I I u[Yn�--r�-1VIIm� __ 0.JI xp Y:nw¢RFN _WY-IXO3I-WI b MASTER COPY 01/23=19 6:57:57 AM By:KathleenScham •, uu, a[ rtmwlm,'w, w.l o[ nwuv m n¢,a� xran m wxaw, axes a xirmn —.1corp Alaska, LLC � wmcnw mA�/n awn Nd:w u+M/�, NOOSE PI.O TI �N — -- ronin, mooucrrox rncun oMNe PWIN6 MID INS1 NTA CH p>tl1.U1 �c icy/i, PPCOIICIIRI XEMER A /JW .T NMER P _ id6IN1YN PW W OYE 1q T' w 11118019 R-NpY-WpJ]-W2 UB + e c u c m ;z VCA I p ma� A wcew wrNnm ' ' u.m Fa%�mA wmx xrmm PI-usa-mw- ro-am-oi_Ir-x / rc rows.-�r-x _ tot___7tatt. ____�m� 1' . E: Iti �. nc [ r�ft le�lkw. �• I I y I m A. ww-mr-w•-x / rc u.m.m-.r. `° "°A`�'"`R !, _ w ______ __ __ __ _ E_"_"-^�,� ,a, •`,,,e',rap � um a000e-am -usa-mw-am ire". m� � I mq W, �4 7 T � Racl �ir}rza- yl-rdlum-lXxrra — MASTER COPY 01/2312019 8:57:57 AM By:KalhleenSchanz Hilcozp Alaska, LLC Ole s sw.wmar mrwn,rcmwr N-,m-mw�-�.b.-.m-mw. "� TAN m r, MOOY n�mwu %idTICTd! FACMY A. us PI%NC NO IXSrR111AENiATm1 DIAGiIII = l L T AND Wlll'r U S Pm mw a..+uc ��nwnr cmnrxrrca mwm mro xo rormre %-uW-moo+-om W Schwartz, Guy L (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, April 4, 2019 4:13 PM To: Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL] RE: MPU M-10 (PTD 218-165) and M-12 (PTD 218-176) First Production Mr. Schwartz, The delayed startup of the Moose Pad Facility has been due to a series of events. Here are some of the pieces that have led to this and have had compounding effects on the total timeline as the sequencing had to be completed in a specific order for some of the construction: - Fabrication delays from our vendors on major components such as the e -House, Process Building, and some of the skid modules. Skilled labor availability (additional crews beyond the ones that had selected and used through the entire project) & housing for them. We have reached capacity of our camp (including bringing in additional camps) to bring on additional crews. Interconnecting instrument cable that didn't meet our spec. Rather than fight random signal interference in our instrument cable, we elected to pull 8,300' of cable and replace to ensure reliable operations. This has led to further delays in sequencing of the commissioning of the various compoenents to the overall process inside the facility. All in all the project has gone very well and a phenomenal amount has been accomplished to date, but the startup commissioning has pushed to ensure it is right. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 4, 2019 7:56 AM To: Taylor Wellman <twellman@hilcorp.com> Subject: RE: [EXTERNAL] RE: MPU M-10 (PTD 218-165) and M-12 (PTD 218-176) First Production I can write a note in sundry. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended � t recipient of this e-mail, please delete it, wither first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska.aov). From: Taylor Wellman <twellman@hilcoro.com> Sent: Wednesday, April 3, 2019 4:09 PM To: Schwartz, Guy L (DOA) <guy.schwartz(g@alaska.gov>; Roby, David S (DOA) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] RE: MPU M-10 (PTD 218-165) and M-12 (PTD 218-176) First Production Mr. Schwartz, The 10-403 submissions for temporary flow should be headed to or already at your office. I forgot to include a note on the 10-403 applications that the power fluid for the jet pumps in M-10 and M-12 would be staged in temporary upright tanks for the pump truck to pull from. These upright tanks would be filled by approximately 8 vac truck loads daily. If you would like me to include this in there I can amend and send over. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC —Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcoro.com From: Schwartz, Guy L (DOA) [ma ilto:guy.schwa rtz@alaska.govl Sent: Wednesday, April 3, 2019 10:59 AM To: Taylor Wellman <twellman@hilcorp.com>; Roby, David S (DOA) <dave.roby@alaska.Rov> Subject: [EXTERNAL] RE: MPU M-10 (PTD 218-165) and M-12 (PTD 218-176) First Production Taylor, AOGCC will require a sundry for each well for this temporary flowback configuration. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv schwarfz@alasko.aov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, April 2, 2019 12:38 PM To: Schwartz, Guy L (DOA) <guy.schwa rtz@alaska.gov>; Roby, David S (DOA) <dave.robv@alaska.gov> Subject: MPU M-10 (PTD 218-165) and M-12 (PTD 218-176) First Production Guy and Dave, Thanks for the phone conversation yesterday about bringing on the first wells at Moose Pad for production flow. The 2 wells would be MPU M-10 (PTD 218-165) and MPU M-12 (PTD 218-176). The original plan was to bring to commission the Moose Pad facility, bring these wells online to comingle with F&L fluids, separate out and dispose of the water before shipping the combined oil/gas to the Milne Central Plant. As time has progressed the Moose Pad Facility commissioning has slipped. We have adjusted plans to bring M-10 & M-12 online without flowing through the Moose Pad Facility. These wells (jet pump) would be brought online and flowed through a jumper into the pipeline to Milne Central Plant. Jet Pump Flow Direction Originally we had planned on using Normal Flowjet pumps (power fluid down tubing and returns/production from the IA). One of the test completions was MPU F-107, where we encountered solids production which required a coil clean out of the lateral to return to production. The risk of depositing sand in the IA has lead us to opt for Reverse Flow jet pumps (power fluid down the IA and returns/production up the tubing). Both Normal Flow and Reverse Flow will be used on Moose Pad. For the M-10 and M-12 completions, these wells are configured for Reverse Flow and will have the SSV in the vertical run of the tree. Updated tree schematics are included for both wells. Also note that I was incorrect when we talked yesterday and will stage a pump truck next to and connected via hardline to the section of the jet pump header directed to each well vs. engergizing the full header. SVS Testing These wells will not have functional pressure trips installed to automatically shut in the well at the SSV and will therefore be continuously manned to comply with 20AAC25.265.J.2. See the attached redlined P&ID for the wells flowpath. Also note that the pump truck will need to be continuously operated so in the case of an emergency, it can be shut down immediately. These are captured as part of an MOC for temporary flow conditions until the facility is commissioned and the temporary piping is removed. Well Testing We will obtain a well test on these wells by month end. We are currently working the details on this with options including the following. - Primary Option: Have Moose Pad Facility commissioned and able to use the pad test separator. If the facility is not looking to be completed, we will contact ahead of time for discussion on approved test method. - Flow to a tank and measure the fluids produced. This will account for the oil/water and the gas will be allocated based on the solution GOR. - Portable test separator. If you have any additional questions that come up please feel free to reach out and we can talk again. Thanks, Taylor Taylor Wellman Hilcorp Alaska, LLC — Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com eiCtrt1VtD STATE OF ALASKA I MAR 2 % 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil ❑✓ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20A C 25.105 20rwc 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: -I Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Hilcorp Alaska, LLC Abend.: 3/5/2019 218-176 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 February 5, 2019 50-029-23619-00-00 , 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 5037' FSL, 231' FEL, Sec 14, T13N, R9E, UM, AK • February 22, 2019 MPU M-12 Top of Productive Interval: 9. Ref Elevations: KB: 59.3' 17. Field / Pool(s): Milne Point Field 913' FNL, 2277' FWL, Sec 13, T13N, R9E, UM, AK GL: 25' BF: 25' Schrader Bluff Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2012' FNL, 1029' FWL, Sec 20, T13N, RIDE, UM, AK 16,787' MD / 4,028' TVD ADL025514, ADL388235, ADL025615 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 533933 y- 6027889 Zone- 4 11. Total Depth MD/TVD: 16,792' MD / 4,029' TVD 19. DNR Approval Number: LONS 16-008 TPI: x- 536444 y- 6027230 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD1TVD: Total Depth: x- 545730 y- 6020904 Zone- 4 N/A 2,186' MD / 2,099' TVD 5. Directional or Inclination Survey: Yes ✓ (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 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 ROP/ABG/DGR/EWR/ADR 2"/5" MD / PB1 / PB2 ABG/DGR/EWR/ADR 2"/5" TVD / PBI/ PB2 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH ND AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM HOLE SIZE 20" 216# X-52 Surface 114' Surface 114' 42" 270 ft3 9-5/8" 40# L-80 Surface 4,885' Surface 3,945' 12-1/4" Stg 1 L - 275 sx / T - 485 sx Stg 2 L - 277 sx / T - 270 sx 136 bbls 7" 26# L-80 Surface 4,724' Surface 3,936' Tieback Tieback Assy. 6-5/8" 20# L-80 4,710' 16,792' 3,934' 4,029' 8-1/2" Cementless PreDrilled Liner 24. Open to production or injection? Yes ❑✓ No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Pertd): 6-5/8" PreDrilled Liner COMPLETION 5,512' - 16,749' MD / 3,959'- 4,026' TVD DA -PE 0 72 holes/ft, Run on 3/1/19 cl ` VEARED 3-1/2" 4,745' 4,485' MD / 3,879' ND 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No ❑✓ ilf Per 20 AAC 25.283 (i)(2) attach electronic and printed information INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): TBD Jet Pump Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity, - API (corr): Press. 24 -Hour Rate 0► Form 1u0-0}07BR ��9� 2017 /�� � „n, q_(9_1 _ (� `i Obi TINUED ON PAGE 2 RBDMS MARL 8 ZO� Submit ORIGINIAL only' 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 2,186' 2,099' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 5,512' SB OA 3,959' information, including reports, per 20 AAC 25.071. SV5 1,373' 1,339' SV1 2,007' 1,933' Ugnu LA3 3,360' 3,186' SB NA 4,083' 3,709' SB OA 4,523' 3,891' Formation at total depth: Schrader Bluff 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report. 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Dri ing Mana r Contact Email: cdinger@hilggM.com Authorized Contact Phone: 777-8389 Signature: Date: '3 Z� 2-Y/I INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only K Hilcorp Ataska, LLC Orig. KB Elev.: 59.3'/ GL Elev.: 25' RB—THF:2 .98 n 14 I 20' i &58"E5 Oenviter @ ' ir: 2.064 a A 2 � 3.1/?., 3 4 11 12 s — 9 5/8' SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU Moose Pad M-12 Last Completed: 3/5/19 PTD: 218-176 Tree Cameron 31/8" 5M Wellhead FMC 11" SM TC -3A w/11" x 3 1/2" TC -II Top and Bottom Tubing 12-1/4" 2nd stage Hanger with 3" CIW "H" BPV profile. Zea 3/8" NPT control lines. OPEN HOLE / CEMENT DETAIL 42" 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4" 1st stage 275 sx 12.0# Extenda, 485 sx 15.8# SwiftCEM 12-1/4" 2nd stage 277 sx 10.7# Perm L, 270 sx 15.8#SwiftCEM 8-1/2" Cementless Pre -Drilled Liner in 8-1/2" hole CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x34" Conductor (insulated) 216/X-52/Weld N/A ce 114' N/A 9-5/8" Surface 40/L-80/TXP 8.679" ce 4,885' 0.0758 7" Tieback 26/ L-80 / TXP 6.151" ce E4,710' 4,724' 0.0383 6-5/8" Liner (Pre -Drilled) 20/L-80/Hydril 563 5.924" 16,792' 0.0355 • u�1 D1 • • �� • 13 • • • iV6� • • 1. 8-1/2• GS/8" • •. OD Shoe @ : • ` v Hale 16,797 14 11943 TD=16,792' (MD) / TD = 4,02Y(TVD) PBTD=16,787'(MID)/TD=4,028'(TVD) I �i- TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 1 2.867" Surf 4,745' 0.0087 WELL INCLINATION DETAIL KOP @ 400' Max Hale Angle = 70.00 deg. @ Jet Pump Max Hole Angle = 74.00 deg. @ XN profile Max Hole Angle = 82.00 deg. @ Tubing tail Max Hole Angle = 93.5 deg. @ 16,020' MD JEWELRY DETAIL No. Top MD Item Drift ID Upper Completion 1 29' Tubing Hanger (3-1/2" TC -II Top & Btm) w/ Blast Rings on hanger pup 2.867" 2 2,230' 3.5" GLM w/ 1.5" Shear Out Valve (2,000 psi) 2.867" 3 4,398' 3.5" Discharge Pressure Gauge Mandrel (Discharge Gauge) 2.875" 4 4,408' 3.5" XD Sliding Sleeve 2.813" Packing Bore; 3,848' TVD; 70 deg Hole Angle 2.813" 5 4,416' 3.5" Gauge Mandrel w/ Y" Wire (Intake Gauge) 2.875" 6 4,438' 3.5" X Nipple (2.813" Packing Bore) 2.813" 7 4,485' 7" x 3.5" PHL Retrievable Packer (501k Shear Release) 2.885" 8 4,542' 3.5" XN Nipple (2.813" Packing Bore; 2.75" No -Go) Min ID = 2.750" RHC -P set 2.750" 9 4,743' 3.5" WLEG (Btm @ 4,745') 2.867" Lower Completion 30 4,710' BOT SLZXP Liner Top Packer w/BD Slips 7-5/8" x 9-5/8" (11.33'Tieback Sleeve) 6.170' 11 4,724' 7" Tieback Assy. (8.25" OD No -Go @ 4,713') 6.151" 12 4,731' 7" Hydril 563 L-80 x 6-5/8" Hydril 563 L-80 XO 5.924" 13 5,512' 6-5/8" Pre -Drilled Liner (72 holes per ft) w/ 1 straight -vane centralizer per jt 5.924" 14 16,792' Shoe; Btm @ 16,792') - GENERAL WELL INFO API: 50-029-23619-00-00 Drilled and Completed by Doyon 14-3-5-2019 Revised By: CID 3/27/2019 nHilcorp Energy Company Composite Report Well Name: MP M-12 Field: Milne Point Unit County/State: , Alaska i (LAT/LONG): ovation (RKB): API #: Spud Date: 2/5/2019 Job Name: 18143120 MPU M-12 Drilling Contractor Doyon 14 AFE #: AFE $: Activity Dale 2/2/2019 See M-10 completion report for details.;PJSM. Skid the rig floor into moving position.;PJSM. Jack the rig up and move the rig off of well M-10. Layout mats around well M-12. 2/3/2019 Continue to set rig mats around well M-12.;Move the rig over and center the rig on well M-12.;Level and shim the rig.;Lower the stairs and install the handrails. Skid the rig floor into drilling position. SimOps: Repair bypass line on the mud system above pit #2.;Hook up steam, air and water to the rig floor. RU the pump, cement and bleeder lines. Spot the rock washer and cuttings tank. Spot the mud, MWD, and Geo shacks. Spot the fuel and lunch trailers. Orientate the diverter annular and torque the bolts. Welder repaired the toe board in the dernck.;Load, strap, tally and record serial # on 5" NC -50 DP. Repair shaker #3 seal. Prep the shakers and rock washer for drilling surface. NU sections of diverter pipe. Inspect and clean the top drive brakes. Work on rig acceptance checklist. Rebuild pump #1.;Continue to process 5" OP. Continue to NU diverter pipe. Continue to work on rig acceptance checklist. 2/4/2019 Continue to process 5" DP. Continue to NU diverter pipe. Diverter length= 487'. Install the bell nipple. Spot the fresh water tank and pump house. Cleanup and RU the rig Floor. Continue to work on rig acceptance checklist.;Mobilize the mouse hole to the rig floor and place in the rotary table. PU and MU stands of 5" NC50 DP. Rig accepted at 16:00 hours.;Conduct diverter test. Knife valve closed in 12 seconds and the annular closed in 28 seconds. The states right to witness was waived bv AOGCC inspector Lou Laubenstein via email on 2/04/19 at 16:12 hours.;Accumulator Test: System pressure = 3000 psi Pressure after closure = 1850 psi 200 psi attained in 40 seconds Full pressure attained in 157 seconds Nitrogen Bottles - 6 at 2000 psi.;Perform rig evacuation drill and held an AAR.;Continue to PU and MU stands of 5" NC50 DP (55 stands).;PU and MU stands of 5" NC50 HWDP (5 stands+ 1 jar stand) ;Slip and cut 90' It wraps) of drilling Iine.;Changeout the saver sub.;PJSM. PU and MU 12-1/4" conductor cleanout assembly. 2/542019 RIH to tag at 111'. Fill the conductor with water and check for leaks (good). PT the mud line to 3500 psi (good lest).;Drill 12-1/4" surface hole with water from 111' to 121' at 350 GPM = 490 psi, 40 RPM =1 K ft -lbs torque, WOB = 5K. Displace the well to 8.8 ppg spud mud. Continue to drill 12-1/4" surface hole with water from 121' to 221' at 450 GPM = 560 psi, 40 RPM= 5K ft -lbs torque, WOB = 5-13K.;BROOH to the conductor at 350 GPM = 280 psi, 30 RPM. RIH with no pumps to check for fill and tag at 221'. Pump out of hole to the conductor and circulate the well clean.;Lay down mill tooth bit. MU BHA #1: 12-1/4" Kymera bit, 1.5° bent motor, LWD and MWD. Carry scribe for offset;Upload MWD tools. SimOps: Service the draw works.;Continue to MU BHA#1: NM flex collars, crossover and HW DP. PH to tag at 221'.;Drill 12-114" surface hole from 221' to 672' (671' TVD), 451' with AROP of 90.2 FPH. 464 GPM = 1300 psi, 60 RPM = 2-3K ft -lbs torque, WOB = 7-1 1 K, MW = 9.1 ppg, Vis =189, ECD = 9.8 ppg, Max gas = 13 units PU = 75K, SO = 80K, ROT = 80K. Back ream 31' prior to connection.;Drill 12-1/4" surface hole from 672' to 1272'(1 148'TVD), 600' with AROP of 100 FPH. 472 GPM = 1260 psi, 60 RPM= 24K ft -lbs torque, WOB = 5 8K, MW = 9.1 ppg, Vis = 172, ECD = 9.9 ppg, Max gas= 17 units PU = 90K, SO= 90K, ROT= 90K. Back ream 31' prior to connection.;Drill 12-1/4" surface hole from 1272' to 2093'(2013! TVD), 821' with AROP of 136.8 FPH. 460 GPM = 1360 psi, 60 RPM = 2-3K ft -lbs torque, WOB = 1-10K, MW = 9.4 ppg, Vis = 151, ECD = 10.4 ppg, Max gas= 34 units PU = 108K, SO= 98K, ROT= 108K. Back ream 31' prior to connection.;Last survey at 2019.53' MD, 1943.66 TVD, 20.03° Inc, 73.60" Az. Distance to Well Plan #8 = 8.95'(7.99' high and 4.05' left). Base of the Permafrost at 1974' (1901' TVD).;Hauled 680 bbis H2O from L - Pad lake for total = 1075 bbls Hauled 0 bbls heated H2O from G&I = 0 Hauled 635 bbls cuttings/liquids to MPU G&I for total = 635 bbls 2/6/2019 Drill 12-1/4" surface hole from 2093' to 2935' 2799' TVD 842' with AROP of 140.3 FPH. 522 GPM = 1610 psi, 80 RPM= 4K ft -lbs torque, WOB = 8-10K, MW = 9.2+ ppg, Vis = 122, ECD = 10.2 ppg, Max gas = 14 units PU = 132K, SO = 110K, ROT = 120K. Back ream 31' prior to connection.;Pump 20 hi -vis sweep at 2900' with 100% increase in cutting over the shakers. Sweep came back on calculated strokes.;Drill 12-1/4" surface hole from 2935'to 359U (337(Y TVD), 655' with AROP of 109.2 FPH. 570 GPM = 1910 psi, 80 RPM = 5-6K ft -lbs torque, WOB = 9-14K, MW = 9.1 ppg, Vis = 129, ECD = 10.0 ppg, Max gas = 16 units PU = 150K, SO = 120K, ROT = 134K. Back ream 31' prior to connection.;Drill 12-1/4" surface hole from 3590' to 4020' (3675' TVD), 430' with AROP of 71.7 FPH. 567 GPM = 1950 psi, 80 RPM = 6-9K ft -lbs torque, WOB = 10K, MW = 9.1 ppg, Vis = 121, ECD = 9.8 ppg, Max gas = 5 units PU = 155K, SO = 119K, ROT = 136K. Back ream 31' prior to connection.;DHII 12-1/4" surface hole from 4020' to 4630' (3915' TVD), 610' with AROP of 101.7 FPH. 571 GPM = 2060 psi, 80 RPM = 8K ft -lbs torque, WOB = 2-4K, MW = 9.2+ ppg, Vis = 134, ECD = 10.1 ppg, Max gas = 41 units PU = 155K, SO = 113K, ROT = 125K. Back ream 31' prior to connection.;Pump 20 hi -vis sweep at 4346' with 50% increase in cutting over the shakers. Sweep came back on calculated strokes.;Last survey at 4579.68' MD, 3899.83' TVD, 75.06° Inc, 121.99° Az. Distance to Well Plan #8 = 5.59' (1.99' high and 5.22' righl).;Hauled 1270 bbls H2O from L -Pad lake for total = 2345 bbls Hauled 0 bbls heated H2O from G&I = 0 Hauled 1446 bbls cuttings/liquids to MPU G&I for total = 2081 bbis S 1v71 To 2/7/2019 Drill ahead F/ 4630'T/5107'. 472'@ 72 FPH Average 575 GPM, 20 K WOB, 50 RPM, Drilled into OA 1 70' TVD+/- early. Looks like we faulted at 4450' (fault A). While moving down section and building inclination with 5-6`/100ft we crossed two sub seismic faults.: Fault B —14' DTE (4 593' MD/3 844' TVD) moved the bit from mid to upper OA lobe and Fault C —5' DTE (4,709' MD/3,927' TVD) moved the well path from lower to upper OA -2. We crossed into OA -3 at 4,737' MD/3,872' TVD and exited the same OA -3 top at 4,934' MD/3,877' TVD. We stopped drilling at 5,107'.;Pump high vis sweep around at 575 GPM until clean. 1.5 BTM up. ECDS 10.2, MW 9.3, Vis 111. Monitor well, static.;BROOH at 5 min per stand from 5107' to 2548' at 500 GPM = 1470 psi and 60 RPM= 9-1 OK ft -lbs torque. Take 4 half stand surveys on the trip out as per DO check higher DL.;CBU at 5 GPM = 1280 psi while slowly BROOH from 2548' to 2453' at 60 RPM = 4K ft -lbs torque.;Confinue to BROOH at 10 min per stand from 2453' to 1980' at 500 GPM = 1240 psi and 60 RPM = 4K ft -lbs lorque.;Blow down the top drive. TOOH on elevators from 1980' to 750'. Correct displacement.;Obsewe the well for flow and the well is static. TOOH standing back 5" HWDP from 750' to 187'. Lay down 3 NM flex collars from 18T to 98'.;Download MWD data.;Lay down remaining BHA components from 99 to surface: LWD, MWD, motor, bit sleeve and Kymera bit. Bit grade: 2-1-BT-C-E-1-CT-TD.;Clean and clear the floor.;Mobilize casing running equipment to the rig floor. RU Volant tool, bail extensions, 9-5/8" elevators and air slips. Loses= 3 BPH while circulating over the top.;PJSM. PU and MU float shoe, 1 joint of 9-5/8" casing and float collar. Bakerl-ok each connection.;Last survey at 5107' MD, 3927.91' TVD, 93.40° Inc, 126.65° Az. Distance to Well Plan #8 = 45.84'(43.2' high and 15.2' right). 10 hard spots were drilled in the surface, for a total of 63' (1.3%).;Hauled 1575 bbls H2O from L -Pad lake for total= 3920 bbls Hauled 0 bbls heated H2O from G&I = 0 Hauled 810 bbls cuffings/liquids to MPU G&I for total = 2891 bbls 2/8/2019 Check the floats (good), fill the casing with mud and drop the bypass baffle. PU and MU the baffle adapter.;RIH with 9-5/8", 40#, L-80, TXP casing from 123'to n�C' 2903' filling on the fly and topping off every 10 joints.. P/U ESIPC as per Tally and HES inspect same. GOOD. Baker lock both connections. Install centralizers per tally (torqued to 20960 ft -lbs) ;Circulate & condition mud. CBU x2 cutting mud weight from 9.8 to 9.5 ppg.;Continue to RIH with 9-5/8", 40#, L-80, TXP a� l _O�� casing from 2903' to hard tag 4833' filling on the fly and lopping off every 10 joints.;Stage the pumps up to 4 BPM = 280 psi and work through the tight C5 I T7 spot.;Conbnue to RIH with 9-5/8", 40#, L-80, TXP casing from 4833' to885' 4(PU = 225K and SO = 125K). Phase 2 weather conditions at 21:00 hours.;Circulate and condition the mu for the cement job at 6 M = 330 psi, 5 KPM = 20K ft -lbs torque and reciprocating 20'.;PJSM with rig crew, HES C / cementers, MI Swaco, and Peak/CH2 truck drivers. Blow down the top drive and RU the cement line to the cement swivel. SimOps: OR load mud from the pits.;Phase 3 weather conditions. Circulate and condition the mud for the cementjob at 3 BPM = 120 psi and reciprocating 20'.;Hauled 580 bbls H2O from L-Pd lake for total = 4500 bbls Hauled 380 bbls heated H2O from G&I = 380 Wait on weather due to Phase 3 conditions. Circ & condition at 3 BPM while working pipe 20' (PU =225K & SO = 125K) Work on keeping walkways clear & 2/92019 hazard hunts.;Phase reduced to phase 1 after roads cleared. Work on HES air compressor that shut down in phase 3. Bad fuel pump. Could not get it working. Find a portable one from delta leasing on Moose pad. Prep for cmt job. PJSM with all hands, talk about all hazards and the upcoming job.;Line up to HES & pump 5 bbl water. Test lines to 1000 psi/ 4000 psi. Good. Line up, Mix and pump 60 bbl Clean spacer with red die and poly flake in the first 10 bbl. Drop bypass plug. Line up and pump 115.2 bbl 12# Lead Cmt 275 SX Mix & pump 99.2 bbl 15.8 Tail cmt. 485 SX):Drop closing Pluq HES pump 20 bbl H2O Line up to rig pumps & displace with 174 bbl (1727 stks) Pump high vis spacer 30 bbl ( 2024 silks total) Displace with 3345 stks total & bump plug at 3 bpm. Final lift 860 PSI. Bump with 1000 psi & hold for 5 min. Bleed off floats.;Bled back 1.7 bbl and floats held CIP at 14:39 Start packer setting procedure as per HES. Bring pressure up at .25 BPM looking for pressure drop Saw pressure drop at 36 silks at 2070 psi. Bled to 1890 Follow setting procedure pressuring up 100 psi at a time. 2100/2080 2200/2080 2400/ Pressure.;2400/ Pressure Dropped to 680 psi. 45 stks total. 4.5 bbl away. No returns at this point. Start pump & bring to 6 bpm attempting to establish circ. Pumping away fluid at 2200 psi pump away 20 bbl total. Shut down to consult HES town engineer and while talking well started flowing.;Establish circ at 6 bpm & saw polly flake in returns. Looks like mud push. Circ 100 bbl & had to slow due to very thick returns & over run drag chain. Work pumps as necessary to circ out spacer and cmt. Saw good cmt to surface. 30 bbl. Take mud back to pits and continue to stage up pumps to 3-4.;Take mud back to pits & continue to stage up pumps to 3-4 bpm . Had to swap from dumping to the rock & back to the pits & drag chain issues. Gained 1300 psi increase on pump pressure on shut down. Continue to circ and saw pressure drop back down to 450 psi with gain in string wt and flow out.;Rotate and reciprocate at 10 RPM = 20K ft -lbs until the last 10 bbls of the displaceme.nt.;Circ & condition while prepping for second stage cmt lob. PJSM for second stage.;Break off volant & clean dies. Reset dies for second stage. Circ while waiting on HES to batch up spacer.;Start second stage cmt job. Pump 60 bbl 1 O.O ppg spacer with red dye & poly flake at 3.5 BPM =160 psi. Mix & pump 10.7 ppg lead at 5 BPM = 600 psi. At 220 bbls away good cement at surface. Mix & pump 55 bbls of 15.8 ppg tail at 3 BPM = 250 psi. Place ES cementer closing plug into the casing.;HES pump 20 bbls fresh water. Swap to the rig & start displacement. At 30 bbls away the flow line plugged off, open the two 4" valves in the cellar and suck out the returns with a super sucker. At 135 bbls way bumped the closing plug. Pressured up to 1600 psi & the ES cementer closed.;Cement in place at 23:05 hours.;Break off the cement line, check for flow and no flow. Blow down the cement line. Fill the stack with black water. Were able to get black water down the flow line. Disconnect the knife valve & function the diverter bag 3 times. Flush the stack through the 4" valves in the cellar.;ND the diverter line from the diverter tee. Split the diverter stack. Suck mud out of the casing.;PU 100K over, set the casing slips and SO to engage the slips. PU 8K and the welder rough cut the casing. SimOps: Cleaning pits.;Break out and lay down the two pup joints and cut joint (length = 22.9'). SimOps: Cleaning pits.;Pull the riser. ND the bell nipple, knife valve, diverter tee and diverter. SimOps: Cleaning pits. 2/10/2019 Cut an additional 2-5/8" off the casing and dress the stump.;PJSM. NU the FMC wellhead. PT seal to 250 psi for 5 minutes and 2400 psi for 15 minutes (good tests).;ND and remove the bell nipple. NU the MPD equipment.;NU the BOP stack. NU flange to the IA valve. Hookup the Koomey lines to the BOP stack. NU the kill llne.;PJSM. Orient RCD and torque bolts. RU MPD hard lines. Install MPD riser.;RD the 9-5/8" casing elevators, Volant tool and bail extensions. Clear the floor of casing running equipment.;RU BOPE testing equipment. Put new seal on the test plug. Install the test plug.;Flood the choke manifold and BOP stack with fresh water. Purge the air from the system. Attempt to shell test the stack but the test plug was leaking. Pull the test plug, inspect the seal and the seal is in good condition.;Reinstall and use the top drive to seat the test plug. Shell test the BOP stack (good test).;Conduct initial BOPE test to 250/3000 psi: Lower pipe rams (2-718!'x 5" VBR's) with 5" lest joint, upper pipe rams (4-12" x7" VBR's) with 5" test joint, annular with 5" test joint, accumulator drawdown test and test gas alarms. The states right to witness was waived byAOGCC inspector Bob Noble.;Tests: 1.Annular with 5"test joint, 3" Demco kill, upper IBOP, choke valves 1, 12, 13 & 14 (passed)2.UPR with 5" test joint, HCR kill, lower IBOP, choke valves 9 & 11 (passed)3.Manual kill, choke valves 5, 8 & 10 (passed) 4.5" dart valve, choke valves 4, 6 & 7 (passed);5.5" FOSV, choke valve 2 (passed) 6.HCR choke (passed) 7. Manual choke (passed).;Hauled 290 bbls H2O from L -Pad lake for total = 4960 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 1063 bbls cuttings/liquids to MPU G&I for total = 5668 bbls �k i C 2/11/2019 Continue to conduct initial BOPE test to 250/3000 psi with 5" test joint. The states right to witness was waived by AOGCC inspector Bob Noble via email on 2/08/19 at 16:39 hours.;Tests: B.LPR with 5" test joint (passed)Accumulator Test:System pressure= 3000 psi Pressure after closure = 1800 psi 200 psi attained in 44 seconds Full pressure attained in 175 seconds Nitrogen Bottles - 6 at 2008 psi.;Phase 3 weather conditions. SimOps: General light housekeeping around the rig.;Continue to test BOPE to 250/3000 psi.Tests: 9.Blind rams, choke valve 3 (passed IO.Hydraulic super choke (passed) 11.Manual adjustable choke (passed).;PJSM. Pull the MPD riser and install the MPD test plug. Flood the MPD lines with fresh water. PT MPD equipment to 250/1500 psi (good test).;Pull MPD test plug and reinstall MPD riser. RD ROPE testing equipment. Drain the BOP stack. Pull the test plug and install the wear ring.;Mobilize tricone bit, float sub and UBHO sub to the rig floor.;PU and MU cleanout assembly. 8-1/2" VM -3 tricone bit (rerun 2), motor, float sub, UBHO sub, three NM flex collars, 2 stands 5" HWDP, Hydra-Jar/HWDP stand and 3 stands 5" HWDP to 685'.;RIH with cleanout assembly on 5" DP from the pipe shed from 689 to 2051' (PU = 110K and SO = 90K).;Fill the DP and CBU at 450 GPM = 940 psi. At bottoms thick mud coming back. Circulate and cleanup the well at 4 BPM = 280 psi, 40 RPM = 2K fit - lbs torque reciprocating 60' (ROT = 95K).;Wash from 2051' to hard tag at 2063'. Drill cement, closing plug and ES cementer from 2063' to 2069' at 450 GPM = 900 psi, 40 RPM = 3K ft -lbs torque and WOB = 5K. Continue to RIH to 2111'. Work through the ES cementer several times with rotary.;Turn off the rotary and slide through the ES cementer without any issues. Blow down the lop drive.;Continue to RIH with cleanout assembly on 5" DP from the pipe shed from 2111' to 4725' (PU = 11 OK and SO= 90K).;Wash down from 4725' to tag at 4758' at 450 GPM 850 psi.;Hauled 155 bbls H2O from L -Pad lake for total= 5115 bola Hauled 0 bbls heated H2O from G&I = 380 Hauled 108 bbls cultings/liquids to MPU G&I for total = 5776 bbls ' ' C'SO xl. O 2/12/2019 CBU at 450 GPM = 850 psi ;Lay down 1 joint to 4753'. RU the head pin and cement line. RU testing equipment.:PT the 9-5/8" casino to 2500 psi for 30 minutes. It took 3.8 bbls to pressure up and 3.8 bbls bled back.;Blow down and RD testing equipment.;Drill cement from 4758'to 4765'. Drill baffle adapter from 4765to 4766'. Drill float collar from 4807' to 4808'. Drill shoe from 4887' to 4889' pumping 450 GPM = 1000 psi, 40 RPM = 9K ft -lbs torque. WOB-- t OK. Cleanout rat hole to 4914'.;CBU 450 GPM = 1000 psi, making several passes thru 9-5/8" shoe at 4889, no issues, pull into 9-5/8" casing at 4889. Blow down the top drive. Observe the well for flew and the well is static.;RU Pollard E -line and Gyro. Install pump in sub, MU tools and packoff.;RIH to 15U and calibrate tools. RIH to 450' and calibrate tool. Continue to RIH making multiple stops to calibrate tools to 4233'.;Slowly stage up the mud pump to 6 BPM = 700 psi, pump the gyro from /1111� 4233'to seat at 4850' and obtain readings. POOH from 4850'to surface.;RD Pollard E-Iine.;PJSM. TOOH with cleanout assembly from 4882'to 685'.;Obsewe YY, the well for flow for 5 minutes and the well is static. Lay down 15 joints of 5" HWDP and stand back jar/HWDP stand.;Stand back 1 stand of NM flex collars. Lay down UBHO sub, float sub, motor and 8-1/2" tricone bit.;Clean and clear the floor.;Reorient the MPD riser so that the hole fill is not hitting the lifting eye. Jet the flow line with the cement hose to clear debris that was restricting flow.;PJSM. PU and MU 15 stands (45 joints) of 5" DP in the mouse hole.;Hauled 190 bbls H2O from L -Pad lake for total = 5305 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 221 bbls cuttings/liquids to MPU G&I for total = 5997 bbls 211312019 PU and MU remainingl8 stands (54 joints) of 5" DP in the mouse hole for total of 33 stds. Monitor well with trip tank, static.;PJSM, load tools to rig floor, M/U BHA #3:8-1/2" PDC bit, Geo -Pilot, MWD w/ ADR, DGR, PWD & directional to 86', Test & initialize MWD tools, M/U UBHO sub.;RIH w/ drill collars, HWDP and jars from the derrick to 274'. Pressure test Geo -Span lines to 2500 PSI. Shallow pulse test MWD tools w/ 500 GPM, 700 PSI - good. BD TD.;PJSM. Single in the hole with 5" NC -50 DP from 274' to 2155'. Fill DP. Break-in Geo -Pilot seals at 10, 20, 30, 40, 50 & 60 RPM = 2.3K ft -lbs torque, 500 GPM = 850 PSI and function test Geo -Pilot. Continue to single in with 5" DP to 4758'. Note: slow passing ESC @ 2064' with no issues.;CBU at 9 BPM = 850 psi ;PJSM. Install 5" FOSV and DP pup. Hang the blocks. Slip and cut 1600' of drilling line spooling on new drilling line. Calibrate block height.;Lay down the DP pup joint and FOSV. TIH from 4758'to 4882'.;RU AK E -line with pump in sub and grease head. Re -head the E -line. MU gyro tool string.;RIH with gyro and log from 2900'to 4233'. Pump down the gyro at 6 BPM = 610 psi. Continue to log from 4233' to the UBHO sub at 4793'. POOH.;RD AK E-Iine.;Processing gyro data. 21' 4/2019 ish processing gyro data, RD AK E -line and lay down pump in sub.;MU the top drive and wash down at 2 BPM = 120 psi from 4882'to 4896'. Increase pumps to 50 GPM = 1240 psi, 50 RPM= 8K ft -lbs torque and wash/ream from 4896' to 4914' (PU = 155K, SO= 103K & ROT = 125K).;Drill 8-1/2" production hole from 14' to 4920'. Sidetrack from 4920' to 4934' at 450 GPM = 1240 psi, 60 RPM = 7-8K ft -lbs torque & WOB = 3-4K. Departure from old wellbore = 2,3S* inclination.;With 20' new formation drilled, pump 30 bbl hi vis spacer and displace the well to new 9.2 ppg FloPro mud at 450 GPM = 1240 psi, 65 RPM = 8K ft - lbs torque. Dump spud mud to rock washer. TOOH 1 stand parking in 9-5/8" casing at 4849'. Blow down the top drive.;MU head pin, valve and cement hose to / perform FIT. Flood and purge the lines. Close UPR, start applying pressure down DP and kill line, chart recorder clockwork mechanism failed, bleed off pressure, open UPR. Expedite spare chart recorder from L-pad.;While waiting on and getting spare chart recorder ready. PJSM. Break out single, RU and stab MPD bearing on single as per Beyond rep.;MU head pin, valve and cement hose. Flood and purge the lines. Close UPR and perform FIT to 12.0 ppg EMW usina9.2 ppg existing MW Pump 1.3 bbls down DP and kill line apply 575 psi (good test) Bleed off pressure 1.2 bola bled back, open UPR. Remove head pin and blow down ljnes.;PJSM. MU single with MPD bearing installed, pull MPD riser, install bearing in RCD, divert flow thru MPD equipment and obtain SPRs.;Wash down 2 BPM =120 psi from 4850' to 4890'. Increase pump to 450 GPM = 1040 psi, 60 RPM = 8K ft -lbs torque and wash/ream from 4890' to �1.46 J'j 4934'.;Drill 8-1/2" production hole from 4934' to 5137' (3964' TVD), 203' with AROP of 29 FPH. 464 GPM =1210 psi, 60-80 RPM = 5-9K ft -lbs torque, WOB = 10-15K, MW= 9.3+ ppg, Vis = 41, ECD = 10.17 ppg, Max gas = 57 units PU = 153K, SO= 87K, ROT= 112K.;Drill 8-1/2" production hole from 513T to 5564' `rJ (3966' TVD), 427' with AROP of 71.2 FPH. 455 GPM = 1240 psi, 120 RPM= 5-11 K ft-Ibs torque, WOB = 8K, MW = 9.4 ppg, Vis = 42, ECD = 10.66 ppg, Max gas= 85 units PU = 153K, SO = 80K, ROT= 114K.;Last survey at 5448.47' MD, 3973.96' TVD, 91.81 ° Inc, 125.06° Az. Distance to Well Plan #8 = 63.01' (12.25' high and 61.81' right). 5 concretions have been drilled so far this lateral for a total footage of 42' (6.2% of the lateral). 1 fault at 4932' (3958' TVD) has been observed so far this Iat.;Hauled 230 bbls H2O from L -Pad lake for total = 5595 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 667 bola cuttings/liquids to MPU G&I for total = 6699 bbls 2/15/2019 Drill 8-1/2" production hole from 5564' to 6007' (3967' TVD), 443' with AROP of 73.8 FPH. 480 GPM = 1400 psi, 120 RPM= 10K ft-Ibs torque, WOB = 3-6K, MW = 9.3 ppg, Vis = 42, ECD = 10.57 ppg, Max gas= 110 units PU = 160K, SO= 75K, ROT= 115K.;Drill 8-1/2' production hole from 6007' to 6376'(3978' TVD), 369' with AROP of 61.5 FPH. 481 GPM = 1330 psi, 120 RPM= 12Kft-lbs torque, WOB = 8-15K, MW = 9.2 ppg, Vis = 41, ECD = 10.44 ppg, Max gas = 87 units PU = 165K, SO= 75K, ROT= 116K.;Pumped 30 bbl hi vis sweep at 6090', sweep back on time with 100% increase at shakers.;Dnll 8-1/2" production hole from 6376' to 6960' (3968' TVD), 584' with AROP of 97.3 FPH. 474 GPM = 1440 psi, 120 RPM= 13K ft-lbstorque, WOB = 5-10K, MW = 9.2 ppg, Vis = 43, ECD = 10.44 ppg, Max gas= 88 units PU = 160K, SO= 70K, ROT= 114K.;Pumped 30 bbl hi vis sweep at 6662', sweep back on time with 150% increase at shakem.;Drill 8-1/2" production hole from 6969to 7329 (3959' TVD), 369 with AROP of 61.5 FPH. 500 GPM = 1620 psi, 120 RPM= 15K ft -lbs torque, WOB =5-10K, MW =9.3 ppg, Vis = 44, ECD = 10.82 ppg, Max gas = 131 units PU = 170K, SO = 50K, ROT= 112K.;Performing half stand surveys due to close approach with well L-20. Pumped 30 bbl hi vis sweep at 7236, sweep back on time with 50% increase at shakers. Currently drilling in the OA -1 sand.;Last survey at 7257.54' MD, 3960.91' TVD, 90.44° Inc, 125.30° Az. Distance to Well Plan #8 = 34.83' (18.33' high and 29.62' right). 20 concretions have been drilled so far this lateral for a total footage of 148'(6.3% of the Iateral).;Hauled 610 bbls H2O from L -Pad lake for total= 6205 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 710 bbls cuttings/liquids to MPU G&I for total = 7409 bbls 2/16/2019 Drill 8-1/2" production hole from 7329'to 7773' (3964' TVD), 444' with AROP of 74 FPH. 494 GPM =1620 psi, 120 RPM = 13-16K ft-lbs torque, WOB =10- 15K, MW = 9.3 ppg, Ys = 48, ECD = 10.86 ppg, Max gas = 135 unit PU = 185K, SO = 50K, ROT = 111 K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 7709' and sweep back on time with 25% increase at shakers. At 7490', changed out the jet in geo span from 24 to 28;Drill 8-1/2" production hole from 7773' to 8160' (3964' TVD), 387' wfth AROP of 64.5 FPH. 500 GPM = 1620 psi, 120 RPM = 15K ft-lbs torque, WOB = 5-15K, MW = 9.2 ppg, Vis = 45, ECD = 10.78 ppg, Max gas = 126 units PU = 180K, SO = 40K, ROT = 114K. Back reaming 30' prior to connection.;Drill 8-12" production hole from 8160'to 8568' (3982' TVD), 408' with AROP of 68 FPH. 495 GPM = 1730 psi, 120 RPM = 16K ft-lbs torque, WOB = 5-17K, MW = 9.2 ppg, Vis = 49, ECD = 11.13ppg, Max gas = 109 units PU = 180K, SO = 40K, ROT = 113K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 8200' and sweep back on time with 75% increase at shakers.;Drill 8-12" production hole from 8568' to 9119 (3980' TVD), 408' with AROP of 91.8 FPH. 500 GPM = 1800 psi, 120 RPM = 18K ft-lbs torque, WOB = 5-15K, MW = 9.4+ ppg, Vis = 44, ECD = 11.21 ppg, Max gas = 172 units PU = 190K, SO= 40K, ROT= 113K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 8790' and sweep back on time with 20% increase at shakers. Currently drilling in the OA-3 sand.;Last survey at 8973.20' MD, 3985.84' TVD, 91.37° Inc, 125.59° Az. Distance to Well Plan #8 = 21.3' (21.27' low and 1.19' left). 50 concretions have been drilled so far this lateral for a total footage of 262' (6.4% of the lateral).;Hauled 1050 bbls H2O from L-Pad lake for total= 6205 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 861 bbls cuttings/liquids to MPU G&I for total = 8270 bbis 2/172019 Drill 8-12" production hole from 9119 to 9540' (3985' TVD), 421' with AROP of 70.16 FPH. 500 GPM = 1760 psi, 120 RPM= 19K ft-lbs torque, WOB = 9-11K, MW = 9.3 ppg, Vis = 44, ECD = 11.09 ppg, Max gas= 223 units PU = 190K, SO= 40K, ROT= 113K. Back reaming 30' prior to connection.;Dump and dilute with 290 bbls new 9.2 ppg Flo pro mud to lower MBT from 7 to 5 and ECD from 11.28 to 11.09 ppg. Pumped 30 bbl hi vis sweep at 9364', back on time with 50% increase at shakers. MPD start holding 70+ psi annulus pressure during connections at 9619.;Drill 8-1/2" production hole from 9549to 9941' (3976' TVD), 401' with AROP of 66.8 FPH. 500 GPM = 1770 psi, 120 RPM= 20K ft-lbs torque, WOB = 5-15K, MW = 9.3 ppg, Vis = 43, ECD = 11.15 ppg, Max gas = 195 units PU = 195K, SO= 40K, ROT= 115K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 9902', back 200 strokes late with 10% increase at shakers.;Drill 8-12" production hole from 9941'to 10192' (3976' TVD), 251' with AROP of 41.8 FPH. 536 GPM = 2000 psi, 120 RPM= 20K ft-lbs torque, WOB = 5-15K, MW = 9.3 ppg, Vis = 43, ECD = 11.21 ppg, Max gas= 107 units PU = 200K, SO= 40K, ROT= 115K. Back reaming 30' prior to connection ;Exited the OA-3 at 984& through the OA-2 and entered the OA-1 at 9957'.;Drill 8-1/2" production hole from 10192'to 10764' (3968' TVD), 572' with AROP of 95.3 FPH. 550 GPM = 2400 psi,120 RPM = 22K ft-lbs torque, WOB = 101K, MW = 9.3 ppg, Vis = 44, ECD = 11.29 ppg, Max gas = 391 units PU = 200K, SO = 40K, ROT = 113K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 10400', back 250 strokes late with 10% increase at shakers. Currently drilling in the OA-1 sand.;Last survey at 10641.02' MD, 3969.34' TVD, 90.81 ° Inc, 122.78° Az. Distance to Well Plan #8 = 19.12' (8.81' low and 16.97' right). 71 concretions have been drilled so far this lateral for a total footage of 359' (6.2% of the lateral).;Hauled 1050 bbis H2O from L-Pad lake for total = 6205 bbis Hauled 0 bbls heated H2O from G&I = 380 Hauled 861 bbis cultings/liquids to MPU G&I for total = 8270 bbis 2/182019 Drill 8-1/2" production hole from 10764' to 11262' (3971' TVD), 498' with AROP of 83 FPH. Maint. 