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185-103
• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned El • Suspended❑ lb.Well Class: 2OAAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service E • Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp..or . 14.Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC • Aband.: `0/11.10 to 185-103 • 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 May 22, 1985 50-029-21358-00-00• 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 724'FSL,2098'FEL,Sec 10,T13N,R10E, UM,AK May 28, 1985 MPU C-15 Top of Productive Interval: 9. Ref Elevations: KB: 50.4 17. Field/Pool(s): GL:16.7 BF: 16.7 Milne Point Unit/Kuparuk River Oil Pool• Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 4887 FNL,473 FEL,Sec 10,T13N, R10E,UM,AK 7,572'MD/7,231'TVD ADL047434 • 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 558366 y- 6029007 Zone- 4 7,665'MD/7,319'ND N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 559993 y- 6028688 Zone- 4 N/A 1,676'MD/1,675'ND 5. Directional or Inclination Survey: Yes ❑tacked) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 MC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary RECEIVED sCANNED SEP 2 9 2016 .JUS_ 2 9 Z016 . 0 CC 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8" 48# H-40 Surface 105' Surface 105' 13-3/8" To Surface 9-5/8" 36# K-55 Surface 4,692' Top 4,595' 12-1/4" 1315 sx Permafrost 250 sx Class G 7" 26# L-80 Surface 7,652' Top 7,307' 8-1/2" 250 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): -- At3PCNIObN c �"`�`i �)AT�� 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. 1•J Was hydraulic fracturing used during completion? Yes❑ No 0 Ic"�° ' y ,«FLl�I.IFL,f Per 20 MC 25.283(i)(2)attach electronic and printed information 1;25'1( LC DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate . I Form 10-407 Revised 11/201CONTINUED ON PA 2 Submit ORIGINIAL only/ `eKI3 c1 fr /c A5-P.2 -A, ,eb RBDMS w AUG - 2 2016 \IG 28.CORE DATA ConventionalCore(s): Yes No ✓ Sidewall Core Yes n No ✓ If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No El Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval information,including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Wellbore Schematic, Drilling Reports Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Dinger Email: cdinger@hilcorp.com Printed Name: Cod •er Title: Drilling Tech Signature: / Phone: 907-777-8389 Date: /29 /Z2(4. INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only Milne Point Unit II 0 SCHEMATIC • Well: MPU C-15 Abandoned: 6/26/2016 Hilcorp Alaska,LLC PTD: 185-103 KBEIev.:50.4'/GLEIev.:16.7' CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Al ',. : 13 3/8" Conductor 48/H-40/Weld 12.5" Surface 105' 13-3/8" 9-5/8" Surface 36/K-55/BTC 8.921" Surface 4,692' 7" Production 26/L-80/BTC 6.276" Surface 7,653' 4-1/2" Liner 12.6/13Cr-80/Vam TOP 3.958" 6,928 9,928' (C-15A) 9-5/8" • t PERFORATION DETAIL Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup Cl 7,226' 7,240' 6,904' 6,917' 14 Multiple Closed B-silts 7,314' 7,318' 6,986' 6,990' 4 Multiple Closed B-silts 7,338' 7,342' 7,009' 7,013' 4 Multiple Closed Kup A3 7,410' 7,430' 7,077' 7,096' 20 Multiple Closed Kup A2 7,442' 7,468' 7,107' 7,132' 26 Multiple Closed OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt to surface 9-5/8" Cmt w/1,315 sx Permafrost E/250sx Class G in a 12-1/4"Hole 7" Cmt w/250 sx Class G in 8-1/2" 4-%," Cmt w/304 sxs HalCem in 6-1/8" ti, GENERAL WELL INFO API:50-029-21358-00-00 Drilled and Cased by AUD#3 -5/31/1985 Swap to WAG INJ by Nabors 4ES—4/20/1995 Abandoned by Doyon 14—June 26,2016 ti $, . "` -Z, ' 7" 1 V- D(.1.11V 5/k C1 4-i/Y • Created By:LEK 5/6/2016 Modified by: CD 7/29/2016 • • Hilcorp EnergyCompany Composite Report Well Name: MP C-15 Field: Milne Point County/State: ,Alaska I(LAT/LONG): ovation(RKB): API#: Spud Date: Job Name: Contractor AFE#: AFE$: Activity Date Ops Summary 6/12/2016 PJSM,skid rig floor into move position,move rock washer, prep pad for pulling off well. R/D Doyon 14 camp to C-pad;PJSM,with well secure,move off J-28,position rig and Install rear boosters,cleanup around J-28,move rig mats.Mobilize and stage rig mats for rig move. Move rig camp to C-Pad;Install front gooseneck and front boosters,finish Matting soft road areas f/J-Pad to I-Pad,;Notify MP security,move rig f/J-Pad to I-Pad entrance,;Stage rig on I-Pad,Shuffle rig mats from behind rig to in front of rig.;Move rig from I-Pad access road to H-Pad entrance;Stage rig on H-Pad,Shuffle rig mats from behind rig to in front of rig.;Move rig from H-Pad to G-Pad;Stage rig on G-Pad,Shuffle rig mats from behind rig,Mat soft road areas f/G-Pad to Spine road. 6/13/2016 Move Rig f/G-Pad to MPU Spine road intersection and attempt to make corner.Busted through Road at the Spine/Tract 14 Intersection.;Back rig up and lay mats through intersection.;Move rig from Track 14 intersection to A-Pad Entrance.;Stage rig on A-Pad Entrance and shuffle and lay mat boards to front of rig.;Move Rig from A-Pad entrance to L-Pad Entrance.;Stage rig on L-pad Entrance,Shuffle and Lay Mat Boards down C-Pad access Road;Move rig from L-Pad entrance to C-Pad,stage rig on Pad;PJSM,Remove rig boosters and gooseneck.Notify DSO before backing over well. Note:0/A=0 psi,I/A=700 psi,tbg=0 psi;PJSM,Line up rig to back over well. 6/14/2016 Continue to spot rig over C-15.;Skid Rig floor into drilling position.Spot Flow back tank;Rig up floor,air,water,steam,stage manual IBOP on rig and MU to top drive,continue to rig up flow back tank to rig choke manifold,spot rock washer skid,DSL tank,Mud Log shack,;Mud Engineer shack,continue R/U conveyors and tightening chains,prep mud pits and bring on 10.5 ppg mud system.R/U circulating equipment on IA and Tree.Test and calibrate rig gas alarms.;PT lines to flow back tank to 2000 psi.;Rig Evacuation Drill.PJSM on Killing well to flow back tank.;Bleed down IA to tank from 700 psi too psi. 10 bbls bled back to Kill Tank. Pump down TBG taking returns up IA to kill tank pumping 60 bbls FW,follow with 10.5 ppg Drilling Mud.;Pumped 250 bbls to flow back tank and additional 80 bbls to rock washer pit.Circulate additional 60 bbls tubing volume to active system with 10.5 in/out. ICP @ 4 bpm 1090 psi,FCP©5 bpm 980 psi.;Monitor well, well static.Lost 6 bbls while circulating final tubing volume to active.;Suck out circulating line on Tree.Chase BPV Profile BPV Thread chase.Set BPV.;Blow down surface circulating lines,R/D same.;N/D Tree. Inspect tbg hgr. Lift threads good. Function LDS(ok)4-3/4"out,3-3/4"in. Pack top of hanger profile (graphite)for testing. Verify BPV on seat(ok).;N/U BOP equipment. Charge koomey and function components(ok).;R/U BOP test equipment. M/U 2-7/8"test jt (donut anchor). Attempt to fluid pack test jt but lower rams would not seal. Function rams several times and verify koomey psi. Unable to seal lower rams;Troubleshoot lower rams. Drain stack and verify positive closure(ok). Verify leak at ram body around pipe. Bleed dn koomey lines to lower rams,open and change out ram elements.;Daily losses to formation 5 bbls for total=5 bbls Hauled 60 bbls to MP G&I for total=60 bbls Hauled 280 bbls to B-50 for total=280 bbls Hauled 205 bbls from L-Lake for total=205 bbls 6/15/2016 Continue to change out Seals on lower 2-7/8 x 5 VBR's.;Continue to Test BOP and associated equipment to 250/4000 psi,5 min hold on each.Test Rams to 2- 7/8",4"and 4-1/2"pipe size.Test Annular to 2-7/8"pipe size.;Test gas alarms,Perform Accumulator Test:Start 3000 psi,After closure 1625 psi,200 psi build 42 seconds,Full recovery 185 seconds.N@ Bottles 6 @ 1975 psi Average.;R/D test equipment. Blowdown surface equipment and lineup same for upcoming operations.;Pull TWC. Had difficulty removing TWC due to debris in profile. Drain stack and flush profile several times before we were able to remove TWC from hanger profile. Well had slight vac.;M/U landing jt w/xo's. Engage hanger and M/U same. Kelly up w/TDS. BOLDS. Unseat hgr @ 101k,up wt 107k.P/U and space out in stack. Close Annular and lineup on choke.;Stage pumps up and CBU @ 7,136'MD via choke manifold. 5 BPM @ FCP 500 psi. Saw moderate amounts of sand w/residual crude @ btms up then quickly cleaned up.;Monitor Well(Static). B/D choke line and manifold. Drain gas buster and lineup choke for tripping operations. M/U FOSV w/xo.;C/O elevators. POOH w/3-1/2"tbg F/7,136'-T/936'MD. Replaced pivot bracket for handle on power tongs(15-20 mins). No other issues.;Daily losses to formation 3 bbls for total=8 bbls Hauled 57 bbls to MP G&I for total= 117 bbls Hauled 0 bbls to B-50 for total=280 bbls Hauled 75 bbls from L-Lake for total=280 bbls;Rig went on Hi-Line @ 17:45 hrs. Check OA every 12 hrs,Maintain 0 psi throughout day 6/16/2016 POOH w/3-1/2"tbg F/936'-T/surface. 226 total jts+3.05'cutoff jt w/4-1/16"flare.;Clean up tools and equipment. R/D Weatherford casing. Mob milling tools and equipment to pipe shed and rig floor. Install wear ring=9"ID.;Make up packer mill assy w/18"stinger on nose(2.875"OD). Packer mill+3x boot baskets+bit sub+Bumper+Oil Jar+XO+9xDC+XO+Intensifier+pumpout sub+XO=333'total Iength;Single in with Milling assy on 4"dp to 7,113'MD. 160K up, 140k dn. Hole took proper displacement;Establish parameters and wash dn F/7,113'to tag depth of 7,138'MD. Mill F/7,138'to 7144'MD.Various milling parameters-40-80 rpm,2-5 bpm,3-15k wob.;Saw slight increase in flow. P/U and S/D pump. Fluid dropped est 6'in stack. slight gas breaking out @ surface. Circulate btms up as planned thru choke.. 4 BPM,565 psi.;Blow down choke lines and line back up for milling operations. Continue milling lower slip section on packer w/same parameters F/7,144'-T/7146'MD.;Daily losses to formation 0 bbls for total=8 bbls;Hauled 0 bbls to MP G&I for total=117 bbls Hauled 0 bbls to B-50 for total=290 bbls Hauled 480 bbls from L-lake for total=760 bbls • 6/17/2016 Continue milling lower slip section on packer from 7146'.Adjusting parameters as needed.torque up and stalled out @ 7146.50'.PU and set back down PKR fell free.;TIH on elevators chasing PKR f/7137'to 7430'.Start taking wt @ 7430'.Wash and ream PKR to No Go @ 7437'TOF and Tail Pipe @ 7471'. PUW 164K/SOW 140K/Rot 145K/2.5BPM/460 psi/90 RPM/3K Tq;Bottom of fish @ 7471'.Bottom Perfs f/7442'-7468'.PBTD©7572'.Est 100'+-fill below fish.;CBU from 7437'@ 8.5 bpm/1770 psi.Had about 50%increase in fine sands at bottoms up.Continue circulate clean.Monitor well,well static.;POOH on elevators standing back 4"DP from 7437'to 330'.Work BHA standing back DC's.Lay down PKR Mill BHA.Clean out boot baskets and recover 52 lbs metals, recover 281bs from possum belly.;Mu PKR Spear Assy:2 13/16"ITCO Spear/4-3/4"Bumper sub/Oil Jar/XO/9-4 3/4"DC's/XO/intensifier/Pump out sub/XO to DP. BHA length=319.88;TIH on elevators with 4"DP from derrick f/319'to 7,382'MD. Hole took proper displacement.;Establish parameters @ 7,382'MD. 165k up, 145k dn,2 bpm/750 psi. SIO F/7,382'and tag top of fish on depth @ 7,436'MD w/pump on. Saw 180 psi increase @ top of fish. S/D pump.;Continue S/O to 7,442'w/12K set dn. P/U 5'w/no increase in up wt. S/O and set dn 15k. P/U w/increase in up wt. Up wt w/fish 200k-175k.;POOH w/fishing assy F/7,442'-T/ 5,028'MD.;Service rig.;Continue POOH w/fishing assy F/5,028'-T/320'MD. Monitor well(static)prior to working BHA. Hole took proper displacement.;Stand back DC's.Release spear from fish(36.15'). Clean and L/D(Fish)Pkr/xo/pupl'X"nipple/pup and WLEG w/all jewelry intact and in good shape.;Clean and clear rig floor. Bring tools to rig floor for upcoming BHA.;M/U BHA#3-6-1/8"Junk mill/3x Boot baskets/bit sub/(6-1/8")string mill/bumpers/oil jar/xo/9 DC's/xo/intensifiers/pump out sub/xo=338.18'length;TIH w/junk mill assy picking up 4"dp(93 jts)out of shed F/338'-T/3,256'MD.;Daily losses 0 bbls for total =8 bbls;Hauled 0 bbls to MP G&I for total=117 bbls Hauled 0 bbls to B-50 for total=280 bbls Hauled 110 bbls from L-Lake for total=870 bbls 6/18/2016 Continue to TIH w/junk mill assy from 3256'to 7400'.;Wash down from 7400'.Start taking weight @ 7446'in bottom perf interval.Wash/Ream to 7490'. 3 bpm/470 psi/60 rpm/3K tq/PU 163K/SO 144K/Rot 150K.Increase pump to 6 bpm and CBU from 7490';Attempt to achieve FIT on Perfs to 13 ppg.had leak off @ 685 psi for 12.4 EMW;Mix,Pump and spot 20 bbls,40 ppb Baracard/Steel Seal Pill across perfs from 7226'to 7468'.Squeeze pill into perfs.Attempt 13 ppg FIT on perfs and had Leak off @ 850 psi for 12.8 EMW;Continue to wash and ream from 7490',start taking weight @ 7554'.Mill hard CMT from 7554'to 7559'.6-15K WOM/4 bpm/730 psi/70-100 rpm/4-8k tq/165 PU/145 SO/150K Rot.Broke through @ 7559'.;with plug rubber and CMT back at shakers.Mill cement from 7559' to 7575'w/10-12 WOB/100 rpm/4-5K Tq.Set down hard @ 7575'.;Continue shoe track F/7,575'to 7637'MD. Tagged FC and FS 14'high. Drill shoe and wash down rathole F/7,637'to 7,652'MD.;6-15K WOM/4 bpm/730 psi/70-100 rpm/4-8k tq/165 PU/145 SO/150K Rot;Driling new formation w/6-1/8"junk mill F/7,652'- T/7,657'MD. Very slow ROP and samples @ shakers confirm shale formation being drilled.;4 bpm,620 psi,20%flow,70 rpm,3k tq on,2k tq off, 163k up,144k dn, 150k rot. 2'ROP avg.;P/U and spot 17 bbl LCM pill(40 ppb-Steel seal/safe carb)F/7615'-T/7175'MD.;Pull wet F/7,615'-T/7,115'MD. Monitor well (static). Pump dry job. Pull out of hole F/7,115'-T/650'MD.;Daily losses to formation 25 bbls for total=33 bbls;Hauled 290 bbls to MP G&I for total=407 bbls Hauled 0 bbls to B-50 for total=280 bbls Hauled 160 bbls from L-Lake for total=1030 bbls 6/19/2016 Continue to POOH from 650'to BHA.;POOH laying down 4 3/4"DC's,L/D BOT Junk Mill Assy.Clean out boot baskets w/42Ibs metals recovered.Clean and clear rig floor and pipe shed of fishing tools.Stage Directional BHA on rig floor.;MU Drilling BHA#1:6-1/8" NOV SKHI519S PDC Bit, 5"SperryDrill Mtr,Integral Blade @ 5 7/8", 4 3/4"Float Sub,DM Collar,GM Collar, Inline Stabilizer @ 6",ADR Collar PWD,TM HOC;Up Load MWD Tools;Continue PU BHA: 3)4-3.4" NM Flex Collar's, X-Over Sub, 1 jt 4"HWDP;Pulse test MWD @ 200 gpm/640 psi,225 gpm/780 psi.;Continue to PU remaining BHA: 5 jts 4"HWDP HT38, Weatherford HYD Jar, 11 jts 4"HWDP.Total BHA Length=739.99;TIH on elevators from 739'to 7630';C/O drilling line spool. Restring Blocks,Crown and drum w/1800'new line. Adjust COM,brakes and roller guides. Service rig. Sym ops-squeeze Icm pill w/500 psi during cut and slip operations;Wash dn F/7,630'to 7,657'and drill ahead. Drill ahead F/7,657'-T/7,686'MD. 250 gpm, 2080 psi,40 rpm,4k tq on. Clean hole ECD's 11.35 EMW.;Circulate and condition mud for FIT. 250 gpm, 1690 psi. 10.6 mw IN/OUT.;P/U inside shoe to 7,611' MD. R/U test equipment. Fluid pack lines and purge air. Shut rams and lineup dn dp and annulus.;Pump.5 bpm. Psi up to 860 psi @ 29 stks(2.9 bbls pumped). S/D pumps and record psi every min for 10 mins when psi stabilized @ 433 psi.;upper perfs @ 6,904'TVD. (13-10.6)x.052x6904'TVD=860 psi. FIT @ 13ppg @ upper perfs,FIT 12.8 ppg EMW @ btm(7,686'MD/7,340'TVD).Bled back 1.5 bbls;R/D test equipment. B/D lines and lineup for drilling operations.;Wash dn F/7,611'-T/7,686'MD. 250 gpm, 1730 psi,40 rpm,3k tq. 175k up,145k dn,151k rot.;Drill ahead F/7,686'-T/7,815'MD. 129'(21.5 fph avg). 250 gpm,2,030 psi on, 1780 psi off,23%flow,5-7k wob,75 rpm,4k tq on,3k tq off,200 psi diff;Daily losses to formation 14 bbls for total=47 bbls;Hauled 332 bbls to MP G&I for total=739 bbls Hauled 0 bbls to B-50 for total=280 bbls Hauled 115 bbls from L Lake for total=1145 bbls 6/20/2016 Drill ahead F/7,815'-T/7,916'MD. 101'(15.5 fph avg). 275 gpm,22080 psi on, 1980 psi off,23%flow,5-7k wob,80 rpm,4-5k tq on,3k tq off,200 psi diff,MW 10.5/ECD 11.4;Having issue sliding.Lube mud system up to 1%.Still having same issues.Discuss options with DD and Engineer.Decision made to trip for less aggressive bit and drop stabs.;Set back 1 stand and CBU from 7895'.Work pipe 90'Rot 155K/40 rpm/3k Tq/275 gpm/1860 psi.;POOH on elevators from 7895' to7611'(inside shoe) with no issues.PUW 178K/SOW 145K;Monitor well,slug pipe,blow down top drive.;POOH from 7611'to BHA @ 739'.Monitor well,well static.;Stand back HWDP/Jars and NM Flex Collars in derrick.;Down Load MWD Data.;Continue POOH w/BHA#1. Drain and BIO bit. Bit grade= 0,0,NO,A,I,X,NO,PR. 13/0 and laydown Inline stab,IBS and mtr stab.;M/U new 6.125"HDBS 6 blade PDC w/slick mtr assy. RFO=259.92°(witnessed). Download MWD(30 min).RIH w/Monels and 1 std HWDP T/259.92'MD.;Shallow Pulse test(ok). 225 gpm,720 psi(20 min). Continue RIH out of derrick w/ remaining BHA. BHA#2 total length=731.83';TIH F/731'-T/7,321'MD. Fill pipe every 25 stds.;Service blocks,TDS and crown.;TIH F/7321'-T/7,886'MD. Wash dn F/7,886'to 7,916' MD. Hole took proper displacement.;Drill ahead F/7,916'-T/7,942'MD. 101'(6 fph avg). 300 gpm,2410 psi on,2220 psi off,26% flow,15-20k wob, MW 10.5/ECD 11.4;Improved steerability after removing stabilizers from BHA#1 but reduced ROP w/new bit.;Daily losses 3 bbls for total=50 bbls Kick while drilling DRILL @ 04:00 hrs. Good response.;Hauled 57 bbls to MP G&I for total=796 bbls Hauled 0 bbls to B-50 for total=280 bbls Hauled 290 bbls from L-Lake for total=1435 bbls 6/21/2016 Drill ahead F/7,942'-T/8243' 301'(25 fph avg). 300 gpm,2350 psi on,2220 psi off, 15-20k wob, MW 10.5/ECD 11.5.;Drill ahead F/8,243'-T/8389' 146'(25 fph avg). 300 gpm,2370 psi on,200 diff, 7-10k wob, MW 10.5/ECD 11.5.;Drill ahead F/8389'-T/8545' 156'(26 fph avg). 300 gpm,2400 psi on,200 diff, 7- 10k wob, MW 10.5/ECD 11.5.;Distance to Plan=3'high/.6'Left Pumped 20 bbl Lo vis(condet/walnut)sweep @ 8,425'MD w/30%inc(clay/shale). On time. Daily losses 0 bbls for total=50 bbls;Hauled 550 bbls to MP G&I for total=1346 bbls Hauled 0 bbls to B-50 for total=280 bbls Hauled 390 bbls from L-Lake for total 1825 bbls 6/22/2016 Drill ahead F/8545'-T/8829' 284'(24 fph avg). 300 gpm,2400 psi on,200 diff, 7-12k wob, MW 10.5/ECD 11.6;Drill ahead F/8829'-T/8961' 132'(22 fph avg). 310 gpm,2750 psi on,210 diff, 7-12k wob, MW 10.5/ECD 11.7;Drill ahead F/8961'-T/9090'MD.139'(22 fph avg). 310 gpm,2750 psi on,210 diff, 7- 12k wob, MW 10.5/ECD 11.6 Pump Hi Vis sweep @ 8,781'w/20%Inc/On time;Distance to Plan=11.5'High/3'Left Daily losses 0 bbls for total=50 bbls End of tour/OA=165 psi-bled off to 0 psi;Hauled 587 bbls to MP G&I for total=1933 bbls Hauled 0 bbls to B-50 for total=280 bbls Hauled 350 bbls from L-Lake for total=2175 bbls • • 6/23/2016 Drill ahead F/9090'-T/9194'MD. 94'(11.75 fph avg). 250-310 gpm,2750 psi on,210 diff, 7-18k wob, MW 10.5/ECD 11.6 Pump Hi Vis sweep @9150 w/150%Inc/On time;Decide to POOH for bit due to Low ROP&needing to make a wiper trip. Monitor well. POOH F/9094'T/Shoe @ 7560'. 15-20k bobbles. No issues.Hole took the correct fill for the trip. Pump Dry job;POOH F/7560'T/BHA. Rack back HWDP w/Jars. Rack back DC's. P/U and drain mtr(2.5mm end play/good). BIO bit(bit grade=1,1,PN,N,X,I,NO,PR);M/U new Smith 6.125"Z513. TIH w/BHA#3(total length=731.7'). Shallow pulse test @ 731'(ok). TIH T/9100'MD. Wash do last stand. Obtain SPRs. Hole took proper displacement.;Drill ahead F/9194'-T/9278'MD. 84'(15 fph avg). 250-310 gpm,2750 psi on,210 diff, 10-22k wob, MW 10.6/ECD 11.7;Observed slight amount of 1"to 1-1/2"shale slivers @ shakers(9,202'MD). Slowly increase MW to 10.7 ppg. Distance to Plan= 13'High/2'Left;Daily losses 0 bbls for total=50 bbls Pumped Hi Vis sweep @ 9095'w/150%inc(on time). Switch over to Rig Power @ 04:15 hrs.;Hauled 609 bbls to MP G&I for total=2542 bbls Hauled 870 bbls to B-50 for total=1150 bbls Hauled 275 bbls from L-Lake for total=2450 bbls 6/24/2016 Drill ahead F/9278'-T/9660'MD. 382'(32 fph avg). 250-310 gpm,2636 psi on,210 diff,10-16k wob,MW 10.6/ECD 11.7.;Drill ahead F/9660'-T/9928' MD/9250'TVD(TD). 268'(36 fph avg). 300 gpm,2640 psi on, 100 diff, 6k wob, MW 10.8/ECD 11.7.;Encountered connection gas w/50 unit bump @ 9687'MD. 100-150 BGG.Increase MW F/10.6 to 10.8 MW. BGG decreased F/100 to 40 units(Totco).;Circulate and condition hole @ TD(9928'MD). Circ 3.5 btm's up @ 300 gpm,2540 psi w/24%flow, 100 rpm,6k tq. ECD=11.7 EMW.;Pump 20 bbl hi vis sweep @ TD w/200%inc(on time),mostly shale and sand.;Flow check (slight flow). Work pipe and monitor w/no change(slight flow w/slight increase). Cont circulating.Inc MW from 10.8 to 11 ppg MW. Initial BGG=35,BU gas max =230 units.;Final ECD=11.9 w/275 gpm,2300 psi,24 bgg. Flow check w/11 ppg MW.;Distance to plan @ original target depth=9'Low/12'Right Daily losses 0 bbls for total=50 bbls;Hauled 810 bbls to MP G&I for total=3352 bbls Hauled 0 bbls to B-50 for total= 1150 bbls Hauled 520 bbls from L-Lake for total=2970 bbls 6/25/2016 POOH F/9928'T/7792'. Pump Dry job.POOH T/7792'.Drop 2"Drift on wire.POOH T/7508'.Shoe. No over pulls on the trip.Hole took the correct hole fill. Monitor well.Static.;POOH F/7708'T/BHA.L/D HWDP&Jars. Dowload BHA. L/D BHA&Grade bit. 1-1-WT-A-X-I-LT-TD;Clean&Clear Floor. Change over to completion AFE. • Hilcp Energy Company Composite p Re ort Well Name: MP C-15 Field: Milne Point County/State: ,Alaska (LAT/LONG): ovation(RKB): API#: Spud Date: Job Name: Contractor AFE#: AFE$: Activity Date Ops Summary 6/25/2016 Working on the drilling report.Switch to Completion AFE @ 1400.,R/U Weatherford torque turn equipment. PJSM P/U 4.5 Vam Top Chrome Liner.M/U Shoe, FC,&LC joints. Baker lock same.Check Floats.,Service rig while receiving and M/U Floor valve XO.,P/U 4.5 Vam Top 12.6# L-80 13 CR F/120'T/3020'MD. Tq Turn Connections. Verify 69 total jt run(ok),6 left in shed. M/U plug assy on btm LRT. Verify 840#shear pins(ok). Verify 6 shear pins on tool(2284 psi)and 5 pins on setting tool @ 24,500#for pkr ZXP. Mix and install"Pal Mix".,Circulate lx liner Vol @ 3020'MD. Stage up 5 bpm,490 psi. Obtain parameters=15 rpm, 1k tq,80k up,80k dn,80k rot.,Run 4.5"liner in hole on drill pipe out of derrick F/3020'to 6983'MD. Fill on the fly.,Service rig.,Continue run 4.5"liner on dp F/6,983'to 7,641'MD.,Circulate 1-1/2 dp+liner volume©7,641'MD. Stage up 5 bpm,790 psi,22%flow. Obtain parameters-20 rpm/2k tq,30 rpm/2k tq,140k up,123k dn,130k rot.,RIOH w/liner F/7,641'to 9900'MD. Hole took proper displacement. Clean trip.,P/U BOT rot cmt head. R/U lines and manifold. Wash dn F/9900'to 9928'MD. Tag up on depth. Stage pumps up to 3.5 bpm,810 psi, 15 rpm,6k tq. Condition mud for cmt job. R/U Halliburton Cmtrs. 