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Home My WebLink About215-1531. 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): 13,940 NA Casing Collapse Conductor NA Surface 3,090psi Tieback 4,790psi Production Liner 8,540psi 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 NA 8,439 4-1/2" See Schematic Wells Manager March 1, 2024 13,9405,485 4-1/2" 3,549 Perforation Depth MD (ft): See Schematic 7-5/8" x 4-1/2" Tri Point Packer, BOT SLZXP Liner Top Packer, and NA 110 7-5/8"8,439 8,620 907-301-1240 ryan.thompson@hilcorp.com 7,479' MD (3,509' TVD), 8,431' MD (3,670' TVD) and NA 3,689 3,670 110 8,620 20" 9-5/8" 12.6# / L-80 TVD Burst 8,437 MD 6,890psi NA 5,750psi 110 Hilcorp Alaska, LLC Length Size Proposed Pools: 3,549 13,935 3,549 596 SCHRADER BLUFF OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517, ADL0025906 215-153 C.O. 477.05 MILNE PT UNIT J-27 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23557-00-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 9,020psi 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 10:37 am, Feb 16, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.15 21:48:48 - 09'00' Taylor Wellman (2143) 324-091 10-404 DSR-2/16/24SFD 2/23/2024MGR08MAR24*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.11 17:42:22 -08'00'03/11/24 RBDMS JSB 031324 Wellhead Retrofit Well: MPU J-27 Well Name:MPU J-27 API Number:50-029-23557-00-00 Current Status:Operable – RC JP Pad:J-Pad Estimated Start Date:3/1/2024 Rig:WSS Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:215-153 First Call Engineer:Ryan Thompson (907) 564-5005 (O) (907) 301-1240 (M) Second Call Engineer:Brian Glasheen (907) 564-5277 (O) (907) 545-1144 (M) AFE Number:Job Type:Wellhead Repair Current Bottom Hole Pressure: 947 psi @ 3,515’ TVD SBHPS 6-5-21, 5.2 PPGE Maximum Expected BHP: 947 psi @ 3,515’ TVD SBHPS 6-5-21, 5.2 PPGE MPSP: 596 psi (0.1 psi/ft gas gradient) Min ID: 3.725” @ XN nipple Max Dev: 94° @ 12,800’ MD Brief Well Summary: The Milne Point J-27 was drilled and cased as a Schrader Bluff production well in May 2016 & a RWO performed in Aug 2022 to convert from an ESP 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-IA passed to 3,500 psi on 8/19/2022. x MIT-T passed to 3,000 psi on 8/19/2022. x Well is currently online and producing. x XN nipple @ 7,545’ is @ ~72°. 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 12A jet pump from 7,344 MD. 3. Set plug in XN nipple @ 7,545’ MD. 4. Circulate PF into IA/T to fluid pack. 5. Pump 104 bbls Freeze Protect into IA & U-Tube to tubing. 6. CMIT-TxI to 1500 psi. 7. MIT-OA to 1500 psi. 8. RDMO Wellhead Retrofit Well: MPU J-27 Prep Work 9. Disconnect flowline and instrumentation. 10. Verify tubing and IA pressures have been bled to 0 psi. 11. 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. 12. Vac out gravel from well cellar down to cellar liner to remove residual hydrocarbons. 13. 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. 14. 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. 15. 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. 16. Move in and rig up Well Support Structure. Place rig mats as needed to level out support structure legs. 17. Install BPV and nipple down tree at master valve or tubing head adapter as needed to makeup Wellhead Support Structure adapter flange. 18. Prepare to transfer load to the Well Support Structure. Pretension load cells according to operating manual. 19. 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. 20. Increase weight up to 60,000 lbs (50 K preloading) 21. 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, 4 ½” tubing, 7 5/8” tieback and wellhead load = 12.6#*8437’ + 29.7#*8439’ + 8K = 364K b. Maintain constant vertical displacement while well support structure is loaded by well. 22. 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. 23. Leave remaining bell nipple section engaged in starting head. Bevel as needed to ensure smooth entry of slip assembly. 24. Place each half of Reverse Slip Loc assembly around surface casing, bolt halves together. 25. Install energizing plate halves at 90 degree offset from slip assembly such that joint between halves are perpendicular to slips. 26. Lift Reverse Slip Loc up inside conductor starting head. 27. 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. 28. Mark casing at the bottom of the Reverse Slip Loc 29. Release tension, observe for any slippage. If slipping occurs, retension and tighten bolts to 150 ft-lbs. 30. Once load is released to Reverse Slip Loc, conduct MIT-OA to 1,500 psi to confirm integrity is unchanged. 31. Unbolt and remove the adapter flange. 32. Reinstall 5K production tree. Wellhead Retrofit Well: MPU J-27 33. Remove BPV and install TWC. Pressure test tree to 5,000 psi. 34. Re-install flowline and instrumentation. 35. Weld centralizer/landing ring onto top of conductor. 36. Reinstall well house and backfill gravel over cellar liner. 37. Install Corrosion Inhibitor in SC by Conductor Annulus up to the conductor top. Slickline 38. MIRU SL unit. 39. RIH and pull plug from 7,545’ MD. 40. Set new JP (sizing per OE). 41. Turn well back over to operations. Attachments: 1. Wellbore Schematic Wellhead Retrofit Well: MPU J-27 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220930 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU I-17 500292321200 204098 3-Aug-22 READ CaliperSurvey MPU B-24 500292264200 196009 7/19/2022 READ CaliperSurvey MPU F-38 500292261400 195168 9/19/2022 READ CaliperSurvey MPU F-73A 500292274401 200198 7/31/2022 READ CaliperSurvey MPU I-01 500292206500 190090 8/31/2022 READ CaliperSurvey MPU I-30 500292371000 222023 7/12/2022 READ Inj_Profile MPU J-27 500292355700 215153 8/11/2022 READ CaliperSurvey MPU L-47 500292355000 215117 7/23/2022 READ CaliperSurvey Please include current contact information if different from above. T37121 T37122 T37123 T37124 T37125 T37126 T37127 T37128 MPU J-27 500292355700 215153 8/11/2022 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 13:20:28 -08'00' By Samantha Carlisle at 8:00 am, Sep 07, 2022 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW0RQGD\$XJXVW$0 7R$ODVND16$65:HOO6LWH0DQDJHUV &F5HJJ-DPHV%2*& 6XEMHFW5(>(;7(51$/@5($65WHVWUHSRUWUHVXEPLW $WWDFKPHQWV+LOFRUS$655HYLVHG[OV[ )ROORZ8S)ODJ)ROORZXS )ODJ6WDWXV&RPSOHWHG dŚĂŶŬǇŽƵ͘ƚƚĂĐŚĞĚŝƐƚŚĞƌĞǀŝƐĞĚƌĞƉŽƌƚĨŽƌ,ŝůĐŽƌƉ^ZϭϬϴͲϭϰͲϮϮĂĚĚŝŶŐƚŚĞϮϱϬ;ϮϱϬͬϮϱϬϬͿƚŽƚŚĞƚĞƐƚƉƌĞƐƐƵƌĞ͕ϭ KW͞&W͟DŝƐĐ͘ďĂƐĞĚŽŶƚŚĞƌĞŵĂƌŬƐ͕ĂŶĚ͞Ϭ͟ƚŽƚŚĞďůĂŶŬŽŶƚƌŽů͕^ǇƐƚĞŵZĞƐƉŽŶƐĞƚŝŵĞƐ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂǇ͕ƵŐƵƐƚϮϭ͕ϮϬϮϮϮ͗ϱϵD dŽ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх͖ŚĂƌůĞƐ,ƵŶƚŝŶŐƚŽŶͲ;Ϳ фŚĂƌůĞƐ͘,ƵŶƚŝŶŐƚŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх͖ĂƌŽŶ,ĂďĞƌƚŚƵƌͲ;ͿфĂƌŽŶ͘,ĂďĞƌƚŚƵƌΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁Z͗^ZƚĞƐƚƌĞƉŽƌƚƌĞƐƵďŵŝƚ /ĂŵũƵƐƚƐĞĞŝŶŐƚŚŝƐĨŽƌƚŚĞĨŝƌƐƚƚŝŵĞ͕ŶŽǁŵĂ͛Ăŵ͘tŚŝĐŚƚĞƐƚĂƌĞǁĞƌĞĨĞƌƌŝŶŐƚŽŽŝŶƚŚŝƐĞŵĂŝů͍/ĚŽŶ͛ƚďĞůŝĞǀĞŵĞŽƌ ^ĐŽŽƚǁĞƌĞŚĞƌĞďƵƚ/͛ůůĚĞĨŝŶŝƚĞůǇƚƌĂĐŬŝƚĚŽǁŶ͘>ŽŽŬŝŶŐďĂĐŬĂƚƚŚĞůĂƐƚƚǁŽǁĞůůƐ͕ůŽǁƚĞƐƚƉƌĞƐƐƵƌĞƐǁĞƌĞ;ϮϱϬƉƐŝͿŽŶ DWh:ͲϮϳΘWhϬϱͲϮϲ͘,ŽƉĞŽŶĞŽĨƚŚŽƐĞĂƌĞƚŚĞĐƵůƉƌŝƚƐ͘ dŚĂŶŬƐ͕ƐŽƌƌǇĨŽƌƚŚĞĐŽŶĨƵƐŝŽŶ͘ Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com ƌĞǀŝƐĞĚƌĞƉŽƌƚĨ ϮϱϬ;ϮϱϬͬϮϱϬϬͿƚŽƚŚĞƚĞƐƚƉƌĞƐƐƵƌĞ͕ KW͞&W͟DŝƐĐ͘͞Ϭ͟ƚŽƚŚĞďůĂŶŬŽŶƚƌŽů͕^ǇƐƚĞŵZĞƐƉŽŶƐĞƚŝŵĞƐ͘ &ƌŽŵ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗&ƌŝĚĂǇ͕ƵŐƵƐƚϭϵ͕ϮϬϮϮϯ͗ϰϵWD dŽ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗^ZƚĞƐƚƌĞƉŽƌƚƌĞƐƵďŵŝƚ tĂƐƚŚĞůŽǁƚĞƐƚƉƌĞƐƐƵƌĞϮϱϬ͍ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂǇ͕ƵŐƵƐƚϭϱ͕ϮϬϮϮϰ͗ϱϴD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗^ZƚĞƐƚƌĞƉŽƌƚƌĞƐƵďŵŝƚ tĞĨŽƌŐŽƚƚŽĂĚĚƚŚĞŶƵŵďĞƌEϮďŽƚƚůĞƐĂŶĚƚŚĞŶƵŵďĞƌŽĨĨĂŝůƵƌĞƐ͘dŚŝƐƚĞƐƚĨŽƌŵƐŚŽƵůĚďĞŝŶŽƌĚĞƌ͘^ŽƌƌǇĨŽƌƚŚĞ ŵŝƐƚĂŬĞ͘ dŚĂŶŬǇŽƵ ^Z^D͛Ɛ ,ŝůĐŽƌƉ^D͗ϵϬϳͲϲϴϱͲϭϮϲϲ ,ŝůĐŽƌƉůĂƐŬĂ͕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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 8/14/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2151530 Sundry #322-446 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:698 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2-7/8" X 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/6"P Time/Pressure Test Result HCR Valves 1 2-1/6"P System Pressure (psi)3050 P Kill Line Valves 2 2-1/6"P Pressure After Closure (psi)1850 P Check Valve 0NA200 psi Attained (sec)15 P BOP Misc 1 ring gasket FP Full Pressure Attained (sec)53 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 X 2237 P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 26 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:7.0 Hours HCR Choke 2 P Repair or replacement of equipment will be made within 0 days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/13/2022 06:00 Waived By Test Start Date/Time:8/14/2022 11:30 (date) (time)Witness Test Finish Date/Time:8/14/2022 18:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Hilcorp Tested with both 2-7/8" and 4-1/2" test joints. Fail / Pass on test number 2. Grey Lock Ring gasket failed. Changed out Ring gasket and retested good. C. Pace / C. Greub Hilcorp Alaska A. Haberthur / C. Huntington MPU J-27 Test Pressure (psi): NS-ASR-Well Site Managers@hilc AlaskaNS-ASR-Well Site Managers@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0814_BOP_Hilcorp_ASR1_MPU_J-27 9 9 9 9999 9 9 9 9 9 9 9 - 5HJJ 9 FP Fail / Pass on test number 2. 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tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ W& ϮϬΗ ŽŶĚƵĐƚŽƌ ϳϴ͘ϲͬͲϱϯͬtĞůĚ Eͬ ^ƵƌĨĂĐĞ ϭϭϬ͛ Eͬ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd// ϴ͘ϱϮϱ ^ƵƌĨĂĐĞ ϴ͕ϲϮϬ͛ Ϭ͘Ϭϳϱϴ ϳͲϱͬϴ͟ dŝĞďĂĐŬ Ϯϵ͘ϳͬ>ͲϴϬͬsĂŵ^d> ϲ͘ϳϱϬ ^ƵƌĨĂĐĞ ϴ͕ϰϯϵ͛ Ϭ͘Ϭϰϱϵ ϰͲϭͬϮ͟ >ŝŶĞƌ ϭϯ͘ϱͬ>ͲϴϬͬ,dd ϯ͘ϳϵϱ ϴ͕ϰϱϱ͛ ϭϯ͕ϵϰϬ͛ Ϭ͘Ϭϭϰϵ dh/E'd/> ϮͲϳͬϴΗ dƵďŝŶŐ ϲ͘ϱͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϰϰϭ ^ƵƌĨĂĐĞ ϳ͕ϱϴϵ͛ Ϭ͘ϬϬϱϴ ϯͬϴ͟ ĂƉƐƚƌŝŶŐ ^ƚĂŝŶůĞƐƐ^ƚĞĞů Eͬ ^ƵƌĨĂĐĞ ϳ͕ϱϴϵ͛ Eͬ KWE,K>ͬDEdd/> ϮϬΗ ŽŶĚƵĐƚŽƌ ϭϮͲϭͬϰΗ^ ŵƚǁͬϯϴϬƐǆW&ϭϬ͘ϳƉƉŐ͕ϮϳϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ͖ŵƚƚŽ^ƵƌĨĂĐĞ;ϮϱϬďďůͿ ϭϮͲϭͬϰ͟^ŚŽĞ ŵƚǁͬϵϭϱƐǆϭϭ͘ϳƉƉŐ͕ϯϵϬƐǆůĂƐƐ͞'͟ŝŶϭϮͲϭͬϰ͟,ŽůĞ ϴͲϭͬϮ͟ hŶĐĞŵĞŶƚĞĚ^ĂŶĚ^ĐƌĞĞŶ>ŝŶĞƌŝŶϴͲϭͬϮ͟ŚŽůĞ t>>/E>/Ed/KEd/> <KWΛϯϱϲ͛ ϳϭ͘ϭĚĞŐ͘ΛϮ͕ϲϳϴ͛D DĂǆ,ŽůĞŶŐůĞсϵϰ͘ϱĚĞŐ͘ΛϭϮ͕ϴϯϵ͛D dZΘt>>, dƌĞĞ ^ĞĂďŽĂƌĚϯϭͬϴΗϱD tĞůůŚĞĂĚ ^ĞĂďŽĂƌĚϭϲϯͬϰΗϯDǆϭϭΗϱDDƵůƚŝďŽǁůǁͬϭϭΗǆϯϭͬϮΗhdŽƉĂŶĚ ŽƚƚŽŵǁŝƚŚϯΗ/tΗ,ΗWsƉƌŽĨŝůĞ͘ϮĞĂϯͬϴΗEWdĐŽŶƚƌŽůůŝŶĞƐ͘ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϱϱϳͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇŽǇŽŶϭϰͲϱͬϮϯͬϮϬϭϲ ^W^ǁĂƉďǇZϮʹϲͬϭϵͬϮϬϮϭ :t>Zzd/> EŽ͘ ĞƉƚŚ /ƚĞŵ / hƉƉĞƌŽŵƉůĞƚŝŽŶ ϭ Ϯϱ͛ dƵďŝŶŐ,ĂŶŐĞƌ Ϯ͘ϰϰϭ͟ ϮϮϬϬ͛^dϮ͗'>DǁͬŽƌŝĨŝĐĞǀĂůǀĞ Ϯ͘ϰϰϭ͟ ϯϳ͕ϰϭϭ͛^dϭ͗'>DǁͬĚƵŵŵǇǀĂůǀĞ Ϯ͘ϰϰϭ͟ ϰ ϳ͕ϰϲϭ͛ 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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: ESP Swap 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 13,940 feet N/A feet true vertical 3,549 feet N/A feet Effective Depth measured 13,935 feet 8,431 feet true vertical 3,549 feet 3,670 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 7,589' 3,544' BOT SLZXP Packers and SSSV (type, measured and true vertical depth)Liner Top Packer N/A 8431 3670 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: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 84 Water-Bbl MD 110' 8,620' 8,439' TVD 110' 158 Oil-Bbl measured true vertical Packer 13,940' 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.28 807 380 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 842 Representative Daily Average Production or Injection Data 36091 Hilcorp Alaska LLC MILNE PT UNIT J-27 Gas-Mcf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-153 50-029-23557-00-00 Plugs ADL0025517 / ADL0025906 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-264 398 Authorized Signature with date: Authorized Name: David Haakinson dhaakinson@hilcorp.com Casing Pressure Tubing Pressure 112 Junk Liner Casing Conductor Size 200 Surface Tieback N/A measured 5,485' N/A measured 3,670' 3,549' Length 110' 8,439' Burst N/A 5,750psi 6,890psi 8,620' 9,020psi 20" 9-5/8" 7-5/8" 4-1/2" 3,689' 777-8343 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 4,790psi 8,540psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 3:09 pm, Jul 19, 2021 Chad Helgeson (1517) 2021.07.19 14:58:19 - 08'00' SFD 7/20/2021 RBDMS HEW 7/20/2021 DSR-7/19/21MGR30JUL2021 Well Name Rig API Number Well Permit Number Start Date End Date MP J-27 Slickline 50-029-23557-00-00 215-153 6/4/2021 6/19/2021 CDR2 rig released from MPL-06 at 06:00. Continue RDMO checklists, prep to pull off well. Move the pit module and the drilling module off MPL-06. Move rig to MPJ pad. Arrive MP J pad. Park on edge of pad and lower 7-1/16" stack down. Start assembling flow box and 13-5/8" 5k stack. Continue assembling 13-5/8" BOP stack. Install blind rams and 2-7/8" pipe rams. Install choke and kill line valves. Install flow cross. WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/2500H. RAN DUAL SPARTEK GAUGES DOWN TO 7,501 SLM (7,500' MD) & MADE 3 STOPS AS PER ENGINEER (good data). RAN HES MAXFIRE HOLE PUNCH (21 .61" holes) DOWN TO 7,481' SLM (7,480' MD), GOOD INDICATION OF PUNCH FIRING, TOP HOLE @ 7,481' SLM (7,480' MD) BOTTOM HOLE @ 7,486' SLM (7,485' MD). WELL S/I ON DEPARTURE, DSO NOTIFIED. (top gauge sn: 75862, bottom sn: 76647, programed for 10sec samples, 2 days, stops made using +1' corr from esp, battery start: 6:49) 6/5/2021 - Saturday Well Support Techs R/D well kill, set BPV, nipple down production tree and installed dry hole tree. Prep for CDR2. 6/12/2021 - Saturday 6/6/2021 - Sunday Well Support Techs set BPV. Removed production tree and installed a dry hole tree. Pre for CDR 2. BPV was left in hole. No issues. 6/10/2021 - Thursday 6/4/2021 - Friday WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/2500H. LRS PUMPED 45bbls 100deg DIESEL DOWN TUBING TO DISPLACE. RAN 5'x2" DRIVE DOWN BAILER W/ MULE SHOE FLAPPER & TAGGED ESP @ 7,510' SLM (7,509' MD), BAILER EMPTY. RAN HES 24 ARM CALIPLER TO TD @ 7,510' SLM (7,509' MD) & LOGGED TO SURFACE AS PER PROGRAM (good data). PULLED 1" BK-OGLV FROM ST# 2 @ 180' SLM (205' MD), ALL PACKING RECOVERED. SET 1" BK-DGLV IN ST# 2 @ 180' SLM (205' MD), GOOD PULL TEST, SHEARED OFF CLEAN. WELL S/I ON DEPARTURE, DSO NOTIFIED. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J-27 Slickline 50-029-23557-00-00 215-153 6/4/2021 6/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary 6/13/2021 - Sunday Finish NU of 13-5/8" Stack. Secure stack in the cellar. IAP = 220psi, OAP = 0psi, shut in all casing & Tree Valves to back over well. Spot Main Sub over well and lay rig mats. Spot Pit Sub and lay rig mats. Rig spotted, start MIRU Op. Take on fluids, RU Reverse out skid and Tiger Tank, Call out WH Crew to pull BPV, PT surface lines, Accept rig 11:30. RU BPV Lubricator and pull BPV. BPV pulled, WHP = 300psi. Line up tubing to TT and bleed off gas. Line up IA to TT and bleed off gas. Both tubing and IA bled off fairly quick. Line up to pump down the tubing taking returns from the IA, monitor IA for any returns, Online at 3.0 bpm 88psi. 65 bbls pumped down the tubing with no returns from IA. Line up down the IA and BHK well. 290 bbls of 2% KCl with DeepKleen, 270 bbls of 2% KCl. Shut down pump at 1 bbl away 800psi, IA might be froze up. Bring pump online up to max IAP at 1500psi, 1 bbl away, 1550psi, shut down call DE and discuss. Line up was incorrect, tied into the IA & OA, re-rig lines and PT. Re-rig lines in cellar and reverse out trailer. PJSM then PT lines to 3200 psi, good. Open IA to closed choke, about 40 psi. Line up to pump down the tubing taking returns from IA. Pump 4 bpm / 400 psi down the tubing get about 20 psi gas from IA.,After 40 bbls down tbg IA returns go to 0. Shut in IA. Finish pumping 65 bbls 2% KCl down tbg. Shut down pump pressure goes to 0. Line up to pump down IA, shut in tbg. Pump 290 bbls 140 deg 2% KCl + DeepClean + Kla-Stop down IA. Set pump trips at 800 psi, pump 5.7 bpm / 300 psi. Pump another 270 bbls of 2% KCl with Kla-Stop down the IA, tbg shut in. Pump 5.7 bpm / 280 psi. Shut down pump briefly at 70 bbls away, pressure goes to 0. Shut down at 270 bbl, pressure goes to 0. IA and tubing on vac. Dry rod in BPV. Hanger void on vac also. Unflange tree and lift it off, set aside in cellar. Install CTS plug in BPV, test to 5k from above, good. Inspect landing jt threads, good. Pump 15-20 bbls/hr into well. Install BOPs onto wellhead and tighten flange nuts. Install BOP test valves. Install choke and kill lines. 6/14/2021 - Monday Continue monitoring IA and hole fill while installing Choke & K ill Lines. Connect Koomey Lines. Get RKB's. Repair fitting on Air Boot. Repair fitting leak on Blind Rams. PJSM to Function Test BOPE, Fluid Pack Stack and shell test,Test Gas alarms, fluid pack stack & surface lines. 15:10 Test BOPE as per AOGCC & Hilcorp requirements 250psi Low and 2500psi High. Test #1 - Kill line Flange leak, R1 leaking, grease and retest - Fail / Pass,Continue BOP test. Continue pump 10 bbls / 30 min into well. Valve C2 is Fail / Pass after greasing. All valves and rams tested 250 / 2500 psi. L/D test joint and break off TIW. End of BOP test 21:00. Pre-spud meeting with Drilling Engineer David Gorm and rig crews. Prep to pull hanger to floor. Pull CTS plug leave BPV for now. Tubing is on a strong vac. Load capillary spooling equipment, thread protectors to rig floor. Rig up 2-7/8" elevators. Install bushings and drilling riser. Rig down reverse trailer and hoses. Rig up normal line to tiger tank. Spot crane. Lift capillary spooler to rig floor. Use tugger to position it. Lift ESP sheave to rig floor. Run ropes through both sides then lift it back to ground. Hook up containment trunk to sheave. Rig up and function test capillary spooler. PT line to tiger tank, good. Wait on 2-7/8" slips from Deadhorse. Well Name Rig API Number Well Permit Number Start Date End Date MP J-27 Slickline 50-029-23557-00-00 215-153 6/4/2021 6/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary 6/18/2021 - Friday Continue break down 13-5/8" BOP stack. Prep for storage remove rams, remove HCRs. Unflange annular and blinds. Remove hydraulic hoses and plug. Grease ring grooves, grease bolts. Clean and grease rams. Wrap up Koomey lines and hang. Remove flow box. Load BOPs on truck. Jack up rig and install jeeps for transport. Move both rig modules from J to L pad. Spot both modules together. Move the shop over. Prep for stack out. Cover injector motors. Break stand pipe connection. Grease base leg pins. Purge all steam lines. Drain and purge all centrifugal pumps. Wrap centrifugal motors and control boxes. Lube up cables and winch lines. Cover control boxes and computer screens. Continue stackout checklist. Drain glycol from #3 generator. Strip shaker bed. Continue covering motors and stacks. WO Hand Slips from Deadhorse. Hold a PJSM with all crew members & Vendors to pull completion. Pull BPV (CTS was already pulled), WH hand can feel gas bubbling through the BPV, remove dry rod. Close Blinds and BHK the tubing, then displace the IA from the perforated joint to the bottom of the build. Shut down pump, 0psi on tubing & IA, both are on a vac. Pull BPV. MU landing joint (9 turns), BOLDS, PU on landing joint, 60k to unseat hanger. Hanger at surface. Cut cables and Capillary Line, LD hanger. Pull first joint to connect snakes to ESP Cable and Heat Trace. Connect Capillary Line to spooler on rig floor. Pull pipe filling hole every 30 min with 10 bbls of 2% KCl. Pull first 85 jts to 2nd GLM. PJSM with night crew then continue pulling ESP completion. Continue 10 bbls 2% KCl / 30 min into well. Around 107 jts left the ESP cable gets wadded up a bit below the bushings, stop and pull it through by hand. Increase spooler tension. Continue L/D ESP completion. 00:00 depth is 1822'. Continue pulling ESP completion from 1822'. Bring perforated joint, X-nipple and 10' pup to floor. Break off X-nipple and 10' pup. Disassemble old ESP pump and put in pipe shed. 6/16/2021 - Wednesday Prep rig floor to rerun the completion. Swap ESP Spools on spooler. Load new ESP. Hold a PJSM to run completion. Run completion as per approved summary. MU ESP as per plan, fill motor with oil, ESP MU, test Cap Line & ESP Cable. Test Cap Line (1800psi) & ESP Cable (2500v & Meg test), then test at 1000', 2000' then every 2000' to surface. RIH with 2-7/8" ESP completion installing Cannon Claps at every collar. Fill pipe every 5 joints. On jt #61 clamp snagged in the Air slips, stop to inspect cable and test it. Test good. RIH to 2175'. PJSM with night crew then continue M/U ESP completion. Test ESP cable and PT capillary line at 3000', good. Put 1 cross-collar clamp every joint. RIH from 2175' to 4513''. Continue RIH with ESP completion from 4513' to 5390'. Put 1 cross-collar clamp every joint. Test ESP cable and PT capillary line at 5000', both good. Spooling unit generator overheats and quits. Add coolant and re-start. Continue RIH with ESP completion from 5390'. Put 1 cross-collar clamp every joint. RIH to 6624'. 6/17/2021 - Thursday Continue running completion. 7000', test ESP Cable and Capillary Line. All 2-7/8" pipe ran, test ESP Cable and Capillary Line. MU Hanger and terminate ESP Cable & Capillary Line, Land Hanger, RILDS, Back out landing joint & LD. Up WT 58k, SO WT 35k. Set BPV with CTS Plug. Clear rig floor of all completion equipment and excess heat trace clamps. Load 100 bbls of Corrosion Inhibited Water in the pits. Circulate low and high pressure piping , flush with fresh water then blow down. Clean & wash down rig floor. Pull riser from stack. Prep to ND BOPE. Remove choke, Kill & MP Lines, Remove BOP stack. Install tree. Baker tests ESP cable final time, good. Test hanger void to 5k, good. Test tree to 4500 psi, good. Pull CTS plug, leave BPV in hanger. Close all tree valves and PT tree cap 4k, good. PJSM with NES and Nabors crews. Pull pit module off well and spot it at edge of pad. Pull drill module off well and spot it at edge of pad. Break down 13-5/8" BOP stack. 6/15/2021 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP J-27 Slickline 50-029-23557-00-00 215-153 6/4/2021 6/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary 6/19/2021 - Saturday Lay mast over and close windwalls. Cover injector and top drive with tarps. Open and drain / purge all centrifugal pumps. Load storage totes onto rig for small items. Continue wrapping all electric motors. Continue greasing all pins and bearings. Grease crown sheaves. Start removing batteries for warm storage. Place desiccant material in HCR rooms. Empty remaining water from boilers and hotwell tank. Purge all steam lines with air, empty rig water tank and remove plug to verify. Vac remaining fluid out of pits. Release rig at 18:00 on 6/19. No further entries for CDR2. _____________________________________________________________________________________ Revised By: DH 7/12/2021 SCHEMATIC Milne Point Unit Well: MPU J-27 Last Completed: 6/17/2021 PTD: 215-153 TD =13,940’ (MD) /TD =3,549’(TVD) 20” 7-5/8” 4 9-5/8” 1 2 3 PBTD =13,935’ (MD) / PBTD =3,549’(TVD) 9-5/8” ‘ES’ Cementer @ 2,862’ 5 4-1/2” Shoe @ 13,940’ 12 11 13 18 19 6 7 8 10 9 14 17 Orig. KB Elev.: 68.7’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 29.72’ (Doyon 14) 15 16 3/8” capillary 7,589’ CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 110’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.525 Surface 8,620’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL 6.750 Surface 8,439’ 0.0459 4-1/2” Liner 13.5 / L-80 / HTTC 3.795 8,455’ 13,940’ 0.0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,589’ 0.0058 3/8” Capstring Stainless Steel N/A Surface 7,589’ N/A OPEN HOLE / CEMENT DETAIL 20" Conductor 12-1/4" ES Cmt w/ 380 sx PF 10.7 ppg, 270 sx Class “G” in 12-1/4” Hole; Cmt to Surface (250 bbl) 12-1/4” Shoe Cmt w/ 915 sx 11.7 ppg, 390 sx Class “G” in 12-1/4” Hole 8-1/2” Uncemented Sand Screen Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 356’ 71.1 deg. @ 2,678’ MD Max Hole Angle = 94.5 deg. @ 12,839’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23557-00-00 Drilled and Cased by Doyon 14 - 5/23/2016 ESP Swap by CDR2 – 6/19/2021 JEWELRY DETAIL No. Depth Item ID Upper Completion 1 25’ Tubing Hanger 2.441” 2200’ST 2: GLM w/orifice valve 2.441” 37,411’ST 1: GLM w/dummy valve 2.441” 4 7,461’ 2-7/8” X Profile 2.313” (2.205” No-Go Packing Bore ID) 2.205” 5 7,503’ Discharge Head: DSCHG B/O PMP 513 2.87X8 - 6 7,504’ Pump: PMP 538PMSXD Flex 27 135 FER - 7 7,532’ Gas Separator: GASSEP 538GSTHEVX MT - 8 7,548’ Tandem Seal Section: GSBDB H6 SB/AB PFSA - 9 7,584’ Motor: MTR 562XP 350/2440/88_292/2030 - 10 7,587’ Sensor w/ 6 fin Centralizer – Btm @ 7,589’ - Lower Completion 11 8,429’ 7-5/8” Tieback Assy. (No-Go @ 8,439’) 6.151” 12 8,431’ BOT SLZXP Liner Top Packer w/BD Slips 9-5/8” x 7” 6.200” 13 8,452’ 7” H563 x 4.5” HTTC L-80 XO 3.900” 14 8,624’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 8,796’ 4.000” 15 8,920’4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 11,231’4.000” 16 11,354’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 12,252’ 4.000” 17 12,662’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 13,901’ 4.000” 18 13,902’ 4-1/2” Drillable Packoff Sub 2.400” 19 13,935’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) & Shoe – Btm @ 13,940’ - David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type MPU B-13 500292134800 185-093 6/25/21 IPROF MPU E-12 500292326200 205-067 6/21/21 IPROF MPU J-27 500292355700 215-153 6/4/21 Multi Finger Caliper MPU K-06 500292272500 196-191 3/14/21 Leak Detect Log MPU L-29 500292254300 195-009 6/23/21 Multi Finger Caliper Please include current contact information if different from above. Received By: 07/14/2021 37' (6HW By Abby Bell at 2:44 pm, Jul 14, 2021 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: ESP Swap 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,940'N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Liner 8,540psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 3,549'13,935' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 / ADL0025906 215-153 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23557-00-00 Hilcorp Alaska LLC MILNE PT UNIT J-27 3,549'699 N/A MILNE POINT / SCHRADER BLUFF OIL 110'110' TVD Burst 7,954' MD N/A 9,020psi 5,750psi 6,890psi 3,689' Tubing Grade: 8,620' 8,439' See Schematic 110'20" 9-5/8" 7-5/8" 8,620' Authorized Signature: 6/5/2021 2-7/8" Perforation Depth MD (ft): See Schematic 3,670' 3,549' 6.5# / L-80 / EUE 8rd David Haakinson C.O. 477.05 BOT SLZXP LTPand N/A 8,431 MD / 3,670 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 13,940'4-1/2"5,485' 8,439' ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:00 am, Jun 01, 2021 321-264 Chad Helgeson (1517) 2021.05.28 12:49:18 - 08'00' DSR-6/1/21DLB 06/01/2021 X 10-404 MGR04JUN21 BOPE test to 2500 psi. Annular to 2500 psil dts 6/4/2021 JLC 6/4/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.04 15:13:18 -08'00' RBDMS HEW 6/4/2021 ESP Changeout Well: MPU J-27 Date: 5-28-2021 Well Name:MPU J-27 API Number:50-029-23557-00-00 Current Status:Shut-in [Failed ESP]Pad:J-Pad Estimated Start Date:June 5th, 2020 Rig:Innovation Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:215-153 First Call Engineer:David Haakinson (307) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number:Job Type:ESP Changeout Current Bottom Hole Pressure:880 psi @ 3,512’ TVD BHP Gauge 5/28/21 |4.8 ppg Maximum Expected BHP:1,050 psi @ 3,512’ TVD 30 day PBU Extrapolation |5.8 ppg MPSP:699 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 73.3° @ 3,434 MD Note Long 70°+ Sail Max Dogleg:6°/100ft @ 1,928’ MD BPV Profile:2-1/2” CIW Type H Brief Well Summary: MPU J-27 was drilled and completed in the Schrader Bluff N-sands in 2016. The well was completed as a single lateral with 250-micron screens and an ESP artificial lift completion. The was a stable producer and experienced a five-year run life. The ESP failed on 5/24/21 following a power failure within the Milne Point Field. The well will be recompleted as an ESP with a larger motor to reach the full drawdown potential of the well. A jet pump completion was considered but was not chosen due to water handling restrictions at CFP and on the 6” WI line to MPU J-Pad. Notes Regarding Wellbore Condition x The 7-5/8” x 9-5/8” casing annulus (production casing test) was successfully pressure tested to 1,000 psi on 5/20/16. x The 9-5/8” casing was successfully pressure tested to 3,000 psi on 5/11/16. x Note that the well was not completed with a lower circulation point. Due to the low reservoir pressure, a bull-head kill should work for MPU J-27. x Offset injectors with status as of 5/28/21.Wells should be shut in prior to RWO. o J-23A: Online, injecting 1500 bwpd o J-24A: Online, injecting 500 bwpd. Objective: x Pull 2-7/8” tubing string and Baker Hughes ESP x Install new ESP completion with existing 2-7/8” tubing. Pre-Rig Procedure: 1. RU LRS. 2. Kill the well with heated 8.3 ppg produced water. a. Bleed off the tubing and IA gas. Bleed to 0 psi if possible. b. Note that heat-trace is clamped to the tubing. Utilizing Baraclean and hot water to clean the tubulars is desired on this well. 3. Pump 65 bbls of produced water down the tubing while leaving IA open to tank. ESP Changeout Well: MPU J-27 Date: 5-28-2021 a. Allow circulation out IA if any at all. If gas is circulating out, increase volume from 65 bbls and document returns. Contact Engineer. b. DNE 1,000 psi. Achieve max rate. 4. Pump 380 bbls of PW down IA to formation. Ensure Tubing is closed. a. DNE 800 psi. Achieve Max Rate. 5. Confirm well is dead. 6. RD LRS. 7. Clear and level pad area in front of well. Spot rig mats and containment. 