90 deg 527 GPM = 2020 psi, 120 RPM= 24K ft-lbs torque, WOB = 10K, MW = 9.3+ ppg, Vis = 43, ECD = 11.22 ppg, Max gas = 240 units PU = 215K, SO= 40K, ROT= 115K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 10862', sweep back 250 strokes late with no increase. Increase lubes from 0.5 to 1% reducing torque from 24k to 18k ft-lbs and PU from 215K to 185K. Dump and dilute with 290 bbls new 9.2 ppg flow pro mud.;Dnll 8-1/2" production hole from 11262' to 11813' (3994' TVD), 551' with AROP of 91.8 FPH. 530 GPM = 2040 psi, 120 RPM= 17K ft-lbs torque, WOB = 5-10K, MW= 9.3 ppg, Vis = 46, ECD = 11.37 ppg, Max gas = 572 units PU = 185K, SO= 40K, ROT= 110K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 11425', sweep back 200 strokes late with 100% increase. Continue in OA-1 maintaining. 90 deg Inc to 11500'then start down to OA-3. MPD increase to 90-100 psi annulus psi during connections @ 11616'.;Drill 8-1/2" production hole from 1181V to 12194' (3999' TVD), 361' with AROP of 63.5 FPH. 499 GPM = 1950 psi, 120 RPM= 19K ft-lbs torque, WOB =5-15K, MW = 9.3 ppg, Vis = 44, ECD = 11.26 ppg, Max gas= 216 units PU = 200K, SO= 40K, ROT= 110K. Back reaming 30' prior to connection.;Pumped 30 bbl hi vis sweep at 11813', sweep back 300 strokes late with 0% increase.;Drill 8-112" production hole from 12194' to 12739' (3995' TVD), 545' with AROP of 90.8 FPH. 500 GPM = 2110 psi, 120 RPM = 20K ft-lbs torque, WOB = 5-15K, MW = 9.2 ppg, Vis = 44, ECD = 11.34 ppg, Max gas = 264 units PU = 205K, SO = 40K, ROT = 112K. Back reaming 30' prior to con nection.;Pumped 30 bbl hi vis sweep at 12194', did not see come back. Currently drilling in the OA-3 sand.;Last survey at 12595.75' MD, 3997.34' TVD, 90.19° Inc, 125.13° Az. Distance to Well Plan #8 = 32.48' (28.92' low and 14.78' right). 95 concretions have been drilled so far this lateral for a total footage of 438' (5.6% of the lateral).;Hauled 610 bbls H2O from L-Pad lake for total= 7630 bbis Hauled 0 bbis heated H2O from G&I = 380 Hauled 1155 bbis cuttings/liquids to MPU G&I for total = 10171 bbis 2/192019 Drill 8-1/2" production hole from 12739' to 13205' (3987' TVD), 466' with AROP of 77.6 FPH. 500 GPM = 2090 psi, 120 RPM= 231(ft-lbs torque, WOB = 10- 15K, MW= 9.3 ppg, Vis = 48, ECD = 11.43 ppg, Max gas = 249 units PU = 210K, SO= 40K, ROT= 109K. Back reaming 30' prior to connection.;Hi vis sweep pumped at 12194' came back 300 stirs late w/ 25% increase. Pump 30 bbl hi vis sweep @ 13140', back 325 stks late, no increase. Drill in OA-3 to OA-2 @ 12907' and OA-1 @ 13010'.;Drill 8-1/2" production hole from 13205' to 1371 1'(4000' TVD), 506' with AROP of 84.3 FPH. 500 GPM = 2090 psi, 120 RPM = 23K ft-lbs torque, WOB = 10-15K, MW = 9.3 ppg, Vis = 48, ECD = 11.63 ppg, Max gas = 247 units PU = 190K, SO = 40K, ROT = 111 K. Back reaming 30' prior to connection.;MPD increase to 110-120 psi annulus during connections @ 13236'. Pump 30 bbl hi vis sweep @ 13711', back 300 stks late, no increase. Stayed in OA-1.;Dri118-1/2" production hole from 13711'to 14181'(401 1'TVD), 470' with AROP of 78.3 FPH. 500 GPM = 2250 psi, 120 RPM= 19K ft-lbs torque, WOB =5-15K, MW = 9.2 ppg, Via= 47, ECD = 11.69 ppg, Max gas= 277 units PU = 190K, SO= 40K, ROT= 110K. Back reaming 30' prior to connection.;Hold 110- 120 PSI annulus during connections. Stayed in OA-1.;Drill 8-1/2" production hole from 14181'to 14731' (4020' TVD), 550' with AROP of 91.7 FPH. 500 GPM = 2230 psi, 120 RPM = 19K ft-lbs torque, WOB = 3-71K, MW = 9.2 ppg, Vis = 44, ECD = 11.6 ppg, Max gas = 323 units PU = 197K, SO = 40K, ROT = 111 K. Back reaming 30' prior to connection.;Perform 290 dump and dilute with new 9.0 ppg FloPro NT mud at 14270'. ECD reduced from 11.8 to 11.55 ppg briefly, then began climbing to 11.7 ppg. Reduce ROP to 110'/hr and ECD dropped to 11.6 ppg. Begin planned drop at 14468', OA-2 at 14512'.;Hauled 880 bbls H2O from L. Pad lake for total = 8510 bbis Hauled 0 bbls heated H2O from G&I = 380 Hauled 948 bbis cuttings/liquids to MPU G&I for total = 11119 bbls;Drilled 105 concretions for a total thickness of 494' (5.1 % of the lateral). 1 fault has been observed so far this lateral. Last survey at 14584AT MD / 4017.80' TVD, 88.10' Inc, 126.41 ° azm. 58.92' from plan, 58.88' low and 2.27' right. 2/20/2019 Drill 8-112" production hole from 14731' to 15035' (4029' TVD), 304' wfth AROP of 50.6 FPH. 500 GPM = 2290 psi, 140 RPM= 21 K ft-lbs torque, WOB = 7K, MW = 9.2 ppg, Vis = 48, ECD = 11.59 ppg, Max gas = 316 units PU = 193K, SO = 40K, ROT= 110K. Back reaming 90' prior to connection.;Pump 30 bbl hi vis sweep @ 14846', back 450 stks late w/ 15% increase at shakers. MPD hold 110-120 psi annulus pressure during connections. Screen up shakers from 170# to 200#. Drilling in the OA-3.;Drill 8-1/2" production hole from 15035' to 15415'(403,V TVD), 380' with AROP of 63.3 FPH. 500 GPM = 2250 psi, 120 RPM = 22K ft-lbs torque, WOB = 5-15K, MW= 9.2 ppg, Vis = 45, ECD = 11.57 ppg, Max gas = 156 units PU = 200K, SO = 40K, ROT= 110K. Back reaming 30-96 prior to connection.;MPD hold 140-150 psi annulus pressure during connections. Drilling in the OA-3.;Dri118-1/2" production hole from 15415'to 15788' (4040' TVD), 373' with AROP of 62.2 FPH. 500 GPM = 2420 psi, 120 RPM = 23K ft-lbs torque, WOB = 5-15K, MW = 9.2 ppg, Vis = 47, ECD = 11.68 ppg, Max gas = 156 units PU = 195K, SO = 40K, ROT = 11 OK. Back reaming 30-90' prior to connection.;Pump 30 bbl hi vis sweep @ 15418', back 400 stks late w/ 20% increase at shakers. MPD hold 140-150 psi annulus pressure during connections. Drilling in OA-3, begin building up at 15603'.;Dri 118-1 /2" production hole from 15788' to 16078' (4021' TVD), 290' with AROP of 48.3 FPH. 500 GPM = 2430 psi, 120 RPM= 21-25K ft-lbs torque, WOB = 5-15K, MW = 9.2 ppg, Vis = 46, ECD =11.66 ppg, Max gas= 124 units PU = 186K, SO= 40K, ROT= 106K. Back reaming 90' prior to connection.;MPD hold 140-150 psi annulus pressure during connections. OA-2 observed at 15910', OA-1 not observed on logs yet.;Begin 290 bbl 9.0 ppg FloPro new mud dilution at 16025'. Drilled 116 concretions for a total thickness of 614' (5.5% of the lateral). 1 fault has been observed so far this lateral. Last survey at 15914.10' MD / 4032.86' TVD, 92.92° Inc, 124.43° azm. 57.32' from plan, 57.31' low and 1.16' Ieft.;Hauled 725 bbis H2O from L-Pad lake for total= 9235 bbis Hauled 0 bbis heated H2O from G&I = 380^ n Hauled 948 bbls cuttings/liquids to MPU G&I for total = 11119 bbis P6 2121 /2019 Drill 8-1/2" production hole from 16078' to 16392' (4021' TVD), 314' with AROP of 52.3 FPH. 500 GPM = 2430 psi, 120 RPM= 22K ft-lbs torque, WOB = 8K, MW = 9.2 ppg, Vis = 50, ECD = 11.7 ppg, Max gas= 129 units PU = 195K, SO = 40K, ROT= 107K. Back reaming 90' prior to connection.;16200' encountered dirty sand above OA-1, drop to get back in the clean OA-1, formation dip is around 88.3-88.1 deg. Pump 30 bbl hi vis sweep @ 16269', sweep back 600 stks late with no increase at shakers. MPD maintaining 145-150 psi annulus pressure during connections.;Drill 8-1/2" production hole from 16392'to 16643' (4033' TVD), 251' with AROP of 83.6 FPH. Back in clean OA-1 sand at 16500'500 GPM = 2430 psi, 120 RPM = 22K ft-lbs torque, WOB = 8K, MW = 9.2 ppg, Vis = 46, ECD = 11.73 ppg, Max gas = 103 units PU = 195K, SO = 40K, ROT = 107K.;Decision made to side track, take final survey. BROOH f/ 16643 to 15984' 500 gpm, 120 rpm, 22k ft/lbs torque, MPD hold 150 psi annulus pressure during connections.;Open hole side track at 16049. Trough from 16020'to 16040' with 100% deflection at 180 TF. Time drill f/ 16040' tt 16065' with 500 GPM 2410 PSI, 120 RPM, 20K TO, 1-81K WOB. Inclination in new hole 91.72° vs. 93.48° in old hole @ 16061'. Control drill at Sd/hr f/ 16065' U 16079'.;Drill @ 110'/hr to 16110'. POOH 111611 Utl 16015', then TIH past sidetrack point without problem. MW = 9.2 ppg, Vis = 45, ECD = 11.57 ppg, Max gas = 129 units. PU = 185K, SO = 40K, ROT = 106K. MPD maintaining 145-150 psi annulus pressure during connections.;Drill 8-1/2" production hole V 1611 O' t/ 16422' (4030' TVD), 312'w/ AROP of 62.4 FPH. Entered OA-1 sand @ 16160,500 GPM = 2580 psi, 120 RPM = 21 K ft-lbs TO, WOB = 7-12K, MW = 9.2 ppg, Vis = 48, ECD = 11.77 ppg, Max gas = 108 units. PU = 200K, SO = 40K, ROT = 106K. Backream 90'@ connecbons.;Last survey @ 16293.94' MD / 4024.55' TVD, 88.46° inc, 125.54° azm. 49.06' from plan, 49.01' low & 2.24' left. Apparent dip is 88.5° to 88.7°. Drilled 117 concretions for a total thickness of 620' (5.4% of the lateral). 1 fault has been observed so far this Iateral.;Hauled 875 bbis H2O from L-Pad lake for total = 10110 We Hauled 0 bbis heated H2O from G&I = 380 Hauled 990 bbls cuttings/liquids to MPU G&I for total = 12109 bbls 2/22/2019 Drill 8-1/2" production hole f/ 16422't/ 16792'@ TO (4040' TVD), 530'w/ AROP of 75.7' FPH. Drill in OA-1 500 GPM = 2510 psi. 120 RPM = 22K ft-lbs TQ, WOB = 6K, MW = 9.2 ppg, Vis = 48, ECD = 11.81 ppg, Max gas = 131 units. PU = 200K, SO =40K, ROT =109K. Backream 90' @ connections.;MP0 hold150-160 psi annulus pressure during connections. Expected fault came in at 16774' TD well as per Geo ,Take final survey. Last survey at 16672.88' MD / 4037.35' TVD, 87.23' inc, 124.75° azm. 61.98' from plan, 61.81' low and 4.62' right. Swap to completions report @ 1300 hm.;120 concretions were drilled in the lateral, for a total thickness of 629' (5.3%). 2 faults were crossed in the lateral. 1 plugback was drilled.;See completions report for remainder of daily activity.;Hauled 715 bbis H2O from L-Pad lake for total = 10825 bbls Hauled 0 bible heated H2O from G&I = 380 Hilcorp Energy Company Composite Report Well Name: MP M-12 Field: Milne Point Unit County/State: ,Alaska i (LAT/LONG): avation (RKB): API #: Spud Date: 2/3/2019 Job Name: 1814312C MPU M-12 Completion Contractor AFE #: AFE S: A ,, .. . 14 Ops Summary 2122/2019 Drilled 8-1/2" production hole to TD at 16792'. Please see drilling report for details BROOH 1 std f,' 16792' to 16740' 465 gpm, 2400 psi. 120 rpm, 22k fUlbs, rack back 1 std., M/l1 TD, Cleanup wellbore and condition mud ,work pipe 90', 120 rpm, Pump tandem 30 bbl low vis, low wt followed with 30 bbl hi vis 10.6 ppg weighted sweep around, sweep back 600 stks late with 20% increase at shakers, dump and dilute with 290 bbls new 9 ppg flow pro mud w/ 4% Iubes.,Circulate 5 total, Each BU rack 1 std back to 16271', increase lubes from 1.5% to 4% adding 1% 776 and 3% Lotorq lubes. 8 drums 776 and 13 drums Lotorq added. Mud weight cleaned up from a 9.25 ppg to 9.1 ppg during circulating w/ a final 11.02 ECD.,RIH at 30'/min f/ 16271't/ 16792'.Ream down due to no slack off weight. 400 GPM, 1500 PSI, 50 RPM, 17K TO. Perform 5 min. flow check with 118 PSI (9.7 ppg EMW) held via MPD, bled down to 117 PSI over 5 min.- no increase in pressure or flow. 195K PUW, 115K ROT.,BROOH f/ 16792't/ 14269'. 385 GPM, 1540 PSI, 120 RPM, 19K TQ, 10.78 ECD. 91min to 16359', ECD increased to 10.93. Increase pulling speed to 77min. @ 163591 then 10'/min. @ 16119' with 11.03 ECD. Maintain 160 to 180 PSI on connections with MP 223/2019 Continue to BROOH f/ 14269't/ 12764' 10 fpm, 385 GPM,1180 PSI, 120 RPM, 15K TO, 10.34 ECD, seeing slight sand & silt at shakers. MPD holding 170 PSI annulus pressure during connections.,Continue to BROOH f/ 12764' U 10380' 10 fpm, 385 GPM, 1180 PSI, 120 RPM, 13-14K TQ, 10.64 ECD, continue seeing slight sand & silt at shakers. MPD holding 170 PSI annulus pressure during connections.,Continus to BROOH If 10380' 1/ 8284' 10 fpm, 385 GPM, 1000 PSI, 120 RPM, 11 K TO, continue seeing slight sand & silt at shakers. Observed torque & stickslip at 9948'. Work down then ream through w/ no problems. Begin holding 40 PSI backpressure while reaming @ 8512'to maintain 10.2 ppg ECD. MPD holding 170 PSI annulus pressure during connections -Continue to BROOH f/ 8284't/ 6455' 10 fpm, 385 GPM, 950 PSI, 120 RPM, 8K TO, continue seeing slight sand & sift at shakers. Observed 25K overpull at 8200'. Work down then ream through w/ no problems. Hold 40-90 PSI backpressure while reaming to maintain 10.2 ECD and 170 PSI during connections with MPD.,Diesel fuel (gallons): Recd - 0, Used - 2221, On hand - 7783. Hauled 260 bbls H2O from L -Pad lake for total = 11085 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 347 bbls cuttingsfliquids to MPU G&I for total = 13404 bbls 0 daily losses 0 cumulative losses 2/24/2019 Continue to BROOH fl 6455' V 4885'10 fpm, 385 GPM, 950 PSI, 120 RPM, 8-11 K TQ, continue seeing slight sand & silt at shakers. At 5387' seen 10k torque increase and 10k overpull back reaming thru shale, lower to 30 rpm, drop back thru and cleanup same.( shales 54601 to 5263' ) Hold 90-115 PSI back pressure while back reaming to maintain 10.2 ECD and 170 PSI during connections with MPD.,SIow rpm to 80 w/ MWD tools passing thru shoe f/ 5030', survey @ 4988' bit depth. Submit 24 hr BOP test notification to AOGCC @ 07:55.,Pump 30 bbl hi vis sweep, Circulate 9 5/8" casing clean @ 4860' pumping 405 gpm, 950 psi, reciprocating pipe 69, sweep back on time with 100% increase at shakers, sand and shale. Circulate 3 BU, clean at returns. MPD holding 120 psi back pressure to maintain 10.2 ECD. Note: #2 MP traction motor, suspect bearing failure, expedite spare motor f/ DDI yard to rig shop for inspection and C/O.,Shut down MP. MPD holding 170 psi, monitor for 5 min w/ no pressure build, bleed down to 150 psi, monitor pressure build to 155 psi in 5 min with no further pressure increase - calculate 10.02 EMW. PJSM for increasing mud wt. MW 9.2 ppg, vis 40. Will weight up to 10.2 ppg for 0.2 trip margin.,Weighted up to 10.0 ppg by blending 11.3 ppg FloPro NT spike fluid then to 10.2 ppg with sack product. 31206 stks total pumped, 9.35 complete circulations. Initial 385 gpm, 817 psi, 50 RPM, 4K TO, final 385 GPM, 870 PSI, 60 RPM, 2K. MPD maintain 155-120 psi until 10.2 mud @ bit, decreasing pressure slowly until chokes full open. 11.05 ECD with chokes wide open and 10.2 ppg mud.,Blow down top drive. Perform 15 min flow check - static. PJSM with Doyon crew and Beyond MPD. Remove RCD and install trip nipple. Inflate air boots, fill trip nipple & check for leaks - none. Pump 25 bbl 11.6 ppg dry job.,POOH from 4860' to 277' laying down 5" drill pipe. 10.7 bbls lost while POOH.,Perform 5 min flow check -static. UD BHA#3 from 277'to 83'. Plug in and read MWD tools. 2 BPH static losses -Hauled 260 bbls H2O from L -Pad lake for total = 11085 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 171 bbls cuttings/liquids to MPU G&I for total = 13575 bible Rig Fuel (gallons): Rec'd=5659, Used=2303, On hand=11139 14.0 bbls daily losses, 14.0 bible cumulative losses. 225/2019 Finish down loading MWD, L/D remaining BHA, 812" bit grade= 3 -2 -BT -C -X -1 -CT -TD, Inspect same, ILS undercut top and bottom, wear bands on MWD under cut on top edge of band. Monitor "it with trip tank, static loss rate 2 bph.,Clear rig floor, PJSM for LJD 5" DP in denick using mouse hole. Monitor well With trip tank, static loss rate 2 bph.,LID 49 stands 5" DP from derrick using mouse hole, leave 51 stands DP in derrick for liner top clean out. Monitorwell w/ trip tank, static loss rate 2 bph.,Pull 9 1/8" ID wear bushing. R/U wash tool and jet stack, R/U BOP test equipment with 312" test jt, flood lines with fresh water. Pressure up to perform body test, test plug 0 -ring leaking, drain stack, pull test jt. Missing section o -ring, replace same, install test plug and flood stack. Perform shell test to 250 low / 3000 high.,Test BOP equipment as per AOGCC & PTD requirements. AOGCC inspector Matthew Herrera witnessed testing. All tests performed to 250 PSI low/ 3000 PSI high, held for 5 min. & charted. #1: Annular on 3-12" test joint, choke valves 1, 12,13,14, kill line Demco #20 & lower IBOP. #2: Lower 2-7/8"x5" VBR on 3-1/2" test joint. #3: Top 4-1/2"x7" VBR on 5" test joint, upper IBOP, kill line HCR, choke valves 9 &11.04: Kill line manual, choke valves 5, 8 & 10. #5: 5" dart valve, choke valves 4, 6 V. #6: First 5" FOSV, choke valve 2. #7: Second 5" FOSV, choke line HCR. 98: Choke manual & 3 112" FOSV. Accumulator test: 3000 PSI system, 1700PSI after closure, 200 PSI in 40 sec., full in 179 sec., 6 nitrogen bottle avg 2050 PSI. #9: Blind rams & choke valve 3. #10: Hyd. "A" & man. "B" chokes to 1500 PSI. Test gas, PVT & flow alarms.,#11: Upper 41/2"x7" VBR on 7" test joint - failed. Attempt to re -test 4-12"xT' rams on 5" test joint- failed. Change upper rams to 3-1/2"x6" VBR. Top off wellbore with 9 bbis 10.2 ppg mud. Sim -ops: change out wash pipe on top drive.,Continue BOP testing. All tests performed to 250 PSI low / 3000 PSI high, held for 5 min. & charted. #11: upper 3-12"x6" VBR on 5" test joint. #12: upper 3-12"x6" VBR on 3-1/2" test joint. Pull test plug and L/D test joint. Blow down choke & kill lines. Install 9-1/8" ID wear bushing.,Hauled 35 bale H2O from L -Pad lake for total =11120 bbis Hauled 0 bbls heated H2O from G&I = 380 Hauled 277 bbls cuttings/liquids to MPU G&I for total = 13852 bbls Rig fuel (gallons): Rec'd=0, Used=1295, On hand=9844 14.7 bbls daily losses, 28.7 bale cumulative losses. 2/26/2019 Finish installing 91/8" ID wear bushing, clear rig floor, PJSM for LID DP using mouse hole. Monitor the well with trip tank, 2 bph static loss rateJJD 31 stands 5" DP leaving 51 stands in derrick for P'tie back cleanout run. Continue to monitor well, 2 bph static loss rate. Simops: PJSM, crane out MP #2 traction motor, crane in replacement motor.,Claar rig floor, PJSM, slip and cut 72' drilling line, re -calibrate blocks. Inspect and C/O saver sub. Static loss rate 2 bph.,Load 5" HWDP into shed. PJSM, Drift to 2.45", P/U and rack 50 stands of 5" HWDP in derrick using mouse hole. Continue to monitor well.,Rig up 3-1/2" casing equipment to run 3-1/2" EUE tubing. Mobilize equipment to the rig floor. R/U hydraulic tongs and elevators. Cut plywood to place on pipe rack. Clear 5" drill pipe thread protectors from rig floor.,P/U 3-1/2" 9.3# L-80 EUE 8rd tubing perforated stringer (30.88') and single in the hole with 3-1/2" 9.3# L-80 EUE 8rd tubing to 1355'. Torque connections to 2800 fUlbs with Doyon casing double stack hydraulic tongs.,Hauled 25 bbls H2O from L -Pad lake for total = 11145 bbis Hauled 0 bbls heated H2O from G&I = 380 Hauled 57 bbis cuttings/liquids to MPU G&I for total = 13909 bbis Rig Fuel (gallons): Rec'd= 0, Used=1422, On hand=8422. 34.8 bbls daily losses, 63.5 bbls cumulative losses. 2127/2019 Continue to drift, P/U and single in the hole with 3-112" 9.3# L-80 EUE Bird tubing f/ 1355 to 4783' just above 9 5/8 shoe (156 its ) TOOH racking back 52 stands in the derrick, LID perforated stinger. Torque connections to 2800 fr/Ibs Loss rate continues 2 bph.,M/U 3-1/2" mule shoe, Drift and single in with another 156jts 3 1/2" tubing to 4744'. Torque connections to 2800 fUlbs. Circulate 3300 stks surface to surface. Stage up from 2 BPM, 160 PSI to 7.5 BPM, 590 PSI. Initial 42' mud temp out to 60° mud out. MW in/out 10.2 w/ 44 vis. No additional losses over static loss rate while circulating.,TOOH racking back 52 stands 3-1/2" tubing in the derrick. Loss rate continues 2 BPH. No more room in the derrick, unable to rack back all 390 joints/ 130 stands. 78 joints remaining in the pipe shed. Loss rate continues 2 bph.,PJSM. RID 3-1/2" casing equipment & R/U 6-5/8"equipment- Doyon casing 8-518" double stack power tongs, 6- 5/8" HYC elevators and hand slips. Mobilize 294 6-5/8"x8-1/2" centralizers to the rig floor. N1/U 6-5/8" Hydril 563 Wedge safety joint: 6-5/8" H563 pin x 4-1/2" IF box XO, 5" drill pipe joint, 4-12" IF FOSV, 65/8" H563 box x 4-1/2" IF pin XO. 1.7 bph loss rate.,PJSM. P/U 4-1/2" float shoe, WIV, 4-1/2" joint of liner, drillable Pac-Off sub, 4-12" pup joint & 4-112" BTC pin x 6-518" Hydril 563 box XO. MAJ joint #1 to 84'. M/U 6-5/8" safety joint to verify proper operation - good. LID safety joint. Torque connections to 7,100 ft/Ibs. Install 6-5/8"x8-1/2" rigid straight vane centralizers on each joint. 1.7 bph loss rate..Hauled 35 bbis H2O from L - Pad lake for total =11180 blots Hauled 0 bbls heated H2O from G&I = 380 Hauled 57 bbls cuttings/liquids to MPU G&I for total = 13966 bbls Rig Fuel (gallons): Recd=4000, Used=1646, On hand=10776. 146 5 bbis daily losses 110 bola cumulative losses 2/282019 P/U and run 6-518" 20# L-80 Hydril 563 Wedge pre -drilled liner as per tally from 84' to 4307', it # 104. Torque connections to 7,100 ft(lbs. Install 65/8" x 8-1/2" rigid straight vane centralizers on each joint. Loss rate running liner 2 bph.,Cast iron setting plate on 6 5/8 200 ton HC elevators caught collar on liner stump and broke setting plate, decision made to C/O elevators to 125 ton backup 6 5/8 elevators and continue to TIH while having another setting plate machined.,Continue P/U and run 6-5/8" pre -drilled liner from 4307'to 4872', it # 118 just above 9 5/8 shoe, ( PU/SO 155k/100k ) continue to run liner, no issues passing thru shales fl 5263'- 5469, RIH to 12056'. TO to 7,100 fUlbs. Install 6-5/8" x 8-12" centralizers on each joint. Total of 275 pre -drilled joints, 19 solid joints and 291 centralizers ran. 160K PUW, 73K SOW. Loss rate running liner 2 bph., Removed 20 extra joints from the pipe shed, # 276-295. Sim -ops: Completed traction motor replacement on #2 mud pump. Function test- pump 2 BPM through bleeder.,PJSM. RID 6-5/8" power tongs. Mobilize 3-12" handling equipment to the rig floor. R/U 3-1/2" power tongs. Re -configure safety joint with 6-518" H 562 x 3-1/2" EUE triple connect, XO sub & 3-12" EUE pup joint. R/U false rotary table. Break over string after sitting for 2 hours with 180K then 155K PUW. PJSM for running 3-12" inner string. Loss rate 2 bph.,Note: new machined setting plate installed on 200T 6-5/8" elevators.,P/U 2-3/8" slick stinger, 2-318" pup joint, Hydro -hip sub (10 shear screws - 5050 PSI shear), XO sub & 3-1/2" pupjoint. Run 78 singles of 3-1/2" 9.3# L-80 EUE tubing inner string from the pipe shed to 2383'. Run stands of 3-1/2" tubing from derrick f/ 2383' U 4027'. Torque to 28001t/Ibs with Doyon casing double stack tongs. Loss rate at 2 bph.,Hauled 30 bbis H2O from L -Pad lake for total = 11210 bbis Hauled 0 bbls heated H2O from G&I = 380 Hauled 0 bbis cultings/liquids to MPU G&I for total = 13966 bbls Rig Fuel (gallons): Rec'd=0, Used=1485, On hand=9291. 47 bbis daily losses, 157 bbis cumulative losses. 3/12019 Run stands of 3-1/2" tubing from derrick V 4027' U 11880'. P/U singles from the pipe shed it 11880' & no-go @ 12024' w/ 10K. Tag 8' higher than calculated. Change out joint #235 due to bad pin (28.94' out 129.27' in). Torque to 2800 ft/lbs with Doyon casing double stack tongs. Loss rate continues at 2 BPH.,Space out as per Baker rep. LID jt. #295. P/U 6.09' & 6.08' pup its. M/U swivel & triple connect on 5" drill pipe. Work 6-5/8" liner free. PU 200K, SO 45K, PU 225K, SO 45K, PU 260K, SO 45K. WU top drive, apply 20K torque, slack off and liner freed at 50K. Observe 14K TQ, 195K PU, 95K SO while free. Work f/ 12016' U 12056'then release torque. RID triple connect, swivel & 5" drill pipe.,M/U 6.09' pup joint and Baker 7"x9-518" liner top packer. RIH f/ 12092' 1/ 12123'. Final space out is showing 4.27' off of no go. Stage up pumps to 4 BPM, 780 PSI to 5 BPM, 940 PSI, circulate 70 bbis to ensure clear flow path.,Run 6-518" pre- drilled liner on 5" HWDP from the derrick f/ 12123'V 16711'. M/U stand of 5" drill pipe then RIH f/ 1671 1' U 16792'. Note- Pipe filling on its own on the trip in. Float not holding or slick stick not in pack off. Tag bottom w/ 7K. 310K PU 1130K SO. Note- tagged bin 9' deep with liner from calculated.,PJSM. Pump 30 bbl high vis spacer @ 2.4 BPM, 590 PSI. Pump 50 bola seawater, 30 bbis SAPP pill #1, 50 bbis seawater, 30 bbis SAPP pill #2, 50 blols seawater, 30 bbis SAPP pill #3 @ 4 BPM, 1000 PSI. Chase w/ 240 bbis 8.5 ppg seawater then begin 10.2 ppg brine displacement. Reciprocate pipe 20'f/ 16792't/ 16772'. 285K PU I 125K SO. Began to see 30K overpul I at 6300 stks, park liner at 16792' set depth.,Observe 9.2 ppg mud back @ 9800 stks. Observe 8.9 ppg mud back @ 12000 stks (diluted SAPP pills), 4500 stks late. Note: 282 bbls 12800 stks volume in 3-1/2"x6-5/8" annulus not included in displacement numbers. 8.6 ppg seawater back @ 13200 stks. 66% losses began @ 16000 stks. Slow to 2.5 BPM, 290 PSI. No change in losses. Increase to 4.0 BPM, 720 PSI @ 19500 stks.,10.0 ppg brine back at 18500 stks. 10.1 ppg brine back at 19500 stks. Shut down at 20300 stks w/ 10.1 ppg brine out.,Drop 1-1/8" phenolic ball. Pump down at 3 BPM, 360 PSI, increase to 5 BPM, 1080 PSI. Shut down pumps at 448 stks, valve on mud pump #1 leaking. Check mud pump suction valves. Electrical problems with new traction motor on mud pump #2.,Hauled 45 blots H2O from L -Pad lake for total = 11255 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 825 blots cutgngslliquids to MPU G&I for total = 14791 bols Rig Fuel (gallons): Rec'd=0, Used=1574, On hand=7717. 59 bbis daily losses (until midnight), 216 bola cumulative losses. Losses during displacement will be reported tomorrow. 3/2/2019 Pump down 1.125" ball at 3-5 BPM. Over displace by 60 bbl. 200 bbl total. Still no pressure increase. Shut down and Drop 1.75" Ball. Let fall for 20 min while building a high vis spacer sweep. Pump down at 6 bpm. Caught pressure at 1103 stks. Calculated at 1460. Pressure up to 4K and set packer. Line up on test pump and pressure up to 4250 & feel goad indication of release & neutralize of pusher tool.,Confinue to pressure up to shear out the shear out shear sub in slick stick. Pressure up to 5000 psi and never saw the shift. Bleed down pressure and attempt to release from liner. Slack off to 50k & P/U to 260K. Perform this several times with no success. Decide to pressure up again. Pressure up to 500 psi and PIU to 240K. Pipe free. Test back side to 1500 psi for 10 min. Bled down 30 psi. No flow out of DP.,P/U & pull out slick stick. Line up down DP & pressure up to 5100 psi. Held & shear sub sheared out. Establish circ withg 9.8 ppg Brine at 10 bpm while displacing w/ two 3.5 X liner volumes. 570 bbl. 70 BPH losses while circulating. Change out leaking Hyd hose on TD while circ. Monitor well. Flowing out the pipe due to 9.8 in the OP & 10.2 on the back side. Pump 40 bbl 10.2 down the pipe. Static losses at 23 BPH.,POOH f/ 16711't/ 12092' laying down 5" HWDP. 149.6 bbls losses over displacement / 37.4 BPH loss rate.,UD Baker liner running tool - no damage or abnormal wear observed. PJSM. R/U 3-12" elevators & power tongs. UD three 3-112" tubing pup joints. RN 3-1/2" air slips. 18 BPH static loss rate.,POOH laying down 247 joints of 3-1/2" tubing inner string f/ 12000'V 4446'. 138.3 bbls losses over displacement / 18.44 BPH loss rate.,Rack back stands of 3-1/2" tubing for use in completion f/ 4446't/ 28'. L./D Baker slick stick assy. 44.7 bbls losses over displacement 122.35 BPH loss rate.,Hauled 210 bbls H2O from L -Pad lake for total = 11465 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 1731 bbls cuttings/liquids to MPU G&I for total = 16522 bbls Fuel (Gallons): Rec'd=0, Used=1746, On hand=5971 3/3/2019 P/U 5" Safety joint and break down same. Clear rig floor of 3-1/2" equipment.,M/U 3.5 wash tool with no go. RIH with 5" dp from derrick T/ 4710'. Wash down at 3 bpm & Tag out with no go at 4713'. Tag out 8K. ON depth.,Pump high vis sweep around at max rate. 10 BPM. 9.6 in and out. Displace to clean 9.6 brine at 3- 5 BPM. Monitor well. Slight flow. Monitor until static. 20 Min.,Slip & cut driling line. Cut off 71' of line. Service rig and inspect draw works brakes. 6 BPH loss rate.,POOH laying down 5" HWDP f/ 4675to 29'. LID no-go and 3-1/2" perforated wash tool. 37.3 bbls lost over pipe displacement / 9.33 BPH average.,PJSM. Static losses 4 BPH. Close blind rams. Change upper rams to 4-1/2" x 7" VRB. Verify no pressure on choke, open blind rams.,Pull wear bushing & install lower test plug & 7" test joint. R/U test equipment. Fill BOP stack w/ water purge lines. Test 4-1/2"x7" upper VBR on 7" test joint to 250 PSI low / 3000 PSI high. Hold each test for 5 min & chart tests. RID test equipment & pull test plug. Witness waived by AOGCC rep Robert Noble on 3-2-19 @ 18:33 via phone call. SimOps: R/U casing equipment.,Perform dummy run with 7" hanger & landing joint. Hilcorp wellhead rep. verified landing and marked landing joint.,P/U Baker Bullet seals tie -back assembly to 17'. Run 7" 26# L-80 TXP BTC -SR liner f/ 17' U 4723'. Torque to 14750 Wiles with Doyon casing double stack tongs. Performed well control drill, well secure 2 min., all hand responded 2 min. 45 sec. Tag no-go w/ 10K (5' deep). 15 BPH loss rate.,Hauled 200 bbls H2O from L -Pad lake for total= 11465 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 575 bbls cuttings/liquids to MPU G&I for total = 17097 bbls Diesel fuel (Gallons): Rec'd=6446, Used=1724, On hand=10693 linn Khi� cnity losses, 1161 bbis cumulative losses 3/4/2019 P/U liner V to 4723.46. Close annular & pressure up to 250 PSI to verity seal assembly in liner tie -back. UD joint #118, M/U landing joint, hanger and crossovers to circulate. Sting in first seals leaving ports open. 135K PU / 120K SO.,PJSM, Establish circ from annulus to tubing. Good. Line up and pump 74 bbl corrosion inhibitor & 65 bbl Diesel freeze protect.. 2 BPM, with final circ 700 psi. Strip in and land hanger on depth. Bleed down annulus and open annular. Suck back diesel with LRS. RID circ lines and UD Landing Joint.,M/U Pack off running tool and run pack off. set down 10K. RILD & test void to 500/5000 psi 10 min. Good.,Line up to LRS & test T' X 9 5/8 Annulus to 1000 psi for 30 min. Good. Bleed down and Continue to R/U SLB tec spooler.,Clear rig floor of T' Equipment. R/U SLB Tec wire equipment. Bring 160 Cannon clamps to the rig floor. R/U 3-1/2" hydraulic tongs, slips and elevators.,M/U 3-1/2" pup joint w/ wireline entry guide, 6 joints of 3-1/2" 9.3# L-80 EUE tubing, HES XN nipple assy, 1 joint 3-1/2" tubing, HES 3-1/2"x7" retrievable packer,1 joint of 3-1/2" tubing, HES X nipple assy and SLB sliding sleeve and gauges to 352'. Torque to 2800 fUlbs with Doyon casing double stack tongs. 16.5 bbls lost / 11 BPH rate.,Terminate TEC wire and attempt to pressure test- leaking. Re -terminate TEC wire and pressure test to 5000 PSI - good test. 10.9 bbls lost/ 11 BPH rate.,Continue to run 3-1/2" Jet Pump completion on 3-1/2" 9.3# L-80 EUE tubing from the derrick f/ 352't' 4709' as per tally. Torque to 2800 fUlbs with Doyon casing double stack tongs. Install 145 cross coupler Cannon clamp at every connection and four half clamps: two on gauge assy & two on GLM. 71.8 bbls lost/ 12 BPH rate.,C/O elevators & PIU 5" drill pipe landing joint. M/U XO subs & FMC 11"x3-1/2" tubing hanger. Perform TEC wire penetrations through hanger. Land 3-12" completion on hanger. 76K PU, 71 K SO, 31K on hanger. Final pressure gauge readings. Intake: 1953.94 PSI, 66.81', Discharge: 1949.56 PSI, 66.69°. Run in lock down screws. 9 BPH loss rate.,Drop ball (1.31") & rod. R/U circulating head, hoses & chart recorder. Pressure up to 3700 PSI on the tubing, 9 stks. Set packer &testtubing for 30 min. Bleed tubing to 2200 PSI. Pressure up to 3600 PSI on the IA & test casing for 30 min. Tbg climbed to 2800 PSI due to compression. Bleed tubing off, shear valve in GLM @ 2230'.,Pump 2 BPM both directions through shear valve. 230 PSI down IA, 160 PSI down tubing. R/D circulating equipment & landing joint. Install 3" H BPV. Pressure test BPV to 500 PSI for 5 min.,N/D flow nipple, MPD equipment and BOP stack.,Hauled 125 bbls H2O from L -Pad lake for total = 11590 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 114 bbls cuttings/liquids to MPU G&I for total = 17211 bbls Rig Fuel (gallons): Rec'd=0, Used=1568, On hand=9125. 270 bbls daily losses, 1505 bbls cumulative losses. 3/5/2019 Continue to ND the MDP equipment and ND the BOP stack. Rack back the BOP stack on the BOP stand and secure for transport..Clean the tubing hanger. NU the tubing head adapter and tree. PT the tubing hanger void to 500 psi for 5 minutes (good test) and 5000 psi for 15 minutes (good test).,Terminate the TEC wire and MU gauge housing. Test the gauge: upper gauge = 71.77'F & 1948.37 psi and lower gauge = 71.9'F & 1952.74 psi.,RU tree testing equipment. Pull the BPV and install the TWC. SimOps: Break out the upper IBOP assembly from the top drive. Work on the mud pumps.,Fill the tree with diesel and PT to 300/5000 psi (good test).,Pull the TWC and install the BPV. Secure the tree. RD testing equipment.,PJSM. LRS PT lines to 3500 psi (good test). Circulate 90 bbls of diesel down the tubing taking returns up the IA at 2 BPM = 700 psi. Tubing = 0 psi, IA = 225 psi and OA = 0 psi.,Blow down and RD circulating lines. RD LRS. Prep to skid the rig floor.,PJSM. Skid the rig floor into moving position.,Move the rig off of well M-12 and position the rig parallel to the well row.,Remove choke and all the lines from the BOP stack. Remove the BOP stack and place on the transport cradle.,Move the rig forward to clear the BOP stack with cradle from the cellar.,Remove the BOP stand support beam. Secure the choke and kill lines to the cellar wall. Remove ODS rear tire drip pan.,Remove the ODS rear left tire. SimOps: Replace the mix pump motor. Breakout the upper IBOP.,Install the new ODS rear left fire. SimOps: MU new upper IBOP.,Hauled 0 bbis H2O from L -Pad lake for total = 11590 bbls Hauled 0 bbls heated H2O from G&I = 380 Hauled 452 bbls cuffings/liquids to MPU G&I for total = 17663 bbls 3/612019 Install BOP support beam. Install steering arm. Place the BOP stack in the cellar on the pedestal.,Finish laying mat around well M-11.,Move the over and center the rig on well M-11.,Level and shim the Hg.,PJSM. Skid the rig floor into drilling position. Release the rig from M-12.,Refer to M-11 drilling report for more information. Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 500292361900 Sperry Drilling Definitive Survey Report 26 February, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hiloorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12 Survey Calculation Method: Minimum Curvature Design: MPU M-12 Database: NORTH US+CANADA project Milne Point, ACT, MILNE POINT Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-12 Depth From (TVD) +N/ -S (usft) (usft) Well Position +N/S 0.00 usft Northing: 6,027,889.80 usft Latitude: 70' 29' 13.999 N +FJ -W 0.00 usft Easting: 533,933.89 usfl Longitude: 149° 43'21.513 W Position Uncertainty 0.00 usft Wellhead Elevation: 25.00 usfl Ground Level: 25.00 usft Inc Azi TVD TVDSS +NIS Wellbore MPU M-12 Easting DLS Section (usft) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (ft) (ft) (°/100') (`) M (nT) 0.00 User Defined 2/13/2019 16.61 81.00 57,479.00000000 Design MPU M-12 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +N/ -S (usft) (usft) 34.25 0.00 Tie On Depth: 16,009.85 +EI -W Direction (usft) (I 0.00 124.80 Survey Program Date 2/26/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 93.87 4,818.46 MPU M-12PB1 SDI SH Gyro - corrected 2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 02/13/2019 4,863.80 4,863.80 MPU M-12PB1 MWD IFR2 tied into corn 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 01/28/2019 4,920.00 16,009.85 MPU M-12PB2 MWD+IFR2+MS+Sag (2; 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 02/13/2019 16,020.00 16,723.65 MPU M-12 MWD+IFR2+MS+Sag (3) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 02/13/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 34.25 0.00 0.00 34.25 -25.00 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 UNDEFINED 93.87 0.20 253.18 93.87 34.62 -0.03 -0.10 6,027,889.77 533,933.79 0.34 -0.06 2_Gyro-NS-CT_Drill pipe (1) 96.24 0.12 265.12 96.24 36.99 -0.03 -0.11 6,027,889.77 533,933.78 3.64 -0.07 2_Gyro-NS-CT_Drill pipe (1) 100.00 0.09 279.22 100.00 40.75 -0.03 -0.11 6,027,889.77 533,933.78 1.05 -0.07 2_Gym-NS-CT_Drill pipe (1) 120.00 0.21 281.81 120.00 60.75 -0.02 -0.16 6,027,889.78 533,933.73 0.60 -0.12 2_Gym.NS-CT_Drill pipe (1) 140.00 0.31 278.22 140.00 80.75 -0.01 -0.25 6,027,889.79 533,933.64 0.51 -0.20 2_Gym-NS-CT_Drill pipe (1) 160.00 0.46 285.12 160.00 100.75 0.02 -0.38 6,027,889.82 533,933.51 0.78 -0.33 2_Gyro-NS-CT_Drill pipe (1) 180.00 0.62 285.29 180.00 120.75 0.07 -0.57 6,027,889.87 533,933.32 0.80 -0.51 2_Gyro-NS-CT_Drill pipe (1) 200.00 0.60 293.81 200.00 140.75 0.14 -0.77 6,027,889.94 533,933.12 0.46 -0.71 2_Gyro-NS-CT_Drill pipe (1) 220.00 0.58 302.43 220.00 160.75 0.24 -0.95 6,027,890.04 533,932.94 0.45 -0.92 2_Gyro-NS-CT_Drill pipe (1) 240.00 0.55 296.40 240.00 180.75 0.34 -1.12 6,027,890.13 533,932.77 0.33 -1.11 2 -Gyro -INS -CT -Drill pipe (1) 2/262019 1:37:42PM Page 2 COMPASS 5000.15 Build 91 Company: Project: Site: Well: Wellbore: Design: Survey Hilwrp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 MPU M-12 MPU M-12 Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usit True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 260.00 0.58 294.40 259.99 200.74 0.42 -1.30 6,027,890.21 533,932.59 0.18 -1.31 2_Gyro-NS-CT_Drill pipe (1) 280.00 0.73 292.37 279.99 220.74 0.51 -1.51 6,027,890.30 533,932.38 0.76 -1.53 2_Gyro-NS-CT_Drill pipe (1) 300.00 0.78 305.19 299.99 240.74 0.64 -1.74 6,027,890.43 533,932.15 0.88 -1.79 2_Gyro-NS-CT_D611 pipe (1) 320.00 0.73 310.32 319.99 260.74 0.80 -1.95 6,027,890.59 533,931.94 0.42 -2.05 2_Gyro-NS-CT_Drill pipe (1) 340.00 0.85 313.00 339.99 280.74 0.98 -2.15 6,027,890.77 533,931.74 0.63 -2.33 2_Gyro-NS-CT Dnll pipe (1) 360.00 0.92 326.40 359.99 300.74 1.22 -2.35 6,027,891.01 533,931.54 1.09 -2.62 2_Gyro-NS-CT_Drill pipe (1) 380.00 0.98 335.04 379.98 320.73 1.51 -2.51 6,027,891.29 533,931.37 0.78 -2.92 2_Gyro-NS-CT_Drill pipe (1) 400.00 1.35 352.02 399.98 340.73 1.89 -2.61 6,027,891.68 533,931.27 2.51 -3.23 2_Gyro-NS-CT_Drill pipe (1) 420.00 2.32 8.57 419.97 360.72 2.53 -2.59 6,027,892.32 533,931.29 5.48 -3.57 2_Gym-NS-CT_Drill pipe (1) 440.00 2.92 14.22 439.95 380.70 3.42 -2.40 6,027,893.21 533,931.47 3.26 -3.92 2_Gyro-NS-CT_Drill pipe (1) 460.00 3.14 17.03 459.92 400.67 4.44 -2.12 6,027,894.23 533,931.75 1.33 -0.27 2_Gyro-NS-CT_Drill pipe (1) 480.00 3.36 21.42 479.89 420.64 5.51 -1.74 6,027,895.30 533,932.12 1.66 4.57 2 Gyro-NS-CT_Drill pipe (1) 500.00 3.75 22.62 499.85 440.60 6.66 -1.28 6,027,896.45 533,932.58 1.99 4.85 2_Gyro-NS-CT_Drill pipe (1) 520.00 4.30 24.93 519.80 460.55 7.94 -0.71 6,027,897.74 533,933.15 2.87 -5.11 2_Gyro-NS-CT_Drill pipe (1) 540.00 5.26 27.06 539.73 480.48 9.44 0.03 6,027,899.24 533,933.87 4.88 -5.37 2_Gyro-NS-CT_Drill pipe (1) 560.00 6.22 28.50 559.63 500.38 11.21 0.96 6,027,901.01 533,934.80 4.85 -5.61 2_Gyro-NS-CT_Drill pipe (1) 580.00 6.85 30.12 579.50 520.25 13.19 2.07 6,027,903.00 533,935.90 3.28 -5.82 2 -GYM -NS -CT -Drill pipe (1) 600.00 7.29 31.28 599.35 540.10 15.31 3.33 6,027,905.12 533,937.15 2.31 -6.00 2_Gyro-NS-CT_Drill pipe (1) 620.00 7.80 31.75 619.17 559.92 17.55 4.71 6,027,907.37 533,938.51 2.57 -6.15 2_Gyro-NS-CT_Drill pipe (1) 640.00 8.37 32.92 638.97 579.72 19.92 6.21 6,027,909.75 533,940.01 2.97 -6.27 2_Gyro-NS-CT_Drill pipe (1) 660.00 9.05 34.00 658.74 599.49 22.45 7.88 6,027,912.28 533,941.67 3.50 -6.34 2_Gyro-NS-CT_Dnll pipe (1) 680.00 9.69 35.33 678.48 619.23 25.13 9.73 6,027,914.97 533,943.51 3.38 -6.35 2_Gyra-NS-CT_Drill pipe (1) 700.00 9.87 35.68 698.19 638.94 27.89 11.71 6,027,917.74 533,945.47 0.95 -6.30 2_Gyro-NS-CT_Drill pipe (1) 720.00 10.05 35.82 717.88 658.63 30.70 13.73 6,027,920.56 533,947.48 0.91 -6.25 2_Gyro-NS-CT_Dnll pipe (1) 740.00 10.29 37.12 737.57 678.32 33.54 15.83 6,027,923.41 533,949.56 1.66 -6.14 2_Gyro-NS-CT_Will pipe (1) 760.00 10.75 38.97 757.23 697.98 36.41 18.08 6,027,926.29 533,951.80 2.85 -5.94 2_Gyro-NS-CT_Drill pipe (1) 780.00 11.13 41.01 776.87 717.62 39.32 20.52 6,027,929.21 533,954.23 2.71 -5.59 2_Gyro-NS-CT_Drill pipe (1) 800.00 11.54 43.28 796.48 737.23 42.23 23.16 6,027,932.13 533,956.85 3.03 -5.09 2_Gyro-NS-CT_Drili pipe (1) 820.00 11.88 45.86 816.06 756.81 45.12 26.01 6,027,935.04 533,959.69 3.12 4.40 2_Gyro-NS-CT_Drill pipe (1) 840.00 12.28 48.98 835.62 776.37 47.95 29.09 6,027,937.88 533,962.76 3.83 -3.48 2_Gyr -NS-CT_Drll pipe (1) 860.00 12.60 51.58 855.15 795.90 50.70 32.40 6,027,940.65 533,966.06 3.22 -2.33 2_Gyn -NS-CT Drill pipe (1) 880.00 13.10 54.57 874.65 815.40 53.37 35.96 6,027,943.33 533,969.60 4.16 -0.93 2_Gyro-NS-CT_Dnll pipe (1) 900.00 13.73 57.57 894.11 834.86 55.96 39.81 6,027,945.93 533,973.44 4.69 0.75 2_Gyro-NS-CT_Drill pipe (1) 920.00 14.04 59.77 913.52 854.27 58.45 43.91 6,027,948.45 533,977.53 3.06 2.69 2_Gyro-NS-CT_Drill pipe (1) 940.00 14.89 61.44 932.89 873.64 60.90 48.26 6,027,950.92 533,981.87 4.73 4.87 2_Gyro-NS-CT_Drill pipe (1) 960.00 15.07 62.41 952.21 892.96 63.34 52.82 6,027,953.37 533,986.42 1.54 7.23 2 -Gyro -NS -CT -Drill pipe (1) 980.00 15.55 63.65 971.50 912.25 65.73 57.53 6,027,955.79 533,991.11 2.91 9.73 2_Gyro-NS-CT_Drill pipe (1) 1,000.00 16.31 65.22 990.73 931.48 68.10 62.48 6,027,958.18 533,996.05 4.37 12.44 2_Gyro-NS-CT_Drill pipe (1) 1,020.00 17.36 67.30 1,009.87 950.62 70.43 67.78 6,027,960.53 534,001.34 6.05 15.47 2 -Gyro -NS -CT -Drill pipe (1) 1,040.00 17.93 68.53 1,028.93 969.68 72.70 73.40 6,027,962.83 534,006.95 3.41 18.78 2_Gyro-NS-CT_Drill pipe (1) 2262019 1:37:42PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12 Survey Calculation Method: Minimum Curvature Design: MPU M-12 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E1 -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/11001) (ft) Survey Tool Name 1,060.00 18.43 68.97 1,047.93 988.68 74.97 79.22 6,027,965.12 534,012.76 2.59 22.26 2_Gyro-NS-CT_Drill pipe (1) 1,080.00 19.21 70.30 1,066.86 1,007.61 