6/26/2016 Circ&condition staging pumps up to 5 bpm @ 950-1100 psi. ROT @ 15-30 RPM @ 4-7000K.Work pipe 30'. UP/DN/Rot 210/140/165. Conduct PJSM with Halliburton cmt crew Baker hand and Rig crew.,Line up to Halliburton. Fill lines with H20. Test lines to 4500 psi.Good. Pump 20 bbl 12 PPG Clean Spacer, Pump 304 SX @ 1.525 CUFT&15.8 PPG.(83 BBL Total).Shut down.Flush lines to cmt head.R/D Circ lines to TD. Drop dart.Verify dart released.Line up to Rig Pump 10 bbl H2O.Displace with RIG. Caught pressure @ 260 STKS away.Latched plug @ 580 stks. 16.1 BBL Early. Saw 350 psi pressure spike.,We were able to Rot @ 30 rpm 7K TQ &Work pipe until 90 bbl away where we started pressuring up over our 1500 decided max pressure.Decided to put pipe in tension and shut down ROT then finish pumping. Continue pumping @ 1-4 bpm. Had intermittent packing off but were able to maintain flow throughout the job. Bumped plug @ 1023 stks with 2400 psi. 16.16 BBL early.Pressure up to 4200 psi. Hold.,Slack off&Slips appear to be slipping.Slack off to 120K. P/U to 135 &Liner jumped.Assumed Liner running tool released. Bleed off 4200 PSI pressure.Checked Floats.Good. Slack off&set down to 60K. Looked like it was slipping while slacking off. Decide to test the back side. Test annulus to 1500 psi.Good.,Bleed off&open rams.P/U with 700 psi on the drill pipe. Had to pull up to 250K to release. Wt fell off to 135k. P/U Above LT with running tool while bringing pumps to 11 bpm @ 2600 psi. We got Mud push back @ 1370 stks.We did get estimated 3 bbl cmt returned to surface.,CIP©11:05. Circ&condition.Pump total 3 btm up.Mud in good shape.,Break off cmt swivel&double in mouse hole. Slip&cut drilling line. Clean surface lines. Pump Dry job.,POOH on elevators F/6900'T/3109'MD standing back stands in the derrick.,POOH laying down 4"DP F/3109'to surface. B/O and LID LRT. LRT had good indicators of setting tool hydraulic set but dog sub had not sheared. Found debris between dog sub(formation).,Clean and clear rig floor. Bring scraper BHA tools to rig floor. Verify lengths,ID's,and OD'S. Bring Weatherford casing equipment to floor,R/U same. Sym Ops-Kelly up and flush stack. Verify pipe count in shed(97 jts).,Rig Service.,M/U Scraper assy-3-3/4"junk mill,bit sub,4.5"scraper,xo (total=7.92'),2-7/8"HT PAC drill pipe(2965.98'),xo,7"scraper,brush,xo.,Daily losses 0 bbls for total-50 bbls Hauled 646 bbls to MP G&I for total-4230 bbls Hauled 0 bbls to B-50 for total-1200 bbls Hauled 330 bbls from L-Lake for total-3420 bbls • • 4,t-''"/774'• THE • STATE Alaska Oil and Gas ti�,-i��� O ® Conservation Commission f1ZLA S t 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAY�Q` r� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Area Operations Manager SCOW SEP 2'8 2016 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-15 Permit to Drill Number: 185-103 Sundry Number: 316-269 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster ,, Chair DATED this u day of May, 2016. RBDMS MAY 3 1 2016 • • flECEIVED STATE OF ALASKA MAY [ 1. 2016 ALASKA OIL AND GAS CONSERVATIONONSERVATION /1:1 $/2V r4 APPLICATION FOR SUNDRY APPROVALS AOGCG 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 214.1, Perforate 0 Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Redrill Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Prep for Deepening n 2.Operator Name: 4.Current Well Class: 5.Pemiit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development [di 185-103 3.Address: 6.API Number: Stratigraphic ❑ Service [. 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 6kc1c.ry,,,,4 50-029-21358-00-00 7.If perforating: 154,t Pee 51. 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Nlk '" 4.1/4, MPU C-15 Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL047434 Milne Point Unit/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 7,665' 7,319' 7,572' 7,231' 3768 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 105' 105' 1740 750 Surface 4,655' 9-5/8" 4,692' 4,584' 3520 2020 Intermediate Production 7,616' 7" 7,653' 7,307' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic Detail See Schematic Detail 3-1/2"/9.2# L-80 7,179' Packers and SSSV Type: 7"x3-1/2"S-3 Baker Packer Packers and SSSV MD(ft)and TVD(ft): 7,142'MD/6,825'ND 12.Attachments: Proposal Summary Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development[I Service [ ' ' 14.Estimated Date for 15.Well Status after proposed work: 6/8/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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. Contact Paul Chan ,...--------- Email pchan( hilcorp.corn Printed Name Bo York Title Area Operations Manager Signature "X7J Phone 777-8345 Date 5/9/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test 154 Mechanical Integrity Test ❑ Location Clearance ❑ Other: fr ii©ou ,S4'- " S� � ' C aCL4) 7e--1; � ,c O ) / 5 4is .r ' 7Gs-f`" Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes ❑ No 12V- !S Subsequent Form Required: t 0 --LI 0 7 RBDMS LL MAY 3 1 2016 V APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Dates —(� SL6• j oRtimpriAsta.lid Subs in Form ane Form 10-403 ised 11/2015 for 12 months from the at of approval. � Attachments in Duplicate 9143 i'iuu date �z �/ • • Milne Point Unit Well: MPU C-15 SCHEMATIC Last Completed: 4/20/1995 uu�orj��tl.�.-kr�,Ll.(, PTD: 185-103 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:17' Size Type Wt/Grade/Conn Drift ID Top Btm J I L 13-3/8" Conductor 9-5/8" Surface 48/H-40/N/A 12.559 Surface 105' 36/K-55/Btrc. 8.765 Surface 4,692' 13-318"" 7" Production 26/L-80/Btrc 6.151 Surface 7,653' + TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.867 Surf 7,179' JEWELRY DETAIL y;: No Depth Item 9 cf, 1 7,142' Baker"S-3"Packer 2 7,167' HES 2.75"XN Landing Nipple 9-5/8"4 i 3 7,179' Wireline Reentry Guide PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Status I i Kup Cl 7,226' 7,240' 6,904' 6,917' 14 Open B-silts 7,314' 7,318' 6,986' 6,990' 4 Open B-silts 7,338' 7,342' 7,009' 7,012' 4 Open Kup A3 7,410' 7,430' 7,077' 7,096' 20 Open , Kup A2 7,442' 7,468' 7,107' 7,132' 26 Open g OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt to surface , - 9-5/8" Cmt w/1,315 sx Permafrost E/250sx Class G in a 12-1/4"Hole 7" Cmt w/250 sx Class G in 8-1/2" Est TOC@ I WELL INCLINATION DETAIL 6,600' KOP @ 3,115' Max Hole Angle=29.8 deg. @ 4,772'MD t TREE&WELLHEAD Tree 5M FMC 3-1/8",API 5K w/3-1/2"8rd treetop connection Wellhead FMC Tubing Hanger w/3.5""H"BPV Profile Si 2 tii GENERAL WELL INFO API:50-029-21358-00-00 3 Drilled and Cased by AUD#3 -5/31/1985 Swap to WAG INJ by Nabors 4ES-4/20/1995 ii4t 1,1 r 10 is 5 Kew G i5� / , `? �,,:ic a Gam. .� 4 KUP Sands 7 °t TD=7,66'(MD)/TD ,319'(TVD) PBTD=7,572 D)/PBTD 7,231'(TVD) y -4- 'r 5-4-6? Created By:CJD 3/18/2016 . • Well Prognosis Well: MPU C-15 flacon,Alaska,LL Date:5/9/2016 Well Name: MPU C-15 API Number: 50-029-21358-00 Current Status: Producer Pad: C-Pad Estimated Start Date: June 8th, 2016 Rig: Doyon 14 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-103 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Current Bottom Hole Pressure: 4,124 psi @ 7,000' TVDss (Calculated BHP from SITP/ 11.3 ppg EMW) Maximum Expected BHP: 4,124 psi @ 7,000' TVDss (No new perfs being added) MPSP: 1,066 psi (SITP. Long term injector converted to producer on April 30th, 2016) Brief Well Summary: ect,51 MPU C-15 was drilled and completed with a single selectiv completion in June 1985, fracture stimulated in September, and converted to water injection in Decembe 1986. The well was worked over April 1995 in preparation for WAG injection. The well has limited utility in t a Kuparuk well and will be deepened to the Sag River formation. I Co4Gdt, ler rue 41t1`' 04, (2r474i/ 110.4 x`604A 4/r40,/-4 rrc sub;ed' Wel I t.s 54 44 4thie i/` iS nO r /1eC iv).- rU /fr,ju te._ Notes Regarding Wellbore Condition in c?C177 fro' la ;a� �rllf Fly b `k 4 nor4 �- 1,44e c eors e `kirblcCA e% - r4,t k4-0 co gat eok he, • MIT IA to 3000 psi on 05/05/2016 re doled p te;f 1(e- f k'vet 6✓9"%o1 q Objective: prvorent- de c, ion, .37A Cut tubing (pre-rig) and pull 3-1/2" completion. Mill and recover production packer in preparation to deepen the well from the Kuparuk formation to the Sag River formation. Pre-Rig Operations O ' 1. MIT-IA to 3000 psi for 30 minutes. Done S 2. Drift tubing and tag TD E 3. Cut 3-%2" tubing just above the packer(packer at 7143' MD). Establish circulation through the cut. If unable to circulate, RIH and punch tubing. Freeze protect well. S 4. Run SBHPS just prior to rig arrival to determine kill weight mud. O 5. Set BPV, remove the well house and level the pad in preparation for the rig move. Brief RWO Procedure: 1. MIRU Doyon 14. 2. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, calculate kill weight mud/brine and kill well prior to pulling BPV. Set TWC. 3. Test BOPE to 250 psi Low/4,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. .11 • • Well Prognosis Well: MPU C-15 Hilcorp Alaska,LL Date:5/9/2016 c. Test VBR ram on 3-1/2" and 4-1/2" test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. . Contingency: (If the tubing hanger won't pressure test if the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure (`) .��( c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor jv the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5. Pull TWC. Kill well with kill weight mud/fluid if needed. 6. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 7. POOH and lay down the 3-1/2" tubing to the cut. The tubing will be scrapped. 8. PU packer milling assembly and RIH on 4" DP. Mill packer and push to at least 7505' MD to get packer/tailpipe below bottom most perforation at 7468' MD. POOH and stand back DP. 9. PU packer fishing assembly and RIH on 4" DP to top of fish. fi,` 10. With mud in the hole, perform FIT to 13.0 ppg EMW. If unable to obtain 13.0 pp FIT a plan will be submitted to squeeze the Kuparuk sands. (7( 12, 4,-)44.— 0; 11. Engage fish nd POOH. 12. Stand back DP and LD fish. �I' / 13. Prepare to deepen the well as per the drilling program. ONote: The Kuparuk perforations will be hydraulically isolated behind the extended liner lap with ir casing and cement. Attachments: 1. As-built Schematic • . Roby, David S (DOA) From: Anthony McConkey <amcconkey@hilcorp.com> Sent: Thursday, May 12, 2016 11:20 AM To: Roby, David S (DOA) Cc: Paul Chan Subject: RE: Sundry Application for MPU C-15 (PTD 185-103) Hey Dave, I think we've chatted briefly in the past. I'm the Reservoir Engineer for the Kuparuk and Sag reservoirs at Milne Point, responsible for choosing the C-15 as a sidetrack candidate. To understand our decision, I'll run you through our whole thought process... Geologist Daniel Yancey and myself were tasked with drilling a Sag prospect. Given that this is Hilcorp's first Sag drill well at Milne Point,we wanted to make sure we picked a good location that really encompasses the Sag reservoir's development potential (especially since it will have to compete against Schrader and Kuparuk drill well prospects).The location we chose was essentially MPC-01's Sag location. We have proven analogous performance through offset MPC- 23 and detailed MPC-01 logs/core studies that were run through the Sag during Conoco's exploration phase—which greatly reduces our risk and uncertainty for the project. In the beginning,we heavily discussed the cost difference between a sidetrack vs.grossroots option. It became immediately evident that we could save significant costs through sidetracking to our prospect location. We originally researched and ran economics on sidetracking the producer MPC-01.Although the project was still economic with P&A'ing C-01's remaining production and reserves, upper management did not at all like the thought of shutting in a producer. So the next best well (with minimal stepout)was MPC-15i. The great thing about MPC-15i is that it's actually part of a pattern with two injectors, MPC-15i and MPC-02i. Back at BP, we would actually swap injection between the two wells to get the most out of the matured streamline patterns. So once MPC-15i is completed,we'll use MPC-02i to support MPC-14. I've researched the interaction through WAG plots (below)and can confirm that there is communication between the two wells. There is a risk that we may lose some recoverable reserves in C-24A, however, it's never really got adequate support from C-15i due to a fault separating the two—at least we've never been able to see clear evidence of communication in previous reservoir surveillance studies... We actually discovered during C-24A's sidetrack that there's another 3-4 faults between its parent bore location and current BH location,that further baffles support from offset injection. I should also mention that I think it's possible we are also getting some sweep from outside the block as the OOIP in the 237 Acre block containing C-15i,C-02i, C-14, C-24, &C-24A is approximately 13.5 MMBO(using optimistic numbers— 25% POR,45' Net pay, 28%Swi). Current cumulative production is about 6.3 MMBO, which is a 46.7%R.F.which seems a bit high. Sorry for the long e-mail! - I always prefer to be thorough in my explanations, Please let me know if you have any questions,comments or concerns! Thank you, Anthony McConkey 1 • • .Reservoir Engineer Northern Asset Team, Hilcorp Alaska 3800 Centerpoint Dr.,Anchorage,AK 99503 (w)907-777-8460 (c) 907-529-6199 Kuparuk Map A3BC1 A2 A3eC1 G A2 A3 MP -2 ,0. w V; A2 A3 C 1 A2 A3 Cl MP' Qi 11 ( A3e C1 ` 1 i ,) '''' ' ,,,,, j ./- r/ - ` ' , _-PMP -14 � - .. •ADC1 ,_ A2 A3 P ;, ,... __ A2I A31 .r.� *\ f ` f age LL--------1, 7 `� { ! _ ..I 'I Sag Map 2 _- -d6s0 !it s i o1r s s s-s v s R 1-111kis •k s.— a...'T do ■ ! - llyv _,' O -cpm S `-4` ` - „ co -4,4%. Nilip. 6 \/ I LPcYI.NT U , /\ 0 , . ...... , -, i ,. .„ ., ., -- -- "r , .,,,...., /INN '''‘Z"4,\-, \' \ \ ' . O9 - c9100 . ¢, f - 8950 °0 \ y o . . 0n - ' .,� -8880 _ if ;lei%74604;p0 0 0 '''"---.„..___\.:\v___ . _7 . ..._ -1.-----"---..\ N .01 (7441111 :: is -- -� trill;-:3. -(9,9 6b ,40 ':5,:,:. '''' ``-- 920.218 ��,: Q III • Qty 70 t9 ` 'A. 767 =2t, �pO O .9�p �TY '.23. C01 Y / Er-7;i �, �tj ASO, SO. � �`-�_ t� �! s(J `cQ, w,--* ' .Prop -15i\ '- �'` . - -,1 0 ,® 8 r So * _ Co ' -*.\ Pry, i MPC-02i & MPC-14 WAG Communication 3 . • • Voidage Replacement Ratio w/ SBF _ 0 2000 0 � - 2 a ~ 0 0. i % i w i' d /f,,� ,f ..� _ ___ —. _ $ % 1 i s �15 :'/' J IV " r “ffl , 1, , , •.; „1 0 __ , . iii: / , 1 L „ . ' ' i .. _ , d,. , .:% i 1 111 _ i _ , 0 i --, , . ,., . ./ ;i i r :; 97 99 2090 01 02 03 04 05 45 07 0a 4 Date Slide from January Drill Well Presentation 4 C-I 51 Kuparuk Pattern January 12,2O1 • Active injector supporting producer MPC-14 • Do not see any support to MPC-24 due to multiple faults • C-14 currently has two supporting injectors, 0 � . a allowing for injection support without C-15i rA2 . v b1 f r • 226 MBO Recoverable Reserves in C-14 — Estimated based on 8%/yr observed decline - — 80 bopd cut-off F • Injected 12.9 MMBW �. — 12.91 18.68 = 0.69 PV Injected y' Ililc•c From: Paul Chan Sent: Thursday, May 12, 2016 9:57 AM To: Anthony McConkey Subject: RE: Sundry Application for MPU C-15 (PTD 185-103) 5 . • Anthony Please revert to Dave about C-15 utility. Thanks for the help Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) From: Roby, David S (DOA) [mailto:dave.roby0alaska.gov] Sent: Wednesday, May 11, 2016 5:09 PM To: Paul Chan Subject: Sundry Application for MPU C-15 (PTD 185-103) Paul, In looking at the injection history for this well it appears that the well has been a pretty steady injector for quite some time. Can you please expand on why Hilcorp believes this well has"limited utility in the Kuparuk"? Thank you, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby a?alaska.gov. 6 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert to Producer 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: iHilcorp Alaska LLC Development ❑ Exploratory ❑ 185-103 3.Address: Stratigraphic❑ Service ❑✓ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21358-001REr.F ivED 7.Property Designation(Lease Number): 8.Well Name and Number: ADL047434 MPU C-15 MAY 1 1 2016 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Unit/Kuparuk River Oil Pool (�"� w, 11.Present Well Condition Summary: CC Total Depth measured 7,665 feet Plugs measured N/A feet true vertical 7,319 feet Junk measured N/A feet Effective Depth measured 7,572 feet Packer measured 7,142 feet true vertical 7,231 feet true vertical 6,825 feet Casing Length Size MD TVD BurstCollapse Conductor 80' 13-3/8" 105' 80' 1,740psi �� 750psi Surface 4,655' 9-5/8" 4,692' 4,584' 3,520psi 2,020psi Production 7,616' 7" 7,653' 7,307' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/Btrc 7,179' 6,860' Packers and SSSV(type,measured and true vertical depth) 7"x3-1/2"S-3 Baker N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1,617 940 2,880 Subsequent to operation: 0 0 290 400 504 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL El Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-245 Contact Paul Chan ` Email pchan@hilcorp.com Printed Name Bo York Title Operations Manager Signature !" ,/f G Phone 777-8345 Date 5/10/2016 yt_fl/c1 A —7I/4 i Form 10-404 Revised 5/2015 RBDMS \." MAY 1 1 2016 Submit Original Only • . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-15A N/A 50-029-21358-00-00 185-103 4/29/16 5/1/16 Daily Operations: 4/27/2016-Wednesday No activity to report. 4/28/2016-Thursday No activity to report. 4/29/2016- Friday MPC-15 blinded off from water/gas injection. Rigged up for temporary flowback through MPC-14 flowline. 4/30/2016-Saturday Flowing to production header. FTP dropped from 1103 to 378 psi flowing 860 BPD. 5/1/2016-Sunday Passing AOGCC witnessed waived SVS test. 5/2/2016- Monday No activity to report. 5/3/2016-Tuesday No activity to report. 0 Milne Point Unit • Well: MPU C-15 .11 SCHEMATIC Last Completed: 4/20/1995 Ilileorp Alaska,LLC PTD: 185-103 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:17' Size Type Wt/Grade/Conn Drift ID Top Btm t a 13-3/8" Conductor 48 H-40 N A 12.559 Surface105' / / / / '' 9-5/8" Surface 36 K-55 Btrc. 8.765 Surface 4,692' 13-3/8"" 7" Production 26/L-80/Btrc 6.151 Surface 7,653' TUBING DETAIL k 3-1/2" Tubing 9.2/L-80/IBT 2.867 Surf 7,179' s'' JEWELRY DETAIL o .,, No Depth Item I 1 7,142' Baker"S-3"Packer 2 7,167' HES 2.75"XN Landing Nipple 9-5/8"'m k 3 7,179' Wireline Reentry Guide ( PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT I Status Kup Cl 7,226' 7,240' 6,904' 6,917' 14 Open B-silts 7,314' 7,318' 6,986' 6,990' 4 Open B-silts 7,338' 7,342' 7,009' 7,012' 4 Open Kup A3 7,410' 7,430' 7,077' 7,096' 20 Open Kup A2 7,442' 7,468' 7,107' 7,132' 26 Open OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt to surface 9-5/8" Cmt w/1,315 sx Permafrost E/250sx Class G in a 12-1/4"Hole 7" Cmt w/250 sx Class G in 8-1/2" Est.TOC@ ' WELL INCLINATION DETAIL 6,600' KOP @ 3,115' : Max Hole Angle=29.8 deg. @ 4,772'MD 11 TREE&WELLHEAD Tree 5M FMC 3-1/8",API 5K w/3-1/2"8rd treetop connection '' Wellhead FMC Tubing Hanger w/3.5""H"BPV Profile 1 4€ r ,t 2 ', GENERAL WELL INFO t API:50-029-21358-00-00 3 Drilled and Cased by AUD#3 -5/31/1985 Swap to WAG INJ by Nabors 4ES-4/20/1995 t, v 0-KUP Sands , tr TD=7,665(MD)/TD=7,319'(TVD) PBTD=7,572'(MD)/PBTD=7,231'(TVD) Created By:CJD 3/18/2016 • OFT • • •\� yy� � THE STATE Alaska Oil and Gas • F�, ���;\ OfA TAsKA Conservation Commission _ 333 West Seventh Avenue -40;7_ i GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *'* Main: 907.279.1433 OF ALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Area Operations Manager �� t , Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-15 Permit to Drill Number: 185-103 Sundry Number: 316-245 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this Aay of April, 2016. RBDMS v/ APR 2 9 2016 RECEIVED • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 1 2016 APPLICATION FOR SUNDRY APPROVALS 4-( M. 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Convert to Producer Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑ 185-103 • 3.Address. Stratigraphic ❑ Service ❑, 6.