Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
217-092
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: Conductor Retrofit 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,262 NA Casing Collapse Conductor NA Surface 3,090psi Intermediate Production Liner 7,480psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5-1/2" x 2-7/8" PHL Hydraulic Retrievable Packer and NA 9,831' MD / 6,834' TVD NA 5-1/2" See Schematic 907-564-5005 ryan.thompson@hilcorp.com Wells Manager March 15, 2024 10,25910,259 2-7/8" 7,204 Perforation Depth MD (ft): See Schematic 16" 9-5/8" 140 7,015 NA 5,750psi 140 4,804 140 7,015 6.5 / L-80 TVD Burst 9,859' MD Hilcorp Alaska, LLC Length Size Proposed Pools: 7,207 10,133 7,095 1,480 KUPARUK RIVER OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047433, ADL0047434, ADL0047437 217-092 C.O. 432E MILNE PT UNIT C-45 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23579-00-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 10,640psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Ryan Thompson Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:46 pm, Feb 16, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.15 21:51:53 - 09'00' Taylor Wellman (2143) 10-404 DSR-2/16/24MGR23FEB2024SFD 2/23/2024 1,480 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.02.26 11:22:16 -09'00'02/26/24 RBDMS JSB 022724 Wellhead Retrofit Well: MPU C-45 Well Name:MPU C-45 API Number:50-029-23579-00 Current Status:Operable – RC JP Pad:C-Pad Estimated Start Date:3/15/2024 Rig:WSS Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:217-092 First Call Engineer:Ryan Thompson (907) 564-5005 (O) (907) 301-1240 (M) Second Call Engineer:Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) AFE Number:Job Type:Wellhead Repair Current Bottom Hole Pressure: 2,180 psi @ 7,000’ TVD SBHPS 9/15/2020, 6.0 PPGE MPSP: 1,480 psi (0.1 psi/ft gas gradient) Min ID: 2.205” ID 2 7/8” XN Nip at 9,876’ MD Max Dev: 54° @ 3,422’ Brief Well Summary: The Milne Point C-45 was drilled and cased as a Schrader Bluff production well in October 2017 & wellwork was performed in Sept 2020 to convert from a GL producer to JP producer. The well’s surface casing was fully cemented during drilling with a 2 stage cement job and hung off a slip style casing hanger as part of a conductor supported wellhead system. The system has since been identified as having the potential to cause wellhead movement in the event of conductor subsidence. In order to fully tie well load back to the single 9-5/8” casing string, the conductor will be cut and a reverse acting slip style hanger assembly will be installed. Notes Regarding Wellbore Condition x MIT-T passed to 3,500 psi on 9/28/2020. x MIT-IA passed to 3,500 psi on 9/28/2020. x Well is currently online and producing. Objective: Cut conductor bell nipple below starting head and install Seaboard Reverse Slip Loc assembly to ensure fully supported by surface casing. Procedure: Pre-Sundry Work Slickline & Fullbore 1. MIRU SL unit. 2. Pull 9A jet pump from 9,681’ MD. 3. Set plug in XN nipple @ 9,846’ MD. 4. Circulate PF into IA/T to fluid pack. 5. Pump 53 bbls Freeze Protect into IA & U-Tube. 6. CMIT-TxI to 3500 psi. 7. RDMO Prep Work 8. Disconnect flowline and instrumentation. 9. Verify tubing and IA pressures have been bled to 0 psi. Wellhead Retrofit Well: MPU C-45 10. Sniff cellar and adjacent area with multi-gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations. 11. Vac out gravel from well cellar down to cellar liner to remove residual hydrocarbons. 12. Install fire blankets around well to prevent hot debris from falling downhole. Sundry Work (Approval required to proceed) Surface Casing Support Retrofit – Note: Photo Document Repair Work on a Daily Project Timeline. 13. Sniff cellar and adjacent area with multi-gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations. 14. Flush conductor with water from the conductor starting head valve and while taking fluid returns from the cement return line bull plug. Flush with hot diesel until clean returns are observed. 15. Move in and rig up Well Support Structure. Place rig mats as needed to level out support structure legs. 16. Install BPV and nipple down tree at master valve or tubing head adapter as needed to makeup Wellhead Support Structure adapter flange. 17. Prepare to transfer load to the Well Support Structure. Pretension load cells according to operating manual. 18. Pull 8,000 lbs (Wellhead Weight) gradually building up load in 1,000 lb increments. a. Monitor the wellhead for any signs of movement and discontinue increasing tension if movement observed. 19. Increase weight up to 60,000 lbs (50 K preloading) 20. Once pre-loaded, begin cutting conductor horizontally at bottom of conductor bell nipple using air arc cutter. a. Monitor load on Well Support Structure in addition to wellhead vertical displacement during cutting operations. a. Maximum dry, 2 7/8” tubing, 5 ½” PC and wellhead load = 6.5#*9858’ + 17#*8508’ + 8K = 218K b. Maintain constant vertical displacement while well support structure is loaded by well. 21. Proceed to cut conductor bell nipple below the starting head and then remove conductor bell nipple section. a. Ensure minimum of 12” of clearance between bottom of starting head and top of conductor. b. Record Well Support Structure Load in WSR once conductor fully loaded. 22. Leave remaining bell nipple section engaged in starting head. Bevel as needed to ensure smooth entry of slip assembly. 23. Place each half of Reverse Slip Loc assembly around surface casing, bolt halves together. 24. Install energizing plate halves at 90 degree offset from slip assembly such that joint between halves are perpendicular to slips. 25. Lift Reverse Slip Loc up inside conductor starting head. 26. In a criss cross pattern, begin to tighten bolts on energizing plates initially to 50 ft-lbs on first pass then to a final torque of 100-125 ft-lbs on second pass. 27. Mark casing at the bottom of the Reverse Slip Loc 28. Release tension, observe for any slippage. If slipping occurs, retension and tighten bolts to 150 ft-lbs. 29. Once load is released to Reverse Slip Loc, conduct CMIT-TxI to 1,500 psi to confirm integrity is unchanged. 30. Unbolt and remove the adapter flange. 31. Reinstall 5K production tree. 32. Remove BPV and install TWC. Pressure test tree to 5,000 psi. 33. Re-install flowline and instrumentation. Wellhead Retrofit Well: MPU C-45 34. Weld centralizer/landing ring onto top of conductor. 35. Reinstall well house and backfill gravel over cellar liner. 36. Install Corrosion Inhibitor in SC by Conductor Annulus up to the conductor top. Slickline 37. MIRU SL unit. 38. RIH and pull plug from 9,846’ MD. 39. Set new JP (sizing per OE) in SS @ 9681’. 40. Turn well back over to operations. Attachments: 1. Wellbore Schematic Wellhead Retrofit Well: MPU C-45 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Convert to Jet Pump Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,262 feet 10,133 feet true vertical 7,207 feet N/A feet Effective Depth measured 10,133 feet 9,681 feet true vertical 7,095 feet 6,704 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 / EUE-8rd 9,859' 6,858' Packers and SSSV (type, measured and true vertical depth)PHL Hyd. Ret. N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8343 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 7,480psi Burst Surface Liner N/A 5,750psi 10,540psi 16" 9-5/8" 5-1/2" 4,804' 7,204' Junk measured Length 140' 7,015' 10,236' Tubing Pressure 305 N/A measured N/A Casing Conductor Size 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 260 Authorized Signature with date: Authorized Name: David Haakinson dhaakinson@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-092 50-029-23579-00-00 Plugs ADL047433, ADL047434 & ADL047437 5. Permit to Drill Number: Milne Point Field / Kuparuk River Oil Pool 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 31 Representative Daily Average Production or Injection Data 28539 MP C-45 Gas-Mcf 1,050 84 Oil-Bbl measured true vertical Packer 2,805 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 82 Casing Pressure WINJ WAG 140 Water-Bbl MD 140' 7,015' 10,259' TVD 140' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson 2020.11.18 18:13:44 -09'00' By Samantha Carlisle at 10:36 am, Nov 19, 2020 SFD 11/18/2020 RBDMS HEW 11/20/2020 DSR-11/23/2020MGR30NOV20 _____________________________________________________________________________________ Revised By: DAH 11/18/2020 SCHEMATIC Milne Point Unit Well: MPC-45 Last Completed: 11/7/2017 PTD: 217-092 TD =10,262’ (MD) / TD =7,207’(TVD) 1 Orig. KB Elev.: 41.3’/ GL Elev.: 14.8’ RKB – THF: 23.25’ (Innovation) 3 4 5 6 2 9-5/8” MIN ID= 2.205 @ 9,846’ MD PBTD =10,133’(MD) / PBTD =7,092’(TVD) Tag fill @ 9,997’ MD 5/23/19 Stage Tool @ 2,195’ MD 5-1/2” 16” 10 11 12 13 7 8 9 Kup C1 TOC @ 8,508’ MD USIT 10/21/17 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor 164 / A-106B / Weld N/A Surface 140’ 9-5/8” Surface 40/ L-80/ DWC/C 8.835 Surface 7,015’ 5-1/2" Intermediate 17 / P-110/ GeoConn 4.892 Surface 10,259’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE-8rd 2.441” Surface 9,859’ WELL INCLINATION DETAIL Max Hole Angle = 54° @ 3,423’ MD Hole Angle @ Perfs = 30° JEWELRY DETAIL No Depth ID Item GLM Detail – 2-7/8” Patco SPMO-1.0M w/ BK-2 latches 1 2,809’ 2.441”GLM 8:1” BK-DGLV – Set 9/20/2020 2 4,561’ 2.441”GLM 7:1” BK-DGLV – Set 9/19/2020 3 5,700’ 2.441”GLM 6:1” BK-DGLV – Set 9/19/2020 4 6,651’ 2.441”GLM 5:1” BK-DGLV – Set 9/17/2020 5 7,538’ 2.441”GLM 4:1” BK-DGLV – Set 9/17/2020 6 8,367’ 2.441”GLM 3:1” BK-DGLV – Set 9/16/2020 7 8,977’ 2.441”GLM 2:1” BK-DGLV – Set 9/17/2020 8 9,622’ 2.441”GLM 1:DGLV Set 11/07/17 9 9,681’ 2.313” HES XD DURASLEEVE SSD, X-profile w/ 2.5” 9A Jet pump 10 9,819’ 2.313” 2-7/8” X Nipple –Min ID 2.313” 11 9,831’ 2.360” 5-1/2” x 2-7/8” L-80 PHL Hydraulic Retrievable Packer 12 9,846’2.205”2-7/8” XN Nipple –Min ID 2.205” 13 9,858’ 2.441” 2-7/8” WLEG –Bottom @ 9,859’ OPEN HOLE / CEMENT DETAIL 9-5/8” 3,708 cu/ft 12-1/4” Hole 5-1/2" 431 cu/ft in 8-1/2” Hole GENERAL WELL INFO API: 50-029-23579-00-00 Drilled & Cased by Innovation – 10/18/2017 Perforated – 10/25/2017 Completed by ASR#1 – 11/7/2017 Convert to Jet Pump – 9/29/2020 PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF Kuparuk C-1 9,976’ 9,996’ 6,959’ 6,976’ 20 10/25/17 Open 3-3/8” 12 Reference Log: SLB USIT log dated 21-Oct-2017 / 3-3/8” SLB PowerFlow 3412, 12 SPF, 135°/45° WELL STIMULATION DETAIL Frac Well 10/27/2017 – 165,427 lbs Proppant estimated behind pipe Well Name Rig API Number Well Permit Number Start Date End Date MP C-45 Slick Line 50-029-23579-00-00 217-092 9/12/2020 11/11/2020 No operations to report. Hot Flush Tbg (SL work) (Prssure Test Surface lines 250/3,000 psi) Pump 5 bbls 60/40 and 30 bbls 180* Dsl down Tbg. WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/3,500H. ATTEMPT DRIFT WITH 5'x2" DRIVE DOWN BAILER (mule shoe ball) AND SD AT 1,320'-1,360' SLM (recovered ~1 cup of hydrates) LRS PUMP 5bbls 60/40 AND 30bbls HOT DIESEL. DRIFT TBG WITH 5'x2" DRIVE DOWN BAILER (mule shoe ball) TO 9,995' SLM/10,018' MD (23' KB correction, 22' rat hole). RDMO, CLOSE PERMIT W/PAD-OP 9/12/2020 - Saturday No operations to report. 9/15/2020 - Tuesday 9/13/2020 - Sunday No operations to report. 9/14/2020 - Monday 9/11/2020 - Friday No operations to report. 9/9/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/10/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-45 Slick Line 50-029-23579-00-00 217-092 9/12/2020 11/11/2020 No operations to report. WELL S/I ON ARRIVAL, NOTIFY PAD OP & FILL OUT PERMIT, PT PCE 200L/ 3,000H. PULL 1" BK-LGLV (1,253psi TRO) & SET 1" BK-DGLV IN STA #6 @ 5,679' SLM / 5,700' MD. PULL 1" BK-LGLV (1,282psi TRO) & SET 1" BK-DGLV IN STA #7 @ 4,541' SLM / 4,561' MD. 9/19/2020 - Saturday No operations to report. 9/22/2020 - Tuesday 9/20/2020 - Sunday WELL S/I ON ARRIVAL, NOTIFY PAD OP & FILL OUT PERMIT, PT PCE 200L/ 3,000H. PULL 1" BK-LGLV (1,317psi TRO) & SET 1" BK-DGLV IN STA #8 @ 2,789' SLM / 2,809' MD. RUN 2-7/8" 42BO POSITIONING TOOL (keys down to open) & SHIFT XD SSD DOWN @ 9,653' SLM / 9,681' MD, PIN NOT SHEARED. JOB COMPLETE, NOTIFY PAD-OP & LEAVE WELL S/I UPON DEPARTURE. 9/21/2020 - Monday 9/18/2020 - Friday No operations to report. 9/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, NOTIFY PAD OP & FILL OUT PERMIT, PT PCE 200L/ 3,000H. PULL 1" BK-LGLV (1,182psi TRO) & SET 1" BK-DGLV IN STA #3 @ 8,344' SLM / 8,367' MD. PULL 1" BK-LGLV (1204 TRO) FROM STA #4 @ 7,516' SLM / 7,538' MD. MAKE SEVERAL ATTEMPT TO PULL STA #5 @ 6,630' SLM / 6,651' MD. 9/17/2020 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD OP & FILL OUT PERMIT, PT PCE 200L/ 3,000H. PULL 1" BK-LGLV (1,228psi TRO) & SET 1" BK-DGLV IN STA #5 @ 6,631' SLM / 6,651' MD. SET 1" BK-DGLV IN STA #4 @ 7,516' SLM / 7,538' MD. SET 1" BK-DGLV IN STA #2 @ 8,954' SLM / 8,977' MD. 2-7/8" CAT STANDING VALVE STILL IN WELL @ XN-NIPPLE. NOTIFY PAD-OP TO WELL LEFT S/I UPON DEPARTURE. Well Name Rig API Number Well Permit Number Start Date End Date MP C-45 Slick Line 50-029-23579-00-00 217-092 9/12/2020 11/11/2020 9/25/2020 - Friday Circ well down IA up TBG w/return to production. (Pressure test RU. 293/2,430 psi) Pumped 165 bbls Source water down IA w/returns up TBG. Pumped 45 bbls diesel for IA freeze protect, gas in TBG unable to u-tube FP. Pump 15 bbls diesel down TBG. hang tags 9/23/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/24/2020 - Thursday No operations to report. WELL S/I ON ARRIVAL, PT PCE 200L/3,000. PULLED 2-7/8" CAT STANDING VLV @ 9827' SLM (9846' MD). TBG/IA BOTH LOST PRESSURE. SET 2.5" JET PUMP (sn# BP-1156, ratio=9X, oal lih=41") @ 9650' SLM (9681' MD). JOB COMPLETE, WELL LEFT S/I (STILL NEED PIPING ROUTED FOR POWER FLUID). WELL S/I ON ARRIVAL, PT PCE 200L/3,000H. MADE 1 ATTEMPT TO CLOSE XD SSD @ 9,650' SLM (9,681' MD). SHIFTING TOOL SHEARED. SSD STILL OPEN. 9/26/2020 - Saturday CONT. FROM 09/27/20 WSR, WELL S/I ON ARRIVAL, PT PCE 200L/4,200H. LRS PERFORMED PASSING MIT-T TO 3,500 PSI. SHIFT XD SSD OPEN W/ 2-7/8" 42BO SHIFTING TOOL @ 9,650' SLM (9,681' MD). PIN NOT SHEARED LRS CIRCULATED 10 BBLS CRESAL DOWN IA & UP TBG THRU XD SSD CONFIRMING SSD OPEN, IA & TBG TRACKED. 9/29/2020 - Tuesday 9/27/2020 - Sunday CONT. FROM 09/26/20 WSR, WELL S/I ON ARRIVAL, PT PCE 200L/3,000H. MADE TWO RUNS W/ 2-7/8" 42BO SHIFTING TOOL TO XD SSD @ 9650' SLM (9,681' MD). 2ND RUN PIN UNTOUCHED, XD SSD CLOSED. LRS ATTEMPTED MIT-T PUMPING ~100* CRESAL WHICH POSSIBLY CREATED THERMAL ISSUES, WILL LET FLUID SIT OVERNIGHT & RE-ATTEMPT MIT-T ON 09/28/20. 9/28/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-45 Slick Line 50-029-23579-00-00 217-092 9/12/2020 11/11/2020 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. USE ~12bbls PF TO PT TBG 1,500psi FOR 15min (pass, T/I after 15min 1,490/0). PULL 2.5" JET PUMP (serial# BP-1158, ratio: 7A, the 2 bottom pieces of packing blown out) FROM XD-SS AT 9,675' SLM/9,681' MD. SET ISOLATION SLEEVE (top/bottom packing stacks on sleeve are 2" wider apart than on jet pump) IN XD-SS AT 9,675' SLM/9,681' MD. USE PF AND ATTEMPT TO PT IA 1,500psi/3,500psi (fail, IA would bleed back to 0psi from 1,500psi in ~1min, attempt multible times). EQUALIZE ISOLATION SLEEVE FROM XD-SS AT 9,675' SLM/9,681' MD. L/D FOR THE NIGHT, NOTIFY PAD-OP. No operations to report. 10/10/2020 - Saturday No operations to report. 10/13/2020 - Tuesday 10/11/2020 - Sunday WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. PULL 2.5"" JET PUMP (serial# BP-1156, ratio: 9X, recovered all packing & pins) FROM XD-SS AT 9675' SLM/9681' MD. SET 2.5"" JET PUMP (serial# BP-1158, ratio: 7A, OAL=41"") IN XD-SS AT 9675' SLM/9681' MD. RDMO, TAG WELL & CLOSE PERMIT W/PAD-OP. 10/12/2020 - Monday 10/9/2020 - Friday No operations to report. 10/7/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/8/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-45 Slick Line 50-029-23579-00-00 217-092 9/12/2020 11/11/2020 No operations to report. No operations to report. 10/17/2020 - Saturday No operations to report. 10/20/2020 - Tuesday 10/18/2020 - Sunday No operations to report. 10/19/2020 - Monday 10/16/2020 - Friday No operations to report. 10/14/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. PULL ISOLATION SLEEVE FROM XD-SS AT 9,675' SLM/9681' MD (looks good, recovered all packing). CHANGE PACKING STACK MEASUREMENTS TO MATCH XD-SS DRAWING. TOP OF TOP PACKING STACK TO BOTTOM OF BOTTOM PACKING STACK 36.875", DRAWING CALLS FOR 36.996". SET ISOLATION SLEEVE IN XD-SS AT 9,675' SLM/9,681' MD. USE PF AND ATTEMPT TO PT IA 1,500psi/3,500psi (fail, IA would bleed back to 0psi from 1,500psi in ~2min, attempt multible times). PULL ISOLATION SLEEVE FROM XD-SS AT 9,675' SLM/9,681' MD (looks good, recovered all packing). RDMO, CLOSE PERMIT W/PAD. 10/15/2020 - Thursday Freeze Protect (SL work) (Pressure test surface lines 250/2,500psi) Pump 7 bbls 60/40 down Tbg. Pump 22 bbls 60/40 down IA. Well Name Rig API Number Well Permit Number Start Date End Date MP C-45 Slick Line 50-029-23579-00-00 217-092 9/12/2020 11/11/2020 10/23/2020 - Friday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/ 2,500H. PUMPED 10bbls OF 60/40 W/ TRIPLEX & ATTEMPTED TO PRESSURE UP IA, NEVER CAUGHT PRESSURE. PULLED ISO SLEEVE FROM XD SS @ 9,680' SLM (9,681' MD), ALL PACKING & PINS RECOVERED. SET 2-7/8" CAT STANDING VALVE (oal: 33") IN XN @ 9,845' SLM (9,846' MD). RAN 2.2" CENT, 3'x1-1/2" STEM, 2-7/8" 42BO (keys up) & SHIFTED XD SS @ 9,680' SLM (9,681' MD) CLOSED, 42BO PIN NOT SHEARED, PUMPED 10bbls 60/40 DOWN TUBING & PRESSURE IT UP TO 1500psi, WATCHED FOR 10min. TUBING HOLDS, IA REMAINED @ 0psi. RAN 2.2" CENT, 3'x1-1/2" STEM, 2-7/8" 42BO (keys down) & SHIFTED XD SS @ 9,680' SLM (9,681' MD) OPEN, 42BO PIN NOT SHEARED, SAW TUBING PRESSURE DROP 400psi. SET 2-7/8" ISO SLEEVE (38.5" from 90 on keys to bottom of lower packing stack, oal: 56") IN XD SS @ 9,680' SLM (9,681' MD), GOOD PULL TEST, SHEARED OFF CLEAN, ALL PINS ON X-LINE RECOVERED, LRS PRESSURED UP TUBING TO 1500psi, LOST 350psi IN 5min, PRESSURED TUBING BACK UP TO 1500psi, LOST 150psi IN 3min, IA REMAINED @ 0psi, LRS PUMPED TOTAL OF 7.5bbls DIESEL DURNING TEST. WELL S/I ON DEPARTURE, DSO NOTIFIED. 10/21/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/22/2020 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/ 2,500H. SET 2-7/8" ISO SLEEVE (38.5" from 90 on keys to bottom of lower packing stack, oal: 56") IN XD SS @ 9,680' SLM (9,681' MD), GOOD PULL TEST, SHEARED OFF CLEAN, ALL PINS ON X- LINE RECOVERED. PUMPED 50bbls 60/40 W/ TRIPLEX DOWN IA W/ OUT CATCHING PRESSURE. WELL S/I ON DEPARTURE, DSO NOTIFIED. No operations to report. WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/ 2,500H. PRESSURED UP TUBING W/ TRIPLEX TO 2,000psi, LOST 400psi IN 10min, PRESSURED BACK UP 3 TIMES W/ SAME RESULTS. PULLED 2-7/8" ISO SLEEVE FROM XD SS @ 9,680' SLM (9,681' MD), ALL PACKING & PINS RECOVERED, MISSING 1 2" PIECE OF ORING FROM UPPER PACKING STACK. SET 2-7/8" X-LOCK W/ 2-7/8" ISO SLEEVE (38.25" from 90 on keys to bottom of lower packing stack, 36.75" from 90 to top of lower stack, upper & lower stacks both have 6 pieces of packing w/ orings, oal: 56"), ALL PINS ON X-LINE RECOVERED. LRS PUMPED 17bbls CRIESEL DOWN IA & PRESSURED UP TO 2500psi FOR MIT-IA (pass), LOST 44psi IN FIRST 15min & 14psi THE SECOND. LRS PRESSURED UP TUBING TO 2000psi FOR T-MIT, LOST 122psi THE FIRST 15min & 52psi THE SECOND (pass), NO PRESSURE GAIN ON IA, BLED TUBING DOWN TO 800psi. PULLED 2-7/8" ISO SLEEVE FROM XD SS @ 9,680' SLM (9,681' MD), ALL PACKING & PINS RECOVERED. PULLED 2-7/8" CAT STANDING VALVE FROM XN @ 9,845' SLM (9,846' MD), ALL PACKING RECOVERED. WELL S/I ON DEPARTURE, DSO NOTIFIED. 10/24/2020 - Saturday No operations to report. 10/27/2020 - Tuesday 10/25/2020 - Sunday No operations to report. 10/26/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-45 Slick Line 50-029-23579-00-00 217-092 9/12/2020 11/11/2020 11/13/2020 - Friday No operations to report. 11/11/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. SET 2.5" JET PUMP (serial# BP-1156, ratio: 9A, OAL=50") IN XD-SS AT 9,679' SLM/ 9,681' MD. RDMO, TAG WELL & CLOSE PERMIT W/PAD-OP. 11/12/2020 - Thursday No operations to report. No operations to report. No operations to report. 11/14/2020 - Saturday No operations to report. 11/17/2020 - Tuesday 11/15/2020 - Sunday No operations to report. 11/16/2020 - Monday • • 1 O N - O c, _ O 6 J 15 NI o is Q w p N N > NN o O o a o') Z ,n Z N p � CV = 7= v + m NU u) 0 E D J .- E 0N N w • Io O6 m > > E o n " inw • n w vnd U c c Io m cEm m o mc 0 C •In 1 • ii: iL C N N CL LC C LL N LL ❑ O Cii it. LL WZ Z 0 ❑ >O 0 0 0 2 as O > ❑ > ❑ E • •I La m m in in in in in in in n. LLV VF V V 1 . VF V VF V V1- N a w Uo Uo cU U Co Uo Uo Uo Uo Uo p E g i-Q ❑ Q DQ D ❑ ❑ DQ DQ DQ ❑ Q DQ ❑Q J U-Q I a I a I a a a a I LL I a 1 a I a I d I 0 w c , aiU aU 6 ai aaiU aiO aiU aiU aiO aiO a) N , ❑WILLI LLI LLLLLLLI LLILILILaILLI LLUz E ct N W > > > > > > 0 W E c 'E >W C W C C C C W C W E >W C >W C W C W C L. o o 2❑I 2 I 2 I 2 2 2 2 , 2 I 2 I 2 I 2 I 2 U 0 0 r-- a)O 2rz i aUi tUi ami ami at atcc ami amfr i ami at at~ r` LL J -i co C� C� (5 (3 C� _ C� C� C7 _ U o J U W Q lo WOW W W Eo Do W ❑ W ❑ W ❑ lo Doc.' N O Q j U r N- n N- r r N- N- V OM/� y U N 0 0 0 0 0 0 0 0 0 0 0 0 N- li ( > N N N N N N N N N N N N N LU Q F o Ln LO LO 0 V) LO to to In 0 0 Etd re D W N N N N N N N N N",. N N N N Z W 0 U J U = _ s o d OV Z O _ Q CV Q S \ CL a o cc w F. (NI o >J 0m 0 Na co c ZI 70 .E r o coe- o� C0 CTS U) O N a m E Q t0 a U = U E• 0 w co c ° z ac z ° v Qa. U A r... ° u � a o Q C 0 N G ▪ N 0 d CO Z o Iw rnm D cL J 0 a a, o CO W m 6 ❑ ICC J Q Q a zl _i- 0 0 Q z o cL iu U p ' 0 E J a z 2 W c0 as o3 03 co c0 N c6 co as 03 co co o ~ y m m m m CD CD m CD CD CD CO CD CD h.0 I E 0 0000000o0000 N- D Z N m m CD CD CO CO m CD m CO CD CD rn 'm 'g a) rn o) .En .5) .0 .0 m m m o O z W ` '0 O O O ❑ 0 0 0 O O O ❑ ❑ 01 > 0 d ,_ N p) o p) p) O o CO m o 0 o p) o o ~ H .. U co E ccoo corN- corco co conN- W co co W W h Q z v c o cc = co m m co m m m m co m 0o co m a— 2 0 c p W oz N N N N N N N N N N N N N N Ce H .o is O < Os E To L. E O co Z W N w �LL 13 p O W 00 80 U �_ z J J 0 0 0 U U U U U 0 0 U 0 0 r6 E _ mo O o 0 C'! F w m .— a o 0 0 ❑ ❑ ❑ ❑ 0 0 0 0 0 0 d d c O J 3 J OFT W LU W W LU LU LU W LU LU W LU W • • co o9 , a , a -J Q UI UI, ❑ Q UI UI o N o o a a U H F 0 0 I- (7) 1- (7) 0 cn N 00 N 00 N,� W W a�1 oU) a(n aO F'-1 In U) O i N n o I c� 1 m I ❑ ❑ ❑ ❑ JZi5 ❑ ❑ J N Z F- 1 1 1- a Q Q ❑ a 0. 2 co' ❑ a a co U' a N y U) p U)r W WI I I 1D ID I o I D D O R O) OD J D J D 0 2 = Q O_ a n O.O a Ql O. n O) CC F N ❑ vI c Loi c v10• g g o o O o O o ❑ O O I _U) �;o ° c O O 20 2)3 20 2U o 0 _1 _1 U ❑ b Uo I m UI m 01..1 in in of r)I r)1 0 of CO I Ml 0 Ln1 w w m d Co da) v v ai I ai 0 ai 0 ui U I 0 o 0 "T c 2 > > 2 E U 0 Eo E' EW E-1 Uo UX UCC 0 I 0 Z id1 o n.1 o a10 I- F- ow c 01 c 01 as 2� 2 01 2 01 2d 2 ix a) a co ix Z Z 01 a2 c a)c To l01 Ic Ic 10 I OU UE o U OU� H H u o it �U LL›1 0 0 0U oU o}1 od _J _J _, L1 y I y I y 0 I 0 I O ct c) Oiil2 a�i1 2 a) = o w w QUI �� Nd �W o =UI Sa ±.(7) S W N 20 6 N ai 0 ai z z C/) o o m ai(7 hi o ai o hi 5 ai N d J J co a)o Coo mw- d O O -w -c!4) it a) Il I 0 ❑M ❑rn ❑-J LLO it in it o) LL �J it O N 0 00 -(-) 00 o n 2 2. 0 I 0 I 0 I 0 I Q 0 1 0 1 0 1 0 1< o O 0 •� E0 0 0 •cZ_ EZ_ �Z_ �Z_U � Z_ �Z_ Z_ EZ_U c w O` 4.1 d1 o Nc`i S 0< 2 Q N O Q N 2 Q i1 2< 2< 0 2 Q (q 2 Q �1 2 N' y UHF UHn UH o O UM -62A V m v2y -62,v, vet t2a VCU) UJI /\/ o0 .7 our,....O o U n n o _,(1).lo bJ o U)I J o tnl o-,-) 0�1 J 0�I J 0.....-1-1 00 LL J WON •o WON 'o WO N N Wim - WRQ WRQ W� W �� WRQ WRQ W� I WO 0 3 n n n n n n n n n n n n ISI /� y U O 0 0 N N o 0 0 N 0 0 o O 0 0 a. N N N N N N N N N LU «) U' in in U) in u•) in U) an �n Ln 0. r r r r (..•1 -C.: r C.-1 r r r -C-S-1 0 d• LU 0 J V = o Z • Q r. co O O in N MLO coM y m n ao n 0. • 0a. O c N N N n •:1- 2 O O O N 0 0 0 0 Oa O E N 0 0 J N Q a H � Y o 5� V N COan N W z o M a a) W m z ❑ Q J o LP Q Q ci ▪ V c c c c (0E 8 3 Z CO CO m m m N t m m m m m co m m a) (0 (0 (0 •o •o S-1,30 (0 (0 (0 @ co (0 (0 fC no 0 0 0 co co 0 0 ❑ ❑ ❑ 0 ❑ 0 ❑ N To To To I I co (o m m co m m co ca N- . ) rn 0) o o 'rn rn _rn 5) _rn 0) 0) _0) 0) G ❑ ❑ ❑ J J ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ N ❑ O) > 0 cooW W co CO 00 oO co co a0 00 00 co o co co co co ao co co co co co co co co co h co co co co co co co co co co co co co co FA N N N N N N N N N N N N N N N CI▪ 0 O O O C.) « 0 0 0 U U U 0 0 0 0 0 0 0 0 U E l Odd ❑ ❑ (0 ❑ Cr) 0 ❑ 0 0 0 0 0 0 0 0 a M W W W J J W W W W W W W W W '.. • • CO N o • v c'a Ni Ni NI NI ) E E E E E W Fs Z a m a m 0-No O y 0 a s a a d a� N a� N m a� w a� Q , M el O)• 0 a D a p• c1D ceO. w 2 OI OI OI a O N M N N N_ N O. ti) = m ti O D U O U D W o W D W U` O U @ V U t6 Oo 00 00 M U >, 0 MO a a 0 a a a a a 0 in 2 JI 2 0 )nlJI 010 0' J 2 0 2 0 2 o = % L.Ig 'Ct) La .lo .I - E w Qj v '6 JI V V V JI 1i V a) O a) O a) O a) p •v I ? I v I I v v 2 m �1 m o 0-I do a U M V) m m W m of dix Illy acr aix d4 0 L.L. E c 7 c - 7 1- c �1 c 0I c 0I c u..1 M 1 M I I I -0 I- Q N 0 N I U I N �% N +'- N w= N +- d U 1 I I Z U O U O U O U O I I I 7 I Z it c u_ U Ec e-U e• D iiOCe it Oa u_OCC u_0ce e•0 EU e-0 e-0 e-r > N VI y 0 U UI U O 0 d N N 71 N N O O N 71 N.N OI _U O U O V O U O U N F- i.„ J co U c U) U0I 2 0 2 VI -±- W w c mac mac coac 2UI 2VI 2 VI 2UI = U W 2 o m0.0 �o O m m 030-0 �a o �a o y o cfl co m c mus m mus c aim °� c uia 5 m E m m0 m aEi0 m E0 ai� aj� ui� ui•@ ai0 J ❑ 3 2�1 O C4 10 2 UI o c o c r ELT O O N OI 0 m1 0 O)N- 0 ( mI c rl E –coI c rl E –I c JI 0 d m 2W 1 2W`n1 2VI 2NI 2 I rn o er1 o eol o e°I o e�1 20 2° 20 . 20 oU rn ❑ F- U EL F- Var Vr V r Ur O Var Uar jar Var VN VN VN VN UC.) O V r J a) I _m 1 m a) a) r a) 10 m 1 a) 1 r a) 1% _m 0 a) 5 a) m o a)Q r 0 �/ (I)L010 ino 0 0 o u>o )no ' N �o 0 LL J WAN W VN WN ON WN N WAN WAN WAN WAN WO WO WO WO MO N V 03 r r r r r r r r r r r r a �, 0 s o 0 0 0 0 0 o s 0 0 0 0 0 N N N N N N N N N N N N N N re N r r r N r r r r r r r r r W o � 4 De+ V J J Z • O IIIN U) 7 V 7 V w _ oop N O Oo O M M M O O O < ar 3 v v v Cl. o .- o !r o v v v co G o 0 CO co co o 0 N rn rn v v v . al O ; EI U N 0 w 0 o r M —J < . ate. rw r 5 0 N /G� F N W Z SII M I- V/ W CO • 0 ICC Q C E Q Z o v) CO CO E 0 c c c z m U) 0 � — co co m as m a) m m m m m m m m m `m m co co as co co is 'O CO CO Cf0 CCO CO CO i0 73 'a a • N0 0 0 0 0 Ili CI 0 0 0 0 0 0 0 m)0 Cl)) N m m m m m 2 m m m m m m m m m 2 2 o_) 0) °_' °_' °_' 0) '0) °_) °_) °_) o) o) °_) Zs '°_) o 0 o ❑ ❑ ❑ ❑ ❑ J ❑ ❑ ❑ ❑ 5 ❑ ❑ ❑ ❑ J J N > N N N N N N M co co co M M co co co M R) O) Co CO CO Co CO CO CO CO CO CO Co co co co 0o 00 O) O Co co co co co co Co co co co co co co co Co co Co ✓ co co co Co co co co Co co co co Co co co Co Co co Y- N N N N N N N N N N N N N N N N N N = N O o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U 0 d ❑ ❑ 0 ❑ ❑ ❑ o ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ p 0 0 '. O. 2 w W w w w J w w w W w w w w w J J • i o I 0 0 oO ico C s 0 �� M Z >->- ›- I y N w N U O. III w O I n O Co t T c>7; in o • co I ✓ C LL °) < Lr. O ° 1 co o � Z ILL z s ° • E. 0 d Q vN `) 2 U ° ° m LL 0 0 -J J 1 N r' LL CQ Q W ° N VC:J Z = c E Zd /�/ V I co l a) c°) 2 Co G LL -1 -11 ° �_ O 1 • it D CO°° O... d ., m N a W zaS 40 c4) roe 0. r io ca i E I ill O y o a) vico J -J a) C.) r*-- f0 0) = p > N E J E co I II Zt ° N .2 U < ras ° ° 0) Cocc 1 J d c ° V E 2 0 U Ct. O NI a) 2 g N II ON z N E c 'I- (1) J } E 0 Q IN ° ° a V a CC)r ° o co E I o 5= Oin N to co c r G F- LO N d p to as a CO0 c a) E D0 3 E I t .0 n d 4) I N 16 O c d Cl) w co N n ° a)= Ca = p p c c oZ — J C — 16Q C — 11 1mn _ aI ik 6 O cOcoQ z L) o as E zI o 0. 'p zC N N ,N yO L0 O I.- r N N CO I RS �/ O c- o O p c.E O c 111o o OD n co w E a O aa)) 1 o)CL W �O N N N N c G CO N a, U O H• m V 0 w a) re C c o o a) Z Q o• =- o 2 Z c 0 c 0 v .' U O I r %) m d v°i '� a) t� L) E V O ° o 2 n m y E a0 O IL.p — LL E o ° E E E d a M w 3 i U LL 0 c� o 0 0 I 0 1110 21 7092 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 RECEIVED Tele: 907 777-8308 11 lenrlaark u,LTA, Fax: 907 777-8510 DATA LOGGED ris E-mail: snolan@hilcorp.com BENDER DEC 15 2017 DATE 12/05/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU C-45 Prints: GR-CCL PRESSURE-TEMP-GR-CCL ABG-DGR-EQR-ALD-CTN 2"/5"TVD ROP-ABG-DGR-EWR-ALD-CTN 2"/5" MD USIT-GR-CCL CEMENT EVALUATION REPORT CD 1: Halliburton MWD/LWD 2 8 8 7 9 MPU C-45 DATA CD 10/24/2017 6:57 PM File folder CD 2: Schlumberger USIT Report 2 8 8 8 0 Hilcorp_MPC-45_Processed USIT_210CT17_... 10/31/2017 5:32 PM File folder CD 3: Schlumberger USIT 2 8 8 8 1 Hilcorp MPC-45USIT 210CT17 FINAL 10/31/2017 5:18 PM File folder CD 4: Schlumberger Perf Record 2 8 8 8 2 Hilcorp_MPC-45_PERF_250CT17 FINAL 11/15/2017 1:30 PM File folder CD 5: Schlumberger Static Survey 2 8 8 8 3 Hilcorp MPC-45_PRESS TEMP_250CT17 FINAL 11/15/2017 1:24 PM File folde Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: va4 6 Date: V RECEIVED • STATE OF ALASKA 0 DEC 0 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION _p WELL COMPLETION OR RECOMPLETION REPORT AND & CG -1'a.Well Status: Oil 0' Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q , Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: 1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill NuiAer/ u h`ryp Hilcorp Alaska, LLC Aband.: 10/25/2017 , • 217-092/317-495/317-505 3.Address: 7. Date Spudded: 15.API Number: 1/4--) !v-4.r4 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 July 28,2017 50-029-23579-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 866'FSL,2351'FEL,Sec 10,T13N, R10E, UM,AK October 13,2017 MPU C-45 • Top of Productive Interval: 9. Ref Elevations: KB: 41.3' 17. Field/Pool(s): Milne Point Field 1902'FNL, 1817'FEL,Sec 14,T13N, R10E, UM,AK GL: 14.8' BF: 14.8' Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1999'FNL, 1727'FEL, Sec 14,T13N, R10E, UM,AK 10,133'MD/7,092'TVD (SHL)ADL047434/(TPH/BHL)ADL047437 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MDITVD: 19. DNR Approval Number: Surface: x- 558111 y- 6029147 Zone- 4 10,262'MD/7,207'TVD LONS 84-123 TPI: x- 563950 y- 6026427 Zone- 4 12.SSSV Depth MDITVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 564041 y- 6026331 Zone- 4 N/A 1,929'MD/1,674'TVD 5. Directional or Inclination Survey: Yes U (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 GR-CCL PRESSURE-TEMP-GR-CCL ABG-DGR-EQR-ALD-CTN 2"/5"TVD ROP-ABG-DGR-EWR-ALD-CTN 2"/5"MD USIT-GR-CCL CEMENT EVALUATION REPORT 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD �� FT. TOP BOTTOM TOP BOTTOM PULLED Std 16" 164# Al 06B Surface 140' Surface 140' Driven 9-5/8" 40# L-80 Surface 7,015' Surface 4803' 12-1/4" Stg 1 -915 sx/Stg 2-531 sx 224 bbls /I 5-1/2" 17# P-110 Surface 10,259 Surface 7204' 8-1/2" 375 sx 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 Perfd): 2-7/8" 9,859' 9,831'MD/6,834'TVD 9,976'-9,996'MD/6,959'-6,976'TVD 12 SPF,3-3/8", 10/25/17 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. (`r; Was hydraulic fracturing used during completion? Yes Q No ❑ / Per 20 AAC 25.283(i)(2)attach electronic and printed information L vl2-3 LII' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED - See Frac Focus Report-Attached** LA-- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 11/19/2017 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 11/28/2017 24 Test Period �♦336.8 268.9 172.4 N/A 798.4 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 223 1146 24-Hour Rate — 336.8 268.9 172.4 23 Form 1Q-407 Revised 017 OW ! /ohir CONTIN D N E 2 TO u.e,1•/e. Submit ORIGINIAL op1G'_ lab ll ILId ' l z���'(�7 . tie( RE3Dillf1S L'i DEC 0 6 2017 Lig • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored(MDFFVD, 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 ❑., Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1,929' 1,674' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval Kup C 9,976' 6,959' information, including reports, per 20 AAC 25.071. Ugnu 3,469' 2,630' Schrader 6,232' 4,333' HRZ 9,440' 6,496' KUP C 9,964' 6,948' KUP A 10,180' 7,136' Formation at total depth: KUP A 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys,Csg and Cmt Reports, Frac Focus. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdinger(c hilcorp.com Authorized Contact Phone: 777.8389 Signature: ��,u,,e Date: ! 20/7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only III • Milne Point Unit II SCHEMATIC Well: MPC-45 Last Completed: 11/7/2017 Hilcurp Alaska,LLC PTD: 217-092 Innovation KB 26.5 Above GL OPEN HOLE/CEMENT DETAIL 9-5/8" 3,708 cu/ft 12-1/4"Hole 16" ' ) 5-1/2" 431 cu/ft in 8-1/2"Hole WELL INCLINATION DETAIL Max Hole Angle=54'@ 3,423'MD 'StageTool.a`' ? CASING DETAIL @2,195' ;,:".';' �"'' MD '�� Drift Size Type Wt/Grade/Conn ID Top Btm -„,, 16" Conductor 164/A-106B/Weld N/A Surface 140' 9-5/8" Surface 40/L-80/DWC/C 8.835 Surface 7,015' 5-1/2" Intermediate 17/P-110/GeoConn 4.892 Surface 10,259' TUBING DETAIL 1 2-7/8" Tubing 6.5/L-80/EUE-8rd 2.441" Surface 9,859' JEWELRY DETAIL *, No Depth ID Item 2 ' 4, GLM Detail-2-7/8"Patco y • ` 1 2,809' 2.441" GLM 8:Port=12/64,1244tro,VLV= DOME {µ 2 4,561' 2.441" GLM 7:Port=12/64,1215tro,VLV= DOME 3 q ,µ0 3 5,700' 2.441" GLM 6:Port=20/64,VLV= Orifice r 9-5/8' ;= ?ole 4 6,651' 2.441" GLM 5:Patco-Dummy Valve Installed ')r l 5 7,538' 2.441" GLM 4: Patco-Dummy Valve Installed a 6 8,367' 2.441" GLM 3: Patco-Dummy Valve Installed 1 7 8,977' 2.441" GLM 2:Patco-Dummy Valve Installed 5 8 9,622' 2.441" GLM 1: Patco-Dummy Valve Installed 9 9,681' 2.313" DURASLEEVE SSD,Opens Down it 10 9,819' 2.313" 2-7/8"X Nipple 6 11 9,831' 2.360" 5-1/2"x 2-7/8" L-80 PHL Hydraulic Retrievable Packer 12 9,846' 2.205" 2-7/8"XN Nipple 13 9,858' 2.441" 2-7/8"WLEG-Bottom @ 9,859' PERFORATION DETAIL 8I Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size 9 Kuparuk 9,976' 9,996' 6,959' 6,976' 20 10/25/17 Open 3-3/8" IWIReference Log:SLB USIT log dated 21-Oct-2017 WELL STIMULATION DETAIL ; 10 Frac Well 10/27/2017-165,427 lbs Propant estimated behind pipe GENERAL WELL INFO MIN ID=2.205@ 11 API:50-029-23579-00-00 9,846'MD y 11 Drilled&Cased by Innovation-10/18/2017 Perforated -10/25/2017 Tag Frac Sand i" ix: :12 Completed by ASR#1-11/7/2017 @9,909'MD +z 13'' 11/12/2017-:y-' 5-1/2' 1,g ` TD=10,262'(MD)/TD=7,207'(TVD) PBTD=10,133'(MD)/PBTD=7,092'(TVD) Revised By:TDF 11/17/2017 410 i Hilcorp Energy Company Composite Report .n Well Name: MP C-45 Field: Milne Point County/State: ,Alaska I(LAT/LONG): evation(RKB): 26.7 API#: Spud Date: 7/28/2017 Job Name: 1710175D MPC-45 Drilling Contractor AFE#: AFE$: 0SON...A.....:.................:.s..1.'ks.^r............................::cf:::::::. ..>.;x:.::.::.;:.;:.;:.;: <:i:.:s:en:>x::,::tW:<::z:.:: :;: ::z>:<x: 7/26/2017 Well support finish up with C-46 tie in.Wait on wire line.Continue w/painting projects throughout rig.Wire in new receptacles for envirovac. Continue working on centrifuge feed pump.;Replumb pill pit#2 gun line.Fuel cold start generators.HAK electricians disconnect rig from hi-line power.;W/O wire line to finish up on C- 46,continue cleaning up from painting projects.Blow down water and steam.Disconnect utilities from interconnects.;Continue to R/D svc lines throughout rig . Roads and pads on location @ 21:00,shoot and level C-45,lay down herculite,set rig mats around C-45.;Rig electrician disconnect modules,start cold start generators.Secure stairways,Install motorshed jeep,jackup pipeshed.Install cross beam in cellar f/mob.Peak trucking on location @ 23:30 hrs.;Set wellhead behind well,install diverter tee.PJSM for rig move.Demob pipeshed,gen module,pits and catwalk. Stage on location. Demob sub off well C-47.;Line up and snot sub module over C-45. 7/2712017 Spot sub module over C-45.Spot pipe skate,pipe shed,pits and motor modules.R/U interconnects on same. Submit 24 hr notification to AOGCC for diverter test.;Set BOP on diverter tee.Start N/U diverter line.Spot envirovac and break room.PJSM,scope up derrick, bridal down,get air,water and steam circulating throughout rig. Put rig on hi-line power.;lnstall berm and set cuttings box in place.Install knife valve,install diverter line.Fill pill pit with water,circulate water thru surface equipment. Rig accepted @ 00:00 hrs.;lnstall 4"valves on conductor.Ready pipe shed for P/U 5"DP. Fill pits with 580 bbls 8.7 ppg spud mud. Complete derrick inspection.;Set spill containment and diverter warning signs in place.Install riser,drip pan and mousehole,R/U bleeder line.Test run mud pumps,charge and mix pumps.R/U tongs and rig floor equipment.;lnstall 12 3/8"ID wear bushing,function diverter,annular closed in 9 sec,knife valve opened in 4 sec. Work on rig acceptance checklist.;Drift and P/U total of 214 jts 5"drill pipe and rack in derrick,currently 35 stands racked back. Note:Tagged bttm @ 41'. 