8. RD well house and flowlines. Clear and level area around well. 9. RU crane. Set 2-1/2” ‘H’ BPV. ND Tree. Inspect the lift threads on the tubing hanger. 10. NU BOPE. RD Crane. RWO Procedure: 11. MIRU Hilcorp Innovation Rig and ancillary equipment. 12. Check for pressure and if 0 psi, pull BPV. 13. Set TWC. 14. Test BOPE to 250/2,500 psi, annular to 250/2,500 psi. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR ram on 2-7/8” test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. RU to pull 2-7/8” ESP completion. Rig up spooler for ESP #2 RD cable and 3/8” capillary string a. Note the large amount of clamps for capillary tubing and heat trace. b. Baker Hughes representative should be onsite for the ESP pull. ESP Changeout Well: MPU J-27 Date: 5-28-2021 16. Pull the TWC. Kill the well with 8.3 ppg produced water as needed. 17. MU landing joint. BOLDS, unseat the tubing hanger and pull to the rig floor. a. SO = 70K and PU = 90K when landed in 9.1 ppg brine by Doyon 14 (block weight = 40K) in 2016 18. Lay down the landing joint and tubing hanger. RU to pull ESP cable and capillary tubing over the sheaves to the spooling unit. a. Inspect the tubing hanger and note any damage. If any damage is found, contact well head specialist for redress or replacement. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 19. POOH and lay down the 2-7/8” tubing. Lay down ESP and motor. a. Engineer may determine to remove specific tubing joints post slickline memory caliper survey. b. Note any corrosion, sand or scale on the tubing with associated depths and ESP components on the morning report. c. Look for over-torqued connections from previous tubing runs. d. If any joint(s) appear suspect of damage to threads or tubing, send to G&I for disposal and replace with new. Equipment Disposition Tubing hanger Visually inspect on site and reuse Tubing & Pup joints Visually inspect on site and reuse ESP equipment/Power Cable Baker Hughes to take possession Capillary Tubing (7,677’)Properly re-wrap and reuse if in good condition. Heat Trace (3445’)Junk. Flat Cannon (8)Visually inspect on site and reuse if in good condition Flat guards (2)Visually inspect on site and reuse if in good condition Protectolizers (5)Visually inspect on site and reuse if in good condition Cannon clamps (67)Visually inspect on site and reuse if in good condition Cross Collar HT Clamps (106)Visually inspect on site and reuse if in good condition Mid-Join HT Clamps (515)Visually inspect on site and send to warehouse for re-inventory SS Bands (5)Junk 20. PU, MU and RIH new ESP on 2-7/8”, 6.5#, L-80, EUE 8rd tubing with new ESP cable. Set base of ESP assembly at ±7,590’ MD. a. Use Brand New #2 Lead Sheathed cable (8,000’ spool). No intra-well splices should be needed between the motor and surface. b. Clamp every joint due to high deviation of well. c. 2-7/8” 6.5# L-80 EUE Tubing Specs: ESP Changeout Well: MPU J-27 Date: 5-28-2021 i. 145K Tensile Strength ii. MU Torque (FT-LBS): 1,690 Min / 2,250 Optimum / 2,810 Max d. Dog leg severity is less than 2°/100ft at 7,590’ MD. 21. Test ESP connectivity every 2,000’. 22. Install Equipment as below. Send tally to engineer prior to Install. a. Motor centralizer b. Motor gauge unit c. ESP motor (300 HP) d. Lower tandem seal e. Upper tandem seal f. Gas Separator Pump g. Pump h. Discharge Head i. 1 Full Joint of tubing j. 2.205” XN Nipple @ ±7,470’ MD k. 2 Full joints of 6.5# EUE8RD L-80 Tubing l. 2-7/8” x 1” GLM @ ±7,410’ MD i. Install Dummy Valve. m. 2-7/8” 6.5# EUE8RD L-80 Tubing n. 2-7/8” x 1” GLM @ 200’ MD. i. Install 3/8” OV. 23. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator and ensure capillary tubing is correctly labelled. a. Install double block and pressure gauge on capillary string to document any pressure on the capillary tubing. 24. Land tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. 25. Set 2.5” ‘H’ BPV. 26. ND BOPE. NU 2-9/16” 5K tree and adaptor flange. a. Contact drill-site operator to inspect directionality of tree and casing valves. 27. Pull BPV. Set TWC. 28. Pressure test the tubing hanger void to 500 psig low and 5,000 psi high. 29. Pressure test the tree to 500 psig Low and 5,000 psig High. 30. Pull TWC. 31. RD Innovation rig and all ancillary equipment. 32. Turn well over to production with the handover form. Attachments: ESP Changeout Well: MPU J-27 Date: 5-28-2021 1. As-built Schematic 2. Proposed Schematic _____________________________________________________________________________________ Revised By: STP 2/02/2017 SCHEMATIC Milne Point Unit Well: MPU J-27 Last Completed: 5/23/2016 PTD: 215-153 TD =13,940’ (MD) /TD =3,549’(TVD) 20” 7-5/8” 5 9-5/8” 1 2 3 PBTD =13,935’ (MD) /PBTD =3,549’(TVD) 9-5/8” ‘ES’ Cementer @ 2,862’ 6 4-1/2” Shoe @ 13,940’ 13 12 14 19 20 2-7/8” 4 7 8 9 10 11 15 18 Orig. KB Elev.: 68.7’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 29.72’ (Doyon 14) 16 17 3/8” capillary 7,594’ CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 110’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.525 Surface 8,620’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL 6.750 Surface 8,439’ 0.0459 4-1/2” Liner 13.5 / L-80 / HTTC 3.795 8,455’ 13,940’ 0.0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,594’ 0.0058 OPEN HOLE / CEMENT DETAIL 20" Conductor 12-1/4" ES Cmt w/ 380 sx PF 10.7 ppg, 270 sx Class “G” in 12-1/4” Hole; Cmt to Surface (250 bbl) 12-1/4” Shoe Cmt w/ 915 sx 11.7 ppg, 390 sx Class “G” in 12-1/4” Hole 8-1/2” Uncemented Sand Screen Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 356’ 71.1 deg. @ 2,678’ MD Max Hole Angle = 94.5 deg. @ 12,839’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23557-00-00 Drilled and Cased by Doyon 14 - 5/23/2016 JEWELRY DETAIL No. Depth Item ID Upper Completion 1 30’ Tubing Hanger 2.441” 2205’ST 2: Patco SPMO-1 GLM BK-2 Latch, 1” OGLV 2.441” 32,866’ST 1: Patco SPMO-1 GLM BK-2 Latch, 1” DGLV 2.441” 4 3,432’ Heat Trace (3,500’ spool) N/A 5 7,498’ 2-7/8” XN Profile (2.205” No-Go Packing Bore ID) 2.205” 6 7,509’ Discharge Head - 7 7,510’ Centrilift ESP: Tandem FLEX17.5 134 Stages - 8 7,557’ Gas Separator - 9 7,560’ Tandem Seal Section - 10 7,574’ Single ESP Motor (210 HP) - 11 7,590’ Phoenix XT150 Sensor w 6 fin Centralizer – Btm @ 7,594’ - Lower Completion 12 8,429’ 7-5/8” Tieback Assy. (No-Go @ 8,439’) 6.151” 13 8,431’ BOT SLZXP Liner Top Packer w/BD Slips 9-5/8” x 7” 6.200” 14 8,452’ 7” H563 x 4.5” HTTC L-80 XO 3.900” 15 8,624’4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 8,796’4.000” 16 8,920’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 11,231’ 4.000” 17 11,354’4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 12,252’4.000” 18 12,662’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 13,901’ 4.000” 19 13,902’ 4-1/2” Drillable Packoff Sub 2.400” 20 13,935’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) & Shoe – Btm @ 13,940’ - _____________________________________________________________________________________ Revised By: TDF 5/27/2021 PROPOSED Milne Point Unit Well: MPU J-27 Last Completed: 5/23/2016 PTD: 215-153 TD =13,940’ (MD) /TD =3,549’(TVD) 20” 7-5/8” 4 9-5/8” 1 2 3 PBTD =13,935’ (MD) / PBTD =3,549’(TVD) 9-5/8” ‘ES’ Cementer @ 2,862’ 5 4-1/2” Shoe @ 13,940’ 12 11 13 18 19 6 7 8 10 9 14 17 Orig. KB Elev.: 68.7’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 29.72’ (Doyon 14) 15 16 3/8” capillary ±7,594’ CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 110’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.525 Surface 8,620’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL 6.750 Surface 8,439’ 0.0459 4-1/2” Liner 13.5 / L-80 / HTTC 3.795 8,455’ 13,940’ 0.0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±7,594’ 0.0058 3/8” Capstring Stainless Steel N/A Surface ±7,594’ N/A OPEN HOLE / CEMENT DETAIL 20" Conductor 12-1/4" ES Cmt w/ 380 sx PF 10.7 ppg, 270 sx Class “G” in 12-1/4” Hole; Cmt to Surface (250 bbl) 12-1/4” Shoe Cmt w/ 915 sx 11.7 ppg, 390 sx Class “G” in 12-1/4” Hole 8-1/2” Uncemented Sand Screen Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 356’ 71.1 deg. @ 2,678’ MD Max Hole Angle = 94.5 deg. @ 12,839’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23557-00-00 Drilled and Cased by Doyon 14 - 5/23/2016 JEWELRY DETAIL No. Depth Item ID Upper Completion 1 ±30’ Tubing Hanger 2.441” 2 ±200’ST 2: GLM 2.441” 3 ±7,410’ST 1: GLM 2.441” 4 ±7,470’ 2-7/8” XN Profile (2.205” No-Go Packing Bore ID) 2.205” 5 ±7,509’ Discharge Head: - 6 ±7,510’ Pump: - 7 ±7,557’ Gas Separator: - 8 ±7,560’ Tandem Seal Section: - 9 ±7,574’ Motor: - 10 ±7,590’ Sensor w/ 6 fin Centralizer – Btm @ ±7,594’ - Lower Completion 11 8,429’ 7-5/8” Tieback Assy. (No-Go @ 8,439’) 6.151” 12 8,431’ BOT SLZXP Liner Top Packer w/BD Slips 9-5/8” x 7” 6.200” 13 8,452’ 7” H563 x 4.5” HTTC L-80 XO 3.900” 14 8,624’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 8,796’ 4.000” 15 8,920’4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 11,231’4.000” 16 11,354’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 12,252’ 4.000” 17 12,662’ 4-1/2” 250P Screen, Baker Excluder 11.6# L-80 DWC/HT – Btm @ 13,901’ 4.000” 18 13,902’ 4-1/2” Drillable Packoff Sub 2.400” 19 13,935’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) & Shoe – Btm @ 13,940’ - ►15-- /63' • Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 S,WS J N 0 7 {}1'8 Phone: 907/777-8547 June 5, 2018 RECEIVED Iil Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission JUN 0 6 202 333 West'7th Avenue, Suite 100 Anchorage, Alaska 99501 AOGCC Re: Conductor Annulus Corrosion Inhibitor Treatments 4/20/18-5/12/18 Dear Mr. Schwartz, Enclosed please find multiple copies of a spreadsheet with a list of wells that were treated with corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease-like" filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, PTD and API numbers, treatment volumes and treatment dates. This treatment campaign represents primarily new Milne Point HAK drill wells along with two Northstar wells which previously had excavations and external surface casing leak repairs. If you have any additional questions,please contact me at 777-8547 or wrivard@hilcorp.com. 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J w 1• o '/►7�1 Lo °w (q 0 E � � (a /r/ o co m> -W V m I, C Ce J WF- NZ l6 "O m O aa.yw m aa N c ; oo I I W Q N N Z Vl p) re cr) N co LL c - co W U a rn N � ♦ J J > co o fl. V = Q d E_1 E m Z 8 - y vi .2 (n re ICC lil o o co J Q c E m O c c U U I; II CL c o in 5 T fi 0 N O cotl E I y V c0 U ... c cqw a0 a) o y cn E N QI 0 o a I"- afi c) N c0 y O 0• N Co � C CO z = Nc • a) E 1.0O E t' Co "_T' p 11I (// uJ• as Cl) • a) c co iii Z a c c p Q J O - ` O N o m a> c •c a Qc a ° m O �1 2 aa) _ d U E c 0 0 0az i RECEIVED Ill STATE OF ALASKA • JUN 21 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WEL❑L CO❑MPLETIO❑N ORrR❑ECOMPL❑ETIONnd ❑REPORT AN[AW C la.Well StatuGas SPLUG Abandoned 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 Number/ Sundry: Hilcorp Alaska,LLC Aband.: 5/23/2016 215-153 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 May 1,2016 50-029-23557-00-00 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2265'FSL,3155'FEL,Sec 28,T13N, R10E, UM,AK May 15,2016 MPU J-27 Top of Productive Interval: 9. Ref Elevations: KB: 68.7' 17. Field/Pool(s):Milne Point Unit 1276'FNL,589'FWL,Sec 29,T13N,R10E,UM,AK GL:35' BF:35' Schrader Bluff Oil Pool ' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1055'FNL,613'FWL,Sec 30,T13N,R10E,UM,AK 13,935'MD/3,549'TVD (SHL)ADL025906/(BHL/TPH)ADL025517 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 552166 y- 6014663 Zone- 4 13,940'MD/3,549'TVD N/A TPI: x- 545334 y- 6016357 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 540117 y- 6016548 Zone- 4 N/A 2,536'MD/1,944'TVD 5.Directional or Inclination Survey: Yes (attached) No ❑ 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary DGR-ADR-EWR-HORIZONTAL PRES 2IN MD,DGR-ADR-EWR INV/REV INTERVALS 2IN TVD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 78.6# A-53 Surface 110' Surface 110' Conductor Stg 1 L-408 bbls/T-79 bbls 90 bbls 9-5/8" 40# L-80 Surface 8,620' ' Surface 3,689' 12-1/4" Stg 2 L-305 bbls/T-56.2 bbls 250 bbls 7-5/8" 29.7# L-80 Surface 8,439' Surface 3,671' Tieback Tieback 4-1/2" 12.6# L-80 8,430' 13,940' 3,670' 3,549' 8-1/2" Cementless Screens Liner 24.Open to production or injection? Yes Q No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/ND of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number): 2-7/8" 7,594' N/A **See attached schematic for full Screen/Solid Liner Detail** Screens: 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. 8,623' 8,795'MD/3,689'-3,701'ND vDMPLET'ON! Was hydraulic fracturing used during completion? Yes❑ No ❑✓ 8,920'-11,229'MD/3,700'-3,664'ND ,�t-;,- N 5 123_4 11,354'-12,251'MD/3,657'-3,632' D Per 20 AAC 25.283(i)(2)attach electronic and printed information 12,661'-13,900'MD/3,609'-3,549'ND - ----- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 5/28/2016 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 6/14/2016 24 Test Period 984 130 26 N/A 132.6 scf Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 312 290 24-Hour Rate — 984 " 130 26 19 Form 10-407 Revised 1�1�/2 �/�/( �� CONTINUED 9N P�4GE 2 RBDMS Lv JUN 2 2 201�ubmit ORIGINIAL or 28.CORE DATA Conventional•(s): Yes ❑ No E Sidewall Corees ❑ No ❑ If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑� Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 2,536' 1,944' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 8,623 3,689' information,including reports,per 20 AAC 25.071. SV1 3,203' 2,154' Ugnu LE 7,600' 3,547' Schrader Bluff NA 8,284' 3,651' Schrader Bluff NB 8,561' 3,683' Formation at total depth: Schrader Bluff 31. List of Attachments: Wellbore Schematic,Drilling and Completion Reports, Definitive Directional Surveys,Casing and Cement Reports, Days vs Depth,MW vs Depth. Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Dinger Email: Cdinger4hlICOrp.COM Printed Name: Cody Dier A.,,...„ Title: Drilling Tech til Signature: efy Phone: 777-8389Date: �QeZ ( /��' INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only II • IIIWell: Point Unit Well: MPU J-27 SCHEMATIC Last Completed: 5/23/2016 xacrrr„Alaska,LLC c PTD: 215-153 Orig.KBElev.:68.7/GLElev.:35' TREE&WELLHEAD Tree Seaboard 3 1/8" 5M A Wellhead 20" Bottom with 3"CIW"H"BPV profile.2ea 3/8"NPT control lines. 2 OPEN HOLE/CEMENT DETAIL 20" Conductor 12-1/4" 508.2 bbls left in 12-1/4"Hole Cement to Surface 2-7/8" ► 8-1/2" Cementless Screens Liner in 8-1/2"hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 78.6/A-53/Weld N/A Surface _ 110' _ N/A 3 9-5/8" Surface 40/L-80/TC II 8.525 Surface 8,620' 0.0758 7-5/8" Tieback 29.7/L-80/Vam STL 6.750 Surface 8,439' 0.0459 4-1/2" Liner Screens 12.6/L-80/DWC/C HT 3.833 8,430' 13,940' 0.0152 9-558"ES' Cementer@ TUBING DETAIL 2,862 2-7/8" Tubing 6.4/L-80/EUE 8rd 2.441 Surf 7,594' 0.0058 WELL INCLINATION DETAIL KOP @ 356' Max Hole Angle=94.5 deg.@ 12,839'MD • JEWELRY DETAIL 4 No. Top MD Item ID Upper Completion 1 III:i, 5 1 Tubing Hanger 2.441" t' 2 205' 2-7/8"GLM BK-2 Latch,1.027"Packing Bore 2.347" 7 5/8" 0 1 3 2,685' 2-7/8"GLM BK-2 Latch,1.027"Packing Bore 2.347" 4 7,498' X Nipple 2.962" 5 7,509' ESP Assembly Lower Completion 10 8,430' BOT SLZXP Liner Top Packer w/BD Slips 7"x 9-5/8" 6.200" `V-' 11 Btm 8,439' 7-5/8"Tieback Assy.(No-Go @ 8,428') 6.151" 12 8,452' 7"H563 x 4.5"HTTC L-80 XO 3.900" 14 13,902' 4-1/2"Drillable Packoff Sub 2.40.0" 11 15 13,935' WIV Valve LTC BxB(1.5"Ball on Seat/Closed) - -10 9-5/8"'4 X12 ' 4-1/2" SOLID LINER DETAIL 4-1/2"Screens LINER DETAIL 13 Jts Top(MD) Btm(MD) Jts Top(MD) Btm(MD) 4 8,430' 8,623' 4 8,623' 8,795' See 3 8,795' 8,920' 54 8,920' 11,229' Screen/ 3 11,229' 11,354' 21 11,354' 12,251' Solid Liner 10 12,251' 12,661' 52 12,661' 13,900' Detail GENERAL WELL INFO API:50-029-23557-00-00 Revised by: 41/2” pri . 14 Drilled and Cased by Doyon 14 -5/23/2016 C.Dinger Shoe @ •' 15 13,940' TD=13,940'(MD)/TD=3,549'(TVD) PBTD=13,935'(MD)/PBTD=3,549'(WD) Revised By:CJD 6/21/2016 • • Hilcorp Energy Company Composite Report Well Name: MP J-27 Field: County/State: (LAT/LONG): nation(RKB): API#: Spud Date: 5/1/2016 Job Name: 1511626D MPJ-27 DRILLING Contractor Doyon 14 AFE#: AFE$: Activity Date Ops Summary 4/30/2016 Move rig From J-23 to J-27.Skid rig floor into drilling position. Skid#2 drag chain into drilling position,connect steam and water,Spot rock washer,Sperry shack, fuel tanks.;Load strap&tally 260 joints of DS-50.BHA#1.(8 Joints of 5"HWDP) Safe out Rig walkways. Notified State of upcoming Diverter test on 4-30-2016 @ 11:17.;N/U diverter system.Install diverter tee,set diverter in place,install flanged riser,flow nipple and flow line.R/U high line to rig. Rig accepted @ 1800.;Spot equipment and handling tools. R/U floor for 5"pipe. Continue to R/U pits.Take on spud mud.function test all pit equipment.;Make up stands DS-50, S-135, 19.5#5"drill pipe in mousehole and rack back in derrick(4800'). Drift=2.10";Continue picking up and racking back DS-50,S-135, 19.5#5"drill pipe for a total of 86 stands. Rack back 3 stds 5"HWDP(jars included). Drift=2.10";Bring BHA tools and equipment to rig floor.;Install 15.25"ID wear bushing. RILDS. RKB T/LLDS=33.4',RKB T/GL=33.24'. Flood high psi lines and P/T to 3k(test good). 5/1/2016 Function test surface lines&equipment.Flood test stack.Perform diverter test. MR Chuck Scheve Waived witness of the diverter test. R/U Gyro&Establish true north.Hang sheave in derrick.;Diverter test-Knife valve opened @ 23 sec. Annular closed @30 sec. Starting pressure was 3000 psi. 200 psi increase was in 37 sec.Full pressure in 163 sec. 6 N2 bottles @ 2008 psi average.;Conduct pre-spud meeting with all hands. P/U Clean out BHA#1,12.25 used bit,Motor, HWDP&Drill F/36'T/114'@ 400 gpm 5-10 wob. Drilling with water. Drilling ICE.;Displace to spud mud.8.8 ppg 165 vis.Drill formation F/114'T/300' @ 350- 410 gpm,5-10 wob,40-50 RPM 600 psi. All pea gravel,Coals,Clays.;Pump out of the hole from 300'due to over pull.Pull in to conductor&circ clean. L/D clean out BHA#1.;P/U 12.25 Directional BHA#1 T/90'.Orientate motor,MWD,&UBHO.Upload MWD. Spot Cmt silos&water tank. Continue loading 9 5/8 in shed.;P/U 3 NMFDC. RIH From derrick T/262'.Tag up. Break circ&stage up pumps to 450 gpm 860 psi. Test MWD.GOOD.Take MWD survey.;Circ clean btm up.A lot of Pea gravel,coal&sand. Kelly down.Take Gyro survey.;Wash down through fill F/262'-T/300'MD. KOP @ 300'. Cont drill 12.25"surface hole section as per directional WP03 F/300'-T/715'MD.;450 gpm,1060 psi on, 1020 psi off,44%flow,60 rpm,2k tq on, 1k tq off,20 units bgg,9.3 ECD. 80k up, 79k dn,80k rot. Pea gravel decreased and saw increase in sand/silt @ 500'+/-MD.;Cont Drill 12.25"surface hole F/715'-T/ 1123'. 450 gpm,1550 psi on, 1400 psi off,51%flow,60 rpm,5k tq on,3k tq off,23 units bgg, 10.2 ECD. 95k up,92k dn,94k rot.;20-25k WOB. Continue with Gyro svy's T/735'MD. MWD svy's clean F/735'MD. Gyro on standby F/735'-T/1123'MD. Release Gyro @ 06:00 hrs.;Pump 30 bbl hi vis(condet/walnut)sweep @ 936'w/100%on time (mostly clay and sand). Last svy @ 983'MD/974'TVD-4'low and 9'left of plan WP03a.;Hauled 285 bbls to MP G&I for total=285 bbls Hauled 870 bbls from Vern Lake for total=870 bbls Hauled 215 bbls from 6 mile lake for total=315 bbls 5/2/2016 Drilling 12.25 Directional hole F/1123'T/1700'. 577'@ 96 FPH AV Sliding 50%. 550 GPM,@ 1623 psi, Rot 60 RPM @ 7K tq 16K WOB, MW 9.3 in 9.4 out;Drilling 12.25 Directional hole F/1700'T/2633'. 933'@ 117'FPH AV Sliding 50%. 550 GPM,@ 1623 psi, Rot 60 RPM @ 8K tq 8-10K WOB, MW 9.3 in 9.4 out Pumped sweep @ 2200.200%INC;Geo called base of permafrost @ 2536'MD/1944'TVD.;CBU(Rot/Recip)@ 2633'MD. 500 gpm, 1420 psi,42%%flow,40 rpm,4k tq.;Monitor well(static). Pump out of hole clean F/2633'-T/1220'MD. 500 gpm,1460 ICP,42%flow. Encountered 5-10k drag and diminished returns @ 1220'MD.;Rot @ 20 rpm and reduce pulling speed. Reduced pump rate to 350 gpm and re-establish 100%returns. Slowly backream up w/intermittent losses throughout.;Stop backreaming @ 1120'and continue pumping out @ 2-3 bpm. Saw very little overpull throughout trip w/moderate swabbing issues F/1220'to surface.;BHA and bit est 50%balled up when reaching surface. Clean same. Inspect bit(1,1 in good shape). L/D UBHO sub from string(new BHA length= 460.79');Clean clay from BHA. Clean and clear rig floor from wet trip.;PJSM,Function test ESD's on rig while on high line power. Discuss standing orders for well on diverter along with energy isolation to pad.;Svc rig.;TIH F/surface-T/2633'MD. Set dn @ 1000'and 1280'. Wiped each set down lx and tripped past clean. Hole took proper displacement for trip in. Wash last std dn.;Drilling 12.25 Directional hole F/2633'T/2818'. 185'@ 93'FPH AV Sliding 30%. 550 GPM,@ 1740 psi, Rot 60 RPM @ 8K tq 8-10K WOB, MW 9.3 in 9.4 out Pumped sweep @ 2700. 200%INC;Last svy 2767'MD/2018'TVD=25'low and 5'right of plan(WP03a). Daily losses to formation 29 bbls for total=29 bbls;Hauled 1462 bbls to MP G&I for total=1747 bbls Hauled 100 bbls to B-50 for total= 100 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 1360 bbls from 6 mile lake for total=1675 bbls •5/3/2016 Drilling 12.25 Directional hole F/2818'50'(732')@ 122'FPH AV Sliding 25% 550 GPM,@ 1820 psi, Rot 80 RPM @ 8K tq 8-10K WOB, MW 9.3 in 9.4 out Pumped sweep @ 2632 200%INC;Drilling slowed to 30fph @ 3900'25K WOB @ and after pumping sweep around picked back up to 250-300 fph @ 8-10. Sweep brought back all coal. Gas units up to 505 background.;Drilling 12.25 Directional hole F/3550'T/4380' 830'@ 138'FPH AV Sliding 25% 550 GPM,@ 1900 psi, Rot 60 RPM @ 8K tq 5-22K WOB, MW 9.3 in 9.4 out Pumped sweep @ 3025&3868 300%INC;Drilling 12.25 Directional hole F/4380'T/5250' 870'@ 145'FPH AV Sliding 25%. 550 GPM,@ 1850 psi, Rot 60 RPM @ 10.5K tq 5-25K WOB, MW 9.2+in 9.4 out Pump sweep @ 4833' 50%INC;Note:@ 5000'building.5 deg every 100'drilled,reduce wt on bit to 20k,increase flow rate to 570 gpm. Use Maintenance slides to hold tangent.;Drilling 12.25 Directional hole F/5250'T/5900' 650'@ 108'FPH AV 570 GPM,@ 2150 psi, Rot 60 RPM @ 11K tq 8-20K WOB, MW 9.2+in 9.3+out Pump sweep @ 5568' 200%INC;Note:both centrifuges on,adding water 60 bph to maintain 9.2+ mud wt. ECD 10 ppg,vis 125;Last svy 5604'MD/2898'TVD=7.21'above the line,2.37'left of the line(WP03a). 3.23 slide hrs, 12.45 rotate hrs. Daily losses to formation 0 bbls for total=29 bbls;Hauled 1179 bbls to MP G&I for total=2926 bbls Hauled 50 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 1260 bbls from 6 mile lake for total=2935 bbls 5/4/2016 Drilling 12.25 Directional hole F/5900'T/6027'127'@ 90'FPH AV 570 GPM,@ 2150 psi, Rot 60 RPM @11Ktq 8-20K WOB, MW 9.2+in 9.3+out Pump sweep @ 6027' 200%INC;Cir hole clean @ 80 RPM 570 GPM,Pump sweep high vis/wallnut/condent sweep around. Wallnut came back early&Sweep came back 500 stks late.;Monitor well.Static.Pump out of the hole F/6027'T/3200'.450-550 GPM. Slight over pulls. Slight packing off.Did not have to fight it just slowed down pulling and let it clean up as we went.;Back ream @ 450 gpm F/3200'T/2811', Circ btm up while pulling slow&letting hole unload before getting to the permafrost.;Pooh F/2811'T/1500'.Try to pull on elevators. 