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 50-029-21358-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O 432C Will planned perforations require a spacing exception? Yes ❑ No 0 MPU C-15 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL047434 • Milne Point Unit/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,665' ` 7,319' 7,572' 7,231' 1850 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 105 80' 1740 750 Surface 4,655' 9-5/8" 4,692' 4,584' 3520 2020 Intermediate Production 7,616' 7" 7,653' 7,307' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic Detail See Schematic Detail 3-1/2"/9.2# L-80 7,179' Packers and SSSV Type: 7"x3-1/2"S-3 Baker Packer Packers and SSSV MD(ft)and TVD(ft): • 7,142'MD 16,825'TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 4/27/2016 Commencing Operations: OIL Q , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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. Contact Paul Chan e.` Email pchan�x hilcorp.com Printed Name Bo York Title Area Operations Manager /7 Signature t ! Phone 777-8345 Date *u 'f t;A Z1Z k h COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Ue. - 24-{5 Plug Integrity ❑ f/ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: * J V .. - .;1 ? (f- �t.tJt�t, fi-8-- 7.---.5 !64-c-z s . z-`.. 6- 0") Post Initial Injection MIT Req'd? Yes ❑ No ❑ AA Spacing Exception Required? Yes ❑ No VSubsequent Form Required: /0_ (--to ( RBDMS �'v ANR L 9 2016 APPROVED BY Approved by: RINA COMMISSIONER THE COMMISSION Date:0 isinForm 10-40eved11/2015 valid for 12 months from the to of pro al. Attachments in Duplicate .n • Hilcorp Alaska, LLC Post Office Box 244027 RECEIVED Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 APR 21 2016 Anchorage,AK 99503 AOGCC Phone: 907/777-8300 April 20, 2016 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Conversion of Milne Point Well C-15 (PTD 185-103) from Injector to Producer Dear Chair Foerster: Attached for your approval is Form 10-403 to convert the above referenced well from injector_to producer in order to reduce the pressure in the Kuparuk sands. Hilco Alaska would li, - • . er the Ku.aruk reservoir .ressure .rior o ee.enin_ the . - . th . The well would be tied into and flowed back through the production system and reported as per our normal procedures. If you need any additional information,please contact Paul Chan at 907-777-8333. Sincerely, B ork Operations Manager 3- co h CU,. • Milne Point Unit • Current Schematic Well: MPU C-15 Last Completed: 4/20/1995 Mean)Alaska,LLC 185-103 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:17' Size Type Wt/Grade/Conn Drift ID Top Btm id i,,, .t 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 80' 9-5/8" Surface 36/K-55/Btrc. 8.765 Surface 4,692' 13-3/8- 7" Production 26/L-80/Btrc 6.151 Surface 7,653' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.867 Surf 7,179' JEWELRY DETAIL No Depth Item 1 7,142' Baker"5-r Packer 2 7,167 HES 2.75"XN Landing Nipple 95/8 • 3 7,179' Wireline Reentry Guide PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Status Kup Cl 7,226' 7,240' 6,904' 6,917' 14 Open B-silts 7,314' 7,318' 6,986' 6,990' 4 Open B-silts 7,338' 7,342' 7,009' 7,012' 4 Open Kup A3 7,410' 7,430' 7,077' 7,096' 20 Open Kup A2 7,442' 7,468' 7,107' 7,132' 26 Open OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt to surface 9-5/8" Cmt w/1,315 sx Permafrost E/250sx Class G in a 12-1/4"Hole 7" Cmt w/250 sx Class G in 8-1/2" Est.TOC@ WELL INCLINATION DETAIL 6,600 KOP @ 3,115' Max Hole Angle=29.8 deg. @ 4,772'MD c; TREE&WELLHEAD Tree 5M FMC 3-1/8",API 5K w/3-1/2"8rd treetop connection Wellhead FMC Tubing Hanger w/3.5""H"BPV Profile <a ►i , f 2 . GENERAL WELL INFO API:50-029-21358-00-00 3 * Drilled and Cased by AUDI#3 -5/31/1985 I Swap to WAG INJ by Nabors 4ES-4/20/1995 f 4, 1 4' tF KUP Sands T 777 7":a 11/ TD=7,665(MD)/TD=7,319'(TVD) PBTD=7,572'(MD)/PBTD=7,231'(TVD) Created By:CJD 3/18/2016 • S Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, November 16, 2015 10:26 AM To: Wallace, Chris D (DOA); Alaska NS - Milne - Wellsite Supervisors Cc: Regg, James B (DOA); Stan Porhola; Alaska NS - Milne - Field Foreman Subject: RE:Injector MPC-15 (PTD # 1851030) Monitoring Results Attachments: MPC-15 TIO.xlsx All, MPC-15 (PTD# 1851030) returned to injection on 10/21/15 following repacking of the production casing packoff test void. An AOGCC witnessed MIT-IA was obtained on 10/28/15.The well has exhibited no further IAxOA tracking and will remain on injection. A TIO plot is attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Scot4ED MAY 1 ? 2016 Il 1, .ep 1iaau. I.14 From: Wyatt Rivard Sent: Tuesday, October 20, 2015 9:29 AM To: 'Wallace, Chris D (DOA)' Cc: 'Regg, James B (DOA)'; 'Brooks, Phoebe L (DOA)' Subject: RE: Injector MPC-15 (PTD # 1851030) Return to Injection Chris, Shut-in WAG injector MP PTD# 1851030) failed a production casing packoff void test at 1500 psi on 10/17/15.The packoff test void was then repac - with plastic packing and successfully tested to 5000 psi.The well had a passing pre MIT-IA to 1922 psi on 10/19/15 (attache. Going forward, we would like to return the well to injection and monitor the OA for 28 days to determine if there is any fur - tracking. Please confirm if the plan forward is acceptable. Plan Forward—Operations. 1) Return well to injection. Once online and stable,ensu - .t least a 500 psi differential between IA and OA. 2) Monitor OA for 28 days for signs of tracking with IA 3) Obtain AOGCC witnessed MIT-IA, well is due for 4 year MIT-IA by ' 10/15.Test to at least 1800 psi, ensuring 500 psi differential between TBG and IA. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • • • ... . ars 0 0 al.111.1•Mmam........ Lel <7. c . . .. 111111=11 ... 1 0 LeN ... CO 6 1111 : 45 cc = CL E c .i 5 411 ' 1,1 .-1 CZ/ eN1 -._ Cr; CD I- I ) 7.>"... .. r . t J • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,November 09,2015 P.I.Supeervisor ' � 1�Zd� �� SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-15 FROM: Johnnie Hill MILNE PT UNIT KR C-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry :Tam'-- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR C-15 API Well Number 50-029-21358-00-00 Inspector Name: Johnnie Hill Permit Number: 185-103-0 Inspection Date: 10/28/2015 Insp Num: mitJWH151029112841 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-15 - ;Type Inj W- TVD 6826 - Tubing 2651 • 2651 • 2650 " 2650 - PTD 1851030 Type Test SPT Test psi 1706 ' IA 1180 - 2020 • 1991 - 1980 , Interval j4YRTST IP/F P / OA 414 501 - 504 505 - 1 Notes: .7 bbls of diesel , SCANNED SEP 1 6 2Q16 Monday,November 09,2015 Page 1 of 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, October 20, 2015 2:27 PM To: 'Wyatt Rivard' Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA) Subject: RE:Injector MPC-15 (PTD# 1851030) Return to Injection Wyatt, Approved for up to 28 days monitoring and plan forward as proposed below. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue SCANNED APR 0 8 2016 Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wyatt Rivard [mailto:wrivard@ hilcoro.com] Sent: Tuesday, October 20, 2015 9:29 AM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L(DOA) Subject: RE: Injector MPC-15 (PTD # 1851030) Return to Injection Chris, Shut-in WAG injector MPC-15 (PTD# 1851030)failed a production casing packoff void test at 1500 psi on 10/17/15.The packoff test void was then repacked with plastic packing and successfully tested to 5000 psi.The well had a passing pre MIT-IA to 1922 psi on 10/19/15 (attached). Going forward, we would like to return the well to injection and monitor the OA for 28 days to determine if there is any further tracking. Please confirm if the plan forward is acceptable. Plan Forward—Operations. 1) Return well to injection. Once online and stable, ensure at least a 500 psi differential between IA and OA. 2) Monitor OA for 28 days for signs of tracking with IA 3) Obtain AOGCC witnessed MIT-IA, well is due for 4 year MIT-IA by 12/10/15.Test to at least 1800 psi, ensuring 500 psi differential between TBG and IA. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 1 • • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, October 16, 2015 4:38 PM To: Wallace, Chris D (DOA); Alaska NS - Milne - Wellsite Supervisors; Alaska NS - Milne - Field Foreman Cc: Schwartz, Guy L (DOA); Regg, James B (DOA); Stan Porhola; Anthony McConkey Subject: Injector MPC-15 (PTD # 1851030) Possible IA x OA communication Attachments: MPC-15 TIO.xlsx All, WAG injector MPC-15's(PTD# 1851030) IA and OA appear to be tracking suggesting possible IA x OA communication. The well will be SI and remain SI until further diagnostics/remediation are complete. A TIO plot is attached for reference. Path Forward—Operations 1) Shut-in well and freeze protect. 2) Test production casing packoff seals.Attempt to reenergize if failed. 3) Perform pre MIT-IA to 1800 psi. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 LtA: U APR 0 8 2016 1 0 • O 0 O I, CD tfl o C 0 1111 I 1 tom. U-10 N 1I 0 O C O v C Zi:, 4.7 \ q Q i •-•lel `/ O 1 Q V 0 Y CC I d E Ilif C H W p N co O X 4(''al?'-'5". V, O N h O O O O O O O tano LA", O in N N ti ...4 WELL HISTORY FILE COVER PAGE XH V zs This page identifies oversize material and digital information available for this individual Well History fiJe and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this fiJe. ¡8S /03 Well History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # [I Diskettes - # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # 0 Mud Logs # - 0 Other # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this fiJe. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1215 if you have any questions or in fOllTlation requests regarding this tile. i ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, December 20, 2011 TO: Jim Regg ; � 1 \ t 31 I v P.I. Supervisor �/ I I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C -15 FROM: Jeff Jones MILNE PT UNIT KR C -15 Petroleum Inspector Src: Inspector Reviewed By:� P.I. Supry ,6C.., NON- CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR C - 15 API Well Number: 50 029 - 21358 - 00 - 00 Inspector Name: JeffJones Insp Num: mitJJ111219110449 Permit Number: 185 - 103 - Inspection Date: 12/10/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C - 15 Type Inj. W TVD 6826 ' IA 560 2020 ' 2020 -- 2030 ' 2000 1980 - P.T.D 1851030 ' TypeTest SPT Test psi 1706 - OA 320 480 510 540 520 510 Interval 4YRTST P/F P • Tubing 2800 2800 2800 2800 2800 2800 Notes: 0.9 BBLS diesel pumped. 1 well inspected; no exceptions noted. ' SCALP 1 C 201 Tuesday, December 20, 2011 Page 1 of 1 ~ STATE OF ALASKA ~ ` ALAS IL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ gRIGHT WATER Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. N 4. Current Weil Class: 5. Permit to Driil Number: j% ame: De~lopment r Exploratory ~ 185-1030 / 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: / Anchorage, AK 99519-6612 50-029-21358-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 52 KB MPC-15 ~ 8. Property Designation: 10. Field/Pooi(s): ADLO-047434 / MILNE POINT UNIT Field/ KUPARUK RIVER SANDS Pool 11. Present Well Condition Summary: §- Y~ . .. ~ / Total Depth measured 7665 feet Plugs (measured) None ~ i~/ ; ~j <F V. i ~ ~• true vertical 7319.81 feet Junk (measured) None ° Effective Depth measured 7561 feet ' true vertical 7221 feet Casing Length Size MD TVD Burst Collapse Conductor 80 13-3/8" 48# H-40 SurFace - 1115 Surface - 115 1740 750 Surface 4643 9-5/8" 36# K-55 SurFace - 4692 Surface - 4584 3520 2020 Production 7732 7" 26# L-80 32 - 7652 32 - 7307 7240 5410 ,,~ ~ r ~, y .~ ,~~`~:. u . ,~... , . ' ~' ~ ~. ,. PerForation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 SURFACE - 7179' 0 0 ~ Packers and SSSV (type and measured depth) 7"X3-1/2" S-3 BAKER PACKER 7142'~---~ .~ e C ~, t r 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or fnjection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1139 2256 Subsequent to operation: 1174 2244 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory r Dev~elopment ~ Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas I~ WAG ~ GINJ ~ WINJ T~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/10/2009 Form 10-404 vised 04/2006 -~ ~ . , , ,-, ~f _' ,Subm~ igi~~ ly •'`4 '~~, ~~"~ ~F t ~ ti LE.;U:i `d~. ~S ° ~ l~ M PC-15 185-103 PERF ATTACHMENT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-15 5/31/85 PER 7,226. 7,240. 6,904.08 6,917.17 MPC-15 5/31/85 PER 7,314. 7,318. 6,986.53 6,990.29 MPC-15 5/31/85 PER 7,338. 7,342. 7,009.09 7,012.86 MPC-15 5/31/85 PER 7,410. 7,430. 7,077.05 7,095.99 MPC-15 5/31/85 PER 7,442. 7,468. 7,107.36 7,132.04 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ • MPC-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/21/09 - 8/9/09 ! Bright Water pump operations. Began EC9360A (surfactant) pre-flush injection ~on 7/21/09 with a water injection rate of 1342 BWPD and iniection pressure of 2299 si. Began EC9378A (polymer) injection on 07/24/09 with a water injection rate 12 8 BWPD and injection pressure of 2203 psi. Finished pumping EC9378A 08/08/09 with a water injection rate of 1139 BWPD and iniection ;pressure of 2256 ~si_ Finished pumping EC9360A on 08/09/2009 with a water 'injection rate of 1174 BWPD and iniection pressure of 2244 psi. Total EC9378A ~ injection volume 13986 gallons. Total EC9360A injection volume 4567 gallons. 08/05/08 sue" ~ ~~`~~IIIfGM~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall _Inh fF N0.4812 Company: State of Alaska ~~ ~ , D~~~ A~ ~ ~ .k ~(~t~ Alaska Oil & Gas Cons Comm iL+' Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 .... nwww ..t:.... n~~~ e~ P1-03 12021163 MEMORY SBHPS 06/11/08 1 MPC-15 12066534 MEM INJ PROFILE / 07/19/08 1 1 L-205 12061697 MDT (SUMMARY PRINT) 05/26/08 1 1 L-205 12061697 MDT ~ 05/26/08 1 1 04-22A 12005220 MEMORY LDL G -. 07/26/08 1 1 H-22A 11968956 SBHP SURVEY ~ ~ 07/28/08 1 1 C-37A 12005221 MEMORY CBL 07/28/08 1 1 ~~ .-~... ~.. ~~............ ~.. . ... v..wn...v .+nv n.-. vn..n.v v~~c ~rvr ~ c'+~n : v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Stre t, Suite 0 Anchorage, AK 9 3-28 ATTN: Beth Received by: a • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission ,.-1 DATE: Tuesday, December 18, 2007 To: Jim Regg ~ (~!~/ u P.I. Supervisor ~ r ~( ~ / SliBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-15 FROM: Jp]m Crisp MILNE PT [JNIT KR C-15 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~J ~- Comm Well Name• MILNE PT UNIT ICR C-15 API Well Number: 50-029-21358-00-00 Inspector Name• John Crisp Insp Num: mitJCr071213193156 Permit Number: 185-103-0 ~ Inspection Date: 12/12/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ Well j c-'s Type Inj. j w TVD 6sz6 /~ IA ~ sso ~ zzzo ~ ~ ztso zvo ~ ~ p T ~ Iasto3o ~TypeTest ~ sPT i Test psi ~ I7o6.s OA ~ 400 ~ soo ~ soo ~ soo ~ Interval aYRTST p~F P ~ Tubing ~ noo I I7oo ~ t7oo ~t 700 NOtes• 1.3 bbl's pumped for test. ~~,, ~i, tt ~~~~ C~~y~' . ~~tr.~ J~lV )n ~ ~ 10D~ Tuesday, December 18, 2007 Page I of 1 ( WELL LOG TRANSMITTAL \ 8S~' \03 ŒPSII. ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 MP G-15i 2-4-2004 Res. Eva!. CH Ir9LJlr 1 1 . . Mech. CH 1 Caliper Survey Signed: ~\~'9~0^<ì REŒ' F~' ",1,:",,"'4 ',-. J ..-,' I._...~" LJ Date: Print Name: j~'GasC ,tl¡~'~!I~m-n J\r: .. I .~ ._-, {i-õ,tPli) C'\) fY¡ 2"OA ~.,..~~/;'"' :'- ".1 :..~\..~.i~~ :I,! r ~ D LCJ ~ tJ 'Lj ;~.~..,..,~:: '" " t..._-,.' t.¡.~ PRoAcTivE DiAGNOSTic SERviCES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~ .. '" ~ýVl~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: July 20, 2003 Commissioner -.-~ ..... '~' ~,{.~:~/ SUBJECT: Mechanical I nteg rity Test THRU: Ton:~Mau~ler ~-.~.~"( BPX P.I. Supervisor MPU C Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL P.T.D. Notes: P.T.D. Notes: Well P.T.D. Notes: P.T.D. Notes: P.T.D. Notes: 'Packer Depth Pretest Initial 15 Min. 30 Min. I C-15 I s I T.V.D. 16825 I Tubing 12650 12650 12650 12650 I lntervall 4 I ITy"e "i'I p ITestpsil 4706 I CasingI 900 I 21001 207Sl 20751 P/F I E I 185-103 IType test I Isi I,,,erv ,l 4 I 185-296ITypetestl P ITestpsil 2030 I Casingl 0 I 2200 I 2160 I 2160I P/F IPI I Type test IType Inj. Type test Type Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU C Pad and witnessed the routine 4year MIT on wells C-15 and C-19. The pretest tubing and casing pressures were observed and found to be stable. The pressure tests were then performed for 30 minutes with the both wells demonstrating good mechanical integrity. M.I.T.'s performed' 2 Number of Failures: 0 Attachments: Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. 2003-0720 MIT MPU C-19 cs.xls 7/23/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _X WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4553' FNL, 2098' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 4800' FNL, 600' FEL, Sec. 10, T13N, R10E, UM At effective depth 4885' FNL, 506' FEL, Sec. 10, T13N, R10E, UM At total depth 4887' FNL, 473' FEL, Sec. 10, T13N, R10E, UM 5. Type of Well: Development _ Explorato~_~ Stratigraphic__ Service_X (asp 's 558365, 6029010) (asp's 559866, 6028775) (asp's 559962, 6028692) (asp's 559993, 6028688) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Miline Point Unit MPC-15 9. Permit number / approval number 185-103 10. APl number 50-029-21358-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4643' Production 7732' 7665 feet Plugs (measured) 7319 feet 7561 feet Junk (measured) 7221 feet Size Cemented Measured Depth True Vertical Depth 13-3/8" 100 cf Cement 115' 115' 9-5/8" 2500 cf Cement 4692' 4584' 7" 290 cf Class 'G' 32' - 7652' 32' - 7307' Perforation depth: measured Open Perfs 7226' - 7240', 7314' - 7318', 7338' - 7342', 7410' - 7430', 7442' - 7468' true vertical Open Perfs 6904' - 6917', 6986' - 6990', 7009' - 7012', 7077' - 7096', 7107' - 7132' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tubing @ 7179' MD. 7" x 3-1/2" S-3 Baker Packer set @ 7142'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 10/10/2002 Subsequent to operation 10/20/2002 OiI-Bbl Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl 2122 1250 Casing Pressure Tubing Pressure 3121 2090 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG Injector 17. I hereby certify that the foregoing i~s true and correct to the best of my knowledge. .,~-~~ .~~~~'~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · RBD IS BFL Date November 11, 2002 Prepared b~/DeWayne R, Schnor! 564-5174 SUBMIT IN DUPLICATE MPC-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS O3/03/2OO2 O5/O3/2OO2 O6/07/2OO2 O9/O4/2OO2 10/19/2002 11/10/2002 03~03/02 05/03/02 06/07/02 09/04/02 10/19/02 WAG SWAP FROM GAS TO WATER INJECTION WAG SWAP FROM WATER TO GAS INJECTION WAG SWAP FROM GAS TO WATER INJECTION WAG SWAP FROM WATER TO GAS INJECITON WAG SWAP FROM GAS TO WATER INJECTION TESTEVENT --- INJECTION PRESSURE, PSI: 2,313 TYPE: PW VOL: 142 BWPD. EVENT SUMMARY HB&R PUMPED 10 DIESEL DOWN THE TUBING AND 2 BBLS OF DIESEL DOWN THE FLOWLINE TO FLUSH THE NGL's FROM THE LINE. WELL SUPPORT TECHS SWAPPED BLINDS AND TORQUE TO SPEC. HB&R RIGGED UP AGAIN AND PUMPED 10 BBLS METHANOL, 88 BBLS SOURCE WATER AND THEN 5 BBLS METHANOL. PUMPED FROM I TO 2.5 BPM FROM 3400 TO 2900 PSI. JOB WAS COMPLETED WITH NO PROBLEMS AND TURNED OVER TO OPERATOR TO PUT ON INJECTION. PJSM. BLED DOWN AND SAFED OUT SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUE FLANGES TO SPEC. MIRU HB&R PT'd TO 3500 PSI. PUMPED 2 BBLS METHANOL DOWN THE FLOW LINE AND 20 BBLS DOWN THE TUBING @ I BPM. 1800 TO 2500 PSI. RDMO. PUT ON INJECTION AT 3000 MCFPD. PJMS. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUE FLANGES TO SPEC. MIRU HB&R. PT'd TO 4800 PSI. PUMPED 80 BBLS SOURCE WATER AND 10 BBLS METHANOL, 3500 TO 3300 PSI @ 1.5 TO 2.0 BPM. RDMO. PUT WELL ON WATER INJECTION AT 2400 BWPD. PJSM. BLED DOWN AND SAFED OUT SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUE FLANGES TO SPEC. MIRU HB&R PT'd TO 3500 PSI. PUMPED 2 BBLS METHANOL DOWN THE FLOW LINE AND 20 BBLS DOWN THE TUBING @ I BPM. 1800 TO 2500 PSI. RDMO. PUT ON INJECTION AT 2000 MCFPD. PJMS. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUE FLANGES TO SPEC. MIRU FESCO. PT'd TO 4800 PSI. PUMPED DOWNTHE TUBING 5 BBLS METHANOL AT 1.5 BPM, 3700 TO 3500 PSI. SWITCHED TO SOURCE WATER. PUMPED 75 BBLS AT 1.8 BPM, 3500 TO 2800 PSI & 5 BBLS METHANOL @ 1.6 BPM, 2800 PSI. RDMO. WELL WAS CONVERTED TO WATER AND PUT ON INJECTION @ 3000 BWPD. DEC .l. 8 200Z, Page I MPC-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/10/02 WELLEVENTS --- INJECTION PRESSURE, PSI: 2,313 TYPE: PW VOL: 142 BWPD. FLUIDS PUMPED BBLS DISCRIPTION 79 METHANOL 243 SOURCE WATER 12 DIESEL 334 TOTAL Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __ Exploratow__ Stratigraphic__ Service__X 4. Location of well at surface 4553' FNL, 2098' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 4800' FNL, 600' FEL, Sec. 10, T13N, R10E, UM At effective depth 4885' FNL, 506' FEL, Sec. 10, T13N, R10E, UM At total depth 4887' FNL, 473' FEL, Sec. 10, T13N, R10E, UM (asp's 558365, 6029010) (asp's 559866, 6028775) (asp's 559962, 6028692) (asp's 559993, 6028688) 12. Present well condition summary Total depth: measured true vertical 7665 feet Plugs (measured) 7319 feet Perforate _ Other_X WAG SWAP 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Miline Point Unit MPC-15 9. Permit number / approval number 185-103~ 10. APl number 50-029-21358-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands Effective depth: measured true vertical 7561 feet Junk (measured) 7221 feet Casing Length Conductor 80' Surface 4643' Production 7732' Size Cemented Measured Depth True Vertical Depth 13-3/8" 100 cf Cement 115' 115' 9-5/8" 2500 cf Cement 4692' 4584' 7" 290 cf Class 'G' 32' - 7652' 32' - 7307' Perforation depth: measured Open Perfs 7226' - 7240', 7314' - 7318', 7338'- 7342', 7410'- 7430', 7442'- 7468' .... i 1 i i.