7/28/2017 Service top drive,inspect handling equipment and pipe skate.;Drift and P/U 34 jts 5"DS50 DP and rack in derrick.;Conduct diverter drill with a state witness by Mr.Adam Earl with AOGCC.Annular shut time 13 sec,Knife valve 6 sec Starting 3150 200 psi,12 Full pressure 40 sec N2 6 BTL @ 2280psi.;P/U 27 stands Drill Pipe&stand back.;Conduct diverter drill with rig and muster all hands on C pad. Good lessons learned. All hands accounted for in 8 min. Talk to all hands about how to get better.;Continue to P/U 5"Dp.P/U 107 stands total, Take initial gyro measurements on rig floor. P/U 9 stands 5"HWDP.;M/U motor&12.25 Varel bit on HWDP stand. Test lines to 3000 psi.Good.Break circulation,70 gpm,500 psi,possible plugged jets,shut off pump.;Pull 1 stand HWDP,pull mud motor,break off bit,found 5 plugged nozzles on bit,small pieces of gravel,clean same,M/U bit,RIH w/mud motor,M/U 1 std HWDP and top drive.;PJSM,break circulation,pump 500 gpm,900 psi,30 rpm,1k tq,1-2k wob,Cleanout 16"conductor f/41'to 166'jetting flowline.Circulate clean before connections.;Spud well, Drill 12 1/4"hole from 166'to 226'pumping 350 gpm,430 psi,30 rpm,1k tq.1-2k wob.Pull slow into conductor @ 161',open bleeder,pump 500 gpm,cleanup flowline. R/U Gyro.;Wash and ream to bttm 350 gpm,480 psi.Break out top drive,park @ 225',RIH with Gyro,check shot survey @ 179'(1.05 inc,333.54 az)100'(0.72 inc,326.41 az).;POOH on elevators f/225'to 161',pump 550 gpm 900 psi,Circulate until clean,POOH,rack 2 stds HWDP.;M/U BHA 1=12 1/4"varel PDC bit, 1.5 deg motor w/BSS,IBS,DMC,TF offset @267.89 deg.M/U RLL,TM,UBHO,download MWD data.Scribe UBHO to motor.M/U 2 NMFC,BN X0=153.97, M/U 1 sd HWDP.;RIH to 184',shallow test MWD,good.RIH to 211',Gyro survey,orient w/89 deg TF, pump 350 gpm,540 psi,Tag bttm @ 226'w/3'of fill.;Drill 12 1/4"hole f/226'to 461',350 gpm,560 psi,40 rpm,2.5k tq,4k wob,Stage pump up 50 gpm ea.std drilled to 500 gpm,1180 psi. Gyro survey every std.;PU/SO/ROT 60/57/56,avg rop 78.3 fph(235') Jet flowline thru bleeder @ connections and as needed. Start build @ 396',3 deg/100'.;Currently 0.18'below the line,1.7'left. 0.47 slide hrs,.61 rotate hrs.;POOH f/461'to 337'racking back 2 stands HWDP,RIH with jars/single HWDP and 1 std HWDP to 461';Hauled 57 bbls cuttings for total=57 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 150 bbls H2O from L-Pad for total=750 bbls;Hauled 0 bbls from B-Pad for total=0 bbls Daily losses 0 bbls to formation for total=0 bbls 7/29/2017 Drill Ahead 12.25 Hole F/461'T/955' 494'@ 82 FPH Avg 500 gpm 1500 Psi 5K WOB 60 RPM @ 4K tq On Flushing flow line through bleeder on connections Gyro survey every std. Sliding 2/3.;NA19 ppg in 9.3 out ECD 9.6. Start working on 9 5/8 Casing.;Drill Ahead 12.25 Hole F/955'T/1535' 580'@ 96.6 FPH Avg 500 gpm 1500 Psi 5K WOB 60 RPM @ 4K tq On.;Drill Ahead 12.25 Hole F/1535'T/2272' 737'(123 FPH Avg)225 FPH on bttm 500 gpm 1600 Psi 10-15K WOB 60 RPM @ 5K tq On MW in/out 9.2 vis 180 ECD 10.21 PU/SO/ROT 97/78/64.;Pump 30 bbl hi vis sweep @ 1709',back on time,250%increase,mostly sand/clay.Pump 20 bbl hi vis sweep @ 2150',back on time,50%increase. Note:top of permafrost @ 1932'MD,1675'TVD EOB 1662';Drill Ahead 12.25 Hole F/2272'T/3090' 818'(136FPH Avg)237.7 FPH on bttm 500 gpm 1650 Psi 3-8K WOB 60 RPM @ 8.5K tq On MW in/out 92+vis 139 ECD 10.23 PU/SO/ROT 108/73/88.;Pump 20 bbl hi vis sweep @ 2600',strung out at returns w/100%increase,mostly sand/clay.Currently 9.82' above the line,8.97'right.5.47 slide hrs,6.41 rotate hrs.;Hauled 855 bbls cuttings for total=912 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 1000 bbls H2O from L-Pad for total=1750 bbls;Hauled 0 bbls from B-Pad for total=0 bbls rlailu inccac n hhic fn fnrmatinn fru.Intal c n hhls i • • 7/30/2017 Drill Ahead 12.25 Hole F/3090'T/ 3719' 629'(104FPH Avg) 200 FPH on bttm 550 gpm 2130 Psi 3-8K WOB 60-80 RPM @ 8.5K tq On MW in 9.1 vis 139 ECD 9.7 PU/SO/ROT 121/83/98.;Pumped sweeps at 3470' with 50%increase & 3600'@ 100%increase.Both back on time.;Drill Ahead 12.25 Hole Fl 3719' T/ 4414' 695(115FPH Avg) 225 FPH on bttm 575 gpm 2300 Psi 8-11K WOB 80 RPM @ 12.5K tq OnMW in 9.1 vis 139 ECD 9.9 PU/SO/ROT 142/84/104.;Pumped sweeps at 4160' with 100%Increase.on time.Continue working on 9 5/8 Casing.;Drill Ahead 12.25 Hole F/4414'T/ 4977' 563'(94 FPH Avg) 182 FPH on bttm 575 gpm 2350 Psi 8-10K WOB 80 RPM @ 14K tq On MW in 9.1+vis 140 ECD 10.01 PU/SO/ROT 157/89/110.;Pump 20 bbl hi vis sweep @ 4600',sweep back 2000 stks early,200%increase mostly clay.;Drill Ahead 12.25 Hole F/4977'T/ 5606' 629'(104.8 FPH Avg) 166 FPH on bttm 575 gpm 2400 Psi 7-10K WOB 80 RPM @ 15.5K tq On MW in 9.2 vis 97 ECD 9.89 PU/SO/ROT 168/89/120.;Pump 20 bbl hi vis sweep @ 5100',sweep back 1000 stks early,100%increase,sand,silt.At 5480'seeing oil at shakers Currently 0.13'above the line,23.07'right 2.07 slide hrs,11.84 rotate hrs.;Hauled 1484 bbls cuttings for total=2396 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 1800 bbls H2O from L-Pad for total=3550 bbls;Hauled 0 bbls from B-Pad for total=0 bbls flailu Inccac n hhlc to fnrmatinn fnr Intal=(1 hhlc 7/31/2017 Drill Ahead 12.25 Hole F/5606'T/ 5920' 314'(52 FPH Avg) 73 FPH on bttm 575 gpm 2400 Psi 15-20K WOB 80 RPM @ 19K tq On MW in 9.3 vis 97 ECD 10 PU/SO/ROT 179/91/24.;Pumped 20 bbl hi vis sweep @ 5775',on time w/50%increase.;Drill Ahead 12.25 Hole F/5920'T/ 6235 315'(52.5 FPH Avg) 79 FPH on bttm 575 gpm 2400 Psi 15-20K WOB 80 RPM @ 20K tq On MW in 9.1+vis 77 ECD 9.6 PU/SO/ROT 193/92/130.;Drill Ahead 12.25 Hole F/6235 TI 6642' 407'(67.8 FPH Avg) 196.6 FPH on bttm 575 gpm 2450 Psi 10-17K WOB 80 RPM @ 21K tq On MW in 9.1+vis 80 ECD 9.8 PU/SO/ROT 204/94/132.;Pump 20 bbl hi vis sweep @ 6365,back on time,no increase.Note:6510'gas peaked @ 932u,no flow increase.C/O swab on#1 MP,#1 swab.;Drill Ahead 12.25 Hole F/6642'T/7020'@ TD 378'(75.6 FPH Avg) 126 FPH on bttm 575 gpm 2650 Psi 14-17K WOB 80 RPM @ 22K tq On MW in 9.3 vis 80 ECD 10.07 PU/SO/ROT 206/95/135.;Note:TD surface hole section in heavy clay an per Hilcoro Geo, 0 7020'MD.4806'TVD 7.19'below the line, 6.36'right 6 slide hrs,7.83 rotate hrs.;L/D top single,take final survey,Circulate and condition,pump 20 bbl hi vis sweep around,575 gpm,2450 psi reciprocate )6) �N `and rotate 80 rpm.;Hauled 1026 bbls cuttings for total=3422 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls - Hauled 1050 bbls H2O from L-Pad for total=4600 bbls;Hauled 0 bbls from B-Pad for total=0 bbls Daily losses 0 bbls to formation for total=0 bbls 8/1/2017 Circ hole clean 575 gpm/2400 psi,80 rpm/20k,Recip full stand to 6960'.Rack back 1 std,CBU w/same parameters,Recip full stand to 6895'.PUW 208K,SOW 98K,RWT 137K.Sweep back on time.;Monitor Well for 10 min.Well Static.LID 1 single,pump OOH f/6930'to 6867',500 gpm/1800 psi,208K PUW,98K SOW.;Observed shot pin failure on Top Drive Handler Lock/Back up Grabber Interlock,not allowing TD to be made up to Drill String.Circ 2 bpm/200 psi,working pipe as practical with TD repairs.;lnvestigate TD Shot pin hyd system.Found broken snap ring keeping shot pin bushing in housing.Remove shot pin assy and replace snap ring.Reinstall Same and test good.;Wash down from 6867,to 7020',500 gpm/2000 psi,tag bottom with no fill.Flow check well,static.PU/SO/ROT 210/97/137.;Orient TF to hi side,Pump OOH 525 gpm,2000 psi f/7020'to 6474'with 15k over pull,back ream 30 rpm f/6474'6443',continue to Pump out f/ 6443'to 4995'ECDs gradually climbing f/9.76 to 10.14.;Pump 20 bbl hi vis sweep aroung pumping 600 gpm,2200 psi,80 rpm,P/U string slowly f/4995'to 4896',sweep back 200 sks early,100%increase.Lower ECD to 9.9.;Orient TF to hi side,Pump OOH 525 gpm,1900 psi f/4896'to 3200'with no other issues.;Hauled 570 bbls cuttings for total=3992 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 900 bbls H2O from L-Pad for total=5500 bbls;Hauled 0 bbls from B-Pad for total=0 bbls naily Inceae n hhlc to fnrmafinn fnr total=(1 hhlc 8/2/2017 Continue to Pump OOH from 3313'to 3062'.575 gpm/1950 psi,125K PUW/75K SOW;Observed ECD @ 10.2.CBU fom 3062'@ 575 gpm/1920 psi,pulling pipe slowly f/3062'to 2995'.ECD down to 9.8 @ BUS.;Continue to Pump OOH f/3062'to 1303',575 gpm/2000-1780 psi.87K PUW/72K SOW.ECD's @ 10.6. CBU f/1303'.ECD down to 9.7.Continue to Pump OOH to 500'.Lower Flow rate to 200 gpm f/500'to BHA.;(POOH on elevators from 1773'-1710'Observe Swabbing)(Attempt to POOH on elevators from 500'with swab and over pull.Pump OOH from 500'-400'@ 200 gpm.);PJSM on lay down BHA.Monitor well with 2 bph loss rate.;Stand back HWDP,L/D NMFC's to 89';Plug In and Down Load MWD,PJSM w/on coming crew for handling BHA.;L/D remaining directional tools,mud motor and bit,bit grade=516/CT/A/N/I/ER/TD;Clear and clean rig floor,load tools out,drain stack,pull 12 3/8"ID wear bushing. Monitor well with trip tank,static loss rate 1.5 bph;PJSM,load tools to rig floor,R/U Volant tool,Torq to 38k,R/U fill up line,power tongs and handling equipment. Monitor well,static loss rate remains 1.5 bph;PJSM,with crew,tong operator,TP and DSM,Inspect,Bakerlock and M/U shoe track,HES rep inspect and witness M/U of BA,ensure proper float operation. Tq to optimum @ 32500 ft/Ibs.;Note:Shoe jt install 1 centralizer 10'f/ea.end over stop ring,install 1 centralizer mid tube over stop ring on flt collar and baffle adaptor jts.;P/U and RIH w/DWC/C 9.625",40#,L-80 casing per tally,utilize dog collar clamp on 1st 10 jts ran,use BOL 2000 thread dope,fill on the fly,break circulation every 15 jts.;lnstall centralizer over collar every other jt to jt#22,RIH to 1307'(32 jts ran) Loss rate continues 1.5-2 bph while RIH.;;Hauled 699 bbls cuttings for total=4691 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 850 bbls H2O from L-Pad for total=6350 bbls;Hauled 0 bbls from B-Pad for total=0 bbls Daily losses 9 bbls to formation for total=9 bbls 8/3/2017 Continue to run 9 5/8 Casino from 1361'to 2066'.Tq connections to 32K.Fill pipe on fly,topping off every 5 jts,Loss rate @ 2.25 bph while running casing.;Establish circulation staging up to 4 BPM/110 ICP-70 FCP.Observed increase of cuttings at shakers.Circulate BUS.Lost 5.5 bbl on circulation.;Continue 5r un casing from 2066'to 3920';Establish circulation staging up to 4 BPM/100 psi.Circulate BUS.Lost 5.8 bbl on circulation.;Continue to run 9 5/8 Casing from \ 3920'to 5118'.Tq connections to 32K.Fill pipe on fly,topping off every 5 jts,Break circ every 15 jts. Loss rate @ 2.25 bph while running casing.;Continue to run ` 9 5/8"casing from 5118'to 6907',wash last 3 jts down staging pump 2 bpm,ICP 290 psi,FCP 6 bpm,170 psi.tag bttm @ 7030'MD per casing tally. PU/SO 305/125;Note:tagged 10'deeper versus DP tally TD @ 7020' Note:total losses running casing=42.4 bbls R/U cementers;Circulate and condition pumping 6 bpm,170 psi,reciprocate pipe slow 15'from 7025'to 7015'with no losses. PJSM w/cementers,rig crew,DSM and Tool pusher.;R/D power tongs and elevators.R/U circulating hose.Close upper and lower IBOP,Pump 5 bpm,380 psi. ,1i4%' . Shut down pump.;Pump 1st stage CMT:With cementers,pump 5 bbls water,pressure test lines to 800 psi low,4000 psi. Pump 54 bbls 10.5 ppg tunned spacer with red dye. Drop bypass plug.;Mix and pump 700 sxs(304 bbls)Extenda Cern Lead Cement at 11.7 ppg. '5 Mix and pump 215 sxs(43.2 bbls)Swift CemTail Cement at 15.8 ppg. t �r Drop Shut off Plug.;Displace cmt w/20 bbls FW ft Cmt Unit Z.iii 1 al ( 00 Rig Pump 295.7 bbls,9.5 ppg mud Cmt Unit 80 bbls FW Currently pumpng 80 bbls FW displacement from Cmt Unit.;Hauled 114 bbls cuttings for total=4805 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 300 bbls H2O from L-Pad for total=6650 bbls;Hauled 0 bbls from B-Pad for total=0 bbls Daily losses 42.4 bbls to formation for total=51.4 bbls • 8/4/2017 Continue pump Displacement w/80 bbls water f/Cmt Unit @ 3 bpm,320 ICP, 610 FCP Rig pump 128.4 bbls 9.4+ppg mud,3 bpm 640 ICP,FCP 825 psi @ 2 bpm,. Bump plug 500 psi over FCP to 1325 psi.;1 st Stage Details: Total Displacement 525 bbls(1.8 bbl over) CIP @ 07:55 hrs. Lost 22 bbls during displacement. Pump Cement @ 5.5 BPM Average.;Pump Disp @ 3 BPM Average.Calculated Disp 523.3 bbl,Actual Disp 525.1 bbl. FCP 825 psi @ 2 BPM. 13 Bump plug 500 psi over FCP to 1350 psi. D a Floats held.:Using ria pump.stage pressure up 3000 psi to open ES Cementer. CBU through Stage tool staging up to 5 bpm,bringing all of spacer and 78 bbls green CMT to surface.Over boarded Total of 181 bbls.;Shut down pumping. Disconnect knife valve. Flush stack and work annular with"Black Water". Circulate"Black Water"through flow line jets and all surface lines.;Continue to circulate through Stage tool @ 2200'@ 4 bpm/140 psi while prepping for 2nd stage Cmt.;PJSM on Pumping 2nd Stage Cement.;Pump 2nd stage CMT: Pump 55 bbls 10.5 ppg tunned spacer with red dye. Mix and pump 351 sxs(297 bbls)Permafrost"L"Lead Cement at 10.7 ppg;Saw trace spacer 190 bbls lead pumped.Overboard returns @ 210 bbl. Lead cmt @ surface 280 bbls pumped. Shut down and swap to tail. 5er Mix and pump 180 sxs(39 bbls)slurry Tail cement at 15.8 ppg.;Shut Down,load closing plug.HES pumped 20 bbls H2O.Shut down.Turnover to rig Rig Pump 147.8 bbls 9.5 ppg mud. Land Closing Plug.Shift Tool Closed @ 1350 psi.;Hold 1850 psi/5 min,bleed down w/no flow.CIP @ 18:45 hrs;2nd Stage Details: Lost 21 bbls pumping cement. Pump Cement @ 6 BPM Average. Pump Disp @ 6 BPM Average.Calculated Disp 167.8 bbl,Actual Disp 167.8 bbl.;FCP 490 psi @ 2 BPM.Bump plug 500 psi over FCP to 990 psi. Over board 224 bbls Cement.;Drain stack,flush surface equipment with black water.Blow down cement lines,RID same.R/D Volant tool.R/U 9 5/8"handling equipment.;R/D outer diverter line,pull mouse hole,remove drip pan,unsecure stack and hoist up same.Install 9 5/8"E-Slips per wellhead rep w/275k set on slips.Rough cut casing,LID same.31.55;Set down-4 bolt and secure BOP, jet stack,pull flowline inspection covers and clean flowline.;N/D diverter system, pull riser,R/D knife valve,Tee and diverter pipe.remove diverter tee from cellar,vac out cellar box. Continue to clean in pits.;Cut off and dress 9 5/8"casing stub(total cut jt 31.90')install 7"x 11"5m multi bowl and flange up same.Install packing per wellhead rep,currently testing void to 500/3780 psi 5/15 min ea.;Hauled 1454 bbls cuttings for total=6259 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 600 bbls H2O from L-Pad for total=7250 bbls;Hauled 0 bbls from B-Pad for total=0 bbls Daily losses 43 bbls to formation for total=94.4 bbls 8/5/2017 Continue to N/U BOP and associated Eauioment.Continue cleaning pits.;Rig up BOPE test equipment.Build 5"test jt.Flood stack and Choke Manifold.;Test Bope as per AOGCC on 5"and 4.5"pipe size.Test Gas alarms and PVT System.Test Accumulator Start 3000,After close 1550,200 psi build 21 sec.Full 75 Sec. N2 6 @ 2305 psi average.;R/D Test Equipment.Blow down choke manifold and lines,Install 10"ID wear bushing,RI4LDS.;Service rig;P/U Clean Out BHA with VM-1 RR Tricone Bit wino jets.17 jts HWDP/Jar.Total length=555.96;TIH with 5"DP from Derrick.Tag soft cement @ 2180'.Wash down and tag hard @ 2205.;Drill ESCMTR @ 2205',5 bpm/115 psi,40-60 rpm/4-7K Tq,5-12 WOB.Make dry pass with no issues.;Continue to TIH from 2206'to 4670',fill drill pipe. RIH to 6773',wash 5 bpm,590 psi f/6773;to 6873'tag soft cmt,wash to 6878'w/20k set down hard cmt Correct displacement on TIH PU/SO 230/81;Pump 40 bbl hi vis seawater spacer,Displace well from 9.4 spud mud to 8.5 ppg seawter pumping 6 bpm,660 psi,reciprocate and rotate 60 rpm. FCP 160 psi;Close annular,line up kill line and circulate thru choke,test 9 5/8"casing to 3000 psi f/30 min charted.Good test,bleed off pressure,open annular. Pumped 6.2 bbls/bled back 6.2 bbls;Flowcheck well,static.POOH LID 5"drill pipe f/6868'to 1600' Correct displacement TOH;;Hauled 753 bbls cuttings for total=7012 bbls Hauled 0 bbls H2O from 6 mile lake for total=0 bbls Hauled 150 bbls H2O from L-Pad for total=7400 bbls;Hauled 0 bbls from B-Pad for total=0 bbls Daily losses 0 bbls to formation for total=94.4 bbls 8/6/2017 Continue to POOH L/D 5"DP f/1622'to HWDP @ 555'.TIH with remaing DP in Derrick.POOH and L/D Same.;L/D HWDP/Jar/Bumper Sub.Break bit,bit sub. L/D same.;Pull Wear bushing.Clear floor of Misc handling tools.Prep to PU 7"casing.;Clear floor of Misc handling tools.R/U 7"Handling equipment.;PU and run 3 jts+Mule shoe jt of 7"HTTC Casing.MU 7"mandrel hgr and Land out @ 173.64'.Back out landing Jt.;MU Running tool&Pack off.Land Pack off,RILDS, Test to 500/5000 psi for 5/15 minutes.LD Landing Jt.;RU to run 4 1/2",13.5#,L-80,Hydril 625 Kill String.;Run in hole PU 4 1/2",13.5#,L-80,Hydril 625 Kill String from surface to 2995'.;MU Tubina Har and Landina Joint.Land mule shoe @ 3105'.65K PI IW_55K SOW.Land with 20K on Tbg Hgr.RILDS.L/D landing jt.Install TWC;Bleed off accumulator,pull bell nipple,disconnect accumulator lines.R/D service lines,unflange,remove stack and DSA,rack BOP stack back.;N/U dry hole tree.Test tree to 5000 psi,good test.Remove TWC.;R/U LRS and freeze protect well w/208 bbls diesel(3000'+/-). Pump down TBG taking retu s back thru OA @ 2 BPM,250 psi. U-tube diesel. R/D lines and clean out cellar box.install BPV.;Remove bails,R/D rig tongs,clear t1 floor.Pin tong wt buNts.Cleanout degasser.Service crown drwks and top drive.Flush choke manifold and lines w/fresh water;Pressure wash derrick and t.y drive. R/D flow shock and jumper hoses from pits to mezzanine.Cleanout cuttings box.Open and inspect both mud pumps.Clean in cellar;Rig releas-±t -m C-45 @ (2: 1/4�( 6:00;Hauled,518 bbls cuttings for total=7530 bbls U Hauled 0 bbls H2O from 6 mile lake for total 0 bblsAo eV '&. Hauled 0 bbls H2O from L-Pad for total=7400 bbls;Hauled 0 bbls from B-Pad for total=0 bbls Daily losses 0 bbls to formation for total=94.4 bbls 0 10/6/2017 R/U remaining pipe handling equipment in pipeshed. Test run same(good). Put rig on Hi-line power @ 09:00 hrs. Plumb in arctic package for TDS. Re-install lube pump and purge TDS.;Complete boiler#1.Flood#1 boiler and stage up to temp and psi throughout day.R/U flow line,mud line,and choke lines.Install shed roof handrails and lights. R/U derrick climber&Geronimo llne.;R/U remaining utility lines. Install misc mod cushions. Spot break room and hook up same. Prep#2 boiler for water.;R/U and troubleshoot hydraulic to TDS(swap hoses around and fixed issues).Spot cuttings box and kill tank. Perform derrick inspection (good). Continue staging up boiler#1.;Charge steam,water and air system throughout rig. Finish rigging up TDS. Tq all connections on upper/lower IBOP and saver sub. Install tq clamps and safety wire same.;Replace bolts on handling equipment in pipeshed with new hardware. N/U koomey lines to BOP stack. General housekeeping.;Continue rigging up koomey lines. Charge koomey. Continue rigging up TDS. Install bails,elevators,link tilt and adjust same. Adjust Kelly hose. Function test equipment(good).;Finish service/inspection#2 boiler. Psi wash and organize pipeshed from truck move. Prep pits to take on fluid. • • 10/7/2017 Modify bell nipple and install.Install mouse hole.Calibrate gas alarms.Install outer shed section covers.Pull BPV/Set TWC.CIO Boiler#1 Fuel Pump electric motor. Rig Accepted @ 06:00 hrs,10/7/17;Prep for BOPE Test.PU Misc handling equipment.Install tong weights.Finish R/U tongs.;RU to test BOPE.Build 5"Test Joint.Thread into Hanger.Flood Stack/Choke Manifold;Test BOPE as per AOGCC to 250/4000 psi.Test witnessed by Guy Cook.Test Gas Alarms.Test Bag, TPR,CMV's 1-15,TIW,Dart,Man IBOP,OuterMan HCR Kills,Blinds.;Manual Choke with no issues.Attempt to obtain test on LPR,Upper IBOP&super choke with no success. Note:Start load and process DS-50 DP.;Rig service. Rebuild super choke(found heavily worn Teflon seal in bonnet for disc plate). Move upper VBR's to lower gate and install fixed body 4.5"rams in upper gate due to damaged lower rams.;Replace failed upper IBOP with new rebuild. Install tq clamps and safety wire same.;Make up 4.5"test joint with donut. M/U XO and pump in sub. Mark jt for LPR/UPR. Flood BOP equipment and purge air. Obtain good body test on equipment.;Re-test super choke 250/1500 psi(good). Re-test#1 LPR(VBRs),Upper IBOP. Test#2-LPR(vbr's),lower IBOP. Test#3-UPR w/4.5"fixed body rams(failed),Retest UPR(failed);Test#4-Annular,HCR choke. Test#5-Annular,Manual choke. 10/8/2017 Continue test BOP on 4 1/2"test Joint to 250/4000'against TWC.all test good.Accumulator Test:Start 3072 psi,After closure:1550 psi,200 psi attained:20 sec,Full 78 sec.;Nitgn Bottles:6 @ 2292 psi.;R/D Test Equipment.Break down Test Jt.;Service Rig;Pull TWC.Rig up circulating lines from IA to Kill Tank.PT Mud Line to 2500 psi.;Close Blinds,Pump down tubing taking returns through IA,displacing DSL with Sea Water.Pumped 250 bbls SW.Open Blinds.;M/U landing joint to Hanger.RU Weatherford 4 W Handling equipment.BOLDS,unseat tbg hgr w/66K.BOLDS,pull and UD Tbg Hgr.;POOH laying down 73 jts 4'/" Tbg.;R/D 4%"and RU 7"handling equipment.;Grab 7"Landing Jt,BOLDS, Pull Pack off. Engage Csg hgr,pull and UD 4 jts 7"casing.R/D Csg handling equipment;Bleed down Koomey,CIO UPR to 5"Solid Body.Build 5"Test Jt.Land test plug. Flood equipment and purge air. Test upper/lower rams w/5"test jt. 250/4000 psi w/5 min hold each. Chart and record;R/D test jt. Install 10"ID wear bushing. B/D BOP equipment and lineup for drilling operations. Svc choke. Calibrate load cell,4'tongs and TDS.;Make up 5"mule shoe. RIH w/5",DS-50,19.5#,S-135 drill pipe picking up singles from surface to 1575'MD @ midnight. 2.85"drift.;Continue single in F/1575'-T/4094'MD. 2.85"drift.(130 jts total).;POOH racking back 5"DS-50 drill pipe F/4094'-T/surface.;Hauled 500 bbls to MP G&I for total=500 bbls RCP drill whiles frinninn!Af r1d•15 w/5R cars 10/9/2017 MU BHA#3:RSS w/NOV SK616M-J1 D Bit Geo Pilot,MWD Tools,2 NMFC,6 jt HWDP,Up Jar/Bumper sub,11 jts HWDP.Total BHA=719.11';TIH picking up 5"DS-50 DP to 3522';Fill Pipe,break in Geo Pilot Seals as per Sperry.Test MWD Tools.Test good.;Continue TIH picking up DP from 3522'to 6816'MU top Drive.;Break Circulation.400 gpm/930 psi.40 rpm/19K Tq,PUW 210K,SOW 105K,RTW 141K.Wash Dn f/6816 to 6863'start to see stringers.Take Wt @ 6873'solid 10K Dn.;Work String w/30 rpm/19K Tq.Pump 40 bbl Hi Vis Spacer&Displace Sea Water w/9.5 ppg LSND Mud System.Pump 530 bbls.Set Back Std.Put rig on Hi Line Power. No Black out issues while on Gen Power.;Ran cats for 3 days in manual mode without any blackout issues;Cut and slip drilling line(80').;Rig Service. Grease and inspect TDS,Crown,Drawworks,Pipe spinners,Calibrate block ht.;Wash and ream down from 6816'MD to tag @ 6873'MD. Drill hard cmt Fl 6873'-T/ 6893'(BFL). 2-6k wob,60-80 rpm,450 gpm,800 psi,52%flow,16.5k tq.;Drill BFL F/6893'-T/6895'MD. Continue drilling hard cmt and remaing shoe track F/ 6895'-T/7020'MD. 2-11k wob,80 rpm,450 gpm,900 psi,52%flow,16.5k tq.;Tagged float equipment 4'+/-deep. Work thru float equipment clean before drilling ahead.;Drill new formation F/7020'-T/7040'MD. 15k wob,80 rpm,17k tq,450 gpm,880 psi,52%flow.;Circulate and condition mud for FIT. Rot and recip pipe @ 7040'MD. 540 gpm,1223 psi,55%flow,80 rpm,17.5k tq,10.4 ECD,13 bgg.;Hauled 471 bbls to MP G&I for total=971 bbls Hauled 280 bbls H2O from L-Pad lake for total=280 bbls 10/10/2017 Circ&condition @ 540 GPM for FIT. Perform FIT to 12.5 PPG/750 PSI. Took 2 BBL to pressure up and bled back one bbl.GOOD test.;Service rig,Trouble shoot TD sensor.Had to unplug to reset.;RIH&Drill ahead F/7040'T/7710' 670'@ 75 FPH Average. 14-18 WOB,18K TQ 140 RPM, 500 GPM,1650 PSI. Increase Lubes to 1%ES Glide due to stick slip.Worked good. Pumped 20 BBL,with 200%in;MW,9.5 Vis 52;Drill ahead F/7710'T/8036'MD.326'@ 55 FPH Average. 14-16 WOB,19.7K TQ,140 RPM, 505 GPM,1680 PSI,57%flow,10.6 ECD,74 bgg.;Drill ahead F/8036'T/8325'MD.289'@ 49 FPH Average. 22K WOB,19.7K TQ,140 RPM, 520 GPM,1980 PSI,57%flow,10.6 ECD,75 bgg.;Pumped 20 bbls Hi vis sweep @ 8083'MD. Came back on time w/20%increase in cuttings.;Hauled 171 bbls cuttings to MP G&I for total=1142 bbls Hauled 280 bbls H2O for total=560 bbls I xf cuneov chnu+nrl,, nn!11c linc of nI,n M!P RN 10/11/2017 Drill ahead F/8325'T/8386'MD.61'@ 61 FPH Average. 22K WOB,19.7K TQ,140 RPM, 520 GPM,1980 PSI,57%flow,10.6 ECD,75 bgg.;Pump 20 bbl sweep,@ 520 GPM,1830 PSI,140 RPM,22K TW,Sweep back on time with 50% Increase.;Monitor well, POOH on Elevators Ff 8386'T/7225'.Started over pulling 25-40 K over. Back ream F/7225'T/shoe 7015'. No torque spikes or pressure increase.;Circ&Condition while Servicing the rig.;RIH F/6998'T/8326', Wash down last stand.Clean. Btm up gas @ 212.;Drill ahead F/8386'T/8780'MD.394'@ 65 FPH Average. 100-125 Fast ROP 10-18K WOB,19.7K TQ,140 RPM, 520 GPM,1780 PSI,57%flow,10.5 ECD,100 bgg.;Drill ahead F/8780'T/9145' MD.365'@ 61 FPH Average. 100-125 Fast ROP 15-20K WOB,20K TQ,140 RPM, 520 GPM,2030 PSI,57%flow,10.6 ECD,130 bgg.;20 bbl hi vis sweep @ 8890',on time,20%inc.;Drill ahead F/9145'T/9393' MD.248'@ 83 FPH Average. 100-125 Fast ROP 17-20K WOB,21.5K TQ,140 RPM, 520 GPM,2060 PSI,57%flow,10.6 ECD,100 bgg.;Wiper trip 9393'MD est 200'above proj HRZ. Circ 3x btms up while rot&recip pipe. 545 gpm,2080 psi, 59%flow,140 rpm,24k tq,10.6 ECD's,68 bgg. 20 bbl hi vis sweep,on time,50%inc.;Monitor well(static). B/D TDS.;POOH F/9393'-T/ 8988'MD. Pulled tight @ 8988'MD. Attempt to work thru with no rotary or pump 3x w/max pull 40k(no go). Kelly up and pump/rot past.;Hauled 460 bbls cuttings to MP G&I for total=1602 bbls Hauled 420 bbls H2O for total=980 bbls I Cl'1CK._17. 'I'I..... 4 C.I..p..1.,../lA/O 01 • • 10/12/2017 Work over pulls @ 8988'.Back ream out TI 8955.RIH clean and Pooh on elevators T/shoe at 7015.See occasional 10-15K bobbles.;Service rig.;Circ btm up with no increase in cuttings.;RIH F17015'T/9386'.Wash last stand down staging up pumps to 480 gpm. Bring wt up to 10.3 adding 13.5 spike fluid on the fly while drilling.;Drill ahead F/9386'T/9655'520 GPM,1830 psi,10-14 WOB,100-140 RPM 22-25 TQ.Lost swab in#2 Pump,Drill at 390 gpm for short time while changing swab.;Bring wt up to 10.3 adding 13.5 spike fluid. Ratty drilling in to the HRZ.Play with parameters trying to minimize stick slip. Lower RPM worked best.;Drill ahead F/9655'T/9833'MD. 178'-30 ft/hr arop. 520 GPM,2180 psi, 10-20 WOB,100-140 RPM 22-25 TQ.;20/20 bbl tandem to wt&vis/hi wt&vis(9.5 ppg,45 vis followed by 10.3 ppg,300 vis)@ 9685' MD. 300 stks late with 50%increase in cuttings.;Drill ahead Fl 9833'T/9962.129'-22 ft/hr arop. Pump condet/nutplug w/no change in ROP.Work string to clean bit(no change).520 GPM,2190 psi, 10-24 WOB,100-140 RPM 22-25 TQ.;Hauled 510 bbls cuttings to MP G&I for total=2112 bbls Hauled 420 bbls H2O for total=1400 bbls Last svy @ 9870.09'MD,30.57°Inc,139.13°Az. Currently.8'high,2.6'left plan(WP 8). 10/13/2017 Drilling Fl 9962'T/10262' 300'@ 60 FPH. Drilling the Kuparuk sands holding back ROP to 80-125 FPH. WOB,5-14 28K TQ,520 GPM @ 2150 psi.;Circ 550 gpm 150 RPM Pump Tandem sweep. High vis low vis.20/20.Minimal increase.Bring MW 10.5 after second btm up. Pump 6 btm up total Shakers cleaned up after 1.5 btm up. Monitor well.;Short trip on elevators F/10262 T/9300'.Pulled tight at the base of the Kalubik @ 9880 20 over Also pulled 10-35 over through the HRZ Fl 9545-T/9400'. Work back through and no over pull after;Work back through and no over pull after wiping. Pulled clean after getting above HRZ.Pulled above last short trip depth clean. Had correct hole fill for trip out.;TIH F/9300-T/10210'MD. Washed down F/10210'-T/10262'MD(TD). Hole took proper displacement. Clean trip back to btm without issue.;Circulate and condition hole @ 10,262'MD/ 7206'TVD(rot&recip pipe).Stage pumps up to 550 gpm,2400 psi,59%flow,150 rpm,27k tq.Pumped 25 bbl hi vis/walnut sweep.;Came back 800 stks late w/100%inc in cuttings. Circulated clean @ 3x btms up.Saw 890 units gas @ btms up then dropped down to 10 units bgg. 313k up,129k do after cleanup cycle.;SPR's.Monitor well(static).Spot 112 bbls 10.5 liner running pill @ max 7 bpm,915 psi. Displace w/182 bbls @ full rate. Monitor well(static).;POOH Ff 10,262'-T/6999'MD.Staged up trip speed from 500 fph initially and staged up to 2000 fph by 8341'MD. Work tight spot @ 8554'MD(worked 4x w/max 38k over). Pull past and tripped clean.;Hole took proper displacement.;Circulate 2x btms up @ 6999'MD. 550 gpm,2000 psi,75 rpm,15.6k tq. Shakers clean(fine sands).;Hauled 228 bbls cuttings to MP G&I for total=2340 bbls Hauled 560 bbls H2O for total=1960 bbls Projected to bit @ TD 10,262'MD. Currently 1'high,2.6'left plan(WP 8). 10/14/2017 Monitor Well.Static. POOH F/ 7015'T/719,Staging up to 4000 FPH. Hole took proper displacement.;UD 5"HWDP,Jars&1 NMDC. Conduct Nuclear PJSM, Pull Sources.UD remaining BHA to Bit. Stabs looked good little wear. Bit Grade,0-1-CT-G-X-I-NO-TD.;Clean&Clear rig floor,Pull Wear bushing.Flush stack with water with Stack Wash tool. Well took correct hole fill.;Change top rams to 5.5. Test to 250/4000 psi.R/D testing equipment.;Swap to Completion Report. Released Canrig sample catchers. MWD/DD finish shipping out tools and nukes. Released Sperry 10/16117. Staged cmt equipment onsite.;Hauled 518 bbls cuttings to MP G&I for total=2858 bbls Hauled 0 bbls H2O from 6 mile lake for total=1960 bbls Hauled 150 bbls H2O from B-Pad for total=150 bbls 0 . Hilcorp Energy Company Composite Report Well Name: MP C-45 Field: Milne Point County/State: ,Alaska (LAT/LONG): :vation(RKB): 26.7 API#: Spud Date: Job Name: 1710175C MPC-45 Completion Contractor AFE#: AFE$: 40060ate.......:...:: . . :.; ... : ::, ,::; ;. ,.:;"......... ENNUt$. 6. MiNINSIMEINIMMIKEIMENINIMISIMEM 10/14/2017 PJSM,R/U Doyon Casing. M/U CRT II 5.5"and tq same. R/U power tongs,hydraulic lines,snub lines and bring handling equipment to floor. M/U XO on FOSV and stage readily available. Final count on centralizers on floor(32)and total pipe in shed(260 jts). Function test equipment and verify proper sizing for pipe. R/U fill up line.,PJSM,Run 5.5"GeoConn,17#, P-110 production liner as per detail F/surface-T/820'MD. M/U shoe track(120'between FS and FC). Flashlight float equipment(good), Bakerlok shoe track and M/U to triangle(10,800 ft/lbs tq). Check floats(good).,Circulate thru shoe track after all was made up(good)@ 6 BPM,360 psi,42%flow.Install centralizers as per detail. Fill every 10 jts on the fly with fill up.Stage up to 2000 fph max.,Continue running 5.5"liner F/-820'-T/1992'MD.,Rig service. Circulate string volume during rig service. 4.5 bpm,270 psi.,Continue run 5.5"liner F/1992'-T/4,065'MD. Hole taking proper displacement. 2000 fph max running speed. 10/15/2017 P/U 5.5 Geoconn P110 17#Casing making connections up to 10800 FT# F/4065'T/6980'. Running 2000 FPH Max filling on the fly and topping off every 10 Joints.Correct pipe displacement. up/dn/ROT 136/83/113K,Circ and condition @ shoe staging pumps up to 6 BPM @ 600 psi.Take ROT parameters @ 10 `: RPM 11500 TQ.,P/U 5.5 Geo conn P110 17#Casing making connections up to 10800 FT# Fl 6980'T/8300. Running 2000 FPH Max filling on the fly and topping off every 10 Joints.Correct pipe displacement.UP/DN 154/87K.,Circ and condition staging pumps up to 6 BPM @ 660 psi. Work pipe. UP/DN.,P/U �/\#J 5 Geo conn P110 F/8300 T/9300'. Running 2000 FPH Max filling on the fly and topping off every 10 Joints.Correct pipe displacement. UP/DN 7 54/87K.,Run 5.5",17#Geo conn P110 F/9300 T/10,260'MD.Reduce running speed T/1200 FPH Max.Fill on fly,top off every 10 jts. No losses during 0114 liner run.UP/DN 202/110K.Ran a total of 235 jts pipe. Ran 34 solid body spiral centralizers(7.375"OD). 31 for the first 1300',3x across 9-5/8"shoe(7015' CB MD).,Washed down last jt to get on depth @ 10,260'MD. No fill.Staged pumps up to 6 BPM,778 psi,41%flow,10 rpm, 15k tq(would stall if not reciprocating pipe).Observed 0 losses while circulating.Circulate 1x btms up wl max gas @ 230 units.H2O @ 50 bph to condition mud for cmt job.,B/D TDS. R/U cmt line thru rotary cmt head. Stage up to 6 bpm,875 psi,42%flow,10 rpm,15k(stall w/no recip). Circulate lx liner volume.,PJSM for cmt job.Break and Make up CRT to ensure serviceability during cmt job while dropping plugs(good). Wet lines with 5 bbls H2O. P/T lines 1000/4127 psi(good).Pump 77`i bbls 11.5#Tuned spacer III(3 born.500 psi)Drop btm plua. Pump 76 bbls 15.8#class G premium cmt(3.7 bpm,700 psi). Batched Coil 23:40 hrs.Shut down and drop top plug. Clear cmt lines washing up back to pits w/11 bbls H2O.,HES displace cmt with 20 bbls H2O(5 bpm,450 psi).Turnover to rig.Displace w/ of10.5#LSND(MP#2,6 BPM,1200 psi,43%flow).Reduce rate to 2 bpm,800 psi last 10 calculated bbls. Bumped @ 3480 stks(215.8 bbls calc/217.5 bbls actual). CIP @ 01:07 hrs(10/16/17).Psi uo to 1300 psi w/5 min hold. Bleed off(floats held),Bled back.8 bbls.Full returns throughout job.Rot and recip V throughout job.,WOC-3 hrs(CIP @ 01:07)Work tq out of string without breaking over string up or down.R/D Doyon CRT(Volant),Install TIW and monitor annulus via trip tank and visually monitor tubing while rigging down floor.Prep cellar for N/D.Clear floor of 5.5 handling equipment. Load 2-7/8"cleanout scraper string. Est TOC @ 8470'MD(calc w/0%washout).,N/D BOP's.Vac out cutoff jt. Remove choke and kill lines.Drain stack. N/D stack and P/U. Set "E"slips w/115k. Mark cutoff jt @ table. Start making rough cut.,Hauled 100 bbls cuttings to MP G&I for total=2858 bbls Hauled 0 bbls H2O from 6 mile lake for total=1960 bbls Hauled 140 bbls H2O from B-Pad for total=290 bbls 10/16/2017 N/D BOPs,Make rough cut on 5.5 casing.Set back stack.Make final cut and dress casing stump.Install pack off with running tool from the rig floor.RILD& Test to 250/5000 psi.,N/U BOPS, Install VBR rams in upper rams.Test top rams to 250/4000 psi on 2 7/8 test joint. Test annular to 250/2500 psi on 2 7/8. R/D test joint.R/U Hauk Jaw.,Wear bushing. Finish R/U Hauk Jaw.Function test.Good. R/U Little red&bullhead 116 bbl Diesel down the 5.5 X 9 5/8. Starting injection pressure 600 psi, Final pressure @ 2 BPM 1300 psi.,PJSM,Train crew on Hauk Jaw operation. Start UD 16 joints of 5"Dp out of derrick.,Continue UD 5"DS-50 out of derrick via mousehole using Hawk Jaws double stack. Inspect and separate pipe for hard band.290 jts total laid down.,Hauled 755 bbls cuttings to MP G&I for total=3713 bbls Hauled 0 bbls H2O from 6 mile lake for total=1960 bbls Hauled 140 bbls H2O from B-Pad for total=420 bbls 10/17/2017 UD 5"Dp out of derrick with Hauk Jaw.21 tsands.,R/D Hauk jaw.Clear rig floor. R/U Weatherord 2 7/8 Equipment.,P/U 4.75 Bit,5.5 Casing scraper,Bit sub with float.P/U 2 7/8 Pac HT DP F/Surface T/9295'.Fill pipe every 2000'.,Continue to drift,P/U and RIH w/ 2 7/8 Pac HT DP Fl 9295'to 10086'.Correct displacement on trip in the hole. PU/SO 160/70.,M/U XOs and single in mouse hole,M/U top drive,pump 2 bpm,1350 psi,wash f/10086'to 10128'tag float - collar on depth(17'in on jt 322)set torq limit to 5100 ft/lbs,unable to rotate unless working pipe.,Pump 40 bbl barazan hi vis sweep 4 bpm,3400 psi, increase to 5.5 bpm,3760 psi,displace w/9.8 ppg brine w/1%cla-web,reciprocate pipe 30',torq set at 5100 ft/lbs,minimal rpm due to torq limitations while working pipe,pump 530 bbls total,(2 112 circulations)until clean brine @ returns.,UD XOs and single,Blow down top drive,flow check well,static.POOH UD 2 718"Pac workstring from 10113'to 2600'. Note:rinse pipe with fresh water before UD.,Hauled 290 bbls cuttings to MP G&I for total=4003 bbls Hauled 0 bbls H2O from 6 mile lake for total=1960 bbls Hauled 140 bbls H2O from B-Pad for total=560 bbls • • 10/18/2017 POOH L/D 2 7/8 Pac HT DP Fl 2816'T/Surface.L/D Bit and scraper. Looked good. Bit Grade. Still New.,Clean and clear rig floor.RID Weatherford.,Test 5.5 casing to 3000 psi for 30 Min. Good.,Attempt to set TWC.Unable to get more than one thread.Attempt to vac out,Still unable to set. Set test plug. Flush surface equipment and lines.,N/D BOPS.Remove choke and kill lines,Blow down remaining surface lines. Rack back stack. Remove test plug.,Dress BPV profile as per Well head specialist. Install TWC. N/U adapter flange and tree. Rig move prep,Prep Pumps,Finish cleaning pits,Clean hopper room,R/D tongs„N/U tree,attempt to test tree,TWC profile leaking,Perform visual pressure test on tree to 5000 psi,no visual leaks on tree connections.Pull TING,fill tree with diesel,install top flange on tree.Secure tree. Note:wellhead rep re-test packoff to 5000 psi for 5 min,good.,Blow down water lines,load 5”drill pipe into pipe shed,prep pits for rig move.Rig down rig floor equipment. Perform derrick inspection.PJSM,Bridal up,scope derrick down. Rig released from C-45©00:00 hrs,Hauled 803 bbls cuttings to MP G&I for total=4806 bbls Hauled 0 bbls H2O from 6 mile lake for total=1960 bbls Hauled 140 bbls H2O from B-Pad for total=700 bbls 10/20/2017 MIRU SLB E-Line. Unable to function upper and lower master valves on dry hole tree due to cold.Wrap,heat,and flush with arctic grease.Open UMV and LMV.Lower USIT and Sonic CBL tool into well.TAG ICE at-3'below GL.MU 1-1/2"HP hose and lower into well/circ neat meth down to ice/wait/broke thru ice.Drift down 20'with e-line tool.Good.Night cap well.SDFN 10/21/2017 MU and RIH with USIT and Sonic CBL/GR/CCL for bond log.Set down at 4,206'WLM.Unable to pass deeper. ,* t� L� Make 4.74"Junk basket run to PBTD at 10,126'WLM.Recovered cupful of metal flakes from casing only.No cement. V[ MU and RIH with USIT only+GR/CCL tools. Log 3 passes from PBTD to 500'above TOC at 0 psi,300 psi,and 900 psi. 10/22/2017 Attempt to PT 5-1/2"casing to 6000 psi. 1st attempt to set Tree Saver-4.850"OD Cup mandrel can pass restriction just below BPV profile. Restriction is 3.76"ID,Cup mandrel is 4.850"OD 2nd attempt-Set tree saver with 4.64"OD cups.Pressured up to seat cups(2000 psi),cups wouldn't hold in 4.892"ID casing. Pull Tree Saver.Take 4.850"OD cups to machine shop to turn down to 4.75"OD. Return tomorrow to re-test.,Used LRS 10k pump truck Used Oil Stated Tree Saver Halliburton staged Sand Castle for upcoming Frac 10/23/2017 PU Oil States Tree Saver-MU extensions and 4.75"OD Cup Mandrel. 120'stroke on this Tree Saver. Stab Tree Saver and stroke into place.RU LRS 10k pump.PT surface line to 6,100 psi. 1,2k,,Open MV on Tree saver, 0 psi on well.Pressure up casing to 1000 psi,set packer cups.Cups holding good. Pressure up 5-1/2"casing to 6,112 psi and hold v and chart for 30 minutes, Lost 46 psi in 1st 15 min.Lost 18 psi in 2nd 15 minutes,Total loss of 64 psi in 30 minutes.MIT passed to 6000 psi. 6 RDMO LRS pump.Pull Tree Saver.Close LMV and UMV.Install Tree Cap. Pull horseshoe scaffolding out for wellhead packoff changeout when packoff arrives. Halliburton set berm and stage frac tanks for upcoming Frac. 10/24/2017 Load Sand Castle with 16/20 CarboBond Lite proppant Install Visquene Hootch around well in preparation for packoff changeout At 15:00 discover packoff lost in transit. Plan is to proceed with perforating.Call out SLB E-line to be on location in the morning-7:00 10/25/2017 Remove scaffold hootch that was to be used to change out packoff. Packoff did not arrive.Set horseshoe scaffolding around welI,MIRU SLB E-line. Stab on well with BOPE,lubricator,QTS,and wt bars for tools. PT with triplex to 340 psi low/3500 psi high. 1st test encountered leak on plug valve on pump in sub. Grease valve and retest same.Good Test. MU GR/CCL,Firing head,20'pert gun(HSD,3-3/8"PowerFlow, 3412,Max 12 SPF). CCL to top shot=7.9'. Stab on well. PT QTS to 3,500 psi.,Open well to 0 psi SICP.RIH with 20'perf gun. Tag PBTD at 10,128'ELMD.Make 3 correlation passes to get on depth 4R A from PBTD to 9700'. Tie into SLB USIT log dated 21-Oct-2017. Log up to shooting depth.Stop at 9968.1'CCL depth/Top shot at 9976'ELM.Fire gun and SHOOT 9976'-9996'ELM.Good indication. Log off up to 9460'ELM.POOH.WHP=5 psi. Lay down gun-ASF. Vac trucks start hauling water for frac,MU GR/CCL/Press/Temp tools. RBIH to PBTD.Correlate to get on depth tied in to USIT log.Log up at 30 fpm across perforated interval.Get 30 min stop count with pressure sensor at 9976'ELM. PUH 1000'and get stop count at 8977.5'.PUH 1000'and get stop count at 7977.5'. POOH 10,128'-3604 psi/172 deg 9976'-3537 psi/175 deg 8976'-3102 psi/139 deg 7976'-2741 psi/118.5 deg,At surface,Close UMV.L/D tools.RDMO SLB E-line.,Continue filling frac tanks with 120 degree Fresh water from Prudhoe hot water plant 10/26/2017 MIRU Halliburton Frac Spread.Stab Oil states tree saver.RU treating lines.Stage bleed tanks.RU casing pop off on outer annulus. Pressure test frac treating lines with 60/40 methanol to 300 psi low/6500 psi high. Bleed pressure off.Secure location.SDFN 10/27/201 Standby for Sundry approval,Pump mini-frac at 30 bpm,perform step down and analyse data for frac.Cut pad size from 500 bbls to 300 bbls.Test gel and x- linked fluids. Pump main frac at 30 bpm. 1-7 ppg 16/20 CarboBond Lite proppant. Total proppant pumped=167720 lbs vlr-1 Proppant behind pipe=165,427 lbs est. `��! A Total Slurry vol=2176 bbls W t Total Clean vol=1987 bbls,Max pressure during frac -3500 psi Min pressure-2100 psi 15 min ISIP=2200 psi,Flush and blow down surface lines and pumps Haul off remaining water in frac tanks Haul off fluids for disposal 10/29/2017 MIRU SLB CT.Pressure test lines and BOP to 250 psi and 3500 psi.Good BOP test.PJSM for job.,RIH w/1.91"OD CRC,1.75"OD BPV,2x 4'x 1.75"OD 4 Weight bars,and 2.5"OD down jet nozzle.SIWHP=470 psi.Circulate 5bbl gel sweep every 30 bbls of Slk 1%water at 3200 psi and 2.5 bpm.,Tag top of ('i proppant at 9,958'ctmd. RIH and cleanout proppant to PBTD of 10,125'ctmd while pumping at 2.5 bpm and 3200 psi.Took 50'bites then POH 50'until TD l was reached.,At 10,215'ctmd,pump 15 bbl NVis 65 yield gel sweep and chased out of hole at 110 fpm while pumping SLK 1%water at 2.5 bpm at 3200 psi.,At surface.See broken gel in returns.Close flow cross and rig down SLB CT.,Flow well at 200 BPD 165 psi WHP through test separator. No gas in returns.Returns are 100%cloudy water. • • JJ 10/30/2017 Rig up coil with 5.5"EVO Plug.Discover EVO plug will not pass through SLB 4-1/16"BOPS.Call HES Slickline to deliver 7"pressure equipment in order to set plug using slickline.,Break pump in sub off tree and M/U tree cap flange with 7"Otis connection.R/U SL with 7"BOPs and risers to 7"Otis connection.RIH with SL and set 5.5"EVO plug at 9,800'slmd. Freeze protect with 10 bbls of methanol prior to setting plug.Successful setting of plug. 10/31/2017 PJSM. RD Flowcross.M/U Pump In Sub.M/U hardline to flowback tank.M/U MHA:2.25"CTC,2.13"MHA,2.13"ported crossover,2.5"OD nozzle to SLB 1.75"CT.,RIH w/CT to 9,750'ctmd.Bleed 380 psi of gas off to 0 psi on 5-1/2"casing.Circulate in 290 bbls of 9.8ppg brine.Wellbore volume is 227bb1s.(FP is-5 F).POH w/coil to 100'Circulate in 60/40 methanol.,Pressure test plug to 3,500 psi for 30 minutes.Lost 30 psi in 30 minutes.Good test.,Close well.UD coil BHA.RDMO coil for maintenance. 11/3/2017 Place company rep trailer and doghouse in place on C-45.Start main rig generator and hook up power to both trailers.SIMOPS:Alaska Crane remove BOPE from well G-02,pick wellhouse 2-3'off the ground and remove it from wellhead,set production tree in place.Wellhead reps on location to help N/U tree and pressure test void.Centrilift on location to perform electrical checks on ESP once tree in place.,Continue to move equipment fl G-pad to C-pad.Alaska Crane, load well house and rig floor onto roads and pads,scissor neck trailer and relocate to A pad,for the time being.,Clear pad of snow from wind,wk on eq.set up crane&spot eq.,Winds slowed,N/D tree,install hanger w/TWC,N/U BOPE,spot mud boat in position,set well house and rig floor in position,spot rig. 11/4/2017 Continue to rig up on C-45,pull out glycol lines and wrap circ lines.Take on 45bbls of fresh water in pit#4,and 170bbls of 9.7ppg heavy NaCI in pits 1-3.Dig out catwalk and surrounding equipment removing snow so it is functional.,Fill BOPE stack w/fresh water from pit#4,grease choke and kill manifold in prep for BOPE test.Perform shell test and inspect for leaks,in prep for BOPE test.,Test BOPE as per Sundry to 250psi low/3000psi high f/5 charted mins w/2-7/8" test joint,and 250psi low/2500psi high on the annular element.AOGCC repBob Noble waived witness to testingon 11/2/17 15:30.SIMOPS:load and P P 9 @ ) strap completion/work string.,Continue to load and strap pipe.330jnts loaded and tallied.Blow down lines from BOPE testing.Well head reps on location to )l)4) strap TWC,P/U landing joint and pull 2-7/8"TBG hanger.,P/U and M/U Halliburton/Baker,Evo-trieve plug,fishing BHA.,RIH w/Evo-trieve fishing BHA on 2-7/8" EUE work string f/surface 90'md.Circulate 10bbls out to tiger tank.Blow down lines.Continue to RIH to-300'md.,H2S drill with rig crew,followed by AAR. Milne Point ERT on location as drill commenced.ERT conduct rig walk through and assessment with rig team.,Cont. RIH w/Evo-trieve fishing BHA on 2-7/8" EUE work string f/300'md to 9238'md(JNT 300).P/U=21 Klbs,S/O=55Klbs, TBG collars hanging up in the wellhead.Attempt to adjust rig and wellhead alignment. Utilize link tilt when approaching collar to center string. 11/5/2017 Conduct rig service.,Continue to RIH to JNT 315(9700'md).P/U=64klbs,S/0=21.5klbs.,Weight up 200bbls in the pits from 9.7ppg+to 9.9ppg.Empty pit# 4 to take returns.Perform table top discussion with rig crews about well control response when pulling Evo-trieve plug.,Circulate the long way surface to surface w/9,9ppg brine pulling fluids out of pit#3,isolating returns in pit#4.Take fluid weight every 20bbls.Pump @ 2BPM=1300-2000psi,increase pumps to 3BPM =3000-3500psi,slow pumps to 2.5BPM=2000-2500psi.Once pit#3 is empty,equalize pits#3-4 and pull fluids out of pit#2.Returns 9.7-9.8ppg until reaching 200bbls away. 9.9ppg seen after 200bbls pumped.Blow down lines,RIH fl jnt 315-319.Tag up on plug @ 9820'md.Set down 500Ibs,watch fluid level.No movement.P/U=65klbs,no sign of over pull.Continue to S/D on plug in increments up to 1500lbs,P/U to break over weight indicator @ 65klbs each time weight is set down on plug. No over pull seen,no fluid movement seen.Rotate string in elevators 180deg and set down 1.5klbs.Tool latch and over pull seen.Pull 70klbs to free plug.,RIH f/9820'md to 9852'md(32'past tag up depth).No signs of drag on the down movement.Monitor wellbore ft 15mins. Fluid level dropped 2'in stack.,Close pipe rams and line up to pump the long way taking returns through MGS. Pump 220bbls,seeing dirty returns after 120bbls away.Weigh returns after every 20bbls pumped,9.9ppg returns throughout circulation.Gas back to surface-150bbls away.,POOH w/Evo-Trieve retrieval BHA on 2-7/8"EUE TBG f/9852'md to 7388'md(JNT 240),Cont.POOH U surface,recovered Evo-trieve plug,broke down BHA,Note 38 bbl loss for trip,Clean &clear floor,prep pipe rack&floor for completion run, PJSM,PIU 2 7/8"6.5#L-80 EUE completion,drift same,RIH w/packer&gauge assembles,m/u connection U gauge&clamp wire. 11/6/2017 RIH w/gas lift completion as per ODE iSet down in wellhead wt GLM.P/U and assess any Tec wire damage.Tec wire compressed at the bottom of GLM. Caliper GLM wt Tec wire,unable to fit in ID of 5.5"CSG.Contact ODE,decision made to drop HES gauge.POOH and UD HES gauge. P/U jnt of TBG to replace gauge in tally.,Continue to RIH/w gas lift completion as per adjusted tally.RIH f/-70'md to 6900'md. No returns seen while tripping into hole.Fill hole' every 15 joints and record fluid levels in trip sheet.TBG collars catching in wellhead every 18'into each joint.Operator slowing down and linking out to avoid any contact with wellhead.,Continue to RIH/w gas lift completion as per adjusted tally.RIH f/-6900',U9832',up wt 56k,dn wt 24k,M/U hanger&landing jt, land hanger placing tubing tail @ 9858'„Drop ball&rod(ball 1 5/16")UD landing jt,R/U Upump dn tubing for packer set,Pump dn tubing @ 1.2bpm,2.6 bbls pumped,pressure up t/4000psi,pressure bled down U 2000psi in 2 1/2 minutes,had communication with 5.5 casing x tubing annulus.Worked through troubleshooting possible surface issues changing line ups attempted to pressure up with same results.,With further diagnostics found ball&bar hung up in landing jt.recovered same&re dropped waited 10 min,pressured tubing up U 4000 psi,held 30 min on chart good,setting packer @ 9830'bleed tubing U 2000psi,pressure up 5.5"casing x tubing annulus U 3700 psi testing packer,hold&chart f/30 min.good,bleed tubing off seeing DCR valve in GLM-1 shear @ 500psi cont.bleeding tubing&annulus to 0.,Blow down&r/d circulating lines,install BPV,Cont.blow down&break down lines,r/d pipe rack,ready rig floor. 11/7/2017 Continue to R/D on well C-45.Prep rig floor to lower mast.Lower mast on carrier and move to A pad.Roads and pads on location w/crane.Perform crane pick to remove rig floor,well house,BOPE,and install production tree.Well head rep on location for tree installation.Test void(good test).Tree set and void tested @ 12:00pm 11/7/17. continue to shuffle rig components to A pad in prep for maintenance. 11/10/2017 ****WELL SHUT IN UPON ARRIVAL"**(pull ball&rod,glv do,static) PT PCE 250psi LOW/3,000psi HIGH PULLED BALL&ROD FROM 9,817'SLM(9,846'MD) ****CONTINUE JOB ON 11/11/17**** 11/11/2017 PT PCE 250psi LOW/3,000psi HIGH PULL 1” BK,DMY.VLV.FROM STA#6 AT 5,685'SLM(5,700'MD) PULL 1"BK, DMY.VLV.FROM STA#7 AT 4,545'SLM(4,561'MD) PULL 1"BEK,SHEAR.VLV. FROM STA#8 AT 2,790'SLM(2,808 MD) SET 1"BK,DOME VLV.