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217-174
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J O a d A I Co) a o o a a m - E .a • m D D o m o ° a°) 0 o aoi d E I o a 2 w 3 i 0 a 0 0 0 0 0 i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,February 05,2018 TO: Jim Regg tef P.I.Supervisor O 15 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC L-52 FROM: Adam Earl MILNE PT UNIT L-52 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT L-52 API Well Number 50-029-23590-00-00 Inspector Name: Adam Earl Permit Number: 217-174-0 Inspection Date: 2/1/2018 Insp Num: mitAGE180201150629 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-52 Type Inj W TVD 3925 - Tubing 405 405 - 405 405 - PTD 2171740 Type Test SPT Test psi 1500 - IA 122 1704 1639 - 1623 - BBL Pumped: . 2.5 - BBL Returned: 2.5 OA Interval INITAL / P/F P Notes: MIT-IA Mono-bore,no 0/A ./ Monday,February 05,2018 Page 1 of 1 • I, E.. `: STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 120''3 1a.Well StatuWEL❑L Oil COMGas❑PLETSPLUGO ❑ON OROther R❑ECOMPLE❑TION Abandoned nded RE❑PORT1b.Well cANQ� � Ci� 20AAC 25.105 20AAC 25.110 Development [ Exploratory ❑ GINJ ❑ WINJ Q WAGE] WDSPL❑ No.of Completions: _1 Service Q Stratigraphic Test ❑ 2.Operator Name: 6. Date Com.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC Aband.: 1/18/2018 217-174 * 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 December 25,2017 50-029-23590-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 3732'FSL,5227'FEL,Sec 8,T13N, R10E, UM,AK January 8,2018 MPU L-52 •• Top of Productive Interval: 9. Ref Elevations: KB: 42.2' 17. Field/Pool(s):Milne Point Field 488'FSL,2072'FWL,Sec 7,T13N, R10E, UM,AK GL:15.7' BF: 15.7' Schrader Bluff Oil Pool s. Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1374'FNL,438'FWL,Sec 19,T13N, R10E, UM,AK 13,920'MD/3,696'TVD . ADL 022509/ADL 025515. 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 544648 y- 6031919 Zone- 4 14,000'MD/3,697'TVD - LONS 88-002 TPI: x- 541511 y- 6028658 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 539916 y- 6021507 Zone- 4 N/A 2,320'MD/1,918'TVD 5. Directional or Inclination Survey: Yes [J (attached) No ❑ 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary ROP DGR ABG EWR ADR Horizontal Presentation MD DGR EWR ADR Invert Section TVD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 164# A-53 Surface 107' Surface 107' 36" 270 ft3 Stg 1 L-458 sx/T-397 sx 9-5/8" 40# L-80 Surface 6,280' Surface 3,950' 12-1/4" 233 bbls Stg 2 L-475 sx/T-270 sx 4-1/2" 13.5# L-80 6,030' 13,925' 3,925' 3,697' 8-1/2" Injection Liner w/Swell Pkrs 4-1/2" 12.6# L-80 Surface 6,036' Surface 3,926' Tieback Tieback 24.Open to production or injection? Yes Q No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 4-1/2" 6,036' 6,030'MD/3,697'TVD ""Please see schematic for Slotted(Injection)Liner Detail**" 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information 111511E, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1,� 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Injection began 1/29/2018 Injection Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period .♦ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 1511 0 24-Hour Rate .� Form 1Q-407 Revispd 2017,,..yy a-/L•"Z " iy Of1TIN E ON PAGE 2 Submit ORIGINIAL on6 eK) 0414,11V ...:4 ,/1-(/,' Fn-.!':‘r,'“, 1,(- Fr 9. - 7 �=;,8 • • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑r Sidewall Cores: Yes ❑ 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 TVD Well tested? Yes ❑ No ❑Q Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 2,320' 1,918' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 6,671'(Schrader Bluff) 3,941' information, including reports,per 20 AAC 25.071. SV5 1,524' 1,429' SV1 2,679' 2,129' Ugnu LA3 4,934' 3,444' Schrader NA 6,014' 3,922' Schrader NB 6,242' 3,949' Formation at total depth: Schrader Bluff • 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys,Csg and Cmt Report. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name:Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdingerCa�hilcorp.com Authorized [� Contact Phone: 777-8389 Signature: �� Date: .Z - ( • 2) INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • Milne Point Unit Well: MPU L-52 SCHEMATIC PTD: 217-174 Hilcerp Alaska,LLC API: 50-029-23590-00-00 KB Elev above MSL:42.2' TREE&WELLHEAD Tree Cameron 4 1/16" 5M w/4-1/16"5M Cameron Wing y € V Wellhead Cameron MBS 11"5K 16" S x OPEN HOLE/CEMENT DETAIL {' t 16" -270 ft3 12-1/4" Stg 1-458 sx Lead/397 sx Tail it Stg 2-475 sx Lead/270 sx Tail(233 bbl surface returns) 8-1/2" Cementless Injection Liner in 8-1/2"hole .. CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF t ) i 16" Conductor 164/A-53/Weld N/A Surface 106.5' N/A 9-5/8-ES M 9-5/8" Surface 40/L-80/DWC/C 8.75" Surface 6,280' 0.0758 Cementer@ • 4-1/2" Liner 13.5/L-80/Hyd 625 3.85" 6,030' 13,925' 0.0149 2,503' 4 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TXP-SR 3.833" Surf 6,036' 0.0152 I :# WELL INCLINATION DETAIL ti t ti KOP @ 75' M Max Hole Angle=95.8°@ 7,400'MD JEWELRY DETAIL No Top MD Item ID 1 Upper Completion 1 5,731' XN Nipple profile:3.725"No Go/3.813 Packing Bore e 2 6,026' No-Go Locater on Tieback Assy([4]-1"Ported Seal Stem) 3.960 • t 3 6,036' Tieback Shoe 5.180 4-1/2" Lower Completion )tt • 4 6,030' Liner Top Packer ii 6 4 5 13,920' WIV(Ball on Seat/Closed)PBTD 3 1 1 I Depth Depth MD ND : 2/3 Screen Detail _ { 6,671' 3,941' 4-F,"13.5#/Ft Hydril 625 Mesh Screen 250 Micron l''®I® i ®a®j 7,468' 3,925' 4-1/4"13.5#/Ft Hydril 625 Mesh Screen 250 Micron 15/8" 4 1' 8,357' 3,885' 4-/"13.5#/Ft Hydril 625 Mesh Screen 250 Micron 9,376' 3,853' 4-'/"13.5#/Ft Hydril 625 Mesh Screen 250 Micron 10,188' 3,826' 4-'/,"13.5#/Ft Hydril 625 Mesh Screen 250 Micron 11,083' 3,794' 4-1/2"13.5#/Ft Hydril 625 Mesh Screen 250 Micron 11,977' 3,761' 4-1/4"13.54/Ft Hydril 625 Mesh Screen 250 Micron 12,910' 3,727' 4-F"13.54/Ft Hydril 625 Mesh Screen 250 Micron 13,802' 3,699' 4-1/4"13.5#/Ft Hydril 625 Mesh Screen 250 Micron See ICD , &Swell MD TVD Swell Packer Detail Packer : 1 Detail 6,319' 3,952' 5-1/4"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 6,761' 3,939' 5-'/,"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 7,324' 3,988' 5-/"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 7,845' 3,908' 5-/"17#/ft L-80 DWC/C Tendeka Water Swell Pkr . 9,106' 3,868' 5-'/"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 41/2" 9,466' 3,848' 5-F,"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 10,979' 3,796' 5-1/4"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 11,503' 3,779' 5-F,"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 12,190' 3,761' 5-1/4"17#/ft L-80 DWC/C Tendeka Water Swell Pkr 5 13,367' 3,716' 5-'/"17#/ft L-80 DWC/C Tendeka Water Swell Pkr TD=14,000'(MD)/TD=3,69Y(TVD) GENERAL WELL INFO PBTD=13,920'(MD)/PBTD=3,696'(TVD) API#:50-029-23590-00-00 Completed by Innovation C.ID 1/29/2018', • . Hilcorp Energy Company Composite Report .11 Well Name: MP L-52 Field: Milne Point County/State: ,Alaska i(LAT/LONG): evation(RKB): 26.5 API#: Spud Date: 12/26/2017 Job Name: 1713437D MPL-52 Drilling Contractor Innovation AFE#: AFE$: 12/24/2017 Cont to walk sub ovewr L-52.Spot/level/shim same.Set out riggers.Stage Diverter TEE in cellar.Spot remaining Modules.R/D Jeep,Release Peak.Install handrails ect.;Lower Mod landings/stairways.R/U Interconnect utility hoses.Bring on steam.Set/Contain Cutting Box.Spot Enviro vac,Break shack and power up same.;Shovel out and clean out cellar for Starter head install.RU Mud/choke/flow lines @ pit interconnect.Start dress MP's.Install outer diverter line.;Welder and Well head Rep Install and tack weld Starter head.(Cut 14"off conductor.Intal)4"outlets.Plug in and Power up rig on High Line @ 17:00 hrs.;Welder finish welding starter head onto conductor as per WH rep.Spot cuttings box,get water circulating throughout rig. Work on rig acceptance checklist.;PJSM,scope up and pin derrick,bridal down.R/U tongs on rig floor.Perform derrick inspection.Service top drive,blocks, drawworks and crown sheaves.Reassemble MP fluid ends.;Circulate hot water thru all pit lines.Test PVT system,operate flow line paddle.Inspect drwks Crakes, check brake tolerance.Install BOP work platform.Load shed with 5"DS50 DP.;Accept rig @ 00:30.;Install diverter adaptor,test seals as per well head rep to 2000 psi.N/U diverter system,Set diverter Tee,install knife valve,install diverter line,set BOP stack.;R/U accumulator lines to annular and knife valve,install flow box riser. 12/25/2017 Finish Tq up Stack flanges.R/U Bag/Knife Valve hoses.Prep Drip Pan.;Trouble shoot elevator psi switch Issues.Replaced TD frame sensor batteries. SINIOPS: Process HWDP.Stage BHA in pipe shed.R/U Hawk Jaw.Modify Pump Rod Clamps and install same.;Cama-long Stack over to center up under table due to un plumb Conductor.;Secure Stack.Set Bell Nipple.Install drip pan.House keep cellar.Grab Joint for Diverter Test.;Test Diverter System on 5"DP Start:3000 After close 2000 psi,200 psi build 14 sec,Full Recovery 42 sec.Ann.Close time 6 sec,Knife Valve Open.6 sec.;Test Gas alarms and PVT System. Had FP on Methane.Had FP on LEL Audible in pits/Pump Room.Received a Variance per Jeff Jones on 16"Vent line facing the F-Pad access Road.;Set Mouse hole in Rotary table. Drift and PU 5"DS-50 DP racking 129 stds in derrick.Drift and P/U 17 jts 5"HWDP and jars and rack in derrick.;R/D Hawk jaw and remove from rig floor.Clear rig floor,R/U Rig tongs.Load BHA short tools to rig floor.UD mouse hole from rotary table.;Conduct pre Spud meeting with all parties involved.;M/U 12 1/4"PDC bit,1.5 deg mud motor,XO and 1 std of HWDP,Flood lines and fill stack with water,verify no leaks on stack and diverter line.Test Mud lines to 2500 psi,good.Tag @ 104'.;SPUD WELL:C/O conductor to 106',Drill 12 1/4"Hole to 218'.400 gpm/480 psi,40 rpm,1.4k tq,Up/Dn Rot 45K. Circulate Clean.;Set Back weight pipe,pull bit to surface,balled up with clay,clean bit.MU remaining BHA as per sperry,offset @ 48.39 deg.M/U UBHO, upload MWD,RU Gyro;Daily losses to formation 0 bbls for total=0 bbls Hauled 57 bbls fluid to G&I for total=57 bbls Hauled 780 bbls H2O from 6 mile lake for total=780 bbls 12/26/2017 Finish Upload MWD.RIH to 207'.Shallow test tools w/400 gpm/610 psi. Note:Lost MP 1#Lube Oil Pump.Continue with MP#2.;Drill 12 1/4"Hole F/219'to 824'w/400 gpm/615 psi,450 gpm/920 psi.40 rpm/2K Tq,2-6 WOB.Start Gyro @ 453'bit depth,352'UBHO depth.Up/Dn/Rot 74/72/73. Note:Replace MP 1 lube pump.;KOP @ 453'MD.;Drill 12 1/4"Hole F/824'-T/1328'MD. 504'total(84'AROP)450 gpm/1330 psi.40 rpm/3.2K Tq,4-6 WOB. Up/Dn/Rot 74/72/73. Gyro on standby @ 717'MD. Release @ 1014',R/D same(21:45 hrs).;Drill 12 1/4"Hole F/1328'-T/1780'.452'total(76'AROP)500 gpm /1350 psi.60 rpm/3k tq,5k wob 86k up,78k dn,82k rot.;Last svy @ 1728'MD=5.2'low,1.4'right of directional plan 13.;Hauled 807 bbls cuttings to G&I for total=864 bbls Hauled 520 bbls H2O from 6 mile laky,for total=1300 bbls 12/27/2017 Drill 12 1/4"Hole F/1780'-T/2522'.742'total(106'AROP)550 gpm/1475 psi.60 rpm/5k tq,6-10k wob 101k up,77k dn,83k rot.ECD 9.9,MW 9.3+,Vi'c 210.;Logged base of permafrost @ 2320'MD,1918 ND.No notable gas seen drilling through base permafrost.Drilled to EOB @ 1850',drilling tangent w h 30' corrective slides every other stand.;Service Rig.;Open up TD and inspect for leaks.Tighten hose fittings on Arctic Package.Circulate @ 3 bpm/250 psi whi e making repairs.;Drill 12 1/4"Hole F/2522'-T/2838'.316'total(126.4'AROP)550 gpm/1570 psi.70 rpm/6-7k tq,2-8k wob 108k up,79k dn,90k rot.EC 9.9, MW 9.3+,Visc 150.;Drilled 200'below permafrost lowering visc to 130-150 range.Screen up to 120's on both shakers.;Having to fight shaker after screeni g up. Mud Check showed sand content @ 2.25%and Mud Wt @ 9.3+.Pump clean up cycle,stage pumps f/380 to 600 gpm.Sand content down to 1%,MW do n to 9.2 ppg.;Drill 12 1/4"Hole F/2838'-T/3342'.504'total(92'AROP)550 gpm/1710 psi.70 rpm/7k tq,5-8k wob.;Drill 12 1/4"Hole F/3342'-T/3903'MD. 61' total(94'AROP)550 gpm/1630 psi,60%flow.70 rpm/8.5k tq,5-8k wob,9.7 ECD's,8 BGG.;Continually showed improving mud properties throughout th evening with 120 screens on both shakers. Dropped sand content from 1%to.5%and MW from 9.2 to 9.1 ppg.Negligible gas.;35 bbl hi vis nut plug swe p @ 3529'MD,100%inc and 600 stks early.Last svy @ 3805'MD=2'low,1.5'right of directional plan 13.;Hauled 1154 bbls cuttings to G&I for total=2018 b Is Hauled 1230 bbls H2O from 6 mile lake for total=2530 bbls 12/28/2017 Drill 12 1/4"Hole F/3903'-T/4530'MD.627'total(104'AROP)550 gpm/1875 psi,60%flow.70 rpm/8-10k tq,6-12k wob,9.8 ECD's,10 BGG.;Pump Hi Vis Sweep @ 4100'w/300%increase in cuttings back.;Drill 12 1/4"Hole F/4530'-T/4788'MD.258'total(103'AROP)600 gpm/2180 psi,60%flow.70 rpm/11- 12k tq,6-12k wob,9.9 ECD's,8 BGG. Send Sweep @ 4730'.;Continue to Circulate Sweep out of hole @ 600 gom/2055 psi,70 rpm/10-12 Tq.Brought back 100%increase of mostly fines blinding off shakers.;Drill 12 1/4"Hole F/4788'-T/5164'MD.376'total(107'AROP)600 gpm/2150 psi,60%flow.70 rpm/11- 13k tq,6-25k wob,10 ECD's.;Circulate and condition mud @ 5164'MD. 600 gpm,2015 psi,62%flow,70 rpm,12.2k tq Tandem hi/vis nut plug sweep w/100% inc/700 stks early.;Start build and turn F/5164'-T/5544'MD.380'total(95'AROP)600 gpm/2115 psi,60%flow.70 rpm/11-13k tq,6-25k wob,9.9 ECD's, 259 max gas.;Drill 12 1/4"Hole F/5544'-TI 5919'MD.375'total(69'AROP)600 gpm/2160 psi,60%flow.70 rpm/13k tq,6-25k wob,9.9 ECD's,95 bgg.;Circulate w/#2 MP while changing out swab on MP#1 (#1 cyl). 333 gpm,960 psi,30 rpm,12.1k tq.;Last svy @ 5817'MD=6.5'high,2'right,6.7'ctr to ctr of directional plan 13.;Hauled 1411 bbls cuttings to G&I for total=3430 bbls Hauled 1500 bbls H2O from 6 mile lake for total=4030 bbls • • -0)50-464-&-0 42.11 (0.% 12/29/2017 Drill 12 1/4"Hole F/5919'-Tl 6289'MD.Section TD 370'total(82'AROP)600 gpm/2250 psi,60%flow.70 rpm/14-16k tq,6-25k wob,10 ECD's,Max Gas 340.;Pull to 6105'.C/O#3 Cyl Piston.Pump 30 bbl Tandem Sweep @ 600 gpm/2005 psi,80 rpm/13K Tq.See eratic Tq swings.Adjust parameters as needed to mitigate Tq swing.;Max Gas @ 1175u.;Run back to Bottom,no fill.Monitor well,well static.BROOH f/6289'to 3781'.600 gpm/1985 psi,70 rpm/17-18 Tq. PU/SO/Rot,165/83/111K.See occasional pack off attempts through slide intervals.;See increase in cutting @ shakers.Circulate hole clean staging pump up from 400 gpm to 600 gpm,1760 psi,70 rpm,10.5k tq.;BROOH F/3781'-T/2500'MD. 600 gpm,1700 psi,70 rpm,6.5k tq,max pulling speed 40 fpm.;Circulate and condition mud prior to pulling through upper build section. Circulate @ 600 gpm,1600 psi,70 rpm,7k tq. Shakers showed mostly fine sand/silt w/traces of pea gravel.;Continue BROOH F/2500'-T/702'MD(BHA). 600 gpm,1450 psi,70 rpm to 1200'then reduced rpm's to 60 after seeing several erratic tq spikes. Tq smoothed out with lower rpms thru build section.;Max pulling speed while backreaming 40 fpm. Hole unloaded starting @ 1200'-T/700'with mostly pea gravel/ clay. Reduced pulling speed to 15 fpm and allowed hole to clean up as needed.;POOH F/702'-17 surface w/12-1/4"BHA. Pumped out from 700'to 300'. Racked back HWDP w/jars. UD NM flex DC's,Download MWD. UD remaining 8"MWD/LWD tools.;Projected to bit @ 6289'MD=3.5'high,17'right of directional plan 13.;Hauled 750 bbls cuttings to G&I for total=4180 bbls Hauled 1050 bbls H2O from 6 mile lake for total=5080 bbls 12/30/2017 Continue to UD BHA.Bit Graded:1-2-CT-T-E-1-NO-TD.Clean and clear rig floor of tools.Ready floor for Slip Cut Ops.;Slip and Cut 80'Drill line.;Service Rig. Grease Traveling/RT/Handling equipment.;R/U CRT,Power tongs,250 Ton side doors on bail extensions. Count 9-5/8"in shed(168 jts+ES cmtr). Visually inspect shoe track w/flashlight(good).;M/U 9-5/8",DWC/C,40#,L-80 shoe track to 33k tq. Bakerlok shoe track jts. Check floats(good). Circulate through shoe track on jt#5,6 BPM,25 psi.;Run 9-5/8"surface casing from surface to 2483'MD. Fill on the fly.Break Circulation back to pits every 15 jts.;Break Circulation and CBU from 2483'@ 6 bpm/90 psi,Up Wt 126K,Dn Wt 79K.;Continue run 9-5/8",40#,DWC/C,L-80 F/2483'-T/4603'MD. Fill on the fly and break circulation every 15 jts staging up to 6 bpm while washing down slow. No issues.;Cont run 9-5/8"csg Fl 4603'-T/4724'MD. Started pushing away fluid.Washed down F/ 4724'-T/5133'MD. Full returns while washing down. Install HES stg collar between#92493(6 pins).;CBU lx @ 5133'MD. Recip pipe and stage up to 6 bpm,165 psi,44%flow. Observed mostly fine sand/silt @ btms up. Full returns w/no issues. 8 units bgg.;Continue running 9-5/8"casing F/5,133'to final set depth as per tally @ 6279'MD landing out. Washed down last jt.;Hauled 814 bbls cuttings to G&I for total=4994 bbls Hauled 750 bbls H2O from 6 mile lake for total=5830 bbls 12/31/2017 Circulate and condition mud for CMT job.Lower YP to 19.Circulated STS volume.6 bpm/145 psi,Up Wt 298K,Dn Wt. Full returns while circulating.;R/D bail extensions,elevators,power tongs and clear equipment from rig floor while circ and condition mud. Blowdown cmt line back to HES trucks.;PJSM,1 stg surface cmt:Clear cmt line to cmt units. Flood lines w/5 bbls water. P/T lines 1000/4400 psi(good).60 bbls 10.5#Tuned Spacer III w/4#red dye first 10 bbls. Drop bypass plug.;Mix and pump 458 sxs(209 bbls)Extenda Cern Lead Cement at 11.7 ppg.Mix and pump 397 sxs(82 bbls)Swift CemTail Cement at 15.8 p 7g., Drop Shut off Plug.;Displace cmt w/20 bbls FW f/Cmt Unit,Rig Pump 217 bbls,9.2 ppg mud.Cmt Unit 80 bbl�s FW @ 5.5 bpm,290 ICP, 380 FCP.Rigump 150 bbls 9.2 ppg mud,6 bpm 370 ICP,FCP 750 psi @ 3 bpm.;1 st Stage Details:Total Displacement 467 bbls'CIP @ 13:40 hrs.Full Returns through out'ob, Pump Cement @ 5.5 BPM Average.;FCP 750 psi @ 3 BPM.Bump plug 500 psi over FCP to 1250 psi.Floats held.;Using rig pump,stage pressure up 2880 psi to open ES Cementer. CBU through Stage tool staging up to 5 bpm,bringing all of spacer and 11 bbls green CMT to surface.:Shut down pumping. Disconnect knife valve. Flush stack and work annular with"Black Water". Circulate"Black Water"through flow line jets and all surface Iines.;Continue to circulate through stage tool @ 4 bpm while prepping for 2nd sage Cement.;PJSM,Pump 2nd stage cmt job:Lineup to cmtrs,wet lines w/5 bbls FW. P/T lines 1000 low/5000 high(good).60 bbls 10.5#Tuned Spacer III w/4#red dye first 10 bbls,5 BPM,427 psi.; 00 bbls 10.7#lead Perm"L"cmt,4.33 yld,400 sxs,4.5 BPM,370 psi,, 56 bbls 15.8#tail Premium"G"cmt,1.16 yld,270 sxs,2.3 BPM,296 psi.Drop closing plug.;HES pump 20 bbls FW,2.5 bpm,300 psi,Turnover to rig(MP#1/ .062 pump output).Disp&bump @ 171.5 bbls/2766 stks(170.3 bbls calc)9.3#mud 6 BPM,910 psi. Slowed last 20 bbls,2 bpm,710 FCP;Bumped and psi up to 1860 psi(ES shift @ 1830 psi)Held 5 min. Bled back 1.25 bbls,flow stopped.CIP @ 00:21 hrs.;100%returns,60 bbls spacer returned to surface, bbls cmt returned to surface(1 34 bbls cmt left in hole)(11#w/11.3 PH).;R/D cmt lines and clear same. B!O and laydown CRT to cradle. R/U side door 9-5/8" elevators. Blow down TDS. UD remaining Weatherford handling equipment and release casing;N/D diverter system. Un flange 16"diverter line and remove from cellar.Disconnect koomey lines from knife valve. Flush BOP stack w/black water(function annular decrease to 500 psi)and Iines.;Remove drip pan,N/D stack and lift same. Ctr casing to set slips.;AOGCC BOP witness notification sent via email @ 02:45 hrs/1-1-2018.;Hauled 1087 bbls cuttings to G&I for total= 6081 bbls Hauled 600 bbls H2O from 6 mile lake for total=6430 bbls 0 bbls lost to formation for total=10 bbls 1/1/2018 Pull Bell Nipple Hoist stack,Reposition landing Ring.Center casing in conductor.S *Slins as per well head Rep w/140K below slips.Make Rough Cut.(28.94')(Jt 153).UD same.Set Dn&4 bolt.;Re set bell nipple, MU Flushing tool and flush stack,UD same.Blow Down TD.;R/D DSA/Diverter TEE/Starter Head&stage in cellar.Puul and UD Bell Nipple.Make final cut and Dress stub.Cut.33"Total Cut+28.94'.Welder and Wellhead Rep begin installation of Well Head.;Welding done @ 15:30 hrs.Wait for well head to cool.OFF LINE:Begin Restring New Drill Line.;PJSM,Spool out 1300'drilling line and stage on pad.Cut line from spool. String line from spool to rig. Dress and prep drilling line for cable pulling snake. Install snake per manufacture.;Sym Ops-Load pits w/300 bbls Baradril"N". Well head temp 170°@ 00:00 hrs.Mechanic C/O leaking hoses on Arctic package on top drive.;PJSM,Reset TDS.M!U TDS to DP and set slips to hang b ocks. Install safety clamp. Hang blocks. Unwrap line from deadman. Stage personnel and restring blocks and drawworks w/new drilling line.;Respool spent drill ng line on shipping drum and secure same. Sym Ops-Attempt Nitrogen test on wellhead void(fail). Leak on internal weld of head. Update AOGCC via email 2. 06:00 hrs.;Hauled 897 bbls cuttings to G&I for total=6980 bbls Hauled 900 bbls H2O from 6 mi lake for total=7330 bbls 1/2/2018 Install dead man and crown saver indicator.Prep Cellar and well head.UD hang off joint.Re install Dead line&Crown saver indicator.Assist welder with repairing failed weld on wellhead.;Finish weld&Wait on weld to cool @ 0900.;Wait on weld to cool. Trouble shoot elevator PSI switch relay issue,Modify conveyor grease points. Install new valves and seats in MP#1.;Grease traveling equipment and rig.Perform derrick inspection. Clean suction pods on both pumps.Test welds @ 350 DEG to 1650 psi @ 1500.Good.Continue to wait on welds to cool. 230 deg @ 1800.;Wait on wellhead to cool.Install new Teflon wear pads for drag chain. Housekeeping.187°@ 20:30,160°@ 22:30,140°23:00.;P/T adapter head void w/N2 to 1500 psi(good). Wellhead @ 127°F at time of final test. Dress head with seal and lightly grease same. Install 11",5M single bowl wellhead w/5M 11"x13-5/8"Spool.;RILDS on adapter.Test wellhead adapter seal T/1 k,3k,5k w/5 min hold on each(good).pU 13-5/8",5M Class IV Blow out preventers w/2-7/8 x 5-1/2"VBR's in both pipe rams.Hook up choke/kill lines. Make up koomey lines and charge system. 4 pt stack and R/U drip pan.;Hauled 0 bbls cuttings for total=6979 bbls Hauled 150 bbls H2O from 6 mi lake for total=7480 bbls • • 1 ✓ 1/3/2018 R/U testing equipment&set test plug. Energize accumulator and function test system.Good. Perform body test to 250/3000.;Test BOPE per AOGCC to 250/3000 psi.Test to on 4.5&5"Test joint. test witnessed by Matt Herrera with AOGCC. Had one FP on test#5.Cycled valves and serviced.Retested good.; a orP ed Accum 1ator drawdown Starting pressure-3000 200 PSI Increase-27 sec Full Pressure-92 sec 6 N2 Bottles@ 23psi;R/D testing equipment. Clear rig floor Prep for BHA. Set Wear bushing with 101157;Service Rig. Adjust Kelly Hose.;P/U BHA#2,8.5 Used bit,Motor with 1.22 Bend,Move jars and adjust wt pipe. RIH to 582';RIH P/U 5"DP F/582'T/ 2460'.;Attempt to psi test Kelly hose (wash pipe leaking). Shut down pump. Tighten wash pipe and grease. P/T surface equipment 200 low/3000 high(test good).;Wash down F/2460'-T/tag depth of 2512'on stage tool(7'low to tally). 400 gpm,680 psi,40 rpm,5k tq. Set dn 3k on tag. Drill ES cmtr and wash down F/2512'-T/2523'MD.;Drilled stage tool then saw intermittent tq and tags to 2523'MD. Assumed to be debris from stage tool. Trippedthrough with no pump/rot clean.;PJSM,Perform choke drill with crew. Blow down kill and choke to clear any debris from stage tool. Flood kill and choke lines. Shut in annular and psi up 200 psi.;Alternate personnel running choke.Driller bring pump up 2bpm&dn. Choke hand maintain 200 psi on casing. Review with crew post drill. B/D choke and kill lines and lineup to drill FE.;Wash down chasing debris/stringer F/2523'-T/2621'MD. 400 gpm,680 psi,40 rpm,5k tq. Cleaned up with no tq or tag issues last few feet.;Continue RIH P/U 5",S-135,19.5#DP F/2621'-T/6132'MD. Tag @ 6132'MD.;Circulate out air and condition mud. R/U test equipment. Flood lines and test 9-5 8", 40#,L-80 surface casing to 3000 psi w/30 min hold. Chart and recordsame.;Hauled 114 bbls cuttings to G&I for total=7094 bbls Hauled 150 bbls H2O from 6 mi lake for total=7630 bbls La 1/4/2018 Finish 30 min pressure test on 9 5/8 casing @ 3000 psi.Good.Bleed down&blow down testing equipment.;P/U&Rack back 5 stand of HWD7• RIH to 6 10'& le wash down©195 GPM 30 RPM, to 6132'&tag soft stringer. Bring rate to 500 GPM&drill down to 6152'.Tag hard cmt.Drill plug&Bfl @ 6155'.;Contin e to drill to shoe on depth.Drill shoe,Rat hole and 20'New formation T/6309'. Start mud swap after drilling through shoe.;Pull in to shoe&continue to 8isplac to 8.9 2q Baradril @ 9 bpm. Build slug. Monitor well atter getting good mud back.Static.;R/U Testing equipment. Perform FIT to 12 PPG @ 636 psi. Good test. P mped 1.4 bbl and bled back.5 per strap. Pressure stabilized @ 505 psi. Open up well&monitor well.Pump S"ug.;POOH F/6230'T/582'.;Set back wt pipe&J rs, L/D Excess HWDP. UD Motor&Bit. Bit Grade-1-1-WT-A-E-1-NO-BHA. Clear rig floor. Correct hole fill on the trip out.;PJSM,P/U BHA#3. P/U Geo Pilot assembly as per Sperry,8.5 Kymera KM624 bit,Stab,Geo Pilot,DM,IDS,ADR,DGR,PWD, TM, NMFS, NMFC x2, HWDP&Jars. 270' Total.;Finish download and shallow pulse test(good). Trip in hole F/270'-T/6309'MD. Break Geo-Pilot in @ 3300'MD(good). Washed down last stand.;Pattern bit,Drill 8.5"production hole F/6309'-T/6460'MD. 415 gpm,950 psi,53%flow 80 rpm,13.5k tq.15k wob.;Drill 8.5"production hole F/6 60'- T/6928'MD.490 gpm,1400 psi,60%flow 90 rpm,14.6k tq.20k wob.;Drilled out of zone F/6335'-T/6620'MD. Currently in zone dropping to get out of zone again as per plan due to AC issues with L-34.Last svy @ 6709'=12'high,23'right of WP 13;Hauled 728 bbls cuttings to G&I for total=7822 bbls Hauled 150 bbls H2O from 6 mi lake for total=7780 bbls 0 lbs metal collected for total=0 lbs 0 bbls lost to formation for total=0 bbls 1/5/2018 Drill ahead 8.5 Directional hole F/6931'T/7497'. 566'@ 94 FPH average.415 GPM,1092,90 RPM,16K TQ 10-20 WOB.MW 9.0,ECD 10.2.;Had to drill out of ZONE as per plan to go under well L-34. Built back up and got back into the NB Sand©7480'.;Drill ahead Fl 7497'T/8123'. 626'@ 104 FPH average.100 RPM, 16.5 TQ 415 GPM,1025 PSI, 2400 Max Gas units MW 9.0,10.2 ECD.Last Survey 7841'@ 7.35 High @ 8.47'Left. In zone.;Drill ahead F/8123'T/ 8362'. 239'@ 48 FPH average.90 RPM, 17 TO 450 GPM,1120 PSI, MW 9.0,10.2 ECD.Drill concretion @ 8345'MD.;ABI showed 14.35°DL @ 8345' ND. Wash and ream F/8345'-T/8362'MD to reduce DLS.90 rpm,16.2k tq,450 gpm,1120 psi,58%flow,10.1 ECD.Tandem sweep @ 8360',300 stks late w/ 200%inc.;Reduced dogleg Fl 14.35°to 12.9°ABI. (10°for recommended max on rotary steerable assembly). Drill ahead with reduced rpm until tools clew'high dogleg hole section(8346-8360').;Drill ahead F/8362'T/8944'. 582'@ 97 FPH average.70-90 RPM, 17 TQ 430 GPM,1090 PSI, MW 9.0,10.3 ECD 550 BGG.;Last svy @ 8596'MD,91.63°Inc,195.13°Az=14.8'high,8'right of WP 13.2.42%concretions encountered for lateral.;Hauled 456 bbls cuttings to G&I for total=8278 bbls Hauled 580 bbls H2O from 6 mi lake for total=8360 bbls 0 lbs metal collected for total=0 lbs n hhlc Inst to fnrmatinn few tnfal=n hhlc 1/6/2018 Drill ahead F/8944'T/9430 486'@ 81 FPH average.70-90 RPM, 17 TQ 450 GPM,1230 PSI, MW 9.0,10.3 ECD 550 BGG.;Drilled out of zone @ 9145 T/ 9255'. Target dip is 91.6 deg.;Drill ahead F/9430'T/9821' 391'65 @ FPH average 80 RPM, 17 TQ 375 GPM,990 PSI, MW 9.0,10.5 ECD 550 BGG.;Drilled on a concretion @ 9428'T/9438'.Took 3 hrs.Fighting hard right hand walk.Dropping hard when trying to build. Last sweep 300%increase.;Drill ahead Fi 9821' T/10072'MD. 251'@ 126'AROP 80 RPM, 18.4 TQ 375 GPM,990 PSI, MW 9.0,10.6 ECD.;Drilled @ lower parameters to obtain desired Az and Inc for directional WP13 while setting max 350 ROP.;Circulate out tandem sweep while rot/recip pipe @ 10072'MD. Inc flow to 500 gpm,1600 psi,120 rpm. Sweep back 12.5 bbls late w/300%inc in cuttins. ECD's stayed @ 10.6.;Resume normal drilling parameter and headed back to plan Drill ahead F/10072'T/10509'MD. 437'@ 125'AROP 80 RPM, 19 TQ 450 GPM,1350 PSI, MW 9.0,10.6 ECD 400 bgg.;Lost dn wt©10,300 MD.;Circulate out tandem sweep to help reduce ECD's. Sweep came back 31 bbls late w/200%inc. ECD's dropped F/10.7 to 10.5. 500 gpm,1440 psi,80-100 rpm.;Drill ahead F/10509'T/10827'MD. 318' @ 159'AROP 80 RPM, 20k TQ,15k wob 425 GPM,1250 PSI, MW 9.0,10.5 ECD 550 bgg.;Wash and ream out excessive dogleg @ 10827'MD. ABI showed 22°DL over 9'(10810'-10819'). Reduced to DL to 13.5°. 80 rpm,19k tq,450 gpm,1320 psi. ECD's reduced to 10.4. Reduced to 75 BGG.;Last svy @ 10734' MD,93.05°Inc,184.24°Az=23'high,11.5'left of WP 13 1.80%concretions encountered for lateral.;Hauled 570 bbls cuttings to G&I for total=8848 bbls Hauled 620 bbls H2O from 6 mi lake for total=8980 bbls 0 lbs metal collected for total=0 lbs 0 bbls lost to formation for total=0 bbls 1/7/2018 Drill ahead F/10821'T/11330'MD. 509'©101'AROP 100 RPM, 22 TQ 400 GPM,1190 PSI, MW 9.0,10.7 ECD 400 bgg.;Circ&Condition 30 bbl tandem sweep out @ 500 GPM, 1600 PSI,100 RPM. Reduce ECDs from 10.8 to 10.5.Sweep came back 1600 Stks late with 200%Increase.;Drill ahead F/11330'T/ 11868' MD. 538'@ 89'FPH AROP 100 RPM, 22 TQ 400 GPM,1350 PSI, MW 9.0,10.8 ECD 400 bgg.;Saw 10.5 Deg dogleg after hitting concretion @ 11530'.Ream out and cont drilling ahead. 