- true vertical Open Perfs 6904' 6917', 6986' 6990', 7009' 7012', 7077' 7096, 7 07,-7t32,,,~ i~ ",: Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tubing @ 7179' MD. Packers & SSSV (type & measured depth) 7" x 3-1/2" S-3 Baker Packer set @ 7142'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/25/2002 Subsequent to operation 02/03/2002 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 1695 1766 Casing Pressure Tubing Pressure 2565 3257 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant DeWayne R. Schn~'rr . Form 10-404 Rev 06/15/88 · Date February 27, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE MPC-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/28/2OO2 01/28/02 WAG SWAP FROM WATER TO GAS INJECTION EVENT SUMMARY PJSM. SAFED OUT AND BLED DOWN SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUED FLANGES TO SPEC. MIRU HB&R. PT'd TO 4600 PSI. PUMPED 2 BBLS DOWN THE FLOW LINE TO FREEZE PROTECT AND 20 BBLS DOWN THE TUBING AT 1.3 BPM @ 3000 PSI. RDMO. FLUIDS PUMPED BBLS DISCRIPTION 22 METHANOL 22 TOTAL Page 1 . . MEMORANDUM State of Alas ka Alaska Oil and Gas Conservation Commission TO: Dan Seamount, 0.7:) DATE: July 12, 2000 Commissioner 0 //ey-bc~ THRU: Blair Wondzell, @~ P. I. Supervisor .9'1(00 FROM: ~t!¡ Jeff Jones .-" SUBJECT: Safety Valve Tests Petroleum ' I sp ct!'r Milne Point Unit B & C Pads JulV 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap a-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 JvK>,- r.z..~~+- 21 well houses were inspected, no failures. - -r Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-]2-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test n.eport Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 ~ ,/ ::.r:'~;('~{¡:~'WðïiiJãtâ ' . \ " ' ~" .. " Pilots "':: ;:~n;.\!~~»:,~ "~." ItSl~~.''-' "S~\~:/ ,~~~'~'~t ~~~ ;':f. 0.~'~~. .~, '~YelrTyþe'.'", : r . I," Well Permit Sepal' Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GJNJ, GAS or CYCLE . @...Ol"',¡j\./,;:,,/ 1811430 140 100 95 P P OIL {: . . .' . :,t..~:'. . ,- C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 ]980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG 12 Conzponents: 23 Failures: 6 Failure Rate: 26.00/0090 Day We lis: Rcmarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these itelns corrected. 8/7 lOa Page 1 of 1 V] v7irqrn.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change to WAG Injector 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 724' NSL, 2098' WEL, SEC. 10, T13N, R10E At top of productive interval 4800' SNL, 600' WEL, SEC. 10, T13N, R10E At effective depth 4885' SNL, 506' WEL, SEC. 10, T13N, R10E At total depth 4832' SNL, 403' WEL, SEC. 10, T13N, R10E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-15 9. Permit Number / Approval No. 85-103 95-056 10. APl Number 50-029-21358 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 7665 feet true vertical 7319 feet Effective depth: measured 7561 feet true vertical 7221 feet Casing Length Structural Conductor 80' Surface 4643' Intermediate Production Liner 7732' Size 13-3/8" 9-5/8" Plugs (measured) Junk (measured) Cemented 100 cuft cement 2500 cuft cement 7" 290 cuft cement MD TVD 115' 115' 4692' 4584' 32'-7652' 32'-7307' Perforation depth: measured true vertical 7226'- 7240', 7314'-7318', 7338'-7342', 7410'-7430', 7442'- 7468' 6904'-6917', 6986'-6990', 7009'-7012', 7077'-7096', 7107'-7132' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 TO 7180' Packers and SSSV (type and measured depth) Baker 'S-3' packer at 7143' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure O?,i6!h!AL RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. Prior to well operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 15. Attachments 116. Status of well classifications as: [] Copies of Logs and Surveys run I [] Oil [] Gas [] Suspended [] Daily Report of Well Operations 17. I hereby certify that the for.,.egoing is trueCnd correct to the best of my knowledge Tim Sc~ofield Title Senior Drilling Engineer Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Service Water & Gas Injector Date o0.- ! ~t - q~':' Terrie Hubble, 564-4628 Submit In Duplicate BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPU C-15I BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/13/95 10:00 SPUD: RELEASE: 04/20/95 04:30 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 04/13/95 ( 1) TD: 7653 PB: 7572 MOVING RIG MW: 0.0 SCOPE DOWN AND LD DERRICK. MOVE PIPE SHED, PITS, AND SUB BASE TO C-15I. 04/14/95 ( 2) TD: 7653 PB: 7572 04/15/95 (3) TD: 7653 PB: 7572 04/16/95 ( 4) TD: 7653 PB: 7572 CIRC & WT UP BRINE MW: 0.0 SPOT RIG MODULES ON C-15I. RAISE DERRICK. RU MUD LINES AND FLOWLINE. SCOPE UP DERRICK. DRESS HERCULITE AROUND MODULES AND TANKS. ACCEPT RIG @ 1000 HRS 04/13/95. PULL BPV W/ LUBRICATOR. RU AND PUMP OPEN SSSV. CIRC WELL TO 11.6# BRINE. RETURNS TO FLOW TANK UNTIL 11.3% RETURNS. CIRC THRU GAS BUSTER TO PITS. HIGHEST WT SEEN WAS 11.4#. BULLHEAD 15 BBLS DOWN TBG. BLED OFF TO FORMATION. BLED OFF PRESSURE. MONITOR WELL. CIRC AND RAISE WT TO 11.5+%. MONITOR WELL. SLIGHT FLOW. CIRC AFTER PULLING HANGER MW: 0.0 CONTINUE CIRC AND WT UP TO 11.6#. SHUT IN. CONTINUE CIRC AND WT UP TO 11.7#. MONITOR WELL, OK. RU LUBRICATOR AND SET TWC. ND TREE. BREAK DOWN BOP STACK. CHANGE OUT MUD CROSS. NU BOPE. TEST BOPE. RU LUBRICATOR AND SCREW INTO HANGER. PULL TWC. RD LUBRICATOR. MU LANDING JT. BOLDS AND ALIGNMENT PIN. PULL HANGER TO FLOOR. PULLED 10K OVER TO STING OUT OF PACKER. RU TO CIRC. CIRC HOLE VOLUME. REVERSE CBU BY FISH MW: 0.0 FINISH CIRC WELLBORE AFTER UNSTING F/ PACKER. MONITOR WELL, OK. L/D 3.5" TBG AND SSSV. RECOVERED 132 SS BANDS. CUT 84' AND SLIP 42' DRLG LINE. FINISH LD 3.5" TBG AND BOT SEAL ASSEMBLY. INSTALL WEAR RING. RU TO RUN 3.5" DP. LOAD PIPE SHED. MU FTA #1. RIH W/ 3.5" DP F/ PIPE SHED. CBU. LATCH FISH @ 7060'_ BLED OFF JARS. STRAIGHT PULLED TO 100K OVER. JARRED @ 70K OVER. JARRED LOOSE. PU WT 125K. REVERSE CBU. WELL : MPU C-15 OPERATION: RIG - NABORS 4ES PAGE: 2 04/17/95 ( 5) TD: 7653 PB: 7572 04/18/95 ( 6) TD: 7653 PB: 7572 04/19/95 ( 7) TD: 7653 PB: 7572 04/20/95 (8) TD: 7653 PB: 7572 RIH W/ SPEAR MW: 0.0 FINISH REVERSE CBU. MONITOR WELL, OK. POH SLOW, FISH DRAGGING. LD FTA %1 AND FISH. RECOVERED EVERYTHING ABOVE LOWER PACKER. STRAP AND MU FTA %2. RIH ON 3.5" DP TO 7322'. MILL PKR F/ 7353 - 7355'. PACKER DROPPED. CBU. CIRC GAS OUT THRU GAS BUSTER. PUSH PKR DOWN TO 7420'. CIRC XANVIS SWEEP AROUND. MONITOR WELL, OK. POH. LD MILL AND JUNK BASKETS. MU FTA %3. START RIH. NU SHOOTING FLANGE MW: 0.0 SERVICE RIG. FINISH RIH TO 7400'. CBU. SPEAR FISH @ 7420' PULL FREE W/ 25K OVER. MONITOR WELL, OK. POH. LD PACKER AND TAIL PIPE ASSEMBLY. STRAP AND MU BHA %4. RIH TO 7400' CBU. WASH AND REAM F/ 7440 - 7567' STARTED TAKING PIT GAIN. CHECK WELL, FLOWING. NO PRESSURE. CIRC THRU CHOKE. TOOK APPROXIMATELY 20 BBL GAIN. ON BOTTOMS UP, WT CUT TO 10.6% W/ SMALL AMOUNT OF GAS. WT BACK UP TO 11.7%. MONITOR WELL, OK. POH. ND FLOWLINE AND RISER. NU SHOOTING FLANGE. RUNNING COMPLETION MW: 0.0 FINISH NU SHOOTING FLANGE. RU ATLAS. TEST LUBRICATOR T/1500 PSI. OK. MADE 3-PERF RUNS W/4" ALPHA JET GUNS LOADED W/4 SPF. TIE-IN T/SCHLUMBERGER DIL/SFL/GR DATED 5/28/85. RUN %1:7442 T/7470; RUN %2 7410 T/7430 & RUN %3 F/7226 T/7240. LOST 8 BBLS WHILE PERFORATING. RD ATLAS. ND PERF FLANGE. NU RISER & FLOWLINE. RIH W/DP & DC T/4570. SLIP 42' DL. CONTINUE T/RIH T/7160. RU & REVERSE CIRC. LD DP & DC. PULL WEAR RING. PU BAKER S-3 PACKER & TAIL PIPE ASSY. START RIH ON 3.5", 9.3%, L-80, EUE 8RD MOD TBG F/PIPE SHED. RELEASE RIG MW: 0.0 RIH WITH BAKER 'S-3' PACKER AND 225 JTS 3 1/2" 9.3% L-80 TBG 8RD EUE. M/U FMC HANGER AND LAND TBG. RILDS. SET TWC AND NIPPLE DOWN BOP AND NIPPLE UP ADAPTER FLG AND TREE, TEST. REVERSE CIRC 135 BBL SOURCE H20 TREATED WITH COREXIT AND FOLLOW WITH 55 BBL DIESEL AND BULL HEAD 17 BBL 60/40 MECH DOWN TBG. DROP PKR SETTING BALL AND SET PKR. TEST BACK SIDE OF PKR. RIG DOWN LINES TO TREE AND SET BPV AND SECURE TREE. RELEASE RIG @ 0430 HRS ON 04/20/95. SIGNATURE: (drilling superintendent) DATE: RECEIVED AUG I 6 1996 Alaska Oil & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501 . Date: 24 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 6406.01 Run # 1 6409.01 Run # 1 6410.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return Petrotechnteal-Data Center BP Exploration (Alaska) 900 East Benson Boulevard Aneh_~ra~e, Alaska 99508 MAY 0 4 1995 _. ~m~1~- Alaska 0ii & Gas C~ns. Commis~ion ~nchora~e 'LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear-Sir/Madam, Reference: Date: RE: 13 April 1995 Transmittal of Data ECC #: 6406.00 Sent by: PRIORITY MAIL Data: CCL MPC-15 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 CCL FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s i~n a~nd ~etu~-n ~! Petrctechnical Data Cente~ BP Expicration (Alaska) ~00 East Benson Boulevard ~L~r a ~e ~..~ aska~ 99508 APR 2 0 1995 -~as~ Oil &'~g"Oons. Oommission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 725' NSL, 2098' WEL, SEC. 10, T13N, RIOE Operation Shutdown __ Re-enter suspended well .__ Plugging_ Time extension __ Stimulate__ Pull tubing x Variance__ Pedorate__ Other X Change status 6. Datum elevation (DF or KB) KBE = 52' feet 5. Type of Well: Development Exploratory Stratigraphic __ Service x 7. Unit or Property name Milne Point Unit 8. Well number MPC- 15 At top of productive interval 9. Permit number 4800' SNL, 600' WEL, SEC. 10, T13N, RIOE At effective depth At total depth 4832' SNL, 403' WEL, SEC. 10, T13N, RIOE O. iGiNAL 12. Present well condition summary Total depth: measured 7764 feet true vertical 7400 feet 85-103 10. APl number 50- 029-21358 11. Field/Pool Milne Point- Kuparuk Sands Plugs (measured) Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 80' 13-3/8" 100 cuft cement 115' 4643' 9-5/8" 2500 cu ft cement 4676' 7732' 7" 290 cuft cement 32'-7764' measured 7410'-7430', 7226'-7240', 7314'-7318', 7338'-7342', 7442'-7468' true vertical 7077'-7096', 6904'-6917', 6986'-6990', 7009;7012', 7107'-7132' Tubing (size, grade, and measured depth) 3-1/2", L-80 butt. tubing to 7407' MD True vertical depth 115' 4600' 32'-7400' Rrcc£1V D Gas Cons. Comm~ssiol Anchora ° Packers and SSSV (type and measured depth) BOT 'HB'packer @ 7089'; Camco TRDP-1A SSSV @ 1904' MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 4/30/95 16. If proposal was verbally approved Oil__ Gas __ Name of approv/~/. Date approved Service Water Injector 17. I hereby certif/C'~a~Lthe f~regoing is true/and correct to the best of my knowledge. / "" ' ' ? Title Drilling Engineer Supervisor Signed / '~/ -- FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended Date Conditions of al~proval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- Z/O/¢ Original Signed By Approved by order of the Commission David W, Johnston /Approval Approved Colby Returned Commissioner Form 10-403 Rev 06/15/88 Date 3/12,-~/~'(~'~- SUBMIT IN TRIPLICATE MI-' C-15i RWO SUNDRY INFORMATION Objective' The objective of this workover is to convert C-15i from water to WAG injection well with new 3-1/2" 9.2# L-80 EUE AB-Mod tubing and a 7" latch type packer. The existing straddle assembly will also be retrieved, to optimize the injection rate, during this RWO. The C pad WAG is critical for fulfilling future MPU gas disposal requirements and 5 mmcfd of gas injection capacity is needed from MP C-15i. Scope' , Pre- rig: Obtain a static pressure survey w/ Amerada gauges after ceasing injection. Chemical cut the straddle assembly @ 7,220'MD (+/-20' below MMG-2 GLM @ 7,201'MD) for fishing operation. Punch two 3/4" holes @ 7,064'MD (+/-10' above BOT PBR @ 7074') for well kill operation. Record SITP and SICP. Install BPV. Remove wellhouse and flowline for Nabors 4ES rig move. . MIRU Nabors 4ES workover rig. Perform well kill operation before ND tree and NU BOP. . Pull existing 3.5" 9.2# L-80 BTC tubing w/one GLM and seal assembly. Retrieve the straddle packers assembly. Clean out wellbore to PBTD. . Perform wireline conveyed perforations at Kuparuk sands, see attached perforating guideline for the proposed perforation intervals. . RIH with 7" latch type packer on new 3-1/2" 9.2# L-80 AB-MOD tubing and standard 3-1/2" tailpipe. , Freeze protect the well before setting the tubing packer. ND BOP and NU tree. RDMO Nabors 4ES. Timing- Nabors 4ES will be making a pad to pad move from G-08A to C-15i on approximately 4/30/95. This workover should take approximately 13 days rig time. MIRU / Kill well/ND_NU 2 days Pull 3-1/2" old tubing and L/D same 2 days Fish Straddle assembly 6 days (Note: the fishing operation may encounter similar problem as MP C- 09 for retrieving the straddle packer--BOT "2-B" packer) Cleanout wellbore 1 days Complete well w/3-1/2" new tubing 2 days Total: 13 days DH, March 19, 1995, 12:38 PM MAR 2.5 i995 Oil & Gas Cons. O0mmissi0r~ Anch0ra" Milne Point Unit C Pad WAG Conversion Wells C-15i, C-17i & C-19i Perforating Guidelines Atlas - Use 4" Alpha Jet 4 spf guns, 90°phasing, 32 gram RDX charge, .5" EHD, 32" TTP Well Perforation Intervals (MD) Feet of Perfs C-15i 7,226. - 7,240' 14' 7,410' - 7,430' 20' 7,442' - 7,470' 28' total 62' C-17i 10,855' -10,870' 15' 11,040' -11,058' 18' 11,073' -11,108' 35' total 68' C-19i 11,478' - 11,498' ' 20' 11,738' - 11,764' 26' 11,780' - 11,820' 40' 11,866' - 11,876' 10' total 96' .o RECEIVED MAP, 2 3 1995 Oil & Gas CoDs. CommissioD N6~S: 1. ALL MEASUREMENTS ARE FROM KDB OF ALASKA UNITED #3 KDB - SL = 52' KDB - GL = 35' 2. MAX. ANGLE = 29.8' @ 4772' MD K.O.P. = 311-5' 4. SLANT HOLE: YES 5. MIN. ANGLE = NA 6. TREE TYPE: FMC 3. 1/8" APl 5000# WITH 3 1/2' 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS CAMCO 'D' NIPPLE @ 7398' (2.75" ID) 8. COMPLETION FLUID: 10.2 PPG NoCI-NoBr ... 9. FRACTURE STIMULATION: 8-31-85 LK-2 43,000 LBS. 16-20 ISP (SCREENED OUT) WELL No. C-15 COMPLETION SKETCH MILNE POINT UNIT (I) APl No.: 50-029-21358 '=,- PERMIT No.: 85-103 COMPLETED: 5/31/85 LAST WORKOVER: N/A FMC TUBING HANGER W/ 3 1/2' 'H' BPV PROFILE ~3 1/2', 9.2# L-80 BUTTRESS TUBING (2.992" I.D., 2.867" DRIFT) 1904' CAMCO TRDP-IA SSA SSSV (2.812" ID) MAR 2 3 1995 OJJ & Gas Cons. 6ommls,~ion Anchora ,. PERFORATIONS: 12 SPF, 120' PHASING, 5" GUNS (ALL DEPTHS FROM OIL LOG 5-28-85) MK-1 7226'-7240' MD 6904'-6917' TVD L-8 7314'- 7318' MD 6986'-6990' TVO ,.. L-9 7338'-7342' MD 7009'-7012' TVD LK-2 7442'-7468' MD 7107'-7132' TVD 4 SPF, 0' PHASING, 2 1/8" GUNS (ALL DEPTHS FROM DIL LOG 5-28-'85) LK-I 7410'- 7430' MD 7077'- 7096' TVD CONOCO INC. ANCHORAGE DIV1SION ~7074' 7089' 7127' 7161' 7201' ~7240' BOT PBR, SEAL ASSEMBLY BOT 'HB' PACKER (2.89" ID) CAMCO 'W-l' SELECTIVE NIPPLE (2.812" ID) CAMCO 'MMG-2' GAS LIFT MANDREL 2.92" ID, 1.5' VALVES CAMCO 'MMG-2' (;AS LIFT MANDREL 2.92" ID, 1.5" VALVES BLAST JOINT (19,80' TOTAL LENGTH) 7375' BOT LOCATOR, SEAL ASSEMBLY 7374' BOT '2-B' PERMANENT PACKER (5.875' OD, 4.0' ID) WITH MILLOUT EXTENSION 7398' CAMCO 'D' NIPPLE (2.750" ID) 7407' TUBING TAIL - 7653' 7" 26# L-80 BTRS (6.276' ID, 6.151" DRIFT) APPROVED BY: HDS DATE: 03/17/92 DRAFTED BY: SJN CAD FILE: WCOC15 MPU C-15i Proposed Completion FMC Tubing Hanger w/3-1/2' ~i 'H' BPV profile.' Conductor13'3/8" 48# H-4Ocasing 1105' MDIJ ii' ' I Tree: FMC 3-1/8", APl 5K i [ w/3-1/2" 8rd treetop J L '- connection i ~ KDB-SL 52' '~, KDB-GL 35' 9-5/8" 36# K-55, BTRC 14,692, MD [ 'j' ' Surface Casing KOP @ 3,115' Max Hole Angle: 29.9° @ 4,772' MD 3-1/2" Threaded L-80 Tubing AB-MOD connections 9.3 ppf, 2.992" i.d. Completion Fluid - x.xx ppg STIMULATION SUMMARY 43K# 16/20 ISP - 8/31/85 Lower Kup (2) - (screened out) Latch Type Packer I 7,150, MD ( i.d. · tbg i.d.) Camco'O'Nipple I7'155'MD I []iLPERFORATION SUMMARY (2.75' i.d.) REF: LOG: DIL 5/28/85 Tubing Tail w/WLReent~, I7'160'MD I SIZE SPF INTERVAL OPEN/SQZ'D GuiOe 5" 12 7226' - 7240' open 120° (6904' - 6917') 5" 12 7314'- 7318' open ~ ~ 120° (6986' - 6990') -- -- 5" 12 7338' - 7342' open , · _ _ 120° (7009' - 7012') ---- -' 5" 12 7442' - 7468' open i 120° (7107' - 7132') _----~ 2-1/8"! 4o0 7410'-7430' Ii open ~ . DATE REV. BY COMMENTS MILNE POINT UNIT 3/9/94 DKW COIvIPLETION DATE WELL C-1 5i WORKOVER DATE APl NO' 50-029-21358 BP EXPLORATION (AK) STATE OF ALASKA ALAS,,,~ OIL AND GAS CONSERVATION COMMI,~,~ON APPLICATION FOP, SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend ._ ,= Alter casing __ Repair well Change approved program Operation shutdown __ Re-enter suspended well Plugging__ Time extention __ Stimulate__ Pull tubing Variance x.. Perforate__ Other 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development Exploratory Stratigraphic Ser,xice X 4. Location of well at surface 725' FSL, 2098' FEL, Sec. 10, T13N, R10E, U.M. At top of productive interval 4867' FNL, 612' FEL, Sec. 10, T13N, R10E, U.M. At effective depth 4885' FNL, 506' FEL, Sec. 10, T13N, R10E, U.M. At total depth 4890' FNL, 473' FEL, Sec. 10, T13N, R10E, U.M. 12. Present well condition summary Total depth: measured 7665' feet true vertical 7319' feet Effective depth: measured 7561' feet true vertical 7221' feet Casing Length Size Plugs (measured) Junk (measured) Cemented 6. Datum elevation (DF or KB) 59' KDB 7. Unit or Property name Milne Point Unit 8.Well number C-15 9.Permit number 85-103 10. APl number 50-029-21358 11. Field/Pool Kuparuk River Field RECEIVED NOV 2 6 1991 Alaska .Oil & Gas Cons. ,~_mn~i~ Measured ~te qrrue vertical depth Structural Conductor 80' 13-3/8" Surface 4656' 9-5/8" Intermediate Production 7618' 7" To Surface 115' 115' 250 sx Class G 4692' 4584' 1315 sx Permf E 250 sx Class G 7652' 7307' Uner Perforation Depth: measured 7226-7240', 7314-7318', 7338-7342', 7410-7430', 7442-7468' true vertical 6904-6917', 6986-6990', 7009-7012', 7077-7096',7107-7132' feet Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", L-80, 7407' CAMCO TRDP-1A SCSSV @1904';BOT HB Pkr @7089', 2B Pkr @7374' 13. Attachments Description summaryof proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation N/A 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service Watedlood Injector 17. I hereby ce~rtifythat t~fe foregoing is true and correct to the best of my knowledge. I/I. Signed \..../I~ //'~/~)~ J.H. Andrew Title Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Date Nov 19, 1991 ORiGi~"~)AL S!GNED BY : ~fl~,~,~!~ C. SNI1TH Commissioner Form 10-403 Rev 08/15/88 SUBMIT IN TRIPLICATE Milne Point Unit C-15 Well The MPU C-15 well is an active water injection well. Pressure on the 3-1/2" x 7" production tubing-casing annulus is currently 2570 psig. This is in excess of the 500 psig maximum pressure guideline established by the Commission for continuous operation of injection wells. Conoco requests a variance to allow injection to continue while diagnostic work is performed. This work is necessary to determine the exact source of pressure communication in the water injection wells. Multiple attempts have been made to control the annulus pressure in the C-15 well by bleeding it off. The pressure can be bled to 500 psig in 15 minutes with less than 2 barrels of fluid extracted. However, annular pressure returns to previous levels almost immediately. There has been no apparent improvement in either the build rate or final build-up pressure. The wellhead has also been tested. All seals were determined to be holding. This indicates the source of the pressure is downhole mechanical communication rather than thermal or ballooning effects. Three similar B-Pad water injectors have been worked over within the past four months to resolve similar annular pressure problems. New tubing strings were run in all three wells to eliminate the possibility of leaks due to corrosion and to replace the buttress thread connections with 8rd threads. New packer/'S~al assemblies were also run in two wells to ensure any leaking production seals would be isolated. Workovers in two wells, MPU B-14 and MPU B-17, were successful. Annular pressure has re-appeared in the third well, MPU B-12. It is not known why workovers were successful in the B-14 and B-17 wells, and not in the B-12 well. It is recommended that remedial work to resolve annular pressure in this well be deferred until the exact source of the communication in the B-12 well is determined. Our current plan is to run additional logs the B-12 well to isolate the leak. This information should enable us to design a workover program to successfully eliminate annular pressure in this well the first time rather than by trial and error. Additional testing is being planned in the interim period to reconfirm annular fluids are not in communication with uncased hole. We will continue to keep the Commission informed of the results of all testing. STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION 1. Type of Request: Abandon__ Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging __ Time extention __ Stimulate Change approved program Pull tubing X Variance __ Pedorate X Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development__ 59' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit Service x 4. Location of well at surface 8. Well number 725' FSL, 2098' FEL, Sec. 10, T13N, R10E, U.M. C-15 At top of productive interval 9. Permit number 4867' FNL, 612' FEL, Sec. 10, T13N, R10E, U.M. 85-103 At effective depth 10. APl number 4885' FNL, 506' FEL, Sec. 10, T13N, R10E, U.M. 50-029-21358 At total depth 11. Field/Pool 4890' FNL, 473' FEL, Sec. 10, T13N, R10E, U.M. Kuparuk River Field ,. ~ ,L ,~ ~. '~; 12. Present well condition summary. ~ · /~ Total depth: measured 7665' feet Plugs (measured) true vertical 7319' feet .. Effective depth: measured 7561' feet Junk (measured) ~'~:~ ' ~: true vertical 7221' feet ;i ,:;.