(ports 12/64", 1244tro)IN STA#8 AT 2,790'SLM(2,808'MD) SET 1"BK,DOME VLV.(ports 12/64", 1215tro)IN STA#7 AT 4,545'SLM(4,561'MD) 11/12/2017 PT PCE 250psi LOW/3,000psi HIGH SET 1"BK,ORIFICE VALVE(ports 20/64")AT 5,685'SLM(5,700'MD) PULL RHC BODY FROM 9,827'SLM(9,846'MD)-19'Correction RUN DUAL STATIC GAUGES*SEE JOB LOG FOR DETAILS* RUN 2'DRIVE DOWN BAILER AND TAG FRAC SAND AT 9,890'SLM(9,909'MD) • i Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-45 50029235790000 Sperry Drilling Definitive Survey Report 24 October, 2017 1 P HALLIBURTON Sperry Drilling • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU C-45 Project: Milne Point TVD Reference: MPU C-45 Actual RKB @ 41.50usft Site: M Pt C Pad MD Reference: MPU C-45 Actual RKB @ 41.50usft Well: MPU C-45 North Reference: True Wellbore: MPU C-45 Survey Calculation Method: Minimum Curvature Design: MPU C-45 Database: Sperry EDM-NORTH US+CANADA Project Milne Point,ACT,MILNE POINT Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU C-45 Well Position +N/-S 0.00 usft Northing: 6,029,147.50 usft Latitude: 70°29'24.898 N +E/-W 0.00 usft Easting: 558,111.14 usft Longitude: 149°31'29.845 W Position Uncertainty 0.00 usft Wellhead Elevation: 41.50 usft Ground Level: 14.80 usft Wellbore MPU C-45 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2017 7/21/2017 17.65 81.04 57,506 Design MPU C-45 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 26.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 26.70 0.00 0.00 117.99 Survey Program Date 10/24/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 851.00 SRG-SS(MPU C-45) SRG-SS Surface readout gyro single shot 07/26/2017 910.88 6,975.73 MWD+IFR2+MS+sag(1)(MPU C-45) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 07/31/2017 7,038.94 10,232.37 MWD+IFR2+MS+sag(2)(MPU C-45) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/06/2017 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N15 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.70 0.00 0.00 26.70 -14.80 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 UNDEFINED 100.00 0.72 326.41 100.00 58.50 0.38 -0.25 6,029,147.88 558,110.88 0.98 -0.41 SRG-SS(1) 168.00 0.80 331.32 167.99 126.49 1.16 -0.72 6,029,148.65 558,110.41 0.15 -1.18 SRG-SS(1) 231.00 0.75 78.19 230.99 189.49 1.63 -0.53 6,029,149.12 558,110.60 1.98 -1.23 SRG-SS(1) 293.00 1.41 151.14 292.98 251.48 1.04 0.24 6,029,148.54 558,111.37 2.24 -0.28 SRG-SS(1) 351.00 2.11 166.41 350.95 309.45 -0.62 0.83 6,029,146.89 558,111.98 1.44 1.03 SRG-SS(1) 413.00 2.76 134.97 412.90 371.40 -2.79 2.16 6,029,144.73 558,113.32 2.35 3.21 SRG-SS(1) 476,00 4.57 116.45 475.77 434.27 -4.98 5.48 6,029,142.57 558,116.66 3.40 7.17 SRG-SS(1) 537.00 6.31 108.18 536.49 494.99 -7.10 10.84 6,029,140.48 558,122.03 3.12 12.91 SRG-SS(1) 599.00 7.67 102.17 598.03 556.53 -9.04 18.12 6,029,138.60 558,129.33 2.49 20.25 SRG-SS(1) 662.00 10.23 97.27 660.26 618.76 -10.63 27.78 6,029,137.08 558,139.00 4.24 29.52 SRG-SS(1) 725.00 13.67 97.15 721.89 680.39 -12.27 40.72 6,029,135.55 558,151.95 5.46 41.72 SRG-SS(1) 10/24/2017 5:34:19PM Page 2 COMPASS 5000.1 Build 810 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: 1 . Well MPU C-45 Project: Milne Point TVD Reference: MPU C-45 Actual RKB @ 41.50usft Site: M Pt C Pad MD Reference MPU C-45 Actual RKB @ 41.50usft Well: MPU C-45 North Reference: 9 True Wellbore: MPU C-45 Survey Calculation Method: Minimum Curvature Design: MPU C-45 Database: ,..., .4 - Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +141.5 +E/-W Northing Easting DLS Section (usft) (°) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 787.00 16.25 101.67 781.78 740.28 -14.94 56.49 6,029,133.01 558,167.74 4.56 56.89 SRG-SS(1) 851.00 17.31 107.07 843.06 801.56 -19.54 74.36 6,029,128.54 558,185.65 2.94 74.84 SRG-SS(1) 910.88 17.14 106.41 900.25 858.75 -24.65 91.34 6,029,123.57 558,202.66 0.43 92.23 MWD+IFR2+MS+sag(2) 973.19 20.21 108.11 959.28 917.78 -30.59 110.39 6,029,117.77 558,221.75 5.00 111.83 MWD+IFR2+MS+sag(2) 1,036.76 22.71 109.07 1,018.43 976.93 -38.02 132.42 6,029,110.52 558,243.84 3.97 134.78 MWD+IFR2+MS+sag(2) 1,098.28 25.95 109.70 1,074.48 1,032.98 -46.44 156.33 6,029,102.29 558,267.81 5.28 159.83 MWD+IFR2+MS+sag(2) 1,161.44 30.18 110.48 1,130.20 1,088.70 -56.65 184.22 6,029,092.29 558,295.78 6.72 189.26 MWD+IFR2+MS+sag(2) 1,224.24 33.12 107.48 1,183.66 1,142.16 -67.33 215.38 6,029,081.86 558,327.02 5.31 221.79 MWD+IFR2+MS+sag(2) 1,287.40 35.36 106.44 1,235.87 1,194.37 -77.69 249.37 6,029,071.77 558,361.09 3.67 256.67 MWD+IFR2+MS+sag(2) 1,348.87 37.33 107.15 1,285.38 1,243.88 -88.22 284.25 6,029,061.51 558,396.04 3.28 292.40 MWD+IFR2+MS+sag(2) 1,412.52 40.44 105.62 1,334.92 1,293.42 -99.47 322.58 6,029,050.56 558,434.45 5.11 331.53 MWD+IFR2+MS+sag(2) 1,475.06 43.27 104.07 1,381.50 1,340.00 -110.15 362.91 6,029,040.20 558,474.87 4.82 372.16 MWD+IFR2+MS+sag(2) 1,537.81 46.27 102.90 1,426.05 1,384.55 -120.44 405.88 6,029,030.25 558,517.91 4.96 414.93 MWD+IFR2+MS+sag(2) 1,600.51 49.98 101.93 1,467.89 1,426.39 -130.46 451.47 6,029,020.58 558,563.57 6.03 459.89 MWD+IFR2+MS+sag(2) 1,663.10 51.87 101.82 1,507.34 1,465.84 -140.46 499.02 6,029,010.96 558,611.19 3.02 506.57 MWD+IFR2+MS+sag(2) 1,725.14 51.57 100.71 1,545.78 1,504.28 -149.97 546.78 6,029,001.82 558,659.02 1.49 553.21 MWD+IFR2+MS+sag(2) 1,787.36 52.18 101.85 1,584.19 1,542.69 -159.55 594.78 6,028,992.62 558,707.09 1.74 600.09 MWD+IFR2+MS+sag(2) 1,850.69 50.50 102.11 1,623.75 1,582.25 -169.81 643.15 6,028,982.73 558,755.54 2.67 647.62 MWD+IFR2+MS+sag(2) 1,913.82 50.09 103.02 1,664.08 1,622.58 -180.38 690.56 6,028,972.54 558,803.02 1.29 694.44 MWD+IFR2+MS+sag(2) 1,976.00 49.11 103.24 1,704.38 1,662.88 -191.13 736.67 6,028,962.15 558,849.21 1.60 740.21 MWD+IFR2+MS+sag(2) 2,038.75 48.85 103.94 1,745.57 1,704.07 -202.26 782.69 6,028,951.38 558,895.31 0.94 786.06 MWD+IFR2+MS+sag(2) 2,101.51 49.77 103.06 1,786.48 1,744.98 -213.36 828.96 6,028,940.64 558,941.66 1.81 832.13 MWD+IFR2+MS+sag(2) 2,164.00 51.47 103.24 1,826.13 1,784.63 -224.35 875.99 6,028,930.02 558,988.78 2.73 878.82 MWD+IFR2+MS+sag(2) 2,227.29 53.16 101.52 1,864.82 1,823.32 -235.08 924.91 6,028,919.68 559,037.77 3.43 927.05 MWD+IFR2+MS+sag(2) 2,290.27 53.46 100.67 1,902.45 1,860.95 -244.80 974.47 6,028,910.35 559,087.40 1.18 975.38 MWD+IFR2+MS+sag(2) 2,353.30 52.80 100.85 1,940.27 1,898.77 -254.21 1,024.01 6,028,901.32 559,137.01 1.07 1,023.54 MWD+IFR2+MS+sag(2) 2,416.35 53.23 101.08 1,978.20 1,936.70 -263.79 1,073.45 6,028,892.13 559,186.52 0.74 1,071.69 MWD+IFR2+MS+sag(2) 2,479.38 53.15 101.63 2,015.97 1,974.47 -273.73 1,122.93 6,028,882.58 559,236.06 0.71 1,120.04 MWD+IFR2+MS+sag(2) 2,542.48 53.10 98.79 2,053.83 2,012.33 -282.67 1,172.60 6,028,874.02 559,285.80 3.60 1,168.10 MWD+IFR2+MS+sag(2) 2,604.91 52.44 97.38 2,091.61 2,050.11 -289.67 1,221.81 6,028,867.42 559,335.06 2.09 1,214.84 MWD+IFR2+MS+sag(2) 2,668.22 51.41 97.26 2,130.65 2,089.15 -296.02 1,271.24 6,028,861.45 559,384.53 1.63 1,261.47 MWD+IFR2+MS+sag(2) 2,731.34 50.33 97.80 2,170.48 2,128.98 -302.43 1,319.78 6,028,855.42 559,433.11 1.84 1,307.34 MWD+IFR2+MS+sag(2) 2,794.00 49.44 98.96 2,210.86 2,169.36 -309.41 1,367.18 6,028,848.81 559,480.57 2.01 1,352.48 MWD+IFR2+MS+sag(2) 2,857.00 50.56 100.32 2,251.35 2,209.85 -317.50 1,414.76 6,028,841.10 559,528.20 2.43 1,398.28 MWD+IFR2+MS+sag(2) 2,920.25 50.88 100.73 2,291.40 2,249.90 -326.44 1,462.90 6,028,832.53 559,576.40 0.71 1,444.99 MWD+IFR2+MS+sag(2) 2,982.56 49.85 100.52 2,331.14 2,289.64 -335.29 1,510.06 6,028,824.05 559,623.63 1.67 1,490.78 MWD+IFR2+MS+sag(2) 3,045.44 50.99 101.08 2,371.21 2,329.71 -344.37 1,557.66 6,028,815.34 559,671.30 1.94 1,537.08 MWD+IFR2+MS+sag(2) 3,108.60 50.41 101.42 2,411.21 2,369.71 -353.91 1,605.60 6,028,806.18 559,719.30 1.01 1,583.89 MWD+IFR2+MS+sag(2) 3,171.69 52.16 101.59 2,450.67 2,409.17 -363.73 1,653.83 6,028,796.74 559,767.61 2.78 1,631.09 MWD+IFR2+MS+sag(2) 3,234.32 52.97 101.41 2,488.74 2,447.24 -373.64 1,702.57 6,028,787.21 559,816.41 1.31 1,678.77 MWD+IFR2+MS+sag(2) 10/24/2017 5:34:19PM Page 3 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU C-45 Project: Milne Point TVD Reference: MPU C-45 Actual RKB @ 41.50usft Site: M Pt C Pad MD Reference: MPU C-45 Actual RKB @ 41.50usft Well: MPU C-45 North Reference: True Wellbore: MPU C-45 Survey Calculation Method: Minimum Curvature Design: MPU C-45 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/I00') (ft) Survey Tool Name 3,297.36 51.49 101.90 2,527.35 2,485.85 -383.71 1,751.37 6,028,777.53 559,865.29 2.43 1,726.59 MWD+IFR2+MS+sag(2) 3,360.28 52.83 100.28 2,565.95 2,524.45 -393.26 1,800.13 6,028,768.36 559,914.11 2.94 1,774.13 MWD+IFR2+MS+sag(2) 3,422.64 54.16 99.38 2,603.05 2,561.55 -401.81 1,849.52 6,028,760.19 559,963.56 2.43 1,821.75 MWD+IFR2+MS+sag(2) 3,485.49 53.35 99.63 2,640.21 2,598.71 -410.18 1,899.51 6,028,752.22 560,013.61 1.33 1,869.83 MWD+IFR2+MS+sag(2) 3,548.73 52.41 100.07 2,678.37 2,636.87 -418.80 1,949.19 6,028,743.98 560,063.36 1.59 1,917.75 MWD+IFR2+MS+sag(2) 3,611.45 51.87 100.48 2,716.86 2,675.36 -427.64 1,997.91 6,028,735.53 560,112.14 1.00 1,964.92 MWD+IFR2+MS+sag(2) 3,674.21 52.77 99.69 2,755.23 2,713.73 -436.33 2,046.82 6,028,727.22 560,161.11 1.75 2,012.18 MWD+IFR2+MS+sag(2) 3,737.06 52.30 99.79 2,793.46 2,751.96 -444.77 2,095.98 6,028,719.16 560,210.33 0.76 2,059.55 MWD+IFR2+MS+sag(2) 3,800.19 51.34 100.67 2,832.48 2,790.98 -453.58 2,144.82 6,028,710.74 560,259.23 1.87 2,106.81 MWD+IFR2+MS+sag(2) 3,863.12 53.24 99.79 2,870.97 2,829.47 -462.42 2,193.81 6,028,702.28 560,308.29 3.22 2,154.22 MWD+IFR2+MS+sag(2) 3,925.86 53.33 99.91 2,908.48 2,866.98 -471.02 2,243.36 6,028,694.07 560,357.90 0.21 2,202.01 MWD+IFR2+MS+sag(2) 3,988.61 51.58 99.74 2,946.71 2,905.21 -479.51 2,292.38 6,028,685.96 560,406.98 2.80 2,249.29 MWD+IFR2+MS+sag(2) 4,051.69 50.47 98.14 2,986.39 2,944.89 -487.14 2,340.82 6,028,678.72 560,455.47 2.64 2,295.64 MWD+IFR2+MS+sag(2) 4,114.61 53.01 97.49 3,025.35 2,983.85 -493.85 2,389.77 6,028,672.39 560,504.46 4.12 2,342.01 MWD+IFR2+MS+sag(2) 4,177.37 53.67 97.98 3,062.82 3,021.32 -500.63 2,439.65 6,028,666.00 560,554.40 1.22 2,389.24 MWD+IFR2+MS+sag(2) 4,240.61 52.59 98.63 3,100.77 3,059.27 -507.93 2,489.71 6,028,659.09 560,604.51 1.90 2,436.87 MWD+IFR2+MS+sag(2) 4,302.91 51.88 98.71 3,138.92 3,097.42 -515.36 2,538.40 6,028,652.04 560,653.25 1.14 2,483.35 MWD+IFR2+MS+sag(2) 4,365.87 51.32 99.34 3,178.03 3,136.53 -523.10 2,587.13 6,028,644.69 560,702.03 1.19 2,530.01 MWD+IFR2+MS+sag(2) 4,429.12 52.25 99.48 3,217.15 3,175.65 -531.22 2,636.16 6,028,636.95 560,751.11 1.48 2,577.11 MWD+IFR2+MS+sag(2) 4,490.54 52.47 98.92 3,254.66 3,213.16 -539.00 2,684.17 6,028,629.55 560,799.18 0.81 2,623.16 MWD+IFR2+MS+sag(2) 4,554.48 52.23 98.56 3,293.72 3,252.22 -546.69 2,734.20 6,028,622.25 560,849.27 0.58 2,670.95 MWD+IFR2+MS+sag(2) 4,617.40 50.93 99.04 3,332.82 3,291.32 -554.23 2,782.92 6,028,615.09 560,898.04 2.15 2,717.51 MWD+IFR2+MS+sag(2) 4,680.23 50.38 99.56 3,372.65 3,331.15 -562.08 2,830.87 6,028,607.61 560,946.04 1.08 2,763.53 MWD+IFR2+MS+sag(2) 4,743.51 51.72 100.61 3,412.43 3,370.93 -570.70 2,879.32 6,028,599.37 560,994.55 2.48 2,810.36 MWD+IFR2+MS+sag(2) 4,806.83 52.38 101.08 3,451.37 3,409.87 -580.10 2,928.36 6,028,590.36 561,043.66 1.20 2,858.07 MWD+IFR2+MS+sag(2) 4,869.80 52.12 101.47 3,489.93 3,448.43 -589.83 2,977.18 6,028,581.01 561,092.56 0.64 2,905.76 MWD+IFR2+MS+sag(2) 4,932.48 51.99 101.80 3,528.47 3,486.97 -599.80 3,025.60 6,028,571.42 561,141.04 0.46 2,953.19 MWD+IFR2+MS+sag(2) 4,995.87 52.72 101.89 3,567.18 3,525.68 -610.10 3,074.72 6,028,561.50 561,190.24 1.16 3,001.40 MWD+IFR2+MS+sag(2) 5,058.27 52.70 102.05 3,604.99 3,563.49 -620.40 3,123.29 6,028,551.59 561,238.88 0.21 3,049.12 MWD+IFR2+MS+sag(2) 5,121.24 52.18 102.26 3,643.37 3,601.87 -630.91 3,172.08 6,028,541.46 561,287.75 0.87 3,097.14 MWD+IFR2+MS+sag(2) 5,184.25 51.74 102.32 3,682.20 3,640.70 -641.47 3,220.57 6,028,531.28 561,336.32 0.70 3,144.91 MWD+IFR2+MS+sag(2) 5,247.28 52.11 102.48 3,721.07 3,679.57 -652.13 3,269.03 6,028,521.00 561,384.85 0.62 3,192.71 MWD+IFR2+MS+sag(2) 5,310.00 52.71 102.64 3,759.33 3,717.83 -662.94 3,317.54 6,028,510.57 561,433.44 0.98 3,240.61 MWD+IFR2+MS+sag(2) 5,372.67 52.65 102.52 3,797.33 3,755.83 -673.79 3,366.18 6,028,500.10 561,482.16 0.18 3,288.66 MWD+IFR2+MS+sag(2) 5,435.85 52.76 102.05 3,835.61 3,794.11 -684.48 3,415.29 6,028,489.79 561,531.35 0.62 3,337.05 MWD+IFR2+MS+sag(2) 5,498.49 52.51 102.55 3,873.62 3,832.12 -695.09 3,463.94 6,028,479.57 561,580.07 0.75 3,384.98 MWD+IFR2+MS+sag(2) 5,561.59 52.95 102.90 3,911.84 3,870.34 -706.15 3,512.92 6,028,468.89 561,629.13 0.83 3,433.42 MWD+IFR2+MS+sag(2) 5,624.57 52.78 102.46 3,949.86 3,908.36 -717.17 3,561.90 6,028,458.25 561,678.19 0.62 3,481.85 MWD+IFR2+MS+sag(2) 5,687.64 52.64 104.71 3,988.07 3,946.57 -728.96 3,610.67 6,028,446.85 561,727.05 2.85 3,530.44 MWD+IFR2+MS+sag(2) 5,750.15 51.78 107.61 4,026.38 3,984.88 -742.70 3,658.11 6,028,433.48 561,774.59 3.92 3,578.78 MWD+IFR2+MS+sag(2) 10/24/2017 5:34:19PM Page 4 COMPASS 5000.1 Build 81D • 0 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU C-45 0, Project: Milne Point TVD Reference: MPU C-45 Actual RKB @ 41.50usft Site: M Pt C Pad MD Reference: MPU C-45 Actual RKB @ 41.50usft Well: MPU C-45 North Reference: True 1 Wellbore: MPU C-45 Survey Calculation Method: Minimum Curvature Design: MPU C-45 Database: Sperry EDM-NORTH US+CANADA Survey 01000+-i0-007011010111.° " I Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section .0,000-0011-00,0000i " (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,813.20 51.29 109.71 4,065.60 4,024.10 -758.49 3,704.88 6,028,418.06 561,821.48 2.72 3,627.49 MWD+IFR2+MS+sag(2) 5,876.00 51.42 112.91 4,104.83 4,063.33 -776.31 3,750.56 6,028,400.60 561,867.29 3.98 3,676.19 MWD+IFR2+MS+sag(2) 5,938.89 50.06 115.65 4,144.63 4,103.13 -796.32 3,794.95 6,028,380.94 561,911.83 4.01 3,724.77 MWD+IFR2+MS+sag(2) 6,001.93 49.25 118.29 4,185.44 4,143.94 -818.10 3,837.76 6,028,359.50 561,954.81 3.44 3,772.80 MWD+IFR2+MS+sag(2) 6,065.00 48.79 121.78 4,226.81 4,185.31 -841.92 3,878.97 6,028,336.00 561,996.20 4.24 3,820.37 MWD+IFR2+MS+sag(2) 6,127.88 49.94 125.01 4,267.77 4,226.27 -868.19 3,918.80 6,028,310.05 562,036.22 4.31 3,867.87 MWD+IFR2+MS+sag(2) 6,190.84 51.44 128.08 4,307.66 4,266.16 -897.20 3,957.91 6,028,281.35 562,075.56 4.46 3,916.03 MWD+IFR2+MS+sag(2) 6,253.65 52.41 131.67 4,346.40 4,304.90 -928.89 3,995.84 6,028,249.95 562,113.73 4.76 3,964.39 MWD+IFR2+MS+sag(2) 6,316.57 53.35 134.88 4,384.38 4,342.88 -963.28 4,032.36 6,028,215.85 562,150.51 4.33 4,012.78 MWD+IFR2+MS+sag(2) 6,379.46 53.53 134.83 4,421.84 4,380.34 -998.91 4,068.17 6,028,180.50 562,186.60 0.29 4,061.12 MWD+IFR2+MS+sag(2) 6,442.50 53.27 137.48 4,459.43 4,417.93 -1,035.41 4,103.22 6,028,144.29 562,221.93 3.40 4,109.20 MWD+IFR2+MS+sag(2) 6,503.68 53.32 139.08 4,496.00 4,454.50 -1,072.02 4,135.86 6,028,107.94 562,254.85 2.10 4,155.20 MWD+IFR2+MS+sag(2) 6,568.33 53.09 138.16 4,534.72 4,493.22 -1,110.86 4,170.08 6,028,069.37 562,289.37 1.19 4,203.65 MWD+IFR2+MS+sag(2) 6,631.07 53.38 138.46 4,572.27 4,530.77 -1,148.39 4,203.51 6,028,032.10 562,323.09 0.60 4,250.78 MWD+IFR2+MS+sag(2) 6,693.98 53.48 138.83 4,609.75 4,568.25 -1,186.32 4,236.89 6,027,994.44 562,356.77 0.50 4,298.06 MWD+IFR2+MS+sag(2) 6,756.84 53.55 138.34 4,647.13 4,605.63 -1,224.22 4,270.32 6,027,956.80 562,390.49 0.64 4,345.37 MWD+IFR2+MS+sag(2) 6,819.32 53.05 137.74 4,684.47 4,642.97 -1,261.47 4,303.82 6,027,919.82 562,424.27 1.11 4,392.43 MWD+IFR2+MS+sag(2) 6,882.36 52.59 137.08 4,722.57 4,681.07 -1,298.45 4,337.81 6,027,883.11 562,458.54 1.11 4,439.80 MWD+IFR2+MS+sag(2) 6,945.34 52.39 137.01 4,760.92 4,719.42 -1,335.01 4,371.85 6,027,846.82 562,492.87 0.33 4,487.02 MWD+IFR2+MS+sag(2) 6,975.73 52.28 136.86 4,779.49 4,737.99 -1,352.59 4,388.28 6,027,829.37 562,509.43 0.53 4,509.77 MWD+1FR2+MS+sag(2) 7,038.94 52.09 137.22 4,818.24 4,776.74 -1,389.13 4,422.31 6,027,793.10 562,543.74 0.54 4,556.97 MWD+IFR2+MS+sag(3) 7,102.32 52.45 137.06 4,857.03 4,815.53 -1,425.88 4,456.40 6,027,756.63 562,578.12 0.60 4,604.33 MWD+IFR2+MS+sag(3) 7,165.50 52.15 134.94 4,895.67 4,854.17 -1,461.84 4,491.13 6,027,720.95 562,613.12 2.70 4,651.86 MWD+IFR2+MS+sag(3) 7,227.36 52.05 133.47 4,933.67 4,892.17 -1,495.87 4,526.11 6,027,687.19 562,648.37 1.88 4,698.73 MWD+IFR2+MS+sag(3) 7,291.44 52.27 131.32 4,972.98 4,931.48 -1,529.98 4,563.49 6,027,653.37 562,686.00 2.67 4,747.74 MWD+IFR2+MS+sag(3) 7,354.54 52.29 131.29 5,011.58 4,970.08 -1,562.93 4,600.98 6,027,620.72 562,723.75 0.05 4,796.31 MWD+IFR2+MS+sag(3) 7,417.05 52.25 132.04 5,049.84 5,008.34 -1,595.79 4,637.91 6,027,588.15 562,760.94 0.95 4,844.35 MWD+IFR2+MS+sag(3) 7,479.40 52.20 133.51 5,088.03 5,046.53 -1,629.26 4,674.09 6,027,554.97 562,797.37 1.87 4,892.00 MWD+IFR2+MS+sag(3) 7,542.52 52.14 132.31 5,126.75 5,085.25 -1,663.20 4,710.60 6,027,521.32 562,834.14 1.50 4,940.17 MWD+IFR2+MS+sag(3) 7,605.56 52.38 131.67 5,165.33 5,123.83 -1,696.55 4,747.65 6,027,488.26 562,871.45 0.89 4,988.54 MWD+IFR2+MS+sag(3) 7,666.73 52.21 131.60 5,203.97 5,162.47 -1,729.76 4,785.01 6,027,455.35 562,909.06 0.28 5,037.11 MWD+IFR2+MS+sag(3) 7,731.59 52.16 132.40 5,242.51 5,201.01 -1,762.99 4,821.91 6,027,422.42 562,946.21 1.01 5,085.29 MWD+IFR2+MS+sag(3) 7,793.71 52.23 133.57 5,280.59 5,239.09 -1,796.45 4,857.81 6,027,389.24 562,982.37 1.49 5,132.70 MWD+IFR2+MS+sag(3) 7,856.70 52.35 133.97 5,319.11 5,277.61 -1,830.92 4,893.80 6,027,355.05 563,018.62 0.54 5,180.65 MWD+IFR2+MS+sag(3) 7,919.60 52.38 133.48 5,357.52 5,316.02 -1,865.35 4,929.79 6,027,320.91 563,054.89 0.62 5,228.60 MWD+IFR2+MS+sag(3) 7,982.61 52.37 133.77 5,395.99 5,354.49 -1,899.78 4,965.92 6,027,286.76 563,091.28 0.36 5,276.65 MWD+IFR2+MS+sag(3) 8,045.40 52.16 133.19 5,434.42 5,392.92 -1,933.95 5,001.95 6,027,252.88 563,127.57 0.80 5,324.51 MWD+IFR2+MS+sag(3) 8,107.84 52.03 133.00 5,472.78 5,431.28 -1,967.61 5,037.93 6,027,219.51 563,163.80 0.32 5,372.07 MWD+IFR2+MS+sag(3) 8,170.58 51.28 133.51 5,511.70 5,470.20 -2,001.33 5,073.76 6,027,186.07 563,199.90 1.35 5,419.54 MWD+IFR2+MS+sag(3) 8,234.00 49.51 133.93 5,552.13 5,510.63 -2,035.10 5,109.08 6,027,152.59 563,235.47 2.84 5,466.57 MWD+IFR2+MS+sag(3) 10/24/2017 5:34:19PM Page 5 COMPASS 5000.1 Build 81D 0 • Halliburton Definitive Survey Report Company: HilcorpAlaska,LLC Local Co-ordinate Reference: Well MPU C-45 Project: Milne Point TVD Reference: MPU C-45 Actual RKB @ 41.50usft Site: M Pt C Pad MD Reference: MPU C-45 Actual RKB @ 41.50usft Well: MPU C-45 North Reference: True Wellbore: MPU C-45 Survey Calculation Method: Minimum Curvature I Design: MPU C-45 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,296.58 48.14 132.96 5,593.33 5,551.83 -2,067.49 5,143.27 6,027,120.46 563,269.92 2.48 5,511.97 MWD+IFR2+MS+sag(3) 8,359.30 47.36 132.73 5,635.50 5,594.00 -2,099.06 5,177.31 6,027,089.16 563,304.20 1.27 5,556.85 MWD+IFR2+MS+sag(3) 8,422.08 45.90 132.15 5,678.61 5,637.11 -2,129.86 5,210.99 6,027,058.63 563,338.11 2.42 5,601.04 MWD+IFR2+MS+sag(3) 8,484.99 44.55 132.62 5,722.92 5,681.42 -2,159.96 5,243.98 6,027,028.79 563,371.33 2.21 5,644.29 MWD+IFR2+MS+sag(3) 8,547.93 42.63 132.90 5,768.50 5,727.00 -2,189.42 5,275.84 6,026,999.58 563,403.42 3.07 5,686.25 MWD+IFR2+MS+sag(3) 8,610.83 42.26 133.85 5,814.92 5,773.42 -2,218.57 5,306.69 6,026,970.68 563,434.50 1.18 5,727.18 MWD+IFR2+MS+sag(3) 8,673.65 41.22 133.61 5,861.79 5,820.29 -2,247.48 5,336.91 6,026,942.01 563,464.94 1.67 5,767.43 MWD+IFR2+MS+sag(3) 8,736.54 40.10 133.98 5,909.50 5,868.00 -2,275.84 5,366.49 6,026,913.88 563,494.74 1.82 5,806.86 MWD+IFR2+MS+sag(3) 8,800.23 38.78 134.80 5,958.69 5,917.19 -2,304.14 5,395.41 6,026,885.81 563,523.87 2.23 5,845.68 MWD+1FR2+MS+sag(3) 8,863.31 37.04 136.09 6,008.46 5,966.96 -2,331.75 5,422.60 6,026,858.42 563,551.28 3.03 5,882.65 MWD+IFR2+MS+sag(3) 8,926.69 35.74 136.04 6,059.47 6,017.97 -2,358.83 5,448.69 6,026,831.55 563,577.57 2.05 5,918.39 MWD+IFR2+MS+sag(3) 8,988.90 34.63 136.57 6,110.32 6,068.82 -2,384.74 5,473.46 6,026,805.83 563,602.54 1.85 5,952.42 MWD+IFR2+MS+sag(3) 9,051.89 33.34 137.25 6,162.55 6,121.05 -2,410.45 5,497.51 6,026,780.31 563,626.79 2.13 5,985.73 MWD+IFR2+MS+sag(3) 9,115.00 32.07 137.95 6,215.65 6,174.15 -2,435.63 5,520.51 6,026,755.32 563,649.98 2.10 6,017.85 MWD+IFR2+MS+sag(3) 9,178.70 30.48 137.73 6,270.09 6,228.59 -2,460.14 5,542.70 6,026,730.98 563,672.36 2.50 6,048.96 MWD+IFR2+MS+sag(3) 9,240.67 29.73 137.31 6,323.70 6,282.20 -2,483.07 5,563.69 6,026,708.22 563,693.53 1.26 6,078.25 MWD+IFR2+MS+sag(3) 9,303.77 30.11 138.74 6,378.39 6,336.89 -2,506.47 5,584.74 6,026,684.99 563,714.76 1.28 6,107.82 MWD+IFR2+MS+sag(3) 9,365.87 30.62 138.94 6,431.98 6,390.48 -2,530.10 5,605.40 6,026,661.52 563,735.60 0.84 6,137.15 MWD+IFR2+MS+sag(3) 9,429.67 30.63 138.14 6,486.88 6,445.38 -2,554.46 5,626.92 6,026,637.34 563,757.30 0.64 6,167.59 MWD+IFR2+MS+sag(3) 9,492.71 30.11 138.41 6,541.27 6,499.77 -2,578.25 5,648.13 6,026,613.72 563,778.70 0.85 6,197.48 MWD+IFR2+MS+sag(3) 9,555.64 29.66 136.77 6,595.83 6,554.33 -2,601.40 5,669.27 6,026,590.73 563,800.02 1.48 6,227.02 MWD+IFR2+MS+sag(3) 9,618.51 30.30 136.57 6,650.29 6,608.79 -2,624.25 5,690.83 6,026,568.05 563,821.76 1.03 6,256.78 MWD+IFR2+MS+sag(3) 9,681.38 30.23 136.97 6,704.59 6,663.09 -2,647.34 5,712.53 6,026,545.14 563,843.64 0.34 6,286.78 MWD+IFR2+MS+sag(3) 9,744.00 30.40 136.55 6,758.65 6,717.15 -2,670.36 5,734.19 6,026,522.29 563,865.47 0.43 6,316.70 MWD+IFR2+MS+sag(3) 9,807.58 30.73 137.68 6,813.39 6,771.89 -2,694.05 5,756.19 6,026,498.77 563,887.65 1.04 6,347.25 MWD+IFR2+MS+sag(3) 9,870.09 30.57 139.13 6,867.17 6,825.67 -2,717.88 5,777.34 6,026,475.11 563,908.99 1.21 6,377.11 MWD+IFR2+MS+sag(3) 9,933.05 29.93 139.12 6,921.56 6,880.06 -2,741.86 5,798.10 6,026,451.29 563,929.93 1.02 6,406.70 MWD+IFR2+MS+sag(3) 9,996.11 29.53 139.83 6,976.32 6,934.82 -2,765.63 5,818.42 6,026,427.68 563,950.43 0.85 6,435.79 MWD+IFR2+MS+sag(3) 10,058.79 30.03 140.43 7,030.72 6,989.22 -2,789.53 5,838.37 6,026,403.95 563,970.57 0.93 6,464.63 MWD+IFR2+MS+sag(3) 10,121.87 29.95 137.44 7,085.36 7,043.86 -2,813.29 5,859.08 6,026,380.35 563,991.46 2.37 6,494.07 MWD+IFR2+MS+sag(3) 10,185.08 30.00 134.65 7,140.11 7,098.61 -2,836.02 5,880.99 6,026,357.79 564,013.55 2.21 6,524.09 MWD+IFR2+MS+sag(3) 10,232.37 30.42 132.91 7,180.98 7,139.48 -2,852.48 5,898.17 6,026,341.47 564,030.86 2.05 6,546.98 MWD+IFR2+MS+sag(3) 10,262.00 30.42 132.91 7,206.53 7,165.03 -2,862.70 5,909.16 6,026,331.34 564,041.92 0.00 6,561.48 PROJECTED to TD mitchell.lairdphalliburton.com Michael Calkins °""'"""""- Checked By: 2017.102414:3920-08.00• Approved By: ,,,„- ��--��^ Date: 1 0/24/1 7 10/24/2017 5:34:19PM Page 6 COMPASS 5000.1 Build 81D III • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. MP C-45 Date Run 4-Aug-17 County State Alaska Supv. J.Lott/D.Yessak CASING RECORD I Surface IX TD 7,020.00 Shoe Depth: 7,015.00 PBTD: 6,887.00 No.Jts.Delivered 178 No.Jts.Run 169 No.Jts.Returned 9 Ftg.Delivered 7,340.00 Ftg.Run 6,967.86 Ftg.Returned 373.10 Length Measurements W/O Threads Ftg.Cut Jt. 31.00 Ftg.Balance 342.00 RKB 26.70 RKB to BHF 25.85 RKB to CHF RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Float Shoe 9 3/4 40.0 L-80 DWC/C HES 1.60 7,015.00 7,013.40 1 Shoe It 95/8 40.0 L-80 DWC/C 41.61 7,013.40 6,971.79 Flt Clr 9 3/4 40.0 L-80 DWC/C 1.31 6,971.79 6,970.48 3 Flt Its 95/8 40.0 L-80 DWC/C 82.25 6,970.48 6,888.23 Bfl Adpt 9 3/4 40.0 L-80 DWC/C HES 1.59 6,888.23 6,886.64 116 Casing Its 95/8 40.0 L-80 DWC/C 4,668.47 6,886.64 2,218.17 Csg Pup 9 5/8 40.0 L-80 DWC/C 19.13 2,218.17 2,199.04 ES CMTR 97/8 40.0 L-80 DWC/C HES 3.92 2,199.04 2,195.12 ke Csg Pup 95/8 40.0 L-80 DWC/C 19.59 2,195.12 2,175.53 168 Casing Its 95/8 40.0 L-80 DWC/C 2,151.89 2,175.53 23.64 1 Cut It 95/8 40.0 L-80 DWC/C 23.64 23.64 0 Csg Wt.On Hook: 300 Type Float Collar. HES No.Hrs to Run: 23.5 Csg Wt.On Slips: 275 Type of Shoe: HES Casing Crew WOT Rotate Csg Yes X No Recip Csg X Yes No 15 Ft.Min. 9.5 PPG Fluid Description: Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: _Yes_No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: 1 @ 10'each end shoe jt.1 Mid Tube Float Jt.1 Mid tube Ball Jt.1 every other jt to 6100'.1 every jt for 3 jt above and below Stage tool.20 total run CEMENTING REPORT Shoe @ 7015 FC @ 6,970.48 Top of Liner Preflush(Spacer) Type: Tunned Spacer III Density(ppg) 10.5 Volume pumped(BBLs) 60 Lead Slurry Type: HWS I/II Sacks: 700 Yield: 2.47 Density(ppg) 11.7 Volume pumped(BBLs) 304 Mixing I Pumping Rate(bpm): 6 Tail Slurry t- w Type: Prem G Sacks: 215 Yield: 1.16 r Density(ppg) 15.8 Volume pumped(BBLs) 43.2 Mixing/Pumping Rate(bpm): 2 h Post Flush(Spacer) y �/ L2 Type: Density(ppg) Rate(bpm): Volume: l a LL Displacement: Type: Spud Mud Density(ppg) 9.5 Rate(bpm): 6 Volume(actual/calculated): 295/295.7 FCP(psi): 825 Pump used for disp: RIG Bump Plug? X Yes No Bump press 1325 Casing Rotated? Yes X No Reciprocated? X Yes No %Retums during job 98 Cement retums to surface? X Yes No Spacer retums? X Yes No Vol to Surf: 78 Cement In Place At: 8:00 Date: 8/11/2017 Estimated TOC: 2,195 Method Used To Determine TOC: STAGE TOOL Stage Collar @ 2195 Type HES Closure OK Yes Preflush(Spacer) Type: TUNNED III Density(ppg) 10.5 Volume pumped(BBLs) 60 Lead Slurry b)° Type: PERM L Sacks: 351 Yield: 4.33 Density(ppg) 10.7 Volume pumped(BBLs) 297 Mixing/Pumping Rate(bpm): 6 Tail Slurry � tf4 Type: PREM G Sacks: 180 Yield: 1.17 Y y Density(ppg) 15.8 Volume pumped(BBLs) 39 Mixing/Pumping Rate(bpm): 2 z Post Flush(Spacer) c°: Type: Density(ppg) Rate(bpm): Volume: w v+ Displacement: Type: SPUD MUD Density(ppg) 9.5 Rate(bpm): 6 Volume(actual/calculated): 167.8/167 FCP(psi): 490 Pump used for disp: RIG Bump Plug? X Yes No Bump press 990 Casing Rotated'? Yes X No Reciprocated? Yes X No %Returns during job 98 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 224 Cement In Place At: 18:45 Date: 8/4/2017 Estimated TOC: 0 Method Used To Determine TOC: RETURNS TO SURFACE Post Job Calculations: Calculated Cmt Vol @ 0%excess: 398.5 Total Volume cmt Pumped: 683.2 Cmt returned to surface: 302 Calculated cement left in wellbore: 381.2 OH volume Calculated: 381.8 OH volume actual: 381.2 Actual%Washout: WELLHEAD Make Sea Board Type Multibowl Serial No. Size 11 W.P. 5000 Test head to 3780 PSIG 15 MIN y OK www.wellez.net WellEz Information Management LLC ver_102716bf • • Hilcorp Energy Company CASING &CEMENTING REPORT Lease&Well No. MP C-45 Date Run 15-Oct-17 County State Alaska Supv. S.Sunderland/S.Barber CASING RECORD Intermediate w TD 10,262.00 Shoe Depth: 10,258.92 PBTD: 10,132.60 No.Jts.Delivered 235 No.Jts.Run 235 No.Jts.Returned Ftg.Delivered 10,258.92 Ftg.Run 10,258.92 Ftg.Returned Length Measurements W/O Threads Ftg.Cut Jt. 23.25 Ftg.Balance 10,235.67 RKB 26.70 RKB to BHF 25.85 RKB to CHF RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Float Shoe 6 17.0 P-110 BTC HES 1.82 _ 10,258.92 10,257.10 3 Casing 51/2 17.0 P-110 BTC Tenaris 123.09 10,257.10 10,134.01 1 Float Collar 6 17.0 P-110 BTC HES 1.41 10,134.01 10,132.60 233 Casing 51/2 17.0 P-110 GeoConn Tenaris 10,132.60 10,132.60 0 Csg Wt.On Hook: 150,000 Type Float Collar: Conventional No.Hrs to Run: 29 Csg Wt.On Slips: 115,000 Type of Shoe: Conventional Casing Crew: Doyon Casing Rotate Csg X Yes No Recip Csg X Yes No 20 Ft.Min. 17 PPG Fluid Description: 10.5 LSND mud Liner hanger Info(Make/Model): Slips Liner top Packer?: Yes X No Liner hanger test pressure: 5000 Floats Held X Yes No Centralizer Placement: CEMENTING REPORT II Shoe @ 10258.92 FC @ 10,134.01 Top of Liner 7Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 11.5 Volume pumped(BBLs) 27.5 Lead Slurry Type: Premium Class"G" Sacks: 375 Yield: 1.15 Density(ppg) 15.8 Volume pumped(BBLs) 76 Mixing/Pumping Rate(bpm): 4 Tail Slurry w Type: Sacks: Yield: F Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): u) Post Flush(Spacer) 1- Ix Type: H2O Density(ppg) 8.3 Rate(bpm): 5 Volume: 20 a Displacement: Type: LSND Density(ppg) 10.5 Rate(bpm): 6 Volume(actual/calculated): 217.5/215.75 FCP(psi): 800 Pump used for disp: Rig#2 Bump Plug? X Yes No Bump press 1300 Casing Rotated? X Yes No Reciprocated? X Yes No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 1:07 Date: 10/16/2017 Estimated TOC: 8,470 Method Used To Determine TOC: Calculated Post Job Calculations: Calculated Cmt Vol @ 0%excess: 48.4 Total Volume cmt Pumped: 76 Cmt returned to surface: 0 Calculated cement left in wellbore: 76 OH volume Calculated: 132.4 OH volume actual: 132.4 Actual%Washout: www.wellez.net WellEz Information Management LLC ver_102716bf • • V' ( {'v c o E co co cd E u i c f 0 • C co . N co C O O Is;j ........„ iri X N a) I-L.a O c *. o 0 _ Oa, �, o O N ` ami � a 0 0 0 4ICCCa 0) � d .0 o 75 ._ . ... — w aa)iNZEQ OS OS 0 • 0 - QwZU N N 4.... V co CO C r ti N- .1.J C aw N. N- ca Z O 0 to 0 0_ N- 0 0 f� 2 C 0 O O C 'O 0 J 1- a f N Z Z N O a) Q. J m i — o n1 0 N LI-) N d E Z L O O O L ' - E , N o 0 Lo cz - c N Q L L O i � O � a) N 4.0 m O n' a) - t) n3 o O OV : 13 tr) ^O Cl)U) a) I.i c a 'a o a Q a a) ami M O ca L E m 13) 0 C 1i i ai ��. ,,1-: ai ,L.: ai ai E -- >— r ^ iiiV L03 a) 4.., -t V' 0 2 >CU Z o Z o 0 - U 75 LL (n LEa J p U = L N LL o Q a 0 > > . O J i a) C1 Z z U a) ca103 U) E Ci)°' " - i �� m m Z a - co t6 i N L ', H Fes- = �' c • • o O 0 O 0 O O O T) Cl) a� Cl) a) u ) m m m m m m m m m 0 "O 'p "O 'D V V a a) a) a) a) a) a) a) a) ' in U) n U) J : J J J J 11- .J L L a) Cl)OL V C L C a) a) L C a) C N O N p ? 0 • co to 1.0 co N- I,- N N CX) C) V' CO CO CO CO 0) O N. O 0) N. O O CO ti CO O 0 CO N �- 0) CO 'd' 6) O N ct 0 CO CO .- 0 CO CO N. CO LO CO Lf) 0) CO LO LI) N N r O 0 0 0 0 0 0 CO t- O N O O O O O O O O O O O O O O O N - O O O O O O O O O O O O O O O N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O 0 O O O 0 0 0 0 0 O 0 0 0 O O O O 0 0 O 0 O 0 0 0 0 0 0 0 0 0 0 O 0 O 0 O O O O O O O O O O O O O O O O O O O LU O O O O O O O O O O Lf) LU O O Lf) O OO Co CO CO CO CO CO 0 CD CO CO CO r r r r N C 0 0 0 7 �t o L L L co O °) N Ln Z T) m m �, up r o c° �r ca co .jr, rn CO 'ct cts coo ca i CDr) 'p -p C N CO C? CO •C N C r .0 N in O i '� CO C O a) a) a) O co CO O Q i p. r Q '`,Jr ti O O N Q O p N 'inp CO . O O p O p p N. N N. r '4' 0 CO 0 C CC) N. O O •- C) I. rt ,- � NCO CO CO rt _I J J CO CD C) C) Q. Ln n. CO n. CO N. r N. C r d C) EC NJ (U C C6 -o C i) co 2 z CO U) L E . U r p 0 a) N a) C E C6 C Cn - U a) as E o o a ''''0 o m o a) '_ Ts p aa) its CO a E L _o cis -- C) a) T) CO E E > "'" .y r E C -o c ) E2 cc '- ' a3— co is m > p E m cn _ F2 co` a) = CO > E o `p _ x aa)co m E o 0 0 D c' c COIt a) 0 2 o_ It 0 1 0 CL CO W 0 I n < CL CO CO 0 0 0 Z co a) E' as C CO a) m Q o C C a) CO 7c3 Zs a) U) 0 x a) a) L .0 C C 2i -t a) as To 76 I Ia) 0 E. Z F a) J _1 @ O W a) Z 0 o as I Co Z mm ' • • W c' T co z O O Y ti Oat- OC CO M C.)• c U)co O 7 C i a) c O O I- U) _p = U) 00 c - E � O co, 01w c N- N CO c- N. c- C) N. N- 0,.. "I- N CO ti N- N. CO CO - CD CO N CD 0 O O CD 0 CD O O CD CD CD O 0 CD CD CD O 0 0 O O O O O O O O O O CD CD O O CD CD CD CD U) c 0 CD O 0 O CD CD CD CD CD CD = U) CD 0 0 CD O O CD CD CD CD C 2 CDO CD CD CD O O CD O O O 0 O OO CD 0 NO CD CD O O 0 a) LI) O O r- <- Lf) O O Y .c O CD CO -. T 7 co O t° a 0 co >, E m O O U) O m > m 3 00 O ••c a' ch L'' co -o m g o N- ti N N O O CO •co N 3 m N CO CO N 1 Ln a) co >. 0 > OdO -L.-. _ to O a N- 2 a a) ) 1-- M O p Ln O c CV N- - a L( N C) 0_ C) d N- c c o- O CD a:1 c m E >.r. T C co o 0 L 2 0 T ' a) N N 10 a `.. 0) 0-0 CU CZ a) a) E a) cu = °w E `-� L fl. A O (�2 CZ >' a) .0 O` �O O a a) �, X .: 0 E j, C3 0 p N O c.0 T 0 a) - 4E C) Eoo 4. r (i) o 0 a m v a) .E 2 71 (.7) 3 0 o O cB a O 0 cC0 c E 7 O p ~ up) a) E u) 0 > o 0 _ c >,L a) C i Q La a "p 2 L, ca .E .- 2 L N c) Q E i2 m OL O O O ( U N o) O E O n m C a d 70 O .O N 0_ U) U) U) U < '- a < U) c L_• 3 u)Q 2-0 2 - C c m-0 n ca - c0 O•- O R a o N L O co 72' EN EN 0-0 C O O a 00 0 •0 cc `pa NLL y4- `) .cU =O_ m N N ct c 0 0 >« -0... O a° ° c �• Eo a .3 Em ON T x 'OTD- ,--"' O C O O • E 8 a E CO 0 U L.. a 'EL O • C (p 0 0 0) ao u).0 C 0 0 0'.= N C Ecco >2 7L 5, o m o 0 E >'- O -O p c a) o2 •c as ti m • € 8 O 0 0 0 > ..0 o c w a) 1-cc .% o 0) cc Z • • HALLI B U RTO N Sales Order# 904385503 Hilcorp Alaska, LLC A)orc MPC-45 Interval 1 Cas; -P .,e- Kuparuk C Sand Formation \ (54/z," ) Beechey Point County,AK API: 50-029-23579 Prepared for:Jim Fagnant October 27, 2017 Stimulation Treatment Post Job Report Hybor 30# Prepared By: Jonathan Alcantar Alan Kaiser Nanook Crew Notice:Although the information contained in this report is based on sound engineering practices,the copyright owner(s)does(do)not accept any responsibility whatsoever,in negligence or otherwise,for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise.The application,therefore,by the user of this report or any part thereof,is solely at the user's own risk. • HALLIBURTON pr ade.c,R.aeon • Lnhmcamamant Table of Contents Section Page(s) Executive Summary 3 Actual Design 4 Interval Summary 5-6 Well Summary 7 Interval 1 Plots 8-17 Appendix 18 Chemical Summary 19 Planned Design 20 Event Logger 21 Water Straps Day 1 22 15 Min FANN 23 Bacteria Testing 24 Water Report 25 Lab Testing 26-27 Broken Samples 28-30 HilCorp-MPC-45 TOC 2 • Engineering Executive Summary On October 27,2017 a stimulation treatment was performed in the Kuparuk C Sand formation on the MPC-45 well in Beechey Point County,AK. The MPC-45 was a 1 stage Casing Single Design. The proposed treatment consisted of: 12,180 gallons of 20#Linear 7,140 gallons of 30#Linear 52,760 gallons of 30#Hybor G 4,116 gallons of Freeze Protect 167,305 pounds of CarboBond Lite 16/20 The actual treatment fully completed 1 of 1 stages.0 stages were skipped,and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 13,116 gallons of 20#Linear 7,128 gallons of 30#Linear 53,824 gallons of 30#Hybor G 3,454 gallons of Freeze Protect 167,220 pounds of GarboBond Lite 16/20 A more detailed description of the actual treatment can be found in the attached reports.The following comments were provided to summarize events and changes to the proposed treatment: Halliburton is strongly committed to quality control on location. Before and after each job all chemicals,proppants,and fluid volumes are measured to assure the highest level of quality control.Tank fluid analysis,crosslink time,and break tests are performed before each job in order to optimize the performance of the treatment fluids. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well.We hope to be your solutions provider for future projects. Thank you, Jonathan Alcantar Technical Professional Halliburton Energy Services HilCorp-MPC-45 Executive Summary 3 t \ N ., Q , or . N • `n 8 S 8888888888 VI - 0-3 " • ' 8 � iW _ omm ~ ~ moo 1m � m . „ 00 00 oaoo 3 a cid d cid d88 8888T8mT0o888 Vg '- 2 ° e 11 '6: 88 8 8 8 8 8 8 8 8 8 8 8 8 8 8 3 . , ts= .. .4 .4 .4 .4 .4 .4 .4 ., .4 .. ., .. ri a m "I « R 0 « « N 0 « 8 PIP! 8 0 m a o 0 0 0 0 0 0 0 0 o u - .40 Y 1g n \N m m v q . .1-; 6V' u V o 0 0 0 0 0 0 0 0 0 0 0 o u e Ail 0000000000000 \aa , 0 0 8 N §` `9 � 8 8 8 „ . , S S 8 8 8 8 �$ % N ? EEiEEmq g ° a _ 7. 2 E 1-61' o 0 P .r, 888mUN888 R 15 x 411E r - a « 0 W .. $ 30 . I ii ce - :72' . « m n r. m m 2 , . E 3E1 a o yoff r v 0 — ro L., = Q 1101 -5 r ;, -,!, g. m « .gee ,^ � , « m E � c. 3 o E R o i 8 § 588 § E � r oe m� a « « « mmMm ate « va g g n E 0 0 o im m m m M M 4 m m m M 8 8 m M "i, C o .9 t. o g � « Me � grg ,. � cn °d N o u `ro n` as dg 1111111 B ° 2282 $ 22 3 3 3 3 3 3 3 3 3 3 e Ee 'eaga E. � � x EE EE 0 0 0 0 0 0 0 0 0 0 0 0 . g, < . S S , S S a 8 t 8 8 a S a - , 8 g 8 n. HmHi w o� 8 5 z « m . m m r• m r, ,. « « u t. V g '' .9L6966696646@ ¢ ti g ynredn) d Pi ,,e—mpue U I • 0 Interval Summary MPC-45-Kuparuk C Sand-Interval 1 Interval Summary Date: 10/27/2017 Start Time: 2:25:00 PM End Time: 6:15:00 PM Initial Rate(Breakdown): 2.0 bpm Initial Pressure(Breakdown): 2873 psi Max Rate: 32.1 bpm Max Pressure: 3305 psi Max Pressure(SLF): 3302 psi Average Rate: 28.8 bpm Average Pressure: 2592 psi Average Missile Pressure 2697 psi Average Missile HHP: 1904 hhp Average Visc: 27 cP Average Temp: 70 F Average pH: 10.5 ISIP: 2009 psi Initial Fracture Gradient: 0.733 psi/ft 5 min: 1928 psi 10 min: 1790 psi 15 min: 1615 psi ISDP: 2569 psi Final Fracture Gradient: 0.817 psi/ft 5 min: 2332 psi 10 min: 2279 psi 15 min: 2232 psi Proppant Summary CarboBond Lite 16/20 Pumped: 164,349 lbs Total Proppant Pumped* : 164,349 lbs Proppant in Formation: 164,349 lbs Fluid Summary(by fluid description) 20#Linear Volume: 13,116 gal 312 bbls 30#Linear Volume: 7,128 gal 170 bbls 30#Hybor G Volume: 53,824 gal 1,282 bbls Freeze Protect Volume: 3,454 gal 82 bbls Fluid Summary(by stage description) Load Well Volume: 5,124 gal 122 bbls Pad Volume: 11,540 gal 275 bbls Proppant Laden Fluid Volume: 39,700 gal 945 bbls Sweep Volume: 2,584 gal 62 bbls Flush Volume: 7,128 gal 170 bbls MiniFrac Volume: 7,992 gal 190 bbls Freeze Protect Volume: 3,454 gal 82 bbls Treatment Volume: 77,522 gal 1,846 bbls Total Fluid Volume: 77,522 gal 1,846 bbls Interval Summary 5 • Interval Status: Completed Comments: Pumped to design Engineer: Jonathan Alcantar Treater.' Chad Burkett Supervisor: Alan Kaiser "Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Jim Abel Interval Summary 6 • • /®\ /) \) \) 79 (ƒC �~ \ ®\ ® \ \}/ \ *( \ ® ((\\} 2 2 {{! 0,ii ' ; ! § } { `i `6& « : ! & 2 $ 2 { \ Ai / r tiEE . / 5 §r 5 } z 0 a ® @ ° I - e !Z\: @/k E\ k ^ §{ ;)/\§ } E 7 - ,! / 1 ! ! _ t 1 • • co U O O\ 00 S N d' en N .--, O 1 1 , 1 , 1 , 1 , 1 , 1 1 , 1 , 1 , 1 O ON 00 O C) O Q O 0 0 0 ^ Oo a 1 , 1 1 , 1 iii 1 , 1 , 1 . J Oc 4 o o N v' d 0 1 � d2VU _�N d. ,0 4 c 0. rsi v, H ii ;tl1. 4 - '-. Fr?) E" 0 s. M 7,-5: , `�i o (-----"J 0 H L N to as +-' a a co n0 0 ci) W p4 c) 0 0 0 H � 0� 0 0 0 f/1 a ' N en CV W = r+: 1 - _M ON tt fl .CApm P v1.0 _S iZG O v ..__El o cW � U C 0 a �, o � o D D $:10 _ W/ C O o WI � �t1 . �' eu H FM IZA I= g po O CI, ^'N f..' VJ 0 Cd 03 4 0.1 cu 0 CD a.ao = — HE"0C) CAC4 a a C) OT 00 S qO VI 'Cr en N .--- v u 0 E- o o v _ x • U O 00 O N 0 I I I I , I , 1 pa 8 r. 0000 O NN 0 1 I , I I I O o MM rr ) r 0 0 1 h��•1 Oi/ V O O 1 N 00 s N V' n M 6 O N .M-. en MN ~C b y Q n Q .�..t1 2.. .D t" _ ' F. E-. N I IL-6N 0 16 O a' 76 a ) N W o 0 0 E—+ 0 0 0 0 0 0 .^ - (0 o0 C:21061 ~ 1-. N N ate, s� % - MM an cn cn 42 14 aw N o c - o a b CU a.) C o o b co) in V1 '.. M N 0 Q H F V1 c4 a a s 1 I I I P 0 0 00 Ls, I II- 2- o`o u i • i 0 ,. U o o, 00 N ',I tet- en N o GQ S rn 00C o C o C 0 en 0 0 0 0 i.E U U z 4o • n ~O cp H _ � --1 1-4 1— • 00 — a„+ O O a N _ cu _ems A., 'It 0 _ ••••1 cct N , _en \ _ CA eaki) m0 \—(71 III ! = = •. H toCA co .c.- N _ r Q § § o § § o § S o § u cia 0 • • U 0, 00 r-- .0 in d- M N — i , i 1 1 1 1 1 1 1 1 1 1 , 1 1 1 1 1 gc) O O O O O O O O O O o r-+ CA 00 t-- ‘.0 kr) 'ct Cr) N - 0 I I I I 1 I 1 I I I r � r , _ a - O 8 O N ~ o N —�O 8 1/4O O N0To To 7 p -, CCS woo Qpj ri) C140 CIO •ftwo/ � O V C Q i.� cu E o cts m.• aoO PV, O dN a •.-. dN 1.4 �yy O W x H vl pa 'i iiiiiiiii S r a� • • N H utr, 0 0 Lc) O 0 MI .-I , 0 N o P4/ r r O o ..., z •........` 0 _ .. • .._ 0 0 ry -411111 i....i la O 3 N • VI _ ' - 0 a o H C to 0.10 CI t- C.) a,o Cc 0 Et= V c CA � � • C_ o E4. a ~o Hv) v) gel i i l i 1 ¢ ?8 0 0 0 0 U a a 0 U = • • M m o Ln o Ln o CD • CO N N . O O Q O� 0 LO cv ,:l•N . V-O To O) - 2 0 - 0 Ln o -.4- •t••- d• O • _ N - N Qm . - C-... -Oo 73 A- --y a) 7. U - vg E rn� �r s o U Ln N V m Qm 1 • m ro cu • c o U =o - U V Da N ' LOo ++ (V N It a 0O c}'N Q O co co .4; N O CO Co .t N 0 N v- .— r- V— r— O6 O O CU v u a a `0 u x • • a CO 0 U) 0 U) O U) 0 MN N O O Q _ 2 , O ° "N j c CON j O 1 (0 c - O 2 0 Tri co5 U iiir j_.__.....—...--- C O U Cfl LO —.......} — - •• C Qm O I N I - O o --` • o m _ _ 2 a aI ali • - co m U c - E • • - o UO v co ) —o � _ U (..) 0 _ • a) �- sa • J 0.. 0 C0 L mam O To m c I's 2 O� O C ON ♦U U .IIIItiN V _ _ r0 D N O J ti- 00 UO . O 00 .o .4; N O c0 COV.. N O N t- V— C— V- 6 6 6 6 v 0 6 F2- 0 0 U • • in 0 N VO O p may{n Q'N 2 - 0 • - `1" O 2 N d • r O _'r T.• ,r To - 0, N - C c O gM N 0 �- _O o Ur E. CL > N Z V Q CO F. c E .4. • _..cU ........ D i+) Q _ N To M cmm rn U C O^ U 0 01" O O �o c`) - .- 7 U, 0 Qd Cr) N O q U a n 0 o •x • . lID a0 0 0 o O ,r CO N O i i I - I NN 0 o0N T.--Oz – c 3 ...- 1 O I — 13111F--- iLr r C N o _.. ' 0 • , coMki. of o CL d • z a 0 Q I E •.. • O Un! —S CI. 0 Q • 0 w_ O 2 c N N-N V-O 0 C - 0 0 0 0 0 Cr) W 0 J Q d M N O a U a D. `o _U • . N m 0 N O CD V- - co Co ':1- N O I , I , I I I z { 1 11 z 0 a j a / F ... "3-1.---Lipth • -I-, CD C U) a) z N ^ c (1) Z Qm0 c E -. t6 0 Er) o •7 o s7-.� N Q. N 7 toCri i C N M 002 _ U a n `_ 03 •E' 2 r-- -o � Z _ o Q4— •In---- -F u U O o a) 8_ d Z m u) I o E 0 o P. mco r co vo v 4i N 1 mm n. co ,n 4 m N O O O < O O O� 0 T- ul T- a a c- .a `o u I • i HALLIBURTON66466 66 6666 µF Hilcorp Alaska, LLC MPC-45 Interval 1 Kuparuk C Sand Formation Beechey Point County,AK API: 50-029-23579 Prepared for:Jim Fagnant October 27, 2017 Stimulation Treatment Appendix - Chemical Summary - Planned Design - Event Logger - Water Straps Day 1 - 15 Min FANN - Bacteria Testing - Water Report - Lab Testing - Broken Samples HilCorp-MPC-45 Appendix 18 • 01 call 0 n N N 0 u. a 0 o m o N Q. > O -13 Q Z" 0 l0 00 w -CI e-IO W epi fd tfl V' -fl 0 o o 6O N N ON 4,2C 2 U D 0 5 IS o Ln Ln in CL.LW E Z E CO t U f U c O O p a 3 al CU > ,.1 rL) J '0 n Q N _ U 3 O' J NLO _ O ° oN N O pi N v J J - 0 @c 01 R U M .-i 16 M -� Q Y N O u i -a 0 Ln n h h, o Q U o n s �n _ D a. o o U J 2 Y e Ln 1-i m a. E a.E D c 3 v M E U a 4) O y E .-i Q .y 0- O H CL E v N>. C 0 a O m n , v 8 • 0 ✓ LJ Q O = S o y i 0 N - 1,-'1,; 0 0 ,9, _4 .7,, „' n 0 n d '�` 0 8 8 0 8 ° b E �+ Z u ry ry ry Pi ry ry Pi N 'V Pi Pi ry Pi ,48 - o O m O O o 0 m 1 4 0 0 0 0 0 0 0 0 0 L.0 0 0 0 0 0 Ll-';, m 9 0 3 n.8 o B o o m �., m m m m m m m m 62e ,„%, a .4 3 n,'+ 66g-`' V u Iq m ',1:,, i; C o 0 0 0 0 0 0 0 0 0 0 0 o 2 V_ Z U V U O , = E ti .:i! rv [m 0 0 0 0 0 0 0 0 0 0 0 0 0 a d ry a- o a u u u x a o E a m __ 0 0 0 0 0 0 0 0 0 0 0 0 0 O a. O a o O o E 4 4 ~ E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E .. . a v av 2 2i '57, `2 9 4) m E E N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .. _ 11 z a ¢ Y, ry §j,'..g m :4'2-- �_ v m .o cr.4., 4 ., ry ry m :, h 'a 8 8 ry .� w m F_,4 o c o`"' > TA o bD :10 , (') 0 n `o 1 E 3 9 m lz-, n n m m2 me m m z -c 8 a o 8 o o o & oi ry rv .i a N m m m m m m ry• to . 0 d, S - v m m m m m m m m m m m m m m m m i0 =y o g 8 8 0 0 $ 0 di"' a d u 'a i o F a 7 7 F F 7 - a o 0 3 8888 ,536338 QN o f o . % �, 8 - i � x .. .. 0 0 0 0 0 0 0 0 0 0 0 0 0 o " :-' 'f. "- -- -1-4 .11-14'vx x x x a, w a LL o t-9m m m m m 8 , 2 m m m m m '0, t _ ,^1 W o LL LL .Va E ,, ry m ,n ,o n ro 00000 ., ., ., 0 ry V z U n E d ,9L l 1i 6866-6966 N7 ,. 