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M K 99503 TAnchorage, 907 77 3 7 8337 HiIrorp Alaska.LTA. Fax: 907 777-8510 DEC 2017 E-mail: doudean@hilcorp.com 07DATE 12/05/2017 AOGCC To: Alaska Oil & Gas Conservation Commission DATA LOGGED Meredith Guhl, Petroleum Geology Assistant I2-/11i2ot7 333 W. 7th Ave. Ste#100 K BENDER Anchorage, AK 99501 DATA TRANSMITTAL GP 11-24RD (217-123 2 8 8 4 4 GP 11-24RD PB1 2 8 8 4 5 Prints: ROP ABG ADR CTN ALD MD/TVD CD: _Log Viewers 11/16/201710:20... File folder CGM 11/16/2017 10:20... File folder Definitive Survey 11/16/2017 10:20... File folder EMF 11/16/201710:20... File folder LAS 11/16/2017 1020_. File folder PDF 12/1/2017 4:17 PM File folder TIFF 11/16/2017 10:22_. 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: Date: 217123 • • IItr,i, Hilcorp Alaska, LLC t' + e h3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 C07 2017 Tele: 907 777-8337 Hilrnrp Atooka,LLC Fax: 907 777-8510 E-mail: doudean@hilcorp.com AOGCC DATE 12/05/2017 DATA LOGGED M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 DATA TRANSMITTAL GP 11-24RD (217-123) 2 8 8 4 6 GP 11-24RD PB1 2 8 8 4 7 Prints: Formation Log 5IN/2IN MD / TVD LWD Combo Log MD /TVD Gas Ratio Log MD /TVD Drilling Dynamics Log MD / TVD Final Well Report CD: Final Well Data _Log Viewers 11/16/2017 10:20... File folder CGM 11/16/2017 10:20_. File folder J Definitive Survey 11/16/201710:20... File folder EMF 11/16/201710:20... File folder LAS 11/16/201710:20... File folder PDF 11/16/201710:21... File folder k TIFF 11/16/20171022... 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 Recei vecf r Date: 4/ • 21123 010ebra Oudean Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive, Suite 100 ' HOZ 3 Anchorage, AK 99503 Tele: 907 777-8337 ` (o Z :‘11tAa,1.1.t: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 12/05/2017 RECEIVED To: Alaska Oil & Gas Conservation Commission cc o 7 2017 Meredith Guhl, Petroleum Geology Assistant ®�^r+ 333 W. 7th Ave. Ste#100 t�JJVV Anchorage, AK 99501 DATA TRANSMITTAL GP 11-24RD (217-123 Transmitted herewith are cuttings WELL BOX # SAMPLE INTERVAL t4o2q GP 11-24RD PB 1 OF 4 8005'-9780' GP 11-24RD PB 2 OF 4 9780'-11280' 1b2:3 GP 11-24RD 3 OF 4 10700'-12300' GP 11-24RD 4 OF 4 12300'-12616' 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 R eiv,t3(11n Date: / I IU/ 'Vn�, ( I ( RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Nov 3 U 2017 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil r Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1•A 2 r 1-- 20AAC 25.105 20AAC 25.110 Development , Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Dateomp. Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC . Aband.: 11/3/2017 . . 217-123/317-461 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 September 26,2017 50-733-20046-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2383'FSL, 1368'FEL, Sec 13,T1ON, R12W,SM,AK October 21,2017 Granite Pt St 11-24RD Top of Productive Interval: 9. Ref Elevations: KB: 115' 17. Field/Pool(s):Granite Point Field 366'FNL, 1446'FWL,Sec 24,T1ON, R12W,SM,AK GL:0 BF:55.3' Middle Kenai Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1572'FNL,2392'FEL,Sec 24,T1ON,R12W,SM,AK . 12,483'MD/10,431'TVD ADL018761 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 263398 y- 2544542 Zone- 4 ' 12,613'MD/10,476'TVD N/A TPI: x- 263414 y- 2541283 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 264832 y- 2540048 Zone- 4 376'MD/376'TVD N/A 5. Directional or Inclination Survey: Yes Li 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 75' (ft MSL) 8,006'MD/7,418'TVD CO- 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printelogs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary ROP ABG DGR ADR CTN ALD MD,ABG DGR ADR CTN ALD TVD, FORMATION LOG 51N/2IN MD/TVD, LWD COMBO LOG MD/TVD,GAS RATIO LOG MD/TVD, DRILLING DYMANICS MD/TVD ROP ABG DGR ADR CTN ALD MD,ABG DGR ADR CTN ALD TVD, FORMATION LOG 51N/2IN MD/TVD,LWD COMBO LOG MD/TVD,GAS RATIO LOG MD/TVD, DRILLING DYMANICS MD/TVD PB1 CBL 10/31/17 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT HOLE SIZE CEMENTING RECORD CASING FT. GRADE TOP BOTTOM TOP BOTTOM PULLED 7" 26# L-80 7,756' ., 12,611' " 7,191' 10,475' 8-1/2" 586 sx 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): 2-7/8" 10,468'MD 10,408'MD/9,621'TVD 10,568'-10,616'MD/9,719'-9,746'TVD 10,682'-10,782'MD/9,779'-9,829'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 10,876'-12,400'MD/9,874'-10,405'TVD / Was hydraulic fracturing used during completion'? Yes❑ No Q 4-5/8",6 SPF, 10/31/17 I (' Per 20 AAC 25.283(i)(2)attach electronic and printed information ((( DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 11/5/2017 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 11/16/2017 24 Test Period O 1042.8 303.6 0 N/A 291.1 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 83 794 24-Hour Rate . 1042.8 303.6 0 39 Form 10-407 Revis d 5/ 017 CONTINUED ON PAGE 2 Submit ORIGINIAL o y It'� 124474I17-- 1Z/ > ; /2-27—l7 RP!S Ai [I n 2917 • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No ❑l If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No Q Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10,568'Tyonek C5 9,719 information, including reports,per 20 AAC 25.071. Cl 9,656' 9,008' C2 9,990' 9,305' C5A 10,568' 9,719 Formation at total depth: Tyonek C5 31. List of Attachments: Wellbore Schematic, Decomplete, 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: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdingerp.com Authorized // Contact Phone: 777-8389 Signature: ? ' f z4 Date: �' zo 11 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 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water:Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • Granite Point Platform Well: Granite Pt St#11-24rd SCHEMATIC PTD:217-123 API: 50-733-20046-01 1Iilcorp Alaska,LLC Last Completed: 11/03/2017 RHO CASING DETAIL 105.9'RIOtoMSL Size Wt Grade Conn ID Top Btm J 18" 70.59 B Ventura Surf 638' 13-3/8" 61 J-55 8rd 12.515" Surf 4,030' ill 18„ 40 N-80 Butt 8.835" Surf 82' 43.5 N-80 Butt 8.755" 82' 123' C DV Collar N-80 Butt 8.835" 123' 1,955' 9-5/8" @2,285 40 N-80 LT&C 8.835" 1,955' 5,547' 40 S-95 ST&C 8.835" 5,547' 6,537' 43.5 S-95 ST&C 8.755" 6,537' 8,007'(KOP) 13-3/8" 7" 26 L-80 DWC/C 6.276" 7,756' 12,611' TUBING DETAIL 2-7/8" 6.5 L-80 8 rnd EUE 2.441" Surf 10,468' 13-38(-440) Bad spot veere , screwed into csg after pahng _ JEWELRY DETAIL 1 H Depth Depth ID OD Item (MD) (TVD) 54' 54' Tubing Hanger 1 376' 376' 2.313" 4.91" Halliburton TRSV-NE 2,639' 2,509' 2.441" 4.750" GLM#1—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch M. 4,499' 4,225' 2.441" 4.750" GLM#2—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch 5,922' 5,512' 2.441" 4.750" GLM#3—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch 6,908' 6,419' 2.441" 4.750" GLM#4—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch 2 7,676' 7,121' 2.441" 4.750" GLM#5—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch 2 8,318' 7,707' 2.441" 4.750" GLM#6—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch �V�' 9-5/8" 8,835' 8,214' 2.441" 4.750" GLM#7—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch V/(1100 ' 9,353' 8,717' 2.441" 4.750" GLM#8—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch 9,870' 9,203' 2.441" 4.750" GLM#9—PSPO-1M Mandrel,R-1 Valve,BK-2 Latch I1� 10,356' 9,586' 2.441" 4.750" GLM#10—PSPO-1M Mandrel,RO-1 Orifice,BK-2 S Latch 7"x 3-1/2"Packer—DLH Hydraulic Retrievable w/ �`� 3 10,408' 9,621' 3.000" 5.875" 46k Shear(DL-935-7000-061—26.0-32.0#) k� 4 10,461' 9,655' 2.313" 3.210" X Nipple 5 10,468' 9,659' 2.430" 3.700" WLEG PERFORATION DETAIL TOC@ I Top Btm Top Btm 9,914 Zone (MD) (MD) (TVD) (TVD) FT SPF Date Status a. 0 i 1 f C-5 10,568' 10,616' 9,719' 9,746' 48' 6 10/31/17 Open C-5 10,682' 10,782' 9,779' 9,829' 100' 6 10/31/17 Open 3 r,' • C-5 10,876' 12,400' 9,874' 10,405' 1,524' 6 10/31/17 Open ti 4 li .11 5 G5 tN7' PBTD:12,483' TD:12,613' Max Hole Angle 77.85°@ 12,208' Updated By:JLL 11/27/17 • • Hilcorp Energy Company Composite Report Well Name: GPF GP 11-24RD Field: County/State: ,Alaska (LAT/LONG): avation(RKB): API#: Spud Date: Job Name: 1711828P GP 11-24RD PreDrill Contractor AFE#: AFE$: tEQ ,'?iWilStEt ...::.:.:.:.:.:.:... :..:..:..:..:..:. 6/11/2017 (Initial report)Skidded rig South then East from 22-13RD2 to 11-24. Laid derrick over in order to use crane while finishing skid with chain hoists-stowed jacking equipment.,Spotted choke and koomey houses,electrical bang box-hooked up all high pressure hoses to mud pump-installed all handrails and walkways-positioned racking matt. Cleaned and organized deck.,Held PJSM w/rig and crane crews,production,NOS(2)and WSM-insured casings were open to atmosphere. N/D dry hole tree-L/D same. Cleaned corrosion and old emergency packing material from top of 9 5/8"x 13 3/8"packoff-pulled and replaced packoff w/fresh one. NOS reps tested packoff to 500 psi low 3500 psi high-installed 4 1/2"IF test plug w/drain hole.,Began N/U 13 5/8"5M BOPE. 6/12/2017 Finished N/U 13 5/8"5M BOP stack.,Raised and scoped out derrick securing all guy lines. Ran and connected koomey and circ lines to stack-positioned drill shack-mounted rig floor,wind walls,steps to drill shack and off side-hooked up remote control panel-set bang box in place at front of rig along w/test pump. Energized koomey unit and functioned all hyd components.,Changed brakes pads on draw works and functioned tested after mounting-all good,R/U floor w/ handing tools and tongs- M/U test equipment wI 3 1/2"test jt-screwed into test sub and shell tested to 3500 psi.,Tested BOPE to 250 psi low 3500 psi high as per Sundry in accordance to AOGCC and Hilcorp requirements-performed successful koomey draw down test. Test witness waived by Mr. Regg at 2:02 PM 6/12/17.,R/D test equipment and pulled test plug.,M/U BHA#1 8 1/2"bit and scraper= 8.93'. TIH picking up 3 1/2"12.95#P-110 PH-6 workstring off deck- strapping,drifting and torqueinq to 6000 FPT. 938'in hole at report time. 6/13/2017 TIH w/8 1/2"bit&scraper picking up 3 1/2"12.95#P-110 PH-6 workstring off deck-strapping,drifting,torqueing to 6000 FPT. Ran in 290 jts=9,003'(PUW • 126k SOW 78k). M/U safety valve and lined up to rev across shaker-closed pipe rams.,Reversed 1 hole volumes(655 bbls clean FIW)at 2.7 bpm 350 psi.,R/U and tested 9 5/8"casing to 2600 psi for 45 mins on chart w/no loss(9 5/8"X 13 3/8"annular pressure is 150 PSI @ 2600 PSI on 9 5/8"casing)- all good. Bled off pressure-R/D test equipment.,Started OOH L/D 3 1/2"PH6 work string-0330 hrs worked MN Titon receiving kill string and hanger. 224 of 290 jts OOH at report time=2,052'. 0 fluid lost to well last 24 hrs. 6/14/2017 Finished POOH WI BHA#1 (8 1/2"bit&scraper)-laying down workstring. B/D bit&scraper-cleared rig floor.,Spotted and RIU Pollard ELine equipment. M/U GR/Sector Cement Bond Tool and TIH tagging at 9,248'(correlated to GP11-24_GR.las file)-logged from 9,248'to 7,248'in 9 5/8"40-43.5#casing(poor quality to no cement thru interval). POOH&B/D bond tool.,M/U PDS Multifinger Casing Caliper Tool(memory mode)and TIH to 9,220'-pulled log from 9,220' to surface. OOH at 1700 hrs-tool programed to close at 1736 hrs. RID ELine.,Laid out&strapped 3 1/2"9.2#L-80 BTC kill string after moving ELine unit-ran in open ended wI 70 jts(2,187.81')-M/U hanger w/pup&landing jt(w/assistance from NOS)- PUW 26K SOW 26K.,Drained stack and landed hanger(EOT at 2,235.50')-ran in holdown pins-laid down landing jt and and set BPV.,Cleared rig floor of handling tools and tongs-rigged down floor. Scoped in and laid over derrick-moved pipe racking mat.,N/D BOPE-began prepping workover package for transpot to Dolly.,N/U dry hole tree. 6/15/2017 Finished N/U dry hole tree-tested hanger void to 800 psi low f/5 mins,5000 psi high f/15 mins. Pulled BPV and set 2-way check-shell tested tree to 600 psi low ft 5 mins,5000 psi high f/15 mins. Pulled 2-way check and handed well back to production.,Organizing and cleaning W/O package in prep for move to Dolly Platform D-16RD well. Cleaned front end of rig tank,unstrung drill line onto spool,unbolted draw-works,moved driller shack,washed down carrier& derrick,washed down BOPE,cleaned out sand trap. Night crew will depart for Dolly Platform at 6 am while Day crew will load MN with 1st load of W/O equipment. This will be the last report on pre-drill AFE. • ! Hilcorp Energy Company Composite Report Well Name: GPF GP 11-24RD Field: County/State: ,Alaska i(LAT/LONG): ovation(RKB): API#: Spud Date: 9/26/2017 Job Name: 1711828D GP 11-24RD Drilling Contractor Kuukoik 5 AFE#: AFE$: 9/22/2017 Skid rig from 22-13&spot over well.Install storm clamps.stairs&landings.Connect service lines. 9/23/2017 Install Koomey landing,water tank landing.Move service lines for bridge stand.Lower bridge stand and upper bridge stand.Set catwalk and beaver slide.Pull rotary table.Pull riser spool out of;cellar.Assist with setting BPV.Prepare to nipple down tree.Begin working on flow line.;Secure cat walk stand and support complex.Hold PJSM.Nipple down tree.Install riser and gray lock.Nipple up BOPE.;Cont.to N/U BOPE.CIO upper rams to 2-7/8"X5"VBR's.N/U kill line manifold.Welding projects.;N/U Koomey lines&function BOPE.N/U flow line,flow box,&pollution pans. Install rotary table.Clean&clear rig floor. 9/24/2017 Install flow line to shakers.Hang service lines in sub.Clear and clean rig floor.R/U vacuum unit to sub.Fabricate new flow nipple.Organize and clean cellar area.;Organize and clean all areas of rig.Continue with miscellaneous welding projects.;Make up 41/2" test joint.Fill stack.Shell test at 2500 psi.Test BOPE at 250 L/3500 H,and annular at 250 L/2500 H.AOGCC(Jim Regg)waived witness of test on 9/22 at 14:20 hrs.;Changed out 1 ea. 2 1/8"annulus valve during BOPE test.UD 4 1/2"test joint.;M/U 3 1/2"test joint.Test upper pipe rams at 250 L/3500 H,and annular at 250 L/2500 H.UD 3 1/2"test joint.;Pull BPV.M/U landing joint& &engage hanger.BOLDS.Pull hanger to rig floor&UD landing joint.;R/U Weatherford to LID tubing.Breakout of hanger&UD same.;POOH &UD 70 jts 3-1/2"tubing from 2188'.;R/U Pollard E-Line&M/U Baker CIBP.;RIH with CIBP.;Wellhead pressures:20"=34 psi,13 3/8"=40 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered: 0 lbs.Total:0 lbs. 9/25/2017 Pollard e-line RIH with CIBP.Correlate on depth and set plug at 8,028'.POOH and R/D wire line unit.;Test casing at 1500 psi on chart for 30 minutes(good test). Pumped 5 bbls/bled off 4 bbls.;RIH picking up 14 joints of HWDP and 10 joints of CDS-40 drill pipe.;Service rig.Hold'kick while tripping'drill.;RIH picking up drill pipe.Picked up a total of 56 joints.;POOH standing back HWDP and drill pipe.;Clear rig floor.Pick up whip stock assembly.;M/U whipstock milling assembly as per Baker rep to 595'.Shallow hole test MWD(good).;RIH with whipstock&mills to 7,854'.;Orient whipstock to 48 Right.Set whipstock&shear as per Baker rep.TOW-8,006'/BOW-8,023'.;Clean&clear floor.Prep for OBM displacement.;Wellhead pressures:20"=34 psi,13 318"=40 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered: 0 lbs.Total:0 lbs. 9/26/2017 Displace FIW to production at 5 BPM/380 psi.;Take on OBM from beam tank for pit volume and well displacement.;Displace well with OBM at 5 BPM/400 psi. Circulate and condition mud.;Establish SPRs&Beain millina window at 8 006'.,per Baker hand.DW 97K,ROT 105K,100 RPM,TQ 5K off bottom,TQ 6-10K on %.) )bottom,420 GPM 2050 PSI.;Mill window from 8,006'to 8,016',with 60%CMT,15%Metal,10%Coal,15%Claystone in returns.Continue milling window from \� c" 8,016 to bottom of window at 8,023'. Drill 20'of new hole in 5'.;increments due to fast ROP. Stop rotation and lowered pump rate,formation would hold 10K ,!) WOB. Drill 20'of new hole,work mills through window cleaning up same. (Recovered 311 lbs metal).;Circ hole clean and condition for FIT.;Perform FIT to 12.5 EMW,charting same took 6 BBL to achieve 12.5 EMW and bled back 5 BBL.;Continue drilling new formation from 8,043'to 8,073'for a total of 50'of new hole B.L4 outside of window.at 2.5K WOB,90 ROP,425 GPM.2020 PSI SPP.;Rack back 1 stand to 7,982'.Circulate and condition mud prior to tripping out of hole for directional BHA,while polishing and drifting window.F/C&pump dryjob.;POOH from 7,982'to 80'.Racked back HWDP.;UD Baker milling BHA from 80'.;Clean &clear floor.R/U Johnny wacker to flush stack.;Wellhead pressures:20"=20 psi,13 3/8"=110 psi I Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered: 311 lbs.Total:311 lbs. 9/27/2017 Wash out stack with Jonny Wacker and lay down same. Make up test plug,with one stand of HWDP below,and land same.;Screw top drive into landing joint and cut drilling line 100',while changing out drillers side hinge pin seals on upper pipe rams and blind rams.;Service rig and center torque tube,assist SWACO 1`,.a� technician,installing the shaker pulser's on shakers.;Charge accumulator system,operate upper pipe rams and blind rams to verify hinge pin seal integrity. Note: Door seals were never compromised and did not require a shell test of same.;Screwed landing joint into test plug,backed out lockdown pins and pulled test plug. Laid down test plug,and HWDP below same.;Pick up BHA#2,Halliburton Geo-Pilot rotary steerable assembly to the float sub.;Screw into tools with top drive, and upload data to tools.Shallow hole test MWD tools(good).PJSM&load sources.Cont.to M/U BHA to 676';RIH with BHA#2 from 676'to7,993'(Fill pipe& test MWD tools @ 4,076');Break circulation to warm up mud.Service rig.SPR's;Cont.to RIH washing with 1 bpm from 7,993'to 8,073'.No issues running thru window&no fill on bottom;Drill ahead 8 1/2"production hole from 8,073'to 8,150'.400 gpm,2250 psi,PU wt 116 k,SO wt 97 k,ROT wt 107,80 rpm,8 k trq, ECD 9.6 ppg with 9.2 ppg mud wtWellhead pressures:20"=3 psi,13 3/8"=76 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:0 lbs.Total:311 lbs. • • 9/28/2017 Drill 8-1/2"hole f/8150'V 8154'.Appears to be going along side old wellbore.;Contact engineer and decided to trough f/8121't/8151'then time drill.Continue to trough and started seeing indications of getting away from old wellbore.;Time drill at 1 FPH f/8151'V 8158'.402 GPM,2091 Psi,90 RPM,5700 TQ.;Continue time drilling at a lower pump rate and RPM f18158'V 8158.50'.325 GPM,1410 Psi,70 RPM,5300 TQ.;Lost air boot on bottom of flow nipple.Shut down and change out boots.;Time drill at the lower pump and rotary rates f/8158'V 8162'.320 GPM,1400 PSI,70 RPM,5.5 K TQ,PU 120 K,SO 97 K,ROT 107 K.;Time drill at the lower pump and rotary rates f/8162't/8169'.320 GPM,1400 PSI,70 RPM,5.5 K TQ,PU 120 K,SO 97 K,ROT 107 K.;Wellhead pressures:20"=4 psi,13 3/8"=152 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal rprnvprpd•34 Ihs Total'344 Ihs 9/29/2017 Time drill from 8169'to 817,320 GPM,1400 PSI,70 RPM,5.5K TQ.;Attempt to drill ahead and depart from original wellbore,drilled from 8170'to 8191',started taking extra wt and wouldn't drill off,possible non rotating sleeve on RSA hanging on casing coupling'.;Pull up 7955'into window with no issues. Contacted town, decision made to trip for motor with 1.76 bend to attempt departure from original wellbore.;Monitor well,static,pump dry job.;Trip out of hole with Geo-Pilot from 7955'to BHA at 676'.;Work BHA.Stand back NM DCs,Hold PJSM and remove source.Down load LWD data.Cont.to LID BHA#2.Bit Grade:1-7-BT-T-X-2-CT- BHA.;Clean&clear floor of BHA tools&equipment.;Service rig&top drive.;M/U mud motor BHA#3 to 609'.Motor offset 44.61.;Shallow hole test MWD tools.RIH with BHA#3 from 609'to 7986'.;Fill pipe.Orient motor.RIH thru window without pumps&no issue to 8050'.;Trough from 8050'to 8080',not able to maintain tool face.RIH&trough from 8100'to 8130'as per DD.370 GPM,2000 PSI.Tool face 170 Right.;Time drill sidetrack from 8130'to 8,131'.370 GPM,2000 PSI.Tool face 170 Right.;Wellhead pressures:20"=4 psi,13 3/8"=20 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:2 lbs.Total:350 lbs. 9/30/2017 Time drill to attempt to make an open hole side track f/8130'V 8134 to gain departure from open wellbore.;Wash down to bottom at 8191'maintaining tool face of 170 right.;Slide drill to achieve departure from original wellbore f/8191'V 8251'.;Rotate f18251'V 8281'.Had to work through a hard spot f/8262't/8267'by changing the parameters.413 Gpm,2360 Psi,60 RPM,6 V 7k Tq.Inc at 8281 was 21.18=1.7 deg separation f/orig well.;Slide drill f/8267't/8410'(11'from original well bore @ 15.8°Inc). 415 GPM,2400 PSI,PU wt 111 K,SO wt 93 K,ROT wt 104 K,70-80 RPM,5-6.5 K TRQ.;Circ B/U 420 GPM,2450 PSI.SPR's. Pump dry job.;POOH from 8410'to 7986'.Tight hole from 8360'-8310'with 10-40 k over pull&occasional jarring.No issues pulling thru window.;Preventative maintenance on rig by install protective wrap on top drive service loop.Service rig.Center BOPE stack under rotary table.;Cont.POOH from 7986'to 6178'.;Wellhead pressures:20"=4 psi,13 3/8"=86 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal rernvarpd•q Ihs Total•459 Ihs 10/1/2017 Trip out of hole with BHA#3 from 6178'to BHA at 609'.;Work BHA,drain motor,remove bit and laydown TM,DM collars along with motor.Bit Grade:1-2.;Clean and clear rig floor,begin picking up BHA#4,making bit up on Geo-Pilot.;Continue making up BHA#4,upload MWD,PJSM,load sources in LWD tools,shallow test tools. Continue to run in hole with NMDC,jars,and HWDP to 676'.;Trip in hole with BHA#4 from 676 to 4080',break in seals on Geo-Pilot,fill pipe and test MWD and Geo-Pilot,at 362 GPM,1450 PSI.;Continue to trip in hole from 4080'to 7935',with BHA#4.;Service rig,draw works&traveling equipment.C/O hydraulic fittings on auxiliary HPU pump.;Adjust top drive torque tube alignment with rotary table so slips will set properly when top drive is made up to drill pipe.;RIH from 7935'to 8234'.Tight hole¬ able to work thru.P/U to 8210'&M/U top drive.No issues running in thru window.;Top drive lube oil light flashing. Trouble shoot.W&R while trouble shooting from 8210'to 8240'(Saw slight bobble @ 8230').Cont.to trouble shoot top drive.;POOH from 8240'to inside window @ 7992'.No issues pulling thru window.;Cont.to trouble shoot top drive lube pump.Lube pump not getting power from VFD house.;Wellhead pressures:20"=4 psi,13 3/8"=32 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal rprnvprpd•9 the Total•4R1 the 10/2/2017 Trouble shoot TD lube pump.Have power at VFD but no power to lube pump.Run jumper from lube pump to VFD and everything worked.Unhook jumper and run new cable from lube pump on TD following the;service loop back to the VFD.Tie into lube pump then tie the other end into the VFD.Test run TD and all the issues were solved.While working on TD the crane rigger noticed the cutting dump hose;from the auger to the slope tank had parted.No spill.;Pull hose down and remove vitrolic connection to hose adaptor.Turn cuttings dump hose around so the new section of hose was on top.Put newer section of hose on and secure it.;RIH to 8310'and tag up.wash and ream to bottom at 8410'.400 GPM,2200 Psi,60 to 100 RPM,5 to 10k TQ.;Directional drill 8 1/2"hole f/8410 t/8650'.415 GPM,2355 Psi,140 RPM,6 to 7k TQ,10 to 15k Bit wt,Mud wt 9 ppg,ECD 9.64 ppg.;Directional drill 8 1/2"hole f/8650't18942',415 GPM,2300 Psi,140 RPM, 6 to 7 k TQ,12k WOB,PU wt 122k,SO wt 100k,ROT wt 108k,ECD 9.6ppg.;Directional drill 8 1/2"hole f/8942'V9210',415 GPM,2300 Psi,140 RPM,6 to 7 k TQ,12k WOB,PU wt 124k,SO wt 102k,ROT wt 109k,ECD 9.6ppg.;Distance to Plan:14.52'(12.19'High/7,89'Left).;Wellhead pressures:20"=4 psi,13 3/8" =31 psi Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal rarnvprp,4 R the Total'4Rq the 10/3/2017 Directional drill 8 1/2"hole f/9210'V 9421'.417 GPM,2300 Psi,140 RPM,8 to 9k TQ,12 to 15k Bit wt,MW 9 ppg,ECD 9.6 ppg.;Pump sweep and circ hole clean.Sweep came back 5 bbls late w/a 10%increase in cuttings.;Short trip back up into the window.POH on elevators w/up to 40k over pulls to 9230'.Had to backream f19230'to 8224'.Then pulled on elevators to 7989'.;Clean and clear rig floor.;Hold PJSM and cut and slip drilling line 92'.Serviced rig and topdrive. Well on trip tank,no gain,no losses.;MU TIW on stump,lowered topdrive to rig floor.Rig electrician checked continuity of pig tail and electrical junction box on topdrive.Pig tail and junction box are good,appears to be a bad wire in;service loop.Buttoned up topdrive panel.Removed TIW from stump.Also screened down shaker screens for TIH,serviced centrifuge,found worn drive belts and feed tube.Checked saver sub(OK).;TIH from 7989',easing down through window with no problems.Cont to trip in open hole to 9295'.MU topdrive and washed/reamed from 9295'to 9405'and encountered fill.Cont to work down to 9412'.;Cont to work fill from 9412'to bottom at 9421'.Hole trying to packoff.Used various pump rates and rpm's and managed to work to bottom.389 gpm-2200 to 2400 psi,72 rpm- 6500 to 7200 ft/lbs torque.;Resumed directionally drilling from 9421'to 9635',wob-14K,413 gpm-2400 psi,140 rpm-9000 ft/lbs on bolt torque,6 to 100 ft/hr ROP,MW 9.0/vis 91,ECD's at 9.5 ppg,BGG 8 units.;Distance to Plan:11.99'(11.72'High/2.55'Left) Wellhead pressures:20"=6 psi,13 3/8"=30 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:0 lbs.Total:369 lbs. • 10/4/2017 Cont directional drilling 81/2"hole f/9635't/9656',;Air boots on flow nipple started leaking.Ended up replacing both bottom boots and 1 of the top boots.Work pipe while changing boots.;Directional drill 8 1/2"hole ft 9656't/9795'.410 GPM,2320 psi off bottom,2340 on bottom, 140 RPM,8 to ilk TQ,Bit wt 12 to 16k,;Directional drill 81/2"hole f/9795't/10,019'.Pumped a high vis weighted sweep at 9980'and drilled next std dn while sweep went around.Sweep came back 37 bbls late w/100%increase in cuttings.;Directional drill 81/2"hole f/10,019'U 10,207'.14 to 15K wob,426 gpm-2425 psi,120 to 160 rpm-8800 to 12,000 ft/lbs on bott torque,10 to 80 ft/hr ROP,MW 9.1/vis 80,ECD's at 9.5 ppg,BGG 14.;Seeing considerable stick/slip when drilling in conglomerate with 1% lube in mud system.Cont alternating rpm's and wob to reduce stick/slip.;Directional drill 8 1/2"hole f/10,207'to 10,310',14 to 15K wob,416 gpm-2326 psi,139 rpm-8700 to 9700 ft/lbs on bott torque,30 to 54 ft/hr ROP.Stick/slip not bad at 14K wob,140 rpm's.;Seeing a cont drop in pump psi(2300 to 1900 psi),starting at 10,275'.;PU off bottom and check surface equipment.Surface equipment is good.SPP down to 1850 psi on bottom at time of shut down,at 420 gpm.Most likely a washout in drill string.;POOH on elevators from 10,310'to 9,290',up wt 180K,dwn wt 128K.Seeing some 20K overpulls and pipe pulling dry.Filled pipe at 9974'(30 spm)and cont pull up hole slowly.;;Distance to Plan:15.87'(10.21'High/12.15'Right) Wellhead pressures:20"=6 psi,13 3/8"=30 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:4 lbs.Total:373 lbs. 10/5/2017 Cont pulling up hole slowly,with pump at idle,looking for washout in drill string,from 9290'to 8761'.Washout was just above slip area on std#131.;Change out bad jt.Pump to make sure pressure was good and it was.;RIH with no obstructions to 10,225'where we sat down.;Fill pipe and wash and ream f/10,225 U bottom at 10,310'.Looks like we had 85'of fill due to not circ before POH.;Directional drill 8 1/2 hole f/10,310 U10,345.Drilling through a lot of conglomerate and we had to keep changing the parameters to keep the slip-stick dn.;Directional drill 8 1/2"hole f/10,345 U 10,477'.Pumped high vis high wt sweep at 10,355'.Came back 24 bbls late wt a 50%increase in cuttings.GPM 425,psi 2576,140 RPM,7 to Ilk TQ,BW 10 t/16k;Directional drill 8 1/2"hole f/10,477'U 10,570'.13 to 20K wob,428 gpm-2535 psi,90 to 140 rpm-6900 to 13,000 ft/lbs on bott torque,10 to 120 ft/hr ROP,MW 9.1/vis 93,ECD's at 9.5 ppg,BGG 43.;Received 510 sx cement and staged in SLB silo.Saw 256 units gas after drilling through coal at 10,500'.Appears we entered the C5 formation top at 10,568'md/9716'tvd.;Cont drilling 8 1/2"hole from 10,570'to 10,684',15 to 17K wob,423 gpm-2501 psi,160 rpm-9100 ft/lbs on bott torque,10 to 25 ft/hr ROP,MW 9.1/vis 80,ECD's at 9.5 ppg,BGG 33.;;Distance to Plan:8.27'(4.36'High/7.02'Right) Wellhead pressures:20"=0 psi,13 3/8"=135 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:3 lbs.Total:376 lbs. 10/6/2017 Cont drilling 8 1/2"hole f/10,684'U10,828'.425 GPM,2535 psi,160 RPM,10k TQ,16 to 20k WOB,MW 9.1 ppg,ECD 9.5 ppg,Avg ROP 30 FPH,BGS 120 units.;Directional drill 8 1/2"hole f/10,828 U 10,875'.422 GPM,2485 Psi,160 RPM,10k TQ,18 to 25k WOB,Pump high vis&wt sweep on connection at 10,848'.Sweep came back 30 bbls late w/a 30%increase;ROP has been falling off steady.Decided to POH for bit change.Circ 3 more bottoms up to clean hole.;Monitor well for flow,Well static.POH on elevators,from 10,845 to 7989' with no issues.BHA pulled smooth through window at 8006'.;MU topdrive at 7989' and pumped 20 bbl dry job.Serviced rig and topdrive.Racked and tallied 141 jnts 7"liner during trip.;Cont POOH from 7989'to 6430'.;Cont POOH from 6430'to ALD collar.Held PJSM and removed sources,plugged in and downloaded MWD data,cont lay down BHA#4.;Distance to Plan:8.33'(5.36'High/6.38'Right) Wellhead pressures:20"=7 psi,13 3/8"=195 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:4.6 lbs.Total:380.6 lbs. 10/7/2017 Cont to POOH LD BHA#4.Bit graded at 3,4,CT,A,F,I,NR,PR.LD the rest of the BHA.;Parted lube pump cable that was running along service loop while POH. Remove bad section of wire and tie back into TD.Use plastic spiral wrap to secure wire to TD hose.Test TD and everything works.;PU BHA#5.MU Security bit on Geo-Pilot Rotary Steerable,PU the rest of the BHA to the float sub.MU XO and screw in TD.PU and upload tools.Do shallow pulse test at 400 GPM and load source's.;RIH w/NM DCs,HWDP,and jars.Continue RIH to 4079',and fill pipe.Continue RIH to just above window at 7992'Fill pipe and break in tool.;Serviced rig and TD,opened up grabber assembly and visually inspected saver sub threads(OK).;Cont TIH from 7992',exiting window at 8023'with no issue.Set dwn 20K at 8182',30K at 8284',8318'(slide areas)10,429'and 10,511'(coals).Washed and reamed from 10,511'to 10,782'.;We were able to run second to last stand on elevators with no indication of fill,from 10,782'to 10,845',then washed/reamed last stand down to bottom at 10,875'.;Resumed drilling 8 1/2"hole from 10,875'to 10,880'.2-8K wob,398 gpm-2400 psi,140 rpm-8000 to 10,000 ft/lbs on bott torque,MW 9.2/vis 125,ECD's at 9.6 ppg,BGG 32 units.;Cont drilling 8 1/2"hole from 10,880'to 11,113',10-12K wob,421 gpm-2628 psi,140-150 rpm-10,000 to 15,000 ft/lbs on bott torque,20 to 100 ft/hr ROP,MW 9.1+/vis 109, ECD's at 9.6 ppg,BGG 43.;Seeing a good amount of stick/slip since we started drilling ahead.Increasing lube to 2%.At 11,030'it appears we drilled out the bottom of C-5.Seeing very little sand,just hard claystone and;siltstone in shaker samples.Notified Drilling Engineer and Geologist.Decision made to cont drilling ahead building inclination,to see if we can get back up into C-5 formation.;;Distance to Plan:1.85'(0.9'Low/1.62'Right) Wellhead pressures:20"=6 psi,13 3/8"=52 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:0 lbs.Total:380.6 lbs. 10/8/2017 Cont drilling 8 1/2"hole f/11,113'tJ 11,280',10K wob,421 gpm-2627 psi,160 rpm-10,000 to 13,000 ft/lbs on bott torque.Went out of the bottom of the pay. Building up to 77 Degrees to get back in;Pump high vis and high wt sweep at 10:45 so it would be coming out of the bit at 11:00.;Circ hole clean.Sweep came back 33 bbls late w/a 25%increase in cuttings.Circ 2 3/4 bottoms up and shakers cleaned up good.Monitor well and it was Static.;POH to window on elevators. Had numerous spots we pulled 20 to 45k over but pull through.Had one spot at 8183'we pulled 45k over and had to break it back down,and then it was gone when we pulled;back up.Didn't see any drag or overpulls coming through the window.;Blow dn mud line so Sperry can change choke size in there manifold while draining BOP stack.MU 4 1/2"test jnt assembly with test plug on drill string.Land test plug.(string hung off);Flood surface equipment/lines with water and purge air.AOGCC Rep Adam Earl on board at 17:00 hrs to witness testing.Rig electrician tested gas detection equipment.;Shell tested stack at 2500 psi(OK),tested annular at 250/2500.Performed low test on upper rams,then pressured up to 3500 for high test.Pressure not holding.Found leak;at dual string hanger "alignment pin"on wellhead,just below upper lockdowns.Contacted Hilcorp wellhead Rep who advised backing pin out to shoulder and try re-test.Pin still leaking.Pin can only;be removed from wellhead from inside.Notified AOGCC Rep and Drilling Engineer.AOGCC Rep gave the ok to test choke manifold and topdrive and flew back to town(will return to witness;testing BOP stack when alignment pin is repaired).Pin holds 2500 psi,but leaks at 2700 psi.Notified Halliburton for storm packer and Rep.;Drained water from stack/riser,pulled test plug to floor,LD test jnt assembly and plug.Pulled one stand and racked back in derrick.Fill hole and monitor on trip tank.;RU and test CMV's#7,15,16 and lower IBOP at 250/3500 psi for 5 minutes each.;Cont testing remaining CMV's and topdrive at 250/3500 psi for 5 minutes each.;Cont monitoring well on trip tank.Servicing and inspecting mud pump#1,oil change#1 gen set,clean cellar area, clean pit areas while waiting on storm packer and Rep.;;Distance to Plan:8.03'(7.98 High/0.92 Left) Wellhead pressures:20"=9 psi,13 3/8"=92 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:3.4 lbs.Total:384 lbs. • • 10/9/2017 Cont housekeeping and equipment maintenance throughout the rig while waiting on Halliburton storm packer.Finish going through#1 mud pump,Cut drilling line,Replace rubber splash guard on back of;shakers,prep loads for the boat,and clean up around the rig.;Storm packer arrived at the platform at 12:30. Checked the tool over and got required measurements.Made the tool up on a jt of DP.,MU tool on string and RIH 1 std.Dn wt 112,Up wt 136.Turn 1/2 rd;& slack off setting storm pkr.Release f/same by turning 22 left hand turns.Pull setting tool out, Wrap tool up&lay it dn.Top of tool at 61.59,Center of element 65.4.Test above pkr to 1000 psi.;Drain stack&Start to nipple dn.Had issues getting the pins out of the rotary table.finally got them out after about 1 1/2 hrs. Pulled rotary,Cleaned and pulled drip pan,flowline,fill up line;and flow box.Remove turn buckles,and choke line.Shackle PU slings to the Shaffer annular. Remove graylock clamps and raise stack up about 2'.;Assist wellhead hand with the removal of the alignment pin.End of pin was smashed due to not being backed out before dual hanger removal at some point.Dress up threads and install a used pin.;Stab riser back on wellhead and install graylock clamps.Installed choke line to mudcross,installed flowbox,flow riser,drip pan and rotary table.;PU and MU test joint assembly w/test plug.Land plug in wellhead and flood riser/BOP stack with water.No leaks.Function rams to remove any air from cavities.Close upper rams and shell test at 250;low f/5 min,attempt to test at 3500 but had a manual kill line valve stem leak.Bled off and inserted stem packing.Performed shell test at 3500 f/5 min(OK).Called out AOGCC Rep at 21:30.;Tested BOP stack,IBOP and TIW valves,manual kills and choke valves,CMV's 1-8-12-and 14 at 250/3500 psi.Performed koomey draw down test.All tests good. Called for chopper for AOGCC Rep.;Unseat test plug and drain stack/riser.Notified Production of drained riser so they could replace wing valve on 9 5/8" annulus.Cont pull LD test joint assembly and test plug.AOGCC Rep Adam Earl;left platform at 00:00,and we also sent rig electrician in.Electrician feeling ill,has high blood pressure(BP checked by Production Rep)and is going to local hospital to get checked out.;RU and remove rotary table and drip pan.Clean,re-seal and re-install drip pan.Clean,seal and install rotary table,pin table to rotary beams.;PU stinger assembly and RIH,engage storm packer at 61.59'.Turn by hand 9 rounds to the right and MU topdrive.Fill hole.Turn 11 rounds to the right and see no pressure on DP.Closed annular;Iined up on auto choke and pulled up hole 6',136K up wt.Allow 10 minutes for packer element to relax.No flow at shakers.Open annular and pulled storm packer to surface.LD same.;TIH from 7929', exiting window at 8023',to 9600'.;Distance to Plan:8.03'(7.98 High/0.92 Left) Wellhead pressures:20"=8 psi,13 3/8"=28 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total Sept:12.5 hrs Metal recovered:0 lbs.Total:384 lbs. 10/10/2017 Cont TIH on elevators from 9600'to 10,662'.Set down 40K at 10,590'and 10,640'.Worked pipe a dozen times on each and able to get through.Up wt 165K,dwn wt 116K.;MU topdrive at 10,662'and fill pipe.Cont washing down to 10,701',PU and start troughing from 10,680'to 10,700'.;Time drill f/10,700'to 10,703.375 GPM/2160 psi. 150 RPM/8K torque.;Time drill f/10,703'to 10,714.2-3K wob,375 GPM/2160 psi. 150 RPM/8K torque.2-3 ft/hr ROP,MW 9.0/vis 90,ECD's at 9.4 ppg,BGG 21 units.ABI 61.59 degrees.;PU off bottom,shut down pumps and replaced two bad air boots on flow riser.These were installed new yesterday during NU,prior to BOP test.;Time drill f/10,714'to 10,719,2-3K wob,375 GPM/2160 psi. 150 RPM/8K torque.2-3 ft/hr ROP,MW 9.0/vis 90,ECD's at 9.4 ppg, BGG 21 units.;Cont time drilling 8 1/2"hole from 10,719'to 10,784',2K wob,420 gpm-2453 psi,160 rpm-9300 ft/lbs on bolt torque,4 ft/hr ROP,MW 9.1/vis 92, ECD's at 9.4 ppg,BGG 38 units.;ABI at 10,722'shows 61.06 degrees giving us 2.15 degrees separation from GP 11-24RD PB1.At 10,745'seeing 5-8 degrees /100 drop rate.Increased wob to 10K,ROP at 14 ft/hr.;At 10,751'tool is at 30R to build to 61 degrees inc.;;Distance to Plan:(High/Left) Wellhead pressures:20"=8 psi,13 3/8"=120 psi;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total October:0 hrs Metal recovered:2 lbs.Total:386 lbs. 10/11/2017 Cont time drilling 8 1/2"hole from 10.784'to 11,006',11K wob,422 gpm-2488 psi,125 rpm-8 to 14K ft/lbs on bolt torque,37 ft/hr ROP,MW 9.1/vis 88,ECD's at 9.5,BGG 92.;Achieved desired inclination of 61 degrees at 10,810'md.Drilling ahead in tangent section we initially had a slight drop tendency then changed to slight build and 1.5 deg/100 right hand walk.;Continue drilling 8 1/2"hole from 11,006'to 11,070',11K wob,422 gpm-2488 psi,125 rpm-8 to 14K ft/lbs on bolt torque,10.7 ft/hr ROP,MW 9.1/vis 88,ECD's at 9.5,BGG 78.;Having some trouble getting assembly to build inclination and ROP has dropped off considerably. Still seeing high full stall stick/slip even with 2%lube in mud system.;Continue drilling 81/2"hole from 11,070'to 11,122',12K wob,380 gpm-1993 psi,150 rpm- 8500 to 14,300 ft/lbs on bolt torque,8-10 ft/hr ROP,MW 9.1/vis 83,ECD's 9.3 ppg,BGG 46.;Reduced pump rate in attempt to get more build.By 11,115'we are seeing 3.6 to 5.1/100 build rates.Backed off on deflection to 60%.Still having some issue holding tool face due to stick/slip.;Continue drilling 81/2"hole from 11,122'to 11,162',8-17K wob,403 gpm-2251 psi,140 to 160 rpm-8700 to 16,000 ft/lbs on bolt torque,8-20 ft/hr ROP,MW 9.0+/vis 96,ECD 9.3,BGG 45.;At 11,158'we started a 20 bbl hi-vis sweep around while drilling ahead.14K wob,387 gpm-2080 psi,170 rpm-9900 to 12,000 ft/lbs torque,7 ft/hr ROP.;Distance to Plan:1.47'(1.35'High/0.57'Right)of directional plan#13. Wellhead pressures:20"=10 psi,13 3/8"=190 psi.;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total October:0 hrs Metal recovered:1 lbs.Total:387 lbs. 10/12/2017 Cont drilling 8 1/2"hole from 11.162'to 11 215' 14K wob,425 gpm-2450 psi,173 rpm-9000 to 16,000 ft/lbs on bolt torque,7 to 35 ft/hr ROP,MW 9.O/vis 96, ECD's at 9.4 ppg,BGG 38.;Sweep came back 34 bbls late with 30%increase in cuttings.Pumped second sweep at 11,200'.Came back 34 bbls late with 40% increase in cuttings.;Circulate hole clean at 420 GPM/2400 psi while rotating and reciprocating at 160 RPM.;POOH on elevators from 11,215'into window at 8000'.Had over pulls at 10,682',10,650',10266',8261'and 8183'.;Continue POOH from 8000'to 6900'.;Service rig and topdrive.;Cont POOH inside casing, from 6900'to BHA at 674'.;LD 5 jnts HWDP and 1 jnt NMDC to change up next BHA.Rack back jars and 1 stnd NMDC.PJSM and removed sources.Plugged in and downloaded MWD.LD remaining BHA,bit grade 2-5.;Clean and clear rig floor.Changed out both upper air boots on flow riser(had slight weeping).Serviced rig and topdrive.;PU Geo-Pilot and MU new HDBS EME74DC PDC jetted w/7 x 12's.MU DM,ILS,DGR,PWD,ADR,ALD,CTN and TM collars.MU NM float sub,plug in to upload MWD.;Up load MWD,perform shallow pulse test,PJSM and loaded RA sources.;Distance to Plan:1.47'(1.35'High/0.57'Right)of directional plan#13. Wellhead pressures:20"=10 psi,13 3/8"=246 psi.;Fluid loss to well today:0 bbls.Total:0 bbls. Code 8: 0 hrs,Total:0 hrs Total October:0 hrs Moral rarnvarad•0Ihs Tntal•'R7 Ihs 10/13/2017 Cont MU,TIH with directional BHA#6,from 116'to 431'(total BHA length).Cont TIH on 4 1/2"DP to+/-1200'and MU agitator.;RIH with BHA#6 to 6782'filling pipe every 2500'.;RIH from 6782'to 7965'.Fill pipe.;RIH on elevators to 11,062'.Tight spots at 10,396'and 10,663'but able to work through without issue.;Wash and ream from 11,062'to 11,186'.P/U 162,S/O 122,Rot 142/8.5 K torque at 80 RPM.375 GPM/2300 psi,driller got low oil pressure alarm for topdrive lube pump.;Circulate and condition mud while troubleshooting top drive lube oil pump issue.Had to switch to only spare wire in our jumper wire to lube pump. Screened up both shakers while circ.;Washed/reamed down to bottom 11,215'topdrive working as it should.;Cont directional drilling 8 1/2"hole from 11,215'to 11,369'.10 to 13K wob,425 gpm-2777 psi,150 rpm-11,400 ft/lbs on bolt torque,28 to 92 ft/hr ROP,MW 9.1/vis 99,ECD's at 9.5 ppg,BGG 29 to 87.;Cont directional drilling 81/2"hole from 11,369'to 11,559',12-13K wob,425 gpm-2767 psi,150 rpm-8000 to 15,000 ft/lbs on bolt torque,50 to 80 ft/hr ROP,MW 9.1/vis 90,ECD's at 9.5 ppg,;BGG 74 to 211 units.Started seeing good amount of stick/slip at 11,386'.Built to 67 deg inc as per GeoSteer Geologist,as we were +/-24'above C5-A base and closing in.;Formation dip appears to be 24 degrees.Both rig gensets stalled at 11,460'and rig blacked out due to over frequency.Re. started both and had no further issues.;At 11,559'(kelly down)HPU#2 drive coupler failed.(engine to pump coupler).;Obtained survey and SPR's while replacing drive coupler on HPU#2.Back up and running at 06:00.;Distance to Plan:9.22'(4.84'High/7.85'Right)of directional plan#13. Wellhead pressures:20"=9 psi,13 3/8"=180 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 1 hrs,Total:1 hrs Total October:1 hrs Metal recovered:2 lbs.Total:389 lbs. • • 10/14/2017 Cont directional drilling 8 1/2"hole from 11,559'to 11,626,15K wob,425 gpm-2780 psi,150 rpm-9600 to 11,800 ft/lbs on bott torque.Pumped sweep at 11,575'. Came back 40 bbls late/25%increase.;Cont directional drilling 8 1/2"hole from 11,626'to 11,651',15-27K WOB,425 gpm-2766 psi,150 rpm-9600 to 11,800 ft/lbs on bott torque.ROP reduced to 2-3 ft/hr and low torque.;Notified Drilling Engineer and Manager of low ROP,decision made to POOH for bit change. Pumped 20 bbl hi-vis/hi wt sweep around.Came back 34 bbls late,100%increase in cuttings.Cont to circ until;shakers cleaned up.Flow check was static.;POOH on elevators from 11,651'.Had over pulls at 10,753',10,655'and 10,641'but did not have to work pipe or circ.Pumped dry job after 1st 10 stands as hole fill is good.Pulled into casing OK.;Parked bit at 7963'and serviced rig and topdrive.;Cont to POOH from 7963'to BHA at 431'.LD agitator at 1500',cont to pull to smart iron,PJSM and removed sources.Plugged in and downloading MWD.;Distance to Plan at 11,651':54.30'(28.81'High/46.02'Right)of original directional plan#13 Wellhead pressures:20"=10 psi,13 3/8"=200 psi;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 1 hrs,Total:1 hrs Total October:1 hrs Mptal rarnvPrarl•7 Ihs Tntal•391 Ihs 10/15/2017 Cont download MWD and handle remaining BHA#6.HDBS EME74DC bit graded at 7-3 in gauge but rung out.;Make up BHA#7 with Hughes Kymera bit. Download MWD.Load sources.Shallow hole test.Cont TIH and MU agitator 1548'up from bit.Sperry tools set up for max 470 gpm.;RIH with BHA#7 to 7962'. Fill pipe every+-2500'.Lube pump failure on topdrive at 7962'.;Cut and slip 162'of drill line.Service rig.;Replaced lube pump jumper cable with new cable,tape and re-wrap armor on service loop.Lube pump functions as it should.;Cont trip in open hole,exiting BOW at 8,023'with no problem.Up wt 140K,dwn wt 120K.At 10,542'we set down couple times 20K.Worked pipe and got through.At 10,575'we set down again,;20 to 30K,could not work through on elevators.MU topdrive, filled pipe and washed down with no rotation to 10,602'.Washed and reamed at 225 gpm-1040 psi,30 rpm from 10,602'to 10,690'.;From 10,690'we were able to TIH on elevators to 11,557'with no problem(open hole sidetrack at 10,700').MU topdrive on second to last stand,filled pipe and washed down to 11,620'at 30 rpm.;MU last stand and worked 30'while staging pump rate up to control shakers and shear mud,easing to bottom at 11,651'to break in bit.;Resumed directional drilling 8 1/2"hole from 11,651'to 11,666',12-15K wob,385 to 457 gpm-2434 to 3034 psi,120 rpm-9200 to 10,000 ft/lbs on bott torque,2-50 ft/hr ROP,MW 9.2Nis 94,;ECD's at 9.4,BGG 28 units.Very low ROP at report time.Geo Tech feels we are 19'above base of C-5.Cuttings samples are basically hard cemented sandstone.;Distance to Plan:54.30'(28.81'High/46.02'Right)of original directional plan#13. Wellhead pressures:20"=10 psi,13 3/8"=74 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 1 hrs,Total:1 hrs Total October:1 hrs Metal recovered:0 lbs.Total:391 lbs. 10/16/2017 Directional drill 8 1/2"hole from 11,666'to 11,688'.P/U 169K,S/O 124K,ROT 141K, 430 GPM/2840 psi,9.5 torque. 