~ ~,~. ;~;;-~.;.~ !~':-";~' '~'"*'--"-~: .... Casing Length Size Cemented Measured depth .... ~ True vert ca depth Structural Conductor 80' 16" TO Surface 115' 115' surface 4656' 9-5/8" 250 sx Class G 4692' 4584' Intermediate 1315 SX Permf E Production 7618' 7" 250 SX Class G 7652' 7307' Liner Perforation Depth: measured 7226-7240', 7314-7318', 7338-7342', 7410-7430', 7442-7468' true vertical 6904-6917', 6986-6990', 7009-7012', 7077-7096',7107-7132' Tubing (size, grade, and measured depth) 3-1/2", L-80, 7407' Packers and SSSV (type and measured depth) CAMCO TRDP-1A SCSSV @1904';BOT HB Pkr @7089', 2B Pkr @7374' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: February 1991 16. If proposal was verbally approved Oil ~ Gas Suspended Name of approver Date approved Service Waterflood Injector 1,., oe ,, ,,.,/,e ,rue .n, ,o ,,e o, m, Si~ned (.~,AAj /' ~r~ J.H. Andrew Title Production Engineer Date 12/'08/90 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness [^pprovai No. ~ Plug integrity B~/l'est __ Location clearance ~ -" ~) Mechanical Integrity Test .,'× Subsequent form required 10- ./-' ORIGINAL SIGNED BY ^pprovea LONNIE C, SMITH Returned Approved by order of the Commission " ~ / ' commissioner Date APPL1'CATTON FOR SUNDRY APPROVALS SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 MPU C-15 Workover - Reperforate to Access LK-! ]n.iection Zone Procedure Summary 1. Monitor SITP to determine reservoir pressure. 2, , t MIRU workover rig on well. Kill well with NaBr/NaC1 brine (density determined by SITP). ND tree, NU and test BOP's. PU to release from Brown Oil Tools PBR assembly at 7074'. Circulate hole full of kill weight fluid. POOH and LD 3-1/2" production tubing. TIH with overshot/grapple BHA to Brown Oil Tools PBR above HB retrievable packer at 7089'. Latch PBR stinger and release packer. POOH and LD PBR stinger, packer, and isolation tubing. . . PU packer milling/pulling BHA and TIH to Brown Oil Tools 2B permanent packer at 7374'. Latch packer and mill slips. POOH wi th packer and tailpipe assembly. GIH with 5" perforating guns and reperforate the LK-1 sand 7412'-7430' DIL. Reperforate the L-8 lobe at 7314'-7318' and the L-9 lobe at 7338'- 7342'. . TIH with full bore retrievable packer on drillpipe and set near 7380' (below L-9 perforations). Circulate down source water and establish injection into LK-1 and LK-2 sands. Allow injection to stabilize. 8~ RU electric line. GIH with production logs while injecting source water and confirm LK-1 is taking fluid at an acceptable rate. NOTE' Additional work will be required if measured injectivity is insufficient. 9. Kill well. Release retrievable packer and POOH. 10. PU permanent packer and 3-1/2" tailpipe with wireline nipple and re-entry guide. GIH on electric line and set packer at 7360'. POOH with setting tool and RD electric line. 11. PU isolation assembly for MK/L-8/L-9 perforations consisting of production seals, 3-1/2" gas lift mandrels, and wireline nipple below retrievable packer/PBR assembly . TIH on 3-1/2" production tubing pinned to packer PBR. 12. Sting into permanent packer at 7360'. Space out, land hanger. RU wireline and set tu_b__i_~g~~ug_in__nipple below packer. Set retrievable packer near 7075' . 13. ND BOP's. NU and test tree. 14. 15. RU slickline. GIH and pull tubing plug and dummies mandrels. RD slickline. ~.i. Return well to waterflood injection service. /"kILNE POINT UNIT E-t5 CO/ PLETED ON 5-31-85 r~ T1.B]~ ~ V/3 I/2' 'H' ~ R~[LE I ~ -% ,52' I'~- 6t.., 35' AAX. AN6LE, 29.8 ,,1772' I,~, 3115' TF~ETEP CEIIECI iON ~1 IqC).: ~-029-21358 CO,¥LET[ON FLUID , lB.2 PPG N, od~ 12 ~, 12B Pi-~lt,13 5' L-8: 7314-7318' tO tX-2: S2F, 0 R'IkSi~ I/8 F'RACTLI~- ~-2 43.0~ lbs. 3 I/2' 9.2' L'~ BUTTRESS 1984' CA/O) I ID ' 2.992) li;~P'IA SSA ~ I ID ' 2.812~ 71)'74' BOT PE~. SEAL AS.SEtS_Y 7889' BDT '~' P~ I ID, 2.89 ) 7127' r_A/'09. 'V-.I.' .... 5ELECl IVE NIPPLE lID, 2,812) 7161 ' CN'i~ 'AAG-2' 6t.A ( ID ' 2.921 T241)' B.~T ,..ELINT 119.75'i V/LEEAER "-4-- 7398' CAr(Z) 'D' NIPPLE 12.75 ID) 741~" l~lhl3 TAIL :'S61' TOP CF FiLL IVII:;ELI)£ 6/29/t'8) 7572' PSTD ?653' 7' ~ L-Sg BI'RS. (6.276 lO, 6.151 ~IFfl 7/25/90 4293 SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY · AK OIL, & GAS CONSERVATION COMMISSION LOCATION · 3001 PORCU]~INE DR. ATTENTION · JOHN BOYLE COMPUTING CENTER PRINT CENTER WELL NAME .V~'MILNE POINT UNIT C--6 SERVICES . 1 PL ADVISOR REPJORT WELL NAME :VMILNE POINT UNIT C-8 SERVICES · 1PL ADVISOR REPORT NO. OF BOXES: ALL IN ONE BOX JOB NO. · 73975 ADD'L TAPES · -- WELL NAME SERVICES · ;/MILNE POINT UNIT C-12 . 1 PL .ADVISOR REPORT NO. Of BOXES' ALL IN .ONE BOX JOB NO. · 73974 ADD'L TAPES · -- WELL NAME ~/MILNE POINT UNIT C-ll SERVICES · 1 WF/PL ADVISOR REPORT NO. OF BOXES' ALL IN ONE BOX JOB NO. · 73959 ADD'L TAPES · -- WELL NAME · MILNE POINT UNIT C-18 SERVICES · 1 PL ADVISOR REPORT JOB NO. · 73951 -ADD'L TAPES · -- Alas~ SCHLUMBERGER COURIER: DATE DELIVERED: NO. OF BOXES' ALL IN ONE BOX JOB NO. ' 73973 ADD'L TAPES · -? WELL NAME ~ MT',~LNE POINT UNIT C-15 SERVICES ' 1 WF/PL ADVISOR REPORT NO. OF BOXES: ALL IN ONE BOX JOB NO. ' 73946 ADD'L TAPES ' -- I. GEORGE'S COURIER SERVICE 1824 S.2 I 344-3323 FROM "'" ,,- .~ -"7 ,.,.,,. ~ .,.,, - . STATE ZIP DATE ;//,.-.,,i'/"/"~,j TIME t' --', ,"[ L-, ~P STATE' ZIP ADDRESS CITY ADDRESS ~:~' ~ C:: /' CITY ~[~ 24 HOUR CASE NO. COURT DOCUMENTS SAME DAY 'FI P/U BY 3PM _. . ONE HOUR $ SAME DAY $ 24 HOUR $ OTHER $ TOTAL $ [] ONE,HOUR RECEIVED BY i DATE / TI ME i $CHLU~IBERGER WELL SERVICES JUL ~ ~ ~ggg m~u~~ WELL Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc, 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention'_ Marc Shannon Gentlemen: Enclosed ore2 JlL_prints of the. Compony CONOCO, Inc. Well MiIne ?OfLnt Urdt C-15 FL,Run ~ro7~0½~/9_0 3ect~on I~og, Run 1,_6~_/_90 FieJd MJlne Point Additio~o! prints ore bei.ng sent to: 1 BL ~rints COI~OCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb -_OF 2018 PER Count y _2ina:J:J:~S ~o_pe_~ Store __l_RL__pr;nts , 1 R¥ Sepia CO,~OCO_, Thc ~ 1000 South Pine Alaska Ponca City, OK 7a603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc, ~ Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5600) I BLprints, 1 RF Sepia __Chevron ~.S.A, .. _6OO1 Bol!Jnger Canyon Road _~an ~aIg_Q~ CA 945_~-0943 _At t n: ?r~cil!a MacLeroy ~& Gas Conservation 3001Pc~cupine Drive . Anchorage, AK 99501 ' ttn: John The film isJ~eturned to Log Library. We appreciate the privilege of serving you. prints prints _ ~nrints Received by; Date: Very truly yours ...... SCH L U M BE'RGE'R"WEE !~( ARCO Alaska, Inc. Date: September 30, 1988 Transmittal #: 7307 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-11 1E-06 3J-10 3C-11 3C-11 Kuparuk Well Pressure Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey 9 - 2 2 - 8 8 Amerada 9 - 2 5 - 8 8 Casing 9 - 2 5 - 8 8 Casing 8 - 1 3 - 8 8 Amerada 8-13-88 Receipt Acknowledged' DISTRIBUTION: D&M State of Alaska SAPC Unocal Chevron Mobil Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 56zr-7600 May 29, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: ~nclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. C-13, C-14, C-15 and B-13. If you require additional information concerning this well history, please contact Don Girdler at 564-7637. Yours ve~r_~~ E. D. Wilson Sr. Administrative Coordinator DRG/vv C-13, C-14, C-15, B-13 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.13- CONFIDENTIAL (7,380'-Kuparuk River) AFE 10-61-1115 AP1 No. 50-029-21348. Ak. Permit No. 85-93. Elevation: 59' KB. Location: 532' FSL, 979' FWL, Sec. 18, T13N, RILE, Umiat Meridian 5-16-85: ACCEPT RIG. NU hydril & diverter line. Mix spud mud. Strap & PU BHA. Service & orient MWD. Test hydril to 200 psi. Drill from 105' to 330'. Surface pressure loss of 700 psi. POOH from 330'. Check for washout. Change bit. TIH to 330'. Drill & survey 330' to 660'. 5-17: Drill & survey 660' to 1427'. Reaming 1305' to 1427'. Drill & survey 1427' to 1579'. Ream 1489' to 1579'. Drill & survey 1579' to 2019'. 5-18: Drill & survey 2019' to 3324'. Pump pill. TOOH from 3324'. Change BHA. TIH to 3324'. Drill & survey 3324' to 4197'. 5-19: Drill & survey 4197' to 6076'. Bit failed. Pump pill. Short trip 6076' to 3036'. Circ. & cond. hole. Start out of hole from 6076'. SLM. 5-20: Continue TOOH. Service & lay down MWD. RU Gearhart. RIH to 3000' w/GR-SP-DIL-CNS-CDL. DIL failed @ 3000'. POOH & replace DIL. Log w/GR-SP-DIL; CNS-CDL; 2500' to 6072'. Lay down logging tools. PU side wall core guns. RIH w/side wall coreguns. Cores taken @ 5588'-5589'; 5625'-31'; 5664'-70'; 5682'-88'; 5833'-39'; 5933'-39'. ATT: 41; Rec. 35; Lost 3; Misfire 2; Empty 1; Lay down guns. RD Gearhart. TIH to 2189'. Slip & cut drlg line. TIH to 6076'; hit bridge @ 3914'. Drill 6076' to 6147'. Circ. & cond. mud. TOOH from 6147' w/D.P. & H.W.D.P. 5-21: Lay down BHA. RU to run csg. Run 9 5/8" 36# K-55 buttress csg, 156 jts. PU fluted mandrel hanger w/pup jt and landing jt. Land csg., float shoe @ 6127' and float collar @ 6044'. RU cementing head. Full returns running pipe. Circ. 9.7 ppg mud while recip, pipe w/15' strokes. Pump 40 bbl 11 ppg Zeogel sweep; 829 bbls 12.2 ppg Arctic Set III w/4 lb/sk Gilsonite; 57 bbls Class "G" 15.8 ppg w/3% NaC1; 0.2% D-46. Displace w/467 bbls 9.7 ppg mud. Bump plug w/2100 psi. Floats held. Lost returns w/60 bbls of cement left to pump. Lay down landing jt, cementing head. ND hydril. RU to do top job. Pump 14 bbls Arctic Set I @ 15.8 ppg. Install speed head w/16000 ft. lb. torque. Install BOP stack. 5-22: NU BOP stack. Install test plug. Test BOP stack to 5000 psi, Hydril to 3500 psi, choke manifold to 5000 psi, upper & lower Kelly, inside BOP & ball valve to 5000 psi. Function test accumulator system. Test witnessed by Doug Amos AOGCC. Remove test plug. Install wear bushing. PU BHA. Service & orient MWD. Test Navidrill. TIH to 6044'. Test csg. to 1500 psi. Drill out float equip & cmt; 34' of new hole to 6181'. Perform mud weight equivalent test. Drill & survey 6181' to 6814'. --1-- · Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.13- CONFIDENTIAL (7,380'-Kuparuk River) AFE 10-61-1115 AP1 No. 50-029-21348. Ak. Permit No. 85-93. Elevation: 59' KB. Location: 532' FSL, 979' FWL, Sec. 18, T13N, RilE, Umiat Meridian 5-23: Drill & survey 6814' to 8730'. 5-24: Drill & survey 8730' to 9832'. 5-25: Drill & survey 9832' to 10,168'. Navidrill failed. Pump pill. TOOH from 10,168'. Lay down Navidrill & MWD. Change bit. Start in hole w/D.P. 5-26: Continue TIH to 10,068'. Ream from 10,068' to 10,168'. Drill from 10,168' to 10,522'. Drop single shot survey tool. Pump pill. TOOH from 10,522'. Change bit. TIH w/pipe to 1700'. Slip & cut drlg line. 5-27: TIH to 10,492'. Ream from 10,492' to 10,522'. Drill from 10,522' to 10,727'. Short trip to 9727'. Circ. & cond. mud. Drop single shot survey tool. Pump pill. TOOH from 10,727'. RU Gearhart. Log w/GR-SP-DIL; 10,730' to 6127'; CN-CD-Caliper 10,730' to 7865'. RD Gearhart. TIH w/BHA & ~DP. 5-28: Continue TIH to 10,727'. Circ. & cond. mud. POOH. Lay down DP & BHA. Remove wear bushing. Change top rams to 7". RU to run csg. Running 7" 26# L-80 buttress csg. Broke Circ. @ 4800' & 8000'. 5-29: Continue running 7" 26# L-80, 265 jts of csg. PU landing jt & hanger w/packoff. NU cementing head, float shoe @ 10,461', float collar @ 10,379', bottom packer @ 10,332', top packer @ 10,273', RA marker @ 9985'. Full displacement returns while running csg. Circ. 430 bbls 10.4 ppg mud. Pump 40 bbl Desco sweep 8.4 ppg; 58 bbl 15.8 ppg Class "G" cement w/0.8% D-60; 0.25% D-13; 0.2% D-46; 396 bbls 9.6 ppg NaC1 brine. Inflate packers w/2700 psi. Floats held. CIP, full returns. RD Dowell. Lay down landing jt. RU Camco. Run Gyro survey 10,300' to surface. Run CCL-CR; log 10,330' to 9900'. RD Camco. Pressure test csg. to 2000 psi, 30 min. RU to run completion string. PU & run Geo-Vann 5" guns, 12 JSPF, 30' loaded. BOT HB production packer, tbg 3½" 9.2# L-80 buttress. Gas lift mandrels & SSSV. Still running in hole @ report time. 5-30: Run 321 jnts of 9.2#/ft L-80 buttress tbg. RU & run GR & CCL w/Camco. Land hanger, displace tbg w/il0 bbls diesel. Close circ. vent. Set packer, open production vent. Test SSSV w/1000 psi, test packer w/1500 psi. Unseat hanger & attempt to shear out PBR. Original string wt - 95,000 lbs. PBR calculated shear - 56,000 lbs. Attempt to shear w/60,000 lbs to 90,000 lbs over string wt. Press. tbg w/2000 psi. Close SSSV, PU 80,000 lbs. over string wt. Packer released. -2- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.13- CONFIDENTIAL (7,380'-Kuparuk River) AFE 10-61-1115 AP1 No. 50-029-21348. Ak. Permit No. 85-93. Elevation: 59' KB. Location: 532' FSL, 979' FWL, Sec. 18, T13N, RILE, Umiat Meridian 5-30 cont'd.: Reverse circulate w/9.6 ppg brine. RU to POOH. POOH & LD packer & PBR. Packer release pins sheared. RIH w/prod, vent open. LD damaged jnts. Space out, due to new pipe lengths. Land hanger, test control line to 5000 psi. RU Otis wireline to set Camco standing valve in D-nipple & inflate packer. 5-31: RU & RIH w/Otis to set standing valve in D-nipple. Slickline counter indicating D-nipple to be 24' too deep. POOH test tbg & valve to 500 psi. Wait on wireline unit to verify depth of packer & guns. RU & RIH w/GR & CCL. Packer & guns found to be 1½' below desired depth. Packer @ 10,088'. Top shot @ 10,184'. POOH, RD Camco. RU & press, up on tbg. to 2500 psi to inflate packer. Test packer w/1500 psi, unlock hanger. Shear out PBR w/53,000 lbs over string wt. RU & displace tbg. thru PBR w/diesel. Stab into PBR & test SSSV. RIH & retrieve standing valve. POOH. ND BOP. NU tree & test tree & valves to 5000 psi. RD. RELEASE RIG. Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 March 5, 1987 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Chatterton: Production Profile Logs for Wells B-10; B-Ii; C-9; C-13; C-14; C-15; C-16 Included with this cover letter are the logs and related pressure data for production profile work completed at Milne Point prior to shutdown. This information is submitted to the State as per Rule 9 of the Kuparuk River Field RUles. If you should have any questions or comments, please contact Mr. Don Girdler at 564-7637. Division Manager DRG/vv Oil & Gas Cons. 6~mmission AP.~,h3rc, ge Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Miine Point Unit. There are 19 active and 5 inactive production wells at Milne ?tint. AC/IVE: B-3, B-4A, B-6, B-9, B-i0,~ B-li,~_ x-~_ ~, B-_~l%, x-~6,_ ~ C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-i£, C-!6 STATIC: C ~8 B-20, B-21, B-22 C-17, -~ Ail active production wells will be freeze protected by disp!ac°-~z~s tne~ top 3000' of the tubing with a 1:3 diesel:oil mixture. %he annular fluid levels will be monitored for leaking gas ~ valves. ~ necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'· Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells · in the Milne Point Unit r~}u~.~u.~ 2 ~.~,:~., ~ ~ ~, ~, ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-il, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. %hough only one well is active at any given time, all wells are capable of produc- ingo A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the. glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wel!bore is filled with natural gas so that freezing is not a concern, but to prevent potential aorrosion an inhibitor will be displaced into the wail. A 50:50 methanol:water mix will be used to carry ~ ~ - ~= innib i~or. ~ you ~, , any ...... the ....... ~.o~e~u~e p_ _e contact Don Girdler at 564-7637. Yours very truly, . o STATE OF ALASKA ALASI,, OIL AND GAS CONSERVATION COMk 31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon D Suspend © Operation Shutdown Re-enter suspended well [] Alter casing ~ Time extension ~ Change approved program [] Plugging ~ Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other ~, 2. Name of Operator Conoco -rnc. 3'Ad~l C Street, Ste. 200, Anchorage, Alaska 99503 4. Location of well at surface 725' FSL, 2098' FEL, Sec. At top_ of productive interval 4867' FNL, 612' FEL, Sec. At effective depth N/A 10, T13N, R10E, U.M. 10, T13N, R10E, U.M. At t~q~¢p~, 473' FEL, Sec. 10, T13N, R10E, U.M. 5. Datum elevation (DF or KB) 59' KB feet 6. UniLo[; Prop..ert,y r}arp, e ~vtz±ne 'roI~'f unit 7. Well number c-15 8. Permit number 85-103 9. APl numlp'effn-2u,,~ 1358 50-- 10..POO~uparuk River 11. Present well condition summary Total depth: measured true vertical 7665 feet 73 19 feet Plugs (measured) Effective depth: measured N/A true vertical feet Junk (measured) feet Casing Length Structural Conductor 80 ' Surface 4656' Intermediate Production 7618 ' Liner Perforation depth: measured Size Cemented Measured depth 16" To Surface 115' 9 5/8" 1565 Sxs 4692' 7" 250 Sxs 7652' 7442'-68';7410'-30';7338'-42';7314'-18';7226'-40' ~ue Verticaldepth 115' 4584' 7307' true vertical 7107'-32;7077'-96' ;7009'-12' ;6986'-90' ;6904'-17' Tubing (size, grade and measured depth) 3½", L-80, 7398' Packers and SSSV (type and measured ~d~p~t'h)SCSSV @ 1904' ; Ret. Pkr. @ 7089' ; Perm. Pkr. @ 7374' 12.Attachments Description summary of proposal,~ Detailed operations piogram'~ BOP Sketch 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Commission Use Only Conditions of approval Notify commission so representative may witness Approval No. [] Plug integr ty [] BOP Test [] Location clearance Date Approved by Form 10-403 Rev 12-1-85 Commissioner by order of / ;' the commission Date / Submlt in triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX-I OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-103 3. Address 8. APl Number 3201C Street, Suite 200, Anchorage, Alaska 99503 5o_029-21358 FSL, 2098' FEL, Sec. 10, T13N, RIOE, U.M. 4. Location of Well 725' 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number C-15 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 12-14-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The sl~ace b(~,F~' for Commission use / Date Conditions ~-~ Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate John R, Kemp Manager of Alaskan Operations January 7, 1986 Mr. Robert Burd, Director U.S.E.P.A. Water Division, Region X 1200 Sixth Avenue, M/S 409 Seattle, Washington 98101 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 Dear Mr. Burd: Attached please find a completion report for Milne Point Unit Wells C-6 and C-15 which were issued emergency injection permits in accordance with 40 CFR 144.34(a)(3) on December 21, 1984. Also included are geophysical logs and wellbore diagrams. Thank you for your timely response to our urgent business. Rod Schulz at (907) 564-7633 if you have any questions. Please call I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. Division Ma ~nager Anchorage Division RRS/slt Att cc/att: Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RECEIVED Alaska Oil & Gas Cons, Commission Anchorage EPA UNIT ~;TATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON. DC 20460 : COMPLETION REPORT FOR BRINE DISPOSAL, HYDROCARBON STORAGE, OR ENHANCED RECOVERY WELL Form A oproved OMB No. 204~.0042 Approval exDtres ~-30-~-f~ NAME AND AOORESS OF EXISTING PERMI~EE Conoco [nc. 320! C Street, Suite 200' Anchorage, Alaska 99503 NAMEANOADDRES$OFSURFACEOWNER State of Alaska W LOCATE WELL AND OUTLINE UNIT ON SECTION PLAT -- 640 ACRES N l-k l I I F 1 J- I I I STATE J COUNTY PERMIT NUMBER AK I, North Slope Borough AK-2ROO82-E SURFACE LOCATION OESCR:PTION NW '/,OF SW :/,OF SE '/`SECTION 10 TOWNSHIP 13N RANGE iOE LOC.~TE WELL IN TVVO DIRECT]ONS FROM NEAREST LINES OF QUARTER SECTION AND DRILLING UNIT Surface L~catlon 7 ~) ~ ft. from (N/S) _.~'.._ Line of quarter section 2O98 andI I~. from {E/W1 E Line of quarter section WELL ACTIVITY TYPE OF PERMIT [-1 Brine Disl:~osai [~ Individual ~] Enham:~l Recovery ~ Area [] Hydrocarbon Storaqe Number of Wells 23 Antlcioated Daily Iniect~on Volume IBbls) Average I Maximum 3000 1OOOO Anticloated Oailv Iniectlon Pressure IPSI) Average I Maximum 1900 2500 Type of Inle~1,on Fluid fCheck the a~l~rop~/ate block($J) Sail Water ~ Brackish Water [] Fresh Water [] Liquid Hydrocarbon ~] Other l Date Drilling Began ~ Date Well Completed 5/21/85 I 5/31/85 Dale Orllhng Comoleled - Estimated Fracture Pressure of Injection Zone O.75 psi/ft OD S,ze 13 3/8" Injection Interval Fee, 7226 fo F~68 Oeoth to Bottom of Lowermost Freshwater Formation (Feet) 3100' (See UIC Permit) Infer'vet Treated 7442 '-68' 5/28/85 Lea~ Nam~ MILNE POINT UNIT Name of Inie~lon Zone Kuparuk River lWt/Ft -- Grade -- New or Us~ i 48~ - H40 - New 36# - LUO - New I 2b# - L~O New Permeability of Injection Zone 60 - 300 md Porosity of Injection Zone 20% CASING AND TUBING CEMENT HOLE Doom Class i B,t Diameter 105' 4692' INJECTION ZONE STIMULATION 7653' Malerlal~ and Amount Us~ 43000 lb 16-20 US mesh proppant and 50000 gaks water base gek i ComDlete A, rtaclnments A -- E I~sted on the reverse. Sacks Surface 1315 25O 25O Arctic Grad ?ermafrosE E Deolh ~. 