'v o i' pueg a yniednN _ lienialug 0 • 0 Treating Slurry Treatmen Treatmen lob Clean lob Slurry Seq No. Time Activity Code Value Comment Pressure Rate t Clean [Slurry Vol(gal) Vol(gal) (psi) (bpm) Volume Volume (gal) (gal) 115:49:20(10/26/17) Start Job 0 Starting Job 0 0 0 0 0 0 1 15:49:20(10/26/17) Next Treatment 1 Treatment Interval 1 -35 0 0 0 0 0 2 17:13:26 Pressure Test 0 Pressure Test-Test Globals 100 psi 3 0 40 40 40 40 3 17:18:39 Pressure Test 0 Pressure Test-Test Locals 500 psi 672 0 40 40 40 40 4 17:29:03 Pressure Test 0 Pressure Test-1st bank 6500 psi 6583 0 40 40 40 40 5 17:32:59 Pressure Test 0 2nd Bank Pressure Test-6500 psi 6556 0 40 40 40 40 6 17:41:28 Pause 0 Suspending Job 0 0 40 40 40 40 7 05:56:07(10/27/17) Resume 0 Resuming Job 46 0 40 40 40 40 8 9:57:12 Pause 0 Suspending Job 0 0 40 40 40 40 9 12:57:19 Resume 0 Resuming lob -31 0 40 40 40 40 10 13:07:48 Prime Pumps 0 Prime Pumps -28 0 40 40 40 40 11 13:32:46 Pressure Test 0 Pressure Test-Globals @ 100 psi -26 0 40 40 40 40 12 13:34:27 Pressure Test 0 Pressure Test-Globals Passed 295 0 40 40 40 40 13 13:35:25 Pressure Test 0 Pressure Test-test locals 500 psi 423 0 40 40 40 40 14 13:40:45 Pressure Test 0 Pressure Test-6500 psi-one side 6542 0 40 40 40 40 15 13:44:21 Pressure Test 0 Pressure Test-6500 psi-2nd side 6518 0 40 40 40 40 16 13:54:57 Safety Meeting 0 Safety Meeting-Pre Job meeting 61 0 40 40 40 40 17 14:25:00 Open Well 0 Open Well 37 0 40 40 40 40 1 14:28:35 Next Stage 1 Shut-In 34 0 40 40 40 40 18 14:29:47 Break Formation 0 Break Formation 2873 1.9 39 39 39 39 2 14:31:49 Next Stage 2 Load Well 3570 21.9 944 944 944 944 3 14:35:26 Next Stage 3 Step Rate Test 3710 30.1 5145 5145 5145 5145 4 14:41:46 Next Stage 4 Flush 3360 30.1 13138 13138 13138 13138 5 14:43:44 Next Stage 5 Shut-In for FET Analysis 2023 0 14147 14147 14147 14147 6 17:03:05 Next Stage 6 Pad 3267 30 20091 20091 20091 20091 7 17:09:58 Next Stage 7 Sand Slug 2983 29.4 28523 28523 28523 28523 8 17:12:02 Next Stage 8 Pad 3024 29.9 31107 31121 31107 31121 9 17:14:29 Next Stage 9 Proppant Laden Fluid 2884 30 34215 34234 34215 34234 10 17:18:28 Next Stage 10 Proppant Laden Fluid 2831 30.1 39083 39285 39083 39285 11 17:22:35 Next Stage 11 Proppant Laden Fluid 2669 29.8 43874 44462 43874 44462 12 17:25:23 Next Stage 12 Proppant Laden Fluid 2635 30 47141 48002 47141 48002 13 17:28:24 Next Stage 13 Proppant laden Fluid 2577 30.1 50519 51811 50519 51811 14 17:31:26 Next Stage 14 Proppant Laden Fluid 2480 30 53728 55634 53728 55634 15 17:34:39 Next Stage 15 Proppant Laden Fluid 2357 30 56990 59687 56990 59687 16 17:38:30 Next Stage 16 Proppant Laden Fluid 2255 30 60890 64542 60890 64542 17 17:42:27 Next Stage 17 Proppant Laden Fluid 2201 30.1 64760 69530 64760 69530 18 17:46:39 Next Stage 18 Proppant Laden Fluid 2039 28.8 68662 74751 68662 74751 19 17:52:17 Next Stage 19 Flush 2077 30.1 73935 81807 73935 81807 20 17:58:19 Next Stage 20 Other 2605 26.2 81063 88996 81063 88996 19 18:00:40 ISIP 0 ISIP 2569 0 83469 91401 83469 91401 20 18:05:41 Shut-In Pressure @ 5 Minutes 0 Shut-In Pressure @ S Minutes 2332 0 83469 91401 83469 91401 21 18:10:40 Shut-In Pressure @ 10 Minutes 0 Shut-In Pressure @ 10 Minutes 2279 0 83469 91401 83469 91401 21 18:12:13 Next Stage 21 Shut-In 2265 0 83469 91401 83469 91401 22 18:15:41 Shut-In Pressure @ 15 Minutes 0 Shut-In Pressure @ 15 Minutes 2232 0 83469 91401 83469 91401 23 18:22:45 Clean Lines 0 Clean Lines 11 0 83469 91401 83469 91401 24 18:59:17 End Job 0 Ending lob 15 0 83469 91401 83469 91401 Hi]Cop•M-C-45 Event Logger 21 • • Customer: Hilcorp Alaska LLC Well: MPC-45 Date: 10/27/2017 Zones: 1 TICKET#: 904385503 BEGINNING STRAP VOLUME VOLUME TEMP ENDING STRAP VOLUME VOLUME TANK# TANK TYPE FEET INCHES (GAL.) (BBLS.) DEG F FEET INCHES (GAL.) (BBLS.) 1 500 MISER 86 17,220 410 110 85 17,010 405 2 500 MISER 100.5 20,160 480 110 58 11,340 270 3 500 MISER 101 20,370 485 110 3 567 14 4 500 MISER _ 99.5 19,950 475 105 13 2,457 59 5 500 MISER 102 20,580 490 105 9 1,701 41 6 500 MISER 98 19,740 470 105 11 2,079 50 7 105 8 105 9 105 10 105 11 105 12 100 13 100 14 100 _ 15 100 _ _ 16 100 17 105 18 100 19 100 20 100 21 100 22 100 23 100 24 100 25 98 Transport TOTAL: 118,020 2,810 TOTAL: 35,154 837 Minus 50 bbl bottoms 1,560 477 Water summary Starting(gal) Used(gal) 82,866 Starting(bbl) Used(bbl) 1,973 HidCorp-MPC-45 Water Straps Day 1 22 • • Fluid is broken at200cp Zone I Crosslink Tests Pad -1 ppg -2 ppg -3 ppg -4 ppg -5 ppg 7000 6000 5000 -�! 4000 Tr; 3000 -- U y > 2000 1000 \\ 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08 00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) HilCorp-MPC-45 15 Min FANN 23 • 0 a v c • O O m N N E a i .n o8� co el CO om IN vel 01 01 Al Q je1 ^I:N Al c m t O y N y a >' 00 LP v 01 n n 71'n°EEEEE n > N V1 V1 Q N U m co p �v} M M to LI rI '1'12N N H : N To E � fLL w a c u v _ w 5 w o .17 000000 tA to to IA IAd C _ E 0 ✓ -o E v o w — v a � E >o y E• LL u c E E V v 'n co co 0o oo co co w �^ ri vi vi v ID ID ID�o io ID 'o 76 > m Q E 00 00 00 00 V 0 0 V N e1 a 01 IA E E a o 8 -o > a' 2 0 — v' N .p # N C 2 E o� m Y v > > • 'u E o : c V2 • o o E E w .y;N Met to to - E U o y�j a YY Y '4.Y C 10 • • HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: Hilcorp Well Name/No.: MPC-45 Date Tested: October 26,2017 Water Type: Fresh Water Units Tank 1 Tank 2 Tank 3 Tank 4 Tank 5 Tank 6 Tank 7 Tank 8 Tank 9 Specific Gravity 1.001 1.001 1.001 1.001 1.001 1.0010 Temperature °F 80 81 79 80 80 80 pH — 8.2 8.170 8.160 8.170 8.170 8.1700 Iron(Fe) mg/L 0 0 0 0 0 0 Chloride(CI) mg/L 33 33 33 33 24 24 Sulfate(SO4) mg/L 200 200 200 200 200 200 Hardness mg/L 250 250 250 250 250 250 Linear Viscosity cp 25 28 28 28 28 29 Crosslink pH pH 10.7 10.65 10.7 10.7 10.7 10.7 Crosslink Test(Y/N) Y Y Y Y V' Y This report is the property of Halliburton services and neither it nor any part there of nor copy thereof may be published or disclosed without first securing the express written approval of laboratory management.It may however.he used in the course of regular business operations by any person or concom and employees thereof receiving such report from tiallibtuwn Services. NOTICE:This report is limited to the described sample tested.Any user of this report agrees that Halliburton shall rot be liable for any loss or damage,whether due to act or omission.resulting from such report or it use. MCorp-MPC-45 Water Report 25 I-4ALLIELIPTON Prudhoe Bay Field Laboratory-Rockies NWA Laboratory Project ID Number: 2051SOS-1 Customer: HilCotp Well Name&Number: MPC-45 Fluid System: Hibor G Date: October 25,2017 Summary of Testing and Rendts First 10 minutes at 511 lisee at IOC degrees After 10 minutes the shear rate was decreased to 100 l'sec.and the sample was brought up to temperature with in 20ininutes A:1 testing was done using Location water(SL.594)and Field Chemicals(SL*565). Technician Perfon"—,TTestiag Amar.is Marlton ReTtesved Sc Appro^:ed By. Iii1Corp-MPC-45 Lab Testing 26 • • JOB INFORMATION AND TESTING CONDITIONS i Customer Hi3Ccop Fluid System. Ibises 0 Bob T.pe: B5 Well Nate. \g(-t5 Water Source. Location ete Shea:Fate(1 sec). 511 1'r Ente: October 25.2017 BHST(T}: 170 Labproiect0. 2OS1EG;l FLUID DESIGN Test No 5 WaOM A*1ETzis,.. Lot a Chemical Cats Chemical Concentrations ',maple D. Vi 7.1-3` :7, ...D, 3:-- -:-- B;C2.7b20,2:e(Mg L.) Bbfi i, C;` t:' Calcinis;me L) icssrs3C n: -.: -_ ierborsatet .Lt MO-6 7 _, r:. ._. Calcc&tLWZ° C531 p: i's: -,' boo DMZL) C'leSck - ..: ... `..lameezum ilL- ors. "24 -_- j'H SF b:a;v Potassium(nL=i Reenti-rs(S?-azi Sodium($L)• Specific Gra-city Sn1IEe:Me L) IDS'mg L) • Teo.„--e-attue CTI FI33ID PROPERTIES Test No. 2 5 Get Hrdretive.01) Water pH -4- -.4-. _„-Y .,,.:.-._ T: Base Gel(F) 3.23 SC X 33 b_ "- Base Gel fist(cP) =5-D 2.3 0 -.93 - Bac Gel pH 7 45 -.3_ - . , _ Base Gel Tete.(F) - - -. _ -. Buffered pH 9'2' 50; S. . _ -, Cmsslink pH 5'-75 5 5: _.7 -. FioalpB 5.- -. Tes:Temtp.Cr) :5$ 154 15 Bre::B-Lame 1bruvu) -. -- - BREAK TEST CRART - .as Man* .........•9v.a.. —.—ac e, —r.m.b .__.....%Awl* MO 130 MO ,0,420,f101-1 `1,..---,-6-'--1-46.1ass_,..,...;:.:...,..u..____-__'---- rysoi t t0 a \\%CI'\_.-- - '''\I\''''',\..., -80 ma r i \ 1m -m _.._._ a o 003 032 224 334 048 2116 T"ae.a.2ma HilCorp-MPC-45 Lab Testing 27 • S ..„2...,,,..„..,,„ . ., . ..., ...4 .., d Np Y Y Broken Sample (Pad,1PPg,SPPg,7pPg6) HilCorp-MPC-45 Broken Samples 28 i i S k 4 , 1,4i43/4 7 Broken Sample (Pad) HilCorp-MPC-45 Broken Samples 29 0 k ' ' ''' ''' 2 ,",,',.,,,,'''',:f.,..s.J.:,,:.:',..,,,"'-',..,:iFiji 1:''''i..if,,,\ 4 Broken Sample (7 ppg) HilCorp-MPC-45 Broken Samples 30 • • p N N W A O g . o 8 8 8 0 0 0 CO j u UNJ.N N NI A N A F. O N V N V A N N O's N [ v. NJ N NNJ 7D /41. I 0 (V i O N ^ V ' N i G fv 0 X lD p N Cn N 00 J O " D v F c [ -� ro NI NJ Cyt a` NI Hama imam rearimarsifisirsiesess 1.,..,4 al coo 77 0 ts N , ( V 11''' I F. t+ ONO N NIJ.N IAJ V y 1 an J▪. NJ V 7 CO C") O m N .... 1 0 r..., rn J A W OF Tit 44,1 ,1///7./ ,sTHE STATE • Alaska Oil and Gas F "Z''� : O /� LAsKA Conservation Commission �l 1 tItt$1£i _. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 � Main: 907.279.1433 FALAS* Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MP C-45 Permit to Drill Number: 217-092 Sundry Number: 317-505 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a2acC\ -- Hollis S. French Chair DATED this Z day of November, 2017. • RBD CPS 1,(- 1„'; - ` 2017 • 111 RECEIVED OCT 252017 STATE OF ALASKA p CC ALASKA OIL AND GAS CONSERVATION COMMISSION �'1 V APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 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 0 Other: Complete 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: C .,s L p F Hilcorp Alaska LLC Exploratory ❑ Development 2, 217-092 3.Address: 3800 Centerpoint Dr,Suite 14000 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-23579-00-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D + Will planned perforations require a spacing exception? Yes ❑ No 0 .1 MP C-45 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL047433,ADL047434&ADL047437 a Milne Point Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,262' 7,207' 10,133' 7,095' 2,738 10,133' N/A Casing Length Size MD TVD Burst Collapse Conductor 140' 16" 140' 140' N/A N/A Surface 7,015' 9-5/8" 7,015' 4,804' 5,750psi 3,090psi Liner 10,236' 5-1/2" 10,259' 7,204' 10,640psi 7,480psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 2-7/8" 6.5/L-80/EUE-8rd ±9,850' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/29/2017 OIL ❑ r WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchanCcr�hiIcorp.Com Contact Phone: 777-8333 Authorized Signature: "r - Date: 10/23/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Numbers/ C/V) s Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance CI ✓% Other: ../-34000 eS c. RBDMS LL—Iw - 2 2017 Post Initial Injection MIT Req'd? Yes ❑ No ❑ (61_4244.9 gort.....1--) Spacing Exception Required? Yes ❑ No Q' Subsequent Form Required: / y ,!E :DC-2 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: t t "2— ) \ \ 4ti�� , . 04/47 ORIGINAL �/ Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • i II Well Prognosis Well: MPC-45 Ililcorp Alaska,LI) Date:10/23/2017 Well Name: MP C-45 API Number: 50-029-23579-00 Current Status: Oil Well (New Well) Pad: C-Pad Estimated Start Date: October 29th, 2017 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 217-092 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 (M) Current Bottom Hole Pressure: 0 psi @ 7,000'TVD (Not yet perforated) Maximum Expected BHP: 3,438 psi @ 7,000'TVD (Estimated reservoir pressure/9.5 ppg EMW) MPSP: 2,738 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point C-45 well was drilled as a Kuparuk River development well in October 2017 with 5-1/2" P-110 production casing. After the fracture stimulation, the well will be completed with a 2-7/8" permanent completion.The well is cased and cemented. Objective: ha=s z Y" C‘r"115 . Run 2-7/8" L-80 gas lifted completion. 1 ti.)a F I Pre-Rig Procedure: �; �L, � ;�- 4e 5 v /L17. 11 1. RU SL.Test lubricator to 250 psi low/3,000 psi high. 2. Drift 5-1/2" P-110 casing to PBTD with GR/JB. 3. POOH. r 4. PU and RIH with bridge plug. Set BP at—9,500' MD. LA, 5. POOH t'I j. 6. PT casing and BP to 3000 psi for 30 minutes. 5. fie 7. RD SL. `tj 8. Clear and level pad area in front of well. Spot rig mats and containment. 9. RU crane. ND 5-1/8" 5M frac valves. NU 11" BOPE. RD Crane. 10. NU BOPE house.Spot mud boat. Brief RWO Procedure: 11. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 12. Note: BOPE will be tested against brigge plug at 9,500' MD as the BPV profile is damaged. 13. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. n j4� b. Notify AOGCC 24 hours in advance of BOP test. y,/,�r c. Confirm test pressures per the Sundry Conditions of approval. d. Test Annular,VBR and pipe rams on 2-7/8"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. • • Well Prognosis Well: MPC-45 Hik.erp Alaska,LI) Date: 10/23/2017 14. Bleed any pressure off casing due to thermal effects to 500 bbl returns tank. 15. MU bridge plug retrieving tool on 2-7/8"tubing. RIH to top of plug and establish parameters. 16. Engage and release BP. Circulate bottoms up with kill weight fluid. t, C 17. POOH and LD tubing and retrieving tool. L-- - ` ` � X13 f. 18. PU new gas lift completion and RIH on 2-7/8" tubing. Set tailpipe at±9,850' MD. a. RU i-wire spooling unit for TEC wire b. Space out GLM and jewelry per completion running order. 19. Land tubing hanger. RILDS. Note PU (Pick Up)and SO (Slack Off)weights on tally. 20. Drop ball and rod. Pressure up and set Halliburton PHL packer(start 2,500 psi/final 4,000 psi). 21. Pressure up and test tubing to 4,000 psi for 30 min and chart. Bleed tubing to 1500- 1700 psi. 22. Test inner annulus to 3,700 psi for 30 min and chart. Bleed off the tubing pressure and shear the valve in GLM#1. Bleed all pressures to 0 psi. 23. Lay down landing joint. 24. RU hot oil pump and freeze protect the tubing and IA to—2000' MD with diesel. Allow freeze protect to U-tube down tubing. 25. Set BPV. Rig down ASR. Post-Rig Procedure: 26. RD mud boat. RD BOPE house. Move to next well location. 27. RU crane. ND BOPE. 28. NU new 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. Set TWC. Pressure test tree flanges. 29. RD crane. Move 500 bbl returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. 31. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Proposed Tree/Wellhead 5. Blank RWO MOC Form • • Milne Point Unit 11 SCHEMATIC Well: MPC-45 Last Completed: Future Hilcorp Alaska,LLC PTD: TBD V WELL INCLINATION DETAIL Innovation KB 26.5'Above GL Max Hole Angle=54°@ 3,423'MD 16" .+ CASING DETAIL •i Drift "4 Size Type Wt/Grade/Conn Top Btm 16" Conductor 164/A-106B/Weld N/A Surface 140' ,i 9-5/8" Surface 40/L-80/DWC/C 8.75 Surface 7,015' , iI 5-1/2" Production 17/P-110/GeoConn 4.767 Surface 10,259' Stage Tool " GENERAL WELL INFO @2,195' 'mac ,' API:50-029-23579-00-00 MD ^ Drilled&Cased by Innovation—10/18/2017 x' ',I: = '40- T 4M 9-5/8" 't, k of * tea,. 4 s 1/z'g� aa TD=10,262'(MD)/TD=7,207'(ND) PBTD=10,128'(MD)/PBTD=7,091'(TVD) Revised By:TDF 10/19/2017 • • Milne Point Unit PROPOSED Well: MPC-45 Last Completed: Future }Won,Ala.-U.11A PTD:TBD Innovation KB26.5'Above GL OPEN HOLE/CEMENT DETAIL 9-5/8" 3,708 cu/ft 12-1/4"Hole 16" , 1 5-1/2" 431 cu/ft in 8-1/2"Hole WELL INCLINATION DETAIL Max Hole Angle=54°@ 3,423'MD Stage Tool CASING DETAIL @2,195' Drift rev '----y0 Size Type Wt/Grade/ConnID Top Btm 16" Conductor 164/A-106B/Weld N/A Surface 140' 9-5/8" Surface 40/L-80/DWC/C 8.835 Surface 7,015' 5-1/2" Intermediate 17/P-110/GeoConn 4.892 Surface 10,259' TUBING DETAIL III 1 2-7/8" Tubing 6.5/L-80/EUE-8rd 2.441" Surface ±9,850' JEWELRY DETAIL No Depth ID Item 2 1 ±2,794' STA 8:2-7/8" L-80 SPMO-1.0M GLM(DCR Shear Valve) 2 ±4,554' STA 7:2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 3 ±5,688' STA 6:2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 3 4 ±6,631' STA 5:2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 95/$, 5 ±7,543' STA 4:2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 4b 06 6 ±8,359' STA 3:2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 7 ±8,989' STA 2:2-7/8" L-80 SPMO-1.0M GLM (Dummy Valve) 8 ±9,535' STA 1:2-7/8" L-80 SPMO-1.0M GLM (Dummy Valve) 5 9 ±9,597 2-7/8"XD Sliding Sleeve 10 ±9,653' 2-7/8" ROC Pressure Intake Gauge 11 ±9,739' 2-7/8"X Profile 6 12 ±9,760' 52--71//82::"x 2-7/8"L-80 PHL Hydraulic Retrievable Packer 13 ±9,817' XN Profile . 14 ±9,850' 2-7/8"WLEG 8 PERFORATION DETAIL '''9 Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size � Ito 11Kuparuk 9976' 9996' 6976' 20 Proposed ,.11 HIS 12 GENERAL WELL INFO „13 API:50-029-23579-00-00 Drilled&Cased by Innovation—10/18/2017 14 ', S-A N b -,-- 54/2" A . .1, TD=10,262'(MD)/TD=7,207'(1VD) PBTD=10,128'(MD)/PBTD=7,091'(TVD) Revised By:PC 10/24/2017 • • Milne Point ASR Rig 1 BOPE t{ttr„rp %144n. 11" BOPE Stripping Head 1 1 3.98' Shaffer ' 11" - 5000 al di Willi- Lt.( iiilii- CI ► -U 4.54' 6 49 �= VBR or Pipe Rams a " 11-11:g1.;00 OMMIC Blind ,Thamitain 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves { i5L 4 € E 200' ' ;:(4 0 Manual Manual Manual HCR Updated 8/19/2015 • • WELL MPC-45 DATE 10-23-17 IINI Planned Hilcorp Alaska, LLC 5 0 ! Swab cap, 2 9/16" 5K i 1, x Otis connection. 6 %" ACME Swab valve Cameron FL,2 PN 2048774-01-01 ,, ®� 9/16" 5K, FE,DD L-U 00 C. / PN 141522-31-07-02 SN [ , 5, 0 Q ;I0 WA Wing valve Cameron FL, 2 O 9/16" 5K, FE,DD L-U 11.i p t 1/41* V i ,,) PN 141522-31-07-02 SN 0 ®cit SSV valve Cameron Model ®°°®® FL, 2 9/16" 5K, FE,DD L-U PN 2012403-03-01 ) O 0(004 ._ ,_, Master valve Cameron FL, 2 9/ 11 x 2 9/16" 5K 01 am 16" 5K, FE,DD L-U Adapter, 6A-U-DD PN 141522-31-07-02 p _ API 11„ 5K PN W16730-0001 -.w. SN 1 L 5” BPV prep Seal Assy, SMB-32 Emergency, 11 =A is :1 !!: .,, Nom x 51/2 Csg, 10" 4TPI Stub Acme 1) 1 �r top. Comes w/ 5" "H" BPV prep. Min 11 x 5 1/2, S21,SIip type [TT 1----4.-i API 11" 5K ID 4.98" casing hanger I I" 4,� PN W16760-001 PN A27301-001 9 i Ilk, , , -'6 ° API 13 5/6" 5K 0 II 1 riCsg Hgr,Seaboard I�'I j'° ... .11 7;. 5% 17" P-110 csg, 5 IA S-22 13 5/8 x 9 5/8" ,. Geo-Conn Slip type hanger LU,DD-NL 4,14 NW PN A16232-001 SN 9 5/8 40" L-80, 9 5/8 �� / DWC • i Ts _ C .CD CD .> al m e-, a) Vias a) o — c � 0 Qaa) =� Qa E E co oo . C N CD a) Y > - a = a) = av >, E Q >, Tsa) c L • o o• 92 Q L - 2 m Q � ` Q RS a) a m al to ate+' 4- o 0 CI u) c a) N C o (B N O U L o o To W/ a) o v -oQ O co a) ezi > a)w a 0 �� as Q. ° s ns 3 v 40 -ay = c0 1 C a) as U c a) cn O c OQ O a ) G1 2 E ti; a O -a 0cu -0 . 2CD a) O Ift to c 41) 105mcc m eca c s 2 wCt. p et i E. �• � O V 0 0 ii 0 � aU O >0 = 0 0 L: I , _ E Ua. o o. m• ,-a w .Q c >, U iio n n °aN Q n_ V �w\�OF 7,FJ • • Alaska Oil and Gas ����j,�s� THE STATE Conservation Commission .�� to, of T A 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MP C-45 Permit to Drill Number: 217-092 Sundry Number: 317-495 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 2-3 day of October, 2017. RED:uJ - L 2617 ► • • � - % STATE OF ALASKA " I0i 7 l f ALASKA OIL AND GAS CONSERVATION COMMISSION 7 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑✓ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Cr ,c&VW u 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: c:/N' Hilcorp Alaska LLC Exploratory ❑ Development D 217-092 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23579-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D• Will planned perforations require a spacing exception? Yes ❑ No Q f • MP C-45 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL047433,ADL047434&ADL047437 Milne Point Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total DeepthlvlD(ft9: Total Depth [VD (ft): EffectiveODe MD: Effective TV79b MPSP(psi): Plugs(MD): Junk(MD): 7720''' 4,i87' 6, / 4 3,003 6,887' N/A Casing Length Size MD TVD Burst Collapse Conductor 140' 16" 140' 140' N/A N/A Surface 6,992' 9-5/8" 7,015' 4,804' 5,750psi 3,090psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): t ?<;'CI rVI 12.Attachments: Proposal Summary ElWellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/26/2017 Commencing Operations: OIL ❑✓ , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ; N. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan(c�hilcorp.com //;���L Contact Phone: 777-8333 Authorized Signatur . a/1/1�+�- Date: 1 L!V V* '�I 4. v`, .� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 7t A I-kevrL4 11--,' id1.° S L...4-51-:--- c eG'.4A : Z ST Z 2/3 Q) t-- r,,,,cc',. 't.d"--.-c_ S 4.4-61Y►` }�s O:s l >7- . .'h..jti--'l el".... ❑ / Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 6—410 cy APPROVED BY < l�BC���sS C,--. 1,7,V - 1 261V7 Approved by: •-a COMMISSIONER THE COMMISSION Date: III i-1-3 Itl LA PRQII�7- ORIGINAL (6, x.3- ,7 4( Submit Form and `�� Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • October 13th, 2017 2 Chantal Walsh, Director Division of Oil and Gas Alaska Department of Natural Resources 550 W. 7th Avenue/Ste. 1100 Anchorage AK 99501-3510 Re: Notice of Hydraulic Fracturing Operation—Milne Point MP C-45 Dear Mrs. Walsh, Hilcorp Alaska, LLC ("Hilcorp Alaska"), as Operator of the Milne Point Unit, has recently submitted an application to the Alaska Oil and Gas Conservation Commission ("AOGCC") to allow for the hydraulic fracturing of Milne Point Unit Well MP C-45. The surface of the well is located on ADL 047434 and the bottom hole location falls on ADL 025516. See attached maps. Hilcorp and our joint working interest owner, BP Alaska Exploration, Inc. ("BPXA"), own all applicable leases within the MPU. The State of Alaska, Department of Natural Resources is the sole landowner and surface owner. There are no other affected landowners, owners or operators within a '/2 mile radius of the well. Moreover, there are no water wells within this affected area and therefore no water well sampling is required. A complete copy of our Application for Sundry Approval can be obtained from the undersigned or by requesting a copy from the public records at the following address: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue - Suite 100 Anchorage, Alaska 99501 Phone: (907) 279-1433 Sincerely, Paul Chan, Sr. Operations Engineer HILCORP ALASKA, LLC CC: John Dittrich, BPXA (via email John.dittrich@bp.com) • Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Paul Chan Senior Operations Engineer (907)777-8333 October 13th, 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Hydraulic Fracturing Application,Milne Point Unit,MP C-45 Dear Commissioner, Hilcorp Alaska, LLC ("Hilcorp"), as Operator of the Milne Point Unit, herein submits its application to fracture stimulate MP C-45. Please do not hesitate to contact Paul Chan at 907-777-8333 should you have any questions regarding this application. Sincerely, o York, Operations Manager HILCORP ALASKA, LLC Enclosures: Form 10-403 Sundry Attachments • • 20 AAC 25.283 (a)(1) Affidavit Affidavit stating that all owners, landowners, surface owners, and operators within a one-half mile radius of the current or proposed wellbore trajectory have been provided a notice of operations that is in compliance with 20 AAC 25.283 (a)(1) • • VERIFICATION OF NOTICE PER 20 AAC 25.283(a) MILNE POINT UNIT MP C-45 I, PAUL CHAN, Hilcorp Alaska, LLC, ("Hilcorp") do hereby verify the following: I am acquainted with Hilcorp Alaska, LLC's application for sundry approval to the Alaska Oil and Gas Conservation Commission to enhance production of the MP C-45 well via hydraulic fracturing. Pursuant to 20 AAC 25.283(a)(1), I assert that all owners, landowners, surface owners, and operators within a one-half mile radius of the current or proposed wellbore trajectory have been provided notice of Hilcorp Alaska, LLC's proposed operations. VI- DATED at Anchorage, Alaska this (� day of OG-rOg+✓" -2017. —?- 1 (' ' Paul Chan, Sr. Operations Engineer Hilcorp Alaska, LLC STATE OF ALAKSA ) ) THIRD JUDICIAL DISTRICT ) SUBSCRIBED TO AND SWORN before me this I"day of DcbbeiN 2017 � �i /' iL Nle A'YPU: 'CINANDFOR STATE OF ALASKA(.4;* ,L� THE STATES ALSKA NOTARY PUBLIC My Commission expires: 11-12101 21 Cortney M. Moore My Commission Expires:April 26,2021 • • 20 AAC 25.283 (a)(2) A Plat (A)Showing The Well Location; (B)Identifying each Water Well,if any, Located within a One-Half Mile Radius of the Well's Surface Location;and • i aN L o U U cp Lc), ri)) u) ,_ U O Lf) r-- _J S L V 0 6 D Q_ 2 M 0 vt Y a , Z U) .0 o o nzw u) l) 0 715o v a) 0 12 O co M 5 c- a. 0 r`. z 0 J 0 Q o / ,O �Z r.w ' M c co D a) T ,_ O N c L!7 o G U •p ,t. CL st U CC _ = R (/) a) Ln v ° (31 t, a) is Q U) c a) 0 , o .s OM 0 —I n V N a) O O ct La 0 -51:5 a3 C OLt� Q) C L = � 0 _..... _.... 4O LL a) (L QII a) p L__" 0 (0 2 LL_ cm cagb op P� o U T ■ : _ N `) �' -� a) • • • i J - -®.. -- M'''. <CS (C) Identifying for all Well Types each Well Penetration Well API PTD Pool Type Status MPC-01 50029206630000 1811430 KR ESP Producing MPC-02 50029208660000 1821940 KR WAG Injecting MPC-03 50029207860000 1820500 KR 1-OIL Producing MPC-04 50029208010000 1821260 KR 1-OIL Producing MPC-05A 50029212440100 1842430 KR 1-OIL Shut In MPC-06 50029212570000 1842410 KR WAG Injecting MPC-07 50029212660000 1850020 KR 1-OIL Producing MPC-08 50029212770000 1850140 KR WAG Shut In MPC-09 50029212990000 1850360 KR 1-OIL Producing MPC-10 50029212780000 1850150 KR WAG Injecting MPC-11 50029213210000 1850590 KR PWI LTSI MPC-12A 50029213730100 1990910 KR SUSP Suspended MPC-13 50029213280000 1850670 KR ESP Producing MPC-14 50029213440000 1850880 KR ESP Producing MPC-15A 50029213580100 2160700 SR JET Producing MPC-16 50029213640000 1851100 KR SUSP Suspended MPC-17 50029214730000 1852630 KR WAG Shut In MPC-18 50029214790000 1852690 P&A P&A MPC-19 50029215040000 1852960 KR WAG Shut In MPC-20 50029219140000 1890150 KR 1-OIL LTSI MPC-21 50029224860000 1940800 KR 1-OIL Shut In MPC-22A 50029224890100 1951980 KR ESP Producing MPC-23 50029226430000 1960160 SR JET Producing MPC-24A 50029230200100 2091340 KR 1-OIL Producing MPC-25A 50029226380100 1960210 KR WAG Shut In MPC-26 50029226340000 1952060 KR JET Producing MPC-28A 50029226480100 2051630 KR WAG Injecting MPC-36 50029228530000 1980010 KR WAG Injecting MPC-39 50029228490000 1972480 KR WAG Shut In MPC-40 50029228710000 2002130 KR JET Producing MPC-41 50029230140000 2010780 SB PWI Injecting MPC-42 50029231960000 2040280 KR WAG Injecting MPC-43 50029232000000 2040390 KR ESP Producing MPC-46 50029235760000 2170520 SR 1-OIL Producing 0 0 I / I , / / I/ / /+. / /I / / / 'I / / 4) / r 1 / , O Q) v f / / OU_ M \ // I! I // / N O 1(/ / I/ / U \ / N 1 N \ I/ /I O \/ O / / I O 0) ./\� m to ' /' I m J , , ,04 o d S Co N /'// I o5 c° v 41ICI / I S. O V \ / I .... R. O I h o p� I 0 Y 0 c0 i a � aCD I o � � Q o co N 1 v / \ ,v I N / I \ I- I _ 0 / / 1 0 0 U m / y 1 __ p =u �, n. , '/ p� M 1 N N In U M\ Tr ".:U �/I N / // U . 1 Y U Qy 1 \ ,14 i /f 1 0, CJ / GVH (/j \ CI \ Q N I 7 f LI / /' , �� / 1 QU iv)'ti � '/din r�/ 000 / U \\ � u I a ,/ 1. O O A V I ;�� �., i U m O Q \ \ I // f / U �� 1 m Q U I \\ \ I d , /, ��� } W C7 "tel N \ / 1. / /i �"�"" U) -) J J \k cc)c�� I �� s ? a 0 0 a N \ i 1, , , r\ --- LJJ • • \ J U \ i\ t: /// ,- / 4. i� I��� *-_ N�7 ` A ," / '0� \ ow > ', / -� to / .i-i ( rLc) d v v v N M , •'-'-::—' —/ ij', -�� I c, o o 0 o J - _ _ -§- - � N /Y O 0 a °a o a °¢ X - //I J v _ c Q c Cm Li-)i I `. OUd, A v/ 42 / N/ �' @ /// O ruT /U / 1 °a. — \• ' / ✓/ / / I A ✓K" _.£Z Ykl r k v:e "'.� 'd�Y'ZF e �€ G CoI o r)/ / � / 1 I \ \ Q / I / \ d I 0. V A ,. (fl 00 o N [O /n 1 t Wy y p o CD 1 1 N o —/ $ '0 p N N I i 5 N c7 c6 U O 1 , CC CC LL 2 �1 m a� o 0 n d' 1 I • 'a N N N O. O 1 O I C r CO I— CO _ N - a m • • 20 AAC 25.283 (a)(3) Identification of Freshwater Aquifers There are no underground sources of drinking water within a one-half mile radius of the current wellbore trajectory. Any and all freshwater aquifers lying below the Milne Point Unit are exempted aquifers under Aquifer Exemption Order 2 (AEO-2). See the Conclusion of AEO-2, which states that"The portions of freshwater aquifers lying directly below Milne Point Unit qualify as exempt freshwater aquifers under 20 AAC 25.440." I • 20 AAC 25.283 (a)(4) Baseline Water Well Sampling There are no water wells located within one-half mile radius of the current wellbore trajectory. A water sampling program is not required. / • • 20 AAC 25.283 (a)(5) Detailed Casing and Cementing Information 9-5/8"40#/ft L-80 DWC/C surface casing set at 7,015' MD with stage tool at 2,195' MD. First stage cemented with 700 sxs/304 bbls of 11.7 ppg Type I/II followed by 215 sxs/43.2 bbls of 15.8 ppg Class G cement. Second stage cemented with 351 sxs/297 bbls of 10.7 ppg PermaFrost L followed by 180 sxs/ 39 bbls of 15.8 ppg Class G cement. Proposed: 5-1/2" 17#/ft P-110 GeoConn production casing set at''10,688' MD. Cement with 249.7 ft3 /215 sxs of 15.3 ppg SwiftCEM cement. Detailed Casing Information Size Type Wt/Grade/Conn Pipe Body Yield Collapse Pressure Internal Yield (lbs) (psi) Pressure(psi) Conductor N/A N/A N/A N/A 9-5/8" Surface 40#/L-80/DWC/C 916,000 3,090 5,750 5-1/2" Production 17#/P-110/GeoConn 568,000 7,480 10,640 • • 20 AAC 25.283 (a)(6) Assessment of Each Casing and Cementing Operation Performed to Construct or Repair the Well The 9-5/8" surface casing was set below the base of the Schrader Bluff sands. The first stage cement job was started by pumping 54 bbls of 10.5 ppg tuned spacer with red dye followed by 700 sxs/304 bbls of 11.7 ppg Type I/II lead cement and 215 sxs/43.2 bbls of 15.8 ppg Class G tail cement at 5.5 BPM average rate. 22 bbls was lost during the first stage cement job. The stage tool was then opened and the tuned spacer and 78 bbls of green cement were circulated out. The second stage was cemented by first pumping 55 bbls of 10.5 ppg tuned spacer with red dye followed by 351 sxs/297 bbls of 10.7 ppg PermaFrost L lead cement and 180 sxs/39 bbls of 15.8 ppg Class G cement tail at 6 BPM average rate. Recovered 224 bbls of cement at surface. Bumped plug and closed stage tool at 1350 psi. Floats held. The job was pumped with cement to surface indicating a competent cement job. The 5-1/2" production casing has not yet been run and cemented. The 5-1/2" CBL will be submitted post-rig. • . 20 AAC 25.283 (a)(7) Plans to Pressure-Test the Casings and Tubing Installed in the Well The 9-5/8" casing was pressure tested to 3000 psi for 30 minutes on August 6, 2017. The 5-1/2" casing will be pressure tested to 6000 psi for 30 minutes post-rig. V ,� jtez V • • 20 AAC 25.283 (a)(8) Pressure Ratings and Schematics for the Wellbore,Wellhead, BOPE,and Treating Head Weight API Collapse API Internal Yield Size #/ft Grade Pressure(psi) Pressure(psi) 9-5/8" 40 L-80 3,090 5,750 5-1/2" 17 P-110 7,480 10,640 Treating 15M Head Wellhead 5M -4/ . 11^rA--54v"' ? BOPE N/A 0 — 4._..0--seitio---- Akc.g mALi)g Milne Point Unit n ` . II PROPOSED Well: MPC-45 Last Completed: Future HilcorpAlaska,LLC PTD:TBD Innovation KB 26.5 Above GL OPEN HOLE/CEMENT DETAIL 9-5/8" 3,708 cu/ft 12-1/4"Hole 16 �*"1• 5-1/2" 431 cu/ft in 8-1/2"Hole WELL INCLINATION DETAIL Max Hole Angle=54°@ 3,423'MD Stage Tool CASING DETAIL @ 2,195' Drift MD ----...b Size Type Wt/Grade/ConnID Top Btm 16" Conductor 164/A-1068/Weld N/A Surface 140' 9-5/8" Surface 40/L-80/DWC/C 8.835 Surface 7,015' 5-1/2" Intermediate 17/P-110/GeoConn 4.892 Surface 10,259' TUBING DETAIL 1 -7/8" Tubing 6.5/L-80/EUE-8r: 2.441" Surface ±9,85 JEWELRY DETAIL , No Depth ID Item 2 1 ±2,794' STA 8: 2-7/8" L-80 SPMO-1.0M GLM(DCR Shear Valve) 2 ±4,554' STA 7: 2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 3 ±5,688' STA 6: 2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 3 4 ±6,631' STA 5: 2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 9-5/8" 45 ±7,543' STA 4: 2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 6 ±8,359' STA 3: 2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 4 7 ±8,989' STA 2: 2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 8 ±9,535' STA 1: 2-7/8" L-80 SPMO-1.0M GLM(Dummy Valve) 5 9 ±9,597' 2-7/8"XD Sliding Sleeve 10 ±9,653' 2-7/8" ROC Pressure Intake Gauge 11 ±9,739' 2-7/8"X Profile 6 12 '-9,760' 5-1/2"x 2-7/8" L-80 PHL Hydraulic Retrievable Packer 13 X17' 2-7/8"XN Profile 14 ±9,850' 2-7/8"WLEG 8 PERFORATION DETAIL "I" 9 Sand Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Size - lio Kuparuk 9976' 6976' 20 Proposed -',.11 12 GENERAL WELL INFO 13 API:50-029-23579-00-00 Drilled&Cased by Innovation—10/18/2017 14 5-1/2,, a . , .4, TD=10,262'(MD)/TD=7,207'(TVD) PBTD=10,128'(MD)/PBTD=7,091'(TVD) Revised By:PC 10/24/2017 Milne Point Unit Well: MPC-45 14 Pr osed SCHEMATIC Last Completed: Future Hilcoru Alaska,LLC PTD: 217-092 Innovation KB 26.5'Above GL 16" CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 16" Conductor 164/A-106B/Weld N/A Surfac• 138' 9-5/8" Surface 40/1-80/DWC/C 8.75 Surf. e 7,010' 5-1/2" Intermediate 17/P110/GeoConn 4.767 Su ace 10,262' Stage Tool @±2,190' MD • • 44, PERFORATION DETAIL Sand Top(MD) B (MD) Top(TVD) Btm(TVD) FT Date Status Size Kup C 9,969' 9,989' 6,953' 6,970' 20 Proposed 9-5/8" 0 Planner TOC 7,864' / of of Kuparuk C C l -9,970) WELL INCLINATION DETAIL Max Hole Angle=54° OPEN HOLE/CEMENT DETAIL is 9-5/8" 3831 cu/ft 12-1/4"Hole 5-1/2" 427 cu/ft in 8-1/2"Hole(Proposed) GENERAL WELL INFO 4 API:50-029-23579-00-00 5-1/2„ Original Completion -TBD TD=±10,262'(MD)/TD=7,088'(TVD) PBTD=±10,125'(MD)/PBTD=7,207'(TVD) Revised By:PC 10/13/2017 • • WELL MPC-45 DATE 10-13-17 Hilcorp Alaska, LLC Tree Cap. Otis style, 7" ACME 5 1/8" 5K, FE,DD L-U PN Iii-m Swab valve Seaboard MEM Model 510,5 1/8" 5K, DD, ,AO C� L-U DOTwo PN ..�boil01 Master valve Seaboard Om Model 510,5 1/8" 5K, DD, -- Si© Tin L-U PN 352971-003 SN rr= 5"BPV prep • I • API 11" 5K 11 x 5 1/2, S21,SIip type on _� casing hanger �I atc of f API 13 5/6" 5K Csg Hgr, Seaboard II. - .«; S-22 13 5/8 x 9 5/8" Slip type hanger LU,DD-NL PN A16232-001 SN �&Y • • I nit sTATEs PROPOSAL: Casing Isolation Tool Energy Services(Canada) Inc. Maximum Allowable Pumping Rates SIZE ID OD RATE nilmin CSG 2.250 3.750 10 m'tmin 3 1/2"Big Bore 1.750 2.750 6 m'/min —2-7/8"&3 1/2" 1.438 2.360 4 m'lmin 2 3/8" 1.000 .1.900 2 m3/min 3 1116&4 1116 with tapered mandrel 2.750 4.000 15 m'/min 41/16 X Tool Mandrel 3.610 4.750 24 m'/min OPEN PosmoN CLOSED PosmoN (rxva m t.twrvek.IMEN11o) (;wx:att OnER-E0.1 ' [ WNW(O' M O (/�^'�y a ' � waw. 1 /AWiFR W.I. � �, P., dlllYYY/'!!!i. �7 , �j i, raoxxaaF' jf' \...g7 r1 � r r RMIT OYWitO ' J iAUER VMVt J 1 s.4\ I An.- '' 'ili--.:‘,1,:i I `' %how ty 'Clik ff Tz itA ♦ now 1[t XAI Z r ,i,,-'rt """`E W[iV..., i— H µFt 4' fly is o .I f € u r to„<"L 1 [} k 1r C �x r. Fr "p. r (t::. 04.1~IXr 0 # 0 nwa*ILOINc R 91 www.StingerCanada.com 15M Treating Head 20 AAC 25.283 (a)(9) Data for the Fracturing Zone and Confining Zones (A) a lithologic description of each zone; (B) the geological name of each zone; (C)the measured depth and true vertical depth of each zone; (D)the measured thickness and true vertical thickness of each zone; and (E) the estimated fracture pressure for each zone; The Kuparuk formation is a Cretaceous-aged,fine-grained marine sandstone. The productive Kuparuk interval in the C-45 area is—25'TVD thick(Kuparuk C and B7 sands). The top Kuparuk C Sand in C-45 is expected at 10,044' MD/7018'TVD. The estimated fracture gradient for the Kuparuk interval is 0.63 psi/ft. The overlying confining zone consists of 2000'TVD of HRZ shale and Colville siltstones and shales. The top HRZ shale is expected in C-45 at—9520' MD/6565'TVD. The top of the Colville was encountered at 7000' MD/4794'TVD. The estimated fracture gradient for the HRZ is 0.701 psi/ft. The underlying confining zone consists of"'170'TVD of Kuparuk siltstones and shales (B-silts).The top of the B-Silts is expected in C-45 at"'10,075' MD/7,045 TVD. The estimated fracture gradient for the B- Silts is 0.67 psi/ft. • • 20 AAC 25.283 (a)(10) The Location,the Orientation, and a Report on the Mechanical Condition of Each Well that May Transect the Confining Zones MP B-28: Schrader Bluff well does not transect the confining zone. MP B-29: Schrader Bluff well does not transect the confining zone. MP B-32: Schraderuconfining Bluff well does not transect the zone. MP B-10: 7" casing set across the Kuparuk sands with ECP at 9,094' and 9,194' MD and cemented with 72 bbls Class G cement with no returns while pumping. Pressure test casing to 2000 psi after setting EZSV at 9,346'WLM. MP B-18: 7" casing set across the Kuparuk sands with ECP at 10,456' and 10,517' MD and cemented with 78 bbls/330 sxs of Class G cement with 5% returns during job. Bump plug with 3000 psi. Estimated top of cement at 9,200' MD (100%excess cement pumped). MP C-14: 7" casing set across the Kuparuk sands with ECP at 8,518' and 8,539' MD and cemented with 56 bbls of 15.8 ppg Class G cement with partial loss of returns. Bump plug with 2800 psi. Estimated TOC • 7,650' MD. MP C-16: 7" casing set across the Kuparuk sands with ECP at 9,825' and 10,003' MD and cemented with 64.5 bbls/315 sxs of 15.8 ppg Class G cement with full returns during job. Bump plug with 2900 psi. Estimated TOC 8,900' MD. Well suspended with cement retainers at 9,700' MD/67 sxs 15.8 ppg Class G cement and 10,014' MD/46 sxs 15.8 ppg Class G cement across the Kuparuk perforated intervals. MP C-18: P&A February 20th, 1998 MP C-24A: 3-3/16" x 2-7/8" liner cemented with 31 bbls of 15.8 ppg Class G cement with no losses ' during CT sidetrack. Bump plug with 2200 psi. MP D-02A: 7" casing set across the Kuparuk sands with ECP at 8,767' and 8,864' MD and cemented with 925 sxs of Class G cement. Estimated TOC 6,300' MD 0 0 20 AAC 25.283 (a)(11) The Location of, Orientation of, and Geological Data for Each Known or Suspected Fault or Fracture that May Transect the Confining Zones \i/ii. -MPC 14 MPC 18 , 0 r tet- � f ,„----- ---\\\ / / _ _.„ / _______ // // . 7000 r 1 .,_______ ________ ,.. M P -45 --�_ , l „_________ 4 , ,,,,,.. /::: ii „ , g, A.,...... \ FEET 1 The map above shows the structure at the top of the Kuparuk C Sand interval. All faults shown are inferred from seismic data. The MPC-45 plan is to stay away (>500') from suspected faults based off of seismic data and we do not expect to encounter any faults during drilling. • • Horizontal principal stress from well data indicate that the fracture should propagate approximately NW-SE (SHmax is NW-SE, SHmin is NE-SW). Based on current mapping,the fracture wings should not extend into suspected faults based off of seismic data. • • 20 AAC 25.283 (a)(12) Proposed Hydraulic Fracturing Program M � 1. RU tree saver. PT 5-1/2" P-110 casing to 6,000 psi for 30 charted minutes 2. RU e-line and line wiper(no PCE). Note that the wellbore is hydraulically isolated from the reservoir with pressure tested cemented 5-1/2" casing. 3. Run CBL/VDL from PBTD to-500'above TOC. Continue logging to surface with GR/CCL. Note: This log will be the primary depth control log(reference log). 4. RU PCE. PT to 3500 psi. 5. Perforate the Kuparuk River form tion from ±9,969'—±9,989' MD. Final depths to be determined from OH logs. tok ti),'-; 5 6. RDMO e-line. 7. MIRU frac fleet. MIRU frac and slop tanks. MIRU all ancillary support equipment. 8. Fill frac tanks with water. Heat water as needed. 9. Lay all hardlines and manifolds. Install pressure monitoring equipment o wellhead and tree. 10. RU 15K tree saver and hard line. - 5C '�' 11. Pressure test all high pressure treating lines topsi. 12. Set the staggered pump kickouts between 5800 psi and 5200 psi. • Note: The fracture stimulation provider, Halliburton, has a three level protection system designed to disengage the pumps to limit the line pressure to the test pressure in (a) 12 (E). The first level of protection "kicks out" a frac pump in a staggered fashion as the treating pressure approaches the test pressure thereby slowing the rate and pressure. The second layer of protection is a global kick out that will place all the frac pumps into neutral at the pre-determined set pressure. The third layer of protection is the DPM (Discharage Pressure • i'/ Monitoring system)which is independent of the computer controls and will continue to � ' , ,�• function if the computer controls malfunction. The DPM cuts power to the engines to limit v L' c the rate and pressure (instead of taking the frac pumps to neutral). • Hilcorp Alaska requests a ariance fro the PRV requirement in lieu of the Halliburton multi- level system described ab • Hilcorp Alaska also requests a waiver to the requirement for the well to be equipped with a remotely controlled shut-in device in lieu of the Halliburton multi-level system described above. 13. Prepare frac fleet to pump. 14. Pump Kuparuk DFIT and analyze the results to obtain fluid loss coefficients. Adjust frac design. 15. Fracture stimulate Kuparuk interval with 16/20 mesh resin coated proppant in cross-linked gel. See "Pump Schedule"for proposed design. 16. Displace with freeze protect fluid. Underdisplace by 3 bbls. Do not over displace. 17. Shut well in. RDMO. • • 18. MIRU CTU and associated equipment 19. RU CTU BOPE and PT to 3500 psi. RIH and cleanout frac sand/frac fluid to a portable test separator with filtered 2% KCI brine and N2 as needed to PBTD. 20. POOH jetting liner and tubing clean. RD CTU 21. RU SL and PCE and PT. Drift casing and tag with GR/JB. RDMO. 22. Turn well over to operations. rer-c J • i 20 AAC 25.283 (a)(12) (A) Estimated Total Volumes Planned 20 AAC 25.283 (a)(12) (B) Trade Name,Generic Name,and Purpose of each Base Fluid and Additive to be Used; 20 AAC 25.283 (a)(12) (C) Chemical Ingredient Name of,and the Chemical Abstracts Service(CAS)Registry Number Assigned to, each Base Fluid and Additive to be used; 20 AAC 25.283 (a)(12) (D) Estimated Weight or Volume of each Inert Substance, including a Proppant or other Substance injected ' c .0 0 LL . 0 0 0 0 0 0 0 0 0 0 0 0 0 \ ��� n 11.o 0 v i x888 888888888 3a'� E, "Ak- 0 0 o n N g.I- o m aaoo 0000000000 �m1'� .n, $oo 7888 8888888888 2a � A n m,�m am R M 8888888888 3- a ' t'r" `° _ 8 §_ § o a § spa fo5 3 .*=888 0 8 8 8 8 8 8 0 8 8 \ 3%r 3 e^it-Lhrg. o z d 0 000, 000 0 0 0 a'�n da0 Vi ¢ = T6 O O o 0 0 0 oo 0 0g &66 a; g 8 888888888 1 'tige aE" o 2 .92 o of o $ a888 8888888888 x.l!„ gE" 0 .4.4 .4 .4 ..;. .. .. ., ., a` a _ n 3 E n z ., E S o 2 .n t i O F E M n Q o o 0o 0i r .,, - ., .. ..0 0 000000 0 $ $ ':° Y j i 4,..v.. �pJ N n '.,e e - p., „ 28 FEsoo 00000000000 ., I 0 c mss nnm6 0 F o f 8 m> V o` 17 RH 7: Eo. m m m n J ;a 8m m88888888m o oa> n m Vn 0 F^ 'f = m m .� C O O t r EZE m N a nn nnnnrvrvrvrvrvry �& 0 88888888 a°8 °' $ V E .. a ra g a a > 8 °:°4 ; ; ; ; 74 :474 ~ n « « .- _ .- C n t E 0 0 a € € 5 fi a 0 m 0 i a o 22 ! " d 33 ~ 3833 ,386a r E ii E '7e' V �, Ng BELL ' aka 3 LL E&' 3 a a o a o a a w _ _ _ '4-_ F iF x a _ t� t� t� t� t� t� o t7 ,9 .9 ._ t ' ry ry z ncSJ5S8$ 88888B _ s 6 § o 'S J > T > a $ 0 M $ $ ", $ $ o A S M $ M $ M m' ,;,;;;i -, ' LL W o LL o Vi .,,, ,,,.. ." n m .,.. 