10-15 k over pulls.Well swabbing. Pump out of the hole @ 200-300 gpm.5-10 K over pulls. Never had to work back down.Clean.;Blow down top drive.POOH Clean on elevators. F/1500'T/464'. HWDP full of clay.Cleaning as we are pulling.;POOH F/464'stand back HWDP.Scraping clay off of BHA.;Pull bit to surface,stabilizers and bit severly packed with clay,strip clay off same.Drain motor,breakoff bit,grade=1,2,CT,C,E,1,NO,BHA Note:9 buckets of clay stripped off HWDP and BHA.;Inspect mud motor.M/U new 12 1/4"Varel RS616HX PDC bit,RIH with motor and MWD tools,M/U bottleneck XO on top TMC,M/U pup jt and top drive.;PJSM,monitor well,hang blocks,cut and slip 59.5'drlg line.Reset and test crown saver.;M/U flex collars, bottleneck XO, 1 Std HWDP,shallow test MWD,orient bit to as drilled,BD top drive.M/U jars and remaining HWDP from derrick=460.75';TIH on elevators from 460'tag @ 1277',work thru easily,fill pipe @ 2230'.RIH to 5840'washing last 2 stds to bttm @ 6027',no fill.;Note:M/U top drive,orient to(as drilled)working thru tight hole @ slide intervals easily-pumps off @ 2310',2350',2722',3475'and 4234';Drilling 12.25 Directional hole F/6027'T/6408' 381' @ 108 FPH AV 551 GPM,@ 2050 psi, Rot 80 RPM @ 11K tq 5-7K WOB, MW 9.3 in 9.4 out ECD 9.91,vis 130;Last svy 6170.71'MD/3085.84'TVD=1.17'above the line,3.25'left of the line(WP03a). .32 slide hrs,.66 rotate hrs. Daily losses to formation 0 bbls for total=29 bbls;Hauled 1203 bbls to MP G&I for total=4129 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 1260 bbls from 6 mile lake for total=4195 bbls 5/5/2016 Drilling 12.25 Directional hole F/640825' 717' @ 119 FPH AV • 572 GPM,@ x2350 psi, Rot 70 RPM @ 15K tq 5-7K WOB, MW 9.3 in 9.4 out ECD 9.8,vis 105;Drilling 12.25 Directional hole F/7125'T/7850 725' @ 120 FPH AV 540 GPM,@ 2000 psi, Rot 70 RPM @ 15K tq 5-7K WOB, MW 9.3 in 9.4 out ECD 9.8,vis 105;Had max gas at 2591 units @ 7500'.Background came down to 250. Geo reports fault crossed @ 7794';Drilling 12.25 Directional hole F/7850'T/8465' 625' @ 105 FPH AV 540 GPM,@ 2280 psi, Rot 80 RPM @ 17K tq 5-10K WOB, MW 9.3+in 9.4 out ECD 10.12,vis 130;Note:Rotate tangent section f/7934'to 8187'per DD and Geo.;Drilling 12.25 Directional hole F/8465'T/8630' 165' @ 110'FPH AV 540 GPM,@ 2270 psi, Rot 80 RPM @ 17K tq 10-12K WOB, MW 9.5 in 9.5 out ECD 10.21,vis 108,Note:2496u gas @ 8470';Dropped INC from 85 deg after drilling fault to 81 deg looking for Schrader bluff sand. Found Schrader bluff sand 40 Low TVD.;TD surface hole section @ 8630'MD,3690'TVD in Schrader bluff NB-sand. Last svy 8585.89'MD/3685.53'TVD=38.03'below the line,15.98' left of the line(WP03a).3.6 slide hrs,9.77 rotate hrs.;Rack 1 std back to 8560'.Pump 30 bbl hi vis sweep w/15 ppb walnut/15 gal Condet 600 gpm,2460 psi, rotate 80 rpm,reciprocate pipe,cleanup wellbore. Note:high gas at 7640u @ BU receding to 150u.;Sweep back on time w/30%increase at shaker consisting of mostly sand,clay balls and small amount of coal small pieces.Flowcheck well,static.;Pump out of the hole from 8560'to 7056'pumping 600 gpm,2350 psi.Condition mud with Desco while pumping out.;Daily losses to formation 0 bbls for total=29 bbls;Hauled 1372 bbls to MP G&I for total=5501 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 1080 bbls from 6 mile lake for total=5275 bbls 5/6/2016 Pump out of the hole F/7056'T/3780'pumping 600 gpm. Condition mud with Desco while pumping out.5-15 k bobbles. POOH F/3780'T/2550'on elevators. Started swabbing and 15-20 k over pulls.;Pump out of the hole @ 320 gpm.F/2550'T/1980'. Pull slow through base of permafrost. Pull on elevators F/1980'T/BHA. Stand back HWDP.Clean off Clay.;Pump water through NMFDC&MWD. L/D 3 NMFDC.;POOH to bit. L/D same.Plug in to MWD&download data.Bit Grade=1,2,CT,T,X,I,WT,TD;L/D MWD.Clean&Clear floor.;R/U Doyon volant&cmt swivel. R/U to run 9 5/8 casing.;R/U and pull 15.375"ID wear bushing.Load tools to rig floor,R/U power tongs,handling equipment,XO to FOSV.;PJSM.Bakerlock and P/U shoe and flt Equip.install 2 centralizers over stop collars 10'f/ea.end on shoe jt, 1 centralizer mid tube fit jt.ensure proper fit operation.Torque TCII to 13600 ft/Ibs;M/U TCII X DWC XO, crushed XO,attempt to break out XO,Power tongs failed,would not release off jt,C/O power tongs.remove damaged XO,Bakerlock and M/U new XO,torque DWC to 29800 ft/lbs;Breakout and Bakerlock collar on XO below Baffle adaptor,Bakerlock and M/U Baffle adaptor jt.IBOP would not open,thaw ice plug and operate same.;P/U and RIH w/DWC,L-80,40#casing,torque DWC to 29800 ft/lbs,utilize dog collar clamp on first 10 jts and rig tongs for backup.RIH from 134' to 1265',fill on the fly and every 10 jts;with Volant tool,install centralizers on every other jt for 15 jts ran.;Daily losses to formation 0 bbls for total=29 bbls;Hauled 937 bbls to MP G&I for total=6438 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 690 bbls from 6 mile lake for total=5965 bbls 5/7/2016 Run 9 5/8 40#DWC casing F/1265'T/3376'.;Circ casing volume staging up pumps from 2 bpm,180 psi to 8 bpm, 190 psi.P/U 195K,SIO 85K;Continue RIH with 9 5/8"40#L-80 DWC casing from 3376'to 5755',continue to fill on the fly and every 10 jts,M/U ES cmtr and jt,confirm 6 shear pins installed.continue RIH TO 6200'w/setdown.;5 centralizers installed on ea.jt below ESC,5 centralizers installed on ea.jt above ESC;Set down @ 6200.Unable to break over up pulling 100k over.Stage up pumps to 8 bpm.Still unable to break over. Bring on rot @ 25K tq.Work down torque and get it to turn 2 rotations on surface.;Finally got broke over down and work pipe up @ 350K start to get movement.Work pipe 40'pulling 100 k over and setting all wt down.Circ well clean and hole cleaned up @ 70 dnwt&275 up.;P/U 275K,S/O 75K.Circulate and condition mud staging pump to 8 bpm,440 psi from 9.5+ppg in/9.7 ppg out to 9.4+in/9.5+out,@ BU slow pumps to 5 bpm 270 psi.wash to 6247'past tight spot.;Circ&condition mud bringing MW F/9.8 out to 9.5 in and out.Lots of fine sand and silt in returns.;Continue RIH with 9 5/8"40#L-80 DWC casing from 6247'to 8597',continue to fill on the fly and every 10 jts,;M/U last jt, stage pump from 3 bpm,280 psi to 8 bpm,320 psi,unable to rotate,wash to bttm,with no S/O wt,tag @ 8619',attempt to work pipe pulling 380K P/U wt several times,unable to work pipe;Circ and cond mud for cmt job,start MW IN 9.4+ out 9.7 vis 87,YP Cad 18,final mw 9.4+/9.5in/out,_vis 41 YP a1 F Full returns while circulating.Hold PJSM for cmt job.;R/U cement lines,chart recorder.Blow down top drive,close manual lower IBOP.Circulate 8 bpm 440 psi' while emptying pits to handle returns.;Shut down rig pump,line up on cementers,pump 10 bbls water,attempt to test lines,plug valve leaking,C/O same,test AN lines to 500 psi low,3500 psi hi for 5 min ea.;Pump 46.6 bbls 10.5 ppg spacer,drop bypass plug.Pumas lead cmt,915 sx Ca,11.7#for a total of 408 bbl.4.5 bpm, G 320 psi.;Daily losses to formation 0 bbls for total=29 bbls;Hauled 440 bbls to MP G&I for total=6875 bbls Hauled 0 bbls to B-50 for total=150 bbls ( : Hauled 0 bbls from Vern Lake for total=870 bbls \-747 Hauled 423 bbls from 6 mile lake for total=6388 bbls C. fti 5/8/2016 Mix/Rump 390 sx 79 bbl 15.8 ppg to +/-4 bpm_Drop openingplug.Pum�20 bbl H2O on topWwith Halliburton.Swap to rig&Displace with mud @ 8 bpm until Mud push 2 the shoe.;Slow pumps to 5 bpm&finish displacement. Pump Calculated disp+1/3 shoe track. Bumped plug&held 500 over.Good.Bled down and checked floats.Good. Open ES cmt tool @ 2980 psi. CIP©09:12;Circ out cmt @ 3 bpm.Got mud push back @ 10 bbl away.Got cmt back @70 bbl away. 90 bbl good cmt returned to surface. Circ&condition mud staging up pumps to 8 bpm. Flush stack.;Break out Volant tool to check.Good.prep for second stage cmtjob.Load water tanks.Clean rock washer.Off load fluids.Circ @ 8 bpm.;PJSM, Pump second stage cmt job as per plan. Pump 60 bbls 10.5 ppg spacer 6 bpm 450 psi,pump 305 bbls 10.7 ppg lead cement 4.5 bpm 275 psi start,400 psi final. (Lead 380 sx);240 bbls away see spacer @ returns,pump 56.2 bbls 15.8 ppg tail cmt 3 bpm,365 psi start,212 psi finish,(note:see cement returns after 24 bbls tail pumped) drop closing plug. ,.2.ail sTA4t= (Tail 270 sx);Pump 20 bbls water,swap to rig pump.Displace with 198.2 bbls 9.2 ppg mud 5 bpm,240 psi start,with 740 psi.170 bbls into displacement slow to 3 bpm,710 psi FCP,closing plug landed @ calc disp;Pressure to 1680 psi closing ES cmtr,hold for 5 min,bleed off pressure,confirm tool closed.CIP @ 20:50 hrs. 2 60 bbls spacer and 250 bbls cement returned to surface,No losses;Release volant tool,flush stack and lines with black water and drain.P/U stack,set casing /slips per wellhead rep with 125k string wt on slips.Cut off casing w/1'stickup;L/D cut joint,N/D diverter system,Clean pits.;lnstall packoff,RILDS.Make final cut Ip `y @ 6 1/8"above flange and dress same.Install multibowl.Packoff seals in secondary packoff.Test void to 500 psi low 5 min,3000 psi hi for 10 min.;N/U 13 5/8" L 5M BOPE,continue to clean mud pits.;Daily losses to formation 0 bbls for total=29 bbls;Hauled 1641 bbls to MP G&I for total=8519 bbls Hauled 0 bbls to B-50 for total= 150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 310 bbls from 6 mile lake for total=6698 bbls 5/9/2016 Continue to N/U 13 5/8"BOPE,LID bell nipple.Clean mud pits,Load 5"DP in shed.;PJSM,C/O 13 5/8"annular element.Strap and tally 5"DP.Load pits with 8.8 ppg Baradril-N drlg mud;Finish N/U riser,bell nipple and flowline.;PJSM,M/U XOs and test jt,Function Bope.fill stack with water.perform BOP shell test to 3000 psi.Rig elect calibrate and test rig gas alarms. AOGCC rep Brian Bixby on location to witness test.;Test BOPE using 5"and 2 7/8"test jts,test upper/lower 2 7/8"x 5"VBR rams,blind rams,mud cross valves, upper/lower IBOP,Choke manifold valves,;FOSV,dart valve to 250 psi low,3000 psi high 5 min ea.;Test annular with 5"and 2 7/8"test jts to 250 psi low and 2500 psi hi 5 min ea.chart record all tests.Perform accumulator drawdown test,perform manual and hyd choke bleed test.;Note:lower 2 7/8"x 5"VBR ram failed low pressure test using 2 7/8"test jt. Test PVT flow,Pit gain/loss alarms.;Drain stack, PJSM,LOTO accumulator,start to remove lower 5"x 2 7/8"VBR ram,open doors,close pipe rams,found Drillers side actuator for lower pipe ram not functioning properly.;Ram body binding on ram slide,while waiting on another door/ram actuator assy sent f/DDI yard to arrive-Remove VBR rams,R/D and remove BOP door/actuator assembly.;Remove same from cellar,load spare actuator in cellar,install same per DDI mechanic.;Daily losses to formation 0 bbls for total=29 bbls;Hauled 520 bbls to MP G&I for total=9039 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 240 bbls from 6 mile lake for total=6938 bbls 5/10/2016 Continue to install new Ram Actuator on DS Lower Ram.Function test rams with no issues.;Continue testing BOPS.Test bottom rams with 2 7/8"and 5"pipe size to 250/3000 psi with no issues.;Perform Accumulator test: Start-3000 psi/after closure-1550 psi/200 psi Attained-38 sec/Full Recovery-187 sec./N2 Bottles-6 @ ^ 2025 ave. !\ Test Witnessed by Brian Bixby of AOGCC.;Rig down/blow down test equipment.Set 9 3/4"ID wear bushing.;Make up C/O BHA:8.5"HDBS Tricone Bit/7"Mtr/NM , Float Sub/3-6 3/4"flex Collars/1-HWDP/Jars/1-HWDP.Total BHA Length=214.78.;Continue to TIH picking up NC-50 DP from Pipe Shed.Tag soft cement @o V 2839'.;Wash down through soft cement from 2839'to 2848'.Drill hard Cement and closing plug to 2861'.Drill ES Cementer from 2861':2863.5'.Wash down to yl� 2881'.;Circulate bottoms up from 2881'.PT casing to 3000 psi to check integrity of ES Cementer.Held test for 5 minutes with no bleed off.;Continue TIH picking up NC-50 DP from pipe shed from 2275'to 5461'.;Circulate BU 7 bpm 580 psi.Circulate out thick mud.;Continue TIH picking up NC-50 DP from pipe shed from 5461'to 6059'(p/u total of 186 jts DP)continue TIH w/stds from derrick to 6900',string starting taking wt.;Circulate BU 5.5 bpm,600 psi,40 rpm working pipe. circulate out thick mud.;Continue TIH w/stds from derrick from 6900'to 8324',wash from 8324'to 8418',4 bpm,640 psi.Blow down top drive.;Circulate out air, close annular,test 9 5/8"casing to 3000 psi for 30 min,charted,Good test.Bleed off pressure,open annular. 7.2 bbls pumped,7 bbls bled back.;Wash down from 8418'tag baffle adaptor on depth @ 8526'.;Drill FE,drill plug/baffle adaptor @ 8526',drill plug/float collar on 3 depth @ 8573',drill soft cement from 8580'to top of shoe @ 8617',drill shoe,rathole and 20'formation to 8650'.;Note:@ BU seeing plug rubber and cement @ 61 shakers.;Work pipe,pump 30 bbl hi vis baradril-n spacer,displace with new 8.8 ppg Baradril-N drilling mud.;Daily losses to formation 0 bbls for total=29 X" bbls;Hauled 172 bbls to MP G&I for total=9211 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 150 bbls from 6 mile lake for total=7088 bbls 5/11/2016 Work pipe,pump 30 bbl hi vis baradril-n spacer,displace with new 8.8 ppg Baradril-N drilling mud.;Rack back 1 stand,blow down Top Drive.R/U to perform FIT. J Perform FIT to 12.0 ppg EMW with 618 psi surface pressure with 8.8 MW and Shoe ND @ 3688'.Rig down/blow down test equipment.;Monitor well,pump dry job,TOH on elevators from 8604'to 314'.;Rack back HWDP w/jars,1 stand Flex Collars.Lay down Mtr and Bit.;MU BHA#4:8 1/2"HYC SK616M bit,geopilot, DGR,PWD,ILS,ADR,DM.;Up Load MWD tools.;Continue to M/U remaining BHA:M/U TM,FS,3 NMFCs, 1 HWDP,jars,1 HWDP.TIH with DP from derrick to 1153'.;Attempt to test MWD with no pulse.TOH from 1153'to trouble shoot MWD Tools,stand back HWDP and NMFC,troubleshoot tools,C/O DM and TM collars,upload MWD tools.;TIH with BHA#5,M/U NMFCs,HWDP and jars,surface Test MWD,good.TIH to 1150',end of unplanned time.;Continue TIH from 1150'to 8566',fill pipe @ 3050',5850', Note:Break in Geo-steer seals;PJSM,install FOSV,hang blocks,cut and slip drilling line,re-set and test crown saver.L/D FOSV.;Service top drive and blocks, inspect saver sub.;M/U top drive,get parameters,wash last stand to bttm.P/U 240k,S/O 70K,ROT 130K.Wash last std to bttm @ 8650';Drill 8.5"hole from 8650'to 8660';Daily losses to formation 0 bbls for total=29 bbls;Hauled 894 bbls to MP G&I for total= 10105 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 150 bbls from 6 mile lake for total=7238 bbls 5/12/2016 Drill 8 1/2"Hole f/8660'to 9513'(853') P 142 FPH • 360 GPM/920 PSI,70 RPM/18-19 Tq,PU 230K/SO 55K/Rot 125K,MW 8.9/ECD 10.1 Max Gas @ 9700u;Drill 8 1/2"Hole f/9513'to 9700'(187')AROP 187 FPH 360 GPM/920 PSI,70 RPM/18-19 Tq,PU 230K/SO 55K/Rot 125K,MW 8.9/ECD 10.9;Note:Drilling with lower flow rate to hold Inc.Having issues with Geo pilot walking to the right while targeting left.;Pick up hole to 9640.Work pipe from 9640 to 9610'and CBU @ 500 GPM/120 RPM.Hole unloaded 200%with max gas @ 9800u.Continue circulate clean.;Drill 8 1/2"Hole f/9700'to 9983'(283')AROP 188 FPH 5K WOB,360 GPM/970 PSI,70 RPM/18-19 Tq,PU 235K/SO 55K/Rot 124K,MW 8.8/ECD 10.2;Could not get planned turn rate from Geo Pilot to achieve desired Azimuth.Geo Pilot wanting to walk right.Made decision to TOH and reconfigure BHA with stabilized Geo Pilot and less aggressive Bit.;Last Survey: 9913.14'MD/ 3693'TVD/89.07 INC/287.66°AZI Distance to plan 53.32 Low/123.32 Right.;Stand back 1 stand.Circulate Bottoms Up f/9888'@ 550 gpm/1600 psi, 100 rpm/18-20 Tq,had 100%+increase in cutting at shakers for entire Btm Up circulation.;Wash out of hole from 9888'@ 550 gpm/1550 psi,230K Up Wt,265K with out pumps.Had to back ream BHA through the shoe @ 8620'.Pull up to 8500';CBU at the 9 5/8"shoe @ 550 gpm/1500 psi.;POOH on elevators from 8500'to BHA.Work BHA,down load MWD,L/D TM&DM Collar,Geo Pilot and Bit. Bit Graded:0-1-CT-T-X-I-NO-BHA;Held Active Fire/Rig Evacuation Drill.;PJSM,M/U BHA#5:Hyc SKHI616M Bit/Geopilot 7600/DGR/ILS/PWD/ADR/DM/TM/NMFS.;Up Load MWD;Continue to M/U BHA:1 std 6 3/4"NMFC/1 std 5"HWDP w/Jars.RIH 1 std 5"DP.Shallow test tools. Test good.;TIH with BHA#5 from 365'to 4900';Daily losses to formation 0 bbls for total=29 bbls;Hauled 331 bbls to MP G&I for total=10436 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 295 bbls from 6 mile lake for total=7533 bbls 5/13/2016 Continue TIH with BHA#6 on elevators from 4900'to 8569',filling pipe every 2000'.;Obtain parameters @ the shoe:PUW 235K,SO 90K,Rot 130K. Had to rotate BHA through the shoe @ 10 RPM no pump. Had to wash and ream from the shoe to 9888'@ 100 gpm/220 psi/20-40 rpm.;Wash/Ream last stand to btm from 9888'to 9983'. PU 235K/SO 89K/Rot 130K/50 RPM/19-20K Tq/150 GPM/300 PSI;CBU from 9983'©550 gpm/1550 psi.Hole unloaded with 200%increase at shakers and cleaned up shortly after bottoms up.;Make connection and perform check shot survey with 1.2°difference to the right from previous BHA survey.;Drill 8 1/2"Hole f/9983'to 10670'(687')AROP 153 FPH 15K WOB,560 GPM/1640 PSI, 100 RPM/20 Tq,PU 225K/SO 67K/Rot 126K,MW 8.8/ECD 10.26 Survey @ 10,008'INC 89.38/Azm 289.03;Pumped low vis/low wt Sweep @ 10548',sweep back on time,50%increase @ shaker mostly sand. Survey @ 10574.59'MD/3683.95 TVD/92.04 INC/270.92 Azm Distance to Plan:52'low/285'right;Drill 8 1/2"Hole f/10646'to 11302'(656')AROP 109 FPH 15-20K WOB,600 GPM/1850 PSI,90 RPM/20 Tq,PU 215K/SO 60K/Rot 124K,MW 8.9+/ECD 10.4;Note:crossed fault @ 11090'with 9'throw,came in @ 91.5 deg inc,build up shooting for 95 deg inc. 11178'hi gas©8235u;Drill 8 1/2"Hole f/11302'to 11965'(663')AROP 110 FPH 8-20K WOB,600 GPM/1850 PSI,90 RPM/21.5k Tq,PU 250K/SO 55K/Rot 120K,MW 9/ECD 10.9;Pumped low vis/low wt Sweep @ 11500',sweep back on time, 60%increase @ shaker mostly sand. Last survey 11706.31'MD,3641.55'TVD=31.24'below the line,208.51'right of the line.;Daily losses to formation 0 bbls for total=29 bbls;Hauled 545 bbls to MP G&I for total=10981 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 285 bbls from 6 mile lake for total=7818 bbls 5/14/2016 Drill 8 1/2"Hole f/11965'to 12627'(662')AROP 110 FPH 10-15K WOB,475 GPM/1620 PSI, 100 RPM/24k Tq,PU 245K/SO 55K/Rot 115K,MW 9/ECD 11.2;Dropped below base of NB sand©12,265'to 12,517'and again @ 12567'.Drill to 12627'attempting to re acquire NB sand.Having difficulty building Inclination in soft sands.;Stand back 1 stand,CBU working pipe from 12533'to 12439',650 gpm/2500 psi,PU 245,SO 50,Rot 115K,120 rpm/23K Tq.;Drill ahead @ reduced flow rate of 400 gpm from 12624'to 12,690'.Drill with normal parameters f/12690'and appear to be back in NB sand @ 12,716'.;Continue to drill 8 1/2"hole to 12,809'.Had over heat alarm on Electric Drive Motor on Top Drive.;Stand back 1 stand.Circulate @ 320 gpm/908 psi while changing the DS top drive filter on Electric Drive Motor. Work pipe every 5 min.;Drill 8 1/2"Hole f/12809'to 13002'(193')AROP 128 FPH 10-15KK WOB,475 GPM/1620 PSI, 100 RPM/24k Tq,PU 245K/SO 55K/Rot 115K,MW 9/ECD 11.2 TD alarm f/overheating.;Stand back 1 stand.Circulate @ 520 gpm/1800 psi while changing the ODS top drive filter on Electric Drive Motor. Work pipe every 5 min.;Drill 8 1/2"Hole f/13002'to 13286'(284')AROP 114 FPH 5-10KK WOB,550 GPM/1900 PSI, 100 RPM/28k Tq,PU 275K/SO 55K/Rot 120K,MW 9/ECD 10.7 Hi gas at 13250'@ 8960u;Stand back 1 stand.Circulate @ 550 gpm/1900 psi while trouble shoot blower motor,remove inspection plates,check blower for proper rotation and amps,ok Work pipe every 5 min.;Drill 8 1/2"Hole f/13286'to 13475'(189')AROP 126 FPH 5-10KK WOB,550 GPM/1900 PSI,80 RPM/25k Tq,PU 265K/SO 70K/Rot 117K,MW 9/ECD 10.7 Note:start adding NXS lube.;Last survey 13309.64'MD/3568.78'TVD=6.89'below the line,39.54'right of the line.;Hole unloading,stop drlg,slow pumps down to 360 gpm, 1150 psi,70 rpm to keep mud from going over shakers,circulate until hole cleans up,shakers can handle returns w/o losses Lubes currently @ 3%;Continue to work pipe,Reduce pump to min rate,screens blinding off,C/O screens on the fly.;Continue drilling from 13475'to 13522';Daily losses to formation 0 bbls for total=29 bbls;Hauled 535 bbls to MP G&I for total=11516 bbls Hauled 0 bbls to 13-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 720 bbls from 6 mile lake for total=8538 bbls 5/15/2016 Drill 8 1/2"Hole f/13522'to 13940'(TD)(418')AROP 84 FPH 3-7K WOB,382 GPM/1140 PSI, 110 RPM/13k Tq,PU 180K/SO 50K/Rot 118K,MW 9/ECD 10.6 Note:Drill @ Low Flow rate due to screens blinding off.;Final Survey @ 13,871'MD,3550'TVD,Inc 90.49,Azm 262.63.Distance to plan: 12'low,36'right;CBU from 13940'.Screens still blinding off.Stage pumps up from 250 gpm over 2 bottoms up circulations to establish 550 gpm over 120/170 screens.;Circulate additional bottoms up©550 gpm/2150 psi, 150 rpm/11 K Tq.MW 9.0/ECD 10.5.Attempted 600 gpm,but started losing fluid.;Reduce parameters to 300 gpm and 70 rpm.Screen up with 200 mesh screens on all 4 shakers.;Continue to circulate and condition mud,staging flow rate up from 300 gpm to 550 gpm over 200 mesh screens.Mud Engineer Performing Production Screen Plugging Test's as needed.;Perform 3 tests,1st test passed w/avg: 14.1 sec,.5 sec dev.2nd test passed w/avg:14 sec, 1.1 sec dev.3rd test passed w/avg of 13.2 sec,.4 sec dev.;At final able to pump 500 gpm, 1900 psi,shakers not blinding off.Get SPRs, flow check well,static.;Backream out of hole 120 rpm,450 gpm, 1500 psi f/13940'to 10100',make 1 more pass cleaning up concretions drilled @ the following depths-;(13820'-13818')(13657'-13640')(13286'-13278') (12686'-12676')(12169'-12166')(10737'-10734');Daily losses to formation 0 bbls for total=29 bbls;Hauled 1281 bbls to MP G&I for total=12797 bbls Hauled 0 bbls to 8-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 1060 bbls from 6 mile lake for total=9598 bbls • Hilcorp Energy Company Composite Report Well Name: MP J-27 Field: County/State: (LAT/LONG): evation(RKB): API#: Spud Date: 5/1/2016 Job Name: 1511626C MPJ-27 COMPLETION Contractor AFE#: AFE$: Activity Date Ops Summary 5/16/2016 Continue to back ream out of hole from 10100'to inside the 9 5/8"shoe @ 8569'. ICP @ 450 gpm/1430 psi,120 rpm/9-10K Tq. FCP @ 450 gpm/1090 psi,120 rpm/3-4K Tq.,Flow check well at the shoe.Well static.Pump 30 bbl high vis sweep and circulate casing clean 450 gpm/1100 psi,130 rpm/3-4K Tq. 100% increase in cuttings at bottoms up,and 50%increase with sweep @ surface.,Flow check well.Well Static.Slip and cut 54'drill line.Re-set and test crown saver, service top drive,inspect saver sub and DRWKS brakes,Drop 2"drift on wire,POH on elevators from 8569'to 5823',mix dry job while TOOH,Pump dry job,blow down top drive.TOOH on elevators from 5823'to 2073',Continue TOOH L/D 5"drill pipe from 2073'to 271'@ BHA. Note:5 bbls over calculated displacement on trip out.,L/D BHA,Recover drift on top flt sub,L/D 2 jts HWDP,jars and 3 NMFCs.Download MWD data.L/D remaining BHA.bit grade=1,2,CT,G,X,I,NO,TD,Load out tools,clear and clean rig floor.Drain stack,Perform Bi-weekly BOP ram function test.R/U 4 1/2" handling equipment.M/U 5"safety jt w/XOs and FOSV,PJSM for running 4 1/2"completion,review well control plan.M/U lower completion per tally,M/U shoe, WIV valve,packoff valve and XO pup,ensure WIV is open.P/U and RIH with 4 1/2"DWC/HT production screens,torque DWC thread to 5500#,HTTC thread to 7800#,use BOL 2000 pipe dope.RIH to 2000',Daily losses to formation 0 bbls for total=29 bbls Rig fuel on hand 6900 gal,Rig fuel used 300 gal. Rig fuel received=0 gal.,Hauled 171 bbls to MP G&I for total=12968 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 580 bbls from 6 mile lake for total=10178 bbls 5/17/2016 Continue to P/U and RIH with 4 1/2"DWC/HT production screens f/2000'to 5486'torque DWC thread to 5500#,HTTC thread to 7800#,use BOL 2000 pipe dope. PU total of 108 screens and 20 blank pipe as per tally.,Rig up to run 2 3/8"PH6 inner string.Confirm pipe count and kick out 37 screens and 11 blank pipe from pipe shed.Start loading 6 1/4"DC's and HWDP in pipe shed for push pipe.,PU and run 2 3/8"inner string.space out inner string.,M/U"SLZXP"pkr/hgr w/bumper sub and dp pup jt(5537'). Mix and load pal mix(let stand 30 min). Break circulation @ 2 bpm/590 psi. Liner 126k up,101k dn.,Run 4-1/2"liner F/5537'-T/ 8553'on 5"drill pipe out of derrick.,Circulate surface to surface w/5%lube in casing @ 8553'MD. Stage up to 2.5 bpm/960 psi. Circulated a total of 490 bbls. 154k up, 110k dn prior to exiting shoe.,Continue running 4-1/2"liner F/8553'-T/12,600'MD on 5"drill pipe out of derrick. Clean exiting shoe but took wt @ 8773'(25k). Work pipe 3x then pass w/little issue.,Continue running pipe with good up and dn wts. No push pipe needed thus far.,Daily losses to formation 0 bbls for total=29 bbls,Hauled 382 bbls to MP G&I for total= 13350 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 140 bbls from 6 mile lake for total=10,318 bbls 5/18/2016 Continue running 4-1/2"liner F/12600'-T/13764'MD on 5"drill pipe out of derrick,with no issues or push pipe needed.Fill pipe and break circulation @ 13764'. Wash last 2 stds to bottom from 13,764'@ 2 bpm/750 psi,Pu wt 173K,SOW 90K.Tag bottom @ 13944'.PUH to Up Wt @ 175k Park @ 13940'.,Pump 40 bbls 9.1 ppg hi vis spacer,down DP and Inner string,displacing annuls to 9.1 ppg 3%filtered KCL @ 3 bpm/1530 psi.,Drop and chase 1 '''h' ball on seat @ 3bpm/1500 psi.Walk pressure up to 3000 psi.Saw indication of shear @ 2180 psi.Hold 3000 psi for 10 minutes.Step pressure up and hold 3500 for 5 minutes. Pressure up and hold 4000 psi for 10 min.Bleed off pressure,slack off to no go,PUH and verify release.,Rig up to test Liner top PKR.Line up kill line,close annular,pressure up to 1500 psi and test annulus to TOL PKR for 10 min,charted,good test.,P/U 15'to 13917'and unsting from Packoff.Pump 2nd displacement,displacing ID of Production screens with 9.1 ppg 3%KCL @ 4.7 BPM/3760 PSI @ PUW 150K.,POH F/13,917'to 12,916'MD laying down 5"DP. 150k up.,Pump 20 bbl 10.1 ppg dry job. Blow down top drive.,Continue POH F/12,916'to 8,442'MD laying down 5"DP.,Circulate lx btm's up @ 8442'MD just inside TOL(8430'). Circulate @ 209 gpm,3930 psi.,Monitor well(static). Pump 20 bbl dry job. Blow down top drive.,POOH laying down 5"dp F/8442'to 7712' MD. Hole taking slightly over calculated for trip. Failed hydraulic hose on laydown machine.,Service rig while troubleshooting laydown machine.,Isolate failed hose on laydown machine. Will replace offline.,Continue laying down 5"drill pipe from 7,712'to 6,400'MD.,Daily losses 18 bbls for total=47 bbls,Hauled 2193 bbls to MP G&I for total=15,543 bbls Hauled 0 bbls to B-50 for total= 150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 195 bbls from 6 mile lake for total=10,513 bbls 5/19/2016 Continue laying down 5"drill pipe from 6400'to the Liner running tool.L/D Bumper sub.,TBIH from 5495'with Excess DP in Derrick to 8137',while repairing ejector hose on pipe skate.,POOH L/D 5'DP from 8137'to the Liner Running Tool @ 5495'.,Lay down Liner running tool.Rig up to L/D 2 3/8"Inner String. MU Safety Joint.,POOH Laying down 2-3/8"PH6 inner string from 5437'to surface. 79 bbl loss for total trips laying down drill pipe.,Clean and clear rig floor.,Drain stack and pull wear bushing. Set test plug. Change out upper pipe rams to 7-5/8"fixed body rams. Test same 250/3000 psi on rams,250/2500 psi on annular (test good). R/D same.,P/U and dummy run hanger w/Wellhead tech present(Greg Ruge). Landed out on depth and verified(30.83'). L/D same,R/U Weatherford casing. PJSM,M/U bullet seal assy. 7.31"OD on mule shoe(Verified by Shane Barber). 216 total jts in shed prior to job. tq connections to 5300 ft/lbs tq.,Run 7-5/8",29.7#,L-80,Vam STL casing from surface to 2,615'MD. Static losses maintaining+/-6 bph.,Daily losses to formation 115 bbls for total= 162 bbls,Hauled 150 bbls to MP G&I for total=15,693 bbls Hauled 0 bbls to B-50 for total=150 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 200 bbls from 6 mile lake for total=10,713 bbls '/�i 5/20/2016 Run 7-5z8L2,91#,L-8Q.VamSTL case _om 2,515'to 8355'.PUW 175,SOW 127K,X0 to 5"DP pace out Ported Bullet Seal Assembly,locating TOL© III 8430'.NO Go in SBR @ 8441'.Lay down 3 jts DR MU 3.88'space out pup,csg jt 207.MU landing joint with Csg Hgr and Pups.Land out Hgr having to work Mule shoe into SBR.M/U 5'DP Pup on top of landing jt,MU Top drive.PUH leaving Mule shoe inside Liner Top,and exposing 1"ID seal assembly ports to annulus.,Close bag Bring on pumps and establish reverse circulation through 1"Ports on Seal Assembly @ 3 bpm/320 psi.Shut down pumps.Line up and Reverse circulate 114 bbls 11.4 ppg corrosion inhibited Bromide pill and chase with 48 bbls Diesel FP with 290 psi FCP©end of circulation.Shut down pumps, with Bag closed,slack off and land out Casing Hanger placing Mule shoe depth @ 8438'(1.5'off No Go),Drain stack. Install packoff,RILDS and test void(500 psi w/5 min hold, 3000 psi w/10 min hold). Test good.,R/U test equipment. Test 9-5/8"x 7-5/8"annulus to 1000 psi w/30 min hold(Ok). Chart and record same. R/D test equipment.,Bring tools and equipment to floor. Inventory cannon clamps and other associated equipment prior to running assy. Prep and organize tools in shed. 245 jts 2-7/8"tbg in shed prior to start. Monitor well(via trip tank)during rig up. Hang sheaves and run pulling line for cable. Run esp and heat trace cable to floor.,Test 3-1/2 IF TIW(250/3000).,PJSM, P/U and M/U mtr/pump asy as per detail w/centralizer and sensor sub. Fill assy w/oil. tq flanges.,Daily losses 255 bbls for total=417 bbls 20 bph static Iosses,Hauled 48 bbls to MP G&I for total= 15,741 bbls Hauled 25 bbls to B-50 for total= 175 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 200 bbls from 6 Mile Lake for total=10,913 bbls 5/21/2016 Continue to P/U and M/U mtr/pump asy as per detail w/centralizer and sensor sub. Fill assy w/oil. tq flanges.M/U Mtr Lead,Test same.,Run in hole PU 2 7/8" ESF'completion as per tally to 4162'(125 jts),Rig up Heat Trace equipment.,Continue running 2-7/8"tbg(ESP)completion F/4162'-T/5,002'MD. Install heat Trace @ 3445'from surface. Perform conductivity test @ MTR,2000',3000',4000',and 5002'MD(all test good). 