8-20 WOB.;Cont drilling from 11,688'to 11,852'.20K wob,401 gpm-2600 psi,138 rpm-10,400 ft/lbs on bolt torque,1-to 20 ft/hr ROP,MW 9.1/vis 77,ECD's at 9.4+,BGG 48.;BHL about 21'above the C5-A base,formation dip estimated at 20 degrees.Building Inc to 75 degrees.;Cont drilling from 11,852'to 11,936'.18 to 20K wob,404 gpm-2624 psi,142 rpm- 10,200 ft/lbs on bott torque,8 to 30 ft/hr ROP,MW 9.1/vis79,ECD's at 9.4+,BGG 49.;Current BHL about 33'above the C5-A base,formation dip estimated to be at 23.5 degrees.Holding Inc at 75 degrees.Pumped 20 bbl sweep at 11,872'.35 bbls late and 20%increase in cuttings.;Distance to Plan:101.36'(55.40'High/ 84.89'Right)of original directional plan#13. Wellhead pressures:20"=10 psi,13 3/8"=75 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 1 hrs,Total:1 hrs Total October:1 hrs Metal recovered•7 lbs Total.39R Ihs 10/17/2017 Cont directional drilling 81/2"hole from 11,936'to 11,988'. 18 to 20K WOB,404 gpm-2624 psi,142 rpm-10,200 ft/lbs on bott torque,8 to 30 ft/hr ROP,MW 9.1/vis79,ECD's at 9.4+,BGG 49.;Directional drill from 11,988'to 12063'.18 to 20K WOB,404 GPM,2624 PSI,142 RPM,10,200 On BTM TQ,8-30 FPH ROP, MW 9.1/vis79,ECD's at 9.4+,BGG 49.;Pumped sweep at 12,000'.Came back 35 bbls late with 100%increase in cuttings.;Directional drill from 12063'to 12124'. 18 to 22K WOB,415 GPM,2770 PSI,142 RPM,10,500 On BTM TQ,8-20 FPH ROP,MW 9.1/vis79,ECD's at 9.4+,BGG 41.;Continue directional drilling 81/2" hole from 12,124'to12,175'. 18 to 21K WOB,440 gpm-3000 psi,142 rpm-10,700 ft/lbs on bott torque,6 to 20 ft/hr ROP,MW 9.1/vis79,ECD's at 9.45,BGG 54.;Service rig;TD,draw works,HPU's. Obtain SPR's.;Continue directional drilling 8 1/2"hole from 12,175'to 12,178'. 18 to 21K WOB,440 gpm-3000 psi,142 rpm-10,700 ft/lbs on bott torque,6 ft/hr ROP,MW 9.1/vis79,ECD's at 9.45,BGG 54.;Distance to Plan:149.54'(86.16'High/122.23'Right)of original directional plan#13. Wellhead pressures:20"=11 psi,13 3/8"=218 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Metal rernvered•5 Ihs Tntal.41Yi Ihs 10/18/2017 Continue directional drilling 8 1/2"hole from 12,178'to 12,230'. 18 to 21K WOB,440 gpm-3000 psi,142 rpm-10,700 ft/lbs on bott torque,6 ft/hr ROP,MW 9.1/vis79,ECD's at 9.45,BGG 54.;Pumped sweep at 12,185'.Came back 35 bbls late with 10%increase in cuttings.;Continue directional drilling 8 1/2"hole from 12,230'to 12,255'. 18 to 21K WOB,440 gpm-3000 psi,142 rpm-10,700 ft/lbs on bott torque,6 ft/hr ROP,MW 9.1/vis79,ECD's at 9.45,BGG 54.;Stand back one stand.Circulate sweep while rotating at 180 RPM/K torque.450 GPM/3100 psi. Sweep came back 50 bbls late with 25%increase in cuttings.;Continue directional drilling 8 1/2"hole from 12,255'to 12,257'. 18 to 21K WOB,440 gpm-3000 psi,150 rpm-10,700 ft/lbs on bott torque,decision made to trip due to insufficient penetration rate.;Stand back one stand.Circulate sweep while rotating at 180 RPM/K torque.450 GPM/3100 psi. Sweep came back 45 bbls late with 25%increase in cuttings.;Monitor well for flow,pull out of hole on elevators from 12257 to 11555,170K UW with no issues,pump dry job,and continue to trip out of hole on elevators to 8,894';work through tight spots at;10879',10707',and 10897'30-35K over.;Continue to POOH with drilling assembly from 8894'to 430' with no issues. Stand back HWDP. UD Jars to 243'.;Distance to Plan:176.92'(103.77'High/143.29'Right)of original directional plan#13. Wellhead pressures:20"=10 psi,13 3/8"=235 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Metal recovered:4 lbs.Total:407 lbs. 10/19/2017 Work BHA#7,unload sources from LWD tools and down load data from MWD tools,continue to lay down BHA,bit graded 1-3 and was 1/16 under gauge.;Make up BHA#8,with new Varel 7 blade bit,upload MWD,shallow test MWD,load sources,continue to trip in hole picking up NMDC and cars to 430'.;Trip in hole with BHA#8 to 1573',pick up agitator,and continue to trip in hole to 3868'fill pipe and break in seals on Geo-Pilot 335 GPM 1530 PSI.;Continue to trip in hole from 3868'to 7964"top of window at 8006',fill pipe.;Per form rig service,inspect and service top drive,draw works and travelling equipment.;Continue to trip in hole from 7964,to 9453'exit window with no issues,had to work through tight spots at 8198'(20K)and 9016'(30K dn,40K up)UW 145K,DW 114K.;Continue to trip in hole from 9453'. Attempt to work through tight spot at 10564'(40K)unable to. Establish circulation and stage pumps up to 324gpm/1922psi with pack-off issues.;Establish rotary 30 rpms/9K-11 Kft-lbs and W/R from 10,564'to 10629'. Attempt to work tight spot at 10,653'(35K dn,30kup)unable to. Establish circulation.;324gpm/1900 psi and attempt to wash,unable to. Establish rotary 30 rpms and attempt to W/R,erratic torque up to 14Kft-lbs. Increase rotary to 45 rpms/8K-13Kft-lbs and ream to 10690'.;Continue to trip in hole on elevators from 10,690'to 11,218'set down 40K with 40K overpull. Establish circulation 350gpm/2100 psi and attempt to wash down,unable to. Establish rotary 40 rpms;8-14k-ftlbs. Wash and ream to 11,408'increasing rotary to 100 rpms to minimize drag and stick slip. Attempt to RIH on elevators several times,unable to. • • 10/20/2017 Wash and ream 11,408'to 11,680'.RIH on elevators 11580'to 12,181'.P/U 157,S/O 117,ROT 135 at 140 RPM/9.5 torque.425 GPM/3025 psi.;Wash and ream 12,181'to 12,257'.Break in PDC bit.;Directional drill from 12,257'to 12,312'. 8 to 12K WOB,425 GPM,3025 PSI,140 RPM,10,200 On BTM TQ,8-30 FPH ROP,MW 9.2/vis79,ECD's at 9.4+,BGG 20.;Directional drill from 12,312'to 12,376'. 6 to 10K WOB,425 GPM,2850 PSI,120-170 RPM,10-16K On BTM TQ,8-30 FPH ROP,MW 9.1/vis79,ECD's at 9.6+,BGG 65.Working slip stick issues.;Pumped sweep at 12,365'.Sweep came back 40 bbls late with 50% increase in cuttings.;Directional drill from 12,376'to 12,437'. 5 to 9K WOB,425 GPM,2850 PSI,170 RPM,10-16K On BTM TQ,20-30 FPH ROP,MW 9.2/vis85,ECD's at 9.6+,BGG 61.Working slip stick issues.;Directional drill from 12,437'to 12,534'. 5 to 9K WOB,425 GPM,2890 PSI,120-170 RPM,9-16K On BTM TQ,7-30 FPH ROP,MW 9.2/vis86,ECD's at 9.6+,BGG 61.Working slip stick issues.;Directional drill from 12,534'to 12,585'. 5 to 12K WOB,450 GPM,3150 PSI,120-170 RPM,9-16K On BTM TQ,6-15FPH ROP,MW 9.25/vis86,ECD's at 9.6+,BGG 43.Working slip stick issues.;Adjust parameters to attempt and increase ROP. Pump high vis 10.3ppg sweep at 12556;30%increase in cuttings 40 bbls late.;Distance to Plan:233.69'(133.03'High/192.12' Right)of original directional plan#13. Wellhead pressures:20"=10 psi,13 3/8"=167 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Mortal rarnvarprl•5 the Tntal`219 the 10/21/2017 Directional drill from 12,585'to 12,613'. 5 to 12K WOB,450 GPM,3150 PSI,120-170 RPM,9-16K On BTM TQ,6-15FPH ROP,MW 9.25/vis 86,ECD's at 9.6+,BGG 43.;Pump 3 each 20 bbl hi-vis,weighted sweeps while rotating and reciprocating pipe at 180 RPM/10 K torque.440 GPM/3160 psi. Sweep#1 back 40 BBL late and 50%increase in cuttings,sweep#2 back;40 BBL late and 20%increase in cuttings,sweep#3 back 40 BBL late and 0%increase in cuttings.;Trip out of hole on elevators from 12613'to 11615',with no issue UW 178K,DW 133K.;At 11615 pulled 40K over,Make up top drive and circulate 3 bottoms up at 430 GPM,2930 PSI SPP,and 180 RPM,to clean hole.;Trip out of hole on elevators from 11615'to 7890',worked through several tight spots that correlated with coals.;Clean and clear rig floor and cellar while building dry job.;Perform rig service,service top drive,draw works,and travelling equipment.;Continue to clean rig floor,cellar. While monitoring well on trip tank-static.;Pump dry job. POOH with BHA#8 from 7890'to 373'.;Distance to Plan: 244.19'(132.07'High/205.40'Right)of original directional plan#13. Wellhead pressures:20"=12 psi,13 3/8"=284 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Mata/rarnvwad•'i Ihs Tntal•415 lbs 10/22/2017 Work BHA#8.Lay down 3 joints HWDP and jars,remove source,down load MWD,lay down MWD,break bit and lay down Geo-Pilot. Bit graded 1-3,and was in gauge.Note:Found 2 5/16"drift on top of jars.;Clean and clear rig floor.;Rig service,maintain and service top drive,and draw works,service all handling equipment.;Drain stack,remove TDS service loop guard rail from derrick for modifications,set test plug with 2 stands of HWDP hanging below,make up 4.5"test joint,along with floor valves,flood stack.;Test annular on 4 1/2"pipe to 250-2500 PSI,5 minutes each all good,test remainder of BOPE to 250-3500 PSI,5 minutes each all good.Perform accumulator draw down test 24 seconds for 200 PSI;recovery and 121 seconds for full recovery of 3000 PSI.;Rig down test equipment,pull test plug,break out and lay down test joint,clean and clear rig floor.;PJSM,install modified service loop guard rail on off drillers side of Q derrick.;PJSM,pick up BHA#9,(8.5"clean out)to 324'.;Cut and slip 124'of drilling line.;RIH with BHA#9 cleanout assembly to 5540',filling pipe every ,( 2500'.;Distance to Plan:244.19'(132.07 High/205.40'Right)of original directional plan#13. .0�\ Wellhead pressures:20"=11 psi,13 3/8"=88 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Metal recovered:0 lbs.Total:415 lbs. 10/23/2017 Trip in hole with cleanout assembly BHA#9,from 5540'to 12500'filling pipe every 2500'. set down 15K at 10215',10570,and 10700',making up top drive and washing through each interval.;UW135K,DW 100K,22OGPM,875 PSI SPP at 10700'.;Continue to trip in hole with cleanout BHA from 12500',washing and reaming last stand down to 12613'.;Pump sweep#1, at 433 GPM,150 RPM,2553 PSI SPP,had 10-15%increase in cuttings coming back 45 BBL late. Had a significant increase in cuttings primarily sand in a secondary wave of;cuttings 300 BBL after initial sweep returned. Pumped sweep#2,at 430 GPM,2390 PSI SPP,had a 5-10%increase in cuttings.;Trip out of hole on elevators from 12613'to 10189'with no issues.;Circulate 3x bottoms up until shakers clean up,rotating and reciprocating pipe,in preparation of dropping gyro.at 441 GPM,2023 PSI SPP,180 RPM.;Drop gyro tool and drift. Pump down at 1 bpm as per toolhand.;Clean up OBM release on dance floor and ISO tank-while transferring OBM from beam tanks to ISO tank on dance floor the hose and nozzle jumped out of the hatch on the ISO tank,causing a 1 BBL spill.;Continue to POOH with cleanout assembly from 12189'to 7942'with no issues.;Pump dry job,clean and clear rig floor.;Continue to POOH with BHA#9 clean out assembly from 7942'to 5505'.;Distance to Plan:244.19'(132.07'High/205.40'Right)of original directional plan#13. Wellhead pressures:20"=11 psi,13 3/8"=88 psi.;Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Mortal rarnwarad•n Iha Tntal•415 the 10/24/2017 Trip out of hole with BHA#9 with gyro,from 5375'to 2804'.;Continue to trip out of hole laying down drill pipe from 2804',vacuuming out each joint.;Stand back HWDP,Pull drift and Gyro tool.LD jars,flex collars,bit sub and bit.;Clean and clear rig floor of extra tools.;Set test plug with two stds of HWDP below. Open and inspect junction box on TD.Didn't find any oil inside of the box.Chance bottom rams to 7".;MU 7"test joint at test LPR's 250/3500 psi-good,test annular 250/2500 psi-good.;L/D test joint. Make up 2 joints and X-O,pull test plug. Stand back 3 stands HWDP.;Service top drive,drawworks.;Rig up to run 7"DWC Liner. Rig up fill up line,M/U XO to floor valve,rig up Weatherford casing equipment. Replace hose on Weatherford tongs.;PJSM,rig up to RIH with 7"DWC /� lt" Liner. Make up shoe track and check floats-good. Continue to RIH with Liner to 959'.;Wellhead pressures:20"=12 psi,13 3/8"=76 psi CV Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Metal recovered:0 lbs.Total:415 lbs. 10/25/2017 RIH picking up 7"DWC liner f/959't/3785'filling pipe every jt and topping of every 10 jts.;Continue RIH picking up 7"liner t/4829'.;MU Baker SDD liner top packer and fill tie back sleeve with Pal Mix.RD Weatherford tongs and liner running equip.;PU 2 jts of HWDP and circ the liner vol.;PJSM,pick up a total of 20 joints of HWDP and continue to run in hole with 7"liner to 7957'with drill pipe from derrick,filling pipe every 10 stands.;Cut and slip drilling line perform rig service while circulating at 125 GPM 550PSI 1.5 pipe volumes,prior to entering open hole with Iiner.;PJSM,pick up cement head making up pups for space out.;Obtain parameters 125gpm/550 psi,200gpm/750 psi. 10rpms/6000ft-lbs,20rpms/6600ft-lbs,30rpms/6900 ft-lbs. PUW 162,SOW 130,ROT 141. Continue to RIH with 7"liner on drill pipe to 11,012'.;tight at 10182'(25K dn,20K up). Attempt to wash through,unable to. Wash and ream from 10,182'to 10194'.146 gpm/679psi;20rpms/10,000ft-lbs. Tight at 10570'(25K dn,20K up). Wash and ream;from 10570'to 10625';150gpm/660 psi,20 rpms/9,500- 12500 ft-lbs. work pack off issues. Wash and ream from 11,000'to 11,012'20rpms/10,500 ft-lbs,130 gpm/700 psi.;Wellhead pressures:20"=12 psi,13 3/8"= 62 psi Fluid loss to well today:0 bbls.Total:0 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Mptal rprnvarad•n the Tntai•215 the • • 10/26/2017 Wash in hole w/7"liner f/11012'to 11040'.Having bad packoff issues.Rack back 1 std and work pipe free back to 10969'.;Work to regain circ staging pumps back up to 200 GPM while working pipe f/10969'U 11005'.Circ and condition mud to get vis down.Started w/a 300+vis and going to a short system we got it coming.;Out of the hole at 146 and going in at 115 vis. Up wt 200k,Dn wt 135k,Rt wt 160k.;RIH w/7"liner washing and reaming f/11005'U11145'.100 GPM, 550 Psi,20 RPMs,9 to 12k TQ.;RIH w/7"liner f/11,145'U bottom at 12,613'.100 GPM,550 Psi.Up wt 205,Dn wt 137.;PU cmt head.Circ and condition mud for cmt job.Staging pump up to 200 GPM.While circ we were RU Schlumberger,Shipping mud from pits,mixing Mud Push,and transferring LVT.;PJSM. SLB loaded lines with water and checked for leaks.SLB pressure tested lines at 1000 low 5000 high,good tests.Rig pumped 20 bbls 12 ppg MudPush II at 5 bpm, 116 psi,and shut down.pr000ed:bottom piva and pumped 142 bbls(586 sx)15.3 ppq Class G cement at 4.5 bpm,450 psi. Dropped top plug,rig displaced with 286 bbls 9.2 ppg OBM at 5 bpm.;Orserved packing off issues at 210 bbls into the displacement with pressures up to 2300 psi,and quickly bleeding off. Stop �� reciprocating pipe on depth as liner hanger appears to begin to set.;Slow to 2.5 bpm 1100 psi with intermittent pack-offs up to 1600 psi,with no losses. 260 bbls C, into the displacement pressured up to 2600 psi and slow rate to 1 bpm as pressure built to 3200 psi.;Shut pumps down at 266 bbls into displacement,pressure does not bleed off. Bleed off pressure and begin pumping 1 bpm,pressure builds up 3200 psi,with minimal returns.;Pump 286 bbls(1/2 shoe track volume !1 extra)and did not bump plug. Check floats,bled back 3 bbls and held. Cemnet was added at V4 ppg during job. 15 bbls lost displacement. CIP at 02:02.;Slack of 30K to confirm liner hanger set. Release from liner as per BOT. Rotate to left 2 turns and work torque down,slacking off down to 90K hookload and Pickup to 170K. Running tool released.;Pick up to expose dogs. Slack off and observe assembly take weight. Slack off 40K,positive indication of packer set at 30K. Pick up and establish rotary 10 rpms,set down 50K on assembly while;rotating. Break off cement head.;Pressure up 500 psi,pick up on liner running tool maintain 500 psi until tool clears. Continue circulating hole volume at 430pm/1480psi. No indications of mud push or cement at bottoms up.;UD cement head. Clean and clear rig floor.;POOH from 7756'to 7595'.;Wrap top drive service loop with spiral wrap.;Wellhead pressures:20"=14 psi,13 3/8"=75 psi Fluid loss to well today:15 bbls.Total:15 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs �s it)) JC Metal recovered:O lbs.Total:415 lbs. 6 �v� g'" lr CV/if') ' 10/27/2017 Finish wrapping service loop,and pump dryjob.;Pull out of hole with Baker liner running tool,racking back HWDP,inspected tools,had good indication from shear on running tool that ZXP liner top packer had set. Laid down tools.;Clean and clear rig floor.;Set test plug with 2 stds of HWDP hanging below same. Change lower rams 7"fixed to VBRs. Break down Baker rotating cement head while changing rams.;Test lower VBR rams and annular on 2 7/8"and 4.4"pipe,at 250 PSI,and 3500 PSI high.;Pull test plug,lay down test joints,stand back HWDP.;Bring BHA components to rig floor and strap. M/U 7"scraper assembly.;RIH to 4777'with scraper assembly.;M/U XO's and 9-5/8"casing scraper.;Continue to trip in hole to 7714',just above TOL. Fill pipe.;M/U crossovers and second 9- 5/8"casing scraper. Continue to RIH to I0,428'.;Wellhead pressures:20"=16 psi,13 3/8"=72 psi Fluid loss to well today:0 bbls.Total:15 bbls Code 8: 0 hrs,Total:1 hrs Total October:1 hrs Metal recovered:0 lbs.Total:415 lbs. 10/28/2017 RIH with Scraper assembly to 10,558'.Continue to RIH picking up DP to 11,170'.;Shut down due to diesel running out from under the pits. Secure well and all personal responded to clean up diesel.Found that pit 4 was leaking out of the bottom of the pit. Pit 4 was isolated;and its contents were transferred to other pits. Found that the suction valve in pit 4 had been impacting the bottom of the pit when it was cycled and caused a hole to form. 20 gallons of diesel;was contained and cleaned up from the platform drill deck,with none hitting the water. Cleaned prepared the pit to be repaired. Ship 50 bbls OBM from pit 5 to production beam tank.;Continue RIH picking DP from 11,170'tagging up at 12,339',set down 10K. Went to screw in and TD had a lube oil pressure fault. Stood one stand back and started trouble shooting TD.;Continue prepping to weld hole in mud pit#4.;Trouble shoot lube pump issue on TD.[Had good PJSM and did the repairs on mud pit#4. After we welded the holes we tested the pit with water and it held good.]Found bad wire going to TD lube pump.;Rigged up and circulated with a head pin while trouble shooting top drive,removed protective wrap,and installed junction box with a plug in in the derrick by service loop bridal and ran a new;power cable to top drive lube oil pump. While circulating treated mud with Baroid OBM thinner and was able to lower yield from 18 to 14,and we were able to lower our viscosity from a 700+to 95;after new cable was installed the protective wrap was replaced.;Tagged up again at 12339'and attempted to wash down with no luck at 385 GPM 2350 PSI,engaged rotary and drilled up wiper plug had rubber coming back across shakers at bottoms up. 3-8K WOB,;60 RPM 7.5-9K TQ. Continue to drill cement to 12,483 with 3-7K WOB and 25-50 ROP,385 GPM,2527 PSI,7.5-9K TQ.;Circulate hole clean at 385 gpm/2420 psi;circulate 1.5 x annular volume.;POOH from 12,483'to 12,301'.;Service rig:top drive,draw works.;Wellhead pressures:20"=18 psi,13 3/8"=54 psi Fluid loss to well today:15 bbls.Total:15 bbls Code 8: 3 hrs,Total:4 hrs Total October:4 hrs Metal recovered:0 lbs.Total:415 lbs. 10/29/2017 Short trip to where upper 9 5/8"scraper was at surface and lower 7"scraper came out of liner.;RIH U 12,483,just above landing collar.;Having issues w/the TD lube pump again.Space out so TD was close to floor.Circ hole clean and mix spacer for displacement.Work on TD while circ.;RU and Test csg to 2200 psi for 30 min on a chart.Lost 75 psi.Good test.Bleed of press and RD test equip.;TD lube pump wire is replaced and tested.LD pup and PU sng.and prep for displacing well to diesel.;Hold PJSM with drill crew and production for changing over from OBM to diesel,review JSA and assign roles and responsibilities.;Transfer OBM to platform beam tank,pull shaker screens,pump 20 BBL spacer at 130 GPM,followed by 150 BBLM of diesel at 168 GPM to load drill pipe,filled pits 2-4 with diesel from production.;Continued with displacement pumping diesel at 260 GPM,rotating and reciprocating pipe,while taking on diesel from production and ISO tanks on deck,taking OBM returns and shipping to;platform beam tank. Pumped a total of 792 BBL of diesel with about 100 BBL of interface,final mud weight was 7.2 PPG with an ES of 2000. Initial rotating torque was 7800,and final was 17500.;Clean and clear rig floor,pump trip tank to pit#1 ensure all hoses and equipment was secure.;Service rig.;Clean trip tank and pill pit. RID hoses/manifold used for displacement. R/U to begin laying down drill pipe.;POOH with casing scraper assembly,Laying down drill pipe to 11,123'.;Wellhead pressures:20"=20 psi,13 3/8"=80 psi Fluid loss to well today:0 bbls.Total:15 bbls Code 8: 3 hrs,Total:4 hrs Total October:4 hrs Metal recovered:3 lbs.Total:420 lbs. 10/30/2017 Continue POH w/scraper clean out assem to 10,478'.;Hose on TD compensator started leaking,and air boot on flow nipple also started leaking.Build a new hose and replace it on the TD compensator and air up boot on flow nipple.Will change lower top;boot on lower flange when we get out of the hole.;POH f/ 10,478'to surface. UD casing scrapers and XO's. UD HWDP,bit sub,and bit.;Clean and clear rig floor. Replace air boot at flow nipple.;R/U Pollard E-Line. M/U CBL,CCL,and gamma tool string. RIH to 11,755'-and log up. POOH and RID E-line.*Note:change over to completion AFE at 00:00;Wellhead pressures:20"= 20 psi,13 3/8"=61 psi Fluid loss to well today:0 bbls.Total:15 bbls Code 8: 0 hrs,Total:4 hrs Total October:4 hrs Metal recovered.0 lbs Total.420 lbs • Hilcorp Energy Company Composite Report Well Name: GPF GP 11-24RD Field: County/State: ,Alaska (LAT/LONG): ovation(RKB): API#: Spud Date: Job Name: 1711828C GP 11-24RD Completion Contractor Kuukpik 5 AFE#: AFE$: 10/30/2017 R/D E-i e :......................:....................,,....................................................................... I n .,Rig up to RIH with TCP guns.,PJSM. P/U TCP gun assembly as per TriPoint to 861' 10/31/2017 RIH PU 4 5/8"6 SPF perf guns f/892 t/1832.Picked up 87 guns.,MU 4 1/2 blank safety spacer,firing head,3 2 7/8 pups,impact actuated valve,stop fill valve,ann press prod valve, 1 jt 2 7/8 tbg,lower transfer sub,retrievable pkr,tbg pup,upper transfer sub,2 XOs,1 jt 4 1/2 DP,XO, RA sub,XO.Total= 1,979.58'.,RI H w/pelf guns on DP out of the derrick t/5572'.Pump dn tbg to ensure that fast fill valve closed.,Pump dn DP to see if fast fill had closed and it circ so it wasn't closed.Close upper pipe rams and line up on choke.Pump dn DP and both the DP and the ann pressured up to 515 psi.Bled off DP and csg press held.Bled off csg press and shut back in. Pressure up on DP to 300 psi and csg press stayed at 0 psi.Valve had closed. Bleed everything off and open well.,RIH to just above liner top at 7682'.,Blow dn TD and change swivel packing.,Slip and cut drlg line 145'.Service rig.,Cont.to RIH TCP guns on DP f/7683' to 12,402'.,R/U Pollard E-Line.,RIH with E-Line&correlate to RA marker @ 10,428'.Send logs to town for verification.,POOH&R/D E-line.,M/U TIW,&10' pup.Load firing rod.Space out RA marker @ 10,424'. Apply 6 wraps to right&set packer.5/0 f/98K to 73K&confirm packer set with 25K compression.,R/U TriPoint to monitor for firing of guns.Pressure up annulus to 400 psi.Drop rod&after 2 min saw slight indication thatuns fired.Monitor well with slight vacuum on DP.Top of perfs 10,568&bottom of perfs 12,400'.,P/U 10'@ 220K While holding 400 psi on annulus And open bypass valve above packer. Annulus psi dropped to 0 psi&annulus on slight vac.,Fill drill pipe&circ with 1.2 bpm&@ 128 bbls pumped saw increase in pressure on annulus. Cont.to circ with 2 bpm taking returns thru choke monitoring for losses&or gas. 11/1/2017 Circ gun gas out with annular closed going through choke and through bypass above pkr. Pumped a total of 1 1/4 bottoms up. Pumping at 2 BPM, 170 Psi. Gas peaked at 405 units.,Open annular and PU to release packer.Attempted several time to release pkr but it would set every time we would set back down. Pull one std and lay it dn staying on the up stroke.,Circ bottoms up again over the top of the well.Had a high of 75 units of gas.,Went to break off the TD and it was flowing back,Circ 1/2 DP vol and it was still flowing back.Circ again and it still flowed back.Pumped a 10 bbl water pill and it came dry.,POH standing 45 stds back in the derrick f/12,336'to 9,571'.,Circ B/U with packer inside 9-5/8"casing with 5 BPM @ 200 PSi.No gas observed on B/U&no losses.,Monitor well for flow(slight drop).Pump dry job&PJSM for UD DP.,POOH&UD DP f/9,571'to 5,388'.,Service rig.,Cont.to POOH&UD DP f/5,388'to 1,980'.Monitor well for flow(slight drop). UD 2 jt work string&RA marker to 1,900'.,M/U safety joint.UD packer&pup jts to 1850'.R/U Weatherford. 11/2/2017 RU Weatherford and hold PJSM for laying dn perf guns.,LD 87 pert guns.All shots fired.,Break down safety jt.Clear and clean floor.,RU to run completion. Hold PJSM.PU and run completion to GLM#5 at 2,156'.,Continue RIH picking up and running 2 7/8 completion f12,156'to 7,099'.,Continue RIH picking up and (1).,:40.1 l! running 2 7/8 completion f/7,099'to 10,412'(M/U SSV A 10,092'&function test)..CIO elevators.M/U tubing hanger&terminate control line. 11/3/2017 Drop bar.MU landing jt and land out hanger.RILDS.Pressure up dn tbg to 3500 psi on a chart for 30 min.This set the packer and tested the tbg.,RU to test back side with the test pump holding 2500 psi on the tbg.Using test pump to pressure up but it was to slow.Shut down and RU rig pump to ann.Test ann to 2100 psi on a chart for 30 min..RD landing jt and test equip.,Set BPV.Bleed off and terminate SSSV control line on rig floor.,Blow dn TD,Kill line,High press hose to wellbay,and mudline back to pumps.Pull pins on rotary.,Pull mouse hole, RU PU slings, PU back of rotary and remove back floor plate.Pull rotary and set on pipe rack by v-door.Clean drip pan and remove same.Pull flow nipple,flowline,and flow box.Hot bolt bops and riser in preparation to remove all BOP equip.,Get BOP trolly moved over in place. N/D BOPE stack&riser.,N/U tree.Test void 5000 psi(good).NIU SSV.Pull BPV&set TWC.Test tree to 5000 psi (good)Pull TWC.,R/U Pollard&R/U lubricator.RIH with Pollard slick line to retrieve rod&plug in X nipple. • • Hilcorp Alaska, LLC Granite Point Granite Point Platform GP 11-24RD 507332004601 Sperry Drilling Definitive Survey Report 29 October, 2017 HALLIBURTDN Sperry Drilling 0 • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: . , GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD Survey Calculation Method: Minimum Curvature Design: GP 11-24RD Database: Sperry EDM-NORTH US+CANADA ;i ti Project Granite 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 GP-11-24RD,Leg3 Slot8 Well Position +N/-S 0.00 usft Northing: 2,544,542.44 usft Latitude: 60°57'29.235 N +E/-W 0.00 usft Easting: 263,398.89 usft Longitude: 151°19'52.405 W Position Uncertainty 0.00 usft Wellhead Elevation: 129.00 usft Water Depth: 75.00 usft Wellbore GP 11-24RD ,. a :.. , , tr a ..=,aim AILWAM. s..,- <._. .- Magnetics Model Name Sample Date DeclinationDip Angle Field Strength 4 4 (°) (°) 4a.(nT) BGGM2017 10/9/2017 16.04 73.84 55,438 Design GP 11-24RD Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,694.57 Vertical Section: " `I' Depth From(TVD) +N/-S +E/-W Direction „rf? i, (usft) (usft) (usft) `' (°) i 0.00 0.00 0.00 161.14 Survey Program Date 10/29/2017 : Ili :: From To a . .h (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date `^...:. . k.. „,„,X.:. ., tom..r. 208.00 7,961.89 GP 11-24RD Drop Gyro(GP-11-24 PB1) 2_Gyro-NS-CT_Drop H038Ga:Continuous dropped into a drill collar 10/24/2017 8,007.00 10,010.21 GP 11-24RD Gyro(GP 11-24RD PB1) 2_Gyro-NS-CT_Drop H038Ga:Continuous dropped into a drill collar 10/24/2017 10,074.68 10,694.57 GP 11-24RD PB1 MWD+AX+sag(GP 11 2_MWD+AX+Sag A004Mb/ISC4:BGGM dec&axial+sag corr. 10/03/2017 10,700.00 12,585.12 GP 11-24RD MWD+AX+sag(GP 11-24R 2_MWD+AX+Sag A004Mb/ISC4:BGGM dec&axial+sag corr. 10/09/2017 Survey Map � Map Vertical MD Inc Azi TVD TVDSS 4., +N/-S ,:..'+E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) i.... (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 0.00 0.00 0.00 0.00 -129.00 0.00 0.00 2,544,542.44 263,398.89 0.00 0.00 UNDEFINED 208.00 0.46 257.39 208.00 79.00 -0.18 -0.81 2,544,542.28 263,398.07 0.22 -0.09 2_Gyro-NS-CT_Drop(1) 238,89 0.77 256.25 238.89 109.89 -0.26 -1.14 2,544,542.21 263,397.75 1.00 -0.12 2_Gyro-NS-CT Drop(1) 269.82 0.92 250.70 269.81 140.81 -0.39 -1.57 2,544,542.08 263,397.31 0.55 -0.14 2_Gyro-NS-CT_Drop(1) 300.89 1.09 238.94 300.88 171.88 -0.63 -2.06 2,544,541.86 263,396.82 0.86 -0.07 2_Gyro-NS-CT_Drop(1) 331.55 1.64 237.78 331.53 202.53 -1.01 -2.68 2,544,541.49 263,396.19 1.80 0.09 2_Gyro-NS-CT_Drop(1) 362.46 2.90 246.02 362.41 233.41 -1.56 -3.77 2,544,540.95 263,395.09 4.20 0.26 2_Gyro-NS-CT_Drap(1) 393.36 4.07 247.45 393.26 264.26 -2.30 -5.50 2,544,540.25 263,393.35 3.80 0.40 2_Gyro-NS-CT_Drop(1) 424.31 4.80 245.79 424.11 295.11 -3.25 -7.69 2,544,539.34 263,391.13 2.39 0.59 2_Gyro-NS-CT_Drop(1) 455.25 5.25 243.10 454.93 325.93 -4.42 -10.14 2,544,538.22 263,388.67 1.64 0.91 2_Gyro-NS-CT_Drop(1) 486.11 5.47 242.21 485.66 356.66 -5.75 -12.70 2,544,536.95 263,386.08 0.76 1.34 2_Gyro-NS-CT_Drop(1) 10/29/2017 6:54:11 PM Page 2 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD a Project: Granite Point TVD Reference: k" GP 11-24RD WPO8 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: o ' f. GP 11-24RD WP08 Actual RKB @ 129.O0usft Well: GP-11-24RD North Reference: ? True Wellbore: GP 11-24RD Survey Calculation Method: '. Minimum Curvature il Design: GP 11-24RD 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 517.01 5.49 242.13 516.42 387.42 -7.13 -15.31 2,544,535.63 263,383.44 0.07 1.80 2_Gyro-NS-CT_Drop(1) 547.93 5.41 242.27 547.20 418.20 -8.50 -17.90 2,544,534.31 263,380.82 0.26 2.25 2_Gyro-NS-CT_Drop(1) 579.53 5.43 242.29 578.66 449.66 -9.89 -20.55 2,544,532.98 263,378.15 0.06 2.71 2_Gyro-NS-CT_Drop(1) 610.46 5.34 243.31 609.45 480.45 -11.21 -23.13 2,544,531.70 263,375.54 0.42 3.14 2_Gyro-NS-CT_Drop(1) 641.35 5.24 243.49 640.21 511.21 -12.49 -25.68 2,544,530.48 263,372.97 0.33 3.52 2_Gyro-NS-CT_Drop(1) 672.28 5.11 244.29 671.01 542.01 -13.72 -28.18 2,544,529.30 263,370.44 0.48 3.87 2_Gyro-NS-CT_Drop(1) 703.20 4.93 244.32 701.81 572.81 -14.89 -30.62 2,544,528.18 263,367.98 0.58 4.19 2_Gyro-NS-CT_Drop(1) 734.14 4.75 244.12 732.64 603.64 -16.02 -32.97 2,544,527.09 263,365.61 0.58 4.51 2_Gyro-NS-CT_Drop(1) 765.10 4.53 244.33 763.50 634.50 -17.11 -35.22 2,544,526.05 263,363.33 0.71 4.81 2_Gyro-NS-CT_Drop(1) 795.92 4.46 245.06 794.23 665.23 -18.15 -37.41 2,544,525.06 263,361.12 0.29 5.08 2_Gyro-NS-CT_Drop(1) 826.86 4.30 245.34 825.08 696.08 -19.14 -39.55 2,544,524.11 263,358.96 0.52 5.33 2_Gyro-NS-CT_Drop(1) 857.69 4.04 243.04 855.83 726.83 -20.11 -41.57 2,544,523.18 263,356.92 1.00 5.60 2_Gyro-NS-CT_Drop(1) 886.65 3.59 236.64 886.72 757.72 -21.14 -43.35 2,544,522.19 263,355.12 2.00 5.99 2_Gyro-NS-CT_3rop(1) 919.53 3.32 222.98 917.54 788.54 -22.32 -44.77 2,544,521.03 263,353.68 2.80 6.66 2_Gyro-NS-CT_Drop(1) 950.45 3.30 204.13 948.41 819.41 -23.79 -45.74 2,544,519.58 263,352.68 3.50 7.73 2_Gyro-NS-CT_Drop(1) 981.34 3.80 185.45 979.24 850.24 -25.62 -46.20 2,544,517.76 263,352.18 4.06 9.31 2_Gyro-NS-CT_Drop(1) 1,012.22 4.80 173.12 1,010.04 881.04 -27.92 -46.15 2,544,515.46 263,352.19 4.39 11.51 2_Gyro-NS-CT_Drop(1) 1,043.15 5.99 167.94 1,040.83 911.83 -30.79 -45.66 2,544,512.59 263,352.62 4.15 14.38 2_Gyro-NS-CT_Drop(1) 1,074.05 7.28 165.31 1,071.52 942.52 -34.26 -44.82 2,544,509.10 263,353.39 4.29 17.93 2_Gyro-NS-CT_Drop(1) 1,105.75 8.50 166.25 1,102.92 973.92 -38.48 -43.76 2,544,504.86 263,354.37 3.87 22.27 2_Gyro-NS-CT_Drop(1) 1,136.67 9.71 166.24 1,133.45 1,004.45 -43.23 -42.59 2,544,500.09 263,355.43 3.91 27.14 2_Gyro-NS-CT_Drop(1) 1,167.54 10.82 171.94 1,163.83 1,034,83 -48.63 -41.57 2,544,494.67 263,356.35 4.87 32.58 2_Gyro-NS-CT_Drop(1) 1,199.17 11.94 174.48 1,194.83 1,065.83 -54.82 -40.84 2,544,488.46 263,356.95 3.88 38.68 2_Gyro-NS-CT_Drop(1) 1,230.08 12.89 178.25 1,225.02 1,096.02 -61.45 -40.42 2,544,481.83 263,357.23 4.04 45.09 2_Gyro-NS-CT_Drop(1) 1,260.91 13.87 180.94 1,255.02 1,126.02 -68.58 -40.38 2,544,474.69 263,357.13 3.76 51.85 2_Gyro-NS-CT_Drop(1) 1,291.79 14.98 182.71 1,284.92 1,155.92 -76.27 -40.63 2,544,467.01 263,356.72 3.87 59.05 2_Gyro-NS-CT_Drop(1) 1,322.72 16.10 184.66 1,314.72 1,185.72 -84.54 -41.17 2,544,458.76 263,356.02 4.00 66.70 2_Gyro-NS-CT_Drop(1) 1,353.58 17.40 184.94 1,344.27 1,215.27 -93.40 -41.91 2,544,449.91 263,355.09 4.22 74.85 2_Gyro-NS-CT_Drop(1) 1,384.46 18.64 185.61 1,373.64 1,244.64 -102.91 -42.79 2,544,440.42 263,354.02 4.07 83.56 2_Gyro-NS-CT_Drop(1) 1,415.39 19.97 186.69 1,402.83 1,273.83 -113.08 -43.89 2,544,430.28 263,352.72 4.45 92.83 2_Gyro-NS-CT_Drop(1) 1,446.34 19.96 186.94 1,431.92 1,302.92 -123.57 -45.14 2,544,419.82 263,351.25 0.28 102.35 2_Gyro-NS-CT_Drop(1) 1,477.26 22.41 187.83 1,460.74 1,331.74 -134.65 -46.58 2,544,408.77 263,349.58 7.99 112.37 2_Gyro-NS-CT_Drop(1) 1,508.20 22.41 187.85 1,489.35 1,360.35 -146.34 -48.19 2,544,397.12 263,347.74 0.02 122.91 2_Gyro-NS-CT_Drop(1) 1,539.13 23.80 187.80 1,517.80 1,388.80 -158.36 -49.84 2,544,385.13 263,345.84 4.49 133.75 2_Gyro-NS-CT_Drop(1) 1,570.05 24.94 188.49 1,545.96 1,416.96 -170.99 -51.65 2,544,372.54 263,343.78 3.80 145.12 2_Gyro-NS-CT_Drop(1) 1,600.99 25.71 188.81 1,573.93 1,444.93 -184.07 -53.65 2,544,359.50 263,341.52 2.53 156.86 2_Gyro-NS-CT_Drop(1) 1,631.86 26.04 189.11 1,601.70 1,472.70 -197.38 -55.74 2,544,346.24 263,339.15 1.15 168.77 2_Gyro-NS-CT_Drop(1) 1,662.78 26.32 189.04 1,629.45 1,500.45 -210.85 -57.90 2,544,332.82 263,336.73 0.91 180.83 2_Gyro-NS-CTDrop(1) 1,693.71 26.44 189.18 1,657.16 1,528.16 -224.42 -60.07 2,544,319.29 263,334.28 0.44 192.96 2_Gyro-NS-CT_Drop(1) 1,724.57 26.33 189.02 1,684.80 1,555.80 -237.96 -62.24 2,544,305.80 263,331.83 0.42 205.08 2_Gyro-N5-CT_Drop(1) 10/29/2017 6:54:11PM Page 3 COMPASS 5000.1 Build 810 • Halliburton Definitive Survey Report c,,m.2 Fes, r,a.. -.r:.,---...w.-,.., ..,sac,.....,::: ,,,-.--,,,,,,,,,,,T-07.7.77,,,,,,, z"", ., ..,,-,,.,aas-: ^,,,.. «.,.Y=:a : • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC 'Local Co-ordinate Reference: Well GP-11-24RD Project: -Granite Point - TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: 'Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: ?GP-11-24RD North Reference: True " Wellbore: GP 11-24RD Survey Calculation Method: Minimum Curvature Design: a GP 11-24RD Database: Sperry EDM-NORTH US+CANADA Survey ' 6 Map Map Vertical MD Inc ,a' Azi TVD TVDSS +N/-S y +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,803.17 21.81 186.20 3,586.27 3,457.27 -1,069.80 -150.54 2,543,475.96 263,226.66 0.17 963.74 2_Gyro-NS-CT_Drop(1) 3,865.11 22.17 186.38 3,643.70 3,514.70 -1,092.85 -153.08 2,543,452.96 263,223.65 0.59 984.73 2_Gyro-NS-CT_Drop(1) 3,926.88 22.53 186.74 3,700.83 3,571.83 -1,116.19 -155.77 2,543,429.69 263,220.49 0.62 1,005.95 2_Gyro-NS-CT_Drop(1) 3,989.45 22.32 186.84 3,758.67 3,629.67 -1,139.89 -158.59 2,543,406.05 263,217.19 0.34 1,027.47 2_Gyro-NS-CT_Drop(1) 4,051.33 21.30 186.33 3,816.12 3,687.12 -1,162.72 -161.23 2,543,383.27 263,214.09 1.68 1,048.23 2_Gyro-NS-CT_Drop(1) 4,113.21 22.20 186.91 3,873.60 3,744.60 -1,185.50 -163.87 2,543,360.56 263,210.98 1.50 1,068.93 2_Gyro-NS-CT_Drop(1) 4,175.93 23.10 187.23 3,931.48 3,802.48 -1,209.47 -166.85 2,543,336.65 263,207.52 1.45 1,090.65 2_Gyro-NS-CT_Drop(1) 4,238.65 23.85 187.36 3,989.01 3,860.01 -1,234.25 -170.02 2,543,311.94 263,203.84 1.20 1,113.07 2_Gyro-NS-CT_Drop(1) 4,301.87 24.54 187.38 4,046.67 3,917.67 -1,259.95 -173.34 2,543,286.32 263,200.00 1.09 1,136.32 2_Gyro-NS-CT_Drop(1) 4,363.68 25.38 187.44 4,102.71 3,973.71 -1,285.81 -176.71 2,543,260.53 263,196.11 1.36 1,159.71 2_Gyro-NS-CT_Drop(1) 4,425.45 25.83 188.45 4,158.41 4,029.41 -1,312.25 -180.40 2,543,234.17 263,191.88 1.01 1,183.53 2_Gyro-NS-CT_Drop(1) 4,487.38 25.64 188.20 4,214.20 4,085.20 -1,338.86 -184.29 2,543,207.65 263,187.45 0.35 1,207.45 2_Gyro-NS-CT_Drop(1) 4,549.15 25.89 187.89 4,269.83 4,140.83 -1,365.44 -188.05 2,543,181.15 263,183.15 0.46 1,231.40 2_Gyro-NS-CT_Drop(1) 4,611.07 25.19 188.49 4,325.70 4,196.70 -1,391.87 -191.85 2,543,154.81 263,178.82 1.21 1,255.18 2_Gyro-NS-CT_Drop(1) 4,673.05 25.41 188.56 4,381.73 4,252.73 -1,418.06 -195.78 2,543,128.70 263,174.36 0.36 1,278.70 2_Gyro-NS-CT_Drop(1) 4,734.90 25.91 188.72 4,437.48 4,308.48 -1,444.54 -199.80 2,543,102.31 263,169.80 0.82 1,302.45 2_Gyro-NS-CT_Drop(1) 4,796.76 26.16 188.82 4,493.07 4,364.07 -1,471.38 -203.94 2,543,075.56 263,165.11 0.41 1,326.51 2_Gyro-NS-CT_Drop(1) 4,858.59 25.56 189.12 4,548.71 4,419.71 -1,498.01 -208.15 2,543,049.02 263,160.37 0.99 1,350.36 2_Gyro-NS-CT_Drop(1) 4,920.49 25.88 189.57 4,604.47 4,475.47 -1,524.52 -212.51 2,543,022.61 263,155.47 0.61 1,374.03 2_Gyro-NS-CT_Drap(1) 4,982.38 25.87 190.01 4,660.16 4,531.16 -1,551.14 -217.10 2,542,996.09 263,150.34 0.31 1,397.74 2_Gyro-NS-CT_Drop(1) 5,044.15 25.46 189.66 4,715.83 4,586.83 -1,577.50 -221.67 2,542,969.83 263,145.23 0.71 1,421.21 2_Gyro-NS-CT_Drop(1) 5,106.00 26.06 189.79 4,771.54 4,642.54 -1,603.99 -226.21 2,542,943.44 263,140.15 0.97 1,444.81 2_Gyro-NS-CT_Drop(1) 5,167.85 25.00 190.02 4,827.35 4,698.35 -1,630.25 -230.80 2,542,917.28 263,135.04 1.72 1,468.18 2_Gyro-NS-CT_Drop(1) 5,229.54 25.52 190.38 4,883.14 4,754.14 -1,656.16 -235.46 2,542,891.47 263,129.85 0.88 1,491.19 2_Gyro-NS-CT_Drop(1) 5,291.37 25.01 191.30 4,939.05 4,810.05 -1,682.07 -240.42 2,542,865.66 263,124.36 1.04 1,514.11 2_Gyro-NS-CT_Drop(1) 5,353.31 25.67 191.38 4,995.03 4,866.03 -1,708.07 -245.63 2,542,839.78 263,118.62 1.07 1,537.03 2_Gyro-NS-CT_Drop(1) 5,415.24 24.73 191.52 5,051.07 4,922.07 -1,733.91 -250.87 2,542,814.05 263,112.87 1.52 1,559.79 2_Gyro-NS-CT_Drop(1) 5,477.09 25.01 191.87 5,107.18 4,978.18 -1,759.38 -256.14 2,542,788.69 263,107.08 0.51 1,582.19 2_Gyro-NS-CT_Drop(1) 5,538.94 25.14 192.32 5,163.20 5,034.20 -1,785.01 -261.63 2,542,763.18 263,101.07 0.37 1,604.67 2_Gyro-NS-CT_Drop(1) 5,600.88 24.53 192.51 5,219.42 5,090,42 -1,810.42 -267.22 2,542,737.89 263,094.96 0.99 1,626.91 2_Gyro-NS-CT_Drop(1) 5,662.81 24.81 191.66 5,275.69 5,146.69 -1,835.69 -272.63 2,542,712.73 263,089.04 0.73 1,649.08 2_Gyro-NS-CT_Drop(1) 5,724.70 24.47 192.72 5,331.95 5,202.95 -1,860.91 -278.08 2,542,687.63 263,083.08 0.90 1,671.19 2_Gyro-NS-CT_Drop(1) 5,786.57 24.15 192.75 5,388.33 5,259.33 -1,885.76 -283.70 2,542,662.90 263,076.96 0.52 1,692.88 2_Gyro-NS-CT_Drop(1) 5,848.15 24.71 192.26 5,444.40 5,315.40 -1,910.62 -289.21 2,542,638.16 263,070.94 0.97 1,714.63 2_Gyro-NS-CT_Drop(1) 5,910.01 24.24 192.84 5,500.70 5,371.70 -1,935.64 -294.78 2,542,613.26 263,064.87 0.85 1,736.50 2_Gyro-NS-CT_Drop(1) 5,971.93 24.16 193.02 5,557.18 5,428.18 -1,960.38 -300.46 2,542,588.64 263,058.69 0.18 1,758.08 2_Gyro-NS-CT_Drop(1) 6,033.91 23.09 192.82 5,613.96 5,484.96 -1,984.59 -306.01 2,542,564.55 263,052.64 1.73 1,779.19 2_Gyro-NS-CT_Drop(1) 6,095.74 23.91 193.15 5,670.66 5,541.66 -2,008.61 -311.55 2,542,540.65 263,046.62 1.34 1,800.14 2_Gyro-NS-CT_Drop(1) 6,158.43 23.36 193.80 5,728.10 5,599.10 -2,033.05 -317.41 2,542,516.33 263,040.27 0.97 1,821.38 2_Gyro-NS-CT_Drop(1) 6,220.47 23.16 193.98 5,785.09 5,656.09 -2,056.83 -323.29 2,542,492.67 263,033.90 0.34 1,841.98 2_Gyro-N5-CT_Drop(1) 10/29/2017 6:54:11 PM Page 5 COMPASS 5000.1 Build 810 • o Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.O0usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD Survey Calculation Method: Minimum Curvature Design: GP 11-24RD 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 6,282.30 23.44 194.54 5,841.88 5,712.88 -2,080.54 -329.31 2,542,469.10 263,027.40 0.58 1,862.47 2_Gyro-NS-CT_Drop(1) 6,344.93 23.23 194.65 5,899.39 5,770.39 -2,104.54 -335.56 2,542,445.22 263,020.66 0.34 1,883.17 2_Gyro-NS-CT_Drop(1) 6,407.71 22.88 194.81 5,957.15 5,828.15 -2,128.32 -341.82 2,542,421.58 263,013.93 0.57 1,903.65 2_Gyro-NS-CT_Drop(1) 6,469.65 22.89 195.25 6,014.22 5,885.22 -2,151.59 -348.06 2,542,398.45 263,007.21 0.28 1,923.64 2_Gyro-NS-CT_Drop(1) 6,532.42 22.63 195.78 6,072.10 5,943.10 -2,174.98 -354.56 2,542,375.19 263,000.24 0.53 1,943.69 2_Gyro-NS-CT_Drop(1) 6,594.34 22.59 196.95 6,129.26 6,000.26 -2,197.82 -361.26 2,542,352.49 262,993.07 0.73 1,963.13 2_Gyro-NS-CT_Drop(1) 6,656.21 22.59 196.34 6,186.39 6,057.39 -2,220.59 -368.07 2,542,329.86 262,985.81 0.38 1,982.48 2_Gyro-NS-CT_Drop(1) 6,718.07 22.48 196.41 6,243.52 6,114.52 -2,243.34 -374.75 2,542,307.26 262,978.66 0.18 2,001.85 2_Gyro-NS-CT_Drop(1) 6,780.00 22.86 197.25 6,300.67 6,171.67 -2,266.19 -381.67 2,542,284.56 262,971.29 0.81 2,021.23 2_Gyro-NS-CT_Drop(1) 6,842.07 22.60 196.21 6,357.92 6,228.92 -2,289.15 -388.57 2,542,261.74 262,963.92 0.77 2,040.74 2_Gyro-NS-CT_Drop(1) 6,904.77 21.76 197.32 6,415.98 6,286.98 -2,311.82 -395.39 2,542,239.22 262,956.64 1.50 2,059.98 2_Gyro-NS-CT_Drop(1) 6,967.40 22.25 197.41 6,474.04 6,345.04 -2,334.21 -402.40 2,542,216.97 262,949.18 0.78 2,078.91 2_Gyro-NS-CT_Drop(1) 7,030.10 22.04 198.16 6,532.12 6,403.12 -2,356.72 -409.62 2,542,194.61 262,941.50 0.56 2,097.88 2_Gyro-NS-CT_Drop(1) 7,092.81 22.62 199.04 6,590.13 6,461.13 -2,379.30 -417.22 2,542,172.19 262,933.45 1.07 2,116.79 2_Gyro-NS-CT_Drop(1) 7,155.46 23.59 199.70 6,647.75 6,518.75 -2,402.49 -425.38 2,542,149.17 262,924.82 1.60 2,136.10 2_Gyro-NS-CT_Drop(1) 7,217.37 24.51 201.79 6,704.29 6,575.29 -2,426.08 -434.32 2,542,125.77 262,915.40 2.02 2,155.53 2_Gyro-NS-CT_Drop(1) 7,279.28 24.36 202.45 6,760.65 6,631.65 -2,449.80 -443.96 2,542,102.25 262,905.28 0.50 2,174.87 2_Gyro-NS-CT_Drop(1) 7,341.93 24.62 203.36 6,817.67 6,688.67 -2,473.73 -454.07 2,542,078.54 262,894.69 0.73 2,194.24 2_Gyro-NS-CT_Drop(1) 7,404.06 24.85 204.20 6,874.09 6,745.09 -2,497.51 -464.55 2,542,054.97 262,883.72 0.68 2,213.36 2_Gyro-NS-CT_Drop(1) 7,466.61 24.92 203.35 6,930.84 6,801.84 -2,521.60 -475.16 2,542,031.10 262,872.62 0.58 2,232.73 2_Gyro-NS-CT_Drop(1) 7,528.47 23.68 199.62 6,987.22 6,858.22 -2,545.27 -484.50 2,542,007.63 262,862.81 3.19 2,252.11 2_Gyro-NS-CT_Drop(1) 7,590.33 24.92 199.99 7,043.60 6,914.60 -2,569.22 -493.13 2,541,983.86 262,853.70 2.02 2,271.98 2_Gyro-NS-CT_Drop(1) 7,652.21 25.70 201.44 7,099.54 6,970.54 -2,593.96 -502.49 2,541,959.32 262,843.84 1.61 2,292.37 2_Gyro-NS-CT_Drop(1) 7,714.19 25.80 202.00 7,155.36 7,026.36 -2,618.97 -512.45 2,541,934.51 262,833.37 0.42 2,312.82 2_Gyro-NS-CT_Drop(1) j� 7,776.05 25.19 201.88 7,211.20 7,082.20 -2,643.67 -522.40 2,541,910.02 262,822.92 0.99 2,332.98 2_Gyro-NS-CT_Drop(1) 7,837.98 24.62 201.67 7,267.37 7,138.37 -2,667.89 -532.08 2,541,886.00 262,812.75 0.93 2,352.77 2_Gyro-NS-CT_Drop(1) ., "�� �� 7,900.00 25.00 201.85 7,323.67 7,194.67 -2,692.06 -541.73 2,541,862.04 262,802.62 0.62 2,372.53 2_Gyro-NS-CT_Drop(1) 7,961.89 24.64 202.64 7,379.84 7,250.84 -2,716.11 -551.56 2,541,838.20 262,792.30 0.79 2,392.11 2_Gyro-NS-CT_Drop(1) 8,007.00 24.48 204.53 7,420.87 7,291.87 -2,733.29 -559.06 2,541,821.17 262,784.45 1.78 2,405.94 2_Gyro-NS-CT_Drop(2) 0 8,023.71 24.43 20523 7,436.08 7,307.08 -2,739.56 -561.97 2,541,814.96, 262,781.41 1.76 2,410.94 2_Gyro-NS-CT_Drop(2) 8,085.58 24.35 205.93 7,492.43 