61 '`- r 'v = ,di - n v A.LE'BLL 716866-6966@ LL 0, v E W „d Z pueB 3 ynrednN LL d - - ,,.,—,u, z W 1 • 0., co • c v m ii E T o <A U N < < Q < < < < < < < < < < 0 Z Z Z Z ZZZ Z Z Z Z Z Z U) fn R 2 C N 0 .0 a CD L W W C O CO Cr) CO O O O O O O O O O O O O O N- c- CO C a., C sa E = O zi, * '�° aoow = d r —:... cl , o 'n o ,--1m E u)N d' 0 0 0 X L C = CO 61 0 0 0 C4 C) 0 LL E0 0 0 0 C LL O = U O 0 0o)a o)0 0 o > 0 0 0 0 C a+ 0 0 C 0 d '8 0o M 'a .a O C N C).— Cl) C E O E = L E �+ o C o X O as t) G = O 0 C/) a cll E ca c ) U 3 3 3 3 3 3 3 3 3 3 3 3 3 .E L L O O O O O O _O O O O _O O O a.+ > d It , a) N N a) N a) N N CI) O N O N Q) L .Q 0 .0 co m 0] c] co c] c] c7 c] m c] m m c0 co r r C/) E a a a a a s a a a a a a a M O) U Q C N o a s a CD d c> ,n (A Z N N N N N N N N N N N N N N V O r J J J J J J J J J J J J J 0) so 0) C.) N Q o C m O c m y yN 0- CU = O E — O C a 73 N M 0 Ca L 1] C C) = 3 3 3 3 3 3 3 3 3 3 3 3 w t i+ OOOOOOOO OOOO O O N a = N N N N ) aaU) 5 aaN N U Cl) m m m m m CO m m m m CO CO m - Oa a a a a a a a a vH E _ O U) UU) OaUU) a) a) a)) «) V a aNN N NN ,-7)' 17) 7.5' n) NNoN3 N m a) U L-:, J J J J J J J J J J J � N Q E O r Y E N.Q N a N V' c CO O Y U N m LL M!!I m () N L N w 4-. Q T ON)J W a+ CO' a3 d U 'w L N C NQ ' c U) N "O O 73 O o U) a J C 0 't a 0 s c Q N .0 > CO a Y Y U co9 0- 0 a) a L c c > E o m > > Q c O a (, N O O Y Y Y C w+ w+ - a 2 .. O m cn v) 0 ca m ca — — a' .- 2 w Na 0 o_ O O -o 0 2 2 2 2 m a a ,- m •0 o m m m 0 0 < Z o_ m m c0 CU <C Q m J ON i 0 a) C a C C C a C C a a C (4 N O 0 w c .o E -0 3 j O a) >a. > 0 0 o 0 0 0 0 'O0 0 'O0 0 0 0 'O0 O O 0 Q C c) ' E `a E . = o a F- H a — 1:-.° CO y U Z Z C J O LL O_ 7 S] S] 4 9 S] S] C yam,, d R a J d o O- j u. U) n m m �a is a CC CC m CC To a) CC U) ) O T. Q `m m ;a c o o ) 0 I 2 2 2 2 2 2 2 2 2 2 O d coQ J LL O. 0 J C a0 Tts > (/) OE u 2 CZ 0 W CLL' co c0 y _ Z a)-L co E ❑ ❑W _ OV Z O O— J 22> LL Z O _ Z2O = W J Z Z0co = ❑ w ❑ �in a = oas U c L O d Wm � i O } } Q � 0c t W)— 3 -0 ~ O = n a) n JQYJ � upHc0 MS a ca L LOLLZ cN � 2r.0 QWQ - QWQcoZ OpN Cr) a a F- v) N LL WO N c? O (n F J J W F- J J W m th W -2 N F 0 O CJ2 x LLm0 < 0C) 00 2O ❑ CCm0 ❑ CCcO (.05QO ° 2 •oo0 oD U M 0 = N >,L O -- c a) o f O N 0 • U L_ @ T r C0 C@ O 3 O 4) '6 o @ZYXC �. a) aSZdFco N . E 0 O O a) N O E .N O. >O .O @ o U c o C O O NI N 0 O _ N •co C O r- 0) N CO CO N LU LC)C) o .- co r o) u7 V r CO V CO CS) Nn N CV u7 N COCO r N CO O r U N- N N r CO r to In CO N r CO V CO N f� CO M r .- V r r N CO r r -p _C C 0 - ' CO ,_ 3 O O o\o CO ow ow ow °M 0 ao o\o 0\0 ow ow 0\0 o\o ow 0\0 o\o o\o ow om o\o ow ow 0\0 ow o\o ow l0 0 l0 N co0 N 0 0 to N � N 0 M N (0 Nc (r 01 l0 to l0 rl rl 0 N0 4- lc rl cc 0 W rl CI) 0 NH (N 61 LO O C D C0 CC O N M N� 0) 0 M 0 O O1 U O CV 0 0 l0 Ci 0 l0 l0 M N Ci N N CO 01 OJ CO r-I (N Ln 0 0 0 M 0 0 N @ 0) @ 0 0 N N d' 0 0 O' OJ N 0 u1 0 N NaD 0 0 N 0 0 0 0 N 0 0 CO 0 0 0 0 0 0 0 0 N 0 OJ 0 0 0 N 0 0 0 0 0 0 0 0 0 0 0 rl '� C 0 0 0 0 0 0 0 0 0 0 0 0 0 o O 0 0 0 0 0 0 0 0 0 0 0 0 0 (j a) 0 a) ▪ w C• '•E -6 ow op 0.0 ow 00 ovo ovo ovo ow a 0, ov0 00 ovo ovo 00 0w 0 oy ao 0), ow 00 do oo ovo op ovo 0 E @ 0 0 0 0 0 0 0 0 0 0 0 0 0 O o 0 o O o 0 o 0 0 0 0 0 0 0 O_-O _ o ,--1 0 0 0 0 o O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ,--i 0 � Q c rl 0 0 0 0 0 o O 0 0 0 0 0 LU 0 Lf) 0) 0 v) 0 0) 0 ) r LI-) 0 0 0 0 `- L O 0 0 l0 0 CO CO l0 0 M0 to CO l0 (0 CO 0 O �"' @ CC C C CC 0m E • 0 .N I `o `o a c c • i6 a) U) N _T a) O. (I) c 13.) O m U 0O ..0 — O2 - C .@ Q U 0 C . C 7 (6 a) a) U a0 a) U O C Q Q U ,r'' N O O o L a) -o O C - L C a a N CO O N N M M CA N CO V CO r N W r 0@ o, p_ , N� o_ O O Cl ' O V V Cl O c. M O 00 N O O C2 V N O O uU N N o "' -O U O O N O V Co o O N N 0 N 0 O N O N 0 O V C) N LU ('') 0 .0 0 O a) 0 M r (fl V V O V V O N CA CO CO O CO N CO N� N N a) -o U LI_ o r-- do r d (O Cn CO CO d Cr) d CD r to r r CL o) N N r N N r 3 T C L • T O @ (fl o E c @ O.as r U O @ ,c w a) o v o N 0 _c Q v -o m - o a) > T C O _Co. T a) a) C i L -_-c- C@ O O a) @ as E O N O E ',,, --:,-o c N j, T C 7 O_ C @ E a' 'C a) N a) @ L G U @ 7 CT C O_ ) o o L ca a) w L 72 o a) E a) 0 a) - Q ` @ ai a) N E o f @ o@ > o a w o@ d @ U E U a 0 @ o C 12 O O E o E o o o - a) 3 c o O T @ Q .O„ .N U C 'O T N L @ N O L E @ o U -`O U 6 -O .0 LL U a) o w E E @ N E a) Y c c E Z' @ L ? T o o L o_ m 7 7 @ E t o E E@ @ a) `o r c a EEE E CO o o m L O_ U • o @ to (6 _ @ a) ], @ 'O T 7 7 7 C C U fl_ U E 'E o o - ° o 0) x L o x a L 'y '� '� EEEEEE o fl m a) o o 2 .- . @ a c T o o m o 0 o co U U m m z = o _c _c 43 o a) c o_ a) 3 .0 E E @ 0:5E7 N L @ as -0 -� Cl T T @ @ a a 'D -o -a a O_ C O) U -0 J C...) E E E o a) L Z' c c a) T T @ x L o o 0 0 0 0 0 0 0 0 0 o 0 Q < Q Q m U o U 0 w U` S S I Z 0 (z a_ c a o_ d d 0 u) CO CO CO CO U) 5 • U Q s m @ p (-i's a N -0 rj p L N U Ot L LL X_ U C U w U -O D n 0_ c m CO0 o 0. 7 E — _cs 0 < .) 3 to OO C O .E E O U a) c 7 @ U) @ E @ O- oO N O E a o cE. U .O� C U 0 (N O a) O O O• O E O U C O a) N O ca O EU > �� � 7 @ a) 0 C .E LL 0 9 0 C D U 0 > '- -6a3 F o) C N C Cr) N Ci) O — C a ) O O >@ @ O U N U E 0 !? C 7 a) E .o U (6 O O O Q 0 C a) 0 0 7 I- — o — 7 Cr) q O k Z < Cr o .'n • • 20 AAC 25.283 (a)(12) (E) Maximum Anticipated Treating Pressure and Information Sufficient to Support a Determination that the Well is Appropriately Constructed for the Proposed Hydraulic Fracturing Program. The 5-%"production casing will be tested to 6000 psi for 30 minutes prior to the fracture stimulation. The calculated maximum treating pressure is 4,283 psi. • • 20 AAC 25.283 (a)(12) (F) Designed Height And Length Of Each Proposed Fracture (i) the calculated measured depth and true vertical depth of the top of the fracture: 9,961' MD/6946'TVD (ii) a description of each method and assumption used to determine designed fracture height and length: The MP C-45 fracture stimulation was modeled using the GOPHER program. • 20 AAC 25.283 (a)(13) Description of the Plan for Post-Fracture Wellbore Cleanup and Fluid Recovery through to Production Operations The well will be cleaned up through a portable separation system before turning the well over to Production. Initial returns will be taken to the permitted Milne Point G&I facility for disposal. • • c d r o v0 3wC 2a Vic U E 0Qa12.O.a D � a -- E E 0) o .} 'a N a)0 Y > - = (I) 2CLv 3 CQ M/>y�, L,C Q W a) C L = 0 > 7Y !E a) a Q 7 = CD ca a a /M, L W o rn ea res' 0 0 en C a) C13 0).0 C O CO d) 0 U o Z o To CD E C.) v o• a) a) I � coa)a. � 0. L .+ .0 C V C a) m co U ai 'O V) L a) 0 0 V L. 9O a a O 0 i Ea) d o a) 0 U o � 0) o a S z �/2' . = L > a) re tc a) d c U r a Q— c cc )..4 0 N N > a) co = 14 ^ Q 0 .. V1 Q i N o o 0 ea i.. .4 0 C C i i Q 'i./ rte+ IC o a) a) Q. 0. x m E UQ 2 CO 0- ••••4 .0 C 0 22 glil �T' 0 0 cn as fl a a • STANDARD WELL PROCEDURE HiteorpAlaska.IAA. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets(formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher.Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • I- x S a R° c0 c0 � ., o o E 1' o oeQ o < 0 < Itc > U A= R Y > Er, 7 In U W W ? ry r¢ 0 ,c f W {- W G. > m r.1 G p 7 j a K Z Q OC Z El Gx. 3002< 02 < to , u.1 i•••-it- k'0 441 XZ Ze DR ® b 6 > Na i Q " p, mwy 0_..� .W-1 w > 0 0.x1 U a` ' i .... c IV2 • v • Y O j V ,:;$ 414 '''...Q -coadatiol- v -COI V voa—>— V i. G LL y - t f 1 1' s. II T k rY.. Q 1111 iil'ilil IIII 0 �'" '�,Z,„� { it '_ - lilt 111111 111. a �I T O O O W 9 Oa O O m W m Q in .. a V Y Z Q F Y J to [L 8 0 • • II- I- o to 2 = D E et. m ....4".... . • Tr° 0 74 Er ,-4 on • > 0 . 2 —'5 0 i 3 w. > 1. 3 3 a 3 3 a o o '10IXZZO .., ,,• IE ' 0 —iIIIHMIII-- L..... .• VI 1/1 --. 0 O. LuZ 0 ....: ... < III. LuZ 0 ....: .1 a: 1 1°.E >>• ''*' (?) a 0! 0 cc • z : i z _ , ,...- ...; ; 10166 .0 g ir 0 -E 11 —1:0:1641:01-- • 'NS . I ,. ,q.t T 77,7 -7: 1 8• g 1 0 __nun in iim mi L._ • - .,,,c lin I fill i .-4,' 11 11101111101i.; _ 74 44.4 —MI 111131 III, ,-:-. E 8 ,F,, t,.` L.. r..., z 11 L,.., < LL., ,... 00 -0 0. 1.1. t , ..0 .0 It, Q. V Y Z < 1.- -I-' CIO-' CO 00 VI "..- 2%- • • Bettis, Patricia K (DOA) ?..& "J i /iii z. 43 From: Paul Chan <pchan@hilcorp.com> '7/ Sent: Tuesday, October 24, 2017 3:43 PM To: Bettis, Patricia K(DOA) Subject: RE: MPU C-45 (PTD 217-092): Frac Sundry Application Attachments: MPC-45 PROPOSED 10-24-2017.pdf Patricia Attached is the proposed wellbore completion schematic and formation depths as requested. Top HRZ: 9440' MD/6496'ND Kup C: 9965' MD/6949'ND B-Silts: 9989' MD/6971'ND Kup A3: 10,180' MD/7,136'ND Thanks Paul than Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Tuesday, October 24, 2017 1:28 PM To: Paul Chan<pchan@hilcorp.com> Subject: MPU C-45 (PTD 217-092): Frac Sundry Application Good afternoon Paul, Please provide the total depth of the well, both MD and ND; and a current wellbore schematic showing final depth of the well, packers, proposed perf intervals,TOC,casing shoes, etc. Also please provide the following formation tops (MD and ND) based on actual well logs for MPU C-45: HRZ, Kuparuk C, top Kuparuk B-silts. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 1 Tel: (907) 793-1238 • • CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Wednesday, October 25, 2017 5:58 PM To: Wallace, Chris D (DOA); Bettis, Patricia K (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Hydraulic Fracturing Application Sundry 317-495 MP C-45 (PTD 2170920) Attachments: MP C-45 Fault Map Throws.pptx Patricia/Chris Attached is the requested information: On the structural map at the top of Kuparuk C, four faults are shown within the%2 mile AOR. Please provide the range of vertical throw on those faults. The vertical throw on the faults are shown on the attached PowerPoint slides. Please discuss Hilcorp's planned mitigation measures if there are indications that a fracture has intersected a fault during fracturing operations. If there are indications that the fracture intersected a fault, such as a sharp reduction in the surface treating pressure, Hilcorp would terminate the job at that time. 20 AAC 25.283(a)(12)(F) requires the fractures, height, length, MD, and TVD to top and description of fracturing model used. I have in the application a response identifying the calculated depths of the top of the fracture as 9961 ft MD /6946 ft TVD and use of the GOPHER program. I see separately the schematic with proposed perforation top 9976 ft MD / 6959 ft TVD. Please provide clarification on the latest actual designed model depths and lengths of the fractures. Anticipated half length etc? The top of the fracture depth of 9961' is from the open hole log. The top of the perforation is 9976' MD from the cased hole primary depth control log. Hence the discrepancy in depths. The revised GOPHER model run with 5' cells is predicting: Top fracture MD: 9962 ft Top fracture TVD: 6947 ft Btm fracture MD: 10111 ft Btm fracture TVD: 7077 ft Propped fracture half-length: 500 ft Fracture height: 130 ft Hilcorp is currently planning to pump the fracture stimulation on Friday October 27th. Sincerely Paul Chan Senior Operations Engineer 1 Alaska North Slope Team • • Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent:Wednesday, October 25, 2017 3:29 PM To: Paul Chan<pchan@hilcorp.com> Cc:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov>; Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov> Subject: Hydraulic Fracturing Application Sundry 317-495 MP C-45 (PTD 2170920) Paul, We are reviewing the Frac stimulation sundry for C-45. 20 AAC 25.283(a)(12)(F) requires the fractures, height, length, MD, and TVD to top and description of fracturing model used. I have in the application a response identifying the calculated depths of the top of the fracture as 9961 ft MD /6946 ft TVD and use of the GOPHER program. I see separately the schematic with proposed perforation top 9976 ft MD / 6959 ft TVD. Please provide clarification on the latest actual designed model depths and lengths of the fractures. Anticipated half length etc? Thanks and Regards, Chris Wallace,Sr.Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 2 S • - 1 - L 1 1 c I \ 1 III o3 , .2.,u7' ilk 0 Li c t-- \ v m +-, LT_ LT- Nil ------ -------- ...." it0 „,.-------- / ---'-- 0 A4:0 e c, c.7 u • • kip kipL I— r1 N 4.., a..+ 4--+ CO cp cV I..L LL LL r ,..- • t FIn ... ..� ..4, F Nb , , . . + cO N "s a + ,..,...t LL 0 w o z '' ---tis 1 .z ,k ,. .....,.,......,, 1O I amp t ,,N N1 to *1- i ' t i 1 .1 i 0=,s ; ,-,' 4 '9" • • Q O N O t - L +, U tbA co O >, ix) To a) N c c O N N Q) N i C ) > `n 0 co +, O O O -0 co U 4) O 2 2 rts = - M Y N = i-- M N N _c i +-, a-,+ a--+ +, 8 a-+ co a + Q Lrow w i LL U `L = .....,.--i- Ai / 1 I/ 4,1 . i!n- x U C1 4� LL '� � O'r ,:jot...6 Ohl z a 0 4, .„....„ ,,,,.„._ . , .",.' ill' ,..., .„.. , : , .,.. goo t ,,o v ''Alf ' ' . ' j '- U O e i a , i A N • • N n„ O aJ ^ ^ N W CO CO CO CO CO CO m mv1 m ( m uti Q, Y Y Y Y Y Y Y Y —1 d —i d' Y Y N E a a a a a a a o_ 0 ` C9 a a L a) 0 o� o� _0 1 0 v 1 0 N co r. 01 a) N vi v •C on C I .5 [0 U1 i 01 'o O) (O _N C @ .ai a1 a., ,-1I t •> 01 i Q U v� a) co +-c+ co o Q o 1D °- E a) o V 0..4A t `+ a) c x .... a as .0 O N U N as vs c in �, 3 Co .47' v c Y -a c v N 'oo >. I ^ - 111 a t 0 O m i C 'cn Q 4J Q G = v) D ++ u `V c6 e Uo co '01 ai O M (u a = o- m a, ° 3 I ,� co a — — E -vN OO 0 a N @at '� c i a °' 2 w O a Y rn `�° c '^ Oco URI C 3 m o .--- 2 N cu a at•, 00 +� o a) •`-^ RI Z aJ '^ O Y m C .3 O 3 L N -a @ m co 'Q H +,+ 2 "a z 3 0 -a '~ N co a O +v+ C fo ii a L O `• U a) cp a) to LZ. L O O v�'i tLo '� C ++ 0 0 • O c E Q 11 L a' W +' 'a a O a1 Co ++ Q . C �c H _ U two C1) C L E = a C �' h 0oca m ai o . C_ j N N C N - i N a" C O ' poo « — '- O Y E • N ' m c +r C >cl5 p 0 c O au N . a }t U ci 3 O D N 16 .c N X V1 C m C 4- \� L C-..,. W > d I� N L +�' a) a' 3 U 3� '.. a) O V 0 �O a) a! a1 O L L t N +- +• co , Op i t' v) O ++{ a) E O. 'a 'a 7 Q a) U a1 a1 i L g P. N Li-) C3 O ^ o 5 a ow v 1't7 a) O ci RS I� 1 2 > > c 3 .v '1.- _ CO a) E E N op i_ o o. ;._ „a _c ` " s a, U. N ca 0 0 O I.• I .ate X X u�'10 n N � � a• o = tom dp V O a a z M +.. O_ < co Y a L) w n O1 co Q cn 3 N COC3 of O Q C c L = \ c E c c o 0 > H a o a o zs CI' c '3 0 °v a, `° o o a e _ -c v a, E 1:31 E 0 v v N M a a a, a, .a o Es; S; a O -O N• V LA a o 3 3 ° a LA cs o`, 04) v v Li.) v v N - 3 v ° o, v v . a °L' Q �. V �C- 0 3 •5 a 3 c c a, -c � -c a - H a z �. a a - a, a a E ti', .c GI c 3 3 = a) a, ' 1- '`) u a ... 3 W y o v c a v a w° Q a m CO° v vEi,n .:[Et L 4� O NC OP 41 O• O a`o a a i U Q 0m. a II V s H I 0 O Q • • _ N ti. � 10 41 N 0 3 ? m m m v) m to 0 0 Y Y Y 0 C7 aY N E U U a. a a L) a) O V 0 U 1 N c A 4- 0 EVI .fid 0 ? N aJ vt N .vl 3 L N O l' I•n N O ..0 2 a a 0 4, 4- U I. y co 1 N a) 3 4- LO r•1 i1 C (j Ne O 3 0 +O, a) to a .: 4-, O — 0. +4., = in LO Q_ Qj p1 O N ca N C a) c a N 1 cca o v, p 00 ,,, ^ cu p .� -a `—° U can O °' cu bp 4 a I— a • to L C i C ON N la E (o N a) f6 m of :Ca N OU 'c N a) w () o \ v) a0 > 0 O rn > *' *' cu -cs = > co C ,Ma - Y �'� lb C O a a) as a (13 11-3 i ' �I v in V C a) in a) 0 cn N O ns a1 L C _C 0 to . a O L � `�' tri ;�, i @ v) moi-, C 0 2 d• "C ut 16- !"Q �N C 4-' .+ L = O .E [o Utr) O gyp' c6 > L -0 4= O 0 ++ 0 +, X Q. i Q Y '_' °° v o. C 'A $ c0 0 * on .IV . a1 Q. O c +, U a) > Y oi, v �a 4_, c 0 — r, ' c al L Q L O N a'C.., c a) O ++ +=., cLa (it O +, N t ,V.! +' `�- 'I'' rp O -) 1 — 0 C L f�0 O cp 1 U pp v- ++ �G COL +- N O O bp O O .bb a) U bn Op Q- •`� 'Cr' a),.F i1 v-'i L w op -0 co US `.'- _o Ov .� • +., L _C 3 L •C C U al �o O a) L +, a) = C I 4.a +, C — O L ^ a to c a) c 'C x v ..0 v o . 0 co n3 o ac) v a) 4_ N a; 0 =_ 0 > — 4- 0 0 a) ns v •c 0 N t � — :-0 . 4-, > 0 Ol u, a +-, N a) c c t._ .N 1 U is 4- c -, o), a� co 1•,_ -0 v e-, u0 a0-, 'v) a) '-co i OV OU > a N • j-Y i..; ti F )a) C CU al N U . of O i- +., d C CO 1 L L 4- O CC v)1 = N \, a) i- L CO L 4-, ++ (O C C; (O N coo ,. Y m v Y Y = m l co 0) 4, > u 4 ° cn a) 4-'I L +•(13 D +-, a) i 0 u 0- o a a a a N 4= ca u +- v, _V v tA a rn In a E D _ ++ 0 FO0 o Y Z CO o 0 v `L° _C O O c' a a) ca . cu @ o • N t o f a VI CO 4_ .,.., 0 u 01 0 3 E a) a V •MINIM v • ) N +I- 4-, 0 a) L-0 p -0 v. _ 0 0 0�a ° ° aU _ a _ =+., , N N at t a) .Z ° Cua) a a) a0 o_ ° -- 10. o0 0f v; 0 Coell Ln m op o L. U a s ° a o E 3 2 .2. -z la. CU 0 o 4 CU V L ^ v o o' ° s ° °) a ° o Q v °° to 3 0 a)° � 3a) a a U a OJ 1 _ 4-,o= a o; za Q v . i J v Z:j __— _ -C a L 00 m L m a u 0 0 a • • -- N r►• 0 42)d N 12. UUU 0 Ni E U U 0 0 L O a) V 0 u CU O c p L 4- - = 1?. .� co _c ,_ 2 1 - �O o -c +-, 4- a v CD 4- ++ 4D U _ Y L i ch 4- 0 ( = L } a-+ p in a) >Z O V d' ._ Z a, m 1 O 1 0 I c cCO >' L ,- 4--, L ( C a) to I-- • M � 3 X o oE ` : v a'c v • +. . a) —CO t/) rn p O CD 0 le I 03 c V Z CO >- O c- L v s ai O c ai Qin o ! [N otl?esz i — a a Ts N CL. O cCA a) - Q ( N to '13 l6 V) L l0 H N Z Q j C Qv 0 -6 , t a' p 0 03 O C' v N co >Z 0 ate-, fp +a) Q. a-.I ' -0 SI u trs d 4- U cu c 'yam N r a Q o p `- o o m a ccs Ol 3 m o a v E Q- u CI _ i a •N C c (5U I p •_v p L + 6 a1 i cu v a1 a I O 7 m L I N L c L N 'B '+3 't_3 'a of 0 - a) _ +� p bA L •••• N > > > Xco _ C a) U. P'l 1 v p coo v bD 'J ate+ 0 0 O O O caas as = 0 . a, j' D a, i 3 iii". 2 , v O i 'i O ate., NO ► t +�, I N h O Q Oi i H a O Z3 U v i c i _ m>11 1 r ai �=' i a a 4 = 4 — M M R \ `~ ° n, v i � ° a, o 4'..., -1= l0 0 c N o C3 °' y a vv a N n a. o E y 10 Q av X• vV v o ala o ° o cu a ,-a oi.c c c Li °a ° 'c , a -. 4H a, +a o a 1 a o Q CO v Q o.� a14o c. c 012 1 � NN a N N a)iN v N "� i ; E is M o 3 aa ° a ° C. C3--a' ; o .. > a y a . t a R L on RI L co a U 0 Q • 0 M ,-1 O N J 3 3 N C _ o 0 0 a 0o v o -0 U 0 4, 0 ao = O To�f• L a) 'L •� N • a. .a > 73 N 0 Q O B U 7 a) N u V^' O Cl.) to ,y„ , Q) QJ ao i Qn ° co o a- j 0 c L V^ 00 - a) [ O Q- p v 01 H V 4) N �� Li 1 V C X QQ C O C ,_ Ea a N to L N• en N N N N X ++= co 1 i _ y) a.+ M CO •.. C7 • O VI O 0 N CU in▪ Q) C ; a znRI •� z _" t!• ? y Q on n3 +o' .E = Qom. v) , g -, C L to N 16 v 0 +� C CO 0 U a-+ 4- N N "3 L ° °° m 3 OA `° 'v _ rocE- (,c .oai o o 411 Nt C o CO ' E U $ N ° � 'N• O400 0 t 'II 3 .. 0) E + p p O ao - rn co +� n1 er) v 0 00 = 036 L 4J NV O co vi N ^ v . N w. c -OoN (6 • ^ � ..c U o O1 =' 0) •-i 0 C c E ago U `n +� rnQ1in a a, 00 U c 7, a h t.1 N rn 3 Lnoo .�Iin aX) I- Ln 4- a. 0 v coal ate. • Co Z v vL Q Qin) aa., tui 4 41 4 0 i IA VI O ....I CI- t .Q. O a , a v 'o 0. N C 4.5 M 111 m C.; k y 4 a c C Co m c 3 a ° Cl.)� v a c -c S. o o� Q. N as a o — E i u o a • '" c v c a, V x a, v o` CX 'S o a, 3 p c� o 0 V h \ ^ 'i 1^ • v z c am~ •- Q `O a cc v v o c vC7 v) -0 v uo op ._ O cLI n a °)O -a a. u . o :a o Z v (,)i Q � v oEiIo > cx � � �� o O � N 01 •co tiv a o. -.j a . .0In v o, a, t QJ a v L. °' c c o 0 f a a, �' E a 06 0)) 0 c v v u �, a� a oc v 0o a, v a c, a p a i p U ,� it; Q L Com) 'i a p a�.t, C `ti C a c a c° to in Q v) c `. In ca, o u cc a v a o v a s v -. a o o t -. c. c9 a • • I ai � d U •p M + C co o Z a a. s. a C c VI I- N = 01 4.1 Ln S....• I� a) L ' l a N `a a. %.• Z L. `° s. tA A 1— % Cu Z a 0 a- `"' s 4a v en Ln a� U v�' 1 °° o, v , cN ' V Iav) 13. ojN = . � CIL 3 a , oaV Qts al o 0 a v C U " L a `ti O N acx o •i� (., y,c °i Ia e��o ac ct., bp Q. a 0 u , i a,1:r3 [ c a,I M c i4, a n. t. 1:3-e ivi � 0 O Q 0 0 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, October 25, 2017 3:29 PM To: pchan@hilcorp.com Cc: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA) Subject: Hydraulic Fracturing Application Sundry 317-495 MP C-45 (PTD 2170920) Paul, We are reviewing the Frac stimulation sundry for C-45. 20 AAC 25.283(a)(12)(F) requires the fractures, height, length, MD, and ND to top and description of fracturing model used. I have in the application a response identifying the calculated depths of the top of the fracture as 9961 ft MD /6946 ft TVD and use of the GOPHER program. I see separately the schematic with proposed perforation top 9976 ft MD / 6959 ft ND. Please provide clarification on the latest actual designed model depths and lengths of the fractures. Anticipated half length etc? Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, October 25, 2017 3:05 PM To: pchan@hilcorp.com Subject: MPU C-45 (PTD) 217-092): Frac Sundry Application Good afternoon Paul, On the structural map at the top of Kuparuk C,four faults are shown within the 1/2 mile AOR. Please provide the range of vertical throw on those faults. Please discuss Hilcorp's planned mitigation measures if there are indications that a fracture has intersected a fault during fracturing operations. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, October 24, 2017 1:28 PM To: pchan@hilcorp.com Subject: MPU C-45 (PTD 217-092): Frac Sundry Application Good afternoon Paul, Please provide the total depth of the well, both MD and TVD; and a current wellbore schematic showing final depth of the well, packers, proposed perf intervals,TOC,casing shoes,etc. Also please provide the following formation tops (MD and TVD) based on actual well logs for MPU C-45: HRZ, Kuparuk C, top Kuparuk B-silts. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Schwartz, Guy L (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Tuesday, October 24, 2017 7:37 AM To: Schwartz, Guy L(DOA) Cc: Wallace,Chris D (DOA); Bettis, Patricia K(DOA) Subject: MP C-45 Fracture stimulation sundry submittal (PTD 217-092) Attachments: MP C-45 Cement Bond Log 2017-10-21.pdf Guy Hilcorp Alaska has finished running and cementing the 5-1/2" production casing in the MP C-45 well. I have updated the following sections: 20 MC 25.283(a)(5) 5-1/2" 17#/ft P-110 GeoConn production casing set at 10,259' MD and cemented with 427 ft3/375 sxs of 15.8 ppg Class G cement 20 MC 25.283(a)(6) The CBL/VDL shows TOC at' 8495' MD. Very good to good cement bond is noted from 9090'—10,125'. The log is attached for your reference. 20 MC 25.283 (a)(7) 5-1/2" P-110 production casing pressure tested to 6000 psi for 30 minutes on October 23, 2017. 20 MC 25.283 (a)(12): Step 5 Kuparuk perforation interval: 9,976'-9,996' MD Please let me know if you require any further information. Sincerely Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) 1 • • Schwartz, Guy L (DOA) From: Paul Chan <pchan@hilcorp.com> Sent Friday, October 20, 2017 3:01 PM To: Schwartz,Guy L(DOA) Cc: Wallace, Chris D (DOA); Bettis, Patricia K(DOA);James Fagnant- (C);Alaska NS - Milne - Field Foreman;Alaska NS - Milne -Wellsite Supervisors;Isaac Paterniti Subject: RE:C-45 Frac sundry( PTD -217-092) Guy Hilcorp Alaska and Halliburton will have real time monitoring and a PRV on the 9-5/8"x 5-1/2" annulus. The PRV will be set at 2000 psi. Hilcorp Alaska will adjust the pressure on the 9-5/8" x 5-1/2" annulus until the well pressure stabilizes due to pressure and temperature changes. This step will be added between lines 11 and 12 in the "Proposed Hydraulic Fracturing Program" Halliburton's SOP method to handle a screen out or overpressure event is to use their three level protection system: The fracture stimulation provider, Halliburton, has a three level protection system designed to disengage the pumps to limit the line pressure to the test pressure in (a) 12 (E). The first level of protection "kicks out" a frac pump in a staggered fashion as the treating pressure approaches the test pressure thereby slowing the rate and pressure. The second layer of protection is a global kick out that will place all the frac pumps into neutral at the pre-determined set pressure. The third layer of protection is the DPM (Discharage Pressure Monitoring system)which is independent of the computer controls and will continue to function if the computer controls malfunction. The DPM cuts power to the engines to limit the rate and pressure (instead of taking the frac pumps to neutral). This system protects the surface treating lines and the production casing from an overpressure event as described above without the need for a remote shut-in for the surface line. In addition this system reduces the "water hammer" effect during a screen out and is faster acting then a GORY. Please let me know if you require any further information Regards Paul than Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday,October 19, 2017 3:40 PM To: Paul Chan<pchan@hilcorp.com> Cc:Wallace,Chris D (DOA)<chris.wallace@alaska.gov>; Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject:C-45 Frac sundry( PTD-217-092) Paul, 1 In the fracture procedure there is mention of monitoring or PRV on the OAe"x 9 5/8" annulus). Even though the shoe is open if casing ruptures or leaks you will see a pressure spike and be prepared to SD pumps.Would like this documented in the procedure.. Alaska does very few casing fracs (no frac string)and am not sure how Halliburton is set up to monitor an annulus without a PRV. Why doesn't Halliburton use a Remote shut-in for surface line(per 20 AAC 25.283(d)? Is this SOP for them to use only staged pump kick offs to limit pressure? I am used to seeing some kind of GORV(gas operated valve) . Are you submitting another sundry to run the final completion? 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.schwartz@alaska.gov). 2 • • Schwartz, Guy L (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Friday,October 27, 2017 9:09 AM To: Schwartz, Guy L(DOA) Cc: James Fagnant- (C); Bo York;John Barnes; Matthew Linder,Alaska NS - Milne- Field Foreman Subject: MP C-45 Fracture stimulation program (PTD 217-092) Guy Hilcorp Alaska respectfully requests to replace steps 18-22 on of the"Proposed Hydraulic Fracturing Program"as follows: 18. MIRU CTU and associated equipment. MIRU portable test separator. Route gas to production header. 19. RU CTU BOPE and PT to 3500 psi. RIH and cleanout frac sand/frac fluid to a portable test separator with filtered 2%KCI brine(N2 if needed)to PBTD. 20. POOH jetting casing clean. 21. Flowback well through portable test separator. 22. RIH with CT and clean out casing. Displace well to^'9.8 ppg kill weight fluid. 23. MU bridge plug and RIH. Set plug at 9,500' MD. POOH 24. Test BP to^3500 psi for 30 charted minutes. 25. RDCTUandPTS. 26. Turn well over to Operations With the proposed change,please also remove steps 1—6 on the"Pre-Rig Procedure for the 2-7/8"completion program (submitted as a separate 10-403). Thanks Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) 1 Debra Oudean Hilcorp Alaska, LLC II AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Hilnarp Ahiska,1.1A: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 10/23/2017 To: Alaska Oil & Gas Conservation Commission Meredith Guhl, Petroleum Geologist Assistant 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL MILNE POINT MPU C-45(217-092 RECEIVED Transmitted herewith are cuttings OCT 2 3 2017 WELL BOX SAMPLE INTERVAL /� MPU-C-45 BOX 1 OF 2 7020' - 8610' AOGC;C MPU-C-45 BOX 2 OF 2 8610' - 10262' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Rece ved By. Date: „ I s i 4 • 0 V OF Tit 4. 0)",,���v7,'6. THE STATE Alaska Oil and Gas Pt F o o T e c KA Conservation Commission fALAs S fWa 333 West Seventh Avenue "' C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Fi'C Main: 907.279.1433 Off°'ALAS 1‘14. Fax: 907.276.7542 www.aogcc.alaska.gov Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-45 Permit to Drill Number: 217-092 Sundry Number: 317-363 Dear Mr. Mazzolini: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Commissioner 41/ DATED this 4day of August, 2017. RBDMS t,t, AUG - 9 2017 . • • RECEIVED STATE OF ALASKA AUG 0 3 2 1 ALASKA OIL AND GAS CONSERVATION COMMISSION S 2 11,1(7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown l] Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development El 4 217-092 ' 3.Address: Stratigraphic 0 Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 50-029-23579-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A , MPU C-45 ' Will planned perforations require a spacing exception? Yes 0 No CI/ 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL047434 YP,133 41.7513 ;421 Milne Point Unit/Kuparuk River Oil Pool• 11. I PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,020' 4,806' 6,881' 4,722' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 138' 16" 138' 138' Surface 7,010' 9-5/8" 7,010' 4,802' 5750 3090 Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 4-1/2" L-80 13,000' Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Proposal Summary ❑� Wellbore schematic Ei 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development❑�' Service 0 14.Estimated Date for 8/5/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown j] . Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name:Paul Mazzolini Contact Name: Joe Engel Authorized Title:DrillingManager Contact Email: jenciel(C�hiIcorp.corn 4 y�� Contact Phone: 777-8395 Authorized Signature: iii Date:p$�o3/2,0 j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- 34.3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 bps /"-"` � J f,}__yQ� �^�-�t�J'f �'-e � t�i.✓'e,.S/ r --� V�.S 46 r3`"a -,— C,-t�n 'VI'a.f..c e_. t-;%' Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No (2( Subsequent Form Required: I D ---Li O41 RBDMS \,, - AUG - 9 2017 APPROVED BY Approved by: / /� COMMISSIONER THE COMMISSION Date: 8 _ 4_ 17 'Pia s13J1 gif V1 1 3- 17 0 Rice ffJItAijlidSubmin Form ane Form 10-403 Revised 4/2017 for 12 months from the date of approval. Attachments in Duplicate Joe Engel S Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email jengel@hilcorp.com Hilcorp Alaska,LLC 8/3/2017 Commissioner RECEIVED Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 AUG 0 3 2017 AOGCC Re: Sundry Application for Operational Shutdown of MPU C-45 (PTD#217-092) Dear Commissioner, Hilcorp Alaska, LLC hereby submits for review and approval of the operational shutdown of the planned onshore production well at Milne Point'C' Pad,well slot 45. This sundry application follows verbal communication regarding the proposed operational shutdown, on August 2, 2017 Drilling operations commenced on July 27, 2017 Due to potential rig schedule conflicts and an upcoming rig move to Endicott SDI, in order to not jeopardize the scope of work or barge window at Endicott, Hilcorp Alaska, LLC would like to shut down operations on MPU C-45 after surface casing has been ran and cemented to surface, as per the approved Permit to Drill. Prior to shutdown, the 9-5/8"casing will be pressure tested to 3000psi, a kill string will be ran and the well freeze protected.,/ Please find attached the Form 10-403, Application for Sundry Approval, procedure for operational shutdown and the proposed wellbore schematic for MPU C-45. Hilcorp Alaska, LLC plans to return to MPU C-45 after the rig returns from Endicott, estimated late September/early October. If the operational shutdown period will exceed 60 days, Hilcorp Alaska, LLC will submit the form 10-404. If you have any questions, or require further information, please do not hesitate to contact myself(Joe Engel) at 777- 8395 orjengel@hilcorp.com or Paul Mazzolini at 777-8369. Sincerely, 4 Op"Jo ngel Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska - MPU C-45 Operation Shutdown Procedure 8.3.2017 Current Operation: Running 9-5/8" Surface Casing Plan Forward: • Run 9-5/8" casing to 7,020' MD • Cement 9-5/8" casing to surface Prep Work: • Ensure 7" and 4-1/2" hangers are available • 3,000'4-1/2" 12.6# H625 killstring • Seawater for Displacement • Diesel for Freeze Protect Procedure,following the successful surface cement job and 9-5/8" slip setting: 1. NU &Test BOPE with 5" &4.5" test joints 2. PU clean out BHA 3. RIH and drill out stage cementer at^ 2000' MD 4. Continue RIH and tag top of shoe track 5. CBU 6. Pressure test casing to 31:_a_) 125i, chart test 7. Displace well to seawater 8. POOH, LD clean out BHA 9. RU and Run 3000' of 4-1/2" 12.6# H625 killstring 10. Land hanger, set TWC 11. ND BOPE, NU Tree 12. Pull TWC, Freeze protect tubing 13. Install BPV 14. RDMO If the operational shutdown period will exceed 60 days, Hilcorp Alaska, LLC will submit the form 10-404. • 0 Milne Point Unit H Well: MPC-45 ` Proposed SCHEMATIC Last Completed: Future Hilcorp Alaska,LLC PTD: 217-092 Innovation KB 26.5'Above GL 16 Atm`' z.'r CASING DETAIL rt . Size Type Wt/Grade/Conn Drift ID Top Btm ,:..' 16" Conductor 164/A-106B/Weld N/A Surface 138' 9-5/8" Surface 40/L-80/DWC/C 8.75 Surface 7,010' 4-1/2" Tubing Kill String 12.6/L-80/Hyd 625 3.833 Surface ±3,000' `W= Stage Tool @±2,190'14/70 MD 4, -7. ' OPEN HOLE/CEMENT DETAIL Planned Volumes: xs `,* 1"Stage Lead:304.6 bbls,11.7#Type I/II 1 Stage Tail:43.1 bbls 15.8#Class G'' 12-1/4" 2nd Stage Lead:292.1 bbl 10.#Permafrost L nd . ., 2 Stage Tail:36.3 bbl 15.8#Class G Total Volume:676.1 bbl Calculated Gauge Hole Volume:391.4 bbl r a, PO I 4 , FIt Cij 04,,IA - 4 i¢ WELL INCLINATION DETAIL r Max Hole Angle=54° "1141 6 iii 1 `.4 10 GENERAL WELL INFO tf-,t) t API:50-029-23579-00-00 Ali Original Completion -Future I z ° 9-5/8" E,+�# ' Ca i S0 TD=7,020'(MD)/TD=4,806'(TVD) PBTD=6,881'(MD)/PBTD=4,722(TVD) Revised By:GD 6/15/2017 .... ................—,...................-.-.......-,-.-,........v gi°���\III/7; 4A THE STATE Alaska Oil and Gas sKA ti -s i of Le0 Conservation Commission t,,,,..-_,, -- ,,,- i-iN 333 West Seventh Avenue k " t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Op a�"*t, - p,• ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Paul Mazzolini Drilling Manager Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool,MPU C-45 Hilcorp Alaska LLC Permit to Drill Number: 217-092 Surface Location: 866' FSL,2351' FEL, Sec. 10, T13N, R10E, UM, AK Bottomhole Location: 2392' FSL, 1511' FEL, Sec. 14, T13N, R10E,UM, AK Dear Mr. Mazzolini: Enclosed is the approved application for 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. A minimum of a gamma ray log is required from surface casing point to base of conductor pipe. A cased-hole gamma ray log is acceptable. 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, d:Cg -- Hollis S.French Chair DATED this 2- day of July, 2017. RECEIVED STATE OF ALASKA JUN 2017 AL OIL AND GAS CONSERVATION COMMON PERMIT TO DRILL , G CC 20 AAC 25.005 1a.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is proposed for: Drill CI• Lateral ❑ Stratigraphic Test ❑ Development-Oil 2• 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 Q . Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 • MPC-45 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK MD: 10,688' TVD: 7,261' Milne Point Field 4a. Location of Well(Governmental Section): 7. Property Designation:;f:b.4.,.. 0./74/55 /0 Kuparuk River Oil Pool Surface: 866'FSL,2351'FEL,Sec 10,T13N,R10E,UM,AK (SHL)ADL047434/(TPH/BHL)ADL047437 G'(9'' Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: 2281'FSL, 1612'FEL,Sec 14,T13N,R10E,UM,AK LONS 84-123 7/1/2017 • Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2392'FSL, 1511'FEL,Sec 14,T13N,R10E,UM,AK 5104 10,300 to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 41.3 . 15.Distance to Nearest Well Open Surface: x-558111 • y- 6029147 • Zone-4 GL/BF Elevation above MSL(ft): 14.8 • to Same Pool: 2111'to MPB-18 16.Deviated wells: Kickoff depth: 525 feet . 17.Maximum Potential Pressuresin psig(see 20 AAC 25.035) Maximum Hole Angle: 54 degrees Downhole: ��37 5 ;��"�" Surface: 2977 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Gond 16" 164# A-106B Weld 138' Surface Surface 138' 138' Driven 12-1/4" 9-5/8" 40# L-80 DWC/C 7,000' Surface Surface 7,000' • 4,748' • Stg 1 -1967 ft3/Stg 2-1864.5 ft3 8-1/2" 5-1/2" 17# P-110 GeoConn 10,688' Surface Surface 10,688'' 7,261' • 249.7 ft3 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 0 No ❑ 20. Attachments: Property Plat 2 BOP Sketch 7 Drilling Program 7 Time v.Depth Plot 7 Shallow Hazard Analysis 7 Diverter Sketch 7 Seabed Report 7 Drilling Fluid Program 7 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I 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:Paul Mazzolini Contact Email: jengel@hilcorp.com Authorized Title:Drilling Manager Contact Phone: 777-8395 )-."—�(, rat PAUL 04 A-2-1.0 Li r 1 Authorized Signature Date: 06— /b—/?- Commission Use Only Permit to Drill 0, -•� ,._.9,.,_, API Number: Permit Approval See cover letter for other Number: ( 50-OZ -�Z3 j 9—W" Date: '"1-2-0 —V-1 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane as hydrates,or gas contained in shales: MI Other: itB Doc) y` sz) G� Samples req'd: Yes ❑ No[ Mud log req'd:Yes❑ No L ' r1 �' H2S measures: Yes R"No LI Directional svy req'd:Yes gNo❑ ie 2-5) l .. 4,., ,,,.....1.--, t e-%e- Spacing exception req'd: Yes❑ No Le' Inclination-only svy req'd:Yes❑ No 911 Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY I i Approved by: COMMISSIONER THE COMMISSION Date: 2.4 Submit Form and ( `(1 f rr�10-401 Revised 5/2017 i nths from the date of approval per 20 AAC 25.005(g) Att mentsinDupcate 'Ri11GJarJ° `� .� 7 ./3 7,,x/7 II • Joe Engel 0Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8395 Email jengel@hilcorp.com Hilcorp Alaska,LLC 6/16/2017 Commissioner 1 Alaska Oil &Gas Conservation Commission RECEIVED 333 W. 7th Avenue Anchorage, Alaska 99501 JUN 1. 62017 Re: Application for Permit to Drill MPC-45 AOGCC Dear Commissioner, • Hilcorp Alaska, LLC hereby submits for review and approval for a Permit to Drill an onshore production well at Milne Point'C' Pad,well slot 45. Drilling operations are intended to commence approximately July, 1 2017, pending rig schedule. MPU M C 45 anned to be agrassroots oil producing well, targeting the Kuparuk River Pool. The directional plan is 4 —an S-type slant well with the kick off point at—525' MD/484'TVD. The hole is built to 53 degrees and held to 9,234' MD/6021'TVD where the hole angle is dropped to 30 degrees inclination and held to TD. The 12-1/4" surface hole will TD below the Schrader Bluff OA sand, ±7,000 MD/4,748' TVD, and then 9-5/8" casing will be set and cemented to surface via a two stage primary cement job. Cement returns to surface will confirm TOC at • surface. If cement returns to surface are not observed,a Temp log will be run between 6—18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC. • The 8-1/2" production section will then be drilled to TD in the Kuparuk A at ±10,688' MD / 7,261' TVD. This hole will then be cased with 5.5" 17# P-110 casing and cemented to 500'above the uppermost hydrocarbon bearing zone via a )'-• single stage cement job. �, The Innovation Rip will be used to drill and complete the well. After reviewing the LWD logs obtained while drilling the /ti 'well, a determination will be made whether or not fracture stimulation will be performed at a later date. The base plan, L ori'however, is to fracture stimulate the Kuparuk reservoir. A CBL will be run on the 5-1/2" production casing in the event Ac-6/fracture stimulation is performed. g Please find attached the Form 10-401, Application For Permit to Drill per 20 AAC 25.005 (a) and the drilling program for MPC-45, 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 orjengel@hilcorp.com or Paul Mazzolini at 777-8369 or pmazzolini@hilcorp.com. Sincerely, Joe : gel 'rilli g Engineer Hilcorp Alaska, LLC Page 1 of 1 i • Hilcorp Alaska, LLC Milne Point Unit (MPU) C-45 Drilling Program Version 1 June 16, 2017 Milne Point Drilling Procedure Hilcorp Energy Company 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 Casing Inspection 4 6.0 Internal Reporting Requirements 5 7.0 Planned Wellbore Schematic 6 8.0 Drilling/Completion Summary 7 9.0 Mandatory Regulatory Compliance/Notifications 8 10.0 R/U and Preparatory Work 10 11.0 N/U 13-5/8" 5M Diverter Configuration 10 12.0 Drill 12-1/4" Hole Section 12 13.0 Run 9-5/8" Surface Casing 16 14.0 Cement 9-5/8" Surface Casing 20 15.0 BOP N/U and Test 25 16.0 Drill 8-1/2" Hole Section 26 17.0 Run 5-1/2" Production Casing 29 18.0 Cement 5-1/2" Production Casing 32 19.0 Perform Cleanout Run and CBL 5.5"Cement Job 35 20.0 NU Tree&RDMO 35 21.0 Post Rig Completion Work 35 22.0 Innovation Rig Diverter Configuration 36 23.0 Innovation Rig BOP Schematic 37 24.0 Wellhead Schematic 38 25.0 Days Vs Depth 39 26.0 C Pad Formation Description 40 27.0 Anticipated Drilling Hazards 41 28.0 Innovation Rig Layout 44 29.0 FIT Procedure 45 30.0 Innovation Choke Manifold Schematic 46 31.0 Casing Design Information 47 32.0 8-1/2"Hole Section MASP 48 33.0 Spider Plot(NAD 27)(Governmental Sections) 49 34.0 Surface Plat(As Built)(NAD 27) 50 35.0 Offset MW vs TVD Chart 51 36.0 Drill Pipe Information 5" 19.5#S-135 DS-50&NC50 52 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well MPU C-45 Pad Milne Point"C"Pad Planned Completion Type 5-1/2"Cemented Casing,2-7/8"Gas Lift Target Reservoir(s) Kuparuk C Sand Planned Well TD,MD/TVD 10,688.78' MD/7261.3' TVD . PBTD, MD/TVD ±10,600' MD/7,184' TVD Surface Location(Governmental) 866' FSL,2351' FEL, Sec 10, T13N, R10E,UM,AK Surface Location(NAD 27—Zone 4) X=558,111.1401,Y=6,029,147.5 • Surface Location(NAD 83) Top of Productive Horizon (Governmental) 2281'FSL, 1612' FEL, Sec 14, T13N, R10E, UM,AK TPH Location(NAD 27) X=564,160 Y=6,026,050 TPH Location(NAD 83) BHL(Governmental) 2392'FSL, 1511'FEL, Sec 14, T13N,R10E,UM,AK BHL(NAD 27) X=564,261.82 Y=6,025,939.72 BHL(NAD 83) AFE Number 1710175D AFE Drilling Days 16 Days AFE Completion Days 10 Days AFE Drilling Amount $4,076,408.84 AFE Completion Amount $ 1,856,700 AFE Facility Amount $321,000 Maximum Anticipated Pressure (Surface) 2977 psig Maximum Anticipated Pressure (Downhole/Reservoir) 3571 psig Work String 5" 19.5# S-135 DS-50 (Weatherford Rental) KB Elevation above MSL: 26.5 ft+ 14.8 ft=41.3 ft GL Elevation above MSL: 14.8 ft BOP Equipment 13-5/8""x 5M Annular,(3)ea. 13-5/8"x 5M Rams Page 2 Version 1 June 2017 S Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Energy Company Changes to Approved Permit to Drill Date: 06-14-2017 Subject: Changes to Approved Permit to Drill for MPU C-45 File#: MPU C-45 Drilling and Completion Program Any modifications to MPU C-45 Drilling&Completion Program will be documented and approved below_ Changes to an approved APD will be communicated to and approved by the AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 3.0 Tubular Program: Hole Casing Casing Drift Conn Wt Grade Conn Burst Collapse Tension Sections 1 -# (# ' Cond 16" 14" - - 164 A-106B Weld 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 DWC/C 5750 3090 916 8-1/2" 5-1/2" 4.892" 4.767" 6.050" 17 P-110 GeoConn 10,640 7,470 545 4.0 Drill Pipe Information: Hole OD ID (in) TJ t n }' Section (in) (ink (in) (#/jt ..., . .. ,w $.. (Min) (Max) . (k-1;J )., Surface& 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560k1b Intermediate 5" 4.276 3.25" 6.625" 19.5 S-135 NC50 31,032 34,136 560k1b 5.0 Casing Inspection All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery). Page 4 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 6.0 Internal Reporting Requirements 6.1 Fill 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 tab. • 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. 