77.21 85.27 6,027,967.39 534,018.79 4.45 25.95 2_Gyn-NS-CT_Drill pipe (1) 1,100.00 19.99 71.10 1,085.71 1,026.46 79.43 91.60 6,027,969.64 534,025.12 4.12 29.89 2_Gyro-NS-CT_Drill pipe (1) 1,120.00 20.72 71.73 1,104.46 1,045.21 81.64 98.19 6,027,971.88 534,031.70 3.81 34.04 2_Gyro-NS-CT_Dnll pipe (1) 1,140.00 21.20 72.10 1,123.13 1,063.88 83.86 104.99 6,027,974.13 534,038.49 2.49 38.35 2_Gyro-NS-CT_Drill pipe (1) 1,160.00 21.54 72.49 1,141.76 1,082.51 86.08 111.93 6,027,976.38 534,045.42 1.84 42.79 2_Gym-NS-CT_Drill pipe (1) 1,180.00 21.84 72.12 1,160.34 1,101.09 88.33 118.98 6,027,978.66 534,052.45 1.65 47.29 2_Gym-NS-CT_Drill pipe (1) 1,200.00 22.06 72.19 1,178.89 1,119.64 90.62 126.09 6,027,980.98 534,059.56 1.11 51.82 2_Gyr-NS-CT_Drll pipe (1) 1,220.00 22.22 72.43 1,197.42 1,138.17 92.91 133.27 6,027,983.31 534,066.73 0.92 56.41 2_Gyr-NS-CT_Dnll pipe (1) 1,240.00 22.13 72.42 1,215.94 1,156.69 95.19 140.47 6,027,985.62 534,073.91 0.45 61.02 2_Gyro-NS-CT_Drill pipe (1) 1,260.00 22.19 72.55 1,234.46 1,175.21 97.46 147.66 6,027,987.92 534,081.09 0.39 65.63 2_Gym.NS-CT_Drill pipe (1) 1,280.00 22.06 72.41 1,252.99 1,193.74 99.72 154.85 6,027,990.22 534,088.27 0.70 70.24 2 -Gym -NS -CT Drill pipe(1) 1,300.00 22.05 72.35 1,271.52 1,212.27 102.00 162.01 6,027,992.53 534,095.41 0.12 74.82 2_Gym-NS-CT_Drill pipe (1) 1,320.00 22.01 72.30 1,290A6 1,230.81 104.28 169.15 6,027,994.84 534,102.55 0.22 79.39 2_Gym-NS-CT_Dnll pipe (1) 1,340.00 21.85 72.30 1,308.62 1,249.37 106.55 176.27 6,027,997.14 534,109.65 0.80 83.94 2_Gym-NS-CT_Dnll pipe (1) 1,360.00 21.90 72.56 1,327.18 1,267.93 108.80 183.37 6,027,999.42 534,116.75 0.55 88.49 2_Gyra-NS-CT_Drill pipe (1) 1,380.00 21.68 72.55 1,345.75 1,286.50 111.02 190.46 6,028,001.68 534,123.82 1.10 93.03 2_Gyro-NS-CT_Drill pipe (1) 1,400.00 21.84 72.69 1,364.32 1,305.07 113.24 197.53 6,028,003.93 534,130.88 0.84 97.58 2_Gyr-NS-CT_Drill pipe (1) 1,420.00 21.98 72.81 1,382.88 1,323.63 115.45 204.66 6,028,OO6.17 534,138.00 0.73 102.17 2_Gyro-NS-CT_Drill pipe (i) 1,440.00 22.08 73.14 1,401.42 1,342.17 117.65 211.83 6,028,008.40 534,145.16 0.80 106.80 2_Gyro-NS-CT_Drill pipe (1) 1,460.00 22.22 73.33 1,419.94 1,360.69 119.82 219.05 6,028,010.61 534,152.37 0.79 111.49 2_Gyn-NS-CT_Drill pipe (1) 1,480.00 22.20 73.50 1,438.46 1,379.21 121.98 226.30 6,028,012.80 534,159.61 0.34 116.21 2_Gyro-NS-CT_Drill pipe (1) 1,500.00 22.37 73.54 1,456.96 1,397.71 124.13 233.57 6,028,014.98 534,166.87 0.85 120.95 2_Gyro-NS-CT_Drill pipe (1) 1,520.00 22.57 74.12 1,475.45 1,416.20 126.26 240.91 6,028,017.14 534,174.20 1.49 125.77 2_Gym-NS-CT_Drill pipe (1) 1,540.00 22.47 73.96 1,493.92 1,434.67 128.36 248.28 6,028,019.28 534,181.55 0.59 130.61 2_Gyro-NS-CT_Drill pipe (1) 1,560.00 22.13 73.77 1,512.42 1,453.17 130.47 255.57 6,028,021.43 534,188.83 1.74 135.40 2_Gyro-NS-CT_Drill pipe (1) 1,580.00 21.94 74.07 1,530.96 1,471.71 132.55 262.78 6,028,023.54 534,196.03 1.10 140.13 2_Gym-NS-CT_Drill pipe (1) 1,600.00 21.71 74.16 1,549.53 1,490.28 134.59 269.93 6,028,025.60 534,203.17 1.16 144.84 2 Gym-NS-CT_Drill pipe (1) 1,620.00 21.36 73.88 1,568.13 1,508.68 136.61 276.99 6,028,027.66 534,210.22 1.82 149.48 2_Gyro-NS-CT_Drill pipe (1) 1,640.00 21.06 73.91 1,586.78 1,527.53 138.62 283.94 6,028,029.70 534,217.16 1.50 154.05 2_Gyro-NS-CT_Drill pipe (1) 1,660.00 20.59 73.76 1,605.47 1,546.22 140.60 290.77 6,028,031.71 534,223.98 2.37 158.52 2 Gyro-NS-CT_Drill pipe (1) 1.680.00 20.29 73.08 1,624.21 1,564.96 142.59 297.46 6,028,033.73 534,230.67 1.91 162.88 2_Gym-NS-CT_Drill pipe (1) 1,700.00 19.93 72.70 1,642.99 1,583.74 144.61 304.03 6,028,035.78 534,237.23 1.91 167.13 2_Gyro-NS-CT_Drill pipe (1) 1,720.00 19.62 72.40 1,661.81 1,602.56 146.64 310.49 6,028,037.84 534,243.68 1.63 171.27 2_Gyro-NS-CT_Drill pipe (1) 1,740.00 19.22 71.72 1,680.68 1,621.43 148.69 316.81 6,028,039.92 534,249.99 2.30 175.29 2_Gym-NS-CT_Drill pipe (1) 1,760.00 18.87 71.45 1,699.58 1,640.33 150.75 323.01 6,028,042.01 534,256.17 1.80 17920 2_Gyro-NS-CT_Drill pipe (1) 1,780.00 18.89 71.14 1,718.51 1,659.26 152.82 329.14 6,028,044.11 534,262.29 0.51 183.05 2_Gyro-NS-CT_Drill pipe (1) 1,800.00 18.91 71.26 1,737.43 1,678.18 154.91 335.27 6,028,046.22 534,268.42 0.22 186.90 2_Gyro.NS-CT_Drill pipe (1) 1,820.00 18.73 70.92 1,756.36 1,697.11 157.00 341.37 6,028,048.34 534,274.51 1.05 190.71 2 Gyro-NS-CT_Drill pipe (1) 1,840.00 18.94 71.00 1,775.29 1,716.04 159.11 347.48 6,028,050.48 534,280.60 1.06 194.52 2_Gyro-NS-CT_Dnll pipe (1) 2/262019 1:37:42PM Page 4 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: MPU M-12 Design: MPU M-12 Survey MD Inc (usft) V) 1,860.00 19.25 1,880.00 19.19 1,900.00 19.46 1,920.00 19.67 1,940.00 19.74 1,960.00 19.97 1,980.00 20.20 2,000.00 20.01 2,020.00 20.26 2,040.00 20.51 2,060.00 20.x4 2,080.00 21.20 2,100.00 21.38 2,120.00 21.72 2,140.00 21.87 2,160.00 22.03 2,180.00 22.00 2,200.00 21.98 2,220.00 22.18 2,240.00 22.04 2,260.00 21.62 2,280.00 21.47 2,300.00 21.35 2,320.00 21.28 Azi 71.21 71.69 71.85 72.33 72.39 72.99 73.23 73.02 73.68 73.56 72.75 71.80 71.65 71.38 70.91 70.27 69.22 68.91 68.59 TVD (usft) 1,794.19 1,813.07 1,831.95 1,850.79 1,869.62 1,888.43 1,907.21 1,926.00 1,944.77 1,963.52 1,982.23 2,000.90 2,019.54 2,038.14 2,056.71 2,075.26 2,093.80 2,112.35 2,130.88 TVDSS (usft) 1,734.94 1,753.82 1,772.70 1,791.54 1,810.37 1,829.18 1,847.96 1,866.75 1,885.52 1,904.27 1,922.98 1,941.65 1,960.29 1,978.89 1,997.46 2,016.01 2,034.55 2,053.10 2,071.63 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 190.68 193.17 195.76 198.44 201.16 68.90 2,149.41 Map +NIS +E1 -W Northing (usft) (usft) (ft) 161.23 353.67 6,028,052.62 163.32 359.91 6,028,054.75 165.39 366.20 6,028,056.85 167.45 372.57 6,028,058.93 169.50 378.99 6,028,061.01 171.52 385.48 6,028,063.06 173.51 392.05 6,028,065.08 175.51 398.63 6,028,067.11 177.48 405.23 6,028,069.11 179.45 411.91 6,028,071.10 181.49 418.67 6,028,073.18 183.68 425.50 6,028,075.40 185.95 432.40 6,028,077.71 188.28 439.36 6,028,080.07 190.68 193.17 195.76 198.44 201.16 68.90 2,149.41 2,090.16 203.89 70.04 2,167.97 2,108.72 206.50 70.64 2,186.58 2,127.33 208.97 70.79 2,205.20 2,145.95 211.38 71.00 2,223.83 2,164.58 213.76 2,340.00 20.93 70.88 2,242.49 2,183.24 2,360.00 20.49 70.63 2,261.20 2,201.95 2,380.00 20.37 70.53 2,279.94 2,220.69 2,400.00 20.30 70.66 2,298.69 2,239.44 2,420.00 20.39 70.71 2,317.44 2,258.19 2,440.00 20.53 70.90 2,336.18 2,276.93 2,460.00 20.71 70.63 2,354.90 2,295.65 2,480.00 20.77 71.11 2,373.60 2,314.35 2,500.00 20.93 71.11 2,392.29 2,333.04 2,520.00 21.04 71.20 2,410.97 2,351.72 2,540.00 20.96 71.40 2,429.64 2,370.39 2,560.00 20.86 71.52 2,448.32 2,389.07 2,580.00 20.74 71.79 2,467.02 2,407.77 2,600.00 20.77 71.86 2,485.72 2,426.47 2,620.00 20.55 71.80 2,504.43 2,445.18 2,640.00 20.12 72.06 2,523.19 2,463.94 216.11 218.45 220.77 223.08 225.38 227.67 229.99 232.32 234.62 236.93 239.23 241.50 243.74 245.95 248.15 250.30 446.39 6,028,082.50 453.44 6,028,085.01 460.48 6,028,087.64 467.47 6,028,090.35 474.48 6,028,093.11 481.49 6,028,095.87 488.46 6,028,098.51 495.37 6,028,101.01 502.26 6,028,103.45 509.13 6,028,105.86 515.94 6,028,108.24 522.62 6,028,110.61 529.20 6,028,112.96 535.76 6,028,115.30 542.32 6,028,117.63 548.92 6,028,119.95 555.57 6,028,122.30 562.26 6,028,124.66 569.00 6,028,126.99 575.78 6,028,129.33 582.57 6,028,131.66 589.33 6,028,133.96 596.07 6,028,136.23 602.81 6,028,138.47 609.51 6,028,140.70 616.12 6,028,142.89 Well MPU M-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°I100-) (ft) Survey Tool Name 534,286.78 1.59 198.40 2_Gyro-NS-CT_Drill pipe (1) 534,293.01 0.85 202.33 2_Gyro-NS-CT_Drill pipe (1) 534,299.29 1.38 206.31 2_Gyro-NS-CT_Drill pipe (1) 534,305.65 1.32 210.37 2_Gyro-NS-CT_Dn1l pipe (1) 534,312.07 0.36 214.48 2_Gyro-NS-CT_Drill pipe (1) 534,318.54 1.54 218.65 2_Gyro-NS-CT_Drill pipe (1) 534,325.11 1.22 222.91 2_Gyro-NS-CT_Drill pipe (1) 534,331.68 1.02 227.17 2_Gyro-NS-CT_Drill pipe (1) 534,338.26 1.69 231.46 2_Gyro-NS-CT_Drill pipe (1) 534,344.94 1.27 235.83 2_Gyro-NS-CT_Drill pipe (1) 534,351.68 2.18 240.21 2_Gyro-NS-CT_Drill pipe (1) 534,358.51 2.48 244.57 2_Gyro-NS-CT_Drill pipe (1) 534,365.39 0.94 248.94 2_Gyro-NS-CT_Drill pipe (1) 534,372.35 1.77 253.33 2_Gyro-NS-CT_Dnll pipe (1) 534,379.36 1.15 257.73 2 Gyro-NS-CT_Drill pipe (1) 534,386.40 1.44 262.10 2_Gyro-NS-CT_Drill pipe (1) 534,393.42 1.97 266.39 2_Gyro-NS-CT Drill pipe (1) 534,400.40 0.59 270.61 2_Gyro-NS-CT_Drill pipe (1) 534,407.40 1.17 274.81 2_Gyro-NS-CT_Drill pipe (1) 534,414.40 0.91 279.01 2_Gyro-NS-CT_Drill pipe (1) 534,421.35 2.98 283.24 2_Gyro-NS-CT_Drill pipe (1) 534,428.25 1.33 287.51 2_Gyro-NS-CT_Drill pipe (1) 534,435.13 0.66 291.79 2_Gyro-NS-CT_Dn1l pipe (1) 534,441.99 0.52 296.08 2_Gyro-NS-CT_Drill pipe (1) 534,448.79 1.76 300.32 2_Gyro-NS-CT_Dri1l pipe (1) 534,455.45 2.24 304.48 2_Gyro-NS-CT_Drill pipe (1) 534,462.03 0.62 308.56 2_Gyro-NS-CT_Drill pipe (1) 534,468.57 0.42 312.62 2_Gyro-NS-CT_Drill pipe (1) 534,475.12 0.46 316.70 2_Gyro-NS-CT_Drill pipe (1) 534,481.71 0.77 320.81 2_Gyro-NS-CT_Drill pipe (1) 534,488.35 1.02 324.95 2 -Gyro -NS -CT Drill pipe (1) 534,495.03 0.90 329.12 2_Gyro-NS-CT_Drill pipe (1) 534,501.76 0.80 333.33 2_Gyro-NS-CT_Ddil pipe (1) 534,508.52 0.57 337.58 2_Gyro-NS-CT_Drill pipe (1) 534,515.30 0.54 341.84 2_Gyro-NS-CT_Drill pipe (1) 534,522.06 0.54 346.10 2_Gyro-NS-CT_Drill pipe (1) 534,528.79 0.77 350.36 2_Gyro-NS-CT_Dnll pipe (1) 534,535.51 0.19 354.63 2 Gyro-NS-CT_Drill pipe (1) 534,542.20 1.11 358.88 2_Gyro-NS-CT_Drill pipe (1) 534,548.80 2.20 363.07 2_Gyro-NS-CT_Dnll pipe (1) 2262019 1:37:42PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: MPU M-12 Design: MPU M-12 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (`) (1) (usft) (usft) (usft) 2,660.00 19.89 71.98 2,541.98 2,482.73 252.42 2,680.00 19.76 72.10 2,560.80 2,501.55 254.51 2,700.00 19.84 72.26 2,579.61 2,520.36 256.58 2,720.00 20.16 72.17 2,598.41 2,539.16 258.67 2,740.00 20.26 72.29 2,617.18 2,557.93 260.78 2,760.00 20.42 72.56 2,635.93 2,576.68 262.88 2,780.00 20.54 72.64 2,654.66 2,595.41 264.97 2,800.00 20.55 72.64 2,673.39 2,614.14 267.06 2,820.00 20.74 72.64 2,692.11 2,632.86 269.17 2,840.00 20.92 72.82 2,710.80 2,651.55 271.28 2,860.00 20.93 72.68 2,729.48 2,670.23 273.40 2,880.00 20.94 72.45 2,748.16 2,688.91 275.54 2,900.00 20.80 72.33 2,766.85 2,707.60 277.69 2,920.00 20.99 72.35 2,785.53 2,726.28 279.86 2,940.00 21.06 71.97 2,804.20 2,744.95 282.06 2,960.00 21.32 71.75 2,822.85 2,763.60 284.31 2,980.00 21.84 72.09 2,841.45 2,782.20 286.59 3,000.00 22.29 73.16 2,859.98 2,800.73 288.83 3,020.00 23.06 74.62 2,878.44 2,819.19 290.97 3,040.00 23.70 76.14 2,896.80 2,837.55 292.97 3,060.00 24.18 77.09 2,915.08 2,855.83 294.85 3,080.00 24.23 77.90 2,933.32 2,874.07 296.63 3,100.00 24.17 79.08 2,951.56 2,892.31 298.26 3,120.00 24.19 80.79 2,969.81 2,910.56 299.69 3,140.00 24.29 82.33 2,988.04 2,928.79 300.90 3,160.00 24.38 83.09 3,006.27 2,947.02 301.94 3,180.00 24.30 84.05 3,024.49 2,965.24 302.87 3,200.00 24.63 85.61 3,042.69 2,983.44 303.61 3,220.00 24.80 87.67 3,060.86 3,001.61 304.10 3,240.00 25.06 89.71 3,079.00 3,019.75 304.29 3,260.00 25.42 91.53 3,097.09 3,037.84 304.20 3,280.00 25.90 92.75 3,115.12 3,055.87 303.88 3,300.00 26.76 94.35 3,133.04 3,073.79 303.33 3,320.00 27.88 95.90 3,150.81 3,091.56 302.50 3,340.00 28.91 96.68 3,168.40 3,109.15 301.46 3,360.00 29.47 97.26 3,185.86 3,126.61 300.28 3,380.00 30.24 98.23 3,203.21 3,143.96 298.93 3,400.00 31.29 98.96 3,220.39 3,161.14 297.40 3,420.00 32.70 99.75 3,237.36 3,178.11 295.68 3,440.00 33.94 100.43 3,254.07 3,194.82 293.75 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US + CANADA 2262019 1:37.42PM Page 6 COMPASS 5000.15 Build 91 Map Map vertical +E/ -W Northing Easting DLS Section (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 622.63 6,028,145.03 534,555.30 1.16 367.21 2_Gyro-NS-CT_Drill pipe (1) 629.08 6,028,147.15 534,561.74 0.68 371.32 2_Gyro-NS-CT_Drill pipe (1) 635.53 6,028,149.25 534,568.18 0.48 375.43 2_Gyro-NS-CT_Drill pipe (1) 642.04 6,028,151.37 534,574.68 1.61 379.59 2_Gyro-NS-CT_Drill pipe (1) 648.62 6,028,153.51 534,581.25 0.54 383.79 2_Gyro-NS-CT_Drill pipe (1) 655.25 6,028,155.64 534,58T87 0.93 388.03 2_Gyro-NS-CT_Drill pipe (1) 661.93 6,028,157.76 534,594.54 0.62 392.32 2_Gyro-NS-CT_Drill pipe (1) 668.63 6,028,159.89 534,601.23 0.05 396.63 2_Gyro-NS-CT_Drill pipe (1) 675.36 6,028,162.02 534,607.95 0.95 400.95 2_Gyro-NS-CT_Drill pipe (1) 682.15 6,028,164.16 534,614.73 0.96 405.32 2_Gyro-NS-CT_Drill pipe (1) 688.97 6,028,166.31 534,621.54 0.25 409.72 2_Gyro-NS-CT_Drill pipe (1) 695.79 6,028,168.48 534,628.34 0.41 414.09 2_Gyro-NS-CT_Drill pipe (1) 702.58 6,028,170.67 534,635.13 0.73 418.44 2_Gyro-NS-CT_Drill pipe (1) 709.38 6,028,172.86 534,641.91 0.95 422.78 2_Gyro-NS-CT_Drill pipe (1) 716.21 6,028,175.09 534,648.73 0.77 427.14 2_Gyro-NS-CT_D411 pipe (1) 723.08 6,028,177.38 534,655.59 1.36 431.50 2 -Gyro -NS -CT Drill pipe (1) 730.07 6,028,179.69 534,662.57 2.67 435.93 2_Gyro-NS-CT_Drill pipe (1) 737.24 6,028,181.97 534,669.73 3.02 440.54 2_Gyro-NS-CT_DO pipe (1) 744.65 6,028,184.14 534,677.13 4.77 445.40 2_Gyro-NS-CT_Drill pipe (1) 752.33 6,028,186.17 534,684.80 4.40 450.57 2 Gyro-NS-CT_DnIl pipe (1) 760.22 6,028,188.09 534,692.68 3.08 455.98 2_Gyro-NS-CT_Drill pipe (1) 768.23 6,028,189.90 534,700.68 1.68 461.54 2_Gyro-NS-CT_Drill pipe (1) 776.26 6,028,191.57 534,708.70 2.44 467.20 2_Gyro-NS-CT_Drill pipe (1) 784.32 6,028,193.04 534,716.76 3.50 473.01 2 Gyro-NS-CT_Drill pipe (1) 792.45 6,028,194.28 534,724.88 3.20 478.99 2_Gyro-NS-CT_Drill pipe (1) 800.62 6,028,195.36 534,733.05 1.63 485.11 2_Gyro-NS-CT_Drill pipe (1) 808.81 6,028,196.32 534,741.23 2.02 491.30 2 Gyro-NS-CT_Dnll pipe (1) 817.06 6,028,197.11 534,749.48 3.63 497.65 2_Gyro-NS-CT_Dnll pipe (1) 825.41 6,028,197.64 534,757.82 4.39 504.23 2_Gyro-NS-CT_Drill pipe (1) 833.83 6,028,197.87 534,766.24 4.49 511.04 2_Gyro-NS-CT_Drill pipe (1) 842.36 6,028,197.81 534,774.77 4.28 518.09 2_Gyro-NS-CT Drill pipe (1) 851.01 6,028,197.53 534,783.43 3.57 525.38 2_Gyro-NS-CT_Drill pipe (1) 859.87 6,028,197.02 534,792.28 5.57 532.97 2_Gyro-NS-CT_Drill pipe (1) 869.01 6,028,196.24 534,801.42 6.63 540.94 2_Gyro-NS-CT_Drill pipe (1) 878.46 6,028,195.24 534,810.88 5.47 549.30 2_Gyro-NS-CT_Drill pipe (1) 888.14 6,028,194.10 534,820.57 3.14 557.93 2_Gyro-N8-CT_Drill pipe (1) 898.01 6,028,192.80 534,830.44 4.54 566.79 2_Gyro-NS-CT_Drill pipe (1) 908.12 6,028,191.31 534,840.56 5.57 575.97 2_Gyro-NS-CT_Drill pipe (1) 918.58 6,028,189.64 534,851.02 7.35 585.54 2_Gyro-NS-CT_Drill pipe (1) 929.39 6,028,187.76 534,861.84 6.48 595.52 2_Gyro-NS-CT_Drill pipe (1) 2262019 1:37.42PM Page 6 COMPASS 5000.15 Build 91 Survey Map Map MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') 3,460.00 34.68 101.16 3,270.59 3,211.34 291.64 940.47 6,028,185.70 534,872.92 4.23 3,480.00 35.45 102.08 3,286.96 3,227.71 289.33 951.72 6,028,183.44 534,884.19 4.67 3,500.00 36.37 102.87 3,303.16 3,243.91 286.79 963.18 6,028,180.96 534,895.65 5.15 3,520.00 37.21 103.69 3,319.17 3,259.92 284.04 974.83 6,028,178.26 534,907.32 4.87 3,540.00 37.73 104.35 3,335.05 3,275.80 281.09 986.64 6,028,175.36 534,919.14 3.28 3,560.00 37.95 104.79 3,350.84 3,291.59 278.01 998.51 6,028,172.33 534,931.02 1.74 3,580.00 38.85 105.58 3,366.52 3,307.27 274.75 1,010.50 6,028,169.13 534,943.03 5.13 3,600.00 40.03 106.57 3,381.96 3,322.71 271.23 1,022.71 6,028,165.67 534,955.25 6.69 3,620.00 41.14 107.36 3,397.15 3,337.90 267.43 1,035.15 6,028,161.93 534,967.71 6.12 3,640.00 41.88 107.91 3,412.13 3,352.88 263.42 1,047.78 6,028,157.97 534,980.36 4.12 3,660.00 42.52 108.48 3,426.94 3,367.69 259.22 1,060.55 6,028,153.83 534,993.14 3.73 3,680.00 43.14 109.04 3,441.61 3,382.36 254.85 1,073.42 6,028,149.52 535,006.03 3.64 3,700.00 44.20 109.74 3,456.08 3,396.83 250.26 1,086.45 6,028,144.99 535,019.08 5.82 3,720.00 44.36 110.05 3,470.40 3,411.15 245.51 1,099.58 6,028,140.30 535,032.23 1.35 3,740.00 44.68 110.32 3,484.66 3,425.41 240.67 1,112.74 6,028,135.52 535,045.41 1.86 3,760.00 45.12 110.97 3,498.82 3,439.57 235.70 1,125.95 6,028,130.61 535,058.64 3.18 3,780.00 45.80 111.41 3,512.85 3,453.60 230.54 1,139.24 6,028,125.52 535,071.95 3.74 3,800.00 46.24 111.99 3,526.74 3,467.49 225.22 1,152.61 6,028,120.26 535,085.35 3.03 3,820.00 45.56 112.12 3,540.66 3,481.41 219.83 1,165.92 6,028,114.92 535,098.68 3.43 3,840.00 45.05 112.12 3,554.72 3,495.47 214.48 1,179.09 6,028,109.63 535,111.88 2.55 3,860.00 45.30 112.65 3,568.82 3,509.57 209.07 1,192.21 6,028,104.29 535,125.02 2.26 3,880.00 46.03 113.80 3,582.80 3,523.55 203.43 1,205.35 6,028,098.71 535,138.18 5.50 3,900.00 46.97 114.72 3,596.57 3,537.32 197.47 1,218.58 6,028,092.81 535,151.44 5.76 3,920.00 47.71 115.42 3,610.12 3,550.87 191.24 1,231.90 6,028,086.64 535,164.78 4.51 3,940.00 47.85 115.66 3,623.56 3,564.31 184.85 1,245.27 6,028,080.31 535,178.18 1.13 3,960.00 48.83 115.85 3,636.85 3,577.60 178.36 1,258.72 6,028,073.88 535,191.66 4.95 3,980.00 50.26 116.34 3,649.83 3,590.58 171.66 1,272.39 6,028,067.25 535,205.36 7.39 4,000.00 52.46 116.69 3,662.32 3,603.07 164.69 1,286.37 6,028,060.34 535,219.36 11.08 4,020.00 54.41 117.00 3,674.23 3,614.98 157.44 1,300.70 6,028,053.15 535,233.73 9.83 4,040.00 55.79 117.14 3,685.67 3,626.42 149.97 1,315.30 6,028,045.76 535,248.37 6.92 4,060.00 57.15 117.32 3,696.72 3,637.47 142.34 1,330.13 6,028,038.20 535,263.22 6.84 4,080.00 58.55 117.57 3,707.36 3,648.11 134.54 1,345.15 6,028,030.46 535,278.28 7.08 4,100.00 59.22 117.90 3,717.70 3,658.45 126.57 1,360.31 6,028,022.56 535,293.47 3.64 4,120.00 59.94 118.19 3,727.83 3,668.58 118.46 1,375.53 6,028,014.52 535,308.73 3.81 4,140.00 60.11 118.60 3,737.82 3,678.57 110.22 1,390.77 6,028,006.36 535,324.01 1.97 4,160.00 60.14 119.27 3,747.78 3,688.53 101.83 1,405.95 6,027,998.04 535,339.22 2.91 4,180.00 60.50 119.93 3,757.68 3,698.43 93.25 1,421.06 6,027,989.52 535,354.37 3.39 4,200.00 60.37 120.05 3,767.55 3,708.30 84.55 1,436.12 6,027,980.90 535,369.47 0.83 4,220.00 60.19 120.19 3,777.47 3,718.22 75.84 1,451.15 6,027,972.25 535,384.53 1.09 4,240.00 60.59 120.33 3,787.35 3,728.10 67.08 1,466.17 6,027,963.56 535,399.59 2.09 Vertical Section (ft) Survey Tool Name 605.82 2_Gyr -NS-CT D611 pipe (1) 616.38 2_Gyro-NS-CT_Drill pipe (1) 627.23 2_Gyro-NS-CT_Drill pipe (1) 638.38 2_Gyro-NS-CT_Dnll pipe (1) 649.75 2_Gyro-NS-CT_Drill pipe (1) 661.26 2_Gyro-NS-CT_Drill pipe (1) 572.97 2_Gyro-NS-CT_Drill pipe (1) 685.00 2_Gyro-NS-CT Drill pipe (1) 697.39 2_Gym-NS-CT_Drill pipe (1) 710.05 2 -GYM -NS -CT Drill pipe (1) 722.92 2_Gyro-NS-CT_Dril1 pipe (1) 735.99 2_Gyro-NS-CT_Drill pipe (1) 749.30 2_Gyro-NS-CT_Drill pipe (1) 762.80 2_Gyro-NS-CT_Drill pipe (1) 776.37 2_Gyro.NS.CT_Drill pipe (1) 790.06 2_Gyro-NS-CT_Drill pipe (1) 803.91 2_Gyro-NS-CT_Drill pipe (1) 817.93 2_Gyro-NS-CT_Drill pipe (1) 831.94 2 Gyro-NS-CT_Drill pipe (1) 845.81 2_Gyro-NS-CT_Drill pipe (1) 859.66 2_Gyro-NS-CT_Drill pipe (1) 873.67 2_Gyro-NS-CT_Dnll pipe (1) 887.94 2_Gyro-NS-CT_Drill pipe (1) 902.43 2_Gym-NS-CT_Drill pipe (1) 917.05 2_Gyro-NS-CT_Drill pipe (1) 931.81 2_Gym-NS-CT_Drill pipe (1) 946.85 2_Gyro-NS-CT_Drill pipe (1) 962.31 2_Gyro-NS-CT_Drill pipe (1) 978.22 2_Gyro-NS-CT_Drill pipe (1) 994.47 2_Gyro.NS-CT_Drill pipe (1) 1,011.00 2_Gyro-NS-CT_Drill pipe (1) 1,027.79 2_Gyro-NS-CT_D611 pipe (1) 1,044.78 2_Gyno-NS-CT_Drill pipe (1) 1,061.91 2_Gym-NS-CT_Drill pipe (1) 1,079.13 2_Gyno-NS-CT_Drill pipe (1) 1,096.38 2_Gyro-NS-CT_Drill pipe (1) 1,113.68 2_Gyro-NS-CT_Drill pipe (1) 1,131.02 2_Gyro-NS-CT_Drill pipe (1) 1,148.33 2_Gyro-NS-CT_Drill pipe (1) 1,165.66 2_Gyro-NS-CT_Dnllpipe(1) 2262019 1:37.42PM Page 7 COMPASS 5000.15 Build 91 Halliburton I Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12 Survey Calculation Method: Minimum Curvature Design: MPU M-12 Database: NORTH US+CANADA Survey Map Map MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') 3,460.00 34.68 101.16 3,270.59 3,211.34 291.64 940.47 6,028,185.70 534,872.92 4.23 3,480.00 35.45 102.08 3,286.96 3,227.71 289.33 951.72 6,028,183.44 534,884.19 4.67 3,500.00 36.37 102.87 3,303.16 3,243.91 286.79 963.18 6,028,180.96 534,895.65 5.15 3,520.00 37.21 103.69 3,319.17 3,259.92 284.04 974.83 6,028,178.26 534,907.32 4.87 3,540.00 37.73 104.35 3,335.05 3,275.80 281.09 986.64 6,028,175.36 534,919.14 3.28 3,560.00 37.95 104.79 3,350.84 3,291.59 278.01 998.51 6,028,172.33 534,931.02 1.74 3,580.00 38.85 105.58 3,366.52 3,307.27 274.75 1,010.50 6,028,169.13 534,943.03 5.13 3,600.00 40.03 106.57 3,381.96 3,322.71 271.23 1,022.71 6,028,165.67 534,955.25 6.69 3,620.00 41.14 107.36 3,397.15 3,337.90 267.43 1,035.15 6,028,161.93 534,967.71 6.12 3,640.00 41.88 107.91 3,412.13 3,352.88 263.42 1,047.78 6,028,157.97 534,980.36 4.12 3,660.00 42.52 108.48 3,426.94 3,367.69 259.22 1,060.55 6,028,153.83 534,993.14 3.73 3,680.00 43.14 109.04 3,441.61 3,382.36 254.85 1,073.42 6,028,149.52 535,006.03 3.64 3,700.00 44.20 109.74 3,456.08 3,396.83 250.26 1,086.45 6,028,144.99 535,019.08 5.82 3,720.00 44.36 110.05 3,470.40 3,411.15 245.51 1,099.58 6,028,140.30 535,032.23 1.35 3,740.00 44.68 110.32 3,484.66 3,425.41 240.67 1,112.74 6,028,135.52 535,045.41 1.86 3,760.00 45.12 110.97 3,498.82 3,439.57 235.70 1,125.95 6,028,130.61 535,058.64 3.18 3,780.00 45.80 111.41 3,512.85 3,453.60 230.54 1,139.24 6,028,125.52 535,071.95 3.74 3,800.00 46.24 111.99 3,526.74 3,467.49 225.22 1,152.61 6,028,120.26 535,085.35 3.03 3,820.00 45.56 112.12 3,540.66 3,481.41 219.83 1,165.92 6,028,114.92 535,098.68 3.43 3,840.00 45.05 112.12 3,554.72 3,495.47 214.48 1,179.09 6,028,109.63 535,111.88 2.55 3,860.00 45.30 112.65 3,568.82 3,509.57 209.07 1,192.21 6,028,104.29 535,125.02 2.26 3,880.00 46.03 113.80 3,582.80 3,523.55 203.43 1,205.35 6,028,098.71 535,138.18 5.50 3,900.00 46.97 114.72 3,596.57 3,537.32 197.47 1,218.58 6,028,092.81 535,151.44 5.76 3,920.00 47.71 115.42 3,610.12 3,550.87 191.24 1,231.90 6,028,086.64 535,164.78 4.51 3,940.00 47.85 115.66 3,623.56 3,564.31 184.85 1,245.27 6,028,080.31 535,178.18 1.13 3,960.00 48.83 115.85 3,636.85 3,577.60 178.36 1,258.72 6,028,073.88 535,191.66 4.95 3,980.00 50.26 116.34 3,649.83 3,590.58 171.66 1,272.39 6,028,067.25 535,205.36 7.39 4,000.00 52.46 116.69 3,662.32 3,603.07 164.69 1,286.37 6,028,060.34 535,219.36 11.08 4,020.00 54.41 117.00 3,674.23 3,614.98 157.44 1,300.70 6,028,053.15 535,233.73 9.83 4,040.00 55.79 117.14 3,685.67 3,626.42 149.97 1,315.30 6,028,045.76 535,248.37 6.92 4,060.00 57.15 117.32 3,696.72 3,637.47 142.34 1,330.13 6,028,038.20 535,263.22 6.84 4,080.00 58.55 117.57 3,707.36 3,648.11 134.54 1,345.15 6,028,030.46 535,278.28 7.08 4,100.00 59.22 117.90 3,717.70 3,658.45 126.57 1,360.31 6,028,022.56 535,293.47 3.64 4,120.00 59.94 118.19 3,727.83 3,668.58 118.46 1,375.53 6,028,014.52 535,308.73 3.81 4,140.00 60.11 118.60 3,737.82 3,678.57 110.22 1,390.77 6,028,006.36 535,324.01 1.97 4,160.00 60.14 119.27 3,747.78 3,688.53 101.83 1,405.95 6,027,998.04 535,339.22 2.91 4,180.00 60.50 119.93 3,757.68 3,698.43 93.25 1,421.06 6,027,989.52 535,354.37 3.39 4,200.00 60.37 120.05 3,767.55 3,708.30 84.55 1,436.12 6,027,980.90 535,369.47 0.83 4,220.00 60.19 120.19 3,777.47 3,718.22 75.84 1,451.15 6,027,972.25 535,384.53 1.09 4,240.00 60.59 120.33 3,787.35 3,728.10 67.08 1,466.17 6,027,963.56 535,399.59 2.09 Vertical Section (ft) Survey Tool Name 605.82 2_Gyr -NS-CT D611 pipe (1) 616.38 2_Gyro-NS-CT_Drill pipe (1) 627.23 2_Gyro-NS-CT_Drill pipe (1) 638.38 2_Gyro-NS-CT_Dnll pipe (1) 649.75 2_Gyro-NS-CT_Drill pipe (1) 661.26 2_Gyro-NS-CT_Drill pipe (1) 572.97 2_Gyro-NS-CT_Drill pipe (1) 685.00 2_Gyro-NS-CT Drill pipe (1) 697.39 2_Gym-NS-CT_Drill pipe (1) 710.05 2 -GYM -NS -CT Drill pipe (1) 722.92 2_Gyro-NS-CT_Dril1 pipe (1) 735.99 2_Gyro-NS-CT_Drill pipe (1) 749.30 2_Gyro-NS-CT_Drill pipe (1) 762.80 2_Gyro-NS-CT_Drill pipe (1) 776.37 2_Gyro.NS.CT_Drill pipe (1) 790.06 2_Gyro-NS-CT_Drill pipe (1) 803.91 2_Gyro-NS-CT_Drill pipe (1) 817.93 2_Gyro-NS-CT_Drill pipe (1) 831.94 2 Gyro-NS-CT_Drill pipe (1) 845.81 2_Gyro-NS-CT_Drill pipe (1) 859.66 2_Gyro-NS-CT_Drill pipe (1) 873.67 2_Gyro-NS-CT_Dnll pipe (1) 887.94 2_Gyro-NS-CT_Drill pipe (1) 902.43 2_Gym-NS-CT_Drill pipe (1) 917.05 2_Gyro-NS-CT_Drill pipe (1) 931.81 2_Gym-NS-CT_Drill pipe (1) 946.85 2_Gyro-NS-CT_Drill pipe (1) 962.31 2_Gyro-NS-CT_Drill pipe (1) 978.22 2_Gyro-NS-CT_Drill pipe (1) 994.47 2_Gyro.NS-CT_Drill pipe (1) 1,011.00 2_Gyro-NS-CT_Drill pipe (1) 1,027.79 2_Gyro-NS-CT_D611 pipe (1) 1,044.78 2_Gyno-NS-CT_Drill pipe (1) 1,061.91 2_Gym-NS-CT_Drill pipe (1) 1,079.13 2_Gyno-NS-CT_Drill pipe (1) 1,096.38 2_Gyro-NS-CT_Drill pipe (1) 1,113.68 2_Gyro-NS-CT_Drill pipe (1) 1,131.02 2_Gyro-NS-CT_Drill pipe (1) 1,148.33 2_Gyro-NS-CT_Drill pipe (1) 1,165.66 2_Gyro-NS-CT_Dnllpipe(1) 2262019 1:37.42PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: MPU M-12 Design: MPU M-12 Survey MD Inc Azi TVD TVDSS +Nl-S (usft) V) V) (usft) (usft) (usft) 4,260.00 62.05 120.48 3,796.95 3,737.70 58.20 4,280.00 63.70 120.91 3,806.07 3,746.82 49.11 4,300.00 64.87 121.32 3,814.74 3,755.49 39.80 4,320.00 65.50 121.54 3,823.14 3,763.89 30.33 4,340.00 66.68 121.76 3,831.24 3,771.99 20.74 4,360.00 67.90 121.93 3,838.96 3,779.71 11.00 4,380.00 69.12 122.18 3,846.29 3,787.04 1.13 4,400.00 69.67 122.49 3,853.33 3,794.08 -8.89 4,420.00 70.13 122.75 3,860.20 3,800.95 -19.01 4,440.00 71.25 122.98 3,866.82 3,807.57 -29.25 4,460.00 72.35 123.27 3,873.06 3,813.81 -39.64 4,480.00 73.04 123.35 3,879.01 3,819.76 -50.12 4,500.00 73.06 123.49 3,884,84 3,825.59 -60.66 4,520.00 73.56 123.65 3,890.59 3,831.34 -71.25 4,540.00 74.36 123.87 3,896.11 3,836.86 -81.93 4,560.00 74.92 123.92 3,901.41 3,642.16 -92.69 4,580.00 75.11 123.96 3,906.58 3,847.33 -103.48 4,600.00 75.12 124.09 3,911.72 3,852.47 -114.29 4,620.00 75.49 124.42 3,916.79 3,857.54 -125.18 4,640.00 76.87 4,660.00 78.38 4,680.00 79.87 4,700.00 80.97 4,720.00 81.84 4,740.00 83.21 4,760.00 84.32 4,780.00 85.44 4,800.00 86.35 4,818.46 87.71 4,863.80 90.49 4,920.00 89.64 4,972.70 88.89 5,067.57 87.35 5,161.83 87.04 5,257.72 87.35 5,353.38 88.41 5,448.47 91.81 5,544.36 93.41 5,639.63 90.37 5,734.29 90.01 124.79 3,921.57 3,862.32 -136.21 125.36 3,925.86 3,866.61 -147.44 125.62 3,929.63 3,870.38 -158.84 125.74 3,932.96 3,873.71 -170.34 125.96 3,935.95 3,876.70 -181.92 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +EI -W Northing (usft) (ft) 1,481.30 6,027,954.75 1,496.60 6,027,945.73 1,512.03 6,027,936.49 1,527.52 6,027,927.10 1,543.08 6,027,917.57 1,558.76 6,027,907.91 1,574.53 6,027,898.11 1,590.35 6,027,888.17 1,606.17 6,027,878.12 1,622.02 6,027,867.95 1,637.93 6,027,857.64 1,653.89 6,027,847.23 1,669.86 6,027,836.77 1,685.82 6,027,826.25 1,701.80 6,027,815.64 1,717.81 6,027,804.96 1,733.83 6,027,794.25 1,749.85 6,027,783.50 1,765.84 6,027,772.69 1,781.83 6,027,761.73 1,797.82 6,027,750.58 1,813.81 6, 027, 739.25 1,829.83 6,027,727.83 1,845.85 6,027,716.32 126.29 3,938.55 3,879.30 -193.61 1,861.87 6,027,704.70 126.83 3,940.72 3,881.47 -205.46 1,877.84 6,027,692.93 127.21 3,942.51 3,883.26 -217.45 1,893.75 6,027,681.01 127.30 3,943.94 3,884.69 -229.53 1,909.62 6,027,669.01 127.31 3,944.89 3,885.64 -240.70 1,924.29 6,027,657.91 126.55 3,945.61 3,886.36 -267.93 1,960.52 6,027,630.84 128.42 3,945.54 3,886.29 -302.13 2,005.12 6,027,596.85 127.20 3,946.22 3,886.97 -334.44 2,046.75 6,027,564.74 126.98 3,949.33 3,890.08 -391.62 2,122.38 6,027,507.91 126.97 3,953.94 3,894.69 -448.24 2,197.59 6,027,451.63 126.78 3,958.64 3,899.39 -505.72 2,274.21 6,027,394.52 125.76 3,962.17 3,902.92 -562.27 2,351.28 6,027,338.32 124.62 3,961.99 3,902.74 -617.06 2,428.98 6,027,283.89 123.53 3,957.62 3,898.37 -670.72 2,508.32 6,027,230.59 120.50 3,954.48 3,895.23 -721.19 2,589.04 6,027,180.50 120.89 3,954.17 3,894.92 -769.51 2,670.43 6,027,132.56 Well MPU 10-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US+CANADA Map vertical Easting DLS Section (ft) (°1100') (ft) Survey Tool Name 535,414.76 T33 1,183.15 2_Gym-NS-CT_Will pipe (1) 535,430.11 8.47 1,200.91 2_Gyro-NS-CT_Drill pipe (1) 535,445.57 6.13 1,218.89 2_Gyro-NS-CT_Drill pipe (1) 535,461.11 3.30 1,237.01 2 -Gyro -NS -CT -Drill pipe (1) 535,476.71 5.99 1,255.27 2_Gyr0-NS-CT_Dn11 pipe (1) 535,492.43 6.15 1,273.69 2_Gym-NS-CT_Drill pipe (1) 535,508.24 6.21 1,292.28 2_Gym-NS-CT_Drill pipe (1) 535,524.10 3.11 1,310.98 2_Gym-NS-CT_DAll pipe (1) 535,539.97 2.60 1,329.75 2_Gyro-NS-CT_Dnll pipe (1) 535,555.87 5.70 1,348.62 2 -GYM -NS -CT -Drill pipe (1) 535,571.82 5.67 1,367.61 2_Gyro-NS-GT_Drill pipe (1) 535,587.83 3.47 1,386.69 2_Gyro-NS-CT_Drill pipe (1) 535,603.84 0.68 1,405.82 2_Gyno-NS-CT_Drill pipe (1) 535,619.85 2.61 1,424.97 2_Gyro-NS-CT_Drill pipe (1) 535,635.88 4.14 1,444.19 2_Gyro-NS-CT_Dn11 pipe (1) 535,651.93 2.81 1,463.47 2_Gyro-NS-CT_DHII pipe (1) 535,668.01 0.97 1,482.79 2_Gyro-NS-CT_Drill pipe (1) 535,684.07 0.63 1,502.12 2_Gyro-NS-CT_Drill pipe (1) 535,700.11 2.44 1,521.46 2_Gyro-NS-CT_Drill pipe (1) 535,716.15 7.13 1,540.88 2_Gym-NS-CT_Driil pipe (1) 535,732.18 8.05 1,560.42 2_Gyro-NS-CT_Drill pipe (1) 535,748.22 7.56 1,580.06 2_Gyro-NS-CT_Drill pipe (1) 535,764.29 5.53 1,599.78 2_Gyro-NS-CT_Dnll pipe (1) 535,780.37 4.48 1,619.55 2_Gym-NS-CT_Drill pipe (1) 535,796.44 7.04 1,639.37 2_Gyro-NS-CT_Drill pipe (1) 535,812.46 6.16 1,659.24 2_Gym-NS-CT_Drlll pipe (1) 535,828.42 5.91 1,679.15 2_Gyro-NS-CT_Drill pipe (1) 535,844.35 4.57 1,699.08 2_Gyro-NS-CT_Drill pipe (1) 535,859.07 7.37 1,717.50 2_Gyro-NS-CT_DHII pipe (1) 535,895.42 6.36 1,762.79 2_MWD+IFR2+MS+Sag (2) 535,940.16 3.65 1,818.93 2_MWD+IFR2+MS+Sag (3) 535,981.94 2.72 1,871.55 2_MWD+IFR2+MS+Sag (3) 536,057.83 1.64 1,966.29 2_MWD+IFR2+MS+S2g(3) 536,133.29 0.33 2,060.37 2_MWD+IFR2+MS+Sag(3) 536,210.16 0.38 2,156.08 2_MWD+IFR2+MS+Sag(3) 536,287.48 1.54 2,251.64 2_MWD+IFR2+MS+Sag (3) 536,365.42 3.77 2,346.72 2_MWD+IFR2+MS+Sag (3) 536,444.99 2.02 2,442.49 2_MWD+IFR2+MS+Sag (3) 536,525.93 4.50 2,537.58 2_MWD+IFR2+MS+Sag (3) 536,607.54 0.56 2,631.99 2_MWD+IFR2+MS+Sag(3) 2262019 1:3742PM Page 8 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU Mt -12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well; MPU M-12 North Reference: True Wellbore: MPU M-12 Survey Calculation Method: Minimum Curvature Design: MPU M-12 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting OLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,830.13 90.81 122.55 3,953.48 3,894.23 -819.90 2,751.95 6,027,082.55 536,689.28 1.92 2,727.69 2_MWD+IFR2+MS+Sag(3) 5,925.47 88.89 122.09 3,953.73 3,894.48 -870.87 2,832.52 6,027,031.95 536,770.07 2.07 2,822.93 2_MWD+IFR2+MS+Sag (3) 6,021.15 87.23 121.12 3,956.97 3,897.72 -920.98 2,913.95 6,026,982.22 536,851.73 2.01 2,918.41 2_MWD+IFR2+MS+Sag (3) 6,116.58 89.89 121.82 3,959.37 3,900.12 -970.78 2,995.31 6,026,932.79 536,933.31 2.88 3,013.64 2_MWD+IFR2+MS+Sag(3) 6,211.94 90.01 122.84 3,959.45 3,900.20 -1,021.77 3,075.89 6,026,882.17 537,014.11 1.08 3,108.91 2_MWD+IFR2+MS+Sag(3) 6,307.01 88.59 122.86 3,960.61 3,901.36 -1,073.34 3,155.75 6,026,830.98 537,094.19 1.49 3,203.91 2_MWD+IFR2+MS+Sag(3) 6,402.72 88.16 122.58 3,963.33 3,904.08 -1,125.05 3,236.24 6,026,779.63 537,174.91 0.54 3,299.52 2_MWD+IFR2+MS+Sag(3) 6,497.84 90.07 124.61 3,964.80 3,905.55 -1,177.67 3,315.46 6,026,727.38 537,254.36 2.93 3,394.60 2_MWD+IFR2+MS+Sag (3)M 6,593.25 91.86 126.78 3,963.19 3,903.94 -1,233.33 3,392.92 6,026,672.09 537,332.07 2.95 3,489.97 2_WD+IFR2+MS+Sag(3) 6,688.30 91.86 127.69 3,960.11 3,900.86 -1,290.81 3,468.56 6,026,614.95 537,407.96 0.96 3,584.89 2_MWD+IFR2+MS+Sag(3) 6,736.37 91.06 127.59 3,958.88 3,899.63 -1,320.16 3,506.61 6,026,585.78 537,446.14 1.68 3,632.88 2_MWD+IFR2+MS+Sag(3) 6,783.87 90.87 127.73 3,958.08 3,898.83 -1,349.17 3,544.21 6,026,556.94 537,483.87 0.50 3,680.32 2_MWD+IFR2+MS+Sag (3) 6,818.18 90.69 127.68 3,957.61 3,898.36 -1,370.16 3,571.35 6,026,536.09 537,511.10 0.54 3,714.58 2 MWD+IFR2+MS+Sag (3) 6,879.45 90.32 126.50 3,957.07 3,897.82 -1,407.10 3,620.22 6,026,499.37 537,560.14 2.02 3,775.80 2_MWD+IFR2+MS+Sag (3) 6,925.37 91.68 125.86 3,956.27 3,897.02 -1,434.21 3,657.28 6,026,472.43 537,597.31 3.27 3,821.69 2_MWD+IFR2+MS+Sag(3) 6,973.89 92.05 125.76 3,954.69 3,895.44 -1,462.58 3,696.61 6,026,444.24 537,636.77 0.79 3,870.18 2_MWD+IFR2+MS+Sag(3) 7,015.33 91.93 125.20 3,953.25 3,894.00 -1,486.62 3,730.33 6,026,420.36 537,670.60 1.38 3,911.59 2_MWD+IFR2+MS+Sag (3) 7,069.88 91.92 125.24 3,951.42 3,892.17 -1,518.06 3,774.87 6,026,389.13 537,715.28 0.08 3,966.11 2_MWD+IFR2+MS+Sag (3) 7,107.10 91.80 124.27 3,950.21 3,890.96 -1,539.27 3,805.43 6,026,368.06 537,745.93 2.62 4,003.31 2_MWD+IFR2+MS+Sag (3) 7,164.94 90.31 124.21 3,949.15 3,889.90 -1,571.81 3,853.24 6,026,335.75 537,793.88 2.58 4,061.14 2_MWD+IFR2+MS+Sag(3) 7,208.39 89.88 124.24 3,949.08 3,889.83 -1,596.24 3,889.17 6,026,311.47 537,829.91 0.99 4,104.58 2_MWD+IFR2+MS+Sag(3) 7,257.54 90.44 125.30 3,948.94 3,889.69 -1,624.27 3,929.54 6,026,283.63 537,870.41 2.44 4,153.73 2_MWD+IFR2+MS+Sag(3) 7,353.69 89.58 126.52 3,948.92 3,889.67 -1,680.66 4,007.41 6,026,227.60 537,948.53 1.55 4,249.86 2_MWD+IFR2+MS+Sag (3) 7,450.79 89.39 127.69 3,949.80 3,890.55 -1,739.24 4,084.85 6,026,169.39 538,026.23 1.22 4,346.88 2_MWD+IFR2+MS+Sag (3) 7,545.60 88.21 124.72 3,951.78 3,892.53 -1,795.22 4,161.32 6,026,113.76 538,102.95 3.37 4,441.63 2_MWD+IFR2+MS+Sag(3)M 7,641.29 90.51 123.41 3,952.85 3,893.60 -1,848.81 4,240.58 6,026,060.54 538,182.45 2.77 4,537.29 2_WD+IFR2+MS+Sag(3) 7,736.01 90.13 122,64 3,952.32 3,893.07 -1,900.43 4,320.00 6,026,009.28 538,262.09 0.91 4,631.97 2_MWD+IFR2+MS+Sag (3) 7,831.79 89.76 122.42 3,952.41 3,893.16 -1,951.94 4,400.75 6,025,958.15 538,343.07 0.45 4,727.67 2_MWD+IFR2+MS+Sag(3)M 7,878.48 89.82 122.05 3,952.58 3,893.33 -1,976.84 4,440.24 6,025,933.43 538,382.67 0.80 4,774.31 2_WD+IFR2+MS+Sag (3) 7,927.53 90.82 121.49 3,952.31 3,893.06 -2,002.67 4,481.94 6,025,907.80 538,424.48 2.34 4,823.29 2_MWD+IFR2+MS+Sag(3) 7,974.10 90.81 120.49 3,951.65 3,892.40 -2,026.64 4,521.86 6,025,884.01 538,464.50 2.15 4,869.76 2_MWD+IFR2+MS+Sag(3) 8,022.18 90.19 120.66 3,951.23 3,891.98 -2,051.10 4,563.25 6,025,859.74 538,506.00 1.34 4,917.70 2_MWD+IFR2+MS+Sag (3) 8,067.57 89.70 119.68 3,951.27 3,892.02 -2,073.91 4,602.49 6,025,837.11 538,545.34 2.41 4,962.94 2_MWD+IFR2+MS+Sag (3) 8,117.48 89.14 118.86 3,951.78 3,892.53 -2,098.31 4,646.03 6,025,812.92 538,588.99 1.99 5,012.62 2_MWD+IFR2+MS+Sag (3) 8,213.21 87.29 119.11 3,954.76 3,895.51 -2,144.68 4,729.72 6,025,766.94 538,672.88 1.95 5,107.81 2_MWD+IFR2+MS+Sag(3) 8,308.40 87.23 121.70 3,959.31 3,900.06 -2,192.79 4,811.72 6,025,719.20 538,755.09 2.72 5,202.60 2_MWD+IFR2+MS+Sag(3) 8,403.82 87.42 124.35 3,963.76 3,904.51 -2,244.74 4,891.63 6,025,667.63 538,835.23 2.78 5,297.86 2_MWD+IFR2+MS+Sag (3) 8,499.33 87.29 126.59 3,968.17 3,908.92 -2,300.10 4,969.33 6,025,612.63 538,913.17 2.35 5,393.26 2_MWD+IFR2+MS+Sag(3) 8,591.63 88.41 126.18 3,971.63 3,912.38 -2,354.81 5,043.58 6,025,558.26 538,987.66 1.29 5,485.45 2 MWD+IFR2+MS+Sag (3) 8,689.33 89.15 126.73 3,973.71 3,914.46 -2,412.85 5,122.14 6,025,500.59 539,066.48 0.94 5,583.09 2_MWD+IFR2+MS+Sag(3) 2/262019 1:37:42PM Page 9 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: MPU M-12 Design: MPU M-12 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +Nl-S +El -W Northing (usft) (1) (") (usft) (usft) (usft) (usft) (ft) 8,784.91 89.21 126.04 3,975.08 3,915.83 -2,469.54 5,199.08 6,025,444.25 8,877.61 90.44 125.40 3,975.37 3,916.12 -2,523.66 5,274.34 6,025,390.48 8,973.20 91.37 125.59 3,973.86 3,914.61 -2,579.15 5,352.16 6,025,335.35 9,070.64 89.70 124.57 3,972.95 3,913.70 -2,635.15 5,431.89 6,025,279.72 9,165.86 91.31 125.06 3,972.11 3,912.86 -2,689.51 5,510.06 6,025,225.72 9,261.49 89.14 124.95 3,971.73 3,912.48 -2,744.36 5,588.39 6,025,171.23 9,356.37 89.39 124.64 3,972.95 3,913.70 -2,798.50 5,666.29 6,025,117.46 9,452.61 89.45 123.85 3,973.92 3,914.67 -2,852.66 5,745.85 6,025,063.67 9,546.70 89.14 123.63 3,975.08 3,915.83 -2,904.91 5,824.08 6,025,011.78 9,642.43 89.58 123.77 3,976.15 3,916.90 -2,958.02 5,903.72 6,024,959.03 9,739.35 91.12 123.53 3,975.56 3,916.31 -3,011.73 5,984.40 6,024,905.71 9,832.49 92.91 123.39 3,972.28 3,913.03 -3,063.05 6,062.05 6,024,854.75 9,92924 93.60 124.01 3,966.79 3,907.54 -3,116.64 6,142.41 6,024,801.53 10,024.33 91.18 124.92 3,962.82 3,903.57 -3,170.40 6,220.73 6,024,748.13 10,120.16 91.18 125.34 3,960.85 3,901.60 -3,225.53 6,299.09 6,024,693.36 10,215.78 90.81 127.31 3,959.19 3,899.94 -3,282.16 6,376.11 6,024,637.09 10,280.79 89.57 127.34 3,958.97 3,899.72 -3,321.58 6,427.81 6,024,597.91 10,308.98 89.76 127.57 3,959.14 3,899.89 -3,338.72 6,450.19 6,024,580.87 10,355.19 90.13 128.87 3,959.18 3,899.93 -3,367.31 6,486.49 6,024,552.45 10,407.41 90.38 130.09 3,958.95 3,899.70 -3,400.51 6,526.79 6,024,519.44 10,451.70 89.70 129.71 3,958.92 3,899.67 -3,428.92 6,560.77 6,024,491.19 10,503.09 90.20 129.24 3,958.97 3,899.72 -3,461.59 6,600.44 6,024,458.70 10,598.65 90.94 125.05 3,958.01 3,898.76 -3,519.28 6,676.59 6,024,401.37 10,641.02 90.81 122.78 3,957.37 3,898.12 -3,542.92 6,711.74 6,024,377.89 10,694.05 89.32 122.12 3,957.31 3,898.06 -3,571.37 6,756.49 6,024,349.65 10,742.79 88.40 122.36 3,958.28 3,899.03 -3,597.36 6,797.71 6,024,323.84 10,788.27 88.39 121.35 3,959.55 3,900.30 -3,621.36 6,836.32 6,024,300.03 10,835.34 89.15 122.32 3,960.56 3,901.31 -3,646.18 6,876.30 6,024,275.39 10,884.99 89.70 122.55 3,961.06 3,901.81 -3,672.81 6,918.21 6,024,248.96 10,980.49 90.50 125.53 3,960.89 3,901.64 -3,726.26 6,997.33 6,024,195.87 11,028.97 90.44 126.81 3,960.49 3,901.24 -3,754.87 7,036.47 6,024,167.44 11,076.45 89.88 125.68 3,960.36 3,901.11 -3,782.94 7,074.76 6,024,139.55 11,121.83 90.44 124.57 3,960.24 3,900.99 -3,809.05 7,111.87 6,024,113.61 11,171.58 90.38 123.52 3,959.88 3,900.63 -3,836.90 7,153.09 6,024,085.95 11,218.73 90.57 123.55 3,959.49 3,900.24 -3,862.95 7,192.39 6,024,060.09 11,266.86 89.57 123.61 3,959.43 3,900.18 -3,889.57 7,232.49 6,024,033.65 11,315.90 88.21 122.84 3,960.38 3,901.13 -3,916.43 7,273.51 6,024,006.98 11,361.80 86.60 122.40 3,962.46 3,903.21 -3,941.15 7,312.13 6,023,982.44 11,457.14 87.17 121.95 3,967.64 3,908.39 -3,991.84 7,392.70 6,023,932.12 11,505.31 87.04 121.93 3,970.07 3,910.82 -4,017.29 7,433.53 6,023,906.86 Well MPU M-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°1100') (ft) Survey Tool Name 539,143.67 0.72 5,678.62 2_MWD+IFR2+MS+Sag (3) 539,219.17 1.50 5,771.31 2_MWD+IFR2+MS+Sag (3) 539,297.23 0.99 5,866.88 2_MWD+IFR2+MS+Sag (3) 539,377.21 2.01 5,964.31 2_MWD+IFR2+MS+Sag (3) 539,455.62 1.77 6,059.52 2_MWD+IFR2+MS+Sag (3) 539,534.19 2.27 6,155.14 2_MWD+IFR2+MS+Sag(3) 539,612.33 0.42 6,250.02 2_MWD+IFR2+MS+Sag (3) 539,692.12 0.82 6,346.25 2_MWD+IFR2+MS+Sag (3) 539,770.59 0.40 6,440.31 2_MWD+IFR2+MS+Sag(3) 539,850.46 0.48 6,536.02 2_MWD+IFR2+MS+Sag(3) 539,931.37 1.61 6,632.91 2_MWD+IFR2+MS+Sag (3) 540,009.25 1.93 6,725.97 2_MWD+IFR2+MS+Sag(3) 540,089.85 0.96 6,822.54 2_MWD+IFR2+MS+Sag(3) 540,168.41 2.72 6,917.54 2_MWD+IFR2+MS+Sag(3) 540,247.01 0.44 7,013.35 2_MWD+IFR2+MS+Sag(3) 540,324.28 2.10 7,108.91 2_MWD+IFR2+MS+Sag(3) 540,376.15 1.91 7,173.86 2_MWD+IFR2+MS+Sag(3) 540,398.60 1.06 7,202.02 2_MWD+IFR2+MS+Sag(3) 540,435.03 2.92 7,248.15 2 MWD+IFR2+MS+Sag(3) 540,475.49 2.38 7,300.19 2_MWD+IFR2+MS+Sag (3) 540,509.59 1.76 7,344.30 2_MWD+IFR2+MS+Sag(3) 540,549.40 1.34 7,395.52 2_MWD+IFR2+MS+Sag(3) 540,625.81 4.45 7,490.98 2_MWD+IFR2+MS+Sag(3) 540,661.07 5.37 7,533.33 2_MWD+IFR2+MS+Sag (3) 540,705.94 3.07 7,586.32 2_MWD+IFR2+MS+Sag (3) 540,747.27 1.95 7,635.00 2_MWD+IFR2+MS+Sag (3) 540,785.99 2.22 7,680.40 2_MWD+IFR2+MS+Sag (3) 540,826.08 2.62 7,727.40 2_MWD+IFR2+MS+Sag(3) 540,868.10 1.20 7,777.00 2_MWD+IFR2+MS+Sag 13) 540,947.46 3.23 7,872.48 2 MWD+IFR2+MS+Sag(3) 540,986.72 2.64 7,920.94 2_MWD+IFR2+MS+Sag(3) 541,025.14 2.66 7,968.41 2_MWD+IFR2+MS+Sag(3) 541,062.37 2.74 8,013.79 2_MWD+IFR2+MS+Sag(3) 541,103.71 2.11 8,063.53 2_MWD+IFR2+MS+Sag(3) 541,143.12 0.41 8,110.67 2_MWD+IFR2+MS+Sag(3) 541,183.34 2.08 8,158.78 2_MWD+IFR2+MS+Sag(3) 541,224.47 3.19 8,207.80 2_MWD+IFR2+MS+Sag(3) 541,263.20 3.64 8,253.61 2_MWD+IFR2+MS+Sag(3) 541,344.00 0.76 8,348.71 2_MWD+IFR2+MS+Sag(3) 541,384.94 0.27 8,396.76 2_MWD+IFR2+MS+Sag(3) 2/262019 1:37:42PM Page 10 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: MPU M-12 Design: MPU M-12 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) 11,552.77 87.11 122.30 3,972.49 3,913.24 -4,042.49 7,473.67 6,023,881.85 11,599.10 87.48 122.49 3,974.68 3,915.43 -4,067.29 7,512.75 6,023,857.23 11,648.20 87.73 123.06 3,976.73 3,917.48 -4,093.84 7,554.00 6,023,830.87 11,744.18 86.98 123.56 3,981.16 3,921.91 -4,146.50 7,634.12 6,023,778.59 11,838.48 88.28 11,887.78 88.09 11,934.78 88.90 11,985.56 89.15 12,029.95 90.01 12,124.82 90.32 12,219.73 89.27 12,268.75 90.38 12,314.52 91.50 12,409.07 90.87 123.27 123.49 123.63 123.71 125.09 126.07 123.97 124.33 125.04 126.14 3,985.06 3,925.81 -4,198.38 7,712.77 6,023,727.07 3,986.62 3,927.37 4,225.49 7,753.91 6,023,700.15 3,987.86 3,928.61 4,251.46 7,793.06 6,023,674.36 3,988.72 3,929.47 4,279.61 7,835.32 6,023,646.40 3,989.05 3,929.80 4,304.69 7,871.94 6,023,621.49 Well MPU M-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°I100-) (ft) Survey Tool Name 541,425.19 0.79 8,444.11 2_MWD+IFR2+MS+Sag(3) 541,464.38 0.90 8,490.34 2_MWD+IFR2+MS+Sag (3) 541,505.74 1.27 8,539.37 2_MWD+IFR2+MS+Sag (3) 541,586.10 0.94 8,635.21 2_MWD+IFR2+MS+Sag (3) 541,664.97 1.41 8,729.40 2_MWD+IFR2+MS+Sag (3) 541,706.24 0.59 8,778.66 2_MWD+IFR2+MS+Sag(3) 541,745.50 1.75 8,825.64 2_MWD+IFR2+MS+Sag (3) 541,787.88 0.52 8,876.40 2_MWD+IFR2+MS+Sag (3) 541,824.62 3.66 8,920.79 2 MWD+IFR2+MS+Sag (3) 3,988.77 3,929.52 -4,359.89 7,949.10 6,023,566.65 541,902.02 