50#metal recovered on magnets for the interval.;Drill ahead F/11868'T/11959' MD.91'@ 91' AROP 100 RPM, 22 TQ 430 GPM,1422 PSI, MW 9.0,10.8 ECD 650 bgg.;Circulate out tandem sweep to clean hole and reduce ECD's. 450-500 gpm,1630-1750 psi,11 ECD's dn to 10.9 ECDs. Sweep back 1400 stks late w/300%Inc.;Drill ahead F/11959'-T/12400' MD.441'©110' AROP 90 RPM, 23 TQ 400 GPM,1315 PSI, MW 9.0,10.8 ECD 650 bgg.;12,200'MD increase max ROP to mitigate strong drop tendencies of BHA. Helped to establish adequate build rates to Geo-steer it zone. Backream 2x between connections for hole cleaning.;Drill ahead F/12400'-T/12965' MD.565'@ 94' AROP 80 RPM, 24.6 TO 380 GPM,121 PSI, MW 9.05, 10.9 ECD 650 bgg.;BHA continue showing strong drop and right hand walk tendencies in the NB sands.Max ROP 480 fph to obtain build and turn w/390 gpm.;Last svy©12746'MD,93.37°Inc,200.79°Az=Middle of structure&9.9'right of WP 13.1.60%concretions encountered for lateral.;Hauled 613 bbls cuttings to G&I for total=9461 bbls Hauled 540 bbls H2O from 6 mi lake for total=9520 bbls 0 lbs metal collected for total=50 lbs 0 bbls lost to formation for total=0 bbls S 1/8/2018 Drill ahead F112965'T!13563' MD.598'@ 92' AROP 80 RPM, 25 TQ 380-425 GPM,1350 PSI, MW 9.05,11 ECD 650 bgg.;Fighting housing roll&right hand walk.Get the OK from Kevin Eastham to focus on left hand turn instead of trying to stay in zone. Continue to drill ahead trying all parameters from 100-450 ROP.;380-440 GPM,80 RPM Drilled out of zone to attempt a better turn rate @ 13410'. Bring AZ from 200 to 193 F/12871 T/13500'We entered the btm of the \�C A NB©13586'.;Drill ahead F/13563'T/14000 MD(TD). 437'@ 125' AROP 80 RPM, 25 TQ 380-425 GPM,1350 PSI, MW 9.05,11 ECD 650 bgg.;Last 500' 6V From TD Begin bringing up Lubes to 3%ez glide&1%Barlube gold seal.Total 4%.;Pump tandem 30 bbl High/Low sweeps @ 526 GPM 120 RPM. Starting p ECDs 11.Starting PSI 2000 Circ sweep out @ 300%increase in cuttings. Second sweep 50%increase in cuttings 1600 stks late.;Obtain SPR's then monitor Ol t well(static). P/U back up single from std#219 and get final up wt 202k no pump. BGG dropped to 40 units before shutting down to monitor.;BROOH F/14,000'- T/12,900'MD @ 10 fpm. 110 rpm,23k tq,400 gpm,1260 psi,52%flow. ECD's 10.7.35 units BGG during backreaming operations.;BROOH F/12,900 T/ 10,956'MD©10 fpm. 100 rpm,20k.3 tq,400 gpm,1200 psi,52%flow. ECD's 10.5 ppg. Water @ 15 bph to minimize wt inc in mud system.Cont mix baracarbs and maintain 4%lube.;Last svy©13969'MD,89.T Inc,189.23°Az=113'right of WP 13.1.37%concretions encountered for entire production lateral.;Hauled 456 bbls cuttings to G&I for total=9917 bbls Hauled 820 bbls H2O from 6 mi lake for total=10340 bbls 15 lbs metal for total=65 lbs 80 bbls lost to formation for total=80 bbls • • Hilcorp Energy Company Composite Report Well Name: MP L-52 Field: Milne Point County/State: ,Alaska (LAT/LONG): ovation(RKB): 26.5 API#: Spud Date: 12/26/2017 Job Name: 1713437C MPL-52 Completion Contractor AFE#: AFE$: Actizti. a e 1/9/2018 Continue back reaming @ 400 GPM,100 RPM, F/10956'T/9065'. Started packing off.,RIH to 9115'. Back ream two stands slow cleaning up F/9115' /:... 8990'.,Continue back reaming @ 400 GPM,100 RPMs.MW climbing to 9.2.Treat as needed. Slight pack offs @ 7777',7666',7440'. Pull slow&cle-n up good. Current MW 9.2.,Continue back reaming @ 400 GPM 1100 psi,100 RPMs f/7434'to 6234'just above shoe,work thru several slight packoffs f/7;20'to 7306',7148'to 7138',7103'to 7050',6927'to 6910',6765'to 6744'w/5-10k overpulls,cleanup same.Pulling BHA into shoe f/6427 to 6302'slow rota to 60 rpm due to slight packoff and 5-10k overpull. 135 bbl losses BROOH.Max gas 758u.,Pump 30 bbl lo vis low wt/30 bbl hi vis hi wt tandem sweep,increase f/ 400 gpm to max rate 550 gpm 1700 psi once sweep out of bit,reciprocate 65'and rotate 120 rpm cleaning up wellbore.Sweep back on time w/100%i,crease at shakers mostly clay,some sand,shale,circ 2 BU total. Blow down top drive,monitor well 15 min,static.,RIH on elevators f/6234'to 7600'wipe thru .ut of zone hole section as a precautionary measure for running liner,no issues.Correct displacement TIH.,BROOH 400 gpm,1100 psi,100 rpm f/7600'to 6800'.,Hauled 228 bbls cuttings to G&I for total=10145 bbls Hauled 130 bbls H2O from 6 mi lake for total=10470 bbls 10 lbs metal for total=75 lbs 55 bbls lost to formation for total=135 bbls 1/10/2018 Back ream to shoe @ 400 GPM 100 RPM. F/6868'.,Circ 2 btm up @ 550 gpm 120 rpm,1600 psi. Clean. Pump slug.Blow down TD.,L/D DS-50 F/1.239'T/ 4478'.RIH with DS-50 7/5736'. UD DS-50 F/5736'T/4478,drop drift on wire, POH standing back remaining stands of NC-50 to 270'.,PJSM,UD BH . Recover drift.Down load MWD. Install housing clamp on geo-pilot,UD bit,Bit Grade=1-0-LT-C2-E-I-NO-TD. ILS showed damage. 5 bbl losses on ToH f/ shoe.Clean floor while downloading BHA.,RIH w/27 stds DS50 DP,POOH UD 54 jts.Monitor well,static.,M/U perforated flush tool,jet stack,function pper, lower pipe rams and annular,jet stack again.UD jet tool.,R/D Hawk jaw,CLear rig floor. R/U 4 1/2"handling equipment and power tongs.Ready FOSV and XO.,PJSM with all parties involved,discuss plan for well control with screens across BOP.M/U and RIH with lower screen completion as per tally,P/U t shoe assy,WIV w/1"ID ball seat,xo, 4 1/2"drillable packoff sub,xo pup jt,solid jt 4 1/2"13.5#L80 hydril 625 liner,P/U and RIH w/4 1/2"13.5#hydril petr.gaurd screen/tendaka swell pkr.Lower completion as per tally,screens quit auto filling @ 1500'.,M/U to optimum tq @ 9600 ft/lbs,utilize dog collar clamp on =very jt, use BOL 2000 pipe dope.Install 1 straight blade centralizer on pin end of ea.screen and ea.jt of liner ran next to stop collar.,RIH to 2072' with 3 screen- in the hole,still not auto filling.Stop running in the hole, Prep to L/D 3 jts and 3rd screen ran to circulate w/ 9.2 brine.,Hauled 171 bbls cuttings to G&I for tot-I= 10316 bbls Hauled 410 bbls H2O from 6 mi lake for total=10880 bbls 0 lbs metal for total=75 lbs 5 bbls lost to formation for total=140 bbls 1/11/2018 UD 3 Joints of 4.5 Hydril 625&one screen to 1906'. R/U to circ down liner with brine. Build brine in pill pits to 9.4 ppg.Move 300 bbl brine from uprig t tanks to truck. Hook up to rig.,Circ @ 5 bpm monitoring returns. Circ until good bring in returns. 218 bbl. Well displaced over to brine at 1900'. Blow down -urface equipment&prep to run Iiner.,Run liner as per tally Ft 1900'T/4991'. UD joint#110 damaged box. P/U Joint#175 in its place.Continue running 4.5 ydril 625 Liner/Packer/Screens as per plan F/4991'T/6762'+/-. Fill with fill up hose with 9.4 to keep fluid moving out the liner.Liner is auto filling also.,Cont nue running 4.5 Hydril 625 Liner/Packer/Screens as per plan F/6762'T/7445'setting down 4k,P/U 20'and work thru easily,continue to RIH setting down '.k @ 7655'attempt to work thru several times.Use fill up hose with 9.4 brine to keep fluid moving out the liner.Liner is auto filling also.,UD single,M/U drive "ushing on single,P/U same and M/U TD.Top drive TQ set @ 10k,rotate 5 rpm,5.5k TQ. attempting to work down,increase rpm slowly staging to 20 rpm wt p to 25k set down wt finally working past after several attempts.UD drive sub. Note:tight hole when 1st swell packer hanging up on concretion drilled f/712 'to 7145'w/5.5 deg dog leg.PU/SO/ROT 99/65/80.,RIH f/7695'to 7895'@ jt 175, UD 1 jt putting string in tension parked @ 7859'.Note:Verify 10 swell packers,9 screens,174 jts liner, 193 straight blade 7"OD centralizers ran.Lost 6.2 bbls over calc displacement on TIH.PU/SO 98/65.,R/U False table, 3/8" handling equipment,C/O to 2 3/8"tong dies.Ready FOSV and XOs. Monitor well w/trip tank.,PJSM,M/U slick stinger. Drift/PIU and RIH with 2-3/8" H6 inner string to 3117'@ 100 jts ran.,Hauled 182.7 bbls cuttings to G&I for total=10498.7 bbls Hauled 130 bbls H2O from 6 mi lake for total=11010 bbls 0 lbs metal for total=75 lbs 6.2 bbls lost to formation for total=146.2 bbls 1/12/2018 Drift/P/U and RIH with 2-3/8"PH6 inner string F/3117'T/7830'.Tag up with inner string. Space out as per baker. P/U 10',8'&4'pup on joint 250. I,nor string wt 67K. Change handling equipment to 5"DP.,P/U LT packer as per baker. M/U to inner string and liner. Let slips ride.Good.Inspect packer in the table.Good. Install pal mix as per baker.P/U on string broke over @ 177. String wt 137K.,R/D false table&Weatherford equipment. Circ 1 inner string volume @ 2 bpm 900 psi. Blow down TD.,RIH w/5"DP from derrick @ 50 FPM as per baker. F/7906'T/10040'.UP/DN 160/84K P/U 6.25 DC F/10040' T/10440'. UP/DN 160/84. 11 bbl lost on the trip in.,Continue to P/U and RIH wt 27 total-6 1/4"DCs to 10867' M/U XO,PU/SO 188/99.RIH wI 23 stds 5" DP f/10869'to 12316',work thru tight spot @ 11590'.PU/SO 195/64,Drift,P/U and RIH with 5"HWDP f/12136'work thru tight spot @ 12205',RIH to 12823',attempt to wok past.Correct displacement RIH.,M/U top drive,est circulation 1 bpm,340 psi,2 bpm 950 psi,w/TO set @ 10k,able to rotate 2-6 rpm when working pipe,making very slow progress washing ft 12823'to 12880',4-6 inches ea.time washing down, start making 1'to 1 1/2 ft ea time f/12880'to 12902'.Note:tight spot when 1st swell packer starting in silt zone drilled @ 12250'. 13.3 bbl losses washing and working liner down.PU/SO 218/75.,Hauled 115.4 bbls cuttings to G&I for total=10614.1 bbls Hauled 0 bbls H2O from 6 mi lake for total=11010 bbls 0 lbs metal for total=75 lbs 11 bbls lost to formation for total=157.2 bbls • • 1/13/2018 Continue to wash liner down 2 bpm,920 psi f/12902'to 13340'.2 bpm,12K Tq.Stalls on set down.Making 1"-6"each time we work it.,Continue to w.sh liner down 2 bpm,960 psi f/13340'to 13586', 1-3 rpm 12k,stalling on set down,making 2"to 6"each time we work pipe,very slow progress @ 13586'sta ng back in zone drilled.Condition mud to control water loss and PH.,Continue to wash liner down reducing to 1 bpm,480 psi,unable to make any progress @ 2 bpm.Wash f/13586'1-3 rpm 12k,stalling on set down,making 3" each time we work pipe,slow progress to 13680',start making 6"ea time to 13715' 35 bbl losses washing completion down.P/U 216.,Hauled 115.4 bbls cuttings to G&I for total=10729.4 bbls Hauled 130 bbls H2O from 6 mi lake for total=11140 bbls 0 lbs metal for total=75 lbs 41.3 bbls lost to formation for total=198.5 bbls 1/14/2018 Wash down Fl 13715'T/13765'. Making about 15 FPH. Worked 5 hrs and only made it inches from 13765'. Working with pump and without. Tried p !ling up hole and we would lose what we gained. Consulted town engineers and Geologist on possible Set point.Continue working pipe and started making ole after 5 hrs. 1-2 BPM,520-1000 psi, 12.5K TQ.1-3 RPMs while moving.,Continue work pipe Fl 13765 T/13870'.,Continue to wash and work pipe do n 1-2 bpm,540-1000 psi,1-3 rpm,stalling out and P/U to gain rotation back f/13870'to 13925 @ shoe depth 75'f/TD, Note:2 hrs to make last 40', 13 bbl osses washing down.P/U 245.,PJSM for displacing, Parked @ 13925'P/U to 225k putting string in tension.Flush mud ft MP 1,Pump 58 bbl spacer 2 bpm,1230 psi,followed w/750 bbls 9.1 brine 2.8 bpm,1800 psi.Dump mud returns.Pump 40 bbl SAPP pill #1 followed w/50 bbls brine,40 bbl SAPP pill#2,50 bbls brine,SAPP pill#3 Dump 1085 bbls mud and interface,235 bbls over calculated displacement before taking brine returns to pits.,Continue to circulate out SAPP pills 3.3 b.m, 1780 psi.No losses while displacing.,Hauled 515.8 bbls cuttings to G&I for total=11245.3 bbls Hauled 0 bbls H2O from 6 mi lake for total=11140 bbls 0 lbs metal for total=75 lbs 13 bbls lost to formation for total=211.5 bbls 1/15/2018 Parked @ 13925'with string in tension,Continue to displace out SAPP pills 3.3 bpm,1780 psi dumping sap pills as they returned. Continue circulating over 270s while prepping for Liner X OH displacement.,Line up vac trucks with clean brine to pumps.Circ 600 bbl displacing 1.5 OH Liner volumes dumping all returns. Drop 1.25 Phinolic Closing ball&pump in to place at 3 bpm.Slow pumps to 2 bpm.Bump @ 90 bbl. Blow down TD.,Pressure up and close IV @ 1500 psi. Pressure up to 2600 to set LT and hold.Slack off and set down on LT. Pressure up to 3500 to set packer.Hold 5 min.Seen shift @ 2900. P essure up to 4500 psi with test pump to release tool. P/U&verify release.Good. Test back side 1500 psi 1U min with LH'open.NO visual leaks observed out he DP. Lost 20 psi in 10 min.,Bleed down open up rams.Pressure up to 200 psi.1117exposing po s at LK I pump Thu bbl circulating out of LT.Two planned Li er volumes if circulation was out of the 2 3/8. @ 6 bpm 280 psi. Dump all returns.,Slip and cut 137' drilling line. Static loss rate @ 10 BPH.Function tes Emergency break release for the draw works brakes. Lots learned.Tighten line back on drum.Test crown saver.Submit 24 hr BOP test notification to OGCC @ 19:00 Hrs.,Service top drive,crown sheaves and drawworks.,POOH UD 5"HWDP f/13865'to 12316', POOH racking 9 stds of 5"DP in derrick f/12;16'to 10869'@ DCs.M/U safety joint,POOH UD 27 6.25"DCs to 10038',UD safety jt. P/U 170K.,Continue POOH UD 5"DP f/10038'to 7905',inspect an• UD liner running tools as per BOT rep,R/D Hawk jaw,R/U 2 3/8"handling equipment.M/U safety jt for inner string.Static loss rate 15 bph,146 bbl losses OOH to inner string.,PJSM, LID space out pups,POOH UD 2 3/8"inner string f/7860'to 6200', Rinse 2 3/8"w/fresh water,dope pin and box end before ins ailing thread protectors. Loss rate continues @ 15 bph.,Hauled 2202.2 bbls cuttings to G&I for total=13447.5 bbls Hauled 260 bbls H2O from 6 mi lake for total=11400 bbls 0 lbs metal for total=75 lbs 78 bbls lost to formation for total=289.5 bbls 511)4...11 P Q 1/16/2018 POOH UD 2 3/8"inner string f/6200'to surface,L/D slick stick and safety jt. Loss Rate @ 16 bph.,Rig Down Weatherford Tongs. Rig up 5"DP handlin. equipment.,Clean and clear rig floor. Break down 2 3/8"safety Jt.,MU 3 1/2"Eue Stinger on DP. R/U Hawk Jaw.,RIH with 27'3 1/2"eue stinger on 5"ap from derrick to LT @ 6030'. Pu Wt 140,Dn Wt 92.,L/D last 6 joints from derrick using mouse hole/Hawk Jaw.,PU drift and MU 10'DP Pup Jt and RIH to 60.0'(10' inside TOL).,Pump 30 bbl hi vis sweep,chase w/9.1 brine,stage pump to max rate 14 bpm,560 psi.Sweep back on time w/minimal increase of silt and sand.UD pup jt.75 bbl losses pumping sweep around.,Blow down TD,monitor well w1 trip tank,Offload 290 bbls clean brine f/vac truck into pits,build 20 bbl spacer..W/0 more clean brine to arrive and offload another 290 into pits, Static loss rate 18 bph.,Pump 20 bbl spacer,displace to clean 9.1 brine pumping 12 bpm,400 psi,w/clean brine @ returns,480 bbls. Blow down TD.Monitor well,static loss rate 15 bph.60 bbl losses displacing.,POOH UD 5"DP f/6030'to surface.UD stinger and X/O, 15 bph loss rate.86 bbl losses on trip out.,Clear and clean rig floor,finish loading out pipe shed,monitor well.,Pull wear bushing, R/U test equipment using 4 1/2"test jt,flood stack and lines.Test Witness waived by Jeff Jones Mon 1/15/2018 7:04 PM.Monitor and fill I/A with hole fill while testing.,Hauled 665.4 bbls cuttings to G&I for total=14112.9 bbls Hauled 280 bbls H2O from 6 mi lake for total=11680 bbls 0 lbs metal for total=75 lbs 584 bbls lost to formation for total=873.5 bbls 1/1 712 01 8 PJSM on Testing BOPE.Walk lines and verify valve alignment.Flood Stack/Choke manifold.,Test BOP to 250/3000 psi.Test gas alarms. Perform Accumulator Test:Start 2950 psi,after close 1550 psi,200 psi build 20 sec,full recovery 82 sec.6 bottles @ 2283 psi average.Test Witness waived by Jeff Jones.f/P on Mezz Kill Valve,Cycle and Retest good.F/P on Super Choke,Cycle and Re test good.Hole fill on annulus adding lb bph while testing.,l-lush through choke Manifold and Gas buster with FW.(8 bbls to fill Gas Buster)Blow down Choke and kill.R/D Test equipment.,RU to run 4 1/2"Upper Completion w/7"bullet seal assembly.Static loss rate @ 90 bph.,PJSM on running completion.Count and verify 170 jts 4 1/2"tubing in pipe shed.Jt#7 flagged for XN VOL, Nipple.,M/U seal assy(%.3"OD). Run 4.5",TXP-SR,L-80,12.6#tbg to 304',MU XN Nipple.Continue to run completion to 3470'.,Continue to Run completion from 3470'to 6004'@ jt#149,M/U jt 150.P/U 88K,S/0 66K,see seals entering TOL w/8k drag,nogo out @ TOL 6028.58', adjust bag pressure to 800 psi, O%, close bag,line up and pressure test I/A to 400 psi,good.bleed off pressure,open bag. � 105 bbl losses running llner.,L/D jt 149 and 150 to 5964' space out as per BOT rep.M/U 3.92'pup jt,M/U jt 149.M/U pup w/Hanger,M/U landing jt,drain r stack,land out hanger leaving 2'off nogo. R/U to reverse circ.R/U LRS on I/A, PT lines to 3500 psi, p/u 2',Close bag,pressure to 500 psi,good,bleed to 250 gnik psi,P/U 4'exposing ports dumping pressure. Loss rate 45 bph.,PJSM w/all parties involved.Reverse circ,fump 165 bbls corrosion inhibited 9.1 brine from /j�� vac truck 4 bpm,20 psi,chase w/10 bbls 9.1 brine to clear lines.Swap to LR,pump 169 bbls 70 deg diesel 5 bpm,250 psi freeze protecting I/A to 3000', RIH �D `0 3'closing ports,drain and vac out stack. Land hanger,Open bag.,RILDS per wellhead rep.With LRS test 4 1/2"x 9 5/8"I/A w/diesel to 3100 psi f/30 min !�f_ri 00 charted.Chase slow bleed off on casing test,Bleed off pressure.Isolate f/LR,utilize rig pump for test achieving a passing 30 min charted test to 3000 psi. bleed off pressure.Pumped 3.8 bbls,bled off 3.8 bbls.,lnstall BPV.Lower power tongs and casing tools out slide.Blow down lines.Start NW tjUrt.,nauied 209 bbls cuttings to G&I for total=14321.9 bbls Hauled 130 bbls H2O from 6 mi lake for total=11810 bbls 0 lbs metal for total=75 lbs 712 bbls lost to formation for total=1585.5 bbls • • 1/18/2018 PJSM.N/D Choke and Kill Lines.N/D BOP and set back.Flush through TD,Kill Line,and Mud Pump Bleeder/Pop Off Lines w/FW. Blow Down Same.Finish flushing lines in Mud pits w/FW.,N/U Adapter flange and Tree.PT void to 500/5000 psi.Slight bleed on adapter test.Tighten flange to tbg spool.Re Test good. Pull BPV,Install TWC,Finish cleaning pits.Continue work on new drag chain.Begin open up Mud Pumps for inspection and in prep for rig move.,Fill tree with 1i DSL.PT 500/5000 psi.Observed slight leak off.Pull and rebuild TWC.Set TWC PT Tree 500/5000 psi good test.,LRS R/U and freeze protect tbg to 3000'w/ �(GB 4 diesel @ 4.5 bpm/300 psi. R/D LRS.Continue working on Drag Chain and Mud Pumps.Beginn ing up rs.Disconnect hi-line power,put rig on 7 gen power.,Drain liner wash on both mud pumps,disassemble mud pump fluid ends to ensure dry for rig move.vac out cellar box,vac out sumps,clearup „rt) cellar area. C/O saver sub and gripper dies.R/D tongs.Bridal up.Finish cleaning pits.Disconnect pit interconnects.Prep pipe shed for move.Continue to work on drag chain.,Finish R/U bridal lines,Continue working on drag chain.Blow down water lines.PJSM,Scope derrick down.Roll up derrick wt bucket line. Flip up roof hatches between modules. Freeze protect laundry room.Cleanout and freeze protect Vac unit.R/D Pit interconnects.Fire up cold start generators. Peak trucks on location @ 03:00.,Empty test pup tank.Blow down steam lines.Remove cuttings box.Secure cellar for rig move.Secure pipe shed and shop, Load shop on trailer.Milne Point went to Phase 2 weather conditions @ 05:00.,Phase 3 conditions on pad and phase 2 conditions on main roads,suspend operations,wait on weather.Release rig©0600.,Hauled 518 bbls cuttings to G&I for total=14840 bbls Hauled 180 bbls H2O from 6 mi lake for total=11990 bbls 0 lbs metal for total=75 lbs Total losses to formation =1585.5 bbls • Hilcorp Alaska, LLC Milne Point M Pt L Pad MPU L-52 50-029-23590-00 Sperry Drilling Definitive Survey Report 09 January, 2018 HALLIBURTDN Sperry Drilling • • Halliburton Definitive Survey Report Company: gHilcorpAlaska,LLC Local Co-ordinate Reference: ` ' Well MPU L-52 Project: ,Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft ti Site: .M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft l Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: 1 i MPU L-52 Database: Sperry EDM-NORTH US+CANADA ;S Project Milne Point,ACT,MILNE POINT ( Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU L-52 Well Position +N/-S 0.00 usft Northing: 6,031,919.76 usft Latitude: 70°29'53.079 N +E/-W 0.00 usft Easting: 544,648.93 usft Longitude: 149°38'5.523 W Position Uncertainty 0.00 usft Wellhead Elevation: 42.40 usft Ground Level: 15.10 usft Wellbore MPU L-52 _..... ,.,� ,. ...:. ,. .. , � ...... �,�s ag w�.0��,. ._•.;�r� .r. ...�,,. --tee>,.-.,m.. Magnetics Model Name Sample Date Declination Dip Angle.?, Field Strength BGGM2017 12/29/2017 17.37 81.03 57,490 Design MPU L-52 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.30 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction r (usft) ,. . (usft) (usft) (°) SK ... 27.30 0.00 0.00 204.46 _ � �� Survey Program Date 1/9/201841r , z From To ,'•.. '" (usft) (usft) Survey(Wellbore) Tool Name Description '' Survey Date 75.00 717.00 SDI Gyro Surveys(MPU L-52) 2_Gyro-NS-GC Drill collar H029Ga:North seeking single shot in drill collar 12/26/2017 786.77 6,248.74 MWD+IFR2+MS+sag(1)(MPU L-52) 2_MWD+IFR2+MS+Sag A013Mb:IIFR dec&multi-station analysis+sag 12/26/2017 6,330.47 13,969.02 MWD+IFR2+MS+Sag(2)(MPU L-52) 2_MWD+IFR2+MS+Sag A013Mb:IIFR dec&multi-station analysis+sag 01/05/2018 Survey ':s , ., ''xj-*r.' 4161",:..* e :`' 4 ;r mss. ' m Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.30 0.00 0.00 27.30 -15.10 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 UNDEFINED 75.00 0.60 159.92 75.00 32.60 -0.23 0.09 6,031,919.53 544,649.02 1.26 0.18 2_Gyro-NS-GC_Drillcollar(1) 150.00 0.71 161.18 149.99 107.59 -1.04 0.37 6,031,918.72 544,649.31 0.15 0.80 2_Gyro-NS-GC_Drill collar(1) 225.00 0.88 161.18 224.99 182.59 -2.03 0.71 6,031,917.74 544,649.65 0.23 1.55 2_Gyro-14S-GC_Drillcollar(1) 300.00 1.13 163.13 299.98 257.58 -3.28 1.11 6,031,916.49 544,650.06 0.34 2.53 2_Gyro-NS-GC_Drill collar(1) 346.00 1.11 166.45 345.97 303.57 -4.15 1.34 6,031,915.62 544,650.30 0.15 3.22 2_Gyro-NS-GC_Drill collar(1) 406.00 1.26 176.99 405.95 363.55 -5.37 1.51 6,031,914.40 544,650.48 0.44 4.26 2_Gyro-NS-GC_Drill collar(1) 468.00 1.40 206.85 467.94 425.54 -6.73 1.21 6,031,913.04 544,650.18 1.13 5.62 2_Gyro-NS-GC_Drill collar(1) 531.00 1.82 214.70 530.91 488.51 -8.24 0.29 6,031,911.53 544,649.27 0.75 7.38 2_Gyro-NS-GC_Drill collar(1) 593.00 2.73 234.92 592.86 550.46 -9.90 -1.48 6,031,909.86 544,647.51 1.94 9.62 2_Gyro-NS-GC_Drill collar(1) 654.00 4.64 254.67 653.74 611.34 -11.38 -5.05 6,031,908.35 544,643.95 3.72 12.45 2_Gyro-NS-GC_Drill collar(1) 717.00 6.16 259.19 716.46 674.06 -12.69 -10.83 6,031,907.01 544,638.18 2.50 16.03 2_Gyro-NS-GC_Drill collar(1) 1/9/2018 6:42:35PM Page 2 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: ; Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA 1,:;, ., Survey ,' Map$ ..> Map Vertical MD ..-« Inc ' Azi TVD TVDSS +N/-S +E/-WNorthing Easting DLS Section ` (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 786.77 8.20 257.42 785.68 743.28 -14.48 -19.36 6,031,905.17 544,629.66 2.94 21.19 2_MWD+IFR2+MS+Sag(2) 847.05 10.80 258.31 845.12 802.72 -16.56 -29.09 6,031,903.03 544,619.95 4.32 27.12 2_MWD+IFR2+MS+Sag(2) 911.77 14.61 253.34 908.25 865.85 -20.13 -42.85 6,031,899.38 544,606.21 6.12 36.06 2_MWD+IFR2+MS+Sag(2) 973.25 16.72 248.48 967.45 925.05 -25.60 -58.51 6,031,893.82 544,590.58 4.04 47.52 2_MWD+IFR2+MS+Sag(2) 1,037.65 20.74 247.11 1,028.42 986.02 -33.43 -77.64 6,031,885.86 544,571.50 6.28 62.58 2_MWD+IFR2+MS+Sag(2) 1,100.75 25.91 244.98 1,086.35 1,043.95 -43.62 -100.44 6,031,875.55 544,548.76 8.30 81.29 2_MWD+IFR2+MS+Sag(2) 1,163.40 27.71 242.73 1,142.26 1,099.86 -56.08 -125.79 6,031,862.93 544,523.49 3.30 103.13 2_MWD+IFR2+MS+Sag(2) 1,226.57 30.12 244.06 1,197.55 1,155.15 -69.74 -153.11 6,031,849.10 544,496.26 3.95 126.88 2_MWD+IFR2+MS+Sag(2) 1,289.01 34.44 244.80 1,250.33 1,207.93 -84.12 -183.18 6,031,834.55 544,466.27 6.95 152.42 2_MWD+IFR2+MS+Sag(2) 1,352.70 37.85 243.46 1,301.76 1,259.36 -100.53 -216.97 6,031,817.94 544,432.59 5.50 181.34 2_MWD+IFR2+MS+Sag(2) 1,415.15 41.25 240.78 1,349.91 1,307.51 -119.14 -252.09 6,031,799.11 544,397.58 6.09 212.83 2_MWD+IFR2+MS+Sag(2) 1,477.98 43.43 238.88 1,396.35 1,353.95 -140.42 -288.67 6,031,777.62 544,361.14 4.02 247.34 2_MWD+IFR2+MS+Sag(2) 1,541.09 45.53 236.73 1,441.37 1,398.97 -163.99 -326.07 6,031,753.83 544,323.88 4.09 284.28 2_MWD+IFR2+MS+Sag(2) 1,603.32 45.31 234.43 1,485.06 1,442.66 -189.04 -362.63 6,031,728.56 544,287.48 2.66 322.22 2_MWD+IFR2+MS+Sag(2) 1,666.79 48.90 232.08 1,528.25 1,485.85 -216.87 -399.86 6,031,700.51 544,250.42 6.27 362.97 2_MWD+IFR2+MS+Sag(2) 1,728.33 50.74 231.97 1,567.96 1,525.56 -245.80 -436.92 6,031,671.36 544,213.53 2.99 404.65 2_MWD+IFR2+MS+Sag(2) 1,791.85 52.74 231.53 1,607.29 1,564.89 -276.68 -476.09 6,031,640.25 544,174.56 3.20 448.98 2_MWD+IFR2+MS+Sag(2) 1,854.81 54.30 230.89 1,644.72 1,602.32 -308.40 -515.54 6,031,608.30 544,135.30 2.61 494.18 2_MWD+IFR2+MS+Sag(2) 1,917.09 53.98 230.98 1,681.21 1,638.81 -340.21 -554.73 6,031,576.26 544,096.30 0.53 539.36 2_MWD+IFR2+MS+Sag(2) 1,981.02 55.14 230.36 1,718.27 1,675.87 -373.22 -595.02 6,031,543.01 544,056.22 1.98 586.09 2_MWD+IFR2+MS+Sag(2) 2,043.82 54.30 230.94 1,754.55 1,712.15 -405.72 -634.66 6,031,510.27 544,016.78 1.54 632.10 2_MWD+IFR2+MS+Sag(2) 2,106.55 53.63 231.18 1,791.45 1,749.05 -437.61 -674.12 6,031,478.16 543,977.52 1.11 677.45 2_MWD+IFR2+MS+Sag(2) 2,168.92 52.90 230.13 1,828.75 1,786.35 -469.29 -712.77 6,031,446.24 543,939.06 1.79 722.30 2_MWD+IFR2+MS+Sag(2) 2,232.38 54.96 229.95 1,866.11 1,823.71 -502.24 -752.09 6,031,413.07 543,899.95 3.25 768.57 2_MWD+IFR2+MS+Sag(2) 2,295.58 52.55 230.64 1,903.48 1,861.08 -534.80 -791.29 6,031,380.27 543,860.94 3.91 814.44 2_MWD+IFR2+MS+Sag(2) 2,358.37 53.68 230.15 1,941.17 1,898.77 -566.81 -829.99 6,031,348.03 543,822.45 1.90 859.61 2_MWD+IFR2+MS+Sag(2) 2,420.37 54.40 230.59 1,977.57 1,935.17 -598.82 -868.64 6,031,315.79 543,783.99 1.30 904.74 2_MWD+IFR2+MS+Sag(2) 2,484.40 53.22 231.42 2,015.38 1,972.98 -631.34 -908.80 6,031,283.03 543,744.03 2.12 950.97 2_MWD+IFR2+MS+Sag(2) 2,547.18 55.15 230.61 2,052.12 2,009.72 -663.37 -948.36 6,031,250.77 543,704.66 3.25 996.51 2_MWD+IFR2+MS+Sag(2) 2,610.41 54.12 230.73 2,088.71 2,046.31 -696.05 -988.25 6,031,217.85 543,664.98 1.64 1,042.77 2_MWD+IFR2+MS+Sag(2) 2,673.23 54.04 231.62 2,125.57 2,083.17 -727.94 -1,027.88 6,031,185.73 543,625.54 1.15 1,088.21 2_MWD+IFR2+MS+Sag(2) 2,735.88 55.68 231.34 2,161.62 2,119.22 -759.85 -1,067.96 6,031,153.58 543,585.66 2.64 1,133.85 2_MWD+IFR2+MS+Sag(2) 2,798.92 54.86 231.22 2,197.54 2,155.14 -792.26 -1,108.38 6,031,120.94 543,545.43 1.31 1,180.09 2_MWD+IFR2+MS+Sag(2) 2,861.66 53.78 231.97 2,234.13 2,191.73 -823.92 -1,148.32 6,031,089.04 543,505.69 1.98 1,225.44 2_MWD+IFR2+MS+Sag(2) 2,924.58 56.22 231.39 2,270.22 2,227,82 -855.88 -1,188.75 6,031,056.84 543,465.46 3.95 1,271.27 2_MWD+IFR2+MS+Sag(2) 2,987.43 55.75 231.33 2,305.38 2,262.98 -888.41 -1,229.44 6,031,024.07 543,424.97 0.75 1,317.73 2_MWD+IFR2+MS+Sag(2) 3,050.34 54.96 231.88 2,341.14 2,298.74 -920.55 -1,270.00 6,030,991.69 543,384.60 1.45 1,363.79 2_MWD+IFR2+MS+Sag(2) 3,113.47 53.99 232.50 2,377.82 2,335.42 -952.05 -1,310.59 6,030,959.95 543,344.21 1.73 1,409.26 2_MWD+IFR2+MS+Sag(2) 3,176.07 52.38 232.39 2,415.33 2,372.93 -982.60 -1,350.32 6,030,929.17 543,304.67 2.58 1,453.52 2_MWD+IFR2+MS+Sag(2) 3,239.27 54.46 231.78 2,453.00 2,410.60 -1,013.78 -1,390.36 6,030,897.74 543,264.83 3.38 1,498.48 2_MWD+IFR2+MS+Sag(2) 1/9/2018 6:42:35PM Page 3 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report _� "" �^�"iss,au. ....1a €n. ';•.i �Y.,v.%v:".... ._ - ••?t a v....,oF 5..�.�i :..3... «. i a 3dTziun»TYu..'