6.2 Detailed Daily Plan Forwards • Distributed to jengel@hilcop.com and pmazzolini@hilcop.com 6.3 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, jengel@hilcorp.com and cdinger@hilcorp.com 6.4 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 6.5 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drilling Manager&Drilling Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 6.6 Casing Tally • Send final"As-Run"Casing tally to pmazzolini@hilcorp.com, jengel@hilcorp.com and cdinger@hilcorp.com 6.7 Casing and Cmt report • Send casing and cement report for each string of casing to pmazzolini@hilcorp.com, jengel@hilcorp.com and cdinger@hilcorp.com 6.8 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Paul Mazzolini 907.777.8369 907.317.1275 pmazzolini@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Completion Engineer Paul Chan 907.777.8333 907.444.2881 pchan@hilcorp.com Geologist Matt Brown 907.777.8448 713-458-8667 mbrown@hilcorp.com Reservoir Engineer Anthony McConkey ' 907.777.8460 970.529.6199 amckonkey@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350-9439 iorczewska@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com EHS Field Coordinator Jimmy Watson 907.777.8450 907.744.7376 iiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 1 June 2017 S Milne Point Unit C-45 fl Drilling Procedure HilCOrp Energy Company 7.0 Planned Wellbore Schematic Proposed SCHEMATIC Milne Point Unit Well:MPC-45 Last Completed:II Futur PTD:TBD innouatien 26.5' CASING DETAIL Size Tyr:s Wt,,Grade/Conn Dift ID Top 13tm 16' Cone uctcr 164/A-1;163/Weld N/A Surface 131' 9-5/S Si.rface 40/L-30;DAVE L75 Surface 7,DSCr • 5-1/2' Intennec ace 17/ELIO/GrztQa,a0 4.767 Surface 1O59 Sege-co :`11L13 E5 -23w kV 4' • PERFORATION DETAIL Sand Tp(MD tn ihelD: Top(IND) ISM(1VD) FT Date St3T..iS i1e 54k-- TBD T3D 9111' A '1156 Pri) P.IITACOCC UM MM. WELL INCLINATION DETAIL Max Hole Argie=54 OPEN HOLE f CEMENT DETAIL 9-5,r 3631 cu&12-1,43"Hole -.XJ4 5-1/2' 249 7 cu/sin 8-yr Hole GENERAL WELL INFO API:TBD 5-1.07 Original Completion-TEO TD=±143E9'[NC;""TD=7,251MOD{ PBTD==,920''[heti P5TD•=7,15VITVD1 • RecinedBy OD 6/15/2017 Page 6 Version 1 June 2017 • S Milne Point Unit C-45 Drilling Procedure Hilcorp Enny company 8.0 Drilling / Completion Summary MPU C-45 is a grassroots producer with the Kuparuk C sand as the primary target. • The directional plan is an S-type slant well with the kick off point at—525' MD/484' TVD. The hole is built to 53 degrees and held to 9,234' MD/6021' TVD where the hole angle is dropped to 30 degrees inclination and held to TD. Drilling operations are expected to commence approximately July 1st, 2017,pending rig schedule. The Innovation Rig will be used to drill and complete the well. After reviewing the LWD logs obtained while drilling the well, a determination will be made whether or not fracture stimulation will be performed at a later / date. The base plan,however,is to fracture stimulate the Kuparuk reservoir. A CBL will be run on the 5-1/2" production casing in the event fracture stimulation is performed at a later date. • Surface casing will be run to±7000' MD/4748' 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, a / temp log will be run between 12—24 hours after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC personnel. Production casing will be run to+10,688' MD/7,261' TVD and cemented to 500' MD above the Kuparuk C. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located on"B"Pad. General sequence of operations: 1. MIRU Innovation Rig to well site 2. N/U 13-5/8", 5K BOP stack in diverter configuration with a 13-5/8" diverter T & 16" knife gate valve on the conductor and 16" diverter line. Function test diverter. 3. Drill 12-1/4"hole to TD of surface hole section. Run& cement 9-5/8" surface casing. / 4. N/D diverter line, diverter T &knife gate valve.N/U casing head,N/U&test 13-5/8" BOPE. 5. Drill 8-1/2"hole to TD. 6. Run and cement 5-1/2"production casing. 7. Perform CBL 8. N/D BOP,N/U tree, RDMO. 9. A separated 0-403 sundry will be submitted for the hydraulic fracture stimulation and completion operations. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. LWD: GR+Res 2. Production Hole: No mud logging. LWD: GR+ Res+ CTN 3. Cased Hole Logs: CBL over 5-1/2"production casing. Page 7 Version 1 June 2017 Milne Point Unit C-45 111 Drilling Procedure Hilcorp Faera Company 9.0 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 C-45. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4000 psi & subsequent tests of the BOP equipment will be to 250/4000 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: • There are no variance requests at this time. Page 8 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure Hilcorp Emu CamPanY Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12 1/4" • 13-5/8"5M CTI Annular BOP w/16"diverter line Function Test Only • 13-5/8"x 5M Control Technology Inc Annular BOP • 13-5/8"x 5M Control Technology Inc Double Gate Initial Test:250/4000 t o Blind ram in btm cavity (Annular 2500 psi) • Mud cross w/3"x 5M side outlets 8-1/2" • 13-5/8"x 5M Control Technology Single ram • 3-1/8"x 5M Choke Line Subsequent Tests: • 3-1/8"x 5M Kill line 250/4000 • 3-1/8"x 5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi,220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit 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: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@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.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/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 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure HilEma.o 10.0 R/U and Preparatory Work 10.1 C-45 will utilize a newly set 16" conductor on C Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 10.2 Dig out and set impermeable cellar inside existing culvert. 10.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 10.4 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line• up with flowline later. 10.5 Insure (2) 3"threaded nipples are installed on opposite sides of the conductor with ball valves op each nipple. These will be used to take cement returns to the cellar during the surface cement job, and also to wash out the diverter and hanger in preparation for running the pack-off. 10.6 Level pad and ensure enough room for layout of rig footprint and R/U. 10.7 MIRU Innovation Rig. 10.8 Mud loggers WILL NOT be used on either hole section. 10.9 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 10.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if is accidently dropped. 10.11 Install 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5%volumetric efficiency. 11.0 N/U 13-5/8" 5M Diverter Configuration 11.1 N/U 13-5/8" CTI BOP stack in diverter configuration(Diverter Schematic in Sec 21 of program). • N/U 16" SOW • N/U 13 5/8", 5M diverter"T". • NU 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 ignition source • Place drip berm at the end of diverter line. Page 10 Version 1 June 2017 • S 111 Milne Point Unit C-45 Drilling Procedure Hilcorp ,1 Energy Company 11.2 .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. 11.3 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. 11.4 Rig & Diverter Orientation: 1 i-_i, ■ 19 4 ■ ■ 3 I 43 IC!46 2 ■ ■ 1724 ■ ■ 4225 ■ 9 ■ ■ , 26 II rr^" 44 ii 36 f I ; ,� 46 'I 10 45 ■ 13 +\� / I11 28 ■20 I «.�� ■ `, \ 89 : ` ■ 14 II 47 a 41 B II ■ IS s ■ iii ,s 75'Radius Clear of Ignition Sources ■ 22 Cl[3 ■ la ■ a I 12 q Ip L J o —Diverter Line 0 j fi tt It t t 1 1 MPU C-PAD *Drawing Not To Scale Page 11 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hileorp Energy Company 12.0 Drill 12-1/4" Hole Section 12.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected prior to PU • 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 so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill pipe will be 5" 19.5# S-135 DS50. • Run a solid float in the surface hole section. 12.2 5" drill pipe, 5" HWDP, and Jars will come from Weatherford. 12.3 Hold Pre-Spud Meeting with rig crews and service contractors • Discuss: • Pre Spud Checklist • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation. • Flow rates, hole cleaning, mud cooling, etc. 12.4 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 12.5 Drill 12-1/4"hole section to 7000' MD/4748' TVD. 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. • 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 450-600 gpm. Monitor shakers closely to ensure shaker screens and returns line are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips if necessary. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW and viscosity as necessary to maintain hole stability. • Take Gyro & MWD surveys every stand+/- 60'. Gyro surveys until clear of magnetic interference. • No gas hydrates have been encountered on C Pad wells, however be prepared if hydrates are seen. Page 12 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company • 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 issues. Flow rates can also be reduced to prevent mud from belching over the bell nipple. Consider adding mud products such as Lecithin to all the gas to break out. • Have the water and air flowline jets hooked up and be ready to jet the flowline at the first sign of flowline backup. The combination of air and water is useful to minimize volume of fluid added to the system. • MPC-46 LL: No issues with flow line packing off, managed with jetting. Control drill while cleaning out conductor and drilling t/—280' • Do not stop to circulate on wiper trips with bit across a slide interval, especially not in an area where DLS is>4. • Do not slide for 100' MD above the base of the permafrost or 100' below the base. We want to leave this transition as undisturbed as possible. • Ensure TD of the hole section is 100' MD below Schrader Bluff Sands, at a minimum. Confirm with Geologist 12.6 12-1/4"hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite 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. • PVT System: An electronic PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the Driller's console, Co Man office and Toolpusher office. • Hydrates: Hydrates have not been encountered on any "C" Pad wells drilled to date. Be prepared if any are seen and don't stop to circulate out gas. Control drill when hydrates are encountered. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 45 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. Page 13 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company • 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. • 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 —9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL Temp pH 110'-4800' 8.8—9.5. 75-175 20-40 25-45 <10 <70° F 8.5—9.0 K')�l �b (��.l 41System Formulation: Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 -20 ppb caustic soda 0.1 ppb(8.5-9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8-9.5 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb 12.7 At TD; pump sweeps, Circulate 2-3 BU at high flow rates and rpm—racking back 1 stand per BU and alternating reciprocation depths to minimize risk of troughing and dropping inclination. Pump out of the hole holding TF high side. Pull slow if hole starts unloading. • MPB-33 LL: Drop vise to— 50 cp and MW of 9.4 at TD before coming out of the hole resulting in smooth BROOH out and casing run 12.8 If hole conditions will not allow the BHA to be pulled out on elevators,prior to initiating backreaming,try to orient the motor high side and attempt to pump out to avoid damaging the wellbore. Page 14 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 12.9 Should backreaming be necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 2-3 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (450-600 gpm) and maximize rotation below permafrost Minimize backreaming in permafrost, backreaming is a last resort • Pull slowly, 5— 10 ft/minute, monitor torque closely. • Monitor well for any signs of packing off or losses. • Have the air and water flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling, packing off or running gravels • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 12.10 Trip/Pump/BR OOH as necessary with the drilling assembly and handle BHA components as required. 12.11 No open hole logging program planned. • • Page 15 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 13.0 Run 9-5/8" Surface Casing 13.1 The plan is to set slips for 9-5/8" casing to facilitate good circulation during the cement job. 13.2 -R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8"DWC/C x DS50 XO on rig floor and M/U to FOSV. • Use "Besto Life 2000"thread compound. Dope pin end only w/paint brush. • Consider R/U of CRT if hole conditions require. • R/U a fill up line to fill casing while running. • Ensure all casing has been strapped & drifted to 8.750" 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. 13.3 P/U shoe joint, visually verify no debris inside joint. 13.4 Continue M/U&thread locking shoe track assembly consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). Install (2) centralizers on shoe joint over stop collars 10' from each end. • (1) Joint with float collar bucked on pin end &thread locked. Install (1) centralizer mid tube over a stop collar. • Ensure bypass baffle is correctly installed on top of float collar. Bypass Baffle This end up. 0111111144 rAl 1 • (1) Joint with Halliburton bypass baffle adapter bucked on pin&threadlocked. Install (1) centralizer mid tube over a stop collar. • 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 Version 1 June 2017 0 0 II Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 13.5 Float equipment and Stage tool equipment drawings: "A !, Overall Length r Type H ES Cementer 3' B Part No. Mm.ID Atter Dr out mi C SO No. Max.Tool OD M D Map ESal Order Owing Seat ID A Closing Sleeve No.Shear Pins E .111011111111•1Closing Seat ID Opening Sleeve ! I I. No.Shear Pins Plug Set ES-II Cementer ez ES Cementer i Part No. Depth 2 C5 C+ SO No. 1 1 r Closing Rug Baffle Adapter(if used) Shut oft Plug III ID Opening Plug Depth OD Baffle Adapter 1 OD a Il ! Bypass or Shut-off Baffle 11 , ID By-pass Plug II 11 11) Depth Shut-off Plug Float Collar �� DlIIPIPP�� epth By Pets Baffle i WINT OD Boat Gar Float Store Depth Bypass Plug (if used) Mil Hole TD Roat Shoe "Reference Casing OD Sales Manual Section 5 t Page 17 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 13.6 Continue running 9-5/8" surface casing • Fill casing while running in the hole every joint and top off every 5, using fill up line on rig floor or CRT. Circ through shoe track. • Install (1) centralizer every other joint for the first 15 joints. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • M/U DWC/C connections as per recommended torque ratings below. • 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. 13.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at 2300' MD/ 1924' TVD. This will position the stage collar comfortably below the permafrost. • Install centralizers over couplings on 3 joints below and above stage tool. • Do not place tongs on ES cementer,this can cause damage to the tool. • Ensure tool is pinned with 6 opening shear pins. There are 6 holes,the tool is normally sent with only 4 pins installed. This will allow the tool to open at 3300 psi. 9-5/8" 40#L-80 DWC/C Make Up Torques: Min MU Torque Max MU Torque 28,900 ft-lbs 34,800 ft-lbs 13.8 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 13.9 Slow in and out of slips. 13.10 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. 13.11 Lower casing to setting depth. Confirm measurements. 13.12 Have slips staged in cellar, along with necessary equipment for the operation. Page 18 Version 1 June 2017 • Milne Point Unit C-45 111 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Casing 9-5/8 in 40.00 Ib/ft(0.395 in) L-80 standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) 11111111111111111111111MMIWVSA 95,000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suve 150 Pipe Dimensions Houston.TX 77041 Phone:713-475-3200 9.625 Nominal Pipe Body O.D. (in) Fax:713-479-323-4 8.835 Nominal Pipe Body 1_0.(in) E-mail:VAMUSAsaiese)vam-usa_com 0.395 Nominal Wall Thickness (in) 40.00 Nominal Weight (Ibslft) 38.97 Plain End Weight (Ibs.+ft) 11.454 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 916,000 Minimum Pipe Body Yield Strength (lbs) 3,090 Minimum Collapse Pressure (psi) 5,750 Minimum Internal Yield Pressure (psi) 5,300 Hydrostatic Test Pressure (psi) Connection Dimensions 10.625 Connection O.D. (in) 8.835 Connection I.D. (in) 8.750 Connection Drift Diameter (in) 4.81 Make-up Loss (in) 11.454 Critical Area (sq in) 100.0 Joint Efficiency (%) Connection Performance Properties 916,000 Joint Strength (lbs) 16,380 Reference String Length (ft) 1.4 Design Factor 947,000 API Joint Strength (lbs) 916,000 Structural Compression Rating (lbs) 3.090 API Collapse Pressure Rating (psi) 5,750 API Internal Pressure Resistance(psi) 19.0 Maximum Uniaxial Bend Rating [degrees/100 ft] : Appoximated Field End Torque Values 29,800 Minimum Final Torque (ft-lbs) 34,800 Maximum Final Torque (ft-lbs) 39,800 Connection Yield Torque (ft-lbs) 13.13 R/U circulating equipment and circulate B/U. Reduce YP to <20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. 13.14 Hold casing string and reciprocate casing if possible while conditioning mud. Page 19 Version 1 June 2017 Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 14.0 Cement 9-5/8" Surface Casing 14.1 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 pump 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 iron lines and connections used to route slurry to rig floor. 14.2 Document efficiency of all possible displacement pumps prior to cement job. 14.3 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. 14.4 R/U cementing head (if not already done so). Witness loading of the top and bottom plugs to ensure done in correct order. 14.5 Fill surface cement lines with water and pressure test. 14.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 14.7 Drop bottom plug(flexible bypass plug)—HEC rep to witness. Mix and pump cement per below calculations for the 1St stage, confirm actual cement volumes with cementer after TD is reached. 14.8 Cement volume based on annular volume+ 30% open hole excess. Job will consist of lead& tail, TOC brought to stage tool. Estimated Total Cement Volume: Vol Section Calculation (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" (6500' -2300') x .0558 bpf x 1.3 = 305 1710.5 Casing Total Lead 305 1710.5 11 L 12-1/4" OH x 9-5/8" (7000' -6500') x .0558 bpf x 1.3 = 37 204 Casing 12-1/4" Rat Hole (7010'-7000')x.145 bpf X 1.3 = 1.9 10.67 9-5/8" Shoe Track 90'x.0758 bpf= 6.8 38.2 Total Tail 45.7 256.67 IV 2'" Page 20 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company Cement Slurry Design (both 1st and 2°a stage cement jobs): Lead Slurry Tail Slurry System Type I/II Type I/II Density 11.7 lb/gal 14.5 lb/gal Yield 2.5069 ft3/sk 1.39 ft3/sk Mixed 14.35 gal/sk 6.8 gal/sk Water 14.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, f the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 14.10 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud m out of mud pits. HEC Rep to witness. a. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 14.11 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. /3f M s-t-� 14.12 Displacement calculation: Dv" r301 M,ko (7000'-90')x .0758 bpf= 523.8 bbls total5 Ensure 80 bbls water to be left across stage tool to ensure proper operation once opened. 14.13 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. 14.14 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume,+3.4 bbls before consulting with Drilling Engineer. 14.15 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. 14.16 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 Page 21 Version 1 June 2017 Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 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. 14.17 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. 14.18 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have sacks of sugar 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. Second Stage Surface Cement Job: 14.19 Prepare for the 2nd stage as necessary. Circulate until 1 stage reaches sufficient compressive strength. Hold pre job safety meeting. 14.20 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 14.21 Fill surface lines with water and pressure test. 14.22 Pump remaining 60 bbls 10.5 ppg tuned spacer. 14.23 Mix and pump cement per below recipe for the 2nd stage. 14.24 Cement volume based on annular volume+ open hole excess (200% for lead and 30% 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 Total Cement Volume: Z P Section Calculation Vol (bbl) Vol (ft3) 16" Conductor x 9-5/8" Casing (140')x .1289 bpf x 1= 18 101.3 J 12-1/4" OH x 9-5/8" Casing (1800' - 140')x .0558 bpf x 3 = 277 1555.2 Total Lead 295 1656.5 — 12-1/4" OH x 9-5/8" Casing (2300' - 1800')x .0558 bpf x 1.3 = 37 208 co Total Tail 37 208 Page 22 Version 1 June 2017 4111 Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company Cement Slurry Design (2nd stage cement job): Lead Slurry Tail Slurry System Permafrost L Type I/II Density 11.1 lb/gal 14.5 lb/gal Yield 4.3279 ft3/sk 1.39 ft3/sk Mixed 21.405 gal/sk 6.8 gal/sk Water 14.25 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 14.26 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. f l� 14.27 Displacement calculation: 2300' x .0758 bpf= 174.3 bbls mud 14.28 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 some sacks of sugar available to retard setting of cement. 14.29 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. 14.30 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. Set slips and back out and L/D landing joint. 14.31 Flush out wellhead with FW and BOP stack thoroughly to ensure cement, mud and cuttings are removed. 14.32 M/U pack-off running tool and pack-off to bottom of the landing joint. Set casing slips pack off. Run in lock downs and inject plastic packing element. Pressure test to 2450 psi. 14.33 Lay down landing joint and pack-off running tool. Page 23 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 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 • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • If losses are seen during cement job, note at operation during the cement job they were observed and where the cement was at the time of losses • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped&bump pressure and if floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • 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 jengel@hilcorp.corn and cdinger@hilcorp.corn This will be included with the EOW documentation that goes to the AOGCC. Page 24 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 15.0 BOP N/U and Test 15.1 N/D the diverter T, 16"knife gate, 16" diverter line &N/U 11" x 13-5/8" 5M casing spool. 15.2 N/U 13-5/8"x 5M CTI 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 5.5" VBRs in top cavity, blind ram in bottom cavity. • Single ram should be dressed with 2-7/8" x 5.5" VBRs • N/U 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 & HCR valve on choke side of mud cross. (manual valve closest to mud cross) 15.3 Run 5" BOP test assembly, land out test plug (if not installed previously). • Test BOP to 250/4000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Confirm test pressures with PTD • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. • We will need to test on the following sizes: 5" & 5.5" (for 5" DP & 5.5" Test Joint) 15.4 R/D BOP test assembly. 15.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 15.6 Mix 9.5 ppg Baradrill-N LSND fluid for production hole. 15.7 Set 10" ID wear bushing in wellhead. 15.8 Keep 5" liners in mud pumps. Page 25 Version 1 June 2017 I • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 16.0 Drill 8-1/2" Hole Section 16.1 P/U 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 MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill pipe will be 5" 19.5# S-135 NC50 & DS50. • Install ported float in the BHA. J 16.2 8-1/2" Mud Motor Directional Assembly(Includes triple combo LWD, PWD): COMPONENT DATA Item Description Serial Number OD ID Gauge Weight Top Length Cumulative (in) (in) (in) (lbpt) Connection (ft) Length (ft) PDC 6.360 2.750 8.500 88.03 P 4-112"IF 0.91 0.91 T SperryDrill Lobe 7/8-6.0 stg 11111111111 7.000 ICEIIIIIIIILE011=11116E3111111C1311 Stabilizer -__ 8.250 _--_ © 6 3/4'Integral Blade 6.750 2.813 8.313 100.78 B 4-112"IF 6.95 35.19 6 314"DM Colar NEM 6.750 M 103.40 44.40 ® 6 314"DGR Collar 6.750 t920 97.80 B 4-112"IF 6.75 51.15 11311 6 314"EWR-P4 Collar 6.750 2.000 104.30 B 4-112'IF 12.11 63.26 6 314"PWD Collar • 6.750 1.905 96.30 B 4-112"IF 4.44 67.70 6 314"HCIM Collar 1111111111111 6.750 1.920 1111 101.70 B 4-112"IF majmain Q 6 314'ALD Collar • 6.750 1.920 8.250 104.30 B 4-112"IF 16.27 90.80 Stabilizer111111111111111111 8.250 IIIIII NM= 1111111111 10 6 314"CTN CollarMEM 6.750 1.905 1111111 102.30 Mell IBM 102.63 6 314"TM Collar 6.750 2.810 100.82 B 4-112"IF 10.01 112.64 Km 6 314"Non Mag Flex Collar 111.1111111 6.700 30.98 ® 6 314"Non Mag Flex Collar 6.880 2.813 105.52 B 4-112"IF 30.97 174.59 6jtsx5"X3'HWDP 5.000 3.000 11111111121111111111111111 184.00 MEM ® Jar 6.250 2.250 91.01 B 4-112"IF 31.79 390.38 23 its x 5'X 3"HWDP 1111111111 5.000 3.000 402.00 792.38 Total: 792.38 Page 26 Version 1 June 2017 I • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 16.3 8-1/2" hole section mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1) ppg above highest anticipated MW. • 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. • Run the centrifuge continuously while drilling the production hole, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. • Canrig 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: 9.5— 11.6 ppg KC1 Inhibited WBM Properties: Depths Density Plastic Viscosity Yield Point LGS MBT HPHT pH 7000'-10,688'• 9.5— 11.6 ppg 15-25 15-20 <6% <20 <11.0 9-10 System Formulation: Baradrill-N Product Concentration Water 0.94 bbl KCL 22 ppb Barazan D Plus 1.25 ppb(as req'd for YP) PAC L 1.0 ppb Dextrid LT 3.0 ppb Barotrol Plus 5.0 ppb BDF-515 4.0 ppb Caustic Soda 0.2 ppb Baroid 41 As req'd for MW Aldacide G 0.25 ppb 16.4 Single in the hole w/ 8-1/2" directional assembly on 5" DP from pipe shed to stage tool. Shallow test MWD Page 27 Version 1 June 2017 I Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 16.5 Note depth TOC tagged on AM report. Drill out stage tool as follows: • Do not exceed 75 rev/min rotation speed. A good range is 40 to 75 rpm. • Drilling with minimal WOB is recommended, 2-5 K# is enough. • Apply weight and allow it to drill off before applying more. • After drilling out, chase any remaining debris to bottom with the drill bit. 16.6 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 16.7 R/U and test casing to 2900 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst= 5750/2 =2875 psi. Test pressure for the well is 2900 psi. 16.8 Drill out shoe track and 20' of new formation. 16.9 CBU and condition mud for FIT. OWFF and pull into casing shoe X 16.10 Conduct FIT to 13.5 ppg EMW. If 13.5 ppg EMW is not obtained call and discuss with Drilling Engineer. kj, ,z k F f 3. -- II i.o if 2,5 2'S X .6 S o�� �.a�. 71s0 16.11 Drill 8-1/2"hole section to section TD per Geologist and Drilling Engineer. • • Pump at 500 gpm, 259 ft/min annular velocity • 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. • Take MWD surveys every stand+/- 60'. Surveys can be taken more frequently if deemed . necessary. • Pump high vise sweeps to aid in hole cleaning. • Perform wiper trip 200' before penetrating HRZ • Before drilling into the HRZ, weight up t/ 10.4 ppg and increase KCl to 6% and increase • black products for shale stability • Once below the HRZ, keep drilling ECDs below 1ppg over static MW • Closely monitor PWD information while drilling to minimize ECD, especially important . when drilling through the HRZ. • Keep swab and surge pressures low when tripping, especially important when tripping through the HRZ Formation. • Slow and smooth pulling in and out of slips on each connection. • Slowing ramp pumps on/off on each connection • Monitor hole cleaning indicators, PUW, Pump pressure and ECD, Make wiper trips as 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. Page 28 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 16.12 At TD; pump low vis sweeps, CBU at full rate and RPM at least 3 times at maximum circulation and rotation, Alternate reciprocation depths while CBU to reduce risk of toughing and dropping inclination. 16.13 Weight up at TD for shale stability while TOOH, ±10.8 ppg • While weighting up, keep ECDs at or below drilling ECDs 16.14 If back reaming is necessary: • Circulate at max rate while mainting drilling ECDs (flow will be less due to 10.8 ppg MW) • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std(slip to slip time, not including connections). • If back reaming operations are commenced, continue back reaming to the shoe and circ at least a b/u once at the shoe. Back reaming is a last resort to clean up the hole in the HRZ. 16.15 TOH with the drilling assembly. • While TOOH, watch swab pressures, even if hole is taking proper displacement, swab pressures can destabilize HRZ • TOOH String speed t/500 fph until 1000' above HRZ, then slowly increase string speed in 500 fph increments, not exceeding 3000fph 16.16 L/D BHA. 16.17 VBRs are 2-7/8"x 5.5" and have been tested on prior BOPE test. If necessary, change out upper pipe rams t/5.5" solid body rams. Test 250/4000 psi. 17.0 Run 5-1/2" Production Casing 17.1 R/U 5.5" casing running equipment. • Ensure 5.5" GeoConn x NC-50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been strapped & drifted in the pipe shed prior torunning. • Be sure to count the total # of joints in the pipe shed 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. • R/U CRT or tongs. • Make dummy run with 5.5"hanger and landing joint. 17.2 M/U &threadlock shoe track assembly consisting of: • (1) Float shoe joint w/float shoe bucked on. Install (2) solid body centralizers 10' from each end. • (1) Baker locked joint. Install (1) solid body centralizer mid joint. • (1) Float collar joint w/float collar bucked on pin end. Install (1) solid body centralizer mid joint. • Ensure proper operation of float shoe and float collar. Page 29 Version 1 June 2017 ! • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 17.3 Run 5.5" 17# P-110 GeoConn casing. • Fill casing while running using CRT or fill up line. • Use BestoLife 2000 thread compound, ensure thread compound is compatibale with Geoconn. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install solid body centralizers on each joint from shoe track to — 500' MD above Kuparuk, ±9,888' MD and 3 centralizers across 9-5/8" shoe. 17.4 RIH based upon tripping schedule, keeping surge pressures at or below drilling ECDs. Watch displacement carefully and avoid surging the hole. Slow down running speed as necessary, especially through the HRZ. 17.5 Slow in and out of slips. 17.6 Stage up pumps slowly to minimize potential packoffs. Work pipe while staging up pumps and circulating. Circ clean before rigging down CRT and M/U casing hanger to landing joint. 17.7 P/U casing hanger joint and M/U to string. Position the shoe as close +/- 10' from TD. Strap the landing joint while it is in the pipe shed and mark the joint at(1) ft intervals to use as a reference when landing the hanger. Ensure top of shoe track is below the base of Kuparuk to clear entire perforation interval. 17.8 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 17.9 Casing Contingencies: • Based upon hole conditions, the decision may be made to set the casing with slips. This will facilitate rotation during the cement job. Have emergency slips ready. Confirm measurements to ensure that a collar is not across the landing ring in the wellhead for setting slips. • If there are any issues with the 5.5"hanger, we will cross over and use the 7"hanger 17.10 R/U circulating equipment and circulate B/U. Reduce YP to <20 to help ensure success of cement job. Elevate hanger slightly above hang off point while circulating to avoid plugging the flutes. 17.11 After circulating, lower string and land hanger in wellhead again. Page 30 Version 1 June 2017 Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 5-1/2" GeoConn M/U Torque Min Casing MU Torque Opt. Casing MU Torque Max Casing MU Torque 10,800 12,000 13,200 Page Stn rrrt r liar GeoConn Date 7-Aug-14 Connection Data Sheet _ heetal One Corp Rev. 3 Connection : GeoConn f Imperial S.L Pipe Body Grade P110 P110 Pipe OD f,D) 5.500 in 139.7 mm Weight 17.0 lb'ft 25.33 kq•m wall thickness{t) 0.304 in 7.72 mm Pipe ID i d;1 4.892 in 124.26 mm Drift Dia. 4.767 in 121.08 mm Connection Pipe Critical Aera 4.96 in2 3.200 mm2 Box critical Aera 6.10 in' 3.935 mm= Coupling OD l LL`; 6.050 in 153.67 mrr Coupling Length(NL) 8.350 in 212.09 mrr Make up Loss 4.125 in 104.78 mm Thread Taper 1; 16(3+4"per ft) Number o'tnreads 5 TPI Performance Properties S.M.Y.S. 545.8 kips 2.428 kN Connectiar Jo r:Stena:h 567.9 kips 2.526 kN MJ.P.Y. 10,640 psi 73.38 ' MPa Collapse strength 7,470 psi 51.52 MPa Pipe body Yield Torque 64,642 ft-lb 87,600 N-m Note S.M.Y.S. . Specified Minimum YIELD Strength of Pipe body M.I.Y_P. . Minimum Internal Yield Pressure Torque Recommended Min. 10,800 ft-lb 14,60_) N-m Opti. 12,000 ft-lb 16.230 N-m Max_ 13.200 ft-lb 17.800 N-m Operational Max. 16,200 ft-lb 21,900 N-m riDonnection Yield Torque I 18,400 I ft-lb 1 24,900 I N-m Note:Operational Max.torque can be applied for high torque application Legal Nod e The use of the in'arrr.adon a a the readers risk and no warranty is implied or expressed by MetalCne Corporador with respect to the use of information contained herein. Page 31 Version 1 June 2017 S Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 18.0 Cement 5-1/2" Production Casing 18.1 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. • How to handle cement returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cement operation. • Extra hands in the pits to strap during the cement job to identify any losses • Document efficiency of all possible displacement pumps prior to cement job. 18.2 5.5"cement job will be a single stage, single slurry job. . 18.3 R/U cementing head (if not already done so) or to cement lines on cement swivel on CRT. Witness loading of plugs to ensure they are loaded correctly. 18.4 Fill lines with 5 bbl water. Pressure test surface cementing lines to 4000 psi. 18.5 Pump 40 bbls 13.5 ppg spacer. 18.6 Drop bottom plug, Mix and pump slurry per below calculations, TOC required is 500' MD above si Kuparuk C, volumes based upon 30% OH excess volume: Section: AL Calculation: AtVol : : o '� ) Cement: (10 688 9 888')x .0408 bpf x 1.3 = 42.4 bbls 238 ft3 8-1/2" OH x 5.5" csg: Cement: 90' x .0234 bpf= 2.1 bbls 11.7 ft3 5.5" Shoe Track: Total Volume: 44.5 bbls 249.7 ft3 .21/ Page 32 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company Slurry Information Cement Slurry System SwiftCEM TM System Density 15.3 lb/gal Yield 1.16 ft3/sk Mixed Water 5.04 gal/sk 18.8 After pumping cement, drop top plug and displace cement with drilling mud. Use rig pumps for displacement. Ensure to have a good baseline measurement for pump displacement ahead of time. Displacement calculations: • 10,600 x .0234 bpf=248 bbl. G� 18.9 Monitor returns closely while displacing cement. Adjust pump rate if necessary. 18.10 Do not over displace by more than 1/2 shoe track volume. Total volume in shoe track is 2.1 bbls 18.11 There should be no cement returns to surface. TOC is planned to be at 9,888' MD (500' above Kuparuk). 18.12 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. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Page 33 Version 1 June 2017 40 o Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 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 • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • If losses are seen during cement job,note at operation during the cement job they were observed and where the cement was at the time of losses • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure and if floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • 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 jengel@hilcorp.com and cdinger@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 18.12 R/D cementing equipment. 18.13 Back out and L/D landing joint, flush out wellhead and BOP stack thoroughly with FW. • If slips were used to set casing, observe annulus for a minimum of 3 hrs for no pressure of flow • ND, set slips on 5.5" casing 18.14 M/U pack-off running tool and pack-off to bottom of landing joint. Set casing hanger pack-off. Run in lock downs and inject plastic packing element. Test void to 250/4000 psi for 10 min. 18.15 Lay down landing joint and pack-off running tool. Page 34 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 19.0 Perform Cleanout Run and CBL 5.5" Cement Job 19.1 MU Cleanout BHA 19.2 RIH and cleanout 5.5" casing to top of float collar 19.3 Displace well to completion brine 19.4 POOH to±2,400' MD 19.5 Freeze protect 5-1/2" Casing,±55bb1 19.6 POOH, LD BHA 19.7 RU E-line 19.8 RIH and perform cement bond log from shoe t/,,, 8000' MD to locate TOC 19.9 RD E-line r 'v 3-52> r /C44tj 20.0 NU Tree & RDMO .21 • 17 20.1 Set TWC and test to 1000psi in the direction of flow 20.2 ND BOPE and NU adapter flange and tree,test to 5000 psi 20.3 RU lubricator and pull TWC. 20.4 Install BPV and test to 1000 psi. 20.5 Secure tree and cellar. 20.6 RDMO Innovation. 21.0 Post Rig Completion Work 20.1 A separate 10-403 will be submitted for future completion and stimulation operations. Page 35 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 22.0 Innovation Rig Diverter Configuration nfij mem `'1-13.518"5M Control Technology Annular BOP 1 r . -1_13 fit off ll: Cpd i; i3 F77::) o g;: i �--13 518"5M Control o °o Technology Double Ram I 1 7 J— t /!4r- WA 3.1I8"Kill Line — Ity.p. ,L:t4 ‘410 L ~` —31I8"Choke Line �.. g — 13-518"5M Control—" Technology Single Ram oa 13-5(8"x 5Mo_ l_. . r ------------16"Diverter Line ark, III x-13-518"x 5M 4: :11:.11111=;:;1) ,r, fr, "-2-1(16"x 5M 20"Casing Page 36 Version 1 June 2017 • • Milne Point Unit C-45 Drilling Procedure Hilcorp Enema Company 23.0 Innovation Rig BOP Schematic _ oo, Ili ell m 11-111111 111 it I11 Il 1 ------------13-5/8" 5M Control Technology Annular BOP 1 --1 l....._---1 c a :o E c : ; R 4 _' -.------------13-5/8" 5M Control _1 E Technology Double Ram r -0o ri. __ , 4ao.P 3-1/8 Kill Line _ —{` 1, �•. 3-118" Choke Line 7 A----tia2_ F ::: E" 13-5/8" 5M Control Technology Single Ram — ------ 13-518"x 5M 11"x5M Pii ... : - a -I— f; :.1IEr' . 11 9-5/8" DBL D Seal `► �2-1116"x 5M II _ r% 13-5/8"x 5MCasing Hanger -Ij �EB4S22 r; 13-5/8"NOM 9-5/8" BTC Btm x 2-1/16"x 5M 10.5"-4 SA Pin Top WI Primary Seal 20"Casing 9-5/8"Casing Page 37 Version 1 June 2017 1 1 • Milne DrillingPoint ProcedureUnitC-45 Hilcorp Energy Company 24.0 Wellhead Schematic HILCORP ALASKA, LLC MPC-45 MQ-390 0 i-I CD 1 twirl a'1Frn 41.3 3-1/8 5M EST 0 ito ( .., 3-1/8 5M 90.6 EST t iii . i 3-1/8 5M HYDRAULIC ACTUATED �.' 5 i'' 43.3 „�:,/. EST 3-1/8 5M mom Lif 264.. ADAPTER, TUBING HEAD = � 154.1 SM-E-2CLN EST 11 5M X 3-1/8 5M (SPECIAL) i' '0 WITH TWO (2) 3/8 CL 1iT�• 3-1/8 5M ---{ .:®: til 6.1 iii EST 11 5M111101,111111#1 -- .4__ . _ — ._. } I TUBING HANGER, SM-E-2CL --- is 11 X 3-1/2 EU 8RD BOX TOP � � ��� t7.2 X 3-1/2 OD API MOD BOX BTM EST WITH TWO (2) 3/8 LP PORTS _ �I GO �� ��• ...... .n�r Ail—.At- p' .1 - 11 SM a �� � _ CASING HANGER, SMB-22 imo; , gals 2-1/16 SM 26.O# L-80 DWC/C BOX BTM ; ....^ ;I . - O 25.8 X 8.500-4 = - - 63.5 EST STUB ACME-2G-LH PIN TOP ®; ■MMN(4:10:At: !F,A•1 EST W/SEAL ASSEMBLY :' u,:ajii” ,'w I 9-5/8 DBL IPS ... '. 2-1/16 5M 13-5/8 5M IIIP!, Mg I MI 2-1/16 SM CASING HANGER S-22 '-1 I=' 20.5 13-5/8 X•9-5/8 _ '1 lel 9 EST EA NMMI({ 1 , .1.1 -- ierafor 16" CASING 9-5/8 CASING L 11111�I N 5-1/2" CASING L ..... 2-7/8" TUBING 5,000.PSI WELLHEAD ASSEMBLY - - NOTE: X 9-5/8 X 5-1/2"x 2-7/8" 16" DIMENSIONS SHOWN ON THIS DRAWING ARE RESTRICTED CONFIDENTIAL DOCUMENT — 1"." ESTIMATES ONLY AND CAN VARY SIGNIFICANTLY ' f." 1-10 l "`11/3/16 OO, DEPENDING ON RAW MATERIAL LENGTHS. NO GUARANTEE OF STACKUP HEIGHT IS IMPLIED. cnroas •.. DRAINING NO. DIMENSIONS SHOWN SHOULD BE CONSIDEREDNOM iv ,„,•,,,,,K„ A FOR REFERENCE PURPOSES ONLY. ea,m 01,11111t x..o..e:,•'MAO,. ... P-21 5 7 6 Page 38 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 25.0 Days Vs Depth MPC-45 Days vs. Depth Days 0 5 10 15 20 25 0 2000 MPC-45 Days vs. Depth (AFE) 4000 - 6000 a) co 8000 10000 12000 Page 39 Version 1 June 2017 • S 111 Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 26.0 C Pad Formation Description I C Heavy clay interval 4300 to 4800 ft.especially 4700 to 4800 ft(C-01). TO FACILITATE PRODUCTION WIRE LINE 5 5.000' L OPERATIONS,PLAN TO LIMIT HOLE INCLINATION TO 70 DEGREES AND DOG LEGS TO j 8 DEGREES/1°OFT. HOLE SMOOTHNESS Seabee IS VERY IMPORTANT. Seabee (Colville) Interval: Predominantly interbedded siltstone and clay with beds of sand,shale and occasional seams of coal_ The Seabee is generally uneventful until reaching the HRZ. . TIGHT/PACKING OFF INTERMEDIATE CASING: Expect good penetration rates. C-43: 7-518"CASING STOPPED AT 9413(4755 TVD), UNABLE TO RUN DEEPER,HAD TO PULL. POOR HOLE CLEANING,INSUFFICIENT 6,000' CIRCULATING. MADE HOLE OPENER RUN AND € RERAN CASING. H RZ: Highly Radioactive Zone. Very dark_ fissile type shale,organic,good source rock. C-2$A crossed a fault at 8895(6815 tvd)and experienced minor seepage 1iFt CAT V Tuff(bentonitic)zone possible at top of HRZ i.15 20 bph}which was cured with LCM Ore Mrnent .- TopHRz v plus 10%Tuffs('v"1 t300•9.1300(r_.01) 6490' Kalubik Shale: Good log marker MK19 at RESERVOIR OVER-PRESSURE RESULTING IC-01) V +/-5704, Silts within lower Kalubik and Kuparuk"D' IN WELL FLOWS AFTER PENETRATING , 65781) Base HR7� v become over-pressured due to high injection • KALUBIK, KU PARUK "D" &KUPARUK: pressures into the Kuparuk sands causing the over- WELL PROBLEM MD(surd) FORM. MUD WEIGHT COMMENT Ka l u b i k V pressure problems noted below(to lower right). INITIALIFINAL 6760, I KALUBIK SILTS.SEE OVER-PRESSURE SUMMARY. C-20 GCM 7586(6821) KALUBIK WA1192 IC-011 Kuparuk Interval: ��_ C22 OILS, 7696(6983) KUP"C" MA t 12.6/13 FAULT RELATED C-22 OILS GCM 9856(70191 KUPARUK 12.91132 "D"Shale The'D' Shale is the top Kuparuk seciment and is C-22A GCM 9995(72241 KUPARUK 10,8111A LOW VIS SWEEP 699 C' known as the"Cap Rodu'. KUPARUK OVER- C-28 FLOWIGCM 8897(67831 KUP"D" 9_8110.9 Top sea Kup and drtd ic-01) C PRESSURE MAY OCCUR IN THE DSH.ALE • Kuparuk wJ 16.6 ppg. 691 LC U C SAND: Sandstone.shales upward C-25 FLOW/GCM 11888174361 KUPARIJK 10.3111.1 1,C-111: C-39 CCM 7215(6887) KUP"CJ' 16.2/10.5 OIL BEARING TARGET FOR EASTERN C-PAD. . C-39 SL FLOW 7922174911 K1IPARIJK 10.51112 7,000' B LOU: Lower Cretaceous Unconformity C'39 ANN FLOW 7922174911 KUPARUK BULLHEAD 11.5 C-123 FLOW 8933(69431 KALUBIK 98 111.8 Kuparuk B SHALE OR LAMINATED ZONE: C-123 SL FLOW 8931(68931 KALUBIK 11A112.7 Laminated Zone begins below LCU. .