3,989.11 3,929.86 -4,414.35 8,026.82 6,023,512.55 541,979.98 3,989.26 3,930.01 4,441.87 8,067.39 6,023,485.22 542,020.66 3,988.51 3,929.26 -4,467.91 8,105.02 6,023,459.36 542,058.41 3,986.56 3,927.31 -4,522.92 8,181.89 6,023,404.70 542,135.52 12,503.21 90.19 126.17 3,985.68 3,926.43 -4,578.46 12,595.70 90.19 125.13 3,985.38 3,926.13 4,632.36 12,644.59 90.75 125.08 3,984.98 3,925.73 4,660.48 12,692.50 90.50 125.10 3,984.45 3,925.20 4,688.02 12,739.43 90.63 124.84 3,983.99 3,924.74 -4,714.92 12,786.84 90.50 125.04 3,983.52 3,924.27 -4,742.07 12,823.46 90.32 124.85 3,983.26 3,924.01 -4,763.04 12,881.43 90.32 125.12 3,982.94 3,923.69 -4,796.28 12,909.15 91.25 125.20 3,982.56 3,923.31 -4,812.24 12,976.31 92.98 125.49 3,980.08 3,920.83 4,851.06 13,020.08 92.23 125.22 3,978.09 3,918.84 4,876.36 13,069.08 92.48 125.93 3,976.08 3,916.83 4,904.85 13,114.58 91.05 126.19 3,974.68 3,915.43 4,931.62 13,165.10 90.13 125.94 3,974.16 3,914.91 4,961.36 13,214.19 89.57 125.63 3,974.28 3,915.03 4,990.06 13,259.96 87.96 126.15 3,975.27 3,916.02 -5,016.89 13,308.44 87.60 126.35 3,977.15 3,917.90 -5,045.53 13,354.76 87.48 126.18 3,979.14 3,919.89 -5,072.90 13,449.89 87.23 124.91 3,983.53 3,924.28 -5,128.15 13,544.23 89.71 125.03 3,986.05 3,926.80 -5,182.19 13,638.38 89.33 124.64 3,986.83 3,927.58 -5,235.97 13,733.66 88.46 124.37 3,988.67 3,929.42 -5,289.94 13,828.72 89.08 122.50 3,990.71 3,931.46 -5,342.30 13,922.42 87.78 122.13 3,993.28 3,934.03 5,392.37 14,017.73 88.34 124.86 3,996.51 3,937.26 -5,444.93 14,112.24 89.52 126.87 3,998.27 3,939.02 -5,500.29 8,257.90 6,023,349.52 8,333.05 6,023,295.96 8,373.05 6,023,268.03 8,412.25 6,023,240.67 8,450.70 6,023,213.95 8,489.56 6,023,186.98 8,519.58 6,023,166.15 8,567.08 6,023,133.13 8,589.74 6,023,117.27 8,644.48 6,023,078.70 8,680.14 6,023,053.57 8,719.96 6,023,025.27 8,756.72 6,022,998.67 8,797.56 6,022,969.12 8,837.38 6,022,940.60 8,874.45 6,022,913.95 8,913.52 6,022,885.49 8,950.83 6,022,858.29 9,028.15 6,022,803.40 9,105.42 6,022,749.71 9,182.70 6,022,696.29 9,261.20 6,022,642.69 9,340.51 6,022,590.70 9,419.66 6,022,541.00 9,499.09 6,022,488.80 9,575.66 6,022,433.80 542,211.77 542,287.17 542,327.29 542,366.61 542,405.18 542,444.16 542,474.27 542,521.91 542,544.64 542,599.56 542,635.33 542,675.28 542,712.16 542,753.12 542,793.07 542,830.26 542,869.45 542,906.89 542,984.45 543,061.96 543,139.48 543,218.22 543,297.75 543,377.13 543,456.79 543,533.60 1.08 9,015.65 2_MWD+IFR2+MS+Sag (3) 2.47 9,110.55 2_MWD+IFR2+MS+Sag (3) 2.38 9,159.56 2_MWD+IFR2+MS+Sag(3) 2.90 9,205.33 2_MWD+IFR2+MS+Sag (3) 1.34 9,299.84 2_MWD+IFR2+MS+Sag (3) 0.72 9,393.95 2_MWD+IFR2+MS+Sag (3) 1.12 9,486.43 2_MWD+IFR2+MS+Sag (3) 1.15 9,535.32 2_MWD+IFR2+MS+Sag(3) 0.52 9,583.23 2_MWD+IFR2+MS+Sog(3) 0.62 9,630.15 2_MWD+IFR2+MS+Sag (3) 0.50 9,677.56 2_MWD+IFR2+MS+Sag (3) 0.71 9,714.18 2_MWD+IFR2+MS+Sag(3) 0.47 9,772.15 2_MWD+IFR2+MS+Sag(3) 3.37 9,799.87 2_MWD+IFR2+MS+Sag(3) 2.61 9,866.97 2_MWD+IFR2+MS+Sag(3) 1.82 9,910.70 2_MWD+IFR2+MS+Sag(3) 1.54 9,959.65 2_MWD+IFR2+MS+Sag(3) 3.19 10,005.12 2_MWD+IFR2+MS+Sag (3) 1.89 10,055.62 2_MWD+IFR2+MS+Sag (3) 1.30 10,104.70 2_MWD+IFR2+MS+Sag (3) 3.70 10,150.45 2 MWD+IFR2+MS+Sag (3) 0.85 10,198.88 2_MWD+IFR2+MS+Sag (3) 0.45 10,245.14 2_MWD+IFR2+MS+Sag (3) 1.36 10,340.16 2_MWD+IFR2+MS+Sag (3) 2.63 10,434.46 2_MWD+IFR2+MS+Sag (3) 0.58 10,528.61 2_MWD+IFR2+MS+Sag (3) 0.96 10,623.87 2_MWD+IFR2+MS+Sag (3) 2.07 10,718.87 2_MWD+IFR2+MS+Sag(3) 1.44 10,812.45 2_MWD+IFR2+MS+Sag(3) 2.92 10,907.67 2_MWD+IFR2+MS+Sag(3) 2.47 11,002.14 2_MWD+IFR2+MS+Sag(3) 2262019 1:37:42PM Page 11 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: MPU M-12 Design: MPU M-12 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M1-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US+CANADA Checked By: Chelsea Wright M, a W, Approved By: Mitch Laird Date: 2-26-2019 2/26/2019 1:37:42PM Page 12 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Am TVD TVDSS +N/ -S +E/•W Northing Easting DLS Section (usft) C) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,206.74 89.70 127.34 3,998.92 3,939.67 -5,557.30 9,651.03 6,022,377.14 543,609.22 0.53 11,096.56 2_MWD+IFR2+MS+Sag (3) 14,301.13 90.38 126.82 3,998.85 3,939.60 -5,614.21 9,726.33 6,022,320.58 543,684.78 0.91 11,190.87 2_MWD+IFR2+MS+Sag (3) 14,396.62 89.64 125.55 3,998.83 3,939.58 -5,670.58 9,803.40 6,022,264.56 543,762.09 1.54 11,286.33 2_MWD+IFR2+MS+Sag (3) 14,490.99 86.85 125.14 4,001.72 3,942.47 -5,725.14 9,880.33 6,022,210.36 543,839.27 2.99 11,380.65 2_MWD+IFR2+MS+Sag(3) 14,584.47 88.10 126.41 4,005.84 3,946.59 -5,779.74 9,956.10 6,022,156.12 543,915.27 1.91 11,474.02 2_MWD+IFR2+MS+Sag(3) 14,681.86 86.92 126.47 4,010.07 3,950.82 -5,837.53 10,034.37 6,022,098.69 543,993.80 1.21 11,571.27 2_MWD+IFR2+MS+Sag(3) 14,776.20 88.34 126.32 4,013.97 3,954.72 -5,893.46 10,110.24 6,022,043.11 544,069.92 1.51 11,665.49 2_MWD+IFR2+MS+Sag(3) 14,871.29 88.96 127.03 4,016.21 3,956.96 -5,950.24 10,186.49 6,021,986.69 544,146.41 0.99 11,760.51 2_MWD+IFR2+MS+Sag(3) 14,965.80 87.91 126.39 4,018.79 3,959.54 -6,006.71 10,262.22 6,021,930.57 544,222.40 1.30 11,854.93 2_MWD+IFR2+MS+Sag(3) 15,060.10 86.79 123.09 4,023.16 3,963.91 -6,060.38 10,339.62 6,021,877.25 544,300.03 3.69 11,949.11 2_MWD+IFR2+MS+Sag (3) 15,154.32 90.20 122.83 4,025.63 3,966.38 -6,111.62 10,418.63 6,021,826.38 544,379.27 3.63 12,043.24 2_MWD+IFR2+MS+Sag(3) 15,248.34 90.57 122.77 4,025.00 3,965.75 -6,162.55 10,497.66 6,021,775.82 544,458.52 0.40 12,137.20 2_MWD+IFR2+MS+Sag(3) 15,344.11 88.21 120.11 4,026.02 3,966.77 -6,212.49 10,579.35 6,021,726.25 544,540.43 3.71 12,232.78 2_MWD+IFR2+MS+Sag(3) 15,438.64 89.95 120.96 4,027.54 3,968.29 -6,260.51 10,660.76 6,021,678.61 544,622.05 2.05 12,327.03 2_MWD+IFR2+MS+Sag(3) 15,534.16 88.90 124.89 4,028.49 3,969.24 -6,312.41 10,740.92 6,021,627.08 544,702.44 4.26 12,422.48 2_MWD+IFR2+MS+Sag(3) 15,629.32 89.64 126.31 4,029.71 3,970.46 -6,367.80 10,818.28 6,021,572.05 544,780.05 1.68 12,517.62 2_MWD+IFR2+MS+Sag(3) 15,724.50 92.30 127.35 4,028.10 3,968.85 -6,424.84 10,894.45 6,021,515.36 544,856.46 3.00 12,612.71 2_MWD+IFR2+MS+Sag (3) 15,817.60 91.74 125.15 4,024.81 3,965.56 -6,479.86 10,969.48 6,021,460.70 544,931.73 2.44 12,705.72 2_MWD+IFR2+MS+Sag (3) 15,914.10 92.92 124.43 4,020.89 3,961.64 -6,534.87 11,048.66 6,021,406.05 545,011.16 1.43 12,802.14 2_MWD+IFR2+MS+Sag(3) 16,009.85 93.41 124.28 4,015.60 3,956.35 -6,588.82 11,127.59 6,021,352.47 545,090.32 0.54 12,897.74 2_MWD+IFR2+MS+Sag(3) 16,020.00 93.46 124.30 4,015.00 3,955.75 -6,594.53 11,135.96 6,021,346.80 545,098.72 0.53 12,907.87 2_MWD+IFR2+MS+Sag(4) 16,102.30 90.62 124.27 4,012.07 3,952.82 -6,640.86 11,203.91 6,021,300.79 545,166.87 3.45 12,990.11 2_MWD+IFR2+MS+Sag(4) 16,199.63 90.13 125.00 4,011.43 3,952.18 -6,696.17 11,283.99 6,021,245.84 545,247.20 0.90 13,087.43 2_MWD+IFR2+MS+Sag(4) 16,293.94 88.46 125.54 4,012.59 3,953.34 -6,750.62 11,360.98 6,021,191.75 545,324.43 1.86 13,181.73 2_MWD+IFR2+MS+Sag (4) 16,389.34 88.84 125.88 4,014.84 3,955.59 -6,806.29 11,438.42 6,021,136.44 545,402.11 0.53 13,277.09 2_MWD+IFR2+MS+Sag (4) 16,483.82 88.71 126.24 4,016.86 3,957.61 -6,861.89 11,514.78 6,021,081.19 545,478.72 0.41 13,371.52 2_MWD+IFR2+MS+Sag (4) 16,577.90 87.97 125.86 4,019.58 3,960.33 -6,917.23 11,590.81 6,021,026.20 545,554.99 0.88 13,465.54 2_MWD+IFR2+MS+Sag(4) 16,672.88 87.72 125.08 4,023.15 3,963.90 -6,972.31 11,668.11 6,020,971.49 545,632.53 0.86 13,560.45 2_MWD+IFR2+MS+Sag(4) 16,723.65 87.23 124.75 4,025.39 3,966.14 -7,001.34 11,709.70 6,020,942.65 545,674.25 1.16 13,611.17 2_MWD+IFR2+MS+Sag(4) 16,792.00 87.23 124.75 4,028.69 3,969.44 -7,040.25 11,765.79 6,020,904.00 545,730.52 0.00 13,67944 PROJECTEDto TD Checked By: Chelsea Wright M, a W, Approved By: Mitch Laird Date: 2-26-2019 2/26/2019 1:37:42PM Page 12 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12PB1 500292361970 Sperry Drilling Definitive Survey Report 26 February, 2019 HALLIBURTON Sporry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual IRKS @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB1 Database: NORTH US+CANADA rroject Milne Point, ACT, MILNE POINT Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Asp Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-12 Well Position +N/ -S 0.00 usft Northing: 6,027,889.80 usfl Latitude: 70° 29'13.999 N +E/ -W 0.00 usft Easting; 533,933.89 usfl Longitude: 149° 43'21.513 W Position Uncertainty 0.00 usft Wellhead Elevation: 25.00 usfl Ground Level: 25.00 usft Wellbore MPU M-12PB1 34.25 Vertical Section: Magnetics Model Name Sample Date Declination Dip Angle Field Strength (`) (1) (nT) (usft) User Defined 2/5/2019 16.61 81.00 57,479.00000000 Design MPU M-12PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 34.25 Vertical Section: Depth From (TVD) +NIS +EI -W Direction (usft) (usft) (usft) (I 34.25 0.00 0.00 124.80 Survey Program Date 2/23/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Dale 93.87 4,818.46 MPU M-12PB1 SDI SH Gyro - corrected 2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 02/13/2019 4,863.80 5,051.75 MPU M-12PB1 MWD IFR2 tied into come 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/28/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 34.25 0.00 0.00 34.25 -25.00 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 UNDEFINED 93.87 0.20 253.18 93.87 34.62 -0.03 -0.10 6,027,889.77 533,933.79 0.34 -0.O6 2_Gyro-NS-CT_Drill pipe (1) 96.24 0.12 265.12 96.24 36.99 -0.03 -0.11 6,027,889.77 533,933.78 3.64 -0.07 2_Gym-NS-CT_Drill pipe (1) 100.00 0.09 279.22 100.00 40.75 -0.03 -0.11 6,027,889.77 533,933.78 1.05 -0.07 2_Gym-NS-CT_D611 pipe (1) 120.00 0.21 281.81 120.00 60.75 -0.02 -0.16 6,027,889.78 533,933.73 0.60 -0.12 2_Gyrc-NS-CT_Ddil pipe (1) 140.00 0.31 278.22 140.00 80.75 -0.01 -0.25 6,027,889.79 533,933.64 0.51 -0.20 2_Gym-NS-CT_Drill pipe (1) 160.00 0.46 285.12 160.00 100.75 0.02 -0.38 6,027,889.82 533,933.51 0.78 -0.33 2_Gyro-NS-CT_Drill pipe (1) 180.00 0.62 285.29 180.00 120.75 0.07 -0.57 6,027,889.87 533,933.32 0.80 -0.51 2_Gyro-NS-CT_Ddll pipe (1) 200.00 0.60 293.81 200.00 140.75 0.14 -0.77 6,027,889.94 533,933.12 0.46 -0.71 2_Gyro-NS-CT_Drill pipe (1) 220.00 0.58 302.43 220.00 160.75 0.24 -0.95 6,027,890.04 533,932.94 0.45 -0.92 2_Gyro-NS-CT_Drill pipe (1) 240.00 0.55 296.40 240.00 180.75 0.34 -1.12 6,027,890.13 533,932.77 0.33 -1.11 2_Gym-NS-CT_Drill pipe (1) 260.00 0.58 294.40 259.99 200.74 0.42 -1.30 6,027,890.21 533,932.59 0.18 -1.31 2_Gym-NS-CT_Dnll pipe (1) 280.00 0.73 292.37 279.99 220.74 0.51 -1.51 6,027,890.30 533,932.38 0.76 -1.53 2_Gyro-NS-CT_Drill pipe (1) 2262019 1:42:24PM Page 2 COMPASS 5000.15 Build 91 MD Inc Halliburton TVD TVDSS +NIS Definitive Survey Report (1) Company: Hiloorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: MA Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB1 Database: NORTH US+CANADA Survey 359.99 300.74 1.22 MD Inc Azi TVD TVDSS +NIS (usft) (1) N (usft) (usft) (usft) 300.00 0.78 305.19 299.99 240.74 0.64 320.00 0.73 310.32 319.99 260.74 0.80 340.00 0.85 313.00 339.99 280.74 0.98 360.00 0.92 326.40 359.99 300.74 1.22 380.00 0.98 335.04 379.98 320.73 1.51 400.00 1.35 352.02 399.98 340.73 1.89 420.00 2.32 8.57 419.97 360.72 2.53 440.00 2.92 14.22 439.95 380.70 3.42 460.00 3.14 17.03 459.92 400.67 4.44 480.00 3.36 21.42 479.89 420.64 5.51 500.00 3.75 22.62 499.85 440.60 6.66 520.00 4.30 24.93 519.80 460.55 7.94 540.00 5.26 27.06 539.73 480.48 9.44 560.00 6.22 28.50 559.63 500.38 11.21 580.00 6.85 30.12 579.50 520.25 13.19 600.00 7.29 31.28 599.35 540.10 15.31 620.00 7.80 31.75 619.17 559.92 17.55 640.00 8.37 32.92 638.97 579.72 19.92 660.00 9.05 34.00 658.74 599.49 22.45 680.00 9.69 35.33 678.48 619.23 25.13 700.00 9.87 35.68 698.19 638.94 27.89 720.00 10.05 35.82 717.88 658.63 30.70 740.00 10.29 37.12 737.57 678.32 33.54 760.00 10.75 38.97 757.23 697.98 36.41 780.00 11.13 41.01 776.87 717.62 39.32 800.00 11.54 43.28 796.48 737.23 42.23 820.00 11.88 45.86 816.06 756.81 45.12 Map +EI -W Northing (usft) (ft) -1.74 6,027,890.43 -1.95 6,027,890.59 -2.15 6,027,890.77 -2.35 6,027,891.01 -2.51 6,027,891.29 -2.61 6,027,891.68 -2.59 6,027,892.32 -2.40 6,027,893.21 -2.12 6,027,894.23 -1.74 6,027,895.30 -1.28 6,027,896.45 -0.71 6,027,897.74 0.03 6,027,899.24 0.96 6,027,901.01 2.07 6,027,903.00 3.33 6,027,905.12 4.71 6,027,907.37 6.21 6,027,909.75 7.88 6,027,912.28 9.73 6,027,914.97 11.71 6,027,917.74 13.73 6,027,920.56 15.83 6,027,923.41 18.08 6,027,926.29 20.52 6,027,929.21 23.16 6,027,932.13 26.01 6,027,935.04 840.00 12.28 48.98 835.62 776.37 47.95 29.09 6,027,937.88 860.00 12.60 51.58 855.15 795.90 50.70 32.40 6,027,940.65 880.00 13.10 54.57 874.65 815.40 53.37 35.96 6,027,943.33 900.00 13.73 57.57 894.11 834.86 55.96 39.81 6,027,945.93 920.00 14.04 59.77 913.52 854.27 58.45 43.91 6,027,948.45 940.00 14.89 61.44 932.89 873.64 60.90 48.26 6,027,950.92 960.00 15.07 62.41 952.21 892.96 63.34 52.82 6,027,953.37 980.00 15.55 63.65 971.50 912.25 65.73 57.53 6,027,955.79 1,000.00 16.31 65.22 990.73 931.48 68.10 62.48 6,027,958.18 1,020.00 17.36 67.30 1,009.87 950.62 70.43 67.78 6,027,960.53 1,040.00 17.93 68.53 1,028.93 969.68 72.70 73.40 6,027,962.83 1,060.00 18.43 68.97 1,047.93 988.68 74.97 79.22 6,027,965.12 1,080.00 19.21 70.30 1,066.86 1,007.61 77.21 85.27 6,027,967.39 Map Easting DLS (ft) (°1100') 533,932.15 0.88 533,931.94 0.42 533,931.74 0.63 533,931.54 1.09 533,931.37 0.78 533,931.27 2.51 533,931.29 5.48 533,931.47 3.26 533,931.75 1.33 533,932.12 1.66 533,932.58 1.99 533,933.15 2.87 533,933.87 4.88 533,934.80 4.85 533,935.90 3.28 533,937.15 2.31 533,938.51 2.57 533,940.01 2.97 533,941.67 3.50 533,943.51 3.38 533,945.47 0.95 533,947.48 0.91 533,949.56 1.66 533,951.80 2.85 533,954.23 2.71 533,956.85 3.03 533,959.69 3.12 533,962.76 3.83 533,966.06 3.22 533,969.60 4.16 533,973.44 4.69 533,977.53 3.06 533,981.87 4.73 533,986.42 1.54 533,991.11 2.91 533,996.05 4.37 534,001.34 6.05 534,006.95 3.41 534,012.76 2.59 534,018.79 4.45 Vertical Section (ft) Survey Tool Name -1.79 2_Gyro-NS-CT_Drill pipe (1) -2.05 2_Gyro-NS-CT_Drill pipe (1) -2.33 2_Gyro-NS-CT_Drill pipe (1) -2.62 2_Gyro-NS-CT_Drill pipe (1) -2.92 2_Gyro-NS-CT Drill pipe (1) -3.23 2_Gyro-NS-CT_Dri1l pipe (1) -3.57 2_Gyro-NS-CT_Drill pipe (1) -3.92 2_Gyro-NS-CT_Drill pipe (1) 4.27 2 -Gyro -NS -CT Drill pipe (1) 4.57 2_Gyro-NS-CT_Drill pipe (1) 4.85 2_Gyro-NS-CT_Drill pipe (1) -5.11 2_Gyro-NS-CT_Dnll pipe (1) -5.37 2_Gyro-NS-CT_Drill pipe (1) -5.61 2_Gyro-NS-CT_Drill pipe (1) -5.82 2_Gyro-NS-CT_Drill pipe (1) -6.00 2_Gyro-NS-CT Drill pipe (1) -6.15 2_Gyro-NS-CT_Drill pipe (1) -6.27 2_Gyro-NS-CT_Drill pipe (1) -6.34 2_Gyro-NS-CT_Drill pipe (1) -6.35 2_Gyro-NS-CT_Drill pipe (1) -6.30 2_Gyro-NS-CT_Drill pipe (1) -6.25 2_Gyro-NS-CT_Drill pipe (1) -6.14 2_Gyro-NS-CT Drill pipe (1) -5.94 2_Gyro-NS-CT_Drill pipe (1) -5.59 2_Gyro-NS-CT_Drill pipe (1) -5.09 2_Gyro-NS-CT_Drill pipe (1) 4.40 2_Gyro-NS-CT_Dr11l pipe (1) -3.48 2_Gyro-NS-CT_Drill pipe (1) -2.33 2_Gyro-NS-CT_Drill pipe (1) -0.93 2_Gyro-NS-CT_Drill pipe (1) 0.75 2_Gyro-NS-CT_D611 pipe (1) 2.69 2_Gyro-NS-CT_Drill pipe (1) 4.87 2_Gyro-NS-CT_Drill pipe (1) 7.23 2_Gyro-NS-CT_Drill pipe (1) 9.73 2_Gyro-NS-CT_Drill pipe (1) 12.44 2 -Gyro-NS-CT-Drill pipe (1) 15.47 2_Gyro-NS-CT_Drill pipe (1) 18.78 2 -Gyro -NS -CT -Drill pipe (1) 22.26 2_Gyro-NS-CT_Drill pipe (1) 25.95 2_Gyro-NS-CT_Drill pipe (1) 2262019 1 *42:24PM Page 3 COMPASS 5000.15 Build 91 2!262019 1.42:24PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 10-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) n (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 1,100.00 19.99 71.10 1,085.71 1,026.46 79.43 91.60 6,027,969.64 534,025.12 4.12 29.89 2_Gyro-NS-CT_Drill pipe (1) 1,120.00 20.72 71.73 1,104.46 1,045.21 81.64 98.19 6,027,971.88 534,031.70 3.81 34.04 2_Gyro-NS-CT_Drill pipe (1) 1,140.00 21.20 72.10 1,123.13 1,063.88 83.86 104.99 6,027,974.13 534,038.49 2.49 38.35 2_Gyro-NS-CT_Drill pipe (1) 1,160.00 21.54 72.49 1,141.76 1,082.51 86.08 111.93 6,027,976.38 534,045.42 1.84 42.79 2_Gym-NS-CT_Drill pipe (1) 1,180.00 21.84 72.12 1,160.34 1,101.09 88.33 118.98 6,027,978.66 534,052.45 1.65 47.29 2_Gym-NS-CT_Drill pipe (1) 1,200.00 22.06 72.19 1,178.89 1,119.64 90.62 126.09 6,027,980.98 534,059.56 1.11 51.82 2_Gym-NS-CT_Drill pipe (1) 1,220.00 22.22 72.43 1,197.42 1,138.17 92.91 133.27 6,027,983.31 534,066.73 0.92 56.41 2_Gym-NS-CT_Drill pipe (1) 1,240.00 22.13 72.42 1,215.94 1,156.69 95.19 140.47 6,027,985.62 534,073.91 0.45 61.02 2_Gym-NS-CT_Dri1l pipe (1) 1,260.00 22.19 72.55 1,234.46 1,175.21 97.46 147.66 6,027,987.92 534,081.09 0.39 65.63 2_Gyro-NS-CT_Drill pipe (1) 1,280.00 22.06 72.41 1,252.99 1,193.74 99.72 154.85 6,027,990.22 534,088.27 0.70 70.24 2_Gyro-NS-CT_Drill pipe (1) 1,300.00 22.05 72.35 1,271.52 1,212.27 102.00 162.01 6,027,992.53 534,095.41 0.12 74.82 2_Gyro-NS-CT_Drill pipe (1) 1,320.00 22.01 72.30 1,290.06 1,230.81 104.28 169.15 6,027,994.84 534,102.55 0.22 79.39 2_Gym-NS-CT_Drill pipe (1) 1,340.00 21.85 72.30 1,308.62 1,249.37 106.55 176.27 6,027,997.14 534,109.65 0.80 83.94 2_Gyro-NS-CT_Dnll pipe (1) 1,360.00 21.90 72.56 1,327.18 1,267.93 108.80 183.37 6,027,999.42 534,116.75 0.55 88.49 2_Gyro-NS-CT_Drill pipe (1) 1,380.00 21.68 72.55 1,345.75 1,286.50 111.02 190.46 6,028,001.68 534,123.82 1.10 93.03 2_Gym-NS-CT_Drill pipe (1) 1,400.00 21.84 72.69 1,364.32 1,305.07 113.24 197.53 6,028,003.93 534,130.88 0.84 97.58 2_Gym-NS-CT_Drill pipe (1) 1,420.00 21.98 72.81 1,382.88 1,323.63 115.45 204.66 6,028,006.17 534,138.00 0.73 102.17 2 Gyra-NS-CT_Drill pipe (1) 1,440.00 22.08 73.14 1,401.42 1,342.17 117.65 211.83 6,028,008.40 534,145.16 0.80 106.80 2_Gym-NS-CT_Drill pipe (1) 1,460.00 22.22 73.33 1,419.94 1,360.69 119.82 219.05 6,028,010.61 534,152.37 0.79 111.49 2_Gym-NS-CT_Drill pipe (1) 1,480.00 22.20 73.50 1,438.46 1,379.21 121.98 226.30 6,028,012.80 534,159.61 0.34 116.21 2_Gyro-NS-CT_Drill pipe (1) 1,500.00 22.37 73.54 1,456.96 1,397.71 124.13 233.57 6,028,014.98 534,166.87 0.85 120.95 2_Gyro-NS-CT_Ddll pipe (1) 1,520.00 22.57 74.12 1,475.45 1,416.20 126.26 240.91 6,028,017.14 534,174.20 1.49 125.77 2_Gym-NS-CT_D611 pipe (1) 1,540.00 22.47 73.96 1,493.92 1,434.67 128.36 248.28 6,028,019.28 534,181.55 0.59 130,61 2_Gym-NS-CT_Drill pipe (1) 1,560.00 22.13 73.77 1,512.42 1,453.17 130.47 255.57 6,028,021.43 534,188.83 1.74 135.40 2_Gym-NS-CT_Drill pipe (1) 1,580.00 21.94 74.07 1,530.96 1,471.71 132.55 262.78 6,028,023.54 534,196.03 1.10 140.13 2_Gym-NS-CT_Drill pipe (1) 1,600.00 21.71 74.16 1,549.53 1,490.28 134.59 269.93 6,028,025.60 534,203.17 1.16 144.84 2_Gym-NS-CT_Drill pipe (1) 1,620.00 21.36 73.88 1,568.13 1,508.88 136.61 276.99 6,028,027.66 534,210.22 1.82 149.48 2_Gym-NS-GT_Drill pipe (1) 1,640.00 21.06 73.91 1,586.78 1,527.53 138.62 283.94 6,028,029.70 534,217.16 1.50 154.05 2_Gyro-NS-CT_Drill pipe (1) 1,660.00 20.59 73.76 1,605.47 1,546.22 140.60 290.77 6,028,031.71 534,223.98 2.37 158.52 2_Gyro-NS-CT_Drill pipe (1) 1,680.00 20.29 73.08 1,624.21 1,564.96 142.59 297.46 6,028,033.73 534,230.67 1.91 162.88 2_Gyro-NS-CT_Drill pipe (1) 1,700.00 19.93 72.70 1,642.99 1,583.74 144.61 304.03 6,028,035.78 534,237.23 1.91 167.13 2_Gym-NS-CT_Drill pipe (1) 1,720.00 19.62 72.40 1,661.81 1,602.56 146.64 310.49 6,028,037.84 534,243.68 1.63 171.27 2_Gyro-NS-CT_Drill pipe (1) 1,740.00 19.22 71.72 1,680.68 1,621.43 148.69 316.81 6,028,039.92 534,249.99 2.30 175.29 2_Gym-NS-CT_Drill pipe (1) 1,760.00 18.87 71.45 1,699.58 1,640.33 150.75 323.01 6,028,042.01 534,256.17 1.80 179.20 2_Gyro-NS-CT_Drill pipe (1) 1,780.00 18.89 71.14 1,718.51 1,659.26 152.82 329.14 6,028,044.11 534,262.29 0.51 183.05 2_Gym-NS-CT_Drill pipe (1) 1,800.00 18.91 71.26 1,737.43 1,678.18 154.91 335.27 6,028,046.22 534,268.42 0.22 186.90 2 Gym -NS -CT Drill pipe (1) 1,820.00 18.73 70.92 1,756.36 1,697.11 157.00 341.37 6,028,048.34 534,274.51 1.05 190.71 2 -Gyro -NS -CT -Drill pipe (1) 1,840.00 18.94 71.00 1,775.29 1,716.04 159.11 347.48 6,028,050.48 534,280.60 1.06 194.52 2_Gym-NS-CT_Drill pipe (1) 1,860.00 19.25 71.21 1,794.19 1,734.94 161.23 353.67 6,028,052.62 534,286.78 1.59 198.40 2_Gyro-NS-CT_Dnll pipe (1) 1,880.00 19.19 71.69 1,813.07 1,753.82 163.32 359.91 6,028,054.75 534,293.01 0.85 202.33 2_Gyro-NS-CT_Drill pipe (1) 2!262019 1.42:24PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PBl Survey Calculation Method: Minimum Curvature Design: MPU M-12PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,900.00 19.46 71.85 1,831.95 1,772.70 165.39 366.20 6,028,056.85 534,299.29 1.38 206.31 2_Gyro-NS-CT_Drill pipe (1) 1,920.00 19.67 72.33 1,850.79 1,791.54 167.45 372.57 6,028,058.93 534,305.65 1.32 210.37 2_Gyro-NS-CT_Drill pipe (1) 1,940.00 19.74 72.39 1,869.62 1,810.37 169.50 378.99 6,028,061.01 534,312.07 0.36 214.48 2_Gyro-NS-CT_Drill pipe (1) 1,960.00 19.97 72.99 1,888.43 1,829.18 171.52 385.48 6,028,063.06 534,318.54 1.54 218.65 2 -Gyro -NS -CT -Drill pipe (1) 1,980.00 20.20 73.23 1,907.21 1,847.96 173.51 392.05 6,028,065.08 534,325.11 1.22 222.91 2_Gyro-NS-CT_Dnl1 pipe (1) 2,000.00 20.01 73.02 1,926.00 1,866.75 175.51 398.63 6,028,067.11 534,331.68 1.02 227.17 2_Gyro-NS-CT_Drill pipe (1) 2,020.00 20.26 73.68 1,944.77 1,885.52 177.48 405.23 6,028,069.11 534,338.26 1.69 231.46 2 Gyro-NS-CT_Drill pipe (1) 2,040.00 20.51 73.56 1,963.52 1,904.27 179.45 411.91 6,028,071.10 534,344.94 1.27 235.83 2 -Gyro -NS -CT Drill pipe (1) 2,060.00 20.84 72.75 1,982.23 1,922.98 181.49 418.67 6,028,073.18 534,351.68 2.18 240.21 2_Gyro-NS-CT_DriII pipe (1) 2,080.00 21.20 71.80 2,000.90 1,941.65 183.68 425.50 6,028,075.40 534,358.51 2.48 244.57 2_Gyro-NS-CT_Drill pipe (1) 2,100.00 21.38 71.65 2,019.54 1,960.29 185.95 432.40 6,028,077.71 534,365.39 0.94 248.94 2_Gyro-NS-GT_Dnll pipe (1) 2,120.00 21.72 71.38 2,038.14 1,978.89 188.28 439.36 6,028,080.07 534,372.35 1.77 253.33 2_Gyre-NS-CT_Drill pipe (1) 2,140.00 21.87 70.91 2,056.71 1,997.46 190.68 446.39 6,028,082.50 534,379.36 1.15 257.73 2_Gyro-NS-CT_Dnll pipe (1) 2,160.00 22.03 70.27 2,075.26 2,016.01 193.17 453.44 6,028,085.01 534,386.40 1.44 262.10 2_Gyro-NS-CT_Drill pipe (1) 2,180.00 22.00 69.22 2,093.80 2,034.55 195.76 460.48 6,028,087.64 534,393.42 1.97 266.39 2_Gyro-NS-CT_Drill pipe (1) 2,200.00 21.98 68.91 2,112.35 2,053.10 198.44 467.47 6,028,090.35 534,400.40 0.59 270.61 2_Gyro-NS-CT_Drill pipe (1) 2,220.00 22.18 68.59 2,130.88 2,071.63 201.16 474.48 6,028,093.11 534,407.40 1.17 274.81 2 -Gyro -NS -CT Drill pipe (1) 2,240.00 22.04 68.90 2,149.41 2,090.16 203.89 481.49 6,028,095.87 534,414.40 0.91 279.01 2_Gyro-NS-CT_Drlll pipe (1) 2,260.00 21.62 70.04 2,167.97 2,108.72 206.50 488.46 6,028,098.51 534,421.35 2.98 283.24 2_Gyro-NS-CT_Drill pipe (1) 2,280.00 21.47 70.64 2,186.58 2,127.33 208.97 495.37 6,028,101.01 534,428.25 1.33 287.51 2_Gyro-NS-CT_Drill pipe (1) 2,300.00 21.35 70.79 2,205.20 2,145.95 211.38 502.26 6,028,103.45 534,435.13 0.66 291.79 2_Gy10-NS-CT_Dnll pipe (1) 2,320.00 21.28 71.00 2,223.83 2,164.58 213.76 509.13 6,028,105.86 534,441.99 0.52 296.08 2_Gyro-NS-CT_Drill pipe (1) 2,340.00 20.93 70.88 2,242.49 2,183.24 216.11 515.94 6,028,108.24 534,448.79 1.76 300.32 2_Gyro-NS-CT_Drill pipe (1) 2,360.00 20.49 70.63 2,261.20 2,201.95 218.45 522.62 6,028,110.61 534,455.45 2.24 304.48 2 -Gyro -NS -CT -Drill pipe (1) 2,380.00 20.37 70.53 2,279.94 2,220.69 220.77 529.20 6,028,112.96 534,462.03 0.62 308.56 2 -Gyro -NS -CT Drill pipe (1) 2,400.00 20.30 70.66 2,298.69 2,239.44 223.08 535.76 6,028,115.30 534,468.57 0.42 312.62 2_Gyro-NS-CT_Dnll pipe (1) 2,420.00 20.39 70.71 2,317.44 2,258.19 225.38 542.32 6,028,117.63 534,475.12 0.46 316.70 2_Gyro-NS-CT_Drill pipe (1) 2,440.00 20.53 70.90 2,336.18 2,276.93 227.67 548.92 6,028,119.95 534,481.71 0.77 320.81 2 Gyro-NS-CT_Drill pipe (1) 2,460.00 20.71 70.63 2,354.90 2,295.65 229.99 555.57 6,028,122.30 534,488.35 1.02 324.95 2_Gyro-NS-CT_Drill pipe (i) 2,480.00 20.77 71.11 2,373.60 2,314.35 232.32 562.26 6,028,124.66 534,495.03 0.90 329.12 2_Gyro-NS-CT_Dnll pipe (1) 2,500.00 20.93 71.11 2,392.29 2,333.04 234.62 569.00 6,028,126.99 534,501.76 0.80 333.33 2_Gyro-NS-CT_Drill pipe (1) 2,520.00 21.04 71.20 2,410.97 2,351.72 236.93 575.78 6,028,129.33 534,508.52 0.57 337.58 2_Gyro-NS-CT_Drill pipe (1) 2,540.00 20.96 71.40 2,429.64 2,370.39 239.23 582.57 6,028,131.66 534,515.30 0.54 341.84 2_GymAS-CT Drill pipe (1) 2,560.00 20.86 71.52 2,448.32 2,389.07 241.50 589.33 6,028,133.96 534,522.06 0.54 346.10 2_Gyro-NS-CT_Dnll pipe (1) 2,580.00 20.74 71.79 2,467.02 2,407.77 243.74 596.07 6,028,136.23 534,528.79 0.77 350.36 2 -Gym-NS-CT-Drill pipe (1) 2,600.00 20.77 71.86 2,485.72 2,426.47 245.95 602.81 6,028,138.47 534,535.51 0.19 354.63 2_Gyro-NS-CT_Drill pipe (1) 2,620.00 20.55 71.80 2,504.43 2,445.18 248.15 609.51 6,028,140.70 534,542.20 1.11 358.88 2_Gyro-NS-CT_Drill pipe (1) 2,640.00 20.12 72.06 2,523.19 2,463.94 250.30 616.12 6,028,142.89 534,548.80 2.20 363.07 2_Gyro-NS-CT_Drill pipe (1) 2,660.00 19.89 71.98 2,541.98 2,482.73 252.42 622.63 6,028,145.03 534,555.30 1.16 367.21 2_Gyro-NS-CT_Drill pipe (1) 2,680.00 19.76 72.10 2,560.80 2,501.55 254.51 629.08 6,028,147.15 534,561.74 0.68 371.32 2_Gyro-NS-CT_Drill pipe (1) 2262019 1:42:24PM Page 5 COMPASS 5000.15 Build 91 Company: Project: Site: Well: Wellbore: Design: Survey Hiloorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 MPU M-12PB1 MPU M-12PB1 MD Inc (usft) (°) 2,700.00 19.84 2,720.00 20.16 2,740.00 20.26 2,760.00 20.42 2,780.00 20.54 2,800.00 20.55 2,820.00 20.74 2,840.00 20.92 2,860.00 20.93 2,880.00 20.94 2,900.00 20.80 2,920.00 20.99 2,940.00 21.06 2,960.00 21.32 2,980.00 21.84 3,000.00 22.29 3,020.00 23.06 3,040.00 23.70 3,060.00 24.18 3,080.00 24.23 3,100.00 24.17 3,120.00 24.19 3,140.00 24.29 3,160.00 24.38 3,180.00 24.30 3,200.00 24.63 3,220.00 24.80 3,240.00 25.06 3,260.00 25.42 3,280.00 25.90 3,300.00 26.76 3,320.00 27.88 3,340.00 28.91 3,360.00 29.47 3,380.00 30.24 3,400.00 31.29 3,420.00 32.70 3,440.00 33.94 3,460.00 34.68 3,480.00 35.45 Halliburton Definitive Survey Report Azi TVD TVDSS +N/ -S (`) (usft) (usft) (usft) 72.26 2,579.61 2,520.36 256.58 72.17 2,598.41 2,539.16 258.67 72.29 72.56 72.64 72.64 72.64 72.82 72.68 72.45 72.33 72.35 71.97 71.75 72.09 73.16 74.62 76.14 77.09 77.90 79.08 80.79 82.33 83.09 84.05 85.61 87.67 89.71 91.53 92.75 94.35 95.90 96.68 97.26 98.23 98.96 99.75 100.43 101.16 102.08 2,617.18 2,557.93 260.78 2,635.93 2,576.68 262.88 2,654.66 2,595.41 264.97 2,673.39 2,614.14 267.06 2,692.11 2,632.86 269.17 2,710.80 2,651.55 271.28 2,729.48 2,670.23 273.40 2,748.16 2,688.91 275.54 2,766.85 2,707.60 277.69 2,785.53 2,726.28 279.86 2,804.20 2,744.95 282.06 2,822.85 2,763.60 284.31 2,841.45 2,782.20 286.59 2,859.98 2,800.73 288.83 2,878.44 2,819.19 290.97 2,896.80 2,837.55 292.97 2,915.08 2,855.83 294.85 2,933.32 2,874.07 296.63 2,951.56 2,892.31 298.26 2,969.81 2,910.56 299.69 2,988.04 2,928.79 300.90 3,006.27 2,947.02 301.94 3,024.49 2,965.24 302.87 3,042.69 2,983.44 303.61 3,060.86 3,001.61 304.10 3,079.00 3,019.75 304.29 3,097.09 3,037.84 304.20 3,115.12 3,055.87 303.88 3,133.04 3,073.79 303.33 3,150.81 3,091.56 302.50 3,168.40 3,109.15 301.46 3,185.86 3,126.61 300.28 3,203.21 3,143.96 298.93 3,220.39 3,161.14 297.40 3,237.36 3,178.11 295.68 3,254.07 3,194.82 293.75 3,270.59 3,211.34 291.64 3,286.96 3,227.71 289.33 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +E/ -W Northing (usft) (ft) 635.53 6,028,149.25 642.04 6,028,151.37 648.62 6,028,153.51 655.25 6,028,155.64 661.93 6,028,157.76 668.63 6,028,159.89 675.36 6,028,162.02 682.15 6,028,164.16 688.97 6,028,166.31 695.79 6,028,168.48 702.58 6,028,170.67 709.38 6,028,172.86 716.21 6,028,175.09 723.08 6,028,177.38 730.07 6,028,179.69 737.24 6,028,181.97 744.65 6,028,184.14 752.33 6,028,186.17 760.22 6,028,188.09 768.23 6,028,189.90 776.26 6,028,191.57 794.32 6,028,193.04 792.45 6,028,194.28 800.62 6,028,195.36 808.81 6,028,196.32 817.06 6,028,197.11 825.41 6,028,197.64 833.83 6,028,197.87 842.36 6,028,197.81 851.01 6,028,197.53 859.87 6,028,197.02 869.01 6,028,196.24 878.46 6,028,195.24 888.14 6,028,194.10 898.01 6,028,192.80 908.12 6,028,191.31 918.58 6,028,189.64 929.39 6,028,187.76 940.47 6,028,185.70 951.72 6,028,183.44 Well MPU M-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US + CANADA Map Easting DLS (ft) (-/100') 534,568.18 0.48 534,574.68 1.61 534,581.25 0.54 534,587.87 0.93 534,594.54 0.62 534,601.23 0.05 534,607.95 0.95 534,614.73 0.96 534,621.54 0.25 534,628.34 0.41 534,635.13 0.73 534,641.91 0.95 534,648.73 0.77 534,655.59 1.36 534,662.57 2.67 534,669.73 3.02 534,677.13 4.77 534,684.80 4.40 534,692.68 3.08 534,700.68 1.68 534,708.70 2.44 534,716.76 3.50 534,724.88 3.20 534,733.05 1.63 534,741.23 2.02 534,749.48 3.63 534,757.82 4.39 534,766.24 4.49 534,774.77 4.28 534,783.43 3.57 534,792.28 5.57 534,801.42 6.63 534,810.88 5.47 534,820.57 3.14 534,830.44 4.54 534,840.56 5.57 534,851.02 7.35 534,861.84 6.48 534,872.92 4.23 534,884.19 4.67 Vertical Section (ft) Survey Tool Name 375.43 2_Gyro-NS-CT_Drill pipe (1) 379.59 2_Gyro-NS-CT_Drill pipe (1) 383.79 2 -Gyro -NS -CT -Drill pipe (1) 388.03 2_Gym-NS-CT Drill pipe (1) 392.32 2_Gym-NS-CT_Dnll pipe (1) 396.63 2_Gyro-NS-CT_Dnll pipe (1) 400.95 2_Gyro-NS-CT_Dnll pipe (1) 405.32 2_Gym-NS-CT_DO pipe (1) 409.72 2_Gyro-NS-CT_Dnll pipe (1) 414.09 2_Gyro-NS-CT_Dnll pipe (1) 418.44 2_Gyro-NS-CT_Drill pipe (1) 422.78 2_Gyro-NS-CT_Drill pipe (1) 427.14 2 Gyro-NS-CT_Dnll pipe (1) 431.50 2_Gyro-NS-CT_Dnll pipe (1) 435.93 2 -Gyro -NS -CT -Drill pipe (1) 440.54 2 -Gyne -NS -CT -Drill pipe (1) 445.40 2_Gyro-NS-CT_Dnl1 pipe (1) 450.57 2 -GYM -NS -CT Drill pipe (1) 455.98 2 -Gyro -NS -CT -Drill pipe (1) 461.54 2_Gyro-NS-CT_Drill pipe (1) 467.20 2_Gyro-NS-CT_DO pipe (1) 473.01 2 -Gyro -NS -CT Drill pipe (1) 478.99 2_Gyro-NS-CT_Drill pipe (1) 485.11 2 -Gyro -NS -CT -Drill pipe (1) 491.30 2_Gyro-NS-CT_Dnll pipe (1) 497.65 2_Gyro-NS-CT Dnll pipe (1) 504.23 2_Gyro-NS-CT_Dnll pipe (1) 511.04 2_Gyro-NS-CT_Drill pipe (1) 518.09 2_Gyro-NS-CT_Dnll pipe (1) 525.38 2_Gy(o-NS-CT Drill pipe (1) 532.97 2_Gyro-NS-CT_Drill pipe (1) 540.94 2_Gyro-NS-CT_Drill pipe (1) 549.30 2_Gyro-NS-CT_Drill pipe (1) 557.93 2_Gyro-NS-CT_Dnll pipe (1) 566.79 2_Gyro-NS-CT_Drill pipe (1) 575.97 2_Gyro-NS-CT_Drill pipe (1) 585.54 2_Gyro-NS-CT_Drill pipe (1) 595.52 2_Gyro-NS-CT_Dn(l pipe (1) 605.82 2_Gyro-NS-CT_DO pipe (1) 616.38 2_Gyro-NS-CT Dnll pipe (1) 2262019 1:42:24PM Page 6 COMPASS 5000.15 Build 91 Company: Project: Site: Well: Wellbore: Design: Survey Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 MPU M-12PB1 MPU M-12PB1 MD Inc (usft) (1) 3,500.00 36.37 3,520.00 37.21 3,540.00 37.73 3,560.00 37.95 3,580.00 38.85 3,600.00 40.03 3,620.00 41.14 3,640.00 41.88 3,660.00 42.52 3,680.00 43.14 3,700.00 44.20 3,720.00 44.36 3,740.00 44.68 3,760.00 45.12 3,780.00 45.80 3,800.00 46.24 3,820.00 45.56 3,840.00 45.05 3,860.00 45.30 3,880.00 46.03 3,900.00 46.97 3,920.00 47.71 3,940.00 47.85 3,960.00 48.83 3,980.00 50.26 4,000.00 52.46 4,020.00 54.41 4,040.00 55.79 4,060.00 57.15 4,080.00 58.55 4,100.00 59.22 4,120.00 59.94 4,140.00 60.11 4,160.00 60.14 4,180.00 60.50 4,200.00 60.37 4,220.00 60.19 4,240.00 60.59 4,260.00 62.05 4,280.00 63.70 Halliburton Definitive Survey Report Azi TVD TVDSS +NIS r) (usft) (usft) (usft) 102.87 3,303.16 3,243.91 286.79 103.69 3,319.17 3,259.92 284.04 104.35 3,335.05 3,275.80 281.09 104.79 3,350.84 3,291.59 278.01 105.58 3,366.52 3,307.27 274.75 106.57 3,381.96 3,322.71 271.23 107.36 3,397.15 3,337.90 267.43 107.91 3,412.13 3,352.88 263.42 108.48 3,426.94 3,367.69 259.22 109.04 3,441.61 3,382.36 254.85 109.74 3,456.08 3,396.83 250.26 110.05 3,470.40 3,411.15 245.51 110.32 3,484.66 3,425.41 240.67 110.97 3,498.82 3,439.57 235.70 111.41 3,512.85 3,453.60 230.54 111.99 3,526.74 3,467.49 225.22 112.12 3,540.66 3,481.41 219.83 112.12 3,554.72 3,495.47 214.48 112.65 3,568.82 3,509.57 209.07 113.80 3,582.80 3,523.55 203.43 114.72 3,596.57 3,537.32 197.47 115.42 3,610.12 3,550.87 191.24 115.66 115.85 116.34 116.69 117.00 117.14 117.32 117.57 117.90 118.19 118.60 119.27 119.93 120.05 120.19 120.33 120.48 120.91 3,623.56 3,564.31 184.85 3,636.85 3,577.60 178.36 3,649.83 3,590.58 171.66 3,662.32 3,603.07 164.69 3,674.23 3,614.98 157.44 3,685.67 3,626.42 149.97 3,696.72 3,637.47 142.34 3,707.36 3,648.11 134.54 3,717.70 3,658.45 126.57 3,727.83 3,668.58 118.46 3,737.82 3,678.57 110.22 3,747.78 3,688.53 101.83 3,757.68 3,698.43 93.25 3,767.55 3,708.30 84.55 3,777.47 3,718.22 75.84 3,787.35 3,728.10 67.08 3,796.95 3,737.70 58.20 3,806.07 3,746.82 49.11 Local Co-ordinate Reference: Well MPU M 12 TVD Reference: M-12 Actual RKB @ 59.25usft MD Reference: M-12 Actual RKB @ 59.25usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Map +EI -W Northing (usft) (ft) 963.18 6,028,180.96 974.83 6,028,178.26 986.64 6,028,175.36 998.51 6,028,172.33 1,010.50 6,028,169.13 1,022.71 6,028,165.67 1,035.15 6,028,161.93 1,047.78 6,028,157.97 1,060.55 6,028,153.83 1,073.42 6,028,149.52 1,086.45 6,028,144.99 1,099.58 6,028,140.30 1,112.74 6,028,135.52 1,125.95 6,028,130.61 1,139.24 6,028,125.52 1,152.61 6,028,120.26 1,165.92 6,028,114.92 1,179.09 6,028,109.63 1,192.21 6,028,104.29 1,205.35 6,028,098.71 1,218.58 6,028,092.81 1,231.90 6,028,086.64 1,245.27 6,028,080.31 1,258.72 6,028,073.88 1,272.39 6,028,067.25 1,286.37 6,028,060.34 1,300.70 6,028,053.15 1,315.30 6,028,045.76 1,330.13 6,028,038.20 1,345.15 6,028,030.46 1,360.31 6,028,022.56 1,375.53 6,028,014.52 1,390.77 6,028,006.36 1,405.95 6,027,998.04 1,421.06 6,027,989.52 1,436.12 6,027,980.90 1,451.15 6,027,972.25 1,466.17 6,027,963.56 1,481.30 6,027,954.75 1,496.60 6,027,945.73 Map Easting DLS (ft) (-/100') 534,895.65 5.15 534,907.32 4.87 534,919.14 3.28 534,931.02 1.74 534,943.03 5.13 534,955.25 6.69 534,967.71 6.12 534,980.36 4.12 534,993.14 3.73 535,006.03 3.64 535,019.08 5.82 535,032.23 1.35 535,045.41 1.86 535,058.64 3.18 535,071.95 3.74 535,085.35 3.03 535,098.68 3.43 535,111.88 2.55 535,125.02 2.26 535,138.18 5.50 535,151.44 5.76 535,164.78 4.51 535,178.18 1.13 535,191.66 4.95 535,205.36 7.39 535,219.36 11.08 535,233.73 9.83 535,248.37 6.92 535,263.22 6.84 535,278.28 7.08 535,293.47 3.64 535,308.73 3.81 535,324.01 1.97 535,339.22 2.91 535,354.37 3.39 535,369.47 0.83 535,384.53 1.09 535,399.59 2.09 535,414.76 7.33 535,430.11 8.47 vertical Section (ft) Survey Tool Name 627.23 2_Gyro-NS-CT_Drill pipe (1) 638.38 2_Gyro-NS-CT_Drill pipe (1) 649.75 2_Gyro-NS-CT_D611 pipe (1) 661.26 2_Gym-NS-CT_Dnll pipe (1) 672.97 2_Gyro-NS-CT_Drill pipe (1) 685.00 2 -Gyro -NS -CT -Drill pipe (1) 697.39 2_Gyro-NS-CT_Drill pipe (1) 710.05 2 Gyro-NS-CT_Drill pipe (1) 722.92 2 Gyro-NS-CT_Drill pipe (1) 735.99 2_Gyro-NS-CT_Dnll pipe (1) 749.30 2_Gyro-NS-CT_Dnll pipe (1) 762.80 2_Gym-NS-CT_0611 pipe (1) 776.37 2 Gyro-NS-CT_Drill pipe (1) 790.06 2_Gym-NS-CT_Drill pipe (1) 803.91 2_Gyro-NS-CT_Drill pipe (1) 817.93 2_Gyro-NS-CT_Dnll pipe (1) 831.94 2_Gyro-NS-CT_Dnll pipe (1) 845.81 2 Gyro-NS-CT_Drill pipe (1) 859.66 2_Gyro-NS-CT_Drill pipe (1) 873.67 2_Gyro-NS-CT_Ddll pipe (1) 887.94 2_Gyro-NS-CT_D611 pipe (1) 902.43 2_Gyro-NS-GT_DO pipe (1) 917.05 2 -Gyro -NS -CT -Drill pipe (1) 931.81 2_Gyro-NS-CT_Drill pipe (1) 946.85 2 -Gyro -NS -CT Drill pipe (1) 962.31 2_Gyro-NS-CT_Drill pipe (1) 978.22 2_Gyro-NS-CT_Dnll pipe (1) 994.47 2 -Gym -NS -CT -Drill pipe (1) 1,011.00 2_Gyro-NS-CT_Drill pipe (1) 1,027.79 2_Gyro-NS-CT Drill pipe (1) 1,044.78 2_Gym-NS-CT_Dnll pipe (1) 1,061.91 2_Gym-NS-CT_Dril1 pipe (1) 1,079.13 2_Gyro-NS-CT_Drill pipe (1) 1,096.38 2_Gyro-NS-CT Drill pipe (1) 1,113.68 2_Gyro-NS-CT_Drill pipe (1) 1,131.02 2_Gyro-NS-CT_Dnll pipe (1) 1,148.33 2 -Gyro -NS -CT Drill pipe (1) 1,165.66 2_Gyro-NS-CT_Dnll pipe (1) 1,183.15 2_Gyro-NS-CT_DHll pipe (1) 1,200.91 2 -Gyro -NS -CT Drill pipe (1) 2252019 1:42:24PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 14 12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,300.00 64.87 121.32 3,814.74 3,755.49 39.80 1,512.03 6,027,936.49 535,445.57 6.13 1,218.89 2_Gyro-NS-CT_Drill pipe (1) 4,320.00 65.50 121.54 3,823.14 3,763.89 30.33 1,527.52 6,027,927.10 535,461.11 3.30 1,237.01 2_Gyro-NS-CT_Drill pipe (1) 4,340.00 66.68 121.76 3,831.24 3,771.99 20.74 1,543.08 6,027,917.57 535,476.71 5.99 1,255.27 2_Gyro-NS-CT_DO pipe (1) 4,360.00 67.90 121.93 3,838.96 3,779.71 11.00 1,558.76 6,027,907.91 535,492.43 6.15 1,273.69 2_Gyro-NS-CT_Dnll pipe (1) 4,380.00 69.12 122.18 3,846.29 3,787.04 1.13 1,574.53 6,027,898.11 535,508.24 6.21 1,292.28 2_Gyro-NS-CT_Drill pipe (1) 4,400.00 69.67 122.49 3,853.33 3,794.08 -8.89 1,590.35 6,027,888.17 535,524.10 3.11 1,310.98 2_Gyro-NS-CT_Drill pipe (1) 4,420.00 70.13 122.75 3,860.20 3,800.95 -19.01 1,606.17 6,027,878.12 535,539.97 2.60 1,329.75 2_Gyro-NS-CT_Drill pipe (1) 4,440.00 71.25 122.98 3,866.82 3,807.57 -29.25 1,622.02 6,027,867.95 535,555.87 5.70 1,348.62 2_Gyro-NS-CT_Drill pipe (1) 4,460.00 72.35 123.27 3,873.06 3,813.81 -39.64 1,637.93 6,027,857.64 535,571.82 5.67 1,367.61 2_Gyro-NS-CT_Drill pipe (1) 4,480.00 73.04 123.35 3,879.01 3,819.76 -50.12 1,653.89 6,027,847.23 535,587.83 3.47 1,386.69 2 -GYM -NS -CT Drill pipe (1) 4,500.00 73.06 123.49 3,884.84 3,825.59 -60.66 1,669.86 6,027,836.77 535,603.84 0.68 1,405.82 2_Gyro-NS-CT_Ddll pipe (1) 4,520.00 73.56 123.65 3,890.59 3,831.34 -71.25 1,685.82 6,027,826.25 535,619.85 2.61 1,424.97 2_Gyro-NS-CT_Drill pipe (1) 4,540A0 74.36 123.87 3,896.11 3,836.86 -81.93 1,701.80 6,027,815.64 535,635.88 4.14 1,444.19 2_Gyro-NS-CT_Drill pipe (1) 4,560.00 74.92 123.92 3,901.41 3,842.16 -92.69 1,717.81 6,027,804.96 535,651.93 2.81 1,463.47 2_Gyro-NS-CT_Drill pipe (1) 4,580.00 75.11 123.96 3,906.58 3,847.33 -103.48 1,733.83 6,027,794.25 535,668.01 0.97 1,482.79 2 -Gyro -NS -CT -Drill pipe (1) 4,600.00 75.12 124.09 3,911.72 3,852.47 -114.29 1,749.85 6,027,783.50 535,684.07 0.63 1,502.12 2_Gyro-NS-CT_Drill pipe (1) 4,620.00 75.49 124.42 3,916.79 3,857.54 -125.18 1,765.84 6,027,772.69 535,700.11 2.44 1,521.46 2_Gyro-NS-CT_Drill pipe (1) 4,640.00 76.87 124.79 3,921.57 3,862.32 -136.21 1,781.83 6,027,761.73 535,716.15 7.13 1,540.88 2_Gyro-NS-CT_Drill pipe (1) 4,660.00 78.38 125.36 3,925.86 3,866.61 -147.44 1,797.82 6,027,750.58 535,732.18 8.05 1,560.42 2_Gyro-NS-CT_Drill pipe (1) 4,680.00 79.87 125.62 3,929.63 3,870.38 -158.84 1,813.81 6,027,739.25 535,748.22 7.56 1,580.06 2_Gyro-NS-CT_Drill pipe (1) 4,700.00 80.97 125.74 3,932.96 3,873.71 -170.34 1,829.83 6,027,727.83 535,764.29 5.53 1,599.78 2_Gyro-NS-CT_Drill pipe (1) 4,720.00 81.84 125.96 3,935.95 3,876.70 -181.92 1,845.85 6,027,716.32 535,780.37 4.48 1,619.55 2_Gyro-NS-CT_Drill pipe (1) 4,740.00 83.21 126.29 3,938.55 3,879.30 -193.61 1,861.87 6,027,704.70 535,796.44 7.04 1,639.37 2_Gyro-NS-CT_Drill pipe (1) 4,760.00 84.32 126.83 3,940.72 3,881.47 -205.46 1,877.84 6,027,692.93 535,812.46 6.16 1,659.24 2_Gyro-NS-CT_Drill pipe (1) 4,780.00 85.44 127.21 3,942.51 3,883.26 -217.45 1,893.75 6,027,681.01 535,828.42 5.91 1,679.15 2_Gyro-NS-CT_Drill pipe (1) 4,800.00 86.35 127.30 3,943.94 3,884.69 -229.53 1,909.62 6,027,669.01 535,844.35 4.57 1,699.08 2_Gyro-NS-CT_Drill pipe (1) 4,818.46 87.71 127.31 3,944.89 3,885.64 -240.70 1,924.29 6,027,657.91 535,859.07 7.37 1,717.50 2_Gyro-NS-CT_Ddll pipe (1) 4,863.80 90.49 126.55 3,945.61 3,886.36 -267.93 1,960.52 6,027,630.84 535,895.42 6.36 1,762.79 2_MWD+IFR2+MS+Sag(2) 4,958.78 94.30 126.56 3,941.64 3,882.39 -324.44 2,036.74 6,027,574.68 535,971.89 4.01 1,857.63 2 MWD+IFR2+MS+Sag (2) 5,051.75 93.40 126.65 3,935.39 3,876.14 -379.76 2,111.20 6,027,519.72 536,046.59 0.97 1,950.34 2_MWD+IFR2+MS+Sag(2) 5,107.00 93.40 126.65 3,932.12 3,872.87 412.68 2,155.45 6,027,487.00 536,090.99 0.00 2,005.47 PROJECTED to TD Checked By: Chelsea Wright '�� Approved B Mitch Laird E�...�,„.A.