80k up,69k dn.,Continue running 2-7/8"tbg (ESP)completion F/5,002'-TI 6,300'MD.,Perform conductivity test on ESP and Heat trace. Bring more cannon clamps to rig floor and stage.,Daily losses to formation 273 bbls for total=690 bbls,Hauled 0 bbls to MP G&I for total=15,741 bbls Hauled 570 bbls to B-50 for total=745 bbls r Hauled 0 bbls fro Vern Lake for total=870 bbls Hauled 830 bbls from 6 Mile Lake for total=11,743 bbls 5/22/2016 Continue running ESP completion,installing Heat Trace f/6200'to 7561'(228 jts).Perform conductivity test on Heat Trace and ESP @ 1000'intervals.95K PUW/70K SOW,MU Tubing Hanger w/pup joint and PU Jt#229 for landing jt. Dress tubing hanger with Heat trace and ESP penetrators,Meg test and cut ESP/Heat trace cables.Make Heat Trace and ESP penetrator Splice's.Terminate both to tubing hanger.,Land hanger @ 30.14'RKB,w/upper GLM(orifice) @ 204',lower GLM w/dummy valve @ 2865', "XN"nipple @ 7458',EOP @ 7594',wt on hanger=15k,RILDS per wellhead rep. 95K PUW/70K SOW.,Count for total run=8 Flat cannon clamps,2 Flat guards,5 penetralizers,67 Cannon clamps,515(5')clamps,106 x-collar clamps,and 5 SS bands.,Install BPV. C/O upper pipe rams from 7-5/8"fixed body to 2-7/8"x 5"VBR's. Sym Ops-Clean pits and R/W for move.,N/D BOP equipment and rack back for demob. Demob all 3rd party shacks. Begin setting mats for J-28. Prep for upcoming rig move.,Nipple up adapter flange. Perform conductivity test on penetrators(test good). Nipple up tree. Pull BPV and install TWC. Test tree 250 psi w/5 min and 5,000 psi w/15 min hold(Greg Ruge),R/U LRS to freeze protect. P/T lines 2500 psi (ok). R/U on IA and pump 95 bbls @ 2 bpm,400 psi(bullheading).,Daily losses to formation 247 bbls for total=937 bbls,Hauled 57 bbls to MP G&I for total= 15,798 bbls Hauled 0 bbls to B-50 for total=745 bbls Hauled 0 bbls from Vern Lake for total=870 bbls Hauled 155 bbls from 6 Mile Lake for total=11,898 bbls 5/23/2016 R/U LRS Test lines 250PS1/2500 PSI 5 min,Bull head 95 bbls,2BPM down IA,200 psi ICP,500 psi 2 bpm FCP,Line up and bull head 15 bbls DSL down tubing .5 BPM 1000PSI,FCP=1100PSI,R/D LRS„Review check list for skidding rig floor,secure cellar area,remove circulating equipment from Tree&IA,skid rig floor into moving position. Rig released from J-27 AT 9AM • 9 Hilcorp Energy Company Milne Point M Pt J Pad MPJ-27 50-029-23557-00-00 50-029-23557-00-00 Sn+ rry Drilling Definitive Survey Report 19 May, 2016 s, HALLIBURTDN Sperry Drilling • • • • • Project: Milne Point WELL DETAILS:MPJ-27 NAD 1927(NADCONCONUS) Alaska Zone 04 HALLIBURTON Site: M Pt J Pad Ground Level: 3500 Well: MPJ-27 +rvs +EVW Nord ng Basting Latittude longitude Slot Wellbore: MPJ-27 0.00 0.00 6014663.74 552166.18 70°272.077N 149°34'27.777W Plan: MPJ-27 REFERENCE INFORMATION Co-ordinate(NIE)Reference:Well MPJ-27,True North Vertical(TVD)Reference MPJ-27 W 68.70ustt(Doyon 14) - Measured Depth Reference:MPJ-27 @ 68.70usft(Doyon 14) •• Calculation Method:Minimum Curvature -1300- 0- - 500 w 10p0 p 1300— (,) 300—M �O O b N o d � o topp ' C O O O 2600— h ho 2 O MPJ-27 n S 0 0 oo 8 0 • N N n rr 3900— ' 0 0 0 0 0 $ 0 0 0 0 9 5/8" 0 0 0 4 1/2" 5200— o 1 1 1 oil I : olio , l 1 : : Till oil l 0 1300 2600 3900 5200 6500 7800 9100 10400 11700 Vertical Section at 280.20°(1300 usft/in) • • HAWlUF✓<TON Project: Milne Point WELL DETAILS:MP3-27 Ifteae,y t)L..r= Site: M Pt J Pad Ground Level: 55.00 Well: MPJ-27 +N/-8 +E/-W Nogg Pig tatinede Longitude slur 6000—: Wellbore: MPJ-27 0.00 0.00 6014663.74 552166.18 70027'2.877N 149°34.27.777W Plan: MPJ-27 REFERENCE INFORMATION 5500— Co-ordinate(N/E)Reference:Well MPJ-27.True North — Vertical(TVD)Reference:MPJ-27 a 68.70u.R(Doyon 14) Measured Depth Reference:Mini @ ur au (Doyon 14) Calculation Method:Minimum Curvature 5000— 4500— 4000 3500 3000 2500- - 4 12" 2000— 1000—: 500— _ 8 vd vJ 0_ 150 -500— -1000- -1500— -2000- -2500— T M Azimuths to True North Magnetic North:18.55° -3000 Magnetic Field Strength:57498.3snT CASING DETAILS Dip Angle:81.06° -3500— Date:5/172016 TVD TVDSS MD Size Name Model:BGGM2015 3688.73 3620.03 8619.00 9-5/8 9 5/8" 3549.96 3481.26 13871.23 4-1/2 4 1/2" -4000 llll�iilliill�l,lt�tlll�lllil�ltl�lllllllll�llll�llll�llll�lllt�lill�lill�llll�llli�riitltttlliiii�itl,lltll�ll,i��llilrlll�llll�l�llll�lll��l -13000 -12500-12000 -11500 -11000 -10500 -10000 -9500 -9000 -8500 -8000 -7500 -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 West(-)/Fast(+)(1500 usft/in) 1111 1111(.01V 0 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-27 Project: Milne Point TVD Reference: MPJ-27 @ 68.70usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-27 @ 68.70usft(Doyon 14) Well: MPJ-27 North Reference: True Wellbore: MPJ-27 Survey Calculation Method: Minimum Curvature Design: MPJ-27 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 MPJ-27 Well Position +N/-S 0.00 usft Northing: 6,014,663.74 usft Latitude: 70°27'2.877 N +EI-W 0.00 usft Easting: 552,166.18 usft Longitude: 149°34'27.777 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 35.00 usft Wellbore MPJ-27 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 5/17/2016 18.55 81.06 57,498 Design MPJ-27 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 33.70 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 33.70 0.00 0.00 280.20 Survey Program Date 5/16/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 100.00 735.00 SRG-SS(MPJ-27) SRG-SS Surface readout gyro single shot 05/02/2016 794.91 8,585.89 MWD+IFR2+MS+sag(1)(MPJ-27) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/02/2016 8,685.92 13,871.23 MWD+IFR2+MS+sag(2)(MPJ-27) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/12/2016 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 33.70 0.00 0.00 33.70 -35.00 0.00 0.00 6,014,663.74 552,166.18 0.00 0.00 UNDEFINED 100.00 0.77 182.31 100.00 31.30 -0.45 -0.02 6,014,663.29 552,166.17 1.16 -0.06 SRG-SS(1) 170.00 0.85 155.75 169.99 101.29 -1.39 0.18 6,014,662.35 552,166.37 0.54 -0.42 SRG-SS(1) 263.00 0.88 165.44 262.98 194.28 -2.71 0.64 6,014,661.04 552,166.84 0.16 -1.11 SRG-SS(1) 356.00 2.19 269.33 355.96 287.26 -3.42 -0.96 6,014,660.31 552,165.25 2.74 0.34 SRG-SS(1) 451.00 2.73 277.96 450.87 382.17 -3.13 -5.01 6,014,660.58 552,161.19 0.69 4.38 SRG-SS(1) 546.00 4.33 287.12 545.69 476.99 -1.76 -10.68 6,014,661.91 552,155.51 1.78 10.20 SRG-SS(1) 640.00 8.15 289.50 639.11 570.41 1.51 -20.36 6,014,665.11 552,145.81 4.07 20.30 SRG-SS(1) 735.00 9.12 292.51 733.03 664.33 6.64 -33.66 6,014,670.14 552,132.48 1.13 34.31 SRG-SS(1) 794.91 10.50 296.00 792.07 723.37 10.85 -42.95 6,014,674.29 552,123.15 2.51 44.20 MWD+IFR2+MS+sag(2) 888.77 14.80 286.16 883.64 814.94 17.94 -62.17 6,014,681.24 552,103.90 5.11 64.36 MWD+IFR2+MS+sag(2) 983.49 19.83 288.29 974.04 905.34 26.36 -89.06 6,014,689.47 552,076.95 5.35 92.32 MWD+IFR2+MS+sag(2) 5/19/2016 3:28:47PM Page 2 COMPASS 5000.1 Build 81 • Halliburton 5 Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-27 Project: Milne Point TVD Reference: MPJ-27 @ 68.70usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-27 @ 68.70usft(Doyon 14) Well: MPJ-27 North Reference: True Wellbore: MPJ-27 Survey Calculation Method: Minimum Curvature Design: MPJ-27 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 1,077.69 24.93 290.66 1,061.12 992.42 38.38 -122.83 6,014,701.26 552,043.10 5.50 127.68 MWD+IFR2+MS+sag(2) 1,172.81 28.62 289.96 1,146.02 1,077.32 53.24 -163.01 6,014,715.83 552,002.81 3.89 169.86 MWD+IFR2+MS+sag(2) 1,266.81 33.77 289.31 1,226.40 1,157.70 69.57 -208.86 6,014,731.84 551,956.86 5.49 217.88 MWD+IFR2+MS+sag(2) 1,361.28 38.49 288.70 1,302.68 1,233.98 87.69 -261.52 6,014,749.59 551,904.08 5.01 272.91 MWD+IFR2+MS+sag(2) 1,455.80 39.69 288.24 1,376.05 1,307.35 106.57 -318.04 6,014,768.07 551,847.43 1.31 331.88 MWD+IFR2+MS+sag(2) 1,549.15 40.81 285.16 1,447.30 1,378.60 123.88 -375.80 6,014,784.97 551,789.55 2.45 391.80 MWD+IFR2+MS+sag(2) 1,64-4.54 45.37 284.00 1,516.94 1,448.24 140.25 -438.86 6,014,800.90 551,726.39 4.85 456.76 MWD+IFR2+MS+sag(2) 1,739.03 46.87 283.52 1,582.44 1,513.74 156.45 -505.01 6,014,816.63 551,660.13 1.63 524.73 MWD+IFR2+MS+sag(2) 1,833.24 52.50 283.69 1,643.37 1,574.67 173.34 -574.80 6,014,833.04 551,590.23 5.98 596.41 MWD+IFR2+MS+sag(2) 1,927.90 58.20 283.61 1,697.16 1,628.46 191.71 -650.44 6,014,850.87 551,514.47 6.02 674.11 MWD+IFR2+MS+sag(2) 2,021.17 58.87 283.78 1,745.85 1,677.15 210.54 -727.74 6,014,869.16 551,437.06 0.73 753.51 MWD+IFR2+MS+sag(2) 2,116.45 62.84 284.85 1,792.24 1,723.54 231.13 -808.35 6,014,889.18 551,356.31 4.28 836.49 MWD+IFR2+MS+sag(2) 2,210.79 66.26 283.78 1,832.78 1,764.08 252.18 -890.88 6,014,909.65 551,273.65 3.77 921.45 MWD+IFR2+MS+sag(2) 2,305.10 70.55 283.52 1,867.48 1,798.78 272.86 -976.07 6,014,929.74 551,188.32 4.56 1,008.96 MWD+IFR2+MS+sag(2) 2,399.46 71.64 284.17 1,898.05 1,829.35 294.23 -1,062.74 6,014,950.49 551,101.50 1.33 1,098.04 MWD+IFR2+MS+sag(2) 2,493.74 68.96 284.36 1,929.83 1,861.13 316.10 -1,148.76 6,014,971.76 551,015.34 2.85 1,186.57 MWD+IFR2+MS+sag(2) 2,588.28 72.97 283.38 1,960.66 1,891.96 337.51 -1,235.51 6,014,992.56 550,928.46 4.35 1,275.74 MWD+IFR2+MS+sag(2) 2,677.62 71.13 283.87 1,988.19 1,919.49 357.52 -1,318.11 6,015,011.99 550,845.73 2.12 1,360.58 MWD+IFR2+MS+sag(2) 2,767.37 69.90 283.96 2,018.13 1,949.43 377.87 -1,400.23 6,015,031.76 550,763.47 1.37 1,445.01 MWD+IFR2+MS+sag(2) 2,867.35 71.02 283.89 2,051.57 1,982.87 400.54 -1,491.68 6,015,053.79 550,671.87 1.12 1,539.03 MWD+IFR2+MS+sag(2) 2,961.93 72.42 283.93 2,081.23 2,012.53 422.13 -1,578.85 6,015,074.77 550,584.56 1.48 1,628.64 MWD+IFR2+MS+sag(2) 3,056.56 72.90 283.58 2,109.44 2,040.74 443.61 -1,666.59 6,015,095.63 550,496.68 0.62 1,718.80 MWD+IFR2+MS+sag(2) 3,149.93 71.86 283.44 2,137.70 2,069.00 464.40 -1,753.12 6,015,115.81 550,410.02 1.12 1,807.64 MWD+IFR2+MS+sag(2) 3,245.72 71.01 283.20 2,168.20 2,099.50 485.32 -1,841.48 6,015,136.11 550,321.53 0.92 1,898.31 MWD+IFR2+MS+sag(2) 3,340.27 71.90 282.93 2,198.27 2,129.57 505.58 -1,928.80 6,015,155.76 550,234.08 0.98 1,987.83 MWD+IFR2+MS+sag(2) 3,434.14 73.34 282.34 2,226.31 2,157.61 525.18 -2,016.21 6,015,174.74 550,146.54 1.65 2,077.33 MWD+IFR2+MS+sag(2) 3,528.00 72.32 283.08 2,254.02 2,185.32 544.91 -2,103.69 6,015,193.85 550,058.93 1.32 2,166.92 MWD+IFR2+MS+sag(2) 3,622.74 73.21 282.66 2,282.09 2,213.39 565.06 -2,191.90 6,015,213.39 549,970.59 1.03 2,257.31 MWD+IFR2+MS+sag(2) 3,716.88 72.94 283.06 2,309.49 2,240.79 585.10 -2,279.70 6,015,232.82 549,882.66 0.50 2,347.27 MWD+IFR2+MS+sag(2) 3,811.13 72.17 282.97 2,337.75 2,269.05 605.35 -2,367.31 6,015,252.45 549,794.92 0.82 2,437.08 MWD+IFR2+MS+sag(2) 3,905.69 72.55 282.54 2,366.40 2,297.70 625.25 -2,455.20 6,015,271.73 549,706.90 0.59 2,527.10 MWD+IFR2+MS+sag(2) 4,000.03 71.20 282.53 2,395.75 2,327.05 644.71 -2,542.72 6,015,290.57 549,619.26 1.43 2,616.68 MWD+IFR2+MS+sag(2) 4,094.32 71.01 284.27 2,426.29 2,357.59 665.38 -2,629.50 6,015,310.63 549,532.35 1.76 2,705.75 MWD+IFR2+MS+sag(2) 4,189.01 70.54 284.99 2,457.47 2,388.77 687.96 -2,716.01 6,015,332.61 549,445.69 0.87 2,794.89 MWD+IFR2+MS+sag(2) 4,283.11 72.72 284.51 2,487.12 2,418.42 710.70 -2,802.36 6,015,354.73 549,359.18 2.37 2,883.91 MWD+IFR2+MS+sag(2) 4,377.91 71.37 284.42 2,516.34 2,447.64 733.22 -2,889.68 6,015,376.65 549,271.71 1.43 2,973.84 MWD+IFR2+MS+sag(2) 4,472.53 72.17 283.40 2,545.95 2,477.25 754.82 -2,976.92 6,015,397.63 549,184.34 1.33 3,063.52 MWD+IFR2+MS+sag(2) 4,566.55 70.53 284.13 2,576.01 2,507.31 776.02 -3,063.44 6,015,418.22 549,097.68 1.89 3,152.43 MWD+IFR2+MS+sag(2) 4,661.40 71.14 284.11 2,607.15 2,538.45 797.87 -3,150.33 6,015,439.47 549,010.65 0.64 3,241.81 MWD+IFR2+MS+sag(2) 4,755.52 72.95 284.13 2,636.16 2,567.46 819.72 -3,237.15 6,015,460.70 548,923.68 1.92 3,331.13 MWD+IFR2+MS+sag(2) 5/19/2016 3:28:47PM Pape 3 COMPASS 5000.1 Build 81 0 Halliburton 1110 Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-27 Project: Milne Point ND Reference: MPJ-27 @ 68.70usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-27 @ 68.70usft(Doyon 14) Well: MPJ-27 North Reference: True Wellbore: MPJ-27 Survey Calculation Method: Minimum Curvature Design: MPJ-27 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 4,849.96 71.47 284.33 2,665.02 2,596.32 841.82 -3,324.32 6,015,482.19 548,836.38 1.58 3,420.83 MWD+IFR2+MS+sag(2) 4,944.18 72.54 283.98 2,694.12 2,625.42 863.73 -3,411.20 6,015,503.49 548,749.34 1.19 3,510.22 MWD+IFR2+MS+sag(2) 5,038.77 72.74 283.47 2,722.35 2,653.65 885.15 -3,498.91 6,015,524.29 548,661.50 0.56 3,600.33 MWD+IFR2+MS+sag(2) 5,132.98 72.62 283.38 2,750.39 2,681.69 906.03 -3,586.39 6,015,544.56 548,573.89 0.16 3,690.13 MWD+IFR2+MS+sag(2) 5,227.16 72.45 283.41 2,778.66 2,709.96 926.84 -3,673.78 6,015,564.76 548,486.36 0.18 3,779.83 MWD+IFR2+MS+sag(2) 5,321.83 73.01 282.84 2,806.76 2,738.06 947.37 -3,761.82 6,015,584.67 548,398.18 0.82 3,870.11 MWD+IFR2+MS+sag(2) 5,415.94 70.29 283.15 2,836.39 2,767.69 967.45 -3,848.85 6,015,604.14 548,311.02 2.91 3,959.32 MWD+IFR2+MS+sag(2) 5,510.10 70.76 282.34 2,867.78 2,799.08 987.04 -3,935.44 6,015,623.11 548,224.31 0.95 4,048.00 MWD+IFR2+MS+sag(2) 5,604.87 71.40 282.68 2,898.51 2,829.81 1,006.46 -4,022.96 6,015,641.92 548,136.67 0.76 4,137.58 MWD+IFR2+MS+sag(2) 5,699.28 71.31 282.30 2,928.69 2,859.99 1,025.80 -4,110.29 6,015,660.65 548,049.20 0.39 4,226.96 MWD+IFR2+MS+sag(2) 5,793.56 70.74 283.54 2,959.35 2,890.65 1,045.74 -4,197.19 6,015,679.97 547,962.18 1.38 4,316.02 MWD+IFR2+MS+sag(2) 5,888.12 70.20 283.72 2,990.96 2,922.26 1,066.74 -4,283.80 6,015,700.36 547,875.43 0.60 4,404.98 MWD+IFR2+MS+sag(2) 5,981.89 70.36 283.53 3,022.60 2,953.90 1,087.53 -4,369.59 6,015,720.55 547,789.51 0.26 4,493.09 MWD+IFR2+MS+sag(2) 6,075.80 69.73 284.44 3,054.65 2,985.95 1,108.86 -4,455.24 6,015,741.28 547,703.72 1.13 4,581.17 MWD+IFR2+MS+sag(2) 6,170.71 71.90 284.96 3,085.84 3,017.14 1,131.61 -4,541.94 6,015,763.42 547,616.87 2.34 4,670.52 MWD+IFR2+MS+sag(2) 6,265.32 71.83 285.42 3,115.29 3,046.59 1,155.17 -4,628.71 6,015,786.37 547,529.95 0.47 4,760.09 MWD+IFR2+MS+sag(2) 6,359.76 72.01 285.03 3,144.60 3,075.90 1,178.74 -4,715.34 6,015,809.33 547,443.17 0.44 4,849.52 MWD+IFR2+MS+sag(2) 6,453.97 70.96 283.31 3,174.52 3,105.82 1,200.61 -4,801.94 6,015,830.60 547,356.41 2.06 4,938.63 MWD+IFR2+MS+sag(2) 6,548.10 70.02 283.82 3,205.95 3,137.25 1,221.42 -4,888.19 6,015,850.80 547,270.03 1.12 5,027.21 MWD+IFR2+MS+sag(2) 6,642.34 71.62 284.00 3,236.91 3,168.21 1,242.82 -4,974.59 6,015,871.59 547,183.49 1.71 5,116.02 MWD+IFR2+MS+sag(2) 6,737.12 71.39 284.36 3,266.98 3,198.28 1,264.84 -5,061.74 6,015,893.00 547,096.21 0.43 5,205.69 MWD+IFR2+MS+sag(2) 6,831.39 72.08 284.02 3,296.52 3,227.82 1,286.78 -5,148.52 6,015,914.33 547,009.27 0.81 5,294.99 MWD+IFR2+MS+sag(2) 6,925.71 70.67 282.79 3,326.65 3,257.95 1,307.51 -5,235.46 6,015,934.44 546,922.20 1.94 5,384.23 MWD+IFR2+MS+sag(2) 7,020.41 70.59 281.30 3,358.06 3,289.36 1,326.15 -5,322.83 6,015,952.47 546,834.71 1.49 5,473.52 MWD+IFR2+MS+sag(2) 7,114.71 70.72 281.48 3,389.30 3,320.60 1,343.72 -5,410.06 6,015,969.43 546,747.37 0.23 5,562.48 MWD+IFR2+MS+sag(2) 7,208.48 70.71 281.61 3,420.26 3,351.56 1,361.44 -5,496.78 6,015,986.54 546,660.54 0.13 5,650.96 MWD+IFR2+MS+sag(2) 7,302.94 70.26 281.75 3,451.82 3,383.12 1,379.46 -5,583.96 6,016,003.95 546,573.24 0.50 5,739.96 MWD+IFR2+MS+sag(2) 7,397.46 71.05 282.55 3,483.13 3,414.43 1,398.23 -5,671.15 6,016,022.11 546,485.93 1.16 5,829.09 MWD+IFR2+MS+sag(2) 7,492.24 72.17 283.97 3,513.03 3,444.33 1,418.86 -5,758.69 6,016,042.12 546,398.26 1.85 5,918.90 MWD+IFR2+MS+sag(2) 7,586.53 70.81 284.07 3,542.97 3,474.27 1,440.52 -5,845.43 6,016,063.17 546,311.37 1.45 6,008.11 MWD+IFR2+MS+sag(2) 7,681.07 76.35 284.55 3,569.68 3,500.98 1,462.94 -5,933.27 6,016,084.97 546,223.39 5.88 6,098.53 MWD+IFR2+MS+sag(2) 7,775.58 81.83 285.74 3,587.56 3,518.86 1,487.18 -6,022.81 6,016,108.58 546,133.69 5.93 6,190.94 MWD+IFR2+MS+sag(2) 7,869.74 81.14 286.87 3,601.50 3,532.80 1,513.32 -6,112.18 6,016,134.10 546,044.15 1.39 6,283.53 MWD+IFR2+MS+sag(2) 7,963.89 84.36 288.01 3,613.38 3,544.68 1,541.31 -6,201.27 6,016,161.46 545,954.87 3.62 6,376.17 MWD+IFR2+MS+sag(2) 8,058.97 83.71 287.97 3,623.27 3,554.57 1,570.52 -6,291.21 6,016,190.03 545,864.74 0.68 6,469.86 MWD+IFR2+MS+sag(2) 8,152.32 83.21 287.36 3,633.90 3,565.20 1,598.66 -6,379.58 6,016,217.55 545,776.18 0.84 6,561.82 MWD+IFR2+MS+sag(2) 8,247.34 82.47 287.04 3,645.74 3,577.04 1,626.54 -6,469.64 6,016,244.80 545,685.94 0.85 6,655.39 MWD+IFR2+MS+sag(2) 8,341.62 81.73 287.80 3,658.70 3,590.00 1,654.50 -6,558.75 6,016,272.13 545,596.65 1.12 6,748.03 MWD+IFR2+MS+sag(2) 8,436.35 84.31 288.40 3,670.21 3,601.51 1,683.71 -6,648.11 6,016,300.71 545,507.09 2.80 6,841.16 MWD+IFR2+MS+sag(2) 8,530.70 83.98 288.57 3,679.83 3,611.13 1,713.47 -6,737.13 6,016,329.84 545,417.88 0.39 6,934.04 MWD+IFR2+MS+sag(2) 5/19/2016 3:28:47PM Page 4 COMPASS 5000.1 Build 81 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-27 Project: Milne Point TVD Reference: MPJ-27 @ 68.70usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-27 @ 68.70usft(Doyon 14) Well: MPJ-27 North Reference: True Wellbore: MPJ-27 Survey Calculation Method: Minimum Curvature Design: MPJ-27 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) (°/100') (ft) Survey Tool Name 8,585.89 84.18 288.76 3,685.53 3,616.83 1,731.04 -6,789.14 6,016,347.04 545,365.75 0.50 6,988.33 MWD+IFR2+MS+sag(2) 8,685.92 85.80 290.75 3,694.26 3,625.56 1,764.72 -6,882.91 6,016,380.06 545,271.75 2.56 7,086.59 MWD+IFR2+MS+sag(3) 8,780.56 86.05 291.30 3,700.99 3,632.29 1,798.58 -6,971.03 6,016,413.31 545,183.41 0.64 7,179.31 MWD+IFR2+MS+sag(3) 8,874.35 91.54 291.01 3,702.96 3,634.26 1,832.41 -7,058.44 6,016,446.52 545,095.77 5.86 7,271.33 MWD+IFR2+MS+sag(3) 8,968.70 92.90 289.93 3,699.31 3,630.61 1,865.38 -7,146.76 6,016,478.87 545,007.23 1.84 7,364.10 MWD+IFR2+MS+sag(3) 9,063.72 91.54 289.49 3,695.62 3,626.92 1,897.40 -7,236.15 6,016,510.26 544,917.63 1.50 7,457.74 MWD+IFR2+MS+sag(3) 9,158.36 90.49 289.07 3,693.95 3,625.25 1,928.65 -7,325.46 6,016,540.88 544,828.10 1.19 7,551.17 MWD+IFR2+MS+sag(3) 9,252.19 90.80 289.55 3,692.89 3,624.19 1,959.67 -7,414.01 6,016,571.28 544,739.35 0.61 7,643.81 MWD+IFR2+MS+sag(3) 9,346.60 90.62 289.22 3,691.72 3,623.02 1,991.01 -7,503.06 6,016,601.98 544,650.09 0.40 7,737.00 MWD+IFR2+MS+sag(3) 9,440.03 90.31 287.20 3,690.96 3,622.26 2,020.20 -7,591.80 6,016,630.55 544,561.16 2.19 7,829.51 MWD+IFR2+MS+sag(3) 9,536.53 91.05 288.36 3,689.82 3,621.12 2,049.66 -7,683.69 6,016,659.37 544,469.08 1.43 7,925.16 MWD+IFR2+MS+sag(3) 9,630.84 89.94 287.59 3,689.00 3,620.30 2,078.77 -7,773.39 6,016,687.84 544,379.19 1.43 8,018.59 MWD+IFR2+MS+sag(3) 9,724.09 89.57 286.99 3,689.40 3,620.70 2,106.48 -7,862.42 6,016,714.93 544,289.97 0.76 8,111.13 MWD+IFR2+MS+sag(3) 9,817.48 89.20 287.08 3,690.40 3,621.70 2,133.84 -7,951.71 6,016,741.66 544,200.50 0.41 8,203.85 MWD+IFR2+MS+sag(3) 9,913.14 89.07 287.66 3,691.85 3,623.15 2,162.40 -8,043.00 6,016,769.58 544,109.02 0.62 8,298.75 MWD+IFR2+MS+sag(3) 10,008.01 89.38 289.03 3,693.13 3,624.43 2,192.25 -8,133.03 6,016,798.80 544,018.79 1.48 8,392.65 MWD+IFR2+MS+sag(3) 10,103.15 89.08 284.49 3,694.41 3,625.71 2,219.68 -8,224.10 6,016,825.58 543,927.54 4.78 8,487.13 MWD+IFR2+MS+sag(3) 10,197.66 91.30 282.58 3,694.10 3,625.40 2,241.80 -8,315.97 6,016,847.06 543,835.52 3.10 8,581.47 MWD+IFR2+MS+sag(3) 10,291.40 90.37 279.07 3,692.73 3,624.03 2,259.40 -8,408.02 6,016,864.01 543,743.36 3.87 8,675.18 MWD+IFR2+MS+sag(3) 10,385.88 90.49 275.72 3,692.02 3,623.32 2,271.55 -8,501.70 6,016,875.51 543,649.61 3.55 8,769.53 MWD+IFR2+MS+sag(3) 10,478.72 92.16 273.25 3,689.88 3,621.18 2,278.81 -8,594.22 6,016,882.12 543,557.05 3.21 8,861.87 MWD+IFR2+MS+sag(3) 10,574.59 92.04 270.92 3,686.36 3,617.66 2,282.30 -8,689.96 6,016,884.93 543,461.30 2.43 8,956.71 MWD+IFR2+MS+sag(3) 10,669.62 92.04 268.22 3,682.98 3,614.28 2,281.58 -8,784.91 6,016,883.56 543,366.36 2.84 9,050.05 MWD+IFR2+MS+sag(3) 10,763.35 91.73 267.04 3,679.90 3,611.20 2,277.71 -8,878.51 6,016,879.03 543,272.80 1.30 9,141.48 MWD+IFR2+MS+sag(3) 10,857.80 91.85 264.90 3,676.94 3,608.24 2,271.08 -8,972.68 6,016,871.74 543,178.70 2.27 9,232.99 MWD+IFR2+MS+sag(3) 10,951.23 92.04 264.91 3,673.77 3,605.07 2,262.78 -9,065.68 6,016,862.79 543,085.76 0.20 9,323.06 MWD+IFR2+MS+sag(3) 11,046.09 91.67 264.56 3,670.70 3,602.00 2,254.08 -9,160.09 6,016,853.43 542,991.42 0.54 9,414.44 MWD+IFR2+MS+sag(3) 11,140.87 91.54 265.72 3,668.05 3,599.35 2,246.06 -9,254.49 6,016,844.75 542,897.09 1.23 9,505.93 MWD+IFR2+MS+sag(3) 11,234.75 92.29 265.55 3,664.91 3,596.21 2,238.92 -9,348.05 6,016,836.95 542,803.59 0.82 9,596.74 MWD+IFR2+MS+sag(3) 11,329.74 93.89 265.50 3,659.79 3,591.09 2,231.52 -9,442.61 6,016,828.89 542,709.10 1.69 9,688.50 MWD+IFR2+MS+sag(3) 11,423.86 93.58 264.82 3,653.66 3,584.96 2,223.59 -9,536.19 6,016,820.31 542,615.58 0.79 9,779.20 MWD+IFR2+MS+sag(3) 11,517.41 93.58 265.26 3,647.82 3,579.12 2,215.52 -9,629.21 6,016,811.59 542,522.63 0.47 9,869.32 MWD+IFR2+MS+sag(3) 11,611.93 91.30 263.76 3,643.79 3,575.09 2,206.48 -9,723.20 6,016,801.90 542,428.71 2.89 9,960.23 MWD+IFR2+MS+sag(3) 11,706.31 91.42 264.95 3,641.55 3,572.85 2,197.20 -9,817.10 6,016,791.96 542,334.90 1.27 10,051.00 MWD+IFR2+MS+sag(3) 11,800.52 90.56 265.53 3,639.93 3,571.23 2,189.39 -9,910.97 6,016,783.49 542,241.09 1.10 10,142.00 MWD+IFR2+MS+sag(3) 11,893.29 91.73 264.92 3,638.07 3,569.37 2,181.67 -10,003.39 6,016,775.12 542,148.73 1.42 10,231.60 MWD+IFR2+MS+sag(3) 11,990.20 91.79 264.81 3,635.10 3,566.40 2,173.00 -10,099.87 6,016,765.78 542,052.33 0.13 10,325.02 MWD+IFR2+MS+sag(3) 12,084.32 90.74 263.65 3,633.02 3,564.32 2,163.54 -10,193.49 6,016,755.66 541,958.79 1.66 10,415.49 MWD+IFR2+MS+sag(3) 12,178.92 89.82 263.47 3,632.56 3,563.86 2,152.93 -10,287.49 6,016,744.40 541,864.87 0.99 10,506.12 MWD+IFR2+MS+sag(3) 12,273.17 90.86 263.72 3,632.00 3,563.30 2,142.41 -10,381.15 6,016,733.23 541,771.30 1.13 10,596.44 MWD+IFR2+MS+sag(3) 5/19/2016 3:28:47PM Page 5 COMPASS 5000.1 Build 81 0 Halliburton 0 Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPJ-27 Project: Milne Point TVD Reference: MPJ-27 @ 68.70usft(Doyon 14) Site: M Pt J Pad MD Reference: MPJ-27 @ 68.70usft(Doyon 14) Well: MPJ-27 North Reference: True Wellbore: MPJ-27 Survey Calculation Method: Minimum Curvature Design: MPJ-27 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (01100) (ft) Survey Tool Name 12,366.84 93.70 262.86 3,628.27 3,559.57 2,131.48 -10,474.09 6,016,721.65 541,678.44 3.17 10,685.99 MWD+IFR2+MS+sag(3) 12,461.38 94.08 262.56 3,621.86 3,553.16 2,119.51 -10,567.65 6,016,709.02 541,584.98 0.51 10,775.95 MWD+IFR2+MS+sag(3) 12,555.79 93.21 262.76 3,615.85 3,547.15 2,107.47 -10,661.10 6,016,696.33 541,491.63 0.95 10,865.79 MWD+IFR2+MS+sag(3) 12,650.84 93.33 263.62 3,610.43 3,541.73 2,096.22 -10,755.32 6,016,684.42 541,397.49 0.91 10,956.53 MWD+IFR2+MS+sag(3) 12,744.49 94.26 265.16 3,604.23 3,535.53 2,087.09 -10,848.31 6,016,674.64 541,304.57 1.92 11,046.44 MWD+IFR2+MS+sag(3) 12,838.99 94.57 265.54 3,596.96 3,528.26 2,079.45 -10,942.22 6,016,666.34 541,210.73 0.52 11,137.52 MWD+IFR2+MS+sag(3) 12,933.44 93.52 266.10 3,590.30 3,521.60 2,072.58 -11,036.19 6,016,658.82 541,116.83 1.26 11,228.78 MWD+IFR2+MS+sag(3) 13,026.80 93.77 265.37 3,584.36 3,515.66 2,065.65 -11,129.10 6,016,651.24 541,023.97 0.83 11,319.00 MWD+IFR2+MS+sag(3) 13,119.98 92.78 265.08 3,579.04 3,510.34 2,057.91 -11,221.80 6,016,642.85 540,931.34 1.11 11,408.87 MWD+IFR2+MS+sag(3) 13,216.12 93.39 264.53 3,573.86 3,505.16 2,049.22 -11,317.41 6,016,633.49 540,835.80 0.85 11,501.43 MWD+IFR2+MS+sag(3) 13,309.64 92.84 264.74 3,568.78 3,500.08 2,040.48 -11,410.38 6,016,624.11 540,742.90 0.63 11,591.39 MWD+IFR2+MS+sag(3) 13,405.27 93.15 264.11 3,563.79 3,495.09 2,031.21 -11,505.43 6,016,614.17 540,647.93 0.73 11,683.29 MWD+IFR2+MS+sag(3) 13,499.83 92.41 263.91 3,559.20 3,490.50 2,021.35 -11,599.36 6,016,603.65 540,554.08 0.81 11,773.99 MWD+IFR2+MS+sag(3) 13,593.75 92.41 264.07 3,555.25 3,486.55 2,011.53 -11,692.68 6,016,593.18 540,460.84 0.17 11,864.10 MWD+IFR2+MS+sag(3) 13,688.75 91.11 263.68 3,552.33 3,483.63 2,001.39 -11,787.09 6,016,582.39 540,366.51 1.43 11,955.23 MWD+IFR2+MS+sag(3) 13,783.24 90.68 262.38 3,550.86 3,482.16 1,989.93 -11,880.87 6,016,570.27 540,272.82 1.45 12,045.50 MWD+IFR2+MS+sag(3) 13,871.23 90.49 262.63 3,549.96 3,481.26 1,978.45 -11,968.10 6,016,558.18 540,185.68 0.36 12,129.32 MWD+IFR2+MS+sag(3) 13,940.00 90.49 262.63 3,549.37 3,480.67 1,969.63 -12,036.30 6,016,548.88 540,117.55 0.00 12,194.88 PROJECTED to TD hn.W+a•eau..w..�awwna<o-. A9^SN+ro,,r.c o4o Checked By: b'a""�'"@�1fbu o"`°"On.2`0'_31� Approved By: Cary Taylor ;", ., Date: 5/19/2016 3:28:47PM Page 6 COMPASS 5000.1 Build 81 •• Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. MP J-27 Date Run 7-May-16 County State Supv. Sloan Sunderland/Doug Yessak CASING RECORD Surface V TD 8,630.00 Shoe Depth: 8,620.00 PBTD: 8,533.00 No.Jts.Delivered 212 No.Jts.Run 211 No.Jts.Returned 1 Ftg.Delivered 8,659.61 Ftg.Run 8,579.01 Ftg.Returned 40.82 Length Measurements W/O Threads Ftg.Cut Jt. 33.40 Ftg.Balance 11.14 Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top SHOE 9 5/8 40.0 L-80 TCII 2.89 8,620.00 8,617.11 1 1T 9 5/8 40.0 L-80 TCII 41.16 8,617.11 8,575.95 FLT COLLAR 9 5/8 TCII 2.01 8,575.95 8,573.94 2 1T 9 5/8 40.0 L-80 TCII 40.10 8,573.94 8,533.84 CROSSOVER 9 5/8 40.0 L-80 TCII X DWC 5.77 8,533.84 8,528.07 BAFFLE 95/8 DWC 1.82 8,528.07 8,526.25 143 JT 9 5/8 40.0 L-80 DWC 5,561.46 8,526.25 2,864.79 ES CEMENTR 9 5/8 DWC 3.11 2,864.79 2,861.68 211 JT 9 5/8 40.0 L-80 DWC 2,828.28 2,861.68 33.40 RKB 33.40 33.40 Csg Wt.On Hook: 400,000 Type Float Collar DHP USA No.Hrs to Run: 24 Csg Wt.On Slips: 125,000 Type of Shoe: DHP USA Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg Yes X No 50 Ft.Min. 9.4 PPG Fluid Description: Spud mud Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes_ No Centralizer Placement: 2 CENTRALIZERS ON SHOE JT 10'FROM EA.END.1 CENTRALIZER MID TUBE ON FLT COLLAR JT.1 EVERY OTHER JT ON FIRST 15 JTS RAN,5 CENTRALIZERS BELOW ESC AND 5 CENTRALIZERS ABOVE ESC ON FIVE JTS.11 CENTRALIZERS TOTAL. CEMENTING REPORT Shoe @ 8620 FC @ 8,574.00 Top of Liner Preflush(Spacer) Type: Spacer Density(ppg) 10.5 Volume pumped(BBLs) 46.6 Lead Slurry Type: ExtendaCem 915 sx/yield=2.503 ft3/sk Density(ppg) 11.7 Volume pumped(BBLs) 408 Mixing/Pumping Rate(bpm): 4.5 Tail Slurry w Type: SwiftCem 390 sx/yield=1.13 ft3/sk F Density(ppg) 15.8 Volume pumped(BBLs) 79 Mixing/Pumping Rate(bpm): 4 F Post Flush(Spacer) 'SLL Type: Density(ppg) Rate(bpm): Volume: Displacement: Type: Mud Density(ppg) 9.4 Rate(bpm): 5 Volume(actual/calculated): 568/568 f FCP(psi): 1000 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1500 ✓ Casing Rotated? �, _Yes X No Reciprocated? Yes X No %Returns during job '.QO Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 90 Cement In Place At: 9:12 Date: 5/8/2016 Estimated TOC: 2,862 Method Used To Determine TOC: Calculation Stage Collar @ 2862 Type ES Cementer Closure OK yes Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 10.5 Volume pumped(BBLs) 60 Lead Slurry Type: ExtendaCem 380 sx/yield=4.506 ft3/sk Density(ppg) 10.7 Volume pumped(BBLs) 305 Mixing/Pumping Rate(bpm): 4.5 Tail Slurry ✓` Type: SwiftCem 270 sx/yield=1.16 ft3/sk L,..4 N Density(ppg) 15.8 Volume pumped(BBLs) 56.2 Mixing/Pumping Rate(bpm): 3 o Post Flush(Spacer) z w Type: Density(ppg) Rate(bpm): Volume: N Displacement: Type: Mud Density(ppg) 9.4 Rate(bpm): 5 Volume(actual/calculated): 198.2/198.2 FCP(psi): 710 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1680 Casing Rotated? _Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 250 Cement In Place At: 20:50 Date: 5/8/2016 Estimated TOC: 0 Method Used To Determine TOC: Visual Post Job Calculations: Calculated Cmt Vol @ 0%excess: 507 Total Volume cmt Pumped: 967.4 Cmt returned to surface: 340 Calculated cement left in wellbore: 627 OH volume Calculated: OH volume actual: Actual%Washout: www.wellez.net WellEz Information Management LIC ver_041416bf i • MPJ-27 Days vs Depth FINAL o �--- 500 MPJ-27 Actual 1000 MPJ-27 Plan 1500 MPJ-27 Stretch Goal 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 L a 7000 GJ v 7500 p N 8000 co 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 _ 15000 0 5 10 15 20 25 30 35 Days 11/ • MPJ-27 MW vs Depth 0 _ MPJ-27 Plan 1000 MPJ-27 Actual 2000 3000 4000 5000 a 6000 ai v ar 7000 ar 8000 _ 9000 10000 11000 - 12000 13000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) • • 215153 Maile Sweigart 2 7 2 1 9 Alaska North Slope Team RECEIVED Hilcorp Alaska, LLC 3800 Centerpoint Drive, Ste 1400 Anchorage,Alaska 99503 H lrnr�i A4irka,Elk MAY 2 �� Office: 907.777.8473 msweigart@hilcorp.com lA O 'CC DATA LOGGED 5!ZG/2016 !v, K BENDER Date: 5/24/2016 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MP J-27 J-27 Prints: DGR-ADR-EWR-HORIZONTAL PRES 2IN MD,DGR-ADR-EWR INV/REV INTERVALS 21N TVD E log data CD 1 : Final Well Data Name Date modified Type A files Currently on the Disc (6) CGM 5/23/20161:49 PM File folder Definitive Survey 5/23/2016 1:49 PM File folder DLIS+LAS 5/23/20161:49 PM File folder EMF 5/23/20161:49 PM File folder PDF 5/23/2016 1:49 PM File fclder 416 TIFF 5/23/2016 1:49 PM File folder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received Date: udh&�'.ai1?�GV 6 .em-geot OF TfJ� • • w\��I 77 ,& THE STATE Alaska Oil and Gas of Conservation Commission dAsKA z __ 333 West Seventh Avenue �` `5 / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Iii . . Main: 907.279.1433 of ALAS"- Fax: 907.276.7542 www.aogcc.alaska.gov Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-27 Hilcorp Alaska, LLC Permit No: 215-153 Surface Location: 2265' FSL, 3155' FEL, SEC. 28, T13N, R10E, UM, AK Bottomhole Location: 1017' FNL, 770' FWL, SEC. 30, T13N, R10E, UM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster p Chair DATED this D day of September, 2015. r 0 STATE OF ALASKA 4 � D ALASKA OIL AND GAS CONSERVATION COMMISSION ��(a `� 2O15 PERMIT TO DRILL 20 AAC 25.005 ®0 0 C C 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil Q• Service- Winj ❑ Single Zone Q . 1 c. pecify if well is proposed for: Drill ❑., • Lateral El Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas El 2.Operator Name: 5. Bond: Blanket 0 Single Well El 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 MPU J-27- 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 13,701' . TVD: 3,589' • Milne Point Unit ` 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Schrader Bluff Oil Pool - Surface: 2265'FSL,3155'FEL,Sec 28,T13N,R10E,UM,AK (SHL)ADL 025906/(TPH/BHL)ADL 025517 '.)„- t j CAA.) Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1399'FNL,969'FWL,Sec 29,T13N,R10E,UM,AK N/A 11/15/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1017'FNL,770'FWL,Sec 30,T13N,R10E,UM,AK 5115 Acres 6,209'from Unit Boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: ‘ 65 feet 15.Distance to Nearest Well Open Surface: x-552166.18 y- 6014663.74 Zone-4 ' GL Elevation above MSL: ' 35 feet to Same Pool: 95'from J-20A 16.Deviated wells: Kickoff depth: -300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 92 degrees Downhole: 1655 psi N. Surface: 1285 psi • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) Cond - 20" 78.6# A-53 Weld 80' 0 0 110' 110' Driven Stg#1 Lead-2094 ft3/Tail-445 ft3 12-1/4" 9-5/8" 40# L-80 TC-II 8,247' 0 0 8,247' 3,665' Stg#2 Lead-1565 ft3/Tail-314 ft3 7-5/8" 29.7# L-80 VAM STL 8,100' 0 0 8,100' 3,653' Tieback Liner Assy. 8-1/2" 4-1/2" 11.6# L-80 HYD 521 5,601' 8,100' 3,653' 13,701' 3,589' Cementless Production Liner t`w'',."prJ Sc,r eiitA 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) /., y,3,.,3- Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): ' Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat ❑✓ BOP Sketch ❑✓ Drilling Program Q Time v.Depth Plot j Shallow Hazard Analysis Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luke Keller Email Ikeller@hilcorp.com Printed Name Luke eller Title Drilling Engineer Signature Phone 907-777-8395 Date 3f/4.