��...r C-123 FLOW 13.0 FLOWED WHILE 7363' Fine to medium grain sands becoming R UNN'G 2.3(6 LINER A1c-01) A3 more shaley with depth. Hydrocarbon C-48 FLOW 10449 188211 K4JP"IY' 9.6110.9 FAULT RELATED bearing. +1-7(T thick. The B shale is C4I0 FLOW WA?10.9 T"AN NULUI . vim` FLOWING,WOC 9 hrs unstable for CTU build andior horizontal C12. FLOW 8985(7496 TVD)KUPARUK 9.015.7 FLOWED WHILE POOH hole drilling(C-26L1). RAN BACK TO TO,GC M 7060' A3: Fine grain sandstone,coarsening (C-01) upward,relatively low permeability. SERIOUS POTENTIAL FOR LOST RETURNS WHILE - 17-23rD porosity.10 to 100 and RUNNING,CIRCULATING AND CEMENTING PRODUCTION 7130 A2 permeability. Hydrocarbon bearing. CASING(ESPECIALLY IF SURFACE CASING IS SHALLOW (C-41) SET). ALSO 13E PREPARED FOR POSSIBLE "BREATHING" A2&Al: Similar to A3 FOLLOWING THE CEMENTING JOB. C-01.-02,-05,-06,-07, 71 ss, Al but finer grained and shaley. -06,-14,-17,-19,-22,-26,-23,-28.-39,-36,-12A. (C-tro. Miluveach Miluveach shales: Predominantly ,r .-. , Shale silty shale. Extend 30D-400 ft below -, -" --_. 'KUPARUKFORMATION Kuparuk Al-(Casing Seat for Kuparuk Y PRESSURE MAP 2006 Kingak completion). Serious potential for lost . - returns while running,circulating or Shale cementing casing. 6195' TJD , TJ+ Kingak: marina shale ri11f1 chin irlfarbads Of 8445' sitstone. The Kingak is known to become 6622' TIE unstable the longer his left open to drilling Ji& `1 8872' TJA fluids_ In hole angles above 45 degrees, additional mud weight is required for hole f - _ stabilization. In addition,hole stabilization *"� ,;S "�" ,* +� Sag River mud products are recommended for wells ' �� 7--..,,,,- , u b Sand exposirgthe Kingak. See Recommended Practices ^n.. SAG RIVER SAND: Marine sandstone,gIa :ba, ' . '*: '. ' bot- -. s� z a. , argilaceols,quarto"ose. Potential hydrocarbon bearing. I C-23 targeted the Sag River Sand. -_ Shublik SHUBLIK: Carbonates(limestone.dolomite and °, " I siderite),phosphates,shales,siltstones and occasional rii. r' 1 sandstone. i I. a Tile above depths are based on C-01(straight hole)and 0-21 and ) ` , C-22 prognosis_ Generally,formations drp down to the north. «.: , iiik.44%.„ Major faults run Mts SE and secondary faults run N30E'S30W w '" Secondary faults may be major depending on where you are at ' Faults are not felt to be the cause of lost circulation rn the C-Pad area. C-23(19961 drilled to the Sag R.sand. Page 40 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 27.0 Anticipated Drilling Hazards 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 Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates. We do not want to drill through the hydrates with anything less than a 9.5 ppg MW however. Once v a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section efficiently— control ROP and avoid loading the hole with gas. Minimize gas belching by reducing flow rate if necessary. 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.Utilize cold water when building any mud volume. 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 DRILTREAT 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 (>100 RPM's required for effective hole cleaning)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 adjacent wells in the vicinity. Take directional surveys every 90'60'. Additional surveys can be taken as required. 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 surge and swab pressures generated by the BHA. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase viscosity and/or MW to combat running sands and gravel formations. H2S: Page 41 Version 1 June 2017 • Milne Point Unit C-45 111 Drilling Procedure Hilcorp Energy Company Treat every hole section as though it has the potential for H2S. Review offset wells for documented encouters of H2S. No H2S events have been documented when drilling wells on"C" 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 H2S detection equipment meeting the requirements • of 20 AAC 25.066. 3. In the event H2S is detected, the well will be secured,rig operations suspended and personnel evacuated until a detailed mitigation procedure can be developed. Mitigation efforts can include additives to the mud system, use of personal H2S monitors for rig crews and service personnel and training/deploying SCBA's throughout the rig. Page 42 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 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 as required to maintain proper fluid properties. 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 (>100 RPM's required for most effective hole cleaning)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> 500 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 or other LCM. 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 crossing faults monitor the hole closely for lost circulation(diminished returns) and wellbore stability issues (high or spikey torques, higher pick up weights). H2S: Treat every hole section as though it has the potential for H2S. Review offset wells for documented encounters of H2S. No H2S events have been documented when drilling wells on"C"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 H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, the well will be secured, rig operations suspended and personnel evacuated until a detailed mitigation procedure can be developed. Mitigation efforts can include additives to the mud system, use of personal H2S monitors for rig crews and service personnel and training/deploying SCBA's throughout the rig. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures expected while drilling this well. Page 43 Version 1 June 2017 • Milne Point Unit C-45 14 Drilling Procedure Hilcorp Energy Company 28.0 Innovation Rig Layout 170'-3 " I I MINIM z k ?411 VT M 1 c===511 gliiip ■ • ,111 ,,,, • f ›a-- ® i R a N Ifo ", I I I 1LI * r, co u-) 4i1 1 , . ,... : -, %-w LiV I f 1 k5 v V y 56'-4" ® r I II CV HAK 2 FOOT -ITilig111;PRINT Cr.,! 05/21/16 --------- i,�,,1 r- .1 lu,:ii ., 'iifo''. 7 I'= ' _ 1 il II.1' p I 113'-11 Uj i U 36'-1 " Page 44 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 29.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 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. Page 45 Version 1 June 2017 • • 111 Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 30.0 Innovation Choke Manifold Schematic 7l p 1r—.11_) l_ Ii^ 11-41 113 a p-- pq G-q p a _P--a a s VA II II Om \I k.. .J h ,IL-1- r r ,_ --I h_ q r r .. `p q p q ri b I ICP LI IS IM, r r . 1 lu fG¢ 2-9116"57.1 BB209 -" 2-9116"5M BB209 illiaiFlCIn nkal Piper Ball Valves _ - Piper Ball Valves _...a V IIII II IIII IIII 1 DUQ ' Lc.,-- J it C 10( 1 a /+ \— I la, 411011 WPRI a e). 1 Q T% r pup rfilot p i [ fl—) f E 4—i-jp II Cr 17 II CI a Cr 1. Page 46 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 31.0 Casing Design Information Calculation & Casing Design Factors Milne Point Unit DATE: 6.16.2017 WELL: MPU C-45 DESIGN BY: Joe Engel Design Criteria: Hole Size 1214" Mud Density: 9.5 Hole Size 812" Mud Density: 10.8 Drilling Mode MASP(8.5 ): 2,977 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1. 2 Max MW gradient external stress and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 Casing OD 9-5/8" 5.5" Top(MD) 0 0 Top(TVD) 0 0 Bottom(MD) 7,000 10,688 Bottom(TVD) 4,748 i, 7,261 Length 7,000 10,688 Weight(ppf) 40 17 Grade L-80 P-110 Connection DWC GeoConn Weight v\l'o Bouyancy Factor(lbs) 280,000 181,696 Tension at Top of Section(lbs) 280,000 181,696 Min strength Tension(1000 lbs) 916 567 Worst Case Safety Factor(Tension) 3.27 7 3.12 Collapse Pressure at bottom(Psi) 2,374 3,631 Collapse Resistance w/o tension(Psi) 3,090 7,470 Worst Case Safety Factor(Collapse) 130 206 • MASP(psi) pin 11366— 2,977 Minimum Yield(psi) fJ. 5,750 10,640 Worst case safety Factor(Burst) 357 ' t, i6, zu 17 otecez:5 Page 47 filifVersion 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 32.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation H. 8-1/2" Intermediate Hole Section Uillcurp MPU C-45 Milne Point MD TVD Planned Top: 7000 4748 Planned TD: 10688 7261 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG rd Top Kuparuk C Sand 7,001 3571 Oil 9.8 /0.510 i i Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date C-15A 10.70 8,886 8,972 2016 C-43 12.50 6,900 7,547 2004 C-28A 10.50 6,401 7,339 2006 C-40 11.00 6,821 7,408 2001 C-12 10.50 6,450 7,578 1985 C-11 10.30 6,830 7,526 1985 Assumptions: 1. Fracture gradient at shoe is estimated at 0.7 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"x 9.88"hole section is 11.0 ppg. 3. Calculations assume Kuparuk reservior contains 100%gas(worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 9-5/8" Shoe 7000'MD/4748'TVD 4748(ft) x 0.7(psi/ft)= 3,323.6 psi 323.6(psi)- [0.1(psi/ft)*4748(ft)]= 2,848 psi Drilling Mode MASP MASP from pore pressure(wellbore completely evacuated to gas) 7261(ft) x 0.51(psi/ft)= 3,703 psi 3,703(psi)- [0.1(psi/ft)*7261(ft)]= 2,977 psi - Summary: 1. MASP while drilling 8-1/2" Intermediate hole is governed by the wellbore completely evacuated to gas from the Kuparuk Reservior Page 48 Version 1 June 2017 • • Milne Point Unit C-45 lilt Drilling Procedure Hilcorp Energy Company 33.0 Spider Plot (NAD 27) (Governmental Sections) 1 ISM , , 4 , , t I , I r t 1 I i , 1 I tt i r r 1 t 1 ' t 1 r r j t 11r 1 jt J_� r \. Y, l i -_ 1 1 ,E 1C_iLt PB' ,1 ups ADE014743,4 ,/ Se: 13 ` e I {p .}C y yE `` _FL1 li �` r. 1 �y sr 1 1/ f—Y i i ! l !.' t I 1 I `........ - M t.,`PT_"C.-1:5_S1-1 Y .' aor�botx. •• oti-� T'''''''-- 0000°s°°°000.2._, O°°0 -'.•1'.., o°o°t `Ooai . 9°°°°°00o0.Vt!C�,1,. , _i o cF - cam: W ` 1 °o MILNE POINT UNIT ' T Ud13N010E a°0 • t ♦ ! '1 aQ \, 1 0 55 ` *0 VI•s, e_.. . oo°o �` ! j '- -_•4F5� 00 N''' t y ' --o-' ° 5 , -. 0O i 5 5 0� ! v • 1 a° ! ! • `T 1L S 1 5` ,,?L,C-4'_ TP_.--......,: • ` ` ,D C4 ADL025516 r. ADL047437 `, `, • Legend `t • MPU C-45_SHL • Other Surface Hales(SHL} -:..:A Other Bottom Holes 1BHLi y X MPU C-45_TPH ---Other Well Paths MPU C-45_BHL ONand Sas Urs'Boundary Y s\ c Pad=oc.F,nt -,— _.,....,�.-._«M.._ SeC 22 II Milne Point Unit 0 500 1,OD0 ..,©.�Sal 2] MPC 45 Well Feet r Page 49 Version 1 June 2017 • . Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 34.0 Surface Plat (As Built) (NAD 27) ± N 2400 1 1 .15 ,Qy } ! ~ 12 1 7 V T -i1- . . V , C-PA !_ -iu r_ -T • 19 D-PAC II i 4 • I • 3 'k.La I 1 , 13 IP B-PAD I 2 • U 17 1 es 'A-PAD a .- ...... I 24 1111 •• 42 I 22 24 19 I 2b ■ ■ 21 I -• ." _ ..C� �,I. it ' 1107I 23 • I 1 E-PAD 7 • • II ... I #4 ■ VICINITY MA.P I 3a i NTS 46 I ' 1G 45 / $ 13 I 26 ■20 IL 8 ; • 14 )FC:FND '� 40 + AS-BUILT CONDUCTOR I 47 5 EXISTING COADUCTOR 41 I 6 ■ ■ 15 I I I 5 ! • 16 NOTES I ■ 22 a❑ 5 6005 a- PUMP 1. SURVEY DATE MARCH 12, 2017 1 n 7• 2.REFERENCE FXLD B00;C: 1-1[17-01 PDS, 16-21 16 3.ALASKA STATE PLANE COORDINATES ARE ALASKA !CNE 4. I 1 I NAD 27_ I It.:3D 1.-_J C= I 4. GENETIC COORDINATES An HAD 27, I ® nib 1 4. PAD SCALE FACTOR IS 0.99984385. I I 5 uO HORIZONTAL. T5 IA AND CC L CONTRCL IS BASED 04 I I I 6.ELEVATIONS ARE BASED OR SPX MILNE PT. DATUM/ (N.S.L) - "1 (-rte J \ 1 D � 1 1 11 s 1 -I- N 800 GRAPHIC SCALE 0 175 250 500 WU 0-PAD W (aa FEET) 1 ink ..- 250 ft LOCATED NITHIN PROTRACTED SEC. 10, T. 13 N.. R. 10 E.. UMtAT MERIDIAN, AA. WELL A.S.P. PLANT GEODETIC GEODETIC TOP OF SECTION CELLER BOX NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D_DD) GRAVEL PAD OFFSETS RIM ELEV. C-46 N:6029204.76 N:1757.87 N7029'25.4623' N70.4904062' 15.0 923' FSL 15,22 E:558093.18 E:600.35 W149-31'30,3608" W149,5251002' 2,369' FEL C-45 N:6029147.50' N:1697.85 N70-29'24.8978. N70.4902494- 14,8 866' FSL • 14.78 E:558111.14 • E:599.98 W149'31-29,8454" W149.5249571' 2,351' FEL . C-47 N:5029004.74 N:1547.94 N70'29'23.4902- N70.48913584* _ 15.2 722' FSL 15.15 E:558156.85 E:599.93 X149'31'28.5331' W149.5245925' 2,307' FEL ,- MAIM RNTT NI 11 "' AN�EN Hilcorp Alaska - . 3474/2017 I1�wca-0t arn MPU C-PAD lwat.t, V sn7r1✓4>vnmSe KALEI III TO A4 M1 Li e I I WELLS C-44, C-45, C-46 CO 121/14/+7®CO�..»16u .7a SNI 1-. 250' AS-BUILT WELL LOCATIONS 1°`1 NO OATC liCKI N A OK _ Page 50 Version 1 June 2017 0 0 11 Milne DrillingPoint ProcedureUnitC-45 Hilcorp Energy Company 35.0 Offset MW vs TVD Chart Offset and C-45 MW vs Depth 0 -- —MPC-46 Plan . —MPC-46 Actual 1000 —MPC-46 Sidetrack —MPC-45 Plan ---- \' —MPC-15A 2000 3000 - 4000 F r 5000 1--\--- a d C u 6000 —7 i 7000 7 8000 _ ---Z / 1 ...,_ Trapped Kuparuk Injection Pressure 1 ��+ a a: r 5GLL�� it�� 1' ` 9000 — aerw PA C. {,..bb r 10000 C' 4l �� (7"; moo - G f( per-- 8 9 10 11 12 13 14 ! Mud Density(ppg) .Ri //- V a I 4. Page 51 Version 1 June 2017 • 11 Milne Drilling PointProcedure Unit C-45 Hilcorp Energy Company 36.0 Drill Pipe Information 5" 19.5# S-135 DS-50 & NC50 Drill Pipe Configuration Pipe Body OD 1 r-5.000 80%Inspection Class Pipe Body Wall Thickness in?0.362 Nominal Weight Designation 19.50 Pipe Body Grade 8-135 Drill Pipe Acoroxima:e Length - 31.5 Dril Pipe Length Range2 SrnoottEdge Height m,13732 Raised Connection GCDS50 Tool Joint SPAYS cce+1 120.000 Tool Joint OD 6.625 Upset Type IEU Tool Join:ID in 3.250 Max Upset OD :.DTE} Irl 5.125 Pin Tong 9 Friction Factor 11.0 Box Tong In 12 Woe:Torg spade Tia,InclLde harCaclrg. Drill Pipe Performance Drill-Pipe Length Range2 Performance of Drill Pipe with Pipe Body at Best Estimates Nominal 80%Inspection Class "Ci1treI twin Coanrg? ileaS1accuralel At !Me-X. Operational Max Tension Drill Pipe Adjusted Weigh: nas•nI 24.11 23.29 r`. e Woos:. Torque .n-I.:) nos? Fluid Displacement -;a,nl 0.37 0.36 43,106 Tension Only 0 560,800 Fluid Displacement .et,..%0 0088 0.0085 TraxrnuT mu-43,10Loadn7 Fluid Capacity :ral`ni 0.71 0-70 0.72 39.600 410,504 p tY Fluid Capacity temvrtl 0.0169 0.0167 0-0172 36,100 Tension Only 0 560,800 Drift Size Irl khnrnsrn MUT cpmdned t�adrw 32,100 467,400 3.125 Nate.{)II help Panel equals 42.U.S-gallons. �• !sole:DrIt ppe asoemtly'.araes are hest esernahes and tray racy die to rice tot,'mill toerarce,Internal pla to caning any other radars. Connection Performance GPDS54 ( 6.625 rtes. OD X 3.250(n) ID ) 120,000 000 Rap led r.lake:,tc Terson.at 015,111, Tens¢n ars Darneceerr Tool Joint Dimensions IP ToqueSeaara,an Y''''psi nos: lest Balanced 04 ;Int 6.435 Maximum Make-up Torque 43,100 Tensile Limited des; Mlnrnun Tool Jan1 Ca yr API 5,930 1 !Minimum Make-u0 Torque 36,100 1.202,500 1.250.000 • Pr''''''''Caas +Ino- hex The maxt^um make.to DIV.!shm.la to applied weer;asst.e 6rinrn.rn 7501 Joni 00 br 5.93 ',. p CoLntertOre. :Ir.: tide Tc ntaxln.re connecter:aaerattcnal lens iea ICT 741-37,!C0;A-Ms:should be arpted P. Tool Joint Torsional Strength eat 71,800 V Tool Joint Tensile Strength real 1,250,000 Elevator Shoulder Information Elevator OD 3°32 Raised 6.812 1m) SmoothEdge Height Nominal Tool Joint Worn to Bevel Wom to Min TJ OD for y 3/32 Raised OD Diameter API Premium Class Box OD6.812 6.625 5 063 5 934 Elevator Capacity otos,1,658,000 1.440,203 823,600 685,600 i521 Nr! EI aear.:,r rased rn assurerE..0At..r Por nc wear ra-try,and coolant stress al 110,10Cpsl. No,.Assumed Elevator Bore Diameter I n' . A raised ee.ator OD Increases el-,at:r caam_:tr'w•CIm.oI anec:nC Take-LR Wq,. Pipe Body Slip Crushing Capacity Pipe Body Configuration( 5 I.n? OD 0.362 in? Wall S-135) Nominal 80%Inspection Class API Premium Class /Tr Slip Crush.naCapac:ty498.300 396.500 396.500 Aare:hip':r:sHn,Sip rnwnC load IS r0Y0aOt0 Mtn ma See-Fernald epuatl_r ton V.t'a•Cces DI:Pee Assumed Slip Length In?16.5 Fal In to hhip Arer lAble hi 19:MIa to vp legt,a-n 1.-a s.rme road'a<tnr s+.ar:axe r rcm,e:re t'ansve-se Lcac Facto-1K1 42 ' a r,hip•m' seepernderl a•,Or sip aeson and oredar,:oelrern Warn rotWarn camas 11-e n sips sill ppe n0 and 061 donator,are oa triodes Ca-sit men the SID maridact-erftraacntrA rranmrt=. Pipe Body Performance Pipe Body Confauration( 5 rni OD 0.3621h1 Wall S-135) Nominal 80%inspect-or Class API Premium Class Pipe Tensile Strength ubsl 712,100 560.666 560,800 , Pipe Torsional Strengt i -rt-Itst 74.100 58 100 58,100 T.t'PipeBody Torsional Ratio 0.97 1.24 1.24 80%Pipe Torsional Strength tan-Ics l 59,300 _46.500 46.500 1 ) Burst iv l 17,105 15,638 15.638 Nc er Normal Eus1 Collapse p5115,672 10.029 . 020 Nr.te N d m a-n r RB'A' •• per API. Pipe OD lOu 5.000 4.855 4.855 Wall Thickness :Int 0.362 0 200 0.290 Nominal Pipe ID nm}4.276 4.276 4276 Cross Sectional Area of Pipe Body On^21 5.275 4.'54 4.154 Cross Sectional Area of OD on^21 19.635 18 514 18.514 Cross Sectional Area of ID tln^=I 14.360 14.360 14.360 Section Modulus 1m03I 5.708 4.476 4.476 F. y Polar Section Modulus I1-03t 11.415 8.953 8.953 C:tsrnt Page 52 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company Operational Limits of Drill Pipe Connection GPOS50 Tool Joint OD ;,x,,16.625 Tool Join:ID ,n 13.250 Tool Joint Specified Minimum 120.000 Yield Strength tat 1 Pipe Body 60°%Inspection Class Pipe Body OD ,,,5 Wall Thickness ,x,;10.362 Pipe Body Grade S-135 Combined Loading for Drill Pipe at Combined Loading for Drill Pipe at Maximum Make-up Torque= 43.100n- os' Minimum Make-up Torque= 36.100 rt,;by Operational Assembly Pipe Body Connecucr,IMlaa Operatiora Assembly P15 Scary ccrnc_acn Torque Max Tension renaicei I Torque Max Tension Mno Tersxon Max Taralan q Max Tension in-Ita lib!: Ms 1 •5 leabs' ptsi Ms 011s1 0 560.800 560,800 1.046.900 0 560.800 560.800 1.202,50: 2,100 560,400 560.400 1,046.900 1,700 560,500 560.500 1,202,500 4,200 559,300 559,300 1.046.900 3.400 559.800 5559.800 1.202,500 6,300 557.500 557,500 1,046.900 5,100 558,600 558.500 1.202,500 8,300 555.000 555,000 1.046.900 6.800 556.900 556.930 1.202,500 10,400 551,700 551,700 1,046.900 8,400 554,900 554.900 1,202,500 12,500 547.600 547,600 1.046.900 10.100 552.200 552.200 1.202,500 14.600 542.800 542,800 1,046.900 11.800 549,100 549.100 1,202,500 16.700 537.100 537,100 1.046.900 13.500 545.400 515.400 1.202,50: 18,800 530,600 530,600 1,046.900 15.200 541,200 541.200 1,202,500 20,800 523.600 523,600 1.046.900 16.900 536.500 535.500 1.202.5:: 22,900 515,400 515,400 1,046.900 18.600 531,300 531.300 1.202.50[: 25,000 506.200 506,200 1.046.900 20.300 525.400 525.41+0 1202.5::_ 27.100 496.100 496,100 1,046.900 22.000 519,000 519.000 1,202,50: 29,200 484,800 484,800 1.046.900 23.700 512.000 512.000 1.202,50: 31.3x0 472,500 472,500 1,046.900 25,300 504,800 504.800 1,202,500 33.300 459.600 459,600 1.046.900 27.000 496.600 496.600 1.202,500 35.400 444,700 444,700 1,046.900 28,700 487,600 487.600 1,202.500 37.500 428.400 428,400 1.046.900 30.400 477.900 477.900 1.202,500 39.600 410.500 410,500 1.046.900 32,100 467,400 467.400 1,202,500 Opera:icna drill r tc-que is limited by the Make-up Torque. Operational drilling torque is limited by the Make-up Torque. Connection Make-up Torque Range Make-up Torque Connection Max I,_,,5 Tension ,,t.. Min MUT 36.100 1,202,500 36.900 1,229,200 37,700 1,243,600 �_ 38,400 1,218,100 39.200 1,189,000 40.000 1,159,800 40,800 1,130,700 41.500 1,105,200 42.300 1,076,100 Max MUT 43.100 1,046,900 Page 53 Version 1 June 2017 0 0 II Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company Connection Wear Table Connection GPDS50 Tool Join:OD ,,,,16.625 Tool Join:ID yr; 3.250 -COI Jc r-t Specified i'dminrurn 120.000 Yield Strength ire, Connection Wear Tool Connection Max Connecacr Max Min MUT Connection Max Joint OD Torsional MUT Tension Tension New OD Strength rn-r_.. -.mr pica ae,, °c.y 6.625 71,800 43,100 1,046,900 35,900 1,195.900 T"" 6.562 71,800 43,100 1,034,900 35,900 1.208.700 i 6.499 71,800 43,100 1,022,600 35,900 1,222.400 6.435 71,800 43,100 1,009,800 35,900 1.237.500 j 6.372 71,200 42,700 1,008,100 35,600 1.245200 6.309 68,000 40,800 1,057,300 34.003 1,207.700 6.246 64,800 38,900 1,104,800 32,400 1,169.800 6.183 61,700 37.000 1,150,400 30,80+0 1.131.300 6.12 58,600 35,200 1,190,900 29,300 1,096.100 6.056 55,500 33.300 1,232,300 27,803 1.060.800 Wain OD 5.993 52,600 31,500 1,227,200 26,300 1,024.600 5.93 49,600 29,800 1,187,100 24.800 987.900 Pipe Body Combined Loading Table(Torque-Tension) Pipe Body 80%inspection Class Pipe Body OD .„, 5 wall Th:cknes 0.362 Pine Body Grade S-135 Pioe Body Torque 0 5,300 10 600 15.600 21.100 26.400 31,700 37.000 42.300 47 500 52 600 58 100 Maes? 11e, Pipe Body Max 5d0,800 558.400 551.400 539,600 522.500 499.600 470,000 432,400 384,500 3323.100 234 300 12200 Tension ■ Page 54 Version 1 June 2017 • Milne Point Unit C-45 Drilling Procedure Hilcorp Energy Company 500204050016200 Weatherford 5" 19.50 lb/ft S-135 w1 NC 50 6-518" OD x 3-114" ID Tool Joint DRILL PIPE SPECIFICATIONS Grade 5-135 Connection NC 50 Interchangeable With 5"XH &4-1/2" IF Upset Type IEU NominalWeght per Foot 19.50 lbs Adjusted Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6-518' 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 5.275 sq in 4.154 sq in Maximum Hook Load/Tensile Strength 712,000 lbs 560,800 lbs Slip Crushing t Slip Type (SDXL) 572,100 lbs 453,500 lbs Burst Pressure 17,100 psi 16,100 psi Collapse Pressure 15,700 psi 10,000 psi Torsional Yield Strength 74,100 ft-lbs 58,100 ft-lbs Capacity W/Tool Joint 0.726 US gal/ft 0.726 US aal/ft Displacement W/Tool Joint 0.353 US galfft 0.322 US gait _ 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 55 Version 1 June 2017 • S Hilcorp Alaska, LLC Milne Point M Pt C Pad Plan: MPU C-45 MPU C-45 Plan: MPU C-45 wp06b Standard Proposal Report 14 June, 2017 HALLIBURTON Sperry Drilling Services HALLIBURTONHilcorp Alaska,LLC • REFERENCE INFORMATION II 1 Cilcorp Calculation Method: Minimum Curvature Co-ordinate(N/E)Reference: Well Plan:MPU C-45,True North Sperry Drilling Error System:ISCWSA Vertical(TVD)Reference: As-Built C-45 @41.30usft Scan Method: Closest Approach 3D Measured Depth Reference: As-Built C-45 @ 41.30usft Error Surface: Elliptical Conic Warning Method: Error Ratio Calculation Method: Minimum Curvature Project: Milne Point Site: M Pt C Pad SECTION DETAILS Well: Plan:MPU C-45 Sec MD Inc Azi TVD *N/-S +E/-W Dleg TFace VSect Target Annotation Wellbore: MPU C-45 1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.00 2 525.50 0.00 0.00 525.50 0.00 0.00 0.00 0.00 0.00 Start Dir 3°/100':525.5 MD,484.2'TVD Design: MPU C-45 wp06b 3 825.50 9.00 88.00 824.27 4 1375.50 36.50 88.00 1326.62 8.117 234.03 5.00 2 23.50 3.00 80.00 202.81 Start Dir 5°/100':13755'MD71326 .62.TVD 5 1759.94 53.03 102.14 1599.30 -20.41 500.95 5.00 38.37 451.93 End Dir:1759.94'MD,1558'TVD 6 5742.66 53.03 102.14 3994.31 -689.77 3611.88 0.00 0.00 3513.09 Start Dir 5°/100':5742.66'MD,3953.01'TVD 7 8307.90 53.03 137.73 4341.30 -908.81 3992.26 5.00 100.93 3951.79 MPC-Tulsa SBOA Tgt1 8 6326.55 53.96 137.73 4352.39 -919.91 4002.35 5.00 -0.02 3985.90 End Dir:6326.55'MD,4352.39'TVD 9 9234.30 53.98 137.73 6083.07 -265975 5583.98 0.00 0.00 6179.08 Start Dir 5°/100':9234.3'MD,8021.77'TVD 10 9713.55 30.00 137.73 6416.73 -2895.24 5798.04 5.00 180.00 6478.62 End Dir:9713.55'MD,6375.43'ND 11 10388.55 30.00 137.73 7001.30 -3144.98 6025.05 0.00 0.00 6796.29 MPC-Tulsa TKUC TOO V2 1210688.78 30.00 137.73 7261.30 -3256.06 6126.02 0.00 0.00 6937.58 Total Depth:10688.78'MD,7220'ND WELL DETAILS:Plan:MPU C-45 Ground Level: 14.80 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 6029147.50 558111.14 70°29'24.898 N 149°31'29.845 W -750- SURVEY PROGRAM - Date:2017-05-11T00:00:00 Validated:Yes Version: _ Depth From Depth To Survey/Plan Tool A26.50 1400.00 MPU C-45 wp06b SRG-SS 1400.00 7000.00 MPU C-45 wpo6b MWD+IFR2+MS+sag D 7000.00 10688.78 MPU C-45 wpo6b MWD+IFR2+MS+sag Start Dir 3°/100':525.5'MD,484.2'TVD - 500-_-- Start Dir 5°/100':825.5'MD,782.97'TVD CASING DETAILS 750- ---- - 1000 TVD MD Name Size - 4748.59 7000.00 9 5/8" 9-5/8 - 00 Start Dir 5°/100':1375.5'MD,1326.62'TVD 7261.30 10688.78 5 1/2" 5-1/2 1500- 00 - - - - -v End Dir :1759.94'MD,1558'TVD _ BPRF •v i FORMATION TOP DETAILS O 2250- O� O TVDPath TVDssPath MDPath Formation - h0 1671.30 1630.00 1879.68 BPRF - 'b 4341.30 4300.00 6307.90 SBOA - 00 6391.30 6350.00 9683.96 CM1 - RO 6591.30 6550.00 9915.13 THRZ 3000- 00 6691.30 6650.00 10030.60 TKLGM - b• 7001.30 6960.00 10388.55 TKUC 00 7252.69 7211.39 10678.83 TKA3 h0 w _ h00 0 3750 00 Start Dir 5°/100':5742.66'MD,3953.01'TVD ( - co t - - - �y End Dir :6326.55'MD,4352.39'TVD 0 4500- SBOA 5/8" 0 TO _ MPC-Tulsa SBOA Tgt1 �h �� 0 00 5250- 00 Start Dir 5°/100':9234.3'MD,6021.77'TVD a) - cb B. 00 IL - 90 6000- - 40 End Dir :9713.55'MD,6375.43'TVD - CM1 9 - - - - - - - - - - - - THRZ 0000 -- - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - 6750- TKLGM - - - - - - - - - TKUC- -- - - - - - - - - - - - 1056,69 • 7500- TKA3 � ' / , Total Depth:10688.78'MD,7220'TVD - MPC-Tulsa TKUC Tgt2 V2 `, - 5 1/2" \ 8250- ' - MPU C-45 wp06b 9000- 9750- IiiiiiiiiiiiIIIF IIIIIIIIIIIIIiiiI lillrFilliFIIIirliiii1111111 [ I 1 Iiilii . -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 Vertical Section at 117.99° (1500 usft/in) • • West(-)/East(+)(850 usft/in) -425 0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 6375 6800 7225 1 , , , , I , , , , IIIi / / iliiiiliiiiliiirIiirI IiiIIrIiIIIiiil li 1nIiliiliillllillllllllii HALLIBURTON —850 Project: Milne Point Sperryo,•ming .IhICOTp Site: M Pt C Pad _ Well: Plan:MPU C-45 Wellbore: MPU C-45 .-425 Plan: MPU C-45 wpO6b - 4 R FSPRF A' -0 '4 e 8 n h p \ 2Y n g IMPG7Lla SBOA Tel — n -425 M�7�J n R 45 _ 9 84 ` s �'Jo 9$`MO -_-_ p1",�' SBOA �3'4b, ', g�S0. ' 4�, 7JJB, "-' --850 •J2j, �. •�3�4, Stmt Dir 5°/I00':574266'MD.3953.017YD "p _ • 'r?7� SID �82y �,3Z662, End Dir:6326.33 MD,4352.37 TVD -*445/8" 445/8 --1275 _ rn cf C S _ COMPANY DETAILS:Hilcorp Alaska,LLC .i19 -1700 Calculation Method:Minimum Curvature o Error System:ISCWSA - Scan Method:Closest Approach 3D SS • - + Error Surface:Elliptical Conic --2125 Warning Method:Error Ratio - oo tY CASING DETAILS I95%conE TARGETARESj -- -2550 G• TVD TVDSS MD Size Name ____--- dap _CM1'rats _ 4748.59 4707.29 7000.00 9-5/8 95/8" Start Dv S°/1015:9234.3'MD,6021.77TVD " --- - 7261.30 7220.00 10688.78 5-1/2 5 1/2" - _ _--- '-- TKUC --2975 End DirMD:9713.55' 6375.43'TVD AA TKA3 WELL DETAIL:Plan:MPU C-45 IMPC-Tld 1KUC'Tgt2 V2(Polygon for tarotrmoMainty)I -- -3400 ' - Ground Level: 14.80 - 5 1/2" - +N/S +El-W Northing Eating Latitude Longitude _ - 0.00 0.00 6029147.50 558111.14 70°29 24.898 N 149°31 29.845 W 'total Depth:10688.78'MD,7225 TVD , REFERENCE INFORMATION • MPU C-45 wp06b --3825 • Co-ordinate(N/E)Reference:Wall Plan:MPU C-45.Tme Nerth Vertical(TVD)Reference:As-Buih C45 @ 41.30usa — MeasuredDepthReference:As-Built C45@41.30usa — Calculatlon Method:Minimum Curvature --4250 SURVEY PROGRAM _ Date:2017-05-11700:00:00 Validated:Yes Version: Depth From Depth To Survey/Plan Tool -- -4675 26.50 1400.00 MPU C-45 wp06b SRGSS - 1400.00 7000.00 MPU C-45 wp06b MWD+IFR2+MS+sag - 7000.00 10688.78 MPU C-45 wp06b MWD+IFR2+MS+sag - • • Halliburton H A LLI B U RTO 1 J Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA -Local Co-ordinate Reference Well Plan:MPU C-45 1 Company: Hilcorp Alaska,LLC TVD Reference: As-Built C-45 @ 41.30usft • Project: Milne Point MD Reference: - h As-Built C-45 @ 41.30usft Site: M Pt C Pad North Reference: True Well: Plan:MPU C-45 Survey Calculation Method: Minimum Curvature • Wellbore: MPU C-45 v" °',''`- Design: MPU C-45 wp06b , Project Milne Point,ACT,MILNE POINT Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt C Pad,TR-13-10 Site Position: Northing: 6,027,347.71 usft Latitude: 70°29'7.200 N From: Map Easting: 558,058.04 usft Longitude: 149°31'31.821 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.45° Well Plan:MPU C-45 Well Position +N/-S 0.00 usft Northing: 6,029,147.50 usft ,, Latitude: 70°29'24.898 N +E/-W 0.00 usft Easting: 558,111.14 usft • Longitude: 149°31'29.845 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 14.80 usft Wellbore " MPU C-45 Magnetics t Model Name Sample Date Declination s Field Strength ' (°) (nT) �� ��. BGGM2017_ °�_ 6/15/2017 17.71 �� 81.04 57,509 Design MPU C-45 wp06b Audit Notes: Version: Phase: PLAN Tie On Depth: 26.50 Vertical section ' Depth From(TVD) - . Direction ,i`' ,- (usft) .iVdf --e- .n , (°) 26.50 0.00 0.00 117.99 Plan Sections Measured Vertical TVD ' �a'3 "Dogleg �'1' Build - Turn Depth Inclination Azimuth Depth System : 1'� r +E/-W Rate ,, Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (°/100usft) (°/100usft) (°1100usft) (°) 26.50 0.00 0.00 26.50 -14.80 0.00 0.00 0.00 0.00 0.00 0.00 525.50 0.00 0.00 525.50 484.20 0.00 0.00 0.00 0.00 0.00 0.00 825.50 9.00 88.00 824.27 782.97 0.82 23.50 3.00 3.00 0.00 88.00 1,375.50 36.50 88.00 1,326.62 1,285.32 8.17 234.03 5.00 5.00 0.00 0.00 1,759.94 53.03 102.14 1,599.30 1,558.00 -20.41 500.95 5.00 4.30 3.68 36.37 5,742.66 53.03 102.14 3,994.31 3,953.01 -689.77 3,611.88 0.00 0.00 0.00 0.00 6,307.90 53.03 137.73 4,341.30 4,300.00 -908.81 3,992.26 5.00 0.00 6.30 100.93 6,326.55 53.96 137.73 4,352.39 4,311.09 -919.91 4,002.35 5.00 5.00 0.00 -0.02 9,234.30 53.96 137.73 6,063.07 6,021.77 -2,659.75 5,583.98 0.00 0.00 0.00 0.00 9,713.55 30.00 137.73 6,416.73 6,375.43 -2,895.24 5,798.04 5.00 -5.00 0.00 180.00 10,388.55 30.00 137.73 7,001.30 6,960.00 -3,144.98 6,025.05 0.00 0.00 0.00 0.00 10,688.78 30.00 137.73 7,261.30 7,220.00 -3,256.06 6,126.02 0.00 0.00 0.00 0.00 6/14/2017 5.22.56PM Page 2 COMPASS 5000.1 Build 81 • 0 Halliburton HrLLIBURTON Standard Proposal Report Database: -Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: ;' Well Plan:MPU C-45 Company: Hilcorp Alaska,LLC TVD Reference: As-Built C-45 c@ 41.30usft Project: Milne Point MD Reference: m!' As-Built C-45 @ 41.30usft Site `_" M Pt C Pad North Reference: ` True Well Plan:MPU C-45 '=Survey Calculation Method: Minimum Curvature Wellbore= MPU C-45 `" `' " ' _, Design: MPU C-45 wp06b °� 7,.,---,- AO . 23ten a. _,. , Planned Survey ; Measured _ Verticalry !-„ Map _ Map Depth Inclination Azimuth Depth TVDss ' +N/-S +E/-W va,, Northing Easting DLS Vert Section v (usft) (°) (°) (usft) usft � (ugft) (usft) (usft) (usft) °'� -14.80 4r. 26.50 0.00 0.00 26.50 -14.80 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 100.00 0.00 0.00 100.00 58.70 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 200.00 0.00 0.00 200.00 158.70 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 300.00 0.00 0.00 300.00 258.70 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 400.00 0.00 0.00 400.00 358.70 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 1 500.00 0.00 0.00 500.00 458.70 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 525.50 0.00 0.00 525.50 484.20 0.00 0.00 6,029,147.50 558,111.14 0.00 0.00 Start Dir 3°1100':525.5'MD,484.2'TVD 600.00 2.24 88.00 599.98 558.68 0.05 1.45 6,029,147.56 558,112.59 3.00 1.26 700.00 5.24 88.00 699.76 658.46 0.28 7.96 6,029,147.84 558,119.10 3.00 6.90 800.00 8.24 88.00 799.06 757.76 0.69 19.68 6,029,148.34 558,130.81 3.00 17.06 825.50 9.00 88.00 824.27 782.97 0.82 23.50 6,029,148.50 558,134.63 3.00 20.37 Start Dir 5°1100':825.5'MD,782.97'TVD 900.00 12.73 88.00 897.42 856.12 1.31 37.53 6,029,149.10 558,148.65 5.00 32.52 1,000.00 17.73 88.00 993.88 952.58 2.23 63.76 6,029,150.22 558,174.88 5.00 55.26 1,100.00 22.73 88.00 1,087.68 1,046.38 3.43 98.30 6,029,151.70 558,209.40 5.00 85.19 1,200.00 27.73 88.00 1,178.12 1,136.82 4.92 140.88 6,029,153.52 558,251.96 5.00 122.09 1,300.00 32.73 88.00 1,264.50 1,223.20 6.68 191.17 6,029,155.67 558,302.24 5.00 165.68 1,375.50 36.50 88.00 1,326.62 1,285.32 8.17 234.03 6,029,157.50 558,345.07 5.00 202.81 Start Dir 5°/100':1375.5'MD,1326.62'TVD 1,400.00 37.49 89.19 1,346.19 1,304.89 8.53 248.76 6,029,157.97 558,359.81 5.00 215.66 1,500.00 41.65 93.55 1,423.27 1,381.97 6.90 312.40 6,029,156.84 558,423.45 5.00 272.62 1,600.00 45.95 97.24 1,495.44 1,454.14 0.31 381.26 6,029,150.79 558,492.35 5.00 336.52 1,700.00 50.36 100.43 1,562.14 1,520.84 -11.20 454.83 6,029,139.86 558,566.00 5.00 406.88 1,759.94 53.03 102.14 1,599.30 1,558.00 -20.41 500.95 6,029,131.01 558,612.18 5.00 451.93 End Dir :1759.94'MD,1558'TVD 1,800.00 53.03 102.14 1,623.39 1,582.09 -27.14 532.24 6,029,124.52 558,643.52 0.00 482.72 1,879.68 53.03 102.14 1,671.30 1,630.00 -40.54 594.47 6,029,111.62 558,705.86 0.00 543.96 BPRF I 1,900.00 53.03 102.14 1,683.52 1,642.22 -43.95 610.35 6,029,108.32 558,721.75 0.00 559.58 2,000.00 53.03 102.14 1,743.66 1,702.36 -60.76 688.46 6,029,092.13 558,799.99 0.00 636.44 2,100.00 53.03 102.14 1,803.79 1,762.49 -77.56 766.57 6,029,075.94 558,878.22 0.00 713.30 2,200.00 53.03 102.14 1,863.93 1,822.63 -94.37 844.68 6,029,059.74 558,956.45 0.00 790.16 2,300.00 53.03 102.14 1,924.06 1,882.76 -111.18 922.79 6,029,043.55 559,034.68 0.00 867.02 2,400.00 53.03 102.14 1,984.20 1,942.90 -127.98 1,000.90 6,029,027.35 559,112.92 0.00 943.88 2,500.00 53.03 102.14 2,044.33 2,003.03 -144.79 1,079.01 6,029,011.16 559,191.15 0.00 1,020.74 2,600.00 53.03 102.14 2,104.47 2,063.17 -161.60 1,157.12 6,028,994.97 559,269.38 0.00 1,097.61 2,700.00 53.03 102.14 2,164.60 2,123.30 -178.40 1,235.23 6,028,978.77 559,347.61 0.00 1,174.47 2,800.00 53.03 102.14 2,224.74 2,183.44 -195.21 1,313.34 6,028,962.58 559,425.84 0.00 1,251.33 2,900.00 53.03 102.14 2,284.87 2,243.57 -212.02 1,391.46 6,028,946.38 559,504.08 0.00 1,328.19 3,000.00 53.03 102.14 2,345.01 2,303.71 -228.82 1,469.57 6,028,930.19 559,582.31 0.00 1,405.05 3,100.00 53.03 102.14 2,405.14 2,363.84 -245.63 1,547.68 6,028,913.99 559,660.54 0.00 1,481.91 3,200.00 53.03 102.14 2,465.28 2,423.98 -262.44 1,625.79 6,028,897.80 559,738.77 0.00 1,558.77 3,300.00 53.03 102.14 2,525.41 2,484.11 -279.24 1,703.90 6,028,881.61 559,817.00 0.00 1,635.63 3,400.00 53.03 102.14 2,585.55 2,544.25 -296.05 . 1,782.01 6,028,865.41 559,895.24 0.00 1,712.50 6/14/2017 5.22.56PM Page 3 COMPASS 5000.1 Build 81 • • Halliburton I-IALLIBURTO1\J Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA ,'Local Co-ordinate Reference: Well Plan:MPU C-45 Company: Hilcorp Alaska,LLC TVD Reference: As-Built C-45 @ 41.30usft Project: Milne Point MD Reference: ' .; As-Built C-45 @ 41.30usft Site: M Pt C Pad North Reference: True Well: Plan:MPU C-45 ,Survey Calculation Method: Minimum Curvature Wellbore: MPU C-45 Design: MPU C-45 wp06b Planned Survey # "^•. 7,: # � Measured Vertical § " Map ,:iitikr Map t:,: .'7 , 4.;. Depth Inclination Azimuth Depth TVDss +W-S '+EI-W ,• Northing , Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) ` (usft) (usft) (usft) 2,604.39 3,500.00 53.03 102.14 2,645.69 2,604.39 -312.86 1,860.12 6,028,849.22 559,973.47 0.00 1,789.36 3,600.00 53.03 102.14 2,705.82 2,664.52 -329.66 1,938.23 6,028,833.02 560,051.70 0.00 1,866.22 3,700.00 53.03 102.14 2,765.96 2,724.66 -346.47 2,016.34 6,028,816.83 560,129.93 0.00 1,943.08 3,800.00 53.03 102.14 2,826.09 2,784.79 -363.28 2,094.45 6,028,800.64 560,208.17 0.00 2,019.94 3,900.00 53.03 102.14 2,886.23 2,844.93 -380.08 2,172.56 6,028,784.44 560,286.40 0.00 2,096.80 4,000.00 53.03 102.14 2,946.36 2,905.06 -396.89 2,250.67 6,028,768.25 560,364.63 0.00 2,173.66 4,100.00 53.03 102.14 3,006.50 2,965.20 -413.70 2,328.78 6,028,752.05 560,442.86 0.00 2,250.52 4,200.00 53.03 102.14 3,066.63 3,025.33 -430.50 2,406.89 6,028,735.86 560,521.09 0.00 2,327.39 4,300.00 53.03 102.14 3,126.77 3,085.47 -447.31 2,485.01 6,028,719.67 560,599.33 0.00 2,404.25 4,400.00 53.03 102.14 3,186.90 3,145.60 -464.12 2,563.12 6,028,703.47 560,677.56 0.00 2,481.11 4,500.00 53.03 102.14 3,247.04 3,205.74 -480.92 2,641.23 6,028,687.28 560,755.79 0.00 2,557.97 4,600.00 53.03 102.14 3,307.17 3,265.87 -497.73 2,719.34 6,028,671.08 560,834.02 0.00 2,634.83 4,700.00 53.03 102.14 3,367.31 3,326.01 -514.54 2,797.45 6,028,654.89 560,912.25 0.00 2,711.69 4,800.00 53.03 102.14 3,427.44 3,386.14 -531.34 2,875.56 6,028,638.69 560,990.49 0.00 2,788.55 4,900.00 53.03 102.14 3,487.58 3,446.28 -548.15 2,953.67 6,028,622.50 561,068.72 0.00 2,865.41 5,000.00 53.03 102.14 3,547.71 3,506.41 -564.96 3,031.78 6,028,606.31 561,146.95 0.00 2,942.28 5,100.00 53.03 102.14 3,607.85 3,566.55 -581.76 3,109.89 6,028,590.11 561,225.18 0.00 3,019.14 5,200.00 53.03 102.14 3,667.98 3,626.68 -598.57 3,188.00 6,028,573.92 561,303.42 0.00 3,096.00 5,300.00 53.03 102.14 3,728.12 3,686.82 -615.38 3,266.11 6,028,557.72 561,381.65 0.00 3,172.86 5,400.00 53.03 102.14 3,788.26 3,746.96 -632.18 3,344.22 6,028,541.53 561,459.88 0.00 3,249.72 5,500.00 53.03 102.14 3,848.39 3,807.09 -648.99 3,422.33 6,028,525.34 561,538.11 0.00 3,326.58 5,600.00 53.03 102.14 3,908.53 3,867.23 -665.80 3,500.45 6,028,509.14 561,616.34 0.00 3,403.44 5,700.00 53.03 102.14 3,968.66 3,927.36 -682.60 3,578.56 6,028,492.95 561,694.58 0.00 3,480.30 5,742.66 53.03 102.14 3,994.31 3,953.01 -689.77 3,611.88 6,028,486.04 561,727.95 0.00 3,513.09 Start Dir 5°/100':5742.66'MD,3953.01'TVD 5,800.00 52.54 105.69 4,029.00 3,987.70 -700.75 3,656.19 6,028,475.41 561,772.34 5.00 3,557.37 5,900.00 51.94 111.97 4,090.27 4,048.97 -726.23 3,730.96 6,028,450.52 561,847.30 5.00 3,635.36 6,000.00 51.68 118.32 4,152.13 4,110.83 -759.59 3,802.05 6,028,417.72 561,918.65 5.00 3,713.79 6,100.00 51.77 124.69 4,214.11 4,172.81 -800.58 3,868.92 6,028,377.25 561,985.83 5.00 3,792.08 6,200.00 52.20 131.02 4,275.74 4,234.44 -848.90 3,931.06 6,028,329.43 562,048.34 5.00 3,869.62 6,300.00 52.96 137.24 4,336.54 4,295.24 -904.16 3,988.00 6,028,274.62 562,105.70 5.00 3,945.84 6,307.90 53.03 137.73 4,341.30 4,300.00 -908.81 3,992.26 6,028,270.00 562,110.00 5.00 3,951.79 SBOA 6,326.55 53.96 137.73 4,352.39 4,311.09 -919.90 4,002.35 6,028,258.99 562,120.17 5.00 3,965.90 End Dir :6326.55'MD,4352.39'TVD 6,400.00 53.96 137.73 4,395.61 4,354.31 -963.85 4,042.30 6,028,215.36 562,160.46 0.00 4,021.80 6,500.00 53.96 137.73 4,454.44 4,413.14 -1,023.69 4,096.69 6,028,155.95 562,215.31 0.00 4,097.91 6,600.00 53.96 137.73 4,513.27 4,471.97 -1,083.52 4,151.09 6,028,096.55 562,270.17 0.00 4,174.03 6,700.00 53.96 137.73 4,572.10 4,530.80 -1,143.36 4,205.48 6,028,037.15 562,325.02 0.00 4,250.14 6,800.00 53.96 137.73 4,630.93 4,589.63 -1,203.19 4,259.87 6,027,977.75 562,379.88 0.00 4,326.25 6,900.00 53.96 137.73 4,689.76 4,648.46 -1,263.03 4,314.27 6,027,918.35 562,434.73 0.00 4,402.37 7,000.00 53.96 137.73 4,748.59 4,707.29 -1,322.86 4,368.66 6,027,858.94 562,489.58 0.00 4,478.48 9 5/8" 7,100.00 53.96 137.73 4,807.43 4,766.13 -1,382.70 4,423.05 6,027,799.54 562,544.44 0.00 4,554.59 7,200.00 53.96 137.73 4,866.26 4,824.96 -1,442.53 4,477.45 6,027,740.14 562,599.29 0.00 4,630.71 6/14/2017 5:22:56PM Page 4 COMPASS 5000.1 Build 81 • 0 Halliburton I-IALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA -Local Co-ordinate Reference:` Well Plan:MPU C-45 Company: Hilcorp Alaska,LLC TVD Reference: 4ilifi,41 As-Built C-45 @ 41.30usft Project: Milne Point MD Reference: ,. . . "As-Built C-45 @ 41.30usft Site: M Pt C Pad North Reference:'' True Well: Plan:MPU C-45 Survey Calculation Method: AtI/IA Minimum Curvature Wellbore:', . MPU C-45 Design: '`y.'r.�,..MPU C-45 wp06b Planned Survey --"*1;",',.P5.-"-'77'''''-`'`.7 ter , Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W'" ' Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) - (usft) (usft) „, (usft) 4,883.79 7,300.00 53.96 137.73 4,925.09 4,883.79 -1,502.37 4,531.84 6,027,680.74 562,654.15 0.00 4,706.82 7,400.00 53.96 137.73 4,983.92 4,942.62 -1,562.20 4,586.24 6,027,621.33 562,709.00 0.00 4,782.93 7,500.00 53.96 137.73 5,042.75 5,001.45 -1,622.04 4,640.63 6,027,561.93 562,763.86 0.00 4,859.05 7,600.00 53.96 137.73 5,101.58 5,060.28 -1,681.87 4,695.02 6,027,502.53 562,818.71 0.00 4,935.16 7,700.00 53.96 137.73 5,160.41 5,119.11 -1,741.71 4,749.42 6,027,443.13 562,873.56 0.00 5,011.27 7,800.00 53.96 137.73 5,219.25 5,177.95 -1,801.54 4,803.81 6,027,383.73 562,928.42 0.00 5,087.39 7,900.00 53.96 137.73 5,278.08 5,236.78 -1,861.38 4,858.20 6,027,324.32 562,983.27 0.00 5,163.50 8,000.00 53.96 137.73 5,336.91 5,295.61 -1,921.21 4,912.60 6,027,264.92 563,038.13 0.00 5,239.61 8,100.00 53.96 137.73 5,395.74 5,354.44 -1,981.05 4,966.99 6,027,205.52 563,092.98 0.00 5,315.73 8,200.00 53.96 137.73 5,454.57 5,413.27 -2,040.88 5,021.38 6,027,146.12 563,147.84 0.00 5,391.84 8,300.00 53.96 137.73 5,513.40 5,472.10 -2,100.72 5,075.78 6,027,086.71 563,202.69 0.00 5,467.95 8,400.00 53.96 137.73 5,572.23 5,530.93 -2,160.55 5,130.17 6,027,027.31 563,257.54 0.00 5,544.07 8,500.00 53.96 137.73 5,631.07 5,589.77 -2,220.39 5,184.56 6,026,967.91 563,312.40 0.00 5,620.18 8,600.00 53.96 137.73 5,689.90 5,648.60 -2,280.22 5,238.96 6,026,908.51 563,367.25 0.00 5,696.29 8,700.00 53.96 137.73 5,748.73 5,707.43 -2,340.06 5,293.35 6,026,849.11 563,422.11 0.00 5,772.40 8,800.00 53.96 137.73 5,807.56 5,766.26 -2,399.89 5,347.74 6,026,789.70 563,476.96 0.00 5,848.52 8,900.00 53.96 137.73 5,866.39 5,825.09 -2,459.72 5,402.14 6,026,730.30 563,531.81 0.00 5,924.63 9,000.00 53.96 137.73 5,925.22 5,883.92 -2,519.56 5,456.53 6,026,670.90 563,586.67 0.00 6,000.74 9,100.00 53.96 137.73 5,984.05 5,942.75 -2,579.39 5,510.93 6,026,611.50 563,641.52 0.00 6,076.86 9,200.00 53.96 137.73 6,042.89 6,001.59 -2,639.23 5,565.32 6,026,552.09 563,696.38 0.00 6,152.97 9,234.30 53.96 137.73 6,063.06 6,021.76 -2,659.75 5,583.98 6,026,531.72 563,715.19 0.00 6,179.08 Start Dir 5°/100':9234.3'MD,6021.771VD 9,300.00 50.68 137.73 6,103.22 6,061.92 -2,698.22 5,618.95 6,026,493.53 563,750.46 5.00 6,228.01 9,400.00 45.68 137.73 6,169.88 6,128.58 -2,753.35 5,669.06 6,026,438.80 563,801.00 5.00 6,298.14 9,500.00 40.68 137.73 6,242.78 6,201.48 -2,803.97 5,715.07 6,026,388.55 563,847.40 5.00 6,362.52 9,600.00 35.68 137.73 6,321.36 6,280.06 -2,849.69 5,756.63 6,026,343.16 563,889.31 5.00 6,420.68 9,683.96 31.48 137.73 6,391.30 6,350.00 -2,884.04 5,787.86 6.026,309.05 563,920.81 5.00 6,464.38 CMI 9,700.00 30.68 137.73 6,405.04 6,363.74 -2,890.17 5,793.43 6,026,302.97 563,926.42 5.00 6,472.17 9,713.55 30.00 137.73 6,416.73 6,375.43 -2,895.23 5,798.04 6,026,297.94 563,931.06 5.00 6,478.62 End Dir :9713.55'MD,6375.43'TVD 9,800.00 30.00 137.73 6,491.60 6,450.30 -2,927.22 5,827.11 6,026,266.19 563,960.39 0.00 6,519.30 9,900.00 30.00 137.73 6,578.20 6,536.90 -2,964.22 5,860.74 6,026,229.45 563,994.30 0.00 6,566.36 9,915.13 30.00 137.73 6,591.30 6,550.00 -2,969.82 5,865.83 6,026,223.90 563,999.43 0.00 6,573.48 THRZ 10,000.00 30.00 137.73 6,664.80 6,623.50 -3,001.22 5,894.37 6,026,192.72 564,028.22 0.00 6,613.43 10,030.60 30.00 137.73 6,691.30 6,650.00 -3,012.54 5,904.66 6,026,181.48 564,038.59 0.00 6,627.83 TKLGM 10,100.00 30.00 137.73 6,751.40 6,710.10 -3,038.22 5,928.00 6,026,155.99 564,062.13 0.00 6,660.49 10,200.00 30.00 137.73 6,838.01 6,796.71 -3,075.22 5,961.63 6,026,119.26 564,096.05 0.00 6,707.55 10,300.00 30.00 137.73 6,924.61 6,883.31 -3,112.22 5,995.27 6,026,082.53 564,129.97 0.00 6,754.61 10,388.55 30.00 137.73 7,001.30 6,960.00 -3,144.98 6,025.05 6,026,050.00 564,160.00 0.00 6,796.29 TKUC 10,400.00 30.00 137.73 7,011.21 6,969.91 -3,149.22 6,028.90 6,026,045.80 564,163.88 0.00 6,801.67 10,500.00 30.00 137.73 7,097.82 7,056.52 -3,186.21 6,062.53 6,026,009.06 564,197.80 0.00 6,848.74 6/14/2017 5:22:56PM Page 5 COMPASS 5000.1 Build 81 • • Halliburton H,ALLI B J RT©N Standard Proposal Report 44 « ' , ' . _ .i . » .', , � . � x, tM w : oSperryEDM-NORTH US+CANADA101-1M4111100:74700,11.;.7.4.,-;',;f:- Well Plan:MPU C-45 Hilcorp Alaska,LLC As-Built C-45 @ 41.30usft Milne Point ® As-Built C-45 @ 41.30usft MPtCPad True Plan:MPU C-45 Minimum Curvature MPU C-45 t Desrgn•,CV `MPU C-45 wp06b I �`":4444 •4 777 :u n, .s. 4 .. .... ..:.:..:ev.s44«44«aut,xan=fi:. -_:.