�.,.. pp y: -- Date: 2-26-2019 2262019 1:42:24PM Page 8 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12PB2 dill. Y�c�.Yl�yf Sperry Drilling Definitive Survey Report 26 February, 2019 3/all �`I F62- 1 &'01-0 a06Vi HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA rroject Milne Point, ACT, MILNE POINT dap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point dap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-12 Well Position +NIS +EI -W Position Uncertainty Wellbore MPU M-12PB2 Magnetics Model Name 0.00 usft Northing: 6,027,889.80 usfl 0.00 usft Easting: 533,933.89 usfl 0.00 usft Wellhead Elevation: 25.00 usfl Sample Date Declination V) User Defined 2/13/2019 16.61 Design MPU M-12PB2 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +N/S (usft) (usft) 34.25 0.00 Latitude: 70° 29'13.999 N Longitude: 149° 43'21.613 W Ground Level: 25.00 usft Dip Angle Field Strength (") (nT) 81.00 57,479.00000000 Tie On Depth: 4,863.80 +E/ -W Direction (usft) (1) 0.00 124.80 Survey Program Date 2/26/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 93.87 4,818.46 MPU M-12PB1 SDI SH Gyro - corrected 2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 02/13/2019 4,863.80 4,863.80 MPU M-12PB1 MWD IFR2 tied into corn 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 01/28/2019 4,920.00 16,572.41 MPU M-12PB2 MWD+IFR2+MS+Sag (2; 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 02/13/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (111001) (ft) Survey Tool Name 34.25 0.00 0.00 34.25 -25.00 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 UNDEFINED 93.87 0.20 253.18 93.87 34.62 -0.03 -0.10 6,027,889.77 533,933.79 0.34 -0.06 2_Gyro-NS-CT_Drill pipe (1) 96.24 0.12 265.12 96.24 36.99 -0.03 -0.11 6,027,889.77 533,933.78 3.64 -0.07 2_Gyro-NS-CT_Drill pipe (1) 100.00 0.09 279.22 100.00 40.75 -0.03 -0.11 6,027,889.77 533,933.78 1.05 -0.07 2 Gyr -NS-CT Drill pipe (1) 120.00 0.21 281.81 120.00 60.75 -0.02 -0.15 6,027,889.78 533,933.73 0.60 -0.12 2_Gyro-NS-CT_Drill pipe (1) 140.00 0.31 278.22 140.00 80.75 -0.01 -0.25 6,027,889.79 533,933.64 0.51 -0.20 2_Gyro-NS-CT_Drill pipe (1) 160.00 0.46 285.12 160.00 100.75 0.02 -0.38 6,027,889.82 533,933.51 0.78 -0.33 2_Gyro-NS-CT_Ddll pipe (1) 180.00 0.62 285.29 180.00 120.75 0.07 -0.57 6,027,889.87 533,933.32 0.80 -0.51 2_Gyro-NS-CT_DnII pipe (1) 200.00 0.60 293.81 200.00 140.75 0.14 -0.77 6,027,889.94 533,933.12 0.46 -0.71 2_Gyro-NS-CT_Drill pipe (1) 220.00 0.58 302.43 220.00 160.75 0.24 -0.95 6,027,890.04 533,932.94 0.45 -0.92 2 -Gyro -NS -CT -Drill pipe (1) 240.00 0.55 296.40 240.00 180.75 0.34 -1.12 6,027,890.13 533,932.77 0.33 -1.11 2_Gyro-NS-CT_DnII pipe (1) 260.00 0.58 294.40 259.99 200.74 0.42 -1.30 6,027,890.21 533,932.59 0.18 -1.31 2_Gym-NS-CT_Driil pipe (1) 21262019 1.44:00PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hiloorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 280.00 0.73 292.37 279.99 220.74 0.51 -1.51 6,027,890.30 533,932.38 0.76 -1.53 2_Gym-NS-CT_Dnll pipe (1) 300.00 0.78 305.19 299.99 240.74 0.64 -1.74 6,027,890.43 533,932.15 0.88 -1.79 2_Gyro-NS-CT_Drill pipe (1) 320.00 0.73 310.32 319.99 260.74 0.80 -1.95 6,027,890.59 533,931.94 0.42 -2.05 2_Gyro-NS-CT_Drill pipe (1) 340.00 0.85 313.00 339.99 280.74 0.98 -2.15 6,027,890.77 533,931.74 0.63 -2.33 2_Gyro-NS-CT_Drill pipe (1) 360.00 0.92 326.40 359.99 300.74 1.22 -2.35 6,027,891.01 533,931.54 1.09 -2.62 2_Gyr0-N5-CT_Dn1l pipe (1) 380.00 0.98 335.04 379.98 320.73 1.51 -2.51 6,027,891.29 533,931.37 0.78 -2.92 2_Gym-NS-CT_Dnll pipe (1) 400.00 1.35 352.02 399.98 340.73 1.89 -2.61 6,027,891.68 533,931.27 2.51 -3.23 2 Gyro-NS-CT_Drill pipe (1) 420.00 2.32 8.57 419.97 360.72 2.53 -2.59 6,027,892.32 533,931.29 5.48 -3.57 2 -Gyro -NS -CT -Drill pipe (1) 440.00 2.92 14.22 439.95 380.70 3.42 -2.40 6,027,893.21 533,931.47 3.26 -3.92 2_Gyro-NS-CT_Dnll pipe (1) 460.00 3.14 17.03 459.92 400.67 4.44 -2.12 6,027,894.23 533,931.75 1.33 -4.27 2_Gyro-NS-CT_Drill pipe (1) 480.00 3.36 21.42 479.89 420.64 5.51 -1.74 6,027,895.30 533,932.12 1.66 -4.57 2_Gym-NS-CT_Drill pipe (1) 500.00 3.75 22.62 499.85 440.60 6.66 -1.28 6,027,896.45 533,932.58 1.99 4.85 2_Gyro-NS-CT_Drill pipe (1) 520.00 4.30 24.93 519.80 460.55 7.94 -0.71 6,027,897.74 533,933.15 2.87 -5.11 2_Gyro-NS-CT_Drill pipe (1) 540.00 5.26 27.06 539.73 480.48 9.44 0.03 6,027,899.24 533,933.87 4.88 -5.37 2_Gyro-NS-CT_Dn1l pipe (1) 560.00 6.22 28.50 559.63 500.38 11.21 0.96 6,027,901.01 533,934.80 4.85 -5.61 2_Gyro-NS-CT_Drill pipe (1) 580.00 6.85 30.12 579.50 520.25 13.19 2.07 6,027,903.00 533,935.90 3.28 -5.82 2_Gyro-NS-CT_Dell pipe (1) 600.00 7.29 31.28 599.35 540.10 15.31 3.33 6,027,905.12 533,937.15 2.31 -6.00 2 Gyro-NS-CT_Drill pipe (1) 620.00 7.80 31.75 619.17 559.92 17.55 4.71 6,027,907.37 533,938.51 2.57 6.15 2 -Gym -NS -CT Dnll pipe (1) 640.00 8.37 32.92 638.97 579.72 19.92 6.21 6,027,909.75 533,940.01 2.97 6.27 2 Gyro-NS-CT_Will pipe (1) 660.00 9.05 34.00 658.74 599.49 22.45 7.88 6,027,912.28 533,941.67 3.50 -6.34 2_Gyro-NS-CT_Drill pipe (1) 680.00 9.69 35.33 678.48 619.23 25.13 9.73 6,027;914.97 533,943.51 3.38 -6.35 2 -Gyro -NS -CT -Drill pipe (1) 700.00 9.87 35.68 698.19 638.94 27.89 11.71 6,027,917.74 533,945.47 0.95 -6.30 2_Gym-NS-CT_D611 pipe (1) 720.00 10.05 35.82 717.88 658.63 30.70 13.73 6,027,920.56 533,947.48 0.91 6.25 2_Gyro-NS-CT_Dnll pipe (1) 740.00 10.29 37.12 737.57 678.32 33.54 15.83 6,027,923.41 533,949.56 1.66 -6.14 2_Gym-NS-CT_Drill pipe (1) 760.00 10.75 38.97 757.23 697.98 36.41 18.08 6,027,926.29 533,951.80 2.85 -5.94 2_Gyro-NS-CT_Drill pipe (1) 780.00 11.13 41,01 776.87 717.62 39.32 20.52 6,027,929.21 533,954.23 2.71 -5.59 2 -Gyro -NS -CT -Drill pipe (1) 800.00 11.54 43.28 796.48 737.23 42.23 23.16 6,027,932.13 533,956.85 3.03 -5.09 2_Gyro-NS-CT_Drill pipe (1) 820.00 11.88 45.86 816.06 756.81 45.12 26.01 6,027,935.04 533,959.69 3.12 4.40 2_Gym-NS-CT_Drill pipe (1) 840.00 12.28 48.98 835.62 776.37 47.95 29.09 6,027,937.88 533,962.76 3.83 -3.48 2_Gym-NS-CT_Dri1l pipe (1) 860.00 12.60 51.58 855.15 795.90 50.70 32.40 6,027,940.65 533,966.06 3.22 -2.33 2_Gyra-NS-CT_Drill pipe (1) 880.00 13.10 54.57 874.65 815.40 53.37 35.96 6,027,943.33 533,969.60 4.16 -0.93 2_Gyro-NS-CT_Drill pipe (1) 900.00 13.73 57.57 894.11 834.86 55.96 39.81 6,027,945.93 533,973.44 4.69 0.75 2_Gyro-NS-CT_Drill pipe (1) 920.00 14.04 59.77 913.52 854.27 58.45 43.91 6,027,948.45 533,977.53 3.06 2.69 2_Gyro-NS-CT_Drill pipe (1) 940.00 14.89 61.44 932.89 873.64 60.90 48.26 6,027,950.92 533,981.87 4.73 4.87 2_Gyro-NS-CT_Drill pipe (1) 960.00 15.07 62.41 952.21 892.96 63.34 52.82 6,027,953.37 533,986.42 1.54 7.23 2 -Gyro-NS-CT Drill pipe (1) 980.00 15.55 63.65 971.50 912.25 65.73 57.53 6,027,955.79 533,991.11 2.91 9.73 2_Gyro-NS-CT_Drill pipe (1) 1,000.00 16.31 65.22 990.73 931.48 68.10 62.48 6,027,958.18 533,996.05 4.37 12.44 2_Gym-NS-CT_Drill pipe (1) 1,020.00 17.36 67.30 1,009.87 950.62 70.43 67.78 6,027,960.53 534,001.34 6.05 15.47 2 -Gym -NS -CT -Drill pipe (1) 1,040.00 17.93 68.53 1,028.93 969.68 72.70 73.40 6,027,962.83 534,006.95 3.41 18.78 2_Gyro-NS-CT_Drill pipe (1) 1,060.00 18.43 68.97 1,047.93 988.68 74.97 79.22 6,027,965.12 534,012.76 2.59 22.26 2 -Gyro -NS -CT -Drill pipe (1) 2/2612019 1:44:OOPM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-121`132 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (°) n (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 1,080.00 19.21 70.30 1,066.86 1,007.61 77.21 85.27 6,027,967.39 534,018.79 4.45 25.95 2_Gyro-NS-CT_Drill pipe (1) 1,100.00 19.99 71.10 1,085.71 1,026.46 79.43 91.60 6,027,969.64 534,025.12 4.12 29.89 2 Gyro-NS-CT_Drill pipe (1) 1,120.00 20.72 71.73 1,104.46 1,045.21 81.64 98.19 6,027,971.88 534,031.70 3.81 34.04 2_Gym-NS-CT_Dnll pipe (1) 1,140.00 21.20 72.10 1,123.13 1,063.88 83.86 104.99 6,027,974.13 534,038.49 2.49 38.35 2_Gym-NS-CT_Dnll pipe (1) 1,160.00 21.54 72.49 1,141.76 1,082.51 86.08 111.93 6,027,976.38 534,045.42 1.84 42.79 2_Gyro-NS-CT_Dnll pipe (1) 1,180.00 21.84 72.12 1,160.34 1,101.09 88.33 118.98 6,027,978.66 534,052.45 1.65 47.29 2_Gyro-NS-CT_Drill pipe (1) 1,200.00 22.06 72.19 1,178.89 1,119.64 90.62 126.09 6,027,980.98 534,059.56 1.11 51.82 2_Gym-NS-CT_Drill pipe (1) 1,220.00 22.22 72.43 1,197.42 1,138.17 92.91 133.27 6,027,983.31 534,066.73 0.92 56.41 2 Gyro-NS-CT_Drill pipe (1) 1,240.00 22.13 72.42 1,215.94 1,156.69 95.19 140.47 6,027,985.62 534,073.91 0.45 61.02 2_Gyrc-NS-CT_Dnll pipe (1) 1,260.00 22.19 72.55 1,234.46 1,175.21 97.46 147.66 6,027,987.92 534,081.09 0.39 65.63 2_Gy10-NS-CT_Drill pipe (1) 1,280.00 22.06 72.41 1,252.99 1,193.74 99.72 154.85 6,027,990.22 534,088.27 0.70 70.24 2-GymNS.CT_Dnll pipe (1) 1,300.00 22.05 72.35 1,271.52 1,212.27 102.00 162.01 6,027,992.53 534,095.41 0.12 74.82 2_Gym-NS-CT_Drill pipe (1) 1,320.00 22.01 72.30 1,290.06 1,230.81 104.28 169.15 6,027,994.84 534,102.55 0.22 79..39 2_Gym-NS-CT_DO pipe (1) 1,340.00 21.85 72.30 1,308.62 1,249.37 106.55 176.27 6,027,997.14 534,109.65 0.80 83.94 2_Gym-NS-CT Dnll pipe (1) 1,360.00 21.90 72.56 1,327.18 1,267.93 108.80 183.37 6,027,999.42 534,116.75 0.55 88.49 2_Gyro-NS-CT_Drill pipe (1) 1,380.00 21.68 72.55 1,345.75 1,286.50 111.02 190.46 6,028,001.68 534,123.82 1.10 93.03 2_Gyro-NS-CT_Drill pipe (1) 1,400.00 21.84 72.69 1,364.32 1,305.07 113.24 197.53 6,028,003.93 534,130.88 0.84 97.58 2_Gym-NS-CT_Drill pipe (1) 1,420.00 21.98 72.81 1,382.88 1,323.63 115.45 204.66 6,028,006.17 534,138.00 0.73 102.17 2_Gyro-NS-CT_DO pipe (1) 1,440.00 22.08 73.14 1,401.42 1,342.17 117.65 211.83 6,028,008.40 534,145.16 0.80 106.80 2_Gym-NS-CT_Drill pipe (1) 1,460.00 22.22 73.33 1,419.94 1,360.69 119.82 219.05 6,028,010.61 534,152.37 0.79 111.49 2_Gyro-NS-CT_Drill pipe (1) 1,480.00 22.20 73.50 1,438.46 1,379.21 121.98 226.30 6,028,012.80 534,159.61 0.34 116.21 2_Gym-NS-CT_Drill pipe (1) 1,500.00 22.37 73.54 1,456.96 1,397.71 124.13 233.57 6,028,014.98 534,166.87 0.85 120.95 2_Gyro-NS-CT_Drill pipe (1) 1,520.00 22.67 74.12 1,475.45 1,416.20 126.26 240.91 6,028,017.14 534,174.20 1.49 125.77 2_Gyro-NS.CT_Dnll pipe (1) 1,540.00 22.47 73.96 1,493.92 1,434.67 128.36 248.28 6,028,019.28 534,181.55 0.59 130.61 2_Gyro-NS-CT_Drill pipe (1) 1,560.00 22.13 73.77 1,512.42 1,453.17 130.47 255.57 6,028,021.43 534,188.83 1.74 135.40 2_Gyro-NS-CT_Drill pipe (1) 1,580.00 21.94 74.07 1,530.96 1,471.71 132.55 262.78 6,028,023.54 534,196.03 1.10 140.13 2_Gym-NS-CT_Drlll pipe (1) 1,600.00 21.71 74.16 1,549.53 1,490.28 134.59 269.93 6,028,025.60 534,203.17 1.16 144.84 2 -Gyne -NS -CT -Drill pipe (1) 1,620.00 21.36 73.88 1,568.13 1,508.88 136.61 276.99 6,028,027.66 534,210.22 1.82 149.48 2_Gyro-NS-CT_Dnll pipe (1) 1,640.00 21.06 73.91 1,586.78 1,527.53 138.62 283.94 6,028,029.70 534,217.16 1.50 154.05 2 -Gyro -NS -CT Drill pipe (1) 1,660.00 20.59 73.76 1,605.47 1,546.22 140.60 290.77 6,028,031.71 534,223.98 2.37 158.52 2_Gym-NS-CT_Drill pipe (1) 1,680.00 20.29 73.08 1,624.21 1,564.96 142.59 297.46 6,028,033.73 534,230.67 1.91 162.88 2_Gyro-NS-CT_Drill pipe (1) 1,700.00 19.93 72.70 1,642.99 1,583.74 144.61 304.03 6,028,035.78 534,237.23 1.91 167.13 2_Gyro-NS-CT_Drill pipe (1) 1,720.00 19.62 72.40 1,661.81 1,602.56 146.64 310.49 6,028,037.84 534,243.68 1.63 171.27 2_Gyro-NS-CT_DO pipe (1) 1,740.00 19.22 71.72 1,680.68 1,621.43 148.69 316.81 6,028,039.92 534,249.99 2.30 175.29 2_Gyro-NS-CT_Dnll pipe (1) 1,760.00 18.87 71.45 1,699.58 1,640.33 150.75 323.01 6,028,042.01 534,256.17 1.80 179.20 2_Gyro-NS-CT_Drill pipe (1) 1,780.00 18.89 71.14 1,718.51 1,659.26 152.82 329.14 6,028,044.11 534,262.29 0.51 183.05 2_Gym-NS-CT_Drill pipe (1) 1,800.00 18.91 71.26 1,737.43 1,678.18 154.91 335.27 6,028,046.22 534,268.42 0.22 186.90 2_Gym-NS-CT_Ddll pipe (1) 1,820.00 18.73 70.92 1,756.36 1,697.11 157.00 341.37 6,028,048.34 534,274.51 1.05 190.71 2 Gyro -NS -CT Drill pipe (1) 1,840.00 18.94 71.00 1,775.29 1,716.04 159.11 347.48 6,028,050.48 534,280.60 1.06 194.52 2_Gyr0-NS-CT_Dnll pipe (1) 1,860.00 19.25 71.21 1,794.19 1,734.94 161.23 353.67 6,028,052.62 534,286.78 1.59 198.40 2_Gym-NS-CT_Drill pipe (1) 2/26/2019 1:44:0010M Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 MPU M-12PB2 MPU M-12PB2 Local Coordinate Reference: Well MPU M-12 TVD Reference: M-12 Actual RKB @ 59.25usft MD Reference: M-12 Actual RKB @ 59.25usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) ("1100') (ft) Survey Tool Name 1,880.00 19.19 71.69 1,813.07 1,753.82 163.32 359.91 6,028,054.75 534,293.01 0.85 202.33 2_Gyro-NS-CT_Dnll pipe (1) 1,900.00 19.46 71.85 1,831.95 1,772.70 165.39 366.20 6,028,056.85 534,299.29 1.38 206.31 2_Gyro-NS-CT_Drill pipe (1) 1,920.00 19.67 72.33 1,850.79 1,791.54 167.45 372.57 6,028,058.93 534,305.65 1.32 210.37 2 -Gyro -NS -CT Drill pipe (1) 1,940.00 19.74 72.39 1,869.62 1,810.37 169.50 378.99 6,028,061.01 534,312.07 0.36 214.48 2_Gyro-NS-CT Dnll pipe (1) 1,960.00 19.97 72.99 1,888.43 1,829.18 171.52 385.48 6,028,063.06 534,318.54 1.54 218.65 2_Gym-NS-CT_Drill pipe (1) 1,980.00 20.20 73.23 1,907.21 1,847.96 173.51 392.05 6,028,065.08 534,325.11 1.22 222.91 2_Gyro-NS-CT_Drill pipe (1) 2,000.00 20.01 73.02 1,926.00 1,866.75 175.51 398.63 6,028,067.11 534,331.68 1.02 227.17 2_Gyro-NS-CT_Drill pipe (1) 2,020.00 20.26 73.68 1,944.77 1,885.52 177.48 405.23 6,028,069.11 534,338.26 1.69 231.46 2_Gym-NS-CT_Drill pipe (1) 2,040.00 20.51 73.56 1,963.52 1,904.27 179.45 411.91 6,028,071.10 534,344.94 1.27 235.83 2_Gyro-NS-CT_Dnll pipe (1) 2,060.00 20.84 72.75 1,982.23 1,922.98 181.49 418.67 6,028,073.18 534,351.68 2.18 240.21 2_Gyro-NS-CT_Drill pipe (1) 2,080.00 21.20 71.80 2,000.90 1,941.65 183.68 425.50 6,028,075.40 534,358.51 2.48 244.57 2_Gym-NS-CT_DnIl pipe (1) 2,100.00 21.38 71.65 2,019.54 1,960.29 185.95 432.40 6,028,077.71 534,365.39 0.94 248.94 2_Gym-NS-CT_Dnll pipe (1) 2,120.00 21.72 71.38 2,038.14 1,978.89 188.28 439.36 6,028,080.07 534,372.35 1.77 253.33 2_Gym-NS-CT_Drill pipe (1) 2,140.00 21.87 70.91 2,056.71 1,997.46 190.68 446.39 6,028,082.50 534,379.36 1.15 257.73 2_Gym-NS-CT_Drill pipe (1) 2,160.00 22.03 70.27 2,075.26 2,016.01 193.17 453.44 6,028,085.01 534,386.40 1.44 262.10 2_Gyro-NS-CT_Drill pipe (1) 2,180.00 22.00 69.22 2,093.80 2,034.55 195.76 460.48 6,028,087.64 534,393.42 1.97 266.39 2_Gyr0-NS-CT_Dnll pipe (1) 2,200.00 21.98 68.91 2,112.35 2,053.10 198.44 467.47 6,028,090.35 534,400.40 0.59 270.61 2 Gyro-NS-CT_Dnll pipe (1) 2,220.00 22.18 68.59 2,130.88 2,071.63 201.16 474.48 6,028,093.11 534,407.40 1.17 274.81 2_Gyro-NS-CT_Drill pipe (1) 2,240.00 22.04 68.90 2,149.41 2,090.16 203.89 481.49 6,028,095.87 534,414.40 0.91 279.01 2 -Gyro -NS -CT -Drill pipe (1) 2,260.00 21.62 70.04 2,167.97 2,108.72 206.50 488.46 6,028,098.51 534,421.35 2.98 283.24 2_Gyro-NS-CT_Onll pipe (1) 2,280.00 21.47 70.64 2,186.58 2,127.33 208.97 495.37 6,028,101.01 534,428.25 1.33 287.51 2_Gym-NS-CT_Drill pipe (1) 2,300.00 21.35 70.79 2,205.20 2,145.95 211.38 502.26 6,028,103.45 534,435.13 0.66 291.79 2_Gyro-NS-CT_Drill pipe (1) 2,320.00 21.28 71.00 2,223.83 2,164.58 213.76 509.13 6,028,105.86 534,441.99 0.52 296.08 2_Gyro-NS-CT_Drill pipe (1) 2,340.00 20.93 70.88 2,242.49 2,183.24 216.11 515.94 6,028,108.24 534,448.79 1.76 300.32 2_Gyro-NS-CT_Drill pipe (1) 2,360.00 20.49 70.63 2,261.20 2,201.95 218.45 522.62 6,028,110.61 534,455.45 2.24 304.48 2_Gym-NS-GT_Drill pipe (1) 2,380.00 20.37 70.53 2,279.94 2,220.69 220.77 529.20 6,028,112.96 534,462.03 0.62 308.56 2_Gym.NS-CT_Drill pipe (1) 2,400.00 20.30 70.66 2,298.69 2,239.44 223.08 535.76 6,028,115.30 534,468.57 0.42 312.62 2_Gyro-NS-CT_Drill pipe (1) 2,420.00 20.39 70.71 2,317.44 2,258.19 225.38 542.32 6,028,117.63 534,475.12 0.46 316.70 2_Gym-NS-CT_Drill pipe (1) 2,440.00 20.53 70.90 2,336.18 2,276.93 227.67 548.92 6,028,119.95 534,481.71 0.77 320.81 2_Gym-NS-CT_Drill pipe (1) 2,460.00 20.71 70.63 2,354.90 2,295.65 229.99 555.57 6,028,122.30 534,488.35 1.02 324.95 2_Gyro-NS-CT_Drill pipe (1) 2,480.00 20.77 71.11 2,373.60 2,314.35 232.32 562.26 6,028,124.66 534,495.03 0.90 329.12 2_Gym-NS-CT_Drill pipe (1) 2,500.00 20.93 71.11 2,392.29 2,333.04 234.62 569.00 6,028,126.99 534,501.76 0.80 333.33 2_Gyro-NS-CT_Drill pipe (1) 2,520.00 21.04 71.20 2,410.97 2,351.72 236.93 575.78 6,028,129.33 534,508.52 0.57 337.58 2 -Gyro -NS -CT Drill pipe (1) 2,540.00 20.96 71.40 2,429.64 2,370.39 239.23 582.57 6,028,131.66 534,515.30 0.54 341.84 2_Gyro-NS-CT_D611 pipe (1) 2,560.00 20.86 71.52 2,448.32 2,389.07 241.50 589.33 6,028,133.96 534,522.06 0.54 346.10 2_Gyro-NS-CT_Drill pipe (1) 2,580.00 20.74 71.79 2,467.02 2,407.77 243.74 59607 6,028,136.23 534,528.79 0.77 350.36 2_Gyro-NS-CT_Drill pipe (1) 2,600.00 20.77 71.86 2,485.72 2,426.47 245.95 602.81 6,028,138.47 534,535.51 0.19 354.63 2_Gyro-NS-CT_Drill pipe (1) 2,620.00 20.55 71.80 2,504.43 2,445.18 248.15 609.51 6,028,140.70 534,542.20 1.11 358.88 2_Gym-NS-CT_Drill pipe (1) 2,640.00 20.12 72.06 2,523.19 2,463.94 250.30 616.12 6,028,142.89 534,548.80 2.20 363.07 2_Gym-NS-CT_13nll pipe (1) 2,660.00 19.89 71.98 2,541.98 2,482.73 252.42 622.63 6,028,145.03 534,555.30 1.16 367.21 2_Gyro-NS-CT_DO pipe (1) 2/26!2019 1:44:00PM Page 5 COMPASS 5000.15 Build 91 22612019 1:44:00PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilwrp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NAS +E/ -W Northing Easting DLS Section (usft) (') V) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 2,680.00 19.76 72.10 2,560.80 2,501.55 254.51 629.08 6,028,147.15 534,561.74 0.68 371.32 2_Gyro-NS-CT_Drill pipe (1) 2,700.00 19.84 72.26 2,579.61 2,520.36 256.58 635.53 6,028,149.25 534,568.18 0.48 375.43 2_Gyro-NS-CT_Drill pipe (1) 2,720.00 20.16 72.17 2,598.41 2,539.16 258.67 642.04 6,028,151.37 534,574.68 1.61 379.59 2_Gyro-NS-CT_D611 pipe (1) 2,740.00 20.26 72.29 2,617.18 2,557.93 260.78 648.62 6,028,153.51 534,581.25 0.54 383.79 2_Gyro-NS-CT_Drill pipe (1) 2,760.00 20.42 72.56 2,635.93 2,576.68 262.88 655.25 6,028,155.64 534,587.87 0.93 388.03 2_Gym-NS-CT_Dnll pipe (1) 2,780.00 20.54 72.64 2,654.66 2,595.41 264.97 661.93 6,028,157.76 534,594.54 0.62 392.32 2_Gym-NS-CT_Drill pipe (1) 2,800.00 20.55 72.64 2,673.39 2,614.14 267.06 668.63 6,028,159.89 534,601.23 0.05 396.63 2 Gyro-NS-CT_Drill pipe (1) 2,820.00 20.74 72.64 2,692.11 2,632.86 269.17 675.36 6,028,162.02 534,607.95 0.95 400.95 2_Gym-NS-CT Dnll pipe (1) 2,840.00 20.92 72.82 2,710.80 2,651.55 271.28 682.15 6,028,164.16 534,614.73 0.96 405.32 2_Gyro-NS-CT_Dnll pipe (1) 2,860.00 20.93 72.68 2,729.48 2,670.23 273.40 688.97 6,028,166.31 534,621.54 0.25 409.72 2_Gym-NS-CT_Ddll pipe (1) 2,880.00 20.94 72.45 2,748.16 2,688.91 275.54 695.79 6,028,168.48 534,628.34 0.41 414.09 2_Gym-NS-GT_DnIl pipe (1) 2,900.00 20.80 72.33 2,766.85 2,707.60 277.69 702.58 6,028,170.67 534,635.13 0.73 418.44 2_Gym-NS-CT_Drill pipe (1) 2,920.00 20.99 72.35 2,785.53 2,726.28 279.86 709.38 6,028,172.86 534,641.91 0.95 422.78 2_Gym-NS-CT_Drill pipe (1) 2,940.00 21.06 71.97 2,804.20 2,744.95 282.06 716.21 6,028,175.09 534,648.73 0.77 427.14 2_Gyro-NS-CT_Drill pipe (1) 2,960.00 21.32 71.75 2,822.85 2,763.60 284.31 723.08 6,028,177.38 534,655.59 1.36 431.50 2 -Gyro -INS -CT -Drill pipe (1) 2,980.00 21.84 72.09 2,841.45 2,782.20 286.59 730.07 6,028,179.69 534,662.57 2.67 435.93 2 -Gyro -NS -CT -Drill pipe (1) 3,000.00 22.29 73.16 2,859.98 2,800.73 288.83 737.24 6,028,181.97 534,669.73 3.02 440.54 2 -Gyro -NS -CT Drill pipe (1) 3,020.00 23.06 74.62 2,878.44 2,819.19 290.97 744.65 6,028,184.14 534,677.13 4.77 445.40 2_Gyro-NS-CT_Drill pipe (1) 3,040.00 23.70 76.14 2,896.80 2,837.55 292.97 752.33 6,028,186.17 534,684.80 4.40 450.57 2_Gym-NS-CT_Drill pipe (1) 3,060.00 24.18 77.09 2,915.08 2,855.83 294.85 760.22 6,028,188.09 534,692.68 3.08 455.98 2_Gyro-NS-CT_Drill pipe (1) 3,080.00 24.23 77.90. 2,933.32 2,874.07 296.63 768.23 6,028,189.90 534,700.68 1.68 461.54 2_Gyro-NS-CT_Drill pipe (1) 3,100.00 24.17 79.08 2,951.56 2,892.31 298.26 776.26 6,028,191.57 534,708.70 2.44 467.20 2_Gyro-NS-CT_Drill pipe (1) 3,120.00 24.19 80.79 2,969.81 2,910.56 299.69 784.32 6,028,193.04 534,716.76 3.50 473.01 2_Gyro-NS-CT_Drill plpe (1) 3,140.00 24.29 82.33 2,988.04 2,928.79 300.90 792.45 6,028,194.28 534,724.88 3.20 478.99 2_Gyro-NS-CT_Drill pipe (1) 3,160.00 24.38 83.09 3,006.27 2,947.02 301.94 800.62 6,028,195.36 534,733.05 1.63 485.11 2_Gyro-NS-CT_Drill pipe (1) 3,180.00 24.30 84.05 3,024.49 2,965.24 302.87 808.81 6,028,196.32 534,741.23 2.02 491.30 2_Gyro-NS-CT_Dnll pipe (1) 3,200.00 24.63 85.61 3,042.69 2,983.44 303.61 817.06 6,028,197.11 534,749.48 3.63 497.65 2 -GYM -NS -CT -Drill pipe (1) 3,220.00 24.80 87.67 3,060.86 3,001.61 304.10 825.41 6,028,197.64 534,757.82 4.39 504.23 2_Gym-NS-CT_Drill pipe (1) 3,240.00 25.06 89.71 3,079.00 3,019.75 304.29 833.83 6,028,197.87 534,766.24 4.49 511.04 2_Gyro-NS-CT_Ddll pipe (1) 3,260.00 25.42 91.53 3,097.09 3,037.84 304.20 842.36 6,028,197.81 534,774.77 4.28 518.09 2_Gyro-NS-CT_Drill pipe (1) 3,280.00 25.90 92.75 3,115.12 3,055.87 303.88 851.01 6,028,197.53 534,783.43 3.57 525.38 2_Gyro-NS-CT_Drill pipe (1) 3,300.00 26.76 94.35 3,133.04 3,073.79 303.33 859.87 6,028,197.02 534,792.28 5.57 532.97 2_Gym-NS-CT_Drill pipe (1) 3,320.00 27.88 95.90 3,150.81 3,091.56 302.50 869.01 6,028,196.24 534,801.42 6.63 540.94 2_Gyro-NS-CT_Drill pipe (1) 3,340.00 28.91 96.68 3,168.40 3,109.15 301.46 878.46 6,028,195.24 534,810.88 5.47 549.30 2_Gyro-NS-CT_Dnll pipe (1) 3,360.00 29.47 97.26 3,185.86 3,126.61 300.28 888.14 6,028,194.10 534,820.57 3.14 557.93 2_Gym-NS-CT_Drill pipe (1) 3,380.00 30.24 98.23 3,203.21 3,143.96 298.93 898.01 6,028,192.80 534,830.44 4.54 566.79 2_Gyro-NS-CT_Drill pipe (1) 3,400.00 31.29 98.96 3,220.39 3,161.14 297.40 908.12 6,028,191.31 534,840.56 5.57 575.97 2_Gyro-NS-CT_Drill pipe (1) 3,420.00 32.70 99.75 3,237.36 3,178.11 295.68 918.58 6,028,189.64 534,851.02 7.35 585.54 2_Gyro-NS-CT_Ddil pipe (1) 3,440.00 33.94 100.43 3,254.07 3,194.82 293.75 929.39 6,028,187.76 534,861.84 6.48 595.52 2_Gyro-NS-CT_Dnll pipe (1) 3,460.00 34.68 101.16 3,270.59 3,211.34 291.64 940.47 6,028,185.70 534,872.92 4.23 605.82 2_Gyro-INS-CT_Dnll pipe (1) 22612019 1:44:00PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 3,480.00 35.45 102.08 3,286.96 3,227.71 289.33 951.72 6,028,183.44 534,884.19 4.67 616.38 2 -Gyro -NS -CT Drill pipe (1) 3,500.00 36.37 102.87 3,303.16 3,243.91 286.79 963.18 6,028,180.96 534,895.65 5.15 627.23 2_Gyro-NS-CT_Drill pipe (1) 3,520.00 37.21 103.69 3,319.17 3,259.92 284.04 974.83 6,028,178.26 534,907.32 4.87 638.38 2_Gyro-NS-CT_Drill pipe (1) 3,540.00 37.73 104.35 3,335.05 3,275.80 281.09 986.64 6,028,175.36 534,919.14 3.28 649.75 2_Gyro-NS-CT_Drill pipe (1) 3,560.00 37.95 104.79 3,350.84 3,291.59 278.01 998.51 6,028,172.33 534,931.02 1.74 661.26 2_Gyro-NS-CT_Drill pipe (1) 3,580.00 38.85 105.58 3,366.52 3,307.27 274.75 1,010.50 6,028,169.13 534,943.03 5.13 672.97 2_Gym-NS-CT_Dnli pipe (1) 3,600.00 40.03 106.57 3,381.96 3,322.71 271.23 1,022.71 6,028,165.67 534,955.25 6.69 685.00 2 -Gyro -NS -CT -Drill pipe (1) 3,620.00 41.14 107.36 3,397.15 3,337.90 267.43 1,035.15 6,028,161.93 534,967.71 6.12 697.39 2_Gyro-NS-CT_Dri1l pipe (1) 3,640.00 41.88 107.91 3,412.13 3,352.88 263.42 1,047.78 6,028,157.97 534,980.36 4.12 710.05 2 -Gyro -NS -CT -Drill pipe (1) 3,660.00 42.52 108.48 3,426.94 3,367.69 259.22 1,060.55 6,028,153.83 534,993.14 3.73 722.92 2_Gym-NS-CT_Drill pipe (1) 3,680.00 43.14 109.04 3,441.61 3,382.36 254.85 1,073.42 6,028,149.52 535,006.03 3.64 735.99 2_Gyro-NS-CT_Drill pipe (1) 3,700.00 44.20 109.74 3,456.08 3,396.83 250.26 1,086.45 6,028,144.99 535,019.08 5.82 749.30 2 Gym-NS-CT_Drill pipe (1) 3,720.00 44.36 110.05 3,470.40 3,411.15 245.51 1,099.58 6,028,140.30 535,032.23 1.35 762.80 2_Gyro-NS-CT_Drill pipe (1) 3,740.00 44.68 110.32 3,484.66 3,425.41 240.67 1,112.74 6,028,135.52 535,045.41 1.86 776.37 2_Gyro-NS-CT_Drill pipe (1) 3,760.00 45.12 110.97 3,498.82 3,439.57 235.70 1,125.95 6,028,130.61 535,058.64 3.18 790.06 2_Gyro-NS-CT_Dnll pipe (1) 3,780.00 45.80 111.41 3,512.85 3,453.60 230.54 1,139.24 6,D28,125.52 535,071.95 3.74 803.91 2 Gym-NS-CT_Drill pipe (1) 3,800.00 46.24 111.99 3,526.74 3,467.49 225.22 1,152.61 6,028,120.26 535,085.35 3.03 817.93 2 -Gyro -NS -CT -Drill pipe (1) 3,820.00 45.56 112.12 3,540.66 3,481.41 219.83 1,165.92 6,028,114.92 535,098.68 3.43 831.94 2_Gyro-NS-CT_Ddll pipe (1) 3,840.00 45.05 112.12 3,554.72 3,495.47 214.48 1,179.09 6,028,109.63 535,111.88 2.55 845.81 2_Gyro-NS-CT_Drill pipe (1) 3,860.00 45.30 112.65 3,568.82 3,509.57 209.07 1,192.21 6,028,104.29 535,125.02 2.26 859.66 2_Gyro-NS-CT_Drill pipe (1) 3,880.00 46.03 113.80 3,582.80 3,523.55 203.43 1,205.35 6,028,098.71 535,138.18 5.50 873.67 2_Gyro-NS-CT_Drill pipe (1) 3,900.00 46.97 114.72 3,596.57 3,537.32 197.47 1,218.58 6,028,092.81 535,151.44 5.76 887.94 2_Gyro-NS-CT_Drill pipe (1) 3,920.00 47.71 115.42 3,610.12 3,550.87 191.24 1,231.90 6,028,086.64 535,164.78 4.51 902.43 2_Gyro-NS-CT_Drill pipe (1) 3,940.00 47.85 115.66 3,623.56 3,564.31 184.85 1,245.27 6,028,080.31 535,178.18 1.13 917.05 2_Gyro-NS-CT_Dn1l pipe (1) 3,960.00 48.83 115.85 3,636.85 3,577.60 178.36 1,258.72 6,028,073.88 535,191.66 4.95 931.81 2_Gyro-NS-CT_Drill pipe (1) 3,980.00 50.26 116.34 3,649.83 3,590.58 171.66 1,272.39 6,028,067.25 535,205.36 7.39 946.85 2_Gyro-NS-CT_Drill pipe (1) 4,000.00 52.46 116.69 3,662.32 3,603.07 164.69 1,286.37 6,028,060.34 535,219.36 11.08 962.31 2_Gyro-NS-CT_Ddll pipe ll) 4,020.00 54.41 117.00 3,674.23 3,614.98 157.44 1,300.70 6,028,053.15 535,233.73 9.83 978.22 2_Gym-NS-CT_Drill pipe (1) 4,040.00 55.79 117.14 3,685.67 3,626.42 149.97 1,315.30 6,028,045.76 535,248.37 6.92 994.47 2_Gyro-N8-CT_Dn1l pipe (1) 4,060.00 57.15 117.32 3,696.72 3,637.47 142.34 1,330.13 6,028,038.20 535,263.22 6.84 1,011.00 2_Gyro-NS-CT_Drill pipe (1) 4,080.00 58.55 117.57 3,707.36 3,648.11 134.54 1,345.15 6,028,030.46 535,278.28 7.08 1,027.79 2_Gyro-NS-CT_Drill pipe (1) 4,100.00 59.22 117.90 3,717.70 3,658.45 126.57 1,360.31 6,028,022.56 535,293.47 3.64 1,044.78 2_Gyro-NS-CT_Drill pipe (1) 4,120.00 59.94 118.19 3,727.83 3,668.58 118.46 1,375.53 6,028,014.52 535,308.73 3.81 1,061.91 2_Gyro-NS-CT_Dnll pipe (1) 4,140.00 60.11 118.60 3,737.82 3,678.57 110.22 1,390.77 6,028,006.36 535,324.01 1.97 1,079.13 2 Gyr0-NS-CT_Drill pipe (1) 4,160.00 60.14 119.27 3,747.78 3,688.53 101.83 1,405.95 6,027,998.04 535,339.22 2.91 1,096.38 2 -Gyro -NS -CT Drill pipe (1) 4,180.00 60.50 119.93 3,757.68 3,698.43 93.25 1,421.06 6,027,989.52 535,354.37 3.39 1,113.68 2 -Gym -NS -CT -Drill pipe (1) 4,200.00 60.37 120.05 3,767.55 3,708.30 84.55 1,436.12 6,027,980.90 535,369.47 0.83 1,131.02 2_Gyro-NS-CT_DnII pipe (1) 4,220.00 60.19 120.19 3,777.47 3,718.22 75.84 1,451.15 6,027,972.25 535,384.53 1.09 1,148.33 2_Gym-NS-CT_0011 pipe (1) 4,240.00 60.59 120.33 3,787.35 3,728.10 67.08 1,466.17 6,027,963.56 535,399.59 2.09 1,165.66 2_Gyro-NS-CT_Drill pipe (1) 4,260.00 62.05 120.48 3,796.95 3,737.70 58.20 1,481.30 6,027,954.75 535,414.76 7.33 1,183.15 2_Gyro-NS-CT_Dnll pipe (1) 21262019 1:44o0PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU W12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc An TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) N (1) (usft) (usft) (usft) (usft) (ft) (ft) (^1100•) (ft) Survey Tool Name 4,280.00 63.70 120.91 3,806.07 3,746.82 49.11 1,496.60 6,027,945.73 535,430.11 8.47 1,200.91 2_Gyro-NS-CT_Drill pipe (1) 4,300.00 64.87 121.32 3,814.74 3,755.49 39.80 1,512.03 6,027,936.49 535,445.57 6.13 1,218.89 2 -Gym-NS-CT Drill pipe (1) 4,320.00 65.50 121.54 3,823.14 3,763.89 30.33 1,527.52 6,027,927.10 535,461.11 3.30 1,237.01 2_Gyro-NS-CT_Drill pipe (1) 4,340.00 66.68 121.76 3,831.24 3,771.99 20.74 1,543.08 6,027,917.57 535,476.71 5.99 1,255.27 2_Gyr0-NS-CT_Drill pipe (1) 4,360.00 67.90 121.93 3,838.96 3,779.71 11.00 1,558.76 6,027,907.91 535,492.43 6.15 1,273.69 2_Gyro-NS-CT_Ddll pipe (1) 4,380.00 69.12 122.18 3,846.29 3,787.04 1.13 1,574.53 6,027,898.11 535,508.24 6.21 1,292.28 2_Gyro-NS-CT_Drill pipe (1) 4,400.00 69.67 122.49 3,853.33 3,794.08 -8.89 1,590.35 6,027,888.17 535,524.10 3.11 1,310.98 2_Gyro-NS-CT_Drill pipe (1) 4,420.00 70.13 122.75 3,860.20 3,800.95 -19.01 1,606.17 6,027,878.12 535,539.97 2.60 1,329.75 2 Gyro-NS-CT_Drill pipe (1) 4,440.00 71.25 122.98 3,866.82 3,807.57 -29.25 1,622.02 6,027,867.95 535,555.87 5.70 1,348.62 2 -Gym -NS -CT Drill pipe (1) 4,460.00 72.35 123.27 3,873.06 3,813.81 -39.64 1,637.93 6027,857.64 535,571.82 5.67 1,367.61 2_Gyro-NS-CT_Drill pipe (1) 4,480.00 73.04 123.35 3,879.01 3,819.76 50.12 1,653.89 6,027,847.23 535,587.83 3.47 1,386.69 2 -GYM -NS -CT -Drill pipe (1) 4,500.00 73.06 123.49 3,884.84 3,825.59 -60.66 1,669.86 6,027,836.77 535,603.84 0.68 1,405.82 2_Gyro-NS-CT_Drill pipe (1) 4,520.00 73.56 123.65 3,890.59 3,831.34 -71.25 1,685.82 6,027,826.25 535,619.85 2.61 1,424.97 2_Gyro-NS-CT_Dnll pipe (1) 4,540.00 74.36 123.87 3,896.11 3,836.86 -81.93 1,701.80 6027,815.64 535,635.88 4.14 1,444.19 2 -Gym -NS -CT Drill pipe (1) 4,560.00 74.92 123.92 3,901.41 3,842.16 -92.69 1,717.81 6,027,804.96 535,651.93 2.81 1,463.47 2_Gyro-NS-CT_Drill pipe (1) 4,580.00 75.11 123.96 3,906.58 3,847.33 -103.48 1,733.83 6,027,794.25 535,668.01 0.97 1,482.79 2_Gym-NS-CT_Dnll pipe (1) 4,600.00 75.12 124.09 3,911.72 3,852.47 -114.29 1,749.85 6,027,783.50 535,684.07 0.63 1,502.12 2 -Gyro -NS -CT -Drill pipe (1) 4,620.00 75.49 124.42 3,916.79 3,857.54 -125.18 1,765.84 6,027,772.69 535,700.11 2.44 1,521.46 2_Gyro-NS-CT_Drill pipe (1) 4,640.00 76.87 124.79 3,921.57 3,862.32 -136.21 1,781.83 6,027,761.73 535,716.15 7.13 1,540.88 2_Gyro-NS-CT_Dnll pipe (1) 4,660.00 78.38 125.36 3,925.86 3,866.61 -147.44 1,797.82 6,027,750.58 535,732.18 8.05 1,560.42 2_Gyro-NS-CT_Drill pipe (1) 4,680.00 79.87 125.62 3,929.63 3,870.38 -158.84 1,813.81 6,027,739.25 535,748.22 7.56 1,580.06 2_Gyro-NS-CT_Drill pipe (1) 4,700.00 80.97 125.74 3,932.96 3,873.71 -170.34 1,829.83 6,027,727.83 535,764.29 5.53 1,599.78 2_Gyro-NS-CT_Drill pipe (1) 4,720.00 81.84 125.96 3,935.95 3,876.70 -181.92 1,845.85 6027,716.32 535,780.37 4.48 1,619.55 2 -Gyro -NS -CT -Drill pipe (i) 4,740.00 83.21 126.29 3,938.55 3,879.30 -193.61 1,861.87 6,027,704.70 535,796.44 7.04 1,639.37 2_Gyro-NS-CT_Drill pipe (1) 4,760.00 84.32 126.83 3,940.72 3,881.47 -205.46 1,877.84 6027,692.93 535,812.46 6.16 1,659.24 2_Gyro-NS-CT_Drill pipe (1) 4,780.00 85.44 127.21 3,942.51 3,883.26 -217.45 1,893.75 6027,681.01 535,828.42 5.91 1,679.15 2_Gyno-NS-CT_Drill pipe (1) 4,800.00 86.35 127.30 3,943.94 3,884.69 -229.53 1,909.62 6,027,669.01 535,844.35 4.57 1,699.08 2_Gyro-NS-CT_Dnll pipe (1) 4,818.46 87.71 127.31 3,944.89 3,885.64 -240.70 1,924.29 6,027,657.91 535,859.07 7.37 1,717.50 2_Gyro-NS-CT_Drill pipe (1) 4,863.80 90.49 126.55 3,945.61 3,886.36 -267.93 1,960.52 6,027,630.84 535,895.42 6.36 1,762.79 2_MWD+IFR2+MS+Sag(2) 4,920.00 89.64 128.42 3,945.54 3,886.29 -302.13 2,005.12 6,027,596.85 535,940.16 3.65 1,818.93 2_MWD+IFR2+MS+Sag (3) 4,972.70 88.89 127.20 3,946.22 3,886.97 -334.44 2,046.75 6,027,564.74 535,981.94 2.72 1,871.55 2_MWD+IFR2+MS+Sag (3) 5,067.57 87.35 126.98 3,949.33 3,890.08 -391.62 2,122.38 6,027,507.91 536,057.83 1.64 1,966.29 2_MWD+IFR2+MS+Sag (3) 5,161.83 87.04 126.97 3,953.94 3,894.69 448.24 2,197.59 6,027,451.63 536133.29 0.33 2,060.37 2_MWD+IFR2+MS+8ag(3) 5,257.72 87.35 126.78 3,958.64 3,899.39 -505.72 2,274.21 6,027,394.52 536,210.16 0.38 2,156.08 2_MWD+IFR2+MS+Sag(3) 5,353.38 88.41 125.76 3,962.17 3,902.92 -562.27 2,351.28 6,027,338.32 536,287.48 1.54 2,251.64 2_MWD+IFR2+MS+Sag (3) 5,448.47 91.81 124.62 3,961.99 3,902.74 -617.06 2,428.98 6,027,283.89 536,365.42 3.77 2,346.72 2_MWD+IFR2+MS+Sag (3) 5,544.36 93.41 123.53 3,957.62 3,898.37 -670.72 2,508.32 6,027,230.59 536,444.99 2.02 2,442.49 2_MWD+IFR2+MS+Sag (3)M 5,639.63 90.37 120.50 3,954.48 3,895.23 -721.19 2,589.04 6,027,180.50 536,525.93 4.50 2,537.58 2_WD+IFR2+MS+Sag(3) 5,734.29 90.01 120.89 3,954.17 3,894.92 -769.51 2,670.43 6,027,132.56 536,607.54 0.56 2,631.99 2_MWD+IFR2+MS+Sag(3) 5,830.13 90.81 122.55 3,953.48 3,894.23 -819.90 2,751.95 6027,082.55 536,689.28 1.92 2,727.69 2_MWD+IFR2+MS+Sag(3) 2262019 1:44:OOPM Page 8 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc An TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (`) (") (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,925.47 88.89 122.09 3,953.73 3,894.48 -870.87 2,832.52 6,027,031.95 536,770.07 2.07 2,822.93 2_MWD+IFR2+MS+Sag(3) 6,021.15 87.23 121.12 3,956.97 3,897.72 -920.98 2,913.95 6,026,982.22 536,851.73 2.01 2,918.41 2_MWD+IFR2+MS+Sag(3) 6,116.58 89.89 121.82 3,959.37 3,900.12 -970.78 2,995.31 6,026,932.79 536,933.31 2.88 3,013.64 2_MWD+IFR2+MS+Sag (3) 6,211.94 90.01 122.84 3,959.45 3,900.20 -1,021.77 3,075.89 6,026,882.17 537,014.11 1.08 3,108.91 2_MWD+IFR2+MS+Sag (3) 6,307.01 88.59 122.86 3,960.61 3,901.36 -1,073.34 3,155.75 6,026,830.98 537,094.19 1.49 3,203.91 2_MWD+IFR2+MS+Sag (3) 6,402.72 88.16 122.58 3,963.33 3,904.08 -1,125.05 3,236.24 6,026,779.63 537,174.91 0.54 3,299.52 2_MWD+IFR2+MS+Sag(3) 6,497.84 90.07 124.61 3,964.80 3,905.55 -1,177.67 3,315.46 6,026,727.38 537,254.36 2.93 3,394.60 2_MWD+IFR2+MS+Sag(3) 6,593.25 91.86 126.78 3,963.19 3,903.94 -1,233.33 3,392.92 6,026,672.09 537,332.07 2.95 3,489.97 2_MWD+IFR2+MS+Sag (3) 6,688.30 91.86 127.69 3,960.11 3,900.86 -1,290.81 3,468.56 6,026,614.95 537,407.96 0.96 3,584.89 2_MWD+IFR2+MS+Sag(3)M 6,736.37 91.06 127.59 3,958.88 3,899.63 -1,320.16 3,506.61 6,026,585.78 537,446.14 1.68 3,632.88 2_WD+1FR2+MS+Sa9 (3) 6,783.87 90.87 127.73 3,958.08 3,898.83 -1,349.17 3,544.21 6,026,556.94 537,483.87 0.50 3,680.32 2_MWD+IFR2+MS+Sag (3) 6,818.18 90.69 127.68 3,957.61 3,898.36 -1,370.16 3,571.35 6,026,536.09 537,511.10 0.54 3,714.58 2_MWD+IFR2+MS+Sag(3) 6,879.45 90.32 126.50 3,957.07 3,897.82 -1,407.10 3,620.22 6,026,499.37 537,560.14 2.02 3,775.80 2_MWD+IFR2+MS+Sag (3) 6,925.37 91.68 125.86 3,956.27 3,897.02 -1,434.21 3,657.28 6,026,472.43 537,597.31 3.27 3,821.69 2_MWD+IFR2+MS+Sag(3) 6,973.89 92.05 125.76 3,954.69 3,895.44 -1,462.58 3,696.61 6,026,444.24 537,636.77 0.79 3,870.18 2_MWD+IFR2+MS+Sag(3) 7,015.33 91.93 125.20 3,953.25 3,894.00 -1,486.62 3,730.33 6,026,420.36 537,670.60 1.38 3,911.59 2_MWD+IFR2+MS+Sag (3) 7,069.88 91.92 125.24 3,951.42 3,892.17 -1,518.06 3,774.87 6,026,389.13 537,715.28 0.08 3,966.11 2_MWD+IFR2+MS+Sag(3) 7,107.10 91.80 124.27 3,950.21 3,890.96 -1,539.27 3,805.43 6,026,368.06 537,745.93 2.62 4,003.31 2_MWD+IFR2+MS+Sag(3) 7,164.94 90.31 124.21 3,949.15 3,889.90 -1,571.81 3,853.24 6,026,335.75 537,793.88 2.58 4,061.14 2_MWD+IFR2+MS+Sag(3) 7,208.39 89.88 124.24 3,949.08 3,889.83 -1,596.24 3,889.17 6,026,311.47 537,829.91 0.99 4,104.58 2_MWD+IFR2+MS+Sag(3) 7,257.54 90.44 125.30 3,948.94 3,889.69 -1,624.27 3,929.54 6,026,283.63 537,870.41 2.44 4,153.73 2_MWD+IFR2+MS+Sag (3) 7,353.69 89.58 126.52 3,948.92 3,889.67 -1,680.66 4,007.41 6,026,227.60 537,948.53 1.55 4,249.86 2_MWD+IFR2+MS+Sag(3) 7,450.79 89.39 127.69 3,949.80 3,890.55 -1,739.24 4,084.85 6,026,169.39 538,026.23 1.22 4,346.88 2_MWD+IFR2+MS+Sag(3) 7,545.60 88.21 124.72 3,951.78 3,892.53 -1,795.22 4,161.32 6,026,113.76 538,102.95 3.37 4,441.63 2_MWD+IFR2+MS+Sag (3) 7,641.29 90.51 123.41 3,952.85 3,893.60 -1,848.81 4,240.58 6,026,060.54 538,182.45 2.77 4,537.29 2_MWD+IFR2+MS+Sag(3) 7,736.01 90.13 122.64 3,952.32 3,893.07 -1,900.43 4,320.00 6,026,009.28 538,262.09 0.91 4,631.97 2_MWD+IFR2+MS+Sag(3) 7,831.79 89.76 122.42 3,952.41 3,893.16 -1,951.94 4,400.75 6,025,958.15 538,343.07 0.45 4,727.67 2_MWD+IFR2+MS+Sag (3) 7,878.48 89.82 122.05 3,952.58 3,893.33 -1,976.84 4,440.24 6,025,933.43 538,382.67 0.80 4,774.31 2_MWD+IFR2+MS+Sag(3) 7,927.53 90.82 121.49 3,952.31 3,893.06 -2,002.67 4,481.94 6,025,907.80 538,424.48 2.34 4,823.29 2_MWD+IFR2+MS+Sag(3) 7,974.10 90.81 120.49 3,951.65 3,892.40 -2,026.64 4,521.86 6,025,884.01 538,464.50 2.15 4,869.76 2 MWD+IFR2+MS+Sag (3)M 8,022.18 90.19 120.66 3,951.23 3,891.98 -2,051.10 4,563.25 6,025,859.74 538,506.00 1.34 4,917.70 2_WD+IFR2+MS+Sag (3) 8,067.57 89.70 119.68 3,951.27 3,892.02 -2,073.91 4,602.49 6,025,837.11 538,545.34 2.41 4,962.94 2_MWD+IFR2+MS+Sag(3) 8,117.48 89.14 118.86 3,951.78 3,892.53 -2,098.31 4,646.03 6,025,812.92 538,588.99 1.99 5,012.62 2_MWD+IFR2+MS+Sag(3) 8,213.21 87.29 119.11 3,954.76 3,895.51 -2,144.68 4,729.72 6,025,766.94 538,672.88 1.95 5,107.81 2_MWD+IFR2+MS+Sag(3) 8,308.40 87.23 121.70 3,959.31 3,900.06 -2,192.79 4,811.72 6,025,719.20 538,755.09 2.72 5,202.60 2_MWD+IFR2+MS+Sag (3) 8,403.82 87.42 124.35 3,963.76 3,904.51 -2,244.74 4,891.63 6,025,667.63 538,835.23 2.78 5,297.86 2_MWD+IFR2+MS+Sag(3) 8,499.33 87.29 126.59 3,968.17 3,908.92 -2,300.10 4,969.33 6,025,612.63 538,913.17 2.35 5,393.26 2_MWD+IFR2+MS+Sag (3) 8,591.63 88.41 126.18 3,971.63 3,912.38 -2,354.81 5,043.58 6,025,558.26 538,987.66 1.29 5,485.45 2_MWD+IFR2+MS+Sag (3) 8,689.33 89.15 126.73 3,973.71 3,914.46 -2,412.85 5,122.14 6,025,500.59 539,066.48 0.94 5,583.09 2_MWD+IFR2+MS+Sag(3) 8,784.91 89.21 126.04 3,975.08 3,915.83 -2,469.54 5,199.08 6,025,444.25 539,143.67 0.72 5,678.62 2_MWD+IFR2+MS+Sag(3) 2262019 1:44:00PM Page 9 COMPASS 5000.15 Build 91 Company: Project: Site: Well: Wellbore: Design: Survey Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 MPU M-12PB2 MPU M-12PB2 MD Inc (usft) (1) 8,877.61 90.44 8,973.20 91.37 9,070.64 89.70 9,165.86 91.31 9,261.49 89.14 9,356.37 89.39 9,452.61 89.45 9,546.70 89.14 9,642.43 89.58 9,739.35 91.12 9,832.49 92.91 9,929.24 93.60 10,024.33 91.18 10,120.16 91.18 10,215.78 90.81 10,280.79 89.57 10,308.98 89.76 10,355.19 90.13 Azi (`) 125.40 125.59 124.57 125.06 124.95 124.64 123.85 123.63 123.77 123.53 123.39 124.01 124.92 125.34 127.31 127.34 127.57 128.87 10,407.41 90.38 130.09 10,451.70 89.70 129.71 10,503.09 90.20 129.24 10,598.65 90.94 125.05 10,641.02 90.81 122.78 10,694.05 89.32 10,742.79 88.40 10,788.27 88.39 10,835.34 89.15 10,884.99 89.70 10,980.49 90.50 11,028.97 90.44 11,076.45 89.88 11,121.83 90.44 11,171.58 90.38 11,218.73 90.57 11,266.86 89.57 11,315.90 88.21 11,361.80 86.60 11,457.14 87.17 11,505.31 87.04 11,552.77 87.11 122.12 122.36 121.35 122.32 122.55 125.53 126.81 125.68 124.57 123.52 123.55 123.61 122.84 122.40 121.95 121.93 122.30 TVD (usft) 3,975.37 3,973.86 3,972.95 3,972.11 3,971.73 3,972.95 3,973.92 3,975.08 3,976.15 3,975.56 3,972.28 3,966.79 3,962.82 3,960.85 3,959.19 3,958.97 3,959.14 3,959.18 3,958.95 3,958.92 3,958.97 3,958.01 3,957.37 3,957.31 3,958.28 3,959.55 3,960.56 3,961.06 3,960.89 3,960.49 3,960.36 3,960.24 3,959.88 3,959.49 3,959.43 3,960.38 3,962.46 3,967.64 3,970.07 3,972.49 TVDSS (usft) 3,916.12 3,914.61 3,913.70 3,912.86 3,912.48 3,913.70 3,914.67 3,915.83 3,916.90 3,916.31 3,913.03 3,907.54 3,903.57 3,901.60 3,899.94 3,899.72 3,899.89 3,899.93 3,899.70 3,899.67 3,899.72 3,898.76 3,898.12 3,898.06 3,899.03 3,900.30 3,901.31 3,901.81 3,901.64 3,901.24 3,901.11 3,900.99 3,900.63 3,900.24 3,900.18 3,901.13 3,903.21 3,908.39 3,910.82 3,913.24 Halliburton Definitive Survey Report +N/ -S (usft) -2,523.66 -2,579.15 -2,635.15 -2,689.51 -2,744.36 -2,798.50 -2,852.66 -2,904.91 -2,958.02 -3,011.73 -3,063.05 -3,116.64 -3,170.40 -3,225.53 -3,282.16 -3,321.58 -3,338.72 -3,367.31 -3,400.51 -3,428.92 -3,461.59 -3,519.28 -3,542.92 -3,571.37 -3,597.36 -3,621.36 -3,646.18 -3,672.81 -3,726.26 -3,754.87 -3,782.94 -3,809.05 -3,836.90 -3,862.95 -3,889.57 -3,916.43 -3,941.15 -3,991.84 -4,017.29 -4,042.49 Local Co-ordinate Reference: Well MPU M-12 TVD Reference: M-12 Actual RKB @ 59.25usft MD Reference: M-12 Actual RKB @ 59.25usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Map +El -W Northing (usft) (ft) 5,274.34 6,025,390.48 5,352.16 6,025,335.35 5,431.89 6,025,279.72 5,510.06 6,025,225.72 5,588.39 6,025,171.23 5,666.29 6,025,117.46 5,745.85 6,025,063.67 5,824.08 6,025,011.78 5,903.72 6,024,959.03 5,984.40 6,024,905.71 6,062.05 6,024,854.75 6,142.41 6, 024, 801.53 6,220.73 6,024,748.13 6,299.09 6,024,693.36 6,376.11 6,024,637.09 6,427.81 6,024,597.91 6,450.19 6,024,580.87 6,486.49 6,024,552.45 6,526.79 6,024,519.44 6,560.77 6,024,491.19 6,600.44 6,024,458.70 6,676.59 6,024,401.37 6,711.74 6,024,377.89 6,756.49 6,024,349.65 6,797.71 6,024,323.84 6,836.32 6,024,300.03 6,876.30 6,024,275.39 6,918.21 6,024,248.96 6,997.33 6,024,195.87 7,036.47 6,024,167.44 7,074.76 6,024,139.55 7,111.87 6,024,113.61 7,153.09 6,024,085.95 7,192.39 6,024,060.09 7,232.49 6,024,033.65 7,273.51 6,024,006.98 7,312.13 6,023,982.44 7,392.70 6,023,932.12 7,433.53 6,023,906.86 7,473.67 6,023,881.85 Map Easting DLS (ft) (°1100') 539,219.17 1.50 539,297.23 0.99 539,377.21 2.01 539,455.62 1.77 539,534.19 2.27 539,612.33 0.42 539,692.12 0.82 539,770.59 0.40 539,850.46 0.48 539,931.37 1.61 540,009.25 1.93 540,089.85 0.96 540,168.41 2.72 540,247.01 0.44 540,324.28 2.10 540,376.15 1.91 540,398.60 1.06 540,435.03 2.92 540,475.49 2.38 540,509.59 1.76 540,549.40 1.34 540,625.81 4.45 540,661.07 5.37 540,705.94 3.07 540,747.27 1.95 540,785.99 2.22 540,826.08 2.62 540,868.10 1.20 540,947.46 3.23 540,986.72 2.64 541,025.14 2.66 541,062.37 2.74 541,103.71 2.11 541,143.12 0.41 541,183.34 2.08 541,224.47 3.19 541,263.20 3.64 541,344.00 0.76 541,384.94 0.27 541,425.19 0.79 Vertical Section (R) Survey Tool Name 5,771.31 2_MWD+IFR2+MS+Sag (3) 5,866.88 2_MWD+IFR2+MS+Sag (3) 5,964.31 2_MWD+IFR2+MS+Sag (3) 6,059.52 2_MWD+IFR2+MS+Sag (3) 6,155.14 2 MWD+IFR2+MS+Sag(3) 6,250.02 2_MWD+IFR2+MS+Sag(3) 6,346.25 2_MWD+IFR2+MS+Sag(3) 6,440.31 2_MWD+IFR2+MS+Sag (3) 6,536.02 2_MWD+IFR2+MS+Sag(3) 6,632.91 2_MWD+IFR2+MS+Sag (3) 6,725.97 2_MWD+IFR2+MS+Sag (3) 6,822.54 2_MWD+IFR2+MS+Sag (3) 6,917.54 2_MWD+IFR2+MS+Sag(3) 7,013.35 2_MWD+IFR2+MS+Sag(3) 7,108.91 2_MWD+IFR2+MS+Sag (3) 7,173.86 2_MWD+IFR2+MS+Sag(3) 7,202.02 2_MWD+IFR2+MS+Sag(3) 7,248.15 2_MWD+IFR2+MS+Sag (3) 7,300.19 2_MWD+IFR2+MS+Sag (3) 7,344.30 2 MWD+IFR2+MS+Sag(3) 7,395.52 2_MWD+IFR2+MS+Sag(3) 7,490.98 2_MWD+IFR2+MS+Sag (3) 7,533.33 2_MWD+IFR2+MS+Sag (3) 7,586.32 2_MWD+IFR2+MS+Sag(3) 7,635.00 2_MWD+IFR2+MS+Sag(3) 7,680.40 2_MWD+IFR2+MS+Sag (3) 7,727.40 2_MWD+IFR2+MS+Sag (3) 7,777.00 2_MWD+IFR2+MS+Sag (3) 7,872.48 2_MWD+IFR2+MS+Sag(3) 7,920.94 2_MWD+IFR2+MS+Sag(3) 7,968.41 2_MWD+IFR2+MS+Sag (3) 8,013.79 2_MWD+IFR2+MS+Sag(3) 8,063.53 2_MWD+IFR2+MS+Sag(3) 8,110.67 2 MWD+IFR2+MS+Sag (3) 8,158.78 2_MWD+IFR2+MS+Sag (3) 8,207.80 2_MWD+IFR2+MS+Sag(3) 8,253.61 2_MWD+IFR2+MS+Sag (3) 8,348.71 2_MWD+IFR2+MS+Sag (3) 8,396.76 2_MWD+IFR2+MS+Sag (3) 8,444.11 2_MWD+IFR2+MS+Sag (3) 2262019 1:44.:OOPM Page 10 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-12 Project: Milne Point TVD Reference: M-12 Actual RKB @ 59.25usft Site: M Pt Moose Pad MD Reference: M-12 Actual RKB @ 59.25usft Well: MPU M-12 North Reference: True Wellbore: MPU M-12PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-12PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1700') (ft) Survey Tool Name 11,599.10 87.48 122.49 3,974.68 3,915.43 4,067.29 7,512.75 6,023,857.23 541,464.38 0.90 8,490.34 2_MWD+IFR2+MS+Sag(3) 11,648.20 87.73 123.06 3,976.73 3,917.48 -4,093.84 7,554.00 6,023,830.87 541,505.74 1.27 8,539.37 2_MWD+IFR2+MS+Sag(3) 11,744.18 86.98 123.56 3,981.16 3,921.91 -4,146.50 7,634.12 6,023,778.59 541,586.10 0.94 8,635.21 2_MWD+IFR2+MS+Sag (3) 11,838.48 88.28 123.27 3,985.06 3,925.81 -4,198.38 7,712.77 6,023,727.07 541,664.97 1.41 8,729.40 2_MWD+IFR2+MS+Sag(3) 11,887.78 88.09 123.49 3,986.62 3,927.37 -4,225.49 7,753.91 6,023,700.15 541,706.24 0.59 8,778.66 2_MWD+IFR2+MS+Sag(3) 11,934.78 88.90 123.63 3,987.86 3,928.61 4,251.46 7,793.06 6,023,674.36 541,745.50 1.75 8,825.64 2_MWD+IFR2+MS+Sag(3) 11,985.56 89.15 123.71 3,988.72 3,929.47 4,279.61 7,835.32 6,023,646.40 541,787.88 0.52 8,876.40 2_MWD+IFR2+MS+Sag(3) 12,029.95 90.01 125.09 3,989.05 3,929.80 -4,304.69 7,871.94 6,023,621.49 541,824.62 3.66 8,920.79 2_MWD+IFR2+MS+Sag(3) 12,124.82 90.32 126.07 3,988.77 3,929.52 -4,359.89 7,949.10 6,023,566.65 541,902.02 1.08 9,015.65 2_MWD+IFR2+MS+Sag (3) 12,219.73 89.27 123.97 3,989.11 3,929.86 -4,414.35 8,026.82 6,023,512.55 541,979.98 2.47 9,110.55 2_MWD+IFR2+MS+Sag (3) 12,268.75 90.38 124.33 3,989.26 3,930.01 4.441.87 8,067.39 6,023,485.22 542,020.66 2.38 9,159.56 2_MWD+IFR2+MS+Sag(3) 12,314.52 91.50 125.04 3,988.51 3,929.26 -4,467.91 8,105.02 6,023,459.36 542,058.41 2.90 9,205.33 2_MWD+IFR2+MS+Sag(3) 12,409.07 90.87 126.14 3,986.56 3,927.31 4,522.92 8,181.89 6,023,404.70 542,135.52 1.34 9,299.84 2_MWD+IFR2+MS+Sag (3) 12,503.21 90.19 126.17 3,985.68 3,926.43 -4,578.46 8,257.90 6,023,349.52 542,211.77 0.72 9,393.95 2_MWD+IFR2+MS+Sag (3) 12,595.70 90.19 125.13 3,985.38 3,926.13 4,632.36 8,333.05 6,023,295.96 542,287.17 1.12 9,486.43 2_MWD+IFR2+MS+Sag (3) 12,644.59 90.75 125.08 3,984.98 3,925.73 4,660.48 8,373.05 6,023,268.03 542,327.29 1.15 9,535.32 2_MWD+IFR2+MS+Sag(3) 12,692.50 90.50 125.10 3,984.45 3,925.20 4,688.02 8,412.25 6,023,240.67 542,366.61 0.52 9,583.23 2_MWD+IFR2+MS+Sag (3) 12,739.43 90.63 124.84 3,983.99 3,924.74 -4,714.92 8,450.70 6,023,213.95 542,405.18 0.62 9,630.15 2_MWD+IFR2+MS+Sag (3) 12,786.84 90.50 125.04 3,983.52 3,924.27 4,742.07 8,489.56 6,023,186.98 542,444.16 0.50 9,677.56 2 MWD+IFR2+MS+Sag (3) 12,823.46 90.32 124.85 3,983.26 3,924.01 4,763.04 8,519.58 6,023,166.15 542,474.27 0.71 9,714.18 2_MWD+IFR2+MS+Sag(3) 12,881.43 90.32 125.12 3,982.94 3,923.69 4,796.28 8,567.08 6,023,133.13 542,521.91 0.47 9,772.15 2_MWD+IFR2+MS+Sag(3) 12,909.15 91.25 125.20 3,982.56 3,923.31 -4,812.24 8,589.74 6,023,117.27 542,544.64 3.37 9,799.87 2_MWD+IFR2+MS+Sag(3) 12,976.31 92.98 125.49 3,980.08 3,920.83 -4,851.06 8,644.48 6,023,078.70 542,599.56 2.61 9,866.97 2_MWD+IFR2+MS+Sag (3) 13,020.08 92.23 125.22 3,978.09 3,918.84 4,876.36 8,680.14 6,023,053.57 542,635.33 1.82 9,910.70 2_MWD+IFR2+MS+Sag(3) 13,069.08 92.48 125.93 3,976.08 3,916.83 4,904.85 8,719.96 6,023,025.27 542,675.28 1.54 9,959.65 2_MWD+IFR2+MS+Sag(3) 13,114.58 91.05 126.19 3,974.68 3,915.43 -4,931.62 8,756.72 6,022,998.67 542,712.16 3.19 10,005.12 2_MWD+IFR2+MS+Sag(3) 13,165.10 90.13 125.94 3,974.16 3,914.91 -4,961.36 8,797.56 6,022,969.12 542,753.12 1.89 10,055.62 2_MWD+IFR2+MS+Sag (3) 13,214.19 89.57 125.63 3,974.28 3,915.03 4,990.06 8,837.38 6,022,940.60 542,793.07 1.30 10,104.70 2_MWD+IFR2+MS+Sag (3) 13,259.96 87.96 126.15 3,975.27 3,916.02 -5,016.89 8,874.45 6,022,913.95 542,830.26 3.70 10,150.45 2_MWD+IFR2+MS+Sag(3) 13,308.44 87.60 126.35 3,977.15 3,917.90 -5,045.53 8,913.52 6,022,885.49 542,869.45 0.85 10,198.88 2_MWD+IFR2+MS+Sag(3) 13,354.76 87.48 126.18 3,979.14 3,919.89 -5,072.90 8,950.83 6,022,858.29 542,906.89 0.45 10,245.14 2_MWD+IFR2+MS+Sag(3) 13,449.89 87.23 124.91 3,983.53 3,924.28 -5,128.15 9,028.15 6,022,803.40 542,984.45 1.36 10,340.16 2 MWD+IFR2+MS+Sag (3) 13,544.23 89.71 125.03 3,986.05 3,926.80 -5;182.19 9,105.42 6,022,749.71 543,061.96 2.63 10,434.46 2_MWD+IFR2+MS+Sag (3) 13,638.38 89.33 124.64 3,986.83 3,927.58 -5,235.97 9,182.70 6,022,696.29 543,139.48 0.58 10,528.61 2_MWD+IFR2+MS+Sag (3) 13,733.66 88.46 124.37 3,988.67 3,929.42 -5,289.94 9,261.20 6,022,642.69 543,218.22 0.96 10,623.87 2 MWD+IFR2+MS+Sag(3) 13,828.72 89.08 122.50 3,990.71 3,931.46 -5,342.30 9,340.51 6,022,590.70 543,297.75 2.07 10,718.87 2_MWD+IFR2+MS+Sag(3) 13,922.42 87.78 122.13 3,993.28 3,934.03 -5,392.37 9,419.66 6,022,541.00 543,377.13 1.44 10,812.45 2_MWD+IFR2+MS+Sag (3) 14,017.73 88.34 124.86 3,996.51 3,937.26 5,444.93 9,499.09 6,022,488.80 543,456.79 2.92 10,907.67 2_MWD+IFR2+MS+Sag (3) 14,112.24 89.52 126.87 3,998.27 3,939.02 -5,500.29 9,575.66 6,022,433.80 543,533.60 2.47 11,002.14 2_MWD+IFR2+MS+Sag(3) 14,206.74 89.70 127.34 3,998.92 3,939.67 -5,557.30 9,651.03 6,022,377.14 543,609.22 0.53 11,096.56 2_MWD+IFR2+MS+Sag(3) 2/262019 1: 44:OOPM Page 11 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: MPU M-12PB2 Design: MPU M-12PB2 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-12 M-12 Actual RKB @ 59.25usft M-12 Actual RKB @ 59.25usft True Minimum Curvature NORTH US+CANADA 2/26/2019 1:44:OOPM Page 12 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) n (usft) (usft) (usft) (usft) (ft) (ft) (°/7001) (ft) Survey Tool Name 14,301.13 90.38 126.82 3,998.85 3,939.60 -5,614.21 9,726.33 6,022,320.58 543,684.78 0.91 11,190.87 2_MWD+IFR2+MS+Sag (3) 14,396.62 89.64 125.55 3,998.83 3,939.58 -5,670.58 9,803.40 6,022,264.56 543,762.09 1.54 11,286.33 2_MWD+IFR2+MS+Sag (3) 14,490.99 86.85 125.14 4,001.72 3,942.47 -5,725.14 9,880.33 6,022,210.36 543,839.27 2.99 11,380.65 2 MWD+IFR2+MS+Sag (3) 14,584.47 88.10 126.41 4,005.84 3,946.59 -5,779.74 9,956.10 6,022,156.12 543,915.27 1.91 11,474.02 2_MWD+IFR2+MS+Sag(3) 14,681.86 86.92 126.47 4,010.07 3,950.82 -5,837.53 10,034.37 6,022,098.69 543,993.80 1.21 11,571.27 2_MWD+IFR2+MS+Sag(3) 14,776.20 88.34 126.32 4,013.97 3,954.72 -5,893.46 10,110.24 6,022,043.11 544,069.92 1.51 11,665.49 2_MWD+IFR2+MS+Sag(3) 14,871.29 88.96 127.03 4,016.21 3,956.96 -5,950.24 10,186.49 6,021,986.69 544,146.41 0.99 11,760.51 2_MWD+IFR2+MS+Sag(3) 14,965.80 87.91 126.39 4,018.79 3,959.54 -6,006.71 10,262.22 6,021,930.57 544,222.40 1.30 11,854.93 2 MWD+IFR2+MS+Sag(3) 15,060.10 86.79 123.09 4,023.16 3,963.91 -6,060.38 10,339.62 6,021,877.25 544,300.03 3.69 11,949.11 2_MWD+IFR2+MS+Sag (3) 15,154.32 90.20 122.83 4,025.63 3,966.38 -6,111.62 10,418.63 6,021,826.38 544,379.27 3.63 12,043.24 2_MWD+IFR2+MS+Sag (3) 15,248.34 90.57 122.77 4,025.00 3,965.75 -6,162.55 10,497.66 6,021,775.82 544,458.52 0.40 12,137.20 2_MWD+IFR2+MS+Sag(3) 15,344.11 88.21 120.11 4,026.02 3,966.77 -6,212.49 10,579.35 6,021,726.25 544,540.43 3.71 12,232.78 2_MWD+IFR2+MS+Sag(3) 15,438.64 89.95 120.96 4,027.54 3,968.29 -6,260.51 10,660.76 6,021,678.61 544,622.05 2.05 12,327.03 2 MWD+IFR2+MS+Sag (3) 15,534.16 88.90 124.89 4,028.49 3,969.24 -6,312.41 10,740.92 6,021,627,08 544,702.44 4.26 12,422.48 2_MWD+IFR2+MS+Sag (3)M 15,629.32 89.64 126.31 4,029.71 3,970.46 -6,367.80 10,818.28 6,021,572.05 544,780.05 1.68 12,517.62 2_WD+IFR2+MS+Sag(3) 15,724.50 92.30 127.35 4,028.10 3,968.85 -6,424.84 10,894.45 6,021,515.36 544,856.46 3.00 12,612.71 2_MWD+IFR2+MS+Sag(3) 15,817.60 91.74 125.15 4,024.81 3,965.56 -6,479.86 10,969.48 6,021,460.70 544,931.73 2.44 12,705.72 2_MWD+IFR2+MS+Sag(3) 15,914.10 92.92 124.43 4,020.89 3,961.64 -6,534.87 11,046.66 6,021,406.05 545,011.16 1.43 12,802.14 2_MWD+IFR2+MS+Sag (3) 16,009.85 93.41 124.28 4,015.60 3,956.35 -6,588.82 11,127.59 6,021,352.47 545,090.32 0.54 12,897.74 2_MWD+IFR2+MS+Sag(3) 16,104.05 93.91 124.47 4,009.59 3,950.34 -6,641.90 11,205.18 6,021,299.75 545,168.15 0.57 12,991.74 2_MWD+IFR2+MS+Sag (3) 16,199.27 91.79 123.33 4,004.86 3,945.61 -6,694.94 11,284.11 6,021,247.08 545,247.31 2.53 13,086.83 2_MWD+IFR2+MS+Sa9 (3) 16,294.18 88.58 122.74 4,004.55 3,945.30 -6,746.67 11,363.66 6,021,195.71 545,327.09 3.44 13,181.68 2_MWD+IFR2+MS+Sag(3) 16,389.10 87.35 123.76 4,007.92 3,948.67 -6,798.68 11,442.99 6,021,144.07 545,406.65 1.68 13,276.50 2_MWD+IFR2+MS+Sag(3) 16,483.95 86.98 124.05 4,012.61 3,953.36 -6,851.52 11,521.62 6,021,091.59 545,485.51 0.50 13,371.22 2_MWD+IFR2+MS+Sag(3) 16,572.41 86.80 125.00 4,017.41 3,958.16 -6,901.58 11,594.39 6,021,041.87 545,558.50 1.09 13,459.55 2_MWD+IFR2+MS+Sag(3) 16,643A0 86.80 125.00 4,021.35 3,962.10 -6,942.01 11,652.12 6,021,001.71 545,616.41 0.00 13,530.03 PROJECTED to TD Checked By: Chelsea Wright y ' i r ,- Approved By: Mitch Laird - Date: 2-26-2019 2/26/2019 1:44:OOPM Page 12 COMPASS 5000.15 Build 91 Nilcorp Energy Company CASING & CEMENTING REPORT Lease 8 Well No. MP M-12 Date Run 8 -Feb -19 County State Alaska Sup, SundedarM/Toomey CASING RECORD Surhra � TO 5,107.00 Shoe Depth: 4,885.00 PBTD: 4,721.59 RKB 33.91 RKB to BHF RKB to CHF RKB to THF usg VVL un noox: [ ouuu I ype moat Gollar Antebpe No. Hm to Run16.5 Csg Wt. On Slips: 100,000 Type of Shoe: Antelope Casing C. Doyon Casing Ratats Csg X Yes No Recip Csg X Yes _ No Ft. Min. 94 PPG Fluid Description: Spud Mud Liner hanger Into(Make/Model): Liner top Packer?: _Yes No Liner hanger test pressures Floals Held X Yes_ No Centralizer Placement. Install 83 bow spring centralizers (12-1/4- x 9S/8-) refer to tally for placement. CEMENTING REPORT Shoe @ 4885 FC @ 4,802.65 Casing (Or Liner) Detail Preflush(Spacer) Selling Depths its. Component Size Wt Grade THD Make Length Bottom Top 1 Float shoe 103/4 40.0 L-80 UP Antelope 1.54 4,885.00 4,883.46 2 Casing 95/8 40.0 L-80 TXP Volume pumped(BBLs) 79.56 4,883.46 4,803.90 1 Float Collar 103/4 Type: Fresh Water L-80 TXP Antelope 1.25 4,803.90 4,802.65 1 Casing 95/8 40.0 L-80 TXP Bump Plug? X Yes No Bump press 1000 50.10 4,802.65 4,762.55 1 Baffle Adapter 103/4 as Yes No Spacerretums? L-80 TXP Halliburton 1.17 4,762.55 4,761.38 Methad Used To Determine TOC: Casing 95/8 40.0 L-80 UP Closure OK Yes 2,670.91 4,761.38 2,090.47 1 Pup Joint 95/8 40.0 L-80 TXP 14.65 2,090.47 2,075.82 1 ESIPC 113/4 Density (ppg) 107 L-80 TXP Halliburton 11.91 2,075.82 2,063.91 1 Pup Joint 95/8 40.0 L-80 TXP Volume pumped (BBLs) 14.83 2,063.91 2,049.08 51 Casing 95/8 40.0 1 L-80 TXP w 2,000.20 2,049.08 48.88 1 Cutloint 95/8 40.0 L-80 TXP cap: Rig 16.48 48.88 32.40 X No Reciprocated? _Yes X No % Returns during job 100 Cement returns to surface? % Yes _No Spacer returns? % Yes No Vol to Sud: 136 _ Cement In Place At: 23:05 Dale; 2192019 Estimated TOC: 36 usg VVL un noox: [ ouuu I ype moat Gollar Antebpe No. Hm to Run16.5 Csg Wt. On Slips: 100,000 Type of Shoe: Antelope Casing C. Doyon Casing Ratats Csg X Yes No Recip Csg X Yes _ No Ft. Min. 94 PPG Fluid Description: Spud Mud Liner hanger Into(Make/Model): Liner top Packer?: _Yes No Liner hanger test pressures Floals Held X Yes_ No Centralizer Placement. Install 83 bow spring centralizers (12-1/4- x 9S/8-) refer to tally for placement. CEMENTING REPORT Post on calcuiatlons: Calculated Cmt Vol ® 0% excess: 297 Total Volume curt Pumped: Cmt returned to surface: 187.3 Calculated cement left in wellbore: 306.4 OH volume Calculated 266.2 ON volume actual: Actual % Washout Shoe @ 4885 FC @ 4,802.65 Top of Liner #N/A Preflush(Spacer) Type: Clean Spacer Density (ppg) 10 Volume pumped(BBLs) 60 Lead Slurry Type; ExtendaCEM Sacks: 275 Yield: 2.36 Density (ppg) 12 Volume pumped(BBLs) 115. Mixing/Pumping Rate (bpm): 3 Tail Slurry w Type: SWIBCEM(class G) Sacks: 485 Yeld: 1.56 Density(ppg) 15.8 Volume pumped(BBLs) 99.2 Mixing l Pumping Rate (bpm): 3 '^ r Post Flush (Spacer) as Type: Fresh Water Density (ppg) 8.34 Rate (bpm): 3 Volume: 20 Displacement: Type: Spud Mud Density (ppg) 9.4 Rate (bpm): 5 Volume (actual I calculated). 338/361 FCP (psi). 860 Pump used fordisp: Rig Bump Plug? X Yes No Bump press 1000 Casing Rotated? X Yes _No Reciprocated? X Yes NO % Returns during jab 100 Cement returns to surface? as Yes No Spacerretums? X Yes No Vol to Surf 30 Cement In Place At 14:39 Dale: 2/92019 Estimated TOC: 2,064 Methad Used To Determine TOC: Circulated cement out Stage Collar@ 2003.91 Type ES Cementer Closure OK Yes Preflush (Spacer) Type: Clean Spacer Density(ppg) 10 Volume pumped(BBLs) 60 Lead Slurry Type: PermafrostL Sacks: 277 Yeid: 433 Density (ppg) 107 Volume pumped(BBLs) 220 Mixing/ Pumping Rate (bpm): 3 Tall Slurry Type: SwiftCEM (Gass G) Sacks: 270 Yield: 1.12 n Density (ppg) 15.8 Volume pumped (BBLs) 55.8 Mixing /Pumping Rate (bpm): 3 o Post Flush (Spacer) Type: Fresh Water Density (ppg) 8.34 Rate(bpm): 20 Volume: 5 w Displacement: Type: Spud Mud Density (ppg) 9.4 Rate (bpm): 3 Volume (actual I calculated): 135/156 FCP(psi): 397 Pump used for cap: Rig Bump Plug? X Yes -No Bump press 1600 Casing Rotated? _Yes X No Reciprocated? _Yes X No % Returns during job 100 Cement returns to surface? % Yes _No Spacer returns? % Yes No Vol to Sud: 136 _ Cement In Place At: 23:05 Dale; 2192019 Estimated TOC: 36 Melhod Used To Determine TOC Cement to surface Post on calcuiatlons: Calculated Cmt Vol ® 0% excess: 297 Total Volume curt Pumped: Cmt returned to surface: 187.3 Calculated cement left in wellbore: 306.4 OH volume Calculated 266.2 ON volume actual: Actual % Washout Debra Oudean Hilcorp Alaska, LLC 30 4 3 3 AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 H&,gyp Alz,A..Lre. Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 3/8/2019 To: Alaska Oil & Gas Conservation Commission RECEIVED Natural Resource Technician MAR 12 2019 333 W 7th Ave Ste 100 Anchorage, AK 99501 AOGCC ROP DGR EWR ABG ADR WELLBORE PROFILE MD & TVD _Log Viewers 3/8/20192.06 PM Filefolder CGM 3/8/2019 2.07 PM Filefolder Definitive Survey 3/8/2019 2118 PM Filefolder EMF 318/20192:08 PM Filefolder LAS 3/8/20192:08 PM Filefolder PDF 3/8/20192:08 PM File folder TIFF 318/20192:08 PM Filefolder CD: HALLIBURTON 25 FEB 2019 Please include current contact information if different from above. Please acknowledge rViceipt by,%g} ing and teturning one copy of this transmittal or FAX to 907 777.8510 DATE: 3/8/2019 218176 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 1400 30 4 3 4 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 RECEIVED MAR 12 2019 AOGCC MPU M-12, M-12 PB1 & M-12 PB2 (PTD 218-176) ROP DGR EWR ABG ADR WELLBORE PROFILE MD & TVD Lag Viewers CGM .:, Definitive Suney EMF LAS PDF TIFF CD: HALLIBURTON 25 FEB 2019 3/8/2019 L06 PPJI File folder 3;8J20192:07PM Filefolder 3J82 19 LIM PM Filefolder 3 E!20192MPM Filefolder 3P.20192:D9PI'A Filefolder 312/2019 2:0B PPA Filefolder 3;'E,20192:08 PM Filefolder Please include current contact information if different from above. Please acknowledge Received by s( mg and teturning one copy of this transmittal or FAX to 907 777.8510 DATE: 3/8/2019 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 RECEIVED MAR 12 2019 AOGCC MPU M-12, M-12 PB1 & M-12 PB2 PTD 218-176) ROP DGR EWR ABG ADR WELLBORE PROFILE MD & TVD Log Viewers CGM Definitive Survey EMF LAS PDF TIFF CD: HALLIBURTON 25 FEB 2019 3/8/20192:05 PM Filefolder 3/8/2D1 9 2:07 PM Filefolder 3/8,/2019 2:08 PM File (elder 318/20192: D8PK4 Filefolder 3/8/20192:08 PM Filefolder 3/8/2019 2:08 PM Filefolder 3}8/20192:08 PM Filefolder Please include current contact information if different from above. Please acknowledge Received 2 1 9, 176 30435 by,sigring and keturning one c' py of this transmittal or FAX to 907 777.8510 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: Milne Point Field, Schrader Bluff Oil Pool, MPU M-12 Hilcorp Alaska, LLC Permit to Drill Number: 218-176 Surface Location: 5037' FSL, 231' FEL, SEC. 14, T13N, R9E, UM, AK Bottomhole Location: 1987' FNL, 1010' FWL, SEC. 20, TI 3N, RI OE, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. 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 Hilcorp Alaska, LLC in the attached application, the following well logs are also required for this well: At minimum a gamma ray log is required from base of conductor to surface casing shoe, and gamma ray and resistivity logs are required from surface casing shoe to total depth of this well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair r DATED this day of January, 2019. I STATE OF ALASKA AL..—,<A OIL AND GAS CONSERVATION COMMW� _ION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG LJ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑A • Lateral ❑ Stratigraphic Test ❑ Development - Oil D ' Service - Winj ❑ Single Zone 0 • Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket [] • Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 MPU M-12 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 16,752' ND: 4,019' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5037' FSL, 231' FEL, Sec 14, T13N, R9E, UM, AK • ADL025514: ADL388235, ADL025515 8. DNR Approval Number: 13. Approximate Spud Date: Top of Productive Horizon: 609' FNL, 1949' FWL, Sec 13, T13N, R9E, UM, AK LONS 16-008 1/19/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1987' FNL, 1010' FWL, Sec 20, T13N, R10E, UM, AK 7024 2042' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 58.7 • 15. Distance to Nearest Well Open Surface: x- 533933. y- 6027889 - Zone -4 GL / BF Elevation above MSL (ft): 25 - to Same Pool: 2215' from MPF -110 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 1739 - Surface: 1349 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) Cond 20" - X-52 Weld 113' Surface Surface 113' 113' -270 ft3 Sig 1 L - 647 ft3 / T - 458 ft3 12-1/4" 9-5/8" 40# L-80 TXP SR 5,088' Surface Surface 5,088' 3,969' - Stg 2 L - 1937 ft3 / T - 314 ft3 Tieback 7" 26# L-80 TXP SR 4,938' Surface Surface 4,938' 3,951' Tieback Assy 8-1/2" 6-5/8" 20# L-80 Hyd 563 11,814' 4,938' 3,951' 16,752' , 4,019' PreDrilled Liner / Cementless 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑Q 20. Attachments: Property Plat Q BOP Sketch Drilling Program Time v. Depth Plot Time Shallow Hazard Analysis Diverter Sketch e✓ Seabed Report e Fluid Program 8 20 AAC 25.050 requirements e 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'eD el hilCOf .COfil Authorized Title: Drilling Manager Contact Phone: 777-8395 t Date: Authorized Signature: •- Commission Use Only Permit to Drill n -7 24 9; Number -, 7 / / � Permit Approval I See cover letter for other requirements. Number: <� 50-bZ(- L�tP( Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane. gas hydrates, or gas contained in shales: r Other: ,#L (�a 5_ goP ��- Samples req'd: Yes❑ No& Mudlogreq'd:Yes❑ No[Dw HzS measures: Yes ❑ N, [j'. Directional svy req'd: Yes No El j� Spacing exception req'd: Yes L1 No L�1 Inclination -only svy req'd: Yes ❑ No l'J -,r- Z zs• Post initial injection MIT req'd: Yes ❑ No ❑ !„�f1✓� 2 -d rc�R-� V APPROVED BY l Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and I F 10-401 Revised 5/2017 Q This permit is valid f f ,{ a o approval per 20 AAC 25.00,5(g Attac� Iq s In Duplicate \irJ� `Y°� 1 3 / 1 �`R��A� dy3-�2-31 �X H Hilcorp Bei 12.27.2018 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7m Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill MPU M-12 Joe Engel Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email: jengel@hilcorp.com Dear Commissioner, Hilcorp Alaska, LLC hereby submits for review and approval for a Permit to Drill an onshore production well at Milne Point'M' Pad, well slot 12. Drilling operations are intended to commence approximately Jan. 19th, 2019, pending rig schedule. MPU M-12 is a grassroots let pump producer planned to be drilled in the Schrader Bluff OA sand. M- � j ) 12 is part of a multi well program targeting the Schrader Bluff sand on M -Pad. �''°+i �lQ The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 6-5/8" pre -drilled liner will be run in the open hole section and the well produced with a jet pump assembly. The Doyon 14 will be used to drill and complete the wellbore. Please find attached the Form 10401, Application For Permit to Drill per 20 AAC 25.005 (a) and the drilling program for MPU M-12, which includes information required by 20 AAC 25.005 (c). If you have any questions, or require further information, please do not hesitate to contact myself (Joe Engel) at 777-8395 or jengel@hilcorp.com or Monty Myers at 777-8431 or mmyers@hilcorp.com. Sincerely, Joe Engel Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 H Hilco . C®rpyy En 6.0 Planned Wellbore Schematic HPROPOSED SCHEMATIC uD.... n X64,,.I I I Odg. 0 BM:5& 7/ GLElev.: 25.D TD=16,75Y (MC) / TD= 4019' nYq P81D=1(5741' (N0)/TD=4.019'(IVD) Page 6 Milne Point Unit M-12 SB Producer Drilling Procedure Milne Point Unit Well: MPU Moose Pad M-12 Last Completed: Proposed PTD: TBD TREE & WELLHEAD Tree I Cameron 3 V7- SM Wellhead FMC 163/4"3MX11"SM MuMibowl w/11' x 31/2' WE Top and BOHan% B r CIW "H" 8W c61e. Zea 3 ' NPTControI lines. OPEN HOLE /CEMENT DETAIL 4Y 50k (30 Vndsft�vM dumped down bedside) 12-1/4-I stage 646 R31LM WS3g 458 ft315.6X kW=M 12-1/4'2Wscree 1937ft31O7#Peron L,314ft315."L4ftCE &1/7- Cemen liner in 8-1/2' hole CASING DETAIL Site Type Grade/ConnDrift 1O Top 81m BPF IO'x34' CanduRor Drnulated) -/X-52/Weld WA Surface 113' WA 9.5/8" wna,e 40/L-80/7XPSR &6w wrfam %w Omw r Tiebadr 26/1.-60/7XPSR 6.1Sr Sinfe. 4.938' 0.0982 65/8' Umr(Pre-Od6ed) 20/L-0 /HWd1563 5.924' 4,958' 16,752'. 0.0355 TUBING DETAIL 3w Tubing 9.3/L-90/EUE-M01) 1667- I wrf 9,918' Q009] WELL INCLINATION DETAIL XOP tD 400' MM Hole Mgle =60.00dK. @ let purrm Mu Hole Arele=61.D0 deg. � XN profile Max We Angle 27LOD deg. @Tubing tall Mex sole Angle x MOD deg. @ 5,307 MD IFWFI Ry OFTAII. No. Top MD Item Drift ID Upper Cpmpleb. 1 29' Tubing Hanger (3-112N EUE-MOD TDI, &e 2.867- 2 2,500' 3.5'GL0Iw/L5'DG0Vw/11)(Latch 2,867- 3 4,204 3.5' Wemal %eswre Gauge Mandrel (DnxFnW Garee) 1813' 4 4,255' 3.5'Jet Pump Ca^. Forward CIIC let Pump toMnubs); 3,"WD 2.613' 5 4,300' 3.5'Geuge MandrelwfWWire(lntake Gauge) 2A13- 6 4,350' 7.3.5- PHLRetnevable Packer 1813' 7 4,400 9.5'XNNipple,MinlD•2.7SW Gg2,813'PaddMBore 2.750' 8 4,938' 3.5' WLEG Men @ 4,750') 2,867- 14wer Campletlpn 9 4,938' rTieback MW- (8,25'OD No -Go IN 4,]35) 6.151' 10 4,938- BDr SIZ1IP Li TOp PMker W/BD Rips r x 9-5/8'(11.5 Tieback 5lienel 6.2 114,950' r 569 L -80x63/6" ri1625 L40 XO 5.924' 32 4,915' 6-5/8' PrtOdlled U. sme 13 16,735" 4-1/2' Drillable Paco f Sub L40D' 14 16,745" 1 WV Valve LTC BAD (1.5* Bell en 3v Closed Reveed by. JPE 12/22/2019 Hilcorp Alaska, LLC Milne Point Unit (MPU) M-12 Drilling Program Version 1 12/27/2018 Table of Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 RAJ and Preparatory Work..........................................................................................................10 Anticipated Drilling Hazards.......................................................................................................45 10.0 N/U 21-1/4" 2M Diverter System.................................................................................................11 Doyon 14 Layout............................................................................................................................47 11.0 Drill 12-1/4" Hole Section.............................................................................................................13 FIT Procedure................................................................................................................................48 12.0 Run 9-5/8" Surface Casing...........................................................................................................16 Doyon 14 Choke Manifold Schematic..........................................................................................49 13.0 Cement 9-5/8" Surface Casing.....................................................................................................21 Casing Design.................................................................................................................................50 14.0 BOP NIU and Test.........................................................................................................................26 8-1/2" Hole Section MASP............................................................................................................51 15.0 Drill 8-1/2" Hole Section...............................................................................................................27 Spider Plot (NAD 27) (Governmental Sections).........................................................................52 16.0 Run 6-5/8" Production Pre -Drilled Liner...................................................................................31 Surface Plat (As Built) (NAD 27).................................................................................................53 17.0 Run 7" Tieback..............................................................................................................................36 18.0 Run Jet Pump Completion...........................................................................................................39 19.0 RDMO............................................................................................................................................39 20.0 Doyon 14 Diverter Schematic.......................................................................................................40 21.0 Doyon 14 BOP Schematic.............................................................................................................41 22.0 Wellhead Schematic......................................................................................................................42 23.0 Days Vs Depth................................................................................................................................43 24.0 Formation Tops & Information...................................................................................................44 25.0 Anticipated Drilling Hazards.......................................................................................................45 26.0 Doyon 14 Layout............................................................................................................................47 27.0 FIT Procedure................................................................................................................................48 28.0 Doyon 14 Choke Manifold Schematic..........................................................................................49 29.0 Casing Design.................................................................................................................................50 30.0 8-1/2" Hole Section MASP............................................................................................................51 31.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................52 32.0 Surface Plat (As Built) (NAD 27).................................................................................................53 33.0 Schrader Bluff OA Sand Offset MW vs TVD Chart..................................................................54 34.0 Drill Pipe Information 5" 19.5# 5-135 DS -50 & NC50...............................................................55 Milne Point unit M-12 SB Producer HtIC Drilling Procedure 1.0 Well Summary Well MPU Pad Milne Point "M" Pad Planned Completion Type Jet Pump on 3-1/2" Production Tubing Target Reservoir(s) Schrader Bluff OA Sand Planned Well TD, MD / TVD 16,752' MD / 4,019' TVD PBTD, MD / TVD 16,741' MD / 4,019' TVD Surface Location Govemmental 5037' FSL, 231' FEL, Sec 14, T13N, R9E, UM, AK Surface Location (NAD 27) X= 533,933.8, Y= 6,027,889.8 Top of Productive Horizon (Governmental) 609' FNL, 1949' FWL, Sec 13, TI 3N, R9E, UM, AK TPH Location (NAD 27) X= 536,115.09 Y= 6,027,532.74 BEL Govemmental 1987' FNL, 1010' FWL, See 20, T13N, R10E, UM, AK BHL (NAD 27) X= 545,711.99, Y=6,020,928.0 AFE Number 1814312 AFE Drilling Days 17 days AFE Completion Das 8 days AFE Drilling Amount $4,080,460 AFE Completion Amount $2,293,540 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1349 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1739 psig Work String 5" 19.5# S-135 DS -50 & NC 50 KB Elevation above MSL: 33.7 ft + 25.0 ft = 58.7 ft GL Elevation above MSL: 25.0 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 Milne Point Unit M-12 SB Producer Hilcotp Drilling Procedure E^�® M% 2.0 Management of Change Information H Mlcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: 1212-82018 Subject: Changes to Approved Permit to Drill for MPU M-12 File #: MPU M-12 Drilling and Completion Program Any modifications to MPU M-12 Drilling & Completion Program will be documented and approved below. Changes to an approved APD vall be confflun catgdto the AOGCC. <-t��24i C c. Eca -, -- &,-11G-i.<{/ J Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 M S/ /'R' 3.0 Tubular Program: Milne Point Unit M-12 SB Producer Drilling Procedure 4.0 Drill Pipe Information: All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 n Hilcorp Eo c2,T 5.0 Internal Reporting Requirements Milne Point Unit M-12 SB Producer Drilling Procedure 5.1 Pill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolinina hilcorp.com mmyers@hilcorp jengel@hilcorp.com and cdinizer@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Rud' Casing tally to mmverst7a hilcorp,com ieneelna hilcor p.com and cdingerghilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers hilcorp.com jen eg�hilcoip.com and cdinger@hileorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 len¢el@hilcorp.com Completion Engineer Stan Porhola 907.777.8412 907.331.8228 sporhola@hilcoro.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham(cDhilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 1 907.777.8477 907.350.9439 1 kfleminel@hilcoro.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 0 7.0 Drilling / Completion Summary Milne Point Unit M-12 SB Producer Drilling Procedure MPU M-12 is a grassroots jet pump producer planned to be drilled in the Schrader Bluff OA sand. M-12 is part of a multi well program targeting the Schrader Bluff sand on M -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 6-5/8" pre -drilled liner will be run in the open hole section and the well produced with a jet pump assembly. The Doyon 14 will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately Jan 19, 2019, pending rig schedule. Surface casing will be run to 5,088 MD / 3,968' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. MIRU Doyon 14 to well site 2. N/U & Test 21-1/4" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing 4. N/D diverter, N/U & test 13-5/8" x 5M BOP 5. Drill 8-1/2" lateral to well TD. Run 6-5/8" production liner 6. Run 7" tieback 7. Run completion 8. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 FA H Hileorp Milne Point Unit M-12 SB Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU M-12. Ensure to provide AOGCC 24 Ins notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: Hilcorp Alaska LLC respectfully requests a variance to 20 AAC 25.265 (c)(1), requiring the surface <-- -- safety valve be located in the vertical run of the well tree. Due to the jet pump production method and horizontal tree configuration, Hilcorp Alaska proposes that the surface safety valve be installed horizontally. V- A;ornJ Qr:,�- �el� Page 8 H Hilc �,2,,orp Summary of BOP Equipment & Notifications Milne Point Unit M-12 SB Producer Drilling Procedure Hole Section Equipment Test Pressure(psi) 12 1/4" • 21-1/4" 2M Diverter w/ 16" Diverter Line Function Test Only • 13-5/8" x 5M Hydril "GK" Annular BOP • 13-5/8" x 5M Hydril MPL Double Gate Initial Test: 250/9i o Blind ram in bum cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" 13-5/8" x 5M Hydril MPL Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPS. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: 0 AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email:, iim.rega@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loel2l2@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixsena,alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/oac/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 H Hilcorp �C.-Pr" 9.0 R/U and Preparatory Work Milne Point Unit M-12 SB Producer Drilling Procedure 9.1 M-12 will utilize a newly set 20" conductor on M -Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4" nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Doyon 14. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<80°F). 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Ensure 6" liners in mud pumps. • Continental EMSCO FB -1600 mud pumps are rated at 4665 psi, 462 gpm @ 110 spm @ 95% volumetric efficiency. Page 10 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M Diverter System (Diverter Schematic attached to program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • NIU 21-1/4" diverter "T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ienition source • Place drip berm at the end of diverter line 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 11 Milne Point unit M-12 SB Producer Hilo Drilling Procedure 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M Diverter System (Diverter Schematic attached to program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • NIU 21-1/4" diverter "T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ienition source • Place drip berm at the end of diverter line 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 11 H HilcoT EmBY®V�^9 10.5 Rig & Diver -ter Orientation: • May change on location Milne Point Unit M-12 SB Producer Drilling Procedure 75' Radius Clear of Ignition Sources Diverter Line MPU W Pa d *Drawing Not To Scale Page 12 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 11.2 5" Drill string, HWDP, and Jars will come from Weatherford. 11.3 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. • Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.4 Drill 12-1/4" hole section to section TD, in the Schrader OA sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. • Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). <-- • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. Page 13 Milne Point Unit M-12 SB Producer Hilcorp � �v.�r Drilling Procedure 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 11.2 5" Drill string, HWDP, and Jars will come from Weatherford. 11.3 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. • Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.4 Drill 12-1/4" hole section to section TD, in the Schrader OA sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. • Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). <-- • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. Page 13 H Hilcorp M-2 Milne Point Unit M-12 SB Producer Drilling Procedure • Gas hydrates have not been seen on M -Pad. However, be prepared for them. In MPU they have been encountered typically around 2100-2400' TVD (just below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Past wells on E pad have increased MW to 9.8 ppg and added 1-1.5ppb of Lecithin & .5% lube. After drilling through hydrate sands, MW was cut back to normal • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. • Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. ' 11.5 12-1/4" hole mud program summary: Page 14 • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ L Depth Interval MW ) Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells MW can be cut once —500' below hydrate zone • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. Milne Point Unit M-12 SB Producer Drilling Procedure • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). System Type: 8.8 — 9.2 ppg Pre -Hydrated Aquagel/freshwater spud mud Prnnerfies Section Density Viscosity Plastic Viscosity Yield Point API FL PH Tem Surface 1 8.8-9.8.1 75-175 1 20-40 1 25-45 <10 8.5-9.0 0.08 System Formulation: Gel + FW spud mud Product- Surface hole Size Pkg ppb or (% liquids) M -I Gel 50 lb sx 25 Soda Ash 50 Ib sx 0.25 Pol Pac Supreme UL 50 lb sx 0.08 Caustic Soda 50 lb sx 0.1 SCREENCLEEN 55 gal dm 0.5 11.6 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.7 RIH t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 — 10 ft / minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.8 TOOH and LD BHA 11.9 No open hole logging program planned. 07 c Page 15 Milne Point Unit M-12 SB Producer Hilcorp Drilling Procedure it 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paintbrush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120' shoe track assembly consistin of: 9-5/8" Float Shoe 1 joint — 9-5/8" TXP, 2 Centralizers 10' firm each end w/ stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint w/ stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle 'Top Hat' 1 joint — 9-5/8" TXP, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle M • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 16 H Hilcorp lim®CmpeY 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No. Closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth Baffle Adapter (if used) ID Depth Bypass or Shutoff Baffle ID Depth Float Collar Depth Is Float Store Depth Hole TO "Reference Casing Sales Manual Section 5 Page 17 "A O✓erall Length B Mar. ID After Drillout C Max. Tcol OD D Opening Seat ID E Closing Seat ID Plug Set Part No. SO No - Closing Plug •• Opening Plug OD OD Shul-off Plug OD Bypass Plug 4 (if used) OD Milne Point Unit M-12 SB Producer Drilling Procedure 1 Rikwp ES -11 Running Order ES41 cementer SW Off Aug BaffleA Ater Soars Aug Bypass Baffle Etat CalW Rezt 5fine 1 H Hilcorp U� Milne Point Unit M-12 S8 Producer Drilling Procedure 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: • 1 centralizer every joint t/ — 1000' MD from shoe • 1 centralizer every 2 Joints to 2,000' above shoe (Top of Ugnu) • Verify depth of lowest Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at least 100' TVD below the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used). • Install centralizers over couplings on 5 joints below and 10 joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/81140# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Page 18 J Milne Point unit M-12 SB Producer Hit MT- Drilling Procedure U ��r TXP® BTC Three4s per h 5 Connection OD Oplion REGULAR .... nrosrzols Outside Diameter 9625 n, Min Wali Thickness 87.5% LBO low 916.000 0000 Internal pressuM Capacity 111 5750 000 psi Type III Wall Thickness 0395m_ Connection OD REGULAR COUPLING ME BODY 38'fio08 Option Body Red 1st Band: Red Grade LBO Type 1• 0ritt API Sbndald 1st Bsnd Brown 2nd sand: I 2nd Baro:- Brown Type Casing 3M Band: - 3M Band: - 4di Band. - PIPE BODY DATA GEOMETRY Nominal 00 9BLS in rvsinal lVeight 40 Ibst Out 8679"' Nominal ID 8.8351n. YFailThickness 0395 n. PL. End weight 1697 Ibal OD Tobasce API PERFORMANCE Body Yrs] Sronglh 9th x1000 Is Introns Y*W 5750 psi EGIYs 80000 psi Cofiii 3090 psi GEOMETRY I Ccnu:eetrn OD 10.625 in. Courting Leogdr 10825. Connection 10 8.823 N. Make-up Lcss 4.891 in. Three4s per h 5 Connection OD Oplion REGULAR PERFORMANCE Tension Eftency 100.0% .Mita Yess Shengeh 916.000 0000 Internal pressuM Capacity 111 5750 000 psi III Compression Eificienq 100% Compassion Shcsyth 916.000x1000 Max. Ann"bh-Sending 38'fio08 Ibs Enemal pressun: Capacity 3090.000 psi MAKE-UPTORQUES ld a.lmum lassa R -3s Optimum 20960 fi4bs Manclum 23960 hobs OPERATION LIMIT TORQUES Openiwo To - 35600 Vito Yield Torque 43400 fi4bs Notes This connection is fully interchangeable with: TXPS BTC - 9.625 is - 36143.5147 153.5158.4 IbsHt [1] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C3 I ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable- except for Coupling Face Load, which will be reduced. Please contact a local Tenans technical sales representative. Page 19 H Hilcorp � ��r Milne Point Unit M-12 SB Producer Drilling Procedure 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10' from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 20 Milne Point Unit M-12 SB Producer Hilcorp Drilling Procedure Eovgy CmopmY 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre -job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 RAJ cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the V stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated I" Stage Total Cement Volume: �n0 Page 21 1 5't� -51f- 31 Y 31 ti�* Section Calculation Vol (bbl) Vol (ft3) v 12-1/4" OH x 9-5/8" (4,088'- 2500') x.0558 bpf x 1.3 = 115.2 646.75 J Casing Total Lead 115.2 • 646.75 12-1/4" OH x 9-5/8" (5,088'- 4,088') x.0558 bpf x 1.3 = 72.5 407 Casing 9-5/8" Shoe Track 120'x .0758 bpf = 9.1 51.09 Total Tail 81.6 458 Page 21 1 5't� -51f- 31 Y 31 ti�* Milne Point Unit M-12 SB Producer Hilcorp E, Drilling Procedure Cmmp.eY Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculaC66 4,968' x.0758 bpf=bls 40 bbls of weighted sbe left behind stage tool, confirm spacer is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 / Lead Slurry Tail Slurry System ExtendaCEM "" System SwiftCEM TM System Density 11.7 lb/gal 15.81b/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed Water 21.13 gal/sk 5.04 gal/sk 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculaC66 4,968' x.0758 bpf=bls 40 bbls of weighted sbe left behind stage tool, confirm spacer is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 / Milne Point Unit M-12 SB Producer HilcDrilling Procedure M-22 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. If ESIPC is ran, Increase pressure to 2090 psi to shift ESIPC sleeve and to begin inflating the packer. Inflate packer as per HEC rep. Reference ESIPC procedure. Once ESIPC packer is inflated, increase pressure to 3000 psi to open rupture disc / circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 23 Second Stage Surface Cement Job: Milne Point Unit M-12 SB Producer Drilling Procedure 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. (If ESIPC is used and packer element inflated, CBU xl minimum before pumping second stage). Hold pre job safety meeting. 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cum per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2"d Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation 2'° ' Vol (bbl) Vol (ft3) SwiftCEM .M System (Hal Cem) 20" Conductor 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 v 12-1/4" OH x 9-5/8" Casing (2000'- 110') x .0558 bpf x 3 = 316.4 1776.3 J Total Lead 345 1937 . 12-1/4" OH x 9-5/8" Casing (2500' - 2000') x .0558 bpf x 2 = 55.8 314 Total Tail 55.8 ' 314 . Cement Slurry Design (2nd stage cement job): Page 24 Lead Slurry Tail Slurry System Permafrost L SwiftCEM .M System (Hal Cem) Density 10.7 lb/gal 15.8 lb/gal Yield 4.3279 ft3/sk . 