(47/3---- Commission Use Only Permit to DrillAPI Number: Permit Approval See cover letter for other Number: lot'c--- /`_ 50- 9aQ -p/ --'IO-OJ Date: 15 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: i Other: 3 O0x; i,,,L, 6 0 1� S Samples req'd: Yes❑ [1 Mud log req'd:Yes❑ No Zr —�� H2S measures: Yes ❑ Directional svy req'd:Yes 2'"-No.14 ' 74 Z_S C 1 �5 Al '� "� 1 z� Spacing exception req'd: Yes El No[.� Inclination-only svy req'd:Yes❑ No2r APPROVED BY Approved by: - .(,i -- COMMISSIONER THE COMMISSION Date -( --f?""( u6mit Fong and Form 10-401(R ,..ed 10/2 11215 OiRrltlivtlNrAnIths froe da Of epbfoyai(2FO A 25 005 4 achments in Duplicate • s II RECEIVED Hilcorp Luke Keller Hilcorp Alaska, LLC AUG 2 4 2015 Energy Company Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8395 8/24/2015 Email Ikeller@hilcorp.com Commissioner Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: MPJ-27 Permit to Drill Dear Commissioner, MPU J-27 is a grassroots ESP producer planned to be drilled in the Schrader Bluff NB sand. J-27 is part of a(4)well pilot program targeting the NB sand. The directional plan is a catenary wellpath build with 9-5/8" surface casing set into the top of the Schrader Bluff NB sand. A lateral section will then be drilled. A wire wrapped screen liner will be run in the open hole section and the well produced with an ESP assembly. Drilling operations are expected to commence approximately Nov 15th, 2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. lz_________ Sincerely, ./'"'"---/ Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • S Hilcorp Alaska, LLC Milne Point Unit (MPU) J-27 Drilling Program Version 1 August 20th, 2015 • 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 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 21-1/4"2M Diverter System 11 11.0 Drill 12-1/4"Hole Section 14 12.0 Run 9-5/8"Surface Casing 18 13.0 Cement 9-5/8" Surface Casing 24 14.0 BOP N/U and Test 29 15.0 Drill 8-1/2"Hole Section 30 16.0 Run 5-1/2"Production Liner 34 17.0 Run ESP assy. 39 18.0 RDMO 40 19.0 Diverter Schematic 41 20.0 BOP Schematic 42 21.0 Wellhead Schematic 43 22.0 Days Vs Depth 44 23.0 Formation Tops 45 24.0 Anticipated Drilling Hazards 46 25.0 Nordic#3 Rig Layout(Drillers Side) 48 26.0 Nordic#3 Rig Layout(Well End&Top View) 49 27.0 FIT Procedure 50 28.0 Choke Manifold Schematic 51 29.0 Casing Design Information 52 30.0 8-1/2"Hole Section MASP 53 31.0 Spider Plot(NAD 27)(Governmental Sections) 54 32.0 Surface Plat(As Built)(NAD 27) 55 33.0 Offset MW vs TVD Chart 56 34.0 Drill Pipe Information 5" 19.5#S-135 DS-50 57 • ! Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well MPU J-27 Pad Milne Point"J"Pad Planned Completion Type ESP on 2-7/8"Production Tubing Target Reservoir(s) Schrader Bluff NB Sand Planned Well TD, MD/TVD 13,701' MD/3,589' TVD PBTD, MD/TVD 13,690' MD/3,589' TVD Surface Location(Governmental) 2265' FSL,3155' FEL, Sec 28, T13N,R10E, UM,AK Surface Location(NAD 27) X=552,166.18 Y=6,014,663.74 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1399'FNL, 969' FWL, Sec 29, T13N,R10E,UM,AK TPH Location(NAD 27) X=545715.32,Y=6016237.28 TPH Location(NAD 83) BHL(Governmental) 1017'FNL, 770' FWL, Sec 30, T13N,R10E,UM,AK BHL(NAD 27) X=540274.01, Y=6016587.28 BHL(NAD 83) AFE Number 1511626 AFE Drilling Days 12 days AFE Completion Days 4 days AFE Drilling Amount $3,567,142.00 AFE Completion Amount $2,540,500.00 AFE Facility Amount $381,000.00 Maximum Anticipated Pressure (Surface) 1285 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1655 psig Work String 5" 19.5# S-135 DS-50(Weatherford Rental) KB Elevation above MSL: 30 ft+35 ft=65 ft GL Elevation above MSL: 35 ft BOP Equipment 11"x 5M Annular,(3)ea 11"x 5M Rams Page 2 Version 1 August, 2015 I • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Enemy Company Changes to Approved Permit to Drill Date: 8-10-2015 Subject: Changes to Approved Permit to Drill for J-27 File#: J-27 Drilling and Completion Program Any modifications to J-27 Drilling& Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the BLM and AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 1 August, 2015 S Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 20" 19.25" - - 78.6 A-53 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.235" 40 L-80 TC-II 5,750 ' 3,090 916 7-5/8" 6.82" 6.75" 7.711" 29.7 L-80 VAM sTL 6,890 4,790 473 8-1/2" 4-1/2" 3.96 3.875 4.695 11.6 L-80 H521i1 7780 / 6350 267 4.0 Drill Pipe Information: Hole OD(in) ID (in) TJ ID TJ OD Wt Grade Conn M/U M/U Tension Section (in) (in) (#/ft) (Min) (Max) (k-lbs) All 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 August,2015 • s Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 5.0 Internal Reporting Requirements 18.1 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. 18.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini(ahilcorp.com , Ikeller@hilcorp.com and cdinger@hilcorp.com 18.3 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. 18.4 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drlg Manager& Drlg Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 18.5 Casing Tally • Send final"As-Run"Casing tally to lkeller@hilcorp.com and cdinger@hilcorp.com 18.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and cdinger(a)hilcorp.com 18.7 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 Luke Keller 907.777.8395 832.247.3785 Ikeller@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Keith Elliot 907.777.8355 832.233.5855 kelliott@hilcorp.com Drlg Environmental Coord Julieanna Orczewska 907.777.8444 907.715.7060 jorczewska@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 jiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 1 August,2015 • S II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 6.0 Planned Wellbore Schematic AFE No. Well Name: KB: 30 ft AGL 1511625 Milne Point Unit(MPU)J-27 01+RKB 35 ft+30 ft=65 ft API# AFE WELLBORE DESIGN Proposed TD: 13.701' Permit No. Proposed TVD: 3.589' Geologic Information Wellbore Informatics Casing Info%Mud Info i Hole Size,Cement Specs RKB-Tubing Hanger Mod Program SS TVD FM Lithology Conductor 20"conductor(Pre-set)to 80'BGL(110'RKB) b,terVal, I ' sunaee Hair Surface Casing ar n� 9-5/8"40#L-80 TC-II set at 8,247'MD I 3,665'TVD F,e.nwater.N lve 5 /,4,, µ_`� •i eget Range oc° Surface Casing Cement ae__g.z 2 `, 1st Stage: E B ;' I: 60 bbls 10.5 ppg Tuned spacer III a Lead:(30%OH Excess)ARCTICCEM© 10.7 ppg 3 Tail:(30%OH Excess)SWIFTCEM 15.8 ppg 2nd stage: 60 bbls 10.5 ppg Tuned spacer III [ Lead:(Until returns at surface)ARCTICCEM 10.7 ppg 1750' Tail:SWIFTCEM 15.8 ppg tStage Collar Production Liner m 4-1/2"Screens c/w base pipe: "_ 4' A - 11.6#L-80 Hydril 521screens a 13,701'MD 13,589'TVD CI Y a 0 - Tieback o s d a 7-5/8"29,7#L-80 VAM STL @ 8100'MD 13,665'TVD — u , m ` Production Tubing `^ a 3 ' 2- 7/8"6.4#L-80 8RD EUE IS o 's rT' t d s s ti r' "3500' ''- Om = ESP L nor Top Packer Wire wrapped screen production Liner K-sands Coarse sand,silty shale,better imenrac Bullet Seal Assy UGNU developed Ptede[rlm rare L-Sands intervening shales14114111.11, .1d, y type, --4000' M-sands in the L and M //Mg, ` N-sands Continued layering as t Schrader in Ugnu.more g ' �� I I , f ! � M 0-sands condensed with occ. 7 -43E0 coal , _...-..__._._... ..__._..._. .._..._....._ 1 3 6' 9-wr Shoe Page 6 Version 1 August, 2015 S Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary MPU J-27 is a grassroots ESP producer planned to be drilled in the Schrader BluffNB sand. J-27 is part of a (4)well pilot program targeting the NB sand. The directional plan is a catenary wellpath build with 9-5/8" surface casing set into the top of the Schrader Bluff NB sand. A lateral section will then be drilled. A wire wrapped screen liner will be run in the open hole section and the well produced with an ESP assembly. Drilling operations are expected to commence approximately Nov 15th, 2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. Surface casing will be run to 8,247' MD/3,665' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cmt 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 authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point "A" pad G&I facility. General sequence of operations: 1. MOB Nordic Rig#3 to well site. 2. N/U 21-1/4" conductor and 16" diverter line. 3. Drill 12-1/4"hole to TD of surface hole section. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U & test 11"x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 5-1/2" slotted liner. 6. Run 7-5/8" Tieback. 7. Run ESP assy. 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR+ Res v� 2. Production Hole: No mud logging. On site geologist. LWD: GR+ADR(For geo-steering) Page 7 Version 1 August,2015 • S Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. 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 J-27. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, 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". • 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 August,2015 • Milne Point Unit Producer Drilling Procedure Hilcorp Enmgy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"2M diverter w/16"diverter line Function Test Only • 11"x 5M Hydril Annular BOP • 11"x 5M Shaffer Double Ram Initial Test:250/3000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross w/3"x 5M side outlets 8-1/2" • 11"x 5M Hydril Single Ram • 3"x 5M Choke Line Subsequent Tests: • 3"x 5M Kill line 250/3000 • 3"x 5M Choke manifold(10M Hydraulic remote Choke (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Hydril, 165 gal, 6 station accumulator w/dual electric and air pumps, w/ 1 (ea) electric over hydraulic remote control panel at the driller station. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Tertiary pressure is provided by air pumps. 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:guv.schwartz(a alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.loepp@alaska.gov Primary Contact for Opportunity to witness:AOGCC.Inspectors(a�alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNoti£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 August, 2015 i Milne Point Unit Producer Drilling Procedure Hilcorp Encigy Company 9.0 R/U and Preparatory Work 9.1 20" conductor has been preset at 80' BGL (110' RKB). 9.2 Dig out and set impermeable cellar inside of existing cellar. 9.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.4 Install Seaboard slip-on 16-3/4" 3M"A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.5 Insure (2) 3"threaded nipples are installed on opposite sides of the conductor with ball valves on each nipple. These will be used to take cement returns to the cellar during the surface cmt job, and also to wash out the diverter and hanger in preparation for running the pack-off. 9.6 Level pad and ensure enough room for layout of rig footprint and R/U. 9.7 Rig mat over footprint of rig. 9.8 Confirm that the rig is over the appropriate well slot. 9.9 MIRU Nordic #3. 9.10 Mud loggers WILL NOT be used on either hole section. 9.11 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 9.12 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.13 Install 5-1/2" liners in mud pumps. • Continental EMSCO F-1000 mud pumps are rated at 3500 psi (100%)/354 gpm(120 spm @ 95% eff)with 5-1/2" liners. Page 10 Version 1 August, 2015 • S Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4"Hydril MSP 2M diverter System(Diverter Schematic at Sec 18 at back of program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • N/U 21-1/4"diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 11 Version 1 August, 2015 Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 10.5 Pad Drawin ' a TIMPI »w ttiI u ■ —. I� L_L =■ C I .■ P I `J n■ Dt k■ ■r F■ ■" it Mob' =NM la 1 ■ E yt:!=— --r--r. nf X.. I r.■ P4 F 1 F,Vs�� - i Page 12 Version 1 August, 2015 • 11 Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 10.6 Ri• & Diverter Orientation on"J" sad: .,- � , [) verte[- Lne L. .F < .'�1M -� n 41147,013 3dld ❑ (iJ P144n - : 1 I '3, 6 a � 1 I C' I1 LL i - r:. L...1... n+'d'aa e mdv ,:,., l z 11- 11-1 — U dLi V313 3d1d ❑ Page 13 Version 1 August,2015 I i 11 Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure Gyro MWD is R/U and operational. 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. • Workstring will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 11.2 12-1/4" BHA (GR+ Res LWD and PWD planned in surface hole): HALLIBURTON WELL INFORMATION Created On:May 01 2015 BHA TallCustomer : Hilcorp Engergy Y Well Name : P.1PL-1 Job Number : -XX- Drillstring Rig Name : Nordic 3 IADC Rig BHA# Field Name : Milne Point Run# 100 Country : USA COMPONENT DATA 111.1.1111111111111111111111 MP Item OD ID Gauge Weight 'Top Length Cumuiat .. Description Serial Number (in) tin) (in) (Ibpt) Connection (ft) Length in E. PDC 8.000 3.000 12.250 147.22 P 6-5/B"REG 1.10 1.10 © 8"SpenyDrel Lobe 415-5.3 stg 8.000 5.000 103.09 B 6-518"REG 31.47 32.57 - Stabilizer -__ 12.125 © Float Sub 8.000 2.880 149.10 B 6-5;8"REG 240 34.97 Ell Stabilizer 8.000 3.000 10.250 147.22 B 6-5118"REG 6.00 40.97 ® 8"DM Collar 8.000 3.500 147.40 B 6-5+8"REG 9.20 50.17 lal 8"DGR Collar 8.000 1.920 142.70 B 6-518"REG 4.55 54.72 Eli 8"EWR-P4 Collar 8.000 1.985 151.00 B 6-518"REG 12.19 66.91 8 8"HCIM Collar 8.000 1.920 149.90 B 6-516"REG 4.97 71.88 0 8"POS PULSER 8.000 4.000 145.20 B 6-5;8"REG 15.44 87.32 10 Orienting Sub UBHO 8.000 2.875 149.18 B 6-516"REG 2.50 89.82 ® NM Flex Collar 8.000 2.813 150.13 B 6-5+8"REG 31.00 120.82 ® NM Flex Collar 8.000 2.813 150.13 B 6-518"REG 31.00 151.82 ® NM Flex Collar 8.000 2.813 150.12 B 6-5+8"REG 31.00 182.82 - 80 x 5"X 3"HWDP#49.3-NC50(IF)- 5.000 3.000 49.30 240.00 422.82 ® Jar 7.500 2.813 129.38 B 4-1;2"IF 35.00 457.82 m12jts x 5'X 3"H FDP#49.3-NC50 5.000 3.000 49.30 360.00 817.82 x. .. ;''q 817.82 Page 14 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 11.3 Primary Bit: 12-1/4" {311mm) QHCIGRC PRODUCT SPECIFICATIONS IADC Code 117W �; Total Tooth Count 67 Gage Row-Tooth Count 39 Journal Angle 33° * olov Offset(1/16") 6 Jet Nozzle Types Standard 83244 Extended 302447 .. Center Jet (If Center Jetted)501813 • T.J.Connection 6-5/8"(API Reg.) Recommended Make-Up Torques 28000/32000 Felbs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) Bit Breaker (Mat.firLegacyti) 515353/506463 PRODUCT FEATURES 'r° *°-. New patented Diamond"Claw R tooth bit design. * tit . Tungsten carbide'surf inserts in gage teeth for added gage protection. . Newly formulated,proprietary hardfacing on cutting structure and rr (, gage maximizes carbide and diamond volume for ultimate wear A = resistance. . Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. • QuadPacktl`Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems . Dual sealldual compensation bearing system containing dual seals, dual independent pressure compensators,and a dual grease formulation. . The latest OCP seal technology designed with the highest contact pressures on the outside edges of the seal where it is needed most. Material#740990 helps keep contaminants out extending bearing life. "Calculations based on rcconunendations from API and tool joint manufactur.rs. C 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will he in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www,halliburton.com 11.4 5" Workstring, HWDP, and Jars will come from Weatherford. 11.5 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 8,247' MD/3,665' TVD."Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. Page 15 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. ESP equipment can be damaged if run through high dog legs. Keep DLS <6 deg/ 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 600 - 650 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Ensure to leave a"Pump Tangent" section that is approx. 300' long in the directional plan. The ESP will need a straight section to sit. This will occur very near TD of the hole section. • Make wiper trips every 2000' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. �? • TD the hole section just into the Schrader Bluff OA sand. Geologists and Drilling Engineers will help adjust well path to ensure well is landed correctly. • Take MWD surveys every stand drilled(60' intervals). • Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas cut mud before continuing to drill. There have been no indications of hydrates on any of the "L"pad wells to date. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. Page 16 Version 1 August,2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 11.7 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: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM(10 ppb total)BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5—9.0 range with caustic soda. Daily additions of ALDACIDE G/X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce sstem YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP<20(check with the cementers to see what YP value they have targeted). System Type: 8.8—9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Densit Viscosity Plastic Viscosity Yield Point API FL pH 80-8,247' 8.8—9.2 85-250 20-40 25-75 <10 8.5—9.0 ~'—'System 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—9.2 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb Page 17 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 20" conductor shoe. 11.9 Should backreaming be necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 3 —4 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (600—700 gpm), and maximize rotation. • Pull slowly, 5— 10 ft/minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.10 TOH with the drilling assy, handle BHA as appropriate. 11.11 No open hole logging program planned. 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 Make a dummy run with the 9-5/8" casing hanger. 12.3 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" TC-II x DS50 XO on rig floor and M/U to FOSV. • Consider R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 12.4 P/U shoe joint, visually verify no debris inside joint. 12.5 Continue M/U & thread locking shoe track assy 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. Page 18 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company Bypass Baffle This end up. 011111111% (tat • (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 19 Version 1 August,2015 0 • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 12.6 Float equipment and Stage tool equipment drawings: "A f '°`— Overall Length j Type hl ES Cementer B Part No. Min.ID After Drillout nSO No. C Max.Tool OD 0 e I. - D Hilcorp ES-II Running order ~E"' IOpening Seat ID A Closing Sleeve - No.Shear Pins E a;-*D.- Closing Seat ID Opening Sleeve i�I C Iii No.Shear Pins Plug Set ' It J� ES-II Cementer ES Cementer Part No. Depth T I+Brt1 SO No. 4 airClosing Plug w W T II� Ba"'e Adapter(Id used) OD �— shut Off Plug . ID Opening Plug ■ Depth OD iBaffle Adapter OD a 4 .. I Bypass or Shut-off Baffle s� ID By-Pass Plug ir,I D: Iar th Shut-off Plug *__IDt Depth By Pass Baffle lar OD Float Collar Float Shoe Depth Bypass Plug (if used) IM Hole TD From shoe "Reference Casing rn OD Sales Manual _ Section 5 Page 20 Version 1 August, 2015 • • Milne Point Unit Producer 11 Drilling Procedure Hilcorp Enemy Company 12.7 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use Jet Lube Seal or BOL 72733 thread compound. Dope pin end only w/paint brush. • Install (1) centralizer every other joint for the first 15 joints. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cmt returns to surface. 12.8 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100' TVD below the permafrost. • Install centralizers over couplings on 5 joints below and above stage tool. • Do not place tongs on ES cementer,this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. 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 TC-II Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 11,600 ft-lbs 13,600 ft-lbs Page 21 Version 1 August,2015 • • 11 Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Slze(O.D.): Weight (Wall): Grade: TC-Il Casing 9-5/6 in 40.00 lb/ft(0.395 in) L-80 standard Material L-80 Grade NNW 80.000 Minimum Yield Strength (psi) NNNNNNNINVUSA 95.000 Minimum Ultimate Strength (psi) VAM USA Pipe Dimensions 4424 W.Sam Houston Pkwy.Suite 150 Pipe BodyO.D. (in) Houston, 3-77041 9.625 Nominal Pi P Phone:713-479-3200 8.835 Nominal Pipe Body I.D.(in) Fax:713-479-3234 0.395 Nominal Wall Thickness (in) E-ma11:VAMUSAsales;�uva>t,usa.com 40.00 Nominal Weight (lbs/ft) 38.97 Plain End Weight (lbs/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) 1/ 5.750 Minimum Internal Yield Pressure (psi) it 5.300 Hydrostatic Test Pressure (psi) Connection Dimensions 1110, 10.235 Connection O.D. (in) 8.835 Connection I.D. (in) 14, 8.750 Connection Drift Diameter (in) Si 5.23 Make-up Loss(in) d Connection Performance Properties 916.000 (1) Joint Strength (lbs) 16,360 Reference String Length (ft) 1.4 Design Factor 916.000 Compression Rating (lbs) 3.090 Collapse Pressure Rating (psi) 5.750 Internal Pressure Rating (psi) 38.1 Maximum uniaxial bend rating [degrees/100 ft] Recommended Torque Values 11.600 (2) Minimum Final Torque (ft-lbs) 13.600 (2) Maximum Final Torque (ft-lbs) Page 22 Version 1 August, 2015 • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.12 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.13 Have emergency slips ready to go in the event we can not land the hanger. 12.14 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. Elevate hanger slightly above hang off point while circulating to avoid plugging the flutes. 12.15 After circulating, lower string and land hanger in wellhead again. Page 23 Version 1 August,2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt 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 cmt unit at acceptable rates. • How to handle cmt 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 cmt operation. • Review test reports and ensure pump times are acceptable. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cmt pump or treating iron will not be pumped downhole. 13.4 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.5 Pump 5 bbls LQ 5 pps tuned spacer. Test surface cmt lines. 13.6 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug(flexible bypass plug). Mix and pump cmt per below recipe for the 1st stage. 13.8 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: syf Section: Calculation: Vol(BBLS) Vol(ft3) 12-1/4" OH x 9-5/8" Casing (7,247'- 2100')x .0558 bpf x 1.3 = 373 bbls 2094 ft3 annulus: Ct4 l Total LEAD: 373 bbls 2094 ft3 12-1/4" OH x 9-5/8" Casing (8247'- 7247')x .0558 bpf x 1.3 = 72.5 bbls 407.3 ft3 annulus: 9-5/8" Shoe track: 90 x .0758 bpf = 6.8 38.3 Total TAIL: 79.3 bbl 445 ft3 S-315;( Page 24 Version 1 August,2015 • O Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company Cement Slurry Design: Lead Slurry Tail Slurry System ArcticCEM TM System SwiftCEM TM System Density 10.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed 21.13 gal/sk 5.04 gal/sk Water 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 15t5v 8150' x .0758 bpf=418 bbls mud, 80 bbls water, 119 bbls mud_ = 1 The 80 bbls of water must be left across stage tool to ensure proper operation once opened. 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. Page 25 Version 1 August, 2015 • S Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 13.13 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. We will over displace first before doing this. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 Increase pressure to 2700 psi to open circulating ports in stage collar. Slightly higher pressure /L-j may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface. Circulate until YP <20 again in preparation for the 2nd stage of the cement job. 13.16 Be prepared for cement returns to surface. Dump cmt 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 used to route cmt. Page 26 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company Second Stage: 13.17 Prepare for the 2°a stage as necessary. Hold another pre job meeting if crew change has occurred. 13.18 Load ES cementer closing plug in cmt head. 13.19 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 13.20 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.21 Mix and pump cmt per below recipe for the 2°' stage. 13.22 Cement volume based on annular volume +200% open hole excess. Job will consist of lead& tail, TOC brought to surface. However cmt will continue to be pumped until clean spacer is observed at surface. Estimated Total Cement Volume: SC _ ioo f' Section: Calculation: Vol(BBLS) Vol(ft3) 20" Conductor x 9-5/8" (110')x .27 bpf x 1 = 29.7 bbls 167 ft3 casing annulus: 12-1/4" OH x 9-5/8" Casing (1600'- 110')x .0558 bpf x 3 = 249 bbls 1400 ft3 annulus: Total LEAD: 278.7 bbls 1565 ft3 12-1/4" OH x 9-5/8" Casing (2100'- 1600')x .0558 bpf x 2 = 56 314 ft3 annulus: Total TAIL: 56 bbls 314 ft3 .270 SA 13.23 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.24 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.25 Displacement calculation: 2100' x .0758 bpf= 159 bbls mud Page 27 Version 1 August,2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 13.26 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.27 Decide ahead of time what will be done with cmt returns once they are at surface. We should get back approx. 150 bbls of cmt slurry. 13.28 Land closing plug on stage collar and pressure up to 1500 psi above final circulating pressure to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Back out and L/D landing joint. Flush out wellhead with FW. 13.29 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.30 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped& bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com and cdinger(&,hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 28 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard tubing spool. Install pack-off 9-5/8" P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M BOP as follows: • BOP configuration from Top down: 11"x 5M Hydril annular BOP/11"x 5M Shaffer double ram/11"x 5M mud cross/11"x 5M Hydril single ram • Double ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5" VBRs. • N/U bell nipple, install flowline. • Install (1) manual valve & (1) HCR valve on kill side of mud cross. (manual valve closest to mud cross). • Install (1)manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 5"BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.8 Set 10" ID wearbushing in wellhead. 14.9 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.10 Install 5" liners in mud pumps. Page 29 Version 1 August, 2015 i • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 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 TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135. • Run a ported float in the surface hole section. / 15.2 8-1/2" BHA (Includes GR+Res+ADR LWD components & PWD): COMPONENT DATA ..Item 00 ID Gauge Weight Top Length Cumulative Description Serial Number Connection (in) (in) (in) ow) Connection Length (ft) Ell HOBS-FX65D 8.400 2.500 8.500 172.13 P 4-172'REG 1.00 1.00 ® r SperryDrill Lobe 7B-6.0 stg 7.000 4.952 93.13 M� NE23111 NEM E. Stabilizer -__ 7.750 _--- © Non Mag Float Sub 6.750 2.750 101.71 B 4-112-IF 3.00 31.38 © Integral Blade Stabilizer(NM) 6.750 2.813 8.375 100.77 B 4-112"IF 5.00 36.38 © 63/4"DM(Directional) 6.750 3.125 103 40 B 4-1(2"IF 9.20 45.58 ® 6 314"DGR(Gamma) 6.750 1.920 97.80 B 4-112"IF 4.55 50.14 © 6 314'EWR-P4 (Resistivity) 6.750 2.000 104.30 B 4-112"IF 12.10 62.24 Eill 6 314'HCIM (Processor) 6.750 1.920 101.70 B 4-112"IF 4.97 67.21 • 6 314"ALD Collar 175C 30KSI 6.750 1.920 8.250 104.30 P NC 50 14 54 81.75 - Stabilizer -__ 8.250 _--- 10 6 314'CTN Collar 175C 30KSI 6.750 1.905 102.30 B NC 50 11.84 93.59 6 3/4"TV-HOC(Pulser) 6.900 3.250 103.60 B 4-112"IF 15.59 109 18 ® 6-314"Non Meg Flex Drill Collar 6.750 2.813 100.77 B 4-1;2"IF 30.00 139.18 ® 6-314-Non Meg Flex Drill Collar 6.750 2.813 100.77 B 4-112"IF 30.00 169.18 ® X-0 4-112"CDS 40 Box X 4-1?2"IF Pin 6.500 2.750 92.85 B 4.5"COS 40 2.75 171.93 ® 6 Joints 4-1r2'CDS 40 HWDP 4.500 2.500 37.47 180.00 351.93 El X-O 4-112"IF Box X 4-1/2"CDS 40 Pin 6.500 2.750 92.85 B 4-112'IF 2.75 354.68 ® Weatherford 6-114"Jars 6.250 2.250 91.01 B 4-1r2"IF 30.00 384.68 ElX-04-1''2-IF Pin X 4-1/2-CDS 40 Box 6.500 2.750 92.85 B 4.5"CDS 40 2.75 387.43 ® 19 Joints 4-112'CDS 40 HWDP 4.500 2.500 37.47 570.00 957.43 ii.w 1,r '`s 95743 Bit Number Nozzles : 5x13 Bit Size (in) : 8.5C3 TFA (in2) :0.6481 Manufacturer Dull Grade In . Model Dull Grade Out . Serial Number Page 30 Version I August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 15.3 Primary Bit: 8-1/2" (216mm) SFE56 PRODUCT SPECIFICATIONS Cutter Type X2-Tough Drilling IADC Code S424Alb Body Type STEEL Total Cutter Count 29 V Cutter Distribution 13mm 19mm Face 0 19 Gauge 10 0 Number of Large Nozzles 5 • Number of Medium Nozzles 0 Number of Small Nozzles 0 Number of Micro Nozzles 0 Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 Junk Slot Area(sq in) 20.81 ) 1 i`* trf Normalized Face Volume 73.86% .