�:'>>:XES 5444.444M14,4uV » mas..®> b#t,w,,,,,assc4 a t Planned S Measu .--7 Vertical z_ d �a «, : �., .. ==.7;71C'4,'=' � ;4444`°4444 Depth '' Inclination �'Azimuth Depth TVDss +N/-S +E/-W ' Fasting - (usft) (1 (°) (usft) usft (usft) : (usft) s : t (usft) 'Y" .x . ,�,. a 44 77 .., 10,600.00 30.00 137.73 7,184.42 7,143.12 -3,223.21 6,096.16 6,025,972.33 564,231.71 0.00 6,895.80 10,678.83 30.00 137.73 7,252.69 7,211.39 -3,252.38 6,122.67 6,025,943.38 564,258.45 0.00 6,932.90 TKA3 10,688.78 30.00 137.73 7,261.30 7,220.00 -3,256.06 6,126.02 6,025,939.72 564,261.82 0.00 6,937.58 Total Depth:10688.78'MD,7220'TVD-5 1/2" Targets ,r-z -.4.--- - ,4444,z4 444444:."44 44! .s ,4.4 s am sTarget Ne r 4444 44 ,' 7 E -hit/miss target: o $r 0m TVD � - Ef- w a ott�,x „ "'I ur _ ( )Shape () (usft) , ( sft) (usft) usft MPC-Tulsa TKUC Tgt2 V2 0.00 0.00 7,001.30 -3,144.98 6,025.05 6,026,050.00 564,160.00 -plan hits target center -Polygon Point 1 7,001.30 7.01 -384.99 6,026,054.00 563,775.00 Point 2 7,001.30 -155.48 58.79 6,025,895.00 564,220.00 Point 3 7,001.30 262.83 154.07 6,026,314.00 564,312.00 Point 4 7,001.30 7.01 -384.99 6,026,054.00 563,775.00 MPC-Tulsa SBOATgt1 0,00 0.00 4,341.30 -908.81 3,992.26 6,028,270.00 562,110.00 -plan hits target center -Point Casing Points .,_ 4477„. x., . .4444,.,- . _ �•� Measured Vertical ') ' ®lame ®a t$ R Depth Depth (usft) (usft) '' O u.. 4',.. . . -e- ... x.,.. 7,000.00 4,748.59 9 5/8" 9-5/8 12-1/4 10,688.78 7,261.30 5 1/2" 5-1/2 8-1/2 , Formations , ., I _ Measured B . Depth Depth - ® s (usft) e: (usft) ---,..4-44, , 44.7. ., .-,g9N44.r,. _.-. 10,678.83 7,252.69 TKA3 0.00 6,307.90 4,341.30 SBOA 0.00 1,879.68 1,671.30 B P R F 0.00 10,388.55 7,001.30 TKUC 0.00 9,683.96 6,391.30 CM1 0.00 10,030.60 6,691.30 TKLGM 0.00 9,915.13 6,591.30 THRZ 0.00 6/14/2017 5:22:56PM Page 6 COMPASS 5000.1 Build 81 0 • Halliburton 1"IALLI B lJ RTO I'I Standard Proposal Report ®,- . Sof EDM_N z,�... ..��-s....,._..:. ..'v.,'»»..,.+< sz 1 p ry ORTH US+CANADATiAls. . . . -`' well Plan:MPU C-45 > Hilcorp Alaska,LLC = As-Built C-45 @ 41.30usft Milne Point s As-Built C-45 @ 41.30usft M Pt C Padb , TrueteiiPlan:MPU C-45 t Minimum um Curvature MPU C-45 j Desr n "MPU C-45 wp06b Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-5 +E/IN; i2 (usft) (usft) .s (usft) (usft) " Comment r ,„ , ,,,-0,,, ;- 525.50 525.50 0.00 0.00 Start Dir 3°/100':525.5'MD,484.2'TVD 825.50 824.27 0.82 23.50 Start Dir 5°/100':825.5'MD,782.97'TVD 1,375.50 1,326.62 8.17 234.03 Start Dir 5°/100':1375.5'MD,1326.62'TVD 1,759.94 1,599,30 -20.41 500.95 End Dir :1759.94'MD,1558'TVD 5,742.66 3,994.31 -689.77 3,611.88 Start Dir 5°/100':5742.66'MD,3953.01'TVD 6,326.55 4,352.39 -919.90 4,002.35 End Dir :6326.55'MD,4352.39'TVD 9,234.30 6,063.06 -2,659.75 5,583.98 Start Dir 5°/100':9234.3'MD,6021.77'TVD 9,713.55 6,416.73 -2,895.23 5,798.04 End Dir :9713.55'MD,6375.43'TVD 10,688.78 7,261.30 -3,256.06 6,126.02 Total Depth:10688.78'MD,7220'TVD 6/14/2017 5:22.56PM Page 7 COMPASS 5000.1 Build 81 I S Hilcorp Alaska, LLC Milne Point M Pt C Pad Plan: MPU C-45 MPU C-45 MPU C-45 wp06b Sperry Drilling Services Clearance Summary Anticollision Report 14 June,2017 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt C Pad-Plan:MPU C-45-MPU C-45-MPU C-45 wp06b Well Coordinates: 6,029,147.50 N,558,111.14 E(70°29'24.90"N,149°31'29.85"W) Datum Height:As-Built C-45 @ 41.30usft Scan Range: 0.00 to 10,688.78 usft.Measured Depth. Scan Radius is 1,266.23 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:81 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 ft)* I l' HALLIBURTON Ji J Sperry Drilling Services • • • HALLIBURTON Project: Milne Point REFERENCE INFORMATION WELL DETAILS:Plow MPU C-45 NAD 1927(NADCONCONUS) Ale#a Zone 04 Site: M Pt C Pad Ce-e 0inete(N/E)Reterenca:Well Nem MPU C-45,True North Ground Level: 14.80 Well: Plan:MPU C-45 Verliul(ND)Reference:As-Bain Cds�4laousR xis P/_w 029)47 10° ade Longitude Sperry Grilling Me.aarea Calculation Reference:M-auin C-45 41.3ouaR 0.00 0.00 6029147.50 558111.14 70°2724.898N 149°31'29.845W Wellbore: MPU C-45 Calculation Method:Minimum Curvature ij_, Plan. MPU C-45 wp06b SURVEY PROGRAM GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference II iiiii ) 28.50 To 10688.78 Depth Fern Depth Tote'.2017 3urvley/Plan� ValidatSR S Version: CASING DETAILS Ladder/S.F. Plots 28.50 1400.00 MPU C-45 wp08b TTool 1400.00 7000.00 MPU C-45 wp08b MWD+IFR2+MS+sac TVD TVDSS MD Size Name 7000.00 10688.78 MPU C-45 w50613 MWD+IFR2+MS+0a1 4748.59 4707.29 7000.00 9-5/8 9 5/8" 7261.30 7220.00 10688.78 5.5 5.5" 150.00 a(,;: (i-�� f yi+ __._..... _ • j � I illi I. ;I I f5"I� _ MPG39 i .�.. III i _ I ,'. 19000 2000 m aMPCr13 C-47' • m MPU G46 IJ'i, 141"� _. ..AP& V ..I �. • • - W 60.00 -- Ile _ ____ __ __.- -- b w.,:-.. 3111!0. I MPC-14 1 MPC-28 ...�r�_.. - o ...�Idll • • 'l Illr MPC-20 ___ .. ::: ri,LOr" l� al -._. ._-__ ._..__..111H1 , , , 111H 11111111111111 , , 111111111111111 , , , 1 111111111111111111I , , , , 111111111 , 1 , 1111111 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Measured Depth(1000 usft/in) 4.50— ....._.I�. '___ \\****I'"*.a. I _..... • 1 m 3.00— - _....... .._....... : -__ i g - Collision Risk Procedures Req I I o I ! ...@ _m — ro N 1.50---Collision Avoidance Rec. - i I1 - No-Go Zone-Stop Drilling • �_ 0.00 1111 1111 iiii iiiiiiIil iii h ill 11111111 / 1111 11I11Iill rill Ilii illi 11111 1 11111111 111111 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Measured Depth • 0 Hilcorp Alaska,LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU C-45-MPU C-45 wp06b Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt C Pad-Plan:MPU C-45-MPU C-45-MPU C-45 wp06b Scan Range: 0.00 to 10,688.78 usft.Measured Depth. Scan Radius is 1266.23 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (soft) (usft) (usft) (usft) usft M Pt C Pad MPC-01-MPC-01-MPC-01 1,122.04 289.30 1,122.04 274.8.4 1,084.64 20.005 Centre Distance Pass- MPC-0I-MPC-01-MPC-01 1,150.00 289.52 1,150.00 274.49 1,110.16 19.254 Ellipse Separation Pass- MPC-0I-MPC-01-MPC-01 1,400.00 320.67 1,400.00 299.68 1,325.76 15.424 Clearance Factor Pass- MPC-05-MPC-05-MPC-05 1,043.49 299.25 1,043.49 286.15 1,055.95 22.851 Centre Distance Pass- MPC-05-MPC-05-MPC-05 1,050.00 299.27 1,050.00 286.06 1,061.50 22.659 Ellipse Separation Pass- MPC-0S-MPC-05-MPC-05 1,275.00 334.47 1,275.00 317.12 1,228.67 19.271 Clearance Factor Pass- MPC-0S-MPC-05A-MPC-05A 1,043.49 299.25 1,043.49 286.15 1,055.95 22.851 Centre Distance Pass- MPC-05-MPC-05A-MPC-05A 1,050.00 299.27 1,050.00 286.06 1,061.50 22.659 Ellipse Separation Pass- MPG-0S-MPC-05A-MPC-05A 1,275.00 334.47 1,275.00 317.12 1,228.67 19.271 Clearance Factor Pass- MPC-06-MPC-06-MPC-06 947.93 197.28 947.93 185.76 952.82 17.137 Centre Distance Pass- MPC-06-MPC-06-MPC-06 975.00 197.46 975.00 185.58 977.81 16.621 Ellipse Separation Pass- MPC-06-MPC-06-MPC-06 3,850.00 1,262.41 3,850.00 1,138.82 3,603.60 10.214 Clearance Factor Pass- MPC-07-MPC-07-MPC-07 399.71 150.04 399.71 144.68 410.41 28.008 Centre Distance Pass- MPC-07-MPC-07-MPC-07 525.00 150.75 525.00 144.00 534.00 22.346 Ellipse Separation Pass- MPC-07-MPC-07-MPC-07 850.00 179.49 850.00 169.24 835.08 17.506 Clearance Factor Pass- MPC-08-MPC-08-MPC-08 822.26 80.52 82226 70.70 834.73 8.198 Centre Distance Pass- MPC-0B-MPC-08-MPC-08 825.00 80.52 825.00 70.67 837.37 8.170 Ellipse Separation Pass- MPC-08-MPC-08-MPC-08 900.00 84.56 900.00 73.74 908.34 7.819 Clearance Factor Pass- MPC-09-MPC-09-MPC-09 26.50 260.13 26.50 259.17 3720 270.301 Centre Distance Pass- MPC-09-MPC-09-MPC-09 575.00 261.54 575.00 255.52 564.68 43.442 Ellipse Separation Pass- MPC-09-MPC-09-MPC-09 1,050.00 331.63 1,050.00 320.99 991.20 31.184 Clearance Factor Pass- MPC-10-MPC-10-MPC-10 26.50 30.45 26.50 29.53 37.20 33.216 Centre Distance Pass- MPC-10-MPC-10-MPC-10 725.00 34.15 725.00 25.39 735.47 3.898 Ellipse Separation Pass- MPC-10-MPC-10-MPC-10 800.00 36.24 800.00 26.59 810.02 3.758 Clearance Factor Pass- MPC-11-MPC-11-MPC-11 1,227.30 197.79 1,227.30 180.85 1,213.44 11.674 Centre Distance Pass- MPC-II-MPC-II-MPC-11 1,250.00 198.09 1,250.00 180.58 1,233.42 11.314 Ellipse Separation Pass- MPC-II-MPC-II-MPC-11 1,375.00 212.30 1,375.00 191.83 1,339.79 10.369 Clearance Factor Pass- MPC-I2-MPC-12-MPC-12 1,595.40 134.88 1,595.40 117.26 1,594.00 7.659 Ellipse Separation Pass- 14 June,2017- 17:30 Page2of8 COMPASS • 0 Hilcorp Alaska,LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU C-45-MPU C-45 wp06b Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt C Pad-Plan:MPU C-45-MPU C-45-MPU C-45 wp06b Scan Range: 0.00 to 10,688.78 usft.Measured Depth. Scan Radius is 1,266.23 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPC-12-MPC-12-MPC-12 1,600.00 134.93 1,600.00 117.28 1,59655 7.644 Clearance Factor Pass- MPC-12-MPC-12A-MPC-12A 1,595.40 134.88 1,595.40 117.26 1,594.00 7.658 Ellipse Separation Pass- MPC-12-MPC-12A-MPC-12A 1,600.00 134.93 1,600.00 117.28 1,596.55 7.643 Clearance Factor Pass- MPC-12-MPC-12APB1-MPC-12APB1 1,595.40 134.88 1,595.40 117.26 1,594.00 7.658 Ellipse Separation Pass- MPC-12-MPC-12APB1-MPC-I2APB1 1,600.00 134.93 1,600.00 117.28 1,596.55 7.643 Clearance Factor Pass- MPC-13-MPC-13-MPC-13 1,289.12 82.34 1,289.12 63.75 1,266.02 4.430 Centre Distance Pass- MPC-13-MPC-13-MPG-13 1,300.00 82.54 1,300.00 63.70 1,275.20 4.380 Ellipse Separation Pass- MPC-13-MPC-13-MPC-13 1,325.00 84.63 1,325.00 65.20 1,296.08 4.356 Clearance Factor Pass- MPC-14-MPC-14-MPC-14 1,343.73 36.46 1,343.73 16.94 1,295.36 1.868 Ellipse Separation Pass- MPC-14-MPC-14-MPC-14 1,350.00 36.64 1,350.00 16.96 1,300.49 1.862 Clearance Factor Pass- MPC-15-MPC-15-MPC-15 1,397.00 152.43 1,397.00 131.00 1,354.44 7.115 Centre Distance Pass- MPC-15-MPC-15-MPC-15 1,400.00 152.44 1,400.00 130.92 1,356.82 7.085 Ellipse Separation Pass- MPC-IS-MPC-15-MPC-15 1,450.00 155.27 1,450.00 133.02 1,395.90 6.977 Clearance Factor Pass- MPC-15-MPC-ISA-MPC-15A 1,397.00 152.43 1,397.00 131.22 1,352.78 7.187 Centre Distance Pass- MPC-15-MPC-15A-MPC-15A 1,400.00 152.44 1,400.00 131.13 1,355.16 7.156 Ellipse Separation Pass- MPC-15-MPC-15A-MPC-15A 1,450.00 155.27 1,450.00 133.23 1,394.24 7.045 Clearance Factor Pass- MPC-18-MPG-IS-MPC-1B 1,106.41 431.33 1,106.41 416.86 1,075.10 29.797 Centre Distance Pass- MPC-18-MPC-18-MPC-18 1,150.00 431.68 1,150.00 416.30 1,112.26 28.070 Ellipse Separation Pass- MPC-18-MPC-18-MPC-18 8,925.00 1,259.39 8,925.00 868.77 8,527.56 3.224 Clearance Factor Pass- MPC-20-MPC-20-MPC-20 1,349.72 34.30 1,349.72 14.29 1,309.41 1.714 Centre Distance Pass- MPC-20-MPC-20-MPC-20 1,350.00 34.30 1,350.00 14.28 1,309.63 1.713 Clearance Factor Pass- MPC-23-MPC-23-MPC-23 292.77 179.69 292.77 177.28 296.48 74.474 Centre Distance Pass- MPC-23-MPC-23-MPC-23 350.00 179.87 350.00 177.06 352.58 64.147 Ellipse Separation Pass- MPC-23-MPC-23-MPC-23 950.00 238.65 950.00 231.62 923.64 33.927 Clearance Factor Pass- MPC-26-MPC-26-MPC-26 26.50 230.68 26.50 229.33 31.49 171.328 Centre Distance Pass- MPC-26-MPC-26-MPC-26 350.00 231.66 350.00 228.82 353.51 81.460 Ellipse Separation Pass- MPC-26-MPC-26-MPC-26 1,050.00 305.88 1,050.00 297.91 1,011.60 38.376 Clearance Factor Pass- MPC-26-MPC-26L1-MPC-26L1 26.50 230.68 26.50 229.33 31.49 171.329 Centre Distance Pass- MPC-26-MPC-26L1-MPC-26L1 350.00 231.66 350.00 228.82 353.51 81.461 Ellipse Separation Pass- MPC-26-MPC-26L1-MPC-26L1 1,050.00 305.88 1,050.00 297.91 1,011.60 38.373 Clearance Factor Pass- 14 June,2017- 17:30 Page 3018 COMPASS i • Hilcorp Alaska,LLC HA LLI B U RTO N Milne Point Anticollision Report for Plan: MPU C-45-MPU C-45 wp06b Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt C Pad-Plan:MPU C-45-MPU C-45-MPU C-45 wp06b Scan Range: 0.00 to 10,688.78 usft.Measured Depth. Scan Radius is 1,266.23 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) unit MPC-26-MPC-26LIPB1-MPC-26L1PB1 26.50 230.68 26.50 229.33 31.49 171.329 Centre Distance Pass- MPC-26-MPC-26L1PB1-MPC-26L1PB1 350.00 231.66 350.00 228.82 353.51 81.461 Ellipse Separation Pass- MPC-26-MPC-26L1P81-MPC-26L1PB1 1,050.00 305.88 1,050.00 297.91 1,011.60 38.373 Clearance Factor Pass- MPC-26-MPC-26L1PB2-MPC-26L1PB2 26.50 230.68 26.50 229.33 31.49 171.329 Centre Distance Pass- MPC-26-MPC-26L1PB2-MPC-26L1PB2 350.00 231.66 350.00 228.82 353.51 81.461 Ellipse Separation Pass- MPC-26-MPC-26L1PB2-MPC-26L1PB2 1,050.00 305.88 1,050.00 297.91 1,011.60 38.373 Clearance Factor Pass- MPC-26-MPC-26L1PB3-MPC-26L1PB3 26.50 230.68 26.50 229.33 31.49 171.329 Centre Distance Pass- MPC-26-MPC-26L1 PB3-MPC-26L1PB3 350.00 231.66 350.00 228.82 353.51 81.461 Ellipse Separation Pass- MPC-26-MPC-26L1PB3-MPC-26L1PB3 1,050.00 305.88 1,050.00 297.91 1,011.60 38.373 Clearance Factor Pass- MPC-28-MPC-28-MPC-28 746.97 21.73 746.97 14.13 752.06 2.859 Centre Distance Pass- MPC-28-MPC-28-MPC-28 750.00 21.73 750.00 14.10 755.07 2.848 Ellipse Separation Pass- MPC-28-MPC-28-MPC-28 775.00 22.07 775.00 14.19 779.84 2.803 Clearance Factor Pass- MPC-28-MPC-28A-MPC-28A 746.97 21.73 746.97 14.24 755.74 2.900 Centre Distance Pass- MPC-28-MPC-28A-MPC-28A 750.00 21.73 750.00 1421 758.75 2.890 Ellipse Separation Pass- MPC-28-MPC-28A-MPC-28A 775.00 22.07 775.00 14.30 783.52 2.843 Clearance Factor Pass- MPC-36-MPC-36-MPC-36 100.00 90.33 100.00 89.16 95.60 77.391 Centre Distance Pass- MPC-36-MPC-36-MPC-36 200.00 90.61 200.00 88.77 195.04 49.180 Ellipse Separation Pass- MPC-36-MPC-36-MPC-36 725.00 115.92 725.00 110.45 711.58 21.194 Clearance Factor Pass- MPC-39-MPC-39-MPC-39 876.95 52.19 876.95 45.75 879.53 8.106 Ellipse Separation Pass- MPC-39-MPC-39-MPC-39 950.00 54.86 950.00 47.80 950.29 7.767 Clearance Factor Pass- MPC-40-MPC-40-MPC-40 26.50 119.65 26.50 118.30 31.48 88.904 Centre Distance Pass- MPC-40-MPC-40-MPC-40 75.00 119.75 75.00 118.24 79.50 79.194 Ellipse Separation Pass- MPC-40-MPC-40-MPC-40 950.00 148.62 950.00 141.02 939.59 19.544 Clearance Factor Pass- MPC-41-MPC-41-MPC-41 26.50 179.56 26.50 178.49 30.35 167.811 Centre Distance Pass- MPC-41-MPC-41-MPC-41 75.00 179.65 75.00 178.41 78.27 145.159 Ellipse Separation Pass- MPC-41-MPC-41-MPC-41 950.00 241.19 950.00 234.02 909.85 33.655 Clearance Factor Pass- MPC-41-MPC-41L1-MPC-41L1 26.50 179.56 26.50 178.49 30.35 167.811 Centre Distance Pass- MPC-41-MPC-41L1-MPC-41L1 75.00 179.65 75.00 178.41 78.27 145.159 Ellipse Separation Pass- MPC-41-MPC-41L1-MPC-41L1 950.00 241.19 950.00 234.13 909.85 34.151 Clearance Factor Pass- MPC-41-MPC-41L2-MPC-41L2 26.50 179.56 26.50 178.49 30.35 167.811 Centre Distance Pass- 14 June,2017- 17:30 Page 4 of COMPASS • S Hilcorp Alaska,LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU C-45-MPU C-45 wp06b Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt C Pad-Plan:MPU C-45-MPU C-45-MPU C-45 wp06b Scan Range: 0.00 to 10,688.78 usft.Measured Depth. Scan Radius is 1,266.23 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPC-41-MPC-41L2-MPC-41L2 75.00 179.65 75.00 178.41 78.27 145.159 Ellipse Separation Pass- MPC-41-MPC-41L2-MPC-41L2 950.00 241.19 950.00 234.13 909.85 34.151 Clearance Factor Pass- MPC-41-MPC41P61-MPC41PB1 26.50 179.56 26.50 178.49 30.35 167.811 Centre Distance Pass- MPC-41-MPC-41PB1-MPC-41PB1 75.00 179.65 75.00 178.41 78.27 145.159 Ellipse Separation Pass- MPC-41-MPC-41PB1-MPC-41PB1 950.00 241.19 950.00 233.76 909.85 32.452 Clearance Factor Pass- MPC-41-MPC-41PB2-MPC-41PB2 26.50 179.56 26.50 178.49 30.35 167.811 Centre Distance Pass- MPC-41-MPC41PB2-MPC-41PB2 75.00 179.65 75.00 178.41 7827 145.159 Ellipse Separation Pass- MPC-41-MPC41 PB2-MPC-41PB2 950.00 241.19 950.00 234.02 909.85 33.653 Clearance Factor Pass- Plan:MPC-35 Kuparuk/Sag-Kuparuk/Sag River-MP 525.00 120.15 525.00 115.60 533.70 26.460 Centre Distance Pass- Plan:MPC-35 Kuparuk/Sag-Kuparuk/Sag River-MP 575.00 120.32 575.00 115.45 583.69 24.726 Ellipse Separation Pass- Plan:MPC-35 Kuparuk/Sag-Kuparuk/Sag River-MP 950.00 141.59 950.00 134.09 954.64 18.875 Clearance Factor Pass- Plan:MPU C-47-MPU C-47-MPU C47 wp06 1,200.00 79.36 1,200.00 66.55 1,185.85 6.193 Clearance Factor Pass- Plan:MPU C-47-MPU C47-MPU C47 wp06 1,225.00 78.93 1,225.00 66.34 1,208.00 6.271 Ellipse Separation Pass- Plan:MPU C47-MPU C47-MPU C47 wp06 1,225.76 78.93 1,225.76 66.35 1,208.67 6.274 Centre Distance Pass- RIG:MPU C-46-MPU C-46-MPU C46 wp07 584.57 56.62 584.57 50.99 585.28 10.062 Centre Distance Pass- RIG:MPU C46-MPU C-46-MPU C-46 wp07 650.00 56.89 650.00 50.69 650.53 9.175 Ellipse Separation Pass- RIG:MPU C46-MPU C46-MPU C-46 wp07 800.00 61.61 800.00 54.13 799.31 8.239 Clearance Factor Pass- RIG:MPU C46-MPU C46-MPU C-46 584.57 56.62 584.57 50.88 585.28 9.870 Centre Distance Pass- RIG:MPU C-46-MPU C-46-MPU C-46 650.00 56.89 650.00 50.58 650.53 9.016 Ellipse Separation Pass- RIG:MPU C-46-MPU C-46-MPU C-46 800.00 61.61 800.00 54.02 799.31 8.120 Clearance Factor Pass- RIG:MPU C-46-MPU C-46 PB1-MPU C-46 PB1 584.57 56.62 584.57 50.88 585.28 9.870 Centre Distance Pass- RIG:MPU C-46-MPU C46 PB1-MPU C46 PB1 650.00 56.89 650.00 50.58 650.53 9.016 Ellipse Separation Pass- RIG:MPU C-46-MPU C-46 PB1-MPU C46 PB1 800.00 61.61 800.00 54.03 799.31 8.121 Clearance Factor Pass- M Pt D Pad MPD-02-MPD-02A-MPD-02A 10,688.78 913.97 10,688.78 736.57 9,340.00 5.152 Clearance Factor Pass- 14 June.2017- 17:30 Page 5 of 8 COMPASS S s Hilcorp Alaska,LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU C-45-MPU C-45 wp06b Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 26.50 1,400.00 MPU C-45 wp06b SRG-SS 1,400.00 7,000.00 MPU C-45 wp06b MWD+IFR2+MS+sag 7,000.00 10,688.78 MPU C-45 wp06b MWD+IFR2+MS+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. • Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 14 June.2017-17:30 Page 6 of 8 COMPASS • • Davies, Stephen F (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Wednesday,July 19, 2017 11:41 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Milne Point Unit C-45 (PTD#217-092) - Questions Steve, Yes, our planned mud program is to be statically over balanced while drilling through all sections of the well.This is confirmed by the use of the same mud program/mud weights on previously drilled MPU C Pad wells, C-46 and C-47. Please let me know if you have any other questions. Thank you. Joe From: Davies,Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent:Wednesday,July 19, 2017 10:30 AM To:Joe Engel <jengel@hilcorp.com> Cc:Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov> Subject: RE: Milne Point Unit C-45 (PTD#217-092) -Questions Thank you Joe. Apologies for miss-spelling your email address and the delay it caused. I'm just surprised that none of the emails that I sent bounced back as undeliverable. One more question regarding the proposed mud program: Will the static mud weights of the proposed program exceed Hilcorp's estimates of most likely pore pressures between 2000' and 5500' measured depth? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Joe Engel [mailto:jengel@hilcorp.com] Sent:Tuesday,July 18, 2017 5:20 PM To:Schwartz, Guy L(DOA) <guy.schwartz@alaska.gov>; Davies, Stephen F (DOA)<steve.daviesPalaska.gov> Subject: RE: Milne Point Unit C-45 (PTD#217-092) -Questions 1 • • Davies, Stephen F (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Tuesday,July 18, 2017 5:20 PM To: Schwartz, Guy L(DOA); Davies, Stephen F (DOA) Subject: RE: Milne Point Unit C-45 (PTD#217-092) - Questions Thanks, Steve. After speaking with the Reservoir Engineer and Geologist, all data indicate that the listed formations are normally pressured.Also indicating normal pressure is the mud weight used while drilling nearby wells.We do have a SBHP for the Kuparuk from the offset well, B-10 from 2012,which is being used for estimated Kuparuk pressure. Estimated formation pressures and nearby well MW vs Depth chart is included below. Please let me know if you have any questions. Thanks. Joe 1 • • Formation TVD,ft psi Ugnu 3500 1602 Schrader Bluff 4341 1986 Surface Shoe 4748 2173 Kalubik 6691 3062 HRZ 6591 3016 Kuparuk D 7152 2761 Kuarpuk B 7302 2819 Kuarpuk C 7252 2800 2 411L_ ID Offset and C-45 �� MW vs Depth 0 __... MPC 46 Plan MPC 46 Actual 1000 . .. __ _ -. MPC-46 Sidetrack MPC-4S Plan 1 MPC-1SA 2000 l --MPG-47 3000 , i ___1___ , 4000 _ `>(X)(1 a d O lat..' a 6000v Ili 7000 ILN t 8000 .. • I j 9000 -- d\'''%.44.1'.%***%.'%%*•.\\_. 10000 11000 8 9 10 11 1) 13 14 Mud Density(ppg) 3 • From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday,July 18, 2017 3:49 PM To:Joe Engel<jengel@hilcorp.com> Subject: FW: Milne Point Unit C-45 (PTD#217-092) -Questions fyi Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Davies,Stephen F(DOA) Sent:Tuesday,July 18, 2017 3:48 PM To:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: FW: Milne Point Unit C-45(PTD#217-092)-Questions FYI From: Davies,Stephen F(DOA) Sent:Tuesday,July 18, 2017 1:57 PM To: 'jengle@hilcorp.com' <jengle@hilcorp.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: Milne Point Unit C-45 (PTD#217-092) -Questions Hi Joe, Did you get a chance to look at this? I'd like to keep this permit application moving along through the review process. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Davies,Stephen F(DOA) Sent:Tuesday,July 11, 2017 3:13 PM To: 'jengle@hilcorp.com' <jengle@hilcorp.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: Milne Point Unit C-45(PTD#217-092)-Questions 4 Hi Joe, Did you get a chance to look at this? I'd like to keep this permit application moving along through the review process. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies,Stephen F(DOA) Sent: Monday,June 26, 2017 9:37 AM To: 'jengle@hilcorp.com'<jengle@hilcorp.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: RE: Milne Point Unit C-45 (PTD#217-092)-Questions Hi Joe, Did you get a chance to look at this? I'd like to keep this permit application moving along through the review process. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies,Stephen F(DOA) Sent: Monday,June 19, 2017 6:13 PM To:jengle@hilcorp.com Cc: Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov> Subject: Milne Point Unit C-45 (PTD#217-092) -Questions Joe, I'm reviewing Hilcorp's Permit to Drill application for the Milne Point Unit C-45 well and I have few questions for you. What are the estimated pressures or pressure gradients within the following intervals or points that will be penetrated by C-45? 1. Ugnu sands, 2. Schrader Bluff sands, 3. surface casing shoe, 4. Kalubik Shale, 5 5. HRZ Shale, • 6. Kuparuk D Interval, 7. Kuparuk B sands, and 8. Kuparuk C sands. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 6 • • N1-10 Thousand Cubic Feet of Gas ("MCF") per Day or co Gas-Oil Ratio (MCF per Barrel) O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 001 000 O^ 100 lO M N O- O 1 `49e 1 'tie Qe4 O o Pr 1 E - St 1 �4P - r CO vC u co Mo aQ , r CD er a 5 fC O 0 `' i i 4Pr Toco - ��- ----------------------� �l°� L ° 20 m - _, �`:4 4 v v ' ^ o 1 C'r Z 0 -0 g t2o - �__ r O c ` _ C O- 3 l7 _s===`___ `� 6° Pr m W c .0 a °� O 0 0 0 V�° ------ 0- -0 = E E i 80Qe - 0 o v u' v' 1 4 , �O °1 .o •C1C to 0 d °- Om > - _ 9°O�V. 6 illt ', .,-....,..... p 1 ,, _,.._____. 400e (u 5 0a 0) u QQ2 0 D •-- 4 U 0 r P -o - .' - FQQ� a u .�_ I4Pr eo oe -.' 4Pr _. 1 ,. O O O O O O O OoQ°�4 N O co0100 Cr N Pr ei r- ei lea _lad JaleM jo sla.i.ieg Jo /lea aad Ho Jo spinsu 0 • • Office Project 19 June 2017 INPUT OUTPUT Geographic,NAD27 State Plane,NAD27 5004-Alaska 4,U.S.Feet MPU C-45 1/1 Latitude: 70 29 24.898 Northing/Y: 6029147.523 Longitude: 149 31 29.845 Easting/X: 558111.154 Convergence: 0 26 51.97002 Scale Factor: 0.999903836 Remark: Corpscon v6.0.1,U.S.Army Corps of Engineers • S TRANSMITTAL LETTER CHECKLIST WELL NAME: L �`1 e- PTD: ,� -Z'` 2_ /Development ment Service Exploratory Strati a hic Test Non-Conventional p p D' �' P — K'r FIELD: Mr ( 2_ � L POOL: � ! l���'' i 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 all records, data and logs (fl, g acquired for thepilot hole must be clearlydifferentiated in both well q Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached licat on`,the following well logs are also required for this well: /;t,,(.rti.t«1c..eitt O(aZettEMLl- yeti// Well Logging /CS" l s 6- tx_O- &074-L.L. c2_ s Requirements 1, p(GCrtldtc A8A-r te A c=am�j, 4—lkp ,e Per Statute AS 31.t5.030(d)(2)(B) and vR_egulation 20 AAC 25.071, 6 t 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 410 S D El . , . , . 0) 0 a) 0- ,n cn . 1 _ 5 . , c . „ -.. , , , , o . < , . „ , , , . , . , . , . , . , . , . „ c. co ' 0 ' ' 0 • 1.7 0, . , . , „ , 0, • ' ' 0, . . „ . , , , c. ..:' 0 0, _c 0 , .J. 7 '0 0 ' . E ' .(L) . . , a) , . , , , 0, 0 a, .... 0 , . -6 za " .....' „ 7, .2, .a, (o. . 02 c ' ka - (n o. , CD, a- 0) a) C. „ , g -: -.if' 2 ' ' '''' ' 0 .-' c c c :=, 0 2 (/)' •-• o 1c ' 0' -- .0 cr 0ui ' .--, '0 :- o o CO , 0_ ry, ,O, 13., 1--., 0 , „ , „ , CD, , CD CO • ' ' 2 ....7, 0 cn :E ' . ' a 0 ' 3" (.0 N. 0, cry , ct, , a) .c ,-- •-• P., „ , „ „ , i. 2), 1-, 6 2 ea 2 0 E' --. • o I- C/ 2 c c Co , C 3 . . ,-.. as a " ' :.-. c , a), . „ 'a „ . 2, a c a 4- a, -a c c • , o _a .5 0 0 C W '- C" ' o 0 , co a a ' . ' a) o.) .- a), ...... 3, 3 . . ' . , . 0 ' ' ' ' . . a. '' ")' ' 2' ' vi, o ' o 0, , , . as •a, c° o_ 0 , . , , , , c, ..-, ca ti ir) • ry . i, ,-; cr . (`6. .- o ,... , r--, r.-- 0) •S o, o, 0. , 0, „ ... = a o5 a> 0 cr a •-• . 0. 0. 0 c (A (') as a> tn (0 co .... '0 0. ca .c. 7 -,-.., , . 0 . 2 a) ' 0 ca, 6 ea 2 ' <' <' 5 a a a ', ' ' ' cci .. mc ' C,.. > -,,,, ca 0 r> ,...,. .,..,. D , ' N N' N' _0 ' ' ' 2 Is ...a), , .-, a) . . S, -. sco'. . a a o a' la ri -o o, c, c al .- , --., 0, ' (,) .- ' 0' w" Cr,' ....; a) 0 0_. c i 0 a.. a . ±, ..:. . E u> -a - 0' ,-- Z N , 0, 0 Z, Z, Z, '-' U 0 17i 2. (5 ai ' -CI' Q. ' q ' Itni .5. 8, 0 .0, , -0, .„ ...a., ,,, e 0, ._, ,..,..,-, w 0 ;.12. a '4),. °, 0 ct, „ .. i_., ,:,,. ,, ,_, ,-, ,,L . . , 8, 45' -' -' .' °I -2. a ("' a ' -o' .--- 2 , .2. 06, a, 0, 0, 0, 2, . , , . 0_, a) .§, , a a -=, .c, e , -c, , , a), W, 0, co, , 16, „,_; c c c a . 6, ., ca, _, , -, t.), :=, > 0 a) :._, , ._, ., 2. E -g. .,1 a •aj <0 , 0. c 7 0, 0 0„ , , , . Lfj, ra 0) , ,7), >, 3, ,0. •-. .c, 0)„ 0 V. E a) , 21, - Z '= ...7 ' '7 "c"-(1 c rs c CY co 0 c- E, 0, 0, 0 0 .6 -.- .-U) 0, c . 0. 0, N„ 0 a CO' II:D 0 . , 2 ° av l'.4 [1,-6 g g ''' aE: c0 . 03 ascnoa ,- = C co 2' 33. 76. ' , , E a. ay = ca0- a cf) co, co, ' 8' cut"' Cli (N ..c cn 0) Ch .- a) 0 ' 't' 0' c c c c a' " ' ' " -' .c' - ' ' 0 ' 0' •-' c. x o a)" 2. (I). c.n. -0. 2. aY 0 Z 0, 0 .-. 0 0 0 .. . „ , . zo. 0 (7,.. ,-. I-: 2) EI 0 *Fir CO' 0 '4t' ' 3' N' N' 0' 0' 0' 0 rr W ' CO I---' 2, 0, 0 0 as, . , , , , ,-, z D La, , C0 k, 17, z, 0, M, E, M, , ca i, i, .2, a., < - a. , - ---• 2 „ , , . . , . „ , . „ „ , , , , , . „ . , as LU , , , . „ , „ , , , , a_ rs - T4' -2, o, a), a), a) a) a), a), a), a), a), a) a), a). < <, <, a), < e 0, a), a), a), <, a), a), 1), a), a), a), a), a), < o, a), <, <, < 8. z z >-, >-, >-, >-, >-, >-, >-, >-, >-, >- >-, >-, z z z >-, z >-, Z >-, >-, >-, Z, >-, >-, >-, >-, >-, >-, >-, >-, z z >-, z z z, a) ' (n iii r j c ' . . ., , , . . . ' ' " " " " " " . 0• = '5 -- - , . „ , _0. . in CL I.0 , „ , , t, 0 '8, , , 0 0 . 0, 5 . . -0 „ , , ,_ . , . . . . ?) 0 c . 0, ..,, , , w 9 „ . , „ , . „ 0 . .c. , , , a), , , . E. • (1) ' co > .r.. co -.- ay , a) > 2 0 o a. N EZ as 0 0, 0 a CU , 0, U.. a I , , . , a , co `t a c, a. , a) cr,. 2 . -->:, Y--.. C. . a ai ' 115,-, ' mi. ' -c) 0 ' 0 (U ' .a50. tn' (1Y ' il" ' C. ' a ' co v, a> ay a , -c a --- :- 0 P Pa' la ,I TS 0, 0 , r, , ow, E. cv. c cl i , 4 c - , , , , 0, , , 0, •-, =, , , ,_, 't, 2, E , . =, TX , , CD .7.-.... N '''-' *0 ..... Of C ' ' C' > co' •-' C' 0' ' 0' 2 0 - , - , c .(72" 0.) N' . a). .-•-•-, . i--` Lc), co >,, Z •.-. ' 0 -0 0 ,,D ' E. 0 CO 0 0 CO ,,,, __ i: ° , , , =-, _C, 0) , ' e• .75. . co c a) -c' ' CU)' a 0 ' .- '4. , 9' a ' ' (n' o0 ' -Co" co 5 . 45 +6 .c -a . a ay c' 7. ' -2' a . 8, .s. a), CO 0 0 0) (D. Ili (-,1_ -a , c c, 2, c. -a 4 a) , 8, 1:3 . e E E =, -a„ .c, c E ,-, c * ,s-.- 1-2 ' c' 2 "' D5' Cn' l.' L' c' ' 0 U)' c-'' •'. ,-*,,' 0)" '.-'' ° C" -' 0 -il')' '''-' al cv co' co' >: ' " P..' ; o w < r)'c7 ._.00 _..1 „ .9:„ ' .ri c`a'. 8: 8 ... .s, >, 0 s'. a t'', la ca' Es: , -x, "cif, 2; 2, i3; g, ,-- .2, E: E, 21 .52, "§-, "" -8 ---7 _-• To, ..-. e .c -11 8 , .2, g .04 a g i.: ___Ii c.i -`),i; 2: 2: _a: g: ?i,).: .: -0: -f,: ?,: ._: c, .-,: ,5):, .2', Zal, At, cl), g, 2,,-, u„ §: a a3, 0, •-a----, o c'r 3, g E t, , ca, a, „, „, .,..., _ ,,,,. 0, ...., -, •-, -a, 0, 0 co _ 0, LD, ,_, 0 , 'C sc., 0 O) •- co „D, (1) (1) . .0 .P., .r., ..... Cti 2 0 a. fl.) 0. . 4•-• Cfi 15 0, CO, 0 0, W 0..... TI 1 CI " a *a. c ._.- ...,-- ca 2' m) .a" > ,.... =' L.' .5,.' a ' -'-' a a' ,_' 1-' 0 0' (4 ••••'''„, a 15, ,..,m' ,.„03' ,..' .,.,' "a -c,„ ' "7„ 0 0 c, "4:--, ••••, •••., > a al ck, -0 -0 o OP E, a 2, CD 0, 0, C. a 0 0, (/), -0 E 6. co E .E, •••,, 6, 6. o. „._-,-, ma• c.u, a. co §, c,6 cc 6' 0 -cc' 0' 0' ,,,' -0' „,`''' c-' ,i t 0 2 0 0 ' -0 co' ‘-' a Ell' E a) o 1--- co' ...:--.. a c a - o' , ,a, a. 0, , Cc CC a -„„ Ca. 0, 0, a. ._E, --., .CD, , 0. iti, to, To, (D, 0, CI 8, .„ o.i . .s. 0 N, Ty 0 0, ,n, -' u) 0 a) E, a o o - . 0, Cn, 8n, CO, -.-', '--, E. CI? 3.-3c,a' ' co c' ,.,•-' ‘-' ..,,(13' 3' m to '- •- '§-, c, •- .0 oi 0 0 ,•-' U.' 2, C.4 D' •b- ,_0 a) ,..a, -0, =, ,..., 0, 0, >„, E., -(B, a) 0_ 0) .-- ay 0 •-, .-... 0- a t„, >, 0. e a). ,2, „_ ,,_, - -0 It; -0' -' -0 '0 '0 0 ' , c 0. -0, -0. '0 -.E,, a) in' Wy 413> 43 >' •- to. -c, 2, , , (n, .---, c.> ay -' -0 c as, a E :0ocaco io ac' a' ca 0 a)' co. F-2 0 ,-' 3' "0 g > a. sE-' 2 0000 ,... 0 gi -c, - - - ,,, .., - ._ - a), .... 4 a E F--, 47), -6, , 2, 0• , .._• 0 _I c, -, C, a> 00 0' CO' *-'' ••-• -...' ...' a 0 = 2' S. 8 ? cl.' §' 0) 1,, -iia; ci N. g u.l' Lii xcp: ! (%)' 03: ,-.,_ 0,, ...E., 3 c), -, -, 13, .>, ........ a •-......., ...I i E 0 0- - - - .- a) '-' 0 C i I- = 11, 0_, 0 c- c- 0 E a u), 0, s to' C. . co, ._, 7,), Ty 7), .0, a), a, c_, _, c 7,-, , 0, c `o . (.0, a> (.6 a), ..„-.5. ,..• c) 0 , 0. a 6 ''' 7,.. 0. v CO, 0), „, c, ......, .„, ...,, 0 4 4 CD, 0, CO, --- = ,-, 0, 7, „ , CD, -0„ 13, , c., .C, ....,_ _, _ a), , a), 0„ 0 $-\/ co o o o o <, •=, <, •-, C.1, 03, cO, (..), 5, l'-', 0-, 0, co, co, 0, as --.-..-- CU o. I E N'' ,- N C') nr If) (0 C- co a) ... ... ... F.:2 7-t r. (<f-) c,'-:' (4' N N ("1 2 N 2 NW N2 NCI) C OO C O.- C ON C OV) C OV C OI.° C OW C ON- C OW C OM r-- , 0 I-- r•-• ,- 1-- ,- 1,- iii.• E QC .0 o --- CL 0) 0 0 UJ o 11 Zi5 c N CL N. •a• up R- 130•E CO >, 0 E o1 _J 'E a) ca ,---- o - 0. a 1) AC1 Lii 0 E a. I-L a) a _1 -6 0. 0 < w c < 0 a) < U) Cement Evaluation Company: Hilcorp Alaska, LLC Field: Milne Point Unit Well Name: MPC-45 Log Date: 21-Oct-2017 Service: USIT-GR-CCL Run Number: USIT Analyst: Gaurav Agrawal Reviewed by: Divyani Mishra Cement Evaluation Company: Stone Energy Corporation Field: Mississippi Canyon 29 Software Integrated Solutions Data Services Schlumberger 1 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 1. Schlumberger Legal Disclaimer .............................................................................. 2 2. Executive Summary............................................................................................... 3 Recorded data and comments ..................................................................................................... 3 Objectives ..................................................................................................................................... 3 Observations ................................................................................................................................ 3 3. Summary Log ........................................................................................................ 4 Cement Evaluation ....................................................................................................................... 4 4. Observations ........................................................................................................ 8 Cement Evaluation ....................................................................................................................... 8 5. Contextual Information ....................................................................................... 11 Field Log Header ......................................................................................................................... 11 Well Sketch ................................................................................................................................. 12 Tool Sketch ................................................................................................................................. 13 6. Log Quality Control ............................................................................................. 14 Tool Eccentering (ECCE) ............................................................................................................. 14 Processing flags (UFLG) and anomalies ...................................................................................... 14 First echo amplitude (AWBK) ..................................................................................................... 14 7. Appendix ............................................................................................................ 15 Acoustic Impedance Measurement ........................................................................................... 15 Schlumberger 2 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 1. Schlumberger Legal Disclaimer ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED BY SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES ARE OPINIONS BASED ON INFERENCES FROM MEASUREMENTS, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS ARE NOT INFALLIBLE, AND WITH RESPECT TO WHICH PROFESSIONALS IN THE INDUSTRY MAY DIFFER. ACCORDINGLY, SCHLUMBERGER CANNOT AND DOES NOT WARRANT THE ACCURACY, CORRECTNESS OR COMPLETENESS OF ANY SUCH INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER ACKNOWLEDGES THAT IT IS ACCEPTING THE SERVICES "AS IS", THAT SCHLUMBERGER MAKES NO REPRESENTATION OR WA RRANTY, EXPRESS OR IMPLIED, OF ANY KIND OR DESCRIPTION IN RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES THAT SCHLUMBERGER DOES NOT WARRANT THAT ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION IS FIT FOR A PARTICULAR PURPOSE, INCLUDING BUT NOT LIMITED TO COMPLIANCE WITH ANY GOVERNMENT REQUEST OR REGULATORY REQUIREMENT. CUSTOMER FURTHER ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE EXPLICIT UNDERSTANDING AND AGREEMENT THAT ANY ACTION TAKEN BASED ON THE SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBILITY AND NO CLAIM SHALL BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEREOF. Schlumberger 3 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 2. Executive Summary Recorded data and comments An Ultra Sonic Imager Tool (USIT) log was recorded in MPC-45 well on the 21-Oct-2017. The logging data for USIT was recorded over the 5.5” 17ppf P110 casing, from 7155 ft to 10,125 ft under no surface pressure; from 8427 ft to 10125 ft under 300 psi surface pressure and from 7190 ft to 10125 ft under 900 psi surface pressure. The 0 psi pass was logged at 10 deg azimuthal and 1.5" vertical resolution whereas the 300 psi & 900 psi passes were logged at 10 deg azimuthal and 6" vertical resolution. The data under surface induced pressure was recorded to minimize any effect of micro-annulus. The well was reported to contain 9.8 lb/gal Salt Brine at the time of logging. Objectives The main objective of the logging is to evaluate cement bond quality of 5.5” casing. Observations Cement Evaluation • Poor cement is observed across and below the Kupark C sand (observed approx. across 9,970 ft to 10,000ft as seen on GR). Above the sand, intervals with full azimuthal cement coverage is observed across 9,797ft to 9,813 ft and 9,843 ft to 9,853 ft. • No major difference in the cement data was observed with variation of surface pressures, minimizing the possibility of any presence of micro-annulus across the logged interval. • No clear free pipe was observed across the logged interval. Top of good azimuthal cement was observed at ~ 8,508 ft. Liquid filled annulus with contaminated cement slurry was observed above 8,508 ft till top of the logging interval at 7,155 ft. • Moderate to good azimuthal cement with some contamination and liquid pockets is observed in the intervals 8,508 ft to 8,745 ft, 9,222ft to 9,574ft, 9,620 ft to 9,629 ft, 9,705 ft to 9,740 ft, 9,752 ft to 9,760 ft, 9,768 ft to 9,780 ft, 9,797ft to 9,827ft and 9,843 ft to 9,938 ft. • Poor azimuthal cement with continuous channel and some cement patches is observed across the intervals 8,745 ft to 9,222 ft, 9,574 ft to 9,620 ft, 9,629 ft to 9,705 ft, 9,740 ft to 9,752ft, 9,760 ft to 9,768 ft, 9,780 ft to 9,797 ft, 9,827 ft to 9,843 ft and 9,938 ft to 10,125 ft. Schlumberger 4 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 3. Summary Log Cement Evaluation Schlumberger 5 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 Schlumberger 6 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 Schlumberger 7 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 Schlumberger 8 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 4. Observations Cement Evaluation Figure 5 shows the snapshot of the logged interval from ~7155 ft to ~8,745 ft. No clear free pipe was observed across the logged interval. Top of good azimuthal cement was observed at ~ 8,508 ft. Liquid filled annulus with contaminated cement slurry was observed above 8,508 ft till top of the logging interval at 7,155 ft with an a verage acoustic impedance reading in range ~ 2.4 Mrayls. Slight variation in the data density for acoustic impedance is observed, due to possible contamination. Moderate to good azimuthal cement with some contamination and liquid pockets is observed in the intervals 8,508 ft to 8,745 ft with an average acoustic impedance reading in range ~ 4.5 Mrayls. Schlumberger 9 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 Figure 6 below shows the snapshot of the logged interval from ~8,745 ft to ~9,574 ft. Poor azimuthal cement with continuous channel and some cement patches is observed across the interval 8,745 ft to 9,222 ft with an average acoustic impedance reading in range ~ 2.9 Mrayls. The data density for acoustic impedance shows very minor variation across the interval. Moderate to good azimuthal cement with some contamination and liquid pockets is observed in the intervals 9,222 ft to 9,574 ft with an average acoustic impedance reading in range ~ 4.7 Mrayls. Schlumberger 10 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 Figure 7 below shows the snapshot of the logged interval from ~9,574 ft to ~10,125 ft. The Kupark C sand is observed approx. across 9,970 ft to 10,000ft as seen on GR in this section. Poor cement is observed across and below the sand. Above the sand, intervals with full azimuthal cement coverage is observed across 9,797ft to 9,813 ft and 9,843 ft to 9,853 ft. Poor azimuthal cement with continuous channel and some cement patches is observed across the i ntervals 9,574 ft to 9,620 ft, 9,629 ft to 9,705 ft, 9,740 ft to 9,752ft, 9,760 ft to 9,768 ft, 9,780 ft to 9,797 ft, 9,827 ft to 9,843 ft and 9,938 ft to 10,125 ft with an average acoustic impedance reading in range ~ 2.8 Mrayls. Moderate to good azimuthal cement with some contamination and liquid pockets is observed in the intervals 9,620 ft to 9,629 ft, 9,705 ft to 9,740 ft, 9,752 ft to 9,760 ft, 9,768 ft to 9,780 ft, 9,797ft to 9,827ft and 9,843 ft to 9,938 ft with an average acoustic impedance reading in range ~ 4.5 Mrayls. Schlumberger 11 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 5. Contextual Information Field Log Header Schlumberger 12 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 Well Sketch Schlumberger 13 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 Tool Sketch Schlumberger 14 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 6. Log Quality Control Tool Eccentering (ECCE) The tool eccentralization is generally observed to be slightly higher than the accepted limits in 0 psi and 900 psi passes without affecting the data measurements. Effect of tool eccentralization is usually seen azimuthally only. For example, in some places vertical high acoustic impedance (“cement”) lines are seen that correlate to variation of the amplitude of the first arrival. However, the overall interpretation is not effected due to eccentricity. The eccentricity for 300 psi pass is generally observed to be within accepted limits and it correlates well with the 0 and 900 psi data across the logged section. Processing flags (UFLG) and anomalies Processing flags are noted at the collars which is a normal response due to the increase in metal thickness. Otherwise, the log is generally mostly free from flags. First echo amplitude (AWBK) The first echo amplitude image map is normal. It shows high amplitude (yellow) color when the tool is well centered, suggesting a clean internal surface. When eccentering increases, this becomes progressively darker as expected. Figure 8 below shows a snapshot of a LQC example for the USIT log under 300 psi where echo amplitude image is clean. Radius and thickness measured data is close to respective nominal values. Schlumberger 15 26 October 2017 Cement Evaluation Hilcorp Alaska, LLC. MPC-45 7. Appendix Acoustic Impedance Measurement The USIT sub contains the transducer that acts as both a transmitter and receiver. Short pulse of high frequency acoustic energy is emitted with multiple echoes received from the casing, cement and formation interfaces. The casing will resonant within its thickness mode creating multiple reflections. These multiple reflections lose energy back in to the mud or cement and the decay of this signal is a function of the acoustic impedance of the material at the casing external interface. We also refer to that as the 2nd interface, the 3rd interface being the formation wall or 2nd casing string in multiple casing strings. The acoustic impedance (z) is measured in MRayls. The acoustic impedance of fresh water is 1.5 MRayls. The acoustic impedance of cement can vary from 2.0 MRayls for <11.5 ppg LiteCrete and as high as 8.5 MRayls for a > 16.0 ppg DensCrete. The USI uses a threshold for the cement map to differentiate cement from liquid. The threshold is set 0.5 MRayls above the expected acoustic impedance of the fluid (mud) behind the casi ng. The AI cement map is a 360 degree representation of the azimuthal AI values measured. Any AI (acoustic impedance) above the cement threshold will be a shade of brown and increasingly darker as the AI increases.