1.16 ft3/sk Mixed Water 21.405 gal/sk 5.08 gal/sk Page 24 H Hil Uc-�,orp Milne Point Unit M-12 5B Producer Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500' x .0758 bpf = 190 bbls mud t/ 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. v 13.29 Land closing plug on stage collar and pressure up to 1000 — 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As -Run " casing tally & casing and cement report to ienQeL@hilcorp. com and cdingerghilcorp com This will be included with the EOW documentation that goes to the AOGCC. Page 25 Milne Point Unit M-12 SB Producer Hilcorp Drilling Procedure Evac Cmm{my 14.0 BOP NIU and Test 14.1 N/D the diverter T, knife gate, diverter line & N/TJ 11" x 13-5/8" 5M casing spool. 14.2 N/U 13-5/8" x 5M BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / 13- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in bottom cavity. • Single ram can be dressed with 2-7/8" x 5" VBRs • N/IT bell nipple, install flowline. • Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 14.3 Run 5" BOP test plug 14.4 Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Test 5" test joints Pv • Confirm test pressures with PTD / • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug • Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.5 R/D BOP test equipment 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 8.9 ppg F1oPro fluid for production hole. 14.8 Set wearbushing in wellhead. 14.9 If needed, rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.10 Ensure 6" liners in mud pumps. Page 26 H Hilcorp Milne Point Unit M-12 SB Producer Drilling Procedure 15.0 Drill 8-1/2" Hole Section 15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.22° PDM) 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool or ESIPC. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 _ R/U and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every '/4 bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5750 / 2 = —2875 psi, but max test pressure on 'w ` Vthe well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent C i 0 /pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20' of new formation. / 15.6 CBU and condition mud for FIT. T I- 15.7 15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH & LD Cleanout BHA 15.9 PIU 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TEA is attached below. • Drill string will be 5" 19.5# 5-135 DS50 & NC50. • Run a ported float in the production hole section. 15.10 8-1/2" hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg ✓ above highest anticipated MW. Use appropriate SAFECARB blend on this well Page 27 • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 — 9.5 ppg FloPro drilling fluid Prnncrfice- Interval Int:rval Density Densi Milne Point Unit YP LSYP Total Solids MBT M-12 5B Producer Hardness Hiloorp Drilling Procedure • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 — 9.5 ppg FloPro drilling fluid Prnncrfice- Interval Int:rval Density Densi PV YP LSYP Total Solids MBT HPHT Hardness Production 8.9-9.5 15-25 - ALAP 1 15-30 4-6 1 <10% <g <1 1.0 <100 System Formulation: Product- production dili�Pkg ppb or (% liquids) Busan 1060 55 gal dm 0.095 FLOTROL 55 lb sx 6 CONQOR 404 WH (8.5 gal/ 100 bbls) 55 gal dra 0.2 FLO-VIS PLUS 25 lb sx 0.7 KCl 50 lb sx 10.7 SMB 50 lb sx 0.45 LOTORQ 55 gal dm 1.0 SAFE-CARB 10 (verify) 50 lb sx to SAFE-CARB 20 (verify) 50 lb sx 10 Soda Ash 50 lb sx 0.5 Page 28 n Hilcorp 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Flo Pro drilling fluid Milne Point Unit M-12 SB Producer Drilling Procedure 15.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to WU off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 15.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Reservoir plan is to undulate between Schrader OAl & OA3 lobes in 1000-1500' MD increments, and keeping DLS <3° when moving between lobes • Limit maximum instantaneous ROP to < 250 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Target ROP is as fast as we can clean the hole without having to backream connections • Schrader Bluff OA Concretions: 5-10% of lateral . L-47:6%, L-50 9.5% F-106: 6.1%, F-107: 4.7%, F-018: 9.9%, F-109: 10%, F-110: 10.1% 15.15 Reference: Open hole sidetracking practice: • If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. Page 29 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • Ensure mud has necessary lube % for running liner • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 15.17 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (385 gpm max). • Rotate at maximum rpm that can be sustained. Limit pulling speed to 5 —10 min/std (slip to slip time, not including connections). If backreaming operations are commenced, continue backreaming to the shoe 15.18 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. 15.19 Monitor well for flow. Increase mud weight if necessary Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise , 15.20 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. 15.21 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 30 Milne Point unit M-12 SB Producer Hilcorp Emgy Cm y Y Drilling Procedure 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • Ensure mud has necessary lube % for running liner • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 15.17 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (385 gpm max). • Rotate at maximum rpm that can be sustained. Limit pulling speed to 5 —10 min/std (slip to slip time, not including connections). If backreaming operations are commenced, continue backreaming to the shoe 15.18 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. 15.19 Monitor well for flow. Increase mud weight if necessary Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise , 15.20 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. 15.21 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 30 Milne Point unit M-12 SB Producer HilDrilling Procedure M= 16.0 Run 6-5/8" Production Pre -Drilled Liner 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 6- 5/8" pre drilled liner, the following well control response procedure will be followed: • PIU & M/U the 5" safety joint (with 6-5/8" crossover installed on bottom, TIW valve in open position on top, 6-5/8" handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 6-5/8" Predrilled liner. • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. • Proceed with well kill operations. 16.2. Well control preparedness: In the event of an influx of formation fluids while running the 3- 1/2" inner string inside the 6-5/8" pre drilled liner: • P/U & M/U the 5" safety joint (with 6-5/8" x 3-1/2" triple connect crossover installed on bottom, TIW valve in open position on top, 3-1/2" handling joint above TIW). M/U 3-1/2' and then 6-5/8" to triple connect. • This joint shall be fully M/U with crossovers prior to running the first joint of wash pipe. • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. Proceed with well kill operations. 16.3. R/U 6-5/8" pre -drilled liner running equipment. • Ensure 6-5/8" 20# Hydril 563 x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 16.4. Run 6-5/8" pre -drilled production liner • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run packoff and float shoe on bottom. • 6-5/8" pre -drilled liner will auto —fill • 6-5/8" Liner will be centralized with l Joint free floating • If needed, install swell packers as per the lower completion tally. Remove protective packaging on swell packers just prior to picking up Do not place tongs or slips on the packer element 6-5/8" 20 # H dril 563 Torque OD Minimum Optimum Maximum Yield Torque 6-5/8 5,900 ft -lbs 7,100 ft -lbs 10,300 ft -lbs 36,000 ft -lbs Page 31 ff Hilcorp Wedge 563® Page 32 Milne Point Unit M-12 SB Producer Drilling Procedure „w...91.'T76,'2D18 O=IcIa DlamMen &JM n. Min. NYII 1115% eannpcum l0 CofAnn¢c9»fkhcr. 9.999 n N£GULAe PERFORMANCE Thic#neso ('j Glade LR11 T¢mbn Mwn" Lnmpr¢wbn E'acbn.r EalMnal il'pNwc Capc_II� 9Ri4: 106Jti 36T9_bDO as 9Nnl naltl blrmn.Ta wmpmssian blwngla CaupleyT taco Lpad A9163a1000 Ipi 438.110111 �10J] its 3199602% Type 1 6990A99 as. 92f'r10311 Wall Thlc2 . li-nan. Coro b..OD REGULAR Nlnmum 9900T•Cs option 71M COUPLING PPERCOT OPERATION UMTT TORQUES Ertl/ Red 1 Bmld Red Grade L89 Type 1' Drift API &andlld 11 Bsd: Brown 2M Bzrld. 214 B:nd - Brewn liffli 6lmlmum TMP, Camp 3rd B.st • _4d E Ind.. a1n Bard.. PIPE BODY DATA GEOMETRY N¢mm.100 bide 2GAO tsn Onn Slun Nnmmal9 6.ONm. Wallnns:xn¢ss 9.293 gin_ FI9n End M."' 1951 Ron OD iel¢rW.o- API PERFORMANCE a'A'r Yd snenaln 450e(14019s Tmnmll rete Go" rcl =Kv:S e0o66 ya C¢fapc¢ 3620 pal CONNECTION DATA GEOMETRY CannacwnOL Na\¢•upLms 2396 m. CM,n_ Oauplr\]eunpin inroad. pal In 92#.n. 339 eannpcum l0 CofAnn¢c9»fkhcr. 9.999 n N£GULAe PERFORMANCE T¢mbn Mwn" Lnmpr¢wbn E'acbn.r EalMnal il'pNwc Capc_II� 9Ri4: 106Jti 36T9_bDO as 9Nnl naltl blrmn.Ta wmpmssian blwngla CaupleyT taco Lpad A9163a1000 Ipi 438.110111 �10J] its 3199602% 09¢mL Pry55YN GipatN Wr. AlewaLY E¢edag 6990A99 as. 92f'r10311 MAKE-UP TORQUES Nlnmum 9900T•Cs 9Ftlm¢m 71M S1aJmum 19199n fns OPERATION UMTT TORQUES 9pmlrq Tue¢c Milli Yi¢b Tprqua Miss t,faa BUCK -ON Wlnnm m liffli 6lmlmum 113909 -es Notes This connection is fully interchangeable with- Wedge ithWedge 56381- 6.625 in. - 24128? 32 IbEM Connections with DopelessID Technology are fulilyy compatible aith the same connection in its Standard varseon 6-5/8" Lower Completion Running Order Milne Point Unit M-12 5B Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for approx 150' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8" connection. • Consider having a joint of solid pipe across BOPE Stack while running inner string 16.7. R/U false rotary and run 3-1/2" 9# Inner String • Ensure inner string is drifted for WIV closing ball OD 16.8. Before picking up Baker ZXP liner hanger /packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.9. M/U Baker ZXP liner top packer to inner string and 6-5/8" liner. Fill liner tieback sleeve with "Xanplex", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 16.10. Note PUW, SOW, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH w/ liner on 5" HWDP no faster than 30 ft/min — this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. 16.12. The inner string will prevent the DP from auto filling. Fill DP with mud every 5 stands, more frequently if SOW trend indicates. 16.13. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.14. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 rpm 16.15. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.16. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.17. Rig up to pump down the work string with the rig pumps. Page 33 H Hilcorp Milne Point Unit M-12 SB Producer Drilling Procedure NOTE: The wellbore will be swapped over to brine after the liner has reached TD to remove mud cake from the well bore. Mud cake will cause facility upsets. 16.18. Break circulation and circulate out the mud. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. Displace well to brine (-9.2 ppg KCl/NaCI). , over displace well by at least 100+ bbl. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. 16.19. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the swell packers (if run). Do not exceed 1,600 psi while circulating as noted above. Note all losses. Confirm all pressures with Baker. 16.20. Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 16.21. Displace 1.5 OH + Liner volume. 16.22. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.23. Shut down pumps. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to shift the wellbore isolation valve closed. 16.24. Continue pressuring up to 2700 psi to set the ZXPN liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the Flexlock liner hanger to ensure the HRDE setting tool is in compression for release from the ZXPN liner hanger/packer. Continue pressuring up 4500 psi to activate the hydraulic pusher tool to set the ZXPN packer. This will also release the HRDE running tool. 16.25. Bleed DP pressure to zero. Pick up to expose Rotating Dog Sub and set down 50k# without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k4 again, 16.26. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.27. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.28. PIU pulling 3-1/2" out of the pack off & displace out liner with two volumes at max rate. Note: Flexlock Liner Hanger & separate packer will be run on M-12, with a hydraulic running tool with exposed ports that may inhibit circulation through the toe of the 3-1/2". Page 34 H Hilcorp Emp C�yvy Milne Point Unit M-12 SB Producer Drilling Procedure 16.29. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOR L/D 3-1/2" inner string. Leave enough 5" DP racked back to trip back to 9- 5/8" shoe. 16.30. M/U 3.5" wash tool & RIH w/ remaining DP out of derrick to liner top. 16.31. Wash through liner top at max rate & circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. 16.32. POOH & L/D remaining 5" HWDP & Inner string 16.33. Once inner string is L/D swap to the completion AFE Page 35 Milne Point Unit M-12 SB Producer Hilcorp Drilling Procedure . -21 17.0 Run 7" Tieback 17.1 RIH with mule shoe on 5" DP to Liner Top and circulation Liner Top and SBE clean. POOH. 17.2 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie -back space out calculation. Install and test 7" (250/3000 psi) solid body casing rams. 17.2 R/U 7" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 17.3 P/U tieback seal assembly and set in rotary table. Ensure 7" seal assembly has x4 1" holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7" annulus. 17.4 M/U first joint of 7" to seal assy. 17.5 Run 7" 26# TXP tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. Page 36 H Hilcox Uc® TXP® BTC Outside Diameter 7.010 in. Wall Thickness 0.362 is Grade LOO Type 1' Min, Wall ST5% Thickness Connection OD REGULAR Option Drift AN Standard Type Casing Milne Point Unit M-12 SB Producer Drilling Procedure n.d.a I MW201 B (7 Grade LSO aw Type 1 Connection OD CpGn REGULAR COUPLING PIPB DOOY Body: Red 1st Band: Red 1st Band: Brown 2nd Band. 2nd Band:- Brawn 3rd Band 3rd Band - 6O4.00D x10:43 4th Band: - PIPE BODY DATA GEOMETRY Normal OD 7010,nNom"4 Vlel iht 26 lbs,B Prft 6.151 m Nonnnal ID 6276 in. 'Yaali Ttickrre s. 0.362 in. Plan End Ncright 25.69 tcF. OD Tdera. AN PERFORMANCE 5DW Yeld Srengdr 604 t00D lbs Intemd Yeld 7240 psi SAfys WOOD psi Collapse 5410 psi CONNECTION DATA GEOMETRY Camxrtien OD 7.616 in. Cooling LerVth 10.200 in Cennecticn ID 6260 n. Aske -up Loss 4.579 in. Threads pery 5 Connection OD CpGn REGULAR PERFORMANCE — _l Tension Elfwoe cy 100.0 % Jort't''Ad Strength 6O4.00D x10:43 Iraemal Pressure Capecity 7240.000 psi lbs Cmryressim Efficiency 100% Compression Strength 6D4.DDOxl(C0 Max.AWaable Bening 52 N100 Its External Pressure Capacity 5410ADD psi MAKE-UP TORQUES Mnimu n 13250 fthx [lonnun 14750 ft4bs Maxsnan 16230 ft -Lr; OPERATION LIMIT TORQUES Opsramrg Tcryue 20000 Raba YisMTiorgae 23440 14b Notes Tltis connection is fully interchangeable Mill: TXP® BTC - 7 in. - 23 f 29132135 138 IbsM [11 internal Pressure Capacity related to structural resistance only. Intemal pressure leak resistance as per section 10.3 API 5C3 I ISO 10400 - 2007. Page 37 H Hilcorp M �®1, 17.6 M/U 7" to DP crossover. 17.7 M/U stand of DP to string, and M/U top drive. 17.8 Break circulation at 1 bpm and begin lowering string. Milne Point Unit M-12 SB Producer Drilling Procedure 17.9 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 17.10 Continue lowering string and land out on no-go. Set down 5 — l0k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 17.11 P/U string & remove unnecessary 7" joints. 17.12 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 17.13 Ensure circulation is possible through 7" string. 17.14 RU and circulation corrosion inhibited brine in the 9-5/8" x 7" annulus. 17.15 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7" x 9-5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7", verify collapse pressure of 7" tie back. 17.16 Slack off and land hanger. 17.17 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 17.18 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 17.19 R/D casing running tools. "r ' k 17.20 Test 7" x 9-5/8" production annulus to 1000 psi / 30 min. 17.3 Set test plug and change top rams from 7" to 2-7/8" x 5-1/2" VBR. Test annular and lower rams to 2-7/8" test joint, 250 low / 3000 psi high. Page 38 H Hilcorp Evap Gmpmy 18.0 Run Jet Pump Completion Milne Point Unit M-12 SB Producer Drilling Procedure 18.1 Change upper pipe rams back to 2-7/8" x 5" VBR. Test same. Verify the Jet pump components. 18.2 Run the 3-1/2" Jet Pump Completion as noted by completion engineer. 18.3 M/U Jet Pump assembly and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 18.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.5 MU tubing hanger and landing joint. Terminate control lines. 18.6 Land tubing hanger. 18.7 Drop ball and rod, pressure up to 1,700 psi to start setting of PHL packer. 18.8 Continue to pressure up to 3,000 psi to set packer. 18.9 Pressure up to 3,500 psi to test tubing for 30 minutes and chart. 18.10 Bleed tubing to 2,000 psi. 18.11 Pressure up annulus to 3,500 psi to test casing/packer for 30 minutes and chart. 18.12 Bleed tubing to 0 psi. Pop shear valve from annulus to tubing (2,500 psi differential). 18.13 RILDS and test hanger. LD landing joint. 18.14 Install BPV. Pressure up on 3-1/2" x 7" annulus to 500psi, to test BPV from below. 5 min. WASH 191-011810 18.16 N/U.tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 18.17 Circulate diesel freeze protection down 3-1/2" x 7" annulus (Volume should equal capacity of tubing to 2500' + tubing annulus to 2500'). Connect IA to tree and allow diesel freeze protect to "U-tube" into position. Note — this may be done post -rig. 18.18 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high. Pull TWC. Set BPV. 18.19 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.20 Notify AOGCC of SVS testing. Test SVS on horizontal run of tree within 5 days of the start of production. Set low pressure trip below 275 psi Moose Pad header & separator pressure. 19.0 RDMO ffl�R 1T161101 Page 39 H Hilcorp �u ZT. 20.0 Doyon 14 Diverter Schematic 21-V4' 2M R,w- 21-V4' 2M- Drverter T' 21-118' 2 Spacer SPD 163'4.3M 21-1/4'2M DS Page 40 Milne Point Unit M-12 SB Producer Drilling Procedure -I6' fyY Ope" Kr* Val p `16' Dn a Umf 21.0 Doyon 14 BOP Schematic K,' I Pace 41 Milne Point Unit M-12 SB Producer Drilling Procedure 2-7/8" x 5" VBR Blind Rams x SU HCR poke Lme al Cato Valle 2-7/8" x 5° VBR Milne Point unit M-12 SB Producer Hilc4rp Drilling Procedure 22.0 Wellhead Schematic PLC 10111 1I' "UtBM ,2 5f OIL USB rz-wf-Ire 1 r X•IiiF-T)g11 C[• Page 42 _ r-� r •¢.pe SIpC F GceL] �. Las LY. f1l �'� vu n3o-ggm rC..IIO FLEX 51.(11[+, d55t. BPBf. u s�. s)ue GrN I SunWE RELLNEAO L41 WT 6 :% 9 5/8 x i x 4 v7C4SMG P13GI9U-MJJ PROGRAM, lI _x 1aiEG Ills .\ 1. 41i16.5B, —Yrrl1.SF[Ilai esir. nn.n.n • 10. 0 M, It INCH rlw IAPFP VVO 3"615 6-C, Vp0 Rus Co I IMMr.CL. Rurt0 le 11 .Hary :�LN ql' IGr• Y4bFEL.I NlC1rrC ? rlr.. nOtXB/Il�r":/ 1 10 . S R ILrlJll6 IK 6 $0" BIY ME' ) rSAU 5UN 14f• IOP. µBC 10 , e.21 BCM. uB wo 5 "B'OC (e51n� I TCO IgG GEN 5 SLIM HOLE M51 FIF'llC1(1 SunWE RELLNEAO L41 WT 6 :% 9 5/8 x i x 4 v7C4SMG 41M.N PROGRAM, Bmf,1-5e 1. 41i16.5B, PWIE L6r CU FEIr CM1001333! r C 25 Iv 23.0 Days Vs Depth m 2000 4000 6000 Y t Y a 0 8000 v 9 N 10000 PC Page 43 12000 14000 !. 16000 0 MPU M-12 SB OA Producer Days vs Depth Milne Point unit M-12 SB Producer Hilco ��Wy Drilling Procedure 23.0 Days Vs Depth m 2000 4000 6000 Y t Y a 0 8000 v 9 N 10000 PC Page 43 12000 14000 !. 16000 0 MPU M-12 SB OA Producer Days vs Depth n HilmTEm®' Cmnpoy 24.0 Formation Tops & Information Milne Point Unit M-12 SB Producer Drilling Procedure MPU M-12 Formations (wp05) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2121 1982 2040 897.6 8.46 LA3 3456 3211 3269 1438.36 8.46 Schrader Bluff NA 4280 3742 3800 1672 8.46 Schrader Bluff OA 4945 3895 3953 1739.32 8.46 L -Pad Data Sheet Formation Description (Closest & Most Analogous MPU Pad to Moose Pad) GENERALIZED GEOLOGICAL F REA T SS GEOLOGICAL TVD FM LITH DESCRIPTION COMMENTS u r:oi NOTE: acc individual Well Program for Gutix specific casing dmign, depths, six m, •. rm 60c weights. grades and connections, tlncansonmted coin. to medbmi sand and snuu gravel Pc NT minaailatone. 1,000' s IF SIGNIFICANT AMOUNTS OF GRAVEL A ARE ENCOUNTERED WHEN DRILLING THE ♦m SURFACE HOLE, THE VISCOSITY OF THE MUD SYSTEM SHOULD IMMEDIATELY BE RAISED TO 150 SEC TO ENSURE EFFECTIVE HOLE CLEANING. ns0• Base permafrost htroem of sono, cbys and'itsmros with owsiorul 2000,. Now d coil. Watch possible sidetracking "to wasNnynaming W]8Ld5. swv. �n+a -d<„F= - No hydrates encountered on L -Pad wells drilled to date. ---- -- G Ishabem of sand. and snatonos 10th Traces•I-]10011 acusbml Noxa of con.Traces OIpyrig caskeda of 3.000• hmnaa•r-]amncan be tricky and ugnt0.otl. t aar hbroem bebean 3001 4so0 it C xrr- L A ]sv K—do Y UGNU: soma o+coiraanirg spwaN unm which an (- &ccI main W of: (from top to botmm) woad sand fine sano. stlyahala eener mvN ©ee inarvmirg slobs as 100 UGNU Wogess Into tib L and M(dmport Umand Schrader BlNf: Pusslbie, fydrocaroorn limited Laaem WSWeornerof Miirodowlopnwnt Nor+lwmamals (+ka) dowrbbucturo and wot '])E' MYam (+e<) .1N. (NA) Schrader Bluff Sands: 4,000' N4iba l.As ce. comimaod wyenng coanonngup.aN undo as abora -4111116— Schrader Bluff: Possible lostcireulation . en .,.of mon condensOd od wAh ocualeri coal. zone while drilling long strings and running '4170osw,m1c, Clay rich slat• imuval OW too fit l Posohted ydrocaronn casing. Recommend deep setting surface ug�wandsehnder BlNau (OA) E�.W SWcomof of MOm doveloprnent Lar am L40,n casing for Kuparuk long strings. Also, the mmpbMd in Na SNudar BlNf sand. liodham oma of Schrader Bluff sands are a potential SchraderLead Is d rem,ctuf0 ono cacti. differential stuck pipe interval If left un -cased Bluff svfam cool, point In ansa bel.. for Kuparuk long strings. Sands- Schrader an OBsafor It"reach.ohI Wno Page 44 n Hilcorp Em Gm, 25.0 Anticipated Drilling Hazards Milne Point Unit M-12 SB Producer Drilling Procedure 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hyrates have not been seen on Moose pad. However, be prepared for them. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non -pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are a number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. Page 45 H Hilco E.a Ca X Milne Point Unit M-12 SB Producer Drilling Procedure The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost ' circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: ✓ There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for 1-12S. No 1-12S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on this pad. Page 46 ff Hilw 26.0 Dovon 14 T o 1 TM Page 47 MIN Milne Point Unit M-12 SB Producer Drilling Procedure H Hilcorp E. C®p+vy 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit M-12 SB Producer Drilling Procedure 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 48 H Hilcorp Erc�p,2,T 28.0 Doyon 14 Choke Manifold Schematic Milne Point Unit M-12 SB Producer Drilling Procedure �Z < a<� v o r m ��ddv O G1 yy N ZX Z� ~ p d p T Z ;A Cn N T 3 3 p K F 0v_ W P Y P < A n d o 1 O o n 3 D 3 3 3 n « < M 3 3 p P j C R p J < p y m n < n n u < w < u M < � z V W W N O� r W r o 0 00 '' A r o' ,o D C h 0 y A)= o Page 49 Milne Point Unit M-12 SB Producer Drilling Procedure 29.0 Casing Design 11 Calculation & Casing Design Factors HDA DATE: 1212712016 WELL: MPU M-12 DESIGN BY: Joe Engel Design Criteria: Hole Size 12-114" Mud Density: 92 ppg Hole Size 8-11Y Mud Density: 92 ppg Hole Size Mud Density: Drilling Mode MASP: 1349 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1349 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psVft) and the casing evacuated for the internal stress Page 50 n Hilo 30.0 Milne Point Unit M-12 SB Producer Drilling Procedure 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 11 8-1/2" bole Section Hillcoor MPU M-12 Milne Point Unit MD TVD Planned Top: 5086 3968 Planned TO: 16751 4018 Anticipated Formations and Pressures: 8.8-9.1 Surface 4125 Formation TVD TVDss Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sandl 3,968 3,910 1746 1 Oil 8.46 0.440 Offset Well Mud Densities Well MW range Too fTVDI Bottom ITVDI Date L-50 8.8-9.1 Surface 4125 2015 L-49 9.0-9.2 Surface 4196 2015 L-49 8-9-9.2 Surface 4147 2015 L-47 8.8-9.0 Surface 4158 2015 L-46 9:0-9.3 Surface 4177 2015 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EM W. . 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. v 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 3,966 (ft) x 0.78(psi/ft)= 3D95 3D95(psi) - [0-1(psi/fr)03968(ft)1= F2698 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 3968 (ft) x0A4(psi/ft)= 1746 psi 1746(psi)-0.1(psi/ft)'3968(ft) 1349 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evaluation of entire wellbore to gas at 0.1 psi/ft. Page 51 4- n Hilco M=0rp 22 31.0 Spider Plot (NAD 27) (Governmental Sections) 11 Milne Point Unit M-12 SB Producer Drilling Procedure 1 1 1 1I' I 1 , 1 ' 1 , 1 1 1 an Sec: 23 ' Sec.,24 1 1 I 1 I , �.Ecu!e 11ENl'?A" A01-025519 Sec. 26 Sec. 25 KUPARUK RIVER UNIT I , slw wm-,mrrzo,n Page 52 `up to I ua • 1 + � 1 11.51, I ✓ILJ Milne Point Unit MPU M-12 Well [rB± Sec 17 lald) - I Sec 20 Legend • M-12 SHL X M-12_TPH BHL —: _ Other Surtace roles (SHL) Other Bottom Holes (BHL) ul -------------- Other Well Paths ADL025517 Sec. 30 - -- Coastline (USGS 1:63k) (636) O Oil and Gas unit Boundary z - _ - . Pad Fooylint — 0 1,200 2,400 Feet M-12_TPH ` .` �`.1 M-12 SHL , �• ! / I �° 1Fesuoo I I 1 I ' 1 ' ! Sec. 18 " 1 Sec.'t3I 1 (830) 1 1 �I 1 �+u MILNEPOUNIT � Iy,T 1 ,� (( / U013N009E U013NO10E+ 1 1 /, 1 V i 1,1 / , • ! 1 1 1 1I' I 1 , 1 ' 1 , 1 1 1 an Sec: 23 ' Sec.,24 1 1 I 1 I , �.Ecu!e 11ENl'?A" A01-025519 Sec. 26 Sec. 25 KUPARUK RIVER UNIT I , slw wm-,mrrzo,n Page 52 `up to I ua • 1 + � 1 11.51, I ✓ILJ Milne Point Unit MPU M-12 Well [rB± Sec 17 lald) - I Sec 20 Legend • M-12 SHL X M-12_TPH BHL —: _ Other Surtace roles (SHL) Other Bottom Holes (BHL) ul -------------- Other Well Paths ADL025517 Sec. 30 - -- Coastline (USGS 1:63k) (636) O Oil and Gas unit Boundary z - _ - . Pad Fooylint — 0 1,200 2,400 Feet n Hilcorp 6Mg r1p 32.0 Surface Plat (As Built) (NAD 27) GRID SEC. 12 I 13 2C. 11 I 5£Q 14 M-10 I M-11 I I I M-12 I �fK I I I I M-04 M-03 MPU MOOSE PAD NOTES: 1. A A SIAM PIANE CLURONAT ARE N427. I FE00ED0 MOONS ARE 4A027. 1 BASS R NO02RITA AND SFR CONiRQ 5 MOOSE PAD YONUww t 2. A MRI MOOSE PAD SCARE FA IS: 0.59510236. S OATS OF S vir E mwFR 20. 2016 e- IERERflKE F 0001: xClw-m !P. S! Page 53 Milne Point Unit M-12 SB Producer Drilling Procedure / YOOSE _ _YI_ PAD N PAO� I I23 24 1 q` 0 WCINITY MAP NTS GRAPHIC SCALE 0 100 2W ADO (N PELT ) t In0 =200 N. SURVEYOR'S CERTIFIGATE 1 NDiEBY CDiTfiY MAT 1 AY PROPERLY LANDRED ANG U4MSm TO PRACVM O AILAD(A "DNO N 11E STATE OF ALASNA ANO THAT 1145 AS -WV REPRESENTS A SURV£1' MAGE BYY ME YE OR 1)aAAR YY DAECT $IWINSI S AW 1HAT ALL DIMENSIONS AND DETAILS ARE CCRREtt AS OFF SEPTEMBER 5£P7<YRER 26, 201M WT JM ocnm Aran cm 1A T 13 N R. R F_ EII2IAT MERIDIAN. ALASKA WELL A.S.P. GEODETIC GEODETIC SECTION I CELLAR NO. COORDINATES POSITION DMS POSITION(0.00 OFFSETS BOX EL Y. 6.027,889.71 7079'14.024' 70.4672289' 5,040' FSL 25.0' M-03 X- 533,353.90 149'43.38.285• 149.7273014' 801' FEL Y= 6,027,889.58 70'29'14,021• 70.4872281' 5,040' FSL 25.0' M-04 X= 533,393.80 149'43'37.405" 149.7270569' 771' FEL Y- 6,027,889.85 70'29'13.990" 70.4872194' 5,037' FSI- 24.9' M-10 X= 534,113.80 149'43'16.220" 149.7211722' 51' FEL Y. 6,027,869.81 70'29'13.993' 70.4872203' 5,037' FSL 25.0' M-11 X• 534,023.88 149'43'1&685" 149.7219069' 141' FEL Y. 6.027.889.80 70'29'13.999' 70.4872219' .3,037' FSI - 25.0• M-12 X. 533.933.89 149'43'21.513" 149.7226425' . 231' FEL - YU„PMD. V LSM 3. 04. 1 ac w MOOSE PAD. WELLS N -S- AS -BUILT 10. 11, 12 1 .1 1 eco• CONDUCTOR AS-6ULLT Milne Point unit M-12 SB Producer Hilcorp Drilling Procedure � ��, 33.0 Schrader Bluff OA Sand Offset MW vs TVD Chart Schrader Bluff OA Sand Offset MW vs TVD MW, PPg 8.5 8.7 8.9 9.1 9.3 9.5 9.7 9.9 10.1 10.3 10.5 0 a iJILI y m 1500 2000 x 2500 m 3500 mm 4500 Page 54 —MPU L-46 (2015) —MPU L-47 (2015) —MPU L-48 (2015) MPU L-49 (2015) —MPU L-50 (2015) —MPU F-106 (2017) —MPU F-107 (2017) —MPU F-108 (2017) —MPU F-109 (2017) —MPU F-110 (2017) H H Corp WAM 34.0 Drill Pipe Information Drill Pipe Configuration Milne Point Unit M-12 SB Producer Drilling Procedure 5'9 19.5# S-135 DS -50 & NC50 Pipe Body OD w 5.000 Pipe Body Wall Thi kness m 0.362 Pipe Body Grade S-135 Drill Pipe Length Tool Joint SMYS Connection GPDS60 Tod Joint OD 6.625 Tad Joint ID rte: 3250 Pin Tong 9 Box Tong am: 12 Drill Pipe Performance 36.100 Tension Onry 10 56D.8W woman n�ur cmvnrm tgabnv 32.100 467.400 Nqe. ou rcm bares annum az us gmmss. Iilm: nil Np[MaomnY�dWC ve brl r2lrtVef onC miY Jq�/-'b FR Lv. 80 % inspection Class Nominal Nominal Weight Desi nation 19.50 Drill Pipe Approximate Length m131-5 SmoottlEdge Height mu N32 Raised Tool Joint SMYS a.)1,120-000 Upset Type ll Man Upset OD (DTE) qei 5.125 Friction Factor 1.0 ',mei 6.812 NCe: Tacq iNce adY IntluOe narCdop. Drill -Pipe Length Range2 Connection Performance GPDS50 ( 6.625 mt OD X 3,250 til ID ) Nar:Tdmnlmde connenmapemcw moat... near rru-v*.xn rim:Y:news ee augur. Nominal TCdS itt Torsional StrWM tmmn 71,800 Tod Joird Tensile StreralM ma11,250000 Elevator Shoulder Information 560,800 Pipe Torsional Strength SmlwthEdga Height 58.100 3+32 Raised 7 Bax OD ',mei 6.812 124 Elevator capacity nil 1,658,000 Nominal m®mom; 2329 0.36 00085 0.72 0.0172 120,000 r-? Tool Joint Dimensions Balanced 00 nm 6.435 wrrm,.m nor ram nm mr un 5.930 c�inwn cma. qn wmm,.n T. Igm?m mr 5.93 cornmmr. vn. 332 Raised 6.812 cmi VOM to Bevel Worn to Min TJ OD for Diamntar API Pre um Clara A5219 5219 nam:sm,a>vomrY ed:<ac,._..,nmvem.mw eine. bcvw.rd.a..dm cmmao-�am reb.\ocgai. [Assumed Elevator Bore Diameter �' Nofe: arma.e eeomr oo maadaea emdww�er .,mm almc'Imq nm«e.a mm�e_ Pipe Body Slip Crushing Capacity Pipe BodyConFVuradmr 5-, oD 0.362tm Wall S-135) Nominal I80%hispectionClasal API Premium Qass 17 q Sli Crushin Ca tba1 498.300 396500 396,500 rrc sgo- ime apa�tmme�aawam.m to xrxenvu ecx mwn•t.ae�a mnea Assumed SiloLenoth IY/ to 163 rams agdm ruv tx rxevnabmm+dm wam:mv.msor�amevnnm,a oM. 5q am�mY a [leoeMnn m R 9b mYn a9 DT.Utn`, mCn1m a Ibrn. SW.q avmv. mrt Transverse Load Factor (KI 42 pea ga�bttwamgv wmrcn. aam�mvmna. rmobmmm.mrearesa.m rwammm rrmamYn_ Pipe Body Performance Pipe Bedy Confquradm ( 5 m) OD 0.362 (w Wan S-135) Page 55 N[R: NMmN� Gu,9 v bmaa ar.r. aew MF moi. Nominal 60 % Inspection Otos API Premium Cies Pw Tersk strength mea 71 1®D 560800 560,800 Pipe Torsional Strength (le- 74,100 58.100 58,100 TJPpeBody Torsional Ratio 13.97 124 124 80% Pipe Torsional Strength 59,300 46.500 46500 Burst m+e 17,105 15,638 15,638 collaw ?rm, 15.672 10.029 10,029 Pipe OD tm 5.000 4.855 4.855 Wall Thickness m^ 0.362 0290 0190 Nominal Poe IDtmt 4276 4276 4276 Cross SectlaW Area of Pipe Bodytm.zr 5175 4.154 4.154 Cross Sed onal Area of OD to zt 19.635 18.514 18.514 Cross Sectienar Area of ID •=� 14.360 114,360 14.360 Section Modulus (.•315.708 14.476 4.476 Polar Section Modulus -31111.415 l&953 8953 N[R: NMmN� Gu,9 v bmaa ar.r. aew MF moi. H Hilcox �., Milne Point Unit M-12 SB Producer Drilling Procedure 500204050016200 Weatherford 5" 19.50 IbHt S-135 w/ NC 50 6-518" OD x 3-114" ID Tool Joint DRILL PIPE SPECIFICATIONS Grade S-135 Connection NC 50 Interchangeable With 5' XH & 4-12' IF Upset Type IEU Nominal Weight per Foot 19.50 lbs Adjusted Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6-5/8' Inside Diameter 3-1/4' API Drift 3-1/8' Rabbit OD, Suggested 3-1/16' Minimum Make-up Torque 25.900 ft -lbs Maximum Recommend Make-up Torque 26,800 ft -lbs Torsional Yield Strength 51.700 ft -lbs Tensile Strength 1,269.000 lbs TUBE DATA New Premium Outside Diameter 5.000' 4.855" Inside Diameter 4.276" 4.276' Wall Thickness 0.362' 0.290' Cross Sectional Area 5275 sq in 4.154 sq in Maximum Hook Load/Tensile Strength 712.000 lbs 560,800 Ibs Slip Crushing / Slip Type (SDXL) 572.100 lbs 453.500 lbs Burst Pressure 17,100 psi 16.100 psi Collapse Pressure 1 15,700 psi 10.000 psi Torsional Yield Strength 74,100 ft -lbs 58.100 ft -lbs Capacity WI Tool Joint 0.726 US gaVft 0.726 US al/ft Displacement W/ Tool Joint 0.353 US al/ft 0.322 US gallft Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss. damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 56 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 M-12 Plan: M-12 wp05 Standard Proposal Report 18 December. 2018 HALLIBURTON Sperry Drilling Services Hilwrp Alaska, LLC Calculation Method Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Pedal Curve Warning Method: Error Ratio Coordinate (WE) Reference: Well MPU M-12, True North Vertical (TVD) Reference' M-12 @ 58.70ush Measured Depth Reference: M-12 @ 58.70us8 Calculation Method Minimum Curvature -750 0 750 0 01500 L m 02250 C i $ec MD Inc Azi TVD +N/ -S +E/ -W 1 33.70 0.00 0.00 33.70 0.00 0.00 2 400.00 0.00 0.00 400.00 0.00 0.00 3 616.67 6.50 30.00 616.20 10.63 6.14 4 1013.23 20.29 70.19 1001.66 53.64 82.53 5 2971.96 20.29 70.19 2838.88 283.79 721.49 6 4788.89 84.00 124.80 3937.34 -190.47 1925.71 7 5088.89 84.00 124.80 3968.70 -360.74 2170.70 8 5282.22 89.80 124.80 3979.15 -470.87 2329.16 9 6901.97 89.80 124.80 3984.80 -1395.28 3659.20 10 6941.97 91.00 124.80 3984.53 -1418.10 3692.04 11 6982.03 89.80 124.80 3984.25 -1440.97 3724.94 12 16751.55 89.80 124.80 4018.70 -7016.16 11747.38 Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: M-12 Design: M-12 wp05 HALLIBURTON 0.00 er,...s- oNnt�e SURVEY PROGRAM Depth From Hilwrp Alaska, LLC Calculation Method Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Pedal Curve Warning Method: Error Ratio Coordinate (WE) Reference: Well MPU M-12, True North Vertical (TVD) Reference' M-12 @ 58.70ush Measured Depth Reference: M-12 @ 58.70us8 Calculation Method Minimum Curvature -750 0 750 0 01500 L m 02250 C i $ec MD Inc Azi TVD +N/ -S +E/ -W 1 33.70 0.00 0.00 33.70 0.00 0.00 2 400.00 0.00 0.00 400.00 0.00 0.00 3 616.67 6.50 30.00 616.20 10.63 6.14 4 1013.23 20.29 70.19 1001.66 53.64 82.53 5 2971.96 20.29 70.19 2838.88 283.79 721.49 6 4788.89 84.00 124.80 3937.34 -190.47 1925.71 7 5088.89 84.00 124.80 3968.70 -360.74 2170.70 8 5282.22 89.80 124.80 3979.15 -470.87 2329.16 9 6901.97 89.80 124.80 3984.80 -1395.28 3659.20 10 6941.97 91.00 124.80 3984.53 -1418.10 3692.04 11 6982.03 89.80 124.80 3984.25 -1440.97 3724.94 12 16751.55 89.80 124.80 4018.70 -7016.16 11747.38 Start Dir 3°/100' : 400' MD, 4007VD Start Dir 40/100' : 616.67' MD, 616.2'ND 10 _ _ End Dir : 1013.23' MD, 1001.66' ND 1500 Zg09 g5A40 iF 19y Mo, 21 291 34 A40 O - - _ O114 j1p0 3937 39�? 2500 Star .A'j9080, 50g35900 g1g 19 �.010 O SAND - EodQ6 11jNOD 7100,3 0 0 0N97•pn0,3g0p 00,3gbh25 - O 3 w 3000- 2 000 LA3 \ F - _ SB NA 3750 SB OA 4500 Dleg TFace WELL DETAILS: MPU W12 Target Annotation Ground Level: 25.00 +N/ -S +E/ -W Northing Easling Latittude 0.00 0.00 6027889.80 533933.89 70° 29' 13.999 N 0.00 5088.89 9-5/8 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 33.70 5090.00 M-12 wp05 (M-12) 2 MWD+IFR2+MS+Sag 5090.00 16751.55 M-12 wp05 (M-12) 2_MWD+IFR2+MS+Sag Start Dir 3°/100' : 400' MD, 4007VD Start Dir 40/100' : 616.67' MD, 616.2'ND 10 _ _ End Dir : 1013.23' MD, 1001.66' ND 1500 Zg09 g5A40 iF 19y Mo, 21 291 34 A40 O - - _ O114 j1p0 3937 39�? 2500 Star .A'j9080, 50g35900 g1g 19 �.010 O SAND - EodQ6 11jNOD 7100,3 0 0 0N97•pn0,3g0p 00,3gbh25 - O 3 w 3000- 2 000 LA3 \ F - _ SB NA 3750 SB OA 4500 Dleg TFace VSect Target Annotation 0.00 0.00 0.00 Name Longitude 0.00 0.00 0.00 5088.89 9-5/8 Start Dir 30/100' : 400' MD, 40o'TVD 3.00 30.00 -1.07 3960.00 StartDir 4°/100' : 616.67' MD, 616.2'TVD 4.00 54.95 36.84 End Dir :1013.23' MD, 1001.66' TVD 0.00 0.00 428.24 Start Dir 40/100': 2971.96'MD, 2836.887VD 4.00 58.13 1686.69 End Dir :4788.89' MD, 3937.34' TVD 0.00 0.00 1985.05 Meade Heel wp02 Start Dir 3°/100' : 5088.89' MD, 3968.7 -TVD 3.00 0.00 2178.01 End Dir : 5282.22' MD, 3979.15' TVD 0.00 0.00 3797.74 Start Dir 30/100' : 6901.97' MD, 3984.8'TVD 3.00 0.00 3837.73 3.00 -179.87 3877.80 End Dir : 6982.03' MD, 3984.25' TVD 0.00 0.00 13647.20 Meade toe wp02 Total Depth : 16751.55' MD, 4018.7' TVD TVDPath TVDssPath MDPath Formation CASING DETAILS 1982.00 2120.99 TVD TVDSS MD Size Name Longitude 3456.28 3968.70 3910.00 5088.89 9-5/8 95/8"x121/4" ° 43' 21.573 W 3953.70 4018.70 3960.00 16751.55 6-5/8 6 5/8" x 8 1/2" TVDPath TVDssPath MDPath Formation 2040.70 1982.00 2120.99 BPRF 3269.70 3211.00 3456.28 LA3 3800.70 3742.00 4280.96 SB NA 3953.70 3895.00 4945.39 SB OA 6500 S1yA �OdOa ..5255',053 j19� �Od011 .0g520 0 0 q O O. O O O O O O O O O N O N O N O ro O N O V N 9 5/8" x 12 1/4" Meade Heel wp02 Total Depth: 16757.55' MD, 4018.7' ND M-12 wp05 N O N b O b r _ �16752_ 6 6 5/8" x 8 1/2" Meade toe wp02 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 Vertical Section at 125.00° (1500 usf /in) 0 c -1500 0 0 0 -2250 -4500 -5250 WELL DErA1LR: WUM-12 Ground Level: 25.00 +NI -S +E/ -W Nana, P ain6 Utatude U.0tvde 0.00 0.00 602788980 533933.89 70°29'13,999N 149"43'21.513W REFERENCE INFORMATION Co-oa inate (WE) Reference: Wag MPU Mt 2, True North VeNmI (f3N) Reference: M12 ® 58.78us0 Measured Depth Re"a.: 0.112 ® 50.70.a0 Calculation MMhod: Winton Cumtv2 TVD TVDSS MD St. Name 3968.70 3910.00 5088.89 9-5/8 9 5/8" n 12 1/4" 4018.70 3960.00 16751.55 6-5/8 6 5/8" n 8 12" Meade tce•W- L55' MD, 4018.T TVD 3`y 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 West( -)/East(+) (1500 wittin) HALLIBURTON Project: Milne Point Site: M Pt Moose Pad m .rn Well: MPU M-12 225, Wellbore: M-12 Plan: M-12 wp05 -Start Dir V/100': 400' MD, 40VTVD 1500 Stat DIr4910P: 616,67MI1, 6162TVD End Dir 1013.23' MD, 1001.66 TVD Stan Dnr /]W, 2971.96 MD, 2838.88TVD 750 .. m Fnd llir '47RR N7MD 3917 14'TM 0 c -1500 0 0 0 -2250 -4500 -5250 WELL DErA1LR: WUM-12 Ground Level: 25.00 +NI -S +E/ -W Nana, P ain6 Utatude U.0tvde 0.00 0.00 602788980 533933.89 70°29'13,999N 149"43'21.513W REFERENCE INFORMATION Co-oa inate (WE) Reference: Wag MPU Mt 2, True North VeNmI (f3N) Reference: M12 ® 58.78us0 Measured Depth Re"a.: 0.112 ® 50.70.a0 Calculation MMhod: Winton Cumtv2 TVD TVDSS MD St. Name 3968.70 3910.00 5088.89 9-5/8 9 5/8" n 12 1/4" 4018.70 3960.00 16751.55 6-5/8 6 5/8" n 8 12" Meade tce•W- L55' MD, 4018.T TVD 3`y 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 West( -)/East(+) (1500 wittin) HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: M-12 Design: M-12 wp05 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well MPU M-12 TVD Reference: M-12 @ 58.70usft MD Reference: M-12 @ 58.70usft North Reference: True - Survey Calculation Method: Minimum Curvature -oject Milne Point, ACT, MILNE POINT ap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ao Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ap Zone: Alaska Zone 04 1 Usinq qeodetic scale factor Site M Pt Moose Pad Site Position: Northing: 6,027,877.65usft Latitude: 70° 29' 13.905 N From: Map Easting: 533,363.92usft Longitude: 149'43'38.286W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: 026 ` well MPU M-12 Well Position -NIS 0.00 usft Northing: 6,027,889.80 usft Latitude: 70" 29' J +E/-W 0.00 usft Easting: 533,933.89 usft Longitude: 149" 43' Position Uncertainty 0.00 usft Wellhead Elevation: 25.00 usft Ground Level: - 2 Wellbore M-12 Magnetics Model Name Sample Dale Declination Dip Angle Field Strength (°) l°) K) BGGM2018 10/1/2018 16.98 80.98 57,449.73580238 Design M-12 wp05 -7 Audit Notes: Version: Phase: PLAN Tie On Depth: 33.70 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) _ 33.70 0.00 0.00 125.5. 