* API Connection 4-1/2 I.F.PIN Recommended Make-Up Torques 23.743 FNlbs. !'r. 1 Nominal Dimensions** Make-Lip Face to Nose 8.31 in-211 mm Gauge Length 3 in-76 mm Sleeve Length 0 in-0 mm Shank Diameter 6.688 in-170 mm Break Out Plate(Mat.tt'Legacy#) 181960/44073 Approximate Shipping Weight 120Lbs.-54Kg. SPECIAL FEATURES Anti-Balling Coating.Short Shank.EDL Tool Specific Gage..084"Dia Step..126"Dia Step Material#761417 Page 31 Version 1 August,2015 411 I Milne Point Unit Producer Drilling Procedure Hilcorp EnagY company 15.4 8-1/2"hole section mud program summary: ✓ • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system(1)ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use water or low vis sweeps. • Run the centrifuge continuously while drilling the production hole,this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. / System Type: 8.9—9.2 ppg Baradrill-N drilling fluid' ✓ Properties: Depths ensity Plastic Viscosity Yield Point Total Solids MBT HPHT 8247- 13701 8.9-9.2 15-25 15-25 <10% <7 <11.0 System Formulation: Baradrill-N Product Concentration/Function Water Base Fluid Busan 1060 0.4 ppb Biocide Soda Ash 0.25 ppb PH/Hardness Control Flowzan 1.0 ppb Viscosifier/Rheology KCL 21.8 ppb weight/inhibition NaCI Salt 20.0ppb weight/inhibition Poly Pac Sup UL 0.75 ppb API Fluid Loss EMI-2009 2-3%v/v Clay/Shale inhibitor Safe-Carb 40 If needed for weight increase over Conqor 404 9.0ppg Asphasol Supreme Corrosion Mitigation Sack Black 4ppb Shale/Coal Stabilizer 3ppb-Gilsonite Shale/Coal Stabilizer Page 32 Version 1 August,2015 I • li Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 15.5 TIH w/ 8-1/2"directional assy to stage tool. Shallow test MWD and LWD on trip in. 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. • Because of aggressive nature of PDC bits, drilling with minimal WOB is recommended. Approx 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. 15.6 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.7 R/U and test casing t00 /30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst=6870/2 =—3500 psi, but max test pressure on the well is °ks�g' � Y3,000 psi. 15.8 Drill out shoe track and 20' of new formation. 15.9 CBU and condition mud for FIT. rk 15.10 Conduct FIT to 12 ppg EMW./ 15.11 Drill 8-1/2"hole section to section TD per Geologist and Drilling Engineer. • Pump at 500 - 550 gpm. • 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. • Pump water or other low vis sweeps to aid in hole cleaning. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1500—2000 ft if necessary. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Ideally, we would like to stay in section 100% of the time and DO NOT want to serpentine between the upper and lower lobes. 15.12 Open hole sidetracking practice: • If a known fault is coming up, put a slight"kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. Page 33 Version 1 August,2015 II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 15.13 At TD; pump low vis sweeps, CBU at least 3 times at maximum circulation and rotation, and pull a wiper trip back to the 9-5/8" shoe. If backreaming is necessary: • Circulate at full drill rate (500—550 gpm). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std(slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe and circ at least a b/u once at the shoe. 15.14 TOH with the drilling assy, stand back BHA if possible. Rabbit DP on TOH. 15.15 No open hole logs are planned for the production hole section. 16.0 Run 4-1/2" Wire Wrapped Screen Production Liner 16.1. A ram change to 4-1/2" screen is not necessary. In the event of a well control situation,the screen assy will be crossed over to 5" DP to position a joint of 5"DP across the BOP stack. �f- Then the well can be safely shut in. If there is not enough time to accomplish this, the screen assy will be dropped and well closed in on the blind rams. 16.2. R/U 4-1/2" screen running equipment. • Ensure 4-1/2" Hydril 521 x DS-50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 16.3. Run 4-1/2" screen production liner. • Use "API Modified"thread compound. Dope pin end only w/paint brush. Wipe off excess. Thread compound and can plug the screens. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install swell packers as per guidance from Operations Engineer. • Ensure all plastic packing is removed from element. • Do not place tongs or slips on element. • Run packoff and float shoe on bottom. 4-1/2" Hydril 521 torques Casing OD Minimum Maximum Yield Torque 4.5" 3,600 ft-lbs 4,300 ft-lbs 6,300 ft-lbs Page 34 Version 1 August, 2015 0 II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company Technical Data Sheet EXCLUDER2000TM Premium Standalone Screen i x Material Number 11486900063 Base Pipe Size 4-1/2" i " Base Pipe Weight 11.6Ib/ft I *aSe C`IRe _ Base Pipe Grade L80 Fnr„ftutg n Base Pipe Length API R3 (Min 37ft) —a (C) . r. Thread Down (Y) BTC Pin 3 `_hrcn=d Freer + ,'•,I -- Cartridge /l .1 _ 4 heave Thread Up(X) BTC Box ,j .1 + 1 Pore Size Medium 11 s Screen Acid': 200 pm<d10<300pm l A I• ' End Ring Max OD (A) 5.310" t8J f Min ID(B) 4.000' Nom. (3.875"Drift) nil ti Upper Handling 48" ,l. • Length / '. 3 Shroud Feher i I )' . Cartxsge in ' Lower Handling 38'(minimum) 4 weave 1 • (: Length i i 5 Sueen JucAe1 I Number of 318"-! Total 1638(approx.)/78 Holes/ft{ Base Pipe Holes z End Ring Dual Filter 16tt each/32ft total 6 Cartridge Length Y Page 35 Version 1 August,2015 • O II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company s TenarisHydril Size: 4.500 in. Wail: 0.250 in. Weight: 11.60 lbs/ft Connection: Wedge 521T" Grade: L80.1 Casing/Tubing: TUB Min. Wall Thickness: 87.5 % PIPE BODY DATA GEOMETRY Standard Drift Nominal OD 4.500 in, Nominal Weight 11.60 lbs/ft 3.875 in. Diameter Special Drift Nominal ID 4.000 in. Wall Thickness 0.250 in. N/A Diameter Plain End Weight 11.36 lbs/ft PERFORMANCE Body Yield 267 x 1000 Internal Yield 7780 psi SMYS 80000 psi Strength lbs Collapse 6350 psi WEDGE 521'"' CONNECTION DATA GEOMETRY Connection OD 4.695 in. Connection ID 3.960 in. Make Up Loss 3.620 in. fICritical Section 2.141 sq, in. Threads per in. 3.36 Area PERFORMANCE Internal 171 x 1000 Tension Efficiency 64.2 c� Joint Yield Strength Pressure 7780 psi lbs Capacity Compression 226 x 1000 Compression 84.8% Bending 52 0/100 ft Strength lbs Efficiency External Pressure 6350 psi Capacity MAKE-UP TORQUES Minimum 3600 ft-lbs Optimum 4300 ft-lbs Maximum (1 6300 ft-lbs OPERATIONAL LIMIT TORQUES Operating Torque 10200 ft-lbs Yield Torque 15300 ft-lbs Page 36 Version 1 August,2015 i • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 16.6. Ensure to run enough liner to provide for approx 150' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8"connection. 16.7. Before picking up Baker ZXP liner hanger/packer assy, count the# of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. If inner string is to be run, R/U false rotary and run inner string at this time. 16.9. M/U Baker ZXP liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 16.10. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH w/liner on DP no faster than 1-1/2 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.12. DP should autofill. 16.13. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth+ S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.14. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 16.15. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.16. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.18. Rig up to pump down the work string with the rig pumps. 16.19. Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.20. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 min each up to 4000 psi. Page 37 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp EnerSY Company 16.21. Bleed DP pressure to zero, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. Bleed off pressure and pickup to verify that the HRD setting tool has released. If packer did not test, rotating dob sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. P/U above liner top packer and displace well to 8.9 ppg completion fluid. 16.24. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. 16.25. RIH w/remaining DP out of derrick and L/D same. 17.0 Run 7-5/8" Tieback 17.1 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie-back space out calculation. Install and test 7-5/8" casing rams in top ram. 17.2 R/U 7-5/8" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 17.3 P/U tieback seal assy and set in rotary. M/U ported collar to top of tieback seal assy, then crossover to 7-5/8". Note that tieback seal assy and ported collar are 7". 17.4 M/U first joint of 7-5/8"to seal assy. 17.5 Run 7-5/8"tieback to position seal assy two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. • Install ported collar so it is positioned at 2500' MD when landed out. 17.6 M/U 7-5/8"to DP crossover. 17.7 M/U stand of DP to string, and M/U top drive. 17.8 Break circulation at 1 bpm and begin lowering string. 17.9 Note seal assy entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. Page 38 Version 1 August, 2015 • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 17.10 Continue lowering string and land out on no-go. Set down 5 — 10k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 17.11 P/U string & stand back DP stand, L/D XO. Note P/U weight on morning report. 17.12 M/U (or L/D) necessary joints and pup joints to position seal assy 1 ft above "NO-GO DEPTH" when tie-back hanger lands out in wellhead. 17.13 P/U hanger assy and landing joint. Slack off and land hanger. 17.14 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 17.15 Run in hanger lock downs. 17.16 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off Test void to 3000 psi/ 10 min. 17.17 R/D casing running tools. 17.18 Run in hole with 2-7/8"tubing and ported collar opening tool. Shift open ported collar at 8100'. Spot diesel freeze protection from 2500' to surface in 7-5/8"x 9-5/8" annulus. 17.19 Close ported collar. 17.20 Test 7-5/8"x 9-5/8"production annulus to 1000 psi/30 min. 17.2 POH and stand back 2-7/8"tubing for ESP run. 18.0 Run ESP assy. 18.1 M/U ESP assy and RIH to setting depth. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while RIH. 18.2 Land hanger, RILDs and test hanger. 18.3 Install BPV and N/D BOP. Page 39 Version 1 August,2015 • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 18.4 N/U tree adapter and test tree. Pull BPV. 18.5 Circulate diesel freeze protection down 2-7/8"x 7-5/8" annulus (Volume should equal capacity of tubing to 2500' +tubing annulus to 2500'). Connect IA to tree and allow diesel freeze protect to "U-tube" into position. 18.6 Shut in well and prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 19.0 RDMO 19.1 RDMO Nordic #3. Page 40 Version 1 August, 2015 • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 20.0 Diverter Schematic 16" Full Opening Knife Valve O Tn an an an an nr an rrn en an nn_ Schaffer 21-114"2M Annular rra Rn mama) 21-1/4" Diverter "T" 2,9981 € � € 8 € € € aaaaaoaa 21-114" 2M 16" Diverter Line Spacer Spool 4.0380 Ground Level nammimm 16-3/4" 3M x 21-114" 2MDSA int ,ice, Seaboard Casinghead, S-22-AP-8� 16" SOW x 16-3/4" 3M; (2) ea 2-1116" 5M studded outlets 20" Casing Page 41 Version 1 August, 2015 • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 21.0 BOP Schematic / r 1 l 6 Hydril Annular BOP 11"x5M ▪ s =MCI ▪ rIF 14IP 14.MI el �aShaffer 11" x5MUDap 27, _ 5•t,vBR- [11Pg110 o ❑ ❑ 1 ❑ �,,w Ii 000 •al Al M1 MS it 7-3"x 5M HCR 'I•u'L t.. .Ail ' `1�,��1J' -` —Choke Line Kill Line % / Y �3 x 5M Manual Gate Valve Y Hydril 11"x5M7/ C" 116 11 oea —11"x5M _I 1111111111_ 9-5/8"DBL D Seal Us V 21116"x5M Casing SMB 22r( ` I�,�E tit)[ � 16 314"x 3M 16-314"NOM 1 9-5/8"BTC Btm x \-2-1/16"x 5M 1(15"-4 SA Pin Top W/Primary Seas 20"Casing 9-5/8"Casing Page 42 Version 1 August, 2015 I • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 22.0 Wellhead Schematic 1 HILCORP ALASKA 1 SCHRADER BLUFF WELLS HO-35449H -T- E 2-9/16 51.4 J ) HOLD-GOWN FLANGE ADAPTER, ESP-20. In TOADSTOOL 11 % 2-9/16 5M �+ -� �j 11 v J0 gt- TUBING HANGER • S-SB ESP L1.11 -- UI II X 2-7/8 IRO TOP X...�i r.- AP; APt Moo BTM — . li E,_ r/TAURUS PENETRATOR i; 1 1 . 4 0 S1 43-217-00 MO1 • �j!L• g F •, j � 1 C 1 1VV-�� r - 1. 11 .`,-v 1 777��'''��777�� .' 2-f/16 5M CASING HANGER, SMB-22 lj:1r f — 'I 11 5 7-5/B f - W/PRIMARY SEAL :I., 28.0 , E I ..1 �. G ► f„. lita "I :�4 9-5/8 DBL D .,�'' k 111 1 --_ i L 2 1/16 5M OM FT�::1 a .b .S/• IN CASING HANGER11- MI SMB-22 ______-- 16 X 9-5/8 7�� .,....,AR, SEAL �• TWi•t: • `: MA 4'3 EST : > .1 a 1.3-3/6 CASING .e- 9-5/8 e9 5/8 CASING IIIEII 7-5/8 CAS NG _. �.....• OIL tl OAS 6.000 P9 ESP WELLHEAD ASSEMBLY -- 2-7/B CASING R —...Ai E BACx STYLE DNEN90 S SHOWN OR THS DRAWING PRE 13-3/8 IE 9-5/B X 7-5/8% 2-7/8 ESDNATES ONLY AND CAN YPRIC 9GNIFCCN4TLY RESTRICTED CONF1OENTIAL DOCUMENT OFPEN]WC ON RAW MAIERIAL LENGTHS. rr.rr..rrrw rmar r w M- PPL 1:9 ]~19JUN15 An 145 GUARANTEE OR STACXLP*GNI IS MPLEO. �'^s LOVA"�"•".'b"•M MUM M. CLNFN5IOIS 9411tH SIICUIO NE CCN90ERED ri ts'a 4�1 '+ f1 C 06 *CR REFERENCE PLRPOSES ONLY. a .: r� ...a�1 it. QD-0019 Page 43 Version 1 August,2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 23.0 Days Vs Depth Days Vs Depth 0 2000 4000 6000 v $CCc In u, 10000 12000 14000 16000 -- — — 0 5 1C 15 20 25 30 Days Page 44 Version 1 August, 2015 • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 24.0 Formation Tops Formation TVD (Top) TVD (Bottom) Anticipated Pressure (Psi) SV1 2150 3334 1491 Ugnu LA3 3335 3635 1626 SB NA Sand 3636 3667 1640 SB NB Sand 3668 3700 1655 Page 45 Version 1 August,2015 • • 111 Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 25.0 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. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0—2.0 ppb 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 when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are a number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations btwn surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. Page 46 Version 1 August, 2015 Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event ICS is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 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. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a"ramp" in the wellbore to aid in kicking off(low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on this pad. Page 47 Version 1 August,2015 • • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 26.0 Nordic #3 Rig Layout (Drillers Side) •l «► ► AM RI t.",C ealista I'Services RiG NO. 3 ot),.\:0200>td... giii si ,Deng&:minding Apex&su uno drereraige and ehnti cursor.l,T1w druyml.as the ceehatiw propene of Yonitc• Celina d ie pa wend be U5.rd aeernr.:..ui a.r.ithr law..Tee Lk.ign n flambe&on a c.nfder,ial hum with the earn.a ai raar.m xhr a will wit he toot rrentfrurd.applied rm.d.phreopeephrd.or npaoduerd in one rannn wha.oea,in whale to pan.,nn env nem heron be hall.manafiererrd.or.ewnkkd with the nal of.ie da.ign without the'mint, ter trer of Nordic-Cahill.The Lkeign may not be d ackr.ed to en,other parte e.repr for the .peelfie reerpoor for which a tea to:en preemie&. M b ,11tif 411E00 4,40,,,, 1 _ �♦.. r Wm' ...... "___., Wm' tM—..i.e�t/f ma yr—.-1 If 4- ti 01161•Ilt 1 c rarer, I err s ■.._ Mt IMM um' ^rl Ir9NIYr It , = 111 II —FT.*. ,U 111111 i in NU 1:::'N ‘....: ! /I N:Ita ______i____il ,,,............. .. • �. _,-__�_� �__—l r !I IVY Drillers Side Page 48 Version 1 August,2015 • • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 27.0 Nordic #3 Rig Layout (Well End & Top View) Id III IIII Willi� I 11111 I OM .� MN . 11111111 httii� MIS _ . dIY =BM illifElaliallI111 • MIMI =MN MNMIMI b -•.;-:,:- rY IWO IIiL 000a', -0 ACQpT RCN/U€S as'-,t 441.r Well End _ I` n , �,n, i'1111°1111 *MA MINNS l ^l ' ow coon __YA4,XU 'i Mg 1R4A _ LA COSMO( MINX 7 >- 4 -7 �; I Ir ")' hitIf n �� (” r 5 Q k i.1 .7b A b 11 11.1'1 I ARA ^' - yi_i_ II 744_4 II .. PP(WOO __ill . II PP(rr(4Ann U IlIt 11"Il fH I 1 Top VIEW Page 49 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 28.0 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 the ointwill continue pressure to rise, but at a slower rate. The system is shut in andp ressure monitored as with an FIT. Page 50 Version 1 August,2015 • • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 9a<t.!ie0 D<s Choke hoke aattManifold anifold Sitachietma�tic s > rafus<atis > d..tS s i> >.s.<::s<> s i>a ta. >4 s < s a K<>>�.*<t > tpai r aa Satst < a. 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Page 52 Version 1 August, 2015 • • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 31.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 1.3 8-1/2" Hole Section H i lcnrp MPU J-27 Milne Point Unit MD TVD Planned Top: 8247 3665 Planned TD: 13701 3589 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff NB Sand 3,700 1655 Oil/Wet 8.6 I 0.447 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date MPI- 19 9-9.3 ppg Surface 4,079 2004 MPI-18 9- 10 ppg Surface 3,848 2011 MPI- 17 9-9.5 ppg Surface 3,864 2004 MPI-16 9-9.3 ppg Surface 4,101 2004 MPI -15 9-10.8 ppg Surface 4,042 2002 MPI-14 9.1-9.3 ppg Surface 3,979 2004 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 3665(ft)x 0.78(psi/ft)= 2858.7 2858.7(psi)-[0.1(psi/ft)*3665(ft))= 2493 psi MASP from pore pressure(complete evacuation of wellbore to gas from Schrader Bluff NB sand) M" 3700(ft)x 0.447(psi/ft)= 1655 psi '" F P / 1655(psi)-0.1(psi/ft)*3700(ft) / Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 53 Version 1 August, 2015 • I . II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 32.0 Spider Plot (NAD 27) (Governmental Sections) •, • , , ... •, ADL02551 " Sec. 24 Sec. 19 ••-,.." Sec 20‘ % Sec.121 JAS.. .•.... ‘ k .0,, I ADL3115/34p s t ,„ - . ..,,, Y... + •, , v , _, , . I I • I I I • , • l % , ' MINE SITE E I. % II i 1 A NCIA ) I 1 II * 1 il 1 ,. ,.. ...N....7:7-'1 „_,.._ .. 1 „, v ,O. * +le \H'1-27 1311[, -••• .. ”- k • =p , ,. ..... MPJ-27 TPH . . -, -,- t .... e C41724:2•. - , - , , c_V27a J A /1 ...., ,,,,-, . •. . ‘*: • • -CC-Al*:Ozerappen„, 472t:J-2I •' 174 .e. NTs ---- $E;-Sec-29------,--- ."•••• r..4rMi .7. HI...NE F,T2 NT UN r Sec 30 ,i N -At----------1-272 274:4) .5.'"-s1: , 0 U013N009E . U013N010E, s A • e 'i .... MPJ-27 SHL i 1 , , 5 I ' t lit • t• • t 4FE6: I 1 •'4: t• 1 N t i f / • / I • 1 I . O ".•—",'--" ADL025519„ .--- „," 'ADL025517 - ALI2 • 1 ..L. ' I 't • ,... k •„i • OE=1.,0'4 • . MO . • t . sis N• I ° •- NB, , I ' ...•'*"--....."..-.1.Z'.• ' -• . NI, -, Sec 36, Sec 31 Sec.3-- --------- -------- -161•81 - •. )31.1 9C.AEID -......... 0.91 • ------------ -- __ --.7 _...„....',-^-,, 5: _.....-• r'''' 1:' Legend •........ i..._._,,,A7L.. MPJ-27 SHL MPJ-27 TPH 1 KUPARUK RIVER UNIT + MPJ-27 BHL I ADL025627 Sec.4 Al • Other Surface Holes(SHL) Sec.6 ' U012N010E Sec 3 $ Other Bottom Holes(8HL) 4. - — Other Well Paths .. i inMilne Point Unit 0 1.000 2,000 3,000 FSS Dale MPJ-27 Well iimiciiiiimm Feet r !.:,:,:3.! Page 54 Version 1 August,2015 • •• Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 33.0 Surface Plat (As Built) (NAD 27) .1-1 'CH Ht ,�. 0 • 20 21 ' 22 V C . ry �!.. - _.-._-.. THIS PROJECT_ MPU J—PAD a f 29 I 27 G PAO Ig I $ 5.. ''') 25■ 4. 33 a 34 24• N PAD 23• 1 I . 71• VICINITY MAP 2 ■ 6 • N.T.S. 3 ■ 10• ■ 4%%' tf��111. 4 " OF q g/ .:rr�.' --..4 •9 16• III 12 s,s....—• "� O• P IBIS • 13 WELL J-27 REVISION NOTE ▪ _ I R• ich:4 F. Allison 19• •5 TFaS AS-BUILT ORAIMNG FOR CONDUCTOR I f .1-27 IS A REISSUE OF A PREVIOUS 0.c,,,,.4.•.. 1 7608 • 20• �'J-27 ..: :h• r AS-BUILT ORAIMVG EON CONDUCTOR J-14. `' 21• •7 CONDUCTOR SU TOR 4-27 HAD BM PREVIOUSLY �F, Ad,__ I $ 26• -".i ^— 11 1 % %%0' .SURVEYOR'S CERTIFLCA.IE I HEREBY CERTIFY THAT IAM PROPERLY REGISTERED AND UCENSED TO PRACTICE LAND SJRVEYING IN THE STATE OF ALASKA AND THAT THIS BYTMEEOR UNDER MY DIRECT SUPERVIDON AND THAT ALL DMENSONS AND OTTER DETALS ARE J-2 SOU TN CORRECT AS Cf MAY A 2004. 0 NOTES: t STATE PLANE COORDBNATES ARE ALASKA ZONE 4. VA027. LEGEND 2. GEODETIC COORENATES ARE VA0-27. 3 MPU 4-PAD EACIUTY SCALE FACTOR IS 0.9999031. -BUILT OONDUOTgt 4- RONZONTAL.CONmc.BASED ON MPU 4-PAD OPERATOR MONUMENTS 4-1 AND J-2. EXISTING CONDUCTOR 5. ELEVATIONS ARE BPX MILNEPONT DATUM MEAN SEA LEVEL. 6, DATE OF SURVEY: MAY B, 2004. 40 SURVEY CONTROL MONUMENT 7. REFERENCE FIE..D BOOK: MP04-03 (P9.56-57) LOCATED WITHIN PROTRACTED SEC._28, T. 13 N., R. 10 E., UMI AT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSIT1ON(DMS) POSITION(D.DD) BOX ELEV, OFFSETS J 27 Y. 6,014,663.74 N- 850.39 70'27'02.877" 70.4507992' 35.0' 2 265'15.. X- 552,166.18 E- 1,170.69 149'34'27.777" 149.5743825' 3,155'FEL -- F. Robe IA,r. yrm - - g I,�41i °`R EP.AIM SOA IHilcorp Alaska '!`^' i r ' TROTS IK•,01 ' MILNE POINT UNIT J—PAD Twtn .... 1Ik IJLio . 1P ------ AS—BUILT WELL CONDUCTOR 44 7./ .IIrA •••••••••••," WELL MPJ-27 1a1 Page 55 Version 1 August,2015 S • Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company 34.0 Offset MW vs TVD Chart MW vs TVD Offsets 0 MP1-19(2004) MPF-18(2011) -- MPI-17(2004) MPF-16(2004) 1000 1 2000 1 3000 1 a i i 4000 5000 8.0 9.0 10.0 11.:.: 12.2. 13.0 14.0 15.0 Mud Weight(PPG) Page 56 Version 1 August,2015 • • II Milne Point Unit Producer Drilling Procedure HIlcorp Energy Company 35.0 Drill Pipe Information 5" 19.5# S-135 DS-50 Drill Pipe Configuration Pipe Body OD ,n.5.000 80%Inspection Class Pipe Body Wall Thickness oni 0.362 Nominal Weight Designation 19.50 1 Pipe Body Grade 5-135 Drill Pipe Approximate Length :Ft,31.5 Drill Pipe Length Range2 SmoothEdge Height cin 43/32 Raised Connection GPDS50 Tool Joint SPAYS ;ns'120,000 Tool Joint OD 6.625 Upset Type IEU Tool Joint ID 'aa 3.250 Max Upset OD (DTE) ilei 5.125 Pin Tong 9 iFriction Factor 11.0 Box Tong I:n'r 12 Note T 7'a',1.1 e may include harc'ac n a Drill Pipe Performance Drill-Pipe Length Range2 Performance of Drill Pipe with Pipe Body at 1 Best Estimates 1 Nominal e0 16 Inspection Class 'nA1oa`°°nnQ" ""�`�'0rp' I "` °"'J""' edM*°� Operational Max Tension Drill Pipe Adjusted Weight ban 24.11 23.29 spur to-Ilxt Torque ,n_h,I rb.. Fluid Displacement �c��n�0.37 0.36 tMxanum""UT 43,100 Tension Only ()Operational 560800 Fluid Displacement `B'171:::.00.00.8837 aal roup 0088 0.0085 Canblnea wading 39,600 410.500 Fluid Capacity ttt.+un)0.71- e0.70 0.72 Fluid Capacity mown)0.0169 0.0167 0.0172 Tension Only 0 560.800 3.125 �Iaaa.ttMur 36,100 ocean., 32.100 1467.400 Drift Size onl Note or nein barrel equals 42 US nitrons. Note:Drill cape assembly values are best estimates and may vary due to pipe body mill tolerance,Internal plasto coating.and other ranters. Connection Performance GPDSSO ( 6.625 on) OD X 3.250 a"> ID ) 120,000 (osn AaWedM -up relsstnnalBlqulaer rarlstar'°1`wr'e"oe Tool Joint Dimensions Touque SeparMbn Yield (n-eS) nail ob.) Balanced 00 or,6.435 Maximum Make-up Torque 43.100 Tensile Limited 1.046,900 Minimum Tool,ern 00 tor API Minimum Make-up Torque 36,100 1.202,500 1,250.000 5.930 ' Premium Class Utz "----- -- Note The maximum make-up A'que should be 11011e1 when possibe Minimum Toa Join OD for 5.93 GpagaerbOre Pm Note To mairehae connectbn operational lensfle.a MUT jai-37.300 i;ltabs)should he espied. Tool Joint Torsional Strength to-eat 71,800 Tool Joint Tensile Strength rays 1.250,000 Elevator Shoulder Information Elevator OD 3/32 Raised 6.812 an) 7 SmoothEdge Height Nominal Tool Joint Worn to Bevel Worn to Min TJ OD for 13/32 Raised OD Diameter API Premium Class Box OD 6.812 6.625 6.063 5.930 Elevator Capacity ib=I 1,658,000 1.440,200 823,600 685,600 5.219 No, Eleva c aaa,ty Cased.-n assumed EbVator Bore.no.wear factor.and conlxt stress of 1 i0,10Qpa. Assumed Elevator Bore Diameter No'e A rinsed e evator OD Increases elevator capxny....Mout anectrnc make-ars torque. Pipe Body Slip Crushing Capacity Pipe Body Configuration( 5 an) OD 0.362(rn) Wall S-135) Nominal 80%inspection Class API Premium Class ESlip Crushing Capacity Assumed Slip Length o=)498,300 5 (n)16.5 396.500 Care, itvp" 396.500 (Foom rc 1pnrpYSoatM1tpsaOls..Icek0wtegsW YhamRernrkutl e7'1-'37:AbY0mtr000yanAd y trTccsrcr.mD'eic''Pepe Transverse Load Factor(K'I 4.2 on,' Sip crostini aaeoender"lonInt mTdeSanand conn40'.`onnc°er'tahicton laadro area.,neer• des di,pre.30 aro]Mar ranation.and dhK*xtds Cdn JI Yath Me sip 0011110.00'o addaunl oro nulkn.. Pipe Body Performance Pipe Body Configuration( 5 m) OD 0.362 on) Wall S-135) Nominal 80%Inspection Class API Premium Class Pipe Tensile Strength ti°°'712.100 560800 560.800 Pipe Torsional Strengthn-Il 74.100 58.100 58.1CC TJ/Pipeeody Torsional Ratio 0.97 1.24 1.24 80%Pipe Torsional Strength Burst n-1CSI 59,300 46.500 46.500 w_, pstl 17.105 15.638 15,638 Noor Nominal Burst Collapse Pipe OD co, I 15.672 10.029 10.029 ca'cotated at n7.367.5%RB"N On)5.000 4.855 4.855 per tet. Wall Thickness In 0.362 _0.290 0.290 Nominal Pipe ID tint 4276 4.276 4.276 Cross Sectional Area of Pipe Body ,1,r21r 5.275 4.154 4.154 Cross Sectional Area of OD tn•si 19.635 18.514 _18.514 Cross Sectional Area of ID .I,''21 14.360 14.360 14.360 Section Modulus 3i 544.476 4.476 Mak ' Polar Section Modulus I I"-VS 111..4115 8.953 8.953 Page 57 Version 1 August,2015 s • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company Operational Limits of Drill Pipe Connection GPDSSO Tool Joint 00 ;,46.625 Tool Joint ID ,n13.250 --c-ol Joint Specified Minimum 120,000 Yield Strength tPsii Pipe Body 80%Inspection Class Pipe Body OD 5 Wall Thickness 0.362 Pipe Body Grade 1S-135 Combined Loading for Drill Pipe at Combined Loading for Drill Pipe at Maximum Make-up Torque= 43.100 .n--,s, Minimum Make-up Torque= 36,100 mans Operationa€ Assembly Pipe Body connection Max Operabona Assembly Pipe Body Connection T n Torque Max Tension Max Tension Tension I Torque Max Tension MnnTension Max fn-Ins1 :'n: ;Inst OM) fTabs? tits, Bios) (11,51 ili 0 560.800 560.800 1,046,900 0 560.800 560.800 1,202,500 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 3.400 559.800 559.800 1.202,500 6,300 557.500 557.500 1.046.900 5,100 558.600 558.600 1,202.500 8,300 555.000 555,000 1.046 96060 6.800 556.900 566.900 t202.500 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 13.500 545.400 545.400 1,202,500 18,800 530.6000 530,6 1.046.900 15.200 541,200 541.200 1.202,500 20,800 523.600 523.600 1.046.900 16.900 536.500 536.500 1202,500 22,900 515,400 515,400 1,046,900 18.600 531.300 531.300 1.202,500 25.000 506.200 506.200 1.046.900 20.300 525.400 525.400 1202,51., 27,100 496.100 496,100 1.046.900 22.000 519.000 519.000 1.202.500 29.200 484,800 484.800 1.046.900 23.700 512.000 512.000 1.202.500 31,300 472,500 472,500 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 1202.500 39,600 410.500 410,500 1,046.900 32.100 467.400 467.400 1,202.500 Operational drilling torque 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 „_ „Tension ,t,; Min MUT 36.100 1,202,500 9 36.900 1.229.200 37.700 1,243,600 t 38,400 1,218,100 39.200 1,189,000 t' 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 58 Version 1 August,2015 • II Milne Point Unit Producer Drilling Procedure Hilcorp Energy Company Connection Wear Table Connection GP`DS50 Tool,joint 0D ,, 6.625 Tool Joint ID „r,13-250 Tool Joint Specified Minimum 120,000 Yield Strength toxi> Connection Wear Tool Connection Max Connection Max Min MUT Connection Max New OD Joint DD Torsional MUT Tension Tension Strength , , 0 -.e.: al,: tl.as, ins, I 6.625 71,800 43,100 1,046,900 35.900 1.195.900 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 INN 6.435 71,800 43.100 1,009,800 35.900 1.237.500 6.372 71,200 42,700 1,008,100 35.600 1.245.200 L-- 6.309 68,000 40,800 1,057,300 34.000 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 30.800 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 27.800 1.060.800 Worn 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 Thickness .n,10.362 Pipe Body Grade IS-135 U Pipe Body Torque 0 5.300 10.600 15.800 21-100 26.400 31.700 37.000 42.300 47 500 52.800 58.100 i Pipe Body Max Tension 560.800 558.400 551.400 539.600 522.500 499.600 470.000 432.400 384 500 323.100 234.300 12.200 D Page 59 Version 1 August,2015 S Hilcorp Energy Company Milne Point M Pt J Pad Plan: MPJ-27 MPJ-27 Plan: MPJ-27 WP3 Standard Proposal Report 19 August, 2015 HALLIBURTON soisseseisminamenimmou Sperry Drilling Services • • Project: Milne Point WELL DETAILS:Plan:MP3-27 NAD 1927(NADCONOONUS) Alaska Zone 04 Site: M Pt J Pad cmtmd Level: 3500 Wet: Plan:MPJ-27 +w-s+Pr-w Northing Eostitg Latantae Longitude Slot Wellbore: MPJ-27 000 0.00 6014663 74 552166.18 70°27 2.877 N 149°34'27.777 W Plan: MPJ-27 WP3 REFERENCE INFORMATION -3000— Cooldeste(NTE)Reference:Well Plan:MPJ-27,True North Vertical(TVD)Reference:MPJ-27 Pre 0 66.00usft(NORDIC 3) Measured Depth Reference:MPJ-27 Pre 068.00us0I(NORDIC 3) Calculation Method:Minimum Curvatura -2500- -2000- -1500 -10007 -500 1000- -500it 1- 500— 500 1000— 10p0 O ,y0 moo— L no O N O o 2000- o0 ,v o0 43 O 2500- ° h o0 O - 0 0 5/8"x121/4" 30007 to mo 0 51/2" 9. 