125, 4715' : C 7665' ! 8{" WIRE UNE LOGS. LIST EACH TYPE Log Ty~es SP'U£L-SFL GR-CNL in csg Intervals 4692 - 7660 7100 - 7634 3500 - 4700 CERTIFICATION I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately, respnnsible for obtaining the information, I believe that the information is true, accurate, and complete. I am a ware that there are si2nificant penalties for submitting false information, including the possibility of fine and imprisonm~.nt. (Ret. 40 CFR ~,~4.32). NAME AND OFFICIAL 1TFLE/P/ease type Ot p~mt) JOHN R. KEMP ANCHORAGE DIVISION MANAGER EPA Form 7520-1 D,~TE SIGNED C- 15 ATTACPiMENTS A. See attached casing and completion sketches. B. Pressure tested 9 5/8" casing to 1,500 psi for~30 minutes with no bleed-off. Applied 3000 psi on the tubing to set the packer. Pressure tested casing-tubing annulus to 1,500 psi for 10 minutes with no bleed-off. Pressure tested tree to 5,000 psi for 10 minutes with no bleed-off. C. A report was submitted on May 15, 1985, which was approved on June 21, 1985. D. No defective wells. E. Included are final prints of the SP-DIL-SFL and GR-LDT-CNL-CAL logs. MILNE POINT UNIT 1 5 ACTUAL COMPLETION SKC--TCH COMPLETED ON' '5-31-85 NOTES: 1. All me·aurora·hie are from KDB of Al~lka United ~I* 3 2, KDB - 8L · KDB - GL · 35' 4. Max. angle 29.8° (~ 4772~MD 5. KOP ~'~ 3115' 6. 81ant type hole YES 7. Min. angle 8. FMC S 1/8° APl 6000~ tree with 3 1/2' 8 rd. treetop oonnectlon. I. Min. reetrlctlon Il Camco~D' Nipple " at 7398' (2.750"1D) 10. APl No. 50-O29-213S8 11. Completion fluid 10.2 ppg NaCI-NoBr Ca~lng and cement Information euppllad on oiling and cement Ikatch. FMC TUBING HANGER --3 I/2", 9.2?~e, L-80 buttrele lublng 1904' CAMCO TRDP-IA SSSV (2.992"1D) 2.867" drift) ~ERFORATIONS 12 SPF, 120° phaelng, 5"gunl (All dtpthl from DIL log 5-28-85) BOT PBR, Seal Assembly BOT 'HB' packer (2.~19" ID) MIDDLE KUP 7,226'- 7,240' MD 6,904'- 8,917' TVD L-8 7,314'- 7,318' MD 8,988'- 6~990' TVD 7127' CAMCO 'W-I' Selective Nipple (2.817_" ID) --7161' CAMCO 'MMG-2' Got Lift Mandrel (GLM)=2.92" ID, 1.5" w31vee 77-01' GLM -- 7240' Blast Joint (19.75' total length) L-9 7~358'- 7,342' MD 7,009' - 7,012' TVD LK-2 7,442'- 7,468' MD 7,107'- 7,132.' TVD 4 ~PF, 0e phaelng, 2 I/8"gunl (All dil~hl from DIL log 5-28-8S) LK-i 7,410'- 7,4:50' MO 7,077'- 7,096 ' TVD (~IIIIINAL ~e RE¥111ONI Or/Cl , · BOT 'CL' Seal Assembly with locater BOT '2B' Permanent Packer (5.875" OD, 4.0" ID) with mlllout extemion -- 7398' ' 7407' CAMCO 'D' Nipple (2.750" ID) 'Tubing Tail i.i?,'., i~ : 26~,L-80 Buffroee (~ 7653' (6.276" ID, 6.1$1"drlft) MILNE POINT UNIT :_~-1_5 (I) · · OPERATOR: CONOCO, INC. SURFACE LOCATION: 725'.FSL, 2098' FEL, Section 10, T13N, R10E BOTTOM HOLE LOCATION' 4890' FNL, 473' FEL, Section 10, T13N, R10E SPUD DATE' 05-21-85 NOTES: 1. All measurements from KDB of Alaska United #3 2. KDB - SL ~'-52' 3. KDB - GL = 35' 4. Max. angle = 29.8° @ 4772' ~"~ 5. KOP at 3115' 6. Slant type hole YES 9 5/8" Surface Casing 13 3/8' at 105' 9 5/8' C Iat. 4692' Est. TO, C :'..':.':. '.. :'.' :_..' '7: @ 6600 +_* 1. Pumped 35 Bbls of 11 ppg Sepiolite spacer as pre-flush. 2. Pumped 461 Bbls (1315 sx) of 12.3 ppg Permafrost Type "E" cement with 5~-"/sk. of gilsonite. 3. Pumped 51 Bbls (250 sx) of 15.8 ppg Class "G" cement with 3% salt and 1% CFR-2. 4. Displaced with 351 Bbls of 9.4 ppg mud. NOTE: Full returns with cement to surface. Centralizers 1 per 120' 44'- 3200' 1 per 80' 3200'- 4175' 1 per 40' 4175'- 4685' 7" Production Casing l. Oumped 35 Bbls of 12 ppg Sepiolite pre-flush. 2. Pumped 51 Bbls (250 sx) of 15.8 ppg Class "G" cement with 1,% CFR-2 and 0.3% Halad-24. 3. Disulaced with 290 Bbls of 10.2 ppg NaC1-NaBr. Centralizers 1 per !20' 0'- 3000' 1 per 40' 7100'- 7665' ECP 7374' ±7572' ECP 7395' 7' at 7653' CqIGINAL 06-26-g5 ~rEA / Cf~kd A = Arctic Pak (60 bbls) B = Arctic Set I ( 180 sx ) C = Mud and Spacer ~ I SlMPC'~N LAGOON t~:~..-. F...~... 9?.'?. ~..'~'. i P.~.". ~ ..................... _ -- SCAL~: IN ~,LES CONOCO MILNE POINT UNIT EXISTING OE?JELOP~ E NT NOTES: !. STAT[ PLANE COORDINATES ARE ZONE 4. Z. ALL GEODETIC POSITIONS ARE BASED ON N A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF SECTION CORNER POSITIONS. I LOCATION IN SECTION FROM S. LIN~. F'ROh4 E. UNE 1068' 2205' 6, 029,351.58 496' 2027' 6, 028, 280.21 C-13 I 954' 2169' 6 ,029,237.39 8:59' Zt~4' 6 724' 2098' Il C-16 J --1 6t0' 2063' 1287 ' ::'273' 457' 2219' C-19 ] 1468" 2329' STATE PLANE CO-ORDS. NORTH~NGS LASTINGS 558,255.76 558, 458.90 558, 292.56 ! ~5 s--;~z9.06-' 558 , 566.14 6 ,029,007.58 ___6, 028, 894.48 6, 029,569.69 558, 402.27 558= 185.84 558~ 248. 260 558,128.09 ' ' CERTIFICATE OF SURVEYOR : · I HEREBY CERTIFy THAT I AM PROPERLY R[GmST[~ED -'ND LICENSED TO PRACTICE LAND SuRvEYINO IN TH[r STATE OF ALASKA ~t 5UPLHViSION, ~';D IHAT ~LL 4. L0(:ATED WITHIN SECT. 10, T 13 N, RIO[, U.M.,AK. GEODETIC POSITION LATITUDE 7d~ 29' 26. 894" N. 70 o 29' 21.260" N 70°29' 25.768" N. .... 70029' 24.639" N. 70° ';'9' 23.502"N. I 149°31'20.280" W J II -I-85 J.H. 22-85 149°31'24.486'~ I 6.l,8SI &ELS. 22-85 149°31' 23:438'~I'. J ,,_--r...,J ..... 149°31' 22. 374"W. J " 70° 29'22.$87"N 149° 31'21.557" W. 70° 29'29.044" 70° 29'20.680" 70© 29' 30.821" 149° 31' 29. 208" 149° 31' 27.550" W, 149° 31~ 25. 909" JI1-1 -85 II - 9 - 85 J11-10-85 g.0. 46 -85 . . L. 0. 46 - 85 PAD AS- BUILT WELL LOCATION ~ur,,e~¢d CONOCO i SCALE : J SH£ ET : I' · 400' J 2 OF 2' COUMENTS ; August 19, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No. C-7, C-9, C-Ii, C-12, C-13, C-14, C-I5, and C-16. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, J R Kemp~ ~laskan Operations KJS 5/vv RECEIVED AUG 2 0 1985 Alaska Oil & Gas Cons. Commission Anchorage -,' STATE OF ALASKA ALASKAL .... AND GAS CONSERVATION COl ..... /IISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED E~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 85-103 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50-029-213S8 4. Location of well at surface 9. Unit or Lease Name 725' FSL, 2098' FEL, Sec. 10, T13N, RiOE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 4867' FNL, 612' FEL, 'Sec. 10, T13N, R10E, U.M. C No. At Total Depth 11. Field and Pool 4890' FNL~ 473' FEL, Sec. 10, T13N, R10E, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 52' KBI ADL 47434 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115'Water Depth, if offshore 116. No. of Completions 5-22-85 5-28-85 5-31-85I ~/A feet MSL 17. Total Depth (MD+TVD)7665, (7319'rVD; 18. Plug Back Depth(MD+TVD)7572, (7231'TVU) YES:~:19' Directional SurveYNo[_) I20' Depth wheresSsv set1904' feet MD [ 21. Thickness of Permafrost 22. Type Electric or Other Logs Run D IL-LDT-CNL-GR-CCL-Gyr o 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 7' 26# L-80 O' 7652' 8~" 250 sx Class O 24. Perforations open to Production (MD+TVD of TOp and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7226'-7240' (Middle Kup) 12spf, 120°phasin~ 3~".9.~¢~. ,T.-~0 7398' 7089'. (t~p~. 7374 ' (hn~-~-r~) 7314'-7318' (L-8) 12spf, 120°phasing26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7338'-7342' (L-9) 12spf, 120°phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7442'-7468' (LK-2) 12spf, 120°phasin~ 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKESlZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED~1~ OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. KA MA NA OA .. NAME T/Kup. Interval Middle Kuparuk Laminated Zone !LoWer Kuparuk MEAS. DEPTH 3,752' 4,'030' 4,317' 4,453' .. 7,108' 7,226'~ 7,240' 7,411' TRUE VERT. DEPTH 3,742' 4,002' 4,257' 4,376' 6,793' 6,904' 6,917'i 7,078' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF' ATTACHMENTS 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repor~ and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etC.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 0-407 ~conoco) WATER FLOW ADVISOR PL ADVISOR MPU C-15 Company - CONOCO, INC. Field - MILNE POINT Logging Date - 29-JUNE-1990 Processing Date - 20-JULY-1990 Reference - 73946 Water Injection Well Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 INTERPRETATION SUMMARY Water Injection Well- 2730 BWPD Zone Injection Water % of Interval BPD Total MK - 1 7226 - 7233 1255 44.9 7233 - 7240 0 0.0 L-8 7314- 7318 0 0.0 L - 9 7338 - 7342 0 0.0 LK - 1 7410 - 7416 225 8.0 7416 - 7430 0 0.0 LK - 2 7442 - 7468 1315 47.1 Total Injected Water 2795 100.0% Zone Water % of Total MK - 1 1255 BWPD 44.9% L - 8 0 BWPD 0.0% L - 9 0 BWPD 0.0% LK - 1 225 BWPD 8.0% LK - 2 1315 BWPD 47.1% Surface well head injection pressure was 2650 + 10 psi. Well C-15 was logged in two parts: 1.) Water being injected into all zones at once. The CFM was used to determine the injection pro- file between GLMs and below the tubing. 2.) The Water Flow Log (WFL) was used to determine the injection profile behind the 3.5 inch tub- lng. There was a tubing plug set in the tubing tail while the WFL log was run. The injection rate during the WFL Log was almost the same as the injection rate going through the GLMs in part one. Additional information: There is a 75 to 105 BPD going down to the the lower packer. A CFM was run to verify that the tubing plug was not leaking. The well is deviated 30 degrees. WATER FLOW ADVISOR MPU C-15 Company Field Logging Date Processing Date Reference - CONOCO, INC. - MILNE POINT - 29-JUNE- 1990 - 20-JULY- 1990 - 73946 Water Injection Well Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 CONOCO, INC. ~' Milne Point MPU C 15~:I!'I' '~ (~ii Water Flow Logs .... _.~,.29-Jun-90 INTERPRETATION SUMMARY Data from Water Flow Log Surface Injection Rate- 1365 BWPD Zone Injection Water % of Interval bpd Total MK- 1 7226- 7233 1255 92.3 7233 - 7240 0 0.0 L-8 7314- 7318 0 0.0 L-9 7338-7342 0 0,0 Leaking Packer 7361 75- 105 7.7 Total Injected Water 1360 100.0% eThetubing tail has a tail plug set in it. eThe lower packer or seal assembly is leaking at 7361 feet. A CFM was run to verify that the tubing plug was not leaking. eThe deviation of the wellbore is 30 degrees. CONOCO, INC. -' Milne Point MPU C- 1~ Water Flow Logs 29-Jun-90 1365 BWPD Minitron Detector Det. Measured Flow No. Depth (ft) Depth (ft) Type Velocity Area(in2) 1 7223.0 7225.0 Far 39.7 21.31 2 7226.0 7228.0 Far 31.8 21.31 3 7228.0 7230.0 Far 28.0 21.31 4 7230.0 7232.0 Far 9.5 21.31 5 7232.1 7234.1 Far 4.1 21.31 6 7234.1 7236.1 Far 5.4 21.31 7 7236.0 7238.0 Far 2.8 21.31 8 7237.9 7239.9 Far 4.8 21.31 9 7240.1 7242.1 Far 3.5 21.31 10 7242.1 7244.1 Far 2.8 21.31 11 7275.6 7277.6 Far 2.5 21.31 12 7310.7 7312.7 Far 3.1 21.31 13 7312.6 7314.6 Far 2.4 21.31 14 7314.5 7316.5 Far 3.6 21.31 15 7317.8 7319.8 Far 1.8 21.31 16 7318.8 7320.8 Far 2.5 21.31 17 7326.8 7328.8 Far 3.1 21.31 18 7334.8 7336.8 Far 3.0 21.31 19 7336.8 7338.8 Far 4.7 21.31 20 7338.8 7340.8 Far 4.6 21.31 21 7339.8 7341.8 Far 4.1 21.31 22 7343.0 7345.0 Far 4.4 21.31 23 7360.3 7362.3 Far 1.8 21.31 24 7368.4 7370.4 Far 4.4 21.31 25 7369.1 7371.1 Far 1.8 21.31 CONOCO, INC. Milne Point MPU C- 1 Water Flow Logs 29-Jun-90 Processed Data Depth Interval Average Average No. (ft) - (ft) Velocity Flow Rate 1 7223.0 - 7226.0 39.7 1356.7 2 7226.0 - 7228.0 31.8 1086.4 3 7228.0 - 7230.0 28.0 956.6 4 7230.0 - 7232.1 9.5 324.5 5 7232.1 - 7234.1 4.7 159.9 6 7234.1 - 7236.0 4.7 159.9 7 7236.0 - 7237.9 3.5 122.1 8 7237.9 - 7240.1 3.5 122.1 9 7240.1 - 7242.1 3.5 119.6 10 7242.1 - 7275.6 3.0 103.6 11 7275.6 - 7310.7 3.0 103.6 12 7310.7-7312.6 3.0 103.6 13 7312.6-7314.5 3.0 103.6 14 7314.5- 7317.8 3.0 103.6 15 7317.8 - 7318.8 3.0 103.6 16 7318.8 - 7326.8 3.0 103.6 17 7326.8 - 7334.8 3.0 103.6 18 7334.8 - 7336.8 3.0 103.6 19 7336.8 - 7338.8 3.0 103.6 20 7338.8 - 7339.8 3.0 103.6 21 7339.8- 7343.0 3.0 103.6 22 7343.0 - 7360.3 3.0 103.6 23 7360.3 - 7368.4 2.2 76.6 24 7368.4 - 7369.1 2.2 76.6 25 7369.1 - 7371.1 2.2 76.6 ~conoco) PL ADVISOR Production Logs Interpretation Using a Global Solver (V3) MPU C-15 Company - CONOCO, INC. Field - MILNE POINT Logging date - JUN29,1990 Processing date - JUL20,1990 Reference - 73946 Water Injection Well Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 CONOCO, NC. Milne Point MPU C- 15%'t~:.-: ' Production Logs 29-Jun-90 INTERPRETATION SUMMARY Data from Continuous Flowmeter Surface Injection Rate- 2730 BWPD Zone Injection Water % of Interval BPD Total GLMs 7141 -7149 7181 - 7189 1230 44.4 LK- 1 7410- 7416 225 8.1 7416-7430 0 0.0 LK - 2 7442 - 7468 1315 47.5 TotaJ Injected Water · 2770 100.0% The well is deviated 30 degrees. .--~, ~.~~~~`~~~~C:~`~.~~~-~ -'-'-'-'-------'-'-'- ~,RAY 1990 DOVfl~f-KN_E WATER ~JECTION RATE ~0 (C~AP~ 'nO O. (B~) ~ . .".-- ' ' I ~ i I I , . I ~ i i i~ ' ~:~J~:~:~J~J~:~:~:~J~:~:~:~:~:~:~:~:~:~:~:~[:~:J5~:~:~:~:~:~:~:~:~:[:~:~:~:~:~:~:~:[:~:~:~ ~:~:~:~:~:~:~:~:~:~:~:~: :~:~:~:~:~:~ ' -- i ..... i~-:.:-:.:~:.:;:.:-:.: -:.:.:.:.:.:-:.:..-:.:. :-:.:.:.:.:.:.:-:--. -:-:.:.-...:-:.:.:-:.:..:.:-..:..-.:.:-:.:......:~:.. ' !~~ ¢~~~ .- , . GAI~,tA RAY 1990 7150 _ I 97 TEMPER,~'rUR~ '102 CONOCO, INC. -- Milne Point MPU C- 1_ Production Logs 29-Jun-90 COMPUTED CUMULATIVE INJECTION RATES At Down hole conditions Zone Depth Depth Total Water Oil Gas Global # DH Rate DH Rate DH Rate DH Rate Inco- Feet Feet Bpd Bpd Bpd Bpd herence 1. 7484.5 7468.5 0. 0. 0. 0. 0.000 2. 7442.0 7416.5 1315. 1315. 0. 0. 0.001 3. 7410.0 7390.5 1538. 1538. 0. 0. 0.000 4. 7389.0 7186.5 1538. 1538. 0. 0. 0.172 5. 7182.0 7148.5 1924. 1924. 0. 0. 0.001 6. 7142.0 7099.0 2768. 2768. 0. 0. 0.006 COMPUTED FLOW DESCRIPTION Assuming a I - 11/16" tool presence Zone Water Gas Mixture Friction Liq/Liq Gas/Liq Inj. # Holdup Holdup Density Gradient Slip vel Slip vel Regime Gr/cc Gr/cc Ft/mn Ft/mn 1. 1.000 0.000 0.970 0.000 0.00 0.00 Nolnj. 2. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 3. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 4. 1.000 0.000 0.970 0.025 0.00 0.00 WATER 5. 1.000 0.000 0.970 0.038 0.00 0.00 WATER 6. 1.000 0.000 0.970 0.076 0.00 0.00 WATER CONOCO, NC. Miine Point MPU C - 15TM .... " Production Logs 29-Jun-90 PRODUCTION LOG MEASUREMENTS Zone Depth Spinner Thermo # #1 #1 Feet Ft/mn DegF 1. 7484.5 0.00 101.936 7468.5 101.932 2. 7442.0 27.74 98.727 7416.5 98.528 3. 7410.0 32.37 98.509 7390.5 98.485 4. 7389.0 7186.5 136.97 98.422 97.883 5' 7182.0 171.44 97.911 7148.5 97.877 6. 7142.0 246.07 7099.0 97.739 97.960 MEASUREMENT RECONSTRUCTION QUALITY Measured minus Reconstructed values Zone Spinner Thermo # #1 #1 Ft/mn DegF 1. 0.00 0.000 2. 0.00 -51.143 3. 0.00 -7.383 4. -0.34 -0.061 5. 0.00 ~10.092 6. -0.01 -15.490 CONOCO, INC. Milne Point MPU C- 1~ Production Logs 29-Jun-90 PL Advisor Program Parameters for Zone 1 (at downhole conditions) Zone bottom depth ................................................ 7485. Feet Zone top depth .................................................... 7469. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 30.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5430. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7100 Cp Reservoir fluid temperature ......................................... 150.0 DecjF Minimum water rate .............................................. 0.0000 Bpd Maximum water rate .............................................. 0.0000 Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.5190 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF PL Advisor Program Parameters for Zone 2 (at downhole conditions) Zone bottom depth ................................................ 7442. Zone top depth .................................................... 7417. Pipe internal diameter .............................................. 6.276 Pipe Deviation ..................................................... 30.00 Pipe absolute roughness ........................................... 0.0006 Average injection pressure .......................................... 5430. Water density ..................................................... 0.9700 Water viscosity .................................................... 0.7100 Reservoir fluid temperature ......................................... 149.9 Minimum water rate ............................................... 1315. Maximum water rate ............................................... 3000. Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8610 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Feet Feet Inches Degrees Inches Gr/cc Cp DegF Bpd Bpd Inches FtJmn DegF CONOCO, INC. Milne Point MPU C- 1~ Production Logs 29-Jun-90 PL Advisor Program Parameters for Zone 5 (at downhole conditions) Zone bottom depth ................................................ 7182. Feet Zone top depth .................................................... 7149. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 30.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5430. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7100 Cp Reservoir fluid temperature ......................................... 148.4 DegF Minimum water rate ............................................... 1924. Bpd Maximum water rate ............................................... 3000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8960 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF PL Advisor Program Parameters for Zone 6 (at downhole conditions) Zone bottom depth ................................................ 7142. Feet Zone top depth .................................................... 7099. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 30.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5430. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity ........................... . ......................... 0.7100 Cp Reservoir fluid temperature ......................................... 148.2 DegF Minimum water rate ............................................... 2768. Bpd Maximum water rate ............................................... 3000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8980 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ....... ; ......................................... 0.0000 Inches Ft/mn DegF MILNE POINT UNIT C-15 ACTUAL COMPLETION SKETCH COMPLETED 0N"5-31-85 #OTES: 1. All meeeurementa are from KDB of Al"'ko United ,M 3 2. KDB - SL : 52' KDB - GL : 35 4. Max. angle Zg. Bo (~ 4772' MD 5.KOP L~ 7. Miff. angle FMC 3 1/8' APl 5000. tree w~h 3 112' 8 r~. treeto~ connection. O. MI~ roltrlctlon Il Coreco 'Dr Nipple et 7S98' (2.750"10) 10. APl Mo. 50-029-21S58 I 1. Core.latin t~ld 10.2 ppg NaCI-NaBr Ciolng Ifl~ cemenf ~formetlofl Off caelno afl~ cement 8ketch. FMC TUBING HANGER ~,/ 3 ~/~" 'H' BPV PROFILE -- 3 I/2", 9.2-~a', L-80 buttre~r tub,.~ ( 2.992" ID, 2.867" ~r~ft ) 1904' CAMCO TRDP-IA SSA SSSV ( 2 BI2" ID ) PERFORATIONS 12 SPF, 120° I~koemg, 5"oun. (All depths from OIL log $-28-85 ) IdK-I 7Z2.$' - 7240' MD 69,04'- 6917' T¥0 7}14' - 7~16' MD ~986' - 6~0' TVD ~-9 7~8'- T342' MD 7009'- 7012' TVD LK-2 7442'- 7468' MD 7107'- 71~2' TVD from OIL log 5 - 28 - 85 ) CK -I 7410' - 7430' MD 7077'- 7096' TVD FRACTURE STiMULATiON 8 - 31 - 85 Lo.er Kug ( ~ ) 43t000~ 16-Z0 ISP (set.nee-out) -- 7-~7 3' 7374' B3T PBR, Seal As.~embty 6gT 'NB' pocket {,2. 89" ID) 7127' CAMCO 'W-I' Selechve I'~pple (2.812'" ID) ~7161' CAMCO 'MMG-2' G3~, L,fl I~ondrel (GLM):2.92" ID, 1.5" vq31ve$ 7201' GLM --7240' Blest Jo,hr (1975' total k,'~gthJ -- 7398' C,~MCG 'C' Nl)ore (Z 7.50" ID) -- 7407' Tul~ng TOH 7560' Toe of fill (W,relrne 9 - 17 - 85 ) 7572 PBTD 7653' 7" 26// L-80 BTRS (6.276" ID, 6.151" drift) July 1985 Directional Services Pressure Services Chernlcal Transmission Sys~cn~s Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATT: William Van Alen CONFIDENTIAL Our Boss Gyroscopic Survey Job No: AK-BO-50054 Wel 1: C-15 Milne Pt. , Alaska 'Survey Date: May 50, 1985 Operator: D. Harger, T. McGuire William Van Alen: Please find enclosed the copy of our Boss Gyroscopic Survey on the above well. Thank you lot giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure (two copies of survey are enclosed) cc: According to distribution list NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 CCl N Cl CCi ~ I N 0. C- 15 I'11LNE F'O I IqT ALASKA SF'EF;~RY-::-';LIIq WELL SLIRVEYINIB C:Cq'IF:'ANY ANCHFIRAGE ALAF;KA C: 0 I"IP U T A"I' I 0 N D A T E MAY :31., `1. VERTIF:AL SEC:TICII',I r':AI_CULA]'ED ALOI',I(3 (]:LOSLIRE MEASLIRED VERT I C:AL VERT I CAL DEF'TH DEF'TH DEPTH C: i"l LI R S E ........ C L')LI R '.:; E D 0 '-~ - i._ E-r-4 I N C L. I N A T I 0 N ,II I R E C"I' I 0 hi '.::; E V E R I T Y Fi E G M I N I"l E G R E" E S D E G / .1. (} 0 0 (}. (")0 1 O0 100. :30 ("~ 2'?'? · 9 ? 40('} :3'?'P. '..7,,'F' · 500 499.98 6 00 599.98 7(')C) 6'?'?. '?:::: :{: 0 (} 7'? 9. ,:7¢ 8 .... 'P 00 8'?'?. '? 8 1 ,[") 0 (') '3' 9'?. 98 .1. 100 1. 099. '78 12 ("~ 0 1199. '? 8 1:2:0 ("~ 1 '.P'? 9. '77 ....... 1400 1:2: 9'?. 97 1. 500 :1. 499. '? 7 1600 155;".?. 97 `1. 70 () 1699.97 1800 1799. '? 7 1. ?00 `1.._,..'=":-/':".... 97 ' '- 20 00 199 9. '? 7 21 00 '2:09 '.:.'/. '? 7 2200 2199.97 ........... 2 3 00 229'?. '? 7 2400 2 :--: 99.97 :2500 :2497. '? 7 ........... 2 ~;'C50 25';¢'.-.-¢. 97 2700 's. '699.97 2 L.:: 00 279'?. 