7,363.43 -2,762.61 -573.00 2,541,792.14 262,769.92 0.48 2,429.18 2_Gyro-NS-CT_Drop(2) 8,147.42 23.57 206.10 7,548.94 7,419.94 -2,785.18 -584.01 2,541,769.80 262,758.45 1.27 2,446.98 2_Gyro-NS-CT_Drop(2) 8,209.30 22.58 207.17 7,605.87 7,476.87 -2,806.86 -594.88 2,541,748.35 262,747.14 1.74 2,463.98 2_Gyro-NS-CT_Drop(2) 8,271.15 20.95 203.68 7,663.31 7,534.31 -2,827.55 -604.75 2,541,727.86 262,736.86 3.36 2,480.38 2_Gyro-NS-CT_Drop(2) 8,332.90 18.26 203.18 7,721.47 7,592.47 -2,846.56 -612.99 2,541,709.03 262,728.23 4.36 2,495.70 2_Gyro-NS-CT_Drop(2) 8,394.74 14.65 200.47 7,780.77 7,651.77 -2,862.79 -619.54 2,541,692.92 262,721.35 5.97 2,508.95 2_Gyro-NS-CT_Drop(2) 8,456.70 11.73 193.45 7,841.09 7,712.09 -2,876.26 -623.75 2,541,679.54 262,716.87 5.37 2,520.34 2_Gyro-NS-CT_Drop(2) 8,518.67 10.01 177.08 7,901.96 7,772.96 -2,887.77 -624.94 2,541,668.06 262,715.45 5.67 2,530.85 2_Gyro-NS-CT_Drop(2) 8,581.38 8.57 159.45 7,963.86 7,834.86 -2,897.59 -623.02 2,541,658.20 262,717.17 5.06 2,540.76 2_Gyro-NS-CT_Drop(2) 8,644.09 6.87 137.44 8,026.02 7,897.02 -2,904.73 -618.84 2,541,650.98 262,721.20 5.39 2,548.87 2_Gyro-NS-CT_Drop(2) 10/29/2017 6:54:11PM Page 6 COMPASS 5000.1 Build 81D • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: k .gaGP 11-24RD WP08 Actual RKB @ 129.00usft r Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD Survey Calculation Method: #. Minimum Curvature Li i Design: GP 11-24RD Database: ''41 Sperry EDM-NORTH US+CANADA ::F. Survey - t MD Inc Azi TVD TVDSS +N/-S +E/-W Map Map Vertical Northing Easting DLS Section 1 (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,706.08 7.55 113.97 8,087.53 7,958.53 -2,909.12 -612.61 2,541,646.47 262,727.34 4.84 2,555.03 2_Gyro-NS-CT_Drop(2) 8,767.94 9.88 111.59 8,148.67 8,019.67 -2,912.72 -603.96 2,541,642.69 262,735.91 3.81 2,561.24 2_Gyro-NS-CT Drop(2) 8,829.89 12.09 109.74 8,209.48 8,080.48 -2,916.87 -592.91 2,541,638.32 262,746.88 3.61 2,568.73 2_Gyro-NS-CT_Drop(2) 8,892.62 13.43 103.24 8,270.66 8,141.66 -2,920.76 -579.64 2,541,634.16 262,760.07 3.13 2,576.70 2_Gyro-NS-CT_Drop(2) 8,954.42 14.38 101.33 8,330.65 8,201.65 -2,923.91 -565.13 2,541,630.72 262,774.51 1.71 2,584.37 2_Gyro-NS-CT_Drop(2) 9,016.24 14.21 104.48 8,390.56 8,261.56 -2,927.32 -550.25 2,541,627.01 262,789.31 1.29 2,592.40 2_Gyro-NS-CT_Drop(2) 9,078.09 13.98 105.21 8,450.55 8,321.55 -2,931.17 -535.69 2,541,622.86 262,803.79 0.47 2,600.76 2_Gyro-NS-CT_Drop(2) 9,140.75 13.53 103.61 8,511.41 8,382.41 -2,934.89 -521.26 2,541,618.86 262,818.14 0.94 2,608.93 2_Gyro-NS-CT_Drop(2) 9,202.64 13.36 105.41 8,571.61 8,442.61 -2,938.49 -507.33 2,541,614.97 262,831.99 0.73 2,616.85 2_Gyro-NS-CT_Drop(2) 9,264.63 12.96 110.00 8,631.97 8,502.97 -2,942.77 -493.90 2,541,610.42 262,845.34 1.80 2,625.24 2_Gyro-NS-CT_Drop(2) 9,326.44 14.79 110.29 8,691.97 8,562.97 -2,947.88 -479.98 2,541,605.03 262,859.15 2.96 2,634.57 2_Gyro-NS-CT_Drop(2) 9,389.16 15.04 109.28 8,752.58 8,623.58 -2,953.34 -464.79 2,541,599.26 262,874.22 0.58 2,644.65 2_Gyro-NS-CT_Drop(2) 9,451.87 15.05 108.32 8,813.14 8,684.14 -2,958.59 -449.38 2,541,593.70 262,889.52 0.40 2,654.59 2_Gyro-NS-CT_Drop(2) 9,514.49 15.19 110.95 8,873.59 8,744.59 -2,964.07 -434.00 2,541,587.90 262,904.79 1.12 2,664.76 2_Gyro-NS-CT_Drop(2) 9,576.36 17.40 116.10 8,932.98 8,803.98 -2,971.04 -418.12 2,541,580.61 262,920.52 4.26 2,676.48 2_Gyro-NS-CT_Drop(2) 9,638.23 19.73 118.75 8,991.62 8,862.62 -2,980.14 -400.66 2,541,571.16 262,937.80 4.00 2,690.74 2_Gyro-NS-CT_Drop(2) 9,700.20 22.94 119,29 9,049.34 8,920.34 -2,991.08 -380.95 2,541,559.82 262,957.28 5.19 2,707.46 2_Gyro-NS-CT_Drop(2) 9,762.07 25.08 120.95 9,105.85 8,976.85 -3,003.72 -359.19 2,541,546.74 262,978.78 3.63 2,726.46 2_Gyro-NS-CT_Drop(2) 9,823.91 26.01 119.62 9,161.65 9,032.65 -3,017.17 -336.16 2,541,532.83 263,001.53 1.77 2,746.62 2_Gyro-NS-CT_Drop(2) 9,885.81 28.90 120.47 9,216.57 9,087.57 -3,031.46 -311.46 2,541,518.04 263,025.93 4.71 2,768.13 2_Gyro-NS-CT_Drop(2) 9,948.41 31.84 120.86 9,270.58 9,141.58 -3,047.61 -284.24 2,541,501.35 263,052.81 4.71 2,792.21 2_Gyro-NS-CT_Drop(2) 10,010.21 33.93 119.47 9,322.47 9,193.47 -3,064.46 -255.23 2,541,483.91 263,081.48 3.60 2,817.53 2_Gyro-NS-CT_Drop(2) 10,074.68 36.55 120.13 9,375.12 9,246.12 -3,082.95 -222.96 2,541,464.77 263,113.37 4.11 2,845.46 2_MWD+AX+Sag(3) 10,136.10 38.96 118.19 9,423.68 9,294.68 -3,101.25 -190.11 2,541,445.80 263,145.83 4.37 2,873.39 2_MWD+AX+Sag(3) 10,198.80 39.83 118.07 9,472.13 9,343.13 -3,120.01 -155.02 2,541,426.33 263,180.54 1.39 2,902.49 2_MWD+AX+Sag(3) 10,260.12 42.54 118.65 9,518.28 9,389.28 -3,139.20 -119.49 2,541,406.43 263,215.66 4.46 2,932.13 2_MWD+AX+Sag(3) 10,321.50 45.63 119.38 9,562.36 9,433.36 -3,159.91 -82.16 2,541,384.96 263,252.57 5.10 2,963.80 2_MWD+AX+Sag(3) 10,385.21 48.10 119.18 9,605.92 9,476.92 -3,182.65 -41.61 2,541,361.41 263,292.65 3.88 2,998.42 2_MWD+AX+Sag(3) 10,446.81 50.40 121.37 9,646.13 9,517.13 -3,206.18 -1.32 2,541,337.06 263,332.45 4.60 3,033.71 2_MWD+AX+Sag(3) 10,507.55 52.55 122.09 9,683.96 9,554.96 -3,231.18 39.09 2,541,311.25 263,372.34 3.66 3,070.42 2_MWD+AX+Sag(3) 10,570.21 55.21 122.19 9,720.89 9,591.89 -3,258.10 81.94 2,541,283.46 263,414.64 4.25 3,109.75 2_MWD+AX+Sag(3) 10,631.96 58.18 123.40 9,754.80 9,625.80 -3,286.06 125.32 2,541,254.63 263,457.43 5.08 3,150.22 2_MWD+AX+Sag(3) 10,694.57 61.66 122.48 9,786.17 9,657.17 -3,315.51 170.78 2,541,224.27 263,502.29 5.70 3,192.79 2_MWD+AX+Sag(3) 10,700.00 62.05 122.64 9,788.74 9,659.74 -3,318.08 174.82 2,541,221.61 263,506.27 7.64 3,196.53 2_MWD+AX+Sag(4) 10,752.38 59.83 122.76 9,814.18 9,685.18 -3,342.82 213.34 2,541,196.10 263,544.28 4.24 3,232.38 2_MWD+AX+Sag(4) 10,814.15 61.17 123.23 9,844.59 9,715.59 -3,372.10 258.43 2,541,165.91 263,588.77 2.27 3,274.66 2_MWD+AX+Sag(4) 10,876.35 61.11 123.34 9,874.61 9,745.61 -3,401.99 303.97 2,541,135.10 263,633.69 0.18 3,317.67 2_MWD+AX+Sag(4) 10,938.26 61.38 124.32 9,904.40 9,775.40 -3,432.21 349.06 2,541,103.98 263,678.15 1.45 3,360.84 2_MWD+AX+Sag(4) 11,000.92 61.35 123.36 9,934.43 9,805.43 -3,462.83 394.73 2,541,072.43 263,723.19 1.35 3,404.58 2_MWD+AX+Sag(4) 11,062.18 61.46 124.22 9,963.75 9,834.75 -3,492.75 439.44 2,541,041.61 263,767.28 1.25 3,447.34 2_MWD+AX+Sag(4) 10/29/2017 6:54:11PM Page 7 COMPASS 5000.1 Build 81D I 0 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD Survey Calculation Method: Minimum Curvature Design: GP 11-24RD Database: o: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (a) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,123.05 62.71 125.74 9,992.25 9,863.25 -3,523.58 483.50 2,541,009.89 263,810.70 3.01 3,490.76 2_MWD+AX+Sag(4) 11,183.32 63.68 126.02 10,019.42 9,890.42 -3,555.11 527.09 2,540,977.48 263,853.64 1.66 3,534.68 2_MWD+AX+Sag(4) 11,218.82 63.77 127.71 10,035.14 9,906.14 -3,574.21 552.55 2,540,957.88 263,878.71 4.28 3,560.98 2_MWD+AX+Sag(4) 11,280.51 63.33 128.96 10,062.62 9,933.62 -3,608.47 595.88 2,540,922.75 263,921.33 1.95 3,607.40 2_MWD+AX+Sag(4) 11,342.70 64.58 130.15 10,089.92 9,960.92 -3,644.05 638.95 2,540,886.30 263,963.67 2.64 3,655.00 2_MWD+AX+Sag(4) 11,405.04 64.94 130.15 10,116.51 9,987.51 -3,680.41 682.05 2,540,849.07 264,006.02 0.58 3,703.33 2_MWD+AX+Sag(4) 11,466.27 67.29 131.09 10,141.30 10,012.30 -3,716.86 724.54 2,540,811.77 264,047.76 4.09 3,751.56 2_MWD+AX+Sag(4) 11,528.36 67.35 132.47 10,165.24 10,036.24 -3,755.03 767.26 2,540,772.74 264,089.70 2.05 3,801.49 2_MWD+AX+Sag(4) 11,590.36 68.03 134.14 10,188.78 10,059.78 -3,794.37 809.00 2,540,732.56 264,130.62 2.72 3,852.20 2_MWD+AX+Sag(4) /.�c) 11,651.90 68.14 133.00 10,211.75 10,082.75 -3,833.72 850.36 2,540,692.38 264,171.18 1.73 3,902.81 2_MWD+AX+Sag(4) ` 11,715.47 71.00 132.81 10,233.93 10,104.93 -3,874.27 894.00 2,540,650.96 264,213.98 4.51 3,955.29 2_MWD+AX+Sag(4) /144)-- 11,778.33 74.96 133.13 10,252.33 10,123.33 -3,915.23 937.97 2,540,609.11 264,257.10 6.32 4,008.26 2_MWD+AX+Sag(4) 11,839.03 75.76 132.77 10,267.67 10,138.67 -3,955.24 980.95 2,540,568.23 264,299.27 1.44 4,060.02 2_MWD+AX+Sag(4) 11,899.93 76.59 132.75 10,282.22 10,153.22 -3,995.39 1,024.37 2,540,527.21 264,341.86 1.36 4,112.05 2_MWD+AX+Sag(4) 11,964.07 75.16 133.20 10,297.88 10,168.88 -4,037.79 1,069.88 2,540,483.90 264,386.49 2.33 4,166.88 2_MWD+AX+Sag(4) 12,025.54 75.03 133.01 10,313.69 10,184.69 -4,078.38 1,113.25 2,540,442.43 264,429.03 0.37 4,219.31 2_MWD+AX+Sag(4) 12,085.01 74.92 132.99 10,329.10 10,200.10 -4,117.56 1,155.25 2,540,402.42 264,470.23 0.19 4,269.95 2_MWD+AX+Sag(4) 12,146.64 77.11 134.42 10,344.00 10,215.00 -4,158.87 1,198.48 2,540,360.23 264,512.61 4.21 4,323.02 2_MWD+AX+Sag(4) 12,208.32 77.85 135.10 10,357.37 10,228.37 -4,201.27 1,241.23 2,540,316.97 264,554.49 1.61 4,376.97 2_MWD+AX+Sag(4) 12,272.37 76.83 134.05 10,371.41 10,242.41 -4,245.13 1,285.75 2,540,272.22 264,598.10 2.26 4,432.86 2_MWD+AX+Sag(4) 12,334.43 74.78 133.50 10,386.63 10,257.63 -4,286.76 1,329.19 2,540,229.73 264,640.68 3.41 4,486.28 2_MWD+AX+Sag(4) 12,397.06 73.03 132.37 10,403.99 10,274.99 -4,327.74 1,373.24 2,540,187.85 264,683.89 3.29 4,539.31 2_MWD+AX+Sag(4) 12,460.04 71.36 132.34 10,423.25 10,294.25 -4,368.14 1,417.55 2,540,146.57 264,727.37 2.65 4,591.86 2_MWD+AX+Sag(4) 12,522.14 69.70 132.54 10,443.94 10,314.94 -4,407.65 1,460.76 2,540,106.19 264,769.77 2.69 4,643.21 2_MWD+AX+Sag(4) 12,585.12 69.48 130.98 10,465.91 10,336.91 -4,446.96 1,504.78 2,540,065.99 264,812.98 2.35 4,694.64 2_MWD+AX+Sag(4) 12,613.00 69.48 130.98 10,475.68 10,346.68 -4,464.08 1,524.50 2,540,048.47 264,832.34 0.00 4,717.22 PROJECTED to TD mitchell.laird@halliburton.com Checked By: 2017.10.3013:0.12-08.00' Approved By: Michael Calkins Date: 1 0/29/1 7 10/29/2017 6:54:11PM Page 8 COMPASS 5000.1 Build 81D • Hilcorp Energy Company III CASING&CEMENTING REPORT Lease&Well No. GPF GP 11-24RD Date Run 25-Oct-17 County State Alaska Supv. M Rogers/Lawrence/Montague CASING RECORD Liner V TD 12,613.00 Shoe Depth: 12,611.00 PBTD: 12,483' No.Jts.Delivered 142 No.Jts.Run 120 No.Jts.Returned 22 Ftg.Delivered 5,706.39 Ftg.Run 4,822.89 Ftg.Returned 883.50 Length Measurements W/0 Threads Ftg.Cut Jt. Ftg.Balance RKB RKB to BHF 59.65 RKB to CHF RKB to THF 129.00 Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Float shoe 7 5/8 DWC 2.06 12,611.00 12,608.94 2 Liner 7 26.0 L-80 DWC 80.07 12,608.94 12,528.87 Float collar 7 5/8 DWC 1.29 12,528.87 12,527.58 1 Casing 7 26.0 L-80 DWC 40.51 12,527.58 12,487.07 Landing Collar 7 5/8 DWC 3.39 12,487.07 12,483.68 117 Casing 7 26.0 L-80 DWC 4,702.31 12,483.68 7,781.37 Liner Hanger 8 5/8 DWC 25.22 7,781.37 7,756.15 Csg Wt.On Hook: 190,000 Type Float Collar: No.Hrs to Run: 38.5 Csg Wt.On Slips: Type of Shoe: Bull nose Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg X Yes No 60 Ft.Min. 9.1 PPG Fluid Description: OBM 9.1 PPG Liner hanger Info(Make/Model): Baker SDD Liner Hanger Liner top Packer?: X Yes _No Liner hanger test pressure: Floats Held _Yes X No Centralizer Placement: 1 per joint starting on joint 5(12,402')to 65(9993') CEMENTING REPORT Shoe @ 12611 FC @ 12,483.00 Top of Liner 7756 Preflush(Spacer) Type: Mud Push Density(ppg) 12 Volume pumped(BBLs) 20 Lead Slurry Type: Class G'EasyBlock' Sacks: 586 Yield: 1.36 Density(ppg) 15.3 Volume pumped(BBLs) 142 Mixing/Pumping Rate(bpm): 4.5 Tail Slurry w Type: Sacks: Yield: Q Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): (i' Post Flush(Spacer) 1- re Type: Density(ppg) Rate(bpm): Volume: LL Displacement: Type: OBM Density(ppg) 9.1 Rate(bpm): 5 Volume(actual/calculated): 286/283.5 FCP(psi): 3200 Pump used for disp: Kuukpik Rig 5 Bump Plug? Yes X No Bump press Casing Rotated? Yes X No Reciprocated? X Yes No %Returns during job 95 Cement returns to surface? Yes X No Spacer returns?_Yes X No Vol to Surf: 0 Cement In Place At: 2:02 Date: 10/27/2017 Estimated TOC: 9,912 Method Used To Determine TOC: CBL-Engineer Analysis 664,17 IjL:✓1N Ad- I0e*.`.. 1-t- C 6'4- St4,91;-4 .'4.-1i C, rj 752Y 73" v. Post Job Calculations: ✓ , /2.2.?- ,7 Calculated Cmt Vol @ 0%excess: 101 Total Volume cmt Pumped: 142 Cmt returned to surface: 0 Calculated cement left in wellbore: 142 OH volume Calculated: 101 OH volume actual: Actual%Washout: www.wellez.net WellEz Information Management LLC ver_102716bf • • Hilcorp Alaska, LLC Granite Point Granite Point Platform GP 11-24RD PB1 507332004671 Sperry Drilling Definitive Survey Report 29 October, 2017 F. 8s 3tr' kkyyr I V"rvr C". • it. HALILIBURTON ■ m, Sperry Drilling • Halliburton • Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD PB1 Survey Calculation Method: Minimum Curvature Design: GP 11-24RD PB1 Database: Sperry EDM-NORTH US+CANADA Project Granite 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 GP-11-24RD,Leg3 Slot8 Well Position +N/-S 0.00 usft Northing: 2,544,542.44 usft Latitude: 60°57'29.235 N +E/-W 0.00 usft Easting: 263,398.89 usft Longitude: 151°19'52.405 W Position Uncertainty 0.00 usft Wellhead Elevation: 129.00 usft Water Depth: 75.00 usft Wellbore GP 11-24RD PB1 Magnetics Model Name Sample Date Declination Field Strength (*) e, (nT) BGGM2017 9/20/2017 16.06 73.84 55,441 Design GP 11-24RD PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,961.89 Vertical Section: Depth From(TVD) +N/-S ' +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 169.94 Survey Program Date 10/29/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 208.00 7,961.89 GP 11-24RD Drop Gyro(GP-11-24 PB1) 2_Gyro-NS-CT_Drop H038Ga:Continuous dropped into a drill collar 10/24/2017 8,007.00 10,010.21 GP 11-24RD Gyro(GP 11-24RD PB1) 2_Gyro-NS-CT_Drop H038Ga:Continuous dropped into a drill collar 10/24/2017 10,074.68 11,245.22 GP 11-24RD PB1 MWD+AX+sag(GP 11 2_MWD+AX+Sag A004Mb/ISC4:BGGM dec&axial+sag corr. 10/03/2017 Survey 6`- - T), Map Map Vertical 63f MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section . (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) SUvey Tool Name 0.00 0.00 0.00 0.00 -129.00 0.00 0.00 2,544,542.44 263,398.89 0.00 0.00 UNDEFINED 208.00 0.46 257.39 208.00 79.00 -0.18 -0.81 2,544,542.28 263,398.07 0.22 0.04 2_Gyro-NS-CT_Drop(1) 238.89 0.77 256.25 238.89 109.89 -0.26 -1.14 2,544,542.21 263,397.75 1.00 0.06 2_Gyro-NS-CT_Drop(1) 269.82 0.92 250.70 269.81 140.81 -0.39 -1.57 2,544,542.08 263,397.31 0.55 0.11 2_Gyro-NS-CT_Drop(1) 300.89 1.09 238.94 300.88 171.88 -0.63 -2.06 2,544,541.86 263,396.82 0.86 0.26 2_Gyro-NS-CT_Drop(1) 331.55 1.64 237.78 331.53 202.53 -1.01 -2.68 2,544,541.49 263,396.19 1.80 0.53 2_Gyro-NS-CT_Drop(1) 362.46 2.90 246.02 362.41 233.41 -1.56 -3.77 2,544,540.95 263,395 09 4.20 0.88 2_Gyro-NS-CT_Drop(1) 393.36 4.07 247.45 393.26 264.26 -2.30 -5.50 2,544,540.25 263,393.35 3.80 1.31 2_Gyro-NS-CT_Drop(1) 424.31 4.80 245.79 424.11 295.11 -3.25 -7.69 2,544,539.34 263,391.13 2.39 1.86 2_Gyro-NS-CT_Drop(1) 455.25 5.25 243.10 454.93 325.93 -4.42 -10.14 2,544,538.22 263,388.67 1.64 2.59 2_Gyro-NS-CT_Drop(1) 486.11 5.47 242.21 485.66 356.66 -5.75 -12.70 2,544,536.95 263,386.08 0.76 3.44 2_Gyro-NS-CT_Drop(1) 517.01 5.49 242.13 516.42 387.42 -7.13 -15.31 2,544,535.63 263,383.44 0.07 4.34 2_Gyro-NS-CT_Drop(1) 10/29/2017 6:52:04PM Page 2 COMPASS 5000.1 Build 81D • Halliburton • Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD PB1 Survey Calculation Method: Minimum Curvature Design: GP 11-24RD PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map f Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 547.93 5.41 242.27 547.20 418.20 -8.50 -17.90 2,544,534.31 263,380.82 0.26 5.24 2_Gyro-NS-CT_Drop(1) 579.53 5.43 242.29 578.66 449.66 -9.89 -20.55 2,544,532.98 263,378.15 0.06 6.14 2_Gyro-NS-CT_Drop(1) 610.46 5.34 243.31 609.45 480.45 -11.21 -23.13 2,544,531.70 263,375.54 0.42 7.00 2_Gyro-NS-CT_Drop(1) 641.35 5.24 243.49 640.21 511.21 -12.49 -25.68 2,544,530.48 263,372.97 0.33 7.81 2_Gyro-NS-CT_Drop(1) 672.28 5.11 244.29 671.01 542.01 -13.72 -28.18 2,544,529.30 263,370.44 0.48 8.58 2_Gyro-NS-CT_Drop(1) 703.20 4.93 244.32 701.81 572.81 -14.89 -30.62 2,544,528.18 263,367.98 0.58 9.31 2_Gyro-NS-CT_Drop(1) 734.14 4.75 24.4.12 732.64 603.64 -16.02 -32.97 2,544,527.09 263,365.61 0.58 10.02 2_Gyro-NS-CT_Drop(1) 765.10 4.53 244.33 763.50 634.50 -17.11 -35.22 2,544,526.05 263,363.33 0.71 10.70 2_Gyro-NS-CT_Drop(1) 795.92 4.46 245.06 794.23 665.23 -18.15 -37.41 2,544,525.06 263,361.12 0.29 11.33 2_Gyro-NS-CT_Drop(1) 826.86 4.30 245.34 825.08 696.08 -19.14 -39.55 2,544,524.11 263,358.96 0.52 11.93 2_Gyro-NS-CT_Drop(1) 857.69 4.04 243.04 855.83 726.83 -20.11 -41.57 2,544,523.18 263,356.92 1.00 12.54 2_Gyro-NS-CT_Drop(1) 888.65 3.59 236.64 886.72 757.72 -21.14 -43.35 2,544,522.19 263,355.12 2.00 13.24 2_Gyro-NS-CT_Drop(1) 919.53 3.32 222.98 917.54 788.54 -22.32 -44.77 2,544,521.03 263,353.68 2.80 14.16 2_Gyro-NS-CT_Drop(1) 950.45 3.30 204.13 948.41 819.41 -23.79 -45.74 2,544,519.58 263,352.68 3.50 15.43 2_Gyro-NS-CT_Drop(1) 981.34 3.80 185.45 979.24 850.24 -25.62 -46.20 2,544,517.76 263,352.18 4.06 17.16 2_Gyro-NS-CT_Drop(1) 1,012.22 4.80 173.12 1,010.04 881.04 -27.92 -46.15 2,544,515.46 263,352.19 4.39 19.43 2_Gyro-NS-CT_Drop(1) 1,043.15 5.99 167.94 1,040.83 911.83 -30.79 -45.66 2,544,512.59 263,352.62 4.15 22.34 2_Gyro-NS-CT_Drop(1) 1,074.05 7.28 165.31 1,071.52 942.52 -34.26 -44.82 2,544,509.10 263,353.39 4.29 25.90 2_Gyro-NS-CT_Drop(1) 1,105.75 8.50 166.25 1,102.92 973.92 -38.48 -43.76 2,544,504.86 263,354.37 3.87 30.24 2_Gyro-NS-CT_Drop(1) 1,136.67 9.71 166.24 1,133.45 1,004.45 -43.23 -42.59 2,544,500.09 263,355.43 3.91 35.12 2_Gyro-NS-CT_Drop(1) 1,167.54 10.82 171.94 1,163.83 1,034.83 -48.63 -41.57 2,544,494.67 263,356.35 4.87 40.62 2_Gyro-NS-CT_Drop(1) 1,199.17 11.94 174.48 1,194.83 1,065.83 -54.82 -40.84 2,544,488.46 263,356.95 3.88 46.85 2_Gyro-NS-CT_Drop(1) 1,230.08 12.89 178.25 1,225.02 1,096.02 -61.45 -40.42 2,544,481.83 263,357.23 4.04 53.44 2_Gyro-NS-CT_Drop(1) 1,260.91 13.87 180.94 1,255.02 1,126.02 -68.58 -40.38 2,544,474.69 263,357.13 3.76 60.48 2_Gyro-NS-CT_Drop(1) 1,291.79 14.98 182.71 1,284.92 1,155.92 -76.27 -40.63 2,544,467.01 263,356.72 3.87 68.00 2_Gyro-NS-CT_Drop(1) 1,322.72 16.10 184.66 1,314.72 1,185.72 -84.54 -41.17 2,544,458.76 263,356.02 4.00 76.05 2_Gyro-NS-CT_Drop(1) 1,353.58 17.40 184.94 1,344.27 1,215.27 -93.40 -41.91 2,544,449.91 263,355.09 4.22 84.64 2_Gyro-NS-CT_Drop(1) 1,384.46 18.64 185.61 1,373.64 1,244.64 -102.91 -42.79 2,544,440.42 263,354.02 4.07 93.86 2_Gyro-NS-CT_Drop(1) 1,415.39 19.97 186.69 1,402.83 1,273.83 -113.08 -43.89 2,544,430.28 263,352.72 4.45 103.67 2_Gyro-NS-CT_Drop(1) 1,446.34 19.96 186.94 1,431.92 1,302.92 -123.57 -45.14 2,544,419.82 263,351.25 0.28 113.78 2_Gyro-NS-CT_Drop(1) 1,477.26 22.41 187.83 1,460.74 1,331.74 -134.65 -46.58 2,544,408.77 263,349.58 7.99 124.44 2_Gyro-NS-CT_Drop(1) 1,508.20 22.41 187.85 1,489.35 1,360.35 -146.34 -48.19 2,544,397.12 263,347.74 0.02 135.67 2_Gyro-NS-CT_Drop(1) 1,539.13 23.80 187.80 1,517.80 1,388.80 -158.36 -49.84 2,544,385.13 263,345.84 4.49 147.22 2_Gyro-NS-CT_Drop(1) 1,570.05 24.94 188.49 1,545.96 1,416.96 -170.99 -51.65 2,544,372.54 263,343.78 3.80 159.34 2_Gyro-NS-CT_Drop(1) 1,600.99 25.71 188.81 1,573.93 1,444.93 -184.07 -53.65 2,544,359.50 263,341.52 2.53 171.87 2_Gyro-NS-CT_Drop(1) 1,631.86 26.04 189.11 1,601.70 1,472.70 -197.38 -55.74 2,544,346.24 263,339.15 1.15 184.61 2_Gyro-NS-CT_Drop(1) 1,662.78 26.32 189.04 1,629.45 1,500.45 -210.85 -57.90 2,544,332.82 263,336.73 0.91 197.49 2_Gyro-NS-CT_Drop(1) 1,693.71 26.44 189.18 1,657.16 1,528.16 -224.42 -60.07 2,544,319.29 263,334.28 0.44 210.48 2_Gyro-NS-CT_Drop(1) 1,724.57 26.33 189.02 1,684.80 1,555.80 -237.96 -62.24 2,544,305.80 263,331.83 0.42 223.43 2_Gyro-NS-CT_Drop(1) 1,755.57 26.48 189.19 1,712.57 1,583.57 -251.58 -64.42 2,544,292.24 263,329.38 0.54 236.45 2_Gyro-NS-CT_Drop(1) 10/29/2017 6:52:04PM Page 3 COMPASS 5000.1 Build 810 • Halliburton • Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD PB1 Survey Calculation Method: Minimum Curvature Design: GP 11-24RD PB1 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) 1;; (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 1,787.26 26.51 189.36 1,740.93 1,611.93 -265.53 -66.70 2,544,278.33 263,326.81 0.26 249.79 2_Gyro-NS-CT_Drop(1) 1,818.23 26.61 189.10 1,768.63 1,639.63 -279.20 -68.92 2,544,264.71 263,324.32 0.50 262.86 2_Gyro-NS-CT_Drop(1) 1,849.91 26.64 188.87 1,796.95 1,667.95 -293.22 -71.14 2,544,250.74 263,321.81 0.34 276.28 2_Gyro-NS-CT_Drop(1) 1,880.85 26.53 188.52 1,824.62 1,695.62 -306.91 -73.23 2,544,237.10 263,319.44 0.62 289.39 2_Gyro-NS-CT_Drop(1) 1,911.78 26.62 188.60 1,852.28 1,723.28 -320.59 -75.29 2,544,223.46 263,317.11 0.31 302.51 2_Gyro-NS-CT_Drop(1) 1,942.72 26.71 188.53 1,879.93 1,750.93 -334.32 -77.36 2,544,209.77 263,314.76 0.31 315.66 2_Gyro-NS-CT_Drop(1) 1,973.61 26.81 188.31 1,907.52 1,778.52 -348.08 -79.40 2,544,196.06 263,312.45 0.46 328.85 2_Gyro-NS-CT_Drop(1) 2,004.52 26.71 188.07 1,935.12 1,806.12 -361.85 -81.38 2,544,182.33 263,310.18 0.48 342.07 2_Gyro-NS-CT Drop(1) 2,035.40 26.64 187.78 1,962.71 1,833.71 -375.58 -83.29 2,544,168.64 263,307.99 0.48 355.26 2_Gyro-NS-CT_Drop(1) 2,066.27 26.59 187.68 1,990.31 1,861.31 -389.29 -85.15 2,544,154.98 263,305.86 0.22 368.43 2_Gyro-NS-CT_Drop(1) 2,097.17 26.51 187.20 2,017.95 1,888.95 -402.98 -86.94 2,544,141.32 263,303.79 0.74 381.60 2 Gyro-NS-CT_Drop(1) 2,128.14 26.27 187.40 2,045.69 1,916.69 -416.64 -88.69 2,544,127.71 263,301.76 0.83 394.74 2_Gyro-NS-CT_Drop(1) 2,159.14 26.02 186.96 2,073.52 1,944.52 -430.19 -90.40 2,544,114.19 263,299.78 1.02 407.78 2_Gyro-NS-CT_Drop(1) 2,190.15 25.84 187.00 2,101.41 1,972.41 -443.65 -92.04 2,544,100.77 263,297.86 0.58 420.75 2_Gyro-NS-CT_Drop(1) 2,252.10 25.59 186.36 2,157.22 2,028.22 -470.35 -95.17 2,544,074.14 263,294.19 0.60 446.49 2_Gyro-NS-CT_Drop(1) 2,314.02 25.06 185.65 2,213.19 2,084.19 -496.69 -97.94 2,544,047.86 263,290.88 0.99 471.94 2_Gyro-NS-CT_Drop(1) 2,376.02 25.13 185.49 2,269.34 2,140.34 -522.86 -100.50 2,544,021.75 263,287.80 0.16 497.26 2_Gyro-NS-CT_Drop(1) 2,438.47 24.85 185.17 2,325.94 2,196.94 -549.13 -102.95 2,543,995.54 263,284.82 0.50 522.70 2_Gyro-NS-CT_Drop(1) 2,500.37 24.65 185.04 2,382.16 2,253.16 -574.94 -105.25 2,543,969.78 263,281.99 0.33 547.71 2_Gyro-NS-CT_Drop(1) 2,562.21 24.20 184.73 2,438.46 2,309.46 -600.42 -107.43 2,543,944.35 263,279.29 0.76 572.41 2_Gyro-NS-CT_Drop(1) 2,624.18 23.88 185.02 2,495.06 2,366.06 -625.57 -109.58 2,543,919.25 263,276.64 0.55 596.81 2_Gyro-NS-CT_Drop(1) 2,686.03 23.32 184.89 2,551.73 2,422.73 -650.24 -111.71 2,543,894.63 263,274.00 0.91 620.72 2_Gyro-NS-CT_Drop(1) 2,748.00 23.06 184.58 2,608.70 2,479.70 -674.56 -113.73 2,543,870.36 263,271.49 0.46 644.32 2_Gyro-NS-CT_Drop(1) 2,811.31 23.07 184.41 2,666.95 2,537.95 -699.29 -115.67 2,543,845.68 263,269.04 0.11 668.32 2_Gyro-NS-CT_Drop(1) 2,873.18 23.05 184.43 2,723.87 2,594.87 -723.45 -117.54 2,543,821.56 263,266.69 0.03 691.79 2_Gyro-NS-CT_Drop(1) 2,935.13 23.04 184.46 2,780.88 2,651.88 -747.62 -119.42 2,543,797.42 263,264.31 0.02 715.26 2_Gyro-NS-CT_Drop(1) 2,997.02 22.83 184.58 2,837.88 2,708.88 -771.67 -121.32 2,543,773.43 263,261.93 0.35 738.61 2_Gyro-NS-CT_Drop(1) 3,058.88 22.56 185.37 2,894.95 2,765.95 -795.44 -123.39 2543,749.70 263,259.38 0.66 761.65 2_Gyro-NS-CT_Drop(1) 3,120.72 22.45 185.06 2,952.08 2,823.08 -819.02 -125.54 2,543,726.17 263,256.75 0.26 784.49 2_Gyro-NS-CT_Drop(1) 3,182.68 22.23 185.63 3,009.39 2,880.39 -842.46 -127.73 2,543,702.78 263,254.08 0.50 807.19 2_Gyro-NS-CT_Drop(1) 3,245.36 22.17 185.45 3,067.42 2,938.42 -866.04 -130.02 2,543,679.25 263,251.31 0.14 830.00 2_Gyro-NS-CT_Drop(1) 3,307.93 21.84 185.96 3,125.43 2,996.43 -889.37 -132.35 2,543,655.98 263,248.51 0.61 852.57 2_Gyro-NS-CT_Drop(1) 3,369.89 21.57 185.97 3,183.00 3,054.00 -912.16 -134.73 2,543,633.24 263,245.67 0.44 874.59 2_Gyro-NS-CT_Drop(1) 3,431.89 21.39 185.64 3,240.69 3,111.69 -934.74 -137.03 2,543,610.71 263,242.91 0.35 896.43 2_Gyro-NS-CT_Drop(1) 3,493.66 21.06 185.75 3,298.27 3,169.27 -956.99 -139.25 2,543,588.51 263,240.24 0.54 917.95 2_Gyro-NS-CT_Drop(1) 3,555.63 21.20 185.25 3,356.08 3,227.08 -979.23 -141.39 2,543,566.32 263,237.65 0.37 939.47 2_Gyro-NS-CT_Drop(1) 3,617.48 21.55 185.38 3,413.67 3,284.67 -1,001.68 -143.48 2,543,543.92 263,235.10 0.57 961.21 2_Gyro-NS-CT_Drop(1) 3,679.37 21.54 185.87 3,471.24 3,342.24 -1,024.29 -145.70 2,543,521.35 263,232.42 0.29 983.09 2_Gyro-NS-CT_Drop(1) 3,741.32 21.71 186.10 3,528.83 3,399.83 -1,047.00 -148.08 2,543,498.70 263,229.58 0.31 1,005.03 2_Gyro-NS-CT_Drop(1) 3,803.17 21.81 186.20 3,586.27 3,457.27 -1,069.80 -150.54 2,543,475.96 263,226.66 0.17 1,027.05 2_Gyro-NS-CT_Drop(1) 10/29/2017 6:52:04PM Page 4 COMPASS 5000.1 Build 81D . Halliburton • Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD PB1 Survey Calculation Method: Minimum Curvature Design: GP 11-24RD PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS li +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) ,, (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,865.11 22.17 186.38 3,643.70 3,514.70 -1,092.85 -153.08 2,543,452.96 263,223.65 0.59 1,049.30 2_Gyro-NS-CT_Drop(1) 3,926.88 22.53 186.74 3,700.83 3,571.83 -1,116.19 -155.77 2,543,429.69 263,220.49 0.62 1,071.81 2_Gyro-NS-CT_Drop(1) 3,989.45 22.32 186.84 3,758.67 3,629.67 -1,139.89 -158.59 2,543,406.05 263,217.19 0.34 1,094.65 2_Gyro-NS-CT_Drop(1) 4,051.33 21.30 186.33 3,816.12 3,687.12 -1,162.72 -161.23 2,543,383.27 263,214.09 1.68 1,116.68 2_Gyro-NS-CT_Drop(1) 4,113.21 22.20 186.91 3,873.60 3,744.60 -1,185.50 -163.87 2,543,360.56 263,210.98 1.50 1,138.64 2_Gyro-NS-CT_Drop(1) 4,175.93 23.10 187.23 3,931.48 3,802.48 -1,209.47 -166.85 2,543,336.65 263,207.52 1.45 1,161.72 2_Gyro-NS-CT_Drop(1) 4,238.65 23.85 187.36 3,989.01 3,860.01 -1,234.25 -170.02 2,543,311.94 263,203.84 1.20 1,185.57 2_Gyro-NS-CT_Drop(1) 4,301.87 24.54 187.38 4,046.67 3,917.67 -1,259.95 -173.34 2,543,286.32 263,200.00 1.09 1,210.29 2_Gyro-NS-CT_Drop(1) 4,363.68 25.38 187.44 4,102.71 3,973.71 -1,285.81 -176.71 2,543,260.53 263,196.11 1.36 1,235.17 2_Gyro-NS-CT_Drop(1) 4,425.45 25.83 188.45 4,158.41 4,029.41 -1,312.25 -180.40 2,543,234.17 263,191.88 1.01 1,260.55 2_Gyro-NS-CT_Drop(1) 4,487.38 25.64 188.20 4,214.20 4,085.20 -1,338.86 -184.29 2,543,207.65 263,187.45 0.35 1,286.07 2_Gyro-NS-CT_Drop(1) 4,549.15 25.89 187.89 4,269.83 4,140.83 -1,365.44 -188.05 2,543,181.15 263,183.15 0.46 1,311.59 2_Gyro-NS-CT_Drop(1) 4,611.07 25.19 188.49 4,325.70 4,196.70 -1,391.87 -191.85 2,543,154.81 263,178.82 1.21 1,336.95 2_Gyro-NS-CT_Drop(1) 4,673.05 25.41 188.56 4,381.73 4,252.73 -1,418.06 -195.78 2,543,128.70 263,174.36 0.36 1,362.05 2_Gyro-NS-CT_Drop(1) 4,734.90 25.91 188.72 4,437.48 4,308.48 -1,444.54 -199.80 2,543,102.31 263,169.80 0.82 1,387.42 2_Gyro-NS-CT_Drop(1) 4,796.76 26.16 188.82 4,493.07 4,364.07 -1,471.38 -203.94 2,543,075.56 263,165.11 0.41 1,413.12 2_Gyro-NS-CT_Drop(1) 4,858.59 25.56 189.12 4,548.71 4,419.71 -1,498.01 -208.15 2,543,049.02 263,160.37 0.99 1,438.61 2_Gyro-NS-CT_Drop(1) 4,920.49 25.88 189.57 4,604.47 4,475.47 -1,524.52 -212.51 2,543,022.61 263,155.47 0.61 1,463.95 2_Gyro-NS-CT_Drop(1) 4,982.38 25.87 190.01 4,660.16 4,531.16 -1,551.14 -217.10 2,542,996.09 263,150.34 0.31 1,489.35 2_Gyro-NS-CT_Drop(1) 5,044.15 25.46 189.66 4,715.83 4,586.83 -1,577.50 -221.67 2,542,969.83 263,145.23 0.71 1,514.51 2_Gyro-NS-CT_Drop(1) 5,106.00 26.06 189.79 4,771.54 4,642.54 -1,603.99 -226.21 2,542,943.44 263,140.15 0.97 1,539.80 2_Gyro-NS-CT_Drop(1) 5,167.85 25.00 190.02 4,827.35 4,698.35 -1,630.25 -230.80 2,542,917.28 263,135.04 1.72 1,564.86 2_Gyro-NS-CT_Drop(1) 5,229.54 25.52 190.38 4,883.14 4,754.14 -1,656.16 -235.46 2,542,891.47 263,129.85 0.88 1,589.55 2_Gyro-NS-CT_Drop(1) 5,291.37 25.01 191.30 4,939.05 4,810.05 -1,682.07 -240.42 2,542,865.66 263,124.36 1.04 1,614.20 2_Gyro-NS-CT_Drop(1) 5,353.31 25.67 191.38 4,995.03 4,866.03 -1,708.07 -245.63 2,542,839.78 263,118.62 1.07 1,638.89 2_Gyro-NS-CT_Drop(1) 5,415.24 24.73 191.52 5,051.07 4,922.07 -1,733.91 -250.87 2,542,814.05 263,112.87 1.52 1,663.42 2_Gyro-NS-CT_Drop(1) 5,477.09 25.01 191.87 5,107.18 4,978.18 -1,759.38 -256.14 2,542,788.69 263,107.08 0.51 1,687.58 2_Gyro-NS-CT_Drop(1) 5,538.94 25.14 192.32 5,163.20 5,034.20 -1,785.01 -261.63 2,542,763.18 263,101.07 0.37 1,711.85 2_Gyro-NS-CT_Drop(1) 5,600.88 24.53 192.51 5,219.42 5,090.42 -1,810.42 -267.22 2,542,737.89 263,094.96 0.99 1,735.89 2_Gyro-NS-CT_Drop(1) 5,662.81 24.81 191.66 5,275.69 5,146.69 -1,835.69 -272.63 2,542,712.73 263,089.04 0.73 1,759.83 2_Gyro-NS-CT_Drop(1) 5,724.70 24.47 192.72 5,331.95 5,202.95 -1,860.91 -278.08 2,542,687.63 263,083.08 0.90 1,783.72 2Gyro-NS-CT_Drop(1) 5,786.57 24.15 192.75 5,388.33 5,259.33 -1,885.76 -283.70 2,542,662.90 263,076.96 0.52 1,807.20 2_Gyro-NS-CT_Drop(1) 5,848.15 24.71 192.26 5,444.40 5,315.40 -1,910.62 -289.21 2,542,638.16 263,070.94 0.97 1,830.71 2_Gyro-NS-CT_Drop(1) 5,910.01 24.24 192.84 5,500.70 5,371.70 -1,935.64 -294.78 2,542,613.26 263,064.87 0.85 1,854.37 2_Gyro-NS-CT_Drop(1) 5,971.93 24.16 193.02 5,557.18 5,428.18 -1,960.38 -300.46 2,542,588.64 263,058.69 0.18 1,877.74 2_Gyro-NS-CT_Drop(1) 6,033.91 23.09 192.82 5,613.96 5,484.96 -1,984.59 -306.01 2,542,564.55 263,052.64 1.73 1,900.61 2_Gyro-NS-CT_Drop(1) 6,095.74 23.91 193.15 5,670.66 5,541.66 -2,008.61 -311.55 2,542,540.65 263,046.62 1.34 1,923.29 2_Gyro-NS-CT_Drop(1) 6,158.43 23.36 193.80 5,728.10 5,599.10 -2,033.05 -317.41 2,542,516.33 263,040.27 0.97 1,946.33 2_Gyro-NS-CT_Drop(1) 6,220.47 23.16 193.98 5,785.09 5,656.09 -2,056.83 -323.29 2,542,492.67 263,033.90 0.34 1,968.72 2_Gyro-NS-CT_Drop(1) 6,282.30 23.44 194.54 5,841.88 5,712.88 -2,080.54 -329.31 2,542,469.10 263,027.40 0.58 1,991.01 2_Gyro-NS-CT_Drop(1) 10/29/2017 6:52:04PM Page 5 COMPASS 5000.1 Build 81D . Halliburton 111 Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD PB1 Survey Calculation Method: Minimum Curvature Design: GP 11-24RD PB1 Database: Sperry EDM-NORTH US+CANADA 1 Survey I 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 6,344.93 23.23 194.65 5,899.39 5,770.39 -2,104.54 -335.56 2,542,445.22 263,020.66 0.34 2,013.56 2_Gyro-NS-CT_Drop(1) 6,407.71 22.88 194.81 5,957.15 5,828.15 -2,128.32 -341.82 2,542,421.58 263,013.93 0.57 2,035.88 2_Gyro-NS-CT_Drop(1) 6,469.65 22.89 195.25 6,014.22 5,885.22 -2,151.59 -348.06 2,542,398.45 263,007.21 0.28 2,057.69 2_Gyro-NS-CT_Drop(1) 6,532.42 22.63 195.78 6,072.10 5,943.10 -2,174.98 -354.56 2,542,375.19 263,000.24 0.53 2,079.59 2_Gyro-NS-CT_Drop(1) 6,594.34 22.59 196.95 6,129.26 6,000.26 -2,197.82 -361.26 2,542,352.49 262,993.07 0.73 2,100.91 2_Gyro-NS-CT_Drop(1) 6,656.21 22.59 196.34 6,186.39 6,057.39 -2,220.59 -368.07 2,542,329.86 262,985.81 0.38 2,122.14 2_Gyro-NS-CT_Drop(1) 6,718.07 22.48 196.41 6,243.52 6,114.52 -2,243.34 -374.75 2,542,307.26 262,978.66 0.18 2,143.37 2_Gyro-NS-CT_Drop(1) 6,780.00 22.86 197.25 6,300.67 6,171.67 -2,266.19 -381.67 2,542,284.56 262,971.29 0.81 2,164.66 2_Gyro-NS-CT_Drop(1) 6,842.07 22.60 196.21 6,357.92 6,228.92 -2,289.15 -388.57 2,542,261.74 262,963.92 0.77 2,186.07 2_Gyro-NS-CT_Drop(1) 6,904.77 21.76 197.32 6,415.98 6,286.98 -2,311.82 -395.39 2,542,239.22 262,956.64 1.50 2,207.19 2_Gyro-NS-CT_Drop(1) 6,967.40 22.25 197.41 6,474.04 6,345.04 -2,334.21 -402.40 2,542,216.97 262,949.18 0.78 2,228.02 2_Gyro-NS-CT_Drop(1) 7,030.10 22.04 198.16 6,532.12 6,403.12 -2,356.72 -409.62 2,542,194.61 262,941.50 0.56 2,248.92 2_Gyro-NS-CT_Drop(1) 7,092.81 22.62 199.04 6,590.13 6,461.13 -2,379.30 -417.22 2,542,172.19 262,933.45 1.07 2,269.82 2_Gyro-NS-CT_Drop(1) 7,155.46 23.59 199.70 6,647.75 6,518.75 -2,402.49 -425.38 2,542,149.17 262,924.82 1.60 2,291.23 2_Gyro-NS-CT_Drop(1) 7,217.37 '24.51 201.79 6,704.29 6,575.29 -2,426.08 -434.32 2,542,125.77 262,915.40 2.02 2,312.89 2_Gyro-NS-CT_Drop(1) 7,279.28 24.36 202.45 6,760.65 6,631.65 -2,449.80 -443.96 2,542,102.25 262,905.28 0.50 2,334.57 2_Gyro-NS-CT_Drop(1) 7,341.93 24.62 203.36 6,817.67 6,688.67 -2,473.73 -454.07 2,542,078.54 262,894.69 0.73 2,356.36 2_Gyro-NS-CT_Drop(1) 7,404.06 24.85 204.20 6,874.09 6,745.09 -2,497.51 -464.55 2,542,054.97 262,883.72 0.68 2,377.95 2_Gyro-NS-CT_Drop(1) 7,466.61 24.92 203.35 6,930.84 6,801.84 -2,521.60 -475.16 2,542,031.10 262,872.62 0.58 2,399.81 2_Gyro-NS-CT_Drop(1) 7,528.47 23.68 199.62 6,987.22 6,858.22 -2,545.27 -484.50 2,542,007.63 262,862.81 3.19 2,421.48 2_Gyro-NS-CT_Drop(1) 7,590.33 24.92 199.99 7,043.60 6,914.60 -2,569.22 -493.13 2,541,983.86 262,853.70 2.02 2,443.56 2_Gyro-NS-CT_Drop(1) 7,652.21 25.70 201.44 7,099.54 6,970.54 -2,593.96 -502.49 2,541,959.32 262,843.84 1.61 2,466.28 2_Gyro-NS-CT_Drop(1) 7,714.19 25.80 202.00 7,155.36 7,026.36 -2,618.97 -512.45 2,541,934.51 262,833.37 0.42 2,489.17 2_Gyro-NS-CT_Drop(1) 7,776.05 25.19 201.88 7,211.20 7,082.20 -2,643.67 -522.40 2,541,910.02 262,822.92 0.99 2,511.75 2_Gyro-NS-CT_Drop(1) 7,837.98 24.62 201.67 7,267.37 7,138.37 -2,667.89 -532.08 2,541,886.00 262,812.75 0.93 2,533.91 2_Gyro-NS-CT_Drop(1) 7,900.00 25.00 201.85 7,323.67 7,194.67 -2,692.06 -541.73 2,541,862.04 262,802.62 0.62 2,556.02 2_Gyro-NS-CT_Drop(1) 7,961.89 24.64 202.64 7,379.84 7,250.84 -2,716.11 -551.56 2,541,838.20 262,792.30 0.79 2,577.98 2_Gyro-NS-CT_Drop(1) 8,007.00 24.48 204.53 7,420.87 7,291.87 -2,733.29 -559.06 2,541,821.17 262,784.45 1.78 2,593.59 2_Gyro-NS-CT_Drop(2) 8,023.71 24.43 205.23 7,436.08 7,307.08 -2,739.56 -561.97 2,541,814.96 262,781.41 1.76 2,599.26 2_Gyro-NS-CT_Drop(2) 8,085.58 24.35 205.93 7,492.43 7,363.43 -2,762.61 -573.00 2,541,792.14 262,769.92 0.48 2,620.02 2_Gyro-NS-CT_Drop(2) 8,147.42 23.57 206.10 7,548.94 7,419.94 -2,785.18 -584.01 2,541,769.80 262,758.45 1.27 2,640.32 2_Gyro-NS-CT_Drop(2) 8,209.30 22.58 207.17 7,605.87 7,476.87 -2,806.86 -594.88 2,541,748.35 262,747.14 1.74 2,659.76 2_Gyro-NS-CT_Drop(2) 8,271.15 20.95 203.68 7,663.31 7,534.31 -2,827.55 -604.75 2,541,727.86 262,736.86 3.36 2,678.42 2_Gyro-NS-CT_Drop(2) 8,332.90 18.26 203.18 7,721.47 7,592.47 -2,846.56 -612.99 2,541,709.03 262,728.23 4.36 2,695.69 2_Gyro-NS-CT_Drop(2) li 8,394.74 14.65 200.47 7,780.77 7,651.77 -2,862.79 -619.54 2,541,692.92 262,721.35 5.97 2,710.53 2_Gyro-NS-CT_Drop(2) 8,456.70 11.73 193.45 7,841.09 7,712.09 -2,876.26 -623.75 2,541,679.54 262,716.87 5.37 2,723.06 2_Gyro-NS-CT_Drop(2) 8,518.67 10.01 177.08• 7,901.96 7,772.96 -2,887.77 -624.94 2,541,668.06 262,715.45 5.67 2,734.19 2_Gyro-NS-CT_Drop(2) 8,581.38 8.57 159.45 7,963.86 7,834.86 -2,897.59 -623.02 2,541,658.20 262,717.17 5.06 2,744.19 2Gyro-NS-CT_Drop(2) 8,644.09 6.87 137.44 8,026.02 7,897.02 -2,904.73 -618.84 2,541,650.98 262,721.20 5.39 2,751.95 2_Gyro-NS-CT_Drop(2) 8,706.08 7.55 113.97 8,087.53 7,958.53 -2,909.12 -612.61 2,541,646.47 262,727.34 4.84 2,757.36 2_Gyro-NS-CT_Drop(2) 10/29/2017 6:52:04PM Page 6 COMPASS 5000.1 Build 81D . Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point { TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD PB1 Survey Calculation Method: Minimum Curvature Design: GP 11-24RD PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical - r, ,+eh,Pffi MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section }r (usft) (°) (°) (usft) (usft) (usft) , (usft) (ft) (ft) 0100) (ft) Survey Tool Name .33 8,767.94 9.88 111.59 8,148.67 8,019.67 -2,912.72 -603.96 2,541,642.69 262,735.91 3.81 2,762,42 2_Gyro-NS-CT_Drop(2) 8,829.89 12.09 109.74 8,209.48 8,080.48 -2,916.87 -592.91 2,541,638.32 262,746.88 3.61 2,768.43 2_Gyro-NS-CT_Drop(2) 8,892.62 13.43 103.24 8,270.66 8,141.66 -2,920.76 -579.64 2,541,634.16 262,760.07 3.13 2,774.58 2_Gyro-NS-CT_Drop(2) 8,954.42 14.38 101.33 8,330.65 8,201.65 -2,923.91 -565.13 2,541,630.72 262,774.51 1.71 2,780.22 2_Gyro-NS-CT_Drop(2) 9,016.24 14.21 104.48 8,390.56 8,261.56 -2,927.32 -550.25 2,541,627.01 262,789.31 1.29 2,786.17 2_Gyro-NS-CT_Drop(2) 9,078.09 13.98 105.21 8,450.55 8,321.55 -2,931.17 -535.69 2,541,622.86 262,803.79 0.47 2,792.51 2_Gyro-NS-CT_Drop(2) 9,140.75 13.53 103.61 8,511.41 8,382.41 -2,934.89 -521.26 2,541,618.86 262,818.14 0.94 2,798.68 2_Gyro-NS-CT_Drop(2) 9,202.64 13.36 105.41 8,571.61 8,442.61 -2,938.49 -507.33 2,541,614.97 262,831.99 0.73 2,804.67 2_Gyro-NS-CT_Drop(2) 9,264.63 12.96 110.00 8,631.97 8,502.97 -2,942.77 -493.90 2,541,610.42 262,845.34 1.80 2,811.23 2 Gyro-NS-CT_Drop(2) 9,326.44 14.79 110.29 8,691.97 8,562.97 -2,947.88 -479.98 2,541,605.03 262,859.15 2.96 2,818.69 2_Gyro-NS-CT_Drop(2) 9,389.16 15.04 109.28 8,752.58 8,623.58 -2,953.34 -464.79 2,541,599.26 262,874.22 0.58 2,826.72 2_Gyro-NS-CT_Drop(2) 9,451.87 15.05 108.32 8,813.14 8,684.14 -2,958.59 -449.38 2,541,593.70 262,889.52 0.40 2,834.58 2 Gyro-NS-CT_Drop(2) 9,514.49 15.19 110.95 8,873.59 8,744.59 -2,964.07 -434.00 2,541,587.90 262,904.79 1.12 2,842.67 2_Gyro-NS-CT_Drop(2) 9,576.36 17.40 116.10 8,932.98 8,803.98 -2,971.04 -418.12 2,541,580.61 262,920.52 4.26 2,852.31 2_Gyro-NS-CT_Drop(2) 9,638.23 19.73 118.75 8,991.62 8,862.62 -2,980.14 -400.66 2,541,571.16 262,937.80 4.00 2,864.31 2_Gyro-NS-CT_Drop(2) 9,700.20 22.94 119.29 9,049.34 8,920.34 -2,991.08 -380.95 2,541,559.82 262,957.28 5.19 2,878.53 2_Gyro-NS-CT_Drop(2) 9,762.07 25.08 120.95 9,105.85 8,976.85 -3,003.72 -359.19 2,541,546.74 262,978.78 3.63 2,894.78 2_Gyro-NS-CT_Drop(2) 9,823.91 26.01 119.62 9,161.65 9,032.65 -3,017.17 -336.16 2,541,532.83 263,001.53 1.77 2,912.04 2_Gyro-NS-CT_Drop(2) 9,885.81 28.90 120.47 9,216.57 9,087.57 -3,031.46 -311.46 2,541,518.04 263,025.93 4.71 2,930.43 2_Gyro-NS-CT_Drop(2) 9,948.41 31.84 120.86 9,270.58 9,141.58 -3,047.61 -284.24 2,541,501.35 263,052.81 4.71 2,951.08 2_Gyro-NS-CT_Drop(2) 10,010.21 33.93 119.47 9,322.47 9,193.47 -3,064.46 -255.23 2,541,483.91 263,081.48 3.60 2,972.74 2_Gyro-NS-CT_Drop(2) 10,074.68 36.55 120.13 9,375.12 9,246.12 -3,082.95 -222.96 2,541,464.77 263,113.37 4.11 2,996.58 2_MWD+AX+Sag(3) 10,136.10 38.96 118.19 9,423.68 9,294.68 -3,101.25 -190.11 2,541,445.80 263,145.83 4.37 3,020.35 2_MWD+AX+Sag(3) 10,198.80 39.83 118.07 9,472.13 9,343.13 -3,120.01 -155.02 2,541,426.33 263,180.54 1.39 3,044.95 2_MWD+A)(+Sag(3) 10,260.12 42.54 118.65 9,518.28 9,389.28 -3,139.20 -119.49 2,541,406.43 263,215.66 4.46 3,070.04 2_MWD+AX+Sag(3) 10,321.50 45.63 119.38 9,562.36 9,433.36 -3,159.91 -82.16 2,541,384.96 263,252.57 5.10 3,096.97 2_MWD+AX+Sag(3) 10,385.21 48.10 119.18 9,605.92 9,476.92 -3,182.65 -41.61 2,541,361.41 263,292.65 3.88 3,126.43 2_MWD+AX+Sag(3) 10,446.81 50.40 121.37 9,646.13 9,517.13 -3,206.18 -1.32 2,541,337.06 263,332.45 4.60 3,156.65 2_MWD+AX+Sag(3) 10,507.55 52.55 122.09 9,683.96 9,554.96 -3,231.18 39.09 2,541,311.25 263,372.34 3.66 3,188.32 2_MWD+AX+Sag(3) 10,570.21 55.21 122.19 9,720.89 9,591.89 -3,258.10 81.94 2,541,283.46 263,414.64 4.25 3,222.31 2_MWD+AX+Sag(3) 10,631.96 58.18 123.40 9,754.80 9,625.80 -3,286.06 125.32 2,541,254.63 263,457.43 5.08 3,257.42 2_MWD+AX+Sag(3) 10,694.57 61.66 122.48 9,786.17 9,657.17 -3,315.51 170.78 2,541,224.27 263,502.29 5.70 3,294.36 2_MWD+AX+Sag(3) 10,756.46 66.09 124.24 9,813.42 9,684.42 -3,346.07 217.17 2,541,192.77 263,548.04 7.60 3,332.55 2_MWD+AX+Sag(3) 10,816.98 66.38 122.71 9,837.81 9,708.81 -3,376.62 263.37 2,541,161.29 263,593.61 2.36 3,370.70 2_MWD+AX+Sag(3) 10,841.20 66.18 122.40 9,847.55 9,718.55 -3,388.55 282.06 2,541,148.98 . 263,612.05 1.43 3,385.71 2_MWD+AX+Sag(3) 10,876.51 65.69 121.78 9,861.95 9,732.95 -3,405.68 309.37 2,541,131.31 263,639.01 2.12 3,407.35 2_MWD+AX+Sag(3) 10,937.96 65.51 121.80 9,887.34 9,758.34 -3,435.16 356.94 2,541,100.87 263,685.97 0.29 3,444.69 2_MWD+AX+Sag(3) 10,999.56 65.19 121.32 9,913.03 9,784.03 -3,464.46 404.64 2,541,070.60 263,733.07 0.88 3,481.87 2_MWD+AX+Sag(3) 11,062.30 66.86 122.35 9,938.52 9,809.52 -3,494.70 453.34 2,541,039.38 263,781.14 3.06 3,520.16 2_MWD+AX+Sag(3) 11,124.49 69.75 123.22 9,961.51 9,832.51 -3,525.99 501.92 2,541,007.11 263,829.06 4.83 3,559.45 2_MWD+AX+Sag(3) 10/29/2017 6:52:04PM Page 7 COMPASS 5000.1 Build 81D 4. Halliburton 4111 Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well GP-11-24RD Project: Granite Point TVD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Site: Granite Point Platform MD Reference: GP 11-24RD WP08 Actual RKB @ 129.00usft Well: GP-11-24RD North Reference: True Wellbore: GP 11-24RD PB1 Survey Calculation Method: Minimum Curvature Design: GP 11-24RD PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,187.01 72.88 124.02 9,981.54 9,852.54 -3,558.78 551.22 2,540,973.33 263,877.70 5.15 3,600.35 2_MWD+AX+Sag(3) 11,245.22 75.96 123.56 9,997.17 9,868.17 -3,589.96 597.82 2,540,941.21 263,923.65 5.35 3,639.19 2_MWD+AX+Sag(3) 11,278.00 75.96 123.56 10,005.12 9,876.12 -3,607.54 624.32 2,540,923.10 263,949.78 0.00 3,661.13 PROJECTED to TD mitchell.laird@halliburton.com Michael Calkins Checked By: 2017.10.3013:11:05-08'00' Approved By: ,- " Date: 1 0/29/1 7 10/29/2017 6:52:04PM Page 8 COMPASS 5000.1 Build 81D • • 21 6123 BAKER PRINT DISTRIBUTION LIST 2 8 7 8 0 UGHES a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME 07-15B RECEIVED i\ /� /2011 900 E. Benson Blvd. M K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit NOV 1 3 2017 to acknowledge receipt of this data. COUNTY PRUDHOE BAY AOGCC LOG TYPE RPM:PNC3D BHI DISTRICT Alaska LOG DATE October 18, 2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE November 9,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF I'RIN I S ��#OF COPIESn #OF COPIES #OF COPIES V L U v V BP North Slope. 0 1 1 1 0 EOA,PBOC,PRB•20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 1 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 0 1 1 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division ofOil&Gas *** 0 0 1 1 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 **Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,1R2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn: Dodie Stinson TOTALS FOR THIS PAGE: u • • 21 7123 11 Debra Oudean Hilcorp Alaska, LLC 8 GeoTech II 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage, AK 99503 Tele: 907 777-8337 Iiilcur):Alaski,1,1A. Fax: 907 777-8510 DATA LOGGED E-mail: doudean@hilcorp.com lvl\K BENDER NOV 09 2017 DATE 11/07/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 DATA TRANSMITTA GP 11-24RD(217-123) Prints: GR/CBL CD: CBL 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: j 6 , Date: ®F T� cv.i.1//,,v THE STATE Alaska Oil and Gas Of /® sKAL Conservation Commission 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov Stan Gollis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 11-24RD Permit to Drill Number: 217-123 Sundry Number: 317-461 Dear Mr. Gollis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair rr J DATED this b day of October, 2017. � �eFr, - 6 2017 • • RECEIVED STATE OF ALASKA SEP 2 9 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION r $ / 68 / 7 APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other G/L Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 , 217-123 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-733-20046-01-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 76 Will planned perforations require a spacing exception? Yes ❑ No 0 / Granite Pt St 11-24RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL018761 Granite Point Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ±13,500(proposed) ±10,849(proposed) ±13,000(proposed) ±10,661 (proposed) 1,015 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 638' 18" 638' 633' Surface 4,030' 13-3/8" 4,030' 3,796' 3,090 psi 1,540 psi Intermediate Production 8,007' 9-5/8" 8,007' 7,419' 5,750 psi 3,090 psi Liner ±5,650'(proposed) 7" ±13,500'(proposed) ±10,849'(proposed) 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 " Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/15/2017 OIL 0 - WINJ El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarIowe@hiIcorp.com tt Contact Phone: (907)283-1329 Authorized Signature: 54,..... e.�7 Date: �Z 9 ( } COMMISSION VSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test Lld' Mechanical Integrity Test ❑ Location Clearance ❑ Other. J a^s✓ ,e e 1 les RBDMS uv 0 Of u 120517 Post Initial Injection MIT Req'd? Yes ❑❑ No ❑ o? eL4I /,4 JSpaing Exception Required? Yes No 4��1/ Subsequent Form Required: (j-41 � 1A4-11 / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: t b 4. 1- - A 416 robii?- bi44.?