3500— � J _ '0 0 - - N o N It N MPJ-27 WP3 4000— ,o olo § § 0 0 o g t o 0 45007 MPJ-27 Heel MPJ-27 Toe 5000— 5500— e000— 6500 Illll lllllllllllllll/llllIlI/lI/I/lllllllllllllllllllllllllllll lllltl lllllllllll1111 llllll11 l lllllll lllllllllllllllllllllllllllllll 11 llllllllllil -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 Vertical Section at 280.20°(1500 usft/in) Ell Iil4°orp • • HALLIBURTON Project: Milne Point WELL DETAILS:Plat:MPJ-27 ,ry orwrw Site: M Pt J Pad cn„ma Levet 35.00 SessiWell: Plan:MPJ-27 +N/-S +E/-W Notting F stcg Latitude Longitude Slot W Wellbore: MPJ-27 OAO 0.00 6014663.74 552166.18 70°27 2.871N 149°34'27.777 W - Plan: MPJ-27 1NP3 REFERENCE INFORMATION 55002- Co-ordinate(N/E)Reference:Well Plan:MPJ-27.True North — Ve3kal(70D)Reference:MPJ-27 Pre/8 6e 00usf(NORDIC 3) Measured Depth Reference:MPJ-27 Pre a 6E0000(NORDIC 3) 5000— Calcuktion Method:Minimum Curvature 4500— 4000— 3500— 3000— Fid Dir:8751.08'MD,3659.01'TVD Stan Dir s°/1110:8247.12'MD,3666'TVD \ - End Dir:8415.89 MD,3670.42'TVD / _ :8722.43' `�MD,3659. P Start Ilr s°/IOD' TLr�VD actDir:7747.12'MD,3622.42'TVD 25110- 5 1/2" It Start(Sr 55100:7436.62'MD,3557.39TVD S 2000- TD at 13701.08--I' t z'95/8"x 12;/4 Start Dr 2.55100':500'MD,499.91TVD - a - h Start Dr 1.5/100':300'MD,3007VD 1 �k I 4. I MPJ-27 WPl g 1500—_ 1 hi' 8 End Dir 2277.36'MD,185922'TVD MP1-27 Toe "' ry Stmt(Sr 43100:750 MD,698.92TVD + 1000— _ MPJ-27 Heela \ 500— ,'.,,4'.$1i _ IR ia 0— rq _ -500— -1000— -1500- -2000— -2500-- 2 _ T M Azimuths to True North 3000-_ MagneticNorth:18.93' - Magnetic Field Strength:57574.4snT CASING DETAILS -3500— Dip Angle:81.02° Date:5/26/2015 TVD TVDSS MD Size Name Madel:00042014 3665.99 3599.99 8247.00 9-5/8 9 5/8"x 12 1/4" -40002 • 3589.04 3523.04 13701.08 5-1/2 5 1/2" 11 1 11111111111111111111III 11111(111 11 111111(111111111/111111111(11(1111111111111111 il 1111 Il ljIIII 1111111111111 111111111111111111111111111111111111 -13000-12500-12000-11500 -11000-10500 -10000 -9500 -9000 -8500 -8000 -7500 -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 West(-)/East(+)(1500 usn) I l i l t•t 1 rl 1 • • • HALLIaURTON Project: Milne Point h'e'r Drake Owls= Site: M Pt J Pad Well: Plan:MPJ-27 Wellbore: MPJ-27 7000— MPJ-1: MP1-u p Plan: MPJ-27 WP3 6500— 6000 MPI-09 6000 7496 - MPJ 19MPJ-08 - MPJ-Jar 1‘00101p00 '407 MPJ-\3 5500— 1 .A o� MPi-111 Aid Plan 8s n 5 7487 MPJ-IS 5000— �9 S 1 e W"_ ` A1a3 474]-MPJ-01A 7x10 - MiRLKah y�01 4500— AO G95000� 06 MP1-S0itch WpOI 4000— MP1a4L MPJ-241.1 ,n MPJ24LIPB2` ^ 4028 Ste' 4000 , 3500-:: MPJ-24LIPB1 MPJ-12 M10-240 WP2 6110-08A 5000 MP1-224 Wp5 \ c 3000— 6000 ' _ MPI-24Xiii\,..97 `11 8 25007_ 0,....A �` 4 000 • � `I.1-09A \el/ 000 5000 C 5 If2" MPJ-20A MOO-20A Wp6� MI'1-10 v 2000— '� �' 9 5/8"x 12 1/4" ` - MRI-27 WP3 - MPJ-IFA Wp3 4000 - 1500 1. 8` ti� r MI'.Nl MPJ-05 MPJ-26 MPl ffi P `` )` 4000 -MPJ-23A wp3 MPJ-261,2 wp0 `� �' 3"I C ]000- - -MPJ-26002 MPJ-17 ' � 3000 M10-23LF---- — \ lk. '„ MPJ-26001 MPI-Peaphone wp01 500— MI'.1-2.3 \ p \ \ 219 , E• SI` a�;:f, _ MPl-20-- r ,Y %Q o - q, 2000 500— S g ps gg 5 1000— MPJ-21 -tt 5 ` I Ml'Ja17 -1500— 3000 T M Azimuths to True North MPI Magnetic North:18.93° _2000— _ Magnetic Field - Strength:57574.4snT 2500— Dip Angle:81.02° Date:5/26/2015 = Model:BGGM2014 MPO-03- 4224 3000- . 1111111 IIIIIIIII111II VIII 111111111111111111111111 Illlllllllllllll 111111 II Illllllllllllllll 11 111 11 111111111111111111111 IIIIIIIIl IIIc IIII VIII Alli -12500-12000 -11500 -11000 -10500 -10000 -9500 -9000 -8500 -8000 -7500 -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 West(-)/East(+)(1500 usft/in) • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPJ-27 Company: Hilcorp Energy Company TVD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: Plan:MPJ-27 Survey Calculation Method: Minimum Curvature Wellbore: MPJ-27 Design: MPJ-27 WP3 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 J Pad,TR-13-10 Site Position: Northing: 6,013,415.23 usft Latitude: 70°26'50.647 N From: Map Easting: 551,435.10 usft Longitude: 149°34'49.503 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.40 ° Well Plan:MPJ-27 Well Position +N/-S 0.00 usft Northing: 6,014,663.74 usft Latitude: 70°27'2.877 N +E/-W 0.00 usft Easting: 552,166.18 usft Longitude: 149°34'27.777 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 35.00 usft Wellbore MPJ-27 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 5/26/2015 18.93 81.02 57,574 Design MPJ-27 WP3 Audit Notes: Version: Phase: PLAN Tie On Depth: 31.00 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (usft) (°) 31.00 0.00 0.00 280.20 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NIS +E!•W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1100usft) (°/100usft) (1100usft) (^) 31.00 0.00 0.00 31.00 -35.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 280.00 300.00 234.00 0.00 0.00 0.00 0.00 0.00 280.00 500.00 3.00 300.00 499.91 433.91 2.62 -4.53 1.50 1.50 0.00 300.00 700.00 8.00 300.00 698.92 632.92 12.20 -21.13 2.50 2.50 0.00 0.00 2,277.36 70.78 284.40 1,859.22 1,793.22 279.86 -931.44 4.00 3.98 -0.99 -16.55 7,436.62 70.78 284.40 3,557.39 3,491.39 1,491.18 -5,650.21 0.00 0.00 0.00 0.00 7,747.12 85.00 278.00 3,622.42 3,556.42 1,549.52 -5,947.18 5.00 4.58 -2.06 -24.50 8,247.12 85.00 278.00 3,666.00 3,600.00 1,618.84 -6,440.43 0.00 0.00 0.00 0.00 8,415.89 92.00 273.28 3,670.42 3,604.42 1,635.40 -6,608.17 5.00 4.15 -2.79 -34.05 8,722.43 92.00 273.28 3,659.72 3,593.72 1,652.95 -6,914.03 0.00 0.00 0.00 0.00 8,751.08 90.81 274.08 3,659.01 3,593.01 1,654.79 -6,942.60 5.00 -4.16 2.78 146.23 12,501.08 90.81 274.08 3,606.00 3,540.00 1,921.57 -10,682.73 0.00 0.00 0.00 0.00 13,701.08 90.81 274.08 3,589.04 3,523.04 2,006.94 -11,879.57 0.00 0.00 0.00 0.00 8/19/2015 7:46:31PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton HALL I B U R'I'O N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPJ-27 Company: Hilcorp Energy Company TVD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: Plan:MPJ-27 Survey Calculation Method: Minimum Curvature Wellbore: MPJ-27 Design: MPJ-27 WP3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -35.00 31.00 0.00 0.00 31.00 -35.00 0.00 0.00 6,014,663.74 552,166.18 0.00 0.00 100.00 0.00 0.00 100.00 34.00 0.00 0.00 6,014,663.74 552,166.18 0.00 0.00 200.00 0.00 0.00 200.00 134.00 0.00 0.00 6,014,663.74 552,166.18 0.00 0.00 300.00 0.00 0.00 300.00 234.00 0.00 0.00 6,014,663.74 552,166.18 0.00 0.00 Start Dir 1.5°1100':300'MD,300'TVD 400.00 1.50 300.00 399.99 333.99 0.65 -1.13 6,014,664.39 552,165.04 1.50 1.23 500.00 3.00 300.00 499.91 433.91 2.62 -4.53 6,014,666.33 552,161.63 1.50 4.93 Start Dir 2.51100':500'MD,499.91'TVD 600.00 5.50 300.00 599.63 533.63 6.32 -10.95 6,014,669.99 552,155.19 2.50 11.90 700.00 8.00 300.00 698.92 632.92 12.20 -21.13 6,014,675.79 552,144.97 2.50 22.95 Start Dir 4°/100':700'MD,698.927VD 800.00 11.89 294.47 797.41 731.41 19.95 -36.54 6,014,683.43 552,129.51 4.00 39.49 900.00 15.83 291.65 894.48 828.48 29.25 -58.60 6,014,692.58 552,107.38 4.00 62.85 1,000.00 19.80 289.93 989.66 923.66 40.06 -87.21 6,014,703.18 552,078.70 4.00 92.93 1,100.00 23.78 288.77 1,082.50 1,016.50 52.32 -122.23 6,014,715.20 552,043.59 4.00 129.57 1,200.00 27.76 287.93 1,172.54 1,106.54 65.98 -163.49 6,014,728.57 552,002.25 4.00 172.59 1,300.00 31.75 287.28 1,259.34 1,193.34 80.97 -210.79 6,014,743.23 551,954.85 4.00 221.79 1,400.00 35.74 286.77 1,342.48 1,276.48 97.22 -263.89 6,014,759.10 551,901.64 4.00 276.93 1,500.00 39.73 286.34 1,421.55 1,355.55 114.64 -322.54 6,014,776.11 551,842.88 4.00 337.74 1,600.00 43.72 285.98 1,496.18 1,430.18 133.15 -386.45 6,014,794.17 551,778.84 4.00 403.92 1,700.00 47.71 285.67 1,565.98 1,499.98 152.67 -455.32 6,014,813.20 551,709.85 4.00 475.15 1,800.00 51.71 285.40 1,630.63 1,564.63 173.09 -528.80 6,014,833.11 551,636.24 4.00 551.08 1,900.00 55.70 285.16 1,689.81 1,623.81 194.32 -606.53 6,014,853.79 551,558.36 4.00 631.35 2,000.00 59.70 284.93 1,743.24 1,677.24 216.25 -688.15 6,014,875.15 551,476.60 4.00 715.56 2,100.00 63.69 284.73 1,790.64 1,724.64 238.78 -773.24 6,014,897.08 551,391.36 4.00 803.30 2,200.00 67.69 284.54 1,831.80 1,765.80 261.79 -861.40 6,014,919.47 551,303.05 4.00 894.14 2,277.36 70.78 284.40 1,859.22 1,793.22 279.86 -931.44 6,014,937.05 551,232.90 4.00 966.26 End Dir :2277.36'MD,1859.22'ND 2,300.00 70.78 284.40 1,866.67 1,800.67 285.18 -952.14 6,014,942.22 551,212.16 0.00 987.59 2,400.00 70.78 284.40 1,899.58 1,833.58 308.66 -1,043.61 6,014,965.05 551,120.54 0.00 1,081.76 2,500.00 70.78 284.40 1,932.50 1,866.50 332.14 -1,135.07 6,014,987.89 551,028.92 0.00 1,175.93 2,600.00 70.78 284.40 1,965.41 1,899.41 355.61 -1,226.53 6,015,010.73 550,937.31 0.00 1,270.11 2,700.00 70.78 284.40 1,998.33 1,932.33 379.09 -1,317.99 6,015,033.56 550,845.69 0.00 1,364.28 2,800.00 70.78 284.40 2,031.24 1,965.24 402.57 -1,409.46 6,015,056.40 550,754.08 0.00 1,458.46 2,900.00 70.78 284.40 2,064.16 1,998.16 426.05 -1,500.92 6,015,079.23 550,662.46 0.00 1,552.63 3,000.00 70.78 284.40 2,097.07 2,031.07 449.53 -1,592.38 6,015,102.07 550,570.85 0.00 1,646.80 3,100.00 70.78 284.40 2,129.99 2,063.99 473.01 -1,683.84 6,015,124.90 550,479.23 0.00 1,740.98 3,200.00 70.78 284.40 2,162.90 2,096.90 496.49 -1,775.30 6,015,147.74 550,387.62 0.00 1,835.15 3,300.00 70.78 284.40 2,195.82 2,129.82 519.96 -1,866.77 6,015,170.57 550,296.00 0.00 1,929.33 3,400.00 70.78 284.40 2,228.73 2,162.73 543.44 -1,958.23 6,015,193.41 550,204.38 0.00 2,023.50 3,500.00 70.78 284.40 2,261.65 2,195.65 566.92 -2,049.69 6,015,216.25 550,112.77 0.00 2,117.67 3,600.00 70.78 284.40 2,294.56 2,228.56 590.40 -2,141.15 6,015,239.08 550,021.15 0.00 2,211.85 3,700.00 70.78 284.40 2,327.48 2,261.48 613.88 -2,232.62 6,015,261.92 549,929.54 0.00 2,306.02 3,800.00 70.78 284.40 2,360.39 2,294.39 637.36 -2,324.08 6,015,284.75 549,837.92 0.00 2,400.20 3,900.00 70.78 284.40 2,393.31 2,327.31 660.84 -2,415.54 6,015,307.59 549,746.31 0.00 2,494.37 8/19/2015 7:46:31PM Page 3 COMPASS 5000.1 Build 73 • . Halliburton HALLIBURTOI J Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPJ-27 Company: Hilcorp Energy Company TVD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: Plan:MPJ-27 Survey Calculation Method: Minimum Curvature Weilbore: MPJ-27 Design: MPJ-27 WP3 Planned Survey 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) 2,360.23 4,000.00 70.78 284.40 2,426.23 2,360.23 684.31 -2,507.00 6,015,330.42 549,654.69 0.00 2,588.54 4,100.00 70.78 284.40 2,459.14 2,393.14 707.79 -2,598.47 6,015,353.26 549,563.08 0.00 2,682.72 4,200.00 70.78 284.40 2,492.06 2,426.06 731.27 -2,689.93 6,015,376.09 549,471.46 0.00 2,776.89 4,300.00 70.78 284.40 2,524.97 2,458.97 754.75 -2,781.39 6,015,398.93 549,379.84 0.00 2,871.06 4,400.00 70.78 284.40 2,557.89 2,491.89 778.23 -2,872.85 6,015,421.77 549,288.23 0.00 2,965.24 4,500.00 70.78 284.40 2,590.80 2,524.80 801.71 -2,964.31 6,015,444.60 549,196.61 0.00 3,059.41 4,600.00 70.78 284.40 2,623.72 2,557.72 825.19 -3,055.78 6,015,467.44 549,105.00 0.00 3,153.59 4,700.00 70.78 284.40 2,656.63 2,590.63 848.66 -3,147.24 6,015,490.27 549,013.38 0.00 3,247.76 4,800.00 70.78 284.40 2,689.55 2,623.55 872.14 -3,238.70 6,015,513.11 548,921.77 0.00 3,341.93 4,900.00 70.78 284.40 2,722.46 2,656.46 895.62 -3,330.16 6,015,535.94 548,830.15 0.00 3,436.11 5,000.00 70.78 284.40 2,755.38 2,689.38 919.10 -3,421.63 6,015,558.78 548,738.54 0.00 3,530.28 5,100.00 70.78 284.40 2,788.29 2,722.29 942.58 -3,513.09 6,015,581.61 548,646.92 0.00 3,624.46 5,200.00 70.78 284.40 2,821.21 2,755.21 966.06 -3,604.55 6,015,604.45 548,555.30 0.00 3,718.63 5,300.00 70.78 284.40 2,854.12 2,788.12 989.54 -3,696.01 6,015,627.28 548,463.69 0.00 3,812.80 5,400.00 70.78 284.40 2,887.04 2,821.04 1,013.01 -3,787.48 6,015,650.12 548,372.07 0.00 3,906.98 5,500.00 70.78 284.40 2,919.95 2,853.95 1,036.49 -3,878.94 6,015,672.96 548,280.46 0.00 4,001.15 5,600.00 70.78 284.40 2,952,87 2,886.87 1,059.97 -3,970.40 6,015,695.79 548,188.84 0.00 4,095.33 5,700.00 70.78 284.40 2,985.78 2,919.78 1,083.45 -4,061.86 6,015,718.63 548,097.23 0.00 4,189.50 5,800.00 70.78 284.40 3,018.70 2,952.70 1,106.93 -4,153.32 6,015,741.46 548,005.61 0.00 4,283.67 5,900.00 70.78 284.40 3,051.61 2,985.61 1,130.41 -4,244.79 6,015,764.30 547,914.00 0.00 4,377.85 6,000.00 70.78 284.40 3,084.53 3,018.53 1,153.89 -4,336.25 6,015,787.13 547,822.38 0.00 4,472.02 6,100.00 70.78 284.40 3,117.44 3,051.44 1,177.36 -4,427.71 6,015,809.97 547,730.77 0.00 4,566.19 6,200.00 70.78 284.40 3,150.36 3,084.36 1,200.84 -4,519.17 6,015,832.80 547,639.15 0.00 4,660.37 6,300.00 70.78 284.40 3,183.27 3,117.27 1,224.32 -4,610.64 6,015,855.64 547,547.53 0.00 4,754.54 6,400.00 70.78 284.40 3,216.19 3,150.19 1,247.80 -4,702.10 6,015,878.48 547,455.92 0.00 4,848.72 6,500.00 70.78 284.40 3,249.10 3,183.10 1,271.28 -4,793.56 6,015,901.31 547,364.30 0.00 4,942.89 6,600.00 70.78 284.40 3,282.02 3,216.02 1,294.76 -4,885.02 6,015,924.15 547,272.69 0.00 5,037.06 6,700.00 70.78 284.40 3,314.93 3,248.93 1,318.24 -4,976.49 6,015,946.98 547,181.07 0.00 5,131.24 6,800.00 70.78 284.40 3,347.85 3,281.85 1,341.71 -5,067.95 6,015,969.82 547,089.46 0.00 5,225.41 6,900.00 70.78 284.40 3,380.76 3,314.76 1,365.19 -5,159.41 6,015,992.65 546,997.84 0.00 5,319.59 7,000.00 70.78 284.40 3,413.68 3,347.68 1,388.67 -5,250.87 6,016,015.49 546,906.23 0.00 5,413.76 7,100.00 70.78 284.40 3,446.59 3,380.59 1,412.15 -5,342.33 6,016,038.32 546,814.61 0.00 5,507.93 7,200.00 70.78 284.40 3,479.51 3,413.51 1,435.63 -5,433.80 6,016,061.16 546,722.99 0.00 5,602.11 7,300.00 70.78 284.40 3,512.42 3,446.42 1,459.11 -5,525.26 6,016,084.00 546,631.38 0.00 5,696.28 7,400.00 70.78 284.40 3,545.34 3,479.34 1,482.59 -5,616.72 6,016,106.83 546,539.76 0.00 5,790.46 7,436.62 70.78 284.40 3,557.39 3,491.39 1,491.18 -5,650.21 6,016,115.19 546,506.21 0.00 5,824.94 Start Dir 51100':7436.62'MD,3557.39'TVD 7,500.00 73.67 283.03 3,576.74 3,510.74 1,505.48 -5,708.84 6,016,129.08 546,447.49 5.00 5,885.18 7,600.00 78.25 280.95 3,601.00 3,535.00 1,525.61 -5,803.71 6,016,148.54 546,352.49 5.00 5,982.11 7,700.00 82.83 278.93 3,617.43 3,551.43 1,542.62 -5,900.84 6,016,164.87 546,255.26 5.00 6,080.72 7,747.12 85.00 278.00 3,622.42 3,556.42 1,549.52 -5,947.18 6,016,171.44 546,208.88 5.00 6,127.54 End Dir :7747.12'MD,3622.42'TVD 7,800.00 85.00 278.00 3,627.03 3,561.03 1,556.85 -5,999.35 6,016,178.40 546,156.66 0.00 6,180.19 7,900.00 85.00 278.00 3,635.75 3,569.75 1,570.71 -6,098.00 6,016,191.58 546,057.93 0.00 6,279.73 8,000.00 85.00 278.00 3,644.46 3,578.46 1,584.58 -6,196.65 6,016,204.75 545,959.19 0.00 6,379.28 8/19/2015 7:46:31PM Page 4 COMPASS 5000.1 Build 73 I S Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPJ-27 Company: Hilcorp Energy Company TVD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: Plan:MPJ-27 Survey Calculation Method: Minimum Curvature Wellbore: MPJ-27 Design: MPJ-27 WP3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N1-S +E/-W Northing Easting US Vert Section (usft) (^) (^) (usft) usft (usft) (usft) (usft) (usft) 3,587.18 8,100.00 85.00 278.00 3,653.18 3,587.18 1,598.44 -6,295.30 6,016,217.92 545,860.46 0.00 6,478.83 8,200.00 85.00 278.00 3,661.89 3,595.89 1,612.30 -6,393.95 6,016,231.09 545,761.72 0.00 6,578.37 8,247.00 85.00 278.00 3,665.99 3,599.99 1,618.82 -6,440.31 6,016,237.28 545,715.32 0.00 6,625.16 -.Q.- 9 5/8"x 12 1/4" 8,247.12 85.00 278.00 3,666.00 3,600.00 1,618.84 -6,440.43 6,016,237.30 545,715.20 0.00 6,625.28 Start Dir 5°/100':8247.12'MD,3666'TVD 8,300.00 87.19 276.52 3,669.60 3,603.60 1,625.50 -6,492.76 6,016,243.60 545,662.83 5.00 6,677.96 8,400.00 91.34 273.73 3,670.88 3,604.88 1,634.43 -6,592.32 6,016,251.82 545,563.22 5.00 6,777.53 8,415.89 92.00 273.28 3,670.42 3,604.42 1,635.40 -6,608.17 6,016,252.68 545,547.36 5.00 6,793.30 End Dir :8415.89'MD,3670.42'TVD 8,500.00 92.00 273.28 3,667.48 3,601.48 1,640.21 -6,692.10 6,016,256.91 545,463.41 0.00 6,876.75 8,600.00 92.00 273.28 3,663.99 3,597.99 1,645.94 -6,791.87 6,016,261.94 545,363.61 0.00 6,975.97 8,700.00 92.00 273.28 3,660.50 3,594.50 1,651.66 -6,891.65 6,016,266.96 545,263.81 0.00 7,075.18 8,722.43 92.00 273.28 3,659.72 3,593.72 1,652.95 -6,914.03 6,016,268.09 545,241.42 0.00 7,097.43 Start Dir 5°/100':8722.43'MD,3659.72'TVD 8,751.08 90.81 274.08 3,659.01 3,593.01 1,654.79 -6,942.60 6,016,269.73 545,212.84 5.00 7,125.88 End Dir :8751.08'MD,3659.01'TVD 8,800.00 90.81 274.08 3,658.32 3,592.32 1,658.27 -6,991.40 6,016,272.87 545,164.02 0.00 7,174.52 8,900.00 90.81 274.08 3,656.91 3,590.91 1,665.38 -7,091.14 6,016,279.28 545,064.25 0.00 7,273.95 9,000.00 90.81 274.08 3,655.49 3,589.49 1,672.49 -7,190.87 6,016,285.70 544,964.47 0.00 7,373.37 9,100.00 90.81 274.08 3,654.08 3,588.08 1,679.61 -7,290.61 6,016,292.11 544,864.70 0.00 7,472.79 9,200.00 90.81 274.08 3,652.67 3,586.67 1,686.72 -7,390.35 6,016,298.53 544,764.92 0.00 7,572.21 9,300.00 90.81 274.08 3,651.25 3,585.25 1,693.84 -7,490.08 6,016,304.94 544,665.15 0.00 7,671.63 9,400.00 90.81 274.08 3,649.84 3,583.84 1,700.95 -7,589.82 6,016,311.36 544,565.38 0.00 7,771.05 9,500.00 90.81 274.08 3,648.43 3,582.43 1,708.07 -7,689.56 6,016,317.77 544,465.60 0.00 7,870.47 9,600.00 90.81 274.08 3,647.01 3,581.01 1,715.18 -7,789.29 6,016,324.19 544,365.83 0.00 7,969.89 9,700.00 90.81 274.08 3,645.60 3,579.60 1,722.29 -7,889.03 6,016,330.60 544,266.05 0.00 8,069.31 9,800.00 90.81 274.08 3,644.18 3,578.18 1,729.41 -7,988.77 6,016,337.02 544,166.28 0.00 8,168.74 9,900.00 90.81 274.08 3,642.77 3,576.77 1,736.52 -8,088.50 6,016,343.43 544,066.50 0.00 8,268.16 10,000.00 90.81 274.08 3,641.36 3,575.36 1,743.64 -8,188.24 6,016,349.85 543,966.73 0.00 8,367.58 10,100.00 90.81 274.08 3,639.94 3,573.94 1,750.75 -8,287.98 6,016,356.27 543,866.96 0.00 8,467.00 10,200.00 90.81 274.08 3,638.53 3,572.53 1,757.86 -8,387.71 6,016,362.68 543,767.18 0.00 8,566.42 10,300.00 90.81 274.08 3,637.12 3,571.12 1,764.98 -8,487.45 6,016,369.10 543,667.41 0.00 8,665.84 10,400.00 90.81 274.08 3,635.70 3,569.70 1,772.09 -8,587.19 6,016,375.51 543,567.63 0.00 8,765.26 10,500.00 90.81 274.08 3,634.29 3,568.29 1,779.21 -8,686.92 6,016,381.93 543,467.86 0.00 8,864.68 10,600.00 90.81 274.08 3,632.87 3,566.87 1,786.32 -8,786.66 6,016,388.34 543,368.08 0.00 8,964.10 10,700.00 90.81 274.08 3,631.46 3,565.46 1,793.44 -8,886.40 6,016,394.76 543,268.31 0.00 9,063.53 10,800.00 90.81 274.08 3,630.05 3,564.05 1,800.55 -8,986.13 6,016,401.17 543,168.54 0.00 9,162.95 10,900.00 90.81 274.08 3,628.63 3,562.63 1,807.66 -9,085.87 6,016,407.59 543,068.76 0.00 9,262.37 11,000.00 90.81 274.08 3,627.22 3,561.22 1,814.78 -9,185.61 6,016,414.00 542,968.99 0.00 9,361.79 11,100.00 90.81 274.08 3,625.81 3,559.81 1,821.89 -9,285.34 6,016,420.42 542,869.21 0.00 9,461.21 11,200.00 90.81 274.08 3,624.39 3,558.39 1,829.01 -9,385.08 6,016,426.83 542,769.44 0.00 9,560.63 11,300.00 90.81 274.08 3,622.98 3,556.98 1,836.12 -9,484.82 6,016,433.25 542,669.66 0.00 9,660.05 11,400.00 90.81 274.08 3,621.57 3,555.57 1,843.24 -9,584.55 6,016,439.66 542,569.89 0.00 9,759.47 11,500.00 90.81 274.08 3,620.15 3,554.15 1,850.35 -9,684.29 6,016,446.08 542,470.12 0.00 9,858.89 8/19/2015 7:46:31PM Page 5 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPJ-27 Company: Hilcorp Energy Company TVD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: Plan:MPJ-27 Survey Calculation Method: Minimum Curvature Wellbore: MPJ-27 Design: MPJ-27 WP3 Planned Survey 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) 3,552.74 11,600.00 90.81 274.08 3,618.74 3,552.74 1,857.46 -9,784.02 6,016,452.49 542,370.34 0.00 9,958.31 11,700.00 90.81 274.08 3,617.32 3,551.32 1,864.58 -9,883.76 6,016,458.91 542,270.57 0.00 10,057.74 11,800.00 90.81 274.08 3,615.91 3,549.91 1,871.69 -9,983.50 6,016,465.32 542,170.79 0.00 10,157.16 11,900.00 90.81 274.08 3,614.50 3,548.50 1,878.81 -10,083.23 6,016,471.74 542,071.02 0.00 10,256.58 12,000.00 90.81 274.08 3,613.08 3,547.08 1,885.92 -10,182.97 6,016,478.15 541,971.24 0.00 10,356.00 12,100.00 90.81 274.08 3,611.67 3,545.67 1,893.03 -10,282.71 6,016,484.57 541,871.47 0.00 10,455.42 12,200.00 90.81 274.08 3,610.26 3,544.26 1,900.15 -10,382.44 6,016,490.99 541,771.70 0.00 10,554.84 12,300.00 90.81 274.08 3,608.84 3,542.84 1,907.26 -10,482.18 6,016,497.40 541,671.92 0.00 10,654.26 12,400.00 90.81 274.08 3,607.43 3,541.43 1,914.38 -10,581.92 6,016,503.82 541,572.15 0.00 10,753.68 12,500.00 90.81 274.08 3,606.02 3,540.02 1,921.49 -10,681.65 6,016,510.23 541,472.37 0.00 10,853.10 12,501.08 90.81 274.08 3,606.00 3,540.00 1,921.57 -10,682.73 6,016,510.30 541,471.30 0.00 10,854.17 12,600.00 90.81 274.08 3,604.60 3,538.60 1,928.61 -10,781.39 6,016,516.65 541,372.60 0.00 10,952.53 12,700.00 90.81 274.08 3,603.19 3,537.19 1,935.72 -10,881.13 6,016,523.06 541,272.82 0.00 11,051.95 12,800.00 90.81 274.08 3,601.77 3,535.77 1,942.83 -10,980.86 6,016,529.48 541,173.05 0.00 11,151.37 12,900.00 90.81 274.08 3,600.36 3,534.36 1,949.95 -11,080.60 6,016,535.89 541,073.28 0.00 11,250.79 13,000.00 90.81 274.08 3,598.95 3,532.95 1,957.06 -11,180.34 6,016,542.31 540,973.50 0.00 11,350.21 13,100.00 90.81 274.08 3,597.53 3,531.53 1,964.18 -11,280.07 6,016,548.72 540,873.73 0.00 11,449.63 13,200.00 90.81 274.08 3,596.12 3,530.12 1,971.29 -11,379.81 6,016,555.14 540,773.95 0.00 11,549.05 13,300.00 90.81 274.08 3,594.71 3,528.71 1,978.41 -11,479.55 6,016,561.55 540,674.18 0.00 11,648.47 13,400.00 90.81 274.08 3,593.29 3,527.29 1,985.52 -11,579.28 6,016,567.97 540,574.40 0.00 11,747.89 13,500.00 90.81 274.08 3,591.88 3,525.88 1,992.63 -11,679.02 6,016,574.38 540,474.63 0.00 11,847.31 13,600.00 90.81 274.08 3,590.46 3,524.46 1,999.75 -11,778.76 6,016,580.80 540,374.86 0.00 11,946.74 13,700.00 90.81 274.08 3,589.05 3,523.05 2,006.86 -11,878.49 6,016,587.21 540,275.08 0.00 12,046.16 13,701.08 90.81 274.08 3,589.04 3,523.04 2,006.94 -11,879.57 6,016,587.28 540,274.01 0.00 12,047.23 TD at 13701.08 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) MPJ-27 Toe 0.00 0.00 3,606.00 1,921.57 -10,682.73 6,016,510.30 541,471.30 -plan hits target center -Circle(radius 20.00) MPJ-27 Heel 0.00 0.00 3,666.00 1,618.84 -6,440.43 6,016,237.30 545,715.20 -plan hits target center -Circle(radius 20.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (1 8,247.00 3,665.99 9 5/8"x 12 1/4" 9-5/8 12-1/4 13,701.08 3,589.04 5 1/2" 5-1/2 8-1/2 8/19/2015 7:46:31PM Page 6 COMPASS 5000.1 Build 73 • s Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPJ-27 Company: Hilcorp Energy Company TVD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Project: Milne Point MD Reference: MPJ-27 Pre @ 66.00usft(NORDIC 3) Site: M Pt J Pad North Reference: True Well: Plan:MPJ-27 Survey Calculation Method: Minimum Curvature Wellbore: MPJ-27 Design: MPJ-27 WP3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 Start Dir 1.5°/100':300'MD,300'TVD 500.00 499.91 2.62 -4.53 Start Dir 2.5°/100':500'MD,499.911-VD 700.00 698.92 12.20 -21.13 Start Dir 4°/100':700'MD,698.92'TVD 2,277.36 1,859.22 279.86 -931.44 End Dir :2277.36'MD,1859.22'TVD 7,436.62 3,557.39 1,491.18 -5,650.21 Start Dir 5°/100':7436.62'MD,3557.39'TVD 7,747.12 3,622.42 1,549.52 -5,947.18 End Dir :7747.12'MD,3622.42'TVD 8,247.12 3,666.00 1,618.84 -6,440.43 Start Dir 5°/100':8247.12'MD,3666'TVD 8,415.89 3,670.42 1,635.40 -6,608.17 End Dir :8415.89'MD,3670.42'TVD 8,722.43 3,659.72 1,652.95 -6,914.03 Start Dir 5°/100':8722.43'MD,3659.72'TVD 8,751.08 3,659.01 1,654.79 -6,942.60 End Dir :8751.08'MD,3659.01'TVD 13,701.08 3,589.04 1,921.57 -10,682.73 TD at 13701.08 8/19/2015 7:46:31PM Page 7 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company Milne Point M Pt J Pad Plan: MPJ-27 MPJ-27 MPJ-27 WP3 Sperry Drilling Services Clearance Summary Anticollision Report 19 August,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Well Coordinates:6,014,683.74 N,552,186.18 E(70'27'02.88"N,149°34'27.78"W) Datum Height: MPJ-27 Pre @ 66.O0usft(NORDIC 3) Scan Range:0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1,567.01 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Service. • • Hilcorp Energy Company HALLIBURTON Miine Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range: 0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1,567.01 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 M Pt J Pad MPJ-01-MPJ-01-MPJ-01 1,483.98 290,38 1,483.98 276.11 1,408.87 20.355 Centre Distance Pass- MPJ-01-MPJ-01-MPJ-01 1,500.00 290.57 1,500.00 276.08 1,420.55 20.049 Ellipse Separation Pass- MPJ-01-MPJ-01-MPJ-01 1,625.00 306.15 1,625.00 289.91 1,509.26 18.844 Clearance Factor Pass- MPJ-01-MPJ-01-MPJ-01 1,483.98 290.38 1,483.98 279.57 1,408.87 26.878 Centre Distance Pass- MPJ-01-MPJ-01-MPJ-01 1,500.00 290.57 1,500.00 279.54 1,420.55 26.338 Ellipse Separation Pass- MPJ-01-MPJ-01-MPJ-01 1,675.00 319.56 1,675.00 306.07 1,542.35 23.686 Clearance Factor Pass- MPJ-01-MPJ-0IA-MPJ-01A 1,483.98 290.38 1,483.98 279.79 1,408.87 27.420 Centre Distance Pass- MPJ-01-MPJ-0IA-MPJ-01A 1,500.00 290.57 1,500.00 279.75 1,420.55 26.858 Ellipse Separation Pass- MPJ-01-MPJ-OIA-MPJ-01A 1,675.00 319.56 1,675.00 306.29 1,542.35 24.067 Clearance Factor Pass- MPJ-01-MPJ-01A-MPJ-01A 1,483.98 290.38 1,483.98 276.32 1,408.87 20.664 Centre Distance Pass- MPJ-01-MPJ-0IA-MPJ-01A 1,500.00 290.57 1,500.00 276.29 1,420.55 20.349 Ellipse Separation Pass- MPJ-01-MPJ-01A-MPJ-01A 1,650.00 312.35 1,650.00 295.99 1,525.86 19.093 Clearance Factor Pass- MPJ-01-MPJ-0IALI-Plan#5 1,483.98 290.38 1,483.98 279.57 1,408.87 26.878 Centre Distance Pass- MPJ-01-MPJ-01AL1-Plan#5 1,500.00 290.57 1,500.00 279.54 1,420.55 26.338 Ellipse Separation Pass- MPJ-01-MPJ-0IAL1-Plan#5 1,675.00 319.56 1,675.00 306.07 1,542.35 23.686 Clearance Factor Pass- MPJ-01-MPJ-01AL1-MPJ-01A1.1 1,483.98 290.38 1,483.98 276.41 1,408.87 20.795 Centre Distance Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 1,500.00 290.57 1,500.00 276.38 1,420.55 20.476 Ellipse Separation Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 1,650.00 312.35 1,650.00 296.08 1,525.86 19.197 Clearance Factor Pass- MPJ-01-MPJ-01AL1-Plan#5 1,483.98 290.38 1,483.98 276.11 1,408.87 20.355 Centre Distance Pass- MPJ-01-MPJ-01AL1-Plan#5 1,500.00 290.57 1,500.00 276.08 1,420.55 20.049 Ellipse Separation Pass- MPJ-01-MPJ-01AL1-Plan#5 1,625.00 306.15 1,625.00 289.91 1,509.26 18.844 Clearance Factor Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 1,483.98 290.38 1,483.98 279.57 1,408.87 26.878 Centre Distance Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 1,500.00 290.57 1,500.00 279.54 1,420.55 26.338 Ellipse Separation Pass- MPJ-01-MPJ-01AL1-MPJ-01AL1 1,675.00 319.56 1,675.00 306.07 1,542.35 23.686 Clearance Factor Pass- MPJ-03-MPJ-03-MPJ-03 1,321.83 56.11 1,321.83 40.91 1,320.50 3.693 Clearance Factor Pass- MPJ-03-MPJ-03-MPJ-03 1,321.83 56.11 1,321.83 44.69 1,320.50 4.913 Clearance Factor Pass- MPJ-04-MPJ-04-MPJ-04 1,105.95 153.83 1,105.95 142.74 1,103.82 13.877 Ellipse Separation Pass- MPJ-04-MPJ-04-MPJ-04 1,150.00 156.59 1,150.00 145.02 1,137.37 13.539 Clearance Factor