*kS:� .:.,� Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 0 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical -{ MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section ' (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,302.28 53.52 231.69 2,490.04 2,447.64 -1,045.35 -1,430.37 6,030,865.94 543,225.00 1.50 1,543.79 2_MWD+IFR2+MS+Sag(2) 3,365.20 54.84 231.69 2,526.86 2,484.46 -1,076.97 -1,470.41 6,030,834.08 543,185.16 2.10 1,589.15 2_MWD+IFR2+MS+Sag(2) 3,428.17 53.64 231.84 2,563.66 2,521.26 -1,108.60 -1,510.54 6,030,802.22 543,145.22 1.92 1,634.55 2_MWD+IFR2+MS+Sag(2) 3,490.87 55.65 230.54 2,599.94 2,557.54 -1,140.65 -1,550.38 6,030,769.93 543,105.58 3.62 1,680.23 2_MWD+IFR2+MS+Sag(2) 3,554.28 55.11 231.19 2,635.97 2,593.57 -1,173.59 -1,590.86 6,030,736.75 543,065.31 1.20 1,726.96 2_MWD+IFR2+MS+Sag(2) 3,616.47 54.01 231.43 2,672.03 2,629.63 -1,205.26 -1,630.40 6,030,704.85 543,025.95 1.80 1,772.17 2_MWD+IFR2+MS+Sag(2) 3,679.83 52.20 231.05 2,710.06 2,667.66 -1,236.98 -1,669.92 6,030,672.89 542,986.64 2.90 1,817.40 2_MWD+IFR2+MS+Sag(2) 3,742.79 53.72 231.36 2,747.99 2,705.59 -1,268.46 -1,709.08 6,030,641.18 542,947.66 2.45 1,862.28 2_MWD+IFR2+MS+Sag(2) 3,805.60 52.45 231.85 2,785.71 2,743.31 -1,299.65 -1,748.44 6,030,609.75 542,908.50 2.12 1,906.97 2_MWD+IFR2+MS+Sag(2) 3,869.01 55.29 231.85 2,823.10 2,780.70 -1,331.29 -1,788.71 6,030,577.88 542,868.42 4.48 1,952.43 2_MWD+IFR2+MS+Sag(2) ' 3,931.82 55.02 231.92 2,858.98 2,816,58 -1,363.11 -1,829.27 6,030,545.82 542,828.06 0.44 1,998.19 2_MWD+IFR2+MS+Sag(2) 3,994.48 54.16 232.63 2,895.29 2,852.89 -1,394.35 -1,869.66 6,030,514.34 542,787.86 1.65 2,043.36 2_MWD+IFR2+MS+Sag(2) 4,057.41 54.22 232.42 2,932.11 2,889.71 -1,425.40 -1,910.16 6,030,483.05 542,747.55 0.29 2,088.39 2_MWD+IFR2+MS+Sag(2) 4,120.30 54.04 232.98 2,968.96 2,926.56 -1,456.29 -1,950.70 6,030,451.92 542,707.20 0.78 2,133.29 2_MWD+IFR2+MS+Sag(2) 4,183.11 53.44 233.06 3,006.11 2,963.71 -1,486.75 -1,991.16 6,030,421.22 542,666.93 0.96 2,177.77 2_MWD+IFR2+MS+Sag(2) 4,245.92 55.65 231.54 3,042.54 3,000.14 -1,518.04 -2,031.63 6,030,389.69 542,626.65 4.03 2,223.01 2_MWD+IFR2+MS+Sag(2) 4,308.94 55.65 231.04 3,078.10 3,035.70 -1,550.58 -2,072.23 6,030,356.91 542,586.25 0.66 2,269.44 2_MWD+IFR2+MS+Sag(2) 4,371.99 56.57 231.25 3,113.26 3,070.86 -1,583.42 -2,112.99 6,030,323.84 542,545.70 1.49 2,316.20 2_MWD+IFR2+MS+Sag(2) 4,434.76 56.27 231.63 3,147.98 3,105.58 -1,616.01 -2,153.88 6,030,291.00 542,505.01 0.69 2,362.81 2_MWD+IFR2+MS+Sag(2) 4,497.74 55.05 230.80 3,183.50 3,141.10 -1,648.58 -2,194.42 6,030,258.19 542,464.67 2.22 2,409.24 2_MWD+IFR2+MS+Sag(2) 4,560.90 55.18 230.85 3,219.63 3,177.23 -1,681.31 -2,234.58 6,030,225.22 542,424.71 0.22 2,455.66 2_MWD+IFR2+MS+Sag(2) 4,622.00 53.16 229.97 3,255.39 3,212.99 -1,712.88 -2,272.76 6,030,193.43 542,386.73 3.51 2,500.20 2_MWD+IFR2+MS+Sag(2) 4,686.29 52.78 229.53 3,294.11 3,251.71 -1,746.04 -2,311.93 6,030,160.04 542,347.76 0.80 2,546.60 2_MWD+IFR2+MS+Sag(2) 4,748.93 52.41 229.50 3,332.16 3,289.76 -1,778.34 -2,349.77 6,030,127.51 542,310.11 0.59 2,591.68 2_MWD+IFR2+MS+Sag(2) 4,811.94 52.90 229.21 3,370.38 3,327.98 -1,810.97 -2,387.78 6,030,094.66 542,272.30 0.86 2,637.12 2_MWD+IFR2+MS+Sag(2) 4,874.19 53.23 229.84 3,407.79 3,365.39 -1,843.27 -2,425.63 6,030,062.13 542,234.65 0.97 2,682.19 2_MWD+IFR2+MS+Sag(2) 4,937.51 53.23 230.06 3,445.69 3,403.29 -1,875.91 -2,464.46 6,030,029.27 542,196.03 0.28 2,727.97 2_MWD+IFR2+MS+Sag(2) 4,999.32 53.07 230.65 3,482.76 3,440.36 -1,907.46 -2,502.54 6,029,997.48 542,158.13 0.81 2,772.47 2_MWD+IFR2+MS+Sag(2) 5,061.98 52.82 231.30 3,520.52 3,478.12 -1,938.95 -2,541.39 6,029,965.77 542,119.48 0.92 2,817.21 2_MWD+IFR2+MS+Sag(2) 5,125.66 52.52 231.72 3,559.14 3,516.74 -1,970.47 -2,581.02 6,029,934.02 542,080.04 0.70 2,862.31 2_MWD+IFR2+MS+Sag(2) 5,188.44 54.66 229.76 3,596.40 3,554.00 -2,002.44 -2,620.13 6,029,901.81 542,041.13 4.23 2,907.61 2_MWD+IFR2+MS+Sag(2) 5,251.39 56.59 228.30 3,631.94 3,589.54 -2,036.51 -2,659.35 6,029,867.51 542,002.12 3.61 2,954.86 2_MWD+IFR2+MS+Sag(2) 5,314.40 58.69 225.29 3,665.67 3,623.27 -2,072.95 -2,698.13 6,029,830.84 541,963.57 5.23 3,004.09 2_MWD+1F142+MS+Sag(2) 5,377.23 60.24 222.07 3,697.60 3,655,20 -2,112.09 -2,735.48 6,029,791.48 541,926.45 5.06 3,055.18 2_MWD+IFR2+MS+Sag(2) 5,440.28 60.98 218.99 3,728.55 3,686.15 -2,153.84 -2,771.17 6,029,749.52 541,891.01 4.41 3,107.96 2_MWD+IFR2+MS+Sag(2) 5,502.62 61.96 216.92 3,758.32 3,715.92 -2,197.03 -2,804.85 6,029,706.14 541,857.60 3.31 3,161.22 2_MWD+IFR2+MS+Sa9(2) 5,566.14 63.80 214.08 3,787.28 3,744.88 -2,243.05 -2,837.67 6,029,659.92 541,825.06 4.92 3,216.70 2_MWD+IFR2+MS+Sag(2) 5,628.93 67.10 210.91 3,813.37 3,770.97 -2,291.22 -2,868.32 6,029,611.58 541,794.70 6.98 3,273.24 2_MWD+IFR2+MS+Sag(2) 5,691.74 68.93 208.14 3,836.89 3,794.49 -2,341.89 -2,897.01 6,029,560.73 541,766.32 5.02 3,331.24 2_MWD+IFR2+MS+Sag(2) 5,754.87 70.82 205.26 3,858.61 3,816.21 -2,394.84 -2,923.63 6,029,507.63 541,740.02 5.23 3,390.46 2_MWD+IFR2+MS+Sag(2) 1/9/2018 6:42:35PM Page 4 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 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 5,817.35 74.78 201.26 3,877.09 3,834.69 -2,449.66 -2,947.17 6,029,452.68 541,716.81 8.81 3,450.11 2_MWD+IFR2+MS+Sa9(2) 5,878.27 76.15 199.10 3,892.38 3,949.98 -2,505.01 -2,967.51 6,029,397.21 541,696.81 4.10 3,508.91 2_MWD+IFR2+MS+Sag(2) 5,943.62 76.92 197.76 3,907.60 3,865.20 -2,565.30 -2,987.60 6,029,336.81 541,677.08 2.32 3,572.11 2_MWD+IFR2+MS+Sag(2) 6,006.56 79.60 197.03 3,920.94 3,878.54 -2,624.00 -3,005.99 6,029,278.01 541,659.05 2.90 3,633.15 2_MWD+IFR2+MS+Sag(2) 6,069.46 81.39 197.96 3,931.87 3,889.47 -2,683.07 -3,024.61 6,029,218.83 541,640.79 4.67 3,694.63 2_MWD+IFR2+MS+Sag(2) 6,132.54 82.93 196.97 3,940.47 3,898.07 -2,742.68 -3,043.36 6,029,159.12 541,622.39 2.89 3,756.65 2_MWD+IFR2+MS+Sag(2) 6,193.66 85.73 194.83 3,946.51 3,904.11 -2,801.16 -3,060.02 6,029,100.54 541,606.09 5.76 3,816.78 2_MWD+IFR2+MS+Sag(2) 6,248.74 88.39 193.53 3,949.34 3,906.94 -2,854.49 -3,073.49 6,029,047.14 541,592.94 5.37 3,870.90 2_MWD+IFR2+MS+Sag(2) 6,330.47 88.04 192.22 3,951.88 3,909.48 -2,934.12 -3,091.70 6,028,967.41 541,575.22 1.66 3,950.93 2_MWD+1FR2+MS+Sag(3) 6,394.09 89.79 194.46 3,953.09 3,910.69 -2,996.01 -3,106.37 6,028,905.44 541,560.91 4.47 4,013.33 2_MWD+IFR2+MS+Sag(3) 6,457.05 91.33 192.87 3,952.47 3,910.07 -3,057.18 -3,121.24 6,028,844.19 541,546.41 3.52 4,075.17 2_MWD+IFR2+MS+Sag(3) 6,520.28 92.75 191.99 3,950.22 3,907.82 -3,118.88 -3,134.84 6,028,782.41 541,533.18 2.64 4,136.97 2_MWD+IFR2+MS+Sag(3) 6,583.24 93.55 190.17 3,946.76 3,904.36 -3,180.57 -3,146.93 6,028,720.65 541,521.47 3.15 4,198.13 2_MWD+IFR2+MS+Sag(3) 6,646.46 93.78 188.75 3,942.72 3,900.32 -3,242.81 -3,157.29 6,028,658.37 541,511.48 2.27 4,259.07 2_MWD+IFR2+MS+Sag(3) 6,709.17 91.49 189.97 3,939.84 3,897.44 -3,304.61 -3,167.48 6,028,596.51 541,501.66 4.14 4,319.54 2_MWD+IFR2+MS+Sag(3) 6,772.11 89.27 188.46 3,939.42 3,897.02 -3,366.73 -3,177.56 6,028,534.33 541,491.96 4.27 4,380.26 2_MWD+IFR2+MS+Sag(3) 6,834.85 87.10 190.19 3,941.41 3,899.01 -3,428.60 -3,187.72 6,028,472.40 541,482.17 4.42 4,440.79 2_MWD+IFR2+MS+Sag(3) 6,897.71 86.80 187.49 3,944.75 3,902.35 -3,490.62 -3,197.37 6,028,410.33 541,472.90 4.32 4,501.24 2_MWD+IFR2+MS+Sag(3) 6,960.56 87.31 186.85 3,947.98 3,905.58 -3,552.90 -3,205.20 6,028,348.02 541,465.44 1.30 4,561.17 2_MWD+IFR2+MS+Sag(3) 7,023.23 87.43 187.82 3,950.86 3,908.46 -3,614.99 -3,213.19 6,028,285.89 541,457.82 1.56 4,620.99 2_MWD+IFR2+MS+Sag(3) 7,086.70 89.48 186.77 3,952.57 3,910.17 -3,677.92 -3,221.25 6,028,222.92 541,450.15 3.63 4,681.61 2_MWD+IFR2+MS+Sag(3) 7,148.68 92.82 187.62 3,951.33 3,908.93 -3,739.39 -3,229.01 6,028,161.41 541,442.76 5.56 4,740.78 2_MWD+IFR2+MS+Sag(3) 7,211.54 94.43 189.77 3,947.35 3,904.95 -3,801.40 -3,238.49 6,028,099.35 541,433.65 4.27 4,801.15 2_MWD+IFR2+MS+Sag(3) 7,274.81 94.60 188.82 3,942.37 3,899.97 -3,863.64 -3,248.68 6,028,037.05 541,423.84 1.52 4,862.02 2_MWD+IFR2+MS+Sag(3) 7,338.03 94.78 189.59 3,937.20 3,894.80 -3,925.84 -3,258.76 6,027,974.80 541,414.13 1.25 4,922.81 2_MWD+IFR2+MS+Sag(3) 7,400.26 95.84 191.04 3,931.44 3,889.04 -3,986.80 -3,269.85 6,027,913.78 541,403.41 2.88 4,982.89 2_MWD+IFR2+MS+Sag(3) 7,464.03 95.58 190.10 3,925.10 3,882.70 -4,049.17 -3,281.49 6,027,851.34 541,392.14 1.52 5,044.49 2_MWD+IFR2+MS+Sag(3) 7,527.21 94.35 190.81 3,919.63 3,877.23 -4,111.07 -3,292.91 6,027,789.39 541,381.09 2.25 5,105.56 2_MWD+IFR2+MS+Sag(3) 7,590.03 93.97 191.56 3,915.07 3,872.67 -4,172.53 -3,305.06 6,027,727.86 541,369.31 1.34 5,166.54 2_MWD+IFR2+MS+Sag(3) 7,652.87 92.23 190.88 3,911.67 3,869.27 -4,234.08 -3,317.27 6,027,666.24 541,357.47 2.97 5,227.62 2_MWD+IFR2+MS+Sag(3) 7,715.41 91.06 190.78 3,909.88 3,867.48 -4,295.48 -3,329.02 6,027,604.78 541,346.10 1.88 5,288.37 2_MWD+IFR2+MS+Sag(3) 7,778.67 90.88 191.38 3,908.81 3,866.41 -4,357.55 -3,341.17 6,027,542.64 541,334.32 0.99 5,349.90 2_MWD+IFR2+MS+Sag(3) 7,841.96 90.70 191.88 3,907.94 3,865.54 -4,419.54 -3,353.93 6,027,480.59 541,321.93 0.84 5,411.61 2_MWD+IFR2+MS+Sag(3) 7,903.25 92.32 194.70 3,906.32 3,863.92 -4,479.16 -3,368.01 6,027,420.89 541,308.21 5.30 5,471.71 2_MWD+IFR2+MS+Sag(3) 7,967.18 93.68 195.93 3,902.97 3,860.57 -4,540.73 -3,384.88 6,027,359.23 541,291.72 2.87 5,534.74 2_MWD+IFR2+MS+Sag(3) 8,030.45 94.47 196.89 3,898.48 3,856.08 -4,601.27 -3,402.70 6,027,298.59 541,274.26 1.96 5,597.22 2_MWD+IFR2+MS+Sag(3) 8,093.28 94.03 197.80 3,893.82 3,851.42 -4,661.07 -3,421.38 6,027,238.67 541,255.94 1.61 5,659.40 2_MWD+IFR2+MS+Sag(3) 8,155.66 93.04 197.73 3,889.98 3,847.58 -4,720.37 -3,440.38 6,027,179.28 541,237.30 1.59 5,721.23 2_MWD+IFR2+MS+Sag(3) 8,218.08 90.29 195.21 3,888.16 3,845.76 -4,780.19 -3,458.07 6,027,119.35 541,219.98 5.97 5,783.01 2_MWD+IFR2+MS+Sag(3) 8,281.02 90.64 194.94 3,887.65 3,845.25 -4,840.96 -3,474.43 6,027,058.49 541,203.98 0.70 5,845.10 2_MWD+IFR2+MS+Sag(3) 1/9/2018 6:42:35PM Page 5 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: HilcoreAlaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,343.86 92.63 195.90 3,885.86 3,843.46 -4,901.51 -3,491.14 6,026,997.85 541,187.64 3.52 5,907.13 2_MWD+IFR2+MS+Sag(3) 8,407.05 91.11 195.59 3,883.80 3,841.40 -4,962.30 -3,508.27 6,026,936.97 541,170.87 2.45 5,969.56 2_MWD+IFR2+MS+Sag(3) 8,470.05 91.70 195.34 3,882.25 3,839.85 -5,023.00 -3,525.07 6,026,876.17 541,154.44 1.02 6,031.77 2_MWD+IFR2+MS+Sag(3) 8,533.08 91.57 194.84 3,880.45 3,838.05 -5,083.83 -3,541.47 6,026,815.25 541,138.41 0.82 6,093.93 2_MWD+IFR2+MS+Sag(3) 8,596.09 91.63 195.13 3,878.69 3,836.29 -5,144.67 -3,557.75 6,026,754.31 541,122.49 0.47 6,156.06 2_MWD+IFR2+MS+Sag(3) 8,658.93 91.69 193.74 3,876.87 3,834.47 -5,205.50 -3,573.41 6,026,693.40 541,107.20 2.21 6,217.91 2_MWD+IFR2+MS+Sag(3) 8,721.97 91.32 193.57 3,875.22 3,832.82 -5,266.74 -3,588.29 6,026,632.08 541,092.69 0.65 6,279.81 2_MWD+IFR2+MS+Sag(3) 8,784.79 91.39 193.31 3,873.73 3,831.33 -5,327.82 -3,602.89 6,026,570.92 541,078.46 0.43 6,341.45 2_MWD+IFR2+MS+Sag(3) 8,847.60 91.56 193.89 3,872.11 3,829.71 -5,388.85 -3,617.65 6,026,509.81 541,064.07 0.96 6,403.12 2_MWD+IFR2+MS+Sag(3) 8,911.02 92.62 195.25 3,869.80 3,827.40 -5,450.19 -3,633.59 6,026,448.38 541,048.49 2.72 6,465.55 2_MWD+IFR2+MS+Sag(3) 8,973.68 89.82 195.43 3,868.47 3,826.07 -5,510.59 -3,650.16 6,026,387.88 541,032.29 4.48 6,527.40 2_MWD+IFR2+MS+Sag(3) 9,036.39 90.59 195.48 3,868.24 3,825.84 -5,571.03 -3,666.88 6,026,327.34 541,015.94 1.23 6,589.34 2_MWD+IFR2+MS+Sag(3) 9,099.51 90.26 195.67 3,867.78 3,825.38 -5,631.83 -3,683.82 6,026,266.45 540,999.36 0.60 6,651.70 2_MWD+IFR2+MS+Sag(3) 9,162.50 90.59 195.04 3,867.31 3,824.91 -5,692.57 -3,700.50 6,026,205.62 540,983.05 1.13 6,713.89 2_MWD+IFR2+MS+Sag(3) 9,225.20 92.32 195.06 3,865.72 3,823.32 -5,753.10 -3,716.78 6,026,145.00 540,967.14 2.76 6,775.72 2_MWD+IFR2+MS+Sag(3) 9,288.40 94.80 195.90 3,861.79 3,819.39 -5,813.89 -3,733.61 6,026,084.12 540,950.67 4.14 6,838.02 2_MWD+IFR2+MS+Sag(3) 9,351.05 96.22 196.96 3,855.78 3,813.38 -5,873.70 -3,751.25 6,026,024.21 540,933.40 2.82 6,899.77 2_MWD+IFR2+MS+Sag(3) 9,413.53 94.08 197.27 3,850.17 3,807.77 -5,933.17 -3,769.56 6,025,964.64 540,915.45 3.46 6,961.48 2_MWD+IFR2+MS+Sag(3) 9,476.20 90.72 197.22 3,847.54 3,805.14 -5,992.96 -3,788.12 6,025,904.74 540,897.25 5.36 7,023.59 2_MWD+IFR2+MS+Sag(3) 9,537.78 91.44 196.39 3,846.38 3,803.98 -6,051.90 -3,805.92 6,025,845.70 540,879.80 1.78 7,084.61 2_MWD+IFR2+MS+Sag(3) 9,601.88 91.56 197.20 3,844.71 3,802.31 -6,113.24 -3,824.43 6,025,784.25 540,861.66 1.28 7,148.12 2_MWD+IFR2+MS+Sag(3) 9,665.67 92.49 197.18 3,842.45 3,800.05 -6,174.14 -3,843.28 6,025,723.25 540,843.19 1.46 7,211.36 2_MWD+IFR2+MS+Sag(3) 9,728.33 92.93 195.41 3,839.49 3,797.09 -6,234.22 -3,860.84 6,025,663.07 540,825.99 2.91 7,273.31 2_MWD+IFR2+MS+Sag(3) 9,791.29 89.79 193.82 3,837.99 3,795.59 -6,295.11 -3,876.72 6,025,602.09 540,810.48 5.59 7,335.31 2_MWD+IFR2+MS+Sag(3) 9,853.73 90.58 194.55 3,837.79 3,795.39 -6,355.65 -3,892.02 6,025,541.47 540,795.54 1.72 7,396.75 2_MWD+IFR2+MS+Sag(3) 9,916.88 91.14 194.04 3,836.85 3,794.45 -6,416.84 -3,907.61 6,025,480.20 540,780.32 1.20 7,458.90 2_MWD+IFR2+MS+Sag(3) 9,980.02 91.70 194.07 3,835.28 3,792.88 -6,478.07 -3,922.94 6,025,418.88 540,765.36 0.89 7,520.99 2_MWD+IFR2+MS+Sag(3) 10,043.02 93.12 194.08 3,832.63 3,790.23 -6,539.12 -3,938.24 6,025,357.74 540,750.42 2.25 7,582.90 2_MWD+IFR2+MS+Sag(3) 10,105.63 92.11 191.52 3,829.77 3,787.37 -6,600.10 -3,952.10 6,025,296.68 540,736.93 4.39 7,644.15 2_MWD+IFR2+MS+Sag(3) 10,168.19 92.69 190.12 3,827.15 3,784.75 -6,661.50 -3,963.83 6,025,235.23 540,725.57 2.42 7,704.89 2_MWD+IFR2+MS+Sag(3) 10,230.67 91.80 189.02 3,824.71 3,782.31 -6,723.06 -3,974.21 6,025,173.61 540,715.56 2.26 7,765.22 2_MWD+IFR2+MS+Sag(3) 10,294.18 93.18 187.87 3,821.95 3,779.55 -6,785.82 -3,983.53 6,025,110.80 540,706.62 2.83 7,826.20 2_MWD+IFR2+MS+Sag(3) 10,357.19 91.56 186.95 3,819.34 3,776.94 -6,848.24 -3,991.65 6,025,048.33 540,698.88 2.96 7,886.39 2_MWD+IFR2+MS+Sag(3) 10,419.75 90.77 185.88 3,818.07 3,775.67 -6,910.40 -3,998.64 6,024,986.14 540,692.27 2.13 7,945.86 2_MWD+IFR2+MS+Sag(3) 10,482.99 90.27 185.13 3,817.50 3,775.10 -6,973.34 -4,004.70 6,024,923.17. 540,686.58 1.43 8,005.67 2_MWD+IFR2+MS+Sag(3) 10,545.28 90.95 185.52 3,816.83 3,774.43 -7,035.36 -4,010.48 6,024,861.12 540,681.17 1.26 8,064.51 2_MWD+IFR2+MS+Sag(3) 10,608.75 92.56 186.82 3,814.89 3,772.49 -7,098.43 -4,017.30 6,024,798.02 540,674.73 3.26 8,124.74 2_MWD+IFR2+MS+Sag(3) 10,671.48 93.11 186.02 3,811.79 3,769.39 -7,160.69 -4,024.31 6,024,735.73 540,668.10 1.55 8,184.32 2_MWD+IFR2+MS+Sag(3) 10,734.78 93.05 184.24 3,808.39 3,765.99 -7,223.64 -4,029.96 6,024,672.75 540,662.83 2.81 8,243.96 2_MWD+IFR2+MS+Sag(3) 10,797.51 92.37 184.66 3,805.42 3,763.02 -7,286.11 -4,034.82 6,024,610.25 540,658.34 1.27 8,302.84 2_MWD+IFR2+MS+Sag(3) 1/9/2018 6:42:35PM Page 6 COMPASS 5000.1 Build 81D • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: -`' zap` °S1n_., Sperry EDM-NORTH US+CANADA Survey Map Map Vertical r` �� MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,860.34 94.04 187.40 3,801.91 3,759.51 -7,348.49 -4,041.41 6,024,547.85 540,652.13 5.10 8,362.34 2_MWD+IFR2+MS+Sag(3) 10,923.23 92.97 187.59 3,798.06 3,755.66 -7,410.72 -4,049.59 6,024,485.57 540,644.32 1.73 8,422.38 2_MWD+IFR2+MS+Sag(3) 10,986.23 90.75 186.21 3,796.02 3,753.62 -7,473.23 -4,057.16 6,024,423.03 540,637.13 4.15 8,482.41 2_MWD+IFR2+MS+Sag(3) 11,049.03 90.95 187.17 3,795.08 3,752.68 -7,535.59 -4,064.47 6,024,360.62 540,630.19 1.56 8,542.21 2_MWD+IFR2+MS+Sag(3) 11,111.82 91.27 187.23 3,793.87 3,751.47 -7,597.88 -4,072.34 6,024,298.30 540,622.70 0.52 8,602.16 2_MWD+IFR2+MS+Sag(3) 11,174.01 91.51 189.18 3,792.36 3,749.96 -7,659.41 -4,081.21 6,024,236.72 540,614.20 3.16 8,661.84 2_MWD+IFR2+MS+Sag(3) 11,237.72 92.63 190.01 3,790.06 3,747.66 -7,722.19 -4,091.83 6,024,173.89 540,603.96 2.19 8,723.38 2_MWD+IFR2+MS+Sag(3) 11,300.42 91.99 190.08 3,787.53 3,745.13 -7,783.87 -4,102.75 6,024,112.14 540,593.41 1.03 8,784.05 2_MWD+IFR2+MS+Sag(3) 11,363.16 92.68 190.66 3,784.98 3,742.58 -7,845.54 -4,114.04 6,024,050.42 540,582.49 1.44 8,844.85 2_MWD+1FR2+MS+Sag(3) 11,426.43 92.86 190.92 3,781.92 3,739.52 -7,907.62 -4,125.87 6,023,988.28 540,571.04 0.50 8,906.26 2_MWD+IFR2+MS+Sag(3) 11,489.32 92.05 191.46 3,779.22 3,736.82 -7,969.25 -4,138.06 6,023,926.57 540,559.22 1.55 8,967.41 2_MWD+IFR2+MS+Sag(3) 11,552.29 91.05 191.44 3,777.52 3,735.12 -8,030.95 -4,150.56 6,023,864.81 540,547.09 1.59 9,028.74 2_MWD+IFR2+MS+Sag(3) 11,615.02 91.69 191.89 3,776.02 3,733.62 -8,092.36 -4,163.24 6,023,803.33 540,534.78 1.25 9,089.90 2_MWD+IFR2+MS+Sag(3) 11,677.73 92.01 192.81 3,774.00 3,731.60 -8,153.59 -4,176.64 6,023,742.03 540,521.75 1.55 9,151.18 2_MWD+IFR2+MS+Sag(3) 11,740.52 92.11 192.26 3,771.74 3,729.34 -8,214.84 -4,190.26 6,023,680.70 540,508.50 0.89 9,212.58 2_MWD+IFR2+MS+Sag(3) 11,803.29 92.13 191.92 3,769.42 3,727.02 -8,276.18 -4,203.40 6,023,619.29 540,495.73 0.54 9,273.85 2_MWD+IFR2+MS+Sag(3) 11,866.10 93.05 192.64 3,766.58 3,724.18 -8,337.49 -4,216.74 6,023,557.91 540,482.75 1.86 9,335.18 2_MWD+IFR2+MS+Sag(3) 11,928.89 92.98 191.90 3,763.28 3,720.88 -8,398.76 -4,230.07 6,023,496.57 540,469.80 1.18 9,396.47 2_MWD+IFR2+MS+Sag(3) 11,992.04 91.80 192.15 3,760.64 3,718.24 -8,460.47 -4,243.21 6,023,434.78 540,457.03 1.91 9,458.08 2_MWD+IFR2+MS+Sag(3) 12,054.18 90.12 192.18 3,759.60 3,717.20 -8,521.20 -4,256.31 6,023,373.98 540,444.30 2.70 9,518.79 2_MWD+IFR2+MS+Sag(3) 12,117.08 89.64 191.83 3,759.73 3,717.33 -8,582.73 -4,269.39 6,023,312.38 540,431.59 0.94 9,580.21 2_MWD+IFR2+MS+Sag(3) 12,180.43 89.20 192.67 3,760.37 3,717.97 -8,644.63 -4,282.83 6,023,250.41 540,418.52 1.50 9,642.12 2_MWD+IFR2+MS+Sag(3) 12,243.63 89.84 193.60 3,760.90 3,718.50 -8,706.17 -4,297.19 6,023,188.78 540,404.53 1.79 9,704.08 2_MWD+IFR2+MS+Sag(3) 12,305.81 93.01 195.03 3,759.36 3,716.96 -8,766.39 -4,312.56 6,023,128.48 540,389.53 5.59 9,765.26 2_MWD+IFR2+MS+Sag(3) 12,368.32 94.04 196.45 3,755.51 3,713.11 -8,826.44 -4,329.48 6,023,068.33 540,372.97 2.80 9,826.93 2_MWD+IFR2+MS+Sag(3) 12,431.50 94.72 197.34 3,750.69 3,708.29 -8,886.72 -4,347.79 6,023,007.95 540,355.02 1.77 9,889.38 2_MWD+IFR2+MS+Sag(3) 12,494.07 92.53 197.92 3,746.73 3,704.33 -8,946.23 -4,366.70 6,022,948.34 540,336.47 3.62 9,951.38 2_MWD+IFR2+MS+Sag(3) 12,557.58 91.37 198.30 3,744.57 3,702.17 -9,006.56 -4,386.43 6,022,887.90 540,317.11 1.92 10,014.46 2_MWD+IFR2+MS+Sag(3) 12,620.40 92.51 198.02 3,742.45 3,700.05 -9,066.21 -4,406.00 6,022,828.13 540,297.90 1.87 10,076.86 2_MWD+IFR2+MS+Sag(3) 12,683.60 92.05 200.10 3,739.93 3,697.53 -9,125.90 -4,426.62 6,022,768.33 540,277.64 3.37 10,139.73 2_MWD+IFR2+MS+Sag(3) 12,746.31 93.37 200.79 3,736.97 3,694.57 -9,184.59 -4,448.50 6,022,709.51 540,256.11 2.37 10,202.21 2_MWD+IFR2+MS+Sag(3) 12,809.09 93.67 201.17 3,733.11 3,690.71 -9,243.10 -4,470.93 6,022,650.88 540,234.03 0.77 10,264.76 2_MWD+IFR2+MS+Sag(3) 12,871.40 93.29 200.85 3,729.33 3,686.93 -9,301.16 -4,493.23 6,022,592.69 540,212.09 0.80 10,326.84 2_MWD+IFR2+MS+Sag(3) 12,934.93 93.79 201.52 3,725.41 3,683.01 -9,360.28 -4,516.15 6,022,533.44 540,189.53 1.31 10,390.15 2_MWD+IFR2+MS+Sag(3) 12,997.73 92.60 201.47 3,721.91 3,679.51 -9,418.62 -4,539.12 6,022,474.97 540,166.91 1.90 10,452.76 2_MWD+IFR2+MS+Sag(3) 13,060.85 90.99 200.64 3,719.93 3,677.53 -9,477.49 -4,561.79 6,022,415.96 540,144.60 2.87 10,515.74 2_MWD+IFR2+MS+Sag(3) 13,123.60 89.82 199.70 3,719.49 3,677.09 -9,536.39 -4,583.42 6,022,356.94 540,123.32 2.39 10,578.31 2_MWD+IFR2+MS+Sag(3) 13,186.40 89.53 198.56 3,719.84 3,677.44 -9,595.72 -4,604.00 6,022,297.49 540,103.10 1.87 10,640.83 2_MWD+IFR2+MS+Sag(3) 13,249.39 91.58 198.86 3,719.23 3,676.83 -9,655.38 -4,624.21 6,022,237.72 540,083.26 3.29 10,703.50 2_MWD+IFR2+MS+Sag(3) 13,312.33 92.18 198.04 3,717.17 3,674.77 -9,715.05 -4,644.11 6,022,177.94 540,063.71 1.61 10,766.06 2_MWD+IFR2+MS+Sag(3) 1/9/2018 6:42:35PM Page 7 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 n Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA I Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,375.22 91.06 197.46 3,715.39 3,672.99 -9,774.92 -4,663.28 6,022,117.96 540,044.91 2.01 10,828.49 2_MWD+IFR2+MS+Sag(3) 13,438.09 91.01 195.77 3,714.25 3,671.85 -9,835.15 -4,681.25 6,022,057.63 540,027.30 2.69 10,890.76 2_MWD+IFR2+MS+Sag(3) 13,500.82 91.38 193.56 3,712.95 3,670.55 -9,895.82 -4,697.13 6,021,996.87 540,011.79 3.57 10,952.56 2_MWD+IFR2+MS+Sag(3) 13,563.68 92.06 193.43 3,711.06 3,668.66 -9,956.92 -4,711.79 6,021,935.69 539,997.49 1.10 11,014.25 2_MWD+IFR2+MS+Sag(3) 13,626.85 94.17 192.52 3,707.63 3,665.23 -10,018.38 -4,725.95 6,021,874.15 539,983.70 3.64 11,076.06 2_MWD+IFR2+MS+Sag(3) 13,689.12 94.59 191.63 3,702.87 3,660.47 -10,079.09 -4,738.94 6,021,813.37 539,971.08 1.58 11,136.70 2_MWD+IFR2+MS+Sag(3) 13,752.47 91.55 190.34 3,699.48 3,657.08 -10,141.19 -4,750.99 6,021,751.21 539,959.40 5.21 11,198.21 2_MWD+IFR2+MS+Sag(3) 13,815.30 89.86 190.81 3,698.70 3,656.30 -10,202.94 -4,762.52 6,021,689.39 539,948.24 2.79 11,259.19 2_MWD+IFR2+MS+Sag(3) 13,878.27 91.95 191.34 3,697.71 3,655.31 -10,264.73 -4,774.62 6,021,627.54 539,936.52 3.42 11,320.44 2_MWD+IFR2+MS+Sag(3) 13,940.65 90.31 189.88 3,696.48 3,654.08 -10,326.03 -4,786.10 6,021,566.18 539,925.41 3.52 11,380.99 2_MWD+IFR2+MS+Sag(3) 13,969.02 89.70 189.23 3,696.48 3,654.08 -10,354.00 -4,790.81 6,021,538.18 539,920.87 3.14 11,408.41 2_MWD+IFR2+MS+Sag(3) 14,000.00 89.70 189.23 3,696.64 3,654.24 -10,384.58 -4,795.78 6,021,507.58 539,916.08 0.00 11,438.30 PROJECTED to TD mitchell.laird@halliburton.com Checked By: 2018.01.0915:49:51-0900' Approved By: Michael Calkins Date: 1/9/2018 1/9/2018 6:42:35PM Page 8 COMPASS 5000.1 Build 81D Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. MP L-52 Date Run 31-Dec-17 County State Alaska Supv. J.Lott/S.Barber CASING RECORD surface *1 TD 6,289.00 Shoe Depth: 6,280.00 PBTD: 6,156.00 No.Jts.Delivered 153 No.Jts.Run 153 No.Jts.Returned Ftg.Delivered 6,280.00 Ftg.Run 6,283.00 Ftg.Returned Length Measurements W/O Threads Ftg.Cut Jt. 29.00 Ftg.Balance 29.00 RKB 26.50 RKB to BHF 27.50 RKB to CHF RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Shoe 103/4 40.0 L-80 DWC/C Antelope 1.60 6,280.00 6,278.40 2 CSG JT 9 5/8 40.0 1-80 DWC/C TSA 79.47 6,278.40 6,798.99 1 FLOAT COLLAR 103/4 40.0 I-80 DWC/C Antelope 1.30 6,198.99 6,179.69 1 CSG JT 9 5/8 40.0 L-80 DWC/C TSA 39.67 6,197.69 6,158.02 1 BAFLADPT 103/4 40.0 L-80 DWC/C HES 1.58 6,158.02 6,156.44 90 CSG JT 9 5/8 40.0 L-80 DWC/C 3,649.89 6,156.44 2,506.55 1 STAGE TOOL 103/4 40.0 L-80 DWC/C HES 3.09 2,506.55 2,503.46 62 CSG JT 9 5/8 40.0 L-80 DWC 2,477.79 2,503.46 0 Csg Wt.On Hook: 175 Type Float Collar: Conventional No.Hrs to Run: 18.5 Csg Wt.On Slips: 140 Type of Shoe: Conventional Bull Nose Casing Crew: WOT Rotate Csg Yes X No Recip Csg X Yes No 6 Ft.Min. 9.2 PPG Fluid Description: SPUD MUD Liner hanger Info(Make/Model): Liner top Packer?: _Yes_No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: 2x solid body centralizers on 1st jt(10'from ea end),lx middle of 2nd-4th jt. 22 bow springs every jt from#5-#25. 11 bow spring centralizers every other jt from#27 to#47. 6 bow springs on 3 jts above and below stg tool @ 2500'MD. Total solid body centralizers=4 Total bow spring centralizers=39. CEMENTING REPORT Shoe @ 6280 FC @ 6,198.00 Top of Liner Preflush(Spacer) Type: TUNNED SPACER III Density(ppg) 10.5 Volume pumped(BBLs) 60 ',, Lead Slurry Type: ExtendaCem Sacks: 458 Yield: 2.47 Density(ppg) 11.7 Volume pumped(BBLs) 209 Mixing/Pumping Rate(bpm): 6 Tail Slurry W Type: SwftCem Sacks: 397 Yield: 1.16 F. Density(ppg) 15.8 Volume pumped(BBLs) 82 Mixing/Pumping Rate(bpm): 3 F Post Flush(Spacer) 2 Type: Density(ppg) Rate(bpm): Volume: LL Displacement: Type: Spud Mud Density(ppg) 9.2 Rate(bpm): 6 Volume(actual/calculated): 467/467 FCP(psi): 750 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1250 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during iob 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 11 Cement In Place At: 13:40 Date: 12/31/2017 Estimated TOC: 2,506 Method Used To Determine TOC: Returns to surface Stage Collar @ 2506 Type HES Closure OK Y Preflush(Spacer) Type: TUNNED SPACER III Density(ppg) 10.5 Volume pumped(BBLs) 60 Lead Slurry Type: Perm L Sacks: 475 Yield: 4.33 Density(ppg) 10.7 Volume pumped(BBLs) 300 Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: Premium G Sacks: 270 Yield: 1.17 N Density(ppg) 15.8 Volume pumped(BBLs) 56 Mixing/Pumping Rate(bpm): 2.3 °z Post Flush(Spacer) u Type: Density(ppg) Rate(bpm): Volume: W H Displacement: Type: Spud Mud Density(ppg) 9.2 Rate(bpm): 6 Volume(actual/calculated): 190/190 FCP(psi): 710 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1200 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: 222 Cement In Place At: 0:30 Date: 1/1/2018 Estimated TOC: 0 Method Used To Determine TOC: Visual Post Job Calculations: Calculated Cmt Vol @ 0%excess: 298.9 Total Volume cmt Pumped: 565 Cmt returned to surface: 233 Calculated cement left in wellbore: 332 OH volume Calculated: 350.3 OH volume actual: 332 Actual%Washout: www.wellez.net WellEz Information Management LLC ver_102716bf • • 217174 111 Seth Nolan Hilcorp Alaska, LLC 2 9 0 1 1 AK_GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 '' Tele: 907 777-8337 Ilil..1-1 :tlitaa..LTA, Fax: 907 777-8510 E-mail: doudean@hilcorp.com JAN 3 0 2018 DATE: 01/12/2018 OGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 DATA LOGGED eiv Anchorage, AK 99501 MKK.BE D1 g . BENDER DATA TRANSMITTAL MPU L-52 Prints: ROP DGR ABG EWR ADR Horizontal Presentation MD DGR EWR ADR Invert Section TVD CD: Final Well Data Log Viewers 1/17/2018 6:01 PM File folder CGM 1/17/2018 6:01 PM File folder Definitive Survey 1/17/2018 6:01 PM File folder EMF 1/17/2018 6:01 PM File folder LAS 1/17/2018 6:01 PM File folder PDF 1/17/2018 6:01 PM File folder TIFF 1/17/2018 6:01 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: c../ Date: im le, `e�4"-at 1 • L-cZ Pro Z1 7 I 74.0 Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> ' T7'Kari i�Z3)1$ Sent: Tuesday,January 23, 2018 10:27 AM To: Wallace, Chris D (DOA); Alaska NS - Milne -Wellsite Supervisors Cc: Darci Horner - (C); Regg,James B (DOA); Paul Chan; Brooks, Phoebe L(DOA);Joe Engel Subject: MPL-52 (PTD#2171740) Ready for Injection Attachments: MIT MPU L-52 1-18-18.xlsx; MPU L-52 - Definitive Survey.pdf; MPU L-52 Schematic 1.23.2017_Draft.doc • All, Milne point water injector MPL-52 (PTD#2171740) was recently drilled and completed at Milne Point.The well had a passing pre injection MIT-IA on the rig to 3000 psi on 1-18-18. MIT form is attached for reference. Deviation survey and schematic also attached.The well is ready to put on injection for stabilization and compliance testing. Plan Forward—Operations 1) Place well on injection. Use caution, annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Cernerpoint:Drive,Suite 1400 I Anchorage,AK 99503 1 • • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(Stalaska.aov: AOGCC.Insoectors(malaska.aov. phoebe.brooks(talaska.aov chris.wallace(c]]]dalaska.aov OPERATOR: Hilcorp Alaska,LLC '?e 1 Z31 t$ FIELD/UNIT/PAD: Milne Point/MPU/L PAD C 1 DATE: 01/18/18 OPERATOR REP: James Lott AOGCC REP: Well L-52 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2171740 ' Type Inj N " Tubing 0 0 0 0 Type Test P Packer TVD 3,945• / BBL Pump 3.7 - IA 0 3050 - 3000 � 3000+ Interval O Test psi 3000 ' BBL Return 3.4 , OA 0 0 0 0 Result P - • Notes: Pre Injection MIT prior to Rig Demobilizing.Witness waved by Guy Cook. •-•- Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA - Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial. 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest . Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA - Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) • N=Not Injecting Form 10-426(Revised 01/2017) MIT MPU L-52 1-18-18 11 • i Milne Well: MPU L-52Unit SCHEMATIC Last Completed: rt;h�„r,a.alaska,la,c PTD: 2171740 KB Elev.:42.4'/GL Elev.:15.1' OPEN HOLE/CEMENT DETAIL 16” 270 ft3 16" 9-5/8" Stg 1-1606 ft3/Stg 2 2174 ft3 4-1/2" Cementless Injection Liner in 8.5"hole t • CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-53/Weld N/A Surface 107' N/A 9-5/8" Surface 40/L-80/DWC 6.151 Surface 6,350' 0.0383 4-1/2" Liner 13.5/L-80/Hydril 625 3.920 6,200' 13,779' 0.0149 hTUBING DETAIL 4-1/2" Tubing 12.6/L-80/TXP-SR 3.833 Surf 6,200' 0.0152 WELL INCLINATION DETAIL g{+ KOP @ 450' Max Hole Angle=92 deg JEWELRY DETAIL No. Top MD Item ID if NI, Upper Completion 1 5,731' 4.5"XN Nipple,3.725"No-Go,3.813"Packing Bore 3.725" a� ," Lower Completion 2 6,030' Baker Liner Hanger/Liner Top Packer 6.1" ' 3 See Below 4-1/2"13.5#/ft Weatherford ICDS with Sliding Sleeve 4 See Below 5-1/2"17#/ft Swell Packers 41/2" • 5 13,923' 4-1/2"Shoe 6 ,. Y' a tam 1 p 2 4 ICD DETAIL SWELL PACKER DETAIL Om No Depth ICD Detail Top(MD) Btm(MD) 95/8"41 TBD 4-1/2"13.5#Hyd 625 BxP,WOT ICD w/Sliding Sleeve TBD TBD I. 2 TBD 4-1/2"13.5#Hyd 625 BxP,WOT ICD w/Sliding Sleeve TBD TBD 3 TBD 4-1/2"13.5#Hyd 625 BxP,WOT ICD w/Sliding Sleeve TBD TBD 4 TBD 4-1/2"13.5#Hyd 625 BxP,WOT ICD w/Sliding Sleeve TBD TBD 5 TBD 4-1/2"13.5#Hyd 625 BxP,WOT ICD w/Sliding Sleeve TBD TBD ' 6 TBD 4-1/2"13.5#Hyd 625 BxP,WOT ICD w/Sliding Sleeve TBD TBD 7 TBD 4-1/2"13.5#Hyd 625 BxP,WOT ICD w/Sliding Sleeve TBD TBD I See 34 ' ICD/Svbeil Pkr Detail 4-1/2" GENERAL WELL INFO API:50-029-23590-00-00 Completion Date:TBD 5 TD=13,###(MD)/TD=3,#4:144(TVD) PBTD=13,###(MD)/PBTD=3,4444#(TVD) Revised By:WLR 1/23/201 • • Hilcorp Alaska, LLC Milne Point MPtLPad MPU L-52 50-029-23590-00 Definitive Survey Report 09 January, 2018 I h, hh, am, Sperry Dr#(BEng • . Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 j Project: Milne Point TVD Reference: MPU.L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB©42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA Project Milne Point,ACT,MILNE POINT Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU L-52 Well Position +N/-S 0.00 usft Northing: 6,031,919.76 usft Latitude: 70°29'53.079 N +E/-W 0.00 usft Easting: 544,648.93 usft Longitude: 149°38'5.523 W Position Uncertainty 0.00 usft Wellhead Elevation: 42.40 usft Ground Level: 15.10 usft Wellbore MPU L-52 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BG G M 2017 12/29/2017 17.37 81.03 57,490 Design MPU L-52 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.30 Vertical Section: Depth From(TVD) +N/-S +E(-W Direction (usft) (usft) (usft) (0) 27.30 0.00 0.00 204.46 Survey Program Date 1/9/2018 I From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 75.00 717.00 SDI Gyro Surveys(MPU L-52) 2_Gyro-NS-GC_Drill collar H029Ga:North seeking single shot in drill collar 12/26/2017 786.77 6,248.74 MWD+IFR2+MS+sag(1)(MPU L-52) 2_MWD+IFR2+MS+Sag A013Mb:IIFR dec&multi-station analysis+sag 12/26/2017 6,330.47 13,969.02 MWD+IFR2+MS+Sag(2)(MPU L-52) 2_MWD+IFR2+MS+Sag A013Mb:IIFR dec&multi-station analysis+sag 01/05/2018 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100'') ,, (ft) Survey Tool Name 27.30 0.00 0.00 27.30 -15.10 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 UNDEFINED 75.00 0.60 159.92 75.00 32.60 -0.23 0.09 6,031,919.53 544,649.02 1.26 0.18 2_Gyro-NS-GC Drillcollar(1) 150.00 0.71 161.18 149.99 107.59 -1.04 0.37 6,031,918.72 544,649.31 0.15 0.80 2 Gyro-NS-GC_Drillcollar(1) 225.00 0.88 161.18 224.99 182.59 -2.03 0.71 6,031,917.74 544,649.65 0.23 1.55 2_Gyro-NS-GC_Drillcollar(1) 300.00 1.13 163.13 299.98 257.58 -3.28 1.11 6,031,916.49 544,650.06 0.34 2.53 2 Gyro-NS-GC_Drillcollar(1) 346.00 1.11 166.45 345.97 303.57 -4.15 1.34 6,031,915.62 544,650.30 0.15 3.22 2_Gyro-NS-GC Drillcollar(1) 406.00 1.26 176.99 405.95 363.55 -5.37 1.51 6,031,914.40 544,650.48 0.44 4.26 2 Gyro-NS-GC Drillcollar(1) 468.00 1.40 206.85 467.94 425.54 -6.73 1.21 6,031,913.04 544,650.18 1.13 5.62 2 Gyro-NS-GC Drillcollar(1) 531.00 1.82 214.70 530.91 488.51 -8.24 0.29 6,031,911.53 544,649.27 0.75 7.38 2 Gyro-NS-GC Drillcollar(1) 593.00 2.73 234.92 592.86 550.46 -9.90 -1.48 6,031,909.86 544,647.51 1.94 9.62 2 Gyro-NS-GC Drillcollar(1) 654.00 4.64 254.67 653.74 611.34 -11.38 -5.05 6,031,908.35 544,643.95 3.72 12.45 2_Gyro-NS-GC_Drill collar(1) 717.00 6.16 259.19 716.46 674.06 -12.69 -10.83 6,031,907.01 544,638.18 2.50 16.03 2_Gyro-NS-GC_Drill collar(1) 1/9/2018 6:42:35PM Page 2 COMPASS 5000.1 Build 81D • • . Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 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) (°1100) (ft) Survey Tool Name 786.77 8.20 257.42 785.68 743.28 -14.48 -19.36 6,031,905.17 544,629.66 2.94 21.19 2_MWD+IFR2+MS+Sag(2) 847.05 10.80 258.31 845.12 802.72 -16.56 -29.09 6,031,903.03 544,619.95 4.32 27.12 2_MWD+IFR2+MS+Sag(2) 911.77 14.61 253.34 908.25 865.85 -20.13 -42.85 6,031,899.38 544,606.21 6.12 36.06 2_MWD+IFR2+MS+Sag(2) 973.25 16.72 248.48 967.45 925.05 -25.60 -58.51 6,031,893.82 544,590.58 4.04 47.52 2_MWD+IFR2+MS+Sag(2) 1,037.65 20.74 247.11 1,028.42 986.02 -33.43 -77.64 6,031,885.86 544,571.50 6.28 62.58 2_MWD+IFR2+MS+Sag(2) 1,100.75 25.91 244.98 1,086.35 1,043.95 -43.62 -100.44 6,031,875.55 544,548.76 8.30 81.29 2_MWD+IFR2+MS+Sag(2) 1,163.40 27.71 242.73 1,142.26 1,099.86 -56.08 -125.79 6,031,862.93 544,523.49 3.30 103.13 2_MWD+IFR2+MS+Sag(2) 1,226.57 30.12 244.06 1,197.55 1,155.15 -69.74 -153.11 6,031,849.10 544,496.26 3.95 126.88 2_MWD+IFR2+MS+Sag(2) 1,289.01 34.44 244.80 1,250.33 1,207.93 -84.12 -183.18 6,031,834.55 544,466.27 6.95 152.42 2_MWD+IFR2+MS+Sag(2) 1,352.70 37.85 243.46 1,301.76 1,259.36 -100.53 -216.97 6,031,817.94 544,432.59 5.50 181.34 2_MWD+IFR2+MS+Sag(2) 1,415.15 41.25 240.78 1,349.91 1,307.51 -119.14 -252.09 6,031,799.11 544,397.58 6.09 212.83 2_MWD+IFR2+MS+Sag(2) 1,477.98 43.43 238.88 1,396.35 1,353.95 -140.42 -288.67 6,031,777.62 544,361.14 4.02 247.34 2_MWD+IFR2+MS+Sag(2) 1,541.09 45.53 236.73 1,441.37 1,398.97 -163.99 -326.07 6,031,753.83 544,323.88 4.09 284.28 2_MWD+IFR2+MS+Sag(2) 1,603.32 45.31 234.43 1,485.06 1,442.66 -189.04 -362.63 6,031,728.56 544,287.48 2.66 322.22 2_MWD+IFR2+MS+Sag(2) 1,666.79 48.90 232.08 1,528.25 1,485.85 -216.87 -399.86 6,031,700.51 544,250.42 6.27 362.97 2_MWD+IFR2+MS+Sag(2) 1,728.33 50.74 231,97 1,567.96 1,525.56 -245.80 -436.92 6,031,671.36 544,213.53 2.99 404.65 2_MWD+IFR2+MS+Sag(2) 1,791.85 52.74 231.53 1,607.29 1,564.89 -276.68 -476.09 6,031,640.25 544,174.56 3.20 448.98 2_MVyD+IFR2+MS+Sag(2) 1,854.81 54.30 230.89 1,644.72 1,602.32 -308.40 -515.54 6,031,608.30 544,135.30 2.61 494.18 2_MWD+IFR2+MS+Sag(2) 1,917.09 53.98 230.98 1,681.21 1,638.81 -340.21 -554.73 6,031,576.26 544,096.30 0.53 539.36 2_MWD+IFR2+MS+Sag(2) 1,981.02 55.14 230.36 1,718.27 1,675.87 -373.22 -595.02 6,031,543.01 544,056.22 1.98 586.09 2_MWD+IFR2+MS+Sag(2) 2,043.82 54.30 230.94 1,754.55 1,712.15 -405.72 -634.66 6,031,510.27 544,016.78 1.54 632.10 2_MWD+IFR2+MS+Sag(2) 2,106.55 53.63 231.18 1,791.45 1,749.05 -437.61 -674.12 6,031,478.16 543,977.52 1.11 677.45 2_MWD+IFR2+MS+Sag(2) 2,168.92 52.90 230.13 1,828.75 1,786.35 -469.29 -712.77 6,031,446.24 543,939.06 1.79 722.30 2_MWD+IFR2+MS+Sag(2) 2,232.38 54.96 229.95 1,866.11 1,823.71 -502.24 -752.09 6,031,413.07 543,899.95 3.25 768.57 2_MWD+IFR2+MS+Sag(2) 2,295.58 52.55 230.64 1,903.48 1,861.08 -534.80 -791.29 6,031,380.27 543,860.94 3.91 814.44 2_MWD+IFR2+MS+Sag(2) 2,358.37 53.68 230.15 1,941.17 1,898.77 -566.81 -829.99 6,031,348.03 543,822.45 1.90 859.61 2_MWD+IFR2+MS+Sag(2) 2,420.37 54.40 230.59 1,977.57 1,935.17 -598.82 -868.64 6,031,315.79 543,783.99 1.30 904.74 2_MWD+IFR2+MS+Sag(2) 2,484.40 53.22 231.42 2,015.38 1,972.98 -631.34 -908.80 6,031,283.03 543,744.03 2.12 950.97 2_MWD+IFR2+MS+Sag(2) 2,547.18 55.15 230.61 2,052.12 2,009.72 -663.37 -948.36 6,031,250.77 543,704.66 3.25 996.51 2_MWD+IFR2+MS+Sag(2) 2,610.41 54.12 230.73 2,088.71 2,046.31 -696.05 -988.25 6,031,217.85 543,664.98 1.64 1,042.77 2_MWD+IFR2+MS+Sag(2) 2,673.23 54.04 231.62 2,125.57 2,083.17 -727.94 -1,027.88 6,031,185.73 543,625.54 1.15 1,088.21 2_MWD+IFR2+MS+Sag(2) 2,735.88 55.68 231.34 2,161.62 2,119.22 -759.85 -1,067.96 6,031,153.58 543,585.66 2.64 1,133.85 2_MWD+IFR2+MS+Sag(2) 2,798.92 54.86 231.22 2,197.54 2,155.14 -792.26 -1,108.38 6,031,120.94 543,545.43 1.31 1,180.09 2_MWD+IFR2+MS+Sag(2) 2,861.66 53.78 231.97 2,234.13 2,191.73 -823.92 -1,148.32 6,031,089.04 543,505.69 1.98 1,225.44 2_MWD+IFR2+MS+Sag(2) 2,924.58 56.22 231.39 2,270.22 2,227.82 -855.88 -1,188,75 6,031,056.84 543,465.46 3.95 1,271.27 2_MWD+IFR2+MS+Sag(2) 2,987.43 55.75 231.33 2,305.38 2,262.98 -888.41 -1,229.44 6,031,024.07 543,424.97 0.75 1,317.73 2_MWD+IFR2+MS+Sag(2) 3,050.34 54.96 231.88 2,341.14 2,298.74 -920.55 -1,270.00 6,030,991.69 543,384.60 1.45 1,363.79 2_MWD+IFR2+MS+Sag(2) 3,113.47 53.99 232.50 2,377.82 2,335.42 -952.05 -1,310.59 6,030,959.95 543,344.21 1.73 1,409.26 2_MWD+IFR2+MS+Sag(2) 3,176.07 52.38 232.39 2,415.33 2,372.93 -982.60 -1,350.32 6,030,929.17 543,304.67 2.58 1,453.52 2_MWD+IFR2+MS+Sag(2) 3,239.27 54.46 231.78 2,453.00 2,410.60 -1,013.78 -1,390.36 6,030,897.74 543,264.83 3.38 1,498.48 2_MWD+IFR2+MS+Sag(2) 1/9/2018 6:42:35PM Page 3 COMPASS 5000.1 Build 81D • • Halliburton • Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 3,302.28 53.52 231,69 2,490.04 2,447.64 -1,045.35 -1,430.37 6,030,865.94 543,225.00 1.50 1,543.79 2_MWD+IFR2+MS+Sag(2) • 3,365.20 54.84 231.69 2,526.86 2,484.46 -1,076.97 -1,470.41 6,030,834.08 543,185.16 2.10 1,589.15 2_MWD+IFR2+MS+Sag(2) 3,428.17 53.64 231.84 2,563.66 2,521.26 -1,108.60 -1,510.54 6,030,802.22 543,145.22 1.92 1,634.55 2_MWD+IFR2+MS+Sag(2) 3,490.87 55.65 230.54 2,599.94 2,557.54 -1,140.65 -1,550.38 6,030,769.93 543,105.58 3.62 1,680.23 2_MWD+IFR2+MS+Sag(2) 3,554.28 55.11 231.19 2,635.97 2,593.57 -1,173.59 -1,590.86 6,030,736.75 543,065.31 1.20 1,726.96 2_MWD+IFR2+MS+Sag(2) 3,616.47 54.01 231.43 2,672.03 2,629.63 -1,205.26 -1,630.40 6,030,704.85 543,025.95 1.80 1,772.17 2_MWD+IFR2+MS+Sag(2) 3,679.83 52.20 231.05 2,710.06 2,667.66 -1,236.98 -1,669.92 6,030,672.89 542,986.64 2.90 1,817.40 2_MWD+IFR2+MS+Sag(2) 3,742.79 53.72 231.36 2,747.99 2,705.59 -1,268.46 -1,709.08 6,030,641.18 542,947.66 2.45 1,862.28 2_MWD+IFR2+MS+Sag(2) 3,805.60 52.45 231.85 2,785.71 2,743.31 -1,299.65 -1,748.44 6,030,609.75 542,908.50 2.12 1,906.97 2_MWD+IFR2+MS+Sag(2) 3,869.01 55.29 231.85 2,823.10 2,780.70 -1,331.29 -1,788.71 6,030,577.88 542,868.42 4.48 1,952.43 2_MWD+IFR2+MS+Sag(2) 3,931.82 55.02 231.92 2,858.98 2,816.58 -1,363.11 -1,829.27 6,030,545.82 542,828.06 0.44 1,998.19 2_MWD+IFR2+MS+Sag(2) 3,994.48 54.16 232.63 2,895.29 2,852.89 -1,394.35 -1,869.66 6,030,514.34 542,787.86 1.65 2,043.36 2_MWD+IFR2+MS+Sag(2) 4,057.41 54.22 232.42 2,932.11 2,889.71 -1,425.40 -1,910.16 6,030,483.05 542,747.55 0.29 2,088.39 2_MWD+IFR2+MS+Sag(2) 4,120.30 54.04 232.98 2,968.96 2,926.56 -1,456.29 -1,950.70 6,030,451.92 542,707.20 0.78 2,133.29 2_MWD+IFR2+MS+Sag(2) 4,183.11 53,44 233.06 3,006.11 2,963.71 -1,486.75 -1,991.16 6,030,421.22 542,666.93 0.96 2,177.77 2_MWD+IFR2+MS+Sag(2) 4,245.92 55.65 231.54 3,042.54 3,000.14 -1,518.04 -2,031.63 6,030,389.69 542,626.65 4.03 2,223,01 2_MWD+IFR2+MS+Sag(2) 4,308.94 55.65 231.04 3,078.10 3,035.70 -1,550.58 -2,072.23 6,030,356.91 542,586.25 0.66 2,269.44 2_MWD+IFR2+MS+Sag(2) 4,371.99 56.57 231.25 3,113.26 3,070.86 -1,583.42 -2,112.99 6,030,323.84 542,545.70 1.49 2,316.20 2_MWD+IFR2+MS+Sag(2) 4,434.76 56.27 231.63 3,147.98 3,105.58 -1,616.01 -2,153.88 6,030,291.00 542,505.01 0.69 2,362.81 2_MWD+IFR2+MS+Sag(2) 4,497.74 55.05 230.80 3,183.50 3,141.10 -1,648.58 -2,194.42 6,030,258.19 542,464.67 2.22 2,409.24 2_MWD+IFR2+MS+Sag(2) 4,560.90 55,18 230.85 3,219.63 3,177.23 -1,681.31 -2,234.58 6,030,225.22 542,424.71 0.22 2,455.66 2_MWD+IFR2+MS+Sag(2) 4,622.00 53,16 229.97 3,255.39 3,212.99 -1,712.88 -2,272.76 6,030,193.43 542,386.73 3.51 2,500.20 2_MWD+IFR2+MS+Sag(2) 4,686.29 52.78 229.53 3,294.11 3,251.71 -1,746.04 -2,311.93 . 6,030,160.04 542,347,76 0.80 2,546.60 2_MWD+IFR2+MS+Sag(2) 4,748.93 52.41 229.50 3,332.16 3,289.76 -1,778.34 -2,349.77 6,030,127.51 542,310.11 0.59 2,591.68 2_MWD+IFR2+MS+Sag(2) 4,811.94 52.90 229.21 3,370.38 3,327.98 -1,810.97 -2,387.78 6,030,094.66 542,272.30 0.86 2,637.12 2_MWD+IFR2+MS+Sag(2) 4,874.19 53.23 229.84 3,407,79 3,365.39 -1,843.27 -2,425.63 6,030,062.13 542,234.65 0.97 2,682.19 2_MWD+IFR2+MS+Sag(2) 4,937.51 53.23 230.06 3,445,69 3,403.29 -1,875.91 -2,464.46 6,030,029.27 542,196.03 0.28 2,727.97 2_MWD+IFR2+MS+Sag(2) 4,999.32 53.07 230.65 3,482.76 3,440.36 -1,907.46 -2,502.54 6,029,997.48 542,158.13 0.81 2,772.47 2_MWD+IFR2+MS+Sag(2) 5,061.98 52.82 231.30 3,520.52 3,478.12 -1,938.95 -2,541.39 6,029,965.77 542,119.48 0.92 2,817.21 2_MWD+IFR2+MS+Sag(2) 5,125.66 52.52 231.72 3,559.14 3,516.74 -1,970.47 -2,581.02 6,029,934.02 542,080.04 0.70 2,862.31 2_MWD+IFR2+MS+Sag(2) 5,188.44 54.66 229.76 3,596.40 3,554.00 -2,002.44 -2,620.13 6,029,901.81 542,041.13 4.23 2,907.61 2_MWD+IFR2+MS+Sag(2) 5,251.39 56.59 228.30 3,631.94 3,589.54 -2,036.51 -2,659.35 6,029,867.51 542,002.12 3.61 2,954.86 2_MWD+IFR2+MS+Sag(2) 5,314.40 58.69 225.29 3,665.67 3,623.27 -2,072.95 -2,698.13 6,029,830.84 541,963.57 5.23 3,004.09 2_MWD+IFR2+MS+Sag(2) 5,377.23 60.24 222.07 3,697.60 3,655.20 -2,112.09 -2,735.48 6,029,791.48 541,926.45 5.06 3,055.18 2_MWD+IFR2+MS+Sag(2) 5,440.28 60.98 218.99 3,728.55 3,686.15 -2,153.84 -2,771.17 6,029,749.52 541,891.01 4.41 3,107.96 2_MWD+IFR2+MS+Sag(2) 5,502.62 61.96 216.92 3,758.32 3,715.92 -2,197.03 -2,804.85 6,029,706.14 541,857.60 3.31 3,161.22 2_MWD+IFR2+MS+Sag(2) 5,566.14 63.80 214.08 3,787.28 3,744.88 -2,243.05 -2,837.67 6,029,659.92 541,825.06 4.92 3,216.70 2_MWD+IFR2+MS+Sag(2) 5,628.93 67.10 210.91 3,813.37 3,770.97 -2,291.22 -2,868.32 6,029,611.58 541,794.70 6.98 3,273.24 2_MWD+IFR2+MS+Sag(2) 5,691.74 68.93 208.14 3,836.89 3,794.49 -2,341.89 -2,897.01 6,029,560.73 541,766.32 5.02 3,331.24 2_MWD+IFR2+MS+Sag(2) 5,754,87 70.82 205.26 3,858.61 3,816.21 -2,394.84 -2,923.63 6,029,507.63 541,740.02 5.23 3,390.46 2_MWD+IFR2+MS+Sag(2) 1/9/2018 6:42:35PM Page 4 COMPASS 5000.1 Build 81D III • Halliburton Definitive Survey Report . Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft • Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 c Database: Sperry EDM-NORTH US+CANADA Survey 4)4.0 rub 3(lZc t 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 • 14.(i‘.-, 5,817.35 74.78 201.26 3,877.09 3,834,69 -2,449.66 -2,947.17 6,029,452.68 541,716.81 8.81 3,450.11 2_MWD+IFR2+MS+Sag(2) M.D 5,878.27 76.15 199.10 3,892.38 3,849.98 -2,505.01 -2,967.51 6,029,397.21 541,696.81 4.10 3,508.91 2 MWD+IFR2+MS+Sag(2) 600/Ft- 5,943.62 76.92 197.76 3,907.60 3,865.20 -2,565.30 -2,987.60 6,029,336.81 541,677.08 2.32 3,572.11 2W MD+IFR2+MS+Sag(2) WWWW 6,006.56 78.60 197.03 3,920. 3,878.54 -2,624.00 -3,005.99 6,029,278.01 541,659.05 2.90 3,633.15 2_MD+IFR2+MS+Sag(2) 1•_ W 6,069.46 81.39 197.96 3,931.87 3,889.47 -2,683.07 -3,024.61 6,029,218.83 541,640.79 4.67 3,694.63 2 MWD+IFR2+MS+Sag(2) 6,132.54 82.93 196.97 3,940.47 3,898.07 -2,742.68 -3,043.36 6,029,159.12 541,622.39 2.89 3,756.65 2_MWD+IFR2+MS+Sag(2) 6,193.66 85.73 194.83 3,946.51 3,904.11 -2,801.16 -3,060.02 6,029,100.54 541,606.09 5.76 3,816.78 2_MWD+IFR2+MS+Sag(2) 6,248.74 88.39 193.53 3,949.34 3,906.94 -2,854.49 -3,073.49 6,029,047.14 541,592.94 5.37 3,870.90 2_MWD+IFR2+MS+Sag(2) 6,330.47 88.04 192.22 3,951.88 3,909.48 -2,934.12 -3,091.70 6,028,967.41 541,575.22 1.66 3,950.93 2_MWD+IFR2+MS+Sag(3) 6,394.09 89.79 194.46 3,953.09 3,910.69 -2,996.01 -3,106.37 6,028,905.44 541,560.91 4.47 4,013.33 2_MWD+IFR2+MS+Sag(3) 6,457.05 91.33 192.87 3,952.47 3,910.07 -3,057.18 -3,121.24 6,028,844.19 541,546.41 3.52 4,075.17 2_MWD+IFR2+MS+Sag(3) 6,520.28 92.75 191.99 3,950.22 3,907.82 -3,118.88 -3,134.84 6,028,782.41 541,533.18 2.64 4,136.97 2_MWD+IFR2+MS+Sag(3) 6,583.24 93.55 190.17 3,946.76 3,904.36 -3,180.57 -3,146.93 6,028,720.65 541,521.47 3.15 4,198.13 2_MWD+IFR2+MS+Sag(3) 6,646.46 93.78 188.75 3,942.72 3,900.32 -3,242.81 -3,157.29 6,028,658.37 541,511.48 2.27 4,259.07 2_MWD+IFR2+MS+Sag(3) 6,709.17 91.49 189.97 3,939.84 3,897.44 -3,304.61 -3,167.48 6,028,596.51 541,501.66 4.14 4,319.54 2_MWD+IFR2+MS+Sag(3) 6,772.11 89.27 188.46 3,939.42 3,897.02 -3,366.73 -3,177.56 6,028,534.33 541,491.96 4.27 4,380.26 2_MWD+IFR2+MS+Sag(3) 6,834.85 87.10 190.19 3,941.41 3,899.01 -3,428.60 -3,187.72 6,028,472.40 541,482.17 4.42 4,440.79 2_MWD+IFR2+MS+Sag(3) 6,897.71 86.80 187.49 3,944.75 3,902.35 -3,490.62 -3,197.37 6,028,410.33 541,472.90 4.32 4,501.24 2_MWD+IFR2+MS+Sag(3) 6,960.56 87.31 186.85 3,947.98 3,905.58 -3,552.90 -3,205.20 6,028,348.02 541,465.44 1.30 4,561.17 2_MWD+IFR2+MS+Sag(3) 7,023.23 87.43 187.82 3,950.86 3,908.46 -3,614.99 -3,213.19 6,028,285.89 541,457.82 1.56 4,620.99 2 MWD+IFR2+MS+Sag(3) 7,086.70 89.48 186.77 3,952.57 3,910.17 -3,677.92 -3,221.25 6,028,222.92 541,450.15 3.63 4,681.61 2_MWD+IFR2+MS+Sag(3) 7,148.68 92.82 187.62 3,951.33 3,908.93 -3,739.39 -3,229.01 6,028,161.41 541,442.76 5.56 4,740.78 2_MWD+IFR2+MS+Sag(3) 7,211.54 94.43 189.77 3,947.35 3,904.95 -3,801.40 -3,238.49 6,028,099.35 541,433.65 4.27 4,801.15 2_MWD+IFR2+MS+Sag(3) 7,274.81 94.60 188.82 3,942.37 3,899.97 -3,863.64 -3,248.68 6,028,037.05 541,423.84 1.52 4,862.02 2 MWD+IFR2+MS+Sag(3) 7,338.03 94.78 189.59 3,937.20 3,894,80 -3,925.84 -3,258.76 6,027,974.80 541,414.13 1.25 4,922.81 2_MWD+IFR2+MS+Sag(3) 7,400.26 95.84 191.04 3,931.44 3,889.04 -3,986.80 -3,269.85 6,027,913.78 541,403.41 2.88 4,982.89 2_MWD+IFR2+MS+Sag(3) 7,464.03 95.58 190.10 3,925.10 3,882.70 -4,049.17 -3,281.49 6,027,851.34 541,392.14 1.52 5,044.49 2_MWD+IFR2+MS+Sag(3) 7,527.21 94.35 190.81 3,919.63 3,877.23 -4,111.07 -3,292.91 6,027,789.39 541,381.09 2.25 5,105.56 2_MWD+IFR2+MS+Sag(3) 7,590.03 93.97 191.56 3,915.07 3,872.67' -4,172.53 -3,305.06 6,027,727.86 541,369.31 1.34 5,166.54 2 MWD+IFR2+MS+Sag(3) 7,652.87 92.23 190.88 3,911.67 3,869.27 -4,234.08 -3,317.27 6,027,666.24 541,357.47 2.97 5,227.62 2_MWD+IFR2+MS+Sag(3) 7,715.41 91.06 190.78 3,909.88 3,867.48 -4,295.48 -3,329.02 6,027,604.78 541,346.10 1.88 5,288.37 2_MWD+IFR2+MS+Sag(3) 7,778.67 90.88 191.38 3,908.81 3,866.41 -4,357.55 -3,341.17 '6,027,542.64 541,334.32 0.99 5,349.90 2_MWD+IFR2+MS+Sag(3) 7,841.96 90.70 191.88 3,907.94 3,865.54 -4,419.54 -3,353.93 6,027,480.59 541,321.93 0.84 5,411.61 2_MWD+IFR2+MS+Sag(3) 7,903.25 92.32 194.70 3,906.32 3,863.92 -4,479.16 -3,368.01 6,027,420.89 541,308.21 5.30 5,471.71 2_MWD+IFR2+MS+Sag(3) 7,967.18 93.68 195.93 3,902.97 3,860.57 -4,540.73 -3,384.88 6,027,359.23 541,291.72 2.87 5,534.74 2_MWD+IFR2+MS+Sag(3), 8,030.45 94.47 196.89 3,898.48 3,856.08 -4,601.27 -3,402.70 6,027,298.59 541,274.26 1.96 5,597.22 2_MWD+IFR2+MS+Sag(3) 8,093.28 94.03 197.80 3,893.82 3,851.42 -4,661.07 -3,421.38 6,027,238.67 541,255.94 1.61 5,659.40 2_MWD+IFR2+MS+Sag(3) 8,155.66 93.04 197.73 3,889.98 3,847.58 -4,720.37 -3,440.38 6,027,179.28 541,237.30 1.59 5,721.23 2 MWD+IFR2+MS+Sag(3) 8,218.08 90.29 195.21 3,888.16 3,845,76 -4,780.19 -3,458.07 6,027,119.35 541,219.98 5.97 5,783.01 2_MWD+IFR2+MS+Sag(3) 8,281.02 90.64 194.94 3,887.65 3,845.25 -4,840.96 -3,474.43 6,027,058.49 541,203.98 0.70 5,845.10 2_MWD+IFR2+MS+Sag(3) • 1/9/2018 6:42:35PM Page 5 COMPASS 5000.1 Build 81D • i Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB©42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft • Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,343.86 92.63 195.90 3,885.86 3,843.46 -4,901.51 -3,491.14 6,026,997.85 541,187.64 3.52 5,907.13 2_MWD+IFR2+MS+Sag(3) 8,407.05 91.11 195.59 3,883.80 3,841.40 -4,962.30 -3,508.27 6,026,936.97 541,170.87 2.45 5,969.56 2_MWD+IFR2+MS+Sag(3) 8,470.05 91.70 195.34 3,882.25 3,839.85 -5,023.00 -3,525.07 6,026,876.17 541,154.44 1.02 6,031.77 2_MWD+IFR2+MS+Sag(3) 8,533.08 91.57 194.84 3,880.45 3,838.05 -5,083.83 -3,541.47 6,026,815.25 541,138.41 0.82 6,093.93 2_MWD+IFR2+MS+Sag(3) 8,596.09 91.63 195.13 3,878.69 3,836.29 -5,144.67 -3,557.75 6,026,754.31 541,122.49 0.47 6,156.06 2_MWD+IFR2+MS+Sag(3) 8,658.93 91.69 193.74 3,876.87 3,834.47 -5,205.50 -3,573.41 6,026,693.40 541,107.20 2.21 6,217.91 2_MWD+IFR2+MS+Sag(3) 8,721.97 91.32 193.57 3,875.22 3,832.82 -5,266.74 -3,588.29 6,026,632.08 541,092.69 0.65 6,279.81 2_MWD+IFR2+MS+Sag(3) 8,784.79 91.39 193.31 3,873.73 3,831.33 -5,327.82 -3,602.89 6,026,570.92 541,078.46 0.43 6,341.45 2_MWD+IFR2+MS+Sag(3) 8,847.60 91.56 193.89 3,872.11 3,829.71 -5,388.85 -3,617.65 6,026,509.81 541,064.07 0.96 6,403.12 2_MWD+IFR2+MS+Sag(3) 8,911.02 92.62 195.25 3,869.80 3,827.40 -5,450.19 -3,633.59 6,026,448,38 541,048.49 2.72 6,465.55 2_MWD+IFR2+MS+Sag(3) 8,973.68 89.82 195.43 3,868.47 3,826.07 -5,510.59 -3,650.16 6,026,387.88 541,032.29 4.48 6,527.40 2_MWD+IFR2+MS+Sag(3) 9,036.39 90.59 195.48 3,868.24 3,825.84 -5,571.03 -3,666.88 6,026,327.34 541,015.94 1.23 6,589.34 2_MWD+IFR2+MS+Sag(3) 9,099.51 90.26 195.67 3,867.78 3,825.38 -5,631.83 -3,683.82 6,026,266.45 540,999.36 0.60 6,651.70 2_MWD+IFR2+MS+Sag(3) 9,162.50 90.59 195.04 3,867.31 3,624.91 -5,692.57 -3,700.50 6,026,205.62 540,983.05 1.13 6,713.89 2_MWD+IFR2+MS+Sag(3) 9,225.20 92,32 195.06 3,865.72 3,823.32 -5,753.10 -3,716.78 6,026,145.00 540,967.14 2.76 6,775.72 2_MWD+IFR2+MS+Sag(3) 9,288.40 94.80 195.90 3,861.79 3,819.39 -5,813.89 -3,733.61 6,026,064.12 540,950.67 4.14 6,838.02 2_MWD+IFR2+MS+Sag(3) 9,351.05 96.22 196.96 3,855.78 3,813.38 -5,873.70 -3,751.25 6,026,024.21 540,933.40 2.82 6,899.77 2_MWD+IFR2+MS+Sag(3) 9,413.53 94.08 197.27 3,850.17 3,807.77 -5,933.17 -3,769.56 6,025,964.64 540,915.45 3.46 6,961.48 2_MWD+IFR2+MS+Sag(3) 9,476.20 90.72 197.22 3,847.54 3,805.14 -5,992.96 -3,788.12 6,025,904.74 540,897.25 5.36 7,023.59 2_MWD+IFR2+MS+Sag(3) 9,537.78 91.44 196.39 3,846.38 3,803.98 -6,051.90 -3,805.92 6,025,845.70 540,879.80 1.78 7,084.61 2_MWD+IFR2+MS+Sag(3) 9,601.88 91.56 197.20 3,844.71 3,802.31 -6,113.24 -3,824.43 6,025,784.25 540,861.66 1.28 7,148.12 2_MWD+IFR2+MS+Sag(3) 9,665.67 92.49 197.18 3,842.45 3,800.05 -6,174.14 -3,843.28 6,025,723.25 540,843.19 1.46 7,211.36 2_MWD+IFR2+MS+Sag(3) 9,728.33 92.93 195.41 3,839.49 3,797.09 -6,234.22 -3,860.84 6,025,663.07 540,825.99 2.91 7,273.31 2_MWD+IFR2+MS+Sag(3) 9,791.29 89.79 193.82 3,837.99 3,795.59 -6,295.11 -3,876.72 6,025,602.09 540,810.48 5.59 7,335.31 2_MWD+IFR2+MS+Sag(3) 9,853.73 90.58 194.55 3,837.79 3,795.39 -6,355.65 -3,892.02 6,025,541.47 540,795.54 1.72 7,396.75 2_MWD+IFR2+MS+Sag(3) 9,916.88 91.14 194.04 3,836.85 3,794.45 -6,416.84 -3,907.61 6,025,480.20 540,780.32 1.20 7,458.90 2_MWD+IFR2+MS+Sag(3) 9,980.02 91.70 194.07 3,835.28 3,792.88 -6,478.07 -3,922.94 6,025,418.88 540,765.36 0.89 7,520.99 2_MWD+IFR2+MS+Sag(3) 10,043.02 93.12 194.08 3,832.63 3,790.23 -6,539.12 -3,938.24 6,025,357.74 540,750.42 2.25 7,582.90 2_MWD+IFR2+MS+Sag(3) 10,105.63 92.11 191.52 3,829.77 3,787.37 -6,600.10 -3,952.10 6,025,296.68 540,736.93 4.39 7,644.15 2_MWD+IFR2+MS+Sag(3) 10,168.19 92.69 190.12 3,827.15 3,784.75 -6,661.50 -3,963.83 6,025,235.23 540,725.57 2.42 7,704.89 2_MWD+IFR2+MS+Sag(3) 10,230.67 91.80 189.02 3,824.71 3,782.31 -6,723.06 -3,974.21 6,025,173.61 540,715.56 2.26 7,765.22 2_MWD+IFR2+MS+Sag(3) 10,294.18 93.18 187.87 3,821.95 3,779.55 -6,785.82 -3,983.53 6,025,110.80 540,706.62 2.83' 7,826.20 2_MWD+IFR2+MS+Sag(3) 10,357.19 91.56 186.95 3,819.34 3,776.94 -6,848.24 -3,991.65 6,025,048.33 540,698.88 2.96 7,886.39 2_MWD+IFR2+MS+Sag(3) 10,419.75 90.77 185.88 3,818.07 3,775.67 -6,910.40 -3,998.64 6,024,986.14 540,692.27 2.13 7,945.86 2_MWD+IFR2+MS+Sag(3) 10,482.99 90.27 185.13 3,817.50 3,775.10 -6,973.34 -4,004.70 6,024,923.17 540,686.58 1.43 8,005.67 2_MWD+IFR2+MS+Sag(3) 10,545.28 90.95 185.52 3,816.83 3,774.43 -7,035.36 -4,010.48 6,024,861.12 540,681.17 1.26 8,064.51 2_MWD+IFR2+MS+Sag(3) 10,608.75 92.56 186.82 3,814.89 3,772.49 -7,098.43 -4,017.30 6,024,798.02 540,674.73 3.26 8,124.74 2_MWD+IFR2+MS+Sag(3) 10,671.48 93.11 186.02 3,811.79 3,769.39 -7,160.69 -4,024.31 6,024,735.73 540,668.10 1.55 8,184.32 2_MWD+IFR2+MS+Sag(3) 10,734.78 93.05 184.24 3,808.39 3,765.99 -7,223.64 -4,029.96 6,024,672.75 540,662.83 2.81 8,243.96 2_MWD+IFR2+MS+Sag(3) 10,797.51 92.37 184.66 3,805.42 3,763.02 -7,286.11 -4,034.82 6,024,610.25 540,658.34 1.27 8,302.84 2_MWD+IFR2+MS+Sag(3) 1/9/2018 6:42:35PM Page 6 COMPASS 5000.1 Build 8 lD III • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB©42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 10,860.34 94.04 187.40 3,801.91 3,759.51 -7,348.49 -4,041.41 6,024,547.85 540,652.13 5.10 8,362.34 2_MWD+IFR2+MS+Sag(3) 10,923.23 92.97 187.59 3,798.06 3,755.66 -7,410.72 -4,049.59 6,024,485.57 540,644.32 1.73 8,422.38 2_MWD+IFR2+MS+Sag(3) 10,986.23 90.75 186.21 3,796.02 3,753.62 -7,473.23 -4,057.16 6,024,423.03 540,637.13 4.15 8,482.41 2 MWD+IFR2+MS+Sag(3) 11,049.03 90.95 187.17 3,795.08 3,752.68 -7,535.59 -4,064.47 6,024,360.62 540,630.19 1.56 8,542.21 2_MWD+IFR2+MS+Sag(3) 11,111.82 91.27 187.23 3,793.87 3,751.47 -7,597.88 -4,072.34 6,024,298.30 540,622.70 0.52 8,602.16 2_MWD+IFR2+MS+Sag(3) 11,174.01 91.51 189.18 3,792.36 3,749.96 -7,659.41 -4,081.21 6,024,236.72 540,614.20 3.16 8,661.84 2_MWD+IFR2+MS+Sag(3) 11,237.72 92.63 190.01 3,790.06 3,747.66 -7,722.19 -4,091.83 6,024,173.89 540,603.96 2.19 8,723.38 2_MWD+IFR2+MS+Sag(3) 11,300.42 91.99 190.08 3,787.53 3,745.13 -7,783.87 -4,102.75 ,6,024,112.14 540,593.41 1.03 8,784.05 2_MWD+IFR2+MS+Sag(3) 11,363.16 92.68 190.66 3,784.98 3,742.58 -7,845.54 -4,114.04 6,024,050.42 540,582.49 1.44 8,844.85 2 MWD+IFR2+MS+Sag(3) 11,426.43 92.86 190.92 3,781.92 3,739.52 -7,907.62 -4,125.87 6,023,988.28 540,571.04 0.50 8,906.26 2_MWD+IFR2+MS+Sag(3) 11,489.32 92.05 191.46 3,779.22 3,736.82 -7,969.25 -4,138.06 6,023,926.57 540,559.22 1.55 8,967.41 2_MWD+IFR2+MS+Sag(3) 11,552.29 . 91.05 191.44 3,777.52 3,735.12 -8,030.95 -4,150.56 6,023,864.81 540,547.09 1.59 9,028.74 2_MWD+IFR2+MS+Sag(3) 11,615.02 91.69 191.89 3,776.02 3,733.62 -8,092.36 -4,163.24 6,023,803.33 540,534.78 1.25 9,089.90 2 MWD+IFR2+MS+Sag(3) 11,677.73 92.01 192.81 3,774.00 3,731.60 -8,153.59 -4,176.64 6,023,742.03 540,521.75 1.55 9,151.18 2 MWD+IFR2+MS+Sag(3) 11,740.52 92.11 192.26 3,771.74 3,729.34 -8,214.84 -4,190.26 6,023,680.70 540,508.50 0.89 9,212.58 2_MWD+IFR2+MS+Sag(3) ' . 11,803.29 92.13 191.92 3,769.42 3,727.02 -8,276.18 -4,203.40 6,023,619.29 540,495.73 0.54 9,273.85 2_MWD+IFR2+MS+Sag(3) 11,866.10 93.05 192.64 3,766.58 3,724.18 -8,337.49 -4,216.74 6,023,557.91 540,482.75 1.86 9,335.18 2 MWD+IFR2+MS+Sag(3) 11,928.89 92.98 191.90 3,763.28 3,720.88 -8,398.76 -4,230.07 6,023,496.57 540,469.80 1.18 9,396.47 2_MWD+IFR2+MS+Sag(3) 11,992.04 91.80 192.15 3,760.64 3,718.24 -8,460.47 -4,243.21 6,023,434.78 540,457.03 1.91 9,458.08 2_MWD+IFR2+MS+Sag(3) 12,054.18 90.12 192.18 3,759.60 3,717.20 -8,521.20 -4,256.31 6,023,373.98 540,444.30 2.70 9,518.79 2_MWD+IFR2+MS+Sag(3) 12,117.08 89.64 191.83 3,759.73 3,717.33 -8,582.73 -4,269.39 6,023,312.38 540,431.59 0.94 9,580.21 2 MWD+IFR2+MS+Sag(3) 12,180.43 89.20 192.67 3,760.37 3,717.97 -8,644.63 -4,282.83 6,023,250.41 540,418.52 1.50 9,642.12 2_MWD+IFR2+MS+Sag(3) 12,243.63 89.84 193.60 3,760.90 3,718.50 -8,706.17 -4,297.19 6,023,188.78 540,404.53 1.79 9,704.08 2_MWD+IFR2+MS+Sag(3) 12,305.81 93.01 195.03 3,759.36 3,716.96 -8,766.39 -4,312.56 6,023,128.48 540,389.53 5.59 9,765.26 2 MWD+IFR2+MS+Sag(3) 12,368.32 94.04 196.45 3,755.51 3,713.11 -8,826.44 -4,329.48 6,023,068.33 540,372.97 2.80 9,826.93 2_MWD+IFR2+MS+Sag(3) 12,431.50 94.72 197.34 3,750.69 3,708.29 -8,886.72 -4,347.79 6,023,007.95 540,355.02 1.77 9,889.38 2_MWD+IFR2+MS+Sag(3) 12,494.07 92.53 197.92 3,746.73 3,704.33 -8,946.23 -4,366.70 6,022,948.34 540,336.47 3.62 9,951.38 2_MWD+IFR2+MS+Sag(3) 12,557.58 91.37 198.30 3,744.57 3,702.17 -9,006.56 -4,386.43 6,022,887.90 540,317.11 1.92 10,014.46 2 MWD+IFR2+MS+Sag(3) 12,620.40 92.51 198.02 3,742.45 3,700.05 -9,066.21 -4,406.00 6,022,828.13 540,297.90 1.87 10,076.86 2 MWD+IFR2+MS+Sag(3). 12,683.60 92.05 200.10 3,739.93 3,697.53 -9,125.90 -4,426.62 6,022,768.33 540,277.64 3.37 10,139.73 2_MWD+IFR2+MS+Sag(3) 12,746.31 93.37 200.79 3,736.97 3,694.57 -9,184.59 -4,448,50 6,022,709.51 540,256.11 2.37 10,202.21 2 MWD+IFR2+MS+Sag(3) 12,809.09 93.67 201.17 3,733.11 3,690.71 -9,243.10 -4,470.93 6,022,650.88 540,234.03 0.77 10,264.76 2_MWD+IFR2+MS+Sag(3) 12,871.40 93.29 200.85 3,729.33 3,686.93 -9,301.16 -4,493.23 6,022,592.69 540,212.09 0.80 10,326.84 2 MWD+IFR2+MS+Sag(3) 12,934.93 93.79 201.52 3,725.41 3,683.01 -9,360.28 -4,516.15 6,022,533.44 540,189.53 1.31 10,390.15 2_MWD+IFR2+MS+Sag(3) 12,997.73 92.60 201.47 3,721.91 3,679.51 -9,418.62 -4,539.12 6,022,474.97 540,166.91 1.90 10,452.76 2 MWD+IFR2+MS+Sag(3) 13,060.85 90.99 200.64 3,719.93 3,677.53 -9,477.49 -4,561.79 6,022,415.96 540,144.60 2.87 10,515.74 2_MWD+IFR2+MS+Sag(3) ' 13,123.60 89.82 199.70 3,719.49 3,677.09 -9,536.39 -4,583.42 6,022,356.94 540,123.32 2.39 10,578.31 2_MWD+IFR2+MS+Sag(3) 13,186.40 89.53 198.56 3,719.84 3,677.44 -9,595.72 -4,604.00 6,022,297.49 540,103.10 1.87 10,640.83 2_MWD+IFR2+MS+Sag(3) 13,249.39 91.58 198.86 3,719.23 3,676.83 -9,655.38 -4,624.21 6,022,237.72 540,083.26 3.29 10,703.50 2_MWD+IFR2+MS+Sag(3) 13,312.33 92.18 198.04 3,717.17 3,674.77 -9,715.05 -4,644.11 6,022,177.94 540,063.71 1.61 10,766.06 2 MWD+IFR2+MS+Sag(3) 1/9/2018 6:42:35PM Page 7 COMPASS 5000.1 Build 89D . ' • S Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well MPU L-52 Project: Milne Point TVD Reference: ''MPU L-52 Actual RKB @ 42.40usft Site: M Pt L Pad MD Reference: MPU L-52 Actual RKB @ 42.40usft Well: MPU L-52 North Reference: True Wellbore: MPU L-52 Survey Calculation Method: Minimum Curvature Design: MPU L-52 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS" Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 13,37522 91.06 197.46 3,715.39 3,672.99 -9,774.92 -4,663.28 6,022,117.96 540,044.91 2.01 10,828.49 2_MWD+IFR2+MS+Sag(3) 13,438 09 91.01 195.77 3,71425 3,671.85 -9,835.15 -4,681.25 6,022,057.63 540,027.30 2.69 10,890.76 2_MWD+IF122+MS+Sag(3) 13,500.82 91.38 193.56 3,712.95 3,670.55 -9,895.82 -4,697.13 6,021,996.87 540,011.79 3.57 10,952.56 2_MWD+IFR2+MS+Sag(3) 13,563.68 92.06 193.43 3,711.06 3,668.66 -9,956.92 -4,711.79 6,021,935.69 539,997.49 1.10 11,014.25 2_MWD+IFR2+MS+Sag(3) 13,626.85 94.17 192.52 3,707.63 3,665.23 -10,018.38 -4,725.95 6,021,874.15 539,983.70 3.64 11,076.06 2_MWD+IFR2+MS+Sag(3) 13,689.12 94.59 191.63 3,702.87 3,660.47 -10,079.09 -4,736.94 6,021,813.37 539,971.08 1.58 11,136.70 2_MWD+IFR2+MS+Sag(3) 13,752.47 91.55 190.34 3,699.48 3,657.08 -10,141.19 -4,750.99 6,021,751.21 539,959.40 5.21 11,198.21 2_MWD+IFR2+MS+Sag(3) 13,815.30 89.86 190.81 3,698.70 3,656.30 -10,202.94 -4,762.52 6,021,689.39 539,948.24 2.79 11,259.19 2_MWD+IFR2+MS+Sag(3) 13,878.27 91.95 191.34 3,697.71 3,655.31 -10,264.73 -4,774.62 6,021,627.54 539,936.52 3.42 11,320.44 2_MWD+IFR2+MS+Sag(3) 13,940.65 90.31 189.88 3,696.48 3,654.08 -10,326.03 -4,786,10 6,021,566.18 539,925.41 3.52 11,380.99 2_MWD+IFR2+MS+Sag(3) 13,969.02 89.70 189.23 3,696.48 3,654.08 -10,354.00 -4,790,81 6,021,538.18 539,920.87 3.14 11,408.41 2_MWD+IFR2+MS+Sag(3) 14,000.00 89.70 189.23 3,696.64 3,654.24 -10,384.58 -4,795.78 6,021,507.58 539,916.08 0.00 11,438.30 PROJECTED to TD mitchell.laird@halliburton.com Michael Calkins Checked By: 2018.01.0915:49:51-09'00' Approved By: o,,F;=^: dkilr:. t ...- Date: 1/9/2018 1/9/2018 6.42:35PM Page 8 COMPASS 5000.1 Build 81D • i Schwartz, Guy L (DOA) P ,2 Q-21-7 From: Schwartz, Guy L(DOA) Sent: Tuesday,January 02,2018 9:20 AM To: 'Joe Engel' Subject: RE: MPU L-52 (PTD#217-174)Wellhead Potential Change Joe, I don't see any reason that you couldn't omit the tubing spool either. Functionality would be the same.You have approval to make the change to the new simplified wellhead design. Update the MOC as required. BTW... In the new wellhead drawing I don't see where the LDS are supposed to go? (using the existing pressure ports holes?) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Joe Engel [mailto:jengel@hilcorp.com] Sent: Friday, December 29, 2017 1:35 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject: MPU L-52 (PTD#217-174)Wellhead Potential Change Guy— Hope all is well and you had a good Christmas. Hilcorp Alaska would like to propose a change to the wellhead design that was approved for MPU L-52 SB Injector.The proposed wellhead system would remain a Cameron 11"5K MBS,the only difference would be the removal of the tubing spool. In the proposed change,the tubing hanger would land in the casing head with LDS ports machined in, and the tubing head would bolt directly to the casing head.There would be no change in the monitor-able annuli or function of the wellhead. The driver for this change is that the tubing spool and 7-5/8" hanger in the submitted wellhead design only serve as a landing profile for the tubing hanger, as the approved injector well design only has the 9-5/8"x 4-1/2"annulus-with only a few joints of 7-5/8"casing ran below the hanger. By removing the tubing spool and landing the tubing hanger in the casing spool,we would be removing two unnecessary connections,and thus potential leak points,from the wellhead. We appreciate your consideration. Please let me know if you have any questions or concerns or if you would like a sundry submitted for this change. Thank you for your time. Happy New Year. 1 • -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 I Anchorage I AK 199503 Office:907.777.8395 I Cell: 805.235.6265 2 CAMERON 11" 5K �` A Schlumberger Company 4-1/16" 5K 16.09" 11" 5K M �. �i ' illit 2 1/16 5K Tim" iii 37•34�� 21.25" .I' 1 •[1111111M111 6111111 ; �IIII o�0,0 0 , i ? 4 I! oil 1 it 9-5/8" •�� 4-1/2" Control Lines II 24.87" — I Note: Dimensional information reflected on this drawing are estimated measurements only. • • Note: Dimensional information reflected itatP on this drawing are estimated rtz measurements only. iUI wimi.. .,111101 4-1/16" 5,000# 'n 11111 No 0 O 4-1/16" 5,000# .;I �o c ® ; 86.22" ` moi % ' 4-1/16" 5,000# Ir Hydraulic 51.16" I.IUI.I L'D m A ui M 4-1/16" 5,000# � , ilwo 4-1/16" 5,000# lik, "' I' 7'; 16.09" 11" 5,000# : int` mil mi t ,., 4 it 2-1/16" 5,000# 10.19" 15.74" f_x _i:4 11'-: : ) € 7 1,,:,, . 11" 5,000# 'i II __ 19.17" ,B, I um 2-1/16" 5,000# 21.25" ' f,1-;�I! '1_, -1.,- 6,-11 I I C 1 14.