00 - Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclinatio Azimut Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) n in (usft) usft (usft) (usft) (°/100usft) (°1100usft (°/100usft (") 33.70 0.00 0.00 33.70 -25.00 0.00 000 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 341.30 0.00 0.00 0.00 0.00 0.00 0.00 616.67 6.50 30.00 616.20 557.50 10,63 6.14 3.00 3.00 0.00 30.00 1,013.23 20.29 70.19 1,001.66 942.96 53.64 82.53 4.00 3.48 10.13 54.95 2,971.96 20.29 70.19 2,838.88 2,780.18 283.79 721.49 0.00 0.00 0.00 0.00 4,788.89 84.00 124.80 3,937.34 3,878.64 -190.47 1,925.71 4.00 3.51 3.01 58.13 5,088.89 84.00 124.80 3,968.70 3,910.00 -360.74 2,170.70 0.00 0.00 0.00 0.00 5,282.22 89.80 124.80 3,979.15 3,920.45 -470.87 2,329.16 3.00 3.00 0.00 0.00 6,901.97 89.80 124.80 3,984.80 3,926.10 -1,395.28 3,659.20 0.00 0.00 0.00 0.00 6,941.97 91.00 124.80 3,984.53 3,925.83 -1,418.10 3,692.04 3.00 3.00 0.00 0.00 6,982.03 89.80 124.80 3,984.25 3,925.55 -1,440.97 3,724.94 3.00 -3.00 -0.01 -179.87 16,751.55 89.80 124.80 4,018.70 3,960.00 -7,016.16 11,747.38 0.00 0.00 0.00 0.00 12118/2018 2:30:43PM Pooe 2 COMPASS 5000.15 Build 91 Halliburton HALLI B U RTO N Standard Proposal Report Database: company: Project: Site: Well: Wellbore: Design: NORTH US + CANADA Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 M-12 M-12 wp05 Local Co-ordinate Reference: Well MPU M-12 TVD Reference: M-12 @ 58.70usft No Reference: M-12 @ 58.70usft North Reference: True Survey Calculation Method: Minimum Curvature --- ----� --- Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +E/ -W Northing Easting DLS Vert (usft) V) (1) (usft) usft (usft) (usft) (usft) (usft) -25.00 Section 33.70 0.00 0.00 33.70 -25.00 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 100.00 0.00 0.00 100.00 41.30 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 200.00 0.00 0.00 200.00 141.30 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 300.00 0.00 0.00 300.00 241.30 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 400.00 0.00 0.00 400.00 341.30 0.00 0.00 6,027,889.80 533,933.89 0.00 0.00 Start Dir 3-1100'; 400' MD, 400'TVD 500.00 3.00 30.00 499.95 441.25 2.27 1.31 6,027,892.07 533,935.19 3.00 -0.23 600.00 6.00 30.00 599.63 540.93 9.06 5.23 6,027,898.88 533,939.08 3.00 -0.91 616.67 6.50 30.00 616.21 557.51 10.63 6.14 6,027,900.46 533,939.98 3.00 -1.07 Start Dir 4°1100' : 616.67' MD, 616.2'TVD 700.00 8.84 48.04 698.80 640.10 19.00 13.26 6,027,908.86 533,947.06 4.00 -0.04 800.00 12.27 59.44 797.10 738.40 29.55 28.14 6,027,919.48 533,961.89 4.00 6.10 900.00 15.97 65.79 894.07 835.37 40.60 49.94 6,027,930.62 533,983.54 4.00 17.54 1,000.00 19.78 69.77 989.23 930.53 52.09 78.27 6,027,942.24 534,011.92 4.00 34.24 1,013.23 20.29 70.19 1,001.66 942.96 53.64 82.53 6,027,943.81 534,016.17 4.00 36.84 End Dir : 1013.23' MD, 1001.66' TVD 1,100.00 20.29 70.19 1,083.04 1,024.34 63.84 110.84 6,027,954.14 534,044.42 0.00 54.18 1,200.00 20.29 70.19 1,176.84 1,118.14 75.59 143.46 6,027,966.03 534,076.99 0.00 74.16 1,300.00 20.29 70.19 1,270.64 1,211.94 87.34 176.08 6,027,977.93 534,109.55 0.00 94.14 1,400.00 20.29 70.19 1,364.43 1,305.73 99.09 208.70 6,027,989.83 534,142.12 0.00 114.12 1,500.00 20.29 70.19 1,458.23 1,399.53 110.84 241.32 6,028,001.73 534,174.68 0.00 134.11 1,600.00 20.29 70.19 1,552.03 1,493.33 122.59 273.94 6,028,013.62 534,207.24 0.00 154.09 1,700.00 20.29 70.19 1,645.82 1,587.12 134.34 306.56 6,028,025.52 534,239.81 0.00 174.07 1,800.00 20.29 70.19 1,739.62 1,680.92 146.09 339.18 6,028,037.42 534,272.37 0.00 194.05 1,900.00 20.29 70.19 1,833.42 1,774.72 157.84 371.81 6,028,049.31 534,304.93 0.00 214.03 2,000.00 20.29 70.19 1,927.21 1,868.51 169.59 404.43 6,028,061.21 534,337.50 0.00 234.02 2,100.00 20.29 70.19 2,021.01 1,962.31 181.33 437.05 6,028,073.11 534,370.06 0.00 254.00 2,120.99 20.29 70.19 2,040.70 1,982.00 183.80 443.90 6,028,075.61 534,376.90 0.00 258.19 BPRF 2,200.00 20.29 70.19 2,114.81 2,056.11 193.08 469.67 6,028,085.01 534,402.63 0.00 273.98 2,300.00 20.29 70.19 2,208.60 2,149.90 204.83 502.29 6,028,096.90 534,435.19 0.00 293.96 2,400.00 20.29 70.19 2,302.40 2,243.70 216.58 534.91 6,028,108.80 534,467.75 0.00 313.95 2,500.00 20.29 70.19 2,396.20 2,337.50 228.33 567.53 6,028,120.70 534,500.32 0.00 333.93 2,600.00 20.29 70.19 2,489.99 2,431.29 240.08 600.15 6,028,132.59 534,532.88 0.00 353.91 2,700.00 20.29 70.19 2,583.79 2,525.09 251.83 632.77 6,028,144.49 534,565.45 0.00 373.89 2,800.00 20.29 70.19 2,677.59 2,618.89 263.58 665.39 6,028,156.39 534,598.01 0.00 393.87 2,900.00 20.29 70.19 2,771.38 2,712.68 275.33 698.02 6,028,168.29 534,630.57 0.00 413.86 2,971.96 20.29 70.19 2,838.88 2,780.18 283.79 721.49 6,028,176.85 534,654.01 0.00 428.24 Start Dir 4°1100' : 2971.96' MD, 2838.88'TVD 3,000.00 20.90 72.86 2,865.13 2,806.43 286.91 730.84 6,028,180.01 534,663.34 4.00 434.11 3,100.00 23.38 81.20 2,957.77 2,899.07 295.20 767.51 6,028,188.47 534,699.97 4.00 459.39 3,200.00 26.22 87.93 3,048.56 2,989.86 299.03 809.22 6,028,192.49 534,741.66 4.00 491.35 3,300.00 29.32 93.38 3,137.04 3,078.34 298.39 855.75 6,028,192.06 534,788.19 4.00 529.85 3,400.00 32.59 97.85 3,222.80 3,164.10 293.27 906.90 6,028,187.17 534,839.35 4.00 574.68 12/18/2018 2:30:43PM Pace 3 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: M-12 Design: M-12 wp05 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Map Vertical 2,195.79 Northing Easting Depth Inclination Azimuth Depth TVDss -N/-S +E/ -W (usft) (") (1 (usft) usft (usft) (usft) 3,456.28 34,50 100.02 3,269.70 3,211.00 288.42 937.61 LA3 6,028,123.87 535,084.95 4.00 812.60 6,028,097.50 535,155.10 3,500.00 36.00 101.57 3,305.41 3,246.71 283.69 962.40 3,600.00 39.51 104.71 3,384.46 3,325.76 269.72 1,021.98 3,700.00 43.09 107.42 3,459.59 3,400.89 251.40 1,085.36 3,800.00 46.72 109.79 3,530.41 3,471.71 228.84 1,152.23 3,900.00 50.40 111.89 3,596.58 3,537.88 202.14 1,222.26 4,000.00 54.11 113.77 3,657.79 3,599.09 171.44 1,295.11 4,100.00 57.85 115.49 3,713.72 3,655.02 136.87 1,370.43 4,200.00 61.61 117.07 3,764.12 3,705.42 98.62 1,447.84 4,280.96 64.67 118.27 3,800.70 3,742.00 65.08 1,511.79 SB -NA 3.00 1,996.10 6,027,476.20 536,197.24 3.00 2,095.82 4,300.00 65.39 118.54 3,808.74 3,750.04 56.87 1,526.97 4,400.00 69.18 119.93 3,847.35 3,788.65 11.81 1,607.44 4,500.00 72.98 121.24 3,879.77 3,821.07 -36.32 1,688.85 4,600.00 76.79 122.51 3,905.84 3,847.14 -87.30 1,770.81 4,700.00 80.61 123.73 3,925.44 3,866.74 -140.87 1,852.92 4,788.89 84.00 124.80 3,937.34 3,878.64 -190.47 1,925.71 End Dir :4788.89' MD, 3937.34' TVD 4,800.00 84.00 124.80 3,938.50 3,879.80 -196.77 1,934.78 4,900.00 84.00 124.80 3,948.96 3,890.26 -253.53 2,016.44 4,945.39 84.00 124.80 3,953.70 3,895.00 -279.29 2,053.51 SB OA 5,000.00 84.00 124.80 3,959.41 3,900.71 -310.29 2,098.11 5,088.89 84.00 124.80 3,968.70 3,910.00 -360.74 2,170.70 StartDir 3°1100' : 5088.89' MD, 3968.7TVD - 95/8" x 12 114" - Meade Heel wp02 5,100.00 84.33 124.80 3,969.83 3,911.13 -367.05 2,179.78 5,200.00 87.33 124.80 3,977.09 3,918.39 -423.96 2,261.66 5,282.22 89.80 124.80 3,979.15 3,920.45 -470.87 2,329.15 End Dir : 5282.22' MD, 3979.15' TVD 5,300.00 89.80 124.80 3,979.21 3,920.51 481.02 2,343.75 5,400.00 89.80 124.80 3,979.56 3,920.86 -538.09 2,425.87 5,500.00 89.80 124.80 3,979.91 3,921.21 -595.16 2,507.98 5,600.00 89.80 124.80 3,980.26 3,921.56 -652.23 2,590.10 5,700.00 89.80 124.80 3,980.61 3,921.91 -709.30 2,672.21 5,800.00 89.80 124.80 3,980.96 3,922.26 -766.37 2,754.33 5,900.00 89.80 124.80 3,981.31 3,922.61 -823.44 2,836.44 6,000.00 89.80 124.80 3,981.66 3,922.96 -880.51 2,918.55 6,100.00 89.80 124.80 3,982.01 3,923.31 -937.59 3,000.67 6,200.00 89.80 124.80 3,982.35 3,923.65 -994.66 3,082.78 6,300.00 89.80 124.80 3,982.70 3,924.00 -1,051.73 3,164.90 6,400.00 89.80 124.80 3,983.05 3,924.35 -1,108.80 3,247.01 6,500.00 89.80 124.80 3,983.40 3,924.70 -1,165.87 3,329.13 6,600.00 89.80 124.80 3,983.75 3,925.05 -1,222.94 3,411.24 6,700.00 89.80 124.80 3,984.10 3,925.40 -1,280.01 3,493.35 Halllburton Standard Proposal Report Well MPU M-12 M-12 @ 58.70usft M-12 @ 58.70usft True Minimum Cuwalure Map Map 0.00 2,195.79 Northing Easting DLS Vert (usft) (usft) 3,211.00 Section 6,028,182.47 534,870.08 4.00 602.61 6,028,177.85 534,894.89 4.00 625.63 6,028,164.15 534,954.53 4.00 682.46 6,028,146.13 535,017.99 4.00 744.88 6,028,123.87 535,084.95 4.00 812.60 6,028,097.50 535,155.10 4.00 885.27 6,028,067.13 535,228.08 4.00 962.56 6,028,032.91 535,303.54 4.00 1,044.08 6,027,995.02 535,381.12 4.00 1,129.43 6,027,961.77 535,445.22 4.00 1,201.06 6,027,953.63 535,460.44 4.00 1,218.20 6,027,908.95 535,541.10 4.00 1,309.96 6,027,861.19 535,622.72 4.00 1,404.26 6,027,810.59 535,704:91 4.00 1,500.64 6,027,757.40 535,787.25 4.00 1,598.62 6,027,708.14 535,860.25 4.00 1,686.69 6,027,701.88 535,869.35 0.00 1,697.74 6,027,645.50 535,951.27 0.00 1,797.19 6,027,619.91 535,988.45 0.00 1,842.33 6,027,589.12 536,033.18 0.00 1,896.64 6,027,539.00 536,106.00 0.00 1,985.05 6,027,532.73 536,115.10 3.00 1,996.10 6,027,476.20 536,197.24 3.00 2,095.82 6,027,429.61 536,264.94 3.00 2,178.01 6,027,419.53 536,279.58 0.00 2,195.79 6,027,362.84 536,361.95 0.00 2,295.79 6,027,306.15 536,444.31 0.00 2,395.79 6,027,249.46 536,526.68 0.00 2,495.79 6,027,192.77 536,609.05 0.00 2,595.79 6,027,136.08 536,691.41 0.00 2,695.78 6,027,079.39 536,773.78 0.00 2,795.78 6,027,022.70 536,856.14 0.00 2,895.78 6,026,966.01 536,938.51 0.00 2,995.78 6,026,909.32 537,020.87 0.00 3,095.78 6,026,852.63 537,103.24 0.00 3,195.78 6,026,795.94 537,185.61 0.00 3,295.78 6,026,739.25 537,267.97 0.00 3,395.78 6,026,682.56 537,350.34 0.00 3,495.77 6,026,625.87 537,432.70 0.00 3,595.77 12/18/2018 2:30:43PM Page 4 COMPASS 5000.15 BuW 91 Planned Survey Measured Halliburton HALLI B U RTO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well MPU M-12 Company: Hilcorp Alaska, LLC TVD Reference: M-12 @ 58.70usft Project: Milne Point MD Reference: M-12 @ 58.70usft Site: M Pt Moose Pad North Reference: True Well: MPU M-12 Survey Calculation Method: Minimum Cunature Wellbore: M-12 (usft) (1) Design: M-12 wp05 (usft) usft Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +EI -W Northing Easting DLS Vert (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 3,925.75 Section 6,800.00 89.80 124.80 3,984.45 3,925.75 -1,337.08 3,575.47 6,026,569.18 537,515.07 0.00 3,695.77 6,900.00 89.80 124.80 3,984.80 3,926.10 -1,394.15 3,657.58 6,026,512.49 537,597.44 0.00 3,795.77 6,901.97 89.80 124.80 3,984.80 3,926.10 -1,395.28 3,659.20 6,026,511.37 537,599.06 0.00 3,797.74 Start Dir 3.1100' : 6901.97' MD, 3984.8'TVD 6,941.97 91.00 124.80 3,984.53 3,925.83 -1,418.10 3,692.04 6,026,488.70 537,632.00 3.00 3,837.73 6,982.03 89.80 124.80 3,984.25 3,925.55 -1,440.97 3,724.94 6,026,465.99 537,665.00 3.00 3,877.80 End Dir : 6982.03' MD, 3984.25' TVD 7,000.00 89.80 124.80 3,984.31 3,925.61 -1,451.22 3,739.70 6,026,455.80 537,679.80 0.00 3,895.77 7,100.00 89.80 124.80 3,984.66 3,925.96 -1,508.29 3,821.81 6,026,399.11 537,762.17 0.00 3,995.77 7,200.00 89.80 124.80 3,985.02 3,926.32 -1,565.36 3,903.93 6,026,342.43 537,844.54 0.00 4,095.76 7,300.00 89.80 124.80 3,985.37 3,926.67 -1,622.42 3,986.05 6,026,285.74 537,926.91 0.00 4,195.76 7,400.00 89.80 124.80 3,985.72 3,927.02 -1,679.49 4,068.16 6,026,229.05 538,009.27 0.00 4,295.76 7,500.00 89.80 124.80 3,986.07 3,927.37 -1,736.56 4,150.28 6,026,172.37 538,091.64 0.00 4,395.76 7,600.00 89.80 124.80 3,986.43 3,927.73 -1,793.62 4,232.40 6,026,115.68 538,174.01 0.00 4,495.76 7,700.00 89.80 124.80 3,986.78 3,928.08 -1,850.69 4,314.52 6,026,058.99 538,256.38 0.00 4,595.76 7,800.00 89.80 124.80 3,987.13 3,928.43 -1,907.76 4,396.63 6,026,002.31 538,338.75 0.00 4,695.76 7,900.00 89.80 124.80 3,987.48 3,928.78 -1,964.83 4,478.75 6,025,945.62 538,421.12 0.00 4,795.76 8,000.00 89.80 124.80 3,987.84 3,929.14 -2,021.89 4,560.87 6,025,888.94 538,503.48 0.00 4,895.75 8,100.00 89.80 124.80 3,988.19 3,929.49 -2,078.96 4,642.98 6,025,832.25 538,585.85 0.00 4,995.75 8,200.00 89.80 124.80 3,988.54 3,929.84 -2,136.03 4,725.10 6,025,775.56 538,668.22 0.00 5,095.75 8,300.00 89.80 124.80 3,988.89 3,930.19 -2,193.10 4,807.22 6,025,718.88 538,750.59 0.00 5,195.75 8,400.00 89.80 124.80 3,989.25 3,930.55 -2,250.16 4,889.34 6,025,662.19 538,832.96 0.00 5,295.75 8,500.00 89.80 124.80 3,989.60 3,930.90 -2,307.23 4,971.45 6,025,605.50 538,915.33 0.00 5,395.75 8,600.00 89.80 124.80 3,989.95 3,931.25 -2,364.30 5,053.57 6,025,548.82 538,997.69 0.00 5,495.75 8,700.00 89.80 124.80 3,990.31 3,931.61 -2,421.36 5,135.69 6,025,492.13 539,080.06 0.00 5,595.75 8,800.00 89.80 124.80 3,990.66 3,931.96 -2,478.43 5,217.80 6,025,435.44 539,162.43 0.00 5,695.74 8,900.00 89.80 124.80 3,991.01 3,932.31 -2,535.50 5,299.92 6,025,378.76 539,244.80 0.00 5,795.74 9,000.00 89.80 124.80 3,991.36 3,932.66 -2,592.57 5,382.04 6,025,322.07 539,327.17 0.00 5,895.74 9,100.00 89.80 124.80 3,991.72 3,933.02 -2,649.63 5,464.15 6,025,265.39 539,409.54 0.00 5,995.74 9,200.00 89.80 124.80 3,992.07 3,933.37 -2,706.70 5,546.27 6,025,208.70 539,491.91 0.00 6,095.74 9,300.00 89.80 124.80 3,992.42 3,933.72 -2,763.77 5,628.39 6,025,152.01 539,574.27 0.00 6,195.74 9,400.00 89.80 124.80 3,992.77 3,934.07 -2,820.83 5,710.51 6,025,095.33 539,656.64 0.00 6,295.74 9,500.00 89.80 124.80 3,993.13 3,934.43 -2,877.90 5,792.62 6,025,038.64 539,739.01 0.00 6,395.74 9,600.00 89.80 124.80 3,993.48 3,934.78 -2,934.97 5,874.74 6,024,981.95 539,821.38 0.00 6,495.73 9,700.00 89.80 124.80 3,993.83 3,935.13 -2,992.04 5,956.86 6,024,925.27 539,903.75 0.00 6,595.73 9,800.00 89.80 124.80 3,994.18 3,935.48 -3,049.10 6,038.97 6,024,868.58 539,986.12 0.00 6,695.73 9,900.00 89.80 124.80 3,994.54 3,935.84 -3,106.17 6,121.09 6,024,811.89 540,068.48 0.00 6,795.73 10,000.00 89.80 124.80 3,994.89 3,936.19 -3,163.24 6,203.21 6,024,755.21 540,150.85 0.00 6,895.73 10,100.00 89.80 124.80 3,995.24 3,936.54 -3,220.31 6,285.32 6,024,698.52 540,233.22 0.00 6,995.73 10,200.00 89.80 124.80 3,995.60 3,936.90 -3,277.37 6,367.44 6,024,641.84 540,315.59 0.00 7,095.73 10,300.00 89.80 124.80 3,995.95 3,937.25 -3,334.44 6,449.56 6,024,585.15 540,397.96 0.00 7,195.73 10,400.00 89.80 124.80 3,996.30 3,937.60 -3,391.51 6,531.68 6,024,528.46 540,480.33 0.00 7,295.72 10,500.00 89.80 124.80 3,996.65 3,937.95 -3,448.57 6,613.79 6,024,471.78 540,562.70 0.00 7,395.72 10,600.00 89.80 124.80 3,997.01 3,938.31 -3,505.64 6,695.91 6,024,415.09 540,645.06 0.00 7,495.72 10,700.00 89.80 124.80 3,997.36 3,938.66 -3,562.71 6,778.03 6,024,358.40 540,727.43 0.00 7,595.72 1211812018 2:30:43PM Pam 5 COMPASS 5000.15 Build 91 Halliburton HALL I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well MPU M-12 Company: Hiloorp Alaska, LLC TVD Reference: M-12 @ 58.70usft Project: Milne Point MD Reference: M-12 @ 58.70usft Site: M Pt Moose Pad North Reference: True Well: MPU M-12 Survey Calculation Method: Minimum Curvature Wellbore: M-12 Depth Inclination Design: M-12 wp05 TVDss +NIS Planned Survey ... _ . Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +EI -W Northing Easting DLS Vert (usft) V) (1) (usft) Usti (usft) (usft) (usft) (usft) 3,939.01 Section 10,800.00 89.80 124.80 3,997.71 3,939.01 -3,619.78 6,860.14 6,024,301.72 540,809.80 0.00 7,695.72 10,900.00 89.80 124.80 3,998.06 3,939.36 -3,676.84 6,942.26 6,024,245.03 540,892.17 0.00 7,795.72 11,000.00 89.80 124.80 3,998.42 3,939.72 -3,733.91 7,024.38 6,024,188.34 540,974.54 0.00 7,895.72 11,100.00 89.80 124.80 3,998.77 3,940.07 -3,790.98 7,106.50 6,024,131.66 541,056.91 0.00 7,995.72 11,200.00 89.80 124.80 3,999.12 3,940.42 -3,848.05 7,188.61 6,024,074.97 541,139.27 0.00 8,095.71 11,300.00 89.80 124.80 3,999.47 3,940.77 -3,905.11 7,270.73 6,024,018.29 541,221.64 0.00 8,195.71 11,400.00 89.80 124.80 3,999.83 3,941.13 -3,962.18 7,352.85 6,023,961.60 541,304.01 0.00 8,295.71 11,500.00 89.80 124.80 4,000.18 3,941.48 -4,01925 7,434.96 6,023,904.91 541,386.38 0.00 8,395.71 11,600.00 89.80 124.80 4,000.53 3,941.83 -4,076.31 7,517.08 6,023,848.23 541,468.75 0.00 8,495.71 11,700.00 89.80 124.80 4,000.89 3,942.19 -4,133.38 7,599.20 6,023,791.54 541,551.12 0.00 8,595.71 11,800.00 89.80 124.80 4,001.24 3,942.54 -4,190.45 7,681.31 6,023,734.85 541,633.48 0.00 8,695.71 11,900.00 89.80 124.80 4,001.59 3,942.89 -4,247.52 7,763.43 6,023,678.17 541,715.85 0.00 8,795.71 12,000.00 89.80 124.80 4,001.94 3,943.24 -4,304.58 7,845.55 6,023,621.48 541,798.22 0.00 8,895.70 12,100.00 89.80 124.80 4,002.30 3,943.60 -4,361.65 7,927.67 6,023,564.79 541,880.59 0.00 8,995.70 12,200.00 89.80 124.80 4,002.65 3,943.95 -4,418.72 8,009.78 6,023,508.11 541,962.96 0.00 9,095.70 12,300.00 89.80 124.80 4,003.00 3,944.30 -4,475.78 8,091.90 6,023,451.42 542,045.33 0.00 9,195.70 12,400.00 89.80 124.80 4,003.35 3,944.65 -4,532.85 8,174.02 6,023,394.74 542,127.70 0.00 9,295.70 12,500.00 89.80 124.80 4,003.71 3,945.01 -4,589.92 8,256.13 6,023,338.05 542,210.06 0.00 9,395.70 12,600.00 89.80 124.80 4,004.06 3,945.36 -4,646.99 8,338.25 6,023,281.36 542,292.43 0.00 9,495.70 12,700.00 89.80 124.80 4,004.41 3,945.71 -4,704.05 8,420.37 6,023,224.68 542,374.80 0.00 9,595.70 12,800.00 89.80 124.80 4,004.76 3,946.06 -4,761.12 8,502.48 6,023,167.99 542,457.17 0.00 9,695.69 12,900.00 89.80 124.80 4,005.12 3,946.42 -4,818.19 8,584.60 6,023,111.30 542,539.54 0.00 9,795.69 13,000.00 89.80 124.80 4,005.47 3,946.77 -4,875.26 8,666.72 6,023,054.62 542,621.91 0.00 9,895.69 13,100.00 89.80 124.80 4,005.82 3,947.12 -4,932.32 8,748.84 6,022,997.93 542,704.27 0.00 9,995.69 13,200.00 89.80 124.80 4,006.17 3,947.47 -4,989.39 8,830.95 6,022,941.24 542,786.64 0.00 10,095.69 13,300.00 89.80 124.80 4,006.53 3,947.83 -5,046.46 8,913.07 6,022,884.56 542,869.01 0.00 10,195.69 13,400.00 89.80 124.80 4,006.88 3,948.18 -5,103.52 8,995.19 6,022,827.87 542,951.38 0.00 10,295.69 13,500.00 89.80 124.80 4,007.23 3,948.53 -5,160.59 9,077.30 6,022,771.19 543,033.75 0.00 10,395.69 13,600.00 89.80 124.80 4,007.59 3,948.89 -5,217.66 9,159.42 6,022,714.50 543,116.12 0.00 10,495.68 13,700.00 89.80 124.80 4,007.94 3,949.24 -5,274.73 9,241.54 6,022,657.81 543,198.48 0.00 10,595.68 13,800.00 89.80 124.80 4,008.29 3,949.59 -5,331.79 9,323.65 6,022,601.13 543,280.85 0.00 10,695.68 13,900.00 89.80 124.80 4,008.64 3,949.94 -5,388.86 9,405.77 6,022,544.44 543,363.22 0.00 10,795.68 14,000.00 89.80 124.80 4,009.00 3,950.30 -5,445.93 9,487.89 6,022,487.75 543,445.59 0.00 10,895.68 14,100.00 89.80 124.80 4,009.35 3,950.65 -5,502.99 9,570.01 6,022,431.07 543,527.96 0.00 10,995.68 14,200.00 89.80 124.80 4,009.70 3,951.00 -5,560.06 9,652.12 6,022,374.38 543,610.33 0.00 11,095.68 14,300.00 89.80 124.80 4,010.05 3,951.35 -5,617.13 9,734.24 6,022,317.70 543,692.70 0.00 11,195.68 14,400.00 89.80 124.80 4,010.41 3,951.71 -5,674.20 9,816.36 6,022,261.01 543,775.06 0.00 11,295.67 14,500.00 89.80 124.80 4,010.76 3,952.06 -5,731.26 9,898.47 6,022,204.32 543,857.43 0.00 11,395.67 14,600.00 89.80 124.80 4,011.11 3,952.41 -5,788.33 9,980.59 6,022,147.64 543,939.80 0.00 11,495.67 14,700.00 89.80 124.80 4,011.46 3,952.76 -5,845.40 10,062.71 6,022,090.95 544,022.17 0.00 11,595.67 14,800.00 89.80 124.80 4,011.82 3,953.12 -5,902.47 10,144.83 6,022,034.26 544,104.54 0.00 11,695.67 14,900.00 89.80 124.80 4,012.17 3,953.47 -5,959.53 10,226.94 6,021,977.58 544,186.91 0.00 11,795.67 15,000.00 89.80 124.80 4,012.52 3,953.82 -6,016.60 10,309.06 6,021,920.89 544,269.27 0.00 11,895.67 15,100.00 89.80 124.80 4,012.88 3,954.18 -6,073.67 10,391.18 6,021,864.20 544,351.64 0.00 11,995.67 15,200.00 89.80 124.80 4,013.23 3,954.53 -6,130.73 10,473.29 6,021,807.52 544,434.01 0.00 12,095.66 12118/2018 2:30:43PM Pace 6 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well MPU M-12 Company: Hilcorp Alaska, LLC TVD Reference: M-12 @ 58.70usft Project: Milne Point MD Reference: M-12 @ 58.70usft Site: M Pt Moose Pad North Reference: True Well: MPU M-12 Survey Calculation Method: Minimum Curvature Wellbore: M-12 Design: M-12 wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS -E/-W Northing Easting DLS Vert (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,954.88 Section 15,300.00 89.80 124.80 4,013.58 3,954.88 -6,187.80 10,555.41 6,021,750.83 544,516.38 0.00 12,195.66 15,400.00 89.80 124.80 4,013.93 3,955.23 -6,244.87 10,637.53 6,021,694.15 544,598.75 0.00 12,295.66 15,500.00 89.80 124.80 4,014.29 3,955.59 -6,301.94 10,719.64 6,021,637.46 544,681.12 0.00 12,395.66 15,600.00 89.80 124.80 4,014.64 3,955.94 -6,359.00 10,801.76 6,021,580.77 544,763.49 0.00 12,495.66 15,700.00 89.80 124.80 4,014.99 3,956.29 -6,416.07 10,883.88 6,021,524.09 544,845.85 0.00 12,595.66 15,800.00 89.80 124.80 4,015.34 3,956.64 -6,473.14 10,966.00 6,021,467.40 544,928.22 0.00 12,695.66 15,900.00 89.80 124.80 4,015.70 3,957.00 -6,530.20 11,048.11 6,021,410.71 545,010.59 0.00 12,795.66 16,000.00 89.80 124.80 4,016.05 3,957.35 -6,587.27 11,130.23 6,021,354.03 545,092.96 0.00 12,895.65 16,100.00 89.80 124.80 4,016.40 3,957.70 -6,644.34 11,212.35 6,021,297.34 545,175.33 0.00 12,995.65 16,200.00 89.80 124.80 4,016.75 3,958.05 -6,701.41 11,294.46 6,021,240.65 545,257.70 0.00 13,095.65 16,300.00 89.80 124.80 4,017.11 3,958.41 -6,758.47 11,376.58 6,021,183.97 545,340.06 0.00 13,195.65 16,400.00 89.80 124.80 4,017.46 3,958.76 .6,815.54 11,458.70 6,021,127.28 545,422.43 0.00 13,295.65 16,500.00 89.80 124.80 4,017.81 3,959.11 -6,872.61 11,540.81 6,021,070.60 545,504.80 0.00 13,395.65 16,600.00 89.80 124.80 4,018.17 3,959.47 -6,929.68 11,622.93 6,021,013.91 545,587.17 0.00 13,495.65 16,700.00 89.80 124.80 4,018.52 3,959.82 -6,986.74 11,705.05 6,020,957.22 545,669.54 0.00 13,595.65 16,751.55 89.80 124.80 4,018.70 - 3,960.00 -7,016.16 11,747.38 6,020,928.00 545,712.00 0.00 13,647.19 Total Depth : 16751.55' MD, 4018.7' TVD - 6 518" x 8 1/2" - Meade toe wp02 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Meade Heel wp02 0.00 0,00 3,968.70 -360.74 2,170.70 6,027,539.00 536,106.00 - plan hits target center - Point Meade toe wp02 0.00 0.00 4,018.70 -7,016.16 11,747.38 6,020,928.00 545,712.00 - plan hits target center - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (•') 5,088.89 3,968 70 9 5/8" x 12 1/4" 9-5/8 12-1/4 I 16,751.55 4,018.70 6 5/8" x 8 1/2" 6-5/8 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) 4,280.96 3,800.70 SB_NA 0.00 2,120.99 2,040.70 BPRF 0.00 4,945.39 3,953.70 SB -OA 0.00 3,456.28 3,269.70 LA3 0.00 12/18/2018 2:30:43PM Pace 7 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Prosect: Milne Point Site: M Pt Moose Pad Well: MPU M-12 Wellbore: M-12 Design: M-12 wp05 Plan Annotations Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Vertical Local Coordinates Depth Depth +N/ -S +Ei-W (usft) (usft) (usft) (usft) 400.00 400.00 0.00 0.00 616.67 616.21 10.63 6.14 1,013.23 1,001.66 53.64 82.53 2,971.96 2,838.88 283.79 721.49 4,788.89 3,937.34 -190.47 1,925.71 5,088.89 3,968.70 -360.74 2,170.70 5,282.22 3,979.15 -470.87 2,329.15 6,901.97 3,984.80 -1,395.28 3,659.20 6,982.03 3,984.25 -1,418.11 3,692.05 16,751.55 4,018.70 -1,440.97 3,724.94 Well MPU M-12 M-12 @ 58.70usft M-12 @ 58.70usft True Minimum Curvature Comment Start Dir 3°/100' : 400' MD, 400'TVD Start Dir 4°/100 : 616.67' MD, 616.2'TVD End Dir :1013.23' MD, 1001.66' TVD Start Dir4°/100':2971.96' MD, 2838.88'TVD End Dir : 4788.89' MD, 3937.34' TVD Start Dir 3-1100': 5088.89' MD, 3968.7'TVD End Dir : 5282.22' MD, 3979.15' TVD Start Dir 3°1100' : 6901.97' MD, 3984.8TVD End Dir : 6982.03' MD, 3984.25' TVD Total Depth : 16751.55' MD, 4018.7' TVD Halliburton Standard Proposal Report 12H82018 2:30:43PM Pam 8 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-12 M-12 M-12 wp05 Sperry Drilling Clearance Summary Anticollision Report 18 December, 2018 Services Closest Approach 3D Proximity Scan on Current Survey Data (Highslde Reference) Reference Design: M Pt Moose Pad - MPU M-12 - M-12 - M-12 wp05 Well Coordinates: 6,027,889.80 N, 533,933.89 E (70" 29' 14.00" N, 1491 43'21.51" W) Datum Height: M-12 @ 58.70usft Scan Range: 0.00 to 16,751.55 usft. Measured Depth. Scan Radius Is Unlimited . Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is 5,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for MPU M-12 - M-12 wp05 Hileorp Alaska, LLC Milne Point Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt Moose Pad - MPU M-12 - M-12 - M-12 wp05 Scan Range: 0.00 to 16,751.55 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 5,500.00 wit Measure Minimum @Measure Ellipse @Measure. Clearance Summary Based Site Name d Distance of Separation d Factor on Minimum Separation Warning Comparison Well Name - Wellbore Name -Design Deoth lusHI DeDth lusffl Deoth Alternate Close Approach Scenarios MPL-34 GyrolnDrillPipe - GyrolnDP- GyrolnDP 8,512.66 631.49 8,512.66 512.10 10,764.81 5.289 Centre Distance Pass - MPL-34 GyrolnDrillPipe- GyrolnDP - GyrolnDP 8,550.00 632.55 8,550.00 511.72 10,757.94 5.235 Ellipse Separation Pass - MPL-34 GyrolnDrillPipe-GyrolnDP-GyrolnDP 8,675.00 651.38 8,675.00 525.06 10,735.81 5.157 Clearance Factor Pass - MPL-34 MWD -MWD -MWD 8,575.66 619.74 8,575.66 529.02 10,750.95 6.831 Centre Distance Pass - MPL-34 MWD -MWD -MWD 8,800.00 658.18 8,800.00 499.42 10,719.53 4.146 Ellipse Separation Pass - MPL-34 MWD -MWD -MWD 9,100.00 808.26 9,100.00 566.91 10,687.76 3.349 Clearance Factor Pass - M Pt L Pad MPL-20 - MPL-20 - MPL-20 7.042.89 92.44 7.042.89 13.93 10,633.57 1.177 Centre Distance Paw - MPL-20-MPL-20-MPL-20 7,100.00 107.89 7,100.00 1.90 10,620.44 1.018 Clearance Factor Pan - MPL-32-MPL-32-MPL-32 6,027.31 503.08 6,027.31 449.53 11,215.41 9.394 Centre Distance Pass - MPL-32 - MPL-32 - MPL-32 6,150.00 515.60 6,150.00 442.25 11,167,82 7.029 Ellipse Separation Pass - MPL-32-MPL-32-MPL-32 6,450.00 637.02 6,450.00 513.21 11,060.48 5.145 Clearance Factor Pass - MPL-34 - MPL-34 - MPL-34 8,490.00 648.26 8,490.00 595.00 10,772.58 12.173 Centre Distance Pass - MPL-34 - MPL-34 - MPL-34 8,525.00 649.17 8,525.00 593.97 10,766.65 11.759 Ellipse Separation Pass - MPL-34 - MPL-34 - MPL-34 8,925.00 777.38 8,925.00 689.10 10,708.14 8.805 Clearance Factor Pass - MPL-35 - MPL-35 - MPL-35 10,031.87 229.65 10,031.87 139.65 10,195.34 2.552 Centre Distance Pass - MPL-35 - MPL-35 - MPL-35 10,050.00 230.36 10,050.00 139.41 10,195.57 2.533 Ellipse Separation Pass - MPL-35 - MPL-35 - MPL-35 10,100.00 239.54 10,100.00 143.48 10,196.20 2.494 Clearance Factor Pass - MPL-35 - MPL-35A - MPL-35A 10,031.87 229.65 10,031.87 139.65 10,196.14 2.552 Centre Distance Pass - MPL-35-MPL35A-MPL-35A 10,050.00 230.36 10,050.00 139.41 10,196.37 2.533 Ellipse Separation Pass - MPL-35 - MPL-35A - MPL-35A 10,100.00 239.54 10,100.00 143.48 10,197.00 2.494 Clearance Factor Pass - MPL-35 - MPL-35APB1 - MPL-35APB1 10,031.87 229.65 10,031.87 139.65 10,196.14 2.552 Centre Distance Pass - MPL35-MPL35APB1-MPL-35APB1 10,050.00 230.36 10,050.00 139.41 10,196.37 2.533 Ellipse Separation Pass - MPL-35-MPL-35APB1-MPL-35APB1 10,100.00 239.54 10,100.00 143.48 10,197.00 2.494 Clearance Factor Pass - MPL-35 - MPL-35APB2 - MPL-35APB2 10,031.87 229.65 10,031.87 139.64 10,196.14 2.552 Centre Distance Pass - MPL-35 - MPL-35APB2 - MPL-35APB2 10,050.00 230.36 10,050.00 139.41 10,196.37 2.533 Ellipse Separation Pass - MPL-35-MPL35APB2-MPL-35APB2 10,100.00 239.54 10,100.00 143.48 10,197.00 2.494 Clearance Factor Pass - 18 December, 2018 - 17:42 Page 2 of COMPASS Hileorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for MPU M-12 - M-12 wp05 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt Moose Pad - MPU M-12 - M-12 - M-12 wp05 Scan Range: 0.00 to 16,751.55 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 5,500.00 usft Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Site Name d Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name - Wellbore Name - Design Death Wain, Death fusftl Death MPL-35-MPL35APB3-MPL-35APB3 10,031.87 229.65 10,031.87 139.65 10,196.14 2.552 Centre Distance Pass - MPL-35 - MPL-35APB3 - MPL-35APB3 10,050.00 230.36 10,050.00 139.41 10,196.37 2.533 Ellipse Separation Pass - MPL-35 - MPL-35APB3 - MPL-35APB3 10,100.00 239.54 10,100.00 143.48 10,197.00 2.494 Clearance Factor Pass - MPL-36 - MPL-36 - MPL-36 7,984.12 89.33 7,984.12 17.48 10,635.25 1.243 Centre Distance Pass - MPL-36 - MPL-36 - MPL-36 8,025.00 97.90 8,025.00 6.78 10,627.02 1.074 Ellipse Separation Pass - MPL-36 - MPL-36 - MPL-36 8,050.00 110.20 8,050.00 7.31 10,621.91 1.071 Clearance Factor Paw - MPL-36-MPL-36L1-MPL-361-1 7,984.12 89.33 7,984.12 17.64 10,635.25 1.246 Centre Distance Pass - MPL36-MPL-36L1-MPL-361-1 8,025.00 97.90 8,025.00 6.51 10,627.02 1.071 Ellipse Separation Pass - MPL-36 - MPL-361-1 - MPL-361-1 8.050.00 110.20 8,050.00 6.76 10,621.91 1.065 Clearance Factor Pass - MPL-36 - MPL36L1 PB1 - MPL-361-1 PB1 7,984.12 89.33 7,984.12 17.57 10,635.25 1.245 Centre Distance Pass - MPL-36 - MPL-36L1 Pet - MPL-36L1 PB1 8,025.00 97.90 8,025.00 6.10 10,627.02 1.066 Ellipse Separation Pass - MPL-36 - MPL-361-1 PB1 - MPL-36L1 PB1 8.050.00 110.20 8,050.00 6.13 10,621.91 1.059 Clearance Factor Pass - MPL-36 - MPL-36PB1 - MPL-36PB1 7,984.12 89.33 7,984.12 17.48 10,635.25 1.243 Centre Distance Pass - MPL-36 - MPL36PB1 - MPL-36PB1 8,025.00 97.90 8,025.00 6.78 10,627.02 1.074 Ellipse Separation Pass - MPL-36 - MPL-36PB1 - MPL-36PB1 8,050.00 110.20 8,050.00 7.31 10,621.91 1.071 Clearance Factor Pass - MPL-37- MPL37- MPL37 10,057.65 679.93 10,057.65 598.99 10,498.31 8.400 Centre Distance Pass - MPL-37 - MPL-37 - MPL-37 10,100.00 681.23 10,100.00 598.15 10,493.94 8.199 Ellipse Separation Pass - MPL-37-MPL-37-MPL37 10,500.00 809.74 10,500.00 688.17 10,452.33 6.661 Clearance Factor Pass - MPL-37 - MPL-37A - MPL-37A 10,051-65 679.93 10,057.65 598.99 10,507.51 8.400 Centre Distance Pass- ^ MPL-37-MPL-37A-MPL37A 10,100.00 681.23 10,100.00 598.15 10,503.14 8.199 Ellipse Separation Pass - MPL-37 - MPL-37A - MPL-37A 10,500.00 809.74 10,500.00 688.17 10,461.53 6.660 Clearance Factor Pass- MPU L-51 - MPU L-51 - MPU L51 11,900.00 245.59 11,900.00 126.03 10,675.15 2.054 Clearance Factor Pass - MPU L-51 - MPU L-51 - MPU L51 11,975.00 209.59 11,975.00 115.57 10,703.15 2.229 Ellipse Separation Pass - MPU L-51 - MPU L-51 - MPU L-51 12,065.65 192.13 12,065.65 129.28 10,737.23 3.057 Centre Distance Pass - MPU L-52 - MPU L-52 - MPU L52 10,400.00 246.57 10,400.00 130.02 10,889.89 2.116 Clearance Factor Pass - MPU L-52 - MPU L-52 - MPU L-52 10,475.00 208.90 10,475.00 115.87 10,926.54 2.245 Ellipse Separation Pass - MPU L52-MPU L-52-MPU L-52 10,587.64 184.66 10,587.64 128.76 10,984.81 3.303 Centre Distance Pass - MPUL-53-MPU L-53-MPU L53 8,972.16 182.96 8,972.16 113.95 11,311.29 2.651 Centre Distance Pass - MPU L-53-MPU L-53-MPU L-53 8,975.00 182.97 8,975.00 113.89 11,312.44 2.649 Ellipse Separation Pass- MPU L-53 - MPU L-53 - MPU L-53 9,075.00 205.60 9,075.00 123.78 11,352.81 2.513 Clearance Factor Pass - 18 December, 2018 - 17:42 Page 3 of 7 COMPASS HALLIBURTON Anticollision Report for MPU M-12 - M-12 wp05 Closest Approach 3D Proximity Scan on Current Survey Data (Nighside Reference) Reference Design: M Pt Moose Pad - MPU M-12 - M-12 - M-12 wp05 Scan Range: 0.00 to 16,751.55 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 5,500.00 usft Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-I0-M-10-M-10wp09 Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Centre Distance Site Name d Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name - Wellbore Name - Design Deoth leaftl Denth loath Depth 16,150.00 1,120.84 15,631.40 MPU L-54 - MPU L-54 - MPU L-54 12,850.00 220.00 12,850.00 86.02 11,069.54 1.642 Clearance Factor Pass - MPU L-54 - MPU L-54 - MPU L-54 12,900.00 193.40 12,900.00 78.15 11,089.24 1.678 Ellipse Separation Pass - MPU L -54 -MPU L -54 -MPU L-54 13,006.40 167.13 13,006.40 98.89 11,129.94 2.449 Centre Distance Pass - MPU L-56 - MPU L-56 - MPU L-56 9,774.84 179.49 9,774.84 125.85 11,069.88 3.346 Centre Distance Pass - MPU L56 -MPU L -56 -MPU L-56 9,875.00 199.65 9,875.00 118.56 11,116.59 2.462 Ellipse Separation Pass - MPU L -56 -MPU L -56 -MPU L-56 9,950.00 236.32 9,950.00 131.70 11,149.29 2.259 Clearance Factor Pass- MPU L -57 -MPU L -57 -MPU L-57 11,175.00 252.33 11,175.00 129.60 10,791.96 2.056 Clearance Factor Pass - MPU L -57 -MPU L -57 -MPU L-57 11,250.00 214.31 11,250.00 116.25 10,827.38 2.185 Ellipse Separation Pass - MPU L -57 -MPU L -57 -MPU L-57 11,359.64 190.21 11,359.64 130.26 10,876.35 3.173 Centre Distance Pass - MPU L-57- MPU L57PB1 - MPU L-57PB1 11,175.00 252.33 11,175.00 129.60 10,791.96 2.056 Clearance Factor Pass - MPU L-57 - MPU L-57PB1 - MPU L-57PB1 11,250.00 214.31 11,250.00 116.24 10,827.38 2.185 Ellipse Separation Pass - MPU L-57 - MPU L-57PB1 - MPU L-57PB1 11,359.64 190.21 11,359.64 130.26 10,876.36 3.173 Centre Distance Pass - M Pt Moose Pad MPU M-I0-M-10-M-10wp09 350.00 179.93 350.00 176.75 349.90 56.603 Centre Distance Pass - MPU M -I0 -M -10-M-10 wp09 375.00 180.00 375.00 176.65 373.79 53.675 Ellipse Separation Pass - MPU M -I0- MAO -M-10 wp09 16,150.00 1,645.50 16,150.00 1,120.84 15,631.40 3.136 Clearance Factor Pass - MPU M-11 - M-11 - M-11 wp06 375.00 90.00 375.00 85.59 375.00 26.429 Centre Distance Pass - MPU M-11 - M-11 - M-11 wp06 1,025.00 93.03 1,025.00 85.33 993.89 12.091 Ellipse Separation Pass - MPU M-11 - M-11 - M-11 wp06 16,500.00 841.99 16,500.00 277.56 16,308.46 1.492 Clearance Factor Pass - MPU M-I3-M-13-M-13(Stonewall hill wp02 400.00 127.22 400.00 123.65 396.00 35.635 Centre Distance Pass - MPU M-13 - M-13 - M-13 (Stonewall Inj) wp02 425.00 127.31 425.00 123.56 421.00 33.956 Ellipse Separation Pass - MPU M-I3-M-13-M-13(Stonewall Inj) wp02 16,751.55 837.49 16,751.55 237.26 16,195.97 1.395 Clearance Factor Pass - MPUM-I4-M-14-M-14(McCIlan Prod) wp02 400.00 116.10 400.00 112.66 396.00 33.788 Centre Distance Pass - MPU M-I4-M-14-M-14(McCllan Prod) wp02 425.00 116.26 425.00 112.64 421.00 32.155 Ellipse Separation Pass - MPU M-I4-M-14-M-14(McCllan Prod) wp02 16,751.55 1,651.19 16,751.55 1,053.46 16,125.20 2.762 Clearance Factor Pass - MPU M-15 - M-15 - M-15 (Bragg Inj) wp03 400.00 164.24 400.00 160.79 396.00 47.586 Ellipse Separation Pass - MPU M-15 - M-15 - M-15 (Bragg Inj) wp03 750.00 206.05 750.00 200.15 730.71 34.921 Clearance Factor Pass - Slot 46-Placeholder-Slot 46-Placeholder-Slot 46- 687.23 25.98 687.23 20.40 648.47 4.652 Centre Distance Pass - Slot 46-Placeholtler-Slot 46-Placeholder-Slot 46- 700.D0 26.02 700.00 20.34 661.10 4.583 Ellipse Separation Pass - Slot 46-Placeholtler-Slot 46-Placeholder-Slot 46- 750.00 27.13 750.00 21.08 710.38 4.486 Clearance Factor Pass - 18 December, 2018 - 17:42 Page 4 of COMPASS HALLIBURTON Anticollision Report for MPU M-12 - M-12 wp05 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt Moose Pad - MPU M-12 - M-12 - M-12 wp05 Scan Range: 0.00 to 16,751.55 usft. Measured Depth. Scan Radius Is Unlimited . Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is 5,500.00 usft Measure Minimum @Measure Ellipse Site Name d Distance d Separation Comparison Well Name -Wellbore Name - Design Death (usft) Death (usft) Slot 52-Placeholder-Slot 52-Placeholder-Slot 52- 1,052.83 64.14 1,052.83 55.78 Slot 58-Placeholder-Slot 58-Placeholder-Slot 58- 1,075.00 125.8D 1,075.00 117.52 Slot 58-Placeholder-Slot 58-Placeholder-Slot 58- 1,082.16 125.60 1,082.16 117.33 Survey tool program From To SurveylPlan (usft) (usft) 33.70 5,090.00 M-12 wp05 5,090.00 16,751.55 M-12 wp05 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 centras is the straight line distance between weilbare centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. @Measure Clearance Summary Based d Factor on Minimum Death 1,000.00 7.675 Clearance Factor 1,000.00 15.189 Clearance Factor 1,000.00 15.195 Ellipse Separation Survey Tool 2 MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point Separation Warning Pass - Pass - Pass - 18 December, 2018 - 17:42 Page 5 of COMPASS HALLIBURTON Project: Milne Paint REFERENCE INFORMATION WELLDETAIS:WLIM-12 NAD1927(NADCONCONUS) Alaska2nne04 Reference: Well MPU Tme No4M1 Gaomtical (]round Level' 25.00 Site: M Pt Moose Pad enerr•y G�illing Well: MPU M-12 (TVD) ,70w Vealaal Depth Reference: W12 C 50 70Mft Measuretl Depth Reference: W12®$9)Pusfl +N/.5 +V.W NOMin g lan®mde K Wellbore: M-12 CalaWlion MMM1oO: Mnimum Cuwelure 3393 2V 11399 000 0.00 602]889.80 5339)3.99 ]0°2Y 13999th 149°43'21513W Plan: M-12 wp05 SURVEY PROGRAM GLOBAL FILTER APPLIED: Afl w Lpatha within 200'+ 100/1000 of reference 33.70 To 16751.55 Ladder/S.F. Plots Depth Fhwn ol Depth0.00 CASING DETAILS 3370 M12 WPO50(M-12) 2�MWD+IFR2+MS+Sag TVD TVDSS MD Size Name 5090.00 16751.55 M-12 wpO5(M-12) 2_MWD+IFR2+MS+Sag 3968.70 3910.00 5088.89 9-5/8 95/8"x121/4" 4018.70 3960.00 16751.55 6-5/8 65/8"x81/2" wp0 n X150.00 __ �.�..-- __ — —. _ .:................_.. . w (__- M-13 Stonewall n' w 02 1) P i I V — 6120.00— co ., M-14 MCCIIan PfOtl) w 2 c o 90.00 - - _ p a _ 0N60.00---l.Slat 52= I�Cgh9JQ4r�..I r U 0 Slot 46 - Placeholder ,SII Woo - 0.00 000 000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 1900 Measured Depth (2000 usft/in) 4.50 t _-_ _.... O M3.00 LL C Collision Risk Procedures Req. 0 m a Collision Avoidance Rec. N No -Go Zone - Stop Drilling 0.00 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 15000 16500 18000 Measured Depth (2000 usf /in) TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: v Development Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: /yl/! � 1!0('? POOL: c G1i /�io�✓ La�`tfr [Cc 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 (Comnanv 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 the attached application, the following well logs are also required for this well: t t4C,W,v�t[cl�in ��4 �icdk� r- q y / Well Logging �v4 /> lsur /��tsLCm �Jcc44., oV (c 1/ Requirements SuJr�La t// i Lis;nl�r P'-„�/.�.j�j 2-rc_ 1-r�Lt�r� t .•Qkr��EL� Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 `A'' 3i 45 . WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT M-12 Program DEV Well bore seg ❑ PTD#:2181760 Company HILCORP ALASKA LLC Initial Class/Type DEV I PEND GeoArea 890_ Unit 118 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gasconforms to AS31.05.030(1.1.A),(y2.A-D) - - - - - - - - - - - - - - - - - - - - - - NA_ _ - - . - .. - - - . - - _ - - - - - - - ......... - - _ - _ - - - - _ - - - .................... _ - _ . 1 Permit fee attached . . . . . . .. . .... . ....... 2 Lease number appropriate-- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ _ Surface Location lies within AD1-0025514; Top Productive Interval lies. in ADLO388235;. - _ - - - . - - - . - . _ _ _ 3 Unique well. name and number - - - - - - - - - - - Yes Top Prod Int& TD lie within ADL0025515. 4 Well located in a defined pool - - - - - - - - Yes - Milne Point Schrader Bluff Oil Pool (525140), governed by CO 477, amended by CO 477,05_ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 .Well located proper distancek from drilling unit. boundary... - - - - Yes - - - CO 477.05 specifies: 'There are no restrictions as to well spacing except that no pay shall - .... 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - Yes - - _ - be opened in a well closer than. 500 feet from the exterior boundary of thek affected area." 7 Sufficient acreage available in. drilling unit. - ..... . ..... ....... .. Yes - - - - - Well bore conforms to spacing requirements 8 If deviated, is wellbore platincluded- - - - - Yes 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - 10 Operator has appropriate bond in force - .... Yes Appr Date 11 Permit can be issued without conservation order. - - - - . - - - - - - .... - _ Yes 12 Permit can be issued without administrativeapproval- - - - - Yes SFD 12/31/2018 ... ...... 13 Can permit be approved before 15-day. wait- .. . .... . .............. . . . . Yes - - - - - - - - - - - - - - - - - - - - 14 .Well located within area and strata authorized by. Injection Order # (put 10# in.cpmments) (For. NA--- - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells within 1/4-mile area of review identified (For service well only)- - - - - - - - - - - - - - NA.. 16 18 Pre-produced injector; duration of pre production less than 3 months(For service well only) . _ Conductor string.prgvided...................................... . . . NA. Yes - - . ... . . . . . . . - - - - - - 20" coductor set at 113 It - Engineering 19 Surface casingProtectsall known USDWs - - - NA - - - - - - - - - - - - - - - - ---------- - - - - - - - 20 CMT-vol adequate to circulate on conductor & sLuf_csg - - - - - - -- - - - - - - - - - - - - - - - - Yes - - - _ _ 9 5/8" surface casing will be fullycementedusing 2. stage system. E$ at 2500 ft.. .. . 21 CMT, vol adequate. to tie-in long string to surf csg. ........................... No. production section will have 6 5/8" preperfed liner. 22 CMT-will cover all known productive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes 23 Casing designs adequate for C, T, B &-permafrost - - - - - - - - - - - - - - - - - - - - - - --- - Yes - - - BTC supplied.. 24 Adequate tankage or reserve pit - - . . . . . . . .. . ..... . . . . ... . .. Yes ..... Rig has steel tanks,., all waste to approved disposal site. - - - - - 25 If a. re-drill, has -a 10-403 for abandonment been approved ..................... . NA... 26 Adequate wellbore separation proposed-- - - - - - - - - - - - - - - - - - - - - - - Yes- -------------- 27 If diverter required, does it meet regulations- - -- - - - - -- - - - - - - - - - - - Yes ..... rig, has 15".diverter... layout provided Appr Date 28 Drilling fluidprogram schematic & equip list adequate- . . ........... Yes - - - Max form pressure =_1739 psi (8.7 ppg EMW ) drilling with 8.9-9.5 ppg mud - - GLS 1/2/2019 29 BOPEs,.do they meet regulation . _ - _ - - - - - - _ - - - Yes - _ Doyon 14 has 5000 psi WP-DOPE, 30 DOPE-press rating appropriate; test to (put psig in comments)- - - - - - - - - - - Yes - - _ - MASP = 1349.psi Will.test DOPE to 3000 psi - - - - - - - - - - - - 31 Chokemanifoldcomplies w/API. RP-53 (May 84).. - - ... Yes 32 Work will occur without operation shutdown. - - - - - - _ _ _ - - - - - - _ - Yes - - - - - - - - - - - - - - - - - - - - - - - .. - ............ - - _ - - - - - - - - - - - - - - - - ........ - - - 33 Is presence of H2S gas probable _ - - - - _ - _ - _ - - - _ - Yes - 112S on-pad..., r' has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) _ __ _ _ _ _ _ _ _ _ _ _ _ NA _ 35 Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ Yes ....... None anticipated from drilling-of offset wells; however, rig will have. H2,S. sensors and alarms. Geology 36 Data, presented on potential overpressure zones .......................... Yes - ..... Operator's planned-mud weights appear sufficient to control. expected formation pressures. Operator. Appr Date 37 Seismic analysis of shallow gaszones- - - - - - - - - - - - - - - - - - - - - - - - - - - - NA - - will have onsite materials sufficient to build.active system to-1-ppg above highest anticipated mud - - - - - - - - - SFD 12/31/2018 38 Seabed condition survey (if off-shore) - - - - - - - - - - - - - ----- - - - NA - - - - weight. Some potential exists for encountering-gas hydrates belowpermafrostbase; mitigation 39 Contact name/phone for weekly progress reports. [exploratory only] -- - - - - - - - - - - - - --NA ... - measures discussed in "Anticipated Drilling Hazards"-section. Geologic Engineering Public Normal flow Jet pump requires SVS on IA outlet of wellhead. Variance is granted under 20 AAC25.265 (o)(1) Commissioner: Date: Commissio r: Date Commi r Date