/,i/7 /0.s""-17 4 C Submit Form and a1V Form 10-403 Revised 4/2017 0 firivei,NiA slid for 12 months from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well:GP 11-24rd Date: 09/26/2017 Hilrorp Alaska,LLE Well Name: GRANITE PT ST#11-24RD API Number: 50-733-20046-01 (GP 11-24rd) Current Status: New Sidetrack (was Leg: Leg#3 suspended) Estimated Start Date: October 15, 2017 Rig: Kuukpik 5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 217-123 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 2,000 psi @ 9,850'TVD 0.203 lbs/ft(3.90 ppg)based on offset producers Maximum Expected BHP: 2,000 psi @ 9,850'TVD 0.203 lbs/ft(3.90 ppg)based on offset producers Maximum Potential Surface Pressure: 1,015 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary GP 11-24rd is a C-5 only producer that will be completed with Gas Lift. This new well was side tracked from the current GP 11-24 a suspended producer.This workover will run completion and perforate the new well. Last Casing Test: Casing and liner tested to 2,000 psi under PTD 217-123 Procedure: 1. ***Take over operations from the Drilling Sidetrack Program *** 2. Test BOP's every 14 days continued from last test date from PTD 217-123.Test to 250psi low/3,500psi high/ 2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Completion fluid will be diesel. BOP's will be closed as needed to circulate the well. 'v 4. Rig up E-Line and run gamma/ccl/cbl. POOH. 5. PU and RIH with TCP guns and Gas Lift completion with plug set in X-Nipple g,„,„65‘ C"'" 6. Correlate and space out completion, and set production packer 7. RU E-Line, correlate and space out completion. 8. Set Packer/Pressure test completion: • Pressure up and set packer • Test tubing against plug in X nipple to 2500#and chart for 30 minutes. A • Test IA to 2,000 psi and chart for 30 minutes(This will pressure up tubing also). µ t • Pull prong and plug in X-Nipple. 9. Set BPV. NU tree,test same. 10. Turn on Gas Lift and unload wellbore to achieve desired underbalance. 11. Fire TCP's as per program. 12. Turn over to production. 13. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • •H . Granite Point Platform Well: Granite Pt St#11-24RD PROPOSED PTD:217xxx API: 50-733-20046-xx Ililcorp Alaska,LLC Last Completed: Future RFB=114.75";43'Rig Floor to Wellhead FMC Unihead CASING DETAIL I I Size Wt Grade Conn ID Top Btm J18" 70.59 B Ventura Surf 638' 13-3/8" 61 J-55 8rd 12.515" Surf 4,030' X X 40 N-80 Butt 8.835" Surf 82' /I 18 43.5 N-80 Butt 8.755" 82' 123' pV�i� 9-5/8" 40 N-80 Butt 8.835" 123' 1,955' @2,285' 40 N-80 LT&C 8.835" 1,955' 5,547' 40 5-95 ST&C 8.835" 5,547' 6,537' 43.5 5-95 ST&C 8.755" 6,537' ±8,500'(KOP) 7" 26 L-80 DWC/C 6.276" ±8,300' ±13,083' 13-3/8" 13-98(-440) Bad spot Mere sawed into csg atter parting ,.,jAr irti n PAP JEWELRY DETAIL t , No Depth(MD) Depth ID Item (TVD) 1 ±8,300' 6.059" SDD Baker Liner Hanger „ �� 2 ±8,500' ±7,872' KOP f 3 ±8,300'- 13,083' ±10,521' 6.276" 7" 26# L-80 DWC/C I S ,..S i 35/8" 2 W I�� 3 i . o CEMENT DETAIL __ tr ±it 8,Depth TOC Depth ,, No (MD) (TVD) Volume Item ' 4 ±9,000' ±8,336' 141 bbls 15.3 ppg Class G cement w/%2 bbl 4 cemnet LCM zs • I , r: rig 4 e PBTD:13,000' TD:±13,083' MAX HOLE ANGLE±73° Updated By:MMM 08/22/17 • • Granite Point Platform • 11 Well: Granite Pt St#11-24rd PROPOSED PTD: 217123 API: 50-733-20046-01 Hilcorp Alaska,LLC Last Completed: Future RFB=114.75';43'Rig Floor to Wellhead FMCUnihead CASING DETAIL Size Wt Grade Conn ID Top Btm J ' 1 18" 70.59 B Ventura Surf 638' 13-3/8" 61 1-55 8rd 12.515" Surf 4,030' itgI 18„ 40 N-80 Butt 8.835" Surf 82' / ID43,5 N-80 Butt 8.755" 82' 123' DVCd1ar40 N-80 Butt 8.835" 123' 1,955' @2 9-5/8" 40 N-80 LT&C 8.835" 1,955' 5,547' 40 S-95 ST&C 8.835" 5,547' 6,537' 43.5 5-95 ST&C 8.755" 6,537' 8,007'(KOP) 13 3/8 7" 29 L-80 DWC/C 6.184" ±7,850' ±13,500' TUBING DETAIL: 2-7/8" 6.5 L-80 8 rnd EUE 2.441" Surf ±10,839' 133'8('440) Bad spot Akre +. screwed info csg after paling !A^ JEWELRY DETAIL Depth Depth "I1/4Ur ‘P j No (MD) (TVD) ID OD Item �� 1 ±43' ±43' Tubing Hanger 4 ZJ 1 ±350' ±350' 2.313" SSSV 4iii ±2,631' ±2,500' 2.441" GLM#1 EN ±4,472' ±4,200' 2.441" GLM#2 ±5,911' ±5,500' 2.441" GLM#3 ±6,892' ±6,400' 2.441" GLM#4 2 ±7,658' ±7,100' 2.441" GLM#5 2 ±8,315' ±7,700' 2.441" GLM#6 9-5/8' ±8,848' ±8,200' 2.441" GLM#7 ±9,358' ±8,700' 2.441" GLM#8 ±9,863' ±9,200' 2.441" GLM#9 ±10,560' ±9,711' 2.441" GLM#10 3 ±10,590' ±9,728' RA Marker 4 ±10,630' ±9,750' Packer 5 ±10,641' ±9,755' 2.313" X Nipple ±10,828' ±9,842' Ported Sub ±10,839' ±9,846' N/A Mechanical Firing Head ±10,849' ±9,850' N/A TCP Assembly 7 ±13,371' ±10,801' N/A Lower Firing Adapter ±13,376' ±10,802' N/A Absolute Pressure/Time delay Firing Head 3 ;4 ' I r.,,, 4 5 ••• 6 PERFORATION DETAIL • Zone Top Btm Top Btm FT SPF Date Status • 7 (MD) (MD) (TVD) (TVD) C-5 ±10,849' ±13,370' ±9,850' ±10,800' ±2,521' 6 Future C-5 ,4 r"Mali 7. PBTD:x,xx:l TD:±13,500' MAX HOLE ANGLE±68 Updated By:.ILL 09/26/17 fit • • Granite Point GPP 11-24RD Proposed 09/28/2017 Moor?Alask..1.JA: Granite Point Tubing hanger,FMC-UH- GPP 11-24RD TC-1A-EN-CCL,13 5/8 5M X 18 X133/8 X95/8X 3'/:IBT lift and 3'/:IBT 3 1/2 susp,w/3"type H BPV, 6.990"EN,2-%npt control line feed-thru BHTA,Bowen,31/8 5M FE X 3"Bowen Valve,Swab,WKM-M, 31/8 SM FE,HWO,EE trim Valve,SSV,Wing,WKM-M, 3 1/8 5M,w/15"OMNI oper • Tee,stdd,3 1/8 5M X O 3 1/8 5M Valve,Master,WKM-M, 3 1/8 5M FE,HWO,EE trim it . Valve,Master,WKM-M, 31/85M FE,HWO,EE trim Control line x 2 Adapter,FMC-ASP,13 5/8 5M API clamp X3 1/8 5M,w/ Unihead,OCT type 2,13 5/8 5M API _ 6.990"extended neck pocket hub top X 13 3/8 BTC casing bottom, .. w/2-2"LPO on lower section,2-2 1/16 5M SSO on upper section,IP 1.-'. internal lockpin assy I p-r* all Valve,WKM-M,2 1/16 5M ,-- �. I *PL °a?�'HWO,AA trim I . , . Jim n s i.l ik 8 i 1 —.i, t9, �j"" I Starting head,OCT, 211/4 2M Hub x 24'/.1M jll� .i _11(.....- Valve,OCT -20,2"LPO,HWO, Hub w/2-2"LPO,prepped f/ /"a„,.... rd, AA trim 18"EN hanger II `r � �-"_I-_, • Conductor housing, �� 24%1MHubX II II 24"Buttweld ..a;1i -1 I I 18', 13 3/8" 9 5/8" 334" • • Granite Point Platform 2017 BOP Stack(Kuukpik) 04/24/2017 II Tarp �Lr�ku.1.1A1 Rig Floor ,,..,.,.E I 16" Pipe III Ili lit!hilt 3'74' Shaffer 13 5/8 5M Ili III til tit tit 01111M0- Shaffer SL _ '7f'' 2 7/8-5.5 Variables 2.83' 13 ' .�f4. 5/8 SM • —f Blind .4101M0- 22 1/16 5M 2 1116 5M manual and HCR valve 1 if ®- 1.76 ' • tr.- } 141111111111- r3 4411' 1111.111 Iii 0 Shaffer = 13 5 8 SMM 2 7/8-5 5 Variables III 111111 II11 III Drill deck 13.70' Riser 135/85MFEX 13 5/8 5M API hub 61 1 • i Choke Manifold Valves 2 „ 3" To Shaker 3" Panic To Gasbuster J 3 1/8" 2 1/16" 2 1/16" 2 1/16;, 2 1/16" + i9 3 1/8" 512 2 1/16" .21/16" Manual Choke Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold *10 IA 4 awrf+ k ' N Kuukpik Drilling Rig 5 Choke Manifold • • Q �• o Ty Y " o Oco r-+• a = I I 1 1 1 1 1 1 1 a fig ZJ Irole°Ialo`Irnli.iwl.4i. 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Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile&lift threads were deemed good, but still unable to get good tests 1) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov),Jim Regg (AOGCC-jim.regg@alaska.gov) and Michael Quick(AOGCC—Michael.quick@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory (melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path,test choke manifold per standard procedure 3) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPs looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPS are not leaking. Test#1=Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) 7) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE as per Kuukpik's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. • . Kuukpik 5 BOP Test Procedure F,;,,.,,ri,.u,�a.i.i.c Attachment#1 If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/ pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow ( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/ upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure 1 k � a / \ � $ - 6 g T m c 22 oo2 / / 2k ° § / < a E ® E 2 0o f 7 a / ( I a� f \ < _ \ / � --- Cl.) > P f al" co F, \.§ a q as k / m e- e .§ E = a $ CI 2 \ et � � o a Q. §% tp >- a 77 J Q � 45 L # o _ a n tn. o Q E \ k 2 a oao 6 a3 (L§ c = .. c g .0 0 \ P 2 k \ � k 2 E § ° m je 2 O 2 0 .g a- O / k > 2 $ k / / 2 w _ co c Lu 2 / 2 o ■ W > / - a) o / ¢ $ o 0 . a. / $% @ E O X \ / 0 a) �z Cr) Q § x Ta— ct / X 0 w co en o g e m 7 6 � W -_,=. al co it ƒ .. C) 80 \ c 2 g > z � 2 \2 u \ \ 21 U $ / \ / U / . . 111/- o. • Py of 7,44, yw\ , � THE STATE Alaska Oil and Gas ti -s=r� � of Conservation Commission ,; LAsKA 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of ALAS*P' Fax: 907.276.7542 www.aogcc.alaska.gov Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 11-24RD Hilcorp Alaska, LLC Permit to Drill Number: 217-123 (Corrected) Surface Location: 2383' FNL, 1368' FWL, Sec. 13, T1ON, R12W, SM, AK Bottomhole Location: 1867' FNL, 1548' FEL, Sec. 24, T10N, R12W, SM, AK Dear Mr. Mazzolini: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, d11212CC-- -- Hollis S. French Chair DATED thisaV day of September, 2017. • 410 SOF 711 fr \ y/� 9 THE STATE Alaska Oil and Gas N —s_rA. f Conservation Commission o ALA S lMz7::::17:47: : 333 West Seventh Avenue !�� Anchorage,GOVERNOR BILL WALKER e, Alaska 99501-3572 g Main: 907.279.1433 of SgQ' Fax: 907.276.7542 www.aogcc.alaska.gov Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 11-24RD Hilcorp Alaska, LLC Permit to Drill Number: - 23 Surface Location: 2383' FSL 1368' FEL, .ec. 13, T1ON, R12W, SM, AK Bottomhole Location: 1 FNL, 1 ' '_' EL, Sec. 24, T1ON, R12W, SM, AK Dear Mr. Mazzolini: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French -�l Chair DATED this 29_day of September, 2017. RECEIVED ll STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI N AUG 2 2 2017 PERMIT TO DRILL ��� 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed 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 D 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 Granite Pt St 11-24RD 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,�� Anchorage,AK 99503 MD: 13,083'• TVD: 10,521' • Granite Point Field 4a. Location ,SSe1tion):3,T1ON,R12W,SM,AK ADL018761 7.Property Designation: Middle Kenai Oil Pool Surface: 2383'F of nn, 1368'F�t, Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: 631'FNL,2119'FWL,Sec 24,T1ON,R12W,SM,AK N/A 9/15/2017 Total Depth: . , r�� 9.Acres in Property: 14.Distance to Nearest Property: 1867'FNL,1548'FEL,Sec 24,T1ON,RY1 V,SM,AK 1►r.7 5089 4650'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): ale yA5r 15.Distance to Nearest Well Open Surface: x-263399 y- 2544542 Zone-4 • GL/BF Elevation above MSL(ft): O ,7‘774 to Same Pool: 1840'to GP 12-24 16.Deviated wells: Kickoff depth: 8,500 feet • 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 73 degrees. Downhole: 5155 ' Surface: 2735 • 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) 8-1/2" 7" 26# L-80 DWC/C 4,783' 8,300' 7,680' 13,083' 10,521' 591 sx 15.3# 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): 11,798' 11,068' N/A 9,440' 8,781' N/A Casing Length Size Cement Volume MD TVD Structural 637' 18" Driven 294' 294' Surface 4,030' 13-3/8" 1900 sx 4030' 4030' Intermediate 10,086' 9-5/8" 515 sx 10,086 10,086 Production 1,835' 7" 326 sx 9,963' 11,798' Perforation Depth MD(ft): 9,765'-11,135' Perforation Depth TVD(ft): 9,103'-10,471' Hydraulic Fracture planned? Yes❑ No Q 20. Attachments: Property Plat ❑ BOP Sketch 7 Drilling Program 7 Time v.Depth Plot 7 Shallow Hazard Analysis— Diverter Sketch _ Seabed Report _ Drilling Fluid Program ✓ 20 AAC 25.050 requirements .i 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: Monty Myers Authorized Name: Paul Mazzolini Contact Email: mmyerstC7l.hilcorp.com Authorized Title: Drilling Manager Contact Phone: 777-8431 rY . -, Authorized Signature: -„,,,! Date: /ZZ/A/7 Commission Use Only Permit to Dri API Number: //�� Permit Ap ro I See cover letter for other Number: '7-- 1,3 50- 'i— c OV !to -0 1 -00 Date: ^U/' 1 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: 71 Other: ‘ 3 5•00 ,` 2 `p "� - Samples req'd: Yes ❑ No Mud log req'd:Yes❑ No d p f AC / T. H25 measures: Yes E ( Non Directional Directional svy req'd:Yes RJ"No❑ +c- �s-6u r s et. f t ;;' F Spacing exception req'd: Yes❑ Nog Inclination-only svy req'd:Yes❑ No[@ p Post initial injection MIT req'd:Yes El No❑ (.- tr" e M '° �. .- --- . ,P: ,eJ p"- L-c) 4-c z :5.cit+ J COC 4)6.A) APPROVED BY R I"-/- Itq Appr6ved by: !�— —i 1,1,,,,Te COMMISSIONER THE COMMISSION DateSubmft Form and 4 -orm 1 -4r own i ' RIi r I�v1Ilrho 24 nwnlhb bum lire date of appruvel per 20 AAC 25.005(9) Attachments in Duplicate 111 Hilcorp Alaska, LLC P.O. Box 244027 Monty Myers Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Energy Company 8/23/2017 Commissioner RECEIVED Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue AUG 2 2 2017 Anchorage, Alaska 99501 AOGCC OGCC Re: GP 11-24RD Dear Commissioner, Enclosed for your review is an application for permit to drill GP 11-24RD. GP 11-24RD is an oil production well planned to be re-drilled in a South-easterly direction from the existing GP 11-24 utilizing the existing casing program down to 8500' MD/7873' TVD. At 8500' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several , Tyonek targets. A 4583'x 8-1/2" open hole section is planned. A 7" 26# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8"X 2-3/8"gas lift completion. Drilling operations are expected to commence approximately September 15th, 2017. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • • Hilcorp Alaska, LLC GP 11-24RD Drilling Program McArthur River ro d by: IVi R 41466.0. Revision 0 August 17, 2017 • GP 11-24RD Drilling Procedure Rev 0 Ili!corp Alaska,LLf. 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 Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 BOP N/U and Test 11 11.0 Mud Program and Density Selection Criteria 12 12.0 Whipstock Running Procedure 13 13.0 Whipstock Setting Procedure 16 14.0 Drill 8-1/2"Hole Section 19 15.0 Run 7"Production Liner 22 16.0 Cement 7"Production Liner 25 17.0 Wellbore Clean Up & Displacement 29 18.0 Run Completion Assembly 30 19.0 RD 30 20.0 BOP Schematic 31 21.0 Wellhead Schematic 32 22.0 Days vs Depth 33 23.0 Geo-Prog 34 24.0 Anticipated Drilling Hazards 35 25.0 Rig Layout 36 26.0 FIT Procedure 37 27.0 Choke Manifold Schematic 38 28.0 Fluid Flow Diagrams 39 29.0 Casing Design Information 42 30.0 8-1/2"Hole Section MASP 43 31.0 Plot(NAD 27) (Governmental Sections) 44 32.0 Slot Diagram (As Built) (NAD 27) 45 33.0 Directional Program (wp06) 47 • • GP 11-24RD Drilling Procedure Rev 0 Hilcorp Alaska,ii : 1.0 Well Summary Well GP 11-24RD Pad& Old Well Designation Sidetrack of existing well GP-11-24 (PTD#169-054) Planned Completion Type 7"26#L-80 Liner,2-7/8"Tubing GL Comp Target Reservoir(s) Tyonek Producer C5A Planned Well TD,MD/TVD 13083' MD/ 10521' TVD PBTD, MD/TVD 13000' MD/ 10496' TVD Surface Location(Governmental) 2383' FSL, 1368' FEL, Sec 13,T1ON, R12W, SM,AK Surface Location(NAD 27) X=263398.89,Y=2544542.44 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 631'FNL,2119'FWL, Sec 24, T1ON,R12W, SM,AK TPH Location(NAD 27) X=264082.81,Y=2541004.16 TPH Location(NAD 83) BHL(Governmental) 1867'FNL, 1548'FEL, Sec 24,T1ON,R12W, SM,AK BHL(NAD 27) X=265670.0,Y=2539736 BHL(NAD 83) AFE Number 1711828D AFE Drilling Days AFE Drilling Amount $4.68 MM Work String 4-1/2" 16.6# S-135 CDS-40(From Saxon) RKB—AMSL 115' MSL to ML 75' BOP Equipment 13-5/8" 5M Hydril"GK"Annular BOP 13-5/8" 5M Cameron Type U Double Ram 13-5/8" 5M Cameron Type U Single Ram Page 2 Revision 0 May,2017 • 4110 GP 11-24RD Drilling Procedure Rev 0 IIilrorp: k-ka.I.1 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Energy Company Changes to Approved Permit to Drill Date: August 22, 2017 Subject: Changes to Approved Permit to Drill for GP 11-24RD File#: GP 11-24RD Drilling Program Any modifications to GP 11-24RD Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Monty M Myers 8.22.2017 Drilling Engineer pate Page 3 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 Ililcorp Alaska,L1.: 3.0 Tubular Program Hole Section OD (in) Wt(#/ft) Coupl OD ID (in) Drift(in) Grade Conn Top Bottom 8-1/2" 7" 26 7.875" 6.276 6.151 L-80 DWC/C 8300 13083 4.0 Drill Pipe Information Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) 8-1/2" 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 flilcorp Ala.ka, 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates v. Submit a short operations update each work day to pma77olini@hilcorp.com, mmyers@hilcorp.com and cdinger@hilcorp.com 5.3 5am Weekend Update vi. Submit a short operations update each weekend and holiday to whoever is assigned weekend or vacation duty. Details will be sent before each weekend or holiday. vii. Copy pmazzolini@hilcorp.com,and mmyers@hilcorp.com 5.4 EHS Incident Reporting viii. Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. Leonard Dickerson: 0: (907) 777-8317 C: (907)252-7855 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907)777-8317 C: (907)602-5178 2. Spills: a. Keegan Fleming: 0:907-777-8347 C:907-350-9439 ix. Notify Drlg Manager 1. Paul Ma77olini: 0: 907-777-8369 C: 907-317-1275 x. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally xi. Send final"As-Run"Casing tally to mmyers@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cmt report xii. Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp.com Page 5 Revision 0 May, 2017 • 0 HGP 11-24RD Drilling Procedure Rev 0 Ililcorp Ala.ka.I,I,C 6.0 Planned Wellbore Schematic Granite Point Platform Well: Granite Pt St#11-24RD PROPOSED API.507733 20046-xx Irl,.,,;. 3,',,,.III Last Completed:Future RIO=11475;43'Rig FloorloWilhead CASING DETAIL. FitUmhBBd Size Wt Grade Conn ID Top Btm I 18" 70.59 8 Ventura Surf 638' J 13-3/8" 61 1-55 8rd 12.515" Surf 4,030' X 18 40 N-80 Butt 8.835" Surf - 82' 8 43.5 N-80 Butt 8.755" 82' 123' 0✓Gi� 9-5/8" 40 N-80 Butt 8.835" 123' 1,955' C e 40 N-80 LT&C 8.835" 1,955' 5,547' i 6 40 S-95 ST&C 8.835" 5,547 6,537' 43.5 S-95 ST&C 8.755" 6,537 ±8,500'(KOP) 7" 26 1-80 DWC/C 6.276" ±8,300' ±13,083' - 13-3,8' 13,3(wJ) 8alspoesoe mimed roesg ser Pen x G* JEWELRY DETAIL N.1 p. No Depth(MD) Depth ID Item Sf (ND) tab N 1' 1 ±8,300' 6.059" SDD Baker Liner Hanger 2 ±8,500' ±7,872' - KOP 3 ±8,300' 13,083' ±10,521' 6.276" 7"26#L-80 DWC/C •1 k .! Lyf.i t 2 3 7. CEMENT DETAIL ni Dc TOC Depth TOC Depth t [` No (MD) (TVD) Volume Item ,�. G,= 4 ±9,000' ±8,336' 141 bbls 15.3 ppg Class G cement w/4 bbl l': 4 cemnet LCM 4 5'er( ill, M 1. =F, I,. PEJO:13,000' TD:±13,083' Page 6 Revision 0 May, 2017 • GP 11-24RD Drilling Procedure Rev 0 Ifilcorp Alaska,LLC 7.0 Drilling Summary • Ptd GP 11-24RD is an oil production well planned to be re-drilled in a South-easterly direction from the existing GP 11-24 utilizing the existing casing program down to 8500' MD/7873' TVD. At 8500' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Tyonek targets. A 4583' x 8-1/2"open hole section is planned. A 7"26#L-80 DWC/C prod liner will be run,cemented,and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8"X 2-3/8"gas lift completion. Drilling operations are expected to commence approximately September 15th, 2017. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. 317- 113 A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and for running the completion assembly General sequence of operations pertaining to this approved drilling procedure: 1. Kuukpik 5 will be over(GP 11-24)to decomplete and P&A well under separate sundry. 2. DP should be stood back in derrick 3. PU whipstock, and mills and TIH to CIBP ,p S= �w�L- 4. ` (' �` 4. Orient whipstock and set at 65 deg left of highside. ! iA 7 5. Swap well to 9.0 ppg oil based drilling mud 7 6. Mill 8-1/2" window and 50' of new formation at 8500'. 7. Perform FIT to 12.5 ppg EMW 8. POOH and LD mills. PU rotary steerable directional BHA and TIH to window. 9. Drill 8-1/2" production hole from 8550' to 13083' MD, performing short trips as needed ft.;"/ 10. Perform short trip and condition mud. POOH 11. LD Directional Tools. RIH w/7" liner. Set liner and cement. Circ wellbore clean. 12. POOH, laying down DP and liner running tools, rtm 13. PU 7" casing scraper assembly and TIH to landing collar. 14. Circ casing clean. POOH laying down DP. 15. Run 2-7/8" completion. (Covered under separate sundry) 16. Land hanger and test. 17.ND BOPE,NU tree and test void 4.3)( s-"Ajp4.5 /dz. r s , F•i7./7 Page 7 Revision 0 May,2017 • GP 11-24RD Drilling Procedure Rev 0 Ifilcorp.Alaska,I.LC 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling of GP 11-24RD. Ensure to provide AOGCC 48 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min (annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test ALL BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All.AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: Hilcorp would like to re' . - a variance to regulation 20 AAC 25.035(e)(4)(F)(i) which states - "the outlets _ .e at least two inches in nominal diameter, except that for rotary drilling rig oper. ': s, if the operation has a maximum potential surface pressure of greater than 3,000 psi, the nominal diameter of the choke outlets must be at least three inches". o The calculated MASP for this wellbore when completely evacuated to gas is 5155 psi. However, for Cook Inlet Operations, we assume that the well can never flow 100% gas, due to the water in 5 � e reservoir. We reduce this MASP calculation to 2735 psi which assumes that only 2/3 of the cwellbore is evacuated to gas and 1/3 to 9.0 ppg reservoir fluid. Hilcorp would like to request to have 2-1/16" outlets on the choke line and kill line due to this assumption orr: A (4MkSf ` r,-ate Page 8 Revision 0 May, 2017 „ • • GP 11-24RD Drilling Procedure Rev 0 Ililcorp Alaska,LLC Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 13-5/8"Shaffer 5M annular • 13-5/8"5M Shaffer SL Double gate Initial Test:250/3500 (Annular 2500 psi) • Blind ram in bottom cavity 8-1/2" • Mud cross • 13-5/8"5M Shaffer SL single gate Subsequent Tests: • 3-1/16"5M Choke Manifold 250/3500 (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technology Accumulator, 3000psi, 5 station, 170 gallon reservoir, 4 nitrogen backups and 12 bladder bottles. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back-up is an air pump, and tertiary emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 48 hours notice prior to spud. • 48 hours notice prior to testing BOPs. • 48 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236 (During normal Business Hours) Notification/Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Revision 0 May,2017 • • GP 11-24RD Drilling Procedure Rev 0 Ilileorp AIa.ka,HA: 9.0 R/U and Preparatory Work 9.1 Separate sundries will be submitted that will include the following: • Pull tubing • P&A lower perfs with a cement plug • Set CIBP 9.2 Mix mud for 8-1/2" hole section. 9.3 Verify 4.5" liners installed in mud pump#1 and 5.5" liners installed in pump #2. • Ellis Williams WH-1000 Pumps are rated at 3500 psi (100%) with 4.5" liners and can deliver 171 gpm at 86 spm. • TSM 1000 Pumps are rated at 3500 psi (100%) with 5.5" liners and can deliver 229 gpm at 86 spm. • Ideal pump rate for drilling will be 400 gpm. Both pumps running at 60 spm should achieve this. Pump#1 Ellis Williams WH1000 10" Stroke Pump#2 TSM 10009" Stroke 96% Efficiency Max psi 3500 psi 96% Efficiency Max psi 3500 psi Liner Size bbls/stroke Liner Size bbls/stroke 4.5 0.0472 5.5 0.0635 Strokes/minute bpm gpm Strokes/minute bpm gpm 20 0.94 40 20 127 53 40 1.89 79 40 2.54 107 60 2.83 119 60 3.81 160 86 4.06 171 86 5.46 229 100 4.72 198 100 6.35 267 120 5.67 238 120 7.62 320 140 6.61 278 150 7.08 297 Page 10 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 Ilileorp Alaska,LLC 10.0 BOP N/U and Test 10.1 * BOPE was NU and tested on prior decompletion sundry. We will test BOPE on 7 day cycle until the window is milled, at that point we will switch to the 14 day test cycle. Continue on to step 11. 10.2 N/U 13-5/8"x 5M BOP as follows (top down): • 13-5/8"x 5M Shaffer annular BOP. • 13-5/8" Shaffer Type "SL" Double ram. (2-7/8"X 5"VBR in top cavity, blind ram in btm cavity) • 13-5/8"mud cross • 13-5/8" Shaffer Type "SL" single ram. (2-7/8"X 5"VBR) • N/U pitcher nipple, install flowline. • Install (2) manual valves on kill side of mud cross. Manual valve used as inside or"master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 10.3 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min., Y • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test VBRs on 4-1/2"test joint. • Ensure gas monitors are calibrated and tested in conjunction w/BOPE. 10.4 R/D BOP test assy. 10.5 Continue mixing mud for 8-1/2"hole section. 10.6 Set wearbushing in wellhead. Ensure ID of wearbushing> 7-5/8". Page 11 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 Efileorp Alaska,LLC 11.0 Mud Program and Density Selection Criteria 11.1 8-1/2"Production hole mud program summary: Primary weighting material to be used for the hole section will be barite to minimize solids. We will have enough barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. Canrig PVT will be used throughout the drilling and completionphase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 80/20 Enviromul MOBM Properties: MD Mud Weight Viscosity PV HTHP 1 (PAg) k 8,500—13,083' C.0-9.5 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration a' LVT 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.0 ppg(as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROL PLUS 4 ppb 11.2 Program mud weights are generated by reviewing data from producing& shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Revision 0 May,2017 • • GP 11-24RD Drilling Procedure Rev 0 Ililcorp Ala.ka, 12.0 Whipstock Running Procedure Section 12.1 through 12.5 is covered under decompletion sundry, drilling proceed to 12.6 12.1 M/U window milling assembly and TIH w/4-1/2" DP out of derrick. • Use an 8-1/2"taper mill and a 8-1/2" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (8500' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the # of joints picked up so we know where we are. 12.3 Pressure test casing to 1500 psi/30 min. Chart record casing test & keep track of the amount of fluid pumped. Stage up to 1500 psi in 500 psi increments. 12.4 CBU & circ at least (1) hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.5 TOH. 12.6 Make up mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Leave assembly hanging in the elevators, and stand back on floor. 12.10 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.11 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Note: Attach mills to Whipstock with (1) 35k mill shear bolt. 12.12 If needed, open BOP Blinds. Page 13 Revision 0 May, 2017 • GP 11-24RD Drilling Procedure Rev 0 flilcorp Alaska, 12.13 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.14 Release pick up system at this point, Make up mills. 12.15 With the top drive, pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up, the shear bolt then can be made up by the Baker Rep. 12.16 The assembly can now be picked upto ensure that the shear bolt is tight. g 12.17 Remove the handling system. 12.18 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing. 12.19 Run in hole at 1 1/2 to 2 minutes per stand. 12.20 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.21 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.22 Orient at least 30' —45' above the CIBP. Page 14 Revision 0 May, 2017 0S HGP 11-24RD Drilling Procedure Rev 0 Ililrorp:11a-ka.LLC ri.I I ��um Wndow Master G2 Whipstock BAKER "I•• With Torque Master Bottom Trip Anchor HUGHES , ���� 9.625 53.5#Non Special Drift Casing Baker Oil Tools A • Upper Watermelon Mill OD: 8.500 8.500 —* I ` 4— 6.25 Length: )' Flex Joint OD: 6.375 * Length: 6.375 ' 4-- 9.00 Lower Watermelon Mill i OD: 8.375 Length: i WndowMill 40.6 OD: 8.500 8.250 --i 4— 5.66 Length: Whipstock OD: 8.000 8.500 �j f- Length: 18.54 f � 1 1.13 Face Angle: 1.9 A jAO Face Length: 17.08 Retrieval BTA OD: 8.357 17.08 Length: 18.541.9 Overall length —► " Length: WELL INFORMATION CUSTOMER FIELD f— 8.000 LEASE A ' 1 WELL NO. J SHEAR BOLT 25.000 3.41 35.000 8.357 —0-'1: -4 45.000 55,000 65.000 75.000 •1 TECHUNIT DATA ACTUAL DIMENS10NS IA AY VARY Page 15 Revision 0 May, 2017 • I GP 11-24RD Drilling Procedure Rev 0 Ililcorp Alaska,I,11 13.0 Whipstock Setting Procedure 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using highside MWD. 13.2 Orient Whipstock to desired direction by turning DP in 1/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 65L HS 85L HS Desired orientation of the Whipstock face is 65 degrees left of high side. Hole Angle at window interval (8500' MD) is 22 deg. The wellbore trajectory is planned to kick off at 199 degrees azimuth. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9.0 ppg 80/20 Enviromul MOBM. 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 16 Revision 0 May,2017 GP 11-24RD Drilling Procedure Rev 0 Ililcorp Alaska,CLC 13.10 Estimated metal cuttings volume from cutting window: Wieght of Cuttings For Milled Casing Exit 0.0.Of Casing(in) 9.625 I.D.Of Casing(in) 8.535 Whipstocks Face Length(Ft) 16.00 Percent of Casing Removed(%)* 38 Milled Area(in412) 5.908 Volume of Cuttings(in"3) 1134.272 Density of Casing(IbJin"3)" 0.283 Weight of Cutting Generated(lbs) 321.0 Calculated Average of Casing Removed Based on Drift Mills(38%) Density of Steel=.283 13.11 Drill approx.20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow; and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in=MW out. 13.13 Conduct FIT to 12.5 ppg EMW. • (12.5—9.0) * 0.052 * 7873' tvd= 1433 psi 13.14 Kick Tolerance • (12.5-9.0) * (7873/10521) =2.6 ./ Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 12.5 ppg FIT results in a 2.6 ppg kick tolerance while drilling the interval with a 9.0 ppg fluid density. 13.15 Slug pipe and POOH. Gauge Mills for wear. 13.16 Should a second run be required pick up the following BHA. 6 k Page 17 Revision 0 May, 2017 00 GP 11-24RD Drilling Procedure Rev 0 Ili!cor1,Alaska,LLC Back Up Mills Connection Length O.D. WINDOW MILL 4 Y REG-P X MILL 2.25 8.5 NEW LOWER WATERMELON MILL 4 %2 REG-P X 4 1/2 REG-B 5.5 8.5 FLEX JOINT 4 % REG-P X 4 1/2 REG-B 9.0 6.375 STRING MILL 4 1/2 REG-P X 4 % REG-B 5.5 8.5 FLOAT SUB 4 Y/" IF-B X 4 Y/z" REG-B 3.0 6.375 30 jts-HWDP 4 %2" XH-B X 4 %" REG-P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 18 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 I IiIi orp:1 la'ka.IA A: 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2"rotary steerable directional drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.51 0.61 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 350-425gpm. 14.6 Must keep up with 5 deg/100 DLS in the build section of the wellbore. 14.7 Primary bit will be the Halliburton 8-1/2" MM75DC PDC bit. Ensure to have a back up bit available on location. COMPONENT DATA - :Bem OD ID ` Delt90. iigl►'t`„ ..,Top Let*;. Description Serial Number t'-I (in) (in) (in) (Ibpf) Connection (It) Length (ft) 1 HMS-MMD75DC 5.030 2.250 8.500 54.17 P 4.1/2'REG 0.95 0.95 2 Geo-Pilot 7600 EDL 175C 25KSI 7.625 1.490 8.250 114.40 8 4-1 f2-IF 23.22 24.17 Stabilizer 8.375 Ref Housing Stabilizer 8.250 3 Geo-Pilot 7600 Flex Collar 5.000 1.713 76.00 9.20 33.37 4 6 34'Inline Stabilizer(ILS) 1 6.800 1.920 8.250 113.90 B 4-1 2'IF 3.77 37.14 5 6 3'4'DGR Collar(Gamma) y 6.750 1.920 97.80 B 4.1 2'IF 4.55 41.70 DGR Insert 41.70 DDS Insert 41.70 6 6 3'4'EWR-P4 Collar(Resistivity)J 6.750 2.000 104.30 B 4-1/2'IF 12.10 53.80 EW R-P4 Insert 53.80 7 634'PWD(Pressure) 6.750 1.905 96.30 84-1/2"IF 4.44 58.24 8 6 34'HCIM Collar(Processor) 6.750 1.920 101.70 8 4-1/2-IF 4.97 63.20 HCIM Insert 63.20 9 6 3 4'ALD Collar(Density) 6.750 1.920 8.250 104.30 8 4-1/2-IF 14.54 77.74 Stabilizer 8.250 ALD Insert 77.74 10 6 3'4'CTN Collar(Neutron) 6.750 1.905 102.30 B NC 50 11.84 89.59 CTN Insert 89.59 11 6 34'TM-HOC(Puller) 6.900 3.250 103.60 B 4-1/2-IF 15.50 105.09 12 Non Mag Float Sub 6.750 2.750 101.71 B 4-1/2'IF 3.00 108.09 13 6-34-Non Mag Flex Dnll Collar 6.750 2.813 100.77 B 4-112'IF 30.00 138.09 14 6-34'Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-112-IF 30.00 168.09 15 6-34'Non Mag Flex Drill Collar 6.750 2.813 100.77 30.00 198.09 16 6 Joint 5'HWDP 5.000 3.000 49.30 180.00 378.09 17 6-1 4'Weatherford Hydraulic Jar 6.250 2.250 91.01 30.00 408.09 18 14 Joints 5'HWDP 5.000 3.000 49.30 420.00 828.09 -'TO 828.09 Page 19 Revision 0 May, 2017 I0 HGP 11-24RD Drilling Procedure Rev 0 i l i leorp:11a.ka.1.1.1: HALLIBURTON i orifi Bice Specification Sheet (1033603) s services 8-1/2"(216 mm) MMD75DC Product Specifications 1 gaL_rlirCtel, Cutter Type Select Cutter Mur- 44 IADC Code M422 w r; Body Type MATRIX ' ""�; Total Cutter Count 65 le .4tsir Cutter Distribution 13mm 16mm Face 0 46 `'1 t f�/ . Gauge 0 12 It - Up Drill 7 04 ! - i ffi Number of Small Nozzles 7 3 .4' r l' is Junk Slot Area (Sq in) 12.75 # * ;�'" Normalized Face Volume 41.24% t..; �r , ` 4100 -00� ' ily1111 API Connection 4-1/2 REG. PIN Recommended Make-Up 12,461 —17,766 Ft*lbs i►,, Torque* Nominal Dimensions" o 8 4111k`"`"... Make-Up Face to Nose 11.42 in -290 mm 4; jori tel. Gauge Length 3 in-76 mm Al Shank Diameter 6 in-152 mmx: 1 ++ a ..80 1J ilk Break Out Plate 181954/44040 ' r ���'• " (Mat.#!Legacy#) x* '"" Approximate Shipping Weight 180 Lbs. -82 Kg. •� • • • Special Features1i :.• •• 0.i is• VW . •• ••1 • EDL Tool Specific Gage •♦ s•• ••• • Carbide Impact Arrestor • Optimized Dual Row-"D" Feature • Combo Cutters on Gage Pads Material# 1033603 Page 20 Revision 0 May, 2017 • GP 11-24RD Drilling Procedure Rev 0 Hilcorp Alaska,LLC 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill 8"hole to 13083' MD using motor assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss <6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.11 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.12 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.13 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 May, 2017 S GP 11-24RD Drilling Procedure Rev 0 Ililcorp Ala.ka,1.1.(' 15.0 Run 7" Production Liner 15.1 R/U Weatherford 7" casing running equipment. • Ensure 7"DWC/C x 4-1/2" CDS-40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total # of joints 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. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • No centralizers to be installed on shoe joint, FC joint, and LC joint. • Install centralizers, one per joint to +/- 10,000' TMD, and leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe & FC. 15.4 Continue running 7"production liner • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7" DWC/C M/U torques Casing OD Minimum Maximum Yield Torque 7" 19,200 ft-lbs 22,100 ft-lbs 25,000 ft-lbs Page 22 Revision 0 May, 2017 s • GP 11-24RD Drilling Procedure Rev 0 Hilcorp Alaska,LLC. Technical Specifications Connection Type: Size(O.D.): Weight (Wall): Grade: DWC/C Casing 7 in 26.00 lb/ft (0.362 in) L-80 2012 API SPEC 5CT COUPLING O.D. Material L-80 Grade 80,000 Minimum Yield Strength (psi.) 95,000 Minimum Ultimate Strength (psi.) U SA Pipe Dimensions VAM USA 7.000 Nominal Pipe Body O.D. (in.) 4424 W. Sam Houston Pkwy. Suite 150 6.276 Nominal PipeBodyI.D. in. Houston. 77041 ( ) Phone: 713-479-3200 0.362 Nominal Wall Thickness (in.) Fax: 713-479-3234 E-mail:VAMUSAsaIes@vam-usa.com 26.00 Nominal Weight (lbs./ft.) 25.69 Plain End Weight (lbs./ft.) 7.549 Nominal Pipe Body Area (sq. in.) Pipe Body Performance Properties 604,000 Minimum Pipe Body Yield Strength (lbs.) 5,410 Minimum Collapse Pressure (psi.) ,.- 7,240 Minimum Internal Yield Pressure (psi.) 6,600 Hydrostatic Test Pressure (psi.) Connection Dimensions 7.875 Connection O.D. (in.) 6.276 Connection I.D. (in.) 6.151 Connection Drift Diameter(in.) 4.50 Make-up Loss (in.) 7.549 Critical Area (sq. in.) '' 100.0 Joint Efficiency (%) Connection Performance Properties 604,000 Joint Strength (lbs.) 16,590 Reference String Length (ft) 1.4 Design Factor 641,000 API Joint Strength (lbs.) 302,000 Compression Rating (lbs.) 5,410 API Collapse Pressure Rating (psi.) 7,240 API Internal Pressure Resistance (psi.) 26.2 Maximum Uniaxial Bend Rating [degrees/100 ft] is Approximated Field End Torque Values 18,300 Minimum Final Torque (ft.-lbs.) 21,100 Maximum Final Torque (ft.-lbs.) ' 23,800 Connection Yield Torque (ft.-lbs.) Page 23 Revision 0 May, 2017 GP 11-24RD Drilling Procedure Rev 0 I lilcorp Alaska,LLC 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 15.8 Before picking up Baker SDD liner hanger/packer assy, count the# of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker SDD liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/liner on DP no faster than 1 min/stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 8-1/2"window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. • 15.19 Reciprocate &rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 ❑ilcorp Ala.ka,IAA 16.0 Cement 7" Production Liner • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 15 bbls 12.5 ppg spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Mix and pump 141 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to bring cement up to 7" casing and 8-1/2" open hole. Est TOC 8500' TMD. 16.6 Displacement fluid will be drilling mud. Cement Calculations 8-1/2"OH x 7"Liner: (13083' —9000') x 0.02259 x 1.25 = 138 bbls Shoe Track: 80' x 0.03715 = 3 bbls Total Volume(bbls): 138 +3 = 141 bbls Total Volume(ft3): 141 bbls x 5.615 ft3/bbl= 792 ft3 Total Volume(sx): 792 ft3 / 1.34 ft3/sk= 591 sx Page 25 Revision 0 May,2017 Y� O 1111 GP 11-24RD Drilling Procedure Rev 0 llileorp Alaska,l.LE: Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF/ 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2% BWOC Additives D202 Dispersant 1.5% BWOC D400 Gas Control Agent 0.8% BWOC D154 Extender 8.0%BWOC 16.7 Drop DP dart and displace with drilling mud. 16.8 Pump cement at max rate of 8 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point 16.9 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.10 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.11 Slack off total liner weight plus 30k to confirm hanger is set. 16.12 Do not overdisplace by more than V2 shoe track (-1 bbls). Shoe track volume is 2 bbls. 16.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 May, 2017 S GP 11-24RD Drilling Procedure Rev 0 iiileorp Alaska,LLC 16.14 Bleed pressure to zero to check float equipment. 16.15 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.16 Rotate slowly and slack off 50k downhole to set ZXP. 16.17 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS profile. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area(ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). �. 16.18 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.19 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 16.20 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.21 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.22 If the HRD-E tool still does not release hydraulically, left-hand(counterclockwise)torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.23 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 16.24 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point,the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 May, 2017 S GP 11-24RD Drilling Procedure Rev 0 Hileorp Alaska,TIC Ensure to report the following on Wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Note: Send Csg& mit report+ "As-Run"liner tally to mmyersWzilcorp.com Page 28 Revision 0 May, 2017 • GP 11-24RD Drilling Procedure Rev 0 lileorp Alaska,I.I.I'. 17.0 Wellbore Clean Up & Displacement 17.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 6"bit or mill • Casing scraper&brush for 7"26# casing • +/- 4463' 4-1/2" DP. • Casing scraper& brush for 7" 26#casing • (2000') 4-1/2" DP • Casing scraper&brush for 7"26# casing • 4-1/2" DP to surface. 17.2 TIH & clean out well to landing collar(+/- 12,963' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 6"bit is worked down to the landing collar. • Space out the cleanout BHA so that the 6"bit reaches the 7" landing collar when crossover is +/- 30' above the 7" liner top. S 7 1 �t 17.3 After wellbore has been cleaned out satisfactorily using mud,test casing to 2000 psi/30 min. Ensure to chart record casing test. 6 17.4 Displace drilling fluid in wellbore with a hi-vis pill followed by filtered inlet water. • Circulate 3 to 4 B/U until clean-up is satisfactory. Do not recirculate fluid, pump and dump • After a couple circulations using FIW, short trip the assy to bring the upper 7" scraper assy to surface. • RIH again &tag landing collar w/6"bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Pump a chemical train followed by FIW. Target NTU's are 80-100 17.5 TOH w/clean out assy. LDDP on the trip out. Page 29 Revision 0 May,2017 S i GP 11-24RD Drilling Procedure Rev 0 Ilikorp Alaska,TIC 18.0 Run Completion Assembly 18.1 Run 2-7/8"X 2-3/8"tubing completion assembly as`per [`separate Approved Completion Sundry 19.0 RD 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE,NU tree, test void 19.3 Rig Down Page 30 Revision 0 May,2017 O GP 11-24RD Drilling Procedure Rev 0 11i1r orp Alaska,LLC 20.0 BOP Schematic F Floor 16" Pipe III'Illi I(II IEI • !Mil III III III III III III Shaffer 13 5/8 5M III III ItI ISI III Shaffer SI — 2 7/8-5.5 Variables • 1.fi 3 I 13 5/8 5M it- Blind 2 1/16 51"1 manual valves 2 1/16 5M manual and HCR valve 111 Ill Ill III 111 1.76 • 1^ : 1t1' • l;,1�11:i! • � :kl101 111111111 Ili ill •• v411 Shaffer SL !r - 13 5 8 SM _ _ 2 7/8.5.5 Variables 1.44' --- -. III Iii III III It! Drill deck 13.70' Riser 13 5/8 5M FE X 13 5/8 5M API hub 0 Page 31 Revision 0 May, 2017 • GP 11-24RD Drilling Procedure Rev 0 Ili!eorp Alaska,1,I.1: 21.0 Wellhead Schematic Granite Point NO TUBING HANGER;t 11-24 WELL 18X133/8X95/8 BHTA,OW,external knockup i 1/8 5M FE 1�t� ^r Valve,Swab,McEvoy-C, j. 3 1/8 FE,HWO, EE(( '4; EE trim 11111 Valve.Master,McEvoy{. • �r 3 1/8 5M FE,HWO, EE trimL/� r1 Valve,Master,McEvoy-C, Irk . 11110. 31/85M FE,HWO, . EE trim (ro. 7;1":,. Adapter,FMC-ASP,13 5/8 5M API clamp X 3 1/8 5M,w/ hi 6.990"extended neck pocket Unihead,OCT type 2,13 5/8 SM API hub top X 13 3/8 STC casing bottom. '. fAL w/2.2"LPO on tower section,2.2 , MIIMI • 1/16 SM SSO on upper section,IP Internal iodtpin assy111111111 f tw P. kof f is not seated.n wellhead Valve,OCT-20,21/16 SM ' _'r ,�m�I '� 9 trim j 42��F 1 1. MNI r!. gm. ��r,..a::: �.I. Starting head,OCT, ■�.`; 21 1/4 2M Hub x 24 SS 1M Ili ifve OCT.2o 2 t PO. Hub w/2-2"LPO,prepped f/ tom AA trim 1114 EN hanger �111111111111121 /-1111 •-I• Conductor housing, , 224&Ah etbd ji II Page 32 Revision 0 May, 2017 • GP 11-24RD Drilling Procedure Rev 0 IIiloorp.Ua.k:�.I.1.1: 22.0 Days vs Depth Days Vs Depth _ GP-11-24RD 2000 4000 .-. 6000 s n 4) v v U, N A d i) 8000 10000 12000 14000 0 5 10 15 20 25 30 35 Days Page 33 Revision 0 May, 2017 GP 11-24RD intDrilling Procedure Rev 0 Ililorp:Ua,ka.1,1.1: 23.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: GP 11-24RD FIELD: Granite Point SURFACE X. i X=263398.89 STATE: Alaska SURFACE Y. Y=2544542.44 BOTTOM HOLE X: X=265670.00i TVD REF DATUM KB BOTTOM HOLEY Y=2539736.00 TVD REF ELEV 128 COORD REF.SYSTEM NAD27 AK4 True North GROUND ELEV 0.0 PROPOSED TD. T 13083 MD WATER DEPTH 75.0 PROPOSED TD: 10521 TVD Sidetrack well 11-24 and drill a 2000' lateral through the Tynonek C5 SAND Objective: Geo Summary/ C5 lateral well through untapped oil wedge on east flank of field. Justification: GP 11-24RD TARGETS,ANTICIPATED FORMATION TOPS& GEOHAZARDS ," FLUID KOP 8500 7873 3408 8.3 0.43 C2 Sand Oil/Water 10347 9367 4656 9.6 0.50 C5A Sand Oil/Water 10947 9798 4911 9.6 0.50 TD Sand I Oil/Water 13083 I 10521 I 5184 9.5 0.49 = Primary Objective =Secondary Objective pramialIP 4 50 FT _._...._.._.. DATA COLLECTION REQUIREMENTS: Mud Logging: gas monitoring and cuttings description M/LWD Data: MWD/GR, resistivity, neu,den,dipole sonic E-Line Log Data: RFT,SWC COMPLETION TYPE 7"casing to TD&perf(1500') ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD Run Tubing and Gas lift Valves TUBING SIZE Page 34 Revision 0 May,2017 # 40 GP 11-24RD Drilling Procedure Rev 0 llileorp.Alaska,T.I.0 24.0 Anticipated Drilling Hazards Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual-composition carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 35 Revision 0 May, 2017 in" • • GP 11-24RD Drilling Procedure Rev 0 IIIeorp:1,la-ka.IAA: 25.0 Rig Layout // f/ i'li ��1. ��r. ikt131 ' i.C1)1(4. _ 3 1 0 ely jrc'1" ky •Y t,1 OiA ''fff q� y S.F i 1 - 1J -te,P ' �. rY 51 \11 •t f' I Il 1 il Z.1 I Ma --__ fi li r� ,� nY 43 til �.— � pi rust law st...aftwrm it �� ‘‘ \ .'''.2 UJ A \ N`L\14‘1 / $Q \ ,.. ki ' - 41 -% \\\,. - v. t...-- —.is., [7,2,4%,, 4 I I �-a ,f-V. 1 GsC 3= Page 36 Revision 0 May, 2017 40 4111 GP 11-24RD Drilling Procedure Rev 0 iiilcorp Alaska,IA 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) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure.Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 37 Revision 0 May,2017 • • GP 11-24RD Drilling Procedure Rev 0 I lite orp 27.0 Choke Manifold Schematic Choke Manifold Valves 2" 3" To Shaker 3" Panic To Gasbuster 3 1/8" 2 1/16" © 2 1/16" —1111--10-111 2 1/16" 2 1/16" ©�io � 31/8" I '?/" t f 2 1/16" 4;42 1/16" Manual Choke Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1118" 5,000 PSI VALVES AND LINES BLUE = 2 1/16"5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold C2 fir' \ R 1e 4 2 Ct ff15 101 huukpik Doping Rig b Choke Manifold Page 38 Revision 0 May, 2017 0 • GP 11-24RD Drilling Procedure Rev 0 Iill•orp Ah.la.1.IA: 28.0 Fluid Flow Diagrams i x- x T. n SS W _ 1 1 1 1 ( 1 1 1 I ' a f In i41".la lu 4 ie 1111`t = X I I I I A I I i Cl IJ. 11.114 I1.I1.1114 11.1114 112 11. I, Ij I:I:a I:i'LZ'1t-,i.! r� IP IP Ip 1p iplP is 11 ip I'}cC 11 I luQ 11' 1 IL'I' t i0 inIt inin!i?T ipic !?:•!;:!.;!+t o I n!;!;! n : I il2 � v0)ata"I "1I"I" " FFF p0) g V —X DG—• G) d A 0 --"'7d coo S wo O ` C e X. co o ' K NX a %8 S = o Z i i i I i i i I I I� o _ 1�1^Iit;IM 11.1411+I�10 ioL. a Z.� I i i I i i i i l I !'"!,'Ji1.4ItN1411�P.I N �• Co CD 2,' i iC iii:igi i gi yO It la in'Ip dla la iPi (7 I.ir!li IA I' IIA If I i I'QQ"it S Ini01 igigi i Ig ISI• a) , �t Io,41,4,...*,.,....„.. ..)ICD - �• in! !1:'!O in!ITT ip i NX i G I IIIA it it iw IwI;I I O r .l inintninin,nlnin1 i !r TrV!r!3.!V3.!B. a!ra!"a;a!a!a!a!a!a a 1 t if: r. , 10111 _ 4 i i e i IV((JJ�]] N n IVX I 1 I 'A1 I i i~ - I:w',, 11411.'-101,`" NX N N i i i_ i 1 i I NQ W A !i I.. !O1...1 V IX 00 D4 i i i ig 1"I IS I I iq 1,&I 0, A w I i 1 s i•Iy1 4Y 1 Ir IN it I I is I-Ir 1� ♦I.i�I i1 i igiP ja cEi-Ini>$ v' n'Xi.4i0 c K c0 i roy- I �_I I� 1 i:•i, is ie 1 Ir. y a ® .o a o i 15I_ iq I-I 16 CA O i In IT k ir'I I! a 1 I I 171;6.I ii q � 1�IS 31tpn 1,9'�2:;12yy i±i"Iaia{" 1ais r C P. Page 39 Revision 0 May, 2017 • HEGP 1 1-24RD Drilling Procedure Rev 0 IIit orp Alaska.iii: r n T v 77. o 4 y !—� y� A U O I. W E _ I i i t t i l i t . U: co 1 I I i I I i I II n• fJ. 1,..I..,,,,,...0.1•..1,..0.,......!:,.. (�,1"ir,li�ir�-,Iil (..rt iQ iQ i"'it i°i iQ ie'M i* i i S IoM i iii I i 1 Ig19 Iq1� .!� (� • IC)inini4)inICI ICI iniCI igl2Ilgiqlilqi. IN i•0 .42 I.0 1�19 14 "a ♦ A A A 7 I.•'0 ' J • • loi$ieii" i' i' i° iO ri CTl • •07 •V I I I i° I I I 7 I //''�� *4 ►4 U I CO1 D.T 1+ • 0 W• •—i E CO 4 X- • CD X r W •• (V _a a0 i ID M A r I t Y =y .• • V. i 1 i 1 1 i I 1 I I¢ . 0 . fr Ict,r410`I'1.I60"1"1""tolr CO• Q A V (1 L, t ,I l i I i i i .I, -- I 14 it.I��I"IV 1�Ii..I..'i a; �� Ci !el I I t-.I,..I i s i- N 0 b I'1U IP Ia IUQ i?w ioi+IP1 1,intSQ4y�l I`�yT'IQQQQQQIQQQQI Iii 3 Ie1 1,E i 1o1919"110i 4 ` 7: i�i�i::.iw iw Ift�.i4 19.1 @ `� /1 I 1A 1• IA I.in 10 1.I.I 0•14 IWiliCliriViViiincli --t T 2 S o I$I$I$I$t$I$I$I$ip M • f til , 10 P-1f S. r ♦ i j N v � Y N• it 3 N �• 1 1 1 7i 1 i 1« i i , Iiioi� r �N • W A i ; 4 DQ D4 i i i ioi.I i' i !..!•-) !H i. - c: i i$ii is I•' I iv I 1./ I, 141r i Ip G 1_1; 1_ ,:,C l. I. t Ir - T i�lyyi6 �i_i:Iti IP "o 0 1'O rs d l ice-170 10 A -D K' C .Z. 1 i'1' fA It^i*'t iA C -n i !'.4.-'!e_"' iiiii i i6 N C�. Q� _~• 1 p* ig 1...,1:11, 1.... "' d' i i i i•tv I%1• i �_ I t i I• i� I IA O I Ir)I 'I i inl o C b0i$b0 'ObOi$-O 0 n • A 9F . v le ig.le Fie is lies s Page 40 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 IIilrorp Ala-ka,1.Ll: X _ n r F _v • Y C s W • II 1 1 I 1 I I I ✓ .D =_ cpmya Itl114.!•!v!..!- E6 W flw 1 1 1 1 1 1 ti l V 1 1 1 1 1 1 n it.iNi..i..i..iNiui..i.. I►.1r`.1:.1:.G..1.::1.:.I.:.I :i •0,0,0,0+.0,0, O. O. 0, 4 4 LA1 11 11 SI II II It II II I � II � i ;65. I I4.tFI`I`I�.I�1`I�1` •Y E•Y•Y•Y•Y•�1•�.•Y IA iA 1 1A 1ll IA IA Iq Iq i i i l l i i i i Ininl I 1 101 101 .i-rrxrzri mi0i �— •& a is•s • s•s•s pa D4 0 c n 3. e A O Wp L1-' Q 7R C � 2. Y — W C Ca CD d NQ - Xo o E. A Pa 0 .....! 1 1 1 I I r t 1 I ieevee i d I�I.;�Iply�l�,ly l�j l.—.lpiP. CO v 1 1 1 1 1 1 1 1 1 1+Q. Pa , fla Pa �a 1• 110141t..u.!..•;; N CO c0 I 1.1".....I.,.2'1.","1/..!..1.&...""! 11.11I�IPIa11114iQIP1 O 1�1-1 1,II IIw1 1,zl :1i S A 0. W. Iq 1.11-0Iit.i-in-ir.. ti1 -I OO7 I 1�1ra 1E iiiVi IVii I OV ry -n O• I 14 IZ IA iT IZ lA 1A 1A I _r f f 1 7 1 1 ( 1 1 1 7 • n.n,n .n.n.nn r ISlsls !o!V !� .•..'r •iw i"l'1v lq fq I'l' . �p •1 IGI Iii l l I (�'� 4 o 4 oa •v N Y^ e ® a cn g i 7 N v c Y .....A A 1 1 1 X1 r r 1: :4 ithj�jy ir 11141.=dojo E,Np N N i i i i i i i c co A I i i l i 1 i o PQ D'a 1 1 i ieii 1 IS A <n 1 i iCa I'll I. i Ire i+Iy1 !• _. 1 Iv, ' i�i�I IE 73 O I IY I� ♦IY I�1.�.I- .r - (» m 1 boi°y 1-1 Ince c n TJ fro b *i=iiAiF • C OP 1 •i•i•i� 1rr�i IC. N d ci —0=..• f 171 if i•i le �' 1 1 1 1%i.1 1'4o I 1 1 1�t 1 14 < 410 [244:4, y ID a Page 41 Revision 0 May, 2017 • GP 11-24RD Drilling Procedure Rev 0 Ilileorp:1la-ka,i i is 29.0 Casing Design Information Calculation & Casing Design Factors Cook Inlet Offshore DATE: 8/22/2017 WELL: GP 11-24RD FIELD: McArthur River DESIGN BY: Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 2735 psi (See attached MASP determination & calculation) Production Mode MASP: 5155 psi (See attached MASP determination & calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.43 psi/ft) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 7" Top(MD) 8,300 Top(TVD) 7,680 Bottom (MD) 13,083 Bottom (TVD) 10,521 Length 4,783 Weight (ppf) 26 Grade L-80 Connection DWC/C Weight w/o Bouyancy Factor(lbs) 124,358 Tension at Top of Section (lbs) 124,358 Min strength Tension (1000 lbs) 604 Worst Case Safety Factor(Tension) 4.86 Collapse Pressure at bottom (Psi) 4,524 Collapse Resistance w/o tension (Psi) 5,410 Worst Case Safety Factor(Collapse) 1.20' MASP (psi) 2,735 Minimum Yield (psi) 7,240 Worst case safety factor(Burst) 2.65 Page 42 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 II ileorp:'Luka.I,I,I: 30.0 8-1/2" Hole Section MASP Maximum AnticipatedSurface Pressure Calculation Hilcorp 8-1/2,Hole Section Fncrgy GP 11-24RD Cook Inlet,Alaska MD ND Planned Top: 8500 7873 Planned TD: 13083 10521 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad KOP 8154 3533 COAL 8.3 0.43 C2 9367 4656 Sand 9.6 0.50 C5A 9798 4911 Sand 9.6 0.50 TD 10521 5184 Sand 9.5 0.49 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date A-27RD2 9.3-9.5 7,755 9,718 2016 K-24RD3 8.9-9.3 8,768 9,994 2017 A-27RD 9.5-9.7 6,328 9,950 1997 K-06RD2 9.0-9.3 6,352 9,792 2017 Assumptions: 1. Anticipated fracture gradient at 8500'TMD(8154'ND)=0.7=14.9 ppg EMW 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assumes 9.2 ppg reservoir contains 2/3 gas,1/3 water. Fracture Pressure at window considering a full column of gas from window to surface: 8154(ft)x 0.7(psi/ft)= 5708 5708(psi)-[0.1(psi/ft)*8154(ft)]= 4893 psi MASP from pore pressure;normal gradient at TD,(0.49 psi/ft) 10521(ft)x 0.49(psi/ft)= 5155 psi 5155(psi)-(0.1(psi/ft)*10521(ft))= 4103 psi MASP from pore pressure;unknown gas sand at TD,at 9.4 ppg(0.49 psi/ft) 10521(ft)x 0.49(psi/ft)= 5155 psi Downhole yo 1�S 5155(psi)-[(2/3)*0.1(psi/ft)*10521(ft)]+[(1/3)*0.49(psi/ft)*10521(ft)]= 2735 psi Drilling M GAl' Summary: 1. MASP while drilling 8-1/2"hole is governed by pore pressure minus 2/3 of wellbore evacuated to gas(remaining 1/3 remains 9.4 ppg drilling fluid) Page 43 Revision 0 May, 2017 H • • GP 11-24RD Drilling Procedure Rev 0 II ilcorp.\la.ka.LI.I: 31.0 Plot (NAD 27) (Governmental Sections) s 1 1 SMUCI-03 BHL Legend /' / GP 11-24RD_SHL Other Surface Hole Location GP-31-13 BH: // 1 / GP 11-24RD_TPH • Other Bottom Hole Location 1 // i / — Well Paths GP 11-24RD BHL / ' ' 1 ‘ 1 y-_._ GR-31-14RD1 1 1 t // / f -31-13R14R- - BHL` 1 1 t `�.,� BHL r �� 1 I f // //! moi. \::..............: t I //� , 1111 I1 GP-22-13 BHL GRANITE `• 1,1,,' `�</ POINT 1 1 ---._-_________._____. _.__--UNIT----- ____ -UNIT=_= 1 _ ___GranIte;r t..' GP II-24RD SHL` , „....-- : .•. 6 y.,. . ^� GP-32.13 8HL iii r k,",, SO10N01r2W, S010N01r2W Poe.94r9n GP-13-1'38ML /'/ !! ;I 1 GP,69'8 L :l i _ • 8 a • rrr ,..,..c.„...„/ 1 :I 1 �, -GP`33-13 BHL . . . , SO1DNO19 7 / , f : I 1 • Sec.913 , ,' /ff / : I 1 / f t : I 1 / / I . , , , / / 1 . , .a4-14.ent' ,/ / 1 ADL018761 - i // // P..55 8HL/ I 1 ,, `gP32.13RD / / / 11 I 1 `. ,*HL F • //r// �/ • `I '....GP -32 / / / 1 GP-24-18 BHLf P 24-13RD BHL / // 1 4 BHL / / /1 I / / / / / / / I • / / / I / fQP•I1-24 8HL ( i / ,.GP, 24P8 I / / / BF1L I r / / / °°°ad // / / /1' 1000,01°°°O I GP I I-2-3RD_TPH / / I / °° / / 0 // 0 I 0 / I 0 / I / ° // I / °0 S01ONO12 1// SO1ON012•W ,' A Vigil �'° ' 1 SO1ONO1 tin / 1 °° //(it'I l-2-1RD__t3ItL 0 //// Sec.90 GP-2-24 BHL.--r 1 1 1 1 1 r 1 1 / II 0 500 1,000 1.500 Granite Point Unit Feet GP 11-24RD Alaska State Plane Zone 4,NAD27 I I a„o p 11aaka.I.1.f Map Date:8/17/2017 Page 44 Revision 0 May, 2017 • • GP 11-24RD Drilling Procedure Rev 0 I rl•orp.41:1.1<:1.1,1,c 32.0 Slot Diagram (As Built) (NAD 27) 2 PROTRACTED SECTION LINE NOT TO SCALE(NTS) 74 13 -----1 ci: 1 it 1 SECTION CORNER (PROTRACTED) N:2546957.328 E:262081.754 i CENTER LEG 2 U) LAT:60°57'29.91087"N I' e- LON: 151°19'53.20585"W Z • N:2544611886 W r▪ E:263360.744 -. ASP ZONE 4 NAD 27 • U 2319'FNL 1/) g1326'FWL // ,.....\\ I I— / \ N1 S'.ELIS 12 00 S.OI S C)`'-1' 1326'FNL(NT$} OBSERVE() z+ Z CENTER LEG 1 G LAT:60'57'29.46354'N 40 LON: 151°19'54.53958"W ti W N:2544567808 E.263293.981 J ASP ZONE 4 NAD 27 z2364' 2364'FNL EuaTr .8 , 17- 1260'FWL W 4"... 1,1PTY LLI .ir V) :1t.14RG] .0• 1224 , u9.....-A,_u60 `"`("'Sig,`r•41 3223 GRANITE(POINT PLATFORM CENTER LEG 3 0 E"°'' J'''it`s ' b.W ASBUILT WELL LOCATIONS PS, $Rp LAT:60'57'29.26234"N �cr< �� SECTION 13 T1ON R12W "'' LON:45419'sz.28sa8"w I— 44.0 EMPTY __. ... N:2544545.320 11,1300 .W31W va_1 E:263404.821 O..__A, Cf 1371'FNL WS)-r 657)-1-mg'I- ASP ZONE 4 NAD 27 -.,�•• E OPCI 2 2385 FNL 11-2 W f� 1371'FWL ��,1J W 32 13RD 42-2300 00.53 24-1.300 EMPry EMPTY EMPTY MP TY •' CENTER LEG 4 '"'—'1� -----1305,FW.WS) EMPTY - ; 5' LAT:60°57'28.81798"N ( ) '_; �..S_u LON: 151'19'53.62548"W EMP1V •. !.o' N.2544501.349 • •..4 s.3 E:263337.774 ASP ZONE 4 NAD 27 +0,,NNA,IA EMPTY EMPTY 2430'FNL EMPiY 1305'FWL ='��•O'F AL, 1�I 2 o.' 1,. Sf'V, NOTES .--Ari i* ,yk'j 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION(EPOCH / 2010)AND VERTICAL CONTROL(NAVD88)IS AN OPUS SOLUTION FROM i -.row' 00 NGS STATIONS TBON.TSEA,AND ANC2 TO ESTABLISH POINT#1100 THE r t. (AIN C.BROWN : ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: .. �3 / Zr E=1403394.313 1.111111, 6 ifLT/i!I''' a ELEV.=115.958(NAVD88) �0I`‘\\"`%���. 2.SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED VALUES. SCALE 3. COORDINATE CONVERSIONS(NAD83-NAD27)WERE DONE USING c 30 co `CORPSCON SOFTWARE VERSION 6.0.1 I ' 1 FEET INIF ''--``- HILCORP ALASKA.LLC °E �°" - GRANITE POINT PLATFORM WELL SLOTS °"'°' ''="' COOK INLET ALASKA °"" "°Y ° AS BUILT SURFACE LOCATION 004,1 "0 NAD 27(FOR INFORMATION ONLY) PROJECT NO "` L.`G G,SURVEY*.r TEsne.G BOOK 1a0 ,.... �EE0 BOX.PP FAX.°.,,M VOICEO1SC>120N21E {SPTiro»_wa PROTRACTED SEC. 13 T10N R12W SHEET EMAIL S.McuNEg1Oc.NEC000M IHil orp Alaska.LLC 3 SEWARD MERIDIAN,ALASKA " Page 45 Revision 0 May,2017 + i GP 11-24RD Drilling Procedure Rev 0 na,•„rp 'Ia,.ka.1.I.1: NAD 27 WELL SLOT NORTHING EASTING LATITUDE(N) LONGITUDE(W) CL LEG 3 2544545.120 263404.821 60°57'29.26234" 151°19'52.28588" 31-13 1 2544550.59 263401.139 60°57'29.31546" 151°19'52.36268" 22-13RD2 2 2544551.711 263405.531 60°57'29.32737" 151°19'52.27421" MUCI-1 3 2544549.723 263409.592 60°57'29.30862" 151°19'52.19116" MUCI-2 4 2544545.606 263411.397 60°57'29.26844" 151°19'52.15293" 32-13RD 5 2544541.274 263410.117 60°57'29.22553" 151°19'52.17707" LEG 3 24-13RD 6 2544538.84 263406.528 60°57'29.20086" 151°19'52.24873" 42-23RD 7 2544539.235 263401.999 60°57'29.20384" 151°19'52.34061" x43063 8 2544542.441 263398.892 60°57'29.23478" 151°19'52.40484" 11-13125 9 2544546.905 263398.51 60°57'29.27865" 151°19'52.41439" EMPTY 10 2544543.272 263406.149 60°57'29.24441" 151°19'52.25823" GP-S0 11 2544545.15 263402.616 60°57'29.26219" 151°19'52.33053" GP-51 12 2544547.233 263405.593 60°57'29.28330" 151°19'52.27110" CL LEG 4 2544501.349 263337.774 60°57'28.81798" 151°19'53.62548" EMPTY 1 2544506.617 263333.993 60°57'28.86909" 151°19'53.70421" EMPTY 2 2544507.720 263338.358 60°57'28.88083" 151°19'53.61627" 54 3 2544505.736 263342.508 60°57'28.86212" 151°19'53.53143" 55 4 2544501.552 263344.322 60°57'28.82129" 151°19'53.49299" 53 5 2544497.344 263342.958 60°57'28.77958" 151°19'53.51888" LEG 4 52 6 2544494.923 263339.453 60°57'28.75505" 151°19'53.58885" EMPTY 7 2544495.296 263334.763 60°57'28.75778" 151°19'53.68396" EMPTY 8 2544498.575 263331.660 60°57'28.78944" 151°19'53.74816" EMPTY 9 2544503.081 263331.389 60°57'28.83376" 151°19'53.75548" EMPTY 10 2544499.473 263338.980 60°57'28.79975" 151°19'53.60030" EMPTY 11 2544501.035 263335.567 60°57'28.81445" 151°19'53.67005" EMPTY 12 2544503.340 263338.779 60°57'28.83779" 151°19'53.60597" HILCORP ALASKA, LLC �,. GRANITE POINT PLATFORM WELL SLOTS DATE 0''" COOK INLET ALASKA DRAWN B` KB AS BUILT SURFACE LOCATION NAD 27(FOR INFORMATION ONLY) PROTECT NO 177006 ftiGCrtERRJ° WPPINO:SVR'YE'WO•tE�''.� BOOK NO 16.03 P.O BOK ASO SOLCOTNA,AK SWF, t A v°IOE cx7,20..2,6 F. 0.7,:611203 PROTRACTED SEC. 13 T1ON R12W NEET EM.UL S.LKL,NEL{AICLANEOO°°°' I�ilvurp Ala•;ka. 1.1.(; 3 O. 3 SEWARD MERIDIAN,ALASKA i GP 11-24RD Drilling Procedure Rev 0 I the or1,A larks,LLC 33.0 Directional Program (wp06) Page 47 Revision 0 May, 2017 • Hilcorp Alaska, LLC Granite Point Granite Point Platform Plan: GP-11-24RD GP 11-24RD Plan: GP 11-24RD WP06 Standard Proposal Report 14 July, 2017 HALLIBURTON Sperry Drilling Services • • HALLIBURTON SECTION DETAILS .,rry Drilling Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 1 8500.00 21.61 199.00 7872.63 -2954.61 -456.48 0.00 0.00 2441.85 2 8517.08 22.76 193.76 7888.44 -2960.79 -458.30 13.38 -60.00 2446.58 3 8547.08 22.76 193.76 7916.11 -2972.07 -461.06 0.00 0.00 2455.44 4 9502.35 43.42 104.28 8752.49 -3248.74 -169.80 5.00 -111.82 2832.89 5 10599.33 43.42 104.28 9549.25 -3434.76 560.90 0.00 0.00 3324.96 6 10959.70 50.00 127.45 9798.00 -3550.21 792.41 5.00 76.98 3531.46 GP 11-24RD WP06 C5 Project: Granite Point 7 11402.19 72.12 127.45 10010.77 -3784.22 1097.93 5.00 0.00 3877.07 Site: Granite Point Platform 8 12233.68 72.12 127.45 10266.00 -4265.41 1726.17 0.00 0.00 4587.76 GP 11-24RD WP06 Mid Point 9 12247.89 72.53 127.57 10270.31 -4273.66 1736.90 3.00 16.11 4599.92 Well: Plan: GP-11-24RD 10 13083.12 72.53 127.57 10521.00 -4759.49 2368.36 0.00 0.00 5316.19 GP 11-24RD WP06 BHL Wellbore: GP 11-24RD Design: GP 11-24RD WP06 SURVEY PROGRAM Date:2017-07-14700:00:00 Validated:Yes Version: WELL DETAILS: Plan:GP-11-24RD Depth From Depth To Survey/Plan Tool Water Depth: 75.00 122.00 297.00 GP 11-24 PB1 CB-Gyro(1)SU-3-16161 CB-Gyro-MS +N/-S +E/-W Northing Easting Latittude Longitude 322.00 652.00 GP 11-24 PB1 CB-Gyro(2)SU-3-16163 CB-Gyro-MS 0.00 0.00 2544542.44 263398.89 60°57'29.235 N 151°19'52.405 W 722.00 4022.00 GP 11-24 PB1 CB-Gyro(3)SU-3-16174 CB-Gyro-MS 4122.00 8500.00 GP 11-24 PB1 CB-Gyro(4)SU-3-16199 CB-Gyro-MS CASING DETAILS 8500.00 8850.00 GP 11-24RD WP06 MWD Interp Azi+sag 8850.00 13083.12 GP 11-24RD WP06 MWD+SC+sag TVD TVDSS MD Size DDI = 6.175 10521.00 10393.00 13083.12 8 1/2"x 7" 1000 Start Dir 13.38°/100':8500'MD,7872.63'TVD:60°LT TF 6750- -le)5 q4 jv0 NO 00' 191611, 1�flso, A5000 ' �t< g5 _a54T p8 CSO 10 0- c 7500- 8�a i i E�atOa 01,0 00,b O 535249 054925 500 = - _ 5 35 3 0°' 1000- 1000 Do 8250- 55p0 8000 ��d0cc .(P°-. 0 1�59g3 01-C C`IO 66.44) 1$p0 =tr> 9000 g `a�Oc< \�� �Qo6G69�0`�00�68g 3 102aQo\�`10�1 cls 0 - S - Q 1 33. c 02 2000- 200 ) 9000_ 9500 10000 11r�4� 1102 00 • .122 �Q06 40\01- 7-0C/ti 2500 GP-11-24 P61 10000 \°, G, ��dO' <\'0.\.c 1',<k,1- 1I'T41 ,o0c0 $® o 'o �a G _,.,p‘ - �O� 3000- 0 o 9750- 10288 C5- '..�`o rA o5 O Q V 12A - 550® - 10500 ry 40p0 11000 0-3/Total Depth:13083.12'MD,10521'TVD 4000- p500 10500- _ 6000 - GP-11-24 X1500 8 1/2"x 7" GP 11-24RD WP06 0= 5000- 5500 11250- 11g00 o - I I I I i 1IiIttttI I 1 I I i I I I tIiiiiIIIIII I I I I I I I II IIIIiIi1 1tII C\I - 6000 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 rp0 Vertical Section at 153.54°(1500 usft/in) -- 66 6000 0 -- 10p0 Start Dir 13.38°/100':8500'MD,7872.63'TVD:60°LT TF FORMATION TOP DETAILS 0 q4-NO -010 TVOPath TVDssPath MOPath Formation 7000- 7600 1555. 191611 9798.00 9670.00 10959.70 C5 C - -8000 - .g51105 MO 55p1 a8 MO 52 a9 -NO bi F -sofl k1<d Oc�2ctp<<5°1100 g50235• M�140'g5g9 25 8000- 6500 00 5 nd O<< 105g9'• �O 9000- 90gc,09 1a�a 5 11p0 4R0 VNP06 MO''00101P�<nt 0 1p266 OO 9000- Approximate TOF9500 10000 -GP�1Z .11g02- \NPO6 M1 23368 2,j031 !� GP-11-24 P811000D ,O�Op o E�d�c< 1"k-• 4R01<3�I1p04'169 PP NL Qo y m" GP -5�� 122 p06 g 10288 C5 ,-'N ro;' �-,EnaO<<ZgR�v1 10000- 10500 ti -o GP.1 Hilcorp Alaska,LLC - 11000 -_Total Depth: 13083.12'MD,10521'TVD Calculation Method:Minimum Curvature Error System:ISCWSA 8 1/2"x 7"`` Scan Method: Closest Approach 3D 11000- GP-11-24 17500 Error Surface: Elliptical Conic - 1800 GP 11-24RD WP06 Warning Method: Error Ratio - REFERENCE INFORMATION 12000- Co-ordinate(N/E)Reference:Well Plan:GP-11-24RD,True North _ Vertical(TVD)Reference: GP 11-24RD WP06 @ 128.00usft Measured Depth Reference: GP 11-24RD WP06 @ 128.00usft Calculation Method: Minimum Curvature i i I i i t I I t I I I I I p i i i i r i i i i i i i i i i t t I t I t . ......... . .............. . I I I , I I ] , i , 1 1 l I E - 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 Vertical Section at 153.54°(2000 usft/in) • • (\ $;! )/ ° -k /§! f± - 6 e� « k gj cr }((\ ; z f _ en \/ E\\) 7. a)§ \ -m /§§; Q �5( (§ - \ \]}) \ a, e§ / \f ! a #e# _ / % t ) ( \ en - 2)! .7 - ( _ \� 77 ° c / � \ \) K 4 » \ , ) _ - \6 2 \ � / . 2/ - ( - 0. - \7 , \ / 0- N \( zk, 8 , - 7.= F. `\ - / e .' ® _ Ose. a[ _ _ \( \ - ( \- y d ƒ en ) \_ V / ` - ( S/ k —_ ( ( ` ` / \ 0.0� \ / ( \ s. so _ [ 2 ' z To og / k § ( ( \ \ E . g t r cr\ (0 \ _ § / \ {\'7E} \)\\ ) ° \ ,-/ - f N,be /° CD CD _ 7fa=- Og //§\§ N ƒ 5 •f 0 } \ , - + /-0\\j ` N f NI/� � \en en ' a / £ a - -Pe-li f/ -_� 9000 '- 0 ,-- Z _ - § ! ` � � ■ 2 3 I IIiiIiI1 , IIII III 11 , , II I I } } 0 an 1 0 f \ / % \ } 0 I + y ©mS&>+© -ms 0 Halliburton I-IALLIBI.JRI'DIV Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:GP-11-24RD Company: Hilcorp Alaska,LLC TVD Reference: GP 11-24RD WP06 @ 128.O0usft Project: Granite Point MD Reference: GP 11-24RD WP06 @ 128.00usft Site: Granite Point Platform North Reference: True Well: Plan:GP-11-24RD Survey Calculation Method: Minimum Curvature Wellbore: GP 11-24RD Design: GP 11-24RD WP06 Project Granite Point Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Granite Point Platform Site Position: Northing: 2,544,544.00 usft Latitude: 60°57'29.251 N From: Map Easting: 263,401.O0usft Longitude: 151°19'52.363 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.16° Well Plan:GP-11-24RD,Leg3 Slot8 Well Position +N/-S 0.00 usft Northing: 2,544,542.44 usft Latitude: 60°57'29.235 N +E/-W 0.00 usft Easting: 263,398.89 usft Longitude: 151°19'52.405 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Water Depth: 75.00 usft Wellbore GP 11-24RD I Magnetics Model Name Sample Date Declination Dip Angle Field Strength I (°) (°) (nT) BGGM2017 7/14/2017 16.12 73.85 55,451 Design GP 11-24RD WPO6 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,500.00 Vertical Section: Depth From(TVD) +NIS +E/-W Direction (usft) (usft) (usft) (°) 22.00 0.00 0.00 153.54 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 8,500.00 21.61 199.00 7,872.63 7,744.63 -2,954.61 -456.48 0.00 0.00 0.00 0.00 8,517.08 22.76 193.76 7,888.44 7,760.44 -2,960.79 -458.30 13.38 6.69 -29.95 -60.00 8,547.08 22.76 193.76 7,916.11 7,788.11 -2,972.07 -461.06 0.00 0.00 0.00 0.00 9,502.35 43.42 104.28 8,752.49 8,624.49 -3,248.74 -169.80 5.00 2.16 -9.37 -111.82 10,599.33 43.42 104.28 9,549.25 9,421.25 -3,434.76 560.90 0.00 0.00 0.00 0.00 10,959.70 50.00 127.45 9,798.00 9,670.00 -3,550.21 792.41 5.00 1.83 6.43 76.98 11,402.19 72.12 127.45 10,010.77 9,882.77 -3,784.22 1,097.93 5.00 5.00 0.00 0.00 12,233.68 72.12 127.45 10,266.00 10,138.00 -4,265.41 1,726.17 0.00 0.00 0.00 0.00 12,247.89 72.53 127.57 10,270.31 10,142.31 -4,273.66 1,736.90 3.00 2.88 0.87 16.11 13,083.12 72.53 127.57 10,521.00 10,393.00 -4,759.49 2,368.36 0.00 0.00 0.00 0.00 7/14/2017 7:32:01PM Page 2 COMPASS 5000.1 Build 81D 1110 • Halliburton I-I A LLIB JRTOI\J Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:GP-11-24RD Company: Hilcorp Alaska,LLC TVD Reference: GP 11-24RD WP06 @ 128.00usft Project: Granite Point MD Reference: GP 11-24RD WP06 @ 128.00usft Site: Granite Point Platform North Reference: True Well: Plan:GP-11-24RD Survey Calculation Method: Minimum Curvature Wellbore: GP 11-24RD Design: GP 11-24RD WP06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) -106.00 22.00 0.00 0.00 22.00 -106.00 0.00 0.00 2,544,542.44 263,398.89 0.00 0.00 122.00 0.25 310.00 122.00 -6.00 0.14 -0.17 2,544,542.58 263,398.73 0.25 -0.20 147.00 0.17 305.00 147.00 19.00 0.20 -0.24 2,544,542.64 263,398.66 0.33 -0.28 172.00 0.17 293.00 172.00 44.00 0.23 -0.30 2,544,542.68 263,398.59 0.14 -0.34 197.00 0.25 296.00 197.00 69.00 0.27 -0.39 2,544,542.72 263,398.51 0.32 -0.41 222.00 0.00 240.00 222.00 94.00 0.29 -0.44 2,544,542.74 263,398.46 1.00 -0.46 247.00 0.17 240.00 247.00 119.00 0.28 -0.47 2,544,542.73 263,398.43 0.68 -0.46 272.00 1.17 277.00 272.00 144.00 0.29 -0.75 2,544,542.74 263,398.14 4.16 -0.59 297.00 2.25 270.00 296.99 168.99 0.32 -1.50 2,544,542.79 263,397.40 4.39 -0.95 322.00 1.25 248.00 321.97 193.97 0.22 -2.24 2,544,542.70 263,396.66 4.75 -1.19 347.00 1.08 223.00 346.97 218.97 -0.06 -2.65 2,544,542.44 263,396.24 2.12 -1.13 372.00 2.58 236.00 371.96 243.96 -0.54 -3.28 2,544,541.96 263,395.60 6.19 -0.98 397.00 3.83 257.00 396.92 268.92 -1.05 -4.56 2,544,541.49 263,394.31 6.78 -1.10 422.00 4.08 256.00 421.86 293.86 -1.45 -6.24 2,544,541.12 263,392.63 1.04 -1.48 447.00 4.75 245.00 446.78 318.78 -2.10 -8.04 2,544,540.50 263,390.81 4.31 -1.70 472.00 5.75 240.00 471.68 343.68 -3.17 -10.06 2,544,539.48 263,388.77 4.40 -1.65 497.00 5.58 239.00 496.56 368.56 -4.42 -12.19 2,544,538.27 263,386.62 0.79 -1.47 522.00 5.17 240.00 521.45 393.45 -5.61 -14.21 2,544,537.12 263,384.58 1.68 -1.31 547.00 4.83 237.00 546.35 418.35 -6.74 -16.06 2,544,536.03 263,382.69 1.72 -1.12 572.00 5.33 240.00 571.25 443.25 -7.90 -17.95 2,544,534.91 263,380.78 2.26 -0.93 597.00 5.17 244.00 596.15 468.15 -8.97 -19.97 2,544,533.88 263,378.74 1.60 -0.86 622.00 5.42 245.00 621.04 493.04 -9.96 -22.05 2,544,532.93 263,376.64 1.07 -0.90 652.00 5.33 245.00 650.91 522.91 -11.15 -24.60 2,544,531.79 263,374.07 0.30 -0.98 722.00 5.00 245.00 720.63 592.63 -13.82 -30.31 2,544,529.24 263,368.31 0.47 -1.14 822.00 4.75 240.00 820.26 692.26 -17.73 -37.85 2,544,525.49 263,360.69 0.49 -0.99 922.00 3.75 225.00 919.99 791.99 -22.11 -43.74 2,544,521.22 263,354.71 1.49 0.31 1,022.00 4.75 191.00 1,019.73 891.73 -28.49 -46.85 2,544,514.91 263,351.48 2.66 4.63 1,122.00 8.50 170.00 1,119.06 991.06 -39.84 -46.35 2,544,503.56 263,351.74 4.41 15.01 1,222.00 12.25 177.00 1,217.41 1,089.41 -57.72 -44.52 2,544,485.64 263,353.22 3.95 31.84 1,322.00 15.75 182.00 1,314.43 1,186.43 -81.88 -44.43 2,544,461.48 263,352.81 3.70 53.51 1,422.00 20.25 186.00 1,409.51 1,281.51 -112.67 -46.72 2,544,430.74 263,349.90 4.66 80.06 1,522.00 23.50 187.00 1,502.30 1,374.30 -149.68 -50.96 2,544,393.83 263,344.91 3.27 111.31 1,622.00 26.25 188.00 1,593.01 1,465.01 -191.38 -56.47 2,544,352.25 263,338.55 2.78 146.18 1,722.00 26.50 187.00 1,682.61 1,554.61 -235.42 -62.26 2,544,308.34 263,331.86 0.51 183.03 1,822.00 26.50 187.00 1,772.10 1,644.10 -279.71 -67.70 2,544,264.17 263,325.53 0.00 220.26 1,922.00 26.25 188.00 1,861.69 1,733.69 -323.75 -73.50 2,544,220.26 263,318.84 0.51 257.11 2,022.00 26.25 187.00 1,951.38 1,823.38 -367.60 -79.27 2,544,176.54 263,312.17 0.44 293.79 2,122.00 26.00 187.00 2,041.16 1,913.16 -411.31 -84.64 2,544,132.95 263,305.92 0.25 330.53 2,222.00 25.75 186.00 2,131.14 2,003.14 -454.67 -89.58 2,544,089.70 263,300.10 0.50 367.15 2,322.00 25.25 185.00 2,221.39 2,093.39 -497.52 -93.71 2,544,046.95 263,295.10 0.66 403.67 2,422.00 25.00 185.00 2,311.93 2,183.93 -539.81 -97.41 2,544,004.74 263,290.54 0.25 439.89 2,522.00 24.75 184.00 2,402.66 2,274.66 -581.75 -100.71 2,543,962.88 263,286.39 0.49 475.96 2,622.00 24.00 183.00 2,493.74 2,365.74 -622.94 -103.23 2,543,921.75 263,283.03 0.86 511.72 2,722.00 23.00 183.00 2,585.45 2,457.45 -662.76 -105.32 2,543,881.98 263,280.13 1.00 546.44 2,822.00 23.00 182.00 2,677.50 2,549.50 -701.79 -107.03 2,543,842.99 263,277.64 0.39 580.62 7/14/2017 7:32:01PM Page 3 COMPASS 5000.1 Build 81D S • Halliburton IIALLIBUPTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:GP-11-24RD Company: Hilcorp Alaska,LLC TVD Reference: GP 11-24RD WP06 @ 128.00usft Project: Granite Point MD Reference: GP 11-24RD WP06 @ 128.00usft Site: Granite Point Platform North Reference: True Well: Plan:GP-11-24RD Survey Calculation Method: Minimum Curvature Wellbore: GP 11-24RD Design: GP 11-24RD WP06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section ! (usft) (^) (o) (usft) usft (usft) (usft) (usft) (usft) 2,641.63 2,922.00 22.75 182.00 2,769.63 2,641.63 -740.64 -108.38 2,543,804.18 263,275.49 0.25 614.80 3,022.00 22.75 183.00 2,861.85 2,733.85 -779.28 -110.07 2,543,765.59 263,273.02 0.39 648.64 3,122.00 22.25 184.00 2,954.24 2,826.24 -817.47 -112.40 2,543,727.45 263,269.91 0.63 681.79 3,222.00 22,00 183.00 3,046.88 2,918.88 -855.06 -114.70 2,543,689.92 263,266.85 0.45 714.42 3,322.00 21.50 184.00 3,139.76 3,011.76 -892.05 -116.96 2,543,652.99 263,263.84 0.62 746.53 3,422.00 21.50 184.00 3,232.80 3,104.80 -928.61 -119.52 2,543,616.49 263,260.54 0.00 778.12 3,522.00 21.00 184.00 3,326.00 3,198.00 -964.76 -122.05 2,543,580.39 263,257.28 0.50 809.36 3,622.00 21.25 185.00 3,419.28 3,291.28 -1,000.69 -124.88 2,543,544.53 263,253.72 0.44 840.27 3,722.00 21.50 185.00 3,512.40 3,384.40 -1,037.00 -128.05 2,543,508.29 263,249.81 0.25 871.36 3,822.00 21.50 185.00 3,605.44 3,477.44 1,073.51 -131.25 2,543,471.86 263,245.87 0.00 902.62 3,922.00 23.25 186.00 3,697.91 3,569.91 -1,111.40 -134.91 2,543,434.05 263,241.44 1.79 934.91 4,022.00 22.00 186.00 3,790.21 3,662.21 -1,149.66 -138.93 2,543,395.89 263,236.65 1.25 967.37 4,122.00 22.00 186.00 3,882.93 3,754.93 -1,186.91 -142.84 2,543,358.72 263,231.97 0.00 998.98 4,222.00 22.50 185.00 3,975.49 3,847.49 -1,224.60 -146.47 2,543,321.11 263,227.58 0.63 1,031.11 4,322.00 24.75 184.00 4,067.10 3,939.10 -1,264.55 -149.60 2,543,281.24 263,223.65 2.29 1,065.48 4,422.00 26.00 185.00 4,157.45 4,029.45 -1,307.27 -152.97 2,543,238.60 263,219.41 1.32 1,102.23 4,522.00 26.00 184.00 4,247.33 4,119.33 -1,350.97 -156.41 2,543,194.98 263,215.08 0.44 1,139.82 4,622.00 25.50 186.00 4,337.40 4,209.40 -1,394.24 -160.19 2,543,151.79 263,210.42 1.00 1,176.88 4,722.00 25.75 187.00 4,427.57 4,299.57 -1,437.21 -165.08 2,543,108.93 263,204.66 0.50 1,213.17 4,822.00 26.00 187.00 4,517.54 4,389.54 -1,480.53 -170.40 2,543,065.73 263,198.46 0.25 1,249.58 4,922.00 26.00 186.00 4,607.42 4,479.42 -1,524.08 -175.36 2,543,022.29 263,192.61 0.44 1,286.36 1 5,022.00 25.75 186.00 4,697.40 4,569.40 -1,567.48 -179.93 2,542,978.99 263,187.17 0.25 1,323.18 5,122.00 26.25 185.00 4,787.28 4,659.28 -1,611.12 -184.12 2,542,935.45 263,182.09 0.66 1,360.38 5,222.00 25.50 187.00 4,877.25 4,749.25 -1,654.51 -188.68 2,542,892.16 263,176.66 1.15 1,397.20 5,322.00 25.25 189.00 4,967.61 4,839.61 -1,696.95 -194.64 2,542,849.86 263,169.84 0.89 1,432.54 5,422.00 25.00 188.00 5,058.14 4,930.14 -1,738.94 -200.91 2,542,808.01 263,162.71 0.49 1,467.33 5,522.00 25.50 187.00 5,148.59 5,020.59 -1,781.23 -206.48 2,542,765.84 263,156.28 0.66 1,502.72 5,622.00 24.75 188.00 5,239.13 5,111.13 -1,823.32 -212.01 2,542,723.87 263,149.89 0.86 1,537.94 5,722.00 25.00 188.00 5,329.85 5,201.85 -1,864.98 -217.87 2,542,682.34 263,143.20 0.25 1,572.62 5,822.00 24.25 187.00 5,420.76 5,292.76 -1,906.29 -223.31 2,542,641.15 263,136.91 0.86 1,607.18 5,922.00 24.50 188.00 5,511.84 5,383.84 -1,947.20 -228.70 2,542,600.36 263,130.70 0.48 1,641.41 6,022.00 24.25 187.00 5,602.93 5,474.93 -1,988.12 -234.09 2,542,559.56 263,124.48 0.48 1,675.64 6,122.00 24.00 188.00 5,694.20 5,566.20 -2,028.64 -239.42 2,542,519.16 263,118.32 0.48 1,709.54 6,222.00 23.50 188.00 5,785.73 5,657.73 -2,068.52 -245.03 2,542,479.40 263,111.91 0.50 1,742.75 6,322.00 23.75 189.00 5,877.35 5,749.35 -2,108.16 -250.95 2,542,439.89 263,105.18 0.47 1,775.60 6,422.00 23.25 188.00 5,969.05 5,841.05 -2,147.59 -256.85 2,542,400.59 263,098.48 0.64 1,808.27 6,522.00 23.25 188.00 6,060.93 5,932.93 -2,186.68 -262.34 2,542,361.62 263,092.20 0.00 1,840.82 6,622.00 22.75 191.00 6,152.98 6,024.98 -2,225.21 -268.78 2,542,323.23 263,084.98 1.27 1,872.45 6,722.00 22.75 190.00 6,245.20 6,117.20 -2,263.23 -275.83 2,542,285.36 263,077.16 0.39 1,903.35 6,822.00 23.00 191.00 6,337.34 6,209.34 -2,301.45 -282.91 2,542,247.30 263,069.30 0.46 1,934.41 6,922.00 22.25 191.00 6,429.64 6,301.64 -2,339.21 -290.25 2,542,209.69 263,061.20 0.75 1,964.95 7,022.00 22.25 191.00 6,522.20 6,394.20 -2,376.38 -297.48 2,542,172.68 263,053.22 0.00 1,995.01 7,122.00 23.00 193.00 6,614.50 6,486.50 -2,414.00 -305.48 2,542,135.23 263,044.45 1.07 2,025.12 1 7,222.00 24.00 194.00 6,706.21 6,578.21 -2,452.77 -314.80 2,542,096.66 263,034.35 1.08 2,055.68 7,322.00 24.75 195.00 6,797.29 6,669.29 -2,492.73 -325.14 2,542,056.92 263,023.20 0.86 2,086.85 7/14/2017 7:32:01 PM Page 4 COMPASS 5000.1 Build 81D • • Halliburton HALLIBU RTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:GP-11-24RD Company: Hilcorp Alaska,LLC ND Reference: GP 11-24RD WP06 @ 128.O0usft Project: Granite Point MD Reference: GP 11-24RD WP06 @ 128.00usft Site: Granite Point Platform North Reference: True Well: Plan:GP-11-24RD Survey Calculation Method: Minimum Curvature Wellbore: GP 11-24RD Design: GP 11-24RD WP06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth NDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,760.02 7,422.00 25.00 196.00 6,888.02 6,760.02 -2,533.26 -336.38 2,542,016.63 263,011.14 0.49 2,118.13 7,522.00 24.00 193.00 6,979.02 6,851.02 -2,573.39 -346.78 2,541,976.72 262,999.93 1.60 2,149.42 7,622.00 25.00 193.00 7,070.01 6,942.01 -2,613.80 -356.11 2,541,936.51 262,989.78 1.00 2,181.44 7,722,00 25.75 194.00 7,160.36 7,032.36 -2,655.46 -366.12 2,541,895.06 262,978.93 0.86 2,214.28 7,822.00 25.25 194.00 7,250.62 7,122.62 -2,697.23 -376.53 2,541,853.51 262,967.67 0.50 2,247.04 7,922.00 24.00 195.00 7,341.53 7,213.53 -2,737.58 -386.96 2,541,813.39 262,956.42 1.32 2,278.51 8,022.00 24.00 197.00 7,432.88 7,304.88 -2,776.67 -398.16 2,541,774.53 262,944.42 0.81 2,308.52 8,122.00 24.00 198.00 7,524.24 7,396.24 -2,815.46 -410.40 2,541,736.00 262,931.41 0.41 2,337.80 8,222.00 23.25 198.00 7,615.85 7,487.85 -2,853.57 -422.78 2,541,698.15 262,918.25 0.75 2,366.40 8,322.00 23.00 198.00 7,707.82 7,579.82 -2,890.92 -434.92 2,541,661.05 262,905.36 0.25 2,394.44 , 8,422.00 22.00 199.00 7,800.21 7,672.21 -2,927.21 -447.05 2,541,625.02 262,892.49 1.07 2,421.52 8,500.00 21.61 199.00 7,872.63 7,744.63 -2,954.61 -456.48 2,541,597.82 262,882.50 0.50 2,441.85 Start Dir 13.38°/100':8500'MD,7872.63'TVD:60°LT TF 8,517.08 22.76 193.76 7,888.44 7,760.44 -2,960.79 -458.30 2,541,591.67 262,880.57 13.38 2,446.58 End Dir :8517.08'MD,7888.44'ND 8,547.08 22.76 193.76 7,916.11 7,788.11 -2,972.07 -461.06 2,541,580.46 262,877.58 0.00 2,455.44 Start Dir 5°/100':8547.08'MD,7916.117VD 8,600.00 21.90 187.17 7,965.06 7,837.06 -2,991.81 -464.73 2,541,560.80 262,873.51 5.00 2,471.48 8,700.00 21.08 173.68 8,058.17 7,930.17 -3,028.21 -465.07 2,541,524.41 262,872.42 5.00 2,503.91 8,800.00 21.37 159.86 8,151.44 8,023.44 -3,063.21 -456.82 2,541,489.25 262,879.97 5.00 2,538.93 8,900.00 22.73 147.01 8,244.18 8,116.18 -3,096.54 -440.02 2,541,455.59 262,896.09 5.00 2,576.25 9,000.00 24.98 135.96 8,335.68 8,207.68 -3,127.94 -414.80 2,541,423.68 262,920.66 5.00 2,615.60 9,100.00 27.92 126.85 8,425.24 8,297.24 -3,157.18 -381.36 2,541,393.77 262,953.49 5.00 2,656.67 9,200.00 31.35 119.47 8,512.18 8,384.18 -3,184.04 -339.96 2,541,366.08 262,994.34 5.00 2,699.16 9,300.00 35.12 113.46 8,595.83 8,467.83 -3,208.30 -290.90 2,541,340.83 263,042.90 5.00 2,742.74 9,400.00 39.13 108.52 8,675.57 8,547.57 -3,229.79 -234.56 2,541,318.20 263,098.79 5.00 2,787.08 9,502.35 43.42 104.28 8,752.48 8,624.48 -3,248.74 -169.80 2,541,297.94 263,163.14 5.00 2,832.89 End Dir :9502.35'MD,8752.49'ND 9,600.00 43.42 104.28 8,823.41 8,695.41 -3,265.29 -104.76 2,541,280.07 263,227.83 0.00 2,876.69 9,700.00 43.42 104.28 8,896.04 8,768.04 -3,282.25 -38.15 2,541,261.76 263,294.08 0.00 2,921.55 9,800.00 43.42 104.28 8,968.67 8,840.67 -3,299.21 28.46 2,541,243.45 263,360.33 0.00 2,966.41 9,900.00 43.42 104.28 9,041.31 8,913.31 -3,316.17 95.07 2,541,225.14 263,426.58 0.00 3,011.26 10,000.00 43.42 104.28 9,113.94 8,985.94 -3,333.13 161.68 2,541,206.84 263,492.83 0.00 3,056.12 I 10,100.00 43.42 104.28 9,186.57 9,058.57 -3,350.09 228.29 2,541,188.53 263,559.08 0.00 3,100.98 10,200.00 43.42 104.28 9,259.21 9,131.21 -3,367.04 294.90 2,541,170.22 263,625.33 0.00 3,145.83 10,300.00 43.42 104.28 9,331.84 9,203.84 -3,384.00 361.51 2,541,151.92 263,691.58 0.00 3,190.69 10,400.00 43.42 104.28 9,404.47 9,276.47 -3,400.96 428.12 2,541,133.61 263,757.83 0.00 3,235.55 10,500.00 43.42 104.28 9,477.10 9,349.10 -3,417.92 494.73 2,541,115.30 263,824.08 0.00 3,280.41 10,599.33 43.42 104.28 9,549.25 9,421.25 -3,434.76 560.90 2,541,097.12 263,889.89 0.00 3,324.96 Start Dir 5°/100':10599.33'MD,9549.25'TVD 10,700.00 44.77 111.25 9,621.59 9,493.59 -3,456.16 627.51 2,541,074.37 263,956.04 5.00 3,373.80 10,800.00 46.51 117.81 9,691.54 9,563.54 -3,485.88 692.45 2,541,043.35 264,020.37 5.00 3,429.33 10,900.00 48.60 123.97 9,759.06 9,631.06 -3,523.78 755.68 2,541,004.16 264,082.81 5.00 3,491.43 10,959.70 50.00 127.45 9,798 00 9,670.00 -3,550.21 792.41 2,540,977.00 264,119.00 5.00 3,531.46 1. C5 7/14/2017 7:32:01PM Page 5 COMPASS 5000.1 Build 81D Halliburton HALLIBURTONI Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:GP-11-24RD Company: Hilcorp Alaska,LLC ND Reference: GP 11-24RD WP06 @ 128.00usft Project: Granite Point MD Reference: GP 11-24RD WP06 @ 128.00usft Site: Granite Point Platform North Reference: True Well: Plan:GP-11-24RD Survey Calculation Method: Minimum Curvature Wellbore: GP 11-24RD Design: GP 11-24RD WP06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,695.35 11,000.00 52.01 127.45 9,823.35 9,695.35 -3,569.25 817.27 2,540,957.46 264,143.47 5.00 3,559.58 11,100.00 57.01 127.45 9,881.38 9,753.38 -3,618.75 881.90 2,540,906.66 264,207.07 5.00 3,632.68 11,200.00 62.01 127.45 9,932.10 9,804.10 -3,671.13 950.29 2,540,852.90 264,274.38 5.00 3,710.05 11,300.00 67.01 127.45 9,975.11 9,847.11 -3,726.00 1,021.93 2,540,796.58 264,344.89 5.00 3,791.10 11,402.19 72.12 127.45 10,010.77 9,882.77 -3,784.22 1,097.93 2,540,736.84 264,419.69 5.00 3,877.07 End Dir :11402.19'MD,10010.77'TVD 11,500.00 72.12 127.45 10,040.80 9,912.80 -3,840.82 1,171.83 2,540,678.75 264,492.42 0.00 3,960.67 11,600.00 72.12 127.45 10,071.49 9,943.49 -3,898.69 1,247.38 2,540,619.36 264,566.78 0.00 4,046.14 11,700.00 72.12 127.45 10,102.19 9,974.19 -3,956.56 1,322.94 2,540,559.97 264,641.15 0.00 4,131.61 11,800.00 72.12 127.45 10,132.88 10,004.88 -4,014.44 1,398.50 2,540,500.57 264,715.51 0.00 4,217.08 11,900.00 72.12 127.45 10,163.58 10,035.58 -4,072.31 1,474.05 2,540,441.18 264,789.87 0.00 4,302.55 12,000.00 72.12 127.45 10,194.27 10,066.27 -4,130.18 1,549.61 2,540,381.79 264,864.23 0.00 4,388.03 12,100.00 72.12 127.45 10,224.97 10,096.97 -4,188.05 1,625.16 2,540,322.40 264,938.59 0.00 4,473.50 12,200.00 72.12 127.45 10,255.66 10,127.66 -4,245.92 1,700.72 2,540,263.00 265,012.95 0.00 4,558.97 12,233.68 72.12 127.45 10,266.00 10,138.00 -4,265.41 1,726.17 2,540,243.00 265,038.00 0.00 4,587.76 Start Dir 3°/100':12233.68'MD,102667VD 12,247.89 72.53 127.57 10,270.31 10,142.31 -4,273.66 1,736.91 2,540,234.54 265,048.57 3.00 4,599.92 End Dir :12247.89'MD,10270.31'ND 12,300.00 72.53 127.57 10,285.95 10,157.95 -4,303.97 1,776.30 2,540,203.44 265,087.34 0.00 4,644.61 12,400.00 72.53 127.57 10,315.97 10,187.97 -4,362.14 1,851.91 2,540,143.75 265,161.74 0.00 4,730.37 12,500.00 72.53 127.57 10,345.98 10,217.98 -4,420.30 1,927.51 2,540,084.06 265,236.15 0.00 4,816.12 12,600.00 72.53 127.57 10,376.00 10,248.00 -4,478.47 2,003.11 2,540,024.37 265,310.55 0.00 4,901.88 12,700.00 72.53 127.57 10,406.01 10,278.01 -4,536.64 2,078.71 2,539,964.68 265,384.95 0.00 4,987.64 12,800.00 72.53 127.57 10,436.02 10,308.02 -4,594.81 2,154.31 2,539,904.99 265,459.35 0.00 5,073.39 12,900.00 72.53 127.57 10,466.04 10,338.04 -4,652.97 2,229.92 2,539,845.30 265,533.76 0.00 5,159.15 13,000.00 72.53 127.57 10,496.05 10,368.05 -4,711.14 2,305.52 2,539,785.61 265,608.16 0.00 5,244.91 i 13,083.12 72.53 127.57 10,521.00 10,393.00 -4,759.49 2,368.36 2,539,736.00 265,670.00 0.00 5,316.19 Total Depth:13083.12'MD,10521'TVD Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) GP 11-t4itu','dF-'uu GL. 0.00 0.00 9,798.00 -3,550.21 792.41 2,540,977.00 264,119.00 -plan hits target center -Circle(radius 100.00) GP 11-24RD WP06 BHL 0.00 0.00 10,521.00 -4,759.49 2,368.36 2,539,736.00 265,670.00 -plan hits target center -Circle(radius 100.00) GP 11-24RD WP06 Mid Point 0.00 0.00 10,266.00 -4,265.41 1,726.17 2,540,243.00 265,038.00 -plan hits target center -Circle(radius 100.00) 7/14/2017 7:32:01PM Page 6 COMPASS 5000.1 Build 81D • • Halliburton I-IALLIBURT'ON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:GP-11-24RD Company: Hilcorp Alaska,LLC TVD Reference: GP 11-24RD WP06 @ 128.00usft Project: Granite Point MD Reference: GP 11-24RD WP06 @ 128.O0usft Site: Granite Point Platform North Reference: True Well: Plan:GP-11-24RD Survey Calculation Method: Minimum Curvature Wellbore: GP 11-24RD Design: GP 11-24RD WP06 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 13,083.12 10,521.00 7"x 8 1/2" 7 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology C) (°) 10,959.70 9,798.00 C5 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,500.00 7,872.63 -2,954.61 -456.48 Start Dir 13.38°/100':8500'MD,7872.63'TVD:60°LT TF 8,517.08 7,888.44 -2,960.79 -458.30 End Dir :8517.08'MD,7888.44'TVD 8,547.08 7,916.11 -2,972.07 -461.06 Start Dir 5°/100':8547.08'MD,7916.11'TVD 9,502.35 8,752.48 -3,248.74 -169.80 End Dir :9502.35'MD,8752.49'TVD 10,599.33 9,549.25 -3,434.76 560.90 Start Dir 5°/100':10599.33'MD,9549.25'TVD 11,402.19 10,010.77 -3,784.22 1,097.93 End Dir :11402.19'MD,10010.77'TVD 12,233.68 10,266.00 -4,265.41 1,726.17 Start Dir 3°/100':12233.68'MD,10266'TVD 12,247.89 10,270.31 -4,273.66 1,736.91 End Dir :12247.89'MD,10270.31'TVD 13,083.12 10,521.00 -4,759.49 2,368.36 Total Depth:13083.12'MD,10521'TVD 7/14/2017 7:32:01PM Page 7 COMPASS 5000.1 Build 810 0 • 2 to m LU L rc N 3 rn c M 0 J .■I > QL L G' = til- , In t 0 ct ct o 0 IL v I `' la W 3 6. p w e •u M C f;'; V OI d 0 N 01 r a z a. 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'�° _8 U' m — i — — —...._ o o - op g N a I ' e- m - CO I - o I N o• 'a 3 -. i• - - V > I ' C -O , . .. o CU 7.Z ai I _ • • • (f) � N RI - o O I i a' _ ea o M oo- (N� W G. . U �`� oo 2, 2 - U J �(i) lL I I I 1 1 1 I I I I i I I 111111 I I I 11111111111111 1� I ' III ' OCO J as o v> o u-) o LC) o in o O (,� O r N O r N N O Q (� C O c0 r-: (Li 10 ri N O _ cas .-) (ul/0s.Z)Jo�oed uogeiedag < R • • a• RECUT' D STATE OF ALASKA MAY 0 1 .1017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS M CC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ • Perforate New Pool 0 Re-enter Susp Well ❑ ' Alter Gas' , % Other: 0 2.Operator Name: 4.Current Well Class: 5_Permit to DrDI Number: Hilcorp Alaska,LLC Exploratory 0 Development ;51. 167-057 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number Anchorage,AK 99503 50-733-20046-00 '7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A - Will planned perforations require a spacing exception? Yes ❑ No 0 Granite Pt St 11-24 ' • 9.Property Designation(Lease Number): 10.F: ,/Pool(s): ADL0018761 • Granit ••nt Field/Middle enai Oil Pool , 11. PRESENT WELL •••N"I +N SUMM. Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: E'- I:.th TVD: PSP(psi) Plugs(MD): Junk(MD): 11,800 ' 11,071 . 9,440 8,780 • 2ri) 9,440 N/A Casing Length Size "\ MD Burst Collapse Structural c ,.... Conductor 638' 18" ` 6 :' eV 63 ' Surface 4,030' 13-3 ,030' 31.7 ' 3,090 psi 1,540 par Intermediate Production 10,086' 9-5/8" 10,086' 9,418' 5,750 psi 3,090 psi Liner 1,835' 7" 11,79( 11,069' 11,220 psi 8,510 psi Perforation Depth MD(ft): Perforation DO TVD(ft): T,.ing Se: ‘6Tubing Grade: Tubing MD(ft): N/A N/A /A N/A N/A Packers and SSSV Type: / Packers and SSSV MD(ft)and TVD(ft): N/A WA 12.Attachments: Proposal Sum Q Well . :schematic 0 '13.Well Class after proposed work: Detailed Operations Program ❑ BOP S -tch ❑ Exploratory 0 Stratigraphic❑ Development❑ • Service 0 14.Estimated Date for 15.Well Status after proposed work: - Commencing Operations: \ 8/1/2017 OIL 0 WINJ ❑ WDSPL 0 Suspended El - 16.Verbal Approval: '--te: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing true and the procedure approved herein will not be deviated from without prior writte approval. Authorized Name: Stan W. .is Contact Name: Dan Marlowe Authorized Title: Operati. a Manager Contact Email: dmarlowet hjiCOri,,co Contact Phone: 283-1329 Authorized Signature: . 6..3i Date: VI t r &7 COMMISSION USE ONLY Conditions of approval: Noti Commission that a representative may witness Sundry Number: 7 Plug Integrity 0 BOP Test(' Mechanical hitegrity Test 0 Location Clearance 0 ` '"t GF• C It U lq Other: A 3 S} ' los,: gof 7t— (z...5--.., ©Sa ,-7n4 –rt.",.r-) Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0— / 07- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S—if-/7 ,alet4,-7,-d` 7//7 s-hi-II lNA s„t> rForm and farm 10-403 Revised 412017 0 rawa i Id for 12 months from the date of approval Attachments in Duplicate • •I Well Work Prognosis Well: GP 11-24 Blimp Alaska,LLC Date: 04/07f 2017 Well Name: GRANITE PT ST#11-24 API Number: 50-733-20046-00 (GP 11-24) _ Current Status: Suspended -Producer Leg: Leg#3 Estimated Start Date: June 01,2017 Rig: Moncla 404& Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 167-057 First Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904(M) Second Call Engineer: Monty Myers (907)777-8431 (0) (907)538-1168(M) Current Bottom Hole Pressure: 3,463 psi @ 9,100'TVD 0.410 lbs/ft(7.88 ppg)based on SIBHP Maximum Expected BHP: 3,463 psi @ 9,100'TVD 0.410 lbs/ft(7.88 ppg)based on SIBHP Maximum Potential Surface Pressure: 2,821 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP 11-24 is a suspended C sands produce .Ellrugged back in September 1997.This workover will prepare the well for a side track. Last Casing Test: 09/30/1997 3000 psig against cement plug at 9,440' Procedure: Phase I rAo 1. MIRU Rig. Lim 2. Bleed down well and ND Wellhead 3. Pull and replace 9-5/8" by 13-3/8" pack-off assembly. 4. NU BOP and test to 250psi low/x„500? i high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). •33 5. Monitor well to ensure it is static. 6. RIH with bit and scraper to±9,000',circulate clean. POOH. 7. POOH w/work-string 8. RU E-line and run caliper log from±9,000'to surface. 9. Pressure Test casing to 2,500 ..r30-,minutes and chart. 10. RU e-line and RIH w/CIBP o±8,501 - above casing connection. POOH 11. RIH with ±2,000'of kill strin: :12. Set BPV, ND BOP, NU Dry Hole Tree and test. 13. Suspend operations /rT'1/ we 1 flat o(r'�a r� t'vFei 04,/ ,4 �tf R, /r794rrt o t° / E[ �(o `L fer�5 fete p ''�0, 54 7 Iv • • Well Work Prognosis Well: GP 11-24 WimpUuekn>1.11; Date: 04/07/2017 Phase II 1. Resume operations with Kuukpik#5 2. MIRU Kuukpik#5 3. Circulate well 4. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 5. Monitor well to ensure it is static. 6. Circulate well and pull kill string 11 14. Swap well to OBM drilling fluid. 15. Mill 8-1/2"window and 20'of new formation. POOH and LD mills. I ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure:(informational only) 1. PU directional BHA and TIH to window. 2. Drill 8-1/2" hole to the C-7 sands. 3. Run/Cement/and cleanout 7" casing. 4. Swap to completion sundry. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing—Moncla 404 5. Fluid Flow Diagrams—Moncla 404 6. BOP Drawing—Kuukpik 5 7. Fluid Flow Diagrams—Kuukpik 5 8. RWO Sundry Revision Change Form Granite Point Platform 11 SCHEMATIC Well: Granite Pt St#11-24 PTD:167-057 API: 50-733-20046-00 Temporarily Suspended:9/30/97 Blimp Alaska.LLC RKB=114.75'114.75";43'Rig Floor to Wellhead FMC Unihead CASING DETAIL Size Wt Grade Conn ID Top Btm 18" 70.59 B Ventura Surf 638' 13-3/8" 61 J-55 &d 12.515" Surf 4,030' 40 N-80 Butt _ 8.835" Surf 82' 43.5 N-80 Butt 8.755" 82' 123' w 40 N-80 Butt 8.835" 123' 1,955' 9 5/8" 40 N-80 LT&C 8.835" 1,955' 5,547' '� 40 S-95 ST&C 8.835" 5,547' 6,537' ,fit+ 3 DV Collar 43.5 S-95 ST&C 8.755" 6,537' 10,086' t7 /'7 @ z28S, 7" 29 P-110 X-Line 6.184" 9,963' 11,798' P1/4<( 7.105' TUBING DETAIL (FISH) }}1K- 1�'� 3-1/2" ,_ 9.2 I L-80 I SC-BTC 3.992" + 9,828' I 10,699' t $ , 7`C2Jtac -al /2'G t,-4,-... !t- 1" t- JEWELRY DETAIL No Depth Depth ID OD Item (MD) (TVD) 0,i 1 r 9,440' 8,781' Top Cement Plug(11 BELS)--9,440'-9,585' _ i, 2 9,585' 8,924' _ HES EZ-SV Cement Retainer .9[.fy1 3 9,587' - 8,926' Bottom Cement Plug(47 BELS)-9,587'-11,165' ref .. 777 7-1/8" 8-1'2" Fish:Wash-pipe Shoe(L=4.35',OD=8-1/2"-ID=7- Z� 1/8") Possible Corrosion44 q'l 4 9,828' 9,165' Top of tubing fish is @ 9,833',Top of WP @ 9828' 250'-550' 5 9,836' 9,173' Otis"XO'Sliding Sleeve w/valve 6 10,480' 9,805' Otis"XO"Sliding Sleeve w/valve • TOC Q 9110' 16 ygt/ ' 7 10,699' 10,019' 2.535" Otis"Q'Profile Nipple poor bonding 1,,-."'1 2`NS° ' ABANDONED PERFORATION DETAIL Ghost Hole Top Btm Top Btm Accum 9674'-10,288' 3 Zone (MD) (MD) (TVD) (TVD) FT SPF Date Status P9 Block cmt sqz 28 cult of TOF*9,828' > I II 4 class"G".tested to 5,000 „; _,. ■ 5 9,765' 9,766' 9,103' 9,104' 1' 8 1/5/1968 psi. TOL @ 9,963'F \ C2 - 9,836' 9,866' 9,173' 9,203' 30' 4 1/10/1968 Perf f/Production \ / Pressure tested to 5,000 I ' ' 9,950' 9,951' 9,285' 9,286' 1' 4 1/3/1968 psi,no break down C5 10,095' 10,130' 9,428' 9,462' 35' 4 1/10/1968 Perf f/Production C5 10,150' 10,240' 9,481' 9,570' 90' 4 1/10/1968 Perf f/Production _ C6 10,315' 10,350' 9,643' 9,677' 35' 4 1/10/1968 Perf f/Production O Pressure tested to 5,000 10,400' 10,401' 9,726' 9,727' 1' 4 _ 1/3/1968 psi,no break down D C7 10,535' 10,560' 9,858' 9,883' 25' 8 10/25/1968 _Perf f/Production C7 10,580' 10,660' 9,902' 9,981' 80' 8 _ 10/25/1968 Perf f/Production 0 C7 10,675' 10,700' 9,995' 10,020' 25' 8 10/25/1968 Perf f/Production Pressure tested to 5,000 • •` I 6 10,750' 10,751' 10,069' 10,070' 1' 4 1/2/1968 psi,no break down -1 Isolated below retainer ri• C9 11,135' 11,165' 10,442' 10,471' 30' 4 12/30/1967 @ 11,108' j O FISH r. p Item - !a ,;h 7 Top of tubing fish is @ 9,833',Top of WP @ 9828'. 1 Hole and bad spots in casing from 9,772'to 9,838'. See morning reports for more detail. PBTD=9,440' MAX HOLE ANGLE±25° Updated by RTE 03/16/17 ,- • ill Granite Point Platform . ' Well: Granite Pt St#11-24 PROPOSED PTD:167-057 API: 50-733-20046-00 Hamm Ataska.LLC Temporarily Suspended:9/30/97 FMB=11475";43'Rig Floor to VVellhead CASING DETAIL FMC Unitised Size Wt Grade Conn - ID Top i 1 1 i 18" -3/8" 70.59 61 B J-55 Ventura 8rd 12.515" Surf _ Surf Btm 13 638' 4,030' X X 43.5 N-80 Butt 8.835" Surf 82' 18' N-80 Butt 8.755" 82' 123' L.: Dy Collar 9-5/8" 40 40 N-80 N-80 Butt LT&C 8.835° 8.835" 123' 1,955' 1,955' 5,547' _ (42285' 40 5-95 ST&C_ 8.835" 5,547' 6,537' ri, 43.5 S-95 ST&C 8755" 6,537' ±8,500'(KOP) 7,, 29 P-110 X-Line 6.184" 9,963' 11,798' , TUBING DETAIL(FISH) 13-3/8" ""7 3-1/2" I 9.2 I L-80 SC-BTC 3.992" I 9,828' 1 10,699' 1.3.5.43 HWY) 4FC:.-.140.00 ' • Red rpoterbere screwed nee cs,g alter JEWELRY DETAIL perbag Depth _ Depth No ID OD Item (MD) (TVD) Possible a BP i8,5°°' ±8,500' 0,871' CIBP(Set for whipstock) Corrosion 250-550 1 9,440' 8,781' Top Cement Plug(11 BBLS)--9,440'-9,585' WC. ,o' '- 2 9,585' 8,924' HES EZ-SV Cement Retainer 9110' poor - - '' - .,7 J. 3 9,587' 8,926' Bottom Cement Plug(47 BBLS)--9,587' 1,165' txxicit,g ' . - ' `...7.-.. - -1 Fish:Wash-pipe Shoe(1_,-11.3V,OD=&1/2"-ID.=.7- ??? 7-ve 8-1/2" 1/81 2 4 9,828' 9,165' Top of tubing fish is @ 9,833',Top of WP @ 9828' (.1O‘ dlorc 5 9,836' 9,173' Otis"XO"Sliding Sleeve w/valve 6 10,480' 9,805Otis")(0"Sliding Sleeve w/valve 7 10,699' 10,019' 2.635" Otis"Q"Profile Nipple •- ' 17ig 1 01 ‘i- . . .. ..- 4 , ABANDONED PERFORATION DETAIL . . , . .. 5 Top Btm Top Btm Accum Zone FT Date Status (MD) (MD) 4 (TVD) (TVD) SPF . , - ,...___ Block cmt sqz 28 cuft of rct t ' , . class"G".tested to 9.94:134 ' 9,765' 9,766' 9,103' 9,104' 1' 8 1/6/1968 5,000 psi. tk /O.G S4 C2 9,836' 9,866' 9,173' 9,203' 30' 4 _ 1/10/1968 Pert f/Production ". Pressure tested to 5,000 -. 9,950' 9,951' 9,285' 9,286' 1' 4 1/3/1968 psi,no break down C5 10,095' 10,130' 9,428' 9,462' 35' 4 1/10/1968 Pert f/Production C5 10,150' 10,240' 9,481' 9,570' 90' 4 1/10/1968 Perf f/Production C6 10,315' 10,350' _ 9,643' 9,677' 35' 4 1/10/1968 Pert f/Production Pressure tested to 5,000 v 10,400' 10,401' 9,726' 9,727' 1' 4 1/3/1968 psi,no break down C7 10,535' 10,560' 9,858' 9,883' 25' 8 10/25/1968 Pert f/Production C7 - 10,58f1 10,660' 9,902' 9,981' 80' 8 10/25/1968 Pert f/Production C7 10,675 10,700' 9,995' 10,020' 25' 8 10/25/1968 Pert f/Production Pressure tested to 5,000 s 10,750' 10,751' 10,069' 10,070' 1' 4 1/2/1968 psi,no break down _ - Isolated below retainer C9 1 11,135' 11,165' 10,442' 10,471' 30' 4 12/30/1967 , @ 11,108' ".. ItemFISH Top of tubing fish is @ 9,833',Top of WP @ 9828'. I ".'__':: r PBTD:9,440' ID:11,800' Hole and bad spots in casing from 9,772'to 9,838'. See morning reports for more detail. MAX HOLE ANGLE±255 Updated By:JLL 03/16/17 • TRANSMITTAL LETTER CHECKLIST WELL NAME: &i'64414 ?T SI- PTD: /17-11.3 /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: &Wuk ?Oalf— POOL: 41i4/ . /4c4. 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. 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'— N CO a (O (° (- CO 0) 7- 1- N N N N N N N N N N CO CO CO CO CO M co V) fM co • U I— L_ N . a) ° o °) w) o o° - Oc CO N CO fa N W O c arca N CV ,N . o. °' • CL r c °) a) E (.., _I N N Cl) O O J d] E Q J O` Og. m 0aQ 0 ,‘'.11 I� a c • Is s Q w Q 0 Q a GP 11-24RD 50-733-20046-01-00 Granite Point Field Kenai Peninsula Borough, Alaska September 26, 2017 – October 21, 2017 Provided by: Approved by: Corey Ramstad Compiled by: Allen Odegaard Paul Webster Distribution Date: November 14, 2017 GP 11-24RD 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW .......................................................................................................... 2 1.1 Equipment Summary ..................................................................................................................................... 2 1.2 Crew ............................................................................................................................................................... 2 2 GENERAL WELL DETAILS............................................................................................................................... 3 2.1 Well Objectives .............................................................................................................................................. 3 2.2 Hole Data ....................................................................................................................................................... 4 2.3 Daily Activity Summary .................................................................................................................................. 4 3 GEOLOGICAL DATA ......................................................................................................................................... 8 3.1 Lithostratigraphy ........................................................................................................................................... 8 3.2 Lithology Details ............................................................................................................................................ 9 3.3 Sampling Program ........................................................................................................................................ 18 4 Drilling Data ....................................................................................................................................................... 19 4.1 Surveys ......................................................................................................................................................... 19 4.2 Bit Record .................................................................................................................................................... 25 4.3 Mud Record ................................................................................................................................................. 26 4.4 Drilling Progress ........................................................................................................................................... 27 5 SHOW REPORTS ............................................................................................................................................ 28 6 DAILY REPORTS ............................................................................................................................................. 29 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) Final Data CD GP 11-24RD 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 hrs. -- Effective Circulating Density (ECD) Haliburton 0 hrs. — Hook Load / Weight on bit PASON 0 hrs. — Mud Flow In PASON 0 hrs. — Mud Flow Out PASON 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 hrs. — Pit Volumes, Pit Gain/Loss PASON 0 hrs. — Pump Pressure PASON 0 hrs. — Pump stroke counters PASON 0 hrs. — Rate of Penetration PASON 0 hrs. — RPM PASON 0 hrs. — 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Allen Odegaard 20 25 Eric Andrews 5 21 Paul Webster 38 25 Brendon Schmidt 1 25 Garnet Knopp 1 4 *1 Years’ experience as Logging Geologist *2 Days at wellsite between rig up and rig down of logging unit. GP 11-24RD 3 2 GENERAL WELL DETAILS 2.1 Well Objectives GP 11-24RD is an oil production well planned to be re-drilled in a South-easterly direction from the existing GP 11-24 utilizing the existing casing program down to 8007’ MD / 7,419.26’ TVD. At 8007’ MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Tyonek targets. A 4583’ x 8.5” open hole section is planned. A 7” 26# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8” gas lift completion. The window was milled from 8006’ TOW to 8023’ BOW. Open hole was milled to 8044’ for FIT and an additional 30’ milled to 8074’ for tool clearance. The kickoff point was 8006 ’MD. TD was reached at 12,616’ MD. 7” liner was hung from the 9-5/8” casing and run down to 12,611’’ MD. Operator: HILCORP ALASKA, LLC Well Name: GP 11-24RD Field: Granite Point Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Rick Brumley, Steve Lawrence, Clint Montague, Adam Dorr Location: Surface Coordinates 2383' FSL, 1368' FEL, Sec 13, T10N, R12W, SM, AK Mud Line Elevation 75’ Rotary Table Elevation 129’ RKB Classification: Development - Oil API #: 50-733-20046-01-00 Permit #: 217-123 Rig Name/Type: Kuukpik 5 / Arctic double Spud Date September 26, 2017 Total Depth Date: October 21, 2017 Total Depth 12,613’ MD / 10,475’ TVD Primary Targets Tyonek C2 – C5 Total Depth Formation: Tyonek C-5 Completion Status: — LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service — GP 11-24RD 4 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth LOT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 8.5” Mill 8,074’ 7,480.46’ Tyonek 8.95 24.0 9.625” 8,006’ 7,418.37’ 12.5 8.5” 12,613’ 10,475.52’ Tyonek C-5 9.3 69.5 7” n/a 2.3 Daily Activity Summary 26 Sept, 2017: RIH with whip-stock and milling assembly from 2701’ to 7854’. Orient whip-stock, wash from 7854’ to 8029’. Set whip-stock. (TOW = 8006’, BOW = 8023’). Displace well with oil based mud (OBM). Circulate and condition mud. Begin milling window from 8007’. Mill window from 8006’ to 8023’. Mill new formation to 8044’. Ream through window. Set back one stand, perform FIT with 9.1+ ppg OBM to 12.5 ppg EQMW. Mill new formation from 8044’ to 8074’. Ream upper mill through window 8042’ to 8022’, dress window. Survey at 8069’. Set back one stand. Circulate bottoms up. Observe well (static). Pump dry job. POOH from 7982’ to 6028’. 27 Sept, 2017: POOH from 6028’ to surface. Lay down milling assembly (lower mill 1/8” out of gauge, upper mill in gauge). Clean and clear rig floor. Flush stack. Rig up test plug with one stand of HWDP, drain stack, land test plug, unscrew from test plug, break landing joint and kelly up to it. Slip and cut 100’ drill line. Center torque tube. Service rig. Replace HNGE pin seal on blinds and LPR DS. Function test seals. Lay down test plug. Set back one stand DP and one stand HWDP. Make up BHA #2. Plug in and upload MWD. Shallow test MWD. Load radioactive sources into MWD. Finish making up BHA. RIH from 676’ to 4076’. Fill pipe and test MWD. RIH from 4076’ to 4706’. 28 Sept, 2017: RIH from 4706’ to 7993’. Fill pipe, circulate. Service rig. Wash and ream to bottom (went through window with no problems). Drill from 8074’ to 8154’. Cut trough from 8121’ to 8151’. Time drill from 8151’ to 8162’. 29 Sept, 2017: Time drill from 8162’ to 8170’. Drill from 8170’ to 8191’. POOH from 8191’ to 7994’. Monitor well. Static. Pump dry job. POOH from 7994’ to 676’. Set back 7 stands of HWDP, one stand HWDP/Jars, and one stand of drill collars. Unload radioactive sources. Download MWD. Blow down Geo Pilot. Lay down MWD tools and Geo Pilot. Clean and clear rig floor. Service rig. Pick up and make up BHA #3 to 609’. RIH from 609’ to 2156’. 30 Sept, 2017: RIH from 2156’ to 7977’. Fill pie and orient 45 Right. Wash down to 8100’. Begin troughing to 8130’. Time drill from 8130’ to 8134’. Change of plan. RIH to 8191’. Directionally drill from 8191’ to 8390’. 01 Oct, 2017: Directionally drill from 8390’ to 8410’. Circulate bottoms up. POOH from 8410’ to 7986’ (Work tight hole 8360’-8310’). Service and work on rig. POOH from 7986’ to 609’. Stand back and lay down BHA. Make up BHA #4. Upload MWD and shallow-hole test MWD. Load radioactive sources. Finish making up BHA #4 to 676’. RIH from 676’ to 4080’. Fill pipe, break in seals on Geo Pilot, and test MWD. RIH from 4080’ to 7935’. Service draw works, top drive, traveling equipment, other rig service, and fill pipe/circulate. RIH 7935’ to 8234’. Wash and ream from 8176’ to 8201’. 02 Oct, 2017: Wash and ream from 8201’ to 8240’. Continue to troubleshoot top drive. POOH from 8240’ to inside window at 7992’. Troubleshoot and repair top drive. Repair cuttings shoot line. RIH from 7992’ to 8310’. Wash and ream from 8310’ to 8410’. Drill from 8410’ to 8948’. GP 11-24RD 5 03 Oct, 2017: Drill from 8948’ to 9421’. Pump high viscosity sweep, circulate bottoms up. Wipe hole from 9421’ to shoe, working tight hole and back-reaming as needed. Cut 92’ of drill line. Service rig. RIH from 7969’ to 9295’. Wash and ream from 9295’ to 9412’. 04 Oct, 2017: Wash and ream from 9412’ to 9421’. Drill from 9421’ to 9667’. Riser air boots started leaking. Repair air boots on riser. Drill from 9667’ to 10208’ (pump 11.2 ppg / 415 vis sweep at 9980’ which came back 37 bbls late with a 100% cuttings increase). 05 Oct, 2017: Drill from 10208’ to 10310’. Detect 500 psi stand pipe pressure loss. Test surface lines, all good, POOH (looking for wash out) on elevators from 10310’ to 9989’ (work through from 10055’ to 9889’, pulling 45K over). Pump out of hold from 9989’ to 8739’. Found wash out. Change bad joint. RIH from 8739’ to 10220’ (tagged up). Wash and ream from 10220’ to 10310’. Drill from 10310’ to 10570’. 06 Oct, 2017: Drill from 10570’ to 10875’ (pumped sweep at 10849’ (30% increase in cuttings, 30 bbls late)).Circulate bottoms up and 3 full circulations. POOH on elevators from 10875’ to 7990’ (no notable tight spots). Service rig. POOH from 7990’ to 6502’. 07 Oct, 2017: POOH from 6502’ to 676’. Stand back BHA, unload radioactive sources, and download MWD. Continue to lay down BHA. Break bit. Clear rig floor. Repair service loop cable on top drive. Make up BHA #5. Upload MWD. Clean and clear rig floor. Shallow-hole pulse test directional tools. Finish making up BHA (drill collars, jars, and HWDP). RIH on drill pipe to 4083’. Fill pipe at 4083’. RIH from 4083’ to 7990’. Fill pipe at 7990’. Service rig. RIH on elevators to 10511’. Wash and ream from 10511’ to 10872’ (found bottom 3 feet higher). Drill from 10872’ to 10880’. 08 Oct, 2017: Drill from 10880’ to 11280’. Circulate high viscosity weighted sweep (25% increase cuttings, 33 bbls late) and 2 3/4 bottoms up until shakers cleaned up. POOH on elevators from 11280’ to 7930’ (pulling tight (20-45K overpull) at numerous spots). Blow down geospan. Prepare for BOP test. Test gas alarms, annular to 2500 psi (both good). Failure on upper dart/kill demco (passed on low, failed on high due to alignment pin on wellhead leaking. Rig down test equipment. Rig up to test choke manifold and top drive. Test choke manifold valves 7, 15, 16, and lower IBOP. 09 Oct 2017: Test CMV 1-16 to 250 / 3500 psi. Clean rig floor, cellar and drill deck. Work on mud pump #1. Clean pit area and general housekeeping around rig. Slip and cut 100’ drill line. Service top drive and blocks. Pick up and install storm packer. Good test 1000 psi. Prepare to pick up stack and riser. Pick up stack and riser. Repair alignment pin on wellhead. Nipple up BOP. Prepare for BOP test. Test BOP. Rig down from BOP test. 10 Oct, 2017: Finish rigging down BOP test. Pull rotary table and drip pan. Remove riser, install new air boots, reseal and reinstall all. Clean rotary table. Seal and install rotary table and pin below. Blow down choke and pump out gas buster u-tube. Clean up tools. Make up storm packer retrieval tool. Retrieve storm packer. RIH from 7929’ to 10669’. Wash and ream from 10669’ to 10680’. Trough from 10680’ to 10700’. Time drill from 10700’ to 10720’. 11 Oct, 2017: Time drill from 10720’ to ~10760’. Drill from ~10760’ to 11123’. 12 Oct, 2017: Drill from 11123’ to 11215’. Pump 2 sweeps (30% and 50% increase in cuttings return) and circulate 3 bottoms up. POOH from 11215’ to 6810’ on elevators (tight spots (25-45K over pull) at 10684’, 10649’, 10640’, 10266’, and 8190’)). Service top drive, blocks, and draw works. POOH from 6810’ to HWDP. Lay down and stand back HWDP and drill collars. Remove nuclear sources. Download MWD. GP 11-24RD 6 13 Oct, 2017: Work on / Lay down BHA. Service draw works, top drive, and crown. Pick up BHA #6. Upload MWD, shallow-hole test MWD. Load radioactive sources into MWD. Continue to make up BHA #6. RIH from 431’ to 1546’. Pick up agitator and 2 crossovers. RIH from 1546’ to 11065’ (filling pipe every 2500’, tight spots at 10396’ and 10663’). Wash and ream down from 11065’ to 11185’. Circulate and condition mud while troubleshooting lube pump on top drive. Wash and ream from 11185’ to bottom (tag bottom at 11212’). Drill from 11212’ to 11370’. 14 Oct, 2017: Drill from 11370’ to 11559’. Service top drive and draw works. Replace coupler on HPU #2. Drill from 11559’ to 11651’ (pumped 9.7 ppg / 300 vis sweep at 11580’, 25% increase in cuttings). Pump high vis weighted sweep and reciprocate pipe. POOH on elevators from 11651’ to 7963’ (tight spots at 10753’, 10655’, 10641’, 10632’, and 10558’ (30-50K over pull)). Service top drive, draw works, blocks, and crown. POOH from 7953’ to 6969’. 15 Oct, 2017: POOH from 6969’ to MWD. Unload nukes from MWD tools and download MWD. Work on BHA #6. Make up BHA #7. Download MWD, load nukes. Finish making up BHA #7. RIH to 7962’ (filling pipe every 2500’). Slip and cut 162’ drilling line. Run new external wire for top drive lube pump. RIH from 7962’ to 10074’ (fill pipe at 10074’). 16 Oct, 2017: RIH from 10074’ to 10551’, set down, tight hole, no over pull. Wash from 10540’ to 10640’. RIH on elevators from 10640’ to 11560’. Wash from 11560’ to 10651’. Drill from 11651’ to 11858’. 17 Oct, 2017: Drill from 11858’ to 11880’ (Pump 20 bbl 10.2 ppg / 240 vis sweep at 11880’ (35 bbls late / 20% increase cuttings)). Drill from 11880’ to 12127’ (Pump sweep at 12000’ (35 bbls late / 100% increase cuttings)). 18 Oct, 2017: Drill from 12127’ to 12181’ (Pump sweep at 12181’ (35 bbls late / 10% increase cuttings)). Drill from 12181’ to 12255’, rack one stand back, pump sweep and circulate sweep to surface (50 bbls late / 10% increase cuttings). Drill from 12255’ to 12257’. Rack back one stand, pump sweep surface to surface (45 bbls late / 25% increase cuttings). Pull 10 stands from 12243’, pump dry job. POOH from 11598’ to 8894’ (tight spots at 10879’, 10707’, 10697’ (30-40K over)). 19 Oct, 2017: POOH from 8894’ to 241’. Lay down jars. Make up new set of jars and rack back in derrick. Work on BHA #7. Unload nuclear sources from MWD tools. Download MWD. Lay down BHA #7. Make up BHA #8. Upload MWD. Shallow hole test MWD (good). Finish making up BHA #8 to 430’. RIH from 430’ to 1573’. Pick up agitator to 1602’. RIH from 1602’ to 3868’. Fill pipe. Break in seals on Geo Pilot. RIH from 3868’ to 7964’. Fill pipe. Service rig. RIH from 7964’ to 9453’ (work through tight spots at 8198’ and 9016’). 20 Oct, 2017: RIH from 9453’ to 10564’, stacked out 30K. Wash and ream from 10564’ to 10629’. Set down 10629’ to 10653’. RIH on elevators from 10653’ to 11221’, set down 40K/40K over pull, fired jars twice at 210K. Wash and ream from 11221’ to 11621’. RIH on elevators from 11621’ to 12182’. Wash and ream from 11621’ to 12254’ (break bit in). Drill from 12257’ to 12438’ (pump 10.3 ppg / 330 vis sweep at 12365’ while drilling ahead (40 bbls late / 50% increase cuttings)). Drill from 12438’ to 12534’. 21 Oct, 2017: Drill from 12534’ to 12613’ TD (pump 20 bbl 10.3 ppg / 330 vis sweep at 12556’ (40 bbls late / 30% increase cuttings)). Circulate clean, pumping 2 sweeps (Sweep #1: 20 bbl 10.2 ppg / 315 vis (40 bbls late / 50% increase cuttings), Sweep #2: 20 bbls 10.2 ppg / 400 vis (40 bbls late)). Pump Sweep #3: 0% increase cuttings. Lay down one joint to 11586’. POOH from 11586’ to 11615’, 40K over pull. Top drive up, circulate bottoms up 3X. POOH from 11640’ to 7872’, working through tight spots in coals. Service rig, mix dry job. GP 11-24RD 7 22 Oct, 2017: Finish servicing rig, mix dry job. Pump 20 bbl dry job. POOH from 7891’ to 1554’ (rabbit didn’t make it past agitator). Pick up joint and make up on top of stand 19. Break off and lay down agitator and crossovers. Drop rabbit from 1554’ to 276’. Lay down 3 joints of HWDP and jars. Rack back drill collars. Unload radioactive sources from MWD. Download MWD. Lay down down MWD tools, break bit, and lay down Geo Pilot. Service top drive and draw works. Clean and clear rig floor. Lay down top drive service loop. RIH with 2 stands of HWDP, make up test plug, drain stack, and set test plug. Fill stack, test joint, choke manifold, and work air out of system. Shell test good. Test BOP (good). Rig down from BOP test. Pick up BHA #9 to 325’. 23 Oct, 2017: Trip in hole to bottom, washing and reaming as necessary; pump sweeps to clean hole; rig down mudlogging unit. GP 11-24RD 8 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geologist Corey Ramstad FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) KOP 8,500’ 7,872’ 7,743’ 8,006’ 7,418’ -7,289’ C2 10,347’ 9,367’ 9,238’ 9,990’ 9,305’ -9,176’ C5A 10,947’ 9,798’ 9,669’ 10,682’ 9,779’ -9,650’ CTD 13,083’ 10,521’ 10,392’ 12,613’ 10,475’ -10,346’ *Note: the C3 and C4 are shaled out in this area of the field GP 11-24RD 9 3.2 Lithology Details Lithology descriptions of all Kenai Group and Mesozoic rock cuttings samples started immediately after drilling out the surface conductor, then continued as per pre-set plans and procedures, and modified when directed by the Hilcorp operations geologist. The Kenai Group of Alaska’s Cook Inlet Basin, which includes the Sterling, Beluga, Tyonek, Hemlock and West Foreland Formations, was deposited by a variable-energy fluvial system within a large closed fore- arc basin. The characteristic sedimentary stratigraphy consists of dominant massive to thinly bedded sandstone and claystone-siltstone, generally abundant thin inter-beds of air fall and re-deposited volcanic ash, minor beds of basal or modal conglomerate and extensively-distributed thin beds of coal and carbonaceous rocks. Gradational upward-fining sequences and bi-modal distribution zones are abundant within sandstone sections. Note that in Canrig’s Lithology Descriptions, the special modifying term “tuffaceous” was created to address the pervasive presence and diversity of soft-sediment volcanogenic- origin rocks in the Cook Inlet area. Though generally applied to significantly ash-rich clay-silt-sand lithologies, its wide use in descriptions may include discernible micro-shard concentrations of disaggregated volcanic glass to vitric air fall volcanic ash to smectite-bentonite clays derived from devitrified ash to rare layers of vitric ignimbrite. Tuffaceous Siltstone (8015' - 8055') = dark olive gray; rounded cuttings; soft to slightly firm; mushy to easily crumbly; dull luster; finely grainy texture; no evident structure; fines to tuffaceous claystone, occasionally arenaceous and grading to sandstone; faint to dull yellow oil based mud contamination sample fluorescence; no other oil signs. Tuffaceous Claystone (8065' -8090') = dark olive gray; rounded cuttings; soft to slightly firm; easily crumbly; dull luster; very finely grainy texture; no evident structure; grades to tuffaceous siltstone; no detectable oil indicators. Tuffaceous Siltstone (8090' - 8150') = medium gray to light medium gray to dark olive gray; rounded cuttings; soft to slightly firm; mushy to easily crumbly; dull luster; finely grainy texture; no evident structure; grades to tuffaceous claystone, occasionally arenaceous and grading to tuffaceous sandstone; faint to dull yellow oil based mud contamination sample fluorescence; no other oil indicators. Sand / Tuffaceous Sandstone (8150' - 8240') = light brown to brownish gray, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, black; upper very fine to lower medium grained, dominantly fine; angular to sub-rounded, dominantly sub-angular; fair to good sorting; predominantly unconsolidated with scattered sandstone; very firm to slightly hard; friable at times; fine to medium; grain supported; non-calcareous; trace coal; no oil indicators over oil based mud. Sand (8275' - 8320') = dominant translucent to clear, occasional gray; upper fine to lower coarse; well to moderately sorted; dominant subangular, common angular and subround, occasional round; dominant moderate to occasional low and high sphericity; dominant quartz, occasional igneous lithics; faint to dull yellow oil based mud contamination sample fluorescence. Tuffaceous Sandstone (8330' - 8410') = light to very light gray (brownish when infiltrated by oil based mud); upper very fine to lower fine; well sorted; dominant subround, common subangular; occasional round; dominant moderate to occasional high sphericity; matrix supported with bentonitic matrix grading to grain packed, occasionally calcite-cemented sandstone; dominant quartz, occasional lithics; no detectable oil indicators. GP 11-24RD 10 Tuffaceous Claystone / Tuffaceous Siltstone (8410' - 8490') = medium to medium light gray with light gray secondary hues; firm to crumbly; irregular shaped cuttings habit with PDC bit action shaped cuttings common; silty to clayey texture; dull to earthy luster; easily rehydrated; very soft and mushy; good cohesiveness; poor adhesiveness; non-calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; occasionally interbedded with sand/tuffaceous sandstone; no hydrocarbon indicators over oil based drilling fluid. Sand / Conglomerate (8490' - 8555') = dominant translucent to clear, common grays, white, black; upper very fine to dominant lower coarse; poorly sorted; dominant subangular, common angular and subround, occasional rounded (conglomerate grains originally fairly rounded but bit-shattered to angular); unconsolidated sands probably originally sandstones in situ; quartz sand derived from dominant igneous and occasional volcanic provenance; faint to dull yellow oil based mud contamination sample fluorescence; no other oil indicators. Tuffaceous Siltstone (8565' - 8600') = medium gray; blocky cuttings; soft to moderate firm; mushy to moderate crumbly; dull luster; grainy texture; lithology intermixed with 2mm quartz in claystone matrix, common inter-bedding; grades to tuffaceous claystone and sandstone; no detectable oil indicators. Tuffaceous Claystone (8610' - 8640') = medium to olive gray; irregular cuttings; soft to very firm; mushy to moderately crumbly and brittle; dull luster; very finely grainy texture; grades to tuffaceous siltstone; no detectable oil indicators. Coal (8650' - 8665') = black, blocky to angular cuttings; moderate firm and crumbly; some bedding delineation; no detectable oil indicators. Tuffaceous Siltstone (8675' - 8710') = dominant olive gray, occasional very light gray; amorphous cuttings; soft to moderately firm; mushy to moderately crumbly; dull luster; dominant grading to tuffaceous claystone, occasionally very bentonitic and grading to tuffaceous sandstone; no detectable oil. Tuffaceous Sandstone (8720' - 8760') = light to very light gray; soft to slight firm; mushy to easily friable; lower fine to lower coarse, dominant upper fine; moderately sorted; dominant ashy, bentonitic matrix support, occasionally grain packed with some calcite cement; dominant quartz with common volcanic lithics; no detectable oil indicators. Tuffaceous Claystone / Tuffaceous Siltstone (8770' - 8835') = medium to light gray, olive gray; amorphous to blocky cuttings; soft and mushy to very firm and slightly crumbly; dull luster; very finely grainy to grainy, slightly arenaceous texture; homogeneous cuttings overall but with occasional well- defined bedding contacts between more or less argillaceous and arenaceous material; grading evenly to each other and to tuffaceous sandstone; dull to moderately bright whitish yellow mineral and oil based mud contamination sample fluorescence. Tuffaceous Sandstone (8845' - 8890') = very light gray to light gray; blocky cuttings; soft and mushy to moderately firm and easily friable; upper very fine to lower coarse, dominant lower fine; moderately sorted; dominant matrix supported with ashy, bentonitc matrix to common grain packed with less matrix material and some calcite cement; quartz with common lithics; no oil indicators. Tuffaceous Siltstone (8900' - 8945') = dominant olive gray, occasional light gray; amorphous to blocky cuttings; soft and mushy to very firm and slightly crumbly; dull luster; dominant very finely grainy, argillaceous and grading to tuffaceous claystone, occasionally bentonitic and arenaceous; dull to moderately bright whitish yellow oil based mud contamination and mineral fluorescence. Tuff (8955' - 8980') = very light gray; very soft and mushy; dull luster; smooth to gritty texture; nearly pure bentonite but commonly with ultrafine quartz and volcanic lithics, grading to tuffaceous sandstone; no detectable oil indicators. GP 11-24RD 11 Tuffaceous Sandstone (8990' - 9015') = very light gray; soft; mushy, sticky, easily friable; consists of fine-grained dominant quartz and common volcanic lithcs suspended in bentonitic tuff matrix; no detectable oil indicators. Tuffaceous Sandstone (9025' - 9065') = very light gray; soft; mushy, sticky, easily friable; consists of dominant volcanic quartz and common volcanic lithics that are dominant fine grained but occasionally upper coarse suspended in bentonitic tuff matrix; dull to moderately bright oil based mud contamination and mineral sample fluorescence. Tuffaceous Siltstone (9075' - 9150') = dominant olive gray to occasional light gray; soft to moderately firm; mushy to moderately crumbly; dull luster; very finely grainy texture to grainy texture; grades to tuffaceous claystone; dominant argillaceous to occasionally bentonitic and grading to bentonitic sandstone and tuff; when argillaceous commonly grades to dirty sandstone; dull to moderately bright obm-contamination and mineral sample fluorescence. Coal (9150' - 9210') = black to almost black to brownish black; firm to hard and brittle; splintery to planar fracture with trace conchoidal; platy to flaky to wedge-like; earthy to resinous luster; smooth, slightly silty texture; moderately well to well developed; bituminous; no outgassing observed; present as thin beds, dominantly interbedded with sands and claystone/siltstones. Tuffaceous Claystone / Tuffaceous Siltstone (9210' - 9280') = medium gray to medium dark gray to brownish gray; irregular shaped cuttings with common PDC bit buttercurl cuttings; soft to firm to moderately hard; silty to clayey texture; dull to earthy luster easily rehydrated; common dark brown to black micro-thin carbonaceous laminations and inclusions; non-calcareous; often interbedded with thin coal seams; no hydrocarbon indicators over oil based drilling fluid. Coal (9280' - 9330') = black to almost black to brownish black; firm to hard; brittle; splintery to planar fracture, with trace conchoidal; platy to flaky to wedge-like; earthy to resinous luster; smooth to slightly silty/gritty texture; moderately well to well developed; bituminous; no outgassing observed; present as thin beds, dominantly interbedded with sands and claystone/siltstones. Sand/ Conglomeratic Sand/ Tuffaceous Sandstone (9330' - 9420') = medium brown to medium light brownish gray overall, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, pale rose and dusky red to almost white; very fine upper to very coarse upper with fragments to 5mm, dominantly fine upper to medium upper; angular to sub-rounded, dominantly subangular; poorly sorted; dominantly unconsolidated with scattered to common ash supported grains; ashy matrix is very soft to fragile; very light gray to almost white; non-calcareous; no hydrocarbon indicators over oil based mud. Tuff (9425' - 9465') = very light gray; extremely soft and mushy; soluble and much tuff is lost on sample wash; finely grainy to ultrafine arenaceous texture; grades to tuffaceous sandstone in part; continued dull to moderately bright whitish yellow oil based mud contamination and mineral sample fluorescence; no other detectable oil indicators. Coal (9475' - 9495') = black; hard to very firm; tough to moderately firm but brittle; shiny luster; smooth texture; occasionally splits along bedding; no detectable oil indicators. Tuffaceous Sandstone (9505' - 9540') = very light gray; soft and mushy; dominant lower fine to common upper fine, dominant quartz, common volcanic lithics disseminated in bentonitic tuff matrix; grades to bentonite; moderately bright slightly greenish yellow mineral and oil based mud contamination sample fluorescence. GP 11-24RD 12 Coal (9540' - 9610') = black; hard to very firm; tough to moderately firm but brittle; shiny luster; smooth texture; occasionally splits along bedding; often interbedded with tuffaceous claystones, siltstones, and sandstones; no oil indicators over oil based mud. Tuffaceous Siltstone/Claystone (9610' - 9700') = medium brown to light to medium gray to brown, occasionally with pale yellow to reddish hues; easily friable; unconsolidated; occasionally grading to a tuffaceous sandstone; claystones are dark blackish brown to dark brown with pale yellow and red hues; poor to moderate induration; semi-tough; planar to irregular to occasional conchoidal fracture; platy to tabular cuttings habit; very common PDC bit buttercurl cuttings; dull to earthy to greasy luster; dull yellowish white fluorescence due to oil based mud contamination; no cut; no odor; no hydrocarbon indicators over oil based mud. Tuffaceous Sandstone / Sand (9700' - 9770') = very light yellowish brown to light gray and grayish white; easily friable to unconsolidated; upper fine to lower coarse; poor to moderate sorting; sub-angular to sub-rounded to rounded; sub-spherical to trace sub-discoidal; grain supported; dominated by clear to translucent quartz with common dark lithics; trace reaction to HCl; often interbedded with siltstones and claystones; no cut; no odor; no fluorescence or hydrocarbon indicators over oil based drilling fluid. Sand / Conglomeratic Sand (9770'-9840') = medium brownish gray to light grayish brown; individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, pale rose and dusky red and white; upper very fine to upper very coarse grained, predominantly upper fine to lower coarse grained; angular to sub-angular with trace sub-rounded; poor sorting; dominantly unconsolidated; no cut; no odor; no fluorescence or hydrocarbon indicators over oil based drilling fluid. Tuffaceous Siltstone / Claystone (9840' - 9920') = medium brown to light to medium gray to brown; soft to easily friable; unconsolidated; occasionally grading to a tuffaceous sandstone; claystones are dark blackish brown to dark brown with pale yellow and red hues; poor to moderate induration; semi-tough; planar to irregular to occasional conchoidal fracture; platy to tabular cuttings habit; very common PDC bit buttercurl cuttings; dull to earthy to greasy luster; no cut; no odor; no hydrocarbon indicators over oil- based mud; often interbedded with thin coal seams. Coal (9920' - 9960') = black; hard to very firm; tough to moderately firm but brittle; shiny luster; smooth texture; splintery fracture; often interbedded with tuffaceous claystones, siltstones, and sandstones; no hydrocarbon indicators over oil based mud. Tuffaceous Siltstone (9965' - 9995') = overall olive gray; soft to slightly firm; mushy to easily crumbly; dull luster; finely grainy texture; no obvious structure but appears to be thinly bedded; grades to tuffaceous claystone; no detected oil indicators. Tuffaceous Sandstone (10005' - 10070') = very light gray when not stained by oil based mud; slightly firm; easily friable; lower fine to upper very coarse, upper part is dominant lower fine, lower part coarsens to dominant coarse with stray loose grains > 2mm; moderately to poorly sorted; dominant subangular to subround, common angular; overall matrix supported with dominant bentonitic to occasional gray ashy matrix; dominant quartz, common lithics; 100% moderately bright whitish yellow sample fluorescence that appears brighter than previous samples. Tuffaceous Siltstone (10080' - 10120') = olive gray to light gray; soft and mushy to slightly firm and easily crumbly; dull luster; finely grainy texture; olive gray is more argillaceous and grades to tuffaceous claystone, light gray is bentonitic and grades to tuff and tuffaceous sandstone; no detectable oil indicators over oil based mud background. GP 11-24RD 13 Tuffaceous Sandstone (10130' - 10170') = very light gray; soft and mushy with 100% bentonite (commonly grading to bentonite tuff) matrix; individual grains ultrafine to lower fine, dominant very fine disseminated in matrix; dominant round to common subround; sorting moderate; dominant quartz, occasional lithics; no detectable oil indicators. Tuffaceous Sandstone (10200' -10245') = very light gray; soft and mushy; dominant very fine to occasional lower fine; well to moderately sorted; dominant round to subround, common subangular; continued abundant bentonite matrix but overall with increased argillaceous material, increased grain- packed sandstone; dominant quartz, occasional lithics; no observed oil indicators. Tuffaceous Siltstone (10255' - 10280') = olive gray to light; soft and mushy; dull luster; thinly bedded; argillaceous and grading to tuffaceous claystone or fining down from bentonitic tuffaceous sandstone; no detectable oil indicators. Sand / Tuffaceous Sandstone / Sandstone (10280'- 10380') = light to medium light grayish brown with light yellowish brown secondary hues; light to dark gray, trace dusky red; unconsolidated to easily friable to trace firm; lower fine to upper coarse grained; predominantly upper medium to upper fine grained; sub- angular to sub-rounded; poor to fair sorting; grain to minor matrix supported; white to off white ashy matrix; non-calcareous; trace patchy faint yellowish fluorescence; no visible cut; faint translucent slow yellow-white cut fluorescence; no staining; no odor. Coal (10380' - 10430') = black; hard to very firm; tough to moderately firm but brittle; shiny luster; smooth texture; splintery fracture; often interbedded with tuffaceous claystones, siltstones, and sandstones; no oil indicators over oil based drilling fluid. Tuffaceous Siltstone (10425' - 10465') = overall olive gray, trace light gray; soft, mushy, amorphous cuttings; dull luster; very finely grainy texture; no evident structure; dominant argillaceous with only trace bentonitic; grades strongly to tuffaceous claystone, rarely to tuffaceous sandstone; any oil indicators masked by oil based mud contamination. Tuffaceous Claystone (10475' - 10505') = overall olive gray; soft and mushy; amorphous cuttings; dull luster; very finely grainy texture to slightly smooth texture; grades evenly to tuffaceous siltstone; any oil indicators masked by oil based mud contamination. Sandstone (10515' - 10555') = overall olive gray; blocky cuttings; moderately firm and friable to moderately hard and tough; upper very fine to upper fine; moderately sorted; subangular to subround; grain-packed with moderate to slight amounts of argillaceous matrix fill; dull whitish yellow oil based mud contamination sample fluorescence. Sandstone (10565' - 10640') = overall medium gray; blocky cuttings; dominant slight to moderate firm, occasional very firm; dominant easily to moderately friable, occasionally moderately tough; very fine to lower coarse, dominant lower fine; moderately sorted; subangular to subround; grain-packed with slight to abundant argillaceous matrix fill; dominant quartz, common lithics; oil logged on basis of heavies; no other oil indicators observable over oil based mud. Tuffaceous Sandstone (10640' - 10755') = light to medium gray to dark yellowish brown; blocky cuttings; overall easily friable; dominant upper fine to upper medium grained with occasional lower very fine to lower fine grained; moderately sorted; overall poor to moderate sphericity; sub-angular to sub- rounded; frosted to grinding surface abrasion; grain-supported with ashy matrix; dominantly quartz, common dark lithic fragments; dull yellow sample fluorescence with occasional brighter patches which appear to be brighter and more uniform than background oil based mud contamination; instant dull yellowish white cut fluorescence; dark straw visible cut; dull yellow residual cut fluorescence; light brown residual cut; samples appear to be oil stained with possible visible interstitial oil in cracked-open sandstone cuttings; no odor. GP 11-24RD 14 Tuffaceous Sandstone (10755' - 10875') = light to medium gray to dark yellowish brown; blocky cuttings; overall easily friable; dominant upper fine to upper medium grained with occasional lower very fine to lower fine grained; moderately sorted; overall poor to moderate sphericity; sub-angular to sub- rounded; frosted to grinding surface abrasion; grain-supported with ashy matrix; dominantly quartz, common dark lithics which give a salt and pepper appearance; dull yellow sample fluorescence with brighter patches which are more uniform than background oil based mud contamination; instant dull yellowish white cut fluorescence; dark straw visible cut; dull yellow residual cut fluorescence; light brown residual cut; oil staining visible from interstitial oil in cracked-open sandstone cuttings; no odor. Tuffaceous Sandstone (10875' - 10945') = stained brown by obm and some oil staining, interior is very light gray; overall slightly firm and easily friable; lower very to upper coarse, dominant fine; moderately sorted; dominant subangular to subround, occasional well rounded; grain packed with dominant bentonitic matrix, occasional dense with low matrix fill and some calcite cement; dominant quartz, common lithics; appears oil stained; dull yellow sample with brighter patches over obm contamination. Tuffaceous Siltstone (10955' - 11020') = olive to medium gray; amorphous to slightly platy cuttings; dominant soft and mushy to occasional very firm and slightly crumbly; dull luster; commonly fines down to claystone and coarsens up to tuffaceous