• 25" � II i ■ r,_ 6. --14.62" 7.29" ii 1 ill----L— — Wellhouse Floor 7.12" a ra to Btm. of hanger } (CPLG = I I 16" 6.0" OAL) 9-5/8 !I 7-5/8"hanger and packoff-no casing 4-1/2" 24.87" eCAMERON Well Center Line Jeanette # Name_ Date- Working Prrmnc: • 14.0 L-52 - Regg, James B (DOA) 74' From: Regg,James B (DOA) Sent: Monday, December 25, 2017 3:01 PM leejg �L'Z 11-7 To: Jones, Jeffery B (DOA) I1 I / Subject: Re: Request for Variance L-52 Vent Line Orientation Thank you Jeff. Variance is approved. Merry Christmas! Sent via the Samsung Galaxy 58 Active, an AT&T 4G LTE smartphone Original message From: "Jones,Jeffery B (DOA)" <jeff.jones@alaska.gov> Date: 12/25/17 2:38 PM (GMT-09:00) To: "Regg,James B (DOA)" <jim.regg@alaska.gov> Subject: Fwd: Request for Variance L-52 Vent Line Orientation Jim, I apologize for bothering you on Christmas but I am doing a diverter inspection on the hilcorp innovation rig, drilling MPF grass roots well L-52.The problem in this case is the vent line points directly at the pad entrance and the only access road to MPF F-pad. Looking at the rig configuration and the pad and well row construction, there is no other feasible routing for the vent line. I've had discussions with Hilcorp Co. rep.James Lott& Hilcorp T.P.Jay Compton and we came up with this variance request to address this situation. I am OK with this variance proposal and forwarded it to you for consideration and approval. The rig has passed all other tests and they are ready to spud the well pending approval. Thanks, Merry Christmas! Jeff Jones AOGCC 744-4446 Sent from my iPhone Begin forwarded message: From: "James Lott- (C)" <ilott@yhilcorp.com> To: "Jones,Jeffery B (DOA)" <ieff.iones@alaska.gov> Subject: Request for Variance L-52 Vent Line Orientation Mr.Jones, In regard to Hilcorps request for variance of our current orientation of the 16"vent line on L-52, I have attached a Schematic showing the alternative route for all traffic traveling from L-Pad to F-Pad.This should not be an issue for smaller vehicles. If the situation were to arise where larger support units, ie Vac Trucks/Pumping units ect need access, we will post a SPOC who will have radio communication with the Drill Floor, Pad Operator and Company Man,to escort the Units through the Barricaded zone. Please let us know if you require any other information. Thank You. • James Lott HILCORP Drilling Foreman HILCORP INNOVATION Rig Milne Point, North.Slope Alaska 907-670-3094 jlott@hilcorp.com jameslott352@yahoo.com 2 S 0 E,. Mime Point init 1k 11 52Producer Diii: Frocedure g KikOrp ScovirmA, rc Arkain ivizo wits.. Pro Emmy Company 10.5 Rig&Diverter Orientation: QD,A, \ \ ...... 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's:4f.- ...elf.f.,,...-,-••*4 tg.3! LI Mewl) Alaska. 1,1,4; - . MILNE POINT UNIT ,,a.-•:•,' r.. ."•(,,,, ,.'•4 "',`:- -:,*-- -z,•=izt,=- •,,,'-,,•••••••:,;, :•..".-. ••••=, . - ' ' - •s :.••-. ' •••;:.",,,.- ,.a:, - :',:.;r1 MPU I_PAD MN!PAD . ;4,: 'It.;:.1,:,'„,1-:•;;:-''.:.', 244,41' k-_,- - ,-' . 10•---, n • a4g. M LOCATION MAP ,,,.••-•.,,:CFP• J , G ••••g MINE /..••• :41.,t.„,:,',,,,0„' 0;.1.,. May Scale 1.2000 Fee 4.,..„ ,- 4,...=ii.. Date: I s Map Author: I 'i,c...4';--'"44;;;;;,"-":4-04";!,:':=;...*"*.t•rT..'14=,*,"--,-,*•••'•-:;,.. ,•:*''''' .'***-•="." ka.--'.=:%,.'". Map 14 of 1 TEXACO ;•'••••N,"-•"...4....) ...••;7--:$'4I-:-1'4'1; :1044;?... IE.NT'4• .,d••••;;'.. 47Y,'..'"..-4;1'.•‘•'` °C1(1ber 2°17 I HAI<-MRA 1 ... . . _____ ......... - �V OF Tit • wI/j, s� THE STATE Alaska Oil and Gas of ® SKA Conservation Commission 7. Witt_ RECEIVE 7 STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM ION DEC u 7 2017 PERMIT TO DRILL 20 AAC 25.005 rr la.Type of Work: lb. Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disppt- lc. p Qi lf4elpCosed for: Drill ❑., ` Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑., . Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC • Bond No. 022035244 • MPU L-52 • 3.Address: 6. Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 MD: 13,779' • TVD: 3,742' ' Milne Point Field ' 4a. Location of Well(Governmental Section): 7.Property Designation: Schrader Bluff Oil Pool , Surface: 3732'FSL,5227'FEL,Sec 8,T13N,R10E,UM,AK ADL025509(SHL/TPH)/ADL025515(BHL) Top of Productive Horizon: 8. DNR Approval Number: 13.Approximate Spud Date: 717'FSL,2142'FWL,Sec 7,T13N,R10E,UM,AK LONS 88-002 12/27/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1201'FNL,588'FWL,Sec 19,T13N,R10E, UM,AK 5077 Acres 7,421'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 42.2' 15.Distance to Nearest Well Open Surface: x-544648 y- 6031919 Zone-4 ' GL/BF Elevation above MSL(ft): 15.7' - to Same Pool: 930'to MPL-37 16.Deviated wells: Kickoff depth: 450 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91.68 degrees • Downhole: 1778 + Surface: 1399 ' 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data)' 36" 16" 164# A-53 Weld 80' Surface Surface 107' 107' -270 ft3 12-1/4" 9-5/8" 40# L-80 DWC/C 6,350' Surface Surface 6,350' 3,957' Stg 1 -1606 ft3/Stg 2-2174 ft3 Tubing 4-1/2" 12.6# L-80 TXP-SR 6,200' Surface Surface 6,200' 3,948' 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 7,579' 6,200' 3,948' 13,779' 3,742' Swell Packers w/ICD Completion 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Hydraulic Fracture planned? Yes❑ No ❑., 20. Attachments: Property Plat ❑ BOP Sketch 7 Drilling Program 7 Time v.Depth Plot '— Shallow Hazard Analysis— Diverter Sketch ✓ Seabed Report _ Drilling Fluid Program ✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Paul Mazzolini Contact Email: iencieIt hiIcorp.com Authorized Title: Drilling Manager Contact Phone: 777-8395 Fog_ PAA_ Y•NA(Z1--0Li i-Jk Authorized Signature: ,k,l Date: 1"•L.-$3-CI-- Commission 'rCommission Use Only Permit to Dril API Number: Permit Approval , See cover letter for other r Number: - l �� 50- 019 — �3 Q — & -6--Q Date: (4 ra I ( I1 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: Ed Other: 4 spa) �}V go %ems 74_ Samples req'd: Yes No[V ' Mud log req'd:Yes❑ olE" /j ��```-'�`'''� /y„.4.. H2S measures: Yes No❑ Directional svy req'd:Yes[�No❑ >E to (r jJ4 �,` Spacing exception req'd: Yes ❑ No ' Inclination-only svy req'd:Yes❑ No d 5 L_ ,, j , Post initial injection MIT req'd:Yes❑ No❑ diDCF.....N___ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (2. tt ((s ��l /� f t -! �tiorm and ,`vl� n1 Fo 10-401 Revispd 5 201 This permit is valid for 24 mor0 RI tOtt a�p�v per 20 AAC 25.005( Attachments in Duplicate ,1'&xUself �y z � ' V 'vH1L. • Joe Engel Hilcorp Alaska, LLC Drilling EngineerSP.O. Box 244027 Anchorage,AK 99524-4027 Hilcorp RECEIVED Tel 907 777 8395 Energy Company Email: jengel@hilcorp.com 12.7.2017 DEL 0 7 2017 AOGCC Commissioner Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill MPU L-52 Dear Commissioner, Hilcorp Alaska, LLC hereby submits for review and approval for a Permit to Drill an onshore injection well at Milne Point'L' Pad, well slot 52. Drilling operations are intended to commence approximately Dec 22, 2017, pending rig schedule. MPU L-52 is a grassroots injector planned to be drilled in the Schrader Bluff NB sand. L-52 is part of a six well program targeting the NB sand. s-kr - C P. The directional plan is a catenary wellpath build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff NB sand. An 8.5" lateral section will then be drilled. A 4.5" liner will be run in the open hole section. / The Innovation Rig will be used to drill and complete the wellbore. Hilcorp Alaska respectfully requests a variance to AOGCC regulation 20 AAC 25.412(b). MPU L-52 is a planned to be completed with injection control devices(ICD)and swell packers, with the production packer—500'from the first ICD, and 150' inside the casing shoe as per 20 AAC 25.030(d)(6). The 9- 5/8" passing FIT proves isolation of the injection fluid to the Schrader Bluff interval. Please find attached the Form 10-401, Application For Permit to Drill per 20 AAC 25.005 (a) and the drilling program for MPU L-52, which includes information required by 20 AAC 25.005 (c). If you have any questions, or require further information, please do not hesitate to contact myself(Joe Engel) at 777-8395 orjengel@hilcorp.com or Paul Mazzolini at 777-8369 or pmazzolini@hilcorp.com. Sincerely, Joe Engel Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 s S Area of Review - Proposed MPL-52 Injection Well Prior to completion of the MPL-52 Schrader Bluff NB injection well, an Area of Review (AOR) must be conducted. This AOR found MPL-34, MPL-37A, MPL-35, MPL-51, Pesado 01, Pesado 01A: within 1/4 mile of MPL-52's entry into the SB NB formation. The tables below illustrate the wells within the AOR, the distance from MPL-52, completion details and integrity conditions based on in-depth review of each well. Table 1: Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity Well currently in progress. As of 12/6/17: 12-1/4" surface hole drilled to 6,610' MD/3,937'TVD. 9-5/8" casing run to 6,600' MD and cemented back to surface using a 2 stage cement pumping schedule. 15t stage pumped 292 bbls, (37 MPL-51 217-151 1265' bbls circulated out). 2nd stage pumped 358.8 bbls with visual returns to surface. 252 bbls total returned to surface. This well will be supported by MPL-52 WINJ. NB Sand Top 6,427' MD/3,937'TVD Shut In WINJ. 12-/4" Surface hole drilled and cased 9-5/8",/ to 9,779' MD/4,441'TVD, cemented_back to surfa_ce_._,8- 1/2" hole drilled to 18,310' MD/7,108'TVD. Perforations MPL-34 197-080 25' open in Kuparuk pool. Well suspended in 2008, CIBP installed at 17,494' MD-casing tested against CIBP to 3500 psi good on 12/2/08. No known integrity issues. NB Sand Top-7,193' MD/3,931' TVD Shut in Producer. 12-1/4" surface hole drilled and cased with 9-5/8" to 8,212' MD. Cemented back to surface. Well MPL 37A 198-056 920 perforations open in SB N and OA sands 3,918'-3,924' TVD(N),4,042'-4,048'TVD (OA). NB Sand Top-7,117' MD/3,912'TVD Well Abandoned (for sidetrack). 12-1/4" surface hole drilled, cased 9-5/8" casing to 10,510' MD cemented back MPL-35 197-092 198' to surface, no known integrity issues. NB Sand Top 8,447' MD/3,852'TVD 9-5/8" surface casing to 3,255' MD and cemented back to surface. 8-1/2" OH drilled to 4,497' MD/4,391'TVD for evaluation and cemented back to 3,280' MD with 3 cement Pesado 01 207-025 782' plugs. The top plug was used to kickoff Pesado 01A sidetrack. Well Abandoned. NB Sand Top 3,934' MD/3,861'TVD i 9-5/8" surface casing to 3,255' MD and cemented back to surface. Sidetrack was kicked off using cement plug set in Pesado 01. 8-1/2" OH was drilled to 4,339' MD/4,286'TVD for evaluation and cemented back to 2,955' MD with 3 cement plugs. Well has 9.4 ppg bring F/2,955' MD T/250' Pesado 01A 207-026 1265' MD. CIBP installed inside 9-5/8" casing @ 250' MD. Well cemented to surface, surface/conductor cut off below ground level and abandonment marker installed per AOGCC regulations. NB Sand Top—3,906' MD/3,857'TVD • • j- - ---:7"-'',//.."' � // // ...- / i , 7 /:>,, /el/ \ i I i/ j f N. \ ,---* /1( L // i,,..Arz , , \\ , \ / 4 ., , f/' // / „ , \ { -51 �\ I N `w / / i '� // L-2o �e /./// j�L4 s•47 \ 1 N y �,, r / L4\ 1 a oO 1 I ` N.,., 1 �/ L-36 / // I \ I .,,,\ N / /% ` / // IP IA -II L-50 \ I l 'N. r,/ / / l ��i \ /// /f Af NI N.N. N / /� Iii I ` // / I/ 1 1 ,. / N. / / /. N. / / / // I i HILCORP ALASKA LLC / ..-- / I h1ILNE POINT FIELD -- III AOR Map F.dpe 2C:w2 mem 1 11.l!' . it- FEET lislib POSTEC 7+E—0 ATA LII 1 Yfall Mumbar I y/ e t WELL SYNEDLS /urAN f aa...DI 1A t • n:W.fA'Y.lixd; I iiif)l 011 hpa_kr Lu:ata:n IFinacx Lxsiai / REMARKS Vit Syrtds az tra d Schrader PIONS Sand I Exs'tn3 screen -ACI pack ccanpleters In NS sr'i r 4111111110. pink.11-73 and L-3TA Sian(dash drtle•t32G mous tmn reapased mi*eei and Me r SAM-52 D.rxrbxs a:IT • • Tree: 4 Orig. Wellheadl: 11"551FMCI WM Geno5 w.r MPU L-34i Orig. GBL Elev. = 172.10' (N 27E) 11" x 4.5" FMC Tbg_ Hgr. , 4.5" RT To Tbg. Spool = 35.7' (N 27E) NSCT threads top and bottom, 4" CIW "H" BPV profile 20" 91.1 ppf, H-40 ( 112' 2 7/8'Kill String KOP '8L„i 1000' Max. hole angle = 81 deg. a 6,470' 79 deg. to 81 deg. (4.100'- 14,700') -ow" 2 718'HES XN-Nipple 2555' Hole angle thru' perfs= > 31 deg. (2.250`No-Go ID) WLEG 2599' 9 5/8", 40##Jft, L-80 Btrc. ( 9,779' Casing tested against CIBP to 3500 psi 12/2108 2 718" 6.5 ppf, L-80. IST Tubing ( drift ID = 2.347", cap.= .0059 bpf ) 4.5" 12.6 ppf, L-80, IBT Tubing ( drift ID = 3.958-, cap.= .0152 bpf ) 7"26 ppf, L-80, NSCC casing ( drift ID = 6.151", cap. = 0.0383 bpf) IJet cut 4 112' tag top 11/22/08 17,449' 7"x 4.5"Baker S-3 Perm pkr. 17,479' 17.49= 4.5- Baker CIBP mid elemert Stimulation Summary anig. 4.5'HES XN-Nippde 13.725'id ) 17,502' WLEG 17,514' Perforation Summary Ref log: 5/22/97 LWR Size SPF interval (TVD) Shot with coil 1/'5101 2-718- 4 17.840.-17.860' 2-718" 4 17.868'-17.878' Initial perforations 4.5' 5 17,906'-17.926' 6.775'-6.791' 4.5' 5 17.930'-17.970' 6.794'-6.829' 4.5` 5 18.004'-18.024' 6.858'-6.876' Coil: 2-718'power jet.4SPF.60 degree. EHD=.36 7"float collar(PBTD) 18,202' TTP=27.7 ,. E-Line: , 7" float shoe 18,287' 51 b HJ11 Deep penetrating charges a 60 deg_phasing DATE REV.BY COMMENTS MILNE POINT UNIT I i,31.47 088 I ..n` a oPSY 'ors 278 WELL L-34 1/15/01 M. Linder Add perfs using Coil_ API No: 50-029-22766 11/22/08 REH Set CIBP and Cut TBG/ CTU#9 1213/08 L. Hulme Pull 4 1/2"Tbg and set 2 718"kill string BP EXPLORATION (AK) • • Tree: Cameron 2 9116" 5M M p U L-37a Orig. DF elev. = 46.70' (N22E) Wellhead: 11" 5M FMC Gen 6, Orig. GL elev. =17.60' w/2 7/8" FMC tbg. hng., I DF to tl 9 5/8" hng. = 36.70' 2.5" CIW BPV profile o. e 111 Cameo 2 718" x 1" ' sidepocket KBMM GLM 116 . 20" Conductor Casing 112' . . . KOP @ 350' Max Hole Angle: 75° to 79° from 3750'to PBTD r Hole angle through perfs. = 77 deg. ' Cameo 2 7/8" x 1" Max DLS: 4.1' @ 3800' - sidepocket KBMM GLM 2.664' Centrilift heat trace 3,500' Intake MD = 3794' Intake MD = 6915' - 3.5"x 2 7/8 Y-Tool 6,890' Mid-pert TVD = 3983' Mid-pert MD - 7385' i Centrilift FC 925 ESP, 6,898' PBTD TVD =4303' series 450, FPMTAR 1:1, PBTD MD = 8112' • I--i, 178 Stg. Gas Separator 6,915' 5 at 9 5/8"40 ppf, L-80, Btrc. prod. casing Centrilift GSB3UT HL 6,918' ( drift ID = 8.679", cap. = 0.0758 bpf) ; , seal section, series 513 Centrilift KMH 562 series, 6,931' Stimulation Summary: 76 hp motor, 1360 v. / 34 06/20!98 - 'OA' Sand PropLok Frac ,. amps. 6,941' 60.1 M#of PropLok resin coated & Stablilizer 12-20 Ottawa sand behind pipe7 Y-Tool assembly 06/25198 - 'N' Sand Frac Pack 81.5M#of 16/20 CarboLite placed i di X-Over 3.5'x 2 718" C 6,915 2-718"HES X-Nipple(2.313"id) 6,922' Perforation Summary: -�} WLEG 6,970' Ref loo: Sperry Sun EWR 3/12/98I \ (min_grave!pack ID=3.813"at 7186'1 Size SPF Interval _ (TVD) 7,048' N' Sand 9-518"HES Versatneve pkr. 7 Frac sleeve 7,057' 4.5" 12 7140' - 7160' (3918' - 3924') % OA' Sand i ! e Screen.2G ga Pre-packed 7,135' — 9-518'HES BWD sump pkr. 7.165' 4.5" 4 7610' - 7630' (4042' -4048') I }� _ HES Durasieeve skiing sleeve 7,186' 'OA' Sand -Atlas 28 gm Jumbo Jet (big c EDT: 4.5'x 10'pup 7201' and hole" charges, EHD = 0.93". ftp = 5.2" _ PBTD Cement top 8,112' ' N ' Sand - SWS 43 gm big hole charg %,,,, , 9 518" EZSV retainer 8,162' assembly& 1.6' 42 SO and ting disc' 9-518'csg. shoe 8,212' Cement plug © 14.390' IBP bands and elements lost 1/9/06 8-1/2" hole drilled to 15,425' DATE REV.BY COMMENTS Milne Point Unit 04/12/98 MDO 9-5/8" Plugged back Nabors 22E WELL L-37 07/25/98 MDO Gravel pack & ESP Completion 4 ES API NO: 50-029-22864 BP EXPLORATION (AK) • Tree: Cameron 2 9/16" 5M Orig. KB Elev. = 51.7' (N 27E) Wellhead: 11" x 7 1/16" 5M FMC MPU L-35A Orig. GL Elev. = 17.4' Gen 5A, w/2 718" FMC tbg. Hgr 3" RT To Tbg. Spool = 34.3' (N 27E) LH acme on top and 2 718" EUE Brd on bottom, 2.5" CIW BPV profile BPV set. 20" 91.1 ppf, H-40 112' 1 joint of 2 7/8" Tbg 63' KOP @ 500 to 3,300' Diesel FP to 2000'. Max. hole angle = 3,500' - 16,000' 70 - 79 deg. 80+ 11,250'- 12,250' 8.6 ppg seawater to cement Hole angle thru' perfs = > 35 deg. plug. 9 5/8", 40#/ft, L-80 BTC. 10,510' y, 2-7/S' 6.5 ppf, L-80, EUE 8rd ( drift ID = 2.347", cap. = 0.0059 bpf) 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383bpf) Cement plug tested to 2100 psi with 30k down weight and 240 gpm wash rate. Cement plug from 16964 - 18272' Window from 18272 -18284' Old 4.5-Liner Information: T'HOWCO EZ Drill Bridge Plug 18350' 7'x 5"BOT ZXP Liner Top Packer 18353' BOT-HMC'Liner Hanger 18366' RA Tag 0 18671 Kup C 8 B Sands 18660'-18690'(6538'-6562'TVD) Kup A Sands 18796-18828'(6650-6676 TVD) 6 1/8" hole drilled to 19181' 4.5"Landing Collar(PBTD) 19049' 4+5"Float Shoe 19220' DATE REV. BY COMMENTS MILNE POINT UNIT 6-27-97 MDO Cased hole completion 27E WELL No. : L-35A 12-13-97 MDO ESP Completion Nabors 4ES API : 50-029-22768-01 PTD: 201-109 6/11/98 M. Linder RWO 27-E 10/13/01 L. Hulme Sidetrack attempt- Nabors 27E BP EXPLORATION (AK) • 0 Pesado-O L +/`'1 P&A Orig. KB Elev. = 54.3. Orig. GL Eley. = 23.2" Minsmum 150 - 15.7 ppg AS 1 Cement e . —20' Conductor Casing at-80 MD 11 —9.516' CLOP at 250`MD NOTE- Surface casing and con- 9 9.4 cog 1waCt 9rine ducto,r casing to be cut below ground level and removed- An Abandonment Marker will be installed per AOGCC regulations. TOG-2955' MO s I -112'KOP-3255'MDI* 9-5113', 400.11..L-90 BTC at-3255'MO (Peeado-01A) (Fully Cemented to Surface) 15.7 ppg AS1 Cemenl a 'Remaans-of 170 ppg G Gement fl-3341'to-290r MD 8 Kick-Off Plug ti-3473'MD to-3280'MD 0 - • . 0= _ 4.. P 4 a C 0 a a 0 , 0 8. i - e z. .• .. , .. a 15,8 prig 0 0 it Ii Gement fr-3840'- w xl -3341,MD at . 8 , , 15.5 ppp 0 Gement 0 , f�-3473'to-398:5'MD C 0 a _ • C 3pac • • R a a :s 4 a -. C 0 a " a. a 0 ' . • 15.8pog a a , Cement a 4r 15..8 ppg 0 Cement f r-4339' �..r�••"i, If-3985'10-4497"MID I -3840'MD a •to 0a a a a . a * a ,, 4/. `.. Pesado-O t A Pesado-01 Open-HoleTD TD -4339'MD I 4286'TVD 4497'MD 1 4391'TVD DATE REV BY COMMENTS MILNE POINT UNIT 01125/07 JCR ; Final P&A Schematic Pesado-01 & 01A 04.11 07 JGR Application fISundry Approval Weilbores WIC/ 7" Casing in the 01 Leg BP EXPLORATION (AK) • • Hilcorp Alaska, LLC Milne Point Unit (MPU) L-52 Drilling Program Version 1 12.7.2017 1E1 • i Milne Point H11ilC0� L-52 SB N Injector gycomr Drilling Procedure 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 13-5/8"5M Diverter Configuration 12 11.0 Drill 12-1/4"Hole Section 14 12.0 Run 9-5/8" Surface Casing 17 13.0 Cement 9-5/8" Surface Casing 22 14.0 BOP N/U and Test 27 15.0 Drill 8-1/2"Hole Section 28 16.0 Run 4-1/2"Injection Liner(Lower Completion) 31 17.0 Run 4-1/2" Tubing-Upper Completion 38 18.0 RDMO 39 19.0 Innovation Rig Diverter Schematic 40 20.0 Innovation Rig BOP Schematic 41 21.0 Wellhead Schematic 42 22.0 Days Vs Depth 43 23.0 Formation Tops &Information 44 24.0 Anticipated Drilling Hazards 45 25.0 Innovation Rig Layout 47 26.0 FIT Procedure 48 27.0 Innovation Rig Choke Manifold Schematic 49 28.0 Casing Design Information 50 29.0 8-1/2"Hole Section MASP 51 30.0 Spider Plot(NAD 27) (Governmental Sections) 52 31.0 Surface Plat(As Built) (NAD 27) 53 32.0 Schrader Bluff NB Sand Offset MW vs TVD Chart 54 33.0 Drill Pipe Information 5" 19.5# S-135 DS-50&NC50 55 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well MPU L-52 Pad Milne Point"L"Pad Planned Completion Type 4-1/2"Injection Tubing Target Reservoir(s) Schrader Bluff N Sand Planned Well TD,MD/TVD 13,778' MD/3,741' TVD PBTD,MD/TVD 13,768' MD/3,741' TVD Surface Location(Governmental) 3732'FSL, 5227'FEL, Sec 8,T13N, R10E,UM,AK Surface Location(NAD 27) X=544648.93,Y=6031919.76 Surface Location(NAD 83) X= 1684680.02,Y=6031672.39 Top of Productive Horizon (Governmental) 717'FSL,2142'FWL, Sec 7, T13N,R10E,UM,AK TPH Location(NAD 27) X=541580.24,Y=6028887.54 TPH Location(NAD 83) X= 1681611.35Y=6028640.07 BHL(Governmental) 1201'FNL, 588'FWL, Sec 19, T13N,R10E,UM,AK BHL(NAD 27) X=540065.00,Y=6021682 BHL(NAD 83) X= 1680096.17,Y=6021434.37 AFE Number 1713437 AFE Drilling Days 18 days AFE Completion Days 6 days AFE Drilling Amount $3,799,350 AFE Completion Amount $2,435,968 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1399 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1778 psig Work String 5" 19.5# S-135 DS-50&NC 50(Weatherford Rental) KB Elevation above MSL: 26.5 ft+ 15.7 ft=42.2 ft GL Elevation above MSL: 15.7 ft BOP Equipment 13-5/8"x 5M Annular, (3)ea 13-5/8"x 5M Rams Page 2 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Enemy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Heil Changes to Approved Permit to Drill Date: 12-04-2017 Subject: Changes to Approved Permit to Drill for MPU L-52 File#: MPU L-52 Drilling and Completion Program Any modifications to MPU L-52 Drilling &Completion Program will be documented and approved below. Changes to an approved PTD will be communicated to and approved by the AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Rev 1 October 2017 • Milne Point Unit L-52 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) 6r (psi) (psi) (k-lbs) Cond 16" 15.25" - - A-53 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.235" 40 L-80 DWC 5,750 3,090 916 8-1/2" 4-1/2" 3.96" 3.795" 4.714" 13.5 L-80 H625 9020 8540 279 Tubing 4-1/2" 3.958" 3.833" 5.250" 12.6 L-80 TTP-SR 8,430 7,500 288 4.0 Drill Pipe Information: Hole OD ID (in) TJ ID TJ OD Wt Grade Conn M/U Tension Section (in) (in) (in) (#/ft) (Min) (Max) (k-lbs) Surface & 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560klb Production 5" 4.276" 3.25" 6.625" 19.5 S-135 NC50 31,032 34,136 560klb All casing will be new,PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 5.0 Internal Reporting Requirements 5.1 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. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Detailed Daily Plan Forwards • Distributed to jengel@hilcop.com and pmazzolini@hilcop.com 5.3 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, jengel@hilcorp.com and cdinger@hilcorp.com 5.4 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.5 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drilling Manager&Drilling Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 5.6 Casing Tally • Send final"As-Run" Casing tally to pmazzolini@hilcorp.com,jengel@hilcorp.com and cdinger@hilcorp.com 5.7 Casing and Cmt report • Send casing and cement report for each string of casing to pmazzolini@hilcorp.com, jengel@hilcorp.com and cdinger@hilcorp.com 5.8 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Paul Mazzolini 907.777.8369 907.317.1275 pmazzolini@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Completion Engineer Paul Chan 907.777.8333 907.444.2881 pchan@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Rev 1 October 2017 I • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 6.0 PlanHned Wellbore Schematic Milne Point Unit Well:MPU L-52 SCHEMATIC Last Completed: nilcorl,Ala,k:..I.11. PTD: KB Elev.:42.2'/a Elev.:15.7 OPEN HOLE/CEMENT DETAIL " 16" 270 ft3 16' } 9-5/8" Stg 1—1606 ft3/Stg 2 2174 ft3 '4 4-1/2" Cementless Injection Liner in 8.5"hole 9 I'; II' CASING DETAIL N 0+j� N 7 Size Type Wt/Grade/Conn Drift ID Top Btm BPF )E 16" Conductor 164/A-53/Weld N/A Surface 107' N/A 9-5/8" Surface 40/1-80,"DWC 6.151 Surface 6,350' 0.0383 N 4-1/2" Liner 13.5/L-80/Hydril 625 3.920 6,200' 13,779' 0.0149 't4 (y TUBING DETAIL 1.'1) I 4-112" I Tubing I 12.6/L-80/TXP-SR I 3.833 I Surf I 6,200' I 0.0152 C.5 ti 7 WELL INCLINATION DETAIL �.�yj Lt KOP @ 450' '<"', _��t Max Hole Angle=92 deg b. w 3, '�+ JEWELRY DETAIL >< f r No. I Top MD I Item I ID "-' V. 4 5L„� Upper Completion T"� 2 ±5,700' 4.5'XN Nipple,3.725"No-Go,3.813"Packing Bore 3.725" Lower Completion E * 3 6,200' Baker Liner Hanger/Liner Top Packer F' 4 See Below 4-1/2'13.5 R/ft Weatherford ICD with Sliding Sleeve i 5 See Below 5-1/2"17>r,/ft Swell Packers 4u2„ , 6 13,779' 4-1/2"Shoe J ;II ri 2 y r f. a ti, '64'-' ICD DETAIL SWELL PACKER DETAIL ;j No Depth ICD Detail Top(MD) Btm(MD) 9 $" S. 1(r 511' 1 TED 4-1/2"13.5#Hyd 625 BxP WOT ICD w/Sliding Sleeve TBD TBD 2 TED 4-1/2"13.5#Hyd 625 ExMP WOT ICD w,/Sliding Sleeve T80 TBD 1,J,_,,,_, 3 TED 4-1/2'13.5#Hyd,625 BxP WOT CD w/Sliding Sleeve TBD TBD i 4 TED 4-1/2"13.5#FM,625 BxP WOT ICD w/Sliding Sleeve ts,��� 5 TED 4-1/2"13.54 d 625 BxP WOT ICD w/Sliding Sleeve TED TED 6 Ity TED 4-1/2"13.5#Hyd 625 Be,WOT CD au/sliding Sleeve TED TED TED 7 TED 4-1/2"13.5#Hvd 625 BxP,WOT CD w/Sliding Sleeve TBD TED TED See .y IC is svea Pw Dema 4-1/2" � GENERAL WELL INFO I API:TBD Completion Da:e:TBD I .37 TD=13,779'(MD)/TD=3,742'ITVD) PBTD=13,768'(MD)/PBTD=3,741'(TVD) Page 6 Rev 1 October 2017 1 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary MPU L-52 is a grassroots injector planned to be drilled in the Schrader Bluff NB sand. L-52 is part of a six well program targeting the NB sand. The directional plan is a catenary wellpath build, 12.25"hole with 9-5/8"surface casing set into the top of the Schrader Bluff NB sand. An 8.5"lateral section will then be drilled. A 4.5"liner will be run in the open hole section. The Innovation Rig will be used to drill and complete the wellbore. Estimated spud date 12/22/2017. Surface casing will be run to 6,350' MD/3,956' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observes, 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"B"pad G&I facility. ( General sequence of operations: 1. MIRU Innovation to well site 2. N/U &Test 13-5/8"Diverter and 16" diverter line 3. Drill 12-1/4"hole to TD of surface hole section. Run and cement 9-5/8" surface casing. 4. N/D diverter,N/U &test 13-5/8"x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 4-1/2" injection liner. 6. Run 4-1/2"tubing. 7. N/D BOP,N/U Tree, RDMO. Reservoir Evaluation Plan: J 1. Surface hole: No mud logging. On Site geologist. LWD: GR+Res 2. Production Hole:No mud logging. On site geologist. LWD: GR+ADR(For geo-steering) Page 7 Rev 1 October 2017 S Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2)week intervals during the drilling and completion of MPU L-52. 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 API). • Ensure that all BOPE test results are submitted to the AOGCC within 24 hours after completing the test, as per 20 AAC 25.035(e)(10)(G)(1). o All results must be emailed to jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov; mmyers@hilcorp.com;jengel@hilcorp.com and cdinger@hilcorp.com. • If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore,AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivard@hilcorp.com for submission to AOGCC. • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Page 8 Rev 1 October 2017 • • Milne Point Unit 11 1-52 Producer Drilling Procedure Hilcorp Energy Company • Hilcorp Alaska proposes to demonstrate isolation of the injected fluid as required under 20 AAC 25.412 (d)through cement job operational reports of a complete two stage cement job on the 9-5/8" surface casing. Planned surface cement volumes and cement returns to surface seen during both stages will indicate placement of cement in the entire surface casing annulus. A successful FIT after surface casing drill out will demonstrate isolation of injection fluid. AOGCC Regulation Variance Requests: Hilcorp Alaska respectfully requests a variance to AOGCC regulation 20 AAC 25.412(b). MPU L-52 is a Schrader Bluff horizontal well completed with injection control devices (ICD) and swell packers, 4„, with the production packer— 500' from the first ICD, and 150' inside the casing shoe as per 20 AAC 25.030(d)(6). The 9-5/8"passing FIT proves isolation of the injection fluid to the Schrader Bluff interval. Va,ok-nc . `t,,,,41- W -)2eJ . • , + . 1-e— 414" (Nov-ce."4 1 0 ii e-tnvisl4trr,...: , IC b dz.i s K)( ham„__:__. 2 . P" :,,- Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12 1/4" • 13-5/8"5M CTI Annular BOP w/16"diverter line Function Test Only • 13-5/8"x 5M Control Technology Inc Annular BOP Initial Test:250/3000 • 13-5/8"x 5M Control Technology Inc Double Gate o Blind ram in btm cavity • Mud cross w/3"x 5M side outlets 8-1/2" • 13-5/8"x 5M Control Technology Single ram • 3-1/8"x 5M Choke Line Subsequent Tests: • 3-1/8"x 5M Kill line 250/3000 • 3-1/8"x 5M Choke manifold • Standpipe,floor valves,etc Primary closing unit: Control Technology Inc. (CTI), 6 station,3000 psi,220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Page 9 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email:Victoria.loepp@alaska.gov Primary Contact for Opportunity to witness:AOGCC.Inspectorsalaska.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) 9.0 R/U and Preparatory Work 9.1 L-52 will utilize a newly set 16" conductor on L Pad. Ensure to review attached surface plat . d make sure rig is over appropriate conductor. 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 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 cement job, and also to wash out the diverter and hanger in preparation for running the pack-off. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat over footprint of rig. 9.7 Confirm that the rig is over the appropriate well slot. 9.8 MIRU Innovation Rig 9.9 Mud loggers WILL NOT be used on either hole section. 9.10 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 9.11 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it i§ accidentally dropped. 9.12 Ensure 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5%volumetric efficiency. Page 10 Rev 1 October 2017 • ! Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company Page 11 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 10.0 N/U 13-5/8" 5M Diverter Configuration 10.1 N/U 13-5/8" CTI BOP stack in diverter configuration(Diverter Schematic in Sec 21 of program). • N/U 16" SOW • N/U 13 5/8", 5M diverter"T". • NU Knife gate & 16"diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source ;;/ • Place drip berm at the end of diverter line. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 12 Rev 1 October 2017 • fa Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 10.5 Rig & Diverter Orientation: \ \ I I \ 49 1 \\ I / +$E-59 +$+�- I — _ ■32 ■33 I , I ■28 •29 1 I •24 ■25 •20 •21 ■16 ■17 '\ ,yam CQ ■41 •43 L— 3 + L-56 2 + L— 1 + L-54 32 11 33 / 13 ■ ■ 8 / 39 • • 42 75'Radius Clear of Ignition Sources 1 ■ ■ 8 34 ■ • 14 3 ■ ■ 10 15 ■ ■ 47 2 • • 7 —Diverter Line ■ 12 ■ 40 • • •• • • • •• •• 6 35 4 36 5 37 11 50 p HO i 1 i \ I MPU L-Pad \ I *Drawing Not To Scale 1 i Page 13 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside component, 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. • Drill string will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 11.2 5"Drill string, HWDP, and Jars will come from Weatherford. 11.3 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. • 11.4 Drill 12-1/4"hole section to TD as per geologist and drilling engineer. • Monitor the area around the conductor for any signs of broaching. If broaching is observe,, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. Keep DLS <6 deg/ 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost.✓ • Pump at 400-600 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Based upon hole conditions and hole cleaning, discuss making wiper trips as necessary • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability, ensure MW is at a 9.2 at TD. • TD the hole section just into the Schrader Bluff sand. Geologists and Drilling Engineers 11 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 o t all gas cut mud before continuing to drill. There have been no indications of hydrates on . y of the "L"pad wells to date. • Watch for flowline pack-off issues, which have been seen in the first 300' of previous surf.ce holes. Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pack offs. Page 14 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp 11.5 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 and TD with 9.2+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 system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP<20 (check with the cementers to see what YP value they have targeted). System Type: 8.8-9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8—9.2 75-175 20-40 25-45 <10 8.5—9.0 <70°F 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 15 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 11.6 At TD; PU 2-3 stands off bottom, CBU,pump tandem sweeps and drop vise, 11.7 RIH t/bottom,proceed to BROOH t/HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5— 10 ft/minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.8 No open hole logging program planned. Page 16 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 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(CRT& Tongs) • Ensure 9-5/8"DWC x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/paint brush. • 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 join over stop collars 10' from each end. • (1) Joint with float collar bucked on pin end&thread locked. Install (1) centralizer mid to se over a stop collar. • (1)Joint threadlocked (Total of 2 joints between float collar and baffle collar) • Ensure bypass baffle is correctly installed on top of float collar. Bypass Baffle This end up. ,�� gook 4%,� • (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 17 Rev 1 October 2017 • II Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 1 12.6 Float equipment and Stage tool equipment drawings: "A --- Overall Length Type H ES Cementer _ipB Part No. Mm.ID After Drillout SO No. C Max.Tcol GSD 111 DHikorp ES-ll Running Order Opening Seat ID A Closing Sleeve f No.Shear Pins E Closing Sear C. _.Dy Opening Sleeve C i No.Shear Pins Plug Set ESA Cementer ES Cementer Part No. B—► Depth j J SO No. gm Closing Plug 11111111111/ MEW Baffle Adapter(if used) im OD Shu[On Plug AID Opening Plug ;, Depth OD Baffle Adapter OD a 1_______NI Bypass or Shut-off Baffle • ll ID II Ir. __ - By-Dass Plug Depth Shu:-off Plug - Float Collar 11111,111� Depth T MAs6111e l T OD Float Carer Float Shoe D71 epth .47:" Bypass Plug (if used) go ..,, i Hole TD fbetShoe "Reference Casing ra OD Sales Manual _ Section 5 Page 18 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 12.7 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/paint brush. • Install (1) centralizer every joint t/— 1000' MD from shoe, 1 centralizer every 2 joints to 2,000' above shoe (Top of Ugnu) • Verify depth of lowest Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferabl- to POH with casing and condition hole than to risk not getting cement returns to surface. 12.8 Install the Halliburton Type H ES- I Stage tool so that it is positioned at least 100' TVD belo the permafrost ('—2,500' MD). • 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. This will allow the tool to open at 3300 p.i. 9-5/8" 40#L-80 DWC Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 29,800 ft-lbs 34,800 ft-lbs Page 19 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Casing 9-5/8 in 40.00 Ib/ft(0.395 in) L-80 standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) 111111.111111111111111111111,VBA 95,000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston,TX 77041 Phone:713-479-3200 9.625 Nominal Pipe Body O.D. (in) Fax:713-479-3224 8.835 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsaiesi vam-usa.com 0.395 Nominal Wall Thickness (in) 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) 5,750 Minimum Internal Yield Pressure (psi) 5;300 Hydrostatic Test Pressure {psi) Connection Dimensions 10.625 Connection O.D. (in) 8.835 Connection I.D. (in) 8.750 Connection Drift Diameter(in) 4.81 Make-up Loss (in) , 11.454 Critical Area (sq in) 100.0 Joint Efficiency (%) Connection Performance Properties 916,000 Joint Strength (lbs) 16,360 Reference String Length (ft) 1.4 Design Factor 947,000 API Joint Strength (lbs) 916,000 Structural Compression Rating (lbs) 3,090 API Collapse Pressure Rating (psi) 5.750 API Internal Pressure Resistance (psi) 19.0 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoxlmated Field End Torque Values 29,800 Minimum Final Torque (ft-lbs) 34,800 Maximum Final Torque (ft-lbs) 39,800 Connection Yield Torque (ft-lbs) Page 20 Rev 1 October 2017 411) Milne Point Unit L-52 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 landing joint and M/U to casing string. Position the casing shoe+/- 10' from TD. Strap the landing joint prior to the casing job and mark the joint at(1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to <20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 21 Rev 1 October 2017 411 Milne Point Unit L-52 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 cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all iron lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug(flexible bypass plug)—HEC rep to witness. Mix and pump cement per below calculations for the 1St stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume+30% open hole excess. Job will consist of lead& tail, TOC brought to stage tool. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol(ft3) 12-1/4" OH x 9-5/8" Casing (5,350'- 2500')x .0558 bpf x 1.3 = 207 bbls 1161 ft3 annulus: Total LEAD: 207 bbls 1161 ft3 12-1/4" OH x 9-5/8" Casing (6,350'- 5,350') 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 15.8 ppg TAIL: 79.3 bbl 445 ft3 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company Cement Slurry Design: Lead Slurry Tail Slurry System ExtendaCEM TM System SwiftCEM TM System Density 12.0 lb/gal 15.8 Ib/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. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and contin e with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out o mud pits, spotting water across the HEC stage cementer. a. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be ve accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 6350' x .0758 bpf=—482 bbls 80 bbls of water must be left across stage tool to ensure proper operation once opened. OACE wAT G Z --73u 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume,+3.4 bbls before consulting with Drilling Engineer. Page 23 Rev 1 October 2017 Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Eneisr CompAny 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the fee 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. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats, are holding. If floats do not hold,pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure (*4 may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP <20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 24 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company Second Stage Surface Cement Job: 13.18 Prepare for the 2nd stage as necessary. Circulate until 1 stage reaches sufficient compressive strength. Hold pre job safety meeting. 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume+open hole excess (200% for lead and 100% for tail). Job will consist of lead &tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol(ft3) 16" Conductor x 9-5/8" (110')x .135 bpf x 1 = 14.8 bbls 83.6 ft3 casing annulus: 12-1/4" OH x 9-5/8" Casing (2000'- 110') x .0558 bpf x 3 = 316 bbls 1776 ft3 annulus: Total LEAD: 330.8 bbls 1860 ft3 12-1/4" OH x 9-5/8" Casi annulu •g (2500'- 2000')) x .0558 bpf x 2 = •55.8 314 ft3 Total TAIL: 55.8 bbls 314 ft3 Cement Slurry Design (2nd stage cement job): Lead Slurry Tail Slurry System Permafrost L Type I/II Density 11.1 lb/gal 14.5 lb/gal Yield 4.3279 ft3/sk 1.39 ft3/sk Mixed 21.405 gal/sk 6.8 gal/sk Water Page 25 Rev 1 October 2017 4111 Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 13.24 Continue pumping lead until uncontaminated spacer is seen at surface,then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud o of mud pits. 13.26 Displacement calculation: 2500' x .0758 bpf=—189.5 bbls mud IV 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead si•e outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump • t fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We sho ld circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1000— 1500 psi to ensure stage tool close.. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage too ' has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips and L/D landing joint. 13.30 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packof i.' Run in lock downs and inject plastic packing element. Pressure test packoff. 13.31 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& le 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 inP lace 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 jengel@hilcorp.corn and cdin er hilcor .com This will be included with the EOW documentation that goes to the AOGCC. g @ P Page 26 Rev 1 October 2017 110 I Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the diverter T, 16"knife gate, 16" diverter line &N/U 11" x 13-5/8" 5M casing spool. 14.2 N/U 13-5/8"x 5M CTI BOP as follows: • BOP configuration from top down: 13-5/8"x 5M annular/ 13-5/8" x 5M double gate / 13 5/8"x 5M mud cross/ 13-5/8"x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5.5" VBRs in top cavity, blind ram in bottom cavity. • Single ram should be dressed with 2-7/8" x 5.5" VBRs • N/U bell nipple, install flowline. _.----- • ----• Install (1) manual valve &HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1)manual valve &HCR valve on choke side of mud cross. (manual valve closest to mud cross) 14.3 Run 5"BOP test assembly, 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. • Confirm test pressures with PTD • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does no build up beneath the test plug. 14.4 R/D BOP test equipment 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.7 Set 10" ID wearbushing in wellhead. 14.8 Rack back as much 5"DP in derrick as possible to be used while drilling the hole section. 14.9 Install 5" liners in mud pumps. Page 27 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.15° PDM) 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 R/U and test casing to 3000 psi/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 he well i. 3,000 psi. 15.5 Drill out shoe track and 20' of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12 ppg EMW. Chart Test. Com" Ih 15.8 POOH& LD Cleanout BHA 15.9 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 th.t 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. • Drill string will be 5" 19.5# S-135 DS50 &NC50. • Run a ported float in the surface hole section. 15.10 8-1/2"hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system(1)pp 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 ens e we are running the finest screens possible. Page 28 Rev 1 October 2017 Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company • Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is> 8.5 (hole diameter) for sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9—9.5 ppg Baradrill-N drilling fluid Properties: Depths Density Plastic Viscosity Yield Point Total Solids MBT HPHT 6350— 13778 8.9-9.5 15-25 20-25 <10% <7 <11.0 System Formulation: Baradrill-N Product Concentration/Function Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N-VIS 1.0— 1.5 ppb N-DRIL HT PLUS 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.15 b 15.11 TIH w/ 8-1/2" directional assembly to bottom. 15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid. 15.13 Being drilling 8.5"hole section, on-bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8 4. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations pulsed up real time. Page 29 Rev 1 October 2017 4 a Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company • If BHA begins to show excessive vibrations/whirl/stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. 15.8 Drill 8-1/2"hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm,target AV's 200 ft/min, 385 gpm • RPM: 120+ • Ensure shaker screens are set up to handle this flowrate. Ensure shakers set to maximize solids removal efficiency. Check for holes in screens on every connection. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1500—2000 ft, if necessary. • Take MWD surveys every stand. • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD trends for hole cleaning indication • 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 formation top and bottom • Limit maximum instantaneous ROP to <200 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Previous NB sand wells have seen upwards of 3% of total lateral length as concretions 15.9 Reference: Open hole sidetracking practice: • If a known fault is coming up, put a slight"kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.10 At TD, CBU minimum 4 times at maximum circulation and rotation. Pump tandem sweeps if needed • Injection wells do not require Production Screen Tests 15.11 TOH/BROOH with the drilling assembly to the 9-5/8"casing shoe. If backreaming is necessary: • Circulate at full drill rate (350-550 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 15.12 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. 15.13 POOH& LD BHA Page 30 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 16.0 Run 4-1/2" Injection Liner (Lower Completion) 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2" liner with ICD and swell packers,the following well control response procedure will be followed: • P/U & M/U the 5" safety joint (with 4-1/2" crossover installed on bottom, TIW valve in open position on top, 4-1/2"handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 4-1/2" screen. • Slack off and position the 5"DP across t ems, shut in ram or annular on 5"DP. Close TIW valve. • Proceed with well kill operations. 16.2. Confirm VBR have been tested on 4-1/2" and 2-3/8"test joints to 250 psi low/3000 psi high. 16.3. In the event of an influx of formation fluids while running the 2-3/8" inner string inside the 4- 1/2"production screens: -'"�— • P/U &M/U the 5" safety joint(with 4-1/2"x 2-3/8"triple connect crossover installed on owlbottom, TIW valve in open position on top, 2-3/8"handling joint above TIW). M/U 2-3/8" "/\ and then 4-1/2"to triple connect. .11 • This joint shall be fully M/U with crossovers and available prior to running the first joint of wash pipe. • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. Proceed with well kill operations. 16.4. R/U 4-1/2" screen running equipment. • Ensure 4-1/2"Hydril 625 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. 16.5. Run 4-1/2"injection liner. • Use API Modified or"Best 0 Life 2000 AG"thread compound. Dope pin end only w/paint brush. Wipe off excess. Thread compound can plug the ICDs. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Fill 4-V2" liner with clean completion brine (to keep from plugging ICDs with solids) • Install ICDs and swell packers as per the Running Order(Estimate 7 evenly spaced). • Do not place tongs or slips on swell packer elements or ICDs. • ICD and swell packer placement±40' • The ICD connection is 4-1/2" 13.5#Hydril 625 • Remove protective packaging on swell packers just prior to picking up Page 31 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 4-1/2" 13.5# L-80 Hydril 625 torques Casing OD Minimum Optimum Maximum Yield Torqu Operating Torque 4.5" 8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs 15,000 ft-lbs 4-�/2" Lower Completion Running Order • 4-1/2" Round Nose Float Shoe w/ 12.6#/ft BTC Box • 4-1/2" WIV w/ 11.6#/ft BTC bxp • 4-1/2" Spacer/Crossover Joint IBT-M Box x BTC Pin • 4-'/2" Drillable Packoff w/ 12.6 #/ft IBT-M bxp • Crossover 4-1/2" 13.5#L-80 Hydril 625 Box x 4-1/2" 12.6#L-80 IBT-M Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • 4-1/2" 13.5#/Ft Hydril 625 bxp, Weatherford FloReg ICD w/ 16 Nozzles @ TBD' MD • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • Crossover 5-1/2" 17# L-80 DWC/C Box x 4-1/2" 13.5#L-80 Hydril 625 Pin • 5-1/2" Tendeka Swell Packer#7 w/ 5-1/2" 17# L-80 DWC/C bxp @ TBD' MD • Crossover 4-1/2" 13.5# L-80 Hydril 625 Box x 5-1/2" 17# L-80 DWC/C 625 Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • 4-1/2" 13.5#/Ft Hydril 625 bxp, Weatherford FloReg ICD w/ 16 Nozzles @ TBD' MD • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • Crossover 5-1/2" 17# L-80 DWC/C Box x 4-1/2" 13.5# L-80 Hydril 625 Pin • 5-1/2" Tendeka Swell Packer#7 w/5-1/2" 17# L-80 DWC/C bxp @ TBD' MD • Crossover 4-1/2" 13.5# L-80 Hydril 625 Box x 5-1/2" 17# L-80 DWC/C 625 Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • 4-1/2" 13.5#/Ft Hydril 625 bxp, Weatherford FloReg ICD w/ 16 Nozzles @ TBD' MD • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • Crossover 5-1/2" 17# L-80 DWC/C Box x 4-1/2" 13.5#L-80 Hydril 625 Pin • 5-1/2"Tendeka Swell Packer#7 w/5-1/2" 17#L-80 DWC/C bxp @ TBD' MD • Crossover 4-1/2" 13.5# L-80 Hydril 625 Box x 5-1/2" 17# L-80 DWC/C 625 Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner Page 32 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company • 4-1/2" 13.5#/Ft Hydril 625 bxp, Weatherford FloReg ICD w/ 16 Nozzles @ TBD' MD • 4-%2" 13.5 #/ft Hydril 625 L-80 Liner • Crossover 5-1/2" 17# L-80 DWC/C Box x 4-1/2" 13.5#L-80 Hydril 625 Pin • 5-1/2" Tendeka Swell Packer#7 w/5-1/2" 17# L-80 DWC/C bxp @ TBD' MD • Crossover 4-1/2" 13.5# L-80 Hydril 625 Box x 5-1/2" 17#L-80 DWC/C 625 Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • 4-1/2" 13.5#/Ft Hydril 625 bxp, Weatherford FloReg ICD w/ 16 Nozzles @ TBD' MD • 4-'/2" 13.5 #/ft Hydril 625 L-80 Liner • Crossover 5-1/2" 17# L-80 DWC/C Box x 4-1/2" 13.5#L-80 Hydril 625 Pin • 5-1/2" Tendeka Swell Packer#7 w/ 5-1/2" 17#L-80 DWC/C bxp @ TBD' MD • Crossover 4-1/2" 13.5#L-80 Hydril 625 Box x 5-1/2" 17# L-80 DWC/C 625 Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • 4-1/2" 13.5#/Ft Hydril 625 bxp, Weatherford FloReg ICD w/ 16 Nozzles @ TBD' MD • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • Crossover 5-1/2" 17#L-80 DWC/C Box x 4-1/2" 13.5#L-80 Hydril 625 Pin • 5-1/2" Tendeka Swell Packer#7 w/5-1/2" 17# L-80 DWC/C bxp @ TBD' MD • Crossover 4-1/2" 13.5# L-80 Hydril 625 Box x 5-1/2" 17# L-80 DWC/C 625 Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • 4-1/2" 13.5#/Ft Hydril 625 bxp, Weatherford FloReg ICD 6 Nozzles @ TBD' MD • 4-1/2" 13.5 #/ft Hydril 625 L-80 Liner • Crossover 5-1/2" 17# L-80 DWC/C Box x 4-1/2" 13.5#L-80 Hydril 625 Pin • 5-1/2" Tendeka Swell Packer#7 w/5-1/2" 17# L-80 DWC/C bxp @ TBD' MD • Crossover 4- ' 1 .5# L-80 Hydril 625 Box x 5-1/2" 17# L-80 DWC/C 625 Pin • 4-1/2" 13.5 #/ft Hydril 625 L-80Line • 4' pup joint 4-1/2" 13.5 #/ft Hydril 625 L-80 • Crossover 7"26# L-80 Hydril 563 Box x 4-1/2" 13.5# L-80 Hydril 625 • 9-5/8" Flex Lock Liner Hanger, DWC/C pin x Hydril 563 pin • 9-5/8" ZXP Liner Top Packer, DWC/C box Page 33 Rev 1 October 2017 0 • 11 Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company For the Latest performance data.always visit our website:www.tenaris.com Wedge 625® ..-12/04 17 :1D Outside Diameter 4.500 m. Mm.Wall 87.5 Thickness r)Grade LOU alig‘' Type 1 Wall Thickness 0_290 r. Connection OD REGULAR IF Option COUPLING PIPE BODY Body:Red 1st Ban::Red ag.m., Grade L80 Type"!• Drift API Standard 1st Bid:Brown 2n::Band: timmi' 2nd Band:- Brown Type Casing 3rd Band:- 3ro Band:- 4th Band:- PIPE B.-JOY DAT2*-, GEOMETRY Nominal OD 4.500 in. Nominal Weirt 13.90cs'ft Drift 3.795 In. Martina!ID 3.920 in. Wal Thickness 0.290 "! Plain E,..r:Weight 13.09-r.st CO Tolerance API PERFORMANCE Body Yield Strength 307 xICOD lbs Internal vield 9020 ps StalY2 80000 ps iCollwse 8540 psi 1 f-(_)?'N i 4 'E ITION DATA GEOMETRY Co nneLt-or OD . Threads pe,in &Mit Connector' ..ID 3.849 it Make-up Loss 4/30 in. 3.59 Connect OD Option REGULAR PERFORMANCE Tension Efficiency 91.0% Joint Yield Strength 279.370 x1300 Internal Pressure Capacity 9020.000 osi lbs Conression Efficency 94.9% Compression Strength 290.115 x`CCC Max A-oldable Bending 73.7'flee ft lbs External Pressure Capacity 8540.000 psi MAKE-UP TORQUES Minimum 8000 ft-lbs Optimum 9600 ft4bs Maximum 121100 It-lbs OPERATION LIMIT TORQUES Cperatmg Torque 12800 ft-lbs Yield Torque 15000 ft-lbs Notes For further inforrnalkm on concepts indicated in this datasheet,download the Datasheet Mann!from www.tenaris.al Page 34 Rev 1 October 2017 • Milne Point Unit risL-52 Producer Drilling Procedure Hilcc2 16.6. Ensure that the liner top packer is set— 150' MD above the 9-5/8" shoe. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings per 20 AAC 25.030(d)(6). Ensure hanger/packer will not be set in a 9-5/8" connection. 16.7. R/U false rotary and run 2-3/8" 4.7#/ft Inner String 16.8. Once inner string is run and set inside packoff, displace 9-5/8" casing back to PST passed drilling mud with lubes added. 16.9. 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. 16.10. M/U Baker ZXP liner top packer to inner string and 4-1/2" liner. 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. 16.11. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure clear flow path exists. 16.12. RIH w/liner on DP no faster than 30 ft/min—this is to prevent bucking the liner and drill strin:. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. Fill liner with clean brine if needed. 16.13. The liner and inner string will prevent the DP from auto filling. Fill DP with clean brine every . stands,more frequently if SOW trend indicates. 16.14. 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 strint, to bottom. 16.15. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 0 and 20 rpm 16.16. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensur- shoe enters correct hole. 16.17. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.18. Rig up to pump down the work string with the rig pumps. Page 35 Rev 1 October 2017 Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 16.19. 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. 16.20. Rig up to pump down the work string with the rig pumps. 16.21. Break circulation and begin displacing wellbore to—9.2 ppg KC1/NaC1 (adjust brine weight if needed). Note the large OD on the ICDs. Begin circulating at—1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. 16.22. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the . ICDs. Note all losses. Catch mud for future use if feasible. 16.23. Monitor the returned fluids carefully and when no more filter cake appears at the shaker begin • pumping SAPP pill. 16.24. Mix and pump 40 bbl 10 ppb SAPP pill. Keep circulation rate low to keep from packing off • around the ICDs. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. 16.25. Repeat pumping SAPP pills as needed until the wellbore is clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 16.26. Displace entire wellbore to completion fluid(-9.2 ppg KC1/NaC1). Pump at 10-12 bpm. Monitor the returned fluids to ensure as much mud has been removed from the wellbore as possible. 16.27. Shut down pumps. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to shift the wellbore isolation valve closed. 16.28. Continue pressuring up to 2700 psi to set the ZXP liner hanger/packer._ Hold for 5 minutes. Slack off 20K lbs on the ZXP to ensure the HRDE setting tool is in compression for release from 5*"Ad' the ZXP liner hanger/packer. Continue pressuring up 4100 psi to neutralize and release running tools. 16.29. Bleed DP pressure to zero, Pick up to expose Rotating Dog Sub and set down 50k#without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k# again, 16.30. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 r10 min and chart record same. 1A- /ci r — 16.31. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.32. P/U above liner top packer and displace well to completion fluid. Page 36 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 16.33. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. L/D 2-3/8" inner string. 16.34. RIH w/remaining DP out of derrick and L/D same. Page 37 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 17.0 Run 4-1/2" Tubing — Upper Completion 17.1 M/U injection assembly and RIH to setting depth. TIH no faster than 90 ft/min. • Ensure 4-'/2" TXP-SR(or Buttress)x NC-50 crossover is on rig floor and M/U to FOSV. • Ensure all tubing has been drifted in the pipe shed prior to running. • Be sure to count the total # of joints in the pipe shed before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. • Monitor displacement from wellbore while RIH. 4-1/2" Upper Completion Running Order • 4-1/2"Baker Ported Bullet Nose seal (stung into the tie back receptacle) • 3 joints 4-%2" 12.6#/ft, L-80 TXP-SR tubing • 4-1/2" 10' pup joint • 4-1/2" "XN"nipple at 7300' MD (-70° hole angle) • 4-1/2" 10' pup joint • 4-1/2" 12.6#/ft, L-80 TXP-SR tubing • 4-Y2" 12.6#/ft, L-80 TXP-SR space out pups • 1 joint 4-'/2" 12.6#/ft, L-80 TXP-SR tubing Tubing hanger with 4-1/2" TXP-SR pin down 17.2 Locate and no-go out the seal assembly. Close annular and test to 500 psi to confirm seals engaged. 17.3 Bleed pressure and open annular. Space out the completion(+/- 1' to 2' above No-Go). Place all space out pups below the first full joint of the completion. 17.4 Makeup the tubing hanger and landing joint. 17.5 RIH. Close annular. PU until ports in seal assembly exposed. 17.6 Reverse circulate the well with brine and 1%corrosion inhibitor. 17.7 Freeze protect the tubing and IA to 3000' MD with+214 bbl of diesel. Bullhead tubing freeze protect. 17.8 Land hanger. RILDs and test hanger. Perform a low pressure test on the annulus to 500 psi to confirm seals are engaged 17.9 Continue pressurizing the annulus to 3000 psi and test for 30 minutes. t"t• r" 6 17.10 Set TWC. ND BOPE and NU adapter flange and tree. Test to 5000 psi. Page 38 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 17.11 Pull TWC. Secure the tree and cellar. 18.0 RDMO Page 39 Rev 1 October 2017 • • IIIMilne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 19.0 Innovation Rig Diverter Schematic 114-m rilin mit '-13-5/8'SM Control Technology Annular BOP 1 — 1 _1—.....L ,i ® it ed ® it I ® _-13-518.5M Control 1..f 3o Technology Double Ram a•.. il• 10 SIM 31B'Kill Line `•`:,., _ { �; • illif._,__,;:.:+ fL., l`j '� _''-3•tl8•Choke Line ® Fa c:::r. 10 '— ® i 13-518'5M Controls Technology Single Ram ./ --. 13.5/8'xSMrifil __ —1/gr--49 -------„, 15°wetter Line i \ 0-4„„4-1; -13-5/r x SM c 4 1 14,1 1; 'v w • —2-1/15 x 5M 20'Casing Page 40 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 20.0 Innovation Rig BOP Schematic 0 tli iI fl1 IIT11I m [it lit ~-------13-5/8"5M Control Technology Annular BOP I 1 t I ..'"4"6---. i . ,i a- iii ED t...,' •• ;:_ >1 !'^~---13-5/8"5M Control { ,�rt Technology Double Ram i'La 1 A.:"Zi i:: IF .-t-'''''" 3-1/8"Kill Line •_• .r /r . "� — i�iillhil 1 _ 1. f� o 0 � "f � �' y�` _"`'---3-118"Choke Line C- 7 Fj _ o1 k . iii Lt3 ----------13-5/8" 5M Control I Technology Single Ram 13-5/8"x 5M 11"x5M /ice %I& -I [ "Di - uI 3440"41.00' n'• I— Ger 'Dr I] 9-5/8"DBL D Seal II_ rlitt! =---0111: ... 2-1/16"x 5M CasingHanger _ ��►1111110 -13-5/8"x 5M S-22 u- -Drl II up 13-5/8"NOM 9-5/8"BTC Btm x �2-1/16"x 5M 10.5"-4 SA Pin Top W/Primary Seal 20"Casing I ( 9-5/8"Casing Page 41 Rev 1 October 2017 0 II Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 21.0 Wellhead Schematic Note: Dimemional i formalion reflected r J on this drawing are estimated measurements only. F Pi 4-1/16'5,0000 _ .; 4-1/16'5.0000 a 'f 7 ' r L 86-22' ■ a 4-1/16'5,000# ` ,, t, Hydraulic " 51.16' ? __n1 4-1/16'5,000# '14� c' 4-1/16'5,000# " i`* i` 16.09` gi. 1 11'5,000# e -' , _ 2-1/16'5,000# 1 a.1 15.74'1EC z,• I. _1 r ,,,I,. )-011111•11 : t 11' 5,000# .�I ii —1' 1 ' ,., 2-1/16'5,000# 21.25" it � ' - 4 Ir I i __ i ff 1 7.29' I6 -_._ Welihouse Floor 7.12" ■ • to Btm.of banger } +,CPLG= 1 16" 6.r1°OAL) 7-5/8" 7- ri",hanger,rw:pack('-no cas g L. 4-1/2' -.