97 ....... :2900 2895/. 5/6 4 :---:. 00 ...... 1. 4:--:. Oi") ..,::. 4. / . o9 :.]47. '79 4.4. '7 547.9 647 .:;,c, 747 9:--: :'_'-.':47.9:_--.: '?4.7.98 1047.98 1. 147.98 124.7. '..-;7 1:2:47. '3'/7 _1. 44.7. '?7 1 .=_;4.7. '.'.'-;7 1/_',4'7. '3"7 174.7. '?7 184.7.97 1947.97 2047. '? 7 '--'147 97 · ' · 2247. '77 2:--:47.97 ;.7:447. '?7 .... 2547.9'7 '-' -;" 7' / ...:./:,4 ~ . '-'-' 2747· 97 2847. 'P 6 0 C) N O. () E () 25 ~..'..i; 17.,/:,'.? W -' 0 '" :2 ::: .._,'::' 47']... 5:0 W 0 :~:":-'. ':'7 10 W C) :2::2: ._.,'::' /-,':.:¢. . ::::0 .... W ' ' .-', 0 z .... S 75.60 la (] .1.:.:.'::.E; :"-':7. :3'? W 0 15 Iq 56. :30 W 0 1::: ""._, 2:':: . (].. E (-) -~, _ .:, Iq 75. :'::9 IE C) 22 Iq ":":' /-,('~ W . .mL. aL. ,m _ . 0 14- '..--_.: :E:4. :::'P W C) 1:3 '._--; '::'F, 1o W o :3 E; 20.:::0 W 0 `1.1 N 67. :3o W 0 1:3 N '77. L:..:9 W 0 '.:.'/ Iq 59. 0 W C) lC) '.:; b, 7.39 E ("~ 4 Iq :_--:1.5C. 1`4 (2) 11 .:,'-' lO... 1':). W 0 1:3 S 16. 10 W 0 1._, = S 1:3..-=;_ (]. E-_' 0 9 Iq 61. :'::0 E 0 16, N 6, 6. :30 E (') (") N 47.5:0 W 0 7 :.710.8'? E () 10 ?3 6'3'. ::::0 E C) 19 Iq '7/.:.. 19 E (':) 46 :.-".i; 24.50 W Ii A T E 0 F S I...I IR V E Y M A Y 5:('), B 0 S S G Y R 0 S C 0 P I C S U R VE Y ...I 0 B N IJ I"1B E R A K- B O- 5 (} (') 54 I<EL.L.Y BUSHINf3 ELEV. = OF'E:RATOR-D. HARGIER, T. TOTAL IR E C: T A N G U L A R f_': 0 r'[ R D I N A T E ::; IqOF~TH / .'F.;FII_rTHEAS'I"/WEST 0.0 c) 0.00 ('). 0 c) o 4.2 (') '-' '= :.:;i; 0 1`1. W .. · .. u .,.'.! ..I n 0 ' ":'-'"' (). 'i.a9 S "0", 52 W O. :--:4 `1.. 76, '.35 O. 88 W 0. !57 :2.'.:. 4 .1. S .1. · :--:9 W ci. ]. 4. 2.66 '.:; '7'. 1 'P W 0.i4 2.77 S 2.:::1 W 0.1E: '2.6/:, S :3.25 W 0.45 :2.'71 S -:3.36 W 0 '-"-' '.-.' ::.':8 '-' 3 ~o W . ,."..'l .,_. .2:, C) "~'-' '-:' 5/, S :7:: :31 1,4 . , ..Z, ,Z:, .,.. , - 0.1'? :2.14 S :3.55 W c)... 2("). .,..'-'. O:F: .z.,'-' :_-: · :--:'7 W 0.05: '2.06, S 4.2:3 W 0 21 '-' 12 ':' 4 50 W mm ."" · --; 0.21 ..s:.(-)9 S 4.6,7 W 0.05 `1..'79 S 5.0:2 W o.07 1.87 S 5. :7:::2: W 0.:2',4 1.8/-, S 5.:31 W O. 25 1.86, S 5.2.'.:0 1,4 0.25 `1.. '? ¢: S 5. -7.., 9 W 0 1.:'-] '-.' 7l ':' R z[.O 1,4 . · "'.m ._l _ · . 0 '-"-' :;;'. :":A S .=i-, ..-.-, W .. · .£,._', _ _ _ _ . 0. 11 '.':.'.'70 S 4.:3'? W 0· 2:--: ...'::'. Z-.O_. .:,'-' 4 · 68 W C.). 14 '2. '7C):':i; 4.67 W (') ]. Pi '::' ::-':7:_--: 4- "--1 W .. , ... a.. m · ("~ 21 ":' ........ : .... :3 4.09 W 1.01 :.-::. :3'P :_:i; 4. (')9 W F'AGE 1985 '='-' 0C)FT ._1 ..-' . . MCGLI I RE VERT I" S E C: T i ,_.,',1 0. -0.04 -(}. 31 - 0.5 cE) - 0.87 -1.61 -2. 19 -:2.74 -2.59 -2.72 -":' 04 -:3.39 -:3. -4. 16 -4. :--:4 ~ 4 '--' '-" · -4.71 -4.7::-: -4.82 -4.74 -4.55 -4. '25 -4.06 - 4. (-):3 -:2:. :--: 4. -:3.4 --:--:. :32' C:ON OCO. I NC:. C:-15 MILNE F'O TNT ALASKA S F'E R R Y- S I_1N W E L L. '.'_-'; I_.1R V E Y I N G C 0 FI F'A Iq Y ANCFIL]IRAGE ALAF;KA E: 0 I'1F' U T A T I 0 N D A T E MAY :::1, I985 VERTICAL SEC:TION F:AI_CLILATED ALF~NG CLOSLIRE D A T E 0 F L:.; LIIR V E Y FI A Y :2: 0, BOF;S GYROL:;CF~F'IC F.;LIRVEY ,_lOB NLIMBER AI<-BO-~'..::,0o._,=4 KELLY BLISFIING ELEV. = OF'ERATOR-D. FIARGER, T· F'AGE.-"'-' 52.00 FT. M C: G I_11 R E ] R _IE Fa.lB-SEA MEA,-..L RED VERT I C:AL VERT I CAL DEF'TH DEF'TH [ EF TH ,I. JR.=,E ~:OLIRE;E I N (.'.: L I N A 'r' I o N D I R E C T I 0 N DER M I N DEGREES ]3F,3.-LEF; L:; E V E.' R I 'T' Y D E G / 100 T o T A L Fi E C: T A N G I_l I_ A IR C: 0 Cl R D I Iq A T E S N 0 R T FI / S 0 U T FI E ~ F; T / N E'.:; T VERTI" ",:. SECT z ._.,q 30 c"~ c) 299'F'. 96, 2';? 4 7.96, :B100 3099, 95 :2:047.95 .-! -"1 ' .=,= vn. ._, eO ............ ....... I ,--i ::: ::: A 0 ::: :299 6, 5 .:.,.~ 47,/:-, .5; 34 00 3 :-]'F/9.00 3347.00 5:: .... 5 ()0 ..... 3497" '74 '-':,44._~. 74 .... z,._ ...._,. 74 _ 43 74 :2:700 :2: 6, 9'::.'. 67 .3640.6, 7 L:: ~: Oi) ............. .:,"~ 7,:,,:,. '~' '-'-' 2/-;_ ..... !~i7 :~:6.2/-,_. ":":" 0 0 .':, c, c, .-., · - ..... .. ....... ... 32 4000 3974.94 41' 00 .... 4065. R 9 4200 4154 ':":' · I__1 4:B00 4L-.'42 · ._=,5 . _.-,..' ; · ; / 4500 4417..'.7.:::3 4/:,00 4504.59 4700 -'4.5';91.6l'? 4 liE: c:)(Z} ,- 467 :----:. 4' 6' 4900" 4765. 6,1 5100 4';? 42.6, ~.~1 52 C:, 0 505: 2. :2: 6, F, 4 0 ('1 Pi '~ . ..... ..'14 12 ~ 5 C] 0 c..'r .-. - ~' ...... ',:, (J .J · :--'~ 8 5700 38:2:0.32 :3'F;'.P'2. '.:.) 4 41 o2.8:3 41 'F'O. ~= 4277.97 4.:, e,._ 3:3 4452.59 45-3,.-.-,. 6,.-.-, 46,26.46, 471:3. '6,1 .... 4 :--i'01.7 :--: 4890. 49 :--: 0 · :36 ...... · ~n7(i - '94 · _,162. 12 ~']'--'.=,':' 3 :2 :B? S 65. 0 · _~ 1 ,_,':' S 72 .50 7 4 G1 ~;l_, '~"' [-_., . :~":-: c:} 1'0 I._, = ::::9 .1. :241 E; 80. :::0 1.5; 41 :::; 78. :1. 9 21 1:3 :'B 7:B. :':-:9 :2:3 '7 ':' 80 1 · .,~ . . · '-'= ~':' '-' ·/-,9 · .: ..... ',El .1. 28 2:E: S L--:O. 19 · -:, c,F'] ::: .. ..,_, __ t--; '29 7 :-5 78.69 F; 77. ::::'.-.? · _,':' '7'7. :::'::z_ .. :--; 77.80 ':'77 ':'7::: :---: ~'?. :_--:0 S 75.5:0 S 75.10 S 72.89 '._:: 7A. :5:'? .-. · :, 78. 0 29 7 '2'.-."', 22 · ::.,'F' 2:_--: :2:0 7 2:_-: :--:4 2'7 44 26 4L:: '":'~ ':IF' 24 '29 2:_:: .=,':' 24- 1 L:: ....... · " (.~ '--'---" 4 .... .~. (,.~ .o.." Z(.) -_-, 54 ~--:'F'. 80 545:7.80 "::. ' 1 5'? S 7',3.89 55:_::2.43 55:::C). 4:--: ":.."218 S 78. 56, 74. ::::0 ' 5622. ::: 0 22 4 ::: S 7 :::. 89 0.74 0.84 2..1. 0 '"" 69 ..'_, · -' 94 · .2.51 :2.92 ':' 07 3. 19 '-' 7':.? ':' 20 · ~, .,:. 91 2.5:1. 0.7:3 0 ':'"" 0. :39 (-) .-,r_- . ~ .""!,..I 0..~.:i 0, 76 1,77 0. L--:8 2.06 1,17 1.4 :--: 1,52 ('), 7:_--: 2.06, 0.44 0. :.-:: 2 0.4.2 · :,.9'7 S 4.6,2 W 4-..=":'1 S 4 . Zl.~_ W 5.46 S 1 . ':,":'..._, W 7.8:'4 ,.z; 4. 558 E IP ' 5'? I'E; 15' 74 E 10.14 S 31.39 E .1. '-.' (')'7 "" ~ 1 :1. '= 16 /.,o :_:.; 7~ '-'= E · :24. 10 :!:.': 10:3.59 E :]-:4.00 C; 1. 36,. 04 E 42.51 S 172.74 E 4'.-.?. 02 ::-; 21:3.77 E /-, 2:2 '-' 2~:::.:36 E -- , .~, _ -- /-,4._ .77.:,'-' .... ::c')/-,. 10 E 74 c'):.':: S ':'F,':' 7/-, E · . _ ._1 ._ ._1 1 94 '-'= , ..:,._, '.F.; 449, ].:':-: E 104.90 :E; 4. 97.12 E 11 !5.7o S = =' E '-- o4 .... 6,2 1 '..-_':6.0::: :::; -' 593.52 E 1:35.08 S 6:3':.-'. :--: 4 E 145. ]. :3 '.:; 6,:-':4.52 E 156,41 S 727· 24 E 16.8.07 S 76,7.96 E 17:::. 94 ~-':; 807.5:3 E 188,00 S 847.40 E 195.71 :.:_; 88/-,. 2:2 E '.:::(')2.75E'; 'F'2:7._-:. :2:9 E 210.04 L:.; i? 60. 2..'::E: E ":' 17 44 S '.-? 97 :::;-, E ..'_ · · -- - -:3.72 -:3.51 -0.79 6,. 07 17 ":'.=i 32.79 ~5 .-., ~.-_, 77.05 1 (')/-, · '-~'-' 140. 10 177.77 219.27 :264.8 ::: 312. c.-, :36,1. 410.08 45:--:. 9:"-: 508.06, 557.75 606.76, ='-' '94 ~/_~ ._1 .', . 6, ';? '.?. 7:2: 74:2:. L::5 7:::6. OL--: :--: 27.02 867.91 '707.4 'P 45.2 '.-.; :::'.-'_'. '.'?' 1. 10 21.21 C 0 N 0 CCl ~ ]' N I_-.'. C- 15 MILNE POINT ALASl<A SF'ERI'RY-'SUN WELL SURVEYING CL']MF'ANY ANCHEIRAGE ALAF;i<(:I F:OMF'I_FFAT I ON DATF MAY :2:1 VERTICAL SEF:TION C:ALCLILATED ALOI',IG F:LOSLIRE I"lA T E OF SI_IRVE Y MA Y :30 -, B 0 S L:; G Y R F/E; F: i.-.i F' I F': :.:; I_1R V E Y .J 0 B I',1 I._1M B E R A K - B O- 5 C)C) 54 KELLY BUSHING ELEV. = E~F'ERATF~R-D. HARGER, T. F'A Gl_:" "::' 5:2.00 FI-. MCGIJ I RE ..................................... ]'RUE SUB-E:EA MEASLIRED VERT I F:AL VERT I C:AL DIz. F ] 14 DI--F'TH DEF"I'H C: (] U R S E...... C: 0 LI R S E '1 ~1~.'" I I,,I C L I N A T I 0 N D I R E ... I I 0 N [lEG Fl I N I]E:F:iI:?EEF:; D 0 G- I_ E G SEVER I TY DE G / 1 C!O ]"01-AL ' IR E F: T A N G I_1L A R C O 0 IR D I N A T E Iq El R T H / F:; O I..I T FI E] A F; ]' / W E F; ]' VERT If" SFCT 1 6. 000 62Ci0 6:B00 6400 6500 6, 6 0 0 6700 6,:, U U 690C) 70 (] 0 710 0 7200 7:B00 7400 7500 75:30 7600 7665 =,- ,-, / .~ ,~ '-, /.':,.-,.',':,. `1. 1 :,._ ~./. 11 .."-'1 66'72. 51 6,640. 51 20 ,--1 ! 67,:,,:,. 0 C) 6, 734. C)0 2 C) 6, :--: 79.4.5 6:2:27.45 2 C) 6' ,.~.~l 7 :'::. C) 7 692 `1.. C) 7 20 '70/",7 ..... 2'=; 7015 '~''=:''--' ........ ' 1:2: 716'2. `1.1 7110. 11 17 7190. 70 71:2:8. 7 (') 17 7257. 4'6' 7205. 46 `1. 7 7:':': I 9. 4'6' 7267 · 46' i '7 49 7 4-1 1'? 9 :'2:9 6 46 4:--: 52 17 57 54 · ":, 0 ..' 2:_--: ':' 7:2: 6C) E '..'.-".: 78. :2:9 E S 79.1':') E ':'..., 7:'_-'.':. 3C) ..- '.B 72:.6'F~ .Z .:, 7F:.F:9 "' S 7:2:. ::.':0 - ....... S ' 79./-,9 _- S 77.:2:0 :_- S 79..:,'""c.) Z S 7':.'~.:_::0 ] '.--; 79.39 E' F-'; 7'.?. 8(') E · ::, 1. 10 E-] :2; :2:0. :2:(])E c-81 :_--:0 E '.--; ::::1. :3() E .:, :::1. :_--:0E ('). 21 :2:: 25, 01 F.-; 1 C)35, 8':T,' E (). 1 ,r') 2:.-_-:2.75 S 1 C)'7:2:, '..-T.'/:, E 0_. '7'7 :24. C) .0 C) :.z.i 1 1 :L ...'-., :34 E (') 39 247 C) 3 ':' 11F;1. 00 E . n u ,%.' -- n '--'/'1 11 :::':;" 1 P' E · ..... · .,".._! _ C). 1. 9 2.'..:E, 9.60 S 1263.8:3 E 0.5C) 276.82 E; 130C)·44 E C). :37 .~.":',_.,c'._,':'. 68 .:, ''"' J. :::_ :::_ 6. · 57 E 0.4. 2 2'.-T/0.3 C) :2; .1. :--: 72.29 E (')_ · ._,...':' '-.' 2_ ':.?./-,_. '-?.. 4 '.2; 1 ,I-C) 7 · 41 E C). 02: :B0:3.53 F.: 1442.28 E C)_ . C)_ ':)..:2:10 . .1. (')_ S :L 4 '77 · ..- ._,'-' '= E 0.61 :2:16.4. 5 '.:.; 151 `1. · :2::2: E .1.. 4 C) :2:22. C):2: S 1544.94 I-- 1.C):2: 327.14 '.2; 1576· 15 E 1· 7:2: :':: 2:2: . ._, -=''.:~ :2; 1o '=,:,'-'._, = . 15 E c). C)0 :B 31.77 E; 16, C) 5.9'2: E (:). C) C) :2:34.7:2 :--; 1 &,'.25.21 E 1059.98 1098.84 113'7.88 1177· 17 1216. c)'? 125 4. :':-: ::: 1 '-F"?2.2:'-] 1329.55 136. 6. :32 1402.64 :/4:3:2:. :--:7 147:3. :2:6 ._l L) .-/· 4 2-: 1544-. ~'-' · _, / ,.-_, · . 16o'? · 74 1 ~ 1:3. :2:5 16:2: 9. :2::2: 165'?. :32 ............... -FIOF~IZF, NTAL DISF'L'AC:EMENT' 1/_-,5'F;'32- 'FEET AT SOLITH 7::: DEl3. 2`1. MIN. EAS'F AT MI':f = 7/_-,6,5 THE CALC:I_ILATION F'ROCEDIJRES ARE BASED AI',I THE USE OF ]'FIREE D IMENF;If]NAL RAI]II_IL:; L-JF C:URVATI_IRE METHOD. F':ON ~-~F:n .-, T_ N C. ~;:- :1. 5 M 1' LIqE I'"'011'4 T ALA!:;KA SF'ERRY-'.:;UI',I WELL F;URVEYING .-:OMF'ANY ANCHF~RAGE ALAL:;I<A C I"l M F' U T A T I 0 N Fi A T E I'1A Y 31, 1 '.-.-/85 PAGE 4 DATE OF :2;URVEY MAY :'-'~('~,_ _ :1.':'/'-':'.-..:.,._, ,_IF~B NUMBER AK-BO-50054 KELLY BU'.:];HINr-4 ELEV. = 5:.2.00 FT. F~F'ERATOR-D, HARGER, T. MCGLIIRE I NTERF'OLATED VALI_IES FOR EVEN 1000 FEET OF MEA'.:;LIRED DEF'TH ..... ] R JE F;I IB-F;EA TFITAL MEA::;LIRED VERT I CAL VERT I CAL RECTANGULAR C:I]II]IR f-I I NATES MD-TVD VERT I CAL DEPTH DEF'TH F_IEF'TH NFIRTH/SOUTH EAST/WEST D I FFERENRE CORREE:T I ON 0 0.0(-~ -5'.'2.00 O. 0¢~ O. O0 0.00 ................. .1. 0 d (_~i ..... '.'.-9~;; ~ ".?:=:"~;"'-":. 4/. "-"-':., ,=,'"';...'.. 5/,' "i~:i_ ...... 3 , :--:i W ' (').. ¢)2 .... 0 . ('~'. . 2000 1 'P'.-.-¢'.~. '? 7 1 'P 47, 'F~ 7 1. '? ,/_-, :--; 5.2'.-]) W 0,0 ::-: O, 01 3000 '2'P'P'F¢. ?6 :??¢47. ?/:, :':',, '.:.,'7 S 4 ,, .62 W 0.04 0.02 4 (') 00 :2:'? 74. '.::'¢ 4:2:'? ";.'2 :.7, ? 4 42.51 :::; 1 '72.74 E 25, 06 :2:5.0 :;2: 5000 _zl- ':' 5 ':',_, ._ ._,. 7:_--: 4::-:01, 7:-: 1":'~._,._ . ('):::. _ ._, '=' 637.84 E :1.4/:, . .-.":"-.'.. 12::1. . .1. A_ /-,(")0(] % 7/'-,/-,. 'P::":..:, 714 '.~8 'F_.'2'R, 0 '[ F; .1. ' '~' ''=': :::9 '":' ............... (_)..:,._,, _. E :2:':::2:, 0.,... 86.80 70(:)0 ,':,/:,......_ :i." ,.,:¢.-~;"'"r-; ....... /_.., /.~'21. (') 5 :L 2'F,'6,74""'S ......1 407.4:1. IF. ..... ::-':0_ 7.4'.:.;' 74 .4.7 ' 7/-,/-,~ ""'-' / .:, 19 4/-, 7267 46 :2::2:4.7:;.2 ':' 1 A 2.-'=; :21 E '-' "' .::,::,, . ........· _, _ _, .., 4.:, , !='; 4 "" '" (') 4 ........... ]'H E' F': A E F: U L A TI F~1,4 F' R F~ cE [~ U R E S' A R E B A :2; E D O N 'f' H E ' LI ::.'; E'O F ]' FI R E E I"~ I M E N'.'-"-'; I O 1`4 A L R A D I U ::; F~ F' C U R V A T U R E M E T H ~"~ D. CONACO, INC. C- .1. 5 MILNE PAINT ALASKA SF'ERRY-'.--;I_IN WELL SURVEYING CC~i"'IF'ANY ANCHORAGE ALA:--;KA CFH"IF'UTATIFiN }]ATE MA Y :':: 1, 1 '?:E:5 DATE L-iF '.-;URVEY MAY JOB NLIMBER AK-BA-5C:'C)54 KELLY BLI'.--;HING ELEV. = AF'ERATOR-D. I-IARE'iER-, T. TRUE MEA'.--:LIREF~ VERT I F:AL DEF'I-H DEF'TH I NTERF'OLATED VALLIES FOR EVEN it)c) FEET OF RUB-SEA DEF'TH SI_lB-SEA TOTAL VERT I CAL RECTANGI_ILAR I]:00RI] I NATEL=; MD-TVD I: E P T H N 0 R T H / :-':; A I_1T FI E A ~-'-'; T / W E ~::; T D I F F E R E N C E VERTI CAL i.-_: t']l R R E F: T I I"i N -52.00 0.00 1 ¢)0.00 200· 00 :B ¢)0, 00 4 c) 0. c) 0 50C). 00 600i'¢i6 70c). 00 t-':', 00.00 · '? 0 c). 00 1 ¢) 00.00 1100. O0 i'200.00 1300.00 1400.00 1 .... .~-] '] ~'-'1 ._,._ ..' .~-- ~ '-' 00 i 50 c')_. ¢)0 .1. "="-, ~.':., a, ._, ..' 16._... 00 .1./-,_ 0 C) . C) ¢) 17._ 4 17....-'. 00 1700.0 ¢) 0.0c) 0. ¢)4 c). 71 .1.. 32 '2.22 "::2.57 2. '7"-- · .... 76 ,':.. ,- 7 2. :.-..: 7 2. · .-. 27 ('). c)0 :.'.:.'; ("). 01 "-' 0 '-' "= · _, · ..'L ..'l '.B 0.80 c, ¢). 96) S 1. :_=:4 S 2 '-'= ·._.1._1 S 3. ¢)7 :.-.-'; :;-':. 41 ¢'" '-, ":, '..--; :3.2,::) S :2:. 4:3 3.68 4. 4.47 4.53 4.85 5.21 5.4:2 0.00 W 0.00 W 0. W 0.01 W 0. F) 1 W 0.02 W C). 02 W c'-). c)2 W 0.02 W F). 0'2 W (). 0:2 W 0, ¢)2 W 0.02 W 0.02 W 0.03 W 0.03 W 0.03 W 0.03 W 0.0:.--: ¢). 00 0. C)0 0.00 0.00 ¢). 0C) 0.0() ¢). 00 0.00 0.00 0.0() 0.00 0. (}. ()() 0.00 ¢). 00 ¢). ¢). 00 0.00 FI a 13 E 52. C)() FT. MF:GLI I RE CONOF:F~, INC. Il:- 15 MILNE F'OINT ALA:E;KA SF'ERRY--SUN WELL ::31_IR'v'EYII',IG C:r]MF'ANY ANCHORAAE ALASKA C 0 I"1F' U T A T I 0 N D A T E I"1A Y :':~ 1., 1985 I]ATE OF SI_IRVEY MAY :i::0, ,_IFIB I~ILIMBEI:'< AK-BO-500.=;4 KELI_Y BLISHING ELEV. = OF'ERATOR-D. HARGER, T. F'AGE 52.00 MCGU I RE I NTERPOLATEI] VALLIES FOR EVEN 1C)O FEET OF RUB-SEA DEF'TH TRUE MEAL:;L.IRED VERT I CAL DEF'TH DEF'TH SI_IB-L:;EA TOTAL VERT I CAL REF':TANGI_ILAR CF,-IRD I NATES MD-TVD DEF'TH IWE~RTH/'.--;nI_ITH EAST/WE."ST D I FFERENF:E VERT I E:AL C 0 R R E C T I 0 ixl 5. ("~,'? W 4.69 W 4./=,'? '-W ..... 4./_-,:3 W 4.35 W · · :,. :.--.:6 W 4. :_--:7 W 4.. :E:O W ?':. 81 W 0.92 E 9. ::2:9 E ~'-' .:,'-;. ~:'"/'--, E' 41. ::-:4E 64. '="" · --! °.~ E 0. O. ¢,".). (:). 0. C). O · 0. O. ('). 0. 0. ("). 0. C). 1. !5, 0 3 · , 03 0:3 03 0:3 0:3 (:):3 03 03 (-) (:)4. (:)4 06 1',? 64 54 27 :--:8 0.00 O. O0 O. O0 O. O0 O. 0() (). O. 0.00 O. C)0 ("). O0 O. 00 O. 01 O. O. 01 O. :l 4 ,r'). 44 O. 91 1.72 /..'.-.0 2 ...... FT. C:ONOCF~, INC, F:- 15 MIl_NE F'OI NT AL A'.:-;I<A SF'ERRY-SLIN WELL '.::;LIRVEYII',IG CFIMF'ANY ANE:HORAGE ALAF;I<A C: 0 M F'LI T A T I F~hl D A T E M A Y :B 1, 1 '.-):{:5 DATE OF SURVFZY MAY :--':0, ,JOB NLIMBER AK-BO-5C)O5Zl. I<ELLY BI_IF;FlING ELEV. = OPERATOR-D, HARGER, T. F'AGE 7 · =, 2.0 0 F T. M L-: G U I R E I NTERF'OLATED VALLIES FOR EVEN 10o FEET OF L:;LIB-SEA DEF'TH ]'RUE ::;LIB-:Z;EA ]"OTAL MEAF;LIRED VERT I CAL VERT I F:AL REF:]'ANGULAR C:nOR[~ I NATE::; MO-]'VD .......... DEPTH .... DEF'TH ' DEF'TH NF~RTH/'._:;CIL.ITH EAST/WEF;T DtFFEREI',IF':E VERT I C:AL C 0 R R E C T I 0 N '-' .=;'-' ':~'.--' :.:.:7 :2:761 .:, 7._ ..' C) 0 :37 C) 0 C) 0 20 78 ':' ................... :'B:::/_-,7 .... 3852.00 i':::::00. ..... C)O ....... !EiCi':"?_-,'?-'c.' ............ 1 z.'s.=; .._ (.)- ._,=' 3975.:,'"' ,-v; ._,=' ...-,. 00 ..... ::: '? ¢') 0 . C). O_ 40 .72 S 16:7::...,._.'-' ._, '= 40:34 405'2, ('}(') 4000.00 48.04 '.:; 207, 16 .......................... F,~', "'"= '"" '-' :25'7:3/-, .... -41'.?A 41 ._ ..'. 00 41 O0. O0 ._,._,. -..~6 .:, . _ 431 (')_ 4 ,_'.~' ._.=; ..'-.'. 0 (') 42 o c). 00 /-_,._.=;. 74 :::; :':: 1 I .24 · -'F, '-,.=,'-, . '-' _:, A .5 ., 79 44...._ 4.:,._.... O0 4:--:00. O0 76 44 :--: E '?. :::'? E ' 15.5:_:: ..:..:,. I 1 EE :]-:'.Z.'. E 44.79 E .=;':' E 72: '" .~]. E E .1. C)":'...... 4.:1. F:'" 1. :1.7.4-1 -_ 1:3-'.--':. 5 0 Z 145. _,,.:,. 4'7 :.] 1/_-, ':T/. E .1. '79.94 Z . 189.46 E 1 '?'iF~. 0 7 :.'-':~ 207. '2:.:.: :: ':' :l .~; 11 4. ('):L 5./_-,8 ' 7 .'=;':' '?. 4::: 12.20 14.01 14,4:-" .1. 4,7:':-: 15, 00 15. 1':' 49 .1. 2,4:.-]: :1.1. :-"-'.:,.... 10. 15 9 .r-] .":, '?. 61 ::::. l 6 '7.8'? ~-~ 0 N F~n 0: I N C. C- 15 MILNE POINT ALASKA SF'ERRY-SLIIq WELL SURVEYING COMF'AhlY ANE:FIORAGE ALASKA C: 0 I'tF' I_1T A T I 0 N D A T E M A Y :3.1., 1 '-?':' DATE OF SLIRVEY MAY :30, ,JOB NUMBER AK-BO-5C)(')54 KELLY BLISHINLq ELEV. = F~F'ERATOR-D. HARGER, T. I NTERF'OLATED VALUES FOR EVEN 1 (') (]) F E E'T 0 F S I_1 B- :--; E A D E F' T H .... I R JE S~. IB-:--;EA MEA.'_:;LIRED VERT I CAL VERT I F:AL ............ DEF'TH DEF'TH "' DEF'TH TOTAL REF:TANGULAR F:OORD I NATES NEiRTH/SOUTH EA.ST / WE.'_--;T MD-TVD D I FF'ERENCE VERT I CAL C A R R E C T I 0 N ._ ,:, 7._ 5652 00 5/:, 00 00 ..........................._,='-.-.¢ ,:,'-;'-',:, ........ 57.=,2_ , 'ciri ........ ............. ~7P'¢)'~' On 2:32 1 "-- "" # ._1 ..~ 1 1 5800. O0 5'.-.-,' 00.00 240. ('~/:, 6000. O0 ....... 247.74 'S 6100. O0 25/:,. 04 S /:,200. O0 2/:.4· 2:l S /.:,300,00 272,'i /:,400. O0 279.83 S 6500. O0 28/:,. 93 S 70/:,:2: 6752.00 6700.0() 301. 1:2: S _1. 717 C) /-_, ,_,':' ._~ ..'-". 0 C) /-, .... ::: ¢) (') .0 C) :::_ ('). :::_. 17 ._,':' 1 .......................... 7'277 6 ? 52,-O0 ............ 6 !~,07': ~)0 315, 0 .*', i-, 7 .--., ,:, .:, 7 (') 52.00700. 0 ,00 ._,~.":' ".' _1. , .....~':' '--" S 74.:--:':.? 715':..". 00 7100.00 :326.59 'S .1. ..................... : ..... 75?.')4 .......... 7':. ~5'::. O0 7200.'00 :z:'::: 1: 7/:,65 7:2:1 '.:.>. 4/:. 7267.4/:, :2::2:4.72 S I 22:3.2 :::: _ 231.74 071.0:2: E 240. 2 :.'3 11. "/.-.'./:,:--: E '248. ::: 54 '-'~;"" 1 7:2 E . ..'._ / /:,5 :1. 1 '.'.'-/ /:, . (_")4. E 266. 17 1236.51 F :274. :2:/:-, i 27/:,.._~._, E .,_c" :::,.-.;-'_ .._.._,'":;/- '_, '-" :'-]. 290 1.:,1... /:,5 E .. 1:2:54. :2::_-: E 297.4'.:.;' 3'P2.2'.'-;' E ?-:04. /_-.7 42'-.~,' Pi'-:;' E ".:::11 /-':' · e ~ . # 466 .-.¢..., E :z:l':' /-'.-" [. t_, · _, d.. 5o4 E .... .54 "'-'-'":/ ':'"-" t :.'3 '7 · J.:,:: 7'7 E # .~! .~! # ~ .... ' '-.?::~ :'-~37:37 · - /.," ~ . - E 6 n. 4. ~.'-:' .,~'-' E" :342 , ......", '7 /:,25.2 Z E :--~4.5.54. ':' 17 8.4/:, ':' 54 ':' /:,2 i_! I 8.75 :.--.:. 5:2 ':' 19 ,_, # · 8. Cx) .... '7.65 7.48 7.18 6. ':.76 6. '?8 6. ?2 5.50 4. '.'-) 0 :3.27 ........................... TFIE'-"'CAiZ iS:Ii CA T i OKi' '-F~'~OCE'DCiRE:!;; '"i-isE "-~-' '-'Lii'NEAk~ ....... i kiTEI:~F, OLA T i 0N BE i-WE EN ......... THE NE~RE!_-';T 20 FOOT MD (FROM R~DIUS AF F:LIRV~TI..IRE) PRINTS PAISE,:,'-' 1 'P:--:5 52·0(:) FT. MC:GLI I RE ALAF;KA :::;F'ERRY-SUN WELL F-';LIRVEY:ING COMF'ANY ANF:HORAGE Al_ A'._--;KA C Fi h'l P U T A'I' I 0 N D A"F E MAY 31, 1'-'-'~ .':! ,_-~ ._1 INTERFu]LATED VALI_IEF: FOR SF'EF:IAL F--;URVEY F'OIN]'L--; TRUE F;UB-'.E;EA MEA'.:;LIRED VERT I CAL VERT I L-:AL DEPTH DEF'TH DEF'TH TOTAL R E F: T A N G I_1L A R F: F~ 0 IR D I N A T E ?3 NF~RTH/SOUTH .... EA'.=;T/WEF;T MARKE:'R · .:,7._ ... :2:742.55 :3,/_-, 9 C). ._,=":-.:, :%..:, '~,=, u""'l ........ ._-,""' 7" ''''`~,=, ~-~>"'-.-., ...'" 1 ........ ..-,;";"7 ";"..-, 7 ......, .,::'"" :t · ':, C, ~ .-., .-, ,-, .-, · _, ....... ,=,,:, o,=,. 32 :378/-, '-"-' _ · .-,.~. :3897 3 L=,' 7 9.._ ~ ._,'=' :3 :=: 27 , .... ................. !q 9 :::.~ 3 914.8 :--: :3,,_--: z_-, 2. :--: 8 ..:, .~,:, .~, :'::'P4t':,. 36 :3894, 3/_', 40:_::0 40c)2.44 395C). 44 ..........................41 .,:.:=; 4. ...................... 4 C'~:''; a ,=, 7.47 4 u ' .",:~'._,. 47 42C)F, 4159 '-"-' ..... z..':, 4107 '-" 4317 4257.4:2: 4205.4:3 4:3 :'::A .... 4'274.0='-, ' 4222. U" .:,'- 4..:,.j,:, 4:.?.-,'3 '-"-' . · .,.' ,=, 4241 2 4 :':: 81 4 :-': 1:2:. 37 42:: 61. :37 ~ ~i?;;? 4:~i2'~, .t d ....... 4277, j. o 44.:,/ 4:--:62. '-'C . .... o .) 431 c) :'=-:C) '-' /- 27 . 445:3 4..:,7 ~,. 4:324 :.27 45 ':: .~ 4447. '~'¢..1. .~,~ .:,'-, ,':¢:: ._,,:. ,:..2. 1 4- 6':T/2 .~'-' R"" '-' 4 .... :,4.72 4._,:,.-', 72 /:,97C) 6664 46 661 "" , , ~:. 4/_-, 294 96 ................................................................................... I<F': KD LA LB MA IdB' ' MC: NA NB NC: , ND FIE NF I.'.'1A OB '.-'.~ 5/8" L. F:R. DATE OF SURVEY MAY :30, ,_10 B I',,11_1M B E R A K- B F~- 5 C:, (') 54 KELLY BU'.E;HING ELEV. = F~PERA'I"OR-D. HARGER: T. F:SG UN. PAGE '.:.,' 5 2. (')C) F T. MF:GLI I RE C 0 N 0 E:~-~: I N C:. F:- 15 MILNE F'OINT ALA'.:-;KA SF'ERRY-SUN WELL SURVEYING E:F~MF'ANY ANCHORALqE ALA'._:;KA COMF'LITATION DATE MAY 31, 19:::5 F'AGE 10 DATE OF SLIRVEY MAY 30: 1985 ,_lOB NLIMBER AK-BF~-5C~o54 KELLY BU'.:-;HINLq ELEV. = 5'.'..'. o0 FT· OF'ERATOR-D. HARGER. T. MCGLIIRE INTERF'OLATEFI VALUE:--; FOR SF'ECIAL F-;URVEY F'OINTt:-: MEA::;LIRED DEF'TFI ]'RLIE ::;LIB-SEA TOTAL VERT I CAL VERT I C:AL RECTANGLILAR F:F,_]RD I NATES D E Fi T H D E F' T H Iq 0 R T H / :-:-; F~ I_1T FI F A F; T / W E '.:; T MARKER 702:2: 8,714.01 8,68,2.01 '.F'98.45 S ~ i~ 0::: ....... ~, 7':.-):S-: ~' 4 Fi /:.:,741~.'418 ~-:02~. (]~ 72:28, 8, '?,c~ 3.7.5 6 :::: 51.7._'9 :2:11. :--': 0 724 0 6918,. ,_,._,':":'6 :--: 8, 4 . ::] 3 ._,':' 12 .72 S ,,,~ .-, ...... /.:, 14 6':.-/86. 20 6'.-.-,':z:4.'¢ 20 :317. :31 ,.E; 7::';:37 7007. 77 "'-'='~'"' 0.:'..- ..... 77 ..:,'-'1:'-":. 72 '.::; 74' 11 7077. ,'",_ R- 70...'.'-' ._,"--. ,'::, ._, '=' :::_ .,-.C" .... "2. F, 9 '.:-; .1. 4 _1. 5. 4:2 E MKR 1 'F-' _1. 4'4 5. ,F~,6: E " T 7 KLIF'. I N T .1. 4 :-] 6. :36 E T / MK 1 1491.28, E T/LZ 1518,.8,1 E T/L8 1524.4.8, E T/L9 .1. 548.4. 7 F ]' / L K .1. 1557.46 E T/LK2 158,/2,. 15 E B/LK2 .~. 5 ::: -'[ ':":' E B / K I_1F' I N T 1..11..1 tn .1.585. 15 E SLIRVEY DEF']'H 1597.8,1 E P.B.T.B. 1/-,25.21 E TD C ~CRLE :- I INCH TO 500. O0 / '=~,,u,.,. ' M~ 30. -500. O0 · 7665 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OP~.~L~T6R, ~-ELL NA~E AND Reports and Materials to be received bY: Date Required Date Received Remarks' Comp let ion...,.-.Rep°rt , y~---------~.~ Samples , i , ,, Core Chips .... .................... , ~z~~-. ,,- ~~ Registered Survey Plat ~n~a~on ~v. . ..... Directional Survey ..~~ ,. -.'. .~ ~/~ ~o~ ~u~ 7e~, 7..o~_~~ ~~~, CO~;OCO, INC. SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEASE liE:PLY TO PAGE 1 OF 2 SCNLO..E.