sandstone; faint yellow patchy obm fluorescence, lacking in objective oil indicators. Tuffaceous Claystone (11020' - 11070') = overall olive gray; soft and mushy; amorphous cuttings, often with PDC bit buttercurl; dull luster; very slightly gritty to almost smooth texture; often grades to a tuffaceous siltstone; faint yellow patchy obm fluorescence, lacking in objective oil indicators. Tuffaceous Sandstone (11070' - 11180') = light to medium gray to dark yellowish brown; blocky cuttings; soft to easily friable; dominant upper fine to upper medium grained with occasional lower very fine to lower fine grained; moderately sorted; overall poor to moderate sphericity; sub-angular to sub- rounded; frosted to grinding surface abrasion, some polished to vitreous; grain support with ashy matrix; dominantly quartz, with common dark lithic fragments which give a salt and pepper appearance; dull yellow sample fluorescence with some brighter patches which are more uniform than background oil based mud back- ground; instant dull yellowish white cut fluorescence; dark straw visible cut; dull yellow residual cut fluorescence; light brown residual cut; oil staining visible from interstitial oil in cracked open sandstone cuttings; no odor. Tuffaceous Siltstone (11080' - 11235') = olive gray to medium gray; amorphous to slightly platy cuttings; dominant soft and mushy to trace very firm and slightly crumbly; dull luster; commonly fines down to claystone and coarsens up to tuffaceous sandstone; faint yellow patchy obm fluorescence, lacking in objective oil indicators. Tuffaceous Claystone (11235' - 11280') = overall olive gray; soft and mushy; amorphous cuttings, often with PDC bit buttercurl cuttings; dull luster; very slightly gritty to almost smooth texture; often grades to a tuffaceous silt- stone; faint yellow patchy oil based mud fluorescence, lacking in objective hydrocarbon indicators. GP 11-24RD 15 Begin Open-hole Sidetrack at 10,700’ Tuffaceous Sandstone (10640' - 10810') = light to medium gray to dark yellowish brown; blocky cuttings; overall easily friable; dominant upper fine to upper medium grained with occasional lower very fine to lower fine grained; moderately sorted; overall poor to moderate sphericity; sub-angular to sub- rounded; frosted to grinding surface abrasion; grain-supported with ashy matrix; dominantly quartz, common dark lithic fragments; dull yellow sample fluorescence with occasional brighter patches which appear to be brighter and more uniform than background obm contamination; instant dull yellowish white cut fluorescence; dark straw visible cut; dull yellow residual cut fluorescence; light brown residual cut; samples appear to be oil stained with possible visible interstitial oil in cracked-open sandstone cuttings; no odor. Tuffaceous Sandstone (10810' - 10920') = light to medium gray to dark yellowish brown; blocky cuttings; overall easily friable; dominant upper fine to upper medium grained with occasional lower very fine to lower fine grained; moderately sorted; overall poor to moderate sphericity; sub-angular to sub- rounded; frosted to grinding surface abrasion; grain-supported with ashy matrix; dominantly quartz, common dark lithics which give a salt and pepper appearance; dull yellow sample fluorescence with brighter patches which are more uniform than background oil based mud contamination; instant dull yellowish white cut fluorescence; dark straw visible cut; dull yellow residual cut fluorescence; light brown residual cut; oil staining visible from interstitial oil in cracked-open sandstone cuttings; no odor. Tuffaceous Sandstone (10920' - 11040') = light to medium gray to dark yellowish brown; loose grains transparent to translucent; blocky cuttings; overall easily friable; bit action generates common loose grains; dominant upper fine to upper medium grained with occasional lower very fine to lower fine grained; moderately sorted; poor to moderate sphericity; sub-angular to sub-rounded; frosted to grinding to polished surface abrasion; grain supported with ashy matrix; dominantly quartz, with common dark lithic fragments which give a salt and pepper appearance; dull yellow sample fluorescence; quick to instant dull yellowish white cut fluorescence; dark amber visible cut; dull yellow residual cut fluorescence; amber to light brown residual cut; oil staining visible from interstitial oil in cracked-open sandstone cuttings; no odor. Tuffaceous Sandstone (11040' - 11100') = stained brown by obm and oil; irregular cuttings with very few "curlycue" PDC cuttings; lower very fine to upper coarse, dominant lower fine; moderately sorted; sub- angular to round, dominant subround; dominant moderate, occasional high sphericity; grain to matrix support with abundant very light bentonitic matrix fill; dominant quartz, common lithics; 95% moderately bright yellow sample fluorescence elevated over oil based mud background; appears oil stained. Tuffaceous Sandstone (11100' - 11215') = light to medium gray to yellow-brown, stained brown by obm and oil; irregular cuttings with very few PDC buttercurl cuttings; lower very fine to upper coarse grained, dominant lower fine; moderately sorted; sub-angular to rounded, dominantly sub-rounded; dominant moderate, occasional poor to high sphericity; grain to matrix support with abundant very light bentonitic matrix fill; dominant quartz, common lithics; dull yellow sample fluorescence; quick to instant dull yellowish white cut fluorescence; dark amber visible cut; dull yellow residual cut fluorescence; amber to brown residual cut; no petroleum odor. Sand (11225' - 11280') = dominant clear to translucent, common white, black; lower fine to upper coarse, dominant upper fine to lower medium; rare lower very coarse; poorly sorted; angular to subround, dominant subangular; dominant moderate to occasional high sphericity; dominant quartz, common lithics; 100% moderately bright yellow sample with occasional brighter patches; appears oil stained; possible visible oil inside cracked-open sandstone cuttings. GP 11-24RD 16 Sandstone (11290' - 11335') = overall olive gray; blocky to rounded cuttings; overall moderately firm and friable; lower fine to upper medium, dominant upper fine; grain-packed with common to abundant argillaceous matrix fill; dominant quartz, common lithics; 100% moderately bright yellow sample fluorescence; appears oil stained; possible visible inside cuttings. Tuffaceous Sandstone (11365' - 11435') = stained olive gray to moderate brown, when clean very light gray; lower very fine to lower coarse, dominant fine; poorly to moderately sorted; angular to subround, dominant subangular; overall matrix support with bentonitic tuff matrix, occasional grades to grain-packed argillaceous sandstone; dominant quartz, common lithics that give salt and pepper appearance; 100% moderately bright yellow sample fluorescence with occasional brighter patches; appears oil stained; visible oil found in cracked-open sandstone cuttings. Sand (11445' - 11520') = dominant clear to translucent, common white, black, gray; lower fine to 3mm, dominant upper fine to lower medium; poorly sorted; angular to subround, dominant subangular; dominant quartz, common volcanic and igneous lithics; oil: 100% moderate bright yellow sample fluorescence with occasional brighter patches; appears oil stained; occasional cracked-open sandstone cuttings with interstitial oil. Tuffaceous Sandstone (11520' - 11620') = olive gray to moderate brown, loose grains transparent to translucent to very light gray; lower very fine to lower coarse grained, dominantly fine; poorly to moderately sorted; angular to sub-round, dominant sub-angular; grinding to frosted surface abrasion; overall matrix support with bentonitic tuff matrix, occasionally grades to tuffaceous siltstone; dominantly quartz, with common lithic fragments that give a salt and pepper appearance; very slightly to slightly calcareous; 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil stain visible; visible oil found in cracked- open sandstone cuttings. Tuffaceous Sandstone (11620' - 11750') = olive gray to moderate brownish gray, loose grains transparent to translucent to very light gray; lower very fine to lower coarse grained, dominantly fine; poorly to moderately sorted; angular to sub-rounded, dominant sub-angular; frosted to grinding surface abrasion; overall matrix support with bentonitic tuff matrix, occasionally grades to tuffaceous siltstone; dominantly quartz, with common lithics that give a salt and pepper appearance; slightly to moderately calcareous; 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil staining visible; visible oil found in cracked-open sandstone cuttings. Tuffaceous Sandstone (11755' - 11820') = obm/oil stained moderate brown, true colors probable medium to very light gray; slightly to moderately; easily to moderately friable; lower very fine to lower coarse, dominant lower fine; moderately to poorly sorted; overall moderate sphericity; grain to matrix support with variable bentonitic to gray ash matrix; dominant quartz, common lithics; 100% moderately bright yellow sample fluorescence with occasional brighter patches; appears oil stained; visible oil in cracked-open cuttings. Tuffaceous Siltstone (11850' - 11910') = medium gray: platy cuttings; hard; tough; dull luster; slight abrasive texture; appears to be ~1mm thin beds; light gray: slightly firm; easily friable and crumbly; dull luster; grainy to ultra-fine arenaceous texture, fining down from tuffaceous sandstone with mixed ashy and bentonitic material; oil: 100% moderately bright yellow sample fluorescence with occasional brighter patches; samples appear oil stained; occasional probable interstitial oil. Tuffaceous Sandstone (11910' - 12010') = moderate brownish gray to olive gray, loose grains transparent to translucent to very light gray; lower very fine to lower coarse grained, dominantly fine grained; poorly to moderately sorted; very angular to angular to sub-rounded, dominantly sub-angular; frosted to grinding surface abrasion; overall matrix support with bentonitic tuff matrix, often grades to tuffaceous siltstone; dominantly quartz, with common lithic fragments that give a salt and pepper appearance; moderately to very calcareous; 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil staining visible; visible oil found in cracked-open sandstone cuttings. GP 11-24RD 17 Sand (12020' - 12070') = dominant clear, common translucent, occasional multicolored; lower very fine to upper coarse, dominant fine (strays to >2mm); angular to subround, dominant subangular (less angular in very fines); dominant quartz, common lithics; 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil-stained appearance; possible visible oil in cracked-open sandstone cuttings. Tuffaceous Sandstone (12080' - 12160') = stained brown by obm/oil, very light gray unstained; slightly firm and easily friable; lower very fine to upper coarse, dominant fine; poorly sorted; dominant grain packed to occasional matrix supported; matrix dominant bentonitic, common ash; grades to clean grain- packed, hard sandstone; dominant quartz, common lithics; 100% moderately bright yellow sample fluorescence; appears oil stained; possible visible oil in intergranular pores in sandstone. Sand / Tuffaceous Sandstone (12160' - 12230') = dominantly clear, transparent to translucent, occasional multicolored; lower very fine to upper coarse, dominant fine with scattered grains >2mm; angular to sub-rounded, dominantly sub-angular; dominantly quartz, common darker lithic fragments; slightly calcareous; 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil stained appearance; possible visible oil in cracked-open sandstone cuttings. Tuffaceous Sandstone (12250' - 12370') = moderate brownish to olive gray, loose grains transparent to translucent to very light gray; lower very fine to lower coarse grained, dominantly fine grained, strays to >2mm; poorly to moderately sorted; very angular to angular to sub-angular to sub-rounded, dominantly sub-angular; frosted to grinding surface abrasion; overall matrix support with bentonitic tuff matrix, often grades to tuffaceous siltstone; dominantly quartz, with common lithic fragments that give a salt and pepper appearance; very slightly to non-calcareous; 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil staining visible; visible oil found in cracked-open sandstone cuttings; moderate amber visual cut; light brown residual cut ring. Sand (12390' - 12440') = dominant clear to translucent, occasional black, gray, white; lower very fine to lower coarse, dominant lower fine (trace stray > 2mm); moderately sorted overall; angular to subround, dominant subangular; dominant quartz, common to occasional lithics; oil: 95 to 100% moderately bright yellow sample fluorescence; oil-stained appearance; some possible intergranular oil in cracked-open sandstone cuttings. Sandstone (12450' - 12550') = stained brown by obm/oil; dominant slightly firm and easily friable, grain packed with low to moderately amounts of clay and silt-sized matrix fill, lower very fine to upper medium (dominant lower fine) to occasionally very firm and slightly friable, grain packed with no clay and silt-sized matrix fill but with common calcite cement, lower fine to upper coarse (dominant upper fine to lower medium); dominant quartz, common miscellaneous lithics; oil: 100% mostly even moderately bright yellow sample fluorescence with few to some brighter patches; appears oil stained; trace possible visible oil in sandstones. Tuffaceous Siltstone (12550' - 12613') = moderate brownish to olive gray to medium gray; platy cuttings; friable to tough to hard; dull luster; grainy to ultrafine arenaceous texture, often slightly abrasive, occasionally fining down from tuffaceous sandstone with mixed ashy and bentonitic material; often appears to be ~1mm thin beds; 100% moderately bright yellow sample fluorescence with trace/rare brighter patches; samples appear oil stained; occasional possible interstitial oil. GP 11-24RD 18 3.3 Sampling Program set type and purpose interval frequency distribution A Washed and Dried Reference 8,007’ – 11,280’ (plug back 1) 10,700’ – 12,613’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99503 B Washed and Dried Reference 8,007’ – 11,280’ (plug back 1) 10,700’ – 12,613’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99503 GP 11-24RD 19 4 Drilling Data 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 123.0 0.25 310.00 123.00 -0.10 0.20 -0.20 0.20 148.0 0.17 305.00 148.00 -0.20 0.20 -0.30 0.33 173.0 0.17 293.00 173.00 -0.20 0.30 -0.30 0.14 198.0 0.25 296.00 198.00 -0.20 0.30 -0.40 0.32 223.0 0.00 240.00 223.00 -0.20 0.30 -0.50 1.00 248.0 0.17 240.00 248.00 -0.20 0.30 -0.50 0.68 273.0 1.17 277.00 273.00 -0.10 0.30 -0.80 4.16 298.0 2.25 270.00 298.00 0.00 0.40 -1.50 4.39 323.0 1.25 248.00 323.00 0.20 0.20 -2.30 4.75 348.0 1.08 223.00 348.00 0.60 0.00 -2.70 2.12 373.0 2.58 236.00 373.00 1.20 -0.50 -3.30 6.19 398.0 3.83 257.00 397.90 2.00 -1.00 -4.60 6.78 423.0 4.08 256.00 422.90 2.70 -1.40 -6.30 1.04 448.0 4.75 245.00 447.80 3.80 -2.10 -8.10 4.31 473.0 5.75 240.00 472.70 5.20 -3.10 -10.10 4.40 498.0 5.58 239.00 497.60 6.90 -4.40 -12.20 0.79 523.0 5.17 240.00 522.40 8.50 -5.60 -14.20 1.68 548.0 4.83 237.00 547.40 10.00 -6.70 -16.10 1.72 573.0 5.33 240.00 572.30 11.60 -7.90 -18.00 2.26 598.0 5.17 244.00 597.10 13.00 -8.90 -20.00 1.60 623.0 5.42 245.00 622.00 14.50 -9.90 -22.10 1.07 653.0 5.33 245.00 651.90 16.20 -11.10 -24.60 0.30 723.0 5.00 245.00 721.60 20.00 -13.80 -30.30 0.47 823.0 4.75 240.00 821.30 25.40 -17.70 -37.90 0.49 923.0 3.75 225.00 921.00 31.00 -22.10 -43.80 1.49 1,023.0 4.75 191.00 1,020.70 37.90 -28.50 -46.90 2.66 1,123.0 8.50 170.00 1,120.10 48.90 -39.80 -46.40 4.41 1,223.0 12.25 177.00 1,218.40 65.90 -57.70 -44.60 3.95 1,323.0 15.75 182.00 1,315.40 89.50 -81.80 -44.50 3.70 1,423.0 20.25 186.00 1,410.50 120.10 -112.60 -46.80 4.66 GP 11-24RD 20 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 1,523.0 23.50 187.00 1,503.30 157.10 -149.70 -51.00 3.27 1,623.0 26.25 188.00 1,594.00 199.00 -191.30 -56.50 2.78 1,723.0 26.50 187.00 1,683.60 243.30 -235.40 -62.30 0.51 1,823.0 26.50 187.00 1,773.10 287.70 -279.70 -67.70 0.00 1,923.0 26.25 188.00 1,862.70 332.00 -323.70 -73.50 0.51 2,023.0 26.25 187.00 1,952.40 376.00 -367.60 -79.30 0.44 2,123.0 26.00 187.00 2,042.20 419.90 -411.30 -84.70 0.25 2,223.0 25.75 186.00 2,132.10 463.30 -454.60 -89.60 0.50 2,323.0 25.25 185.00 2,222.40 506.00 -497.50 -93.70 0.66 2,423.0 25.00 185.00 2,312.90 548.10 -539.80 -97.40 0.25 2,523.0 24.75 184.00 2,403.70 589.80 -581.70 -100.70 0.49 2,623.0 24.00 183.00 2,494.70 630.50 -622.90 -103.30 0.86 2,723.0 23.00 183.00 2,586.50 669.90 -662.70 -105.40 1.00 2,823.0 23.00 182.00 2,678.50 708.30 -701.80 -107.10 0.39 2,923.0 22.75 182.00 2,770.60 746.60 -740.60 -108.40 0.25 3,023.0 22.75 183.00 2,862.90 784.70 -779.20 -110.10 0.39 3,123.0 22.25 184.00 2,955.20 822.50 -817.40 -112.40 0.63 3,223.0 22.00 183.00 3,047.90 859.70 -855.00 -114.70 0.45 3,323.0 21.50 184.00 3,140.80 896.30 -892.00 -117.00 0.62 3,423.0 21.50 184.00 3,233.80 932.50 -928.60 -119.60 0.00 3,523.0 21.00 184.00 3,327.00 968.40 -964.70 -122.10 0.50 3,623.0 21.25 185.00 3,420.30 1,004.10 -1,000.70 -124.90 0.44 3,723.0 21.50 185.00 3,513.40 1,040.20 -1,037.00 -128.10 0.25 3,823.0 21.50 185.00 3,606.50 1,076.50 -1,073.50 -131.30 0.00 3,923.0 23.25 186.00 3,698.90 1,114.30 -1,111.40 -134.90 1.79 4,023.0 22.00 186.00 3,791.20 1,152.50 -1,149.60 -139.00 1.25 4,123.0 22.00 186.00 3,883.90 1,189.80 -1,186.90 -142.90 0.00 4,223.0 22.50 185.00 3,976.50 1,227.40 -1,224.60 -146.50 0.63 4,323.0 24.75 184.00 4,068.10 1,267.00 -1,264.50 -149.60 2.29 4,423.0 26.00 185.00 4,158.50 1,309.50 -1,307.20 -153.00 1.32 4,523.0 26.00 184.00 4,248.30 1,352.90 -1,350.90 -156.40 0.44 4,623.0 25.50 186.00 4,338.40 1,396.00 -1,394.20 -160.20 1.00 4,723.0 25.75 187.00 4,428.60 1,439.00 -1,437.20 -165.10 0.50 4,823.0 26.00 187.00 4,518.60 1,482.40 -1,480.50 -170.40 0.25 4,923.0 26.00 186.00 4,608.40 1,526.00 -1,524.10 -175.40 0.44 5,023.0 25.75 186.00 4,698.40 1,569.40 -1,567.50 -180.00 0.25 GP 11-24RD 21 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 5,123.0 26.25 185.00 4,788.30 1,612.90 -1,611.10 -184.20 0.66 5,223.0 25.50 187.00 4,878.30 1,656.30 -1,654.50 -188.70 1.15 5,323.0 25.25 189.00 4,968.60 1,699.00 -1,696.90 -194.70 0.89 5,423.0 25.00 188.00 5,059.20 1,741.30 -1,738.90 -201.00 0.49 5,523.0 25.50 187.00 5,149.60 1,783.80 -1,781.20 -206.50 0.66 5,623.0 24.75 188.00 5,240.10 1,826.10 -1,823.30 -212.10 0.86 5,723.0 25.00 188.00 5,330.90 1,868.10 -1,864.90 -217.90 0.25 5,823.0 24.25 187.00 5,421.80 1,909.60 -1,906.30 -223.40 0.86 5,923.0 24.50 188.00 5,512.90 1,950.70 -1,947.20 -228.70 0.48 6,023.0 24.25 187.00 5,603.90 1,991.80 -1,988.10 -234.10 0.48 6,123.0 24.00 188.00 5,695.20 2,032.50 -2,028.60 -239.50 0.48 6,223.0 23.50 188.00 5,786.70 2,072.70 -2,068.50 -245.10 0.50 6,323.0 23.75 189.00 5,878.40 2,112.60 -2,108.10 -251.00 0.47 6,423.0 23.25 188.00 5,970.10 2,152.40 -2,147.60 -256.90 0.64 6,523.0 23.25 188.00 6,061.90 2,191.80 -2,186.70 -262.40 0.00 6,623.0 22.75 191.00 6,154.00 2,230.80 -2,225.20 -268.80 1.27 6,723.0 22.75 190.00 6,246.20 2,269.40 -2,263.20 -275.90 0.39 6,823.0 23.00 191.00 6,338.40 2,308.30 -2,301.40 -283.00 0.46 6,923.0 22.25 191.00 6,430.70 2,346.70 -2,339.20 -290.30 0.75 7,023.0 22.25 191.00 6,523.20 2,384.60 -2,376.40 -297.50 0.00 7,123.0 23.00 193.00 6,615.50 2,423.10 -2,414.00 -305.50 1.07 7,223.0 24.00 194.00 6,707.20 2,462.90 -2,452.70 -314.80 1.08 7,323.0 24.75 195.00 6,798.30 2,504.20 -2,492.70 -325.20 0.86 7,423.0 25.00 196.00 6,889.00 2,546.20 -2,533.20 -336.40 0.49 7,523.0 24.00 193.00 6,980.00 2,587.60 -2,573.40 -346.80 1.60 7,623.0 25.00 193.00 7,071.00 2,629.10 -2,613.80 -356.10 1.00 7,723.0 25.75 194.00 7,161.40 2,671.90 -2,655.40 -366.20 0.86 7,823.0 25.25 194.00 7,251.60 2,714.90 -2,697.20 -376.60 0.50 7,923.0 24.00 195.00 7,342.50 2,756.60 -2,737.50 -387.00 1.32 8,007.0 24.00 197.07 7,419.26 -2,770.37 -396.43 2,334.69 1.00 8,089.48 24.03 197.62 7,494.60 -2,802.42 -406.44 2,359.38 0.27 8,149.66 23.31 198.05 7,549.72 -2,825.42 -413.84 2,377.00 1.24 8,200.22 22.96 198.46 7,596.22 -2,844.28 -420.06 2,391.39 0.76 8,264.18 20.74 199.05 7,655.58 -2,866.82 -427.70 2,408.49 3.49 8,324.67 18.12 199.76 7,712.62 -2,885.80 -434.38 2,422.79 4.34 8,373.51 15.75 200.50 7,759.34 -2,899.16 -439.27 2,432.78 4.87 GP 11-24RD 22 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 8,396.02 14.64 200.73 7,781.06 -2,904.68 -441.35 2,436.88 4.97 8,459.69 11.57 193.02 7,843.07 -2,918.43 -445.63 2,447.48 5.53 8,521.89 9.93 176.72 7,904.19 -2,929.87 -446.73 2,457.35 5.53 8,583.63 8.48 158.73 7,965.15 -2,939.43 -444.78 2,466.83 5.19 8,645.23 6.73 137.48 8,026.21 -2,946.32 -440.69 2,474.81 5.33 8,707.42 7.30 112.93 8,087.95 -2,950.55 -434.58 2,481.24 4.87 8,769.39 10.10 110.91 8,149.20 -2,954.03 -425.88 2,488.10 4.55 8,831.65 12.01 111.00 8,210.30 -2,958.30 -414.73 2,496.73 3.07 8,893.59 13.48 102.74 8,270.72 -2,962.20 -401.66 2,505.85 3.78 8,955.84 14.28 101.21 8,331.15 -2,965.29 -387.05 2,514.89 1.41 9,019.12 14.18 104.51 8,392.49 -2,968.75 -371.90 2,524.50 1.29 9,080.82 14.04 105.74 8,452.33 -2,972.68 -357.38 2,534.26 0.53 9,143.37 13.50 104.06 8,513.08 -2,976.51 -343.00 2,543.87 1.08 9,206.08 13.39 105.98 8,574.08 -2,980.28 -328.92 2,553.31 0.73 9,268.13 12.93 109.83 8,634.50 -2,984.62 -315.48 2,562.97 1.59 9,330.37 14.72 110.23 8,694.93 -2,989.71 -301.51 2,573.55 2.87 9,389.43 15.07 109.66 8,752.01 -2,994.89 -287.24 2,584.34 0.65 9,452.27 15.01 108.32 8,812.69 -3,000.20 -271.82 2,595.73 0.56 9,514.93 15.11 110.83 8,873.20 -3,005.66 -256.48 2,607.22 1.05 9,576.66 17.45 116.80 8,932.46 -3,012.69 -240.69 2,620.33 4.66 9,638.58 19.62 118.93 8,991.16 -3,021.91 -223.31 2,636.10 3.66 9,701.74 22.79 119.22 9,050.04 -3,033.01 -203.35 2,654.68 5.02 9,764.48 25.19 118.96 9,107.35 -3,045.41 -181.05 2,675.42 3.83 9,825.95 25.92 120.64 9,162.81 -3,058.59 -158.05 2,697.17 1.67 9,888.78 28.90 120.88 9,218.58 -3,073.38 -133.20 2,721.17 4.75 9,951.29 31.71 120.57 9,272.54 -3,089.49 -106.09 2,747.32 4.50 10,012.80 33.98 120.29 9,324.22 -3,106.38 -77.32 2,774.89 3.70 10,074.68 36.55 120.13 9,374.74 -3,124.36 -46.45 2,804.34 4.17 10,136.10 38.96 118.19 9,423.30 -3,142.66 -13.61 2,834.94 4.36 10,198.80 39.83 118.07 9,471.76 -3,161.42 21.48 2,866.90 1.39 10,260.12 42.54 118.65 9,517.90 -3,180.60 57.01 2,899.43 4.46 10,321.50 45.63 119.38 9,561.99 -3,201.32 94.34 2,934.13 5.10 10,385.21 48.10 119.18 9,605.55 -3,224.06 134.89 2,972.02 3.88 10,446.81 50.40 121.37 9,645.76 -3,247.59 175.17 3,010.52 4.60 10,507.55 52.55 122.09 9,683.60 -3,272.58 215.58 3,050.39 3.67 10,570.21 55.21 122.19 9,720.53 -3,299.51 258.43 3,093.06 4.25 GP 11-24RD 23 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 10,631.96 58.18 123.40 9,754.43 -3,327.47 301.80 3,136.88 5.08 10,694.57 61.66 122.48 9,785.81 -3,356.92 347.27 3,182.95 5.71 10,756.46 66.09 124.24 9,813.06 -3,387.48 393.66 3,230.41 7.59 10,816.98 66.38 122.71 9,837.44 -3,418.02 439.86 3,277.78 2.36 10,841.20 66.18 122.40 9,847.19 -3,429.96 458.55 3,296.56 1.42 10,876.51 65.69 121.78 9,861.58 -3,447.09 485.86 3,323.73 2.12 10,937.96 65.51 121.80 9,886.97 -3,476.57 533.43 3,370.72 0.29 10,999.56 65.19 121.32 9,912.66 -3,505.88 581.13 3,417.61 0.88 11,062.30 66.86 122.35 9,938.15 -3,536.12 629.83 3,465.78 3.06 11,124.49 69.75 123.22 9,961.14 -3,567.41 678.40 3,514.83 4.82 11,187.01 72.88 124.02 9,981.17 -3,600.20 727.71 3,565.56 5.15 11,245.22 75.96 123.56 9,996.80 -3,631.38 774.30 3,613.67 5.35 Begin Open-hole Sidetrack at 10,700’ 10,752.38 59.83 122.76 9,814.06 -3,384.11 389.75 3,225.69 3.19 10,814.15 61.17 123.23 9,844.47 -3,413.38 434.84 3,271.44 2.26 10,876.35 61.11 123.34 9,874.49 -3,443.28 480.38 3,317.94 0.19 10,938.26 61.38 124.32 9,904.28 -3,473.50 525.46 3,364.53 1.45 11,000.92 61.35 123.36 9,934.31 -3,504.12 571.14 3,411.75 1.35 11,062.18 61.46 124.22 9,963.63 -3,534.03 615.84 3,457.91 1.25 11,123.05 62.71 125.74 9,992.12 -3,564.87 659.91 3,504.63 3.00 11,183.32 63.68 126.02 10,019.31 -3,596.39 703.49 3,551.77 1.66 11,218.82 63.77 127.71 10,034.78 -3,615.61 729.04 3,577.73 4.30 11,280.51 63.33 128.96 10,062.26 -3,649.87 772.36 3,627.29 1.94 11,342.70 64.58 130.15 10,089.56 -3,685.45 815.44 3,677.93 2.65 11,405.04 64.94 130.15 10,116.15 -3,721.81 858.54 3,729.29 0.56 11,466.27 67.29 131.09 10,140.94 -3,758.26 901.03 3,780.47 4.10 11,528.36 67.35 132.47 10,164.88 -3,796.43 943.75 3,833.30 2.06 11,590.36 68.03 134.14 10,188.42 -3,835.77 985.49 3,886.77 2.71 11,651.90 68.14 133.00 10,211.38 -3,875.12 1,026.86 3,940.08 1.73 11,715.47 71.00 132.81 10,233.57 -3,915.67 1,070.49 3,995.46 4.50 11,778.33 74.96 133.13 10,251.97 -3,956.62 1,114.46 4,051.34 6.32 11,839.03 75.76 132.77 10,267.32 -3,996.64 1,157.45 4,105.95 1.44 11,899.93 76.59 132.75 10,281.87 -4,036.79 1,200.86 4,160.87 1.36 11,964.07 75.16 133.20 10,297.53 -4,079.19 1,246.37 4,218.72 2.33 12,025.54 75.03 133.01 10,313.34 -4,119.78 1,289.74 4,274.02 0.36 12,085.01 74.92 132.99 10,328.75 -4,158.95 1,331.75 4,327.45 0.19 12,146.64 77.11 134.42 10,343.64 -4,200.27 1,374.97 4,383.34 4.20 GP 11-24RD 24 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 12,208.32 77.85 135.10 10,357.02 -4,242.67 1,417.73 4,440.00 1.61 12,272.37 76.83 134.05 10,371.06 -4,286.53 1,462.24 4,498.74 2.26 12,334.43 74.78 133.50 10,386.27 -4,328.15 1,505.68 4,555.00 3.41 12,397.06 73.03 132.37 10,403.63 -4,369.14 1,549.74 4,610.95 3.29 12,460.04 71.36 132.34 10,422.89 -4,409.53 1,594.05 4,666.47 2.66 12,522.14 69.70 132.54 10,443.59 -4,449.04 1,637.25 4,720.72 2.69 12,585.12 69.48 130.98 10,465.56 -4,488.35 1,681.28 4,775.15 2.35 12,616.00 69.48 130.98 10,476.38 -4,507.32 1,703.11 4,801.66 0.01 Note: Survey @ 12,616 is a projection to bit depth. The depth was corrected to 12,613’ from 12,616’. GP 11-24RD 25 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drilled HRS AVE ROP (Ft/HR) CONDITION Mill 8.5” Window Mill 14168575 — 8,007’ 8,074’ 67’ 5.9 11.3 1/8” Under 1 8.5” HDBS MMD75DC 12931974 7x12 8,074’ 8,191’ 117’ 20.9 5.6 1-7-BT-SH-X-1-CT-BHA 2 8.5” Schlumberger / Smith XR+PS RJ1470 3x18 8,191’ 8,410’ 219’ 15.4 14.3 1-2-WT-A-E-0-NO-BHA 3 8.5” Baker/Hughes Christensen Kymera Hybrid KM624 5268475 2x18,2x16 8,410’ 10,875’ 2,465’ 55.5 44.4 3-4-CT-A-F-I-RO-PR 4 8.5” HDBS MM75D 12670052 4x15,1x16 10,875’ 11,280’ 405’ 6.5 63.4 Note: bit used to open hole sidetrack starting at 10,700’ 4 8.5” HDBS MM75D 12670052 4x15,1x16 10,700’ 11,215’ 515’ (920’) 45.2 36.2 2-5-BT-G-X-2-CT-PR 5 8.5” HDBS EME74DC 12943177 7x12 11,215’ 11,651’ 436’ 14.4 30.3 7-3-RO-N-X-I-LT-PR 6 8.5” Baker/Hughes Christensen Kymera Hybrid KMX524 5269766 2x18,2x16 11,651’ 12,257’ 606’ 50.5 12.0 1-3-BT-T-E-1-LT-PR 7 8.5” Varel V711PDG2HRU 4009876 3x11,5x11 12,257’ 12,613’ 356’ 16.7 24.5 1-3-WT-T-X-I-PN-TD GP 11-24RD 26 4.3 Mud Record Contractor: Halliburton Baroid Date Depth MD TVD MW (ppg) VIS (s/qt) PV YP Gels HTHP (cc) FC Sols (%) O/W Ratio Sd (%) ASG AgNO3 CaCl2 (ppbl) Lime (ppb) Enviromul 9/25/17 8028 7438 9.15 109 26 11 8/15/18 4.2 0/3 8.1 80.0/20.0 0.10 3,268 — — — 9/26/17 8074 7482 9.20 79 34 15 10/19/23 3.0 0/2 8.0 77.8/22.2 0.10 3,294 1.6 13.06 6.22 9/27/17 8074 7482 9.22 104 29 13 9/18/23 3.2 0/2 8.3 77.7/22.3 0.10 3,242 1.6 13.54 6.22 9/28/27 8162 7561 9.00 70 23 11 8/17/21 3.0 0/2 6.9 78.6/21.4 0.10 3,309 1.7 15.00 8.81 9/29/17 8192 7588 9.00 85 23 9 7/15/20 3.0 0/2 6.9 78.6/21.4 0.10 3,309 1.7 15.00 9.07 9/30/17 8368 7760 9.12 90 30 16 11/24/30 3.0 0/2 7.8 80.0/20.0 0.10 3,208 1.8 16.94 8.81 10/1/17 8410 7795 9.30 140 31 16 11/23/30 3.0 0/2 8.3 79.9/20.1 0.10 3,323 1.8 16.94 8.81 10/2/17 8897 8273 9.11 91 29 14 10/23/27 3.0 0/2 7.6 80.6/19.4 0.10 3,281 1.8 16.94 8.81 10/3/17 9422 8782 9.20 130 31 15 10/27/33 3.0 0/2 7.9 80.8/19.2 0.10 3,343 1.8 16.94 8.42 10/4/17 10150 9433 9.15 76 24 13 10/24/27 3.0 0/2 8.0 82.2/17.8 0.10 3,305 1.6 14.51 6.73 10/5/17 10535 9702 9.15 76 26 16 13/28/36 3.0 0/2 7.8 82.5/17.5 0.10 3,404 1.6 14.51 6.99 10/6/17 10875 9860 9.10 86 26 14 11/26/30 3.0 0/2 7.4 82.9/17.1 0.10 3,471 1.6 14.03 6.99 10/7/17 10875 9860 9.20 186 28 15 12/26/32 3.0 0/2 8.1 82.8/17.2 0.10 3,390 1.6 14.03 7.12 10/8/17 11280 10004 9.15 101 32 16 12/27/32 3.0 0/2 8.7 83.2/16.8 0.10 3,178 1.6 14.03 7.51 10/9/17 11280 10004 9.20 148 32 13 11/24/30 3.1 0/2 8.6 82.7/17.3 0.10 3,240 1.6 14.03 7.38 Begin Open-hole Sidetrack at 10700’ 10/10/17 10717 9794 9.10 91 29 16 12/26/32 3.0 0/2 8.2 82.2/17.8 0.10 3,205 1.7 14.03 7.38 10/11/17 11091 9971 9.05 81 26 14 11/25/32 2.8 0/2 8.6 83.3/16.7 0.10 3,066 1.6 14.03 7.25 10/12/17 11215 10033 9.12 98 32 15 12/25/30 2.8 0/2 7.8 81.7/18.3 0.10 3,336 1.6 13.06 6.86 10/13/17 11313 10077 9.18 97 33 17 14/29/35 2.8 0/2 8.2 82.5/17.5 0.10 3,352 1.5 13.54 6.09 10/14/17 11651 10211 9.20 83 31 14 11/23/28 2.8 0/2 8.4 82.5/17.5 0.10 3,305 1.5 13.54 6.86 10/15/17 11651 10211 9.18 88 30 15 11/25/29 2.8 0/2 8.4 82.7/17.3 0.10 3,289 1.5 13.06 6.86 10/16/17 11830 10264 9.15 74 29 15 12/25/30 2.8 0/2 8.2 83.3/16.7 0.10 3,326 1.6 13.54 6.09 10/17/17 12108 10335 9.10 76 28 14 12/26/31 3.0 0/2 8.3 84.4/15.6 0.10 3,279 1.4 12.09 6.09 10/18/17 12257 10367 9.25 84 34 15 13/28/35 2.8 0/2 9.8 84.7/15.3 0.10 3,080 1.5 14.03 6.09 10/19/17 12257 10367 9.40 266 34 18 16/33/40 2.8 0/2 9.6 85.1/14.9 0.10 3,336 1.4 13.06 6.09 10/20/17 12491 10433 9.25 95 34 18 15/33/39 3.0 0/2 9.1 83.1/16.9 0.10 3,174 1.6 15.00 6.99 10/21/17 12613 10475 9.25 95 35 17 13/30/34 3.0 0/2 9.0 81.7/18.3 0.10 3,149 1.7 15.97 6.22 10/22/17 12613 10475 9.30 205 35 17 13/30/34 3.0 0/2 9.0 82.0/18.0 0.10 3,219 1.7 15.97 6.09 Abbreviations: MW = Mud Weight VIS = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded GP 11-24RD 27 4.4 Drilling Progress Days vs Depth 7500 8500 9500 10500 11500 12500 13500 9/25/20179/26/20179/27/20179/28/20179/29/20179/30/201710/1/201710/2/201710/3/201710/4/201710/5/201710/6/201710/7/201710/8/201710/9/201710/10/201710/11/201710/12/201710/13/201710/14/201710/15/201710/16/201710/17/201710/18/201710/19/201710/20/201710/21/201710/22/201710/23/20178.5" GP 11-24 RD PB 8.5" GP 11-24 RD GP 11-24RD 28 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 9995'MD 10078'MD Country:25 9309'TVD 9377'TVD ROP (fph)56 ft/hr 51 ft/hr 47 ft/hr 125 ft/hr WOB 18 klbs 16 klbs 14 klbs 19 klbs RPM 140 rpm 133 rpm 160 rpm 160 rpm PP 2413 psi 2379 psi 2321 psi 2468 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chlorides Total Gas 14 37 18 56 C1 (ppm)2,019 4,706 1,527 7,405 C2 (ppm)19 479 214 789 C3 (ppm)7 361 187 640 C4 (ppm)- 172 113 319 C5 (ppm)- 48 43 94 Intensity None Amount 0%Opacity Clear Amount 0% At Shakers No Color None-Gray Color None-Gray Color None-Gray Type None Amount 100%Speed None Intensity None-v wk Fluor Color None Distribution Even Opacity Clear Color None Outgassing No Intensity Mod-strng Intensity None-v wk Mud Type Oil-LVT Color yellow Color None Report by: Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 0.6 10/6/2017 8:00 PM Tuffaceous Sandstone = Very light gray when not stained by OBM; slightly firm; easily friable; lower fine to upper very coars, upper part is dominant lower fine, lower part coarsens to dominant coarse with stray loose grains > 2mm; moderately to poorly sorted; dominant subangular to subround, common angular; overall matrix supported with dominant bentonitic to occasional gray, ashy matrix; dominant quartz, common lithics; 100% moderately bright whitish yellow sample fluorescence that appears brighter than previous samples. Petroleum Odor Before During After Maximum Paul Webster / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20046-01-00GP 11-24 RD Granite Point Field Kuukpik 5 Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1234ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #2 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 10568'MD 10611'MD Country:25 9719'TVD 9743'TVD ROP (fph)24 ft/hr 21 ft/hr 23 ft/hr 33 ft/hr WOB 17 klbs 17 klbs 16 klbs 22 klbs RPM 138 rpm 143 rpm 157 rpm 149 rpm PP 2446 psi 2421 psi 2276 psi 2463 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chlorides Total Gas 43 77 42 110 C1 (ppm)1,253 2,694 953 4,380 C2 (ppm)88 274 129 421 C3 (ppm)42 206 79 323 C4 (ppm)16 105 52 159 C5 (ppm)1 34 6 53 Intensity None Amount 0%Opacity Clear Amount 0% At Shakers No Color None-Gray Color None-Gray Color None-Gray Type None Amount 100%Speed None Intensity None-v wk Fluor Color None Distribution Even Opacity Clear Color None Outgassing No Intensity Mod-strng Intensity None-v wk Mud Type Oil-LVT Color yellow Color None Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Paul Webster / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20046-01-00GP 11-24 RD Granite Point Field Kuukpik 5 10/6/2017 9:00 PM Sandstone = Overall medium gray; blocky cuttings; dominant slight to moderate firm; occasional very firm; dominant easily to moderately friable, occasionally moderately tough; very fine to lower coarse, dominant lower fine; moderately sorted; subangular to subround; grain packed with slight to abundant argillaceous matrix fill; dominant quartz, common lithics; oil logged on basis of heavy gases; no other oil indicators observable over OBM. Petroleum Odor Before During After Maximum Weak to moderate oil show with OBM contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 0.6 1.0 10.0 100.0 1000.0 10000.0 1234ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #3 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 10861'MD 11701'MD Country:25 9867'TVD 10228'TVD ROP (fph)29 ft/hr 46 ft/hr 15 ft/hr 185 ft/hr WOB 12 klbs 13 klbs 20 klbs 30 klbs RPM 134 rpm 144 rpm 119 rpm 172 rpm PP 2390 psi 2534 psi 2805 psi 3310 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chlorides Total Gas 38 112 60 342 C1 (ppm)755 3,370 1,810 12,596 C2 (ppm)93 520 188 1,755 C3 (ppm)72 377 158 1,374 C4 (ppm)49 223 88 721 C5 (ppm)25 89 36 254 Intensity None Amount 10%Opacity Solid Amount 5% At Shakers No Color Amber Color Brown Color Faint Type None Amount 100%Speed Quick Intensity None-v wk Fluor Color None Distribution Patchy Opacity Transpr Color None Outgassing No Intensity Mod-strng Intensity Moderate Mud Type Oil-LVT Color yellow Color None Report by: Moderate oil show with oil based drilling fluid contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.5 10/16/2017 2:00 PM Tuffaceous Sandstone = light to medium gray to dark yellowish brown; blocky cuttings; overall easily friable; dominant upper fine to upper medium grained with occasional lower very fine to lower fine grained; moderately sorted; overall poor to moderate sphericity; sub-angular to sub-rounded; frosted to grinding surface abrasion; grain-supported with ashy matrix;dominantly quartz, common dark lithics which give a salt and pepper appearance; dull yellow sample fluorescence with brighter patches which are more uniform than background oil based mud contamination; instant dull yellowish white cut fluorescence;dark straw visible cut; dull yellow residual cut fluorescence; light brown residual cut; oil staining visible from interstitial oil in cracked-open sandstone cuttings; no odor. Petroleum Odor Before During After Maximum Paul Webster / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20046-01-00GP 11-24 RD Granite Point Field Kuukpik 5 Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1234ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #4 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:25 11730'MD 12585'MD Country:25 10238'TVD 10465'TVD ROP (fph)15 ft/hr 19 ft/hr 14 ft/hr 142 ft/hr WOB 20 klbs 16 klbs 12 klbs 23 klbs RPM 119 rpm 144 rpm 157 rpm 170 rpm PP 2804 psi 2762 psi 3095 psi 3210 psi Mud Weight 9.2 lbs/gal 9.2 lbs/gal 9.2 lbs/gal 9.2 lbs/gal Chlorides Total Gas 62 58 46 104 C1 (ppm)1,872 1,343 836 3,606 C2 (ppm)199 291 346 541 C3 (ppm)169 136 56 313 C4 (ppm)95 84 32 184 C5 (ppm)39 46 27 78 Intensity None Amount 5%Opacity Solid Amount 5% At Shakers No Color Amber Color Amb-Brn Color Faint Type None Amount 50%Speed Slow Intensity None-v wk Fluor Color None Distribution Patchy Opacity Transpr Color None Outgassing No Intensity Moderate Intensity Weak-Dull Mud Type Oil-LVT Color yellow Color None Report by: Moderate oil show with oil based drilling fluid contamination interfering with hydrocarbon fluorescence and odor. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.2 10/21/2017 7:00 AM Tuffaceous Sandstone = moderate brownish gray to olive gray, loose grains transparent to translucent to very light gray; lower very fine to lower coarse grained, dominantly fine grained; poorly to moderately sorted; very angular to angular to sub-rounded, dominantly sub-angular; frosted to grinding surface abrasion; overall matrix support with bentonitic tuff matrix, often grades to tuffaceous siltstone; dominantly quartz, with common lithic fragments that give a salt and pepper appearance; moderately to very calcareous; 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil staining visible; visible oil found in cracked- open sandstone cuttings. Petroleum Odor Before During After Maximum Paul Webster / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska, LLC 50-733-20046-01-00GP 11-24 RD Granite Point Field Kuukpik 5 Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1234ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas GP 11-24RD 29 6 DAILY REPORTS Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Steve Lawrence, Adam Dorr DATE Sep 26, 2017 DEPTH 8074' PRESENT OPERATION POOH TIME 24:00 YESTERDAY 8007' 24 HOUR FOOTAGE 67' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED Mills 8.5" Window Mill 14168575 8007' 8074' 67' 5.9 Window milled DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 345.3 @ 8028' 0.8 @ 8020' 79.1 134.6 FT/HR SURFACE TORQUE 8063 @ 8010' 226 @ 8026' 5515.0 5001.3 FT-LBS WEIGHT ON BIT 13 @ 8028' 0 @ 8032' 1.5 2.0 KLBS ROTARY RPM 98 @ 8021' 0 @ 8026' 82.8 69.5' RPM PUMP PRESSURE 2071 @ 8012' 1992 @ 8022' 1972.1 2052.1 PSI DRILLING FLUIDS REPORT DEPTH 8074' MW 9.20 VIS 79 PV 34 YP 15 FL 3.0 Gels 10/19/23 CL- FC 0/2 SOL 8.0 SD OIL 77.8/22.2 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 324 @ 8053' 0.4 @ 8009' 174.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 83384 @ 8054' 66 @ 8009' 42271.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 84 @ 8066' 0 @ 8009' 45.7 AVG 0 PROPANE (C-3) 41 @ 8023' 1 @ 8010' 19.1 CURRENT 0 BUTANE (C-4) 6 @ 8017' 0 @ 8036' 1.9 CURRENT BACKGROUND/AVG Currently ~35 PENTANE (C-5) 5 @ 8009' 0 @ 8071' 0.7 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Metal Shavings, Cement, Coal, Sandstone, Tuffaceous Siltstone/Claystone PRESENT LITHOLOGY @ 8070': 20% Sandstone; 50% Tuffaceous siltstone, 30% Tuffaceous Claystone DAILY ACTIVITY SUMMARY RIH with whipstock and milling assembly from 2701’ to 7854’. Orient whipstock, wash from 7854’ to 8029’. Set whipstock. (TOW = 8006’, BOW = 8023’). Displace well with OBM. Circulate and condition mud. Begin milling window from 8007’. Mill window from 8006’ to 8023’. Mill new formation to 8044’. Ream through window. Set back one stand, perform FIT with 9.1+ ppg OBM to 12.5 ppg EQMW. Mill new formation from 8044’ to 8074’. Ream upper mill through window 8042’ to 8022’, dress window. Survey at 8069’. Set back one stand. Circulate bottoms up. Observe well (static). Pump dry job. POOH from 7982’ to 6028’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Steve Lawrence, Adam Dorr DATE Sep 27, 2017 DEPTH 8074' PRESENT OPERATION RIH TIME 24:00 YESTERDAY 8074' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED Mills 8.5" Window Mill 14168575 8007' 8074' 67' 5.9 1/8" Out Window milled NB 1 8.5" HDBS MMD75DC 12931974 7 x 12 8074' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 8074' MW 9.22 VIS 104 PV 29 YP 13 FL 3.2 Gels 9/18/23 CL- FC 0/2 SOL 8.3 SD OIL 77.7/22.3 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG Currently ~35 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY @ 8070': 20% Sandstone; 50% Tuffaceous siltstone, 30% Tuffaceous Claystone DAILY ACTIVITY SUMMARY POOH from 6028’ to surface. Lay down milling assembly (lower mill 1/8” out of guage, upper mill in guage). Clean and clear rig floor. Flush stack. Rig up test plug with one stand of HWDP, drain stack, land test plug, unscrew from test plug, break landing joint and kelly up to it. Slip and cut 100’ drill line. Center torque tube. Service rig. Replace HNGE pin seal on blinds and LPR DS. Function test seals. Lay down test plug. Set back one stand DP and one stand HWDP. Make up BHA #2. Plug in and upload MWD. Shallow test MWD. Load radioactive sources into MWD. Finish making up BHA. RIH from 676’ to 4076’. Fill pipe and test MWD. RIH from 4076’ to 4706’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Steve Lawrence, Adam Dorr DATE Sep 28, 2017 DEPTH 8162' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8074' 24 HOUR FOOTAGE 88' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 8.5" HDBS MMD75DC 14168575 7 x 12 8074' 88' 13.1 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 241.1 @ 8137' 0.6 @ 8157' 75.5 0.7 FT/HR SURFACE TORQUE 10308 @ 8153' 5619 @ 8158' 7140.0 5870.6 FT-LBS WEIGHT ON BIT 10 @ 8146' 0 @ 8076' 2.0 2.7 KLBS ROTARY RPM 95 @ 8149' 39 @ 8118' 68.4 69.8 RPM PUMP PRESSURE 2289 @ 8141' 1397 @ 8159' 2136.1 1402.3 PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 195 @ 8111' 12 @ 8160' 117.8 TRIP GAS 68 @ 8074' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 42087 @ 8075' 1209 @ 8158' 24361.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 53 @ 8145.00000 2 @ 8159.00000 32.0 AVG 0 PROPANE (C-3) 23 @ 8111' 1 @ 8159' 13.4 CURRENT 0 BUTANE (C-4) 4 @ 8159' 0 @ 8075' 1.0 CURRENT BACKGROUND/AVG 4-7/6 PENTANE (C-5) 6 @ 8157' 0 @ 8120' 0.8 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Coal; Tuffaceou Sandstone; Sandstone; Tuffaceous Siltstone/Claystone; Cement PRESENT LITHOLOGY @ 8160': 30% Cement; 10% Sandstone; 40% Tuffaceous Siltstone; 20% Tuffaceous Claystone DAILY ACTIVITY SUMMARY RIH from 4706’ to 7993’. Fill pipe, circulate. Service rig. Wash and ream to bottom (went through window with no problems). Drill from 8074’ to 8154’. Cut trough from 8121’ to 8151’. Time drill from 8151’ to 8162’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Steve Lawrence, Adam Dorr DATE Sep 29, 2017 DEPTH 8191' PRESENT OPERATION RIH TIME 24:00 YESTERDAY 8162' 24 HOUR FOOTAGE 29' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 1 8.5" HDBS MMD75DC 14168575 7 x 12 8074' 8191' 117' 20.9 1-7-BT-SH-X-1-CT-BHA BHA NB 2 8.5" Schlumberger/Smith XR+PS RJ1470 3 x 18 8191' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 60.9 @ 8184' 0.7 @ 8170' 15.7 16.5 FT/HR SURFACE TORQUE 8569 @ 8184' 5299 @ 8165' 7066.4 7645.5 FT-LBS WEIGHT ON BIT 13 @ 8179' 0.98 @ 8166' 4.9 5.2 KLBS ROTARY RPM 88 @ 8182' 68 @ 8166' 79.4 88.9 RPM PUMP PRESSURE 2081 @ 8179' 1396 @ 8164' 1691.4 2068.9 PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 47 @ 8185' 12 @ 8165' 23.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9037 @ 8185' 1626 @ 8165' 3913.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 10 @ 8177' 2 @ 8164' 6.7 AVG 0 PROPANE (C-3) 3 @ 8169' 1 @ 8168' 2.4 CURRENT 0 BUTANE (C-4) 5 @ 8168' 0 @ 8179' 1.5 CURRENT BACKGROUND/AVG 9-11/10 PENTANE (C-5) 4 @ 8164' 0 @ 8174' 1.1 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Cement; Sandstone; Coal; Tuffaceous Siltstone/claystone PRESENT LITHOLOGY @ 8185': 10% Cement; 10% Coal; 10% Sandstone; 30% Tuffaceous siltstone; 40% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Time drill from 8162’ to 8170’. Drill from 8170’ to 8191’. POOH from 8191’ to 7994’. Monitor well. Static. Pump dry job. POOH from 7994’ to 676’. Set back 7 stands of HWDP, one stand HWDP/Jars, and one stand of drill collars. Unload radioactive sources. Download MWD. Blow down Geo Pilot. Lay down MWD tools and Geo Pilot. Clean and clear rig floor. Service rig. Pick up and make up BHA #3 to 609’. RIH from 609’ to 2156’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Steve Lawrence, Adam Dorr DATE Sep 30, 2017 DEPTH 8390' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8191' 24 HOUR FOOTAGE 199' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 2 8.5" Schlumberger/Smith XR+PS RJ1470 3 x 18 8191' 199' 13.7 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 162.9 @ 8211' 2.4 @ 8235' 26.7 5.5 FT/HR SURFACE TORQUE 8054 @ 8187' 244 @ 8321' 2246.2 3038.4 FT-LBS WEIGHT ON BIT 17 @ 8352' 0 @ 8211' 10.1 14.1 KLBS ROTARY RPM 88 @ 8190' 0 @ 8312' 20.2 0.7 RPM PUMP PRESSURE 2577 @ 8324' 2055 @ 8237' 2341.9 2542.5 PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 61 @ 8232' 7 @ 8353' 20.2 TRIP GAS 32 @ 8191' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12350 @ 8233' 716 @ 8352' 3414.