— 24.87' eCAMERON Well Center Line ft Page 42 Rev 1 October 2017 • • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 22.0 Days Vs Depth MPU L-52 Days vs Depth 0 L-52 SB N Producer 2000 4000 ._ „ 6000 O 8004 2 10000 I i 12000 I � 14000 j r 16000 0 5 10 15 20 25 Days Page 43 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 23.0 Formation Tops & Information MPU L-52 Formation Tops MD(ft) TVD(ft) SV5 1517 1426 Base Permafrost 2208 1848 SV1 2671 2120 Ugnu LA3(Top Lower Ugnu) 4933 3453 SB_NA(Top Shrader Bluff) 5990 3923 SB_NB(Top Target Sand) 6250 3952 GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL COMMENTS TVD FM LITH DESCRPTION At Geol. NOTE:See individual Well Program for Dept). Gubik specific casing design.depths,sizes, Toleartm r.has. SCO weights.grades and connections. P. Unconsolidated enema to medium sand and small gravel with minor siltstone. IF SIGNIFICANT AMOUNTS OF GRAVEL 1,000' ARE ENCOUNTERED WHEN DRILLING THE • • SURFACE HOLE,THE VISCOSITY OF THE MUD SYSTEM SHOULD IMMEDIATELY BE RAISED TO 150 SEC TO ENSURE EFFECTIVE HOLE CLEANING. 1750' Base permafrost hterbeds of sand,clays and slltstones with occasional 2,000' show of coal. Watch possible sidetracking while washingrreaming.L-33&L-15. Sagavanirktok No hydrates encountered on L-Pad wells drilled to date. Continued inter beds of sand,clays and slltstones with occasional shows of coal.Traces of pyrite at+J.3100 ft. 3,000' interval at W-3400 ft can be sticky and tight(L.01). Clay hterbeds between 3000 and 4500ft C 3472'. * L 3fi5T' A Kean& v UGNU:Series of coarsening upward sands which are i-A,B,C,oi r made up of: (from top to bottom)coarse sand.fine sand, silty shale. Batter developed intervening shales as you UGNU progress into the Land M(deeper). .ignuand Schrader Bluff. Possible hydrocarbons limited L-sands to SW corner of Milne development Northern area Is I-A.B) draw nstructure and wet. '3739' M-nand. I-AB,CI •4000' (NA) fa-Sands Schrader Bluff Sands: 00 4, 0' I-AB,C,D, Continued layering coarsening upward sands as above ..11.11 Schrader Bluff: Possible lost circulation E,F) except more condensed and with occasional coal, zone while drilling long strings and running Clay rich shale interval 4300 to 4600 ft '4170• 0Sands Ugnu and Schrader Bluff: Possible hydrocarbons limited casing. Recommend deep setting surface (OA) Fl. to SW comer of Mune development 1.37 and L.45 are casing for Kuparuk long strings. Also,the completed in the Schrader Bluff sand. Northern area of Schrader Bluff sands are a potential Schrader L-Pad is downstructure and wet. differential stuck pipe interval if left un-cased Bluff Surface casing point In shale below for Kuparuk long strings. Sands: Schrader Bluff OB sand for longer reach wells. Page 44 Rev 1 October 2017 4111 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 24.0 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 lo.t circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Historically, no gas hydrates have been seen on `L' Pad. Remember that hydrate gas behave differentl, 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. Weig mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect th, actual mud cut weight. Add 1.0—2.0 ppb DRILTREAT to the system to help thin the mud and relea'e 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 EC II s 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 •f 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. Maintai 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 documentee on drill wells on this pad. Page 45 Rev 1 October 2017 • Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 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. 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 durin: drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requireme its of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on this pad. Page 46 Rev 1 October 2017 0 Milne Point Unit II Till L-52 Producer Drilling Procedure Hilcorp Energy Company 25.0 Innovation Rig Layout r 170'-3 " I ( f 1,, 4 , . i• I ...„___. , ID . IIC��G 1 , . , :, _ . -' I ■c d N : ri{ I O ii} Ii 1 • . I [Ci CI{ at 1 IIMIN 1W::1 (iii 11, 90, W, _ 4:] ; I t/lND ' '....e ® V V ii- 56' a" I N •I , Ill 1 N HAK 2 FOOT , r va.if _03 PRINT 05/21/16 ---------_II1!,—_. .{ - -- j 1 _ , _ Ill * :a i s ,n IG,n i•111 113'-11 " ■ ■ ■ 36'-1 ' Page 47 Rev 1 October 2017 i . Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 26.0 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) s. 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 stabiliz-s. 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 EM at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of k ck 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 fl d; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and press e monitored as with an FIT. Page 48 Rev 1 October 2017 • rill II Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 27.0 Innovation Rig Choke Manifold Schematic _711171 __,.......,_ _1 i_ ...„___1_ N.: La —Pau sJ 11-4:1 —C t1— d I. 0 , O 6„,,44 004 q r q—CLI i •+ pD 1 Q y r'nr_ i [1:\: an Ij 'SM B82[W 2-&18'5M 882U9-..-_-:-.. _...__ _ n n Sall+M ss Ppm IMM Vahrra ter, —el 17 Ei . ] fT 1 r r 44 q MOO r r Owlrk— loo QI La-Z t--- 1 ----, Page 49 Rev 1 October 2017 Milne Point Unit L-52 Producer CBI Drilling Procedure Hilcorp Energy Company 28.0 Casing Design Information Calculation & Casing Design Factors DATE: 121412017 WELL: MPU L-52 DESIGN BY: Joe Engel Design Criteria: Hole Size 1244" Mud Density: 9.5 ppg Hole Size 8-112" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1399 psi (see attached MASP determination&calculation) MASP: Production Mode MASP: 1399 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.494 psiift) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-518" 4-V2" Top(MD) 0 6,150 Top(TVD) 0 3,942 Bottom(MD) 6,350 13,778 Bottom(TVD) 3,956 3,741 ( Length 6,350 e 7,628 Weight(ppf) 40 13.5 Grade L-80 L-80 Connection ' DWC H625 Weight tAio Bouyancy Factor(lbs) 254,000 ` 102,978 0 Tension at Top of Section(lbs) 254,000 102,978 Min strength Tension(1000 lbs) 916 307 Worst Case Safety Factor(Tension) 3.61 j° 2.98 V Collapse Pressure at bottom(Psi) 1,954 1,848 I-- Collapse Resistance v o tension(Psi) 3,090 ' 8,540 Worst Case SaFety Factor(Collapse) 158 4.62 MASP(psi) 1,399 ' 1,399 Minimum Yield(psi) 5,750 9,020 Worst case safety factor(Burst) ' 411 6.45 ' Page 50 Rev 1 October 2017 S Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 29.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 812"Hole Section Hileorp MPU L-52 Milne Point Unit MD TVD Planned Top: 6250 3952 Planned TD: 13778 3741 Anticipated Formations and Pressures: Formation TVD TVDss Est Pressure ❑iliGaslWet PPG Grad Schrader Bluff NB Sand 3,952 3,912 1778 Oil 8.74 0.454 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date MPU J-27 9-9.3 Surface 3666 2015 MPU J-28 9-9.3 Surface 3617 2015 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 812"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: 3952(ft) x 0.78(psilft)= 3082.56 3082.52(psi) -[0.1(psilift)"3892(ft)]= 2693 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff NB sand) 3952(ft) x 0.454(psilft)= 1794 psi 1794(psi) -0.1(psilft)'3952(ft) 1399 psi Summary: 1. MASP while drilling 812"production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psiift. Page 51 Rev 1 October 2017 • • 14Milne Point Unit L-52 Producer Drilling Procedure Hilcorp EneT y Company 30.0 Spider Plot (NAD 27) (Governmental Sections) Lf- t: 1 `+.� \ .max t. h MPU L-52 SHL ♦ moi+ ,f.„41 ADL388235 /� % �n„r` ADL025509 / '!. +A r ! /ice R// , -,,,,,:,,,,,,/ ! + } q 4 O / 0 ! \ a / 1 `\ 1 a \ ;'!,r MILNE POINT UNI;0 !! ; �\\ w U013N009E/ , e !// U013N010E', �� - ;F:, O / ^^Y 0 ! ! a a • + Sic yam+'' E=C ! / O ! •+ O !• O ADL025514 ADL025515 0 oo a 0 ! 0 ' 0 + 0 a Legend 0 ° • MPU L-52_SHL • Other Surface Holes(SHL) /' ,, .r•Y e 2_ biP15 L-52 BILL. X MPU L52_TPH OtherBottom hides IBHL) '' _.» , ---Other WN4 Paths MPU L52_BHL Doll and Gas Unit Boundary F.'4 Footprint 1 ti Milne Point Unit 7 MPL-52 Well 01,000 2,0CC wp_12 Feet Page 52 Rev 1 October 2017 Milne Point Unit II rilL-52 Producer Drilling Procedure Hilcorp Energy Company 31.0 Surface Plat (As Built) (NAD 27) 1 34 31 I 32 33 r \V� I 114N1 /` I r- -NI- ,,,w T 13 N ( I q C a \ 1 ._ ek 7 e:m lei FPI b s •I i]251 I[E -N- 7-`- er' l' 1 '. L.-?ID , s ■2B ■ay I ,� , A �k . 1 / ■24 ■2s I 1 f / ■20 ■2' T PR rCT �l,, _ 1_ �} !. ■16 ■17 I ---."- ''yam '_` r'['_- i ■4: ■43 I 7 ■45 4.--_- ,t.,. .„,‘16- ''y 1N1 -"11 17 13 I -L____-- IA4, j ' -A , ;74,''-. . c`' 19 I t9 1 21 I .. 2.if t ■ ■ A I' 39 ■ IP42 VICINITY MAP 1 •a L-PAD . ,4 IVES, 15 ■ ■ 47 ' ( OF A( l4 I I 2 ■ ■ 7 `'�P:''. •�•� . /, I • * --:frir 6 35 4 36 5 37 11 .r, ri "e' ,r. or I r'__x I 14� •' a`.hy F. :,,+nhaTt I---, -0' .• 10200 .7 + • -iirc1i1t %or, NOTES: LEGEND rr It 1111 4 1. ALASKA STATE PLANE CCCRCINATES ARE ZONE 4, } AS-BUIL1 CONDLCTOR NAD27. i A S"' ill : I 2. BASIS CF LOCATION IS L-PAC MONUMENTS L-t ■ f%ISflNG CGNOUC fOR I HEREBY CERTFY THAT 1 AM NURTH AND L-2 SOU13. LAND PROPERLY REGISTERED AND LICENSED TO PRADOCE LAND SURVEYING N 3. ELEVATICN DATUM IS.MEL. GRAPriIC SCALE THE STATE Cf ALASKA AND THAT 4. GEODETIC POSITIONS ARE NAD27. D 1O 207 400 TNlS AS-9'JILT REPRESENTS A SURVEY 5. PAD MEAN SCALE FACTOR IS: 0,59954123 r 1 MADE BY ME CR UNDER MY DRECT 6, GATE Cf 21.,N1IEY: OCTOBER 6, 2017. (IN FEET I SM ERVSIOEN9GNS ANNSICD THAT DEL IIM4H5 O OTtfR OE TAILS ARE 7. REFERENCE FELD BOOK. HC17-D3 PGS. 49-54. I inch -200 It. CORRECT AS or OCTOBER 6, 2017. LOCATED WTHIN PROTRACTED SEC. 8, 1. 13 N., R. 10 E., UMIA1 MERIDIAN, Alt. WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION PAD NO. COORDINATES COORDINATES POSITION(DMS) POSITON(D.DD) BOX ELEV. OFFSETS ELEV. Y=6031932.37' N=1750.02' N70'29'53.2038- N70.49811216 3744' FSL L-53 X_544641.12' c=1225,10' W149'38'05.7512" W145.63493088 15'1' 5235' FEL 15.8' L-52 Y=6031919.76' N=1735.18' N70'29'53.0793" N70.498077758 15,1' 3732' FSL 15.T X=544648.93' E=1225.04' W149'38'05.5235- W169,63486764 64 .+227' FEL L-51 Y=6031906.80' N 1719.96' N70'29'52.9514" N70.49804205 15.3' 3719' FSL 15.7' X=54465¢.92' E- 1224,94' 54149'38'05.2909" 54149.63480301 5219 FEL Y=6031990.50' N=1749.75' N70'29'53.7700" N70.49826947 3802' FSL L--56 X=544734.66' =1335,24' W149'38'02.9871" W14,9.63416308 15.2' 5141' FEL 15.T L-57 Y=6031977.71' N=1734.93' N70'29'53.6438" N70.49823438 15.3 3769' F$L 15J' X=544742.15' E=1334.81' W149'38'02.7689" W14.9.63410246 5134' FEL / Y=6031955.09' '4.1719.80' N70'29'53.5191" N70.49819976 15 4' 3736' FSL 15 6' L-54 X-544750,50' E=1335.21' W149'38'02.5253" W149.63403480 5125' FEL ._.-..__ -,._... 0.414., 6161N `"T' "}:.swaNcaER0 11Hilcorp Alaska DOE __ In! 11.011611. MI 7 MK M mm MPU L-PAD WIT: m,cAoM ossa me 11.101411011 ON 41141 AS-OJILT CONDUCTOR • WE 51-54, 56 & 57 1.1 ma Dolt MEYY'J• _!r ce[ Page 53 Rev 1 October 2017 i Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 32.0 Schrader Bluff NB Sand Offset MW vs TVD Chart MPU L-52 SB NB Offset MW vs Depth o —MPJ-27 Actual —MPU L-53 Actual 1000 —MPU L-51 Actual 2000 3000 4000 5000 a 6000 7000 8000 9000 t — 10000 11000 12000 13000 8 8.5 9 9.5 10 10.5 11 11.5 12 Mud Density(ppg) Page 54 Rev 1 October 2017 S II Milne Point Unit L-52 Producer Drilling Procedure Hilcorp Energy Company 33.0 Drill Pipe Information 5" 19.5# S-135 DS-50 & NC50 Drill Pipe Configuration Pipe Body OD n 5.000 60`.<Inspection Class Pipe Body Wall Thickness r..)0.362 Pipe Body Grade Nominal Weight Designation 19.50 5-135 Drill Pipe Approximate Length, In 31.5 Drill Pipe Length Rangel SrnnoothEdge Height on�3t32 Raised Connection GPDSSG Tool Joint SMYS r 120.000 Tool Joint OD 6-625 Upset Type IEU Tool Joint ID in,3.250 Max Upset OD IDTE:I ml 5.125 Pin Tong 9 Friction Factor 11.0 Box Tong n: 12 Ncrr_:Torp spare Ta-�nd�de nard'aclrg. Drill Pipe Performance Drill-Pipe Length Range2 Performance of Drill Pipe with Pipe Body atI, Best Estimates ( Nominal 8O ye inspection Class e,nni C'batndi wr,i Coated {least accurate) `;rf, ^tee Operational Max Tens-ion Drill Pipe Adjus ed Weight nn,'n 24.11 23.29 "tt e :n Dzj Torque rn-Ins) me) Fluid Displacement =a'*n 0.37 0.36 Tension Only ()Operational 560.800 Fluid Displacement ec cant p CiOgg 0.0085 Maxrnurr slu?4311 QQ Ccmt+ned loadnp 39.600 410,500 Fluid Capacity tealrti 0.71 0.70 0.72 Fluid Capacity kealcttn 0.0169 0.0167 0.0172 f u' MUT 35,100 Tension Only 0 560,800 Drift Size nnI 3.125 Ccrndrred eoaCn�32.100 467.400 Note.On Mia barrel equals 42 US gallons. Note:Dell p'pe assemtly values are nest este-eases and nuY vary due In glee Ludy rrel!Demme Internal plastic coating-and other factors. Connection Performance GPDS50 ( 6.625 (.,) OD X 3.250(on) ID ) 120,000 (pal) v► Aapled Make-up Tenon al Shoulder Tension at Connector TTool Joint Dimensions Torque Separator Yell m-bs) nes; iusl Balanced O,0 ;IN 6.435 V Maximum Make-up Torque 43,100 Tensile Limited 1,046,900 !Arms-re Tool Jon)CO to API 5.930 Minimum Make-up Torque 36,100 1.202.500 1.250.000 PreAlrrl Cass :Ir: _--- _-' five The waxen:,'make-,.roteshcultl to a=plied aver poss0ic. r,ASInrnI.nl Tool Jan)03 Ur 5.93 CounterGar'_ art Hct'To maxi,ae canneci[r,oatacenal lensle.a MLR 11,1.1-3','FCC?n.lts should be aFFled Tool Joint Torsional Strength tlRtbsl 71,800 Tool Joint Tensile Strength tom) 1.250.000 Elevator Shoulder Information Elevator OD 332 Raised 6.812 on) SmoothEdge Height Nominal Tool Joint Worn to Bevel Worn to Min TJ OD for IV 3132 Raised OD Diameter API Premium Class t Box OD 6.812 6.625 6.063 5.930 Elevator Capacity Ir.:1,658,000 1440 200 823,600 685,600 ,----------1NO, Eleva:ar caaaaty Lased on assured_levan:r Bore no near fa Z r.and contact stress oft 10,IOCpsl. Assumed Elevator Bore Diameter ,n.15.219 I N,Y., A raised cevator OD Ircreases elevate.caaaar:Mticut atternIc Take-up torque. Pipe Body Slip Crushing Capacity Pipe Body Configuration( 5 CPO OD 0.362<m) Wall S-135) Nominal 80%Inspection Ctass API Premium Class 1 r��J Slip Crushing Capacity l.'-:.,498.300 396.500 396.500 I J HYe:Sip Cr mina SIC=PVC Cadiz r3Kuatec eV,to SprFrrlald equator tum'Why toes Cell Ree 4' Assumed Slip Length tin?16.5 Fal In re Sip Area'i'ArC CF.1^9 to Fr gill IMO,and harrnRtse bad betorslv',,and Is to reference ..-0,510 ctnitr'd s deamdert ce to sic deco and nadtia,t_aeMkrn Of trCnCn balm mho's..ire n Transverse Load Factor(K1 4.2 raps&II pre Ooand Wal aansKr.are otherto=ms Cons-It vtt,the sbmandackserfor adoaaal Pipe Body Performance Pipe Body Configuration( 5(°) OD 0.362 k") Wall S-135) Nominal 80%Inspector.Class API Premium Class Pipe Tensile Strength or>zi 712.100 560,800 560.800 Pipe Torsional Sftrengt1 trt-ms,74.100 58.100 58.100 TJ,'PipeBody Torsional Ratio 0.97 1.24 1.24 80%Pipe Torsional St ength in-Inst 59.300 46.500 46,500 Burst poi 17,105 15,638 15,638 Ncre:vcrrlral Eurs: Collapse ?ps,I 15.672 10.029 10,029 ca cualed at e.7 a".RBA' per API. Pipe OD oro 5.000 4.855 4.855 Wall Thickness ni 0.362 0.290 0.290 Nominal Pipe ID nn)4.276 4.276 4.276 Cross Sectional Area of Pipe Body an^21 5.275 4.154 4.154 Cross Sectional Area of OD (In^21 19.635 18.514 18.514 Cross Sectional Area of ID 0.'21 14.360 14.360 14.360 Section Modulus 0In^3)5.708 .4.476 ,4.476 daPolar Section Modulus Un^31 11.415 8.953 8.953 Page 55 Rev 1 October 2017 I Milne Point Unit L-52 Producer Drilling Procedure Hilcorp E...a company 500204050016200 'V Weatherford 5" 19.50 lb/ft S-135 w/ NC 50 6-5/8" OD x 3-1/4'11D Tool Joint DRILL PIPE SPECIFICATIONS Grade S-135 Connection NC 50 Interchangeable With 5-XH & 4-1/2"IF Upset Type IEU Nominal Weight per Foot 19.50 lbs Adjusted Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6-5/8- Inside Diameter 3-1/4' API Drift 3-1/8' Rabbit OD. Suggested 3-1/16" Minimum Make-up Torque 25.900 ft-lbs Maximum Recommend Make-up Torque 26.800 ft-lbs Torsional Yield Strength 51.700 ft-lbs Tensile Strength 1269,000 lbs J � I TUBE DATA New Premium Outside Diameter 5.000" 4.855' Inside Diameter 4.276" 4.276' Wall Thickness 0.362" 0.290" Cross Sectional Area 5.275 sq in 4.154 sq in Maximum Hook Load/Tensile Strength 712,000 lbs 560.800 lbs Slip Crushing/Slip Type (SDXL) 572,100 lbs 453.500 lbs Burst Pressure 17,100 psi 16,100 psi Collapse Pressure 15.700 psi 10,000 psi Torsional Yield Strength 74.100 ft-lbs 58.100 ft-lbs Capacity W/Tool Joint 0.726 US gaLft 0.726 US gal/ft Displacement W/Tool Joint 0.353 US gauft 0.322 US gal/ft _ Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss. damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 56 Rev 1 October 2017 • 0 ..` Hilcorp Alaska, LLC Milne Point M Pt L Pad Plan: MPU L-52 MPU L-52 Plan: MPU L-52 WP12 Standard Proposal Report 29 November, 2017 N . I II I I Ill HALLIBURTON Sperry Drilling Services r 0 HALLIBURTON ` REFERENCE INFORMATION WELL DETAILS:Plan:MPU L-52 1 I I' °�)r!) Co-ordinate(NW)Reference:Well Plan:MPU L-52,True North Ground Level: 15.10 Sperry Drilling Vertical(TVD)Reference:MPU L-52 As-Built CO 41.60usR +N/-S +E/-W Northing Easting Latittude Longtl ude Measured Depth Reference:MPU L-52 As-Built @ 41.60usft 0.00 0.00 6031919.76 544648.93 70°29 53.079 N 149°38'5.523 W Calculation Method:Minimum Curvature Project: Milne Point SECTION DETAILS Site: M Pt L Pad Well: Plan:MPUL-52 Sec MD Inc Azi ND +N/-S +E/-W Dleg TFace VSect Target Annotation Wellbore: MPU L-52 1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.00 Design: MPU L-52 WP12 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 Start Dir 2°/100':450'MD,450'TVD 3 550.00 2.00 245.00 549.98 -0.74 -1.58 2.00 245.00 1.33 Start Dir 3°/100':550'MD,549.98'TVD Hilcorp Alaska,LLC 4 800.00 9.50 245.00 798.54 -11.32 -24.27 3.00 0.00 20.35 Start Dir 5°/100':800'MD,798.54'TVD Calculation Method:Minimum Curvature 5 1300.00 34.50 245.00 1258.47 -89.85 -192.68 5.00 0.00 161.57 Error System:ISCWSA 6 1730.57 53.90 231.33 1566.36 -251.99 -441.94 5.00 -31.36 412.39 End Dir :1730.57'MD,1566.36'ND Scan Method:Closest Approach 3D ethod: 7 5174.35 53.90 231.33 3595.26 -1990.79 -2614.44 0.00 0.00 2894.77 Start Dir 5°/100':5174.35'MD,3595.26'ND Error Surface:Elliptical R Conic Warning MMethRatio 8 6140.70 85.00 191.00 3942.88 -2752.95 -3036.40 5.00 -59.68 3763.25 End Dir :6140.7'MD,3942.88'TVD 9 6240.70 85.00 191.00 3951.60 -2850.74 -3055.41 0.00 0.00 3860.13 MPU L-52 WP11 Heel Start Dir 4°/100':6240.7'MD,3951.6'TVD _ 10 6407.20 91.66 191.00 3956.45 -3014.02 -3087.15 4.00 0.00 4021.89 End Dir :6407.2'MD,3956.45'ND - 11 7600.00 91.66 191.00 3921.90 -4184.42 -3314.65 0.00 0.00 5181.42 Start Dir 2°/100':7600'MD,3921.9'TVD 12 7766.25 91.68 194.33 3917.05 -4346.53 -3351.07 2.00 89.58 5344.06 End Dir :7766.25'MD,3917.05'ND 1500- 13 11062.42 91.68 194.33 3820.33 -7538.82 -4166.34 0.00 0.00 8587.37 Start Dir 2°/100':11062.42'MD,3820.33'ND - 14 11278.64 91.66 190.00 3814.02 -7750.05 -4211.86 2.00 -90.22 8798.49 End Dir :11278.64'MD,3814.02'ND - 15 13778.64 91.66 190.00 3741.60-10211.04 -4645.80 0.00 0.00 11218.23 MPL-52 wp07 Toe Total Depth:13778.64'MD,3741.6C'ND -750- - SURVEY PROGRAM - /J� Date:2016-06-03700:00:00 Validated:Yea Version: - r/- /JV�I Depth From Depth To Survey/Plan Tool 0 _ Start Dir 2°/100':450'MD,450'ND 26.50 800.00 MPU 1-52 WP12 2GyroSR-SR 850.00 6250.00 MPU 1-52 WP12 2_MWDIFR2+M8+Sag N _ 6250.00 13]]8.64 MPU L32 WP12 2_MWD.IFR2+M8+Sag -- Start Dir 3°/100':550'MD,549.98'ND 500-___ 0 - Start Dir 5°/100':800'MD,798.54'TVD CASING DETAILS 0 750- -- 1000 End Dir:1730.57'MD,1566.36'TVD ND MD Name Size _ 3956.96 6350.00 9 5/8"x 121/4" 95/8 L - 3741.60 13778.64 4 112 x 8 12" 4-12 a • �p co O 1500- .P 0- �p U ��."J� ._`O 1�4C • 'C - 90 .C' .�O .C' _p 'C� 2250- ^Y- bs11' �O l�ry FOP1�G� hy�O�y'1'�`A9rt° A0ry09°' 0, 'T' ,5A'•' 3000-_ i 'fie",' a ' .11��1 .c- .1-'4* .erg 1 nA' �O p 0 ' 10 1 1 1,40 1 1 - 4e ,'�a. ppb c50N , 'e 0` O' ' .,c5 e� E *ON 0 ,CaJ MPL52 wp07 Toe 3750- r , ' c '�0 c '�' MPU L-52 WP12 _ MPU L52 WP11 Hee)' 0 0 0 5 0 c o 0 5 o - 41/2"x812' 4500- 9 5/8"x 12 1/4" 5250- 6000- ii : Iiiilllliiifli : illlilllillliillilillllillliliillilllliiiliiilliiillliiillilillil lilllillllillll -750 0 750 1500 2250 3000 3750 4500 5250 8000 8750 7500 8250 9000 9750 10500 11250 12000 12750 13500 Vertical Section at 204.46°(1500 ustt/in) HALLIBURTON Project: Milne Point WELL DETAILS: Plan:MPU L-52 — — Site: M Pt L Pad Ground Level: 15.10 Sperry Drilling +N/-S +E/-W Northing Easting Latittude Longitude Well: Plan: MPU L-52 0.00 0.00 6031919.76 544648.93 70°29'53.079 N 149°38'5.523W Wellbore: MPU L-52 Plan: MPU L-52 WP12 REFERENCE INFORMATION Hilcori3 Co-ordinate(NIE)Reference:Well Plan:MPU L-52,True North Vertical(TVD)Reference:MPU L-52 As-Built((p 41.60usft Measured Depth Reference:MPU L-52 As-Built(d141.60usf CASING DETAILS Calculation Method:Minimum Curvature TVD TVDSS MD Size Name 3956.96 3915.36 6350.00 9-5/8 9 5/8"x 12 1/4" 3741.60 3700.00 13778.64 4-1/2 4 1/2"x 8 1/2" 0— «o bit iso 4, 3/Io •4sp,4^ �.,` 750— 000 4 5 p� 'psso, ``1,14s, B o so 1'3 '54998 �yB T.. -1500— 120 iso 16636 O o 42, - 2s _ o -2250— 3)80 MPU L-52 WPII Heel Start Dir 5°/100'`5174.35'MD,3595.26'1VD --End Dir:6140.7 MD,3942.88'TVD -3000— 9 5/8"x 12 1/4"-`n Start Dir 4°/100':6240.7'MD,3951.6'TVD End Dir:6407.2'MD,3956.45'TVD -3750- - -Start Dir 2°/100':7600'MD,3921.9TVD -4500— _ End Dir:7766.25'MD,3917.05'TVD O - O -5250— + o _ -6000— rs o -6750- -7500— ___ Start Dir 2°/100':11062.42'MD,3820.33TVD End Dir:11278.64'MD,3814.02'TVD -8250- -9000— V -9750- 4 1/2"x 8 1/2" Total Depth:13778.64'MD,3741.60'TVD MPL-52 wp07 The "` 742 -10500— MPUL-52 typ12 -11250— -12000— -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 West(-)/East(+)(1500 usft/in) I i Halliburton HALLIBURTON Standard Proposal Report Database: },"Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPU L-52 Company: a` Hilcorp Alaska,LLC TVD Reference: MPU L-52 As-Built @ 41.60usft Project: Milne Point MD Reference: XXX-• MPU L-52 As-Built @ 41.60usft Site: M Pt L Pad North Reference: True Well: a Plan:MPU L-52 Survey Calculation Method: " Minimum Curvature Wellbore: MPU L-52 Design: MPU L-52 WP12 _. ,w,. ,mei o-,- ,-,- Project Milne Point,ACT,MILNE POINT z 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 L Pad,TR-13-10 Site Position: Northing: 6,029,799.28 usft Latitude: 70°29'32.230 N From: Map Easting: 544,529.55 usft Longitude: 149°38'9.412 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.34 ° Well Plan:MPU L-52 .... ... .. s. . -... - ;tea.�.iaxezfint c ,:: 1 Well Position +N/-S 0.00 usft Northing: 6,031,919,76 usft Latitude: 70°29'53.079 N +E/-W 0.00 usft Easting: 544,648.93 usft Longitude: 149°38'5.523 W Position Uncertainty 0.00 usft Wellhead Elevation: 41.60 usft Ground Level: 15.10 usft gi..,y ;..s,.. MPU L-52 Magnetics � �} C� Sample Da "� ,� 444.414!.-'1, �P Field Strength 10;:4..� k �$a nT BGGM2017 12/29/2017 17.37 81.03 57,490 DesignMPI L-52 WP12 Audit Notes: Version: Phase: PLAN Tie On Depth: 26.50 Vertical Section: Depth From(TVD) FI(' +N/-S +E/-W ... : . ` ® h'' ' ' ' 44444444_44'4:44A444;44'414 ;. 4. (usft) P (usft). ;(usft) 44444544.14144444A44444.4%4‘44, ' t 26.50 0.00 0.00 204.46 Plan Sections . , t'7.a t ..' -rte- ;.�.; m---',uw a„P,. ani , .,. PPM zs.. -' ,;_. IRF, PIP t ' ;W: ;'' Measured Vertical TVD Dogleg Build Turn" Depth Inclination Azimuth Depth System +NI-S +El-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) O a ;ro 26.50 0.00 0.00 26.50 -15.10 0.00 0.00 0.00 0.00 0.00 0.00 450.00 0.00 0.00 450.00 408.40 0.00 0.00 0.00 0.00 0.00 0.00 550.00 2.00 245.00 549.98 508.38 -0.74 -1.58 2.00 2.00 0.00 245.00 800.00 9.50 245.00 798.54 756.94 -11.32 -24.27 3.00 3.00 0.00 0.00 1,300.00 34.50 245.00 1,258.47 1,216.87 -89.85 -192.68 5.00 5.00 0.00 0.00 1,730.57 53.90 231.33 1,566.36 1,524.76 -251.99 -441.94 5.00 4.51 -3.18 -31.36 5,174.35 53.90 231.33 3,595.26 3,553.66 -1,990.79 -2,614.44 0.00 0.00 0.00 0.00 6,140.70 85.00 191.00 3,942.88 3,901.28 -2,752.95 -3,036.40 5.00 3.22 -4.17 -59.68 6,240.70 85.00 191.00 3,951.60 3,910.00 -2,850.74 -3,055.41 0.00 0.00 0.00 0.00 6,407.20 91.66 191.00 3,956.45 3,914.85 -3,014.02 -3,087.15 4.00 4.00 0.00 0.00 7,600.00 91.66 191.00 3,921.90 3,880.30 -4,184.42 -3,314.65 0.00 0.00 0.00 0.00 7,766.25 91.68 194.33 3,917.05 3,875.45 -4,346.53 -3,351.07 2.00 0.01 2.00 89.58 11,062.42 91.68 194.33 3,820.33 3,778.73 -7,538.82 -4,166.34 0.00 0.00 0.00 0.00 11,278.64 91.66 190.00 3,814.02 3,772.42 -7,750.05 -4,211.86 2.00 -0.01 -2.00 -90.22 13,778.64 91.66 190.00 3,741.60 3,700.00 -10,211.04 -4,645.80 0.00 0.00 0.00 0.00 11/29/2017 11:46'12AM Page 2 COMPASS 5000.1 Build 81D I 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPU L-52 Company: Hilcorp Alaska,LLC TVD Reference: MPU L-52 As-Built @ 41.60usft `Milne Pin MD Reference: I` MPU L-52 As-Built 41.60usft e o t ` Project: , @ Site: M Pt L Pad North Reference: < 1` of True Well: Plan:MPU L-52 Survey Calculation Method: f Ott Minimum Curvature Wellbore MPU L-52 "€' a1 Design: MPU L-52 WP12 If i IIIIIIIVII I:‘,,,,314 Planned Survey k i y. fit' Measured VerticalMap Map '` Depth Inclination Azimuth Depth TVDss +N/-S +Ei-W Northing Eastmg }. . , - (usft) (°) (°) (usft) usft (usft) (usft) (usft) € -x ' (usft) + l x z ' 26.50 0.00 0.00 26.50 -15.10 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 100.00 0.00 0.00 100.00 58.40 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 200.00 0.00 0.00 200.00 158.40 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 300.00 0.00 0.00 300.00 258.40 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 400.00 0.00 0.00 400.00 358.40 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 450.00 0.00 0.00 450.00 408.40 0.00 0.00 6,031,919.76 544,648.93 0.00 0.00 ' Start Dir 2°/100':450'MD,450'TVD 500.00 1.00 245.00 500.00 458.40 -0.18 -0.40 6,031,919.57 544,648.54 2.00 0.33 550.00 2.00 245.00 549.98 508.38 -0.74 -1.58 6,031,919.01 544,647.35 2.00 1.33 Start Dir 3°/100':550'MD,549.981VD 600.00 3.50 245.00 599.92 558.32 -1.75 -3.76 6,031,917.99 544,645.19 3.00 3.15 700.00 6.50 245.00 699.53 657.93 -5.43 -11.65 6,031,914.26 544,637.31 3.00 9.77 800.00 9.50 245.00 798.54 756.94 -11.32 -24.27 6,031,908.30 544,624.74 3.00 20.35 Start Dir 5°/100':800'MD,798.54'TVD 900.00 14.50 245.00 896.33 854.73 -20.10 -43.10 6,031,899.40 544,605.95 5.00 36.14 1,000.00 19.50 245.00 991.93 950.33 -32.45 -69.59 6,031,886.89 544,579.54 5.00 58.36 1,100.00 24.50 245.00 1,084.62 1,043.02 -48.28 -103.53 6,031,870.87 544,545.70 5.00 86.82 1,200.00 29.50 245.00 1,173.69 1,132.09 -67.46 -144.67 6,031,851.44 544,504.69 5.00 121.31 1,300.00 34.50 245.00 1,258.47 1,216.87 -89.85 -192.68 6,031,828.77 544,456.82 5.00 161.57 1,400.00 38.85 240.85 1,338.67 1,297.07 -117.11 -245.77 6,031,801.19 544,403.89 5.00 208.37 1 1,500.00 43.31 237.43 1,414.04 1,372.44 -150.87 -302.10 6,031,767.09 544,347.77 5.00 262.43 1,600.00 47.87 234.53 1,484.01 1,442.41 -190.87 -361.24 6,031,726.74 544,288.88 5.00 323.33 1,700.00 52.48 232.03 1,548.04 1,506.44 -236.81 -422.74 6,031,680.43 544,227.66 5.00 390.62 1,730.57 53.90 231.33 1,566.36 1,524.76 -251.99 -441.94 6,031,665.14 544,208.55 5.00 412.39 End Dir :1730.57'MD,1566.36'TVD 1,800.00 53.90 231.33 1,607.26 1,565.66 -287.05 -485.74 6,031,629.83 544,164.97 0.00 462.44 1,900.00 53.90 231.33 1,666.18 1,624.58 -337.54 -548.83 6,031,578.96 544,102.19 0.00 534.52 2,000.00 53.90 231.33 1,725.09 1,683.49 -388.03 -611.91 6,031,528.10 544,039.42 0.00 606.60 2,100.00 53.90 231.33 1,784.01 1,742.41 -438.52 -675.00 6,031,477.24 543,976.65 0.00 678.68 2,200.00 53.90 231.33 1,842.92 1,801.32 -489.01 -738.08 6,031,426.37 543,913.87 0.00 750.77 2,300.00 53.90 231.33 1,901.84 1,860.24 -539.50 -801.17 6,031,375.51 543,851.10 0.00 822.85 2,400.00 53.90 231.33 1,960.75 1,919.15 -589.99 -864.25 6,031,324.64 543,788.32 0.00 894.93 2,500.00 53.90 231.33 2,019.67 1,978.07 -640.48 -927.33 6,031,273.78 543,725.55 0.00 967.02 2,600.00 53.90 231.33 2,078.58 2,036.98 -690.98 -990.42 6,031,222.92 543,662.78 0.00 1,039.10 2,700.00 53.90 231.33 2,137.50 2,095.90 -741.47 -1,053.50 6,031,172.05 543,600.00 0.00 1,111.18 2,800.00 53.90 231.33 2,196.41 2,154.81 -791.96 -1,116.59 6,031,121.19 543,537.23 0.00 1,183.27 2,900.00 53.90 231.33 2,255.33 2,213.73 -842.45 -1,179.67 6,031,070.32 543,474.45 0.00 1,255.35 3,000.00 53.90 231.33 2,314.24 2,272.64 -892.94 -1,242.76 6,031,019.46 543,411.68 0.00 1,327.43 3,100.00 53.90 231.33 2,373.16 2,331.56 -943.43 -1,305.84 6,030,968.60 543,348.91 0.00 1,399.51 3,200.00 53.90 231.33 2,432.07 2,390.47 -993.92 -1,368.93 6,030,917.73 543,286.13 0.00 1,471.60 3,300.00 53.90 231.33 2,490.99 2,449.39 -1,044.41 -1,432.01 6,030,866.87 543,223.36 0.00 1,543.68 3,400.00 53.90 231.33 2,549.90 2,508.30 -1,094.90 -1,495.10 6,030,816.00 543,160.58 0.00 1,615.76 3,500.00 53.90 231.33 2,608.82 2,567.22 -1,145.39 -1,558.18 6,030,765.14 543,097.81 0.00 1,687.85 3,600.00 53.90 231.33 2,667.73 2,626.13 -1,195.88 -1,621.27 6,030,714.28 543,035.03 0.00 1,759.93 3,700.00 53.90 231.33 2,726.65 2,685.05 -1,246.38 -1,684.35 6,030,663.41 542,972.26 0.00 1,832.01 11/29/2017 11:46:12AM Page 3 COMPASS 5000.1 Build 81D a ! Halliburton HALLIBURTON Standard Proposal Report k, Well Plan:MPU L-52 Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference. Company: Hilcorp Alaska,LLC TVD Reference: I MPU L-52 As-Built @ 41.60usft li Project: Milne Point MD Reference: a , MPU L-52 As-Built @ 41.60usft Site: M Pt L Pad North Reference: True Well: Plan:MPU L-52 Survey Calculation Method: Minimum Curvature Wellbore MPU L-52 i -4,4p 4441 44444,44,444 444444444 -4 Design: MPU L-52 WP12 N144:,c.,::,:.1A,s».'. ..*3>r_..r,aA. l ,.s...sem„ .,.,::. 1y;,,„. ...,,c :.:,a:nG, .,w:§=a26„3.ee:s:':� '...,-,::• ,. Planned Survey .