~E.O~',.O"E'E"V'CE' POUCH 340069 3UNE 21, 1985 PRUDHOE BAY, AK 99734 ATTN: HOLLY BURGAN 320i "C" STREET, SUITE 200 ANCHORAGE, ALASKA 99503 Attention: MIKE BRADSHAW Gentlemen' Enclosed are. 2 BI~orints of the 2" & 5" DIL, LDT/CNL, CASED HOLE CNL/GR Company CONOCO INC. , Well ,NTT.NE PQTNT [TNTt C-1 5 Field MILNE POINT , County. NORTH SLOPE ~tate ALASKA on: Additional prints are being sent to: 1 BLprints & 1RF WEST COAST & .A/bASF~A DIVISION, 290 MuAPLE COURT, SUITE 284 VENTURA, CA 93003 ATTN: PHIL SALVADOR 1 BL prints & 2RF CHEVRON U.S.A., INC. P.O. BOX 107839 ANCHORAGE , AK 99510 ATTN: J. T,_ WEAVER 1 BLprints & CONOCO, INC. P.E.S. RESERVOIR SECTION P.O. BOX 2].97 HOUSTON, TX 77252 ATTN: GERALD KIEL c/o GEORGE LAMB 1 BLprints CONOCO, INC. P.O. BOX 1267 PONCA CITY, OK 74603 ATTN: H.E. GILLILAND/63 56RW 1 BLprints & 1RF ALASKA OIL & GAS CONSERVATION COMMISSION 300~ PORCUPINE DRIVE ANCHORAGE, AK 99501 ATTN: WILLIAM VAN ALEN The film is RETURNED TO CONOCO ~rints & 1 RF CHEVRON U.S.A., INC. P.O. BOX 8200 ATTN: DAVE ENGSTROM C/O LOUIS KLONSKY 1 BL prints & 1 RF CHAMPLIN PETROLEUM COMPANY P.O. BOX 1257 ENGLEWOOD, CO 80150 ATTN: DALE BOSSERT c/o BILL KIRSCHNER 1 BL prints & 1RF READING & BATES PETROLEUM CO. 3200 MID CONTINENT TOWER TULSA, OK 74103 ATTN: C.E. SEERY, JR. RECEIVED DATE: We appreciate the privilege of serving you. Very truly yours, /' ~~_.g~L5 $ iV SCHLUMBERGER OFFSHORE SERVICES DISTRICT MANAGER CONOCO· INC. 3201 "C" STREET SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 I~LEASE REI~LY TO POUCH 340069 JUNE 21, 1985 PRUDHOE BAY, AK 99734 ATTN: HOLLY BURGAN ANCHORAGE, ALASKA 99503 Attention: MIKE BRai]) S HAW Gentlemen: Enclosed are prints of the 2" & 5" DIL, LDT/CNL: CASED HOLE CNL/GR Company CONOCO, INC. , Well MILNE POINT UNIT C-15 Field. MILNE POINT , County NORTH SLOPE State ALASKA Additional prints are being sent to: 1 BL prints & i. RF CITIES SERVICE OiL & GAS CORP. P.O. BOX 939 BAKERSFIELD~. CA 93302 ATTNi NEIL BUTTRAM c/o JIM QUINN prints prints prints prin'L.'s prints prints prints The film is RETURNED TO CONOCO We appreciate the privilege of serving you. DATE: ._. ~ " ~:~s C, uns. COfflr~qiSS[Ot~ Very truly yours, SCHLUMBERGER OFFSHORE SERVICES CATHERINE GADOMS KI DISTRICT MANAGER STATE OF ALASKA ALASKA. .- AN D GAS CONSERVATION CC .... -MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-103 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50D29-21358 4. Location of Well SURFACE: 725' FSL, 2098' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 10, T13N, R10E 6. Lease Designation and Serial No. ADL 47434 12. 9. Unit or Lease Name ~:_ne Point Unit 10. Well Number C-15 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-15 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistantly with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post completion flow test left significant fill in the casing. Prior to the fracture treatment each well is to be checked for fill. If the C-15 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. 14. I hereb'~-~e'rt-ify that the foregoing is,,t~ue and correct to the best of my knowledge. :: ~::':(l) l ' ~' Sr. Production Engineer S gned ~ [ ~,,,.~v -,z.--- ~,- Title The space below for Commission~se Date 6-17-85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Approved Copy / ~turr)~ Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate .~_u~z~z'zUmAL TAPES TO: = CITIES SERVICE : BA~RSFIELD, RE~ING & BATES : TULSA, OK CHAM~LIN : ENGLEWOOD, CO CHEVRON USA : ANCH, AK ,~~ OIL ~ G~: ~CHO~GE SCMLU~MMRgMR OMMSMORE ?ONOCO ~ : ~CHO~GE 500 W. INTERNATION~i AIRPORT RO~ %ONOCO : PONCA CITY, OK ANCHORAGE, AL~ 99502 LO CAT I O N ' WELL NAME ' ~~ ~--/~ WELL NAME N_o 000085, ~ COMPUTINC CENTER PRINT CENTER SERVICES ' / "~////~/.~ SERVICES ' JOB NO. ADD'L TAPES NO. OF BOXES' JOB NO. ' ADD'L TAPES - w E t n N A M E ' /2Z'/~'Z a~ '-/5-- WELL NAME · SERVICES · / -- ¢'~/Z//~/5 SERVICES ;:¢¢-d 2.5~/zz- 5 - dPe/¢ - ~ ..m'~5~- ?~ g? NO. tXES' JOB ~D ' L NO. OF BOXES' JOB NO. ' ADD'L TAPES ' WELL NAME SERVICES ' NO. OF BOXES' JOB NO. · ADD'L TAPES ' SCHLUMBERGER COURIER WELL NAME ' SERVICES ' NO. OF BOXES' jOB r~ ~ ..' '/ /,,.,..',--....' ~.,~-~, AD'D'L TAPES : ' JUiv~ , · i~,bsr,~ [iii & GaS ~on~. Comm[~..~ion DATE DELIVERED RECEIVED B'Y STATE OF ALASKA ~,.. ALASKA O~L AND GAS CONSERVATION COn'MISSION ~/~ ,~i'~ :. MCNTHLY REPCRT .F RILLING AND WCI::L OVER OPERATI NS · Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 85-103 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage~ AK 99503 50-029-21358 4. Locauon of Well at surface 725' FSL, 2098' FEL, Section 10, T13N, R1OE, U.M. 5. Elevation in feet (ir]dm-ate KB, OF, etc.) 52 'KB 6. Lease Designation and Serial No. ADL 47434 For the Month of May ,19__ 12. Doth at e~d of monzh, f~t-~g~ driile~, fi~ing jobs, dir~ti0nal drilling problems, spud date, remarks Spud date: 5-21-85 Drilled from surface to 7665' during the month. Depth at end of month: 7665' MD 13. CasJ~j or ~im~ run ar~ quanzides of c~nent, results of pressure tests 9. Unit or Lease Name Milne Point Unit 10. Well No. C No. 15 11. Field and Pool Kuparuk River Field Kuparuk River 85 Ran 119 its. 9 5/8" 36# K-55 BTRC csg. w/float shoe @4692' pumped 35 bbls. 11 ppg. Sepiolita preflush, 461 bbls. of 12.3ppg. Permafrost - E w 5#/sk of Gilsonite; followed by 51 bbls. of Class "G" cement w/3% salt & 1% CFR-2. 124 bbls cmt returned to surface. Ran 193 its. 7" 26# L-80 BTRC csg w/shoe @ 7652'. Pumped 35 bbls. 12 ppg Sepiolite preflush, 250 sks. Class "G" cmt. w/l% CFR-2 & 3% Hal-24, displaced w/291 bbls of 10.2 ppg NaC1/NaBr. Full returns. 14. Corir~j re~,J~e a~x~ Orief description None. 15. Lc,!~_ run a~ d~h where run #1-DIL 7665' to 4692'; LDT 7665' Hole profile f/7665' to 6600' GR-CCL-Gyro f/o to 7540' to 7200'; CNL-GR f/4692' to 36OO' 16. DST dala. perforating data, shovers of H2S. miscellaneous data Perfed 7442' - 68'; 7338' - 42'; 7314' - 18'; 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE -Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7.1-80 S':3:-ILUbIB' OF:FSiqOPE 5000 GULl- -,~EEWAY, P.O. ~©X 2175 PlY, t~ASE REPLY TO POUCH 4 F. PRIJDHOE BAY, ALASKA 99734 July 4th, 1985. Alaska Oil & Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, AK 99501 Dear William Van Alen, The enclosed RF Sepia Litho Density/Neutron (Raw Data) is to replace the Litho Density/Neutron (Raw Data) o~_~3inally sent with ~lne Point URit ~-l~The orig~ /RF.SeDia had a typo error on ~t and was named as Milne / Poin~ Unit C-13 by mistake. Please destroy previous Litho' / D~n~ity/Neutron (Raw Data) RF Sepia marked Q-13 and replace ith~corrected enclosure. I hope my error has not caused you inconvience. Sincerely, Holly Burgan~ Print Clerk A DIVISION OF SCHLUMBERGER LIMITED R'ECEIVED o Alaska Oii& Gas Cons, Commission' AnChorage M EMORAN OUM State of Alaska ALASKA OIL AND GAS CONSERVATION COI;R-~ISSION TO: C. V terton TliRU: Lonn±e C Sm±th .... i-:. ¢ommi s s loner DATE: May 29, 1985 FILE NO: D. HRH. 37 TELEPHONE NO: FROM: Harold R. Hawkins Petroleum Inspector SUBJECT: Witness BOPE Test Conoco inc., C-15, Miine Pt. Unit, Sec. !0, TI_N,Rt0E, Peinnit No. 85-103. Saturday,_~M~ ~5, 1985: · 1 f c another report to ~-6~oco's--Mi~e P~i~i Onit. i e e O test on Conoco~s well No. C-15, there were no failures. I filled out an AOGCC report which is attached. In sum~_ary, I witnessed the BOPE test on Conoco's well No. C-i5, at Milne Point. %R~en AUDI crew on Rig #3 completed the test, it was satisJactorily performed. Attachment 02-001A(f4ev. ~0/791 O&G #4 5/84 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date ~,/ Well / Operator Well Location: Sec Drilling Contractor ~9/' Location, General ~'/~,'~/ Well Signff/~4~, General Housekeeping .~/-~$qRig ~/~/~.y . Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams__ Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure min,~) sec. Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: ~ min ~ sec. Controls: Master Remote ~/f Blinds switch cover Kelly and Floor Safety Valves Test Pressure_, ~- ~Pd CD Test Pressure .~'-~p ~ 65 Test Pressure_~ ._~]//-~f ~{ Test Pressure .... ~7~ ~5~ Test Pressure ~7~ 6O' Upper KellM Lower KellM Ball Type Inside BOP Choke Manifold No. Valves No. flanges Adjustable Chokes T~' C~ Hydrauically operated choke Test Time / hrs. Repair or Replacement of failed equipment to be made within' ~days and Inspector/ Commission office notified. Remarks :, / · Distribution orig. - AO&GCC .. ~ .,..? :~ j . cc - Operator ' - ~" cc - Supervisor Inspector. , . . May 17, 1985 Mr. Don Girdler Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. C-15 Conoco Inc. Permit NO. 85-103 Sur. Loc. 725'FSL, 2098'FEL, Sec. 10, T13N, R10E, UM. Btmhole Loc. 4832'F~H~, 403'FEL, Sec. t0, T13N, R10E, ~IM. Dear Mr. Girdler: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa~ning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Don Girdler Milne Point Unit C-!5 Ma~7 17 198=; To ~.id us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I,~ere a diverter system is required, please also notify this office 24 hours prior to commencing equ~,pment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. BY ORDER OF THE COmmISSION b~ Enclosure CC: Department of Fish & Game, Habitat Section w/o eno!. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (9O7) 564-76OO ~,~ay 15, 1985 Mr. C. 17. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point C-15. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Don Girdler at 564-7637. Very tru].y yours, John R. Ke~mp Manager of Alaskan Operations DRG/vv cc: MP C-15 Correpondence File RECEIVED MAY 1985 Alaska 0il & (~as Cons, Commission Anchorage la. Type of work. STATE OF ALASKA ALASKA Oru AND GAS CONSERVATION CO~,MISSION PERMIT TO DRILL 20 AAC 25.005 DRILL ~ lb. Type of well REDRILL [] DEVELOPMENT OIL [] DEEPEN [] DEVELOPMENT GAS [] ~ ") l,:/.~, · SINGLE ZONE [] MULTIPLE zo N ~ ~j~,/ ~ 2. Name of operator Conoco Inc. 3. /iddress 3201 "C" Street, Suite 200, Anchorage, AK. 99503 4. Location of well at surface 725' FSL, 2098' FEL, Sec 10, TZ3Np R10E~ U.M. At top of proposed producing interval 4800' FNL, 600'FELp Sec lOp T13NpRZOE~ U.M. At total depth 4832' FNL, 403' FEL, Sec 10p T13N~ ~ZOE~ U.M. 5. Elevationinfe~(indicate KB, DF etc.) 6. heasedesignation andserialno. KB 52' Pad 17' ADL 47434 0il & 8a~ O0.,.s.C. ommi~io~ --, /~ch0mge 9. Unit or lease name Milne Point Unit 10. Well number C No. 15 11. Field and pool Kuparuk River 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi NW of Deadhorse miles 3263' at surf feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7764' MD 7400'TVD feet 2,560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 3200 feet. MAXIMUM HOLE ANGLE 25°~I (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed well C-13 86 feet 18. Approximate spud date 5/2:]_/85 3230 psig@ 80°F Surface 3800 psig@ 7/-,00 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole 12~' 8½"[ Casing 9 5/8 7I! Weight 48 36 26 22. Describe proposed pr~ra~--n~ CASING AND LINER Grade Coupling H-40 PELP K-55 BTRS L- 80 BTRS Length 80' 4643' 7732' SETTING DEPTH MD TOP TVD 35' [ 35' 33' I 33' 32' ~ 32' MD BOTTOM TVD 115' I 115' 4676' I 4600' 7764' I 7400' QUANTITY OF CEMENT (include stage data) ±100 cf Cmt ±2500 cf Cmt ±290 cf Cmt Conoco Inc. proposes drilling the subject well as an injection well in the Kuparuk River field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20", 2000 psi diverter will be installed on the 13 3/8" conductor for drilling surface hole. A 13 3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is C No. 13 which is 86' from C-15 at 3950' TVD. Arctic pack will be placed in the 7" X 9 5/8" annulus after disposing to test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. It will be flow tested after the rig is released. 23.1 hereby~ythattheforegoing~.is~.~e~ndcorrecttothebestN of my knowledge SIGNED ~ .O, tg,~~ ~-~_ TITLE Engineer The space below for Commission DATE Ma.y 14, 1985 Samples required ~YES [~NO Permit number APPROVED BY Form 10q01 5.1',, Mud Icg required I--lYES J~NO Approval date CONDITIONS OF APPROVAL Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May 17, 1 9R5 by order of the Commission Submit in triplicate Rev. 7-1-80 SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. C-15 Conoco Inc. 3201 "C" Street, Ste 200 Anchorage, Alaska 99503 CEMENTING PROGR~.{ RECEIVED MAY 1 "'19 8 5 'Alaska Oil & Gas Cons. Commission --, Anchorage The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. B, The 9-5/8" surface casing will be cemented with ±1100 sacks of Permafrost "E" cement followed by ±250 sacks of Class "G" cement. A top job will be done if cement is not cJ~rculated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±250 sacks of Class "G" cement pumped around the casing shoe (estimated ±1400' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type 'C' cement fo]lowed by 60± barrels of Arctic Pack pumped down the 7" x 9 5/8" annulus. ]1. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at ±1700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±6700' subsea TI~. III. FORb~TION EVALUATION A. Wireline logs for the 8~'~ hole ~from T.D. to ±1000'above the Kuparuk interval) will include: Dual Induction log; Spherically Focused log; Litho Density log; Compensated Neutron log - Gam~a Ray. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. V~ A low solids non-dispersed gel/water mud system will be used from 1000'-Surf. Csg. Pt. Low solids lightly dispersed mud system 4676'-T.D. DIRECTIONAL PROGRAM The C-15 well will be drilled to a proposed K0P of 3200', then build angle in a south 80.7° east direction. The closest that the C-15 will come to another wellbore is approximately 3950' TVD, where the proposed C-15 will be 86' from the existing C-13 well. An M~ too] is to be run while drilling for surveying purposes. Final hole angle will be 25°. The proposed depth is an estimate only. If actual depth exceeds tbe permit depth by over 300', a Sundry Notice will be submitted. 'Nas~ Oil & Gas Cons. Commission Anchorage N LAG OON · l~ ~ILES CO N OEO MILNE POINT UNIT EXISTING OEVELOPMENT NOTES: I. STATE PLANE CO-0RDINATES ARE ZONE 4. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LII':ES ARE COMPUTED BASED 01',l PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. . J LOCATION It~1 SECTION WeLL J FRO'~ S. LIN~ FRO~I E. UN__. IOGG' c-,El C-16 J C~iO' I , 'ZOO7' STATE PLANE C0-OROS. NORTHINGS J EAS TI."{ GS (~,oz9. '551. SZ j 555 ZSS. 7S G.ozg.z37. ZgJ 55-g zez.~ ozg,/z';eo j 55~.'~,.2.9 aZ G. oz 9. oo,S.74 ~. oz~ 694.4g 6. ozs.7$O.~l CERTIFICATE OF SURVEYOR : I HEREBf CERTIFY THAT I AM PROPERLY REGISTERED -'ND LICEtJSED TO PRACTICE L',I;;D SuRvEYING IN THE STATE OF ALASKA A'qD ·THAT [HIS PLAT RF__.PRES.r'NTS LOCATIOtl SURVEY' g-'DE BY ~,~1~ OR UNDER M~' SUPERVISION, A-';D THAT ALL · hlO OTHF_R E--TAIL~ ARE CORRECT. s~S 4oz. ~ GEODETIC; POSITION LATITUDE 7o%z9'. ?_~o:$93 u. LOJ',IG IT U D E J DATE CHEC~(ED FIELD BOOK II- !-84 .7.~. 24.&n 7o'-Zg:ZE.Tb7'~ J4e:~i-z4.49fwJ I1-1 -~4 J.u' 2d-54 JI -J- 11 I-$4 J. H, zz - b~ - i - 'C' PAD AS- BUILT wELL LOCATION ,r_-IO F' i -r- 1'5 ~-~ 'SF___¢T. Io COHOCO · SCALE : J SHF_.F.T = I' · 400' ~ 2 OF 2 COMMENTS : NORTH 250O 1100_ I000 _ 900 _ BO0 _ 700 _ 500 _ 500 _ 2400 2300 2200 I I I CONOCO. INC. : PAD C. WELL NOt 15 PROPOSED MILNE PT., NORTH SLOPE, ALASKA EASTMAN WHIPSTOCK. INC. NOTEt WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 2100 I 3??? 3960 2000 1 900 I I 229! 4137' 4223 4308 391 .1 800 I 2461 407'6 262t 2777, 1700 1600 I I 15( I PAD C. WELL NO: 15 PROPOSED MILNE PT., NORTH SLOPE, ALASKA EASTHAN gH[PSTOCK. [N~. · 0 _ .... 1 000 _ ........ 2000 5000_ SURFACE _ . KOP TVD=3200 THD=3200 DEP=O 5 -, ~cnorage- i !0 BUILD 2 1/2 DEO ~ PER I00 FT 4000 _ 20 - - ~~ mEOB TVD=41 67 THD=41 98 DEP=21 4 ~9 5/8" CSO PI 'rVD--4600 l' D=4676 DEP=415 $000 ~ I AVERAGE ANGLE 4 DEG $6 HI N · 6000 7000_,~ TARGET TVD=6970 THD=7290 DEP=1518 ~ 'T~-NTATIVE" TD TVD=7400 THD=7764 DEP=1718 8000 i 1 000 2000 VERTICAL SECTION HORIZONTAL PROJECTION ^LE 1 IN. = 1000 FEET CONOCO. INC. PAD C. WELL NOt 15 PROPOSED MI LNE PT.. NORTH SLOPE. ALASKA EASTHAN WHIPSTOCK. INC. z o 1000 1 000 2000 WEST-EAST 1000 0 1 000 I I 2000 I SURF~..~( "~'~~"TEN TAT I VE ' TD TARGET TVD=6970 TMD=7290 DEP=1518 SOUTH 245 EAST 14.98 SURFACE LOCAT[ON~ 725' FSL. 2098' FEL SEC. 10. T13N. RIOE -~-'TARGET LOCAT[ON~ 4.800' FNL, 600' FEL SEC. I0. TI3N. RIOE S 80 DEG 43 HI N E 1518' (TO TARGET) ~000 I Alaska Oil & 6as Cons, Oommission Anchorage CONOCO INC. MILNE POINT UNIT BOP STACK __ Fill-up Line~ ~ l r!v eUn ::r --~Flow Line-~' ~ (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE ~to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. 13 5/s"- 5000 --RAM 13 5/8" - 5000 2'~ - 5000 Side Outlets -3"- 5000 Side Outlets 3" - 5000 Side Outlets m~M 13 5/S" - 5000 11" - 5000 ._~ka 0il & Gas Cons. Commissior~ CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK ~ ~ Flow Line Fill-up Line ~ i~evn~!~rP mil HCR ~' I HCR ValveI · · ~ Valve - · ] Drilling i ,, ~ · 6" Relief Line~~ ,,,~'---~ ,?,,Sp°°l (; ~ 6 Relzef Valve x ' ~ ~ 2000 psi ~ ~ Diverter Quick ~ Connect Assembly 1. Relief lines~from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with AP1 specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 ALASKA UNITED RIG NO. 3 DRILLING CHOKE MANIFOLD' LIQUID MUD SYSTEM Active pits Solids removal function 4 each: 6"x 6"centrifugal pumps, 75 hp Reserve pits 16 each: Lightnin' mixers, 5 hp Working Pressure Choke (1) Type ' Choke (2) Type 10,000 psi w/ (2) Manual ( 1 ) Automat i c CAPACITIES ACTIVE SYSTEM I Sand trap 6 bbl I Degasser tank 56 bbl I Oesander suction 54 bbl I Desilter suction SS bbl I gesilter discharge 66 bbl SUBTOTAL Mud Tank No. I I Common 2 Suction Mud Tank No, 2 Receiving Discharge Mud Tank No, 3 SUBTOTAL ACTIVE SYSTEM TOTAL TRIP TANK SURFACE VOLUME GRAND TOTAL (Calculated 4*" below tank topi 237 bbl 38bbl 122 bbl 18,1 bbl 18't bbl 24.0 bbl 768 bbl 1005 bbl I SO bbl I 155 bbl (2) HCR valves ALASKA UNITED DRILLING RIG NO. 3 ,B U'I-TEI~FLY'. V~, LVE CLO~;£D DE:SANDER SUCTION CLOSED ~o~ Flow path ~'-~ . ]__,_] Solids removal ~ ~ DEGASSING FLOW PATH Flowline (in) 8, pass shaker screens Shaker discharge into sand trap (ditch to pit room closed) Sand trap overflow into degasser suction (desander suction closed) Degasser discharge into ditch Overflow returns to degasser suction (underflow butterfly closed) Switch desander suction out of degasser tank Desilter suction (Normal) Cleaned mud to treatment pit Underflow from treatment to suction pit Gravity-flooded suction CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~~ ITEM APPROVE DATE (1) Fee (7~-. ~-/~-~ (~ thru 8) (10 and 1~) / 12. (4) Casg (~l~thru3-~l~/~' ~(2~ thr~ 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 1. Is the permit fee attached .......,. : ...................... 2. Is well to be located in a defined po01 .... , .... .,_. 3. Is well-located proper distance from property.line ..''''' 4. Is well located proper distance from other wells ......... 5. Is sufficient undedicated acreage available in this pool . 6. Is well to be deviated and is-:wellbore plat included ..... 7. Is operator the only affected party , ..... 8. Can permit be approved before ten, day'~i~ YES NO REI~RKS Does operator have a bond in force ............................ Is a conservation order needed , ...................................... Is administrative approval needed ................... ~ ............... Is the lease number appropriate .,,~ ........... · ....................... ~,,~ .............. conductor string provided " IS eeeeeeeeee'eeee~e...~lelee~eeeee'eeeeee eee ee Is enough cement used to, circulate on conductor and surface .,, ..... Will cement'tie in-surfaceland intermediate or production strings ..~ - wilI cement cOver all kn°wn:ProductiVe, h°rizons .'..". .... ~.'...~i. : Will surface casing protect fresh water zones ...' ....... ' .... ~.~.' Will all casing .give adequate safety in collapse, tension and burst Is this well .to be kicked off.from an:existing wellbore.,~.~,,.~, .... Is old wellbore abandonment procedure-included.on-10-403 ....... .,...... A/~/~', ..... Is adeq. uate well.bore .separation. proposed ............... ,..' ..... ....~,., Is a diVerter system :required ............. - ...... Are necessary~ diagrams of diverter and BOP equipment Does BOPE have 'Sufficient preSsUre rating - Test to ~,~.. ps~g Does the choke manifold comply w/API RP-53 (Feb.78). Is the presence of H2S gas Probable ........... ~, .................... Additional requirement ............................ ~' .~"-~../. ........ Additional Remarks ~)~ C'/~ ~[/Z ~ /~/~~ ~0 Geology:/EngiD~erin~: . JAL ~ ~- rev: 03/13/85 6.011 INITIAL GEO. ' ..... UNIT .... ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' .. No special'effort has been made to chronologically organize this category of information. LVP OIO.HOZ VER!Fi~AT.I. uN LISTING PAGE I ** REEL HE~D~ER ~- S~RV£Ck NAME : ;~-g iT gATE :85/06/ 6 gRiGiN : REEL NAME : CO~T~NjATiDN ~ PREV IO~S R~EL : COMMENTS : ~ ~.E ~.~..S I 0 ~ .~ ........ . .... 'DA"TE".' :: ' ' ". ":'"~'"'...."...::" "'" "" '''':~ .." '.. ':' :::." i': ':'":.' '." '". '." ..'.' · ":.'" "." ""'.." .." '. '.' .":;'".' '~'.'~..".:' '"" ' ':. '.'".":.::.':' :".'.'.'... ':.. "'. '.".' ::..".:.r"':'..i' "."." i. '2::!.' '" ..'. 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