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 14 @ 8232' 0 @ 8370' 4.9 AVG 0 PROPANE (C-3) 5 @ 8233' 0 @ 8370' 1.6 CURRENT 0 BUTANE (C-4) 5 @ 8287' 0 @ 8350' 0.5 CURRENT BACKGROUND/AVG 6-35/14 PENTANE (C-5) 4 @ 8198' 0 @ 8364' 0.5 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Coal Tuffaceous Siltstone/Claystone PRESENT LITHOLOGY @ 8370': 10% Tuffaceous Sandstone; 10% Conglomerate; 20% Sandstone; 50% Sand; 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY RIH from 2156’ to 7977’. Fill pie and orient 45 Right. Wash down to 8100’. Begin troughing to 8130’. Time drill from 8130’ to 8134’. Change of plan. RIH to 8191’. Directionally drill from 8191’ to 8390’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Steve Lawrence DATE Oct 01, 2017 DEPTH 8410' PRESENT OPERATION Washing and reaming at ~8201' TIME 24:00 YESTERDAY 8390' 24 HOUR FOOTAGE 20' CASING INFORMATION ( 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8373.51' 15.75 200.50 7759.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 2 8.5" Schlumberger / Smith XR+PS RJ1470 3x18 8191' 8410' 219' 15.35 1-2-WT-A-E-0-NO- BHA BHA NB 3 8.5" Baker / Hughes Christensen KM624 (Kymera) 5268475 2x18, 2x16 8410' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 78.2 @ 8386' 1.3 @ 8376' 27.3 20.3 FT/HR SURFACE TORQUE 6194 @ 8390' 450 @ 8381' 4627.4 2465.2 FT-LBS WEIGHT ON BIT 14 @ 8378' 10 @ 8408' 12.1 13.6 KLBS ROTARY RPM 59 @ 8385' 7 @ 8376' 42.9 0.0' RPM PUMP PRESSURE 2536 @ 8380' 2453 @ 8408' 2567.6 2524.5 PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 122 @ 8394' 9 @ 8375' 38.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 14157 @ 8394' 1074 @ 8375' 4831.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 10 @ 8395' 0 @ 8375' 3.9 AVG 0 PROPANE (C-3) 4 @ 8395' 0 @ 8375' 1.5 CURRENT 0 BUTANE (C-4) 0 @ 8401' 0 @ 8399' 0.1 CURRENT BACKGROUND/AVG 7-9/8 PENTANE (C-5) 1 @ 8406' 0 @ 8400' 0.1 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Conglomerate/Sand; Coal; Tuffaceous Siltstone/Claystone PRESENT LITHOLOGY 20% Tuffaceous Sandstone; 10% Sandstone; 30% Sand; 10% Coal; 20% Tuffaceous Siltstone; 10% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Directionally drill from 8390’ to 8410’. Circulate bottoms up. POOH from 8410’ to 7986’ (Work tight hole 8360’-8310’). Service and work on rig. POOH from 7986’ to 609’. Stand back and lay down BHA. Make up BHA #4. Upload MWD and shallow-hole test MWD. Load radioactive sources. Finish making up BHA #4 to 676’. RIH from 676’ to 4080’. Fill pipe, break in seals on Geo Pilot, and test MWD. RIH from 4080’ to 7935’. Service draw works, top drive, traveling equipment, other rig service, and fill pipe/circulate. RIH 7935’ to 8234’. Wash and ream from 8176’ to 8201’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Steve Lawrence, Adam Dorr DATE Oct 02, 2017 DEPTH 8948' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8410' 24 HOUR FOOTAGE 538' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8521.89' 9.93 176.72 7904.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 8.5" Bkker / Hughes Christensen KM624 (Kymera) 5268475 2x18, 2x16 8410' 538' 8.0 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 227.1 @ 8715' 1.1 @ 8433' 81.0 78.7 FT/HR SURFACE TORQUE 9449 @ 8801' 6093 @ 8425' 8411.8 8778.3 FT-LBS WEIGHT ON BIT 17 @ 8724' 4 @ 8411' 14.0 15.0 KLBS ROTARY RPM 140 @ 8551' 99 @ 8411' 138.4 137.6 RPM PUMP PRESSURE 2407 @ 8836' 1786 @ 8509' 2288.5 2297.2' PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 243 @ 8723' 7 @ 8491' 34.3 TRIP GAS 22 @ 8410' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 54180 @ 8723' 1072 @ 8494' 6854.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 72 @ 8490' 0 @ 8428' 7.6 AVG 0 PROPANE (C-3) 10 @ 8723' 0 @ 8411' 1.1 CURRENT 0 BUTANE (C-4) 0 @ 8948' 0 @ 8948' 0.0 CURRENT BACKGROUND/AVG 10-15/13 PENTANE (C-5) 6 @ 8490' 6 @ 8490' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstoe/Conglomerate/Sandstone/Sand; Coal; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 8940': 10% Tuffaceous Sandstone; 10% Sandstone; 40% Tuffaceous Siltstone; 30% Tuffaceous Claystone; 10% Tuff DAILY ACTIVITY SUMMARY Wash and ream from 8201’ to 8240’. Continue to troubleshoot top drive. POOH from 8240’ to inside window at 7992’. Troubleshoot and repair top drive. Repair cuttings shoot line. RIH from 7992’ to 8310’. Wash and ream from 8310’ to 8410’. Drill from 8410’ to 8948’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Rance Pedersen DATE Oct 03, 2017 DEPTH 9421' PRESENT OPERATION Wiper Trip TIME 24:00 YESTERDAY 8948' 24 HOUR FOOTAGE 473' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9389.43' 15.07 109.66 8752.01' 9330.37' 14.72 110.23 8694.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 8.5" Baker / Hughes Christensen KM624 (Kymera) 5268475 2x18,2x16 8410' 1011' 15.6 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 478.5 @ 9173' 2.7 @ 9350' 76.9 66.4 FT/HR SURFACE TORQUE 9742 @ 9396' 7046 @ 8958' 8725.3 9316.8 FT-LBS WEIGHT ON BIT 16 @ 9335' 7 @ 9166' 14.2 14.8 KLBS ROTARY RPM 140 @ 9175' 137 @ 8983' 139.1 138.7 RPM PUMP PRESSURE 2456 @ 9347' 1777 @ 9110' 2300.4 2328.9 PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 633 @ 9250' 10 @ 9135' 57.0 TRIP GAS CUTTING GAS @ @ WIPER GAS 40 @ 9421' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 132006 @ 9251' 1741 @ 9135' 11368.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 137 @ 9036' 4 @ 9060' 8.8 AVG 0 PROPANE (C-3) 38 @ 9250' 0 @ 9104' 4.3 CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 6-8/7 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone /Conglomerate/Sand; Coal; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 9420': 10% Tuffaceous Sandstone; 10% Sand; 30% Tuffaceous Siltstone; 40% Tuffaceous Claystone; 10% Tuff DAILY ACTIVITY SUMMARY Drill from 8948’ to 9421’. Pump high vis sweep, circulate bottoms up. Wipe hole from 9421’ to shoe, working tight hole and backreaming as needed. Cut 92’ of drill line. Servide rig. RIH from 7969’ to 9295’. Wash and ream from 9295’ to 9412’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Rance Pederson DATE Oct 04, 2017 DEPTH 10208' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9421' 24 HOUR FOOTAGE 787' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9951.29' 31.71 120.57 9272.54' 9888.78' 28.90 120.88 9218.58' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 8.5" Baker / Hughes Christensen KM624 (Kymera) 5268475 2x18, 2x16 8410' 1798' 31.9 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 348.8 @ 9793' 3.6 @ 9539' 63.1 26.2 FT/HR SURFACE TORQUE 10518 @ 9985' 7174 @ 9644' 9165.4 9376.3 FT-LBS WEIGHT ON BIT 20 @ 9986' 8 @ 9479' 14.9 15.7 KLBS ROTARY RPM 159 @ 10091' 118 @ 10168' 139.7 138.6' RPM PUMP PRESSURE 2563 @ 9982' 1881 @ 9737' 2376.5 2308.5' PSI DRILLING FLUIDS REPORT DEPTH 9422' MW 9.20 VIS 130 PV 31 YP 15 FL 3.0 Gels 10/27/33 CL- FC 0/2 SOL 7.9 SD OIL 80.8/19.2 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 8410' TO 10208' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 69 @ 9956' 5 @ 9433' 19.9 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 14751 @ 9956' 476 @ 9567' 2172.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 788 @ 10055' 3 @ 9422' 78.9 AVG 0 PROPANE (C-3) 640 @ 10055' 2 @ 9422' 58.5 CURRENT 0 BUTANE (C-4) 318 @ 10055' 4 @ 9956' 30.3 CURRENT BACKGROUND/AVG 6-14/12 PENTANE (C-5) 93 @ 10055' 5 @ 10000' 10.5 HYDROCARBON SHOWS Trace to Fair INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9995' to 10078' Tuffaceous Sandstone; Sand 11 to 55 Sample fluorescence appears elevated over previous samples; Advent of C-4 and C-5 LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Coal; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY 60% Tuffaceous Sandstone; 10% Sandstone; 10% Tuffaceous Siltstone; 20% Bentonitic Tuff DAILY ACTIVITY SUMMARY Wash and ream from 9412’ to 9421’. Drill from 9421’ to 9667’. Riser air boots started leaking. Repair air boots on riser. Drill from 9667’ to 10208’ (pump 11.2 ppg / 415 vis sweep at 9980’ which came back 37 bbls late with a 100% cuttings increase). CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Rance Pederson DATE Oct 05, 2017 DEPTH 10570' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 10208' 24 HOUR FOOTAGE 362' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10385.21' 48.10 119.18 9605.55' 10321.50' 45.63 119.38 9561.99' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 8.5" Baker / Hughes Christensen KM624 (Kymera) 5268475 2x18, 2x16 8410' 2160' 43.7 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 275.9 @ 10418' 2.0 @ 10445' 44.1 28.5 FT/HR SURFACE TORQUE 10377 @ 10528' 8090 @ 10446' 9367.3 9784.8 FT-LBS WEIGHT ON BIT 25 @ 10537' 8 @ 10417' 15.5 16.9 KLBS ROTARY RPM 140 @ 10544' 89 @ 10542' 134.5 140.4 RPM PUMP PRESSURE 2650 @ 10314' 1891 @ 10310' 2455.5 2449.8 PSI DRILLING FLUIDS REPORT DEPTH 10150' MW 9.15 VIS 76 PV 24 YP 13 FL 3.0 Gels 10/24/27 CL- FC 0/2 SOL 8.0 SD 0.10 OIL 82.2/17.8 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 8410' TO 10570' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 256 @ 10517' 10 @ 10233.' 53.9 TRIP GAS CUTTING GAS @ @ WIPER GAS 112 @ 10310' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 17151 @ 10517' 404 @ 10357' 2802.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 308 @ 10570' 14 @ 10533' 62.6 AVG 0 PROPANE (C-3) 226 @ 10570' 4 @ 10355' 30.4 CURRENT 0 BUTANE (C-4) 100 @ 10570' 1 @ 10468' 16.2 CURRENT BACKGROUND/AVG 21-41/32 PENTANE (C-5) 33 @ 10570' 1 @ 10248' 2.8 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Coal; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 10560': 10% Tuffaceous Sandstone; 20% Sandstone; 10% Sand; 40% Tuffaceous Siltstone; 20% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Drill from 10208’ to 10310’. Detect 500 psi stand pipe pressure loss. Test surface lines, all good, POOH (looking for wash out) on elevators from 10310’ to 9989’ (work through from 10055’ to 9889’, pulling 45K over). Pump out of hold from 9989’ to 8739’. Found wash out. Change bad joint. RIH from 8739’ to 10220’ (tagged up). Wash and ream from 10220’ to 10310’. Drill from 10310’ to 10570’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Rance Pederson DATE Oct 06, 2017 DEPTH 10875' PRESENT OPERATION POOH TIME 24:00 YESTERDAY 10570' 24 HOUR FOOTAGE 305' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10841.20' 66.18 122.40 9847.19' 10816.98' 66.38 122.71 9837.44' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 8.5" Baker / Hughes Christensen KM624 (Kymera) 5268475 2x18, 2x16 8410' 10875' 2465' 55.5 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 106.1 @ 10637' 1.9 @ 10850' 31.2 24.8 FT/HR SURFACE TORQUE 11133 @ 10725' 8399 @ 10615' 9998.5 10082.5 FT-LBS WEIGHT ON BIT 25 @ 10847' 11 @ 10613' 18.5 25.1 KLBS ROTARY RPM 160 @ 10680' 114 @ 10855' 153.6 149.1 RPM PUMP PRESSURE 2557 @ 10724' 1808 @ 10628' 2436.6 2254.6 PSI DRILLING FLUIDS REPORT DEPTH 10875' MW 9.10 VIS 86 PV 26 YP 14 FL 3.0 Gels 11/26/30 CL- FC 0/2 SOL 7.4 SD 0.10 OIL 82.9/17.1 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 8410' TO 10875' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 182 @ 10724' 33 @ 10655' 91.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7023 @ 10725' 680 @ 10617' 2900.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 955 @ 10725' 57 @ 10655' 417.8 AVG 0 PROPANE (C-3) 649 @ 10725' 31 @ 10655' 276.5 CURRENT 0 BUTANE (C-4) 316 @ 10763' 24 @ 10656' 151.6 CURRENT BACKGROUND/AVG Current = 54 PENTANE (C-5) 134 @ 10804' 4 @ 10632' 59.5 HYDROCARBON SHOWS None to Fair INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10568'to 10611' 10681' to 10875' Tuffaceous Sandstone Sandstone 43 to 110 51 to 182 Heavy gases Elevated oil indicators over background; oil staining LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Coal; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 10875': 20% Tuffaceous Sandstone; 20% Sandstone; 50% Sand; 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drill from 10570’ to 10875’ (pumped sweep at 10849’ (30% increase in cuttings, 30 bbls late)).Circulate bottoms up and 3 full circulations. POOH on elevators from 10875’ to 7990’ (no notable tight spots). Service rig. POOH from 7990’ to 6502’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Rance Pederson DATE Oct 07, 2017 DEPTH 10880' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 10875' 24 HOUR FOOTAGE 5' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10841.20' 66.18 122.40 9847.19' 10816.98' 66.38 122.71 9837.44' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 8.5" Baker / Hughes Christensen KM624 (Kymera) 5268475 2x18, 2x16 8410' 10875' 2465' 55.5 3-4-CT-A-F-I-RO- PR ROP/Hrs NB 4 8.5" HBBS MM75D 12670052 3x15, 1x16 10875' 5' 0.2 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10875' MW 9.20 VIS 186 PV 28 YP 15 FL 3.0 Gels 12/26/32 CL- FC 0/2 SOL 8.1 SD 0.10 OIL 82.8/17.2 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10875' TO 10880' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 186 @ 10875' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 22-31/27 PENTANE (C-5) @ @ HYDROCARBON SHOWS No new section at surface at 24:00 hours INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY @ 10875': 20% Tuffaceous Sandstone; 20% Sandstone; 50% Sand; 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY POOH from 6502’ to 676’. Stand back BHA, unload radioactive sources, and download MWD. Continue to lay down BHA. Break bit. Clear rig floor. Repair service loop cable on top drive. Make up BHA #5. Upload MWD. Clean and clear rig floor. Shallow-hole pulse test directional tools. Finish making up BHA (drill collars, jars, and HWDP). RIH on drill pipe to 4083’. Fill pipe at 4083’. RIH from 4083’ to 7990’. Fill pipe at 7990’. Service rig. RIH on elevators to 10511’. Wash and ream from 10511’ to 10872’ (found bottom 3 feet higher). Drill from 10872’ to 10880’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Rance Pederson DATE Oct 08, 2017 DEPTH 11280' PRESENT OPERATION Test BOP TIME 24:00 YESTERDAY 10880' 24 HOUR FOOTAGE 400' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11245.22' 75.96 123.56 9996.80' 11187.01' 72.88 124.02 9981.17' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 4 8.5" HDBS MM75D 12670052 3x15, 1x16 10875' 405' 7.2 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 206.7 @ 11095' 6.2 @ 11177' 64.6 69.1 FT/HR SURFACE TORQUE 13646 @ 11096' 9388 @ 11201' 11718.9 12458.6 FT-LBS WEIGHT ON BIT 18 @ 11031' 4 @ 11094' 10.6 10.5 KLBS ROTARY RPM 160 @ 11000' 119 @ 11015' 148.4 159.0 RPM PUMP PRESSURE 2653 @ 10907' 2038 @ 11279' 2535.9 2457.7 PSI DRILLING FLUIDS REPORT DEPTH 11280' MW 9.15 VIS 101 PV 32 YP 16 FL 3.0 Gels 12/27/32 CL- FC 0/2 SOL 8.7 SD 0.10 OIL 83.2/16.8 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10875' TO 11280' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 224 @ 11109' 40 @ 11032' 102.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9045 @ 11110' 796 @ 11240' 3748.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 1011 @ 11110' 95 @ 11057' 373.6 AVG 0 PROPANE (C-3) 811 @ 11110' 100 @ 11009' 318.5 CURRENT 0 BUTANE (C-4) 371 @ 11110' 58 @ 11009' 165.6 CURRENT BACKGROUND/AVG 40 (Current) PENTANE (C-5) 102 @ 11111' 25 @ 11009' 55.5 HYDROCARBON SHOWS None to Fair INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10876'-10957' 11067'- 11185' Sand/Sandstone/Tuffaceous Sandstone 61 to 177 84 to 224 High gas, oil staining, and sample fluorescence elevated over OBM background basis for logging oil LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 11280': 10% Sand; 30% Tuffaceous Siltstone; 50% Tuffaceous Claystone; 10% Tuff DAILY ACTIVITY SUMMARY Drill from 10880’ to 11280’. Circulate high vis weighted sweep (25% increase cuttings, 33 bbls late) and 2 3/4 bottoms up until shakers cleaned up. POOH on elevators from 11280’ to 7930’ (pulling tight (20-45K overpull) at numerous spots). Blow down geospan. Prepare for BOP test. Test gas alarms, annular to 2500 psi (both good). Failure on upper dart/kill demco (passed on low, failed on high due to alignment pin on wellhead leaking. Rig down test equipment. Rig up to test choke manifold and top drive. Test choke manifold valves 7, 15, 16, and lower IBOP. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Marvin Rogers, Rance Pederson DATE Oct 09, 2017 DEPTH 11280' PRESENT OPERATION Test BOP TIME 24:00 YESTERDAY 11280' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11245.22' 75.96 123.56 9996.80' 11187.01' 72.88 124.02 9981.17' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 4 8.5" HDBS MM75D 12670052 3x15, 1x16 10875' 405' 7.2 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE 2653 @ @ PSI DRILLING FLUIDS REPORT DEPTH 11280' MW 9.20 VIS 148 PV 32 YP 13 FL 3.1 Gels 11/24/30 CL- FC 0/2 SOL 8.6 SD 0.10 OIL 82.7/17.3 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10875' TO 11280' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 40 (Current) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY @ 11280': 10% Sand; 30% Tuffaceous Siltstone; 50% Tuffaceous Claystone; 10% Tuff DAILY ACTIVITY SUMMARY Test CMV 1-16 to 250 /3500 psi. Clean rig floor, cellar and drill deck. Work on mud pump #1. Clean pit area and general housekeeping around rig. Slip and cut 100’ drill line. Service top drive and blocks. Pick up and install storm packer. Good test 1000 psi. Prepare to pick up stack and riser. Pick up stack and riser. Repair alignment pin on wellhead. Nipple up BOP. Prepare for BOP test. Test BOP. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Rance Pederson DATE Oct 10, 2017 DEPTH 10720' PRESENT OPERATION Time drilling TIME 24:00 YESTERDAY 10700' 24 HOUR FOOTAGE 20' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10694.57' 61.66 122.48 9785.81' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 4 8.5" HDBS MM75D 12670052 3x15, 1x16 10700' 405' + 20' = 425' 21.9 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2.1 @ 10715' 0.4 @ 10701' 1.4 1.6 FT/HR SURFACE TORQUE 9308 @ 10705' 7901 @ 10717' 9125.6 8669.1 FT-LBS WEIGHT ON BIT 4 @ 10703' 1 @ 10701' 3.3 4.0 KLBS ROTARY RPM 149 @ 10715' 139 @ 10714' 157.0 148.9 RPM PUMP PRESSURE 2205 @ 10701' 2010 @ 10712' 2178.4 2022.0 PSI DRILLING FLUIDS REPORT DEPTH 10717' MW 9.10 VIS 91 PV 29 YP 16 FL 3.0 Gels 12/26/32 CL- FC 0/2 SOL 8.2 SD 0.10 OIL 82.2/17.8 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 83 @ 10701' 20 @ 10718' 27.4 TRIP GAS 176 @ 10700' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4200 @ 10701' 247 @ 10711' 633.7 CONNECTION GAS HIGH N/A ETHANE (C-2) 31 @ 10705' 4 @ 10718' 12.6 AVG N/A PROPANE (C-3) 34 @ 10701' 4 @ 10713' 10.1 CURRENT N/A BUTANE (C-4) 37 @ 10703' 4 @ 10712' 12.4 CURRENT BACKGROUND/AVG Last background = 19 PENTANE (C-5) 24 @ 10701' 4 @ 10705' 4.8 HYDROCARBON SHOWS Fair INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10700' to 10715' Sandstone/Sand 20 to 83 Sample fluorescence elevated above background OBM; appears oil stained LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Tuffaceous Siltstone/Claystone PRESENT LITHOLOGY @ 10715': 60% Tuffaceous Sandstone' 10% Sandstone; 10% Sand; 10% Tuffaceous Siltstone; 10% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Finish rigging down BOP test. Pull rotary table and drip pan. Remove riser, install new air boots, reseal and reinstall all. Clean rotary table. Seal and install rotary table and pin below. Blow down choke and pump out gas buster u-tube. Clean up tools. Make up storm packer retrieval tool. Retrieve storm packer. RIH from 7929’ to 10669’. Wash and ream from 10669’ to 10680’. Trough from 10680’ to 10700’. Time drill from 10700’ to 10720’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Rance Pederson DATE Oct 11, 2017 DEPTH 11123' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 10720' 24 HOUR FOOTAGE 403' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11000.92' 61.35 123.36 9934.31' 10938.26' 61.38 124.32 9904.28' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 4 8.5" HDBS MM75D 12670052 3x15, 1x16 10700' 405' + 423' = 828' 38.0 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 184.7 @ 10973' 1.3 @ 10720' 42.9 17.0 FT/HR SURFACE TORQUE 13600 @ 10977' 8096 @ 10724' 11256.7 11899.6 FT-LBS WEIGHT ON BIT 17 @ 11079' 1 @ 10722' 11.0 14.4 KLBS ROTARY RPM 180 @ 10758' 80 @ 11077' 138.0 127.4 RPM PUMP PRESSURE 2533 @ 10981' 1570 @ 11078' 2342.8 2249.7 PSI DRILLING FLUIDS REPORT DEPTH 11091 MW 9.05 VIS 81 PV 26 YP 14 FL 2.8 Gels 11/25/32 CL- FC 0/2 SOL 8.6 SD 0.10 OIL 83.3/16.7 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10700' TO 11123' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 243 @ 10992' 19 @ 10720' 78.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 8695 @ 10992' 243 @ 10720' 2258.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 1150 @ 10992' 6 @ 10719' 318.3 AVG 0 PROPANE (C-3) 961 @ 10992' 4 @ 10722' 236.7 CURRENT 0 BUTANE (C-4) 519 @ 10992.00000 4 @ 10724.00000 140.5 CURRENT BACKGROUND/AVG 20-95/54 PENTANE (C-5) 165 @ 10992' 1 @ 10733' 55.3 HYDROCARBON SHOWS Fair to Good INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10715' to 11100' Sand/Sandstone 19 to 243 Sample fluorescence elevated above OBM background; appears oil stained; Heavy Gases/Ditch Gas LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone; Sand; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 11100': 30% Tuffaceous Sandstone; 10% Sandstone; 30% Sand; 20% Tuffaceous Siltstone; 10% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Time drill from 10720’ to ~10760’. Drill from ~10760’ to 11123’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Rance Pederson DATE Oct 12, 2017 DEPTH 11215' PRESENT OPERATION Bit Trip TIME 24:00 YESTERDAY 11123' 24 HOUR FOOTAGE 92' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11183.32' 63.68 126.02 10019.31 11123.05' 62.71 125.74 9992.12' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 4 8.5" HDBS MM75D 12670052 3x15, 1x16 10700' 11215' 515' / 920' Total 45.2 ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 73.6 @ 11175' 0.4 @ 11215' 18.6 0.4 FT/HR SURFACE TORQUE 14282 @ 11180' 9280 @ 11208' 11741.3 9813.6 FT-LBS WEIGHT ON BIT 24 @ 11215' 8 @ 11158' 16.2 24.5 KLBS ROTARY RPM 171 @ 11163' 63 @ 11133' 148.4 161.2 RPM PUMP PRESSURE 2490 @ 11204' 1609 @ 11147' 2232.7 2386.8 PSI DRILLING FLUIDS REPORT DEPTH 11215' MW 9.12 VIS 98 PV 32 YP 15 FL 2.8 Gels 12/25/30 CL- FC 0/2 SOL 7.8 SD 0.10 OIL 81.7/18.3 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 10700' TO 11215' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 84 @ 11182' 40 @ 11125' 58.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 2206 @ 11183' 541 @ 11125' 1214.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 621 @ 11182' 160 @ 11125' 352.8 AVG 0 PROPANE (C-3) 140 @ 11186' 42 @ 11125' 79.8 CURRENT 0 BUTANE (C-4) 84 @ 11111' 29 @ 11173' 49.7 CURRENT BACKGROUND/AVG 37-45/39 At Pumps Off = 32 PENTANE (C-5) 67 @ 11185' 23 @ 11172' 42.7 HYDROCARBON SHOWS Fair to Good INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10715 to 11215' Sandstone/Sand 40 to 84 Sample fluorescence elevated above OBM background; appears oil stained; Heavy Gases/Ditch Gas LITHOLOGY Tuffaceous Sand/Sandstone/Sand; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 11215': 50% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 10% Tuff DAILY ACTIVITY SUMMARY Drill from 11123’ to 11215’. Pump 2 sweeps (30% and 50% increase in cuttings return) and circulate 3 bottoms up. POOH from 11215’ to 6810’ on elevators (tight spots (25-45K over pull) at 10684’, 10649’, 10640’, 10266’, and 8190’)). Service top drive, blocks, and draw works. POOH from 6810’ to HWDP. Lay down and stand back HWDP and drill collars. Remove Nuclear sources. Download MWD. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Rance Pederson DATE Oct 13, 2017 DEPTH 11370' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 11215' 24 HOUR FOOTAGE 155' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11183.32' 63.68 126.02 10019.31' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 4 8.5" HDBS MM75D 12670052 3x15, 1x16 10700' 11215' 515' / 920' Total 45.2 2-5-BT-G-X-2-CT-PR ROP NB 5 8.5" HDBS EME74DC 12943177 7x12 11215' 155' 2.9 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 168.7 @ 11329' 5.0 @ 11216' 59.9 49.8 FT/HR SURFACE TORQUE 12680 @ 11341' 9813 @ 11226' 11699.8 12032. FT-LBS WEIGHT ON BIT 14 @ 11290' 8 @ 11253' 13.0 13.8 KLBS ROTARY RPM 149 @ 11328' 148 @ 11229' 150.1 149.8 RPM PUMP PRESSURE 2779 @ 11257' 2136 @ 11253' 2740.4 2751.3 PSI DRILLING FLUIDS REPORT DEPTH 11313' MW 9.18 VIS 97 PV 33 YP 17 FL 2.8 Gels 14/29/35 CL- FC 0/2 SOL 8.2 SD 0.10 OIL 82.5/17.5 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 11215' TO 11370' TOOLS Directional / Triple combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 190 @ 11285' 40 @ 11216' 116.9 TRIP GAS 124 @ 11215' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7236 @ 11285' 1155 @ 11216' 4184.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 833 @ 11285' 69 @ 11216' 477.3 AVG 0 PROPANE (C-3) 711 @ 11286' 50 @ 11216' 395.8 CURRENT 0 BUTANE (C-4) 380 @ 11286' 26 @ 11216' 212.3 CURRENT BACKGROUND/AVG 22-66/43 PENTANE (C-5) 119 @ 11283' 4 @ 11216' 71.4 HYDROCARBON SHOWS Good trace to Good INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11215' to 11370' Sandstone/Sand 40 to 190 Moderately bright yellow sample fluorescence with brighter patches (elevated over OBM0; appears oil stained; possible visible oil inside sandstone cuttings LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Claystone; Tuff PRESENT LITHOLOGY @ 11370': 60% Tuffaceous Sandstone; 10% Sandstone; 30% Sand DAILY ACTIVITY SUMMARY Work on / Lay down BHA. Service draw works, top drive, and crown. Pick up BHA #6. Upload MWD, shallow-hole test MWD. Load radioactive sources into MWD. Continue to make up BHA #6. RIH from 431’ to 1546’. Pick up agitator and 2 crossovers. RIH from 1546’ to 11065’ (filling pipe every 2500’, tight spots at 10396’ and 10663’). Wash and ream down from 11065’ to 11185’. Circulate and condition mud while troubleshooting lube pump on top drive. Wash and ream from 11185’ to bottom (tag bottom at 11212’). Drill from 11212’ to 11370’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Rance Pederson DATE Oct 14, 2017 DEPTH 11651' PRESENT OPERATION POOH TIME 24:00 YESTERDAY 11370' 24 HOUR FOOTAGE 281' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11590.36' 68.03 134.14 10188.42' 11528.36' 67.35 132.47 10164.88' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 5 8.5" HDBS EME74DC 12943177 7x12 11215' 11651' 436' 14.4 ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 177.1 @ 11509' 1.7 @ 11641' 55.5 2.7 FT/HR SURFACE TORQUE 14051 @ 11531' 9259 @ 11626' 12097.7 10375.8 FT-LBS WEIGHT ON BIT 30 @ 11645' 4 @ 11403' 13.5 28.0 KLBS ROTARY RPM 164 @ 11649' 107 @ 11643' 151.0 164.6 RPM PUMP PRESSURE 2805 @ 11460' 1891 @ 11627' 2652.6 2173.4 PSI DRILLING FLUIDS REPORT DEPTH 11651' MW 9.20 VIS 83 PV 31 YP 14 FL 2.8 Gels 11/23/28 CL- FC 0/2 SOL 8.4 SD 0.10 OIL 82.5/17.5 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 11215' TO 11651' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 342 @ 11525' 43 @ 11649' 158.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12596 @ 11526' 516 @ 11642' 4686.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 1755 @ 11525' 136 @ 11642' 787.5 AVG 0 PROPANE (C-3) 1374 @ 11526' 55 @ 11651' 598.0 CURRENT 0 BUTANE (C-4) 720 @ 11525' 63 @ 11649' 359.8 CURRENT BACKGROUND/AVG 45-129/78 PENTANE (C-5) 253 @ 11531' 61 @ 11649' 142.5 HYDROCARBON SHOWS Good trace to Good INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11370' to 11650' Sand/Sandstone 43 to 342 Moderately bright yellow sample fluorescence with brighter patches (elevated over OBM);appears oil stained; visible oil inside sandstone cuttings LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Tuffaceous Siltstone; Tuff PRESENT LITHOLOGY @ 11650': 30% Tuffaceous Sandstone; 10% Conglomerate; 20% Sandstone; 40% Sand DAILY ACTIVITY SUMMARY Drill from 11370’ to 11559’. Service top drive and draw works. Replace coupler on HPU #2. Drill from 11559’ to 11651’ (pumped 9.7 ppg / 300 vis sweep at 11580’, 25% increase in cuttings). Pump high vis weighted sweep and reciprocate pipe. POOH on elevators from 11651’ to 7963’(tight spots at 10753’, 10655’, 10641’, 10632’, and 10558’ (30- 50K over pull)). Service top drive, draw works, blocks, and crown. POOH from 7953’ to 6969’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Rance Pederson DATE Oct 15, 2017 DEPTH 11651' PRESENT OPERATION RIH TIME 24:00 YESTERDAY 11651' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11590.36' 68.03 134.14 10188.42' 11528.36' 67.35 132.47 10164.88' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 5 8.5" HDBS EME74DC 12943177 7x12 11215' 11651' 436' 14.4 7-3-RO-N-X-I-LT- PR ROP NB 6 8.5" Baker / Hughes Christensen KMX 524 (Kymera) 5269766 2x18, 2x16 11651' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11651' MW 9.18 VIS 88 PV 30 YP 15 FL 2.8 Gels 11/25/29 CL- FC 0/2 SOL 8.4 SD 0.10 OIL 82.7/17.3 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 11651' TO 11651' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 20-24 inside window PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY @ 11650': 30% Tuffaceous Sandstone; 10% Conglomerate; 20% Sandstone; 40% Sand DAILY ACTIVITY SUMMARY POOH from 6969’ to MWD. Unload nukes from MWD tools and download MWD. Work on BHA #6. Make up BHA #7. Download MWD, load nukes. Finish making up BHA #7. RIH to 7962’ (filling pipe every 2500’). Slip and cut 162’ drilling line. Run new external wire for top drive lube pump. RIH from 7962’ to 10074’ (fill pipe at 10074’). CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Rance Pederson DATE Oct 16, 2017 DEPTH 11858' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 11651 24 HOUR FOOTAGE 207' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11715.47' 71.00 132.81 10233.57' 11651.90' 66.14 133.00 10211.38' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 6 8.5" Baker / Hughes Christensen KMX 524 (Kymera) 5269766 2x18, 2x16 11651' 207' 17.6 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 78.2 @ 11811' 0.8 @ 11667' 15.5 36.8 FT/HR SURFACE TORQUE 11731 @ 11841' 8677 @ 11664' 10285.8 11169.9 FT-LBS WEIGHT ON BIT 20 @ 11827' 10 @ 11652' 19.5 20.3 KLBS ROTARY RPM 139 @ 11781' 78 @ 11662' 130.3 138.0 RPM PUMP PRESSURE 3310 @ 11660' 2067 @ 11850' 2683.5 2593.6 PSI DRILLING FLUIDS REPORT DEPTH 11830' MW 9.15 VIS 74 PV 29 YP 15 FL 2.8 Gels 12/25/30 CL- FC 0/2 SOL 8.2 SD 0.10 OIL 83.3/16.7 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 11651' TO 11858' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 94 @ 11758' 24 @ 11669' 57.7 TRIP GAS 93 @ 11651' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 3007 @ 11759' 405 @ 11676' 1465.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 452 @ 11846' 29 @ 11669' 221.2 AVG 0 PROPANE (C-3) 311 @ 11759' 13 @ 11680' 142.9 CURRENT 0 BUTANE (C-4) 184 @ 11759' 8 @ 11682' 89.6 CURRENT BACKGROUND/AVG 24-43/36 PENTANE (C-5) 70 @ 11776' 4 @ 11679' 42.8 HYDROCARBON SHOWS Trace to Good Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11651' to 11850' Sandstone/Sand 24 to 94 Moderately bright yellow sample fluorescence with some brighter patches; appears oil stained; occasional visible oil inside cracked-open sandstone cuttings LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Tuffaceous Siltstone; Tuff PRESENT LITHOLOGY @ 11850': 50% Tuffaceous Sandstone; 30% Sandstone; 20% Sand DAILY ACTIVITY SUMMARY RIH from 10074’ to 10551’, set down, tight hole, no overpull. Wash from 10540’ to 10640’. RIH on elevators from 10640’ to 11560’. Wash from 11560’ to 10651’. Drill from 11651’ to 11858’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Steve Lawrence, Clint Montague DATE Oct 17, 2017 DEPTH 12127' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 11858' 24 HOUR FOOTAGE 269' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11964.07' 75.16 133.20 10297.53' 11899.93' 76.59 132.76 10281.87' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 6 8.5" Baker / Hughes Christensen KMX 524 (Kymera) 5269766 2x18, 2x16 11651' 476' 37.4 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 49.7 @ 11965' 1.0 @ 11953' 15.9 10.2 FT/HR SURFACE TORQUE 12234 @ 11966' 9274 @ 11945' 10635.4 10487.6 FT-LBS WEIGHT ON BIT 22 @ 11957' 14 @ 11990' 20.9 22.1 KLBS ROTARY RPM 159 @ 11938' 119 @ 12014' 140.6 138.4 RPM PUMP PRESSURE 2860 @ 11932' 1904 @ 11956' 2615.6 2564.6 PSI DRILLING FLUIDS REPORT DEPTH 12108 MW 9.10 VIS 76 PV 28 YP 14 FL 3.0 Gels 12/26/31 CL- FC 0/2 SOL 8.3 SD 0.10 OIL 84.4/15.6 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 11651' TO 12127' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 104 @ 11968' 26 @ 11953' 58.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 3605 @ 11968' 333 @ 11952' 1397.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 471 @ 11968' 29 @ 11954' 278.5 AVG 0 PROPANE (C-3) 300 @ 11966' 24 @ 11954' 130.6 CURRENT 0 BUTANE (C-4) 155 @ 11966' 26 @ 11955' 80.1 CURRENT BACKGROUND/AVG 34-41/38 PENTANE (C-5) 71 @ 11856' 18 @ 11958' 46.6 HYDROCARBON SHOWS Trace to Good Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11850' to 12120' Sandstone/Sand 26 to 104 100% Moderately bright yellow sample fluorescence with occasional brighter patches; appears oil stained; possible visible oil inside cracked-open sandstone cuttings LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Tuffaceous Siltstone; Tuff PRESENT LITHOLOGY @ 12120': 50% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drill from 11858’ to 11880’ (Pump 20 bbl 10.2 ppg / 240 vis sweep at 11880’ (35 bbls late / 20% increase cuttings)). Drill from 11880’ to 12127’ (Pump sweep at 12000’ (35 bbls late / 100% increase cuttings)). CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Steve Lawrence, Clint Montague DATE Oct 18, 2017 DEPTH 12257' PRESENT OPERATION Bit Trip TIME 24:00 YESTERDAY 12127' 24 HOUR FOOTAGE 130' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12208.32 77.85 135.10 10357.02' 12146.64' 77.11 134.42 10343.64' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 6 8.5" Baker / Hughes Christensen KMX 524 (Kymera) 5269766 2x18, 2x16 11651' 12257' 606' 50.5 ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 23.2 @ 12167' 1.8 @ 12188' 9.3 7.4 FT/HR SURFACE TORQUE 11503 @ 12171' 9672 @ 12136' 10614.2 9963.9 FT-LBS WEIGHT ON BIT 22 @ 12239' 17 @ 12182' 19.9 22.1 KLBS ROTARY RPM 143 @ 12145' 79 @ 12252' 134.3 99.4 RPM PUMP PRESSURE 3052 @ 12217' 1838 @ 12255' 2882.0 2603.3 PSI DRILLING FLUIDS REPORT DEPTH 12257' MW 9.25 VIS 84 PV 34 YP 15 FL 2.8 Gels 13/28/35 CL- FC 0/2 SOL 9.8 SD 0.10 OIL 84.7/15.3 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 11651' TO 12257' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 @ 12157' 30 @ 12256' 42.9 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 1481 @ 12169' 407 @ 12245' 813.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 313 @ 12157' 52 @ 12256' 205.3 AVG 0 PROPANE (C-3) 117 @ 12157' 13 @ 12256' 67.0 CURRENT 0 BUTANE (C-4) 68 @ 12157' 20 @ 12248' 41.4 CURRENT BACKGROUND/AVG 27-32/29 PENTANE (C-5) 43 @ 12157' 12 @ 12245' 24.9 HYDROCARBON SHOWS Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 12120' to 12255' Sand/Sandstone 30 to 57 100% moderately bright yellow sample fluorescence with occasional brighter patches; oil- stained appearance; possible visible oil in cracked-open sandstone cuttings LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Tuffaceous Siltstone; Tuff PRESENT LITHOLOGY @ 12255': 30% Tuffaceous Sandstone; 10% Conglomerate; 10% Sandstone; 40% Sand; 10% Tuff DAILY ACTIVITY SUMMARY Drill from 12127’ to 12181’ (Pump sweep at 12181’ (35 bbls late / 10% increase cuttings)). Drill from 12181’ to 12255’, rack one stand back, pump sweep and circulate sweep to surface (50 bbls late / 10% increase cuttings). Drill from 12255’ to 12257’. Rack back one stand, pump sweep surface to surface (45 bbls late / 25% increase cuttings). Pull 10 stands from 12243’, pump dry job. POOH from 11598’ to 8827’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Steve Lawrence, Clint Montague DATE Oct 19, 2017 DEPTH 12257' PRESENT OPERATION RIH TIME 24:00 YESTERDAY 12257' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12208.32 77.85 135.10 10357.02' 12146.64' 77.11 134.42 10343.64' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 6 8.5" Baker / Hughes Christensen KMX 524 (Kymera) 5269766 2x18, 2x16 11651' 12257' 606' 50.5 1-3-BT-T-E-1-LT- PR ROP NB 7 8.5" Varel V711PDG2HRU 4009876 3x12, 5x11 12257' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 12257' MW 9.40 VIS 266 PV 34 YP 18 FL 2.8 Gels 16/33/40 CL- FC 0/2 SOL 9.6 SD 0.10 OIL 85.1/14.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 12257' TO TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY @ 12255': 30% Tuffaceous Sandstone; 10% Conglomerate; 10% Sandstone; 40% Sand; 10% Tuff DAILY ACTIVITY SUMMARY POOH from 8894’ to 241’. Lay down jars. Make up new set of jars and rack back in derrick. Work on BHA #7. Unload nuclear sources from MWD tools. Download MWD. Lay down BHA #7. Make up BHA #8. Upload MWD. Shallow hole test MWD (good). Finish making up BHA #8 to 430’. RIH from 430’ to 1573’. Pick up agitator to 1602’. RIH from 1602’ to 3868’. Fill pipe. Break in seals on Geo Pilot. RIH from 3868’ to 7964’. Fill pipe. Service rig. RIH from 7964’ to 9453’ (work through tight spots at 8198’ and 9016’). CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Steve Lawrence, Clint Montague DATE Oct 20, 2017 DEPTH 12534' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 12257' 24 HOUR FOOTAGE 277' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12460.04' 71.36 132.34 10422.89' 12397.06' 73.03 132.37 10403.63' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 7 8.5" Varel V711PDG2HRU 4009876 3x12, 5x11 12257' 277' 10.4 Inc DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 141.7 @ 12492' 4.2 @ 12258' 28.1 24.3 FT/HR SURFACE TORQUE 14150 @ 12530' 10898 @ 12388' 12364.9 13400.2 FT-LBS WEIGHT ON BIT 14 @ 12492' 3 @ 12518' 7.9 9.7 KLBS ROTARY RPM 169 @ 12352' 99 @ 12475' 153.6 158.4 RPM PUMP PRESSURE 3070 @ 12266' 1983 @ 12485' 2905.9 2842.2 PSI DRILLING FLUIDS REPORT DEPTH 12491' MW 9.25 VIS 95 PV 34 YP 18 FL 3.0 Gels 15/33/39 CL- FC 0/2 SOL 9.1 SD 0.10 OIL 83.1/16.9 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 12257' TO 12534' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 98 @ 12377' 23 @ 12258' 63.3 TRIP GAS 94 @ 12257' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 2942 @ 12377' 495 @ 12258' 1555.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 540 @ 12351' 79 @ 12258' 347.2 AVG 0 PROPANE (C-3) 313 @ 12377' 33 @ 12258' 171.8 CURRENT 0 BUTANE (C-4) 176 @ 12377' 18 @ 12258' 103.5 CURRENT BACKGROUND/AVG 37-42/39 PENTANE (C-5) 78 @ 12377' 7 @ 12258' 53.1 HYDROCARBON SHOWS Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 12255' to 12510' Sand/Sandstone 23 to 98 100% moderately bright yellow sample fluorescence with some brighter patches; appears oil stained; possible visible oil in sandstones LITHOLOGY Tuffaceous Sandstone/Conglomerate/Sandstone/Sand; Tuffaceous Siltstone; Tuff PRESENT LITHOLOGY @ 12510': 30% Tuffaceous Sandstone; 50% Sandstone; 20% Sand DAILY ACTIVITY SUMMARY RIH from 9453’ to 10564’, stacked out 30K. Wash and ream from 10564’ to 10629’. Set down 10629’ to 10653’. RIH on elevators from 10653’ to 11221’, set down 40K/40K over pull, fired jars twice at 210K. Wash and ream from 11221’ to 11621’. RIH on elevators from 11621’ to 12182’. Wash and ream from 11621’ to 12254’ (break bit in). Drill from 12257’ to 12438’ (pump 10.3 ppg / 330 vis sweep at 12365’ while drilling ahead (40 bbls late / 50% increase cuttings)). Drill from 12438’ to 12534’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Steve Lawrence, Clint Montague DATE Oct 21, 2017 DEPTH 12616' PRESENT OPERATION POOH TIME 24:00 YESTERDAY 12534' 24 HOUR FOOTAGE 82' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12585.12' 69.48 130.98 10465.56' 12522.14' 69.70 132.54 10443.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 7 8.5" Varel V711PDG2HRU 4009876 3x12, 5x11 12257' 12616' 359 16.7 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 37.8 @ 12573' 4.4 @ 12559' 13.2 9.8 FT/HR SURFACE TORQUE 14063 @ 12593' 11095 @ 12564' 12690.6 12429.4 FT-LBS WEIGHT ON BIT 13 @ 12592' 6 @ 12545' 10.1 11.3 KLBS ROTARY RPM 159 @ 12558' 118 @ 12563' 157.4 157.5 RPM PUMP PRESSURE 3209 @ 12585' 2326 @ 12603' 3038.5 3137.1 PSI DRILLING FLUIDS REPORT DEPTH 12613' MW 9.25 VIS 95 PV 35 YP 17 FL 3.0 Gels 13/30/34 CL- FC 0/2 SOL 9.0 SD 0.10 OIL 81.7/18.3 MBT pH Ca+ CCI MWD SUMMARY INTERVAL 12257' TO 12616' TOOLS Directional / Triple Combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 @ 12541' 35 @ 12554' 46.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 1102 @ 12541' 450 @ 12555' 808.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 424 @ 12605' 153 @ 12565' 318.2 AVG 0 PROPANE (C-3) 110 @ 12541' 37 @ 12570' 64.9 CURRENT 0 BUTANE (C-4) 75 @ 12541' 26 @ 12616' 42.2 CURRENT BACKGROUND/AVG Current = 27 PENTANE (C-5) 65 @ 12541' 23 @ 12614' 38.1 HYDROCARBON SHOWS Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 12510' to 12616' Sand/Sandstone 35 to 57 100% moderately yellow sample fluorescence but with less brighter patches than previous reports; appears oil staining; possible interstitial visible oil LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Claystone PRESENT LITHOLOGY @ 12616': 20% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 40% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drill from 12534’ to 12616’ TD (pump 20 bbl 10.3 ppg / 330 vis sweep at 12556’ (40 bbls late / 30% increase cuttings)). Circulate clean, pumping 2 sweeps (Sweep #1: 20 bbl 10.2 ppg / 315 vis (40 bbls late / 50% increase cuttings), Swwep #2: 20 bbls 10.2 ppg / 400 vis (40 bbls late)). Pump Sweep #3: 0% increase cuttings. Lay down one joint to 11586’. POOH from 11586’ to 11615’, 40K over pull. Top drive up, circulate bottoms up 3X. POOH from 11640’ to 7872’, working through tight spots in coals. Service rig, mix dry job. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster Hilcorp Alaska LLC Granite Point Platform DAILY WELLSITE REPORT GP 11-24 RD REPORT FOR Rick Brumley, Steve Lawrence, Clint Montague DATE Oct 22, 2017 DEPTH 12613' PRESENT OPERATION Making up Clean out BHA TIME 24:00 YESTERDAY 12613' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" TOW @ 8006' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12585.12' 69.48 130.98 10465.56' 12522.14' 69.70 132.54 10443.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 7 8.5" Varel V711PDG2HRU 4009876 3x12, 5x11 12257' 12613' 356' 16.7 1-3-WT-T-X-I-PN-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 12613' MW 9.30 VIS 205 PV 35 YP 17 FL 3.0 Gels 13/30/34 CL- FC 0/2 SOL 9.0 SD 0.10 OIL 82.0/18.0 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG Current = 27 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY @ 12613': 20% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 40% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Finish servicing rig, mix dry job. Pump 20 bbl dry job. POOH from 7891’ to 1554’ (rabbit didn’t make it past agitator). Pick up joint and make up on top of stand 19. Break off and lay down agitator and crossovers. Drop rabbit from 1554’ to 276’. Lay down 3 joints of HWDP and jars. Rack back drill collars. Unload radioactive sources fro MWD. Download MWD. Lay down down MWD tools, break bit, and lay down Geo Pilot. Service top drive and dra works. Clean and clear rig floor. Lay down top drive service loop. RIH with 2 stands of HWDP, make up test plug, drain stack, and set test plug. Fill stack, test joint, choke manifold, and work air out of system. Shell test good. Test BOP (good). Rig down from BOP test. Pick up BHA #9 to 325’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2755 REPORT BY Paul Webster