>e t , Measured ,.... .Vertical `, -t11 Depth Inclination Azimuth Depth TVDss ' +N/-S +EI-W Northing : Easting s Vert Section (usft) (°) (°) «a:' (usft) usft : .:. (usft) usft (usft) _. ; �, (usft) ) (usft) 3,800.00 53.90 231.33 2,785.56 2,743.96 -1,296.87 -1,747.44 6,030,612.55 542,909.49 0.00 1,904.10 3,900.00 53.90 231.33 2,844.48 2,802.88 -1,347.36 -1,810.52 6,030,561.68 542,846.71 0.00 1,976.18 4,000.00 53.90 231.33 2,903.39 2,861.79 -1,397.85 -1,873.60 6,030,510.82 542,783.94 0.00 2,048.26 4,100.00 53.90 231.33 2,962.31 2,920.71 -1,448.34 -1,936.69 6,030,459.96 542,721.16 0.00 2,120.34 4,200.00 53.90 231.33 3,021.22 2,979.62 -1,498.83 -1,999.77 6,030,409.09 542,658.39 0.00 2,192.43 4,300.00 53.90 231.33 3,080.14 3,038.54 -1,549.32 -2,062.86 6,030,358.23 542,595.62 0.00 2,264.51 4,400.00 53.90 231.33 3,139.05 3,097.45 -1,599.81 -2,125.94 6,030,307.36 542,532.84 0.00 2,336.59 4,500.00 53.90 231.33 3,197.97 3,156.37 -1,650.30 -2,189.03 6,030,256.50 542,470.07 0.00 2,408.68 4,600.00 53.90 231.33 3,256.88 3,215.28 -1,700.79 -2,252.11 6,030,205.64 542,407.29 0.00 2,480.76 4,700.00 53.90 231.33 3,315.80 3,274.20 -1,751.29 -2,315.20 6,030,154.77 542,344.52 0.00 2,552.84 4,800.00 53.90 231.33 3,374.71 3,333.11 -1,801.78 -2,378.28 6,030,103.91 542,281.75 0.00 2,624.93 4,900.00 53.90 231.33 3,433.63 3,392.03 -1,852.27 -2,441.37 6,030,053.04 542,218.97 0.00 2,697.01 5,000.00 53.90 231.33 3,492.54 3,450.94 -1,902.76 -2,504.45 6,030,002.18 542,156.20 0.00 2,769.09 5,100.00 53.90 231.33 3,551.46 3,509.86 -1,953.25 -2,567.54 6,029,951.32 542,093.42 0.00 2,841.17 5,174.35 53.90 231.33 3,595.26 3,553.66 -1,990.79 -2,614.44 6,029,913.50 542,046.75 0.00 2,894.77 Start Dir 5°1100':5174.35'MD,3595.26'7VD __ : _... .; , ....._: ','. 9Ai994999„;,49 ,49 � '; Ai 5,200.00 54.56 229.97 3,610.26 3,568.66 -2,003.99 -2,630.53 6,029,900.21 542,030.74 5.00 2,913.44 5,300.00 57.25 224.88 3,666.33 3,624.73 -2,060.02 -2,691.43 6,029,843.81 541,970.18 5.00 2,989.67 5,400.00 60.13 220.10 3,718.31 3,676.71 -2,123.03 -2,749.07 6,029,780.47 541,912.93 5.00 3,070.89 5,500.00 63.18 215.59 3,765.80 3,724.20 -2,192.52 -2,803.00 6,029,710.65 541,859.42 5.00 3,156.48 5,600.00 66.36 211.33 3,808.43 3,766.83 -2,267.99 -2,852.82 6,029,634.90 541,810.06 5.00 3,245.80 5,700.00 69.66 207.27 3,845.88 3,804.28 -2,348.84 -2,898.14 6,029,553.79 541,765.23 5.00 3,338.16 5,800.00 73.04 203.38 3,877.87 3,836.27 -2,434.46 -2,938.63 6,029,467.93 541,725.26 5.00 3,432.86 5,900.00 76.49 199.64 3,904.15 3,862.55 -2,524.20 -2,973.97 6,029,377.98 541,690.47 5.00 3,529.19 6,000.00 80.00 196.00 3,924.52 3,882.92 -2,617.39 -3,003.90 6,029,284.63 541,661.10 5.00 3,626.40 6,100.00 83.55 192.43 3,938.82 3,897.22 -2,713.30 -3,028.18 6,029,188.58 541,637.40 5.00 3,723.75 6,140.70 85.00 191.00 3,942.88 3,901.28 -2,752.95 -3,036.40 6,029,148.89 541,629.42 5.00 3,763.25 End Dir:6140.7'MD,3942.88'TVD ' 6,200.00 85.00 191.00 3,948.05 3,906.45 -2,810.94 -3,047.67 6,029,090.84 541,618.50 0.00 3,820.70 6,240.70 85.00 191.00 3,951.60 3,910.00 -2,850.74 -3,055.41 6,029,051.00 541,611.00 0.00 3,860.13 Start Dir 4°/100':6240.7'MD,3951.6'TVD 6,300.00 87.37 191.00 3,955.54 3,913.94 -2,908.82 -3,066.70 6,028,992.86 541,600.06 4.00 3,917.67 6,350.00 89.37 191.00 3,956.96 3,915.36 -2,957.88 -3,076.23 6,028,943.75 541,590.82 4.00 3,966.27 9518"x121/4' 6,407.20 91.66 191.00 3,956.45 3,914.85 -3,014.02 -3,087.15 6,028,887.54 541,580.25 4.00 4,021.90 End Dir :6407.2'MD,3956.45'TVD 6,500.00 91.66 191.00 3,953.76 3,912.16 -3,105.08 -3,104.85 6,028,796.39 541,563.09 0.00 4,112.11 6,600.00 91.66 191.00 3,950.86 3,909.26 -3,203.20 -3,123.92 6,028,698.17 541,544.61 0.00 4,209.32 6,700.00 91.66 191.00 3,947.97 3,906.37 -3,301.32 -3,142.99 6,028,599.94 541,526.13 0.00 4,306.53 6,800.00 91.66 191.00 3,945.07 3,903.47 -3,399.44 -3,162.06 6,028,501.72 541,507.65 0.00 4,403.74 6,900.00 91.66 191.00 3,942.17 3,900.57 -3,497.56 -3,181.14 6,028,403.49 541,489.17 0.00 4,500.95 7,000.00 91.66 191.00 3,939.28 3,897.68 -3,595.69 -3,200.21 6,028,305.27 541,470.69 0.00 4,598.16 7,100.00 91.66 191.00 3,936.38 3,894.78 -3,693.81 -3,219.28 6,028,207.04 541,452.21 0.00 4,695.37 7,200.00 91.66 191.00 3,933.48 3,891.88 -3,791.93 -3,238.36 6,028,108.82 541,433.73 0.00 4,792.58 7,300.00 91.66 191.00 3,930.59 3,888.99 -3,890.05 -3,257.43 6,028,010.59 541,415.24 0.00 4,889.79 11/29/2017 11:46:12AM Page 4 COMPASS 5000.1 Build 81D • 0 Halliburton I-IALLIBURTO J Standard Proposal Report :;. ... :. ., .�.�.,, ...�.,�.. �.-�� - Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference:'.--„,,,,2•J: Well Plan:MPU L-52 Company: Hilcorp Alaska,LLC TVD Reference: MPU L-52 As-Built @ 41.60usft Project: i Milne Point MD Reference: _ z _ MPU L-52 As-Built @ 41.60usft Site: M Pt L Pad North Reference: True Well. {'Plan:MPU L-52Survey Calculation Method: Minimum Curvature Wellbore: MPU L-52 +,.M " Design: MPU L-52 WP12 Planned Survey � ^^ " bra y ? s.=: "`- ..f Measured Verticalig .f.-,-:-, ; .�,ire'P 4 , ,t Map Map ,lt `` Depth Inclination Azimuth Depth TVDss +NI-S +E1-W Northing' ' Easting DLS . (usft) (°) (°) (usft) usft (usft) (usft) (usft) €; (usft) 3,886.09 , 7,400.00 91.66 191.00 3,927.69 3,886.09 -3,988.17 -3,276.50 6,027,912.37 541,396.76 0.00 4,987.00 7,500.00 91.66 191.00 3,924.79 3,883.19 -4,086.29 -3,295.57 6,027,814.14 541,378.28 0.00 5,084.21 7,600.00 91.66 191.00 3,921.90 3,880.30 -4,184.42 -3,314.65 6,027,715.92 541,359.80 0.00 5,181.42 Start Dir 2°1100':7600'MD,3921.9'TVD 7,700.00 91.67 193.00 3,918.99 3,877.39 -4,282.18 -3,335.43 6,027,618.04 541,339.61 2.00 5,279.02 7,766.25 91.68 194.33 3,917.05 3,875.45 -4,346.53 -3,351.07 6,027,553.60 541,324.35 2.00 5,344.07 End Dir :7766.25'MD,3917.05'TVD 7,800.00 91.68 194.33 3,916.06 3,874.46 -4,379.22 -3,359.42 6,027,520.87 541,316.20 0.00 5,377.28 7,900.00 91.68 194.33 3,913.12 3,871.52 -4,476.06 -3,384.15 6,027,423.89 541,292.05 0.00 5,475.67 8,000.00 91.68 194.33 3,910.19 3,868.59 -4,572.91 -3,408.89 6,027,326.90 541,267.91 0.00 5,574.07 8,100.00 91.68 194.33 3,907.25 3,865.65 -4,669.76 -3,433.62 6,027,229.91 541,243.76 0.00 5,672.46 8,200.00 91.68 194.33 3,904.32 3,862.72 -4,766.61 -3,458.35 6,027,132.93 541,219.61 0.00 5,770.86 8,300.00 91.68 194.33 3,901.39 3,859.79 -4,863.46 -3,483.09 6,027,035.94 541,195.46 0.00 5,869.26 8,400.00 91.68 194.33 3,898.45 3,856.85 -4,960.31 -3,507.82 6,026,938.96 541,171.31 0.00 5,967.65 8,500.00 91.68 194.33 3,895.52 3,853.92 -5,057.16 -3,532.56 6,026,841.97 541,147.16 0.00 6,066.05 8,600.00 91.68 194.33 3,892.58 3,850.98 -5,154.00 -3,557.29 6,026,744.99 541,123.01 0.00 6,164.45 8,700.00 91.68 194.33 3,889.65 3,848.05 -5,250.85 -3,582.02 6,026,648.00 541,098.86 0.00 6,262.84 8,800.00 91.68 194.33 3,886.71 3,845.11 -5,347.70 -3,606.76 6,026,551.01 541,074.71 0.00 6,361.24 8,900.00 91.68 194.33 3,883.78 3,842.18 -5,444.55 -3,631.49 6,026,454.03 541,050.56 0.00 6,459.63 9,000.00 91.68 194.33 3,880.85 3,839.25 -5,541.40 -3,656.22 6,026,357.04 541,026.41 0.00 6,558.03 9,100.00 91.68 194.33 3,877.91 3,836.31 -5,638.25 -3,680.96 6,026,260.06 541,002.27 0.00 6,656.43 9,200.00 91.68 194.33 3,874.98 3,833.38 -5,735.10 -3,705.69 6,026,163.07 540,978.12 0.00 6,754.82 9,300.00 91.68 194.33 3,872.04 3,830.44 -5,831.94 -3,730.43 6,026,066.08 540,953.97 0.00 6,853.22 9,400.00 91.68 194.33 3,869.11 3,827.51 -5,928.79 -3,755.16 6,025,969.10 540,929.82 0.00 6,951.62 9,500.00 91.68 194.33 3,866.17 3,824.57 -6,025.64 -3,779.89 6,025,872.11 540,905.67 0.00 7,050.01 9,600.00 91.68 194.33 3,863.24 3,821.64 -6,122.49 -3,804.63 6,025,775.13 540,881.52 0.00 7,148.41 9,700.00 91.68 194.33 3,860.31 3,818.71 -6,219.34 -3,829.36 6,025,678.14 540,857.37 0.00 7,246.80 9,800.00 91.68 194.33 3,857.37 3,815.77 -6,316.19 -3,854.09 6,025,581.15 540,833.22 0.00 7,345.20 9,900.00 91.68 194.33 3,854.44 3,812.84 -6,413.03 -3,878.83 6,025,484.17 540,809.07 0.00 7,443.60 10,000.00 91.68 194.33 3,851.50 3,809.90 -6,509.88 -3,903.56 6,025,387.18 540,784.92 0.00 7,541.99 10,100.00 91.68 194.33 3,848.57 3,806.97 -6,606.73 -3,928.29 6,025,290.20 540,760.77 0.00 7,640.39 10,200.00 91.68 194.33 3,845.63 3,804.03 -6,703.58 -3,953.03 6,025,193.21 540,736.63 0.00 7,738.78 10,300.00 91.68 194.33 3,842.70 3,801.10 -6,800.43 -3,977.76 6,025,096.23 540,712.48 0.00 7,837.18 10,400.00 91.68 194.33 3,839.77 3,798.17 -6,897.28 -4,002.50 6,024,999.24 540,688.33 0.00 7,935.58 10,500.00 91.68 194.33 3,836.83 3,795.23 -6,994.13 -4,027.23 6,024,902.25 540,664.18 0.00 8,033.97 10,600.00 91.68 194.33 3,833.90 3,792.30 -7,090.97 -4,051.96 6,024,805.27 540,640.03 0.00 8,132.37 10,700.00 91.68 194.33 3,830.96 3,789.36 -7,187.82 -4,076.70 6,024,708.28 540,615.88 0.00 8,230.77 10,800.00 91.68 194.33 3,828.03 3,786.43 -7,284.67 -4,101.43 6,024,611.30 540,591.73 0.00 8,329.16 10,900.00 91.68 194.33 3,825.09 3,783.49 -7,381.52 -4,126.16 6,024,514.31 540,567.58 0.00 8,427.56 11,000.00 91.68 194.33 3,822.16 3,780.56 -7,478.37 -4,150.90 6,024,417.32 540,543.43 0.00 8,525.95 11,062.42 91.68 194.33 3,820.33 3,778.73 -7,538.82 -4,166.34 6,024,356.79 540,528.36 0.00 8,587.37 Start Dir 2°/100':11062.42'MD,3820.337VD 11,100.00 91.68 193.57 3,819.23 3,777.63 -7,575.28 -4,175.39 6,024,320.28 540,519.52 2.00 8,624.31 11,200.00 91.67 191.57 3,816.31 3,774.71 -7,672.83 -4,197.15 6,024,222.61 540,498.35 2.00 8,722.11 11/29/2017 11:46:12AM Page 5 COMPASS 5000.1 Build 81D • 0 Halliburton HALLIBUPTON Standard Proposal Report Database: `'i Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPU L-52 Company: Hilcorp Alaska,LLC TVD Reference '' MPU L-52 As-Built @ 41.60usft Project: "'`'k Milne Point MD Reference: '' a' ' MPU L-52 As-Built @ 41.60usft „AftSite: L M Pt L Pad North Reference: True Well t Plan:MPU L-52 Survey Calculation Method: Minimum Curvature Wellbore , (MPU L-52 F "' Design MPU L-52 WP12 s-.-.r. �‘ ao , .axx: - . -- .. . Planned Survey r ar .. „ ,- Measured #� . ' Vertical 1 f a"" '',/,//,'"'/:',/', ' Map Map 'nil 5 Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing .:°Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,77242 11,278.64 91.66 190.00 3,814.02 3,772.42 -7,750.05 -4,211.86 6,024,145.31 540,484.11 2.00 8,798.49 End Dir :11278.64'MD,3814.02'TVD 8 11,300.00 91.66 190.00 3,813.40 3,771.80 -7,771.07 -4,215.57 6,024,124.26 540,480.53 0.00 8,819.16 11,400.00 91.66 190.00 3,810.51 3,768.91 -7,869.51 -4,232.93 6,024,025.73 540,463.76 0.00 8,915.95 11,500.00 91.66 190.00 3,807.61 3,766.01 -7,967.95 -4,250.29 6,023,927.20 540,447.00 0.00 9,012.74 11,600.00 91.66 190.00 3,804.71 3,763.11 -8,066.39 -4,267.64 6,023,828.67 540,430.23 0.00 9,109.53 11,700.00 91.66 190.00 3,801.81 3,760.21 -8,164.83 -4,285.00 6,023,730.14 540,413.47 0.00 9,206.32 11,800.00 91.66 190.00 3,798.92 3,757.32 -8,263.27 -4,302.36 6,023,631.60 540,396.70 0.00 9,303.11 11,900.00 91.66 190.00 3,796.02 3,754.42 -8,361.71 -4,319.72 6,023,533.07 540,379.94 0.00 9,399.90 12,000.00 91.66 190.00 3,793.12 3,751.52 -8,460.15 -4,337.07 6,023,434.54 540,363.18 0.00 9,496.69 12,100.00 91.66 190.00 3,790.23 3,748.63 -8,558.59 -4,354.43 6,023,336.01 540,346.41 0.00 9,593.48 12200.00 91.66 190.00 3,787.33 3,745.73 -8,657.03 -4,371.79 6,023,237.47 540,329.65 0.00 9,690.27 12,300.00 91.66 190.00 3,784.43 3,742.83 -8,755.47 -4,389.15 6,023,138.94 540,312.88 0.00 9,787.06 12,400.00 91.66 190.00 3,781.54 3,739.94 -8,853.91 -4,406.50 6,023,040.41 540,296.12 0.00 9,883.85 12,500.00 91.66 190.00 3,778.64 3,737.04 -8,952.35 -4,423.86 6,022,941.88 540,279.35 0.00 9,980.64 12,600.00 91.66 190.00 3,775.74 3,734.14 -9,050.79 -4,441.22 6,022,843.34 540,262.59 0.00 10,077.43 12,700.00 91.66 190.00 3,772.85 3,731.25 -9,149.23 -4,458.58 6,022,744.81 540,245.83 0.00 10,174.22 12,800.00 91.66 190.00 3,769.95 3,728.35 -9,247.67 -4,475.93 6,022,646.28 540,229.06 0.00 10,271.01 12,900.00 91.66 190.00 3,767.05 3,725.45 -9,346.10 -4,493.29 6,022,547.75 540,212.30 0.00 10,367.80 13,000.00 91.66 190.00 3,764.16 3,722.56 -9,444.54 -4,510.65 6,022,449.22 540,195.53 0.00 10,464.59 13,100.00 91.66 190.00 3,761.26 3,719.66 -9,542.98 -4,528.01 6,022,350.68 540,178.77 0.00 10,561.38 13,200.00 91.66 190.00 3,758.36 3,716.76 -9,641.42 -4,545.36 6,022,252.15 540,162.01 0.00 10,658.17 13,300.00 91.66 190.00 3,755.47 3,713.87 -9,739.86 -4,562.72 6,022,153.62 540,145.24 0.00 10,754.96 13,400.00 91.66 190.00 3,752.57 3,710.97 -9,838.30 -4,580.08 6,022,055.09 540,128.48 0.00 10,851.75 13,500.00 91.66 190.00 3,749.67 3,708.07 -9,936.74 -4,597.44 6,021,956.55 540,111.71 0.00 10,948.53 13,600.00 91.66 190.00 3,746.78 3,705.18 -10,035.18 -4,614.79 6,021,858.02 540,094.95 0.00 11,045.32 13,700.00 91.66 190.00 3,743.88 3,702.28 -10,133.62 -4,632.15 6,021,759.49 540,078.18 0.00 11,142.11 13,778.64 91.66 190.00 3,741.60 3,700.00 -10,211.03 -4,645.80 6,021,682.00 540,065.00 0.00 11,218.23 Total Depth:13778.64'MD,3741.60'TVD-4 1/2"x 8 1/2" i Targets ; ' p d ,€Target Name , : :, -hit/miss target Di Angle Di Dir. TVD +N/-S -Shape a :ur : s (°) (°) (usft) (usft) 4 r �5 1 a : MPU L-52 WP11 Heel 0.00 0.00 3,951.60 -2,850.74 -3,055.41 6,029,051.00 541,611.00 -plan hits target center -Circle(radius 50.00) MPL-52 wp07 Toe 0.00 0.00 3,741.60 -10,211.04 -4,645.80 6,021,682.00 540,065.00 -plan hits target center -Circle(radius 50.00) 11/29/2017 11:46:12AM Page 6 COMPASS 5000.1 Build 81D 0 • Halliburton HALLI B U RTO N Standard Proposal Report Database Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:MPU L-52 Company: Hilcorp Alaska,LLC TVD Reference: MPU L-52 As-Built @ 41.60usft Project: Milne Point MD Reference: := MPU L-52 As-Built @ 41.60usft Site: M Pt L Pad North Reference: True Well: { :Plan:MPU L-52 Survey Calculation Method: Minimum Curvature Wellbore: MPU L-52 Design: MPU L-52 WP12 Casing Points .:.. .:. ,., _ sir ; : t Measured Vertical , t 's Casing Depth Depth f E , (usft) (usft) # : '' .. �)to Dia meter `4,::'.; w a 6,350.00 3,956.96 9 5/8"x 12 1/4" 9-5/8 12-1/4 13,778.64 3,741.60 4 1/2"x 8 1/2" 4-1/2 8-1/2 Plan Annotations Measured Vertical Local Coordinates � <.... „,," "`' ` Depth Depth +N/-S +E/-Wr (usft) (usft) 4. (usft) (usft) Comment s,s i. 450.00 450.00 0.00 0.00 Start Dir 2°/100':450'MD,450'TVD 550.00 549.98 -0.74 -1.58 Start Dir 3°/100':550'MD,549.98'TVD 800.00 798.54 -11.32 -24.27 Start Dir 5°/100':800'MD,798.54'TVD 1,730.57 1,566.36 -251.99 -441.94 End Dir :1730.57'MD,1566.36'TVD 5,174.35 3,595.26 -1,990.79 -2,614.44 Start Dir 5°/100':5174.35'MD,3595.26'TVD 6,140.70 3,942.88 -2,752.95 -3,036.40 End Dir :6140.7'MD,3942.88'TVD 6,240.70 3,951.60 -2,850.74 -3,055.41 Start Dir 4°/100':6240.7'MD,3951.6'TVD 6,407.20 3,956.45 -3,014.02 -3,087.15 End Dir :6407.2'MD,3956.45'TVD 7,600.00 3,921.90 4,184.42 -3,314.65 Start Dir 2°/100':7600'MD,3921.9'TVD 7,766.25 3,917.05 -4,346.53 -3,351.07 End Dir :7766.25'MD,3917.05'TVD 11,062.42 3,820.33 -7,538.82 -4,166.34 Start Dir 2°/100':11062.42'MD,3820.33'TVD 11,278.64 3,814.02 -7,750.05 -4,211.86 End Dir :11278.64'MD,3814.02'TVD 13,778.64 3,741.60 -10,211.03 -4,645.80 Total Depth:13778.64'MD,3741.60'TVD 11/29/2017 11:45:12AM Page 7 COMPASS 5000.1 Build 81D • • Hilcorp Alaska, LLC Milne Point M Pt L Pad Plan: MPU L-52 MPU L-52 MPU L-52 WP12 Sperry Drilling Services Clearance Summary Anticollision Report 29 November,2017 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan:MPU L-52-MPU L-52•MPU L-52 WP12 Well Coordinates:6,031,919.76 N,544,648.93 E(70°29'53.08"N,149°38'05.52"W) Datum Height: MPU L-52 As-Built @ 41.60usft Scan Range: 0.00 to 13,778.64 usft.Measured Depth. Scan Radius is 1,530.00 ustt. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:810 Scan Type: NO GLOBAL FILTER:Using User defined selection&filtering criteria '-, ', Scan Type: 25.00 .11 HALLIBURTON '1 1 Sperry Drilling Services 0 • II Hilcorp Alaska,LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU L-52-MPU L-52 WP12 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan:MPU L-52-MPU L-52-MPU L-52 WP12 Scan Range:0.00 to 13,778.64 usft.Measured Depth. Scan Radius is 1,530.00 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 L Pad MPL-03-MPL-03-MPL-03 1,700.00 316.78 1,700.00 298.87 1,756.97 17.683 Ellipse Separation Pass- MPL-03-MPL-03-MPL-03 1,712.26 316.65 1,712.26 299.23 1,765.61 18.173 Centre Distance Pass- MPL-03-MPL-03-MPL-03 2,875.00 821.37 2,875.00 721.34 2687.82 8.212 Clearance Factor Pass- MPL-13-MPL-13-MPL-13 1,357.15 229.21 1,357.15 215.56 1,439.12 16.789 Centre Distance Pass- MPL-13-MPL-13-MPL-13 1,375.00 229.48 1,375.00 215.38 1,447.76 16.282 Ellipse Separation Pass- MPL-13-MPL-13-MPL-13 1500.00 252.92 1,500.00 235.85 1,531.18 14.818 Clearance Factor Pass- MPL-16-MPL-16-MPL-16 667.85 141.11 667.85 131.71 667.10 15.023 Centre Distance Pass- MPL-16-MPL-16-MPL-16 725.00 141.99 725.00 131.22 722.84 13.182 Ellipse Separation Pass- MPL-16-MPL-16-MPL-16 850.00 154.25 850.00 140.86. 837.39 11.519 Clearance Factor Pass- MPL-16-MPL-16A-MPL-16A 667.85 141.11 667.85 131.71 667.10 15.023 Centre Distance Pass- MPL-16-MPL-16A-MPL-16A 725.00 141.99 725.00 131.22 722.84 13.182 Ellipse Separation Pass- MPL-16-MPL-16A-MPL-16A 850.00 154.25 850.00 140.86 837.39 11.519 Clearance Factor Pass- MPL-17-MPL-17-MPL-17 404.35 184.03 404.35 179.01 413.76 36.649 Centre Distance Pass- MPL-17-MPL-17-MPL-17 450.00 184.15 450.00 178.58 458.19 33.036 Ellipse Separation Pass- MPL-17-MPL-17-MPL-17 850.00 218.98 850.00 208.72 853.84 21.332 Clearance Factor Pass- MPL-20-MPL-20-MPL-20 620.95 118.13 620.95 109.40 617.37 13.531 Centre Distance Pass- MPL-20-MPL-20-MPL-20 3,525.00 152.34 3,525.00 95.73 3,608.79 2.691 Clearance Factor Pass- MPL-21-MPL-21-MPL-21 26.50 163.15 26.50 162.23 31.10 178.371 Centre Distance Pass- I MPL-21-MPL-21-MPL-21 450.00 164.25 450.00 158.61 452.83 29.142 Ellipse Separation Pass- MPL-21-MPL-21-MPL-21 800.00 195.90 800.00 185.98 793.51 19.751 Clearance Factor Pass-, MPL-24-MPL-24-MPL-24 26.50 90.30 26.50 89.50 34.20 112.106 Centre Distance Pass- MPL-24-MPL-24-MPL-24 700.00 92.01 700.00 83.46 709.75 10.759 Ellipse Separation Pass- MPL-24-MPL-24-MPL-24 850.00 97.58 850.00 87.38 859.89 9.569 Clearance Factor Pass- MPL-25-MPL-25-MPL-25 475.99 141.56 475.99 135.77 471.51 24.477 Centre Distance Pass- MPL-25-MPL-25-MPL-25 525.00 141.89 525.00 135.50 520.57 22.212 Ellipse Separation Pass- MPL-25-MPL-25-MPL-25 800.00 163.32 800.00 153.51 795.04 16.647 Clearance Factor Pass- MPL-28-MPL-28-MPL-28 692.88 53.36 692.88 44.67 703.40 6.137 Centre Distance Pass- ' MPL-28-MPL-28-MPL-28 725.00 53.58 725.00 44.48 735.35 5.893 Ellipse Separation Pass- 29 November,2017-10:56 Page 2 of 8 COMPASS • • Hilcorp Alaska,L C HALLIBURTON Milne Paint Anticollision Report for Plan: MPU L-52-MPU L-52 WP12 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan:MPU L-52-MPU L-52-MPU L-52 WP12 Scan Range: 0.00 to 13,778.64 usft.Measured Depth. Scan Radius is 1,530.00 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 MPL-28-MPL-28-MPL-28 800.00 56.16 800.00 46.13 809.82 5.601 Clearance Factor Pass- MPL-28-MPL-28A-MPL-28A 692.88 53.36 692.88 44.78 703.40 6.215 Centre Distance Pass- MPL-28-MPL-28A-MPL-28A 725.00 53.58 725.00 44.59 735.35 5.964 Ellipse Separation Pass- MPL-28-MPL-28A-MPL-28A 800.00 56.16 800.00 46.24 809.82 5.663 Clearance Factor Pass- i MPL-29-MPL-29-MPL-29 50.00 125.80 50.00 124.77 60.29 122.229 Centre Distance Pass- MPL-29-MPL-29-MPL-29 425.00 129.17 425.00 123.91 433.77 24.556 Ellipse Separation Pass- MPL-29-MPL-29-MPL-29 775.00 162.52 775.00 153.00 775.52 17.075 Clearance Factor Pass- MPL-32-MPL-32-MPL-32 26.50 30.04 26.50 29.12 21.54 32.777 Centre Distance Pass- MPL-32-MPL-32-MPL-32 375.00 33.25 375.00 27.91 369.64 6.226 Ellipse Separation Pass- MPL-32-MPL-32-MPL-32 4,450.00 241.91 4,450.00 163.73 4,643.71 3.094 Clearance Factor Pass- MPL-33-MPL-33-MPL-33 100.00 114.32 100.00 112.96 107.20 83.677 Centre Distance Pass- MPL-33-MPL-33-MPL-33 525.00 115.06 525.00 108.49 533.89 17.517 Ellipse Separation Pass- MPL-33-MPL-33-MPL-33 800.00 129.75 800.00 119.77 813.05 13.004 Clearance Factor Pass- MPL-34-MPL-34-MPL-34 - - M= .31 0.610 Centre Dis4=1111 MPL-34-MPL-34-MPL-34 ,172.21 0.513 Clearance MIMI -`IL' MPL-34-MPL-34-MPL-34 I- ® - _7,190.910.546 Ellipse Sep ;AIL- MPL-35-MPL-35-MPL-35 - Illlllr 96.80 1111111,`(8,784.58 0.654 Ellipse Separation 'AIL- MPL-35-MPL-35-MPL-35 11.1= 1♦ 92.12 111MI MINE W 8,807.21 0.650 Clearance Factor;_ 'MAIL- MPL-35-MPL-35-MPL-35 - 11( 54.04 ' Or -23.89 8,885.54 0.780 Centre Distance' 'AIL- MPL-35-MPL-35A-MPL-35A 1111111111111111♦ - - • -51.14 16,780.36 0.654 Ellipse Sepd111=1 AIL- MPL-35-MPL-35A-MPL-35A 1- I, -49.6+ 0.650 Clearance fliaM IL- MPL-35-MPL-35A-MPL-35A 1- • -23.811 - m. 0.780 Centre Distance AIL- MPL-35-MPL-35APB1-MPL-35APB1 - ® ® 5114 - r 0.654 Ellipse Separation AIL- MPL-35-MPL-35APB1-MPL-35APB1 1- Ir 92.12 ,450.00 -49.64 mire,808.01 0.650 Clearance Factor FAIL- MPL-35-MPL-35APB1-MPL-35APB1 - r 84.54 111.16,536.49 -23.89 W,.8,886.34 0.780 Centre Distance MPL-35-MPL-35APB2-MPL-35AP82 1 ,08 -51.19 8,785.38 0.654 Ellipse Separation FAIL MPL-35-MPL-35APB2-MPL-35APB2 .1•0 -49.64 8,808.01 0.650 Clearance Factor FAIL- MPL-35-MPL-35APB2-MPL-35APB2 1- II9 -23.89 8,886.34 0.780 Centre Distance FAIL- MPL-35-MPL-35APB3-MPL-35APB3 1- r 96.8d 111111.10 -51.19 8,785.38 0.654 Ellipse Separation FAIL- MPL-35-MPL-35APB3-MPL-35APB3 1111111111111111111 ■ 92.12 allie -49.64 8,808.01 0.650 Clearance Factor FAIL- - MPL-35-MPL-35APB3-MPL-35APB3 r 84.54 Ile -23.89 8,886.34 0.780 Centre Distance FAIL- , 29 November,2017-10:56 Page 3 of 8 COMPASS • • Hilcorp Alaska,L C HALLIBURTON Milne Point Anticollision Report for Plan: MPU L-52-MPU L-52 WP12 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan:MPU L-52-MPU L-52-MPU L-52 WP12 Scan Range: 0.00 to 13,778.64 usft.Measured Depth. Scan Radius is 1,530.00 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 MPL-36-MPL-36-MPL-36 7,013.24 545.08 7,013.24 483.67 6,871.28 8.875 Centre Distance Pass- MPL-36-MPL-36-MPL-36 7,125.00 550.00 7,125.00 479.74 6,954.54 7.827 Ellipse Separation Pass- MPL-36-MPL-36-MPL-36 7,625.00 675.73 7,625.00 566.96 7,334.08 6.212 Clearance Factor Pass- MPL-36-MPL-36L1-MPL-36L1 7,013.24 545.08 7,013.24 483.95 6,871.28 8.916 Centre Distance Pass- MPL-36-MPL-36L1-MPL-36L1 7,125.00 550.00 7,125.00 480.02 6,954.54 7.859 Ellipse Separation Pass- MPL-36-MPL-36L1-MPL-36L1 7,625.00 675.73 7,625.00 567.24 7,334.08 6.229 Clearance Factor Pass- MPL-36-MPL-36L1 PB1-MPL-36L1 PB1 7,013.24 545.08 7,01324 483.88 6,871.28 8.906 Centre Distance Pass- MPL-36-MPL-36L1 PB1-MPL-36L1 PB1 7,125.00 550.00 7,125.00 479.95 6,954.54 7.851 Ellipse Separation Pass- MPL-36-MPL-36L1 PB1-MPL-36L1 PB1 7,625.00 675.73 7,625.00 567.17 7,334.08 6.225 Clearance Factor Pass- MPL-36-MPL-36PB1-MPL-36PB1 7,013.24 545.08 7,01324 483.67 6,871.28 8.875 Centre Distance Pass- MPL-36-MPL-36PB1-MPL-36PB1 7,125.00 550.00 7,125.00 479.74 6,954.54 7.827 Ellipse Separation Pass- MPL-36-MPL-36PB1-MPL-36PB1 7,625.00 675.73 7,625.00 566.96 7,334.08 6.212 Clearance Factor Pass- MPL-37-MPL-37-MPL-37 8,775.00 601.00 8,775.00 477.96 8,519.92 4.884 Clearance Factor Pass- MPL-37-MPL-37-MPL-37 9,275.00 553.97 9,275.00 454.05 9,007.32 5.544 Ellipse Separation Pass- MPL-37-MPL-37-MPL-37 9,468.16 547.57 9,468.16 461.43 9,182.33 6.357 Centre Distance Pass- MPL-37-MPL-37A-MPL-37A 8,775.00 601.00 8,775.00 477.96 8,529.12 4.884 Clearance Factor Pass- MPL-37-MPL-37A-MPL-37A 9,275.00 553.97 9,275.00 454.05 9,016.52 5.544 Ellipse Separation Pass- MPL-37-MPL-37A-MPL-37A 9,468.16 547.57 9,468.16 461.43 9,191.53 6.356 Centre Distance Pass- MPL-39-MPL-39-MPL-39 4,381.80 231.36 4,381.80 157.71 4,499.34 3.141 Clearance Factor Pass- MPL-40-MPL-40-MPL-40 4,268.60 503.33 4,268.60 412.80 4,505.12 5.560 Centre Distance Pass- MPL-40-MPL-40-MPL-40 4,525.00 516.60 4,525.00 397.83 4,728.83 4.350 Ellipse Separation Pass- MPL-40-MPL-40-MPL-40 5,050.00 618.51 5,050.00 452.51 5,197.21 3.726 Clearance Factor Pass- MPL-43-MPL-43-MPL-43 26.50 211.14 26.50 210.44 35.70 300.113 Centre Distance Pass- MPL-43-MPL-43-MPL-43 300.00 212.18 300.00 208.20 306.65 53.298 Ellipse Separation Pass- MPL43-MPL-43-MPL-43 825.00 255.77 825.00 245.79 816.61 25.611 Clearance Factor Pass- MPL-43-MPL-43PB1-MPL-43PB1 26.50 211.14 26.50 210.22 35.70 230.232 Centre Distance Pass- MPL-43-MPL-43PB1-MPL-43PB1 300.00 212.18 300.00 207.99 306.65 50.585 Ellipse Separation Pass- MPL43-MPL-43PB1-MPL-43PB1 800.00 250.38 800.00 240.40 794.00 25.068 Clearance Factor Pass- MPL45-MPL-45-MPL-45 437.88 205.68 437.88 200.48 446.86 39.529 Centre Distance Pass- MPL45-MPL-45-MPL-45 500.00 206.08 500.00 200.13 506.84 34.632 Ellipse Separation Pass- '1 MPL-45-MPL-45-MPL-45 900.00 229.80 900.00 219.38 892.90 22.064 Clearance Factor Pass- 1 I 29 November,2017-10:56 Page 4 of 8 COMPASS , I • l Hilcorp Alaska,LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU L-52-MPU L-52 WP12 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan:MPU L-52-MPU L-52-MPU L-52 WP12 Scan Range: 0.00 to 13,778.64 usft.Measured Depth. Scan Radius is 1530.00 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 MPU L-53-MPU L-53-MPU L-53 26.50 14.83 26.50 13.92 26.50 16.268 Centre Distance Pass- MPU L-53-MPU L-53-MPU L-53 325.00 15.70 325.00 11.29 324.85 3.558 Ellipse Separation Pass- MPU L-53-MPU L-53-MPU L-53 400.00 17.79 400.00 12.40 399.47 3.298 Clearance Factor Pass- Plan:MPU L-54-MPU L-54-MPU L-54 WP06 637.44 97.48 637.44 86.49 646.18 8.869 Centre Distance Pass- Plan:MPU L-54-MPU L-54-MPU L-54 WP06 675.00 97.92 675.00 86.28 683.38 8.409 Ellipse Separation Pass- Plan:MPU L-54-MPU L-54-MPU L-54 WP06 800.00 106.08 800.00 92.26 805.73 7.675 Clearance Factor Pass- Plan:MPU L-56-MPU L-56-MPU L-56 WP04 1,068.19 64.42 1,068.19 53.18 1,104.12 5.733 Ellipse Separation Pass- Plan:MPU L-56-MPU L-56-MPU L-56 WP04 1,075.00 64.46 1,075.00 53.19 1,110.64 5,718 Clearance Factor Pass- Plan:MPU L-57-MPU L-57-MPU L-57 WP04 254.10 109.77 254.10 105.53 254.30 25.865 Centre Distance Pass- Plan:MPU L-57-MPU L-57-MPU L-57 WP04 325.00 110.19 325.00 104.72 323.38 20.161 Ellipse Separation Pass- Plan:MPU L-57-MPU L-57-MPU L-57 WP04 625.00 136.05 625.00 125.52 608.88 12.926 Clearance Factor Pass- RIG:MPU L-51-MPU L-51-MPU L-51 WP07a 279.10 15.23 279.10 10.55 279.30 3253 Centre Distance Pass- RIG:MPU L-51-MPU L-51-MPU L-51 WPO7a 425.00 16.02 425.00 8.80 424.96 2217 Ellipse Separation Pass- RIG:MPU L-51-MPU L-51-MPU L-51 WPO7a 475.00 17.62 475.00 9.53 474.63 2,177 Clearance Factor Pass- Milne Point Exploration Pesado-01-PESADO-01-Pesado-01 8,628.87 665.43 8,628.87 579.06 4,178.77 7.704 Centre Distance Pass- Pesado-01-PESADO-01-Pesado-01 8,675.00 666.94 8,675.00 577.46 4,167.57 7.454 Ellipse Separation Pass- Pesado-0l-PESADO-01-Pesado-01 8,825.00 692.06 8,825.00 594.88 4,129.15 7.121 Clearance Factor Pass- Pesado-0l-PESADO-01A-Pesado-01A 8,731.20 768.31 8,731.20 682.39 4,021.36 8.942 Centre Distance Pass- Pesado-0l-PESADO-01 A-Pesado-01A 8,775.00 769.54 8,775.00 681.32 4,016.43 8.723 Ellipse Separation Pass- Pesado-01-PESADO-01 A-Pesado-01A 8,925.00 792.08 8,925.00 697.82 3,999.68 8.404 Clearance Factor Pass- 29 November.2017- 10:56 Page 5 of 8 COMPASS • • Hilcorp Alaska,LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU L-52-MPU L-52 WP12 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 26.50 800.00 MPU L-52 WP12 2_Gyro-SR-GSS 800.00 6,250.00 MPU L-52 WP12 2_MWD+IFR2+MS+Sag 6,250,00 13,778.64 MPU L-52 WP12 2_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. 29 November,2017- 10:56 Page 6 of 8 COMPASS 41110 • HALLIBURTON Project: Milne Point REFERENCE INFORMATION WELL DETAILS:Plmr:MPU L52 NAD 1927(NADCONCONUS) Alaslm Zone 04 Site: M Pt L Pad Co-ordinate(N/E)Reference:Wall Plan:MPU L-52,Tiva North Ground Level: 15.10 S nr;n,n Well: Plan:MPU L-52 Vertical(TVS)Reference:MPUL-53 As-eatsap4l.WusR +ws &-w Northing F 186aae Longitude parry g Measures Depth Reference:MPU Lae Aa-Ruin 414011W 0.00 0.00 6031919.76 544648.93 70°27 53.079N 149.38'5.523 W Wellbore: MPU L-52 Calculation Marred:Minimum Curvature Plan. MPU L-52 WP12 SURVEY PROGRAM GLOBAL FILTER:Using user defined selection&filtering criteria nHilcori) 26.50 To 13778.64 Date:20184)8-03700:00:00 Validated:Yes Version: Ladder/S.F. Plots Depth From Depth To Survey/Plan Tool CASING DETAILS 26.50 800.00 MPU L-52 WP12 2_Gyro-SR-GSS 800.00 6250.00 MPU L-52 WP12 2 MWD+IFR2+MS Sag TVD TVDSS MD Size Name 6250.00 13778.84 MPU L-52 WP12 2_MWD+IFR2+MS Sag 3956.96 3915.36 6350.00 9-5/8 9 5/5"x 12 1/4" 3741.60 3700.00 13778.64 4-1/2 4 1/2"x8 1/2" 150.00- 25__-I-:T.r.'I 1. I l I III -MPL-2" r n 1 'I'.RU L-5 .i I a w „(• 3 ,II�I�� ,, II I .. . 1 t MPI.-35APB0 � — —11 l,I I R i,(LPL-35AP82 o �� I o120.00 - 1 l c e -li rI l,��.32 ..t 1 III�I 71 I i II, �O Pa:55APBI 90.00 �' c0 i n 60.00 0 PL-28A i it Ii I` � 11 1 MP4-35A "''1W07a MP _34 I• 3000 / _ 1i____________ 141 02 MPU L 53 of I 1 I lI�B C) - lwull;-MPU L511MP07a I ) ItI 0.00 1 1 l i l l I l l l l I l l i l , , , I I I I I l l l l 1 1 1 1 1 1 t h 1 1 1 1 1 1 1 1 1 jt I 111111111 1111 1111 1111 11 l l 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 Measured Depth(1500 usft/in) 4.50— .. I L... . IF l j 1 1 m 3.00— _.._ —... ... I `ni m• -, I. to - - Collision Avoidance Req.i to 1.50—No-Go Zone-Stop Drillit I I 0.00 1111 1111 1111 111111111111111 11 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 12800 13600 14400 Measured Depth(1500 usft/in) • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, December 11, 2017 3:23 PM To: jengel@hilcorp.com' Subject: MPU L-52 (PTD 217-174): Permit to Drill Application Good afternoon Joe, In the Drilling Program attached to the Application, is page 11 black under Section 7.0 Drilling/Completion Summary? Page 10 ends with 9.12 (R/U and Preparatory Work)and page 12 begins with 10.0 (N/U 13 5/8" Diverter Configuration). Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • TRANSMITTAL LETTER CHECKLIST WELL NAME: AA?u L ' 6 Z PTD: 2-1 / - 17 `7 Development ✓ Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: M 1)1,- POOL: S UYI Y e- 'b ILA Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted,to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 • a 0 0 w , , , , , ,, a) Q , , , a , y' , o L 7 , C (a' , 0. , , , a)' C ‘r, �� ay O O C' Cy O. V, a' U N p E C m c � O C 3, 0) O, m o lri Q o o' a o, 3. M' fl, @ O? N' . a 6 E. w, (0' J. c a w Y o J' O. N c 'O' y 0 a y O' y W caa -' J, y , C ' O , y , p >, ' O, m a ca , E , g N a �, N' 0, O' O� N, .' O as C" O' M 4 a) o' U, c, �, o' u' a a' 0 1° o. a; 0 .0 6 W c, n' v � v Z0 co,c0) (Cl. o , a' , o. m; m; , -o, . 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