Pass- 19 August,2015- 19:45 Page 2 of 12 COMPASS f, • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range: 0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1,567.01 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 MPJ-04-MPJ-04-MPJ-04 1,105.95 153.83 1,105.95 144.34 1,103.82 16219 Ellipse Separation Pass- MPJ-04-MPJ-04-MPJ-04 1,150.00 156.59 1,150.00 146.71 1,137.37 15.849 Clearance Factor Pass- MPJ-05-MPJ-05-MPJ-05 659.37 19.64 659.37 14.27 662.73 3.658 Centre Distance Pass- MPJ-05-MPJ-05-MPJ-05 675.00 19.76 675.00 14.27 678.21 3.601 Clearance Factor Pass- MPJ-05-MPJ-05-MPJ-05 659.37 19.64 659.37 15.08 662.73 4.306 Centre Distance Pass- MPJ-05-MPJ-05-MPJ-05 675.00 19.76 675.00 15.07 678.21 4.217 Ellipse Separation Pass- MPJ-05-MPJ-05-MPJ-05 700.00 20.45 700.00 15.59 702.94 4.207 Clearance Factor Pass- MPJ-06-MPJ-06-MPJ-06 1,004.81 101.17 1,004.81 95.85 993.49 19.047 Ellipse Separation Pass- MPJ-06-MPJ-06-MPJ-06 1,075.00 104.58 1,075.00 98.80 1,058.85 18.114 Clearance Factor Pass- MPJ-06-MPJ-06-MPJ-06 1,004.81 101.17 1,004.81 97.39 993.49 26.774 Ellipse Separation Pass- MPJ-06-MPJ-06-MPJ-06 1,125.00 111.61 1,125.00 107.18 1,104.67 25.188 Clearance Factor Pass- MPJ-07-MPJ-07-MPJ-07 362.06 28.61 362.06 24.98 366.64 7.871 Centre Distance Pass- MPJ-07-MPJ-07-MPJ-07 425.00 28.91 425.00 24.66 429.72 6.811 Ellipse Separation Pass- MPJ-07-MPJ-07-MPJ-07 550.00 31.53 550.00 26.23 554.84 5.952 Clearance Factor Pass- MPJ-07-MPJ-07-MPJ-07 362.06 28.61 362.06 25.48 366.64 9.140 Centre Distance Pass- MPJ-07-MPJ-07-MPJ-07 425.00 28.91 425.00 25.31 429.72 8.029 Ellipse Separation Pass- MPJ-07-MPJ-07-MPJ-07 575.00 32.71 575.00 27.98 579.79 6.908 Clearance Factor Pass- MPJ-08-MPJ-08-MPJ-08 1,378.46 234.07 1,378.46 227.91 1,313.95 37.967 Ellipse Separation Pass- MPJ-08-MPJ-08-MPJ-08 1,575.00 264.47 1,575.00 256.24 1,467.67 32.136 Clearance Factor Pass- MPJ-08-MPJ-08-MPJ-08 1,378.46 234.07 1,378.46 225.39 1,313.95 26.970 Ellipse Separation Pass- MPJ-08-MPJ-08-MPJ-08 1,525.00 250.65 1,525.00 240.43 1,430.31 24.536 Clearance Factor Pass- MPJ-08-MPJ-08A-MPJ-08A 1,378.46 234.07 1,378.46 225.39 1,313.95 26.970 Ellipse Separation Pass- MPJ-08-MPJ-08A-MPJ-08A 1,525.00 250.65 1,525.00 240.43 1,430.31 24.536 Clearance Factor Pass- MPJ-08A-MPJ-08A-MPJ-08A 1,378.46 234.07 1,378.46 227.70 1,313.95 36.756 Ellipse Separation Pass- MPJ-08A-MPJ-08A-MPJ-08A 1,575.00 264.47 1,575.00 256.04 1,467.67 31.362 Clearance Factor Pass- MPJ-09-MPJ-09-MPJ-09 854.13 63.40 854.13 60.16 835.84 19.590 Ellipse Separation Pass- MPJ-09-MPJ-09-MPJ-09 4,475.00 1,554.14 4,475.00 1,447.37 4,342.24 14.556 Clearance Factor Pass- MPJ-09-MPJ-09-MPJ-09 851.54 64.65 851.54 60.26 833.29 14.729 Ellipse Separation Pass- MPJ-09-MPJ-09-MPJ-09 950.00 68.18 950.00 63.21 929.20 13.706 Clearance Factor Pass- MPJ-09-MPJ-09A-MPJ-09A 851.54 64.65 851.54 60.26 844.61 14.729 Ellipse Separation Pass- MPJ-09-MPJ-09A-MPJ-09A 7,325.00 1,302.32 7,325.00 1,052.47 8,235.00 5.212 Clearance Factor Pass- 19 August,2018-19:45 Pep*3 0112 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range: 0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1,567.01 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) us% MPJ-09-MPJ-09A-MPJ-09A 854.13 63.40 854.13 60.16 847.16 19.590 Ellipse Separation Pass- MPJ-09-MPJ-09A-MPJ-09A 7,325.00 1,301.09 7,325.00 1,035.92 8,235.00 4.907 Clearance Factor Pass- MPJ-10-MPJ-10-MPJ-10 1,091.43 250.43 1,091.43 244.87 1,025.06 45.029 Centre Distance Pass- MPJ-10-MPJ-10-MPJ-10 1,100.00 250.46 1,100.00 244.83 1,032.18 44.473 Ellipse Separation Pass- MPJ-10-MPJ-10-MPJ-10 1,375.00 303.26 1,375.00 294.91 1,223.97 36.322 Clearance Factor Pass- MPJ-10-MPJ-10-MPJ-10 1,091.43 250.43 1,091.43 244.39 1,025.06 41.423 Centre Distance Pass- MPJ-10-MPJ-10-MPJ-10 1,100.00 250.46 1,100.00 244.35 1,032.18 40.944 Ellipse Separation Pass- MPJ-10-MPJ-10-MPJ-10 1,350.00 293.83 1,350.00 285.22 1,208,63 34.121 Clearance Factor Pass- MPJ-12-MPJ-12-MPJ-12 800.95 107.06 800.95 103.68 787.57 31.672 Ellipse Separation Pass- MPJ-12-MPJ-12-MPJ-12 975.00 120.70 975.00 116.29 946.08 27.363 Clearance Factor Pass- MPJ-12-MPJ-12-MPJ-12 800.95 107.06 800.95 102.94 787.57 26.006 Ellipse Separation Pass- MPJ-12-MPJ-12-MPJ-12 950.00 116.71 950.00 111.71 923.97 23.329 Clearance Factor Pass- MPJ-13-MPJ-13-MPJ-13 743.31 47.33 743.31 43.49 738.30 12.333 Centre Distance Pass- MPJ-13-MPJ-13-MPJ-13 750.00 47.35 750.00 43.48 744.77 12.232 Ellipse Separation Pass- MPJ-13-MPJ-13-MPJ-13 800.00 49.27 800.00 45.15 792.76 11.962 Clearance Factor Pass- MPJ-13-MPJ-13-MPJ-13 743.31 47.33 743.31 44.26 738.30 15.448 Centre Distance Pass- MPJ-13-MPJ-13-MPJ-13 750.00 47.35 750.00 44.26 744.77 15.315 Ellipse Separation Pass- MPJ-13-MPJ-13-MPJ-13 800.00 4927 800.00 45.97 792.76 14.918 Clearance Factor Pass- MPJ-15-MPJ-15-MPJ-15 1,039.92 188.81 1,039.92 183.68 974.54 36.808 Centre Distance Pass- MPJ-15-MPJ-15-MPJ-15 1,050.00 188.83 1,050.00 183.65 982.95 36.431 Ellipse Separation Pass- MPJ-15-MPJ-15-MPJ-15 1,925.00 426.11 1,925.00 403.92 1,643.93 19.204 Clearance Factor Pass- MPJ-15-MPJ-15-MPJ-15 1,039.92 188.81 1,039.92 183.79 974.54 37.654 Centre Distance Pass- MPJ-15-MPJ-15-MPJ-15 1,050.00 188.83 1,050.00 183.77 982.95 37.278 Ellipse Separation Pass- MPJ-15-MPJ-15-MPJ-15 1,925.00 426.11 1,925.00 403.45 1,643.93 18.801 Clearance Factor Pass- MPJ-16-MPJ-16-MPJ-16 1,234.21 73.09 1,234.21 67.20 1,185.63 12.399 Ellipse Separation Pass- MPJ-16-MPJ-16-MPJ-16 1,325.00 83.91 1,325.00 76.31 1,265.00 11.034 Clearance Factor Pass- MPJ-16-MPJ-16-MPJ-16 1,234.21 73.09 1,234.21 66.38 1,185.63 10.891 Ellipse Separation Pass- MPJ-16-MPJ-16-MPJ-16 1,325.00 83.91 1,325.00 75.59 1,265.00 10.082 Clearance Factor Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 1,234.21 73.09 1,234.21 67.31 1,191.23 12.631 Ellipse Separation Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 1,325.00 83.91 1,325.00 76.42 1,270.60 11.198 Clearance Factor Pass- nitwits(2015-19:46 Pqe 4 of 12 COMPASS / • 0 Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range:0.00 to 13,701.08 usft.Measured Depth. Scan Radius Is 1,567.01 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 MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 1,234.21 73.09 1,234.21 66.49 1,191.23 11.071 Ellipse Separation Pass- MPJ-16-MPJ-16A Plan-MPJ-16A Wp 3.0 5,625.00 1,165.25 5,625.00 1,001.57 6,100.00 7.119 Clearance Factor Pass- MPJ-17-MPJ-17-MPJ-17 1,635.97 59.02 1,635.97 41.39 1,558.38 3.348 Centre Distance Pass- MPJ-17-MPJ-17-MPJ-17 1,675.00 59.95 1,675.00 40.96 1,595.88 3.157 Ellipse Separation Pass- MPJ-17-MPJ-17-MPJ-17 1,700.00 61.41 1,700.00 41.75 1,620.21 3.123 Clearance Factor Pass- MPJ-17-MPJ-17-MPJ-17 1,635.97 59.02 1,635.97 41.20 1,558.38 3.312 Centre Distance Pass- MPJ-17-MPJ-17-MPJ-17 1,675.00 59.95 1,675.00 40.77 1,595.88 3.126 Ellipse Separation Pass- MPJ-17-MPJ-17-MPJ-17 1,700.00 61.41 1,700.00 41.56 1,620.21 3.093 Clearance Factor Pass- MPJ-18-MPJ-18-MPJ-18 1,314.26 34.61 1,314.26 26.61 1,263,67 4.326 Centre Distance Pass- MPJ-t8-MPJ-18-MPJ-18 1,325.00 34.78 1,325.00 26.36 1,273.67 4.128 Ellipse Separation Pass- MPJ-18-MPJ-18-MPJ-18 1,375.00 39.94 1,375.00 29.57 1,320.34 3.851 Clearance Factor Pass- MPJ-18-MPJ-18-MPJ-18 1,314.26 34.61 1,314.26 27.00 1,263.67 4.546 Centre Distance Pass- MPJ-18-MPJ-18-MPJ-18 1,325.00 34.78 1,325.00 26.71 1,273.67 4.310 Ellipse Separation Pass- MPJ-18-MPJ-18-MPJ-18 1,375.00 39.94 1,375.00 29.80 1,320.34 3.940 Clearance Factor Pass- MPJ-19-MPJ-19-MPJ-19 1,263.82 93.21 1,263.82 85.71 1,223.97 12.427 Centre Distance Pass- MPJ-19-MPJ-19-MPJ-19 1,275.00 93.26 1,275.00 85.61 1,234.36 12.193 Ellipse Separation Pass- MPJ-19-MPJ-19-MPJ-19 1,475.00 110.46 1,475.00 99.93 1,422.55 10.488 Clearance Factor Pass- MPJ-19-MPJ-19-MPJ-19 1,263.86 93.18 1,263.86 82.18 1,223.53 8.477 Centre Distance Pass- MPJ-19-MPJ-19-MPJ-19 1,275.00 93.23 1,275.00 82.07 1,233.89 8.358 Ellipse Separation Pass- MPJ-19-MPJ-19-MPJ-19 1,400.00 100.38 1,400.00 87.38 1,350.57 7.722 Clearance Factor Pass- MPJ-19-MPJ-19A-MPJ-19A 1,263.86 93.18 1,263.86 82.18 1,223.53 8.477 Centre Distance Pass- MPJ-19-MPJ-19A-MPJ-19A 1,275.00 93.23 1,275.00 82.07 1,233.89 8.358 Ellipse Separation Pass- MPJ-19-MPJ-19A-MPJ-19A 1,400.00 100.38 1,400.00 87.38 1,350.57 7.722 Clearance Factor Pass- MPJ-19A-MPJ-I9A-MPJ-19A 1,263.67 93.14 1,263.67 85.65 1,223.87 12.421 Centre Distance Pass- MPJ-19A-MPJ-I9A-MPJ-19A 1,275.00 93.20 1,275.00 85.55 1,234.41 12.184 Ellipse Separation Pass- MPJ-19A-MPJ-19A-MPJ-19A 1,475.00 110.45 1,475.00 99.92 1,422.60 10.491 Clearance Factor Pass- MPJ-20-MPJ-20-MPJ-20 104.88 145.25 104.88 144.28 38.88 149.167 Centre Distance Pass- MPJ-20-MPJ-20-MPJ-20 1,150.00 147.37 1,150.00 140.18 1,046.41 20.492 Ellipse Separation Pass- MPJ-20-MPJ-20-MPJ-20 6,925.00 1,264.51 6,925.00 985.36 6,874.42 4.530 Clearance Factor Pass- MPJ-20-MPJ-20-MPJ-20 104.45 145.25 104.45 144,17 137.85 134.284 Centre Distance Pass- 19 August,2015-19:45 Page 5 of 12 COMPASS • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range: 0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1,567.01 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 MPJ-20-MPJ-20-MPJ-20 1,150.00 147.43 1,150.00 140.48 1,145.78 21.201 Ellipse Separation Pass- MPJ-20-MPJ-20-MPJ-20 6,925.00 1,264.54 6,925.00 992.69 6,973.68 4,652 Clearance Factor Pass- MPJ-20-MPJ-20A-MPJ-20A - - - - - =1111epariBon FAIL- MPJ-20-MPJ-20A-MPJ-20A - - - - =We Fad«I FAIL- MPJ-20-MPJ-20A-MPJ-20A FAIL- MPJ-20-MPJ-20A-MPJ-20A Wp6 - - - - - "`-- FAIL- '..X.". MPJ-20-MPJ-20A-MPJ-20A Wp6 - - - II. Ill .11.11.81tor FAIL- MPJ-20-MPJ-20A-MPJ-20A Wp6 - - 111MINMS- FAIL- MPJ-20-MPJ-20A-MPJ-20A - - - - =11=16081AFAIL- MPJ-20-MPJ-20A-MPJ-20A - - _ - 11.1111111.111FAIL- MPJ-20-MPJ-20A-MPJ-20A - - - 11111111 FAIL- F MPJ-21-MPJ-21-MPJ-21 104.57 148.45 104.57 147.47 103.70 152.630 Centre Distance Pass- MPJ-21-MPJ-21-MPJ-21 225.00 148.56 225.00 147.13 223.71 104.128 Ellipse Separation Pass- MPJ-21-MPJ-21-MPJ-21 4,625.00 1,563.51 4,625.00 1,434.52 4,477.44 12.121 Clearance Factor Pass- MPJ-21-MPJ-21-MPJ-21 104.57 148.45 104.57 147.47 103.70 152.630 Centre Distance Pass- MPJ-21-MPJ-21-MPJ-21 250.00 148.65 250.00 147.05 248.46 93.029 Ellipse Separation Pass- MPJ-21-MPJ-21-MPJ-21 4,625.00 1,563.51 4,625.00 1,432.32 4,477.44 11.918 Clearance Factor Pass- MPJ-22-MPJ-22-MPJ-22 345.46 156.79 345.46 154.92 369.07 83.986 Centre Distance Pass- MPJ-22-MPJ-22-MPJ-22 375.00 156.86 375.00 154.87 397.55 78.829 Ellipse Separation Pass- MPJ-22-MPJ-22-MPJ-22 1,550.00 309.73 1,550.00 298.08 1,502.04 26.584 Clearance Factor Pass- MPJ-22-MPJ-22-MPJ-22 345.46 156.79 345.46 155.04 369.07 89.374 Centre Distance Pass- MPJ-22-MPJ-22-MPJ-22 350.00 156.79 350.00 155.03 373.45 88.823 Ellipse Separation Pass- MPJ-22-MPJ-22-MPJ-22 4,625.00 1,388.85 4,625.00 1,338.11 4,935.89 27.373 Clearance Factor Pass- MPJ-23-MPJ-23-MPJ-23 3,498.58 135.49 3,498.58 120.12 3,277.22 8.818 Centre Distance Pass- MPJ-23-MPJ-23-MPJ-23 3,975.00 155.99 3,975.00 95.46 3,751.22 2.577 Ellipse Separation Pass- MPJ-23-MPJ-23-MPJ-23 4,125.00 176.97 4,125.00 104.81 3,892.11 2.453 Clearance Factor Pass- MPJ-23-MPJ-23-MPJ-23 3,498.58 135.49 3,498.58 112.85 3,277.22 5.986 Centre Distance Pass- MPJ-23-MPJ-23-MPJ-23 4,025.00 161.79 4,025.00 61.53 3,797.24 1.614 Ellipse Separation Pass- MPJ-23-MPJ-23-MPJ-23 4,125.00 176.97 4,125.00 65.15 3,892.11 1.583 Clearance Factor Pass- MPJ-23-MPJ-23L1-MPJ-23L1 3,498.58 135.49 3,498.58 120.12 3,27722 8.818 Centre Distance Pass- 19 August,2015-19:45 Page 6 0112 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range:0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1,567.01 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 MPJ-23-MPJ-23L1-MPJ-23L1 3,975.00 155.99 3,975.00 95.46 3,751.22 2.577 Ellipse Separation Pass- MPJ-23-MPJ-23L1-MPJ-23L1 4,125.00 176.97 4,125.00 104.81 3,892.11 2.453 Clearance Factor Pass- MPJ-23-MPJ-23L1-MPJ-23L1 3,498.58 135.49 3,498.58 113.50 3,277.22 6.161 Centre Distance Pass- MPJ-23-MPJ-23L1-MPJ-23L1 4,025.00 161.79 4,025.00 62.17 3,797.24 1.624 Ellipse Separation Pass- MPJ-23-MPJ-23L1-MPJ-23L1 4,125.00 176.97 4,125.00 65.80 3,892.11 1.592 Clearance Factor Pass- MPJ-23-Plan:MPJ-23A-MPJ-23Awp3 3,498.58 135.49 3,498.58 113.35 3,280.92 6.121 Centre Distance Pass- MPJ-23-Plan:MPJ-23A-MPJ-23A wp3 4,025.00 161.79 4,025.00 60.43 3,800.94 1.596 Ellipse Separation Pass- MPJ-23-Plan:MPJ-23A-MPJ-23Awp3 4,125.00 176.97 4,125.00 63.81 3,895.81 1.564 Clearance Factor Pass- MPJ-24-MPJ-24-MPJ-224 Wp5 2,277.04 412.92 2,277.04 377.34 1,977.97 11.607 Centre Distance Pass- MPJ-24-MPJ-24-MPJ-224 Wp5 2,375.00 414.66 2,375.00 374.98 2,067.11 10.448 Ellipse Separation Pass- MPJ-24-MPJ-24-MPJ-224 Wp5 11,975.00 1,186.06 11,975.00 782.84 11,961.37 2.941 Clearance Factor Pass- MPJ-24-MPJ-24-MPJ-24 2,300.00 413.86 2,300.00 378.27 1,978.85 11.628 Centre Distance Pass- MPJ-24-MPJ-24-MPJ-24 2,425.00 416.85 2,425.00 375.96 2,095.12 10.196 Ellipse Separation Pass- MPJ-24-MPJ-24-MPJ-24 12,000.00 1,063.28 12,000.00 668.29 11,975.00 2.692 Clearance Factor Pass- MPJ-24-MPJ-24-MPJ-24 2,300.00 413.86 2,300.00 372.49 1,978.85 10.004 Centre Distance Pass- MPJ-24-MPJ-24-MPJ-24 2,450.00 418.05 2,450.00 369.27 2,117.79 8.571 Ellipse Separation Pass- MPJ-24-MPJ-24-MPJ-24 12,000.00 1,063.28 12,000.00 571.01 11,975.00 2.160 Clearance Factor Pass- MPJ-24-MPJ-24L1-MPJ-24L1 2,300.00 413.86 2,300.00 378.37 1,978.85 11.662 Centre Distance Pass- MPJ-24-MPJ-24L1-MPJ-24L1 2,425.00 416,85 2,425.00 376.07 2,095.12 10.222 Ellipse Separation Pass- MPJ-24-MPJ-24L1-MPJ-24L1 7,550.00 923.50 7,550.00 660.22 7,189.28 3.508 Clearance Factor Pass- MPJ-24-MPJ-24L1-MPJ-24L1 2,300.00 413.86 2,300.00 372,59 1,978.85 10.030 Centre Distance Pass- MPJ-24-MPJ-24L1-MPJ-24L1 2,450.00 418.05 2,450.00 369.38 2,117.79 8.589 Ellipse Separation Pass- MPJ-24-MPJ-24L1-MPJ-24L1 7,525.00 920.16 7,525.00 604.62 7,162.82 2.916 Clearance Factor Pass- MPJ-24-MPJ-24L1 PB1-MPJ-24L1PB1 2,300.00 413.86 2,300.00 372.47 1,978.85 9.999 Centre Distance Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1PB1 2,450.00 418.05 2,450.00 369.24 2,117.79 8.566 Ellipse Separation Pass- MPJ-24-MPJ-24L1 PB1-MPJ-24L1 PB1 7,525.00 920.16 7,525.00 604.24 7,162.82 2.913 Clearance Factor Pass- MPJ-24-MPJ-24L1P81-MPJ-24L1P81 2,300.00 413.86 2,300.00 378.25 1,978.85 11.622 Centre Distance Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1P81 2,425.00 416.85 2,425.00 375,94 2,095.12 10.190 Ellipse Separation Pass- MPJ-24-MPJ-24L1PB1-MPJ-24L1PB1 7,550.00 923.50 7,550.00 659.86 7,189.28 3.503 Clearance Factor Pass- MPJ-24-MPJ24L1PB2-MPJ24L1PB2 2,300.00 413.86 2,300.00 378,27 1,978.85 11.628 Centre Distance Pass- 19 August,2015- 19:45 Page 7 of 12 COMPASS • i Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range: 0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1567.01 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on aration Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPJ-24-MPJ24L1PB2-MPJ24L1PB2 2425.00 416.85 2,425.00 375.96 2,095.12 10.196 Ellipse Separation Pass- MPJ-24-MPJ24L1PB2-MPJ24L1PB2 7,550.00 923.50 7,550.00 660.12 7,189.28 3.506 Clearance Factor Pass- MPJ-24-MPJ-24L1 PB2-MPJ-24L1PB2 2,300.00 413.86 2,300.00 372.49 1,978.85 10.004 Centre Distance Pass- MPJ-24-MPJ-24L1 PB2-MPJ-24L1PB2 2,450.00 418.05 2,450.00 369.27 2,117.79 8.571 Ellipse Separation Pass- MPJ-24-MPJ-24L1 PB2-MPJ-24L1 PB2 7,525.00 920.16 7,525.00 604.51 7,162.82 2.915 Clearance Factor Pass- MPJ-24-Plan:MPJ-24A-MPJ-24A WP2 2,300.00 413.86 2,300.00 372.20 1,978.85 9.935 Centre Distance Pass- MPJ-24-Plan:MPJ-24A-MPJ-24A WP2 2,450.00 418.05 2,450.00 368.91 2,117.79 8.508 Ellipse Separation Pass- MPJ-24-Plan:MPJ-24A-MPJ-24A WP2 13,701.08 968.00 13,701.08 520.14 12648.96 2.161 Clearance Factor Pass- MPJ-26-MPJ-26-MPJ-26 wp08 290.53 155.85 290.53 153.89 293.23 79.358 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 wp08 325.00 155.93 325.00 153.82 326.56 73.884 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 wp08 7,400.00 469.78 7,400.00 320.52 8,643.62 3.147 Clearance Factor Pass- MPJ-26-MPJ-26-MPJ-26 wp08 290.53 155.85 290.53 153.89 293.23 79.358 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 wp08 325.00 155.93 325.00 153.85 326.56 74.817 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 wp08 7,400.00 469.78 7,400.00 320.93 8,643.62 3.156 Clearance Factor Pass- MPJ-26-MPJ-26-MPJ-26 242.22 154.54 242.22 152.13 244.92 64.172 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 300.00 154.70 300.00 151.92 301.55 55.721 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 7,450.00 478.40 7,450.00 246.38 8,760.00 2.062 Clearance Factor Pass- MPJ-26-MPJ-26-MPJ-26 242.22 154.54 242.22 152.89 244.92 93.773 Centre Distance Pass- MPJ-26-MPJ-26-MPJ-26 300.00 154.70 300.00 152.70 301.55 77.327 Ellipse Separation Pass- MPJ-26-MPJ-26-MPJ-26 7,475.00 479.56 7,475.00 331.87 8,760.00 3.247 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 242.22 154.54 242.22 152.13 244.92 64.172 Centre Distance Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 300.00 154.70 300.00 151.92 301.55 55.721 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 7,450.00 642.91 7,450.00 454.55 8,653.75 3.413 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 242.22 154.54 24222 152.89 244.92 93.773 Centre Distance Pass- MPJ-26-MPJ-26L1-MPJ-26L1 300.00 154.70 300.00 152.70 301.55 77.327 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 7,500.00 665.56 7,500.00 544.60 8,670.00 5.502 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 242.22 154.54 242.22 152.89 244.92 93.773 Centre Distance Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 300.00 154.70 300.00 152.70 301.55 77.327 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 wp06 7,500.00 648.59 7,500.00 525.69 8,653.75 5.277 Clearance Factor Pass- MPJ-26-MPJ-26L1-MPJ-26L1 242.22 154.54 242.22 152,13 244.92 64.172 Centre Distance Pass- 19 August,2015-19:45 Page 8 of 12 COMPASS • 0 Hilcorp Energy Company HALLI B U RTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range: 0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1567.01 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 (waft) (usft) (usft) (usft) net MPJ-26-MPJ-26L1-MPJ-26L1 300.00 154.70 300.00 151.92 301.55 55.721 Ellipse Separation Pass- MPJ-26-MPJ-26L1-MPJ-26L1 7,475.00 662.48 7,475.00 476.13 8,670.00 3.555 Clearance Factor Pass- MPJ-26-MPJ-26L2-MPJ-26L2 242.22 154.54 242.22 152.13 244.92 64.172 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 300.00 154.70 300.00 151.92 301.55 55.721 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-26L2 7,400.00 626.87 7,400.00 437.12 8,535.00 3.304 Clearance Factor Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 242.22 154.54 242.22 152.13 244.92 64.172 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 300.00 154.70 300.00 151.92 301.55 55.721 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 7,425.00 599.90 7,425.00 400.45 8,661.80 3.008 Clearance Factor Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 242.22 154.54 242.22 152.89 244.92 93.773 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 300.00 154.70 300.00 152.70 301.55 77.327 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-26L2 wp05 7,450.00 601.86 7,450.00 472.85 8,661.80 4.665 Clearance Factor Pass- MPJ-26-MPJ-26L2-MPJ-26L2 242.22 154.54 242.22 152.89 244.92 93.773 Centre Distance Pass- MPJ-26-MPJ-26L2-MPJ-26L2 300.00 154.70 300.00 152.70 301.55 77.327 Ellipse Separation Pass- MPJ-26-MPJ-26L2-MPJ-26L2 7,425.00 628.28 7,425.00 505.78 8,535.00 5.129 Clearance Factor Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 242.22 154.54 242.22 152.13 244.92 64.172 Centre Distance Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 300.00 154.70 300.00 151.92 301.55 55.721 Ellipse Separation Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 7,125.00 978.24 7,125.00 714.06 8,074.00 3.703 Clearance Factor Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 242.22 154.54 242.22 152.78 244.92 88.198 Centre Distance Pass- MPJ-26-MPJ-26PB1-MPJ-26PB1 300.00 154.70 300.00 152.60 301.55 73.500 Ellipse Separation Pass- MPJ-26-MPJ-26PB1-MPJ-26P81 7,150.00 980.53 7,150.00 814.04 8,074.00 5.889 Clearance Factor Pass- MPJ-26-MPJ-26PB2-MPJ-26P62 242.22 154.54 242.22 152.13 244.92 64.172 Centre Distance Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 300.00 154.70 300.00 151.92 301.55 55.721 Ellipse Separation Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 7,375.00 621.58 7,375.00 364.96 8,562.00 2.422 Clearance Factor Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 242.22 154.54 24222 152.78 244.92 88.198 Centre Distance Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 300.00 154.70 300.00 152.60 301.55 73.500 Ellipse Separation Pass- MPJ-26-MPJ-26PB2-MPJ-26PB2 7,375.00 621,58 7,375.00 459.41 8,562.00 3.833 Clearance Factor Pass- Plan MPJ-Cipher-Plan MPJ-Cipher-MPJ-Cipher wall 2,017.93 200.17 2,017.93 175.50 1,865.60 8.114 Centre Distance Pass- Plan MPJ-Cipher-Plan MPJ-Cipher-MPJ-Cipher wp0 2,050.00 200.46 2,050.00 174.92 1,895.29 7.848 Ellipse Separation Pass- Plan MPJ-Cipher-Plan MPJ-Cipher-MPJ-Cipher wp0 2,200.00 211.15 2,200.00 182.12 2,033.02 7.273 Clearance Factor Pass- Plan MPJ-Jax-Plan MPJ-Jax-MPJ-Jax wp01 =MMI ME= - _ IIPA- 19 August,2015-19:45 Pegs 9 of 12 COMPASS • . Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt J Pad-Plan:MPJ-27-MPJ-27-MPJ-27 WP3 Scan Range: 0.00 to 13,701.08 usft.Measured Depth. Scan Radius is 1,567.01 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 Plan MPJ-lax-Plan MPJ-Jax-MPJ-Jax wp01 - kg: ON 111111111111 MOM IMIIIIIIIffilikii Plan MPJ-Kali-Plan MPJ-Kali-MPJ-Kali wp01 1,621.53 265.25 1,621.53 250.04 1,483.06 17.439 Centre Distance Pass- Plan MPJ-Kali-Plan MPJ-Kali-MPJ-Kali wp01 1,750.00 266.63 1,750.00 248.75 1,600.00 14.910 Ellipse Separation Pass- Plan MPJ-Kali-Plan MPJ-Kali-MPJ-Kali wp01 7,250.00 1,562.90 7,250.00 1,371.95 6,936.74 8.185 Clearance Factor Pass- Plan MPJ-Persphone-Plan MPJ-Persphone-MPJ-Pe 1,100.53 209.60 1,100.53 201.57 1,065.70 26.086 Ellipse Separation Pass- Plan MPJ-Persphone-Plan MPJ-Persphone-MPJ-Pe 1250.00 223.86 1,250.00 214.37 1,190.33 23.584 Clearance Factor Pass- Plan MPJ-Switch-Plan MPJ-Switch-MPJ-Switch wp0 2001.87 66.36 2,001.87 47.27 1,863.05 3.476 Centre Distance Pass- Plan MPJ-Switch-Plan MPJ-Switch-MPJ-Switch wp0 2,050.00 68.81 2,050.00 45.79 1,906.43 2.990 Ellipse Separation Pass- Plan MPJ-Switch-Plan MPJ-Switch-MPJ-Switch wp0 2,075.00 71.99 2,075.00 47.31 1,928.95 2.917 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 31.00 7,800.00 MPJ-27 WP3 MWD+IFR2+MS+sag 7,800.00 13,701.08 MPJ-27 WP3 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. 19 August,2015- 19:45 Page 10 of 12 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to MPJ-27 Pre @ 66.00usft(NORDIC 3). Northing and Easting are relative to Plan:MPJ-27. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:0.40". • /II'.FZ4,MVJ-L4L I,MN.F24L1 Vit Ladder Plot APJ-24,MPJ-24L1PB1,MPJ-24L1PB1 V1 APJ-24,MPJ-24L1 PB2,MPJ-24L1 PB2 V4 _ - APJ-24,Plan:MPJ-24A,MPJ-24A WP2 V0 to //SII II�� II b 4. �i:i'r� ry, 4+� -f APJ-26,MPJ-26,MPJ-26 V5 n • u ...SLI $ AP,1-26,MPJ-26,MPJ-26wpO8V30 'pp ii �3 � i/Pt`I I A`rz,* � r' '''''I'''''' Eis•/�! �� r� I,ll i I �� --s- Ap,}26,MPJ-26L1,MPJ-26L1 V3 ('I �1 1>7i rl f' P y I $ AP126,MPL26L1,MP126L1 ap06V21 II P ) Io r r ••! �f r,".:4 y .4.to -�- iFJ-26,MPJ-26L2,MPJ-26L2 V4 ,a- 1i piti ate d`f ,, •y". I e,.. '- � 1 $ ARJ-26,MP.L26L2,MP.L26L2v<p05V17 O f ,Nr , r/ 1).e4 p � a 4,r �ill ...LC $ ARF26,MPJ-26PB1 MPJ-26PB1 V3 .,- ', l''!! r / f+ t ' j .. 1 4t,�- -'_ $ APJ-26,MPJ-26PB2,MPJ-26PB2V2 N tilt q '`AAArrfJ<, f t (I `I ' �; APJ-01,MPJ-01,MPJ-01 V3 i41 * /il? _.,i� I �,:•��'"�� •IS $ APJ-01,MPJ-01A,MPJ-01AV2 .p;6., -Ir4 41,.,// _ _$ APJ-01,MPJ-01ALI,MPJ-01AL1 V6 N tit �y -I IA. I` , \ 1�r IY ( $ APJ-01,MPJ-01AL1,Plan#5 V1 C a $ APJ-03 MPJ-03,MPJ-03 V1 U 450 l` a "� r I4b••' ',4i/j0";:, i ' S, P,., It.`•, ! -I- APJ-04, -04.MPJ-04V1 O �r.,y j f/• 'rLSI, H 1, 'y �, `a,` r $ APJ-05,MPJ-05,MP,!-05V1 1.. fIr p. I ; 't. 1:1 ,1, , $i APJ-06,MP.L06,MRL06V1 � ..: L____ ____L_ f_-_ _ AP,!-07,MPJ-07,MPJ-07 V1 0) .. U �� ` $ AP.1-08,MP,LOB,MP,!-08 V1 I �..i :f. ,,� 5+ $ APJ-08A,MPJ08A,MP 108A V7 r APJ-09,MPJ-09,MPJ-09V1 0 2500 5000 7500 10000 12500 APJ-09,MPJ-09A,MPJ-09A V2 Measured Depth(2500 usft/in) 3- APJ-10,MPJ-10,MPJ-10 V1 mac- APJ-12,MPJ-12,MPJ-12 V1 19 August,2015-19:45 Page 11 of 12 COMPASS 111 III Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan: MPJ-27-MPJ-27 WP3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor -- -- = MPJ-24,MPJ-24L1,MPJ-24L1 V8 ' \ ii - t,'NI,„. ,.illi/ III - MPJ -24L1PB1 V1 10.00 �l� �� au MPJ -24L1PB2V4 _ rt • MPJ-24,PIan:MPJ-24A,MPJ-24AWP2V0 IIII�II1 '' AllShIWIRON.F.11%.SZI:I�II� �� ' __._. �I MPJ-26.MP.126.MPJ-26V58.75— -- t Ilrt+.,�"�lay'�__ ,�,II� �.._-.— ]" --- -_._ MPJ-26,MPJ-26,MPJ-26wp08V30 _ i t IGt�� '�� E 1I 4,1/11 A II MPJ-26,MPJ-26L1,MPJ-26L1 V3 . c i i ` 1 1111�\\\ ■, r 1 = MPJ-26,MPJ-26L1,MPJ-26L1wp06V21 7.50I' _ it 1 � „� ';`4),,,.‘',11, Ir ,v;..1, � MPJ-26,MPJ-26L2,MPJ-26L2 V4 „I. �� arlifiwir_ I ;�. 11� /� u = MPJ-26,MPJ-26L2,MPJ-26L2wp05V17 II 4,i UI �r(,` 1\vV 11iIIi6.25-- ;( 1' I I �� 1�, \\\',111 f r' 1 = MPJ-26, -26PB1,MPJ-26PB1V3 �I, '•] �� - MPJ-26,MPJ•26PB2,MPJ-26PB2 V2 5 - I S!1 1!w 1 \,, XI' MPJ-01,MPJ-01,MPJ-01 V3 LI! r 1' 1 c 5.00— II,, { w '*\'''' ✓I �� ; = MPJ-01,MPJ-01A,MPJ-01A V2 o _ p� r ,,•i\ A .1 • ( ' e i4 MPJ-01,MPJ-01ALI,MPJ-01AL1V6 i _ iil I h„ .�T' 0,. ,,* D N �� .,. iii - '� �i�.4 �i "" �� ( ��'-'� MPJ-01,MPJ-01AL1,PIan#5V1 Cl) 3.75---- 1 I,'I!�!�- �� '�� ■ r� .: � �i� - MPJ03,MPJ03,MPJ-03V1 i/ 1 ,,i I\ • 74....,1..k ...'�1 �,�✓A MPJ-04,MPJ-04,MPJ-04V1 _ 1i .i' `P . .,(. r = MPJ-0S,MPJ-0S,MPJ-05V1 2.50------...._._._. \ �. li ,.a ��E` "� .... . .� ___ _ � '� _ MPJ-06,MPJ-06,MRL06 V1 ---- ----0-Zone Avoidance Req ;-"' ,�` MPJ-07,MPJ-07,MPJ07 V1 Zone-Stop Drilling .4:-.1:;" i, MPJ08,MPJ-08,MPJ-08V1 1.25 /� -- (j r: • MPJ-O8A,MPJ-08A,MPJ-08AV7 1 : MPJ09,MPJ-09,MR109V1 , ' 0.00 - MPJ-09,MPJ-09A,MPJ-09A V2 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 150000- MPJ-10,MPJ-10,MPJ-10 V1 Msesuud (2500 in) -IS- MPJ-12,MPJ-12,MPJ-12V1 19 August,2015-19:45 Page 12 of 12 COMPASS • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, September 01,2015 11:22 AM To: 'Luke Keller' Subject: RE:J-27 MPU ( PTD 215-153) Luke, Thanks for the response. J-20A doesn't appear to be a drilling issue as long as you are targeting the NB. Guy Schwartz Senior 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: Luke Keller [mailto:IkellerOhilcorp.com] Sent:Tuesday, September 01, 2015 10:45 AM To: Schwartz, Guy L(DOA) Subject RE: 3-27 MPU ( PTD 215-153) Guy, Thanks for catching those mistakes. I've fixed them in my drilling program. Regarding J-20A, it is a vertical/deviated shut in Schrader injector. It has a severe MBE in the OA with J-23 to the south. We are evaluating it for a workover to recomplete up shallow as a source of clean injection water for these J-Pad lateral wells. It has been shut in since 2008. Although the ellipses have a close approach,we will be drilling the J-27 lateral in the NB sand which is structurally higher than the OA sand where J-23A is located. Make sense? Luke From: Schwartz, Guy L(DOA) [mailto:guv.schwartz(aalaska.gov] Sent: Monday, August 31, 2015 4:30 PM To: Luke Keller Subject: 3-27 MPU ( PTD 215-153) Luke, A couple of quick questions: 1. Close crossing with J-20A at about 10300ft. Assume this well J-20A is completed in the OA sand so you will be geo steering right by it(just above) . Please comment on any avoidance issues . 1 2. On the casing design page 5•e 4.5"screen liner has length of 10048' ..should be 5600 ft. Makes the Tension safety factor better. 3. Page 16 has a typo..should be"TD hole section in NB" not OA. Regards, Guy Schwartz Senior 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). 2 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: ()` PTD: a�Sr �S Development _Service Exploratory Stratigraphic Test Non-Conventional FIELD: / ' !�//j(�6_ nJ POOL: siin t��N— Sch eks NtAW Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements 1 Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 0 ❑❑ -0 m O w Iii 3 Q 0) L L o,la ' o : : O j, a • Z' o ' = ' o Fo O I 2E- 0' O' O' 0Cl. ' o' p' ,n' E ; C: : s v : o. O. 0 u. 3' o : a c CC NI: , 47, C, 0, lig. ' = O .- CO ? y 0 , , a w 3 N, : v`; z a o, , , , . c , v;; o -, o, ,,, , a ax a) r o, 2